20120731Complaint and Petition.PDF

DONOVAN E. WALKER (ISB No. 5921)
JASON B. WILLIAMS (ISB No. 8718)
Idaho Power Company
1221 West Idaho Street (83702)
P.O. Box 70
Boise, Idaho 83703
Telephone: [phone]
Facsimile: [phone]
[e-mail]
[e-mail]
Attorneys for Idaho Power Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE COMPLAINT )
AND PETITION OF IDAHO POWER )
COMPANY FOR A DECLARATORY )
ORDER REGARDING THE FIRM ENERGY )
SALES AGREEMENT AND GENERATOR )
INTERCONNECTION AGREEMENT WITH )
NOTCH BUTTE WIND PARK, LLC. )
------------------------------)
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY'S
COMPLAINT AND PETITION FOR
DECLARATORY ORDER
COMES NOW the Petitioner/Complainant, Idaho Power Company ("Idaho
Power"), by and through its attorneys, Donovan Walker and Jason Williams, and
pursuant to this Commission's Rules of Procedure, including but not limited to RP 54
and RP 101, hereby files this Complaint and Petition for Declaratory Order.
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER-1
RECEIVED
2012 July 31 aM 8:18
IDAHO PUBLIC
UTILITIES COMMISSION
Communications regarding this Complaint and Petition for Declaratory Order
should be sent to:
Donovan Walker
Jason Williams
Idaho Power Company
1221 West Idaho Street (83702)
P.O. Box 70
Boise, Idaho 83703
Telephone: [phone]
Facsimile: [phone]
[e-mail]
[e-mail]
SUMMARY OF THE CASE
1 . This is a dispute between Idaho Power and Notch Butte Wind Park, LLC
(UNotch Butte"), a special purpose entity, that is intended to own and control a wind
generation project to be developed by Exergy Development Group of Idaho, LLC
(UExergy"), a sophisticated developer with extensive knowledge and experience with
such projects.1 In October of 2005 Idaho Power and the special purpose entity entered
into a Firm Energy Sales Agreement (UFESA") pursuant to the Public Utility Regulatory
Policies Act of 1978 (UPURPA"), which provides that the special purpose entity will
design, construct, own, maintain and operate an electric wind generation facility and
that Idaho Power will buy firm electric energy produced by the facility. Attachment 1.
2. The FESA requires, among other things, that the special purpose entity
meet certain construction deadlines, such as placing the project in service by the
Scheduled Operation Date of May 1, 2007. This Scheduled Operation Date was
subsequently amended in 2008 to September 1, 2010. Attachment 2. Exergy did not
1 See, IPUC Case Nos. IPC-E-05-06, IPC-E-05-07, IPC-E-05-09, IPC-E-05-17, IPC-E-05-18, IPC­
E-05-30, IPC-E-05-31, IPC-E-05-32, IPC-E-05-33, IPC-E-09-18, IPC-E-09-19, IPC-E-09-20, all of which
are large wind OF developments on Idaho Power's system by Exergy Development.
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER - 2
achieve the Scheduled Operation Date of September 1, 2010, did not achieve the
Operation Date by July 1, 2011, and defaulted under the FESA at that time. See,
Attachment 3. Exergy has failed to diligently pursue a cure of Notch Butte's default
within a commercially reasonable time, as required by the FESA, and Idaho Power is
entitled to terminate the FESA. Exergy and the special purpose entity now asserts that
alleged "delays" by Idaho Power excuse Exergy's obligation to meet its Scheduled
Operation Date, and to cure its default in a commercially reasonable time and manner.
Idaho Power disagrees that any action excuses Exergy or the special purpose entity
from meeting its construction deadlines, and maintains that Exergy has not diligently
pursued a cure in a commercially reasonable time period. By failing to move forward
with its generator interconnection, and now being removed from the generator
interconnection queue for a second time, Notch Butte can no longer maintain a claim
that it is diligently pursing a cure in a commercially reasonable manner or time.
3. The FESA provides a clear remedy for a party's failure to cure a default,
and that is termination of the FESA. With this Complaint and Petition, Idaho Power is
requesting the Idaho Public Utilities Commission ("Commission") to issue an order
declaring that Idaho Power is authorized to apply such remedy against Exergy and the
special purpose entity. More specifically, Idaho Power asks the Commission to make
findings and enter a declaratory order that: (1) the Commission has jurisdiction over the
interpretation and enforcement of the FESA and the GIA; (2) Exergy's claim of force
majeure does not exist so as to excuse Notch Butte's failure to meet the amended
Scheduled Operation Date, the Operation Date, and failure to cure its default; (3) Notch
Butte failed to place its project in service by the amended Scheduled Operation Date of
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER - 3
September 1, 2010, has failed to achieve the Operation Date by July 1, 2011, (which is
within 10 months of the amended Scheduled Operation Date), and has received Notice
of its default, as of July 26, 2011; and (4) Notch Butte did not cure its default of the
FESA within 60 days of receiving Notice of Default, and has not diligently pursued a
cure of said default within a commercially reasonable time, and that Idaho Power may
terminate the FESA.
FACTUAL ALLEGATIONS
4. Idaho Power is an Idaho public utility subject to the jurisdiction of the
Commission.
5. Notch Butte Wind Park, LLC, is an Idaho limited liability company.
6. On October 14, 2005, Idaho Power and Notch Butte entered into a FESA
for a 20-year term using the then-current non-Ievelized published avoided cost rates as
established by the Commission for energy deliveries of less than 10 aMW. A true and
correct copy of the FESA, dated October 14, 2005, between Idaho Power and Notch
Butte is attached hereto as Attachment 1 and incorporated herein by reference. Notch
Butte selected November 1, 2006, as the Scheduled First Energy Date, and May 1,
2007, as the Scheduled Operation Date. Attachment 1) at Appx. B.
7. On October 20, 2005, Idaho Power filed an Application with the
Commission in Case No. IPC-E-05-32 requesting approval of the 20-year FESA
between Idaho Power and Notch Butte.
8. On December 5, 2005, Exergy submitted the initial Small Generator
Interconnection Request for the Notch Butte wind generating project. A true and correct
copy of the initial Small Generator Interconnection Request for Notch Butte is attached
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER - 4
hereto as Attachment 4 and incorporated herein by reference. Idaho Power initially
assigned a Generator Interconnection Queue Number ("GI #") to Notch Butte of #158.
After Exergy's failure to proceed with GI #158, Notch Butte was subsequently assigned
GI #349 and #359 for subsequent applications and requested configurations of the
project's interconnection. See, Attachment 5 and Attachment 6 which were assigned GI
#349 and #359 respectively.
9. On December 22, 2005, Idaho Power sent to Exergy a Notice of
Incomplete Interconnection Application for five of Exergy's proposed wind project
interconnections: Golden Valley Wind Park, Milner Dam Wind Park, Lava Beds Wind
Park, Notch Butte Wind Park, and Salmon Falls Wind Park. A true and correct copy of
the December 22, 2005, Notice of Incomplete Interconnection Application is attached
hereto as Attachment 7 and incorporated herein by reference. This Notice informs
Exergy of nine items that either needed to be clarified or provided by Exergy in order to
proceed with the interconnection requests. Additionally this Notice informs that the
items must be provided prior to the scoping meeting in order for the projects to retain
their positions in the queue. This Notice also provided a standard Interconnection
Feasibility Study Agreement for Exergy's review and execution.
10. On July 7, 2006, Idaho Power sent to Exergy a letter informing Exergy of
the incomplete status of the Notch Butte interconnection request. A true and correct
copy of the July 7, 2006, letter with attachments is attached hereto as Attachment 8 and
incorporated herein by reference. This letter states, "Since our initial Scoping Meeting,
we have NOT received your designated Point of Interconnection (POI) for this project."
The letter again forwards a draft Feasibility Study Agreement for Exergy's execution and
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER - 5
return. The letter also advises, "We must receive your response no later than 30
Calendar [sic] after your receipt of this letter, or we will consider your request to have
been withdrawn and terminated."
11. Over the next several years, from approximately January 2007 through
approximately January 2011, numerous Feasibility Study Reports were conducted for
the Notch Butte project's requested interconnection at different requested nameplate
capacities, interconnection voltages, locations, interconnection configurations, etc.
12. Attached hereto as Attachment 9 and incorporated herein by this
reference is a true and correct copy of the January 3, 2007, Final Interconnection
Feasibility Study Report for Notch Butte's interconnection. This report was for Exergy's
requested configuration of GI #158 located south of Shoshone, for 19.92 MW at a 34.5
kV connection, with estimated interconnection cost of $2,114,000.
13. On January 24, 2007, Idaho Power sent a letter with an attached draft
Facility Study Agreement for the study of potentially necessary Network Upgrades on
the main grid transmission system. A true and correct copy of the January 24, 2007,
letter is attached hereto as Attachment 10 and incorporated herein by reference. This
letter explains, among other things, that these potential transmission related upgrades
are separate from the project's required interconnection facilities.
14. Attached hereto as Attachment 11 and incorporated herein by this
reference is a true and correct copy of the February 11, 2007, System Impact Study
Agreement for GI #158 signed by James Carkulis.
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER - 6
15. Attached hereto as Attachment 12 and incorporated herein by this
reference is a true and correct copy of the February 24, 2007 Facility Study Agreement
for GI #158 signed by James Carkulis and Idaho Power.
16. Attached here as Attachment 13 and incorporated herein by this reference
is a true and correct copy of the June 22, 2007 letter from Idaho Power to Exergy
forwarding a Interconnection Facility Study Agreement for GI #158. This letter advises
that payment must be received by July 22, 2007, or the application will be deemed
withdrawn.
17. On July 1, 2008, Idaho Power and Exergy executed an amendment to the
FESA that extended the Scheduled Operation Date from May 1, 2007, to September 1,
2010, for Notch Butte. On July 23, 2008, this amendment regarding the Scheduled
Operation Date was filed with the Commission. A true and correct copy of the
amendment between Idaho Power and Notch Butte is attached hereto as Attachment 2
and incorporated herein by reference.
18. Attached hereto as Attachment 14 and incorporated herein by this
reference is a true and correct copy of a July 15, 2008, Interconnection Facilities Study
Agreement, signed by James Carkulis for Exergy.
19. Attached hereto as Attachment 15 and incorporated herein by this
reference is a true and correct copy of the September 2, 2008, Feasibility Study
Agreement RESTUDY signed by Exergy and Idaho Power for GI #158.
20. Attached hereto as Attachment 16 and incorporated herein by this
reference is a true and correct copy of the October 21, 2008, Final Interconnection
Feasibility Study Report for Notch Butte's interconnection. This report was for Exergy's
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER - 7
requested configuration of GI #158 located near Idaho Power's Dietrich substation, for
10.5 MW at a 12.5 kV connection, with estimated interconnection cost of $3,675,000.
21. Attached hereto as Attachment 17 and incorporated herein by this
reference is a true and correct copy of a October 23, 2008, letter from Idaho Power to
Exergy forwarding the October 21, 2008 Final Feasibility Study Report, as well as two
copies of the Facility Study Agreement. The letter advised:
In order to proceed with this application, Idaho Power must
receive your agreement to proceed with the project by
executing both copies of the FSA [Facility Study Agreement]
and submitting completed Attachments, along with the
required deposit in order to remain in the Generator
Interconnection queue. The deposit under this FSA is
$30,000 based on the estimated engineering costs. If you
wish to proceed, please sign both copies and submit them
with the completed Attachment, along with the deposit ... by
November 25, 2008, otherwise your application will be
deemed withdrawn.
22. Attached hereto as Attachment 18 and incorporated herein by this
reference is a true and correct copy of the December 9, 2008, Revised Feasibility Study
Agreement for GI #158, executed by Idaho Power and Exergy, requesting to study a
different configuration for Notch Butte's interconnection.
23. Attached hereto as Attachment 19 and incorporated herein by this
reference is a true and correct copy of the January 22, 2009, Final Interconnection
Feasibility Study Report for Notch Butte's interconnection. This report was for Exergy's
requested configuration of GI #158 located near Idaho Power's Dietrich substation, for
18 MW at a 138 kV connection, with a substation to transform to 34.5 kV, with estimated
interconnection cost of $4,328,000.
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER - 8
24. Attached hereto as Attachment 20 and incorporated herein by this
reference is a true and correct copy of a March 11, 2009, Feasibility Study Agreement
for GI #158, executed by Idaho Power and Exergy, requesting to study a different
configuration for Notch Butte's interconnection.
25. Attached hereto as Attachment 21 and incorporated herein by this
reference is a true and correct copy of the April 16, 2009, Final Interconnection
Feasibility Study Report for Notch Butte's interconnection. This report was for Exergy's
requested configuration of GI #158 located near Idaho Power's Dietrich substation, for 9
MW at a 12.5 kV connection, with estimated interconnection cost of $3,500,000.
26. Attached hereto as Attachment 22 and incorporated herein by this
reference is a true and correct copy of a May 14, 2009, letter from Idaho Power to
Exergy forwarding the April 16, 2009, Final Feasibility Study Report, as well as two
copies of the Facility Study Agreement. The letter advised:
The next step in the Generator Interconnection process is to
begin design work with the Interconnection/Distribution
facilities of this project. Please submit your agreement to
proceed by executing both copies of the attached FSA
[Facility Study Agreement], submitting completed
Attachments to the FSA, along with the required FSA deposit
to Idaho Power Company ... by June 16, 2009, otherwise
your application will be deemed withdrawn. The deposit
under the FSA is $30,000 based on the estimated
engineering costs.
27. Attached hereto as Attachment 23 and incorporated herein by this
reference is a true and correct copy of a July 13, 2009, Facilities Study Agreement for
GI #158, executed by Idaho Power and Exergy.
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER - 9
28. Attached hereto as Attachment 24 and incorporated herein by this
reference is a true and correct copy of an April 27, 2010, Draft Interconnection Facility
Study Report for Notch Butte's interconnection, GI #158.
29. Attached hereto as Attachment 25 and incorporated herein by this
reference is a true and correct copy of a May 12, 2010, communication evidencing
Exergy's failure to pay required funds, and removal of GI #158 from the generator
interconnection queue.
30. Attached hereto as Attachment 5 and incorporated herein by this
reference is a true and correct copy of the August 16, 2010, Small Generator
Interconnection Request by Exergy for the Notch Butte project requesting the
interconnection of 6.5 MW. This request was assigned GI #349.
31. Attached hereto as Attachment 26 and incorporated herein by this
reference is a true and correct copy of an August 27, 2010, Interconnection Feasibility
Study Agreement for GI #349, executed by Idaho Power and Exergy.
32. Attached hereto as Attachment 27 and incorporated herein by this
reference is a true and correct copy of the October 15, 2010, Final Interconnection
Feasibility Study Report for Notch Butte's interconnection. This report was for Exergy's
requested configuration of GI #349 located near Idaho Power's Dietrich substation, for
6.5 MW at a 12.5 kV connection, with estimated interconnection cost of $3,700,000.
33. Attached hereto as Attachment 6 and incorporated herein by this
reference is a true and correct copy of the October 28, 2010, Small Generator
Interconnection Request by Exergy for the Notch Butte project requesting the
interconnection of 11.5 MW. This request was assigned GI #359.
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -10
34. Attached hereto as Attachment 28 and incorporated herein by this
reference is a true and correct copy of a November 29, 2010, Interconnection Feasibility
Study Agreement for GI #359, executed by Idaho Power and Exergy.
35. Attached hereto as Attachment 29 and incorporated herein by this
reference is a true and correct copy of a December 10, 2010, Interconnection Facility
Study Agreement for GI #349, executed by Idaho Power and Exergy.
36. Attached hereto as Attachment 30 and incorporated herein by this
reference is a true and correct copy of the January 12, 2011, Final Interconnection
Feasibility Study Report for Notch Butte's interconnection. This report was for Exergy's
requested configuration of GI #359 located near Idaho Power's Dietrich substation, for
11.5 MW at a 12.5 kV connection, with estimated interconnection cost of $14,220,000.
37. On January 28, 2011, counsel for Exergy sent a letter to Idaho Power
alleging that Exergy "has received interconnection studies with inconsistent engineering
configurations and seemingly high cost projections" and claiming that "Exergy has been
delayed in its ability to enter into an acceptable interconnection agreement, and is now
concerned that further delay will impede its ability [sic] bring the project online in a
timely manner." A true and correct copy of the January 28, 2011, letter from Mr.
Richardson, counsel for Exergy, to Idaho Power is attached hereto as Attachment 31
and incorporated herein by reference.
38. Attached hereto as Attachment 32 and incorporated herein by this
reference is a true and correct copy of a February 17, 2011, Draft Interconnection
Facility Study Report for Notch Butte's interconnection, GI #349.
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -11
39. Attached hereto as Attachment 33 and incorporated herein by this
reference is a true and correct copy of a March 4, 2011, Transmission Service Request
System Impact Study Report for the Notch Butte project, GI #349 and #359. The
Transmission Service Request System Impact Study Report was for 18 MW with Point
of Receipt (POR) of Mid-Snake and the Point of Delivery (POR) of Idaho Power (IPCo).
The transmission service request is OASIS Ref. Number 74993330. The Report
summarizes, "From the analysis on the West of Midpoint and Boise East transmission
paths, both transmission paths have sufficient available transmission capacity to
accommodate the 18 MW of Network Transmission Service Request for the Notch Butte
Wind Projects."
40. On March 14, 2011, Idaho Power responded to Mr. Richardson's January
28, 2011, letter. A true and correct copy of the March 14, 2011 letter from Idaho Power
to Mr. Richardson is attached hereto as Attachment 34 and incorporated herein by
reference. With that letter, Idaho Power takes exception to the allegation that it was
Idaho Power that had in any way delayed Exergy in bringing its project online. The
letter states,
Idaho Power Company ("Idaho Power") takes exception to
your inference that the failure of Exergy to bring its project
on-line in a timely manner is attributable to Idaho Power. It
was Exergy's choice to move forward with obligating itself to
perform, pursuant to the Agreement that it signed, prior to
such time that it had sufficient knowledge, information,
and/or assurance regarding what would be required for the
interconnection of such project, what it is estimated to cost,
and how long interconnection facilities and potential
transmission upgrades may take to construct.
Exergy has requested numerous feasibility studies with
varying locations, interconnection voltages, and project
capacities for the generation interconnection project Nos.
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -12
159, 349, and 359, all of which Exergy has referred to as
their Notch Butte project. For these various projects, the
following feasibility studies have been completed:
January 3, 2007 ... October 21, 2008 ... January 22, 2009
... April 16, 2009 ... October 11, 2010 ... January 12, 2011
. .. The varying interconnection costs found in these studies
have been the result of Exergy's requests to study various
project sizes in terms of requested generation capacity,
various project locations, and various interconnection
voltages.
The letter further explains that because some of the facilities would be for the sole
purpose of Exergy's project, i.e., not used to provide service to any other customers,
that Exergy would be solely responsible for their construction. The letter also
references that Notch Butte lost its interconnection queue position (GI #158) because it
had failed to make the required payment in order to remain, "and was removed as
required of Idaho Power in its non-discriminatory administration of the interconnection
queue process." Attachment 34 at 2.
41. Subsequent to the exchange of the above referenced letters, the parties
met on April 11, 2011, to discuss Exergy's wishes regarding how it wanted to proceed
with the interconnection of the Notch Butte project. Exergy followed this meeting with a
written request to proceed with the study of a reconfigured interconnection. A true and
correct copy of the April 12, 2011, letter from Exergy to Idaho Power is attached hereto
as Attachment 35 and incorporated herein by reference. With this letter, Exergy
confirmed that it wished to move forward under GI #359 to study its requested
reconfiguration: "In response to the Draft Feasibility Study completed January 12, 2011
which studied interconnection of 18 MW for both Nos. 349 and 359, please study the
following reconfiguration we discussed." With regard to GI #349, Exergy requested that
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -13
be placed on hold pending the study results from GI #359: "In response to the Draft
Facility Study sent to us February 17, 2011, please hold this project without removing it
from the queue while the additional study in conjunction with No. 359 is performed ... "
Id.
42. Attached hereto as Attachment 36 and incorporated herein by this
reference is a true and correct copy of a May 3, 2011, Draft Interconnection Facility
Study Report for Notch Butte's interconnection, GI #349.
43. Attached hereto as Attachment 37 and incorporated herein by this
reference is a true and correct copy of a May 11, 2011, letter from Idaho Power to
Exergy following up on an April 27, 2011 communication regarding the restudy for Notch
Butte's interconnection GI #359. The letter forwards two copies of a Feasibility Study
Agreement, and advised, "In order to proceed, and for your application to remain in the
Generator Interconnection study queue, Idaho Power must receive the signed Fe SA
[Feasibility Study Agreement] and the deposit by June 2, 2011 , otherwise your
application will be deemed withdrawn. The deposit under this FeSA is $1,000."
(emphasis in original).
44. Attached hereto as Attachment 38 and incorporated herein by this
reference is a true and correct copy of a May 17, 2011, Interconnection Feasibility Study
Agreement for GI #359, executed by Idaho Power and Exergy.
45. Attached hereto as Attachment 39 and incorporated herein by this
reference is a true and correct copy of the June 29, 2011, Final Interconnection
Feasibility Study Report for Notch Butte's interconnection. This report was for Exergy's
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -14
requested configuration of GI #359 located near Idaho Power's Dietrich substation, for
11.5 MW at a 12.5 kV connection, with estimated interconnection cost of $7,978,000.
46. On June 30, 2011, counsel for Exergy, Mr. Richardson, sent a letter to
Idaho Power regarding Exergy's progress in meeting the Operation Date from the
FESA. A true and correct copy of Mr. Richardson's June 30, 2011, letter is attached
hereto as Attachment 40 and incorporated herein by reference. In this letter Exergy
acknowledged the provisions of the FESA requiring the project to become operational
within 10 months of its Scheduled Operation Date. The letter confirms this date to be
July 1, 2011 .
47. On July 26, 2011, Idaho Power sent Notch Butte Notice of Default of the
FESA. A true and correct copy of the July 26, 2011, Notice of Default is attached hereto
as Attachment 3 and incorporated herein by reference.
48. On August 5,2011, Notch Butte, by letter from counsel for Exergy to Idaho
Power, responded to the Notice of Default with a Request to Extend Cure Period. A
true and correct copy of the August 5, 2011, Request to Extend Cure Period is attached
hereto as Attachment 41 and incorporated herein by reference.
49. Attached hereto as Attachment 42 and incorporated herein by this
reference is a true and correct copy of the August 18, 2011, Interconnection Facility
Study Agreement for GI #359, executed by Idaho Power and Exergy.
50. On August 26, 2011, Idaho Power sent a letter to Exergy acknowledging
receipt of signed Facility Study Agreement, with required deposit for GI #359 (11.5
MW). A true and correct copy of the August 26, 2011, letter is attached hereto as
Attachment 43 and incorporated herein by reference.
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -15
51. On September 1, 2011, counsel for Exergy delivered a letter to Idaho
Power purporting to update Idaho Power that, "progress is being made to achieve
commercial operations within a reasonable time of the deadline contained in the power
purchase agreements." A true and correct copy of the September 1, 2011, letter from
counsel for Exergy to Idaho Power is attached hereto as Attachment 44 and
incorporated herein by reference.
52. November 18, 2011, a Revised Final Feasibility Study Report for GI #359
was issued by Idaho, and sent electronically to Exergy, with formal correspondence on
November 23, 2011 . A true and correct copy of the November 18, 2011, Revised Final
Feasibility Study Report for GI #359, along with November 18 e-mail and November 23,
2011, cover letter is attached hereto as Attachment 45 and incorporated herein by
reference. The November 23 letter forwards two copies of a Facility Study Agreement,
and advised, "Since no SYSTEM IMPACT STUDY is needed, enclosed is a Facility
Study Agreement (FSA) for the next phase of the project. In order to proceed,-and for
your application to remain in the Generator Interconnection study queue, Idaho Power
must receive the 2 copies of the signed FSA, the completed Attachments, and the
deposit by January 9, 2012, otherwise your application will be deemed withdrawn. The
deposit under this FSA is $30,000 based on the estimated engineering costs."
(Emphasis in original.)
53. Attached hereto as Attachment 46 and incorporated herein by this
reference is a true and correct copy of the January 9, 2012, Interconnection Facility
Study Agreement for GI #359, executed by Idaho Power and Exergy.
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -16
54. On March 6, 2012, Idaho Power issued the Draft Facility Study Report for
GI #349 and #359, which begins a comment period for Exergy extending to April 6,
2012. A true and correct copy of the March 6, 2012, Draft Facility Study Report, with
cover letter, is attached hereto as Attachment 47 and incorporated herein by reference.
55. During the comment period on the Draft Facility Study Report issued on
March 6, 2012, Idaho Power and Exergy had a series of communications. Attached
hereto as Attachment 48 is a true and correct copy of an e-mail string of
communications between Idaho Power and Exergy from March 6,2012, through April 9,
2012. In these communications, Exergy requests to include an interconnection option
for a limited output interconnection to be completed by the end of 2012.
56. On April 9, 2012, Idaho Power issued the Final Facility Study Report to
Exergy for GI #349 and #359. A true and correct copy of the April 9, 2012, Final Facility
Study Report, with cover letter, is attached hereto as Attachment 49 and incorporated
herein by reference. The April 9, 2012, letter notifies Exergy:
The estimated interconnection cost for this project is
$7,875,000 requiring approximately 34 months to complete
the design, procurement, permitting, construction, and
commissioning of these facilities. This includes the
permitting of the transmission line across BLM land which is
typically a 20-30 month process, with no guaranteed
outcome.
The response to your request to interconnect with limited
generation output and a shorter timeline is addressed in
Appendix B. Idaho Power accommodated this irregular
request. Please see Appendix B for the additional work ($)
and stipulations required of the Interconnection Customer to
execute this scenario. The funding necessary to execute
this project, including the work stipulated for the limited
generation output, is $7,950,000. If the Generation
Interconnect Agreement (GIA) is signed and funding
received by May 1, 2012, then the interconnection facilities
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -17
will be ready for up to 4.0 MW of generation by December
31,2012.
57. On April 20, 2012, Idaho Power sent a Draft Generator Interconnection
Agreement ("GIA") to Exergy. A true and correct copy of the April 20, 2012, Draft GIA,
with transmittal letter, is attached hereto as Attachment 50 and incorporated herein by
reference. This communication reiterates to Exergy that its response and authorization
to move forward, including payment of the estimated construction costs deposit, is
required by May 1, 2012, in order to construct the limited output facilities by the end of
2012, and additionally that its response and payment is required by May 21, 2012, or
the interconnection request will be deemed withdrawn.
58. On April 27, 2012, Idaho Power re-sends the Draft Generator
Interconnection Agreement, and again reminds that a response and payment is required
by May 1, 2012, in order to be able to meet a December 2012 online date. A true and
correct copy of the communication is attached hereto as Attachment 51 and
incorporated herein by reference.
59. On April 30, 2012, Exergy responds with a communication that, rather
than executing the GIA and paying the required funding to proceed forward with the
interconnection which included the limited output option online by year-end 2012, it
wished to change the configuration. A true and correct copy of the April 30,
communication from Exergy is attached hereto as Attachment 52 and incorporated
herein by reference. It states, "Before we continue forward to execute and fund the
GIA, we need to inform IPeo of a configuration change for the Notch Butte Project. We
will be moving the POI [point of interconnection] from the project site to the Dietrich
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -18
substation and providing 34.5kV at that point. Please let us know what steps need to be
taken for this modification to be in place."
60. On May 23,2012, Idaho Power sent a letter and new draft of the Final GIA
to Exergy. A true and correct copy of May 23, 2012, communication and GIA is
attached hereto as Attachment 53 and incorporated herein by reference. This letter
responds to Exergy's April 30, 2012, request to once again change the interconnection
configuration rather than move forward with the studied configuration. Because the
former May 1, 2012, deadline for commencing construction of the limited output facilities
required for year-end operation had passed, and the May 21, 2012, deadline for moving
forward with the previously communicated GIA had also now passed, Idaho Power
removed the limited output option, and forwarded to Exergy a revised Final GIA for
execution. The deadline for execution and payment required for Exergy to move
forward with the studied configuration was communicated as June 23, 2012.
61. On June 20, 2012, Exergy responded by letter to Idaho Power, and rather
than signing the GIA and paying the required funding, yet again requests another
different configuration for its interconnection at 138 kV. A true and correct copy of the
June 20, 2012, communication from Exergy is attached hereto as Attachment 54 and
incorporated herein by reference. This letter also requests, again, that limited output
facilities to be put in place by December 15, 2012.
62. On June 26, 2012, Idaho Power responds to Exergy's June 20, 2012,
letter and requests, and forwarded a revised Final GIA which, once again, included a
limited output by year-end option. A true and correct copy of the June 26, 2012,
communication and Final GIA is attached hereto as Attachment 55 and incorporated
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -19
herein by reference. This letter reviews the past requests and deadlines, responds to
the inaccurate factual representations in Exergy's June 20, 2012 letter, and again
explains that the request for interconnection at a new voltage and a new configuration
(138 kV from the project site to Idaho Power's existing 138 kV) would require a new
facility study. The letter, once again, accommodates Exergy's request to bring the
facilities online by the end of the year, and sends a new Final GIA reincorporating the
limited output by year-end option. Because Exergy's deadline for executing the GIA
and funding the construction had once again passed, Idaho Power extended the time
for execution of the GIA and payment of the required funds to July 9,2012.
63. On July 2, 2012, Exergy delivery to Idaho Power a Notice of Force
Majeure for both the Notch Butte and Lava Beds Wind Park projects. A true and correct
copy of the July 2, 2012, Notice of Force Majeure from Exergy is attached hereto as
Attachment 56 and incorporated herein by reference. In its Notice of Force Majeure,
Notch Butte contends, among other things, that Idaho Power's estimated date for
construction of interconnection facilities associated with the Jack Ranch projects is a
Force Majeure event because the date makes it impossible for the Jack Ranch projects
to meet their respective Scheduled Operation Date of June 30, 2012, and because of
the "combined financing" of the projects, this also constitutes Force Majeure for Notch
Butte and Lava Beds. The Notice of Force Majeure for Notch Butte and Lava Beds
attaches the similar Notice of Force Majeure for the Jack Ranch projects that was sent
to Idaho Power June 28, 2012.
64. On July 10, 2012, Idaho Power received a July 9,2012, letter from Exergy
that included with it a copy of the June 26, 2012 final GIA that was signed by James
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -20
Carkulis on behalf of Exergy, but with no payment. Instead, Exergy's cover letter
stated:
Exergy has received and executed the final Generator
Interconnection Agreement (GIA) prepared by Idaho Power
and dated June 26, 2012. Exergy is pleased to submit the
enclosed and executed GIA and will submit the funds
described in the enclosed GIA at such time as Idaho
Power countersigns and returns a copy of the document
to our office.
(emphasis added). A true and correct copy of the July 9, 2012, letter from Exergy is
attached hereto as Attachment 57 and incorporated herein by reference.
65. On July 11, 2012, Idaho Power sent a letter responding to Exergy's July 9,
2012, letter and also forwarded back to Exergy the June 26,2012, GIA which was now
signed by both Idaho Power and by Exergy. A true and correct copy of the July 11,
2012, letter from Idaho Power to Exergy, as well as a copy of the executed GIA is
attached hereto as Attachment 58 and incorporated herein by reference. This letter
states, "As you indicated in your letter, because Idaho Power has now returned the
countersigned GIA, Idaho Power expects the required funding to be paid immediately.
Idaho Power needs the required funding from Exergy in order to proceed." This letter
also notifies Exergy that, "Idaho Power will exercise its rights to terminate this GIA and
to remove the project from the generator interconnection queue if the required payment
is not received by close of business, 5:00 p.m. Mountain Time, on Friday July 13, 2012."
66. On July 13, 2012, Exergy responded to Idaho Power by sending two
letters. A true and correct copy of both of Exergy's July 13, 2012, letters to Idaho Power
are attached hereto as Attachment 59 and incorporated herein by reference. Rather
than paying the required funds, as Exergy said it would both in its July 9, 2012, letter,
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -21
and by its execution of the GIA requiring the same, Exergy instead sent the letter dated
July 13, 2012, whereby it claimed that it was under the impression that the GIA it had
signed just four days earlier provided for a different interconnection configuration and
voltage (138 kV) rather than the configuration and voltage that was studied through the
final Facility Study stage including the limited output by year end option (12.5 kV).
Exergy's letter insists upon a revised GIA at a different voltage level (138 kV), which
was previously communicated to Exergy as, at a minimum, requiring a new facility study
process to be conducted.
67. On July 30, 2012, Idaho Power sent at letter to Exergy terminating the
executed GIA, removing the Notch Butte project from the generator interconnection
queue, and notifying Exergy of this filing with the Commission. A true and correct copy
of the July 30, 2012, letter from Idaho Power to Exergy is attached hereto as
Attachment 60 and incorporated herein by reference. This letter also reviews the chain
of events going back through Exergy's March 2012 request to include an option for
limited output that could be brought online by the end of 2012.
JURISDICTION
A. The Commission Has Jurisdiction Over Interpretation and Enforcement of
the FESA and the GIA.
68. The Commission has authority to issue declaratory orders pursuant to the
Idaho Uniform Declaratory Judgments Act. Utah Power & Light Co. v. Idaho Pub. Uti/so
Comm'n, 112 Idaho 10, 12, 730 P.2d 930, 932 (1987). The Idaho Uniform Declaratory
Judgments Act provides for the issuance of a declaratory judgment in a contract dispute
"before or after there has been a breach." Harris v. Cassia County, 106 Idaho 513,516-
517,681 P.2d 988, 991 (1984).
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -22
69. The Commission has jurisdiction over the interpretation of contracts where
the parties have agreed to submit a dispute involving contract interpretation to the
Commission. Afton Energy. Inc. v. Idaho Power Co., 111 Idaho 925, 929, 729 P.2d
400,404 (1986) 929,729 P.2d at 404 (citing Bunker Hill Co. v. Wash. Water Power Co.,
98 Idaho 249, 252,561 P.2d 391,394 (1977)).
1. The Commission Has Jurisdiction Over Interpretation and
Enforcement of the FESA.
70. Paragraph 7.5 of the FESA between Idaho Power and Notch Butte
provides for the continuing jurisdiction of the Commission over the Agreement:
Continuing Jurisdiction of the Commission. This Agreement is a
special contract and, as such, the rates, terms and conditions
contained in this Agreement will be construed in accordance with
Idaho Power Company v. Idaho Public Utilities Commission and
Afton Energy. Inc., 107 Idaho 781, 693 P.2d 427 (1984), Idaho
Power Company v. Idaho Public Utilities Commission, 107 Idaho
1122, 695 P.2d 1 261 (1985), Afton Energy. Inc. v. Idaho Power
Company, 111 Idaho 925, 729 P.2d 400 (1986), Section 210 of the
Public Utility Regulatory Policies Act of 1978 and 18 CFR
§292.303-308.
Attachment 1 at p.11.
71. Idaho Power and Notch Butte have also agreed to the Commission's
jurisdiction regarding any and all disputes under the FESAs. Paragraph 22.1 of the
FESAs further provides that all disputes relating to the Agreement will be submitted to
the Commission:
Disputes -All disputes related to or arising under this Agreement,
including, but not limited to, the interpretation of the terms and
conditions of this Agreement, will be submitted to the Commission
for resolution.
Attachment 1 at p. 22.
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -23
72. Notch 8utte has reaffirmed its position that the Commission has
jurisdiction with regard to disputes under the FESA. Paragraph 2(i) of the Exergy letter
dated July 13, 2012, states as follows:
If Idaho Power disputes [the claim of Force Majeure], then pursuant
to Section 22.1 of the FESA, Idaho Power is contractually obligated
to submit the matter to the Commission for resolution.
Attachment 59 at p. 1-2. (July 13 Exergy letter) Idaho Power agrees that the
Commission has jurisdiction to interpret and enforce the FESA pursuant to both the
FESA itself and the Idaho Uniform Declaratory Judgments Act.
2. The Commission Has Jurisdiction Over Interpretation and
Enforcement of the GIA.
73. FERC has stated that the relevant state authority exercises exclusive
jurisdiction over interconnections in which the electric utility must purchase the entire
output of the qualifying facility:
When an electric utility is obligated to interconnect under
Section 292.303 of the Commission's Regulations, that is, when it
must purchase the OF's total output, the relevant state authority
exercises authority over the interconnection and the allocation of
interconnection costs.
Standardization of Generator Interconnection Agreements and Procedures, Order
No. 2003, FERC Stats. & Regs. ~31,146 at P 813 (2003), order on reh'g, Order
No.2003-A, FERC Stats. & Regs. ~ 31,160, order on reh'g, Order No. 2003-8, FERC
Stats. & Regs, ~ 31,171 (2004), order on reh'g, Order No. 2003-C, FERC Stats. & Regs.
K 31,190 (2005), aff'd sub nom. Nat'l Ass'n of Regulatory Uti!. Comm'rs v. FERC, 475
F.3d 1277 (D.C. Cir. 2007)). Recently, FERC has reaffirmed the finding that it will have
jurisdiction over an interconnection with a qualifying facility only if the host utility is given
notice that third-party sales of the facility's output are occurring or are planned:
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -24
Therefore, consistent with our conclusions in Niagara Mohawk,
where a host utility is not given notice that third-party sales of
output are occurring or are planned (e.g., through a QF's request
for wheeling service or a contract providing the QF an express right
to sell output to third parties), we will assume that all sales of a
QF's output are being made to the host utility and therefore that
Commission jurisdiction will not attach.
Florida Power & Light Co., 133 FERC,-r 61,121 at P 22 (2010) (citing Niagara Mohawk
Power Corp., 121 FERC ,-r61,183 (2007), order denying reh'g, 123 FERC ,-r61,061
(2008)). Here, the FESA would obligate Idaho Power to purchase the entire output of
the project. Therefore, this Commission-and not FERC-has jurisdiction over the GIA.
B. The Dispute Is a Justiciable Controversy.
74. This is an action for declaratory order brought for the purpose of
determining a question of actual controversy between the parties. The dispute is as
follows: Idaho Power claims that Notch Butte has failed to meet its Scheduled
Operation Date of September 1, 2010, defaulted under the FESA by failing to achieve
its Operation Date within 10 months of its Scheduled Operation Date, and failed to cure
its default within either 60 days of the notice of default or if not within 60 days, within a
commercially reasonable period time. Idaho Power further claims that it may now
terminate the FESA with Notch Butte. Notch Butte disputes Idaho Power's claim that it
is not bringing its project online in a commercially reasonable time after default.
Additionally, Notch Butte claims Force Majeure events have occurred that excuse its
required performance under the FESA. Seg Attachment 59 and 56. Article XVI of the
FESA excuses both parties from whatever performance is affected by "any cause
beyond the control of the Seller or of Idaho Power which, despite the exercise of due
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -25
diligence, such party is unable to prevent or overcome." Idaho Power disagrees with
Notch Butte that any Force Majeure event has occurred. See Attachment 58.
75. As a general rule, a declaratory judgment can only be rendered in a case
where an actual or justiciable controversy exists. Harris, at 516, citing (internal cites
omitted). A "justiciable controversy" ripe for a declaratory judgment must be one that is
appropriate for judicial determination, must be definite and concrete, touching the legal
relations of parties having adverse legal interests, and must be real and substantial
admitting of specific relief through a decree of a conclusive character, as distinguished
from an opinion advising what the law would be upon a hypothetical state of facts.
Harris, at 516, citing I.C. § 10-1201; Rules Civ.Proc., Rule 57.
76. Idaho Power and Notch Butte agree that the Commission has jurisdiction
over the dispute at hand. The dispute is appropriate for the Commission's
determination because it requires interpretation of several provisions of the FESA, as
well as Schedule 72 and the generator interconnection process for OF generators. The
dispute is definite and concrete because Idaho Power claims current or impending
violations of specific provisions of the FESA by Notch Butte and because Idaho Power
disagrees with any application of the Force Majeure provision of the FESA. The parties
to the FESA have adverse legal interests. The dispute is real and substantial, as
distinguished from a request for an advisory opinion, because it (1) involves actions or
inactions that have actually occurred, (2) calls for interpretation and enforcement of a
valid and enforceable agreement, and (3) the Commission's resolution of the dispute
would likely involve specific relief expressly provided for in the FESA.
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -26
DECLARATORY ORDER TO TERMINATE CONTRACT
77. Idaho Power realleges and hereby incorporates by reference all of the
foregoing allegations as if fully stated herein.
A. Idaho Power May Terminate the FESA Upon Failure of the Project to
Achieve Its Operation Date.
78. Notch Butte has failed to meet the Scheduled Operation Date of
September 1, 2010, as provided in the 2008 Amendment to the FESAs stated
Scheduled Operation Date in Section B-3 in Appendix B of the FESA. Attachment 2.
As provided in Section 5.3 of the FESA, Notch Butte's failure to achieve its Operation
Date within 10 months of the Scheduled Operation Date is an event of default. Section
22.2.1 of the FESA provides:
Defaults. If either Party fails to perform any of the terms or
conditions of this Agreement (an "event of default"), the
nondefaulting Party shall cause notice in writing to be given
to the defaulting Party, specifying the manner in which such
default occurred. If the defaulting Party shall fail to cure
such default within the sixty (60) days after service of such
notice, or if the defaulting Party reasonable demonstrates to
the other Party that the default can be cured within a
commerCially reasonable time but not within such sixty (60)
day period and then fails to diligently pursue such cure, then,
the nondefaulting Party may, at its option, terminate this
Agreement and/or pursue its legal or equitable remedies.
The Idaho Uniform Declaratory Judgments Act provides for the issuance of a
declaratory judgment in a contract dispute "before or after there has been a breach."
Harris at 516-517,991 (1984). Accordingly, Idaho Power requests an Order from the
Commission declaring that Notch Butte has failed to cure its default within 60 days of
the notice of default, has failed to cure its default within a commercially reasonable
period of time outside of said 60 day time period, and that Idaho Power may terminate
the FESA.
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -27
B. No Force Majeure Event Has Occurred and Notch Butte is Not Diligently
Pursuing a Cure of Its Default Within a Commercially Reasonable Time.
79. Notch Butte claims that events have occurred that constitute Force
Majeure pursuant to Section 16 of the FESA. Paragraph 16.1 states, in relevant part:
As used in this Agreement, "Force Majeure" or "an event of Force
Majeure" means any cause beyond the control of the Seller or of
Idaho Power which, despite the exercise of due diligence, such
Party is unable to prevent or overcome. Force Majeure includes,
but is not limited to, acts of God, fire, flood, storms, wars, hostilities,
civil strife, strikes and other labor disturbances, earthquakes, fires,
lightning, epidemics, sabotage, or changes in law or regulation
occurring after the Operation Date, which, by the existence of
reasonable foresight such party could not reasonably have been
expected to avoid and by the exercise of due diligence, it shall be
unable to overcome.
Attachment 1 .
80. In its Notice of Force Majeure, Notch Butte contends, among other things,
that Idaho Power's estimated date for construction of interconnection facilities
associated with the Jack Ranch projects2 is a Force Majeure event because the date
makes it impossible for the Jack Ranch projects to meet their respective Scheduled
Operation Date of June 30, 2012, and because of the "combined financing" of the
projects, this also constitutes Force Majeure for Notch Butte. See Attachment 59 and
Attachment 56.
81. Notch Butte's attempt to excuse its non-performance fails because it does
not meet the FESA's definition of a Force Majeure event, and Exergy's own actions
and/or inactions caused considerable delay that it now claims constitutes Force
Majeure. Exergy has not, to this day, paid the required construction deposit, nor
authorized Idaho Power to move forward with the required work necessary for the
2 See, Case No. IPC-E-12-20.
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -28
interconnection and transmission upgrades required to connect the Projects to Idaho
Power's system. Exergy has established a pattern of continually requesting changes to
the requested interconnection configuration to avoid committing to any. After nearly 7
years after executing the FESA, more than 5 years after the original Scheduled
Operation Date of May 1,2007, nearly 2 years past the amended Scheduled Operation
Date of September 1, 2010, numerous proposed interconnection configurations, and
now 2 removals from the generator interconnection queue, Notch Butte is not diligently
pursuing its Operation Date in a commercially reasonable manner, nor within a
commercially reasonable period of time.
82. On July 26, 2011, Idaho Power wrote to Notch Butte providing Notice of
Default for Notch Butte's failure to achieve its Operation Date within 10 months of its
Scheduled Operation Date. This letter also advised Notch Butte of the FESAs
requirements to cure the default, and stated that Notch Butte's failure to cure as outlined
in the FESA would result in Idaho Power proceeding with the remedies allowed within
the FESA, one of which is termination of the FESA.
This letter serves as Idaho Power's Notice of Default as of the date
of this letter. If this default is not cured as specified within the
FESA Idaho Power will exercise its rights as allowed within the
agreement one of which may be termination of the FESA.
Idaho Power has received the letter from Mr. Richardson dated
June 30, 2011 in which Mr. Richardson acknowledges the default
commercial on line date to be July 15\ 2011. I n this same letter Mr.
Richardson introduces a short discussion that this default is being
cured by the project making commercially reasonable efforts and
goes on to state that the projects will start construction in
approximately forty-five (45) days from June 30, 2011, and be
online by year end 2011.
However, the letter does not identify any specific activity, actual
commitment and associated evidence that would reasonable
demonstrate to Idaho Power that the default can be cured within a
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -29
commercially reasonable period of time, but not within the sixty (60)
day cure period, i.e., by the end of the year, and that the project is
diligently pursuing such cure.
Article 22 of the FESA states that following notice of an event of
default that Idaho Power may, at its option, terminate the FESA
and/or pursue its legal or equitable remedies if the project fails to
cure such default within sixty (60) days after service of such notice,
or if the project reasonable demonstrates to Idaho Power that the
default can be cured within a commercially reasonable time, but not
within such sixty (60) day period, and then fails to diligently pursue
such cure.
Idaho Power appreciates the project's commitment that it will start
construction and cure its default of the FESA by year end, 2011.
Idaho Power will consider this year-end commitment to be the outer
limit of a commercially reasonable time period with which to cure
the default if it is not on-line within sixty (60) days of this Notice of
Default. If the default is not cured within said sixty (60) days, then
Idaho Power may exercise its rights to terminate and/or pursue its
legal or equitable remedies unless the project demonstrates that it
is diligently pursuing cure of the default by the commercially
reasonable time period of year end, 2011. If the project is not
online by year end 2011, the parties agree that the commercially
reasonable period to cure this default has expired and Idaho Power
will proceed with the remedies as allowed within this Firm Energy
Sales Agreement one of which is termination of this Firm Energy
Sales Agreement.
Attachment 3.
84. In response to the July 26, 2011, letter, counsel for Notch Butte confirmed
receipt of the July 26, 2011, Notice of Default. Attachment 41. This letter also
specifically disagrees that year-end 2011 would be an outer limit to a commercially
reasonable period to cure Notch Butte's default, but none-the-Iess reaffirms, "Exergy
still intends to energize each of these projects [Notch Butte and Lava Beds] by year end
2011." Id. at 1-2.
85. Notch Butte has failed to bring the project online by the Scheduled
Operation Date of May 1,2007. Notch Butte has failed to bring the project online by the
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -30
amended Scheduled Operation Date of September 1, 2010. Notch Butte has failed to
achieve its Operation Date by July 1, 2011, within 10 months of its amended Scheduled
Operation Date and defaulted under the FESA, at that time. Notch Butte failed to bring
the project online by year end 2011, and it committed to at the time of default. Notch
Butte has refused to pay the required construction deposit to move forward with the
construction of the required transmission and interconnection facilities, and has been
removed from the generator interconnection queue for now a second time, which will
require a new application and possibly a new study process. The date for construction
of the interconnection facilities associated with the Jack Ranch projects cannot be an
event of Force Majeure under paragraph 16.1 of the FESA. Exergy, by its own actions,
has refused to move the interconnection process forward or to take the steps necessary
to bring the Notch Butte project online in a commercially reasonable period of time. For
these reasons, Idaho Power requests an Order from the Commission declaring that no
Force Majeure event has occurred to excuse default, and that Notch Butte is not
diligently pursuing a cure of its default within a commercially reasonable period of time.
C. Termination of the FESA is in the Public Interest.
86. Idaho Power's ability to terminate the FESA upon default and breach of
Notch Butte for failure to meet the Operation Date and failure to cure its default
pursuant to Sections 5 and 22 of the FESA is in the public interest. The FESA currently
provides for rates that have subsequently been found to not be in the public interest. In
The Matter of the Commission's Review of PURPA QF Contract Provisions, Case No.
GNR-E-11-03, Order No. 32498 at 2 (March 22, 2012), this Commission stated:
We also find, however, as stated on the record at the conclusion of
the March 21, 2012, hearing, that the methodologies previously
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -31
approved by this Commission, as utilized and applied by Idaho
Power, do not currently produce rates that reflect Idaho Power's
avoided costs and are not just and reasonable, nor in the public
interest. Effective March 21, 2012, and continuing until altered or
amended by Order of the Commission at the conclusion of th is
case, contracts for all projects over 100 kW entered into by Idaho
Power and presented to this Commission for approval will be
individually evaluated with regard to all terms contained therein.
(Emphasis added.) The rates at issue in this Complaint Petition are provided in Article
VII of the FESA. The FESA's rates have subsequently been determined, as described
above, to not be in the public interest. If the Commission issues an order declaring that
Idaho Power is authorized to terminate the FESA upon the failure of Notch Butte to
meet its Operation Date and to subsequently cure it default of the FESA, rates that have
been deemed not to be in the public interest will likewise be terminated. If Idaho Power
and Notch Butte were to execute a new FESA, the parties must obviously comply with
Order 32498, thereby establishing rates that are in the public interest pursuant to the
methodology approved in Order 32498.
REQUESTED RELIEF -CONCLUSION
87. Idaho Power respectfully requests that the Commission grant the following
relief:
1) Entry of a declaratory order that the Commission has jurisdiction
over the interpretation and enforcement of the FESA and the GIA; and
2) Entry of a declaratory order that Exergy's claim of force majeure
does not exist so as to excuse Notch Butte's failure to meet the amended Scheduled
Operation Date, Operation Date, and failure to cure its default; and
3) Entry of a declaratory order that Notch Butte has failed to place its
project in service by the amended Scheduled Operation Date of September 1, 2010;
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -32
has failed to achieve the Operation Date by July 1, 2011, which is within 10 months of
the amended Scheduled Operation Date; and has received Notice of its default, as of
July 26, 2011; and
4) Entry of a declaratory order that Notch Butte did not cure its default
of the FESA within 60 days of receiving Notice of Default, and has not diligently pursued
a cure of said default within a commercially reasonable time, and that Idaho Power may
terminate the FESA; and
5) Any further relief to which Idaho Power is entitled.
Respectfully submitted at Boise, Idaho, th' 1st day of July 2012.
Attorney for Idaho Power Company
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -33
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that, on this 31 st day of July 2012 I served a true and
correct copy of IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR
DECLARATORY ORDER upon the following named parties by the method indicated
below, and addressed to the following:
Exergy Development Group, LLC
Peter J. Richardson
RICHARDSON & O'LEARY, PLLC
515 North 27th Street (83702)
P.O. Box 7218
Boise, Idaho 83707
.lL Hand Delivered
U.S. Mail
_ Overnight Mail
FAX
_ Email [e-mail]
Danielle Clark, Paralegal
IDAHO POWER COMPANY'S COMPLAINT AND PETITION FOR DECLARATORY ORDER -34
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 1
Article
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Definitions
~ENERGYSALESAGREEMENT
BETWEEN
IDAHO POWER COMPANY
AND
NOTCH BUTTE WIND PARK LLC
TABLE OF CONTENTS
No Reliance on Idaho Power
Warranties
Conditions to Acceptance of Energy
Term and Operation Date
Purchase and Sale of Net Energy
Purchase Price and Method of Payment
Environmental Attributes
Facility and Interconnection
Disconnection Equipment
Metering and Telemetry
Records
Protection
Operations
Indemnification and Insurance
Force Majeure
Land Rights
Liability; Dedication
Several Obligations
Waiver
Choice of Laws and Venue
Disputes and Default
Governmental Authorization
Commission Order
Successors and Assigns
Modification
Taxes
Notices
Additional Terms and Conditions
Severability
Counterparts
Entire Agreement Signatures
Appendix A
Appendix B
Appendix C
10110/2005
F~ENERGYSALESAGREEMENT
(10 aMW or Less)
NOTCH BUTTE WIND PARK LLC
Project Number: 31615300
THIS AGREEMENT, entered into on this ------,/J----<'1'--_day of 0 c,-t 2005 between
NOTCH BUTTE WIND PARK, an Idaho limited liability company (Seller), and IDAHO POWER
COMPANY, an Idaho corporation (Idaho Power), hereinafter sometimes referred to collectively as
"Parties" or individually as "Party."
WITNESSETH:
WHEREAS, Seller will design, construct, own, maintain and operate an electric generation
facility; and
WHEREAS, Seller wishes to sell, and Idaho Power is willing to purchase, firm electric energy
produced by the Seller's Facility.
THEREFORE, In consideration of the mutual covenants and agreements hereinafter set forth, the
Parties agree as follows:
ARTICLE I: DEFINITIONS
As used in this Agreement and the appendices attached hereto, the following terms
shall have the following meanings:
1.1 "Commission" -The Idaho Public Utilities Commission.
1.2 "Contract Year" -The period commencing each calendar year on the same calendar date as the
Operation Date and ending 364 days thereafter.
1.3 "Designated Dispatch Facility" -Idaho Power's Systems Operations Group, or any subsequent
group designated by Idaho Power.
1.4 "Disconnection Equipment" -All equipment specified in Schedule 72 and the Generation
Interconnection Process and any additional equipment specified in Appendix B.
1.5 "Facility" -That electric generation facility described in Appendix B of this Agreement.
- 1-
10/10/2005
l.6 "First Energy Date" -The day commencing at 0001 hours, Mountain Time, following the day that
Seller has satisfied the requirements of Article N and the Seller begins delivering energy to
Idaho Power's system at the Point of Delivery.
l.7 "Generation Interconnection Process" -Idaho Power's generation interconnection application
and engineering review process developed to ensure a safe and reliable generation
interconnection in compliance with all applicable regulatory requirements, Prudent Electrical
Practices and national safety standards.
1.8 "Inadvertent Energy" -Electric energy Seller does not intend to generate. Inadvertent energy is
more particularly described in paragraph 7.3 of this Agreement.
1.9 "Interconnection Facilities" -All equipment specified in Schedule 72 and the Generation
Interconnection Process and any additional equipment specified in Appendix B.
1.10 "Initial Capacity Determination" -The process by which Idaho Power confirms that under
normal or average design conditions the Facility will generate at no more than 10 average MW
per month and is therefore eligible to be paid the published rates in accordance with Commission
Order No. 29632.
1.11 "Losses" -The loss of electrical energy expressed in kilowatt hours (kWh) occurring as a result
of the transformation and transmission of energy between the point where the Facility's energy is
metered and the point the Facility's energy is delivered to the Idaho Power electrical system. The
loss calculation formula will be as specified in Appendix B of this Agreement.
1.12 "Market Energy Cost" -Eighty-five percent (85%) of the weighted average of the daily on-peak
and off-peak Dow Jones Mid-Columbia Index (Dow Jones Mid-C Index) prices for non-firm
energy. If the Dow Jones Mid-Columbia Index price is discontinued by the reporting agency, both
Parties will mutually agree upon a replacement index, which is similar to the Dow Jones Mid­
Columbia Index. The selected replacement index will be consistent with other similar agreements
and a commonly used index by the electrical industry.
1.13 "Material Breach" - A Default (paragraph 22.2.1) subject to paragraph 22.2.2.
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1.14 "Maximum Capacity Amount" -The maximum capacity (MW) of the Facility will be as
specified in Appendix B of this Agreement.
1.15 "Metering Equipment" -All equipment specified in Schedule 72, the Generation Interconnection
Process, this Agreement and any additional equipment specified in Appendix B required to
measure, record and telemeter power flows between the Seller's electric generation plant and
Idaho Power's system.
1.16 "Net Energy" -All of the electric energy produced by the Facility, less Station Use, less Losses,
expressed in kilowatt hours (kWh). Seller commits to deliver all Net Energy to Idaho Power at
the Point of Delivery for the full term of the Agreement. Net Energy does not include Inadvertent
Energy.
1.17 "Operation Date" -The day commencing at 0001 hours, Mountain Time, following the day that
all requirements of paragraph 5.2 have been completed.
1.18 "Point of Delivery" -The location specified in Appendix B, where Idaho Power's and the
Seller's electrical facilities are interconnected.
1.19 "Prudent Electrical Practices" -Those practices, methods and equipment that are commonly and
ordinarily used in electrical engineering and operations to operate electric equipment lawfully,
safely, dependably, efficiently and economically.
1.20 "Scheduled Operation Date" -The date specified in Appendix B when Seller anticipates
achieving the Operation Date.
1.21 "Schedule 72" -Idaho Power's Tariff No 101, Schedule 72 or its successor schedules as
approved by the Commission.
1.22 "Season" -The three periods identified in paragraph 6.2.1 of this Agreement.
1.23 "Special Facilities" -Additions or alterations of transmission andlor distribution lines and
transformers as described in Appendix B, Schedule 72 or the Generation Interconnection Process
required to safely interconnect the Seller's Facility to the Idaho Power system.
1.24 "Station Use" -Electric energy that is used to operate equipment that is auxiliary or otherwise
related to the production of electricity by the Facility.
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1.25 "Surplus Energy" -0) Net Energy produced by the Seller's Facility and delivered to the Idaho
Power electrical system during the month which exceeds 110% of the monthly Net Energy
Amount for the corresponding month specified in paragraph 6.2. or (2) If the Net Energy
produced by the Seller's Facility and delivered to the Idaho Power electrical system during the
month is less than 90% of the monthly Net Energy Amount for the corresponding month
specified in paragraph 6.2, then all Net Energy delivered by the Facility to the Idaho Power
electrical system for that given month or (3) All Net Energy produced by the Seller's Facility and
delivered by the Facility to the Idaho Power electrical system prior to the Operation Date.
1.26 "Total Cost of the Facility" -The total cost of structures, equipment and appurtenances.
ARTICLE ll: NO RELIANCE ON IDAHO POWER
2.1 Seller Independent Investigation -Seller warrants and represents to Idaho Power that in entering
into this Agreement and the undertaking by Seller of the obligations set forth herein, Seller has
investigated and determined that it is capable of performing hereunder and has not relied upon
the advice, experience or expertise of Idaho Power in connection with the transactions
contemplated by this Agreement.
2.2 Seller Independent Experts -All professionals or experts including, but not limited to, engineers,
attorneys or accountants, that Seller may have consulted or relied on in undertaking the
transactions contemplated by this Agreement have been solely those of Seller.
ARTICLE ill: WARRANTIES
3.1 No Warranty by Idaho Power -Any review, acceptance or failure to review Seller's design,
specifications, equipment or facilities shall not be an endorsement or a confirmation by Idaho
Power and Idaho Power makes no warranties, expressed or implied, regru;ding any aspect of
Seller's design, specifications, equipment or facilities, including, but not limited to, safety,
durability, reliability, strength, capacity, adequacy or economic feasibility.
3.2 Qualifying Facility Status -Seller warrants that the Facility is a "Qualifying Facility," as that term
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is used and defined in 18 CFR §292.207. After initial qualification, Seller will take such steps as
may be required to maintain the Facility's Qualifying Facility status during the term of this
Agreement and Seller's failure to maintain Qualifying Facility status will be a Material Breach of
this Agreement. Idaho Power reserves the right to review the Seller's Qualifying Facility status
and associated support and compliance documents at anytime during the term of this Agreement.
ARTICLE N : CONDITIONS TO ACCEPTANCE OF ENERGY
4.1 Prior to the First Energy Date and as a condition of Idaho Power's acceptance of deliveries of
energy from the Seller, Seller shall:
4.1.1 Submit proof to Idaho Power that all licenses, permits or approvals necessary for Seller's
operations have been obtained from applicable federal, state or local authorities,
including, but not limited to, evidence of compliance with Subpart B, 18 CFR 292.207.
4.1.2 Opinion of Counsel -Submit to Idaho Power an Opinion Letter signed by an attorney
admitted to practice and in good standing in the State of Idaho providing an
opinion that Seller's licenses, permits and approvals as set forth in paragraph 4.1.1
above are legally and validly issued, are held in the name of the Seller and, based on
a reasonable independent review, counsel is of the opinion that Seller is in substantial
compliance with said permits as of the date of the Opinion Letter. The Opinion Letter
will be in a form acceptable to Idaho Power and will acknowledge that the attorney
rendering the opinion understands that Idaho Power is relying on said opinion. Idaho
Power's acceptance of the form will not be unreasonably withheld. The Opinion Letter
will be governed by and shall be interpreted in accordance with the legal opinion accord
ofthe American Bar Association Section of Business Law (1991).
4.1.3 Initial Capacity Determination -Submit to Idaho Power such data as Idaho Power may
reasonably require to perform the Initial Capacity Determination. Such data will include
but not be limited to, equipment specifications, prime mover data, resource
characteristics, normal andlor average operating design conditions and Station Use data.
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Upon receipt of this information, Idaho Power will review the provided data and if
necessary, request additional data to complete the Initial Capacity Determination within a
reasonable time.
4.1.4 Engineer's Certifications -Submit an executed Engineer's Certification of Design &
Construction Adequacy and an Engineer's Certification of Operations and Maintenance
(O&M) Policy as described in Commission Order No. 21690. These certificates will be
in the form specified in Appendix C but may be modified to the extent necessary to
recognize the different engineering disciplines providing the certificates.
4.1.5 Insurance -Submit written proof to Idaho Power of all insurance required in Article XV.
4.1.6 Interconnection -Provide written proof to Idaho Power that all Schedule 72 and
Generation Interconnection Process requirements have been completed.
4.1.7 Written Acceptance -Request and obtain written confirmation from Idaho Power that all
conditions to acceptance of energy have been fulfilled. Such written confirmation shall be
provided within a commercially reasonable time following the Seller's request and will
not be unreasonably withheld by Idaho Power.
ARTICLE V: TERM AND OPERATION DATE
5.1 Term -Subject to the provisions of paragraph 5.2 below, this Agreement shall become effective
on the date first written and shall continue in full force and effect for a period of twenty (20)
Contract Years from the Operation Date.
5.2 Operation Date -The Operation Date may occur only after the Facility has achieved all of the
following:
a) Achieved the First Energy Date.
b) Commission approval of this Agreement in a form acceptable to Idaho Power has
been received.
c) Seller has demonstrated to Idaho Power's satisfaction that the Facility is complete and
able to provide energy in a consistent, reliable and safe manner and has requested an
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Operation Date in written form.
d) Seller has requested an Operation Date from Idaho Power in a written format.
e) Seller has received written confirmation from Idaho Power of the Operation Date.
This confirmation will not be unreasonably withheld by Idaho Power.
5.3 Seller's failure to achieve the Operation Date within ten (10) months of the Scheduled Operation
Date will be an event of default.
ARTICLE VI: PURCHASE AND SALE OF NET ENERGY
6.1 Delivery and Acceptance of Net Energy -Except when either Party's performance is excused as
provided herein, Idaho Power will purchase and Seller will sell all of the Net Energy to Idaho
Power at the Point of Delivery. All Inadvertent Energy produced by the Facility will also be
delivered by the Seller to Idaho Power at the Point of Delivery. At no time will the total amount
of Net Energy and/or Inadvertent Energy produced by the Facility and delivered by the Seller to
the Point of Delivery exceed the Maximum Capacity Amount.
6.2 Net Energy Amounts -Seller intends to produce and deliver Net Energy in the following monthly
amounts:
6.2.1 Initial Year Monthly Net Energy Amounts:
Season 1
Season 2
Season 3
March
April
May
July
August
November
December
June
September
October
January
February
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5,077,634
4,358,815
4,512,845
3,391,624
3,090,413
4,811,622
4,766,515
4,667,598
3,861,307
5,017,769
4,082,420
5,309,837
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6.2.2 Ongoing Monthly Net Energy Amounts -Seller shall initially provide Idaho Power with
one year of monthly generation estimates (Initial Year Monthly Net Energy Amounts)
and beginning at the end of month nine and every three months thereafter provide Idaho
Power with an additional three months of forward generation estimates. This information
will be provided to Idaho Power by written notice in accordance with paragraph 28.1, no
later than 5:00 PM of the 5th day following the end of the previous month. If the Seller
does not provide the Ongoing Monthly Net Energy amounts in a timely manner, Idaho
Power will use the most recent 3 months of the Initial Year Monthly Net Energy
Amounts specified in paragraph 6.2.1 for the next 3 months of monthly Net Energy
amounts.
6.2.3 Seller's Adjustment of Net Energy Amount -
6.2.3.1 No later than the Operation Date, by written notice given to Idaho Power in
accordance with paragraph 28.1, the Seller may revise all of the previously
provided Initial Year Monthly Net Energy Amounts.
6.2.3.2 Beginning with the end of the 3rd month after the Operation Date and at the end
of every third month thereafter: (1) the Seller may not revise the immediate next
three months of previously provided Net Energy Amounts, (2) but by written
notice given to Idaho Power in accordance with paragraph 28.1, no later than
5:00 PM of the 5th day following the end of the previous month, the Seller may
revise all other previously provided Net Energy Amounts. Failure to provide
timely written notice of changed amounts will be deemed to be an election of no
change.
6.2.4 Idaho Power Adjustment of Net Energy Amount -If Idaho Power is excused from
accepting the Seller's Net Energy as specified in paragraph 14.2.1 or if the Seller declares
a Suspension of Energy Deliveries as specified in paragraph 14.3.1 and the Seller's
declared Suspension of Energy Deliveries is accepted by Idaho Power, the Net Energy
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Amount as specified in paragraph 6.2 for the specific month in which the reduction or
suspension under paragraph 14.2.1 or 14.3.1 occurs will be reduced in accordance with
the following:
Where:
NEA = Current Month's Net Energy Amount (Paragraph 6.2)
SGU = a.) If Idaho Power is excused from accepting the Seller's Net
Energy as specified in paragraph 14.2.1 this value will be
equal to the percentage of curtailment as specified by
Idaho Power multiplied by the TGU as defined below.
b.) If the Seller declares a Suspension of Energy Deliveries as
specified in paragraph 14.3.1 this value will be the sum of
the individual generation units size ratings as specified in
Appendix B that are impacted by the circumstances
causing the Seller to declare a Suspension of Energy
Deliveries.
TGU
RSH
TH
Sum of all of the individual generator ratings of the generation
units at this Facility as specified in Appendix B of this
agreement.
= Actual hours the Facility's Net Energy deliveries were either
reduced or suspended under paragraph 14.2.1 or 14.3.1
= Actual total hours in the current month
Resulting formula being:
Adjusted
Net Energy = NEA
Amount -( ( SGU X NEA
TGU
RSH
TH
This Adjusted Net Energy Amount will be used in applicable Surplus Energy calculations for
only the specific month in which Idaho Power was excused from accepting the Seller's Net
Energy or the Seller declared a Suspension of Energy.
6.3 Unless excused by an event of Force Majeure, Seller's failure to deliver Net Energy in any
Contract Year in an amount equal to at least ten percent (10%) of the sum of the Initial Year Net
Energy Amounts as specified in paragraph 6.2 shall constitute an event of default.
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ARTICLE VII: PURCHASE PRICE AND METHOD OF PAYMENT
7.1 Net Energy Purchase Price -For all Net Energy, Idaho Power will pay the non-levelized energy
price in accordance with Commission Order 29646 with seasonalization factors applied:
Season 1 -(73.50 %) Season 2 -(120.00 %) Season 3 -(100.00 %)
Year MillslkWh MillslkWh MillslkWh
2005 37.00 60.41 50.34
2006 37.85 61.80 51.50
2007 38.73 63.23 52.69
2008 39.62 64.68 53.90
2009 40.53 66.17 55.14
2010 41.46 67.69 56.41
2011 42.42 69.25 57.71
2012 43.39 70.85 59.04
2013 44.39 72.48 60.40
2014 45.42 74.16 61.80
2015 46.47 75.86 63.22
2016 47.54 77.62 64.68
2017 48.63 79.40 66.17
2018 49.76 81.24 67.70
2019 50.91 83.11 69.26
2020 52.07 85.02 70.85
2021 53.28 86.99 72.49
2022 54.51 88.99 74.16
2023 55.76 91.04 75.87
2024 57.05 93.14 77.62
2025 58.37 95.29 79.41
2026 59.72 97.50 81.25
7.2 SUl:plus Energy Price -For all Surplus Energy, Idaho Power shall pay to the Seller the current
month's Market Energy Cost or the Net Energy Purchase Price specified in paragraph 7.1,
whichever is lower.
7.3 Inadvertent Energy-
7.3.1 Inadvertent Energy is electric energy produced by the Facility, expressed in kWh, which
the Seller delivers to Idaho Power at the Point of Delivery that exceeds 10,000 kW
multiplied by the hours in the specific month in which the energy was delivered. (For
example January contains 744 hours. 744 hours times 10,000 kW = 7,440,000 kWh.
Energy delivered in January in excess of 7,440, 000 kWh in this example would be
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Inadvertent Energy.)
7.3.2 Although Seller intends to design and operate the Facility to generate no more than 10
average MW and therefore does not intend to generate Inadvertent Energy, Idaho Power
will accept Inadvertent Energy that does not exceed the Maximum Capacity Amount but
will not purchase or pay for Inadvertent Energy
7.4 Payment Due Date -Energy payments to the Seller will be disbursed within 30 days of the date
which Idaho Power receives and accepts the documentation of the monthly Net Energy and
Inadvertent Energy actually produced by the Seller's Facility and delivered to Idaho Power as
specified in Appendix A.
7.5 Continuing Jurisdiction of the Commission -This Agreement is a specia~ contract and, as such,
the rates, terms and conditions contained in this Agreement will be construed in accordance with
Idaho Power Company v. llaho Public Utilitie Commission and Afton Energy. Inc., 107 Idaho
781,693 P.2d 427 (1984); Idaho Power Company v. Idaho Public Utilities Commission, 107
Idaho 1122,695 P.2d 1261 (1985); Afton Energy, Inc, v. Idaho Power Company, 111 Idaho 925,
729 P.2d 400 (1986); Section 210 of the Public Utilities Regulatory Policies Act of 1978 and 18
CFR §292.303-308.
ARTICLE Vill: ENVIRONMENTAL ATTRIBUTES
8.1 Idaho Power waives any claim to ownership of Environmental Attributes. Environmental
Attributes include, but are not limited to, Green Tags, Green Certificates, Renewable Energy
Credits (REes) and Tradable Renewable Certificates (TRCs) directly associated with the
production of energy from the Seller's Facility.
ARTICLE IX: FA lLITY AND INTERCONNECTION
9.1 Design of Facility -Seller will design, construct, install, own, operate and maintain the Facility
and any Seller-owned Interconnection Facilities so as to allow safe and reliable generation and
delivery of Net Energy and Inadvertent Energy to the Idaho Power Point of Delivery for the full
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term of the Agreement.
9.2 Interconnection Facilities -Except as specifically provided for in this Agreement, the required
Interconnection Facilities will be in accordance with Schedule 72, the Generation Interconnection
Process and Appendix B. The Seller is responsible for all costs associated with this equipment as
specified in Schedule 72 and the Generation Interconnection Process, including but not limited to
initial costs incurred by Idaho Power for equipment costs, installation costs and ongoing monthly
Idaho Power operations and maintenance expenses.
ARTrCLE X: DISCONNECTION EQUIPMENT
10.1 Except as specifically provided for in this Agreement, the required Disconnection Equipment will
be in accordance with Schedule 72, the Generation Interconnection Process and Appendix B.
The Seller is responsible for all costs associated with this equipment as specified in Schedule 72
and the Generation Interconnection Process, including but not limited to initial costs incurred by
Idaho Power for equipment costs, installation costs and Idaho Power ongoing monthly operations
and monthly maintenance expenses.
ARTICLE XI: METERING AND TELEMETRY
11.1 Metering and Telemetry -Idaho Power shall, for the account of Seller, provide, install, and
maintain Metering Equipment to be located at a mutually agreed upon location to record and
measure power flows to Idaho Power in accordance with Schedule 72, Generation
Interconnection Process and Appendix B of this Agreement. The Metering Equipment will be at
the location and the type required to measure, record and report the Facility's Net Energy, Station
Use, Inadvertent Energy and maximum energy deliveries (kW) in a manner to provide Idaho
Power adequate energy measurement data to administer this Agreement and to integrate this
Facility's energy production into the Idaho Power electrical system. All Metering Equipment and
installation costs shall be borne by Seller, including costs incurred by Idaho Power for inspecting
and testing such equipment at reasonable intervals at Idaho Power's actual cost of providing this
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Metering Equipment and services. The Metering Equipment shall be at the location described in
Appendix B of this Agreement. All meters used to determine the billing hereunder shall be
sealed and the seals shall be broken only by Idaho Power when the meters are to be inspected,
tested or adjusted.
11.2 Meter Inspection -Idaho Power shall inspect installations annually and test meters on the
applicable periodic test schedule relevant to the equipment installed as specified in Appendix B of
this Agreement. If requested by Seller, Idaho Power shall make a special inspection or test of a
meter and Seller shall pay the reasonable costs of such special inspection. Both Parties shall be
notified of the time when any inspection or test shall take place, and each Party may have
representatives present at the test or inspection. If a meter is found to be inaccurate or defective,
it shall be adjusted, repaired or replaced, at Idaho Power's expense in order to provide accurate
metering. If a meter fails to register, or if the measurement made by a meter during a test varies
by more than two percent (2 %) from the measurement made by the standard meter used in the
test, adjustment (either upward or downward) to the payments Seller has received shall be made
to correct those payments affected by the inaccurate meter for the actual period during which
inaccurate measurements were made. If the actual period cannot be determined, corrections to
the payments will be based on the shorter of (1) a period equal to one-half the time from the date
of the last previous test of the meter to the date of the test which established the inaccuracy of the
meter; or (2) six (6) months.
11.3 Telemetry -Idaho Power will install, operate and maintain at Seller's expense metering,
communications and telemetry equipment which will be capable of providing Idaho Power with
continuous instantaneous telemetry of Seller's Net Energy and Inadvertent Energy produced and
delivered to the Idaho Power Point of Delivery to Idaho Power's Designated Dispatch Facility.
ARTICLE XU -RECORDS
12.1 Maintenance of Records -Seller shall maintain at the Facility or such other location mutually
acceptable to the Parties adequate total generation, Net Energy, Station Use, Inadvertent Energy
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1011012005
and maximum generation (kW) records in a form and content recommended by Idaho Power.
12.2 Inspection -Either Party, after reasonable notice to the other Party, shall have the right, during
normal business hours, to inspect and audit any or all generation, Net Energy, Station Use,
Inadvertent Energy and maximum generation (kW) records pertaining to the Seller's Facility.
ARTICLE Xill -PROTECTION
13.1 Seller shall construct, operate and maintain the Facility and Seller-furnished Interconnection
Facilities in accordance with Schedule 72, the Generation Interconnection Process, Appendix B
of this Agreement, Prudent Electrical Practices, the National Electrical Code, the National
Electrical Safety Code and any other applicable local, state and federal codes. Seller
acknowledges receipt of the Generation Interconnection Process. If, in the reasonable opinion of
Idaho Power, Seller's operation of the Facility or Interconnection Facilities is unsafe or may
otherwise adversely affect Idaho Power's equipment, personnel or service to its customers, Idaho
Power may physically interrupt the flow of energy from the Facility as specified within Schedule
72, the Generation Interconnection Process or take such other reasonable steps as Idaho Power
deems appropriate. Except in the case of an emergency, Idaho Power will attempt to notify Seller
of such interruption prior to its occurrence as provided in paragraph 14.9. Seller shall provide
anq maintain adequate protective equipment sufficient to prevent damage to the Facility and
Seller-furnished Interconnection Facilities. In some cases, some of Seller's protective relays will
provide back-up protection for Idaho Power's facilities. In that event, Idaho Power will test such
relays annually and Seller will pay the actual cost of such annual testing.
ARTICLE XIV -OPERATIONS
14 .1 Communications Idaho Power and the Seller shall maintain appropriate operating
communications through Idaho Power's Designated Dispatch Facility in accordance with
Appendix A of this Agreement.
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------------------------------------------.------
14.2 Energy Acceptance-
14.2.1 Idaho Power shall be excused from accepting and paying for Net Energy or accepting
Inadvertent Energy produced by the Facility and delivered by the Seller to the Point of
Delivery, if it is prevented from doing so by an event of Force Majeure, or if Idaho Power
determines that curtailment, interruption or reduction of Net Energy or Inadvertent
Energy deliveries is necessary because of line construction or maintenance requirements,
emergencies, electrical system operating conditions on its system or as otherwise required
by Prudent Electrical Practices. If, for reasons other than an event of Force Majeure,
Idaho Power requires such a curtailment, interruption or reduction of Net Energy
deliveries for a period that exceeds twenty (20) days, beginning with the twenty-first day
of such interruption, curtailment or reduction, Seller will be deemed to be delivering Net
Energy at a rate equivalent to the pro rata daily average of the amounts specified for the
applicable month in paragraph 6.2. Idaho Power will notify Seller when the interruption,
curtailment or reduction is terminated.
14.2.2 If, in the reasonable opinion of Idaho Power, Seller's operation of the Facility or
Interconnection Facilities is unsafe or may otherwise adversely affect Idaho Power's
equipment, personnel or service to its customers, Idaho Power may physically interrupt
the flow of energy from the Facility as specified within Schedule 72 or take such other
reasonable steps as Idaho Power deems appropriate.
14.2.3 Under no circumstances will the Seller deliver Net Energy and/or Inadvertent Energy
from the Facility to the Point of Delivery in an amount that exceeds the Maximum
Capacity Amount. Seller's failure to limit deliveries to the Maximum Capacity Amount
will be a Material Breach of this Agreement.
14.3 Seller Declared Suspension of Energy Deliveries
14.3.1 If the Seller's Facility experiences a forced outage due to equipment failure which is not
caused by an event of Force Majeure or by neglect, disrepair or lack of adequate
preventative maintenance of the Seller's Facility, Seller may, after giving notice as
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1011012005
provided in paragraph 14.3.2 below, temporarily suspend all deliveries of Net Energy to
Idaho Power from the Facility or from individual generation unites) within the Facility
impacted by the forced outage for a period of not less than 48 hours to correct the forced
outage condition ("Declared Suspension of Energy Deliveries"). The Seller's Declared
Suspension of Energy Deliveries will begin at the start of the next full hour following the
Seller's telephone'notification as specified in paragraph 14.3.2 and will continue for the
time as specified (not less than 48 hours) in the written notification provided by the
Seller. In the month(s) in which the Declared Suspension of Energy occurred, the Net
Energy Amount will be adjusted as specified in paragraph 6.2.4.
14.3.2 If the Seller desires to initiate a Declared Suspension of Energy Deliveries as provided in
paragraph 14.3.1, the Seller will notify the Designated Dispatch Facility by telephone.
The beginning hour of the Declared Suspension of Energy Deliveries will be at the
earliest the next full hour after making telephone contact with Idaho Power. The Seller
will, within 24 hours after the telephone contact, provide Idaho Power a written notice in
accordance with Article xxvm that will contain the beginning hour and duration of the
Declared Suspension of Energy Deliveries and a description of the conditions that caused
the Seller to initiate a Declared Suspension of Energy Deliveries. Idaho Power will
review the documentation provided by the Seller to determine Idaho Power's acceptance
of the described forced outage as qualifying for a Declared Suspension of Energy
Deliveries as specified in paragraph 14.3.1. Idaho Power's acceptance of the Seller's
forced outage as an acceptable forced outage will be based upon the clear documentation
provided by the Seller that the forced outage is not due do an event of Force Majeure or
by neglect, disrepair or lack of adequate preventative maintenance of the Seller's Facility.
14.5 Voltage Levels -Seller, in accordance with Prudent Electrical Practices shall minimize voltage
fluctuations and maintain voltage levels acceptable to Idaho Power. Idaho Power may, in
accordance with Prudent Electrical Practices, upon one hundred eighty (180) days' notice to the
Seller, change its nominal operating voltage level by more than ten percent (10%) at the Point of
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1011012005
Delivery, in which case Seller shall modify, at Idaho Power's expense, Seller's equipment as
necessary to accommodate the modified nominal operating voltage level.
14.6 Generator Ramping -Idaho Power, in accordance with Prudent Electrical Practices, shall have the
right to limit the rate that generation is changed at startup, during normal operation or following
reconnection to Idaho Power's electrical system. Generation ramping may be required to permit
Idaho Power's voltage regulation equipment time to respond to changes in power flow.
14.7 Scheduled Maintenance -On or before January 31 of each calendar year, Seller shall submit a
written proposed maintenance schedule of significant Facility maintenance for that calendar year
and Idaho Power and Seller shall mutually agree as to the acceptability of the proposed schedule.
The Parties determination as to the acceptability of the Seller's timetable for scheduled
maintenance will take into consideration Prudent Electrical Practices, Idaho Power system
requirements and the Seller's preferred schedule. Neither Party shall unreasonably withhold
acceptance of the proposed maintenance schedule.
14.8 Maintenance Coordination -The Seller and Idaho Power shall, to the extent practical, coordinate
their respective line and Facility maintenance schedules such that they occur simultaneously.
14.9 Contact Prior to Curtailment -Idaho Power will make a reasonable attempt to contact the Seller
prior to exercising its rights to curtail, interrupt or reduce deliveries from the Seller's Facility.
Seller understands that in the case of emergency circumstances, real time operations of the
electrical system, and/or unplanned events Idaho Power may not be able to provide notice to the
Seller prior to interruption, curtailment, or reduction of electrical energy deliveries to Idaho
Power.
ARTICLE XV: INDEMNIFICATION AND INSURANCE
15.1 Indemnification -Each Party shall agree to hold harmless and to indemnify the other Party, its
officers, agents, affiliates, subsidiaries, parent company and employees against all loss, damage,
expense and liability to third persons for injury to or death of person or injury to property,
proximately caused by the indemnifying Party's construction, ownership, operation or
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._-----------------------_._-_ .... ---
maintenance of, or by failure of, any of such Party's works or facilities used in connection with
this Agreement. The indemnifying Party shall, on the other Party's request, defend any suit
asserting a claim covered by this indemnity. The indemnifying Party shall pay all costs, including
reasonable attorney fees that may be incurred by the other Party in enforcing this indemnity.
15.2 Insurance -During the term of this Agreement, Seller shall secure and continuously carry the
following insurance coverage:
15.2.1 Comprehensive General Liability Insurance for both bodily injury and property damage
with limits equal to $1,000,000, each occurrence, combined single limit. The deductible
for such insurance shall be consistent with current Insurance Industry Utility practices for
similar property.
15.2.2 The above insurance coverage shall be placed with an insurance company with an A.M.
Best Company rating of A-or better and shall include:
(a) An endorsement naming Idaho Power as an additional insured and loss payee as
applicable; and
(b) A provision stating that such policy shall not be canceled or the limits of liability
reduced without sixty (60) days' prior written notice to Idaho Power.
15.3 Seller to Provide Certificate of Insurance -As required in paragraph 4.1.5 herein and annually
thereafter, Seller shall furnish Idaho Power a certifIcate of insurance, together with the
endorsements required therein, evidencing the coverage as set forth above.
15.4 Seller to Notify Idaho Power of Loss of Coverage -If the insurance coverage required by
paragraph 15.2 shall lapse for any reason, Seller will immediately notify Idaho Power in writing.
The notice will advise Idaho Power of the specific reason for the lapse and the steps Seller is
taking to reinstate the coverage. Failure to provide this notice and to expeditiously reinstate or
replace the coverage will constitute a Material Breach of this Agreement.
ARTICLE XVI. FORCE MAJEURE
16.1 As used in this Agreement, "Force Majeure" or "an event of Force Majeure" means any cause
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----.-.----------------------------------------------------------
beyond the control of the Seller or of Idaho Power which, despite the exercise of due diligence,
such Party is unable to prevent or overcome. Force Majeure includes, but is not limited to, acts of
God, fire, flood, storms, wars, hostilities, civil strife, strikes and other labor disturbances,
earthquakes, fires, lightning, epidemics, sabotage, or changes in law or regulation occurring after
the Operation Date, which, by the exercise of reasonable foresight such party could not
reasonably have been expected to avoid and by the exercise of due diligence, it shall be unable to
overcome. If either Party is rendered wholly or in part unable to perform its obligations under
this Agreement because of an event of Force Majeure, both Parties shall be excused from
whatever performance is affected by the event of Force Majeure, provided that:
(1) The non-performing Party shall, as soon as is reasonably possible after the
occurrence of the Force Majeure, give the other Party written notice describing
the particulars of the occurrence.
(2) The suspension of performance shall be of no greater scope and of no longer
duration than is required by the event of Force Majeure.
(3) No obligations of either Party which arose before the occurrence causing the
suspension of performance and which could and should have been fully
performed before such occurrence shall be excused as a result of such
occurrence.
ARTICLE XVll: LAND RIGHTS
17.1 Seller to Provide Access -Seller hereby grants to Idaho Power for the term of this Agreement all
necessary rights-of-way and easements to install, operate, maintain, replace, and remove Idaho
Power's Metering Equipment, Interconnection Equipment, Disconnection Equipment, Protection
Equipment and other Special Facilities necessary or useful to this Agreement, including adequate
and continuing access rights on property of Seller. Seller warrants that it has procured sufficient
easements and rights-of-way from third parties so as to provide Idaho Power with the access
described above. All documents granting such easements or rights-of-way shall be subject to
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------------------------------_ .. _--------------------
Idaho Power's approval and in recordable form.
17.2 Use of Public Rights-of-Way -The Parties agree that it is necessary to avoid the adverse
environmental and operating impacts that would occur as a result of duplicate electric lines being
constructed in close proximity. Therefore, subject to Idaho Power's compliance with paragraph
17.4, Seller agrees that should Seller seek and receive from any local, state or federal
governmental body the right to erect, construct and maintain Seller-furnished Interconnection
Facilities upon, along and over any and all public roads, streets and highways, then the use by
Seller of such public right-of-way shall be subordinate to any future use by Idaho Power of such
public right-of-way for construction and/or maintenance of electric distribution and transmission
facilities and Idaho Power may claim use of such public right-of-way for such purposes at any
time. Except as required by paragraph 17.4, Idaho Power shall not be required to compensate
Seller for exercising its rights under this paragraph 17.2.
17.3 J oint Use of Facilities -Subject to Idaho Power's compliance with paragraph 17.4, Idaho Power
may use and attach its distribution and/or transmission facilities to Seller's Interconnection
Facilities, may reconstruct Seller's Interconnection Facilities to accommodate Idaho Power's
usage or Idaho Power may construct its own distribution or transmission facilities along, over and
above any public right-of-way acquired from Seller pursuant to paragraph 17.2, attaching Seller's
Interconnection Facilities to such newly constructed facilities. Except as required by paragraph
17.4, Idaho Power shall not be required to compensate Seller for exercising its rights under this
paragraph 17.3.
17.4 Conditions of Use -It is the intention of the Parties that the Seller be left in substantially the same
condition, both financially and electrically, as Seller existed prior to Idaho Power's exercising its
rights under this Article XVTI. Therefore, the Parties agree that the exercise by Idaho Power of
any of the rights enumerated in paragraphs 17.2 and 17.3 shall: (1) comply with all applicable
laws, codes and Prudent Electrical Practices, (2) equitably share the costs of installing, owning
and operating jointly used facilities and rights-of-way. If the Parties are unable to agree on the
method of apportioning these costs, the dispute will be submitted to the Commission for
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._------
resolution and the decision of the Commission will be binding on the Parties, and (3) shall
provide Seller with an interconnection to Idaho Power's system of equal capacity and durability
as existed prior to Idaho Power exercising its rights under this Article XVII.
ARTICLE XVIII: LIABILITY; DEDICATION
18.1 Nothing in this Agreement shall be construed to create any duty to, any standard of care with
reference to, or any liability to any person not a Party to this Agreement. No undertaking by one
Party to the other under any provision of this Agreement shall constitute the dedication of that
Party's system or any portion thereof to the other Party or to the public or affect the status of
Idaho Power as an independent public utility corporation or Seller as an independent individual or
entity.
ARTICLE XIX: SEVERAL OBLIGATIONS
19.1 Except where specifically stated in this Agreement to be otherwise, the duties, obligations and
liabilities of the Parties are intended to be several and not joint or collective. Nothing contained
in this Agreement shall ever be construed to create an association, trust, partnership or joint
venture or impose a trust or partnership duty, obligation or liability on or with regard to either
Party. Each Party shall be individually and severally liable for its own obligations under this
Agreement.
ARTICLE XX: WANER
20.1 Any waiver at any time by either Party of its rights with respect to a default under this Agreement
or with respect to any other matters arising in connection with this Agreement shall not be
deemed a waiver with respect to any subsequent default or other matter.
ARTICLE XXI: CHOICE OF LAWS AND VENUE
21.1 This Agreement shall be construed and interpreted in accordance with the laws ofthe State of
Idaho without reference to its choice of law provisions.
21.2 Venue for any litigation arising out of or related to this Agreement will lie in the District Court of
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----------------------------------------------------------------------------------------
the Fourth Judicial District of Idaho in and for the County of Ada.
ARTICLE XXII: DISPUTES AND DEFAULT
22.1 Disputes -All disputes related to or arising under this Agreement, including, but not limited to,
the interpretation of the terms and conditions of this Agreement, will be submitted to the
Commission for resolution.
22.2 Notice of Default -
22.2.1 Defaults. If either Party fails to perform any of the terms or conditions of this
Agreement (an "event of default"), the non defaulting Party shall cause notice in
writing to be given to the defaulting Party, specifying the manner in which such
default occurred. If the defaulting Party shall fail to cure such default within the sixty
(60) days after service of such notice, or if the defaulting Party reasonably
demonstrates to the other Party that the default can be cured within a commercially
reasonable time but not within such sixty (60) day period and then fails to diligently
pursue such cure, then, the nondefaulting Party may, at its option, terminate this
Agreement and/or pursue its legal or equitable remedies.
22.2.2 Material Breaches -The notice and cure provisions in paragraph 22.2.1 do not apply
to defaults identified in this Agreement as Material Breaches. Material Breaches must
be cured as expeditiously as possible following occurrence of the breach.
22.3 Security for Performance -Prior to the Operation Date and thereafter for the full term of this
Agreement, Seller will provide Idaho Power with the following:
22.3.1
22.3.2
Insurance -Evidence of compliance with the provisions of paragraph 15.2. If Seller
fails to comply, such failure will be a Material Breach and may only be cured by
Seller supplying evidence that the required insurance coverage has been replaced or
reinstated;
Engineer's Certifications -Every three (3) years after the Operation Date, Seller will
supply Idaho Power with a Certification of Ongoing Operations and Maintenance (0
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& M) from a Registered Professional Engineer licensed in the State of Idaho, which
Certification of Ongoing 0 & M shall be in the form specified in Appendix C. Seller's
failure to supply the required certificate will be an event of default. Such a default
may only be cured by Seller providing the required certificate; and
22.3.3 Licenses and Permits -During the full term of this Agreement, Seller shall maintain
compliance with all permits and licenses described in paragraph 4.1.1 of this
Agreement. In addition, Seller will supply Idaho Power with copies of any new or
additional permits or licenses. At least every fifth Contract Year, Seller will update the
documentation described in Paragraph 4.1.1. If at any time Seller fails to maintain
compliance with the permits and licenses described in paragraph 4.1.1 or to provide
the documentation required by this paragraph, such failure will be an event of default
and may only be cured by Seller submitting to Idaho Power evidence of compliance
from the permitting agency.
ARTICLE XXIII: GOVERNMENTAL AUTH RlZATION
23.1 This Agreement is subject to the jurisdiction of those governmental agencies having control over
either Party of this Agreement.
ARTICLE XXN: COMMISSION ORDER
24.1 This Agreement shall become finally effective upon the Commission's approval of all terms and
provisions hereof without change or condition and declaration that all payments to be made to
Seller hereunder shall be allowed as prudently incurred expenses for ratemaking purposes.
ARTICLE XXV: SUCCESSORS AND ASSIGNS
25.1 This Agreement and all of the terms and provisions hereof shall be binding upon and inure to the
benefit of the respective successors and assigns of the Parties hereto, except that no assignment
hereof by either Party shall become effective without the written consent of both Parties being
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------.--------------------------.-----------
first obtained. Such consent shall not be unreasonably withheld. Notwithstanding the foregoing,
any party which Idaho Power may consolidate, or into which it may merge, or to which it may
conveyor transfer substantially all of its electric utility assets, shall automatically, without further
act, and without need of consent or approval by the Seller, succeed to all of Idaho Power's rights,
obligations and interests under this Agreement. This article shall not prevent a financing entity
with recorded or secured rights from exercising all rights and remedies available to it under law
or contract. Idaho Power shall have the right to be notified by the financing entity that it is
exercising such rights or remedies.
ARTICLE XXVI: MODIFICATION
26.1 No modification to this Agreement shall be valid unless it is in writing and signed by both Parties
and subsequently approved by the Commission.
ARTICLE XXVII: TAXES
27.1 Each Party shall pay before delinquency all taxes and other governmental charges which, if failed
to be paid when due, could result in a lien upon the Facility or the Interconnection Facilities.
ARTICLE XXVill: NOTICES
28.1 All written notices under this agreement shall be directed as follows and shall be considered
delivered when deposited in the U. S. Mail, first-class postage prepaid, as follows:
To Seller: Notch Butte Wind Park, LLC
Attn: James T. Carkulis
515 N 271h Street
P.O. Box 7218
Boise, Idaho 83702
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------------------------
To Idaho Power:
Original document to:
Vice President, Power Supply
Idaho Power Company
POBox 70
Boise, Idaho 83707
Copy of document to:
Cogeneration and Small Power Production
Idaho Power Company
POBox 70
Boise, Idaho 83707
ARTICLE XXIX: ADDITIONAL TERMS AND CONDITIONS
29.1 This Agreement includes the following appendices, which are attached hereto and included by
reference:
Appendix A
Appendix B
Appendix C
Generation Scheduling and Reporting
Facility and Point of Delivery
Engineer's Certifications
ARTICLE XXX: SEVERABILITY
30.1 The invalidity or unenforceability of any term or provision of this Agreement shall not affect the
validity or enforceability of any other terms or provisions and this Agreement shall be construed
in all other respects as if the invalid or unenforceable term or provision were omitted.
ARTICLE XXXI: COUNTERPARTS
31.1 This Agreement may be executed in two or more counterparts, each of which shall be deemed an
original but all of which together shall constitute one and the same instrument.
ARTICLE XXXII: ENTIRE AGREEMENT
32.1 This Agreement constitutes the entire Agreement of the Parties concerning the subject matter
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hereof and supersedes all prior or contemporaneous oral or written agreements between the
Parties concerning the subject matter hereof.
IN WITNESS WHEREOF, The Parties hereto have caused this Agreement to be executed
in their respective names on the dates set forth below:
Idaho Power Company Notch Butte Wind Park L.L.C.
By By ~CLL
/' James T. Carlmlis C. Miller, Sr. Vice President, Power Supply
Dated Dated
/6 // "ltJ j--
"Idaho Power" "Seller"
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--------------------------------------------------------------
APPENDIX A
A -1 MONTHLY POWER PRODUCTION AND SWITCHING REPORT
At the end of each month the following required documentation will be submitted to:
Idaho Power Company
Attn: Cogeneration and Small Power Production
PO Box 70
Boise, Idaho 83707
The Meter readings required on this report will be the reading on the Idaho Power Meter
Equipment measuring the Facility's total energy production, Station Usage, Inadvertent Energy delivered
to Idaho Power and the maximum generated energy (kW) as.recorded on the Meter Equipment and/or any
other required energy measurements to adequately administer this Agreement.
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Idaho Power Company
Cogeneration and Small Power Production
MONTHLY POWER PRODUCTION AND SWITCffiNG REPORT
Project Name
Address
City
Meter Number:
End of Month kWh Meter Reading:
*
1
2
3
4
5
6
7
Beginning of Month kWh Meter:
Difference:
Times Meter Constant:
kWh for the Month:
Metered Demand:
Breaker Opening Record
Breaker Opening Reason Codes
Lack of Adequate Prime Mover
Forced Outage of Facility
Disturbance of IPCo System
Scheduled Maintenance
Testing of Protection Systems
Cause Unknown
Other (Explain)
State
*1
I
I
Facility
Output
Month
Zip
Station
Usage
Year
Project Number:
Phone Number:
Station
Usage
Metered
Maximum Generation
kW
Net Generation
Breaker Closing Record
Reason
I hereby certify that the above meter readings are
true and correct as of Midnight on the last day of the
above month and that the switching record is accurate
and complete as required by the Firm Energy Sales
Agreement to which I am a Party.
Signature Date
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A-2 ROUTINE REPORTING
Idaho Power Contact Information
Daily Energy Production Reporting
Call daily by 10 a.m., 1-800-356-4328 or 1-800-635-1093 and leave the following
information:
• Project Identification -Project Name and Project Number
• Current Meter Reading
• Estimated Generation for the current day
• Estimated Generation for the next day
Planned and Unplanned Project outages
Call 1-800-345-1319 and leave the following information:
• Project Identification -Project Name and Project Number
• Approximate time outage occurred
• Estimated day and time of project coming back online
Seller's Contact Information
24-Hour Project Operational Contact
Name:
Telephone Number:
Cell Phone:
Project On-site Contact information
Telephone Number: ________ _
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APPENDIXB
FACllJTY AND POINT OF DELIVERY
PROJECT NO. 31615300
NOTCH BUTTE WIND PARK
B-1 DESCRIPTION OF FACn.ITY
B-2
The Facility will consist of 12 Wind turbines; model 77 GE SLE with individual generator ratings
of 1.5 MW for each unit, for a total Facility generator rating of 18.0 MW.
LOCATION OF FACn.ITY
Near:
Sections: 36 Township: R06S Range: R16E County: Jerome Idaho.
Sections: 3,4,5,6,8,9 Township: T07S Range: R17E County: Jerome Idaho
Sections: 3,4,5,8,9 Township: T07S Range: R17E County: Lincoln Idaho
B-3 SCHEDULED FIRST ENERGY AND OPERATION DATE
Seller has selected November 1, 2006 as the estimated Scheduled First Energy Date.
Seller has selected _-,M=aJ-v..;l'-'.-, =20-"-0"-'7'--__ as the estimated Scheduled Operation Date.
In making these selections, Seller recognizes that adequate testing of the Facility and completion
of all requirements in paragraph 5.2 of this Agreement must be completed prior to the project
being granted an Operation Date. Idaho Power, based on the information supplied by the Seller,
will schedule its construction in accordance with Schedule 72 and the Generation Interconnection
Process.
B-4 MAXIMUM CAPACITY AMOUNT: This value will be 19.2 MW which is consistent with the
value provided by the Seller to Idaho Power in the Generation Interconnection process. This
value is the maximum energy (MW) that potentially could be delivered by the Seller's Facility to
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the Idaho Power electrical system at any moment in time.
B-5 POINT OF DELIVERY
"Point of Delivery" means, unless otherwise agreed by both Parties, the point of where the Sellers
Facility's energy is delivered to the Idaho Power electrical system. The Idaho Power Generation
Interconnection process will determine the specific Point of Delivery for this Facility. Upon
completion of the Generation Interconnection process the Point of Delivery identified by this
process will become an integral part of this Agreement.
B-6 LOSSES
If the Idaho Power Metering equipment is capable of measuring the exact energy deliveries by the
Seller to the Idaho Power electrical system at the Point of Delivery, no Losses will be calculated
for this Facility. If the Idaho Power Metering is unable to measure the exact energy deliveries by
the Seller to the Idaho Power electrical system at the Point of Delivery, a Losses calculation will
be established to measure the energy losses (kWh) between the Seller's Facility and the Idaho
Power Point of Delivery. This loss calculation will be initially set at 2% of the kWh energy
production recorded on the Facility generation metering equipment. At such time as Seller
provides Idaho Power with the electrical equipment specifications (transformer loss
specifications, conductor sizes, etc) of all of the electrical equipment between the Facility and the
Idaho Power electrical system, Idaho Power will configure a revised loss calculation formula to
be agreed to by both parties and used to calculate the kWh Losses for the remaining term of the
Agreement. If at anytime during the term of this Agreement, Idaho Power determines that the
loss calculation does not correctly reflect the actual kWh losses attributed to the electrical
equipment between the Facility and the Idaho Power electrical system, Idaho Power may adjust
the calculation and retroactively adjust the previous months kWh loss calculations.
B-7 METERING AND TELEMETRY
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The Idaho Power Generation Interconnection process will determine the specific metering and
telemetry requirements for this Facility. At the minimum the Metering Equipment and Telemetry
equipment must be able to provide and record hourly energy deliveries to the Point of Delivery
and any other energy measurements required to administer this Agreement. These specifications
will include but not be limited to equipment specifications, equipment location, Idaho Power
provided equipment, Seller provided equipment, and all costs associated with the equipment,
design and installation of the Idaho Power provided equipment. The entire Generation
Interconnection process, including but not limited to the equipment specifications and
requirements will become an integral part of this Agreement. Seller will arrange for and make
available at Seller's cost communication circuit(s) compatible to Idaho Power's communications
equipment and dedicated to Idaho Power's use terminating at the Idaho Power facilities capable of
providing Idaho Power with continuous instantaneous information on the Facilities energy
production. Idaho Power provided equipment will be owned and maintained by Idaho Power,
with total cost of purchase, installation, operation, and maintenance, including administrative cost
to be reimbursed to Idaho Power by the Seller. Payment of these costs will be in accordance with
Schedule 72 and the total metering cost will be included in the calculation of the Monthly
Operation and Maintenance Charges specified in Schedule 72.
B-7 SPECIAL FACll.JTIES
The Idaho Power Generation Interconnection process will determine the Special Facility
requirements for this Facility. These specifications will include but not be limited to equipment
specifications, equipment location, Idaho Power provided equipment, Seller provided equipment,
and all costs associated with the equipment, design and installation of the Idaho Power provided
equipment. The entire Generation Interconnection process, including but not limited to the
equipment specifications and requirements will become an integral part of this Agreement. Idaho
Power owned equipment will be maintained by Idaho Power, with total cost of purchase,
installation, operation, and maintenance, including administrative cost to be reimbursed to Idaho
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----------------
Power by the Seller. Payment of these costs will be in accordance with Schedule 72 and the total
Special Facility cost will be included in the calculation of the Monthly Operation and
Maintenance Charges specified in Schedule 72.
B-8 REACTIVE POWER
The Idaho Power Generation Interconnection process will determine the reactive power required
to be supplied by Idaho Power to the Seller, based upon information provided by the Seller. The
Generation Interconnection process will specify the equipment required on the Idaho Power
system to meet the Facility's reactive power requirements. These specifications will include but
not be limited to equipment specifications, equipment location, Idaho Power provided equipment,
Seller provided equipment, and all costs associated with the equipment, design and installation of
the Idaho Power provided equipment. The entire Generation Interconnection process, including
but not limited to the equipment specifications and requirements will become an integral part of
this Agreement. Idaho Power owned equipment will be maintained by Idaho Power, with total
cost of purchase, installation, operation, and maintenance, including administrative cost to be
reimbursed to Idaho Power by the Seller. Payment of these costs will be in accordance with
Schedule 72 and the total reactive power cost will be included in the calculation of the Monthly
Operation and Maintenance Charges specified in Schedule 72.
B-9 DISCONNECTION EQUIPMENT
Disconnection Equipment is required to insure that the Seller's Facility will be disconnected from
Idaho Power's system in the event of (1) the Sellers delivery of energy exceeds the Maximum
Capacity Amount or (2) Idaho Power or the Seller require interruption or curtailment of energy
deliveries to Idaho Power or (3) a disturbance on either Idaho Power's system or the Seller's
Facility. The Idaho Power Generation Interconnection process will determine the Disconnection
Equipment specifications and requirements for this Facility, this equipment is for protection of
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the Idaho Power system and equipment only. These specifications will include but not be limited
to equipment specifications, equipment location, Idaho Power provided equipment, Seller
provided equipment, and all costs associated with the equipment, design and installation of the
Idaho Power provided equipment. Seller will install all Seller provided equipment, control wire
and conduit necessary for the operation of the Disconnection Equipment. Through the
Generation Interconnection process, Idaho Power will supply details for the disconnection panel
and will test the equipment prior to any operations of the Facility, Seller will provide drawings of
their interconnection wiring for engineering approval prior to installation. The entire Generation
Interconnection process, including but not limited to the equipment specifications and
requirements will become an integral part of this Agreement. Idaho Power owned equipment will
be maintained by Idaho Power, with total cost of purchase, installation, operation, and
maintenance, including administrative cost to be reimbursed to Idaho Power by the Seller.
Payment of these costs will be in accordance with Schedule 72 and the total Disconnection
Equipment cost will be included in the calculation of the Monthly Operation and Maintenance
Charges specified in Schedule 72.
B-IO COSTS
The Idaho Power Generation Interconnection process and this Agreement will identify all cost for
this Facility to interconnect to the Idaho Power system, including but not limited to the cost of
Metering equipment, Telemetry equipment, Special Facilities, Reactive Power, Disconnection
equipment, Protection equipment and Interconnection Equipment. As specified in the Generation
Interconnection process and in accordance with Schedule 72 and this Agreement the Seller will
reimburse Idaho Power for all costs associated with this equipment. In addition to the equipment,
installation and construction charges as specified above, during the term of this Agreement, Seller
will pay Idaho Power the monthly operation and maintenance charge specified in Schedule 72 or
its successor schedules(s). The monthly operations and maintenance charge will begin on the
first day of the month following the date which Idaho Power has completed installation of the
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Idaho Power provided equipment and the interconnection equipment is available for use by the
Facility. The monthly operations and maintenance charge will be based upon the initial cost paid
by the Seller in accordance with Schedule 72. Upon reconciliation of the actual costs, in
accordance with Schedule 72 the monthly operations and maintenance charge will be adjusted to
reflect the actual cost incurred by Idaho Power and previously charged monthly operation and
maintenance expense will be revised to reflect the actual cost incurred by Idaho Power. Idaho
Power will refund or Seller will remit any underpayment of the adjusted monthly operations and
maintenance charge within sixty (60) days of the determination of this amount.
B-1! SALVAGE
No later than sixty (60) days after the termination or expiration of this Agreement, Idaho Power
will prepare and forward to Seller an estimate of the remaining value of those Idaho Power
furnished Interconnection Facilities as required under Schedule 72, the Generation
Interconnection Process and/or described in this Agreement, less the cost of removal and transfer
to Idaho Power's nearest warehouse, if the Interconnection Facilities will be removed. If Seller
elects not to obtain ownership of the Interconnection Facilities but instead wishes that Idaho
Power reimburse the Seller for said Facilities the Seller may invoice Idaho Power for the net
salvage value as estimated by Idaho Power and Idaho Power shall pay such amount to Seller
within thirty (30) days after receipt of the invoice. Seller shall have the right to offset the invoice
amount against any present or future payments due Idaho Power.
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APPENDIXC
ENGlNEER'S CERTIFICATION
OF
OPERATIONS & MAINTENANCE POLICY
The undersigned on behalf of himself and
__________________ ., hereinafter collectively referred to as "Engineer,"
hereby states and certifies to the Seller as follows:
1. That Engineer is a Licensed Professional Engineer in good standing in the State of Idaho.
2. That Engineer has reviewed the Energy Sales Agreement, hereinafter "Agreement," between
Idaho Power as Buyer, and ----------------,~ Seller, dated
3. That the cogeneration or small power production project which is the subject of the Agreement
and this Statement is identified as IPCo Facility No. and is hereinafter referred to as
the "Project."
4. That the Project, which is commonly known as the ___________ , is located in
Section __ Township ___ . Range ____ , Boise Meridian, ______ County, Idaho.
5. That Engineer recognizes that the Agreement provides for the Project to furnish electrical energy
to Idaho Power for a twenty (20) year period.
6. That Engineer has substantial experience in the design, construction and operation of electric
power plants of the same type as this Project.
7. That Engineer has no economic relationship to the Design Engineer of this Project.
8. That Engineer has reviewed and/or supervised the review of the Policy for Operation and
Maintenance ("O&M") for this Project and it is his professional opinion that, provided said Project has
been designed and built to appropriate standards, adherence to said O&M Policy will result in the
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Project's producing at or near the design electrical output, efficiency and plant factor for a twenty (20)
year period.
9. That Engineer recognizes that Idaho Power, in accordance with paragraph 5.2 of the Agreement,
is relying on Engineer's representations and opinions contained in this Statement.
10. That Engineer certifies that the above statements are complete, true and accurate to the best of his
knowledge and therefore sets his hand and seal below.
By ______________________ _
(P .E. Stamp)
Date __________________________ __
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APPENDIXC
ENGINEER'S CERTIFICATION
OF
ONGOING OPERATIONS AND MAINTENANCE
The undersigned ________________ • on behalf of himself and
hereinafter collectively referred to as "Engineer," hereby
states and certifies to the Seller as follows:
1. That Engineer is a Licensed Professional Engineer in good standing in the State of Idaho.
2. That Engineer has reviewed the Energy Sales Agreement, hereinafter "Agreement," between
Idaho Power as Buyer, and as Seller, dated ___________ _
3. That the cogeneration or small power production project which is the subject of the Agreement
and this Statement is identified as IPeo Facility No. ______ and hereinafter referred to as the
"Project".
4. That the Project, which is commonly known as the ______________ Project,
is located at ______________ -'-
5. That Engineer recognizes that the Agreement provides for the Project to furnish electrical energy
to Idaho Power for a twenty (20) year period.
6. That Engineer has substantial experience in the design, construction and operation of electric
power plants of the same type as this Project.
7. That Engineer has no economic relationship to the Design Engineer of this Project.
S. That Engineer has made a physical inspection of said Project, its operations and maintenance
records since the last previous certified inspection. It is Engineer's professional opinion, based on the
Project's appearance, that its ongoing O&M has been substantially in accordance with said O&M Policy;
that it is in reasonably good operating condition; and that if adherence to said O&M Policy continues, the
Project will continue producing at or near its design electrical output, efficiency and plant factor for the
remaining ___ years of the Agreement.
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9. That Engineer recognizes that Idaho Power, in accordance with paragraph 5.2 of the Agreement,
is relying on Engineer's representations and opinions contained in this Statement.
10. That Engineer certifies that the above statements are complete, true and accurate to the best of his
knowledge and therefore sets his hand and seal below.
By ______________________ _
(P .E. Stamp)
Dffie __________________________ ___
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APPENDIXC
ENGINEER'S CERTIFICATION
OF
DESIGN & CONSTRUCTION ADEQUACY
The undersigned on behalf of himself and
__________________ • hereinafter collectively referred to as "Engineer",
hereby states and certifies to Idaho Power as follows:
1. That Engineer is a Licensed Professional Engineer in good standing in the State of Idaho.
2. That Engineer has reviewed the Firm Energy Sales Agreement, hereinafter "Agreement",
between Idaho Power as Buyer, and as Seller, dated ____ ----'
3. That the cogeneration or small power production project, which is the subject of the
Agreement and this Statement, is identified as IPCo Facility No ________ and is hereinafter
referred to as the "Project".
4. That the Project, which is commonly known as the ___________ _
Project, is located in Section ___ , Township ___ , Range ___ , Boise Meridian,
County, Idaho.
5. That Engineer recognizes that the Agreement provides for the Project to furnish electrical
energy to Idaho Power for a ______ ( __ ) year period.
6. That Engineer has substantial experience in the design, construction and operation of
electric power plants of the same type as this Project.
7. That Engineer has no economic relationship to the Design Engineer of this Project and
has made the analysis of the plans and specifications independently.
8. That Engineer has reviewed the engineering design and construction of the Project,
including the civil work, electrical work, generating equipment, prime mover conveyance system, Seller
furnished Interconnection Facilities and other Project facilities and equipment.
-40-
10/10/2005
9. That the Project has been constructed in accordance with said plans and specifications, all
applicable codes and consistent with Prudent Electrical Practices as that term is described in the
Agreement.
10. That the design and construction of the Project is such that with reasonable and prudent
operation and maintenance practices by Seller, the Project is capable of performing in accordance with the
terms of the Agreement and with Prudent Electrical Practices for a ____ (, ___ ) year period.
11. That Engineer recognizes that Idaho Power, in accordance with paragraph 5.2 of the
Agreement, in interconnecting the Project with its system, is relying on Engineer's representations and
opinions contained in this Statement.
12. That Engineer certifies that the above statements are complete, true and accurate to the
best of his knowledge and therefore sets his hand and seal below.
By _____________ _
(P.E. Stamp)
Date ____________ _
-41-
1011012005
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 2
i5I IDAHO .:!! PCMIER®
An IDACORP Company
zonu Jut 23 MI 8: DB
June 4,2008
Exergy Development Group of Idaho, LLC
Attn: James T. Carkulis
802 W. Bannock, Suite 1200
Boise, ID 83702
Via Certified Mail, Return Receipt Requested
Re: Operation Dates
Dear James:
Randy C. Allphin
Senior Planning Administrator
Tel: [phone]
rallphin@idahoJ)Ower.com
As you have requested, the Scheduled Operation Date for the projects listed below will be
established as September 1,2010. If the projects do not achieve this revised Scheduled Operation Date as
specified in each of the Firm Energy Sales Agreements, Idaho Power may to . , the Agreement(s) and
seek legal andlor equitable recourse. ~
Burley ~utte
2 Oregon Trails
Project Name
6
PU/flu£.
Golden Valley
7 Lava Beds
3 Pilgrim Stage Station
4 _ Thousand Springs
8 MilnerDam
9 Notch Butte
5 Tuana Gulch 10 Salmon Falls
By your signature below you acknowledge that the Scheduled Operation Date as set forth in
Appendix B of each Firm Energy Sales Agreement for the above mentioned projects is hereby amended
,and changed to September 1, 2010. All other terms, conditions, and provisions of those Firm Energy
Sales Agreements remain in full force and effect.
Idaho Power is providing three copies of this documentation. Please sign each copy and return all
three copies to me no later than Friday, June 20, 2008, Idaho Power reserves the right to modify this
document if the signed documents are not received back by this date.
Page 1 of2
POBox 70 Boise, Idaho 83707 1221 W Idaho St. Boise, Idaho 83702
US Mail:
Idaho Power Company
Attn: Randy Allphin
POBox 70
Boise, ID 83707
Overnight Mailing Address:
Idaho Power Company
Attn: Randy Allphin
1221 WIdaho
Boise, ID 83702
Upon receipt of the three signed copies I will arrange for and present this documentation to Idaho
Power Company management for their signatures.
After Idaho Power Company signs these documents, I will return one complete signed original to
you for your records, prepare and file one original with the Idaho Public Utilities Commission (!PUC)
requesting their acceptance of this documentation and keep the thlrd original for our records.
UNDERSTOOD, AGREED AND ACCEPTED:
Signature
Name
Title
Date
CC: Bart Kline (!PCo)
Donovan Walker ([PCo)
Karl Bokenkamp ([Peo)
Mark Stokes (lPCo)
Idaho Power Company
~J 8 b6
M. 1'1~et:.. 5 roV-E:.-'S.
MI\t-l~.f.e, Fb""t~ SUl'f>U1 FLANN/,.J~
I / I I-ZCC>G
Sincerely.
Randy C. Allphin
Page 2 of2
POBox 70 Boise, Idaho 83707 1221 W Idaho St. Boise, Idaho 83702
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 3
An IDACORP company
July 26, 20 II
Randy C. Allphin
Senior Energy Contracts Coordinator
Notch Butte Wind Park, LLC
Attn: James T. Carkulis
802 W. Bannock, Suite 1200
Boise, Idaho 83702
Via Certified Mail, Return Receipt Requested
E-mail Copy: James Carkulis
Peter Richardson
[e-mail]
[e-mail]
Re: Notch Butte Wind Park LLC -Project number: 31615300
Firm Energy Sales Agreement
Mr. Carkulis,
The Firm Energy Sales Agreement ("FESA") between Idaho Power Company and Notch Butte Wind
Park LLC dated October 14th, 2005 specifies in Appendix B, item B3 that the Scheduled Operation Date for
this project shall be May 1,2007. A subsequent letter agreement dated June 4,2008 revised the Scheduled
Operation Date to be September 1, 2010.
Paragraph 5.3 of this same FESA states; "SelJer's failure to achieve the Operation Date within ten
(10) months of the Scheduled Operation Date will be an event of Default". Ten months from the Scheduled
Operation Date calculates to be July 1,2011 (10 months past September 1, 2010).
ntis letter serves as Idaho Power's Notice of Default as of the date of this letter. If this default is not
cured as specified within the FESA Idaho Power will exercise its rights as allowed within the agreement one
of which may be termination of this FESA.
Idaho Power has received the letter from Mr. Richardson dated June 30, 2011 in which Mr.
Richardson acknowledges the default commercial on line date to be July 1 s" 2011". In this same letter Mr.
Richardson introduces a short discussion that this default is being cured by the project making commercially
reasonable efforts and goes on to state that the projects will start construction in approximately forty-five
(45) days from June 30, 2011, and be online by year end 2011.
1
However, the letter does not identifY any specific activity, actual commitment and associated
evidence that would reasonably demonstrate to Idaho Power that the default can be cured within a
commercially reasonable period of time, but not within the sixty (60) day cure period, i.e., by the end of the
year, and that the project is diligently pursuing such cure.
Article 22 of the FESA states that following notice of an event of default that Idaho Power may, at its
option, terminate the FESA and/or pmsue its Legal or equitable remedies if the project fails to cure sucb
default within sixty (60) days after service of such notice, or if the project reasonably demonstrates to Idaho
Power that the default can be cured within a commercially reasonable time, but not within such sixty (60)
day period, and then fails to diligently pursue such cure.
Idaho Power appreciates the project's commitment that it will start construction and cure its default
ofthe FE SA by year end, 2011. Idaho Power will consider this year-end commitment to be the outer limit
of a commercially reasonable time period with which to cure the default if it is not on-line within sixty (60)
days of this Notice of Default. If the default is not cured within said sixty (60) days, then Idaho Power may
exercise its rights to terminate and/or pursue its legal or equitable remedies unless the project demonstrates
that it is diligently pursuing cure of the defaull by the commercially reasonable time period of year end,
2011. If the project is not online by year end 2011, the parties agree that the commercially reasonable
period to cure this default has expired and Idaho Power will proceed with the remedies as allowed within
this Firm Energy Sales Agreement one of which is termination of this Firm Energy Sales Agreement.
If there are any other questions that you have, please feel free to contact me.
Sincerely,
Randy C Allphin
Idaho Power Company
Cc: Donovan Walker (IPCo)
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 4
SMALL GENERATOR INTERCONNECTION REQUEST
(Application Form)
Transmission Provider: IDAHO POWER COMPANY
Designated Contact Person:
Address:
Telephone Number:
Fax:
E-Mail Address:
Rowena Bishop
]221 W. Idaho Street, Boise Tn 83702
208-388-2658
208-388-6647
[e-mail]
An Interconnection Request is considered complete when it provides all applicable and correct
infonnation required below.
Preamble and Instructions
An Interconnection Customers who request interconnection must submit this Interconnection Request by
hand delivery, mail, e-mail, or fax to the Transmission Provider.
Processing Fee or Deposit:
If the Interconnection Request is submitted under the Fast Track Process, the non-refundable processing
fee is $500.
Tfthe Interconnection Request is submitted under the Study Process, whether a (lew submission or an
Interconnection Request that did not pass the Fast Track Process, the Interconnection Customer shall
submit to the Transmission Provider a deposit not to exceed $1,000 towards the cost of the feasibility
study.
Interconnection Customer Information
Legal Name of the Interconnection Customer (or, if an individual, individual's name)
Name: Notch Butte Wind Park, LLC
Contact Person: James T. Carkulis
Mailing Address: 1424 Dodge Ave.
City: Helena State: MT Zip: 59601
Facility Location (if different from above): Section 36, Township R06S, Range RI6E, and ,Section
3,4,5,6,8,9, Township T07S, Range R17E, Jerome County, Idaho, Section 30.31.32, Township T06S,
Range 17 E and Section 3,4,5,8,9, Township T07S, Range Rl7E, Lincoln County, Idaho
Telephone (Day): 406.459.3013 ____ Telephone (Evening): 406.459.3013 __ _
1
Fax: [phone] ________ E-Mail Address: [e-mail] _______ _
A lternative Contact Informatioa (if different from the Interconnection Customer)
Contact Name: --------------------------
Title: _________________________________________________________ ~--______ _
Address: ________________________________________________________________ ___
Telephone (Day): _________ Telephone (Evening): _______________ _
Fax: ______________________________ E-Mail Address: ___________________ _
Application is for: _X __ New Small Generating Facility
___ Capacity addition to Existing Small Generating Facility
If capacity addition to existing facility, please describe: ________________________ _
Will the Small Generating Facility be used for any of the following?
Net Metering? Yes _ No _X_
To Supply Power to the Interconnection Customer? Y es _X_No _
To Supply Power to Others? Yes __ X_No __
For installations at locations with existing electric service to which the proposed Small Generating
Facility will interconnect, provide:
(Local ELectric Service Provider*) (Existing Account Number*)
[*To be provided by the Interconnection Customer if the local electric service provider is different from
the Transmission Provider]
ContactNrune: ___________________________________________________________ _
Title: ______________________________________ ~ ________________________ _
Address: __________________________________________________________________ _
Telephone (Day): _____________ Telephone (Evening): _________ _
Fax: _________________________________ E-Mail Address: __________ _
Requested Point ofInterconnection: As per facility address
Interconnection Customer's Requested In-Service Date: May 2007
3
Small Generating Facility Information
Data apply only to the Small Generating Facility, not the Interconnection Facilities.
Energy Source: _ Solar _ Wind _ ~ Hydro _ Hydro Type (e.g. Run-of-River): _____ _
Diesel Natural Gas _ Fuel Oil _ Other (state type) ______________ _
Prime Mover: _Fuel Cell __ Recip Engine
_Microturbine
_GasTurb
_PV
Steam Turb
~Other
Type of Generator: __ Synchronous Induction Inverter
Generator Nameplate Rating: lS00 __ kW (Typical)
delivered
Generator Nameplate kV AR: 493
Interconnection Customer or Customer-Site Load: <2. ______ kW (If none, so state)
Typical Reactive Load (if known): _______ _
Maximum Physical Export Capability Requested: 19920 ____ kW
List components of the Small Generating Facility equipment package that are currently certified:
Equipment Type Certifying Entity
1. GE 1.5 MW turbine
2. ABB pad mount transformer 3. ________ __
4. ________ _
5. ________ _
Is the prime mover compatible with the certified protective relay package? x Yes __ No
Generator (or solar collector)
Manufacturer, Model Name & Number: GE 1500 kW sle model wind turbine generator
Version Number: __________ _
Nameplate Output Power Rating in kW: (Summer) 3,391,624_ (Winter) 4,082,420 __
Nameplate Output Power Rating in kV A: (Summer) -493 x 12 (Winter) -493 x 12
Individual Generator Power Factor
Rated Power Factor: Leading: O.90 ___ -.:Lagging: 0.95 ____ _
Total Number of Generators in wind farm to be interconnected pursuant to this
Interconnection Request 12 Elevation: hub hgt. 245' _Single phase _x_Three phase
Inverter Manufacturer, Model Name & Number (if used): ________________ _
List of adjustable set points for the protective equipment or software: ___________ _
Note: A completed Power Systems Load Flow data sheet must be supplied with the Interconnection
Request.
4
Small Generating Facility Characteristic Data (for inverter-based machines)
Max design fault contribution current: ___ _ Instantaneous orRMS?
Harmonics Characteristics: ________________________ _
Start-up requirements: __________________________ _
Small Generating Facility Characteristic Data (for rotating machines)
RPM Frequency: _____ _
(*) Neutral Grounding Resistor (If Applicable): ____ _
Synchronous Generators:
Direct Axis Synchronous Reactance7 Xd: ___ P.U.
Direct Axis Transient Reactance, X'd: P.U.
Direct Axis Subtransient Reactance, X" d: ______ -'P.U.
Negative Sequence Reactance, X2: ____ P.U.
Zero Sequence Reactance, Xo: P.U.
KVA Base: ___________ _
Field Volts: _____ _
Field Amperes: ______ _
Induction Generators:
Motoring Power (kW): -::-____ _
llt or K (Heating Time Constant): ______ _
Rotor Resistance, Rr: -------Stator Resistance, Rs: ______ _
Stator Reactance, Xs: ______ _
Rotor Reactance, Xr: -------Magnetizing Reactance, Xm: ______ _
Short Circuit Reactance, Xdn: ______ _
Exciting Current: ______ _
Temperature Rise: ______ _
Frame Size: -------Design Letter: ______ _
Reactive Power Required In Vars (No Load): _____ _
Reactive Power Required In Vars (Full Load): _____ _
Total Rotating Inertia, H: Per Unit on kV A Base
Note: Please contact the Transmission Provider prior to submitting the Interconnection Request to
detennine if the specified information above is required.
5
Excitation and Governor System Data for Synchronous Gener~tors Only
Provide appropriate IEEE model block diagram of excitation system, governor system and power system
stabilizer (PSS) in accordance with the regional reliability council criteria. A PSS may be determined to
be required by applicable studies. A copy ofthe manufacturer's block diagram may not be substituted.
Interconnection Facilities Information
Will a transformer be used between the generator and the point of common coupling? _x_Yes_No
Will the transformer be provided by the Interconnection Customer? _x_Yes __ No
Transformer Data at' Applicable, for Interconnection Customer-Owned Transformer):
Is the transformer: __ single phase _x_three phase? Size: I 750 __ ----'kV A
Transformer Impedance: ___ % on kV A Base
If Three Phase:
Transformer Primary: __ Volts __ Delta __ Wye __ Wye Grounded
Transformer Secondary: __ Volts __ Delta __ Wye __ Wye Grounded
Transformer Tertiary: __ Volts __ Delta __ Wye __ Wye Grounded
Transformer Fuse Data Of Applicable, for Interconnection Customer-Owned Fuse):
(Attach copy of fuse manufacturer's Minimum Melt and Total Clearing Time-Current Curves)
Manufacturer: TBPI ______ Type: _______ Size: ____ Speed: ______ _
Interconnecting Circuit Breaker (if applicable):
Manufacturer: TBP _____________ Type: . ____ _
Load Rating (Amps): Interrupting Rating (Amps): Trip Speed (Cycles): ___ _
Interconnection Protective Relays Of Applicable):
If Microprocessor-Controlled:
List of Functions and Adjustable Setpoints for the protective equipment or software:
Setpoint Function Minimum Maximum
1.
2.
3.
4.
5.
I TBP = To be provided
6
6.
If Discrete Components:
(Enclose Copy of any Proposed Time-Overcurrent Coordination Curves)
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Current Transfonner Data (If Applicable):
(Enclose Copy of Manufacturer's Excitation and Ratio Correction Curves)
Manufacturer: ______________________ _
Type: ________ Accuracy Class: _ Proposed Ratio Connection: __
Manufacturer: _____________________ ---'-_
Type: ________ Accuracy Class: _ Proposed Ratio Connection: __
Potential Transformer Data Of Applicable):
Manufacturer: _________________ ---,-____ _
Type: ________ Accuracy Class: _ Proposed Ratio Connection: __
Manufacturer: ______________________ _
Type: ________ Accuracy Class: _ Proposed Ratio Connection: __
7
General Information
Enclose copy of site electrical one-line diagram showing the configuration of all Small Generating
Facility equipment, current and potential circuits, lliJd protection and control schemes. This one-line
diagram must be signed and stamped by a licensed Professional Engineer if the Small Generating Facility
is larger than 50 kW. Is One-Line DiagramEnclosed?_'_~Yes __ No
Enclose copy of any site documentation that indicates the precise physical location of the proposed Small
Generating Facility (~ USGS topographic map or other diagram or documentation).
Proposed location of protective interface equipment on property (include address if different from the
Interconnection Customer's address) to be determined as to IPCo connection point. __ _
Enclose copy of any site documentation that describes and details the operation of the protection and
control schemes. Is Available Documentation Enclosed? Yes _x -,No TBP
Enclose copies of schematic drawings for all protection and control circuits, relay current circuits, relay
potential circuits, and alalmlmonitoring circuits (if applicable).
Are Schematic Drawings Enclosed? _Yes _x_No TBP
Applicant Signature
I hereby certify that, to the best of my knowledge, alI the information provided in this Interconnection
Request .is true and correct.
For Interconnection Customer:
8
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 5
SMALL GENERATOR INTERCONNECTION REQUEST
(Application Form)
Transmission Provider: IDAHO POWER COMPANY
Designated Contact Pe.rson:
Address:
Telephone Number:
Fax:
E-Mail Address:
Rowena Bisilop
1221 W. Idaho Street, Boise ID 83702
208-3&8·2658
208-388-5504
[e-mail]
An Interconnection Request is considered complete when. it provides all applicable and correct
information required below.
Preamble and Instructions
An Interconnection Customers who request interconnection must submit this Interconn'ectiol'l Request by
hand delivery, mail, e-mail, or fax to the Transmission Provider.
Processing Fee or Deposit:
I f the interconnection Request passes ALL screensdfSG IP Section 2.2.1, the application may be
submitted under the Fast Track Process, and the n.on-refundable processing fee is $500, PleaSe contact
Idaho Power if you have any questions.
All Interconnection Requsts submitted under the Study Process, whether a new sUbmission Or an
Interconnection Request that did not pass the Fast Track Process, shall submit to the Transmission
Provider a d,~p~jt.l).oHo exceed SJ"(}(fo towards the j;:'6Si"i)f Uie~f~sibjl UY.s!!4c;j.y
Interconnection Customer Informution
Legal Name of the Interconnection Customer (or, ifan individual, individual's name)
Cont:/l_ U?~r~9n: _0..,.;;· ;.....,;;;.L.'-L_,I..;...fJ_~~=--'"-'-__ ~ ____ --'--''-''--.=....--=_-"'-'_''---=='-..:...
Mail!~g Address: .....:~'-O..:.~"--_vJ_..:.:.."....;.,,'-t'J'-rv 0,-, C....:..~"'"t' ,.'-5-'-T..:...~-..:.:.[2P'J>_-_-__ -'--,~;...:::.:.... _______ ~"--
qi)i; BOISe: State: ----:....;:' f)_' __ _
:r~I~phOJ)e (Day): (~~ 13.3b~ "1712
Fax: (;7.0') 3~ (, -11f31
T~i~phon.~J&\I~oillg): (:l6i) _336:4W "
E-Mail A~diess:~!iOeS6!V@.;xii.%.(o~ .. Je;L-lPedl ~Mlo'¥\
"
.--:,
Allcmat-ivt:: Contact Information (ifdifferenl fi'oI11 1h~ ImerCoMcctiQn Customer)
."'-...
: .... ;; •. ". --.. "~. -I' -_ :
WiJt, t.~e-$i'ialt d~,h#ta,qi1g':faciHtY; !j6'4sed f91~aI1Y:Qnh~ fo Ilo\vhig'?
To;Slipti1y;:i?6wel\to; tlie[Criret~on'netHort~Glls'folllcJ:·hY:es-'~,;;...: NO:~ tr:;;~~t!pp.Jfp.fO~~~t~:·QHi~1~¥?.},S?-<$~;~tt:'~~~·'· ---'.,-
FOI' installations at locations with existing electric service to which the proposed Small Generating
Facility will interconnect, provide:
(Local Electric Service Provider*) (Existing Account Number*)
.'~
[*To be provided by the interconnectioll Customer if the local electric service provider is different from
the Transmission Provider]
Contact Name: __________________________________ _
Title: _________________________________________ _
Address: _______________________________________ _
Telephone (Day): _____________ Telephone (Evening): _______ _
Fax: ___________________ E-Mail Address: ______ " ____ _
2
Prime Mover:
Type of(jen~' "Cor: __ Sy".;:.c~""'l"""""_~"""""--""''''''''' .. ",,,''--"'--'-~O<'r.:.l~'',,",'
Oe"ers!or Na\fl'epl)!tc R~f1Dg ,~;(/t..C> RW"":fGypical)
Typical Reactive Load (ifknown); _ /'"
Maximum Physical B~ptrf~il6i 'ty It~t}u '&I~ ~~ t<,'i{
List components of the Small Generating Facility equipment packag" tJu~t are ~_H¥1~eJti fled:
Equipment Type .Certifying Entity 1. ______________ __
2. ________ _
3, ___________ __
4, ______________ __
5, _____________ __
Is the prime mover compatible with the certified protective relay pack~ge? __ ,,_Yes ___ No
Generator (or solar collector)
Mariu(aci'urer, Model Name & Number: _______ -------_~--__ _,,_'_,_-
Versi'on Number: _________ _
IndivIdual Generator Po\-ier'!?.acto
Rated Power Fact r: l~a.dipgi -'-_'-'--_____ ,tagging: ___ ...:.;.....:_.....;:;..~
Total Nlunber of Generators in wind farm to be imerCQmlected plirsuant to this
Interconnection Request: , Elevlition: 'tl ,,-, , _' _, Single phase 1Three phase,
Inverter Manufacturer, Model Nanie /Jl. Numb~tt (iJused): ______________ _
List of adj ustable set points for the protective _equ ipmel)t Or software: __________ _
Note: A completed: Power Sysrell'ls Load Flow data sheet must be supplied with the Interconnection
Request. '
3
Small Generating Facility Charactcristic Data (for invertcr-based machines)
Max design fault contribution cUrI'ent: ____ _ Instantaneous or RMS?
Harmonics Characteristics: ___ ~ ____________________ _
Small Generating Facility Characteristic Data (for rotating machines)
RPM Freql/ency: _____ _
(*) Neutral Grounding Resistor (If Applicable); ____ _
Synchronous Generators:
Direct Axis Synchronous Reactance, Xd: ___ P.U.
Direct Axis Tnmsient Reactance, X'd: P.U.
Direct Axis Subtransient Reactance, X" d: ______ P.U.
Negative Sequence Reactance, Xl: P.U.
Zero Sequence Reactance, Xo: ______ .. P.U.
K VA Base: ___________ _
Field Volts: _____ _
f-ield Amperes: _____ _
Induction Generators:
Motoring Power (kW): _____ _
!/t or K (Heating Time Constant): ------Rotor Resistance, Rr; _____ _
Stator Resistance, Rs: _____ _
Stator Reactance, Xs: _____ _
Rotor Reactance, Xr: _____ _
Magnetizing Reactance, Xm: ____ _
ShOl1 Circuit Reactance, Xci"; _____ _
Exciting Current: _____ _
Temperature Rise: _____ _
Frame Size: _____ _
Des'ign Leiter: ---:-=::-.,..,.",0-:-:=:-:-=
Rea8ire:PQ\V'el"ReqiUi:e"cl: FnYiI'i's.'(No toad): ' R~a~!r Ve: Po\'(e?'Reqtiiliclclfl\' Vrt;:!(riilrUlit(I)~--. "-' ... "-.. -.. "'--'---:";
Total Rotating Inertia, H: Per Unit on k V A Base
Note: Please contact [he Transmission Provider prior to submitting the Interconnection Reg ues[ to
determine if the specified infol'mation above is req uil'ed.
4
Excitation and Governor System Data for Synchronolls Generators Only
Provide appropriate I EEE model block diagram of excitation system, governor system and power system
stabilizer (PSS) in accordance with the regional reliability cOllncil criteria. A PSS may be determined to
be required by applicable studies. A copy of the manufacturer's block diagram may not be substituted.
lnlcrconncction Facilities Inform:1tJon
Will a frallsfdr'rn~ei: be:tJ;>():p; get'\~e¢ti , the geIW!'ilt~ra~g.the; P:9n1tc)(~i?llijnCi.n:~Qll~[ltig1JLyes ,':No
Will!ii~tli~h~fofin~);~ ~~:pf~yldeg: bY.t~~ .• I@#:~{j~rt~~jic)r(¢(i~toi~ei:r~:X:y~s.~.·<·.'N(;
Transformer Data (If Applicable, for Interconnection Customer-Owned Transformer):
Is the transformer: __ single phase __ three phase? Size: _____ kVA
Transformer Impedance: _____ % on kVA Base
If Time Phase:
Transformer Primary: __ Volts __ Delta __ Wye __ Wye Grounded
Transformer Secondary: ___ Volts __ Delta __ Wye ___ Wye Grounded
Transformer Tertiary: __ Volts __ Deltll __ Wye __ Wyc Grounded
Tnlnsformer Fuse Dnta (If Anplicable. for Interconnection Customer-Owned Fuse):
(Attach copy of ruse manllfacturer's Minimum Melt and Total Clearing Time-Current Curves)
Manufacturer: ________ Type: Size: ____ Speed: _____ _
Interconnecting Circuit Breaker (if apol icable):
Manufacturer: Type: ___ _
Load Rating (Amps): ____ Interrupting Rating (Amps): _____ Trip Speed (Cycles): ____ .
Interconnection Protective Relays (If Applicable):
I f Microprocessor-Call trolled:
List of Functions and Adjustable Setpoints for the protective equipment or software:
Setpoint Function Minimum Maximum
L
2.
3.
4.
5.
6,
5
[f Discrete Components:
(Enclose Copy of any Proposed Time-Overcurrent Coordination Curves)
Manufilcturer: _____ Type: ___ Style/Catalog No.: Proposed Setting: ____ _
Manufacturer: Type: Style/Catalog No.: Proposed Setting: ____ _
Manufacturer: Type: Style/Catalog No.: Proposed Setting: ____ _
Manufacturer: Type: Style/Catalog No.: Proposed Setting: ____ _
Manufacturer: Type: Style/Catalog No.: ____ Proposed Setting: ____ _
CUrren! Transformer Data (If Applicable):
(Enclose Cnpy of Manufacturer's Excitation and Ratio Correction Curves)
Manufacturer: ____ ~-----::-:-------~___:-:__-_:_-
Type: _______ Accuracy Class: _ Proposed Ratio Connection: __
Manufacturer: ____ ___:---~-------:-::--:-=__-___:-
Type: _______ Accuracy Class: _ Proposed Ratio Connection: __
Potential Transformer Data (If Applicable):
Manufacturer: _____________________ _
Type: _______ AccLH'acy Class: _ Proposed Ratio Connection: __
Mantlfacturer: _____________________ _
Type: _______ Accuracy Class: _ Proposed Ratio Connection: __
6
General Information
Enclose copy orsite electrical one-line diagram showing the confIguration of all Small Generating
Facility equipment, current !lnd potential circuits, and protection and control schemes. This one-line
diagram mllst be signed !lnd stamped by a licensed Professional Engineer if the Small Generating Facility
is larger than 50 kW. Is One~Lfi1e Di~grirlJ: E~C/osed1'·;'~'<YWs?\i!~.N.o
E;iibfose,~~opy:ofi'iIWsi.ted~~i.tll1~h(@ori that indicates the precise physical location of the proposed Small
Generating Facility (Me. USGS topographic map or other diagram or documentation).
Proposed location of protective interface equipment on pl'opcI1y (i nclude address if dilTerent from the
Interconnection Customer's address) _______________________ _
Enclose copy of any site documentation that describes and details the operation of the protection and
control schemes. Is Available Documentation Enclosed? _Yes __ No
Enclose copies of schematic drawings for all protection and control circuits, relay current circuits, relay
potential circuits, and alann/monitoring circuits (if applicable).
Are Schematic Drawings Enclosed? _Yes __ No
Applicant Signature
I hereby certify that, to the best of my knowledge, all the information provided in this Interconnection
Request is true and correct.
For Interconnection Customer:
7
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BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 6
_ Ij j;)j;iJ fI; I I
)0o/}(}~
SMALL GENERATOR INTERCONNECTION REQUEST
(Application Form)
Transmission Provider: IDAHO POWER COMPANY
Designated Contact Person:
Address:
Telephone Number:
Fax:
E-Mail Address:
Rowena Bishop
1221 W. Idaho Street, Boise ID 83702
208-388-2658
208-388-5504
[e-mail]
An Interconnection Request is considered complete when it provides all applicable and correct
information required below.
Preamble and Instructions
An Interconnection Customers. who requeSt intercolUlection must submit this IntercolUlection Request by
hand delivery, mail, e-mail, or fax to the Transmission Provider.
Processing Fee or Deposit:
If the Interconnection Request passes ALL screens of SGIP Section 2.2.1, the application may be
submitted under the Fast Track Process, and the non-refundable processing fee is $500. Please contact
Idaho Power if you have any questions.
All lnterconnection Requsts submitted under the Study Process, whether a new submission or an
Interconnection Request that d-id not pass the Past Track Process, shall submit to the Transmission
Provider a deposi not to xeeea $1:000 towards the cdsf oHhe teas.ib1liiy stbQY.
Interconnection Customer Information
Legal Name of the Interconnection Customer (or, if an individual, individual's name)
.C?'F lDA Ltc>. L.J-.<:..
../
Contact Person: --=U..;.....Ou.._l-'--lV---I...o;... ____ ----L~---""f'-I(3_r-et<+_:19(--40~-ft-:tH.<.~/---
Mailing Address: -"'__ ___ ...,..;"'--:...;;...-'--~_+~.:...--..J~"'---_.:-:..--'----'~'-----------"-
Zip: 637o~
Facility Location(ifdifferent fr9Ql,~QO,ye):~~~-~.:2.Q 53-il"~', W I/I+--> Iv. >7tlO' , . . .
Telephone (Day)" ( ~ 3~(, -«11'1) Telephone (EVening): (~J;u -~1 ·5
Alternative Contact Information (if different from lhe I.nterconnectLon Customer)
Contact Name: _-=---_____ .......:.----'-'-'-_~~___'_'_'___~ ____ =__ __ _.,;;.. _____ _
Title: _____________ ~ _____________ ~ ____ __
Addre$; ________ ~~~~~~~~~~~~ ________________________ ___
Telephone:(Day): _____ ----' __ --'-'Tel~pti~~~~tli~g): _______ ~.""' .. :'-'-' ';"
Fax: __ --"_'---"''----_'--....:....-.;,;,;,,:....---'-1'_·:.;,...· -_' __ ,,_. ~:. ":EiM'au.J\ddi:ess; _________ _
AppJjaation is f0r: ---"--"--"""' ew' SmaH G.enerEJilii~ FaoHl'1
.......:.-"--~g§e.a£ity, . c1clJtjQn 1Q EXis.ting S~1l Generating.Facility
Wilt the Small GeilenitingFactlit}' b~·lJSea·for:aIty;orthe following?
T.o S ipP.1;Y Pawe/ to th~ futtteQIlq,eoUQn C\lste.me{? Yes _No. "'i..
0, ·~u@~y. P,o~ver t 0jJreJS?-Yes I ~,..:.;O><--,
For installations at locations with existing electric service to which the proposed Small Gen.etating
Facility will interconnect, provide:
(Local Electric Service Provider*) (Existing Account Number*)
[*To be provided by the Interconnection Customer if the local electric service provider is different from
the Transmission Provider]
ContactNffiUe: _______________________________ _
Title: _________________________________ _
Address: _________________________________ _
Telephone (Day): ____________ Telephone (Evening): ________ _
Fax: _________________ E-Mail Address: __________ _
Requested Point of Interconnection: -'----"'--~"--'-=----'--"----.I----r--'---'-.....!...---'~------~
Interconnection Customer's Requested In-Service Date: ----'-+-I--+~I---___v.A"""..--.".-------
2
Small Generating Facility Information
Data apply only to the Small Generating Facility, not the Interconnection Facilities.
Energy Source: ,_' _' , Solar .x... Wind _ Hydro _ Hydro Type (e.g. Run-of-River): __ ---:..::.-...:.-'--
, '= DieseL.,,,., Natural Gas. _. _' F~el OR _" Othe.r (stat~Jype), ____ ---"'-_-'"'-":..:...::=
PtjOle Move: _f ue t~1I ,-R,~9Jp E,:.9.&!I!t!._ .,~q~ "I'll~b .
_Micr6furbioe " _PV
_.steam urb
_Othel:
Generator Nameplate leY AR; .. ,v, ,<""
Typical Reactive Load (if known): ______ _
MaxiinU!D;Phys"ic::W Export Capability Requeste~: t1.fcO kW I
List components of the Small Generating Facility equipment package that are cUlTently certified:
Equipment Type Certifying Entity 1. __________________ _
2. __________________ _
3. ________ _
4. __________ __
5. _____________ __
Is the prime mover compatible with the certitled protective relay package? Yes No
Generator (or solar collector)
Manufacturer, Model Name & Number: ______________________________________________ __
Version Number: ____________________ _
Naitieptate:<:)mPut Power Rating in kW: (Summer) \I@O (\Vinle!) )\ ,<'(1)0> Narfiep{~te' Output Power Rating in kVA: (Summer) ....,.I"-----(Winter) _---==--__ -'
Individu81 Generator Power Factor
Rated PriVkr'Factor: Leading: ____ ~Lagging:_--'-___ _
Total Number of Generators in wind farm to be interconnected pursuant to this
Interconnection Request: b Elevation: ~ _Single phase XThree phase
Inverter Manufacturer, Model Name & Number (if used): ______________________________ __
List of adjustable set points for the protective equipment or software: ___________________ _
Note: A completed Power Systems Load Plow data sheet must be supplied wilh the Interconnection
Request.
3
Small Generating Facility Characteristic Data (for inverter-based m.achines)
Max design fault contribution current: ____ _ Instantaneous orRMS?
Hafmonics Characteristics: ________________________ _
Start-up require,rpents: ________________________ _
Small Generating Facility Characteristic Data (for rotating machines)
RPM Fr.equehcy: _____ _
(*) Neutral Grounding Resistor (If Applicable): ____ _
SYnchronous Generators:
Direct Axis Synchronous Reactance, Xd: __ ~ P.U.
Direct AXis TransiehtReactance, X'd: P.U.
Dii;'ectAxis SubttansientReactance, X" d: ______ P.U,
Negative $equenceReactance, X2: ____ P. U.
Zero Sequence Reactance, Xo: P.U.
KVABase: __________ _
Field Volts: _____ _
Field Amperes: _____ _
Induction Generators:
Motoring Power (kW): _____ _
12Zt or K (Heating Time Constant): _____ _
Rotor Resistance; Rr: _____ _
Stator Resistance; Rs: _____ _
Stator Reac~ce, Xs: _____ _
Rotor Reaqta,nc~, Xr: _____ _
MagnetizingReactai;lce, Xm: _____ _
Short Circuit Reactance, Xd": _____ _
Exciting Current: _____ _
Temperature ~jse: _____ _
Frame Size: _____ _
Design Letter: _____ _
Reac61Ve£o\Y..cr Requhted In.:V;ars:(No Load): _____ _
Reaotive Power Req.ufreo Io Vars (Full Load): ___ --,---:---,-_
Total Rotating Inertia, H: Per Unit on kV A Base
Note: Please contact: the Transmission Provider prior to submitti.ng the Interconnection Request to
determine if the specified information above is required.
4
Excitation and Governor System Data for Synchronous Generators Only
Provide appropriate IEEE model block diagram of excitation system, governor system and power system
stabilizer (PSS) in accordance with the regional reliability council criteria A PSS may be determined to
be required by applicable studies. A copy of the manufacturer's block diagram may not be substituted.
WiIl'thetmiliif6:Mfei'b!Vprovided by the Intercortiu~ct1on 'CUstomer? -£Ves _" '_-,_NQ
TransfOlmer Data err Applicable. for interconnection Customer-Owned Transformer):
Is the transformer: __ single phase __ three phase? Size: _____ kVA
Transformer Impedance: % on kV A Base
If Three Phase:
Tmnsfonner Primary: __ VoH:; __ Delta __ \JI/ye __ Wye Grounded
Tninsfo11I\er Secondary: __ Volts __ Delta __ Wye __ W'ye Gtounded
Transfonner Teltiary: __ Volts __ Delta __ Wye __ Wye Grounded
Transformer Fuse Data Of Applicable, fc:Jr fntercOlmection Customer-Owned Fuse):
(Attach copy of fuse manufacturer's Minimum Melt and Total Clearing Time-Current Curves)
Manufacturer: ________ Type: _______ Size: ____ Speed: _____ _
Interconnecting Circuit Breaker (if applicable):
Manufacturer: _-----, ______ -----,---:---:-----:--Type: ____ _
Load Rating (Amps): Interrupting Rating CAmps): Trip Speed (Cycles): ___ _
futerconnection Protective Relays Of Applicable):
If Microprocessor-Contro lied:
List of Functions and Adjustable Setpoints for the protective equipment or software:
Setpoint Function Minimum Maximum
1.
2.
3.
4.
5.
6.
5
If Discrete Components:
(Enclose Copy of any Proposed Time-Overcurt'ent Coordination Curves)
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Man ufacturel': Type: Style/Catalog No.: Proposed Setting:
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Mamrfacturer: Type: Style/Catalog No.: Proposed Setting;
Current Transformer Data (If Applicable):
(Enclose Copy of Manufacturer's Excitation and Ratio Correction Curves)
Manufacturer: ----------------------------------------~ Type: _____________ Accuracy Ciass: __ Proposed Ratio Connection: __
Manufacturer: ------------------------------------------Type: _____________ Accuracy Class: __ Proposed Ratio Connection: __
Potential Transformer Data (If Applicable):
Manufacturer: ----------------------------------~ Type: ____________ Accuracy Class: __ Proposed Ratio Connection: __
Manufacturer: _____________________________________ __
Type: ____________ Accuracy Class: __ Proposed Ratio Connection: __
6
General Information
Enclose copy of site electrical one-line diagram showing the configuration of all Small Generating
Facility equipment, cutrent and potential circuits, and protection and control schemes. This one-line
diagram must be signed and stamped by a licensed Professional Engineer if the Small Generating Facility
is larger than 50 kW. Is One-Line Diagram Enolosed? __ Y;es...lC 0
~Mtj).~·¢QpY of any site documentation that indicates the precise physica11ocation of the proposed Small
Generating Facility (~ USGS topographic map or other diagram or (tocwnentation).
Proposed location of protective interface equipment on property (include address if-different from the
Interconnection Customers address) _____________________ _
Enclose copy of any site documentation that describes and details the operation of the protection and
control schemes. Is Available Documentation Enclosed? _Yes __ No
Enclose copies of schematic drawings for all protection and control circuits, relay current circuits, relay
potential circuits, and alannfmonitotingcircuits (if applicable).
Are Schematic Drawings Enclosed? _Yes __ No
Applicant Signature
I hereby certify that, to the best of my knowledge, all the infonnation provid'ed in thi~ Interconnection
Request is true and correct.
For Interconnection Customer:
Date; 10/ ~12Y(<> --~'-~~--------------------~~ ({ ------
~
Lou" I t-t ~U()~t?rJ
7
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 7
"'-;IDAHO .. POWER
An IDACORP Companv
James Carkulis
IDAHO POWER COMPANY
1221 W.IDAHO STREET
BOISE. 1083702
1424 Dodge Avenue
Helena MT 59601
Ph 406-459-3013
Dear Mr. Carkulis:
December 22, 2005
Re: Notice of Incomplete Interconnection Application
Date Applica/ioll Project Name Proposed Locatioll
Received
12/l9/05 Golden Valley Wind Park Cassia County, ID
12/19/05 Milner Dam Wind Park Cassia County, ID
12/19/05 Lava Beds Wind Park Bingham County, ID
12/l9/05 Notch Butte Wind Park Lincoln County, ID
1211.,905 Salmon Falls Wind Park Twin Falls County, ID
Alllollllt(MW)
TBP
TBP
TBP
TBP
TBP
Thank you for your Generator Interconnection Applications noted above (copies attached). I
have forwarded these applications to our Distribution Planning Leader, Dave Angell, who is
evaluating your request.
In order for an Interconnection Request to be considered valid, all Generation Interconnection
Applications must include certain items before we can proceed. Please clarify or provide the
following for each of the above applications:
1. The required deposit for each application over 2 MW is a total of $1000. Please provide
the additional amount for each application.
2. Page 2, Will you be supplying power to others?
3. Page 3, Verify this is a wind facility, not hydro.
4. Page 3, Maximum Physical Export Capability & Nameplate output does not match
number of units.
5. Page 3, Please provide a completed Power Systems Load Flow data sheet.
6. Page 4, Please provide all data under the INDUCTION section.
7. Page 5, Please provide Transformer Impedance and Three Phase primary. Secondary &
Tertiary information.
8. Page 6, Please provide Current Transformer Data information.
9. Page 7. ALL items need to be provided on this page.
These items must be provided to us on or before the Scoping Meeting in order for you to retain
your position in the Application queue. Dave will be in touch with you to coordinate the
Scoping meeting.
For your reference, enclosed is a copy of Idaho Power Company's Requirements for Generation
Interconnection. This and more information about the Interconnection process can be found on
the [daho Power website at:
http://www.idahopoweI..com/abouLus/b us i ness/ generatio nlnterconnectl
Please refer to the website periodically for a list of current projects. At this time, Idaho Power
Company is unable to establish a specific timeline for work on your project, but it has been
placed on the project list and will be worked on appropriately.
For your review, I am attaching a copy of your applications, along with the standard
Interconnection Feasibility Study Agreement that needs to be executed during or soon following
our Scoping Meeting. Please feel free to contact Dave at 208-388-2701, or me at 208-388-2658
with your questions anytime~
Attachments
Sincerely, !!:.~:ap¥
Operations Analyst
Grid Operations & Plarming
[phone]
[e-mail]
Interconnection Applications submitted 12/19105
Idaho Power Company's Requirements for Generation Interconnection
Standard futerconnection Feasibility Study Agreement
Cc: Dave Angell/IPC
Feasibility Study Agreement
THIS AGREEMENT is made and entered into this __ day of 20_ by and
betweeo , a organized and
existing under the laws of the State of , ("Interconnection
Customer,") and Idaho Power Company a Corporation existing under the laws of the State of Idaho ("Transmission
Provider"). Interconnection Customer and Transmission Provider each may be referred to as a "Parly," or
collectively as the "Parties."
RECITALS
WHEREAS, Interconnection Customer is proposing to develop a Small Generating Facility or generating capacity
addition to an existing Small Generating Facility consistent with the Interconnection Request completed by
Interconnection Customer on ; and
WHEREAS, Interconnection Customer desires to interconnect the Small Generating Facility with the Transmission
Provider's Transmission System; and
WHEREAS, Interconnection Customer has requested the Transmission Provider to perform a feasibility study to
assess the feasibility of interconnecting the proposed Small Generating Facility with the Transmission Provider's
Transmission System, and of any Affected Systems;
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein the Parties agreed
as follows:
1.0 When used in this Agreement, with initial capitalization, the terms specified shall have the meanings
indicated or the meanings specified in the standard Small Generator Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause to be pelformed an
inter 'lection feasibility study consistent the standard Small Generator Interconnection Procedures in
acc,-.lce with the Open Access Transmission Tariff.
3.0 The scope of the feasibility study shall be subject to the assumptions set forth in Attachment A to this
Agreement.
4.0 The feasibility study shall be based on the technical information provided by the Interconnection Customer
in the Interconnection Request, as may be modified as the result of the scoping meeting. The Transmission
Provider reserves the right to request additional technical information from the Interconnection Customer
as may reasonably become necessary consistent with Good Utility Practice during the course of the
feasibility study and as designated in accordance with the standard Small Generator Interconnection
Procedures. If the Interconnection Customer modifies its Interconnection Request, the time to complete the
feasibility study may be extended by agreement of the Parties.
5.0 In performing the study, the Transmission Provider shall rely, to the extent reasonably practicable, on
existing studies of recent vintage. The Interconnection Customer shall not be charged for such existing
studies; however, the Interconnection Customer shall be responsible for charges associated with any new
study 01' modifications to existing studies that are reasonably necessary to pelform the feasibility study.
6.0 The feasibility study report shall provide the following analyses for the purpose of identifying any potential
adverse system impacts that would result from the interconnection of the Small Generating Facility as
proposed:
6.1 Initial identification of any circuit breaker short circuit capability limits exceeded as a result of the
interconnection;
6.2 Initial identification of any thermal overload or voltage limit violations reSUlting from the
interconnection;
6.3 Initial review of grounding requirements and electric system protection; and
6.4 Description and nOll-bonding estimated cost of facilities required to interconnect the proposed
Small Generating Facility and to address the identified short circuit and power flow issues.
7.0 The feasibility study shall model the impact of the Small Generating Facility regardless of purpose in order
to avoid the further expense and interruption of operation for reexamination of feasibility and impacts if the
Interconnection Customer later changes the purpose for which the Small Generating Facility is being
installed.
8.0 The study shall include the feasibility of any interconnection at a proposed project site where there could be
mUltiple potential Points of Interconnection, as requested by the Interconnection Customer and at the
Interconnection Customer's cost.
9.0 A deposit of the lesser of 50 percent of good faith estimated feasibility study costs or earnest money of
$1,000 may be required from the Interconnection Customer.
10.0 Once the feasibility study is completed, a feasibility study report shall be prepared and transmitted to the
Interconnection Customer. Barring unusual circumstances, the feasibility study must be completed and the
feasibility study report transmitted within 30 Business Days of the Interconnection Customer's agreement to
conduct a feasibility study.
11.0 Any study fees shall be based on the Transmission Provider's actual costs and will be invoiced to the
Interconnection Customer after the study is completed and delivered and will include a summary of
professional time.
12.0 The Interconnection Customer must pay any study costs that exceed the deposit without interest within 30
calendar days on receipt of the invoice or resolution of any dispute. If the deposit exceeds the invoiced
fees, the Transmission Provider shall refund such ex.cess within 30 calendar days of the invoice without
interest.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their duly authorized
officers or agents on the day and year tirst above written.
Transmission Provider: Interconnection Customer:
Idaho Power Company -Delivery
Signed, _____________ Signed ___________ _
Name (Printed): Name (Printed):
Title _____________ Title ___________ _
Date, _____________ _ Date ______________ _
Assumptions Used in Conducting the Feasibility Study
The feasibility study will be based upon the information set forth in the Interconnection Request and agreed upon in
the scoping meeting held on ________ _
J) Designation of Point of Interconnection and configuration to be studied.
2) Designation of alternative Points of Interconnection and contiguration.
J) and 2) are to be completed by the Interconnection Customer. Other assumptions (listed below) are to be provided
by the Interconnection Customer and the Transmission Provider.
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 8
July 7, 2006
via email and Certified Mail
James Carkulis
Exergy Development Group, LLC
P.O Box 5212
Helena, MT 59601
Dear Mr. Carkulis
RE:
Pro 'eel name
Notch Butte Wind Park
Amount (MW)
19.92
;!)
M iOACORP Comoanv
This letter is to inform you of the progress of your generation interconnection request referenced
above. Since our initial Scoping Meeting, we have NOT received your designated Point of
Interconnection (POI) for this project.
Attached please find a draft Feasibility Study Agreement for your Generation Interconnection
request. The Feasibility Study is a preliminary evaluation of the feasibility of the proposed
intercoIUlection to Idaho Power Company's electrical system. The estimated cost for the
Feasibility Study to be performed is covered by your application fee.
If this Agreement is acceptable to you, please sign and return a copy to us. We must receive
your response no later than 30 Calendar after your receipt of this letter, or we will consider your
request to have been withdrawn and terminated.
We will continue to keep you apprised as we go through the study process to insure continued
agreement and understanding. Please contact me as soon as possible if you have any questions.
Sincerely,
A:2~¥
David M. Angell
PI arming Leader
Attachments
P.(t BOll '0 (83701)
t 22 t, W. Id3ho St.
8ohe.ID 8P02
Feasibility Study Agreement
Notch Butte Wind Park Project
Feasibility Study Agreement
TillS AGREEMENT is made and entered into this __ day of_' ______ 2006 by and
b~ween~ _________________________________________________ ,a
_______________________ o.rganized and exis ting under the laws of the State of
_______________________________ , (,'Interconnection Customer,") and Idaho Power
Company, a Corporation existing under the laws of the State of Idaho ("Transmission Provider").
Interconnection Customer and Transmission Provider each may be referred to as a "Party," or
collectively as the "Parties."
RECITALS
WHEREAS, Interconnection Customer is proposing to develop a Small Generating Facility or
generating capacity addition to an existing Small Generating Facility consistent with the
Interconnection Request completed by Interconnection Customer on December 19, 2005; and
WHEREAS, Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Provider's Transmission System; and
WHEREAS, Interconnection Customer has requested the Transmission Provider to perform a
feasibility study to assess the feasibility of interconnecting the proposed Small Generating
Facility with the Transmission Provider's Transmission System, and of any Affected Systems;
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the terms specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause to be
performed an interconnection feasibility study consistent the standard Small Generator
Interconnection Procedures in accordance with the Open Access Transmission Tariff.
3.0 The scope of the feasibility study shall be subject to the assumptions set forth in
Attachment .1:1., to this Agreement.
4.0 The feasibility study shall be based on the technical information provided by the
Interconnection Customer in the Interconnection Request, as may be modified as the
result of the scoping meeting. The Transmission Provider reserves the right to request
additional technical information from the Interconnection Customer as may reasonably
become necessary consistent with Good Utility Practice during the course of the
feasibility study and as designated in accordance with the standard Small Generator
Interconnection Procedures. If the Interconnection Customer modifies its Interconnection
Request, the time to complete the feasibility study may be extended by agreement of the
Parties.
Page 1 of 4
Feasibility Study Agreement
Notch Butte Wind Park Project
5.0 In performing the study, the Transmission Provider shall rely, to the extent reasonably
practicable, on existing studies of recent vintage. The IntercOIlllection Customer shall not
be charged for such existing studies; however, the Interconnection Customer shall be
responsible for charges associated with any new study or modifications to existing studies
that are reasonably necessary to pelform the feasibility study.
6.0 The feasibility study report shall provide the following analyses for the purpose of
identifying any potential adverse system impacts that would result from the
interconnection of the Small Generating Facility as proposed:
6.1 Initial identification of any circuit breaker short circuit capability limits exceeded
as a result of the interconnection;
6.2 Initial identification of any thermal overload or voltage limit violations resulting
from the interconnection;
6.3 Initial review of grounding requirements and electric system protection; and
6.4 Description and non-bonding estimated cost of facilities required to interconnect
the proposed Small Generating Facility and to address the identified short circuit
and power flow issues.
7.0 The feasibility study shall model the impact of the Small Generating Facility regardless
of purpose in order to avoid the further expense and interruption of operation for
reexamination of feasibility and impacts if the Interconnection Customer later changes
the purpose for which the Small Generating Facility is being installed.
8.0 The study shall include the feasibility of any interconnection at a proposed project site
where there could be multiple potential Points of Interconnection, as requested by the
Interconnection Customer and at the Interconnection Customer's cost.
9.0 A deposit of the lesser of 50 percent of good faith estimated feasibility study costs or
earnest money of $1,000 may be required from the Interconnection Customer.
10.0 Once the feasibility study is completed, a feasibility study report shall be prepared and
transmitted to the Interconnection Customer. Barring unusual circumstances, the
feasibility study must be completed and the feasibility study report transmitted within 30
Business Days of the Interconnection Customer's agreement to conduct a feasibility
study.
11.0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
12.0 The Interconnection Customer must pay any study costs that exceed the deposit without
Page 2 of 4
Feasibility Study Agreement
Notch Butte Wind Park Project
interest within 30 calendar days on receipt of the invoice or resolution of any dispute. If
the deposit exceeds the invoiced fees, the Transmission Provider shall refund such excess
within 30 calendar days of the invoice without interest.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written.
Transmission Provider: Interconnection Customer:
Idaho Power Company -Delivery
Signed __________________________ Signed. ______________________ __
Name (Printed): Name (printed):
Title. ____________ __ Title. _____________________ _
Page 3 of4
Feasibility Study Agreement
Notch Butte Wind Park Project
Attachment A
Assumptions Used in Conducting the Feasibility Study
The feasibility study will be based upon the information set forth in the Interconnection Request
and agreed upon in the scoping meeting held on March 23, 2006:
1) Designation of Point of Interconnection and configuration to be studied.
The proposed location of the project as defined in an email dated April 24, 2006 differs
11 miles from the original location. Exergy must supply a specific POI to be studies.
2) Designation of alternative Points of Interconnection and configuration.
In the scoping meeting IPC agreed that it would provide:
1. How much generation capacity can be installed at each site without re-conductoring
or significant upgrades
2. What upgrades are needed to meet OUT requested capacity
3. Recommended interconnection location for each site (and voltage level
1) and 2) are to be completed by the Interconnection Customer. Other assumptions (listed
below) are to be provided by the Interconnection Customer and the Transmission Provider.
Page 4 of 4
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 9
GENERATOR INTERCONNECTION
FEASIBILITY STUDY
for integration of the proposed
NOTCH BUTTE WIND PARK PROJECT
III
JEROME AND/OR LINCOLN COUNTIES, IDAHO
to the
IDAHO POWER COMPANY ELECTRICAL SYSTEM
for
EXERGY DEVELOPMENT GROUP, LLC
the
INTERCONNECTION CUSTOMER
FINAL REPORT
January 3, 2007
1.0 Introduction
Exergy Development Group, LLC has contracted with Idaho Power Company (IPC) to perform a
Generator Interconnection Feasibility Study for the integration of his new 19.92 MW Notch
Butte Wind Park Project (project #158). The proposed location of the project is in Idaho Power's
southern Idaho service territory in section 36 ofT6S, R16E and sections 30,31,32 ofT6S, R17E
of Lincoln County as well as sections 3,4,5,6,8,9 ofT7S, R17E of Jerome County. This location
starts approximately 1 mile north or west ofIdaho Power's existing Notch Butte substation.
This report documents the basis for and the results of this Feasibility Study for the Notch Butte
Wind Park. It describes the proposed project, the study cases used, the impact of associated
projects, and results of all work in the areas of concern.
2.0 Summary
The proposed project is a 19.92 MW wind park consisting of twelve 1.5 MW wind turbines.
This wind farm will interconnect with the IPC system at about 900 N. and 200 E. in Jerome
County, Idaho.
The transmission line serving this area is Idaho Power's Twin Falls -Hydra -Midpoint 138 kV
line. With the consideration of other proposed generation projects in the queue ahead of this
project there is adequate capacity available on this line to serve this project. However, this study
has identified limitations in the 138 kV transmission system to the west of this area. This study
demonstrates that there is no available transmission capacity when considering the projects in the
generation queue. Therefore, a System Impact Study will be required to determine the
transmission upgrades needed to serve this project.
The substation serving this area is Idaho Power's Notch Butte (NHBT) substation. With the
consideration of the size of the proposed project there is not adequate capacity in this substation
to serve this proj ect. A second substation transformer will be required.
The distribution feeder serving this area is the Notch Butte 011 (NHBT-011) 12.5 kV feeder.
With the consideration of the size of the proposed project there is not adequate capacity on this
feeder to serve this project. A new 34.5 kV feeder will be required to serve this project. About 4
miles of the existing feeder vlill be rebuilt as a double circuit line, vvith the top circuit being a
34.5 kV feeder for the wind park.
Since the wind park could be located along with other Idaho Power customers, a generation
interconnection package will be required at the point of interconnection.
The estimated cost of all required upgrades is $2,114,000. Lead time is about 72 weeks.
The existing feeder can accept up to 3.82 MV A of generation at the point of interconnection
before feeder reconductoring is required.
2
3.0 Scope oflnterconnectionFeasibility Study
The Interconnection Feasibility Study was done and prepared in accordance with Idaho Power
Company Standard Generator Interconnection Procedures, to provide a preliminary evaluation of
the feasibility of the interconnection of the proposed generating project to the Idaho Power
system. All other proposed Generation projects prior to this project in the Generator
Interconnect queue were considered in this study. A current list of these projects can be found
on the Idaho Power web site as follows:
Small Generator «20 MW):
bttp://W'vvw.idabopower.com/aboutus/business/generationlnterconnectigenerationTnterconnect.cfm
Large Generator (2:20 MW):
http://www.oatioasis.comlipco/index.html.
Because of the nature of these projects, this study was performed using the best-known
information available as of this date.
4.0 Description of Proposed Generating Project
The Notch Butte Wind Park proposes to connect to the Idaho Power distribution system for an
injection of 19.92 MW (maximum project output) using twelve GE 1500 kW sle model wind
turbines.
5.0 Description of Existing Transmission Facilities
The transmission line serving this area is Idaho Power's Twin Falls -Hydra -Midpoint 138 kV
line. This line is a 22.85 mile 138 kV line with both 715 and 795 ACSR conductors, which has a
continuous thermal operating rating of 206.9 MV A. With the consideration of other proposed
generation projects in the queue ahead of this project there is adequate capacity available on this
particular line to serve this project. However, the study has identified limitations in the Midpoint
West transmission system to the west of this area. This study demonstrates that there is no
available transmission capacity when considering other proposed generation projects ahead of
this one in the queue. Because of these limitations, a Transmission System Impact Study will be
reguired to determine the next upgrades required to add this project. An existing study is
attached as Appendix C. This study details the existing system limitations and describes the
improvements necessary to increase the capacity of this system another 305 MW. However, this
proposed capacity is already committed to other proposed generation projects currently ahead of
this one in the queue. The proposed study will determine the additional work necessary to
integrate this project into the Idaho Power system.
6.0 Description of Existing Substation Facilities
The substation serving this area is Idaho Power's Notch Butte (NHBT) substation, which is
located at 700 N. and 400 E. in Jerome County. The existing substation transformer is a
3
138:12.5 kV transformer rated for 14.0 MV A. With the consideration of the size of the proposed
project there is not adequate capacity in this substation to serve this project. Alternatives for
increasing substation capacity to handle this project are listed in section 8.
The feeder breakers at NHBT are each Pacific Electric (manufactured by Federal Pacific
Electric) type "JCE 22" breakers designed for 600 amps continuous load current and each have a
maximum fault current interrupting rating of 11,000 amps. These breakers are operating on 12.5
kV feeders . Because of the size of the proposed project these breakers will not handle the load
current requirement. A new 34.5 kV feeder with a new breaker is proposed. Initial studies
indicate that there is adequate load and short circuit interrupting capability on all other affected
breakers.
7.0 Description of Existing Distribution Facilities
The point of interconnection is defined for this study as the intersection of 900 N. and 200 E. in
Jerome County, Idaho. This location is on the border between Jerome and Lincoln counties
about 3 miles west of Highway 75. The distribution feeder serving this area is the Notch Butte
11 (NHBT-Ol1) 12.5 kV feeder. This is a grounded wye feeder operating at 12.5 kV. The
conductors on the affected portion of the system are 4/0 ACSR, which has a continuous thermal
operating rating of 8.77 MVA, 336 AI, which has a continuous thermal operating rating of 11.58
MV A and 6A Copperweld, which has a continuous thennal operating rating of 3.82 MV A. With
the consideration of the size ofthe proposed project there is not adequate capacity on this feeder
to serve this project. A new 34.5 kV feeder will be built double circuit along an existing
distribution line route. Upgrades for increasing feeder capacity to handle this project are listed in
section 8.
The point of interconnection will be to the proposed 34.5 kV grounded wye feeder. Refer to
Appendix A section 3 for additional grounding requirements.
8.0 Description and Cost Estimate of Required Facility Upgrades
In order to add this project, the capacity of the substation needs to be increased. Because of the
size of the proposed wind park the best way to add this capacity is to install a second substation
transformer for a 34.5 kV feeder to serve the wind park. ,A. 25 !v1VA 138:34.5 kV transformer
and a new 34.5 kV feeder bay will be installed into the existing NHBT substation. Lead time for
the new transformer is about 72 weeks.
In addition to the work at the substation a new 34.5 kV feeder will be required. About 4 miles of
existing distribution line will be rebuilt as a double circuit distribution line, with the top circuit
being a 34.5 kV feeder with 336 Al conductor for the wind park and the bottom circuit remaining
a 12.5 kV feeder to serve the existing load. This new line is from the substation west one mile
along 700 N. to 300 E., then north 2 miles to 900 N., then west 1 mile to the point of
interconnection. This rebuild is highlighted in yellow on the map attached in Appendix B.
4
Since the wind generation farm could be located along with other Idaho Power customers, a
generation interconnection package will be required at the point of interconnection.
The following table details the generation integration directly assignable costs for the upgrades
needed to accommodate the proposed project.
T bl 1 E . a e stImate dC £ R . dU osts or eqwre d pgra les
Description Cost
Substation upgrade $1,317,000
4 miles of double circuit distribution (34.5 kV 336 Al on top, $632,000
existing 12.5 kV on the bottom)
Generator Interconnection Package $165,000
Total Estimated Cost $2,114,000
These cost estimates include direct equipment and installation labor costs, indirect labor costs
and overheads. (Tax Gross Up has not been included presuming construction of interconnection
facilities will not qualify under IRS rules as a taxable event. Allowance for funds used during
construction (AFUDC) has not been included in the cost estimates since it is assumed that IPC
will be provided up-front funding by the Project). These are cost estimates only and final
charges to the customer will be based on the actual construction costs incurred.
9.0 Description of Operating Requirements
In addition to these upgrades, there are also several operating requirements that must be met.
The project will be controlled to operate at unity power factor or meet the voltage schedule
provided by Idaho Power. If this requirement can not be met, further voltage studies will be
necessary. Voltage flicker at startup and during operation will be limited to less than 5% as
measured at the point of interconnection. The project is required to comply with the applicable
Voltage and Current Distortion Limits found in IEEE Standard 519-1992 IEEE Recommended
Practices and Requirements for Harmonic Control in Electrical Power Systems.
10.0 Conclusions
The requested interconnection ofthe Notch Butte Wind Park to Idaho Power's system was
studied. The results of this study work confirm that the existing Idaho Power system can be
upgraded to handle this project. The known required upgrades for the existing substation and
distribution systems are listed. The constraints of the transmission system, caused by projects
ahead of this project in the generation queue, determine that a Transmission System Impact
Study will be required for this project.
5
APPENDIX A
A-1.0 Method of Study
The Feasibility Study plan inserts the Project up to the maximum requested injection into the
selected Western Electric Coordinating Council (WECC) power flow case and then, using GE's
Positive Sequence Load Flow (PSLF) analysis tools or Power World Simulator, examines the
impacts of the new resource on Idaho Power's system (lines, transformers, etc.) within the study
area under various operating/outage scenarios. The WECC and Idaho Power reliability criteria
and Idaho Power operating procedures were used to determine the acceptability of the
configurations considered. The WECC case is a recent case modified to simulate stressed but
reasonable pre-contingency energy transfers utilizing the IPC system. For distribution feeder
analysis, Idaho Power utilizes Advantica's SynerGEE software.
A-2.0 Acceptability Criteria
The following acceptability criteria were used in the power flow analysis to determine under
which system configuration modifications may be required:
The continuous rating of equipment is assumed to be the normal thermal rating of the
equipment. This rating will be as determined by the manufacturer of the equipment or as
determined by Idaho Power. Less than or equal to 100% of continuous rating is
acceptable.
Idaho Power's Voltage Operating Guidelines were used to determine voltage
requirements on the system. This states, in part, that distribution voltages, under normal
operating conditions, are to be maintained within plus or minus 5% (0.05 per unit) of
nominal everywhere on the feeder. Therefore, voltages greater than or equal to 0.95 pu
voltage and less than or equal to 1.05 pu voltage are acceptable.
Voltage flicker during starting or stopping the generator is limited to 5% as measured at
the point of interconnection, per Idaho Power's T &D Advisory Information Manual.
Idaho Power's Reliability Criteria for System Planning was used to determine proper
transmission system operation.
All customer generation must meet IEEE 519 and ANSI C84.1 Standards.
All other applicable national and Idaho Power standards and prudent utility practices
were used to determine the acceptability of the configurations considered.
The stable operation of the system requires an adequate supply of volt-amperes reactive
(VARs) to maintain a stable voltage profile under both steady-state and dynamic system
conditions. An inadequate supply of V ARs will result in voltage decay or even collapse
under the worst conditions.
6
Equipment/line/path ratings used will be those that are in use at the time of the study or that are
represented by IPC upgrade projects that are either currently under construction or whose
budgets have been approved for construction in the near future. All other potential future ratings
are outside the scope ofthis study. Future transmission changes may, however, affect current
facility ratings used in the study.
A-3.0 Grounding Guidance
Idaho Power Company (IPC) requires interconnected transformers to limit their ground fault
current to 20 amps at the point of interconnection.
A-4.0 Electrical System Protection Guidance
IPC requires electrical system protection per Requirements for Generation Interconnections
found on the Idaho Power Web site,
http://www.idahopower.comiaboutus/business/generationInterconnectl.
A-S.O WECC Coordinated Off-Nominal Frequency Load Shedding and Restoration
Requirements
IPC requires frequency operational limits to adhere to WECC Under-frequency and Over­
frequency Limits per the WECC Coordinated Off-Nominal Frequency Load Shedding and
Restoration Requirements available upon request.
7
APPENDIX B
Notch Butte Wind Park
~ -. r:( :::;UDstatlollS
--NHBT-011
NHBT-012
Transmission Lines
PLlNE_KV
345
Notch Butte Generation Location
Notch Butte Wind Feedel" Upgrades
.. , APPENDIXC
GENERATOR INTERCONNECTION
SYSTEM IMPACT STUDY REPORT
for
Up to 305 MW of New Generation
On the 138 kV Transmission System
In the Twin Falls Area
to
IDAHO POWER COMPANY, Transmission Provider
TRANSMISSION SYSTEM
FINAL REPORT
June 8, 2006
1.0 Introduction
Multiple new generation projects have contacted Idaho Power Company (IPC) to perform
Generator Interconnection System Impact Studies for Network Resource Interconnection Service
at 138 kV for the integration of new generation projects in the Twin Falls area
This report documents the basis for and the results of this System Impact Study. It describes the
backbone transmission system improvements required for Network Resource Interconnection
Service of the new generation proposed, the study cases used, outage scenarios assumed and
results of all work in the areas of concern.
2.0 Summary
The performance of the backbone transmission system was evaluated to integrate up to 200 MW
of new generation on the 138 kV transmission system in the Twin Falls area. Four phases of
transmission system improvements are required to provide 200 MW of new generation Network
Resource Interconnection Service.
Phase #1:
Phase #2:
Phase #3:
Phase #4:
Install a 19 ohm 138 kV Series Reactor on the Upper Salmon-Mountain Home
Junction 138 kV transmission line. Without this improvement, the outage of the
Midpoint-Rattlesnake #2230 kV transmission line results in an overload of the
Upper Salmon-Mountain Home Junction 138 kV line with no new generation in
the Twin Falls area. This improvement is necessitated by the transmission
improvements associated with Generation Proj ect 88 , and as a result should be
funded by Idaho Power Company -Delivery. This phase of improvements is
estimated at approximately $290,000.
Install a 10.5 ohm 138 kV Series Reactor on the Lower Malad-Mountain Home
Junction 138 kV transmission line. Without this improvement, the outage of the
Midpoint-Rattlesnake #2 230 kV transmission line results in an overload of the
Lower Malad-Mountain Home Junction 138 kV line with new generation levels
greater than 7 MW in the Twin Falls area. This phase of improvements is
estimated at approximately $290,000.
Fold the Midpoint-DRAM #1 230 kV transmission line into the King Substation
and install a 2301138 kV 300 MVA transformer. Without this improvement, the
outage of the Midpoint-Rattlesnake #2230 kV transmission line results in an
overload of the Upper Salmon-Mountain Home Junction 138 kV line with new
generation levels greater than 60 MW in the Twin Falls area. This phase of
improvements is estimated at $10,320,000.
Reconductor/rebuild the King-DRAM #1 230 kV transmission line with a two
conductor bundle of 795 MCM ACSR "Tern" conductor. This rebuilt line also
10
.' must be folded into the Rattlesnake Substation north of Mountain Home. In
addition, transmission modifications are required at the DRAM end of the line .
Without this improvement, the outage of the Midpoint-Rattlesnake #2 230 kV
transmission line results in an overload of the Upper Salmon-Mountain Home
Junction 138 kV line with new generation levels greater than l35 MW in the
Twin Falls area. This phase of improvements is estimated at $47,525,000.
These cost estimates include direct equipment and installation labor costs, indirect labor costs
and overheads, and allowance for funds used during construction (AFUDC). The proposed cost
allocation is subject to change, as more information is known. These are cost estimates only and
final charges to the customer will be based on the actual construction costs incurred.
3.0 Summary of Interconnection Requests
Requests were made to Idaho Power Co. by multiple generation projects in the Twin Falls area to
study the interconnection ofthe proposed generation projects to Idaho Power's transmission
system at the 138 kV level for Network Resource Interconnection Service.
4.0 Scope of Interconnection System Impact Study
The Interconnection System Impact Study was done and prepared in accordance with the FERC
Order 2003 -A, Standard Large Generator Interconnection Procedures, to provide a preliminary
evaluation of the System Impact of the interconnection of the proposed large generating project
to the Idaho Power transmission system. This study will only be concerned with the capabilities
of the Idaho Power system to manage this new resource within the study area of the proposed
interconnection.
5.0 Description of Existing Transmission Facilities
As shown in Figure 1 of Section 7.0, Midpoint Substation, north of Twin Falls, has three 230 kV
lines that carry bulk power westward to the Boise area. Midpoint-DRAM #1 line utilizes single
715.5 MCM conductor and has a continuous rating of339 MV A. The Midpoint-Rattlesnake-Boise
Bench #2 line utilizes a 2 conductor bundle of715.5 MCM. This line has a continuous rating of 677
MV A. The Midpoint-Boise Bench #3 line has similar conductors and the same rating as the
Rattlesnake-Boise Bench #2 line. In the Mountain Home area, an additional 230 kV line is planned
to carry bulk power westward. The Rattlesnake-Bennett Mountain-Danskin-Mora line utilizes single
1272 MCM conductors(478 MVA) from Rattlesnake-Bennet Mountain, single 1590 MCM
conductors(550 MV A) from Bennet Mountain-Danskin, and a two conductor bundle of 795
MCM(700 MV A) from Danskin-Mora. The Bennett Mountain-Danskin-Mora transmission lines are
required for the interconnection of Generation Project 88 ; scheduled to be in-service Spring of 2008.
11
In addition to the Midpoint to the Boise area 230 kV lines previously mentioned, there are two 138
kV circuits which can carry power from the Twin Falls area to the Mountain Home area. They are:
• King-Lower Malad-Mountain Home Junction 138 kV Line
• King-Upper Salmon-Mountain Home Junction 138 kV Line
Generators located in the Twin Falls area which are intended to serve load growth in the Treasure
Valley area, will be adding new incremental flows on top of existing committed east-to-west
transactions across the Midpoint West transmission cutplane. This System Impact study will model
approximately 1100 MW of transfers across the Midpoint West cutplane, prior to this proposed
generator addition. For these studies, the flow level of the Midpoint west cutplane is defined as the
sum of the flows on the following lines:
• Midpoint-DRAM #1 230 kV line
• Midpoint-Rattlesnake #2 230 kV Line
• Midpoint-Boise Bench #3 230 kV Line
• Lower Malad-Mountain Home Junction 138 kV Line
• Upper Salmon-Mountain Home Junction 138 kV Line
6.0 Description of Configurations Studied
Since the most limiting operating conditions are expected during heavy production on the upper
and middle Snake and Boise River hydro plants, with heavy east-west transfers across the Idaho
Power transmission system, the injection of the new generation at King 138 kV bus was inserted
into a power flow case that would simulate committed (approximately 1100 MW) pre­
contingency flows on the Midpoint West transmission path.
7.0 Post-transient Study Results
This Interconnection System Impact Study Report is for Network Resource Interconnection
Service at 138 kV, for numerous proposed generation additions in the Twin Falls area. System
transfers across the Midpoint West cutplane are modeled at approximately 1100 MW prior to the
proposed transmission improvements or the proposed generators producing any power. Hydro
generation production for the Boise & Snake plants, were modeled at heavy, but realistic levels.
Ouput levels for the existing peakers at Danskin and Bennett Mountain were varied over their
operating ranges as appropriate. N-O and N-I outage performance for the existing system are
recorded. Generation levels at King 138 kV bus are increased until system thermal limits are
reached during N-l outages. The most effective and cost-efficient transmission system
improvements are then added to the model and King generation is then increased until system
thermal limits are reached during N-l outages.
Existing System
The following one line diagram depicts the existing system with no outages.
12
Existing System N-l Outages
Midpoint West = 1111 MW
Existing System -No Outages
Figure 1
The following one line diagram depicts the existing system with no new generation in the Twin
Falls area, and the only N-l outage between Midpoint and the Mountain Home area that results
in loadings above continuous thermal ratings.
Midpoint West = 1.43 MW
Existing System -Midpoint-Rattlesnake #2 Outage
Figure 2
13
Phase #1 Transmission Improvements
The Midpoint Series Capacitor banks are capable of 110% of thermal rating on a continuous
basis. As a result, only the Upper Salmon-Mountain Home Junction 103% overload is
problematic. The most effective and cost-efficient transmission improvement to alleviate this
overload is the installation of a series reactor on the Upper Salmon-Mountain Home Junction 138
k V line to better balance flows on the transmission network. The optimum size of the series
reactor was determined to be 19 ohms for the ultimate build-out of the transmission grid. Since
this N-l overload condition pre-exists the addition of any new generation in the Twin Falls area,
Idaho Power Company would take responsibility to fund this series reactor installation.
The following one line diagram depicts the system with Phase # 1 improvements added, no new
generation in the Twin Falls area, and the same N-l as Figure 2.
Midpoint West = '.1 MW
Mm. Home-Lower Malad sertes reactor is not .,·service
Mtn. Home·Uppef' Sahlon S8f1es reactor Is .100 pu or 19 ohms ~~. ~r "'I~\~,,,,.... . ~~ ~~ . • -t>-o:. --@It.'. ......,m-l.~
Phase #1 Transmission Improvements -Midpoint-Rattlesnake #2 Outage
No New Generation
Figure 3
Phase #2 Transmission Improvements
The following one line diagram depicts Phase # 1 transmission improvements and 7 MW of new
generation in the Twin Falls area, and the only N-l outage between Midpoint and the Mountain
Home area that results in loadings above continuous thermal ratings.
14
Midpoint West = ,.5 MW
"-"I<S l.ol~
Mtn. Home-lower Malad series reactor Is not il-SQ"lk9
Mtn. I-bme~ Sam:n ~ react« Is .100 pu IX 19 otms
Phase #1 Transmission Improvements -Midpoint-Rattlesnake #2 Outage
7 MW of New Generation
Figure 4
The most effective and cost-efficient transmission improvement to alleviate this overload is the
installation of a series reactor on the Lower Malad-Mountain Home Junction 138 k V line to
better balance flows on the transmission network. The optimum size of the series reactor was
determined to be 10.5 ohms for the ultimate build-out of the transmission grid. This overload is
the result ofthe addition of new generation in the Twin Falls area, and as a result the costs ofthis
improvement will be allocated to new generation interconnections.
The following one line diagram depicts the system with Phase #2 improvements added, 7 MW of
new generation in the Twin Falls area, and the same N-l as Figure 4.
15
.,.'D ... J"t~
Midpoint West = 1125 MW
Mtn. Horne-loweJ MaI.x:I series reactQ( Is .055 pu or 10.5 oIYns
Mtn. I-bme-llppel' salmon series reactor Is .100 pu or 19 ohns
Phase #2 Transmission Improvements -Midpoint-Rattlesnake #2 Outage
7 MW of New Generation
Figure 5
Phase #3 Transmission Improvements
The following one line diagram depicts Phase #2 transmission improvements and 60 MW of new
generation in the Twin Falls area, and the onI y N -1 outage between Midpoint and the Mountain
Home area that results in loadings above continuous thermal ratings.
Midpoint West = 11'1 MW
Mtn Home·Lower Malad seOas re«:tor is .055 po or 10.5 oITns
Mtn. ~ s.m-.on serieS reactor is .100 pu or 19 otms
Phase #2 Transmission Improvements -Midpoint-Rattlesnake #2 Outage
60 MW of New Generation
Figure 6
16
To interconnect generation quantities greater than 60 MW will require additional transmission
system improvements. The required system improvements are referred to as "Phase #3" and
include folding the Midpoint-DRAM #1 230 kV transmission line into and back out ofthe King
Substation and installing a 230/138 kV 300 MVA transformer. This overload is the result of the
addition of new generation in the Twin Falls area, and as a result the costs of this improvement
will be allocated to new generation interconnections.
The following one line diagram depicts the system with Phase #3 improvements added, 60 MW
of new generation in the Twin Falls area, and the same N-1 as Figure 6.
Midpoint West = 11 •• MW
Phase #3 Transmission Improvements -Midpoint-Rattlesnake #2 Outage
60 MW of New Generation
Figure 7
Phase #4 Transmission Improvements
The following one line diagram depicts Phase #3 transmission improvements and 135 MW of
new generation in the Twin Falls area, and the onlyN-1 outage between Midpoint and the
Mountain Home area that results in loadings above continuous thermal ratings.
17
Midpoint West = 111' MW
Mtn. Home·lower Malad 5E!ries reactor is ,055 pu or 10.5 ohms
Mtn. Home-Upper Samon series reactor is .100 pu or 19 ohms
Phase #3 Transmission Improvements -Midpoint-Rat~lesnake #2 Outage
135 MW of New Generation
Figure 8
To interconnect generation quantities greater than 135 MW will require additional transmission
system improvements. The required system improvements are referred to a "Phase #4" and
include reconductoring/rebuilding the King-DRAM #1 230 kV transmission line with a two
conductor bundle of 795 MCM ACSR "Tern" conductor. This rebuilt line also must be folded
into and back out of the Rattlesnake Substation north of Mountain Home. In addition,
transmission modifications are required at the DRAM end of the line. This overload is the result
ofthe addition of new generation in the Twin Falls area, and as a result the costs of this
improvement will be allocated to new generation interconnections.
The following one line diagram depicts the system with Phase #4 improvements added, 135 MW
of new generation in the Twin Falls area, and the same N-l as Figure 8.
18
Midpoint West = 1111 MW
Mtn. Home-lower Malad ~ reacto( is: .055 pu Of 10.5 0Crns
Mm. Home-Upper Sah'Ion series reactor Is ~100 pu Of 19 otms
Phase #4 Transmission Improvements -Midpoint-Rattlesnake #2 Outage
135 MW of New Generation
Figure 9
Phase #4 transmission improvements are capable of accomodating approximately 305 MW of
new generation in the Twin Falls area. The following one line diagram depicts the system with
Phase #4 improvements added, 305 MW of new generation in the Twin Falls area, and the loss
of the King 230/138 kV transformer.
Midpoint West = 138. MW
Mtn. Home-Lower Malad series reactor is ,ass pu or 10.5 otms
Mtn. Home-Upper Sarna. series reactor IS .. 100 pu or 19 ohms
Phase #4 Transmission Improvements -King 230/138 kV Xfmr Outage
305 MW of New Generation
Figure 10
19
For generator interconnections in excess of 305 MW, the addition of a second 2301138 kV
transformer at King is required.
8.0 Fault Study Results
Since this System Impact Study lumps all the proposed generation additions at King 138 kV bus,
this Draft Report makes no attempt to address fault study concerns. Each proposed generation
project will have to be evaluated individually based on its specific location.
9.0 Transient Stability Study Results
The Midpoint West Transmission System is not transient stability limited. Therefore, no transient
stability studies were performed.
10.0 Conclusions
The System Impact of interconnecting up to 200 MW of new generation in the Twin Falls area to
Idaho Power's 138 kV transmission system was studied. Four phases oftransmission system
improvements are required to provide Network Resource Interconnection Service to 200 MW of
new generation. Phase #1 is the installation ofa 19 ohm 138 kV Series Reactor on the Upper
Salmon-Mountain Home Junction 138 kV transmission line. This improvement corrects a N-1
overload that exists before any new generation is added in the Twin Falls area. As a result, the
estimated $290,000 cost of this improvement will be borne by Idaho Power Company. After
approximately 7 MW of new generation is added, Phase # 1 improvements are no longer
sufficent. Phase #2 improvements require the installation ofa 10.5 ohm 138 kV Series Reactor
on the Lower Malad-Mountain Home Junction 138 kV transmission line. The estimated
$290,000 cost of this improvement should be allocated to new generator interconnections.
Following the addition of approximately 60 MW of new generation, Phase #3 transmission
improvements are required. Phase #3 involves folding the Midpoint-DRAM #1 230 kV
transmission line into and back out of the King Substation and installing a 230/138 kV 300 MVA
transformer. The estimated $10,320,000 cost of this improvement should be allocated to new
generator interconnections. Following the addition of approximately 135 MW of new
generation, Phase #4 transmission improvements are required. Phase if4 involves
reconductoringlrebuilding the King-DRAM #1 230 kV transmission line with a two conductor
bundle of795 MCM ACSR "Tern" conductor. This rebuilt line also must be folded into and
back out of the Rattlesnake Substation north of Mountain Home. In addition, transmission
modifications are required at the DRAM end of the line. The estimated $47,525,000 cost of this
improvement should be allocated to new generator interconnections. Phase #4 transmission
improvements are adequate to interconnect approximately 305 MW of new generation in the
Twin Falls area before additional improvements are required.
20
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 10
24 January 2007
Mr. James Carkulis
Exergy Development Group, LLC
1424 Dodge Avenue
Helena, MT 59601
Ph 406-459-3013
RE: Generator Interconnection Status and Facility Study Offer -
Notch Butte Wind Park Project #158
Dear Mr. Carkulis:
An IDACORP Company
Attached is a draft Facility Study Agreement for the above referenced project. This Agreement provides
for the study of potentially necessary Network Upgrades on the main grid transmission system. You may
already have signed a separate Interconnection Facility Study for the distribution and transmission
portions of the project providing for Generation Interconnection.
On Tuesday August 15,2006 Idaho Power Company held a meeting to discuss the June 8, 2006
Generator Interconnection System Impact Study Report] and examine possible options to proceed given
the identified Network Upgrades required to integrate generation as Network Resources in the Twin Falls
geographic area.
Since the August 15 meeting, Idaho Power Company has been in discussions with a number of entities.
At least one has indicated willingness to fund the Network Upgrades for all projects subject to refund
provisions similar to those discussed at the meeting. Any such proposal would need agreement and
required approvals by all Parties and the Idaho Public Utilities Commission ("IPUC"). Additionally,
there is a pending Complaint with the IPUC (Case No. IPC-E-06-21) seeking determination for cost
responsibility of Network Upgrades for PURPA QFs. Some projects in the Generator Interconnection
Queue are not subject to this IPUC proceeding but may nevertheless be impacted by its outcome. Even
so, a number of projects in the Queue have expressed a desire to move forward with construction prior to
the conclusion of that proceeding.
Please note that this Facility Study Agreement does not obligate you to proceed with construction of any
Network Upgrades. It will provide the necessary funding and authority to allow the detailed engineering
and design work to proceed so that refined cost estimates and construction timelines can be determined.
Once this Facility Study is completed, Idaho Power will offer a draft Interconnection Agreement to each
project that will establish obligations and commitment to participate in funding of the Network Upgrades
for transmission facilities. That Interconnection Agreement will provide an option to each generator to
select a designation either as a firm resource -also known as a Network Resource (NR), or a non-firm
resource -known as an Energy Resource (ER).
Selection of an NR designation requires the availability of firm transmission capacity to transfer the total
generation output and will require the constlUction of the necessary Network Upgrades. Additionally,
should your NR Project request commercial operation prior to the completion of the required Network
I "for Up to 305 MW of New Generation On the 138 kV Transmission System in the Twin Falls Area".
P.O. Box 70 (83707)
1221 W. Idaho St.
Boise, 10 83702
Notch Butte Wind Park Project #158 Page 2 of 2 January 24, 2007
Upgrades, design and construction of a control system to dispatch/cUltail the Project output may be
required and become part of the scope of this Facility Study, allowing non-firm operation (described
below) until the Network Upgrades are completed.
If you decide to designate your project as an ER you will avoid construction obligation of Network
Upgrades. However, this non-firm ER designation will require generation curtailment during periods
when aclual or scheduled use of transmission paths (affected by your Project) exceed path operating
capacity. Selection as an ER will require the design and construction of a control system to
dispatch/curtail the Project output, and will become part of the scope of this Facility Study.
The ER approach may require modifications to Power Purchase Agreements to recognize the
interruptability of the Project. Cost responsibility of any control system to enable dispatch
control/curtailment will be the responsibility of the Interconnection Customer.
Any determination of direct cost responsibility of Network Upgrades for PURPA generation projects will
be in accordance with orders of the IPUC, the IPUC's approval of a settlement offer, or other IPUC­
approved mutual agreement between the Parties. Any remaining FERC jurisdictional projects would
remain subject to FERC rules and procedures already in effect as provided for in Idaho Power's Open
Access Transmission Tariff ("OATT").
In conjunction with Idaho Power Company's Generator Interconnection procedures, we now consider the
System Impact Study phase completed. Lisa Loomis will be the Project Leader who is responsible for
carrying this project through the Design & Construction phase. If you have questions she can be reached
at 208-388-6337.
If you wish to proceed with this project, we must receive written notice from you and the required
deposit. $10,588.00 for the Facility Study wit hln 30 Calendar Days of this letter. If not, your Generator
Interconnection application will be deemed withdrawn in its entirety. Please contact me if you have any
questions.
Sincerely,
~ot ~--"'~
"Kip" David L. Sikes, P.E.
Commercial Transmission Development Manager
Ph 208-388-2459
[e-mail]
Attachments
Draft Facility Study Agreement
Cc: Rowena Bishop/ IPC
Lisa Loomisl IPC
INTERCONNECTION FACILITIES STUDY AGREEMENT
THIS AGREEMENT is made and entered into this __ day of ____ ----'
2007 by and between a
organized and existing under the laws of the State of
________ , ("Interconnection Customer,") and Idaho Power Company a
Corporation existing under the laws of the State of Idaho, ("Transmission Provider ").
Interconnection Customer and Transmission Provider each may be referred to as a
"Party," or collectively as the "Parties."
RECITALS
WHEREAS, Interconnection Customer is proposing to develop the Notch Butte
Wind Park Generation Project, located in Lincoln County, Idaho hereafter referred to as
"Generating Facility", consistent with the Interconnection Request submitted by
Interconnection Customer dated 12/19/2005; and
WHEREAS, Interconnection Customer desires to interconnect the Generating
Facility with Transmission Provider's Transmission System (the "Transmission
System");
WHEREAS, the Transmission Provider has proposed to group Network Facilities
required for more than one Interconnection Customer in order to minimize facilities costs
for Network Upgrades on the main-grid transmission system through grouped
participation, and has given the affected parties the choice to bring their proposed facility
online with some capacity limitations until Network Facility Studies can be completed;
and
WHEREAS, the Interconnection Customer has requested the Transmission
Provider to perform an Interconnection Facilities Study for the Network Upgrades on the
main-grid transmission system to specify and estimate the cost of the equipment,
engineering, procurement and construction work needed to implement the conclusions of
the Interconnection System Impact Study dated, June 8, 2006 in accordance with Good
Utility Practice to physically and electrically connect the Generating Facility with the
Transmission Provider's Transmission System.
NOW, THEREFORE, in consideration of and subject to the mutual covenants
contained herein the Parties agreed as follows:
-1 -
Facilities Study Agreement
Notch Butte Wind Park Project #158
1.0 Definitions. When used in this Agreement, with initial capitalization, the terms
specified shall have the meanings indicated in Transmission Provider's FERC­
approved Standard Large Generator Interconnection Procedures ("LGIP")
Attachment J, Idaho Power Company, FERC Electric Tariff, First Revised Volume
No.5.
2.0 Agreement. Interconnection Customer elects and Transmission Provider agrees to
perform an Interconnection Facilities Study consistent with Section 8.0 of the
LGIP in accordance with the Tariff.
3.0 Scope. The scope of the Interconnection Facilities Study shall be based upon the
data provided in Attachment A to this Agreement.
4.0 Study timeline. Transmission Provider shall use Reasonable Efforts to complete
the Interconnection Facilities Study and issue a draft Interconnection Facilities
Study report to Interconnection Customer within One hundred eighty (180)
Calendar Days with no more than a +/-10 percent cost estimate contained in the
report.
5.0 Interconnection Facilities Study Report. The Interconnection Facilities Study
report (i) shall provide a description, the estimated cost, and a schedule for
required facilities to interconnect the Generating Facility ' to the Transmission
System and (ii) shall address the short circuit, instability, and power flow issues
identified in the Interconnection System Impact Study.
6.0 Deposit. Interconnection Customer shall provide a deposit of $10,588.00 for the
performance of the Interconnection Facilities Study.
Transmission Provider shall, on a monthly basis, submit an invoice to the
Interconnection Customer which shall reflect the amount due for the work
conducted by the Transmission Provider on the Interconnection Facilities Study
during the invoice month. Interconnection Customer shall pay invoiced amounts
within thirty (30) Calendar Days of receipt of invoice. Transmission Provider
shall continue to hold the amounts on deposit until settlement of the final invoice.
7.0 Effective Date, Duration and Termination. This Agreement becomes effective
upon execution by all. Parties. and shall continue until the work required by the
Agreement is completed; provided, however, the Interconnection Customer may
terminate this Agreement at any time after providing written notice. Any unspent
funds will be returned with interest under the provisions of the LGIP. The
remaining parties agree to an appropriate reallocation of study funds based on
projects remaining in the queue. In addition, if Interconnecting Customer
withdraws its application for interconnection, this Agreement shall terminate
effective with the date the application for interconnection is withdrawn.
-2 -
Facilities Study Agreement
Notch Butte Wind Park Project #158
8.0 No Obligation to Complete Generating Facility. Nothing in this Agreement
obligates Interconnection Customer to continue or complete development of the
Generating Facility or enter into a Generator Interconnection Agreement ("GIA").
A binding agreement and commitment with respect to interconnecting the
Generating Facility to the Transmission System will only occur upon the execution
of a GIA by Transmission Provider and Interconnection Customer.
9.0 Relationship of the Parties. This Agreement is intended to create an independent
contractor relationship between the Parties. It is not to be construed as constituting
the Parties as partners, as creating a joint venture, or as creating any other form of
legal association or arrangement which would impose liability upon a Party for the
act or omission of the other Party.
10.0 Remedies. In no event will Transmission Provider or its respective agents,
employees, officers, directors, affiliates or representatives be liable for incidental,
special, punitive or consequential damages including but not limited to lost profits,
even if the Parties have been advised of the possibility of such damages.
Interconnecting Customer agrees that Transmission Provider's liability arising out
of this Agreement and the services provided under this Agreement, whether under
theories of contract, negligence, tort, strict liability, warranty or equity will not
exceed the amounts payable by Interconnecting Customer to Transmission
Provider for the services that are the basis of such claim.
11.0 Governing Law. The validity, interpretation and performance of this Agreement
shall be governed by the laws of the State of Idaho, without regard to its conflict of
law principles; and in addition, shall be subject to all applicable federal laws,
regulations and judicial or administrative orders of the Federal Energy Regulatory
Commission. Venue for any action to enforce the terms and conditions of this
Agreement shall be in Boise, Idaho.
12.0 Amendment. This Agreement may not be modified except by mutual agreement
by a signed document duly executed by both Parties.
13.0 Waiver. The failure of a Party to this Agreement to insist, on any occasion, upon
strict performance of any provision of this Agreement will not be considered a
waiver of any obligation, right, or duty of, or imposed upon, such Party.
14.0 Severability and Savings Clause. If any provision of this Agreement is held to be
void, voidable, contrary to public policy, or unenforceable, that provision will be
deemed severable from the Agreement as to the smallest part so held, and the
remainder of the Agreement will continue in full effect as if the severed provision
had not been included, in which case the Agreement will be construed and
interpreted to implement the objectives of the Parties as stated in this Agreement.
Facilities Study Agreement
Notch Butte Wind Park Project #158
The Parties agree that neither Party will be deemed the drafter of any term that
may subsequently be found to be ambiguous or vague.
15.0 Survival. This Agreement shall continue in effect after termination to the extent
necessary to provide for final billings and payments and for costs incurred
hereunder, to permit the determination and enforcement of liability obligations
arising from acts or events that occurred while this Agreement was in effect.
16.0 Assignment and Subcontracts. This Agreement may not be transferred or assigned
by either Party hereto without the prior written consent of the other Party, which
such consent will not be unreasonably withheld. Transmission Provider may
subcontract any portion of the work required by this Agreement without the
permission of the Interconnecting Customer.
17.0 Successors and Assigns. This Agreement shall be binding upon and inure to the
benefit of the Parties hereto and their respective successors and permitted assigns.
Nothing in this Agreement shall be deemed to confer upon any other person any
rights, remedies, obligations or liabilities under or by reason of this Agreement.
18.0 Notices. Any notice required by this Agreement is properly given if submitted in
writing and delivered to the individual set forth below in person, delivered to a
nationally recognized overnight courier service properly addressed and with
delivery charges prepaid, delivered to the United States Postal Service properly
addressed and with proper postage prepaid, transmitted by facsimile with
confirmation of successful transmission, or transmitted by email. Either Party may
change at any time the individual authorized to receive notice, an address,
telephone number or email address by providing notice to the other Party.
If to Interconnecting Customer, to: If to the Transmission Provider, to:
Idaho Power Company
Delivery Business Unit
1221 West Idaho Street
Boise, ID 83702
Attn: David "Kip" Sikes
ph 208.388.2459
fax [phone]
Email: [e-mail]
19.0 Entire Agreement. This Agreement and its Attachments constitutes the complete
agreement between the Parties concerning its subject matter and supersedes all
previous communications, negotiation, and agreements, whether oral or written,
with respect to this Agreement. None of the terms or obligations under this
Agreement may be changed or waived in any manner whatsoever by an action or
inaction of either Party unless in a writing duly executed by the Parties. Any
'--4 -
Facilities Study Agreement
Notch Butte Wind Park Project #158
provlSlon of this Agreement which is prohibited or unenforceable in any
jurisdiction shall be, as to such jurisdiction, ineffective to the extent of such
prohibition or unenforceability without invalidating the remaining provisions in
any jurisdiction, and shall not invalidate or render unenforceable such provision in
any other jurisdiction.
20.0 Dispute Resolution. Any dispute between Transmission Provider and
Interconnection Customer involving the provisions of this Agreement shall be
referred to a senior representative of Transmission Provider and a senior
representative of Interconnection Customer for resolution on an informal basis as
promptly as practicable.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly
executed by their duly authorized officers or agents on the day and year first above
written.
Transmission Provider: Interconnection Customer:
Idaho Power Company -Delivery
By:. ____________ _ By: ___________ _
Printed: Printed: ---------------------------------------------------
Title: Title: --------------------------
Date: Dffie:~ ____________ _
-5 -
Facilities Study Agreement
Notch Butte Wind Park Project #158
Attachment A
DATA FORM TO BE PROVIDED BY INTERCONNECTION CUSTOMER
WITH THE
INTERCONNECTION FACILITIES STUDY AGREEMENT
If not already provided:
1. Provide location plan and simplified one-line diagram of the plant and station
facilities. For staged projects, please indicate future generation, transmission circuits, etc.
2. One set of metering is required for each generation connection to the new ring bus
or existing Transmission Provider station. Number of generation connections:
3. On the one line diagram indicate the generation capacity attached at each metering
location. (Maximum load on CTIPT)
4. On the one line diagram indicate the location of auxiliary power. (Minimum load
on CT IPT) Amps
5. Will an alternate source of auxiliary power be available during CTIPT
maintenance?
__ Yes No
6. Will a transfer bus on the generation side of the metering require that each meter
set be designed for the total plant generation? Yes __ No (Please indicate
on one line diagram).
7. What type of control system or PLC will be located at Interconnection Customer's
Large Generating Facility?
8. What protocol does the control system or PLC use?
9. Please provide a 7.S-minute quadrangle of the site. Sketch the plant, station,
transmission line, and property line.
10. Physical dimensions of the proposed interconnection station:
6
Facilities Study Agreement
Notch Butte Wind Park Project #158
11. Bus length from generation to interconnection station:
12. Line length from interconnection station to Transmission Provider's transmission
line.
13. Tower number observed in the field. (Painted on tower leg)* _______ _
14. Number of third party easements required for transmission lines*:
* To be completed in coordination with Transmission Provider.
15. Is the Large Generating Facility in the Transmission Provider's service area?
___ Yes _~No Local provider: ______________ _
16. Please update proposed schedule dates:
Begin Construction
Generator step-up transformer
receives back feed power
Generation Testing
Commercial Operation
Facilities Study Agreement
Notch Butte Wind Park Project #158
Date: ________ _
Date: _________ _
Date: ----------
Date: ________ _
7
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 11
Notch Butte Wind Park -Project 158
System Impact Study Agreement
THIS AGREEMENT is made and entered into this day of 2007 by and
between~" (,. a ""t.; r) ~~.; . .y .. C. '" W' C:L b.,..ws --:-a /.. { ,.... ""'"1 L, .tV"",,.;,.. (Ii ". organized
and existing under the laws of the State f 7094 & , ("Interconn.ection
Customer,") and Idaho Power Company a COll")oration existing under the laws oftbe Stale of
Idaho, ("Transmission Pr vide~" . interconnection Customer and TransmjsSion Provider each
may be referred to as a "Party 11 or collectively as the "Parties."
RECITALS
WHEREAS, the Interconnectton Customer is proposing to develop a Small Generating Facility
or generating capacity addition to an existing Small Generating Facility consistent with the
Interconnection Request completed by the Interconnection Customer on 12119/05 and
WHEREAS, the. Interconnection CuStomer desires to intercolmect the Small Generating Facility
with the TransmissionPtovider's Transmission System;
WHEREAS, the Transmission Provider has completed a Feasibility Study and provided the
results of said study to the Interconnection Customer; and
WHEREAS, the IntercOlmection Customer has requested the Transmission Provider to perform
a System Impact Study(s) to assess the impact of interconnecting the Small Generating Facility
with the Transmission Provider's Transmission System, and of any Affected Systems;
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the terms specified shall have
the meanings indicated or the meanings specified in tbe standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause to be
performed a System Impact Study(s) consistent with the standard SmaIl Generator
Intercdnnection Procedures in accordance with the Open Access Transmission Tariff.
3.0 The scope of a System Impact Study shall be subject to the assumptions set forth in
Attac1mlent A to this Agreement.
4.0 A System Impact Study will be based upon the results of the Feasibility Study and the
technic<l! info11uation provided by Interconnection Customer in the Interconnection
Request. The Transmission Provider reserves the right to request additional technical
info1111ation from the InterGonnection Customer as may reasonably become necessary
consistent with Good Utility Practice during the course of the System lmpact Study. If
the Interconnection Customer modifies its designated Point of IntercoDllection,
System Impact Study Agreemem Page 1 of4
Notch Butte Wind Park-Project 158
Interconnection Request, or the technical infol111ation provided therein is modified, the
time to complete the System Impact Stl,ldy may be extended.
5.0 A system impact Shldy shall consist of a short circuit analysis, a stability analysis, a
power flow analysis, voltage drop and flicker studies, protection and set point
coordination studies, and grounding reviews, as necessary. A system impact study shall
state the assumptions upon which it is based, state the results of the analyses, and provide
the requirement or potential impediments to providing the requested interconnection
service, including a preliminaty indication of the cost and length oftime that would be
necessary to correct any problems identified in those analyses and implement the
interconnection. A system impact study shall provide a list of facilities that are required
as a result ofthe Interconnection Request and non-binding good faith estimates of cost
responsibility and time to construct.
6.0 A distribution system impact study shall incorporate a distribution load flow study, an
analysis of equipment interrupting ratings, protection coordination study, voltage drop
and flicker studies, protection and set point coordination studies, grounding reviews, and
the impact on electric system operation, as necessary.
7.0 Affected Systems may patiicipate in the preparation of a system impact study, with a
division of costs among such entities as they may agree. All Affected Systems shall be
afforded an oPPOltunity to review and comment upon a system impact study that covers
potential adverse system impacts on their electric systems, and the Transmission Provider
has 20 additional Business Days to complete a system impact study requiring review by
Affected Systems.
8.0 If the Transmission Provider uses a queuing procedure for sorting or prioritizing projects
and their associated cost responsibilities for any required Network Upgrades, the system
impact study shan consider all generating facilities (and with respe.ct to paragraph 8.3
below, any identified Upgrades associated with such higher queued interconnection) that,
on the date the system impact study is commenced -
8.1 Are directly interconnected with the Transmission,Provider's electric system; or
8.2 Are interconnected with Affected Systems and may have an impact on the
proposed interconnection; and
8.3 Have a pending higher queued Interconnection Request to interconnect with the
Transmission Provider's electric system.
9.0 A distribution system impact stUdy, if required, shall be completed and the results
transmitted to the Jnterconnection Customer within 30 Business Days after this
Agreement is signed by the Parties. A trat1smission system impact study, ifrequired,
shall be completed and the results transmitted to the Interconnection Customer within 45
Business Days after this Agreement is signed by the Parties, or in accordance with the
Transmission Provider's queuing procedures.
System Impact Study Agreement Page 20[4
Notch Butte Wind Park -Project 158
10.0 A $10,000.00 deposit (the equivalent of the good faith estimated cost of a transmission
system impact study) will be required from the Interconnection Customer.
11.0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
12.0 The Interconnection Customer must pay any study costs that exceed the deposit without
illterest within 30 calendar days on receipt of the invoice or resolution of any dispute. If
the deposit exceeds the invoiced fees, the Transmission Provider shall refund such excess
within 30 calendar days of the invoice without interest.
IN WITNESS THEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents OU the day and year first above \.vritten.
Provider: Interconne~tion Customer:
Idaho Power Company -Delivery
Signed ____________ __
Name (Printed):
Title ------------------------------
Date -------------------------
System Impacl Study Agreement Page 3 of4
Notch Butte Wind Park -Project 158
Atta~hment A
Assumptions Used in CO'Q.ducting the System Impa~t Study
The system impact study shall b,e based upon the res1.ilts of the feasibility study, subject to any
111odifieationSin accotd.ance with tb.e stimdatd Small Generator It1terconn.ection Ptoc:edutes, aild
the fonowing assuruptforts:
PROJECT SCOPE:
1) Design~tiOh dfPoint ofIntercOnRection and configuration to be studied.
2) Designation Qfaltemativ€ Points,ofInterconnection and configuration.
1) and 2) ~e to be cOl11.plel d by the Interconnection Customer. OOtller ass:umpti¢n.S (Hst.e.a,
below) are 1:0 be provided by tbe lntercOlU1ection Customer and the Transmission Provider.
System Impact Study Agre~ll1enl Page 4 of4
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 12
INTERCONNECTION FACILITIES STUDY AGREEMENT ,
THIS AGREEMENT is made and entered into thi&9ld~day of ~e,br ktSYk1 '
2007 by and betweenE,,-v9tf IXIIc,/a;;mtHid arpc.e.,p , a
/1 IJId'-r!J::/ !/iJbdi!t eP~~rganized and existing under the laws of the State of
:::::z:c/~c:) , ("Interconnection Customer,") and Idaho Power Company a
Corporation existing under the laws of the State of Idaho, ("Transmission Provider ").
Interconnection Customer and Transmission Provider each may be referred to as a
"Party," or collectively as the "Parties."
RECITALS
WHEREAS, Interconnection Customer is proposing to develop the Notch Butte
Wind Park Generation Project, located in Lincoln County, Idaho hereafter referred to as
"Generating Facility", consistent with the Interconnection Request submitted by
Interconnection Customer dated 12/19/2005; and
WHEREAS, Interconnection Customer desires to interconnect the Generating
Facility with Transmission Provider's Transmission System (the "Transmission
System");
WHEREAS, the Transmission Provider has proposed to group Network Facilities
required for more than one Interconnection Customer in order to minimize facilities costs
for Network Upgrades on the main-grid transmission system through grouped
participation, and has given the affected parties the choice to bring their proposed facility
online with some capacity limitations until Network Facility Studies can be completed;
and
WHEREAS, the Interconnection Customer has requested the Transmission
Provider to perform an Interconnection Facilities Study for the Network Upgrades on the
main-grid transmission system to specify and estimate the cost of the equipment,
engineering, procurement and construction work needed to implement the conclusions of
the Interconnection System Impact Study dated, June 8, 2006 in accordance with Good
Utility Practice to physically and electrically connect the Generating Facility with the
Transmission Provider's Transmission System.
NOW, THEREFORE, in consideration of and subject to the mutual covenants
contained herein the Parties agreed as follows:
-1 -
Facilities Study Agreement
Notch Butte Wind Park Project #158
1.0 Definitions. When used in this Agreement, with initial capitalization, the terms
specified shall have the meanings indicated in Transmission Provider's FERC­
approved Standard Large Generator Interconnection Procedures ("LGIP")
Attachment J, Idaho Power Company, FERC Electric Tariff, First Revised Volume
No.5.
2.0 Agreement. Interconnection Customer elects and Transmission Provider agrees to
perform an Interconnection Facilities Study consistent with Section 8.0 of the
LGIP in accordance with the Tariff.
3.0 Scope. The scope of the Interconnection Facilities Study shall be based upon the
data provided in Attachment A to this Agreement.
4.0 Study timeline. Transmission Provider shall use Reasonable Efforts to complete
the Interconnection Facilities Study and issue a draft Interconnection Facilities
Study report to Interconnection Customer within One hundred eighty (180)
Calendar Days with no more than a +/-10 percent cost estimate contained in the
report.
5.0 Interconnection Facilities Study Report. The Interconnection Facilities Study
report (i) shall provide a description, the estimated cost, and a schedule for
required facilities to interconnect the Generating Facility to the Transmission
System and (ii) shall address the short circuit, instability, and power flow issues
identified in the Interconnection System Impact Study.
6.0 Deposit. Interconnection Customer shall provide a deposit of $10,588.00 for the
performance of the Interconnection Facilities Study.
Transmission Provider shall, on a monthly basis, submit an invoice to the
Interconnection Customer which shall reflect the amount due for the work
conducted by the Transmission Provider on the Interconnection Facilities Study
during the invoice month. Interconnection Customer shall pay invoiced amounts
within thirty (30) Calendar Days of receipt of invoice. Transmission Provider
shall continue to hold the amounts on deposit until settlement of the final invoice.
7.0 Effective Date, Duration and Termination. This Agreement becomes effective
upon execution by .all. Parties and shall continue until the work required by the
Agreement is completed; provided, however, the Interconnection Customer may
terminate this Agreement at any time after providing written notice. Any unspent
funds will be returned with interest under the provisions of the LGIP. The
remaining parties agree to an appropriate reallocation of study funds based on
projects remaining in the queue. In addition, if Interconnecting Customer
withdraws its application for interconnection, this Agreement shall terminate
effective with the date the application for interconnection is withdrawn.
-2 -
Facilities Study Agreement
Notch Butte Wind Park Project #158
8.0 No ObJj gation to Complete Generating Facility. Nothing in this Agreement
obligates Interconnection Customer to continue or complete development of the
Generating Facility or enter into a Generator Interconnection Agreement ("GIA").
A binding agreement and commitment with respect to interconnecting the
Generating Facility to the Transmission System will only occur upon the execution
of a GIA by Transmission Provider and Interconnection Customer.
9.0 Relationship of the Parties . This Agreement is intended to create an independent
contractor relationship between the Parties. It is not to be construed as constituting
the Parties as partners, as creating a joint venture, or as creating any other form of
legal association or arrangement which would impose liability upon a Party for the
act or omission of the other Party.
10.0 Remedies. In no event will Transmission Provider or its respective agents,
employees, officers, directors, affiliates or representatives be liable for incidental,
special, punitive or consequential damages including but not limited to lost profits,
even if the Parties have been advised of the possibility of such damages.
Interconnecting Customer agrees that Transmission Provider's liability arising out
of this Agreement and the services provided under this Agreement, whether under
theories of contract, negligence, tort, strict liability, warranty or equity will not
exceed the amounts payable by Interconnecting Customer to Transmission
Provider for the services that are the basis of such claim.
11.0 ' Governing Law. The validity, interpretation and performance of this Agreement
shall be governed by the laws of the State of Idaho, without regard to its conflict of
law principles; and in addition, shall be subject to all applicable federal laws,
regulations and judicial or administrative orders of the Federal Energy Regulatory
Commission. Venue for any action to enforce the terms and conditions of this
Agreement shall be in Boise, Idaho.
12.0 Amendment. This Agreement may not be modified except by mutual agreement
by a signed document duly executed by both Parties.
13.0 Waiver. The failure of a Party to this Agreement to insist, on any occasion, upon
strict performance of any provision of this Agreement will not be considered a
waiver of any obligation, right, or duty of, or imposed upon, such Party.
14.0 Severability and Savings Clau s . If any provision of this Agreement is held to be
void, voidable, contrary to public policy, or unenforceable, that provision will be
deemed severable from the Agreement as to the smallest part so held, and the
remainder of the Agreement will continue in full effect as if the severed provision
had not been included, in which case the Agreement will be construed and
interpreted to implement the objectives of the Parties as stated in this Agreement.
Facilities Study Agreement
Notch Butte Wind Park Project #158
The Parties agree that neither Party will be deemed the drafter of any term that
may subsequently be found to be ambiguous or vague.
15.0 Survival. This Agreement shall continue in effect after termination to the extent
necessary to provide for final billings and payments and for costs incurred
hereunder, to permit the determination and enforcement of liability obligations
arising from acts or events that occurred while this Agreement was in effect.
16.0 Assignment and Subcontracts. This Agreement may not be transferred or assigned
by either Party hereto without the prior written consent of the other Party, which
such consent will not be unreasonably withheld. Transmission Provider may
subcontract any portion of the work required by this Agreement without the
permission of the Interconnecting Customer.
17.0 Successors and Assigns. This Agreement shall be binding upon and inure to the
benefit of the Parties hereto and their respective successors and permitted assigns.
Nothing in this Agreement shall be deemed to confer upon any other person any
rights, remedies, obligations or liabilities under or by reason of this Agreement.
18.0 Notices. Any notice required by this Agreement is properly given if submitted in
writing and delivered to the individual set forth below in person, delivered to a
nationally recognized overnight courier service properly addressed and with
delivery charges prepaid, delivered to the United States Postal Service properly
addressed and with proper postage prepaid, transmitted by facsimile with
confirmation of successful transmission, or transmitted by email. Either Party may
change at any time the individual authorized to receive notice, an address,
telephone number or email address by providing notice to the other Party.
If to the Transmission Provider, to:
Idaho Power Company
Delivery Business Unit
1221 West Idaho Street
Boise, ID 83702
Attn: David "Kip" Sikes
ph 208.388.2459
fax [phone]
Email: [e-mail]
19.0 Entire Agreement. This Agreement and its Attachments constitutes the complete
agreement between the Parties concerning its subject matter and supersedes all
previous communications, negotiation, and agreements, whether oral or written,
with respect to this Agreement. None of the terms or obligations under this
Agreement may be changed or waived in any manner whatsoever by an action or
inaction of either Party unless in a writing duly executed by the Parties. Any
--4-
Facilities Study Agreement
Notch Butte Wind Park Project #158
provlslOn of this Agreement which is prohibited or unenforceable in any
jurisdiction shall be, as to such jurisdiction, ineffective to the extent of such
prohibition or unenforceability without invalidating the remaining provisions in
any jurisdiction, and shall not invalidate or render unenforceable such provision in
any other jurisdiction.
20.0 Dispute Resolution. Any dispute between Transmission Provider and
Interconnection Customer involving the provisions of this Agreement shall be
referred to a senior representative of Transmission Provider and a senior
representative of Interconnection Customer for resolution on an informal basis as
promptly as practicable.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly
executed by their duly authorized officers or agents on the day and year first above
written.
Transmission Provider:
Idaho Power Company -Delivery
By: £~J of01JYY\,.v.).J
Printed: L\ StA... Loo f'V\ 15
Title: ?ro ~v+-l-eAbl.e.f·
Date: 3/;)-7/1)7
Facilities Study Agreement
Notch Butte Wind Park Project #158
Interconnection Customer:
-5 -
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 13
James Carkulis
Exergy Development Group, LLC
1424 Dodge Avenue
Helena MT 59601
Ph 406-459-3013
Dear Mr. Carkulis:
Re: Notch Butte Wind Park Project # 158
Milner Dam Wind Park Project # 157
Golden Valley Wind Park Project # 155
An IDACORP company
June 22, 2007
Attached are the Interconnection Facility Study Agreements (FSAs) for the above-referenced
projects. These Agreements are only for the distribution and transmission portions of the
projects which will provide for generation interconnection. A separate Facility Study has already
been executed for the pending network improvements for each of these projects as indicated in
the 305 MW System Impact Study previously provided to you.
I have forwarded your application to our Project Leader, Lisa Loomis, who is responsible for
carrying these projects through the Design & Construction phase. If you have questions, she can
be reached at 208-388-6337.
In order to proceed with this application, we must receive notice and the required deposit for the
Interconnection Facility Study from you by July 22,2007, otherwise your application(s) will be
deemed withdrawn. Please contact me if you have questions.
;O~~
David M. Angell
Planning Manager
Ph 208-388-2701
[e-mail]
Attachments: Interconnection Facility Study Agreements
Cc: Rowena Bishop/IPC
Lisa Loomis/IPC
Interconnection Facilities Study Agreement
THIS AGREEMENT is made and entered into this __ day of 2007 by and
between , a __________ _
organized and existing under the laws of the State of ________ -,--,-
("Interconnection Customer, ") and Idaho Power Company, a Corporation existing under the laws
of the State ofIdaho ("Transmission Provider"). Interconnection Customer and Transmission
Provider each may be referred to as a "Party," or collectively as the "Parties."
RECITALS
WHEREAS, the Interconnection Customer is proposing to develop a Small Generating Facility
or generating capacity addition to an existing Small Generating Facility consistent with the
Interconnection Request completed by the Interconnection Customer on 12/19/05, and
WHEREAS, the Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Provider's Transmission System;
WHEREAS, the Transmission Provider has completed a Feasibility Study and determined that a
System Impact Study is not necessary; and
WHEREAS, the Transmission Provider has proposed to group Network Facilities required for
more than one Interconnection Customer in order to minimize facilities costs through grouped
participation, and to allow the Interconnection Customer to bring their proposed facility online
with some capacity limitations until Network Facility Studies can be completed; and
WHEREAS, the Interconnection Customer has requested the Transmission Provider to perform
a facilities study to specify and estimate the cost of the equipment, engineering, procurement and
construction work needed to implement the conclusions of the system impact study in
accordance with Good Utility Practice to physically and electrically connect the Small
Generating Facility with the Transmission Provider's Transmission System.
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the terms specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause a
facilities study consistent with the standard Small Generator Interconnection Procedures
to be performed in accordance with the Open Access Transmission Tariff
Interconnection Facilities Study Agreement --1 --Notch Butte Wind Park # 158
3.0 The Transmission Provider will proceed with Interconnection Facility Studies, with the
understanding that Network Upgrades associated with this Generator Interconnection
application identified in Idaho Power Company's June 29,2006 Midpoint West System
Impact Study Report will be necessary, along with the uncertainty of whether or not other
Interconnection Customers proceed with each of their applications for Generator
Interconnection.
4.0 The scope of the facilities study shall be subject to data provided in Attachment A to this
Agreement.
5.0 The Interconnection Facilities Study shall specify and estimate the cost of the equipment,
engineering, procurement and construction work (including overheads) needed to
implement the conclusions of the system impact study(s). The facilities study shall also
identify (1) the electrical switching configuration of the equipment, including, without
limitation, transformer, switchgear, meters, and other station equipment, (2) the nature
and estimated cost of the Transmission Provider's Interconnection Facilities and
Upgrades necessary to accomplish the interconnection, and (3) what capacity limitations
or operational issues may exist in the interim until the Transmission Provider completes a
Network Facility Study in the future for the identified study group of Interconnection
Customers, and (4) an estimate ofthe time required to complete the construction and
installation of such facilities.
6.0 Any Interconnection Customer may require the installation of facilities required for its
own Small Generating Facility independent of the identified study group if it is willing to
pay all of the costs associated with those facilities.
7.0 A deposit of the good faith estimated facilities study costs of$IOO,OOO will be required
from the Interconnection Customer.
8.0 The Interconnection Facilities Study will be completed within 90 Calendar Days, or
sooner, upon execution ofthis Agreement. Once the Interconnection Facilities Study is
completed, an Interconnection Facilities Study report shall be prepared and transmitted to
the Interconnection Customer within 10 Business Days.
9.0 Any Interconnection Facility Study fees shall be based on the Transmission Provider's
actual costs and will be invoiced to the Interconnection Customer after the study is
completed and delivered and will include a summary of professional time.
10.0 The Interconnection Customer must pay any Interconnection Facility Study costs that
exceed the deposit without interest within 30 Calendar days on receipt of the invoice or
resolution of any dispute. If the deposit exceeds the invoiced fees, the Transmission Provider
shall refund such excess within 30 Calendar days of the invoice without interest.
Interconnection Facilities Study Agreement -2 -Notch Butte Wind Park # 158
11.0 Effective Date, Duration and Termination. This Agreement becomes effective upon
execution by all Parties and shall continue until the work required by the Agreement is
completed; provided, however, the Interconnection Customer may terminate this Agreement
at any time after providing written notice. In addition, if Interconnecting Customer
withdraws its application for interconnection, this Agreement shall terminate effective with
the date the application for interconnection is withdrawn.
12.0 No Obligation to Complete Generating Facility. Nothing in this Agreement obligates
Interconnection Customer to continue or complete development of the Small Generating
Facility or enter into a Small Generator Interconnection Agreement ("SGIA"). A binding
agreement and commitment with respect to interconnecting the Small Generating Facility to
the Transmission System will only occur upon the execution of an SGIA by Transmission
Provider and Interconnection Customer.
13.0 Relationship of the Parties. This Agreement is intended to create an independent
contractor relationship between the Parties. It is not to be construed as constituting the
Parties as partners, as creating a joint venture, or as creating any other form oflegal
association or arrangement which would impose liability upon a Party for the act or omission
of the other Party.
14.0 Remedies. In no event will Transmission Provider or its respective agents, employees,
officers, directors, affiliates or representatives be liable for incidental, special, punitive or
consequential damages including but not limited to lost profits, even if the Parties have been
advised of the possibility of such damages. Interconnecting Customer agrees that
Transmission Provider's liability arising out of this Agreement and the services provided
under this Agreement, whether under theories of contract, negligence, tort, strict liability,
warranty or equity will not exceed the amounts payable by Interconnecting Customer to
Transmission Provider for the services that are the basis of such claim.
15.0 Governing Law. The validity, interpretation and perfonnance of this Agreement shall be
governed by the laws of the State ofIdaho, without regard to its conflict oflaw principles;
and in addition, shall be subject to all applicable federal laws, regulations and judicial or
administrative orders of the Federal Energy Regulatory Commission. Venue for any action
to enforce the terms and conditions ofthis Agreement shall be in Boise, Idaho.
16.0 Amendment. This Agreement may not be modified except by mutual agreement by a
signed document duly executed by both Parties.
17.0 Waiver. The failure of a Party to this Agreement to insist, on any occasion, upon strict
performance of any provision of this Agreement will not be considered a waiver of any
obligation, right, or duty of, or imposed upon, such Party.
18.0 Severability and Savings Clause. If any provision of this Agreement is held to be void,
voidable, contrary to public policy, or unenforceable, that provision will be deemed severable
from the Agreement as to the smallest part so held, and the remainder of the Agreement will
Interconnection Facilities Study Agreement --3 --Notch Butte Wind Park # 158
continue in full effect as if the severed provision had not been included, in which case the
Agreement will be construed and interpreted to implement the objectives of the Parties as
stated in this Agreement. The Parties agree that neither Party will be deemed the drafter of
any term that may subsequently be found to be ambiguous or vague.
19.0 Survival. This Agreement shall continue in effect after termination to the extent
necessary to provide for final billings and payments and for costs incurred hereunder, to
permit the determination and enforcement of liability obligations arising from acts or events
that occurred while this Agreement was in effect.
20.0 Assignment and Subcontracts. This Agreement may not be transferred or assigned by
either Party hereto without the prior written consent of the other Party, which such consent
will not be unreasonably withheld. Transmission Provider may subcontract any portion of
the work required by this Agreement without the permission of the Interconnecting
Customer.
21.0 Successors and Assigns. This Agreement shall be binding upon and inure to the benefit
of the Parties hereto and their respective successors and permitted assigns. Nothing in this
Agreement shall be deemed to confer upon any other person any rights, remedies, obligations
or liabilities under or by reason of this Agreement.
22.0 Notices. Any notice required by this Agreement is properly given if submitted in writing
and delivered to the individual set forth below in person, delivered to a nationally recognized
overnight courier service properly addressed and with delivery charges prepaid, delivered to
the United States Postal Service properly addressed and with proper postage prepaid,
transmitted by facsimile with confirmation of successful transmission, or transmitted by
email. Either Party may change at any time the individual authorized to receive notice, an
address, telephone number or email address by providing notice to the other Party.
If to Interconnecting Customer, to: If to the Transmission Provider, to:
Idaho Power Company
Delivery Business Unit
1221 West Idaho Street
Boise,ID 83702
Attn: David M. Angell
ph 208.388.2701
fax [phone]
Email: [e-mail]
23.0 Entire Agreement. This Agreement and its Attachments constitutes the complete
agreement between the Parties concerning its subject matter and supersedes all previous
communications, negotiation, and agreements, whether oral or written, with respect to this
Agreement. None of the terms or obligations under this Agreement may be changed or
Interconnection Facilities Study Agreement --4 --Notch Butte Wind Park # 158
waived in any manner whatsoever by an action or inaction of either Party unless in a writing
duly executed by the Parties. Any provision of this Agreement which is prohibited or
unenforceable in any jurisdiction shall be, as to such jurisdiction, ineffective to the extent of
such prohibition or unenforceability without invalidating the remaining provisions in any
jurisdiction, and shall not invalidate or render unenforceable such provision in any other
jurisdiction.
24.0 Dispute Resolution. Any dispute between Transmission Provider and Interconnection
Customer involving the provisions of this Agreement shall be referred to a senior
representative of Transmission Provider and a senior representative of Interconnection
Customer for resolution on an informal basis as promptly as practicable.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written.
Transmission Provider: Interconnection Customer:
Idaho Power Company -Delivery
Signed ________________ Signed _____________ _
Print Print -------------------------------------------------------
Title Title -------------------------------------------------------
Date ---------------------------Date __________________________ _
Interconnection Facilities Study Agreement -5 --Notch Butte Wind Park # 158
Attachment A
Data to Be Provided by the Interconnection Customer
with the Facilities Study Agreement
1. Provide location plan and simplified one-line diagram of the plant and station facilities.
For staged projects, please indicate future generation, transmission circuits, etc.
On the one-line diagram, indicate the generation capacity attached at each metering
location. (Maximum load on CT/PT)
On the one-line diagram, indicate the location of auxiliary power. (Minimum load on
CT/PT) Amps
2. One set of metering is required for each generation connection to the new ring bus or
existing Transmission Provider station. Number of generation connections: _____ _
3. Will an alternate source of auxiliary power be available during CT/PT maintenance?
Yes No ---
4. Will a transfer bus on the generation side of the metering require that each meter set be
designed for the total plant generation? Yes No
(Please indicate on the one-line diagram).
5. What type of control system or PLC will be located at the Small Generating Facility?
6. What protocol does the control system or PLC use?
7. Please provide a 7.5-minute quadrangle map of the site. Indicate the plant, station,
transmission line, and property lines.
8. Physical dimensions of the proposed interconnection station:
Interconnection Facilities Study Agreement --6 --Notch Butte Wind Park # 158
9. Bus length .from generation to interconnection station:
10. Line length from interconnection station to Transmission Provider's Transmission
System.
11. Tower number observed in the field. (Painted on tower leg)*:
12. Number of third party easements required for transmission lines*:
* To be completed in coordination with Transmission Provider.
13. Is the Small Generating Facility located in Transmission Provider's service area?
Yes ___ No __ _ If No, please provide name oflocal provider:
14. Please provide the following proposed schedule dates:
Begin Construction
Generator step-up transformers
receive back feed power
Generation Testing
Commercial Operation
Interconnection Facilities Study Agreement -7 -
Date: ____________ _
Date: -------------------
Date: _______________ ___
Date: -----------------
Notch Butte Wind Park # 158
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 14
Interconnection Facilities Study Agreement r-~ sf
THIS AGREEMENT is made and entered into this 1 (' day of_J,-",_I,t ___ 200jby and
between L \(. ~ f' ~ De..v~.J.o f (Y;Iot., r 4.,,~ ... e "l'~' a _------"L"----L..~c=__ _____ _
organized and exIsting under the laws of the State of .:t:d~V1,..o
("Interconnection Customer, ") and Idaho power Company, a Corporation existing under the laws
of the State ofIdaho ("Transmission Provider"). Interconnection Customer and Transmission
Provider each may be refelTed to as a "Party, " or collectively as the "Paliies."
RECITALS
WHEREAS, the Interconnection Customer is proposing to develop a Small Generating Facility
or generating capacity addition to an existing Small Generating Facility consistent with the
Interconnection Request completed by the Interconnection Customer on 12/19/05, and
WHEREAS, the Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Provider's Transmission System;
WHEREAS, the Transmission Provider has completed a Feasibility Study and determined that a
System Impact Study is not necessary; and
WHEREAS, the Transmission Provider has proposed to group Network Facilities required for
more than one Interconnection Customer in order to minimize facilities costs through grouped
p3.liicipation, and to allow the Interconnection Customer to bring their proposed facility online
with some capacity limitations until Network Facility Studies can be completed; and
WHEREAS, the IntercOlmection Customer has requested the Transmission Provider to perfonn
a facilities study to specify and estimate the cost of the equipment, engineering, procurement and
construction work needed to implement the conclusions of the system impact study in
accordance with, Good Utility Practice to physically and electrically comlect the Small
Generating Facility with the Transmission Provider's Transmission System.
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the tenns specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Intercolmection Customer elects and the Transmission Provider shall cause a
facilities study consistent with the standard Small Generator Intercomlection Procedures
to be perfonned in accordance with the Open Access Transmission Tariff.
IntercOlUlection Facilities Study Agreement -1 --Notch Butte Wind Park# 158
3.0 The Transmission Provider will proceed with Interconnection Facility Studies, with the
understanding that Network Upgrades associated with this Generator Interconnection
application identified in Idaho Power Company's June 29, 2006 Midpoint West System
Impact Study Report will be necessary, along with the unceltainty of whether or not other
Interconnection Customers proceed with each of their applications for Generator
Interconnection.
4.0 The scope of the facilities study shall be subject to data provided in Attachment A to this
Agreement.
5.0 The Interconnection Facilities Study shall specify and estimate the cost of the equipment,
engineering, procurement and construction work (including overheads) needed to
implement the conclusions of the system impact study(s). The facilities study shall also
identify (1) the electrical switching configuration of the equipment, including, without
limitation, transformer, switchgear, meters, and other station equipment, (2) the nature
and estimated cost of the Transmission Provider's Interconnection Facilities and
Upgrades necessary to accomplish the intercOlmection, and (3) what capacity limitations
or operational issues may exist in the interim until the Transmission Provider completes a
Network Facility Study in the future for the identified study group ofInterconnection
Customers, and (4) an estimate of the time required to complete the construction and
installation of such facilities.
6.0 Any Interconnection Customer may require the installation of facilities required for its
own Small Generating Facility independent of the identified study group if it is willing to
pay all of the costs associated with those facilities.
7.0 A deposit of the good faith estimated facilities study costs of$1 00,000 will be required
from the IntercOlUlection Customer.
8.0 The Interconnection Facilities Study will be completed within 90 Calendar Days, or
sooner, upon execution of this Agreement. Once the Interconnection Facilities Study is
completed, an Interconnection Facilities Study report shall be prepared and transmitted to
the Interconnection Customer within 10 Business Days.
9.0 Any IntercoIDlection Facility Study fees shall be based on the Transmission Provider's
actual costs and will be invoiced to the Interconnection Customer after the study is
completed and delivered and will include a summary of professional time.
10.0 The Interconnection Customer must pay any Interconnection Facility Study costs that
exceed the deposit without interest within 30 Calendar days on receipt of the invoice or
resolution of any dispute. If the deposit 'ex ceeds the invoiced fees, the Transmission Provider
shall refund such excess within 30 Calendar days of the invoice without interest.
Interconnection Facilities Stl1dy Agreement -2 --Notch Butte Wind Park # 158
11.0 Effective Date, Duration and Termination. This Agreement becomes effective upon
execution by all Parties and shall continue until the work required by the Agreement is
completed; provided, however, the Interconnection Customer may terminate this Agreement
at any time after providing written notice. In addition, ifInterconnecting Customer
withdraws its application for interconnection, this Agreement shall terminate effective with
the date the application for interconnection is withdrawn.
12.0 No Obligation to Complete Generating Facility. Nothing in this Agreement obligates
Interconnection Customer to continue or complete development of the Small Generating
Facility or enter into a Small Generator Interconnection Agreement ("SGIA"). A binding
agreement and commitmel)t with respect to interconnecting the Small Generating Facility to
the Transmission System will only occur upon the execution of an SGIA by Transmission
Provider and Interconnection Customer.
13.0 Relationship of the Parties. This Agreement is intended to create an independent
contractor relationship between the Parties. It is not to be const1.11ed as constituting the
Parties as partners, as creating ajoint venture, or as creating any other form oflegal
association or arrangement which would impose liability upon a Party for the act or omission
of the other Party.
14.0 Remedies. In no event will Transmission Provider or its respective agents, employees,
officers, directors, affiliates or representatives be liable for incidental, special, punitive or
consequential damages including but not limited to lost profits, even if the Parties have been
advised of the possibility of such damages. Interconnecting Customer agrees that
Transmission Provider's liability arising out of this Agreement and the services provided
under this Agreement, whether under theories of contract, negligence, tort, strict liability,
wananty or equity will not exceed the amounts payable by Interconnecting Customer to
Transmission Provider for the services that are the basis of such claim.
15.0 Governing Law. The validity, interpretation and perfonnance ofthis Agreement shall be
govemed by the laws of the State of Idaho, without regard to its conflict oflaw principles;
and in addition, shall be subject to all applicable federal laws, regulations and judicial or
administrative orders of the Federal EneTgy Regulatory Commission. Venue for any action
to enforce the terms and conditions of this Agreement shall be in Boise, Idaho.
16.0 Amendment. This Agreement may not be modified except by mutual agreement by a
signed document duly executed by both Parties.
17.0 Waiver. The failure of a Patiy to this Agreement to insist, on any occasion, upon strict
perfomlance of any provision of this Agreement will not be considered a waiver of any
obligation, right, or duty of, or imposed upon, such Pmiy.
18.0 Severability and Savings Clause. If any provision of this Agreement is held to be void,
voidable, contrary to public policy, or unenforceable, that provision will be deemed severable
from the Agreement as to the smallest p ali so held, and the remainder of the Agreement will
Interconnection Facilities Study Agreement --3 -Notch Butte Wind Parle # 158
continue in full effect as if the severed provision had not been included, in which case the
Agreement will be construed and interpreted to implement the objectives of the Parties as
stated in this Agreement. The Parties agJ."ee that neither Pmiy will be deemed the drafter of
any term that may subsequently be found to be ambiguous or vague.
19.0 Survival. This Agreement shall continue in effect after tennination to the extent
necessary to provide for final billings and payments and for costs incuned hereunder, to
permit the detelmination and enforcement of liability obligations arising from acts or events
that occuned while this Agreement was in effect.
20.0 Assignment and Subcontracts. This Agreement may not be transfened or assigned by
either Party hereto without the prior written consent of the other Party, which such consent
will not be umeasonably withheld. Transmission Provider may subcontract any portion of
the work required by this Agreement without the permission of the Interconnecting
Customer.
21.0 Successors and Assigns. This Agreement shall be binding upon and inure to the benefit
ofthe Parties hereto and their respective successors and permitted assigns. Nothing in this
Agreement shall be deemed to confer upon any other person any rights, remedies, obligations
or liabilities under or by reason of this Agreement.
22.0 Notices. Any notice required by this Agreement is properly given if submitted in writing
and delivered to the individual set forth below in person, delivered to a nationally recognized
overnight courier service properly addressed and with delivery charges prepaid, delivered to
the United States Postal Service properly addressed and with proper postage prepaid,
transmitted by facsimile with confinnation of successful transmission, or transmitted by
email. Either Party may change at any time the individual authorized to receive notice, an
address, telephone number or email address by providing notice to the other Party.
If to Interconnecting Customer, to:
J. ,1M f1-Y 1..{ (fA
'2..,,~. 1l t. T2~J
If to the Transmission Provider, to:
Idaho Power Company
Delivery Business Unit
1221 West Idaho Street
Boise, ID 83702
Attn: David M. Angell
ph 208.388.2701
fax [phone]
En"lail: daveangel1(c£{idahopower.col11
23.0 Entire Agreement. This Agreement and its Attaclm1ents constitutes the complete
agreement between the Patiies concerning its subject matter and supersedes all previous
communications, negotiation, and agreements, whether oral or written, with respect to this
Agreement. None of the terms or obligations under this Agreement may be changed or
Interconnection Facilities Study Agreement -4 --Notch Bulte Wind Park # 158
waived in any manner whatsoever by an action or inaction of either Party unless in a writing
duly executed by the Paliies. Any provision of this Agreement which is prohibited or
unenforceable in any jurisdiction shall be, as to such jurisdiction, ineffective to the extent of
such prohibition or unenforceability without invalidating the remaining provisions in any
jurisdiction, and shall not invalidate or render unenforceable such provision in any other
jurisdiction.
24.0 Dispute Resolution. Any dispute between Transmission Provider and Interconnection
Customer involving the provisions of this Agreement shall be referred to a senior
representative of Transmission Provider and a senior representative of Interconnection
Customer for resolution on an informal basis as promptly as practicable.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written.
Transmission Provider: Interconnection Customer:
Idaho Power Company -Delivery
Signed __________________________ __
Print ________________________ _
Title ________________ _ Title
Date _________________________ ___ Date L
{;7
Interc0!1llection Facilities Study Agreement -5 -Notch Butte Wind Park # 158
Attachment A
Data to Be Provided by the Interconnection Customer
with the Facilities Study Agreement
1. Provide location plan and simplified one-line diagram of the plant and station facilities.
For staged projects, please indicate future generation, transmission circuits, etc.
On the one-line diagram, indicate the generation capacity attached at each metering
location. (Maximum load on CT/PT)
On the one-line diagram, indicate the location of auxiliary power. (Minimum load on
CT/PT) Amps
2. One set of metering is required for each generation connection to the new ring bus or
. existing Transmission Provider station. Number of generation connections: ------
3. Will an alternate source of auxiliary power be available during CT IPT maintenance?
y~ ~o .
4. Will a transfer bus 011 the generation side of the metering require that each meter set be
designed for the total plant generation? Yes No
(Please indicate on the one-line diagram).
5. What type of control system or PLC will be located at the Small Generating Facility?
6. What protocol does the control systeJ.TI or PLC use?
7. Please provide a 7.S-minute quadrangle map ofthe site. Indicate the plant, station,
transmission line, and property lines.
8. Physical dimensions of the proposed interconnection station:
IntercOlUlection Facillties Study Agreement --6 -Notch Butle Wind Park # 158
9. Bus length from generation to interconnection station:
10. Line length from interconnection station to Transmission Provider's Transmission
System.
11. Tower number observed in the field. (Painted on tower leg)*:
12. Number of third party easements required for transmission lines*:
* To be completed in coordination with Transmission Provider.
13. Is the Small Generating Facility located in Transmission Provider's service area?
Yes ___ No __ _ If No, please provide name oflocal provider:
14. Please provide the following proposed schedule dates:
Begin Construction
Generator step-up transformers
receive back feed power
Generation Testing
Commercial Operation
Interconnection Facilities Stl1dy Agreement --7 -
Date: --------------
Date: ---------------
Date: ---------------
Date: ____________ ___
Notch Bulte Wind Park # 158
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 15
Small Gen Feasibility Study Agreement
Notch Butte Wind Project # 158
Feasibility Study Agreement-RESTUDY
THIS AGREEMENT is made and entered' into this __ day of 2008, by and
between_ Exerg~ gevelopm~nt Gr,oup of Idaho . ,a Limited Liability Company organized
and existing under the laws ofthe State of Idaho , ("Interconnection Customer,") and
Idaho Power Company a Corporation existing under the laws of the State of Idaho
("Transmission Provider"). Interconnection Customer and Transmission Provider each may be
referred to as a "Party, II or collectively as the "Parties."
RECITALS
WHEREAS, Interconnection Customer is proposing to develop a Small Generating Facility or
generating capacity addition to an existing Small Generating Facility consistent with the
Interconnection Request completed by Interconnection Customer on December 19, 2005 also
known as Project # 158, and
WHEREAS, Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Provider's Transmission System; and
WHEREAS, Interconnection Customer has requested the Transmission Provider to perform a
feasibility RESTUDY to assess the feasibility of interconnecting the proposed Small Generating
Facility with the Transmission Provider's Transmission System, and of any Affected Systems;
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the terms specified shan have
the meanings indicated or the meanings specified in the standard Small Generator .
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause to be
performed an interconnection feasibility study consistent the standard Small Generator
Interconnection Procedures in accordance with the Open Access Transmission Tariff.
3.0 The scope of the feasibility study shall be subject to the assumptions set forth in
Attachment A to this Agreement.
4.0 The feasibility study shall be based on the technical information provided by the
Interconnection Customer in Attachment B. The Transmission Provider reserves the
right to request additional technical information from the Intercotulection Customer as
may reasonably become necessary consistent with Good Utility Practice during the
course of the feasibility study and as designated in accordance with the standard Small
Generator Interconnection Procedures. If the Interconnection Customer modifies its
Interconnection Request, the time to complete the feasibility study may be extended by
agreement of the Parties,
Page 1 of3
Small Gen Feasibility Study Agreement
Notch Butte Wind Project # 158
5.0 In perfonning the study, the Transmission Provider shall rely, to the extent reasonably
practicable, on existing studies of recent vintage. The Interconnection Customer shall not
be charged for such existing studies; however, the Interconnection Customer shall be
responsible for charges associated with any new study or modifications to existing studies
that are reasonably necessary to perform the feasibility study.
6.0 The feasibility study report shall provide the following analyses for the purpose of
identifying any potential adverse system impacts that would result from the
interconnection ofthe Small Generating Facility as proposed:
6.1 Initial identification of any circuit breaker short circuit capability limits exceeded
as a result of the interconnection;
6.2 Initial identification of any thermal overload or voltage limit violations resulting
from the interconnection;
6.3 Initial review of grounding requirements and electric system protection; and
6.4 Description and non~bonding estimated cost of facilities required to interconnect
the proposed Small Generating Facility and to address the identified short circuit
and power flow issues.
7.0 The feasibility study shall model the impact of the Small Generating Facility regardless
ofpul'pose in order to avoid the further expense and interruption of operation for
reexamination of feasibility and impacts if the IntercOlUlection Customer later changes
the purpose for which the Small Generating Facility is being installed.
8.0 The study shall include the feasibility of any interconnection at a proposed project site
where there could be multiple potential Points of IntercOlmection, as requested by the
IntercOlUlection Customer and at the Interconnection Customer's cost.
9.0 A deposit of$l,OOO.OO is required to be paid by the Interconnection customer upon
executing this Interconnection Feasibility Study Agreement.
Transmission Provider shall charge and Interconnection Customer shall pay the actual
costs of the Interconnection Feasibility Study. Any difference between the deposit and
the actual cost of the study shall be paid by or refunded to Interconnection Customer, as
appropriate.
Page 2 of3
Small Gen Feasibility Study Agreement
Notch Butte Wind Project # 158
10.0 Once the feasibility study is completed, a feasibility study report shall be prepared and
transmitted to the Interconnection Customer. Barring unusual circumstances, the
feasibility study must be completed and the feasibility study report transmitted within 30
business days of the Interconnection Customer's agreement to conduct a feasibility study.
11.0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
12.0 The Interconnection Customer must pay any study costs that exceed the deposit without
interest within 30 calendar days on receipt of the invoice or resolution of any dispute. If
the deposit exceeds the invoiced fees, the Transmission Provider shall refund such excess
within 30 calendar days of the invoice without interest.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written.
Transmission Provider: Interconnection Customer:
Idaho Power Company -Delivery
Signed /JllVfcfi:«=-=-==-= _
Printed (1;\.0..-1( C. B-He. -r-;!) Y1 ~ __ ~~ __ -L~~ __ ~ ____ ___
Title L-~c.,4 e '(, -,--~ t) C"~I.{. ('
Date '6 ~ I \ ~ 'dU i) 'G -----------------------------Date () 2 -..ree -2 OCJ E
Page 3 of3
Small Gen Feasibility Study Agreement
Notch Butte Wind Project # 158
Attachment A to Fe'asibility Study Agreement
Assumptions Used in Conducting the Feasibility RESTUDY
The feasibility re-study will be based upon the information set forth in the Interconnection
Request and agreed upon August 8, 2008:
1) Designation of Point of Interconnection and configuration to be studied:
The Point of Interconnection will be on Idaho Power Company's Dietrich all 12,5 kV feeder at
approx T06SR19E22, Lincoln County, Idaho. The project will be-studied for 10.5 MW.
Page 1 of 1
Attachment B
Small Gen Feasibility Study Agreement
Notch Butte Wind Project # 158
Generating Facility Information
Interconnection Customer's Requested In-Service Date: _______ _
Type of Generator: _L_Synchronous Induction Inverter
Generator Nameplate Rating: 1,500 kW (Typical) ----Generator Nameplate kV AR: ____ _
Interconnection Customer or Customer-Site Load: _______ --.:kW (if none, so state)
Typical Reactive Load (ifknown): __________ _
Maximum Physical Export Capability Requested: 10,500 kW
List components of the Small Generating Facility equipment package that are cun·ently certified:
Equipment Type Certifying Entity
1. ___________ __
2. _____________ __
" .J.
4.
5. __________ _
Is the prime mover compatible with the certified protective relay package? Yes No
Generator Manufacturer, Model Name & Number: __________________ _
Version Number: ---------------
Nameplate Output Power Rating in kW: (Summer) _________ (Winter) _________ _
Nameplate Output Power Rating in kVA: (Summer) (Winter) ________ _
Individual Generator Power Factor
Rated Power Factor: Leading: ________ Lagging: __________ _
Total Number of Generators in wind fann to be interconnected: ________ Elevation: ___ _
_ Single phase _Three phase
Inverter Manufacturer, Model Name & Number (ifused): ____________ _
List of adjustable set points for the protective equipment or software: ___________ _
Note: A completed Power Systems Load Flow data sheet must be supplied.
Small Gen Feasibility Study Agreement ,
Notch Butte Wind Project # 158
Small Generating Facility Characteristic Data (for inverter-based machines)
Max design fault contribution current: ___ _ Instantaneous orRMS?
Harmonics Charactelistics: _________________________ _
Start~up requirements: ___________________________________ _
Small Generating Facility Characteristic Data (for rotating machines)
RPM Frequency: _____ _
(*) Neutral Grounding Resistor (If Applicable): _____ _
Synchronous Generators:
Direct Axis Synchronous Reactance, Xd: ___ P.U.
Direct Axis Transient Reactance, X'd: P.U .
Direct Axis Subtransient Reactance, X" d: P.U. --------Negative Sequence Reactance, X2: P.U. -----Zero Sequence Reactance, Xo: P.U.
KVABase: ----------------------Field Volts: -------Field Amperes: _______ _
Induction Generators:
Motoring Power (kW):
h2t or K (Heating Time-C::-o-ns-ta-n-:'t)-:---------Rotor Resistance, Rr: -------Stator Resistance, Rs: ______ _
Stator Reactance, Xs: ------Rotor Reactance, Xr:
Magnetizing Reactance, Xm: _____ _
Short Circuit Reactance, Xd": ------Exciting Current: -------Temperature Rise: -------Frame Size: ------Design Letter: -------Reactive Power Required In Val's (No Load): _____ _
Reactive Power Required In Val's (Full Load): __ ---,---_--:--__
Total Rotating Inertia, H: Per Unit on kVA Base
Excitation and Governor System Data fot, SynchrolLous Generators Only
Provide appropriate IEEE model block diagram of excitation system, governor system and power
system stabilizer (PSS) in accordance with the regional reliability council criteria. A PSS may
be determined to be required by applicable studies. A copy ofthe manufacturer's block diagram
may not be substituted.
2
Interconnection Facilities Information
Small Gen Feasibility Study Agreement
Notch Butte Wind Proj ect # 158
Will a transformer be used between the generator and the point of common coupling? _Yes
No
Will the transfonner be provided by the Interconnection Customer? __ Yes __ No
Transformer Data af Applicable, for Intel"connection Customer-Owned Transformer):
Is the transfonner: __ single phase __ three phase? Size: kV A
Transformer Impedance: % on leVA Base
If Three Phase:
Transformer Primary: __ Volts __ Delta __ Wye __ Wye Grounded
Transformer Secondary: __ Volts __ Delta __ Wye __ Wye Grounded
Transformer Tertiary: __ Volts __ Delta __ Wye __ Wye Grounded
Transformer Fuse Data af Applicable, for Interconnection Customer-OwuedFuse):
(Attach copy of fuse manufacturer's Minimum Melt and Total Clearing Time-Cun'ent Curves)
Manufacturer: ______ Type: _______ Size: ____ Speed: ____ _
Interconnecting Circuit Breaker (if applicable):
Manufacturer: Type: ____ _
Load Rating (Amps): Interrupting Rating (Amps): Trip Speed (Cycles): __ _
Interconnection Protective Relays af Applicable):
If Microprocessor-Controlled:
List of Functions and Adjustable Setpoints for the protective equipment or software:
Setpoint Function Minimum Maximum
1.
2.
3.
4.
If Discrete Components:
(Enclose Copy of any Proposed Time-Overcurrent Coordination Curves)
Manufacturer: ____ Type: __ Style/Catalog No.: ___ Proposed Setting: ___ _
Manufacturer: Type: __ Style/Catalog No.: Proposed Setting: ___ _
Manufacturer: Type: __ Style/Catalog No.: Proposed Setting: ___ _
Manufacturer: Type: __ Style/Catalog No.: Proposed Setting: ___ _
Manufacturer: Type: __ Style/Catalog No.: Proposed Setting: ___ _
3
, .
Current Transformer Data (If Applicable):
Small Gen Feasibility Study Agreement
Notch Butte Wind Project # 158
(Enclose Copy of Manufacturer's Excitation and Ratio Con'ection Curves)
~anufacmrer: ________________________________________ _
Type: _____________ Accuracy Class: _ Proposed Ratio Connection: __
~anufacmrer: -----------------------------------------Type: ___________ Accuracy Class: _ Proposed Ratio Connection: __
Potential Transformer Data (If Applicable):
Manufacturer: _______________________________ _
Type: _________ Accuracy Class: _ Proposed Ratio Connection: __
Manufacturer: ------------------------------Type: ______ Accuracy Class: _ Proposed Ratio Connection: __
General Information
EnClose copy of site electrical one-line diagram showing ,the configuration of all Small
Generating Facility equipment, current and potential circuits, and protection and control
schemes, This one-line diagram must be signed and stamped by a licensed Professional
Engineer if the Small Generating Facility is larger than 50 kW. Is One-Line Diagram Enclosed?
__ Yes __ No
Enclose copy of any site documentation that indicates the precise physical location of the
proposed Small Generating Facility (~, USGS topographic map or other diagram or
documentation).
Proposed location of protective interface equipment on property (include address if different
from the Interconnection Customer's address) ~~ _________________ _
Enclose copy of any site documentation that descdbes and details the operation of the protection
and control schemes, Is Available Documentation Enclosed? __ Yes No
Enclose copies of schematic drawings for all protection and control circuits, relay current
circuits, relay potential circuits, and alannlmonitoring circuits (if applicable).
Are Schematic Drawings Enclosed? _Yes __ No
4
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 16
CP
GENERATOR INTERCONNECTION
FEASIBILITY STUDY
for integration of the proposed
NOTCH BUTTE WIND PARK PROJECT
PROJECT #158
in
LINCOLN COUNTY, IDAHO
to the
IDAHO POWER COMPANY ELECTRICAL SYSTEM
for
EXERGY DEVELOPMENT GROUP OF IDAHO, LLC
the
INTERCONNECTION CUSTOMER
FINAL REPORT
October 21, 2008
1.0 Introd uction
Exergy Development Group of Idaho, LLC has contracted with Idaho Power Company (IPCO)
to perform a Generator Interconnection Feasibility Study for the integration of the proposed 10.5
MW Notch Butte Wind Park Project (project #158). The location ofthe project is in Idaho
Power's Southern Idaho service territory in section 22 ofT06S, R19E Lincoln County, Idaho.
This location is approximately 4 miles east ofIdaho Power Company's Dietrich (DTRC)
substation.
This report documents the basis for and the results of this Feasibility Study for the Notch Butte
Wind Park. It describes the proposed project, the study cases used, the impact of associated
projects, and results of all work in the areas of concern.
2.0 Summary
The proposed project is a 10.5 MW wind farm consisting of seven 1.5 MW GE wind turbines.
The proposed Point ofInterconnection (POI) for the generating facility with the IPCO system is
in the southwest corner of section 22. This is located at the corner of 3 70 Sand 1050 E in
Lincoln County.
The substation feeding this area is DTRC. A new four mile feeder will have to be constructed
with new conductor and poles. This feeder will directly connect the facility to the substation and
will not be connected to any customer loads. A generation interconnection and protection
package will also be required at the POI which will be located at the end of the new four mile
feeder.
This area is served from Shoshone by way of a radial 46 kV transmission tap. Four miles of
conductor will need to be upgraded from DTRC Tap to DTRC substation. A second transformer
at the substation will also be added for capacity and reactive power reasons.
Voltage on the 46 kV bus at DTRC substation attains a level that is too high by IPCO standards.
In order for that voltage to be brought down to within those standards the generation facility will
have to maintain a 95% lagging power factor (consuming V ARs) during periods of light loading.
There are limitations in the Midpoint West transmission system to the west of this project. This
study demonstrates that there is no available transmission capacity when considering other
proposed generation projects ahead of this one in the queue. A System Impact Study has been
conducted to determine the transmission upgrades needed to serve this project (Appendix C).
The estimated cost for all required upgrades ofIPCO owned facilities to serve the full project is
$3,675,000.
3.0 Scope oflnterconnection Feasibility Study
2
The Interconnection Feasibility Study was done and prepared in accordance with Idaho Power
Company Standard Generator Interconnection Procedures, to provide a preliminary evaluation of
the feasibility of the interconnection of the proposed generating project to the Idaho Power
system. As listed in the Interconnection Feasibility Study agreement, the Interconnection
Feasibility Study report provides the following information:
preliminary identification of any circuit breaker short circuit capability
limits exceeded as a result of the interconnection;
preliminary identification of any thermal overload or voltage limit
violations resulting from the interconnection; and
preliminary description and non-binding estimated cost of facilities
required to interconnect the Small Generating Facility to the Distribution
System and to address the identified short circuit and power flow issues.
All other proposed Generation projects prior to this project in the Generator Interconnect queue
were considered in this study. A current list ofthese projects can be found on the Idaho Power
web site as follows :
h itp:/ /www.oatioasis.com/ipco/index.htmI.
4.0 Description of Proposed Generating Project
The Notch Butte Wind Park proposes to connect to the Idaho Power distribution system for an
injection of 10.5 MW (maximum project output) using seven General Electric 1.5 MW wind
turbines.
5.0 Description of Existing Transmission Facilities
The transmission line that serves this area is a 46 kV radial tap that runs from Shoshone
substation to DTRC substation. This tap serves DTRC, as well as a 5.3 MY A hydro generation
facility known as DTRC Drop. Voltage problems occur under light loading conditions on the 46
kV system. Before the addition of the project voltage on the 46 kV bus at the substation is at
1.037 p.u. With the addition of the project the voltage is 1.11 p.u. This voltage must be brought
down to below 1.05 p.u. For this to happen the project will have to run at a 95% lagging power
factor (absorbing 3.36 MVAR).
The conductors on this transmission line are 246.9 MCM AAAC and #2 ACSR, which have
continuous thermal operating ratings of30.9 MVA and 15.2 MVA, respectively. With the
addition of this project the transmission line total load could reach 15.8 when running at a unity
power factor. However, at minimum load DTRC is at approximately 450 kV A. This brings the
total loading on the transmission line to 15.35 MVA. There is not enough capacity from DTRC
Tap to DTRC (#2 ACSR) to serve this project during periods of light loading and high
3
generation. This problem will become even more pronounced with the project running at a 95%
power factor, as mentioned above.
There are limitations in the Midpoint West transmission system to the west of this project. This
study demonstrates that there is no available transmission capacity when considering other
proposed generation projects ahead of this one in the queue. A System Impact Study has been
conducted to determine the trarismission upgrades needed to serve this project (Appendix C).
6.0 Description of Existing Substation Facilities
The substation serving this area is IPCO's DTRC Substation, which is located in section 23 of
T06S, R18E in Lincoln County. The existing substation transformer is a 46:12.5 kV transformer
rated for 9.375 MV A. As mentioned in section 5.0, during periods of light loading DTRC
substation has a load near 450 kVA. With the consideration ofthe size of the proposed project
(10.5 MW) there is not adequate capacity on this transformer to serve this project. Also, with the
large amount of reactive power consumption that the wind park will be required to have, it is
better to keep the generation separate from customer loads.
A new transformer will need to be installed at the substation. This transformer will be a 12.5
MVA 46: 12.5 kV transformer and will only be connected to the dedicated feeder that the
generating facility will be on.
The feeder breakers on the DTRC-Oll and DTRC-012 feeders are Cooper type "VWVE38X"
breakers which are designed for 560 amps continuous load current and have a maximum fault
current interrupting rating of 12,000 amps. These feeder breakers will not be connected to the
generating facility, but this type of breaker would be acceptable for addition on the new
dedicated feeder.
7.0 Description of Existing Distribution Facilities
The distribution feeder serving this area is DTRC-O 11. This is a grounded wye feeder operating
at 12.5 kV. The conductor from the point of interconnection to DTRC substation is 2/0 ACSR
and #4 ACSR which have continuous thermal operating ratings of 6.75 MY A and 3.3 MV A,
respectively. There is not adequate capacity on either of these wires to serve this project. Also,
the wind park should not be connected directly to customer loads due to the high amount of
reactive power that will need to flow to the generating facility.
These two reasons point to the reason why a dedicated distribution feeder is needed from DTRC
substation to the generating facility. This feeder will need to be at 12.5 kV and constructed with
795 AAC conductor. This conductor consumes enough V ARs during light loading at DTRC and
heavy generation that the transmission system sees over 5.5 MVAR with the wind park at a 95 %
power factor. This VAR output is enough to bring down the voltage on the 46 kV system to
below 1.05 p.u.
4
"
The point of interconnection will be to the new 12.5 kV grounded wye feeder near the southwest
corner of section 22. Refer to Appendix A section 3 for additional grounding requirements.
8.0 Description and Cost Estimate of Required Facility Upgrades
At the transmission level four miles of#2 ACSR conductor needs to be replaced with 397 ACSR
for capacity reasons. Also, due to capacity constraints, a new 46: 12.5 kV transformer is needed
at the substation along with a transformer bay and feeder breaker. A new 12.5 kV 795 AAC
distribution feeder will have to be installed from the substation to the wind park, and at the POI,
a Generation Interconnection and Protection package will be required.
Description Estimated Cost
New 12.5 MVA 46: 12.5 kV transformer, bay and
feeder breaker. $1,500,000
4 miles of new distribution line at 795 AAC. $875,000
Generation Interconnection 'Protection Package
(Includes 12.47 kV recloser, controls, CTs, PTs, and
communications. $225,000
4 miles of transmission line upgraded to 397.5 ACSR. $1,075,000
Total Estimated Cost $3,675,000
Table 1: Estimated Costs for Required Upgrades
These cost estimates include direct equipment and installation labor costs, indirect labor costs
and overheads. (Tax Gross Up has not been included presuming construction of interconnection
facilities will not qualify under IRS rules as a taxable event. Allowance for funds used during
construction (AFUDC) has not been included in the cost estimates since it is assumed that IPC
will be provided up-front funding by the Project). These are cost estimates only and final
charges to the customer will be based on the actual construction costs incurred.
9.0 Description of Operating Requirements
In addition to these upgrades, there are also several operating requirements that must be met.
The project will be controlled to operate at a lagging 95% power factor during periods of light
loading. That is, the wind park must consume 3.36 MVAR at full output. The project will also
have to meet the voltage schedule provided by Idaho Power. If these requirements can not be
met, further voltage studies will be necessary. Voltage flicker at startup and during operation
will be limited to less than 5% as measured at the POI. For this to occur, the starting inrush
current can not exceed 484 Amps at the 12.5 kV voltage level. The project is required to comply
with the applicable Voltage and Current Distortion Limits found in IEEE Standard 519-1992
IEEE Recommended Practices and Requirements for Harmonic Control in Electrical Power
Systems.
5
11.0 Conclusions
The requested interconnection of the Notch Butte Wind Park to Idaho Power's system was
studied. The results of this study work confirm that the existing Idaho Power system can be
upgraded to handle this project. The known required upgrades for the existing distribution
system are listed. An IPCO Transmission System Impact Study has been conducted to determine
the transmission upgrades needed to serve this project.
6
APPENDIX A
A-1.0 Method of Study
The Feasibility Study plan inserts the Project up to the maximum requested injection into the
selected Western Electric Coordinating Council (WECC) power flow case and then, using Power
World Simulator Version 12, examines the impacts of the new resource on Idaho Power's
transmission system (lines, transformers, etc.) within the studY area under various
operating/outage scenarios. The WECC and Idaho Power reliability criteria and Idaho Power
operating procedures were used to determine the acceptability of the configurations considered.
The WECC case is a recent case modified to simulate stressed but reasonable pre-contingency
energy transfers utilizing the IPC system. For distribution feeder analysis, Idaho Power utilizes
Advantica's SynerGEE Software.
A-2.0 Acceptability Criteria
The following acceptability criteria were used in the power flow analysis to determine under
which system configuration modifications may be required:
The continuous rating of equipment is assumed to be the normal thermal rating of the
equipment. This rating will be as determined by the manufacturer ofthe equipment or as
determined by Idaho Power. Less than or equal to 100% of continuous rating is
acceptable.
Idaho Power's Voltage Operating Guidelines were used to determine voltage
requirements on the system. This states, in part, that distribution voltages, under normal
operating conditions, are to be maintained within plus or minus 5% (0.05 per unit) of
nominal everywhere on the feeder. Therefore, voltages greater than or equal to 0.95 pu
voltage and less than or equal to 1.05 pu voltage are acceptable.
Voltage flicker during starting or stopping the generator is limited to 5% as measured at
the point of interconnection, per Idaho Power's T &D Advisory Information Manual.
Idaho Power's Reliability Criteria for System Planning was used to determine proper
transmission system operation.
All customer generation must meet IEEE 519 and ANSI C84.1 Standards.
All other applicable national and Idaho Power standards and prudent utility practices
were used to determine the acceptability of the configurations considered.
The stable operation ofthe system requires an adequate supply of volt-amperes reactive
(VARs) to maintain a stable voltage profile under both steady-state and dynamic system
7
conditions. An inadequate supply ofVARs will result in voltage decay or even collapse
under the worst conditions.
Equipment/line/path ratings used will be those that are in use at the time of the study or that are
represented by IPC upgrade projects that are either currently under construction or whose
budgets have been approved for construction in the near future. All other potential future ratings
are outside the scope of this study. Future transmission changes may, however, affect current
facility ratings used in the study.
A-3.0 Grounding Guidance
Idaho Power Company (IPC) requires interconnected transformers to limit their ground fault
current to 20 amps at the point of interconnection.
A-4.0 Electrical System Protection Guidance
IPC requires electrical system protection per Requirements for Generation Interconnections
found on the Idaho Power Web site,
http://www.idahopower.com/aboutuslbusiness/ generationInterconnect/.
A-S.O WECC Coordinated Off-Nominal Frequency Load Shedding and Restoration
Requirements
IPC requires frequency operational limits to adhere to WECC Under-frequency and Over­
frequency Limits per the WECC Coordinated Off-Nominal Frequency Load Shedding and
Restoration Requirements available upon request.
8
CP
APPENDIXB
Project #158 Notch Butte
Point Of Interconnection
New Distribution Feeder
Die tri ch SUbstation
APPENDIXC
GENERATOR INTERCONNECTION
SYSTEM IMP ACT STUDY REPORT
for
Up to 330 MW of New Generation
On the 138 kV Transmission System
In the Twin Falls Area
to
IDAHO POWER COMPANY, Transmission Provider
TRANSMISSION SYSTEM
FINAL REPORT
June 29, 2007
1.0 Introduction
Multiple new generation projects have contacted Idaho Power Company (IPC) to perform
Generator Interconnection System Impact Studies for Network Resource Interconnection
Service at 138 kV for the integration of new generation projects in the Twin Falls area.
This report documents the basis for and the results ofthis System Impact Study. Previous
studies were performed with these new generation projects being non-dispatchable. This
System Impact Study will document the transmission system improvements required if the new
generation projects are dispatchable. It describes the backbone transmission system
improvements required for Network Resource Interconnection Service of the new generation
proposed, the study cases used, outage scenarios assumed, redispatch requirements, and results
of all work in the areas of concern.
2.0 Summary
The performance of the backbone transmission system was evaluated to integrate up to 304
MW of new generation on the 138 kV transmission system in the Twin Falls area. Five phases
of transmission system improvements are required to provide 304 MW of new generation
Network Resource Interconnection Service.
Phase #1:
Phase #2:
Phase #3:
Install an 8 ohm 138 kV Series Reactor on the Upper Salmon-Mountain Home
Junction 138 kV transmission line. Without this improvement, the outage of
the Midpoint-Rattlesnake 230 kV transmission line results in an overload of
the Upper Salmon-Mountain Home Junction 138 kV line with no new
generation in the Twin Falls area. This improvement is necessitated by the
transmission improvements associated with Generation Project 88, and as a
result should be funded by Idaho Power Company -Delivery. This phase of
improvements is estimated at approximately $290,000.
Install a 4 ohm 138 kV Series Reactor on the Mountain Home Junction-Lucky
Peak 138 kV transmission line. Without this improvement, the outage of the
Rattlesnake-Boise Bench 230 kV transmission line results in an overload
exceeding the 30 minute emergency rating of the Mountain Home Junction­
Lucky Peak 138 kV line with new generation levels greater than 42 MW in
the Twin Falls area. This phase of improvements is estimated at
approximately $290,000.
Install a 12.35 ohm 138 kV Series Reactor on the Lower Malad-Mountain
Home Junction 138 kV transmission line and increase the impedance of the
existing Upper Salmon-Mountain Home Junction 138 kV Series Reactor to
26.2 ohms. Without this improvement, the outage of the Midpoint­
Rattlesnake 230 kV transmission line results in an overload exceeding the 30
minute emergency rating of the Lower Malad-Mountain Home Junction 138
kV line with new generation levels greater than 94 MW in the Twin Falls
area. This phase of improvements is estimated at approximately $290,000.
-1-
Phase #4:
Phase #5:
Re-configure the Midpoint-Rattlesnake 230 kV series capacitor bank to allow
113 of the compensation to be bypassed via IPC's SCADA system and install
a "automatic 113 bypass scheme" for overloads exceeding series capacitor's
30 minute emergency equipment rating of 135%. Without this improvement,
the outage of the Midpoint-Boise Bench #3 230 kV transmission line results
in an overload exceeding the 30 minute emergency rating of the Midpoint­
Rattlesnake 230 kV Series C.apacitor Bank with new generation levels greater
than 153 MW in the Twin Falls area. This phase of improvements is
estimated at approximately $100,000.
Fold the Midpoint-DRAM #1 230 kV transmission line into the King
Substation and install a 2301138 kV 300 MV A transformer. Without this
improvement, the outage of the Rattlesnake-Boise Bench 230 kV transmission
line results in an overload exceeding the 30 minute emergency rating of the
Mountain Home Junction-Lucky Peak 138 kV line with new generation levels
greater than 156 MW in the Twin Falls area. This phase of improvements is
estimated at $10,320,000.
Once all five phases of improvements have been completed, the transmission system is capable
of interconnecting approximately 330 MW of new generation in the Twin Falls area and
serving them on a dispatchable basis.
Section 8.0 of this report details the results of studies to quantify generation redispatch
requirements following single contingencies on the transmission system. Reductions in the
amount of generation which may be redispatched following contingencies, are possible by
completing Phase #4 improvements earlier than required or funding optional modifications on
the Midpoint-Boise Bench #3 series capacitor bank.
These cost estimates include direct equipment and installation labor costs, indirect labor costs
and overheads, and allowance for funds used during construction (AFUDC). The proposed
cost allocation is subject to change, as more information is known. These are cost estimates
only and final charges to the customer will be based on the actual construction costs incurred.
3.0 Summary of Interconnection Requests
Requests were made to Idaho Power Co. by multiple generation projects in the Twin Falls area
to study the interconnection of the proposed generation projects to Idaho Power's transmission
system at the 138 kV level for Network Resource Interconnection Service.
4.0 Scope oflnterconnection System Impact Study
The Interconnection System Impact Study was done and prepared in accordance with the
FERC Order 2003-A, Standard Large Generator Interconnection Procedures, to provide a
preliminary evaluation of the System Impact of the interconnection ofthe proposed large
generating project to the Idaho Power transmission system. This study will only be concerned
-2-
with the capabilities ofthe Idaho Power system to manage this new resource within the study
area of the proposed interconnection.
5.0 Description of Existing Transmission Facilities
As shown in Figure 1 of Section 7.0, Midpoint Substation, north of Twin Falls, has three 230 kV
lines that carry bulk power westward to the Boise area. Midpoint-DRAM #1 line utilizes single
715.5 MCM conductor and has a continuous rating of339 MY A. The Midpoint-Rattlesnake-Boise
Bench #2 line utilizes a 2 conductor bundle of715.5 MCM. This line has a continuous rating of
677 MY A. The Midpoint-Boise Bench #3 line has similar conductors and the same rating as the
Rattlesnake-Boise Bench #2 line. In the Mountain Home area, an additional 230 kV line is
planned to carry bulk power westward. The Rattlesnake-Bennett Mountain-Danskin-Mora line
utilizes single 1272 MCM conductors (478 MVA) from Rattlesnake-Bennett Mountain, single
1590 MCM conductors (550 MVA) from Bennett Mountain-Danskin and Danskin-Mora. The
Bennett M~)Untain-Danskin-Mora transmission lines are required for the interconnection of
Generation Project 88; scheduled to be in-service Spring of2008.
In addition to the Midpoint to the Boise area 230 kV lines previously mentioned, there are two
138 kV circuits which can carry power from the Twin Falls area to the Mountain Home area.
They are:
• King-Lower Malad-Mountain Home Junction 138 kV Line
• King-Upper Salmon-Mountain Home Junction 138 kV Line
Generators located in the Twin Falls area which are intended to serve load growth in the Treasure
Valley area, will be adding new incremental flows on top of existing committed east-to-west
transactions across the Midpoint West transmission cutplane. This System Impact study will
model approximately 1100 MW of transfers across the Midpoint West cutplane, prior to this
proposed generator addition. For these studies, the flow level ofthe Midpoint west cutplane is
defined as the sum ofthe flows on the following lines:
• Midpoint-DRAM #1 230 kV line
• Midpoint-Rattlesnake 230 kV Line
• Midpoint-Boise Bench #3230 kV Line
• Lower Malad-Mountain Home Junction 138 kV Line
• Upper Salmon-Mountain Home Junction 138 kV Line
6.0 Description of Configurations Studied
Since the most limiting operating conditions are expected during heavy production on the
upper and middle Snake and Boise River hydro plants, with heavy east-west transfers across
the Idaho Power transmission system, the injection of the new generation at King 138 kV bus
was inserted into a power flow case that would simulate committed (approximately 1100 MW)
pre-contingency flows on the Midpoint West transmission path.
7.0 Post-transient Study Results
-3-
This Interconnection System Impact Study Report is for Network Resource Interconnection
Service at 138 kV, for numerous proposed generation additions in the Twin Falls area. System
transfers across the Midpoint West cutplane are modeled at approximately 1100 MW prior to
the proposed transmission improvements or the proposed generators producing any power.
Hydro generation production for the Boise & Snake plants, were modeled at heavy, but
realistic levels. Output levels for the existing peakers at Danskin and Bennett Mountain were
varied over their operating ranges as appropriate. N-O and N-I outage performance for the
existing system are recorded. For generation projects which will be dispatchable, generation
levels at King 138 kV bus are increased until a transmission system component reaches its 30
minute emergency equipment ratings during N-l outages. IPe's 30 minute emergency
equipment ratings are 115% of continuous thermal ratings on transmission lines and
transformers, and 135% on Midpoint series capacitors. The most effective and cost-efficient
transmission system improvements are then added to the model and King generation is then
increased until 30 minute emergency equipment ratings are reached during N-l outages.
Following any N-I outage, transmission line and transformer loadings which are less than or
equal to the 30 minute emergency equipment ratings (115%), but greater than the equipment
continuous ratings (100%), must be reduced to the continuous ratings by generation
curtailments, redispatch, or some other operating procedure. For the Midpoint series capacitor
banks, following any N-l outage, similar corrective actions are required for loadings which are
less than or equal to the 30 minute emergency equipment ratings (135%), but greater than the
equipment 8 hour rating (110%). Various options to correct overloads following N-l outages
will be explored.
System following Generation Project 88
The following one line diagram depicts the transmission system with no outages, after the
addition of Generation Project 88 and its associated improvements.
'I'I!:I!IIUJ .. "
Midpoint West = 1109 MW
System following Generation Project 88 -No Outages
Figure 1
-4-
System following Generation Project 88 with N-l Outages
The following one line diagram depicts the transmission system following the addition of
Generation Project 88 and its associated improvements in 2008, with no new generation in the
Twin Falls area, and the only N-l outage between Midpoint and the Mountain Home area that
results in loadings above continuous thermal ratings on the l38 kV transmission system.
'j'il~'·
Midpoint West = 1038 MW
Phase #1 Transmission Improvements
The Midpoint Series Capacitor banks are capable of 110% of thermal rating for eight hours. A
prolonged outage of the Midpoint-Rattlesnake 230 kV line will require a reduction of transfers
across the Midpoint West cutplane to prepare for the next contingency. The overload of the
Midpoint-Boise Bench #3 Series Capacitor is less than its 8 hour rating, and will be resolved
with the reduction in transfers. As a result, only the overloads on the l38 kV lines between
Upper Salmon and Mountain Home Junction are problematic. The most effective and cost­
efficient transmission improvement to alleviate these overloads is the installation of a series
reactor on the Upper Salmon-Mountain Home Junction l38 kV line to better balance flows on
the transmission network. A series reactor with an impedance of .042 p.u. (8 ohms) alleviates
the overloads. Since this N-l overload condition pre-exists the addition of any new generation
in the Twin Falls area, Idaho Power Company will take responsibility to fund this series reactor
installation.
The following one line diagram depicts the system with Phase #1 improvements added, no new
generation in the Twin Falls area, and the same N-l as Figure 2.
-5-
Midpoint West = 1038 MW
ULUl,Tr/:o{~ I.OJpu
IUIINS UI,.
Phase #1 Transmission Improvements -Midpoint-Rattlesnake 230 kV Outage
NoN ew Generation
Figure 3
Phase #2 Transmission Improvements
The following one line diagram depicts Phase #1 transmission improvements and 42 MW of
new generation in the Twin Falls area, and the only N-l outage that results in loadings at or
above 30 minute equipment ratings.
Midpoint West = 1077 MW
Phase #1 Transmission Improvements -Rattlesnake-Boise Bench #2 230 kV Outage
42 MW of New Generation
Figure 4
-6-
The most effective and cost-efficient transmission improvement to alleviate this overload is the
installation ofa series reactor on the Mountain Home Junction-Lucky Peak 138 kV line to
better balance flows on the transmission network. A series reactor with an impedance of .021
p.u. (4 ohms) was determined to be the optimal size considering future generation additions.
This overload is the result of the addition of new generation in the Twin Falls area, and as a
result the costs of this improvement will be allocated to new generation interconnections.
The following one line diagram depicts the system with Phase #2 improvements added, 42
MW of new generation in the Twin Falls area, and the same N-l as Figure 4. Please note that
generation redispatch will be required following this contingency to reduce loadings to levels
which can be accommodated continuously.
BURNS IOlpU
Midpoint West = 1075 MW
Phase #2 Transmission Improvements -Rattlesnake-Boise Bench #2 230 kV Outage
42 MWofNew Generation
Figure 5
Phase #3 Transmission Improvements
The following one line diagram depicts Phase #2 transmission improvements and 94 MW of
new generation in the Twin Falls area, and the only N-1 outage that results in loadings at or
above 30 minute equipment ratings.
-7-
Midpoint West = 1106 MW
Phase #2 Transmission Improvements -Midpoint-Rattlesnake 230 kV Outage
94 MW of New Generation
Figure 6
To interconnect generation quantities greater than 94 MW will require additional transmission
system improvements. The most effective and cost-efficient transmission improvements to
alleviate these overloads are the installation of a new series reactor on the Lower Malad­
Mountain Home Junction 138 kV line and an increase in the impedance of the Upper Salmon­
Mountain Home Junction 138 kV line series reactor. These improvements, referred to as Phase
#3, will better balance flows on the transmission network. A Lower Malad-Mountain Home
Junction series reactor impedance of .065 p.u. (12.35 ohms) was determined to be the optimal
size considering future generation additions. The impedance ofthe Upper Salmon-Mountain
Home Junction series reactor should be increased to .138 p.u. (26.2 ohms). This overload is
the result ofthe addition of new generation in the Twin Falls area, and as a result the costs of
this improvement will be allocated to new generation interconnections.
The following one line diagram depicts the system with Phase #3 improvements added, 94
MW of new generation in the Twin Falls area, and the same N-l as Figure 6.
-8-
Midpoint West = 1099 MW
Phase #3 Transmission Improvements -Midpoint-Rattlesnake 230 kV Outage
94 MW of New Generation
Figure 7
Phase #4 Transmission Improvements
The following one line diagram depicts Phase #3 transmission improvements and 153 MW of
new generation in the Twin Falls area, and the only N-l outage that results in loadings at or
above 30 minute equipment ratings.
IURHS L.Gl..,
Midpoint West = 1172 MW
Phase #3 Transmission Improvements -Midpoint-Boise Bench #3 230 kV Outage
153 MW of New Generation
Figure 8
-9-
To interconnect generation quantities greater than 153 MW will require additional transmission
system improvements. Ifnew generation levels exceed 153 MW, and the Midpoint-Boise
Bench #3230 kV line opens, the series capacitor bank on the Midpoint-Rattlesnake 230 kV
transmission line may exceed its 30 minute overload capability of 135%. Presently, both the
230 kV series capacitor banks at Midpoint are configured to operate either fully in-service or
fully by-passed. The most effective and cost-efficient transmission improvement to alleviate
this overload is the re-configuration of the Midpoint-Rattlesnake 230 kV series capacitor bank
to allow one third of the compensation to be bypassed. In addition, an automatic control
scheme should be employed to bypass one third of the series capacitor bank when appropriate
system conditions are detected. The re-configuration of the series capacitor bank and the
addition of the automatic control scheme is referred to as Phase #4.
The following one line diagram depicts the system with Phase #4 improvements added, 153
MW of new generation in the Twin Falls area, and the same N-l as Figure 8.
Midpoint West = 1145 MW
Phase #4 Transmission Improvements -Midpoint-Boise Bench #3 230 kV Outage
153 MW of New Generation
Figure 9
Phase #5 Transmission Improvements
The following one line diagram depicts Phase #4 transmission improvements and 156 MW of
new generation in the Twin Falls area, and the only N-l outage that results in loadings at or
above 30 minute equipment ratings.
-10-
'URNS 10111"
Midpoint West = 1151 MW
Phase #4 Transmission Improvements -Rattlesnake-Boise Bench #2 230 kV Outage
156 MW of New Generation
Figure 10
To interconnect generation quantities greater than 156 MW will require additional transmission
system improvements. If new generation levels exceed 156 MW, and the Rattlesnake-Boise
Bench #2230 kV line opens, the Mountain Home Junction-Lucky Peak 138 kV transmission
line may exceed its 30 minute overload capability of 115%. The required system
improvements are referred to as "Phase #5" and include folding the Midpoint-DRAM #1 230
kV transmission line into and back out of the King Substation and installing a 230/138 kV 300
MV A transformer. This overload is the result of the addition of new generation in the Twin
Falls area, and as a result the costs of this improvement will be allocated to new generation
interconnections.
The following one line diagram depicts the system with Phase #5 improvements added, 156
MW of new generation in the Twin Falls area, and the same N-1 as Figure 10.
-11-
Midpoint West = 1165 MW
Phase #5 Transmission Improvements -Rattlesnake-Boise Bench #2 230 kV Outage
156 MW of New Generation
Figure 11
Phase #5 transmission improvements are capable of accommodating approximately 330 MW
of new generation in the Twin Falls area. The following one line diagram depicts the system
with Phase #5 improvements added, 330 MW of new generation in the Twin Falls area, and the
loss of the Midpoint-Rattlesnake 230 kV transmission line. At 330 MW of new generation in
the Twin Falls area, two other outages also result in transmission system components loaded at
their 30 minute emergency equipment ratings.
Midpoint West = 1272 MW
'''''1-'''' /' ,~~~
Phase #5 Transmission Improvements -Midpoint-Rattlesnake #2230 kV Outage
330 MW of New Generation
Figure 12
-12-
8.0 Generation Redispatch Requirements
Generators which have chosen to be dispatchable are allowed to operate at levels which may
create overloads at or below 30 minute emergency equipment ratings following N-l
contingencies. Following any N-l outage, transmission line and transformer loadings which
are less than or equal to the 30 minute emergency equipment ratings (115%), but greater than
the equipment continuous ratings (100%), must be reduced to the continuous ratings by
generation curtailments, redispatch, or some other operating procedure. For the Midpoint
series capacitor banks, following any N-l outage, similar corrective actions are required for
loadings which are less than or equal to the 30 minute emergency equipment ratings (135%),
but greater than the equipment 8 hour rating (110%).
The following table summarizes generation curtailment requirements for the proposed
generation projects modeled at King 138 kV Substation; for various timeframes, and for
numerous transmission system single contingencies.
The fourth column of the table provides information regarding potential benefits of requesting
and funding an optional improvement. The improvement evaluated is the re-configuration of
the Midpoint-Boise Bench #3 230 kV series capacitor bank to allow one third of the
compensation to be bypassed. Unlike Phase #4, no automatic control scheme is contemplated.
This Optional Improvement may reduce the magnitude of generation which must be
redispatched during a Midpoint-Rattlesnake 230 kV Transmission Line outage. The Optional
Improvement is estimated at approximately $50,000.
The fifth column ofthe table provides information regarding potential benefits of completing a
portion of Phase #4 improvements early. Phase #4 improvements can be separated into two
components. The first component is the "re-configuration" of the Midpoint-Rattlesnake 230
kV series capacitor so it can be operated "fully in-service", "1/3 bypassed", "2/3 bypassed", or
"fully bypassed". The second component was the "automatic control scheme". The Phase #4a
improvement contained in the fifth column is for expediting only the "re-configuration"
component. Expediting the phase #4a improvement may reduce the magnitude of generation
which must be redispatched during a Midpoint-Boise Bench #3 230 kV Transmission Line
outage. The Phase #4a improvement is estimated at approximately $50,000.
-13-
Maximum Maximum I
Maximum Allowable Allowable
Allowable Maximum Generation Generation
Generation Allowable After N-l After N-l
Before Generation w/Optional wlPhase #4a
Contingency N-l After N-l Improvement Improvement
After Phase #1, but before Phase #2
Midpoint-Boise Bench #3 230 kV Line 42MW OMW OMW 42MW
Midpoint-Rattlesnake 230 kV Line 42MW 7MW 7MW 7MW
Rattlesnake-Boise Bench 230 kV Line, also
open Mountain Home Junction-Danskin 138 42MW 9MW 9MW 9MW
kV Line
Danskin-Mora 230 kV Line, also open
Mountain Home Junction-Danskin 138 kV 42MW 42MW 42MW 42MW
Line
After Phase #2, but before Phase #3
Midpoint-Boise Bench #3230 kV Line 94MW OMW OMW 94MW
Midpoint-Rattlesnake 230 kV Line 94MW 9MW 9MW 9MW
Rattlesnake-Boise Bench 230 kV Line, also
open Mountain Home Junction-Danskin 138 94MW 32MW 32MW 32MW
kV Line
Danskin-Mora 230 kV Line, also open
Mountain Home Junction-Danskin 138 kV 94MW 80MW 80MW 80MW
Line
Mountain Home Junction-Lower Malad 138 94MW 49MW 49MW 49MW kV Line
Lucky Peak-Micron 138 kV Line 94MW 45MW 45MW 45MW
Danskin 230/138 kV Transformer 94MW 90MW 90MW 90MW
After Phase #3, but before Phase #4
Midpoint-Boise Bench #3 230 kV Line 153MW OMW OMW 153 MW
Midpoint-Rattlesnake 230 kV Line 153MW 17MW 53MW 17MW
Rattlesnake-Boise Bench 230 kV Line, also
open Mountain Home Junction-Danskin 138 153MW 71MW 71 MW 71 MW
kV Line
Danskin-Mora 230 kV Line, also open
Mountain Home Junction-Danskin 138 kV 153MW 120MW 120MW 120MW
Line
Mountain Home Junction-Lower Malad 138 153 MW 129MW 129MW 129MW kV Line
Lucky Peak-Micron 138 kV Line 153 MW 84MW 84MW 84MW
Danskin 2301138 kV Transformer 153 MW 125MW 125 MW 125MW
Maximum Maximum
Maximum Allowable Allowable
Allowable Maximum Generation Generation
Generation Allowable After N-l After N-l
Before Generation w/Optional wlPhase #4a
Contingency N-l After N-l Improvement Improvement
After Phase #4, but before Phase #5
Midpoint-Boise Bench #3230 kV Line 156MW 156MW 156MW N/A
Midpoint-Rattlesnake 230 kV Line 156MW 18MW 53MW N/A
Rattlesnake-Boise Bench 230 kV Line, also
open Mountain Home Junction-Danskin 138 156MW 71MW 71MW N/A
kV Line
Danskin-Mora 230 kV Line, also open
Mountain Home Junction-Danskin 138 kV 156MW 120MW 120MW N/A
Line
Mountain Home Junction-Lower Malad 138 156MW 129MW 129MW N/A kV Line
Lucky Peak-Micron 138 kV Line 156MW 84MW 84MW N/A
Danskin 230/138 kV Transformer 156MW 125MW 125MW N/A
After Phase #5
Midpojnt-Boise Bench #3 230 kV Line 330MW 140MW 140MW N/A
Midpoint-Rattlesnake 230 kV Line 330MW 25MW 123MW N/A
Rattlesnake-Boise Bench 230 kV Line, also
open Mountain Home Junction-Danskin 138 330MW 254MW 254MW N/A
kV Line
Danskin-Mora 230 kV Line, also open
Mountain Home Junction-Danskin 138 kV 330MW 310MW 310MW N/A
Line
Mountain Home Junction-Lower Malad 138 330MW 280MW 280MW N/A kV Line
Lucky Peak-Micron 138 kV Line 330MW 265MW 265MW N/A
Danskin 2301138 kV Transformer 330MW 295MW 295MW N/A
King 230/138 kV Transformer 330MW 245MW 245MW N/A
-/
-15-
9.0 Fault Study Results
Since this System Impact Study lumps all the proposed generation additions at King 138 kV
bus, this Draft Report makes no attempt to address fault study concerns. Each proposed
generation project will have to be evaluated individually based on its specific location.
10.0 Transient Stability Study Results
The Midpoint West Transmission System is not transient stability limited. Therefore, no
transient stability studies were performed.
11.0 Conclusions
The System Impact of interconnecting up t0304 MW of new generation in the Twin Falls area
to Idaho Power's 138 kV transmission system was studied. Five phases of transmission system
improvements are required to provide Network Resource Interconnection Service to 304 MW
of new generation, on a dispatchable basis. Phase # 1 is the installation of an 8 ohm 13 8 k V
Series Reactor on the Upper Salmon-Mountain Home Junction 138 kV transmission line. This
improvement corrects an N-l overload that exists before any new generation is added in the
Twin Falls area. As a result, the estimated $290,000 cost of this improvement will be borne by
Idaho Power Company. After approximately 42 MW of new generation is added, Phase #1
improvements are no longer sufficient. Phase #2 improvements require the installation of a 4
ohm 138 kV Series Reactor on the Mountain Home Junction-Lucky Peak 138 kV transmission
line. The estimated $290,000 cost of this improvement should be allocated to new generator
interconnections. Following the addition of approximately 94 MW of new generation, Phase
#3 transmission improvements are required. Phase #3 improvements require the installation a
12.35 ohm 138 kV Series Reactor on the Lower Malad-Mountain Home Junction 138 kV
transmission line, and increasing the impedance ofthe existing Upper Salmon-Mountain Home
Junction 138 kV Series Reactor to 26.2 ohms. The estimated $290,000 cost of Phase #3
improvements should be allocated to new generator interconnections. Following the addition
of approximately 153 MW of new generation, Phase #4 transmission improvements are
required. Phase #4 involves re-configuring the Midpoint-Rattlesnake 230 kV series capacitor
bank to allow 113 of the compensation to be bypassed via IPC's SCADA system and install a
"automatic 1/3 bypass scheme" for overloads exceeding the series capacitor's 30 minute
emergency equipment rating of 135%. The estimated $100,000 cost of this improvement
should be allocated to new generator interconnections. Following the addition of
approximately 156 MW of new generation, Phase #5 transmission improvements are required.
Phase #5 involves folding the Midpoint-DRAM #1 230 kV transmission line into and back out
of the King Substation and installing a 2301138 kV 300 MVA transformer. The estimated
$10,320,000 cost of this improvement should be allocated to new generator interconnections.
Phase #5 transmission improvements are adequate to interconnect approximately 330 MW of
new generation in the Twin Falls area, on a dispatchable basis, before additional improvements
are required.
~I
APPENDIX A
1.0 Method of Study
The study methodology inserts the proposed generators up to the maximum requested output of
304 MW into the selected WECC power flow case and then, using the PowerWorld Simulator
powerflow program, examines the impacts of the new resource on Idaho Power's transmission
system (lines, transformers, etc.) within the study area under various operating/outage
scenarios. The WECC and Idaho Power reliability criteria and Idaho Power operating
procedures were used to determine the acceptability of the alternatives considered. The WECC
case is a recent case modified to simulate stressed but reasonable pre-contingency energy
transfers utilizing the IPC system.
2.0 Acceptability Criteria
The following acceptability criteria were used in the power flow analysis to determine the
acceptability of the alternatives:
Loadings on transmission lines and transformers should not exceed 115% of the
continuous rating, immediately following any N-l outage. Loading on the Midpoint
230 kV series capacitors should not exceed 135% ofthe continuous rating, immediately
following any N-l outage. These loadings levels of 115% on transmission lines and
transformers and 135% on Midpoint series capacitors correspond to IPC's 30 minute
emergency equipment ratings. Any loadings immediately following an N-l outage,
less than the 30 minute emergency rating is acceptable.
Loadings which are less than the 30 minute emergency equipment ratings, but greater
than the equipment continuous ratings, must be reduced to the continuous ratings by
generation curtailments, re-dispatch, or some other operating procedure. Any remedial
action schemes (RAS) or other transmission switching, must be judged to be reasonable
before the alternatives performance can be deemed acceptable.
The continuous rating of equipment is assumed to be the normal thermal rating of the
equipment. This rating will be as determined by the manufacturer ofthe equipment or
as determined by Idaho Power. Less than or equal to 100% of continuous rating for
transmission lines and transformers is acceptable. Less than or equal to 110% of
continuous rating for the Midpoint 230 kV series capacitors is acceptable.
Transmission voltages, under normal operating conditions, are maintained within plus
or minus 5% (0.05 per unit) of nominal. Therefore, voltages greater than or equal to
0.95 p.u. voltage and less than or equal to 1.05 p.u. voltage are acceptable.
The stable operation of the transmission system requires an adequate supply of volt­
amperes reactive (V ARs) to maintain a stable voltage profile under both steady-state
and dynamic system conditions. An inadequate supply ofVARs will result in voltage
-17-
decay or even collapse under the worst conditions. Idaho Power designs its system to
integrate Network Resources at full capability during specified outage conditions.
Equipment/line/path ratings used will be those that are in use at the time of the study or that are
represented by IPC upgrade projects that are either currently under construction or whose
budgets have been approved for construction in the near future. All other potential future
ratings are outside the scope of this study. Future transmission changes may, however, affect
current facility ratings used in the study.
-18-
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 17
Exergy Development Group of Idaho, LLC
Attn: James Carkulis
802 West Bannock, Suite 1200
Boise, ID 83702
RE: Notch Butte Wind Park-GI Project # 158
Dear James:
®
An IDACORP Company
October 23, 2008
Enclosed is the Final Feasibility Study Report for the above-referenced project. Since no System Impact
Study is required, I have enclosed two (2) copies of the Facility Study Agreement (FSA) for the above­
referenced project.
In order to proceed with this application, Idaho Power must receive your agreement to proceed with the
project by executing both copies of the FSA and submitting completed Attachments, along with the
deposit in order to remain in the Generator Interconnection queue. The deposit under this FSA is
$30,000 based on the estimated engineering costs.
If you wish to proceed, please sign both copies and submit them with the completed Attachment, along
with the deposit to Idaho Power Company, attn: Rowena Bishop by November 25,2008, otherwise your
application will be deemed withdrawn. Please contact me if you have any questions.
Enclosures: Final Feasibility Study Report
2 copies -Facility Study Agreement
Rowena Bishop/IPC
Ed Kosydar/IPC
Sincerely,
Marc Patterson
Engineering Leader, T &D Planning
Ph. 208.388.2712
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 18
Small Gen Feasibility Study Agreement -RESTUDY
Notch Butte Wi rid Project # 158
Revised Feasibility Study Agreement
THIS AGREEMENT is made and entered into this <f ~day of Dec.€W1be.r 2008 by and
between[J(er17 Deve!l2fi?4tf G"4" r:£ 1J.",L.,.. ,a u~+eJ L;:-s.Io~I:1y (""1f"'~ organized
and existing under the laws of tbe State of I cfbo , ("Iriterconnecti Customer,")
and Idaho Power Company a Corporation existing under the laws of the State ofIdaho
("Transmission Provider"). Interconnection Customer and Transmission Provider each may be
referred to as a "Party," or collectively as the "Parties."
RECITALS
WHEREAS, Interconnection Customer is proposing to develop a Small Generating Facility or
generating capacity addition to an existing Small Generating Facility consistent with the
Interconnection Request completed by Interconnection Customer on December 19,2005, also
known as Project # 158; and
WHEREAS, Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Provider's Transmission System; and
WHEREAS, Interconnection Customer has requested the Transmission Provider to perform a
feasibility study to assess the feasibility of interconnecting the proposed Small Generating
Facility with the Transmission Provider's Transmission System, and of any Affected Systems;
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the terms specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause to be
performed an interconnection feasibility study consistent the standard Small Generator
Interconnection Procedures in accordance with the Open Access Transmission Tariff.
3.0 The scope of the feasibility study shall be subject to the assumptions set forth in
Attachment A to this Agreement.
4.0 The feasibility study shall be based on the technical information provided by the
rnterconnection Customer in the Interconnection Request, as may be modified as the
result of the scoping meeting. The Transmission Provider reserves the right to request
additional technical information from the Interconnection Customer as may reasonably
become necessary consistent with Good Utility Practice during the course of the
feasibility study and as designated in accordance with the standard Small Generator
Interconnection Procedures. If the Interconnection Customer modifies its Interconnection
Request, the time to complete the feasibility study may be extended by agreement of the
Parties.
Page 1 of3
Small Gen Feasibility Study Agreement ~ RESTUDY
Notch Butte Wind Project # 158
5.0 In performing the study, the Transmission Provider shall rely, to the extent reasonably
practicable, on existing studies of recent vintage. The Interconnection Customer shall not
be charged for such existing studies; however, the Interconnection Customer shall be
responsible for charges associated with any new study or modifications to existing studies
that are reasonably necessary to perform the feasibility study.
6.0 The feasibility study report shall provide the following analyses for the purpose of
identifying any potential adverse system impacts that would result from the
interconnection of the Small Generating Facility as proposed:
6.1 Initial identification of any circuit breaker short circuit capability limits exceeded
as a result of the interconnection;
6.2 Initial identification of any thermal overload or voltage limit violations resulting
from the interconnection;
6.3 Initial review of grolUlding requirements and electric system protection; and
6.4 Description and non-bonding estimated cost of facilities required to interconnect
the proposed Small Generating Facility and to address the identified short circuit
and power flow issues.
7.0 The feasibility study shall model the impact of the Small Generating Facility regardless
of purpose in order to avoid the further expense and interruption of operation for
reexamination of feasibility and impacts if the Interconnection Customer later changes
the purpose for which the Small Generating Facility is being installed.
8.0 The study shall include the feasibility of any interc0lU1ection at a proposed project site
where there could be mUltiple potential Points of Interconnection, as requested by the
Interconnection Customer and at the Interconnection Customer's cost.
9.0 Interconnection Customer will pay a study deposit of $1,000.00 for the perfonnance of
the Interc0lU1ection Feasibility Study.
Transmission Provider shall charge and Interconnection Customer shall pay the actual
costs of the Interconnection Feasibility Study. Any difference between the deposit and
the actual cost of the study shall be paid by or refunded to Interconnection Customer, as
appropriate.
Page 2 of3
Small Gen Feasibility Study Agreement -RESTUDY
Notch Butte Wind Project # 158
10.0 Once the feasibility study is completed, a feasibility study report shall be prepared and
transmitted to the Interconnection Customer. Barring unusual circumstances, the
feasibility study must be completed and the feasibility study report transmitted within 30
business days of the Interconnection Customer's agreement to conduct a feasibility study.
11.0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
12.0 The Interconnection Customer must pay any study costs that exceed the deposit without
interest within 30 calendar days on receipt of the invoice or resolution of any dispute. If
the deposit exceeds the invoiced fees, the Transmission Provider shall refund such excess
within 30 calendar days of the invoice without interest.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written.
Transmission Provider:
Idaho Power Company -Delivery
Interconnection Customer: ~ C?etg{o(l!"'~~ Gfl>'-"f ...{:' fJc..L
Printed Ma.rc. rt.+I/'r~oV\.
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Page 3 of3
Small Gen Feasibility Study Agreement -RESTUDY
Notch Butte Wind Project # 158
Attachment A
Assumptions Used in Conducting the Feasibility Study
The feasibility Re-study will be based upon the infonnation set forth in the Interconnection
Request and requested by the Interconnection Customer upon review of the Feasibility Study
dated October 21,2008:
1) Designation of Point of Interconnection and configuration to be studied.
The Point ofInterconnection is on Idaho Power Company's (Dietrich 011) 12.5 leV distribution
feeder at approximatelyT06SR19E22, in Lincoln County, Idaho.
The total capacity to be studied is 18 MW.
pr'J'af
..fo Act.-J S <./6 f'lz-iwrt. V}1 V:s;,Lc
Page 1 of 1
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHM,ENT 19
CP
GENERATOR INTERCONNECTION
FEASIBILITY STUDY
for integration of the proposed
NOTCH BUTTE WIND PARK PROJECT
PROJECT #158
in
LINCOLN COUNTY, IDAHO
to the
IDAHO POWER COMPANY ELECTRICAL SYSTEM
for
EXERGY DEVELOPMENT GROUP OF IDAHO, LLC
the
INTERCONNECTION CUSTOMER
FINAL REPORT
January 22,2008
1.0 Introduction
Exergy Development Group of Idaho, LLC has contracted with Idaho Power Company CIPCO)
to pelfornl a Generator Interconnection Feasibility Study for the integration of the proposed 18
MW Notch Butte Wind Park Project (project #158). The location of the project is in Idaho
Power's Southern Idaho service territory in section 22 ofT06S, R19E Lincoln County, Idaho.
This location is approximately 4 miles east ofIdaho Power Company's Dietrich (DTRC)
substation. See Appendix B for general location map ofproject area.
This report documents the basis for and the results of this Feasibility Study for the Notch Butte
Wind Park. It describes the proposed project, the study cases used, the impact of associated
projects, and results of all work in the areas of concern.
2.0 Summary
The proposed project is an 18 MW wind farm consisting of twelve 1.5 MW GE wind turbines.
A new substation will need to be built on the site of the wind park. This substation will have a
22 MY A transformer with LTC. It will be connected to the Midpoint to Wood River 138 kV
transmission line by way of a 5.5 mile transmission tap. The proposed Point of Interconnection
(POI) for the generating facility with the IPCO system is in the northwest comer of section 22.
This will be located outside of the substation at the 34.5 kV voltage level.
There are limitations in the Midpoint West transmission system to the west of this project. This
study demonstrates that there is no available transmission capacity when considering other
proposed generation projects ahead of this one in the queue. A System Impact Study has been
conducted to determine the transmission upgrades needed to serve this project (Appendix C).
The estimated cost for all required upgrades ofIPCO owned facilities to serve the full project is
$4,328,000.
3.0 Scope ofInterconnection Feasibility Study
The Interconnection Feasibility Study was done and prepared in accordance with Idaho Power
Company Standard Generator Interconnection Procedures, to provide a preliminary evaluation of
the feasibility of the interconnection of the proposed generating project to the Idaho Power
system. As listed in the Interconnection Feasibility Study agreement, the Interconnection
Feasibility Study report provides the following information:
preliminary identification of any circuit breaker short circuit capability
limits exceeded as a result of the interconnection;
preliminary identification of any thennal overload or voltage limit
violations resulting from the interconnection; and
2
preliminary description and non-binding estimated cost of facilities
required to interconnect the Small Generating Facility to the Distribution
System and to address the identified short circuit and power flow issues.
All other proposed Generation projects prior to this project in the Generator Interconnect queue
were considered in this study. A current list of these projects can be found on the Idaho Power
web site as follows:
http://www.oatioasis.comiipco/index.html.
4.0 Description of Proposed Generating Project
Notch Butte Wind Park proposes to connect to the Idaho Power transmission system for an
injection of 18 MW (maximum project output) using twelve General Electric 1.5 MW wind
turbines.
5.0 Description of Transmission Facilities
The closest 138 kV transmission line to the wind park is the Midpoint to Wood River 138 kV
transmission line. This line serves Richfield, Carey and the cities of the Wood River Valley. As
such, this line has the least capacity during the winter months when the Wood River Valley
consumes its peak amount of electricity. If the generation facility is run at unity power factor
there is very little change 011 this transmission system. It raises the voltage at the interconnection
to the existing Midpoint to Wood River line by 0.0035 p.u. and does not increase the voltage on
this line to more than 1.05 p.u. During the summer months the loading on the line is smaller and
the voltage change is the same as during the winter months. No system upgrades need to be
undertaken to accommodate this additional generation during these peak periods.
However, during periods of light loading in the spring and fall months this generation addition
pushes the voltage over 1.05 p.u. at the new Notch Butte Wind substation, as well as Lincoln and
Silver substations. Due to the minimal voltage rise at those locations the voltage should be able
to be brought under 1.05 p.u. by the Load Tap Changers (LTCs) at those stations.
There are limitations in the Midpoint West transmission system to the west of this project. This
study demonsti'ates that there is no available transmission capacity when considering other
proposed generation projects ahead of this one in the queue. A System Impact Study has been
conducted to determine the transmission upgrades needed to serve this project (Appendix C).
6.0 Description of Substation Facilities
Dietrich is the closest substation but it is fed from the 46 kV transmission system. In order to
have a connection at the 138 kV transmission level a new substation will have to be built. This
substation will be located at the wind park and will provide voltage transformation from 34.5 kV
3
to 138 kV. The size of the transformer will be 22 MV A and it will need to have an LTC per
IPCO standards. A power circuit breaker at the new substation has not been considered in this
study and is not included in any cost estimates.
7.0 Description of Existing Distribution Facilities
The distribution in this area is served from Dietrich substation. However, it is assumed that
Exergy will be building their own distribution for connection to the substation. Therefore, no
distribution related expenses are included in this study besides the generation interconnection
and protection package. This package will be located outside of the new substation at the 34.5
kV voltage level and POI.
8.0 Circuit Breaker Short Circuit Limits
Existing power circuit breakers on the 138 kV Midpoint -Wood River line were evaluated for
short circuit interrupting capability with the addition of the 18 MW Notch Butte Wind project.
This feasibility study indicates there is adequate short circuit interrupting capability on these
breakers for the addition of this generation project.
8.0 Description and Cost Estimate of Required Facility Upgrades
At the transmission level five and a halfmHes 0[397 ACSR conductor needs to be built fi'om the
Midpoint to Wood River 138 leV transmission line to the location of the wind parle. Three air
brakes will also be needed at this transmission connection. A new substation will have to be
built with a 22 MY A h·ansformer. At the POI, a Generation Interconnection and Protection
package will be required.
Description Cost
5.5 mile 138 kV 397 ACSR transmission tap from the
Midpoint -Wood River line and air breaks. $1,530,000
New Substation with 22 MY A 138:34.5 leV
transfOlmer and LTC $2,510,000
Point of Interconnection (generation interconnection
and protection package). $288,000
Total Estimated Cost $4,328,000
Table 1: Estimated Costs for Requrred Upgrades
These cost estimates include direct equipment and installation labor costs, indirect labor costs
and overheads. (Tax Gross Up has not been included presuming construction of interconnection
facilities will not qualify under IRS rules as a taxable event. Allowance for funds used during
4
construction (AFUDC) has not been included in the cost estimates since it is assumed that IPeO
will be provided up-front funding by the Project). These are cost estimates only and final
charges to the customer will be based on the actual construction costs incurred.
9.0 Description of Operating Requirements
In addition to these upgrades, there are also several operating requirements that must be met.
The project will have to meet the voltage schedule provided by Idaho Power. If these
requirements can not be met, further voltage studies will be necessary. Voltage flicker at startup
and during operation will be limited to less than 5% as measured at the POI. The project is
required to comply with the applicable Voltage and Current Distortion Limits found in IEEE
Standard 519-1992 IEEE Recommended Practices and Requirementsfor Harmonic Control in
Electrical Power Systems.
11.0 Conclusions
The requested interconnection of the Notch Butte Wind Park to Idaho Power's system was
studied. The results of this study work confirm that the existing Idaho Power system can be
upgraded to handle this project. The known required upgrades for the system are listed. An
!PCO Transmission System Impact Study has been conducted to determine the transmission
upgrades needed to serve this project.
5
APPENDIX A
A-1.0 Method of Study
The Feasibility Study plan inserts the Project up to the maximum requested injection into the
selected Western Electric Coordinating Council (WECC) power flow case and then, using Power
World Simulator Version 12, examines the impacts of the new resource on Idaho Power's
transmission system (lines, transformers, etc.) within the study area under various
operating/outage scenarios. The WECC and Idaho Power reliability criteria and Idaho Power
operating procedures were used to determine the acceptability of the configurations considered.
The WECC case is a recent case modified to simulate stressed but reasonable pre-contingency
energy transfers utilizing the IPC system. For distribution feeder analysis, Idaho Power utilizes
Advantica's SynerGEE Software.
A-2.0 Acceptability Criteria
The following acceptability criteria were used in the power flow analysis to determine under
which system configuration modifications may be required:
The continuous rating of equipment is assumed to be the normal thennal rating of the
equipment. This rating will be as determined by the manufacturer of the equipment or as
detennined by Idaho Power. Less than or equal to 100% of continuous rating is
acceptable.
Idaho Power's VoLtage Operating Guidelines were used to determine voltage
requirements on the system. This states, in part, that distribution voltages, under normal
operating conditions, are to be maintained within plus or minus 5% (0.05 per unit) of
nominal everywhere on the feeder. Therefore, voltages greater than or equal to 0.95 pu
voltage and less than or equal to 1.05 pu voltage are acceptable.
Voltage flicker during starting or stopping the generator is limited to 5% as measured at
the point of interconnection, per Idaho Power's T &0 Advisory Information Manual.
Idaho Power's Reliability Criteria for System Planning was used to determine proper
transmission system operation.
All customer generation must meet IEEE 519 and ANSI C84.1 Standards.
All other applicable national and Idaho Power standards and prudent utility practices
were used to detennine the acceptability of the configurations considered.
The stable operation of the system requires an adequate supply of volt-amperes reactive
(V ARs) to maintain a stable voltage profile under both steady-state and dynamic system
6
conditions. An inadequate supply of VARs will result in voltage decay or even collapse
under the worst conditions.
Equipment/line/path ratings used will be those that are in use at the time of the study or that are
represented by IPC upgrade projects that are either currently under constlUction or whose
budgets have been approved for construction in the near future. All other potential future ratings
are outside the scope of this study. Future transmission changes may, however, affect current
facility ratings used in the study.
A~3.0 Grounding Guidance
Idaho Power Company (IPC) requires interconnected transformers to limit their ground fault
current to 20 amps at the point of interconnection.
A~4.0 Electrical System Protection Guidance
IPC requires electrical system protection per Requirements for Generation Interconnections
found on the Idaho Power Web site,
http://www.idahopower.com/aboutuslbusiness/generationIntel.connect!.
A~5.0 WECC Coordinated Off-Nominal Frequency Load Shedding and Restoration
Requirements
IPC requires frequency operational limits to adhere to WECC Under~frequency and Over~
frequency Limits per the WECC Coordinated Off~Nominal Frequency Load Shedding and
Restoration Requirements available upon request.
7
CP
APPENDIXB
#158 Notch Butte Wind
"* Point of Jnterconnection
A New Substation
-Existing 13B kVTransmission Une
APPENDIXC
GENERATOR INTERCONNECTION
SYSTEM IMPACT STUDY REPORT
for
Up to 330 MW of New Generation
On the 138 kV Transmission System
In the Twin Falls Area
to
IDAHO POWER COMPANY, Transmission Provider
TRANSMISSION SYSTEM
FINAL REPORT
June 29, 2007
1.0 Introduction
Multiple new generation projects have contacted Idaho Power Company (IPC) to perfOlID
Generator IntercOlmection System Impact Studies for Network Resource Interconnection
Service at 138 kV for the integration of new generation projects in the Twin Falls area.
This report documents the basis for and the results of this System Impact Study. Previous
studies were performed with these new generation projects being non-dispatchable. This
System Impact Study will document the transmission system improvements required if the new
generation projects are dispatchable. It describes the backbone transmission system
improvements required for Network Resource Interconnection Service of the new generation
proposed, the study cases used, outage scenarios assumed, redispatch requirements, and results
of all work in the areas of concern.
2.0 Summary
The performance of the backbone transmission system was evaluated to integrate up to 304
MW of new generation on the 138 kV transmission system in the Twin Fans area. Five phases
of transmission system improvements are required to provide 304 MW of new generation
Network Resource Interconnection Service.
Phase #1:
Phase #2:
Phase #3:
Install an 8 ohm 138 kV Series Reactor on the Upper Salmon-Mountain Home
Junction 138 IcV transmission line. Without this improvement, the outage of
the Midpoint-Rattlesnake 230 kV transmission line results in an overload of
the Upper Salmon-Mountain Home Junction 138lcV line with no new
generation in the Twin Falls area. This improvement is necessitated by the
transmission improvements associated with Generation Project 88, and as a
result should be funded by Idaho Power Company -Delivery. This phase of
improvements is estimated at approximately $290,000. .
Install a 4 ohm 138 kV Series Reactor on the Mountain Home Junction-Lucky
Peak 138 kV transmission line. Without this improvement, the outage of the
Rattlesnake-Boise Bench 230 kV transmission line results in an overload
exceeding the 30 minute emergency rating of the Mountain Home Junction­
Lucky Peak 138 kV line with new generation levels greater than 42 MW in
the Twin Falls area. This phase of improvements is estimated at
approximately $290,000.
Install a 12.35 ohm 138 kV Series Reactor on the Lower Malad-Mountain
Home Junction 138 kV transmission line and increase the impedance of the
existing Upper Salmon-Mountain Home Junction 138 kV Series Reactor to
26.2 ohms. Without this improvement, the outage of the Midpoint­
Rattlesnake 230 leV transmission line results in an overload exceeding the 30
minute emergency rating of the Lower Malad-Mountain Home Junction 138
kV line with new generation levels greater than 94 MW in the Twin Falls
area. This phase of improvements is estimated at approximately $290,000.
-1-
Phase #4:
Phase #5:
Re-configure the Midpoint-Rattlesnake 230 kV series capacitor bank to allow
113 of the compensation to be bypassed via IPC's SCADA system and install
a "automatic 1/3 bypass scheme" for overloads exceeding series capacitor's
30 minute emergency equipment rating of l35%. Without this improvement,
the outage of the Midpoint-Boise Bench #3 230 kV transmission line results
in an overload exceeding the 30 minute emergency rating of the Midpoint­
Rattlesnake 230 kV Series Capacitor Bank with new generation levels greater
than 153 MW in the Twin Falls area. This phase of improvements is
estimated at approximately $100,000.
Fold the Midpoint-DRAM #1 230 kV transmission line into the King
Substation and install a 2301138 kV 300 MV A transformer. Without this
improvement, the outage of the Rattlesnake-Boise Bench 230 kV transmission
line results in an overload exceeding the 30 minute emergency rating of the
Mountain Home Junction-Lucky Peak 138 kV line with new generation levels
greater than 156 MW in the Twin Falls area. This phase of improvements is
estimated at $10,320,000.
Once all five phases of improvements have been completed, the transmission system is capable
of interconnecting approximately 330 MW of new generation in the Twin Falls area and
serving them on a dispatchable basis.
Section 8.0 of this report details the results of studies to quantify generation redispatch
requirements following single contingencies on the transmission system. Reductions in the
amount of generation which may be redispatched following contingencies, are possible by
completing Phase #4 improvements earlier than required or funding optional modifications on
the Midpoint-Boise Bench #3 series capacitor bank.
These cost estimates include direct equipment and installation labor costs, indirect labor costs
and overheads, and allowance for funds used during construction (AFUDC). The proposed
cost allocation is subject to change, as more information is known. These are cost estimates
only and final charges to the customer will be based on the actual construction costs incurred.
3.0 Summary of Interconnection Requests
Requests were made to Idaho Power Co. by multiple generation projects in the Twin Falls area
to study the interconnection of the proposed generation projects to Idaho Power's transmission
system at the 138 kV level for Network Resource Interconnection Service.
4.0 Scope of Interconnection System Impact Study
The Interconnection System Impact Study was done and prepared in accordance with the
FERC Order 2003-A, Standard Large Generator Interconnection Procedures, to provide a
preliminary evaluation of the System Impact of the interconnection of the proposed large
generating project to the Idaho Power transmission system. Tllis study will only be concerned
-2-
with the capabilities of the Idaho Power system to manage this new resource within the study
area of the proposed interconnection.
5.0 Description of Existing Transmission Facilities
As shown in Figure 1 of Section 7.0, Midpoint Substation, north of Twin Falls, has three 230 kV
lines that carry buli( power westward to the Boise area. Midpoint-DRAM #l1ine utilizes single
715.5 MCM conductor and has a continuous rating of 339 MVA. The Midpoint-Rattlesnake-Boise
Bench #2 line utilizes a 2 conductor bundle of715.5 MCM. This line has a continuous rating of
677 MY A. The Midpoint-Boise Bench #3 line has similar conductors and the same rating as the
Rattlesnake-Boise Bench #2 line. In the Mountain Home area, an additional 230 kV line is
planned to carry bulk power westward. The Rattlesnake-Bennett Mountain-Danskin-Mora line
utilizes single 1272 MCM conductors (478 MY A) from Rattlesnake-Bennett Mountain, single
1590 MCM conductors (550 MY A) from Bennett Mountain-Danskin and Danslein-Mora. The
Bennett Mountain-Danskin-Mora transmission lines are required for the interconnection of
Generation Project 88; scheduled to be in-service Spring of2008.
In addition to the Midpoint to the Boise area 230 kV lines previously mentioned, there are two
138 leV circuits which can carry power from the Twin Falls area to the Mountain Home area.
They are:
• King-Lower Malad-Mountain Home Junction 138 kV Line
• King-Upper Salmon-Mountain Home Junction 138 kV Line
Generators located in the Twin Falls area which are intended to serve load growth in the Treasure
Valley area, will be adding new incremental flows on top of existing committed east-to-west
transactions across the Midpoint West transmission cutplane. This System Impact study will
model approximately 1100 MW of transfers across the Midpoint West cutplane, prior to this
proposed generator addition. For these studies, the flow level of the Midpoint west cutplane is
defmed as the sum of the flows on the following lines:
• Midpoint-DRAM #1 230 kV line
• Midpoint-Rattlesnake 230 kV Line
• Midpoint-Boise Bench #3 230 kV Line
• Lower Malad-Mountain Home Junction 138 leV Line
• Upper Salmon-Mountain Home Junction 138 kV Line
6.0 Description of Configurations Studied
Since the most limiting operating conditions are expected during heavy production on the
upper and middle Snake and Boise River hydro plants, with heavy east-west transfers across
the Idaho Power transmission system, the injection of the new generation at King 138 kV bus
was inserted into a power flow case that would simulate committed (approximately 1100 MW)
pre-contingency flows on the Midpoint West transmission path.
7.0 Post-transient Study Results
-3-
This Interconnection System Impact Study Report is for Network Resource Interconnection
Service at 138 kV, for numerous proposed generation additions in the Twin Falls area. System
transfers across the Midpoint West cutplane are modeled at approximately 1100 MW prior to
the proposed transmission improvements or the proposed generators producing any power.
Hydro generation production for the Boise & Snake plants, were modeled at heavy, but
realistic levels. Output levels for the existing peakers at Danskin and Bennett Mountain were
varied over their operating ranges as appropriate. N-O and N-l outage performance for the
existing system are recorded. For generation projects which will be dispatchable, generation
levels at King 138lcV bus are increased until a transmission system component reaches its 30
minute emergency equipment ratings during N-\ outages. IPC's 30 minute emergency
equipment ratings are 115% of continuous thermal ratings on transmission lines and
transformers, and 135% on Midpoint series capacitors. The most effective and cost-efficient
transmission system improvements are then added to the model and King generation is then
increased unti130 minute emergency equipment ratings are reached during N-l outages.
Following any N-1 outage, transmission line and transformer loadings which are less than or
equal to the 30 minute emergency equipment ratings (115%), but greater than the equipment
continuous ratings (100%), must be reduced to the continuous ratings by generation
curtailments, redispatch, or some other operating procedure. For the Midpoint series capacitor
banks, following any N-l outage, similar corrective actions are required for loadings which are
less than or equal to the 30 minute emergency equipment ratings (135%), but greater than the
equipment 8 hour rating (110%). Various options to correct overloads following N-l outages
will be explored.
System following Generation Project 88
The following one line diagram depicts the transmission system with no outages, after the
addition of Generation Project 88 and its associated improvements.
Midpoint Wast:; 1109 MW
System foJlowing Generation Project 88 -No Outages
Figure 1
-4-
System following Generation Project 88 with N-l Outages
The following one line diagram depicts the transmission system following the addition of
Generation Project 88 and its associated improvements in 2008, with no new generation in the
Twin Falls area, and the only N-l outage between Midpoint and the Mountain Home area that
results in loadings above continuous thennal ratings on the 138 kV transmission system.
Midpoint Wost = 1038 MW
System following Generation Project 88 -Midpoint-Rattlesnake 230 kV Outage
Figure 2
Phase #1 Transmission Improvements
The Midpoint Series Capacitor banks are capable of 110% of thermal rating for eight hours. A
prolonged outage of the Midpoint-Rattlesnake 230 kV line will require a reduction of transfers
across the Midpoint West cutplane to prepare for the next contingency. The overload ofthe
Midpoint-Boise Bench #3 Series Capacitor is less than its 8 hour rating, and will be resolved
with the reduction in transfers. As a result, only the overloads on the 138 kV lines between
Upper Salmon and Mountain Home Junction are problematic. The most effective and cost­
efficient transmission improvement to alleviate these overloads is the installation of a series
reactor on the Upper Salmon-Mountain Home Junction 138 kV line to better balance flows on
the transmission network. A series reactor with an impedance of .042 p.u. (8 ohms) alleviates
the overloads. Since this N-l overload condition pre-exists the addition of any new generation
in the Twin Falls area, Idaho Power Company will take responsibility to fund this series reactor
installation.
The following one line diagram depicts the system with Phase #1 improvements added, no new
generation in the Twin Falls area, and the same N-l as Figure 2.
-5-
Midpoint Wost " 1038 MW
Phase #2 Transmission Improvements
The following one line diagram depicts Phase #1 transmission improvements and 42 MW of
new generation in the Twin Falls area, and the only N-l outage that results in loadings at or
above 30 minute equipment ratings.
O?W~(J1
Midpoint Wost = 1077 MW
Phase #1 Transmission Improvements -Rattlesnake-Boise Bench #2 230 kV Outage
42 MW of New Generation
Figure 4
-6-
The most effective and cost-efficient transmission improvement to alleviate this overload is the
installation of a series reactor on the Mountain Home Junction-Lucky Peak 138 k V line to
better balance flows on the transmission network. A series reactor with an impedance of .021
p.u. (4 ohms) was determined to be the optimal size considering future generation additions.
This overload is the result of the addition of new generation in the Twin Falls area, and as a
result the costs ofthis improvement will be allocated to new generation interconnections.
The following one line diagram depicts the system with Phase #2 improvements added, 42
MW of new generation in the Twin Falls area, and the same N-I as Figure 4. Please note that
generation redispatch will be required following this contingency to reduce loadings to levels
which can be accommodated continuously. ,
MidpoInt Wast = 1075 MW
Phase #2 Transmission Improvements -Rattlesnake-Boise Bench #2 230 kV Outage
42 MW of New Generation
Figure 5
Phase #3 Transmission Improvements
The following one line diagram depicts Phase #2 transmission improvements and 94 MW of
new generation .in the Twin Falls area, and the only N-l outage that results in loadings at or
above 30 minute equipment ratings.
-7-
MIdpoInt WOBt " 1106 MW
Phase #2 Transmission Improvements -Midpoint-Rattlesnake 230 kV Outage
94 MW of New Generation
Figure 6
To interconnect generation quantities greater than 94 MW will require additional transmission
system improvements. The most effective and cost-efficient transmission improvements to
alleviate these overloads are the installation of a new series reactor on the Lower Malad­
Mountain Home Junction 138 kV line and an increase in the impedance of the Upper Salmon­
Mountain Home Junction 138 kV line series reactor. These improvements, referred to as Phase
#3, will better balance flows on the transmission network. A Lower Malad-Mountain Home
Junction series reactor impedance of .065 p.u. (12.35 ohms) was determined to be the optimal
size considering future generation additions. The impedance of the Upper Salmon-Mountain
Home Junction series reactor should be increased to .138 p.u. (26.2 ohms). TIns overload is
the result of the addition of new generation in the Twin Falls area, and as a result the costs of
this improvement will be allocated to new generation interconnections.
The following one line diagram depicts the system with Phase #3 improvements added, 94
MW of new generation in the Twin Falls area, and the same N-l as Figure 6.
-8-
Millpoint Wost .. 1099 MW
Phase #3 Transmission Improvements -Midpoint-Rattlesnake 230 kV Outage
94 MW of New Generation
Figure 7
Phase #4 Transmission Improvements
The following one line diagram depicts Phase #3 transmission improvements and 153 MW of
new generation in the Twin Falls area, and the only N -1 outage that results in loadings at or
above 30 minute equipment ratings.
Midpoint Wost,. 1172 MW
Phase #3 Transmission Improvements -Midpoint-Boise Bench #3 230 kV Outage
153 MW of New Generation
Figure 8
-9-
To interconnect generation quantities greater than 153 MW will require additional transmission
system improvements. If new generation levels exceed 153 MW, and the Midpoint-Boise
Bench #3 230 kV line opens, the series capacitor bank on the Midpoint-Rattlesnake 230 kV
transmission line may exceed its 30 minute overload capability of 135%. Presently, both the
230 leV series capacitor banks at Midpoint are configured to operate either fully in-service or
fully by-passed. The most effective and cost-efficient transmission improvement to alleviate
this overload is the re-configuration of the Midpoint-Rattlesnake 230 kV series capacitor bank
to allow one third of the compensation to be bypassed. In addition, an automatic control
scheme should be employed to bypass one third of the series capacitor bank when appropriate
system conditions are detected. The re-configuration of the series capacitor bank and the
addition of the automatic control scheme is refeued to as Phase #4.
The following one line diagram depicts the system with Phase #4 improvements added, 153
MW of new generation in the Twin Falls area, and the same N-l as Figure 8.
Midpoint Wost = 1145 MW
Phase #4 Transmission Improvements -Midpoint-Boise Bench #3 230 kV Outage
153 MW of New Generation
Figure 9
Phase #5 Transmission Improvements
The following one line diagram depicts Phase #4 transmission improvements and 156 MWof
new generation in the Twin Falls area, and the only N -1 outage that results in loadings at or
above 30 minute equipment ratings.
-10-
Midpoint Wast = 1151 MW
Phase #4 Transmission Improvements -Rattlesnake-Boise Bench #2 230 kV Outage
156 MW of New Generation
Figure 10
To interconnect generation quantities greater than 156 MW will require additional transmission
system improvements. Ifnew generation levels exceed 156 MW, and the Rattlesnake-Boise
Bench #2230 kV line opens, the Mountain Home Junction-Lucky Peale 138 kV transmission
line may exceed its 30 minute overload capability of 115%. The required system
improvements are referred to as "Phase #5" and include folding the Midpoint-DRAM #1230
kV transmission line into and back out of the King Substation and installing a 2301138 kV 300
MV A transfonner. This overload is the result of the addition of new generation in the Twin
Falls area, and as a result the costs of this improvement will be allocated to new generation
interconnections.
The following one line diagram depicts the system with Phase #5 improvements added, 156
MW of new generation in the Twin Falls area, and the same N-l as Figure 10.
-11-
MIdpoInt West .. 1165 MW
Phase #5 Transmission Improvements -Rattlesnake-Boise Bench #2 230 kV Outage
156 MW of New Generation
Figure 11
Phase #5 transmission improvements are capable of accommodating approximately 330 MW
of new generation in the Twin Falls area. The following one line diagram depicts the system
with Phase #5 improvements added, 330 MW of new generation in the Twin Falls area, and the
loss of the Midpoint-Rattlesnake 230 kV transmission line. At 330 MW of new generation in
the Twin Falls area, two other outages also result in transmission system components loaded at
their 30 minute emergency equipment ratings.
Midpoint West = 127:.! MW
'~IR;:' ~I-@:R~" fe}--'"I'fi--RHo{C;:::)/'M::,
Phase #5 Transmission Improvements -Midpoint-Rattlesnake #2 230 kV Outage
330 MW of New Generation
Figure 12
-12-
8.0 Generation Redispatcb Requirements
Generators which have chosen to be dispatchable are allowed to operate at levels which may
create overloads at or below 30 minute emergency equipment ratings following N-l
contingencies. Following any N-l outage, transmission line and transformer loadings which
are less than or equal to the 30 minute emergency equipment ratings (115%), but greater than
the equipment continuous ratings (100%), must be reduced to the continuous ratings by
generation curtailments, redispatch, or some other operating procedure. For the Midpoint
series capacitor banles, following any N-l outage, similar corrective actions are required for
loadings which are less than or equal to the 30 minute emergency equipment ratings (135%),
but greater than the equipment 8 hour rating (110%).
The following table summarizes generation curtailment requirements for the proposed
generation projects modeled at King 138 kV Substation; for various timeframes, and for
numerous transmission system single contingencies.
The fourth column of the table provides information regarding potential benefits of requesting
and funding an optional improvement. The improvement evaluated is the re-configuration of
the Midpoint-Boise Bench #3230 leV series capacitor bank to allow one third of the
compensation to be bypassed. Unlike Phase #4, no automatic control scheme is contemplated.
This Optional Improvement may reduce the magnitude of generation which must be
redispatched during a Midpoint-Rattlesnake 230 kV Transmission Line outage. The Optional
Improvement is estimated at approximately $50,000.
The fifth column of the table provides information regarding potential benefits of completing a
portion of Phase #4 improvements early. Phase #4 improvements can be separated into two
components. The first component is the "re-configunition" of the Midpoint-Rattlesnake 230
kV series capacitor so it can be operated "fully in-service", "113 bypassed", "2/3 bypassed", or
"fully bypassed". The second component was the "automatic control scheme". The Phase #4a
improvement contained in the fifth column is for expediting on Iy the "re-configuration"
component. Expediting the phase #4a improvement may reduce the magnitude of generation
which must be redispatched during a Midpoint-Boise Bench #3 230 leV Transmission Line
outage. The Phase #4a improvement is estimated at approximately $50,000.
-13-
Maximum Maximum
Maximum Allowable Allowable
Allowable Maximum Generation Generation
Generation Allowable After N-l After N-l
Before Generation w/Optional w/Phase#4a
Conting-ency N-I After N-l Improvement Improvement
After Phase #1, but before Phase #2
Midpoint-Boise Bench #3 230 kV Line 42MW OMW OMW 42MW
Midpoint-Rattlesnake 230 kV Line 42MW 7MW 7MW 7MW
Rattlesnake-Boise Bench 230 kV Line, also
open Mountain Home Junction-Danskin 138 42MW 9MW 9MW 9MW
kVLine
Danskin-Mora 230 leV Line, also open
Mountain Home Junction-Danskin 138 kV 42MW 42MW 42MW 42MW
Line
After Phase #2, but before Phase #3
Midpoint-Boise Bench #3 230 kV Line 94MW OMW OMW 94MW
Midpoint-Rattlesnake 230 kV Line 94MW 9MW 9MW 9MW
Rattlesnake-Boise Bench 230 kV Line, also
open Mountain Home Junction-Danskin 138 94MW 32MW 32MW 32MW
kV Line
Danskin-Mora 230 kV Line, also open
Mountain Home lunction-Danskin 138 kV 94MW 80MW 80MW 80MW
Line
Mountain Home Junction-Lower Malad 138 94MW 49MW 49MW 49MW kV Line
Lucky Peale-Micron 138 leV Line 94MW 45MW 45MW 45MW
Danskin 230/138 kV Transfonner 94MW 90MW 90MW 90MW
After Phase #3, but before Phase #4 .
Midpoint-Boise Bench #3 230 kV Line 153MW OMW OMW 153MW
Midpoint-Rattlesnake 230 kV Line 153 MW 17MW 53MW 17MW
Rattlesnake-Boise Bench 230 kV Line, also
open Mountain Home Junction-Danskin 138 153 MW 71 MW 71MW 71MW
kV Line
Danskin-Mora 230 kV Line, also open
Mountain Home Junction-Danslein 138 kV 153 MW 120MW 120MW 120MW
Line
Mountain Home Junction-Lower Malad 138 153 MW 129MW 129MW 129MW leV Line
Lucky Peak-Micron 138 kV Line 153 MW 84MW 84MW 84MW
Danskin 230/138 kV Transformer 153MW 125MW 125MW 125MW
Maximum Maximum
Maximum Allowable Allowable
Allowable Maximum Generation Generation
Generation Allowable After N-l After N-l
Before Generation w/Optional w/Phase #4a
Contingency N-l After N-l IlllQrOvement Im~rovement
After Phase #4, but before Phase #5
Midpoint-Boise Bench #3230 kV Line 156MW 156MW 156MW N/A
Midpoint-Rattlesnake 230 kV Line 156MW 18MW 53MW N/A
Rattlesnake-Boise Bench 230 kV Line, also
open Mountain Home Junction-Danskin 138 156MW 71MW 71MW N/A
leV Line
Danskin-Mora 230 kV Line, also open
Mountain Home Junction-Danskin 138 kV 156MW }20MW 120MW N/A
Line
Mountain Home Junction-Lower Malad 138 156MW 129MW 129MW N/A kV Line
Lucky Peak-Micron 138 kV Line 156MW 84MW 84MW N/A
Danskin 230/138 kV Transfomler 156MW 125MW 125MW N/A
After Phase #5
Midpoint-Boise Bench #3 230 kV Line 330MW 140MW 140MW N/A
Mid.e0int-Rattlesnake 230 kV Line 330MW 25MW 123MW N/A
Rattlesnake-Boise Bench 230 leV Line, also
open Mountain Home Junction-Danskin 138 330MW 254MW 254MW N/A
kVLine
Danskin-Mora 230 kV Line, also open
Mountain Home Junction-Danskin 138 kV 330MW 310MW 310MW N/A
Line
Mountain Home Junction-Lower Malad 138 330MW 280MW 280MW N/A kV Line
Lucky Peak-Micron 138 kV Line 330MW 265MW 265MW N/A
Danskin 230/138 leV Transformer 330MW 295MW 295MW N/A
King 2301138 kV TransfOlmer 330MW 245MW 245MW N/A
-15-
9.0 Fault Study Results
Since this System Impact Study lumps all the proposed generation additions at King 138 IcV
bus, this Draft Report makes no attempt to address fault study concerns. Each proposed
generation project will have to be evaluated individually based on its specific location.
10.0 Transient Stability Study Results
The Midpoint West Transmission System is not transient stability limited. Therefore, no
transient stability studies were performed.
11.0 Conclusions
The System Impact of interconnecting up t0304 MW of new generation in the Twin Falls area
to Idaho Power's 138 kV transmission system was studied. Five phases of transmission system
improvements are required to provide Network Resource Interconnection Service to 304 MW
of new generation, on a dispatchable basis. Phase #1 is the installation of an 8 ohm 138 kV
Series Reactor on the Upper Salmon-Mountain Home Junction 138 leV transmission line. This
improvement corrects an N-1 overload that exists before any new generation is added in the
Twin Falls area. As a result, the estimated $290,000 cost of this improvement will be borne by
Idaho Power Company. After approximately 42 MW of new generation is added, Phase #1
improvements are no longer sufficient. Phase #2 improvements require the installation of a 4
ohm 138 kV Series Reactor on the Mountain Home Junction-Lucky Peak 138 kV transmission
line. The estimated $290,000 cost of this improvement should be allocated to new generator
interconnections. Following the addition of approximately 94 MW of new generation, Phase
#3 transmission improvements are required. Phase #3 improvements require fhe installation a
12.35 ohm 138 kV Series Reactor on the Lower Malad-Mountain Home Junction 138 kV
transmission line, and increasing the impedance of the existing Upper Salmon-Mountain Home
Junction 138 kV Series Reactor to 26.2 ohms. The estimated $290,000 cost of Phase #3 '
improvements should be allocated to new generator interconnections. Following fhe addition
of approximately 153 MW of new generation, Phase #4 transmission improvements are
required. Phase #4 involves re-configuring the Midpoint-Rattlesnake 230 kV series capacitor
banlc to allow 1/3 of the compensation to be bypassed via IPC's SCADA system and install a
"automatic 1/3 bypass scheme" for overloads exceeding the series capacitor's 30 minute
emergency equipment rating of 135%. The estimated $100,000 cost of this improvement
should be allocated to new generator interconnections. Following the addition of
approximately 156 MW of new generation, Phase #5 transmission improvements are required.
Phase #5 involves folding the Midpoint-DRAM #1 230 kV transmission line into and back out
of the King Substation and installing a 230/138 kV 300 MY A transformer. The estimated
$10,320,000 cost of this improvement should be allocated to new generator interconnections.
Phase #5 transmission improvements are adequate to interconnect approximately 330 MW of
new generation in the Twin Falls area, on a dispatchable basis, before additional improvements
are required.
APPENDIX A
1.0 Method of Study
The study methodology inserts the proposed generators up to the maximum requested output of
304 MW into the selected WECC power flow case and then, using the PowerWorld Simulator
powerflow program, examines the impacts ofthe new resource on Idaho Power's transmission
system (lines, transformers, etc.) within the study area under various operating/outage
scenarios. The WECC and Idaho Power reliahility criteria and Idaho Power operating
procedures were used to determine the acceptability of the alternatives considered. The WECC
case is a recent case modified to simulate stressed but reasonable pre-contingency energy
transfers utilizing the IPC system.
2.0 Acceptability Criteria
The following acceptability criteria were used in the power flow analysis to detennine the
acceptability of the alternatives:
Loadings on transmission lines and transformers should not exceed 115% of the
continuous rating, immediately following any N-1 outage. Loading on the Midpoint
230 kV series capacitors should not exceed 135% of the continuous rating, inunediately
following any N-l outage. These loadings levels of 115% on transmission lines and
transfonners and 135% on Midpoint series capacitors correspond to IPC's 30 minute
emergency equipment ratings. Any loadings immediately following an N-l outage,
less than the 30 minute emergency rating is acceptable.
Loadings which are less than the 30 minute emergency equipment ratings, but greater
than the equipment continuous ratings, must be reduced to the continuous ratings'by
generation curtailments, re-dispatch, or some other operating procedure. Any remedial
action schemes (RAS) or other transmission switching, must be judged to be reasonable
before the alternatives performance can be deemed acceptable.
The continuous rating of equipment is assumed to be the normal thelmal rating of the
equipment. This rating will be as detennined by the manufacturer of the equipment or
as detelmined by Idaho Power. Less than or equal to 100% of continuous rating for
transmission lines and transformers is acceptable. Less than or equal to 110% of
continuous rating for the Midpoint 230 leV series capacitors is acceptable.
Transmission voltages, under nomlal operating conditions, are maintained within plus
or minus 5% (0.05 per unit) of nominal. Therefore, voltages greater than or equal to
0.95 p.u. voltage and less than or equal to 1.05 p.u. voltage are acceptable.
The stable operation of the transmission system requires an adequate supply of volt­
amperes reactive (V ARs) to maintain a stable voltage profile under both steady-state
and dynamic system conditions. An inadequate supply ofVARs will result in voltage
-17-
decay or even collapse under the worst conditions. Idaho Power designs its system to
integrate Network Resources at full capability during specified outage conditions.
Equipment/line/path ratings used will be those that are in use at the time of the study or that are
represented by IPC upgrade projects that are either currently under construction or whose
budgets have been approved for construction in the near future. All other potential future
ratings are outside the scope of this study. Future transmission changes may, however, affect
CUtTent facility ratings used in the study.
-18-
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 20
, ,
Small Gen Feasibility Study Agreement
Project #158, Notch Butte
Feasibility Study Agreement
THIS AGREEMENT is made and entered into this 11 tl, day of f'II~'fc..~ 2009 by and
between ~'>(,e...{',) Lk.vL..II>f?mll.ht ~rc"'P Dr 1JJ: ,
a L:rni~J 1..:",1,,1'1.-1-/ c..W,P;"'7 organized and existing under the laws of the State of
I ~"I.l,c? ~ , ("Interconnection Customer, ") and Idaho
Power Company a Corporation existing under the laws of the State of Idaho ("Transmission
Provider"). Interconnection Customer and Transmission Provider each may be referred to as a
"Party," or collectively as the "Parties."
RECITALS
WHEREAS, Interconnection Customer is proposing to develop a Small Generating Facility or
generating capacity addition to an existing Small Generating Facility consistent with the
Interconnection Request completed by Interconnection Customer on December 19, 2005, also
known as Project #158: and
WHEREAS, Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Providees Transmission System; and
WHEREAS, Interconnection Customer has requested the Transmission Provider to perfonn a
feasibility study to assess the feasibility of interconnecting the proposed Small Generating
Facility with the Transmission Provider's Transmission System, and of any Affected Systems;
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the tenns specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause to be
perfonned an interconnection feasibility study consistent the standard Small Generator
Interconnection Procedures in accordance with the Open Access Transmission Tariff.
3.0 The scope of the feasibility study shall be subject to the assumptions set forth in
Attachment A to this Agreement.
4.0 The feasibility study shall be based on the technical information provided by the
Interconnection Customer in the Interconnection Request, as may be modified as the
result of the scoping meeting. The Transmission Provider reserves the right to request
additional technical information from the Interconnection Customer as may reasonably
become necessary consistent with Good Utility Practice during the course of the
feasibility study and as designated in accordance with the standard Small Generator
Interconnection Procedures. If the Interconnection Customer modifies its Interconnection
Page 1 00
Small Gen Feasibility Study Agreement
Project #158, Notch Butte
Request, the time to complete the feasibility study may be extended by agreement of the
Parties.
5.0 In perfonning the study, the Transmission Provider shall rely, to the extent reasonably
practicable, on existing studies of recent vintage. The Interconnection Customer shall not
be charged for such existing studies; however, the Interconnection Customer shall be
responsible for charges associated with any new study or modifications to existing studies
that are reasonably necessary to perform the feasibility study.
6.0 The feasibility study report shall provide the following analyses for the purpose of
identifying any potential adverse system impacts that would result from the
interconnection of the Small Generating Facility as proposed:
6.1 Initial identification of any circuit breaker shOtt circuit capability limits exceeded
as a result of the interconnection;
6.2 Initial identification of any thermal overload or voltage limit violations resulting
from the interconnection;
6.3 Initial review of grounding requirements and electric system protection; and
6.4 Description and non-bonding estimated cost of facilities required to interconnect
the proposed Small Generating Facility and to address the identified short circuit
and power flow issues.
7.0 The feasibility study shall model the impact ofthe Small Generating Facility regardless
of purpose in order to avoid the further expense and intelTUption of operation for .
reexamination of feasibility and impacts if the Interconnection Customer later changes
the purpose for which the Smal1 Generating Facility is being installed.
8.0 The study shall include the feasibility of any interconnection at a proposed project site
where there could be multiple potential Points ofInterconnectibn, as requested by the
Interconnection Customer and at the Interconnection Customer's cost.
9.0 In lieu of Feasibility Study deposit, Interconnection Customer agrees that study funds
will be drawn from the application fee for the perfOlmance of the Interconnection
Feasibility Study.
Transmission Provider shall charge and Interconnection Customer shall pay the actual
costs of the Interconnection Feasibility Study. Any difference between the deposit and
the actual cost of the study shall be paid by or refunded to IntercOlmection Customer, as
appropliate.
Page 2 of3
Small Gen Feasibility Study Agreement
Project #158, Notch Butte
10.0 Once the feasibility study is completed, a feasibility study report shall be prepared and
transmitted to the Interconnection Customer. Ban'ing unusual circumstances, the
feasibility study must be completed and the feasibility study report transmitted within 30
business days of the Interconnection Customer's agreement to conduct a feasibility study.
11.0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
12.0 The Interconnection Customer must pay any study costs that exceed the deposit without
interest within 30 calendar days on receipt of the invoice or resolution of any dispute. If
the deposit exceeds the invoiced fees, the Transmission Provider shall refund such excess
within 30 calendar days of the invoice without interest.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written.
Transmission Provider:
Idaho Power Company -Delivery
Signed_..L..t?_~+,~""-..:..-_..!-,-@;: __ 't:._~~===-----...~=_
Printed Marc ~-f+eV5 t~'L
Title C--:q;Jillec(d1{( lec~v -'71'j) P/aP(I11'r->j
J }
Date J1I/ C<t rc ~ Cf( 20'" f
I
Interconnection Customer:
Date //-./'Z?>'l c:. , .. -2 d If )
Page 3 of3
Small Gen Feasibility Study Agreement
Project #158, Notch Butte
Attachment A to Feasibility Study Agreement
Assumptions Used in Conducting the Feasibility Study
The feasibility study will be based upon the information set forth in the Interconnection Request
and agreed upon in the seoping meeting held on ________ _
1) Designation of Point of Intereonnection and configuration to be studied.
!he. ptO/h f {1 .J;-,;I't.'(NI'7C: elll,,: tv;!/ be "," / da.{ <:> I~w-e I" ~ DI'(' Mc.4 f-YI /2. S'/::-v /eeicv
at a.,IbfZP.<-I 0 6 SR 19£'>5.1 i...1/')co(-'" (O(..L" ~ rTcl.a~c,., 1k ;Jf'c)./u,f VJt!/ be. ~; fz<dr~7d £r
'l/J1W /Yla.~ ~u:fpaf:.
2) Designation of alternative Points of Interconnection and configuration.
1) and 2) are to be completed by the Interconnection Customer. Other assumptions (listed
below) are to be provided by the Interconnection Customer and the Transmission Provider.
Page 1 of 1
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 21
GENERATOR INTERCONNECTION
FEASIBILITY STUDY
for integration of the proposed
PROJECT #158
to the
IDAHO POWER COMPANY ELECTRICAL SYSTEM
for the
INTERCONNECTION CUSTOMER
FINAL REPORT
April 16, 2009
1.0 Introduction
The Generation Interconnection Customer has contracted with Idaho Power Company (IPCO)
to perform a Generator Interconnection Feasibility Study for the integration of the proposed 9
MW Wind Park Project (project #158). The location of the project is in Idaho Power's
Southern Idaho service territory in Lincoln County, Idaho.
This report documents the basis for and the results of this Feasibility Study for the Generation
Interconnection Customer. It describes the proposed project, the study cases used, the impact
of associated projects, and results of all work in the areas of concern.
2.0 Summary
The proposed project is a 9 MW wind farm consisting of six 1.5 MW GE wind turbines. The
proposed Point of Interconnection (POI) for the generating facility with the IPCO system is at
the wind park, where IPCO's distribution facilities connect to the wind park's facilities.
A new four mile feeder will have to be constructed with new conductor and poles. This feeder
will directly connect the facility to IPCO's distribution substation and will not be connected to
any customer loads. A generation interconnection and protection package will be required at
the POI which will be located at the end of the new four mile feeder. At the substation a
second transformer will also be added for capacity and reactive power reasons.
Voltage on the 46.kV bus at the distribution substation attains a level that is too high by IPCO
standards. In order for that voltage to be brought down to within those standards a four mile
transmission line upgrade will be necessary along with the requirement that the generation
facility will have to maintain a 95% lagging power factor (consuming VARs) during periods of
light loading.
There are limitations in the Midpoint West transmission system to the west ofthis project.
This study demonstrates that there is no available transmission capacity when considering
other proposed generation projects ahead of this one in the queue. A System Impact Study has
been conducted to determine the transmission upgrades needed to serve this project (Appendix
B).
The estimated cost for all required upgrades of IPCO owned facilities to serve the full project
is $3,500,000.
3.0 Scope of Interconnection Feasibility Study
The Interconnection Feasibility Study was done and prepared in accordance with Idaho Power
Company Standard Generator Interconnection Procedures, to provide a preliminary evaluation
of the feasibility of the interconnection of the proposed generating project to the Idaho Power
system. As listed in the Interconnection Feasibility Study agreement, the Interconnection
Feasibility Study report provides the following information:
-1-
preliminary identification of any circuit breaker short circuit capability
limits exceeded as a result of the interconnection;
preliminary identification of any thermal overload or voltage limit
violations resulting from the interconnection; and
preliminary description and non-binding estimated cost of facilities
required to interconnect the Small Generating Facility to the Distribution
System and to address the identified short circuit and power flow issues.
All other proposed Generation projects prior to this project in the Generator Interconnect queue
were considered in this study. A current list of these projects can be found on the Idaho Power
web site as follows:
http://www.oatioasis.com/ipco/index.html.
4.0 Description of Proposed Generating Project
Project #158 proposes to connect to the Idaho Power distribution system for an injection of9
MW (maximum project output) using six General Electric 1.5 MW wind turbines.
5.0 Description of Existing Transmission Facilities
The transmission line that serves this area is a 46 kV radial tap. This tap serves one
distribution substation, as well as a 5.3 MY A hydro generation facility. Voltage problems
occur under light loading conditions on the 46 kV system. With the addition of this project the
voltage is increased by over 0.06 p.u. This voltage must be brought down to at least 1.05 p.u.
on the low voltage side of the distribution transformer. To help bring the voltage down, the
project will have to run at a 95% lagging power factor (absorbing 3 MV AR).
With the addition ofthis project the transmission line total load will not exceed its limitations.
There is enough capacity on this tap to serve this project during periods oflight loading and
high generation. However, with the wind park lagging at a 95% power factor, high voltage
still exists. By reconductoring a four mile stretch on transmission line with 397.5 ACSR the
high voltage is brought to an acceptable level.
There are limitations in the Midpoint West transmission system to the west of this project.
This study demonstrates that there is no available transmission capacity when considering
other proposed generation projects ahead of this one in the queue. A System Impact Study has
been conducted to determine the transmission upgrades needed to serve this project (Appendix
B).
6.0 Description of Existing Substation Facilities
-2-
The distribution substation that serves this area is located approximately four miles to the west
of the wind park. The existing substation transformer is a 46: 12.5 kV transformer that does not
have available capacity when considering the reactive requirements that will be placed on the
wind park. Also, with the fairly large amount of reactive power consumption, it is better to
keep the generation separate from customer loads.
A new transformer will need to be installed at the substation. This transformer will be a 12.5
MV A 46: 12.5 kV transformer and will only be connected to the dedicated feeder that the
generating facility will be on. In order to accommodate the additional substation work
required more land will need to be purchased around the existing substation. This cost is not
included in the estimates but will be necessary for this project to proceed.
The feeder breakers on the adjacent feeders are Cooper type "VWVE38X" breakers which are
designed for 560 amps continuous load current and have a maximum fault current interrupting
rating of 12,000 amps. These feeder breakers will not be connected to the generating facility,
but this type of breaker would be acceptable for addition on the new dedicated feeder.
7.0 Description of Existing Distribution Facilities
The distribution feeder serving this area is a grounded wye feeder operating at 12.5 kV. There
is not adequate capacity on this feeder to serve this project. Also, the wind park should not be
connected directly to customer loads due to the high amount of reactive power that will need to
flow to the generating facility.
These two factors point to the reason why a dedicated distribution feeder is needed from the
substation to the generating facility. This feeder will need to be at 12.5 kV and constructed
with 336 AAC. This conductor consumes enough V ARs during light loading and heavy
generation at DTRC that the transmission system sees nearly 5 MV AR with the wind park at a
95 % power factor. This VAR output is enough to bring down the voltage on the 46 kV system
to an acceptable level.
The proposed POI for the generating facility with the IPCO system is at the wind park, where
IPCO's distribution facilities connect to the wind park's facilities. Refer to Appendix A
section 3 for additional grounding requirements.
8.0 Description and Cost Estimate of Required Facility Upgrades
At the transmission level four miles of conductor needs to be replaced with 397.5 ACSR for
voltage reduction reasons. Due to capacity constraints and reactive power concerns, a new
46:12.5 kV transformer is needed at the substation along with a transformer bay and feeder
breaker. A new 12.5 kV 336 AAC distribution feeder will have to be installed from the
substation to the wind park, and at the POI, a Generation Interconnection and Protection
package will be required. Also, more land will need to be purchased around IPCO' s
distribution substation but is not reflected in the following estimated costs.
-3-
Description Estimated Cost
New 12.5 MVA 46:12.5 kV transformer, bay and
feeder breaker. $1,500,000
4 miles of new distribution line at 336 AAC $700,000
Generation Interconnection Protection Package
(Includes 12.47 kV recloser, controls, CTs, PTs, and
comm unications. $225,000
4 miles of transmission line upgraded to 397.5 ACSR $1,075,000
Total Estimated Cost $3,500,000
Table 1: Estimated Costs for Required Upgrades
These cost estimates include direct equipment and installation labor costs, indirect labor costs
and overheads. (Tax Gross Up has not been included presuming construction of
interconnection facilities will not qualify under IRS rules as a taxable event. Allowance for
funds used during construction (AFUDC) has not been included in the cost estimates since it is
assumed that IPC will be provided up-front funding by the Project). These are cost estimates
only and final charges to the customer will be based on the actual construction costs incurred.
9.0 Description of Operating Requirements
In addition to these upgrades, there are also several operating requirements that must be met.
The project will be controlled to operate at a lagging 95% power factor during periods of light
loading. That is, the wind park must consume 3 MV AR at full output. The project will also
have to meet the voltage schedule provided by Idaho Power. If these requirements cannot be
met, further voltage studies will be necessary. Voltage flicker at startup and during operation
will be limited to less than 5% as measured at the POI. For this to occur, the starting inrush
current cannot exceed 416 Amps at the 12.5 kV voltage level. The project is required to
comply with the applicable Voltage and Current Distortion Limits found in IEEE Standard
519-1992 IEEE Recommended Practices and Requirements for Harmonic Control in Electrical
Power Systems.
11.0 Conclusions
The requested interconnection of the Notch Butte Wind Park to Idaho Power's system w~s
studied. The results of this study work confirm that the existing Idaho Power system can be
upgraded to handle this project. The known required upgrades for the existing distribution
system are listed. An IPCO Transmission System Impact Study has been conducted to
determine the transmission upgrades needed to serve this project.
-4-
APPENDIX A
A-1.0 Method of Study
The Feasibility Study plan inserts the Project up to the maximum requested injection into the
selected Western Electric Coordinating Council (WECC) power flow case and then, using
Power World Simulator Version 12, examines the impacts of the new resource on Idaho
Power's transmission system (lines, transformers, etc.) within the study area under various
operating/outage scenarios. The WECC and Idaho Power reliability criteria and Idaho Power
operating procedures were used to determine the acceptability of the configurations considered.
The WECC case is a recent case modified to simulate stressed but reasonable pre-contingency
energy transfers utilizing the IPC system. For distribution feeder analysis, Idaho Power
utilizes Advantica's SynerGEE Software.
A-2.0 Acceptability Criteria
The following acceptability criteria were used in the power flow analysis to determine under
which system configuration modifications may be required:
The continuous rating of equipment is assumed to be the normal thermal rating of the
equipment. This rating will be as determined by the manufacturer of the equipment or
as determined by Idaho Power. Less than or equal to 100% of continuous rating is
acceptable.
Idaho Power's Voltage Operating Guidelines were used to determine voltage
requirements on the system. This states, in part, that distribution voltages, under
normal operating conditions, are to be maintained within plus or minus 5% (0.05 per
unit) of nominal everywhere on the feeder. Therefore, voltages greater than or equal to
0.95 pu voltage and less than or equal to 1.05 pu voltage are acceptable.
Voltage flicker during starting or stopping the generator is limited to 5% as measured at
the point of interconnection, per Idaho Power's T &D Advisory Information Manual.
Idaho Power's Reliability Criteria for System Planning was used to determine proper
transmission system operation.
All customer generation must meet IEEE 519 and ANSI C84.1 Standards.
All other applicable national and Idaho Power standards and prudent utility practices
were used to determine the acceptability of the configurations considered.
The stable operation of the system requires an adequate supply of volt-amperes reactive
(V ARs) to maintain a stable voltage profile under both steady-state and dynamic
-5-
system conditions. An inadequate supply ofVARs will result in voltage decay or even
collapse under the worst conditions.
Equipment/line/path ratings used will be those that are in use at the time of the study or that are
represented by IPC upgrade projects that are either currently under construction or whose
budgets have been approved for construction in the near future. All other potential future
ratings are outside the scope of this study. Future transmission changes may, however, affect
current facility ratings used in the study.
A-3.O Grounding Guidance
Idaho Power Company (IPC) requires interconnected transformers to limit their ground fault
current to 20 amps at the point of interconnection.
A-4.0 Electrical System Protection Guidance
IPC requires electrical system protection per Requirements for Generation Interconnections
found on the Idaho Power Web site,
http://www.idahopower.com/aboutus/business/generationInlerconnect/.
A-S.O WECC Coordinated Off-Nominal Frequency Load Shedding and Restoration
Requirements
IPC requires frequency operational limits to adhere to WECC Under-frequency and Over­
frequency Limits per the WECC Coordinated Off-Nominal Frequency Load Shedding and
Restoration Requirements available upon request.
-6-
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 22
Exergy Development Group of Idaho, LLC
Attn: Collin Rudeen
802 West Bannock, Suite 1200
Boise, ID 83702
RE: Notch Butte Project # 158
Dear Collin:
May 14, 2009
®
An IDACORP company
Enclosed is the Final Feasibility Study Report (FeSR) for the above-referenced project. The feasibility
analysis indicates that the system is capable of integrating your generator at the proposed location. We
would like to schedule a meeting or conference call to discuss the FeSR as soon as possible. Candace
Gentry will contact you to setup this meeting, or you may contact her directly at 208-388-2276.
As you are aware, this project is included in the System Impact Study for Transmission Upgrades in the
Twin Falls area, and no other System Impact Study is required. A separate Facility Study Agreement
(FSA) has already been executed for the transmission upgrades identified in the 305 MW System Impact
Study Report previously provided to you.
Since no System Impact Study is required, I have enclosed two (2) copies of the Facility Study
Agreement (FSA) for the above-referenced project.
The next step in the Generator Interconnection process IS to begin design work for the
Interconnection/Distribution facilities of this project. Please submit your agreement to proceed by
executing both copies of the attached FSA, submitting completed Attachments to the FSA, along with
the required FSA deposit to Idaho Power Company, attn: Rowena Bishop by June 16, 2009, otherwise
your application will be deemed withdrawn. The deposit under the FSA is $30,000 based on the
estimated engineering costs. Please contact me if you have any questions.
Enclosures: Final Feasibility Study Report
2 copies -Facility Study Agreement
c: Candace Gentry/IPC
Rowena Bishop/IPC
Ed Kosydar/IPC
Sincerely,
Marc Patterson
Engineering Leader, T &D Planning
Ph. 208.388.2712
1221 W. Idaho St. (83702)
P.O. Box 70
Boise, 1083707
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COM.PANY
ATTACHMENT 23
Facilities Study Agreement
THIS AGREEMENT is made and entered into this /~ay of -:);;/1 2009 by and
between EXERGY DEVELOPMENT GROUP OF IDAH , a Lf~[TED LlABlUTY
COMPANY organized and existing under the laws of the State of IDAHO, ("Interconnection
Customer,") and Idaho Power Company, a Corporation existing under the laws of the State of
Idaho ("Transmission Provider"). Interconnection Customer and Transmission Provider each
may be referred to as a "Paliy," or collectively as the "Parties."
RECITALS
WHEREAS, the Interconnection Customer is proposing to develop a Small Generating Facility
or generating capacity addition to an existing Small Generating Facility consistent with the
Interconnection Request completed by the Interconnection Customer on 12119/05, and
WHEREAS, the Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Provider's Transmission System;
WHEREAS, the Transmission Provider has completed a system impact study and provided the
results of said study to the Interconnection Customer; and
WHEREAS, the Interconnection Customer has requested the Transmission Provider to perfolm
a facilities study to specify and estimate the cost of the equipment, engineering, procurement and
construction work needed to implement the conclusions of the system impact study in
accordance with Good Utility Practice to physically and electrically connect the Small
Generating Facility with the Transmission Provider's Transmission System.
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows :
1.0 When used in this Agreement, with initial capitalization, the telms specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause a
facilities study consistent with the standard Smail Generator Interconnection Procedures
to be performed in accordance with the Open Access Transmission Tariff.
3.0 The scope of the facilities study shall be subject to data provided in AttacImlent A to this
Agreement.
4.0 The facilities study shall specify and estimate the cost of the equipment, engineering,
procurement and construction work (including overheads) needed to implement the
conclusions of the system impact study(s).
The facilities study shall also identify (l) the electrical switching confi guration of the
equipment, including, without limitation, transformer, switchgear, meters, and other
station equipment, (2) the nature and estimated cost of the Transmission Provider's
Small Generator Facilities Study Agreement - 1 -Notch Butte Wind Project #158
Interconl1ection Facilities and Upgrades necessary to accomplish the interconnection, and
(3) an estimate of the time required to complete the construction and installation of such
facilities.
5.0 The Transmission Provider may propose to group facilities required for more than one
Interconnection Customer in order to minimize facilities costs through economies of
scale, but any Interconnection Customer may require the installation of facilities required
for its OW11 Small Generating Facility if it is willing to pay the costs of those facilities.
6.0 A deposit of $30,000 is due upon execution of this agreement by the Interconnection
customer.
7.0 In cases where Upgrades are required, the facilities study must be completed within 45
Business Days of the receipt of this Agreement. In cases where no Upgrades are
necessary, and the required facilities are limited to Interconnection Facilities, the
facilities study must be completed within 30 Business Days.
8.0 Once the facilities study is completed, a facilities study repOli shall be prepared and
transmitted to the Interconnection Customer. Barring unusual circumstances, the
facilities study must be completed and the facilities study report transmitted within 30
Business Days of the Interconnection Customer's agreement to conduct a facilities study.
9.0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
10.0 The Interconnection Customer must pay any study costs that exceed the deposit without
interest within 30 calendar days on receipt of the invoice or resolution of any dispute. If
the deposit exceeds the invoiced fees, the Transmission Provider shall refund such excess
within 30 calendar days of the invoice without interest.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written.
Transmission Provider:
Idaho Power ~any -Delive y
Signed:~~ __ ~~~ ______ 7L'~~~
Printed Name: Pll1 /~U"c.i-<nJ
Title: £oWf1.ll?j2 J? S'Z' OM
Small Generator Facilities Study Agreement -2 -Notch Butte Wind Project #158
Attachment A to
Facilities Study Agreement
Data to Be Provided by the Interconnection Customer
With the Facilities Study Agreement
1. Provide location plan and simplified one-line diagram of the plant and station facilities.
For staged projects, please indicate future generation, transmission circuits, etc.
On the one-line diagram, indicate the generation capacity attached at each metering
location. (Maximum load on CT/PT)
18 MW at full generation
On the one-line diagram, indicate the location of auxiliary power. (Minimum load on
CT/PT) Amps
2. One set of metering is required for each generation connection to the new ring bus or
existing Transmission Provider station. Number of generation connections:
1
3. Will an alternate source of auxiliary power be available during CT/PT maintenance?
Yes No X
4. Will a transfer bus on the generation side of the metering require that each meter set be
designed for the total plant generation? Yes No
(Please indicate on the one-line diagram).
5. What type of control system or PLC will be located at the Small Generating Facility?
Bachmann Programmable Logic onn-o ller (PLC)
6. What protocol does the control system or PLC use?
v x W [ks operating system with Bachmann extensions
7. Please provide a 7.S-minute quadrangle map of the site. Indicate the plant, station,
transmission line, and property lines.
8. Physical dimensions of the proposed interconnection station:
Small Generator Facilities Study Agreement ..,
-.J -Notch Butte Wind Project #158
9. Bus length from generation to interconnection station:
10. Line length from interconnection station to Transmission Provider's Transmission
System.
N/A
11. Tower number observed in the field. (Painted on tower leg)*:
12. Number of third party easements required for transmission lines*:
NI A -connecting to distribution line
* To be completed in coordination with Transmission Provider.
13. Is the Small Generating Facility located in Transmission Provider's service area?
Yes X No ___ lfNo, please provide name of local provider:
14. Please provide the following proposed schedule dates:
Begin Construction Date: October, 2009
Generator Step-Up TransfOlmers Date: March 2009
Receive Back Feed Power
Generation Testing Date: May 2009
Commercial Operation Date: June 2009
Small Generator Facilities Study Agreement - 4 -Notch Butte Wind Project #158
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'1
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 24
DRAFT
Generator Interconnection
Facility Study Report
for the
Notch Butte Wind Park Project -Project #158
for
Exergy Development Group, LLC
III
Lincoln County, Idaho
April 27, 2010
An IDA CORP Company
DRAFT FACILITY STUDY REPORT (FSR)
Notch Butte Wind Park
Project #158
April 27, 2010
1. General Facility Description
This project consists of integrating and interconnecting the proposed 18 MW Notch Butte Wind Park
Project (project #158). The proposed wind project is an 18 MW wind farm consisting of twelve 1.5
MW GE wind turbines. The location of the project is in Idaho Power's Southern Idaho service
territory in approximately section 22 of T06S, R19E Lincoln County, Idaho.
A new substation will be built by the Customer to collect the generation (the substation will not
serve Idaho Power customers). The substation will be connected to the existing Midpoint to Wood
River 138 kV transmission line by way of a short new transmission tap with airbreak switch.
Interconnection Customer:
Mr. James Carkulis
Exergy Development Group, LLC
802 West Bannock, Suite 1200
Boise, ID 83702
A Standard Generator Interconnection Agreement under Idaho Power Company's Open Access
Transmission Tariff (OATT) or Schedule 72 between Interconnection Customer and Idaho Power
Company -Delivery (Transmission Owner) for the Notch Butte Wind Park Project, specifically
Generator Interconnection Project #158, will be prepared for this project. Final drawings will be
produced in the time line shown below in MILESTONES.
2. Interconnection Point
The Interconnection Point for the Notch Butte Wind Park Project will be the Customer side of the
lOlB au"break. The Interconnection Point must be located within 1500 feet of the existing Midpoint
-Wood River 138 kV transmission line. The project's location is Lincoln County, Idaho. A
drawing identifying the Interconnection Point is attached.
3. Point of Change of Ownership
The Point of Change of Ownership for the Notch Butte Wind Park Project will be the Customer side
of the 101B airbreak. The Customer will own the control building, though space shall be provided
for Idaho Power equipment within the control building.
4. Interconnection Details
All interconnection equipment electrically located on the generator side of the Point of Change of
Ownership shall be owned and maintained by the Generator. All interconnection equipment
1
electrically located on the utility side of the Point of Change of Ownership shall be owned, operated,
and maintained by Idaho Power.
4.1 Project Team
An Idaho Power Company project team was assembled to investigate the proposed project,
and develop cost estimates and a project schedule to construct Idaho Power facilities required
for the interconnection. The project team consisted of the following employees:
------
Project Lead~ __
t Prioci alEnginee_t __ _
I_E~neer -Protection __ _
Area A atatu Leader ---.--_.
De'igll Engineer
Sta~.ion~ Desio-ner
. Senior Engineer _I
,Rela & ~o_mm __ unic_at_io!1s Leader ~
,)v[eterintt .Technical Advisor ~
. Rigb:!..QfWa A ~ ______ ~
I Distribution Line Desi~r ---1
_~._'P_J_·oject Estima~
4.2 Customer's Interconnection Facilities
The Interconnection Customer will install, own, and maintain generators and the distribution
collector system. Additionally the Interconnection Customer will design and install a 138-
34.5 kV substation yard with a building, transformation, feeder protection, and yard lighting.
4.3 Other Facilities Provided by Interconnection Customer
4.3.1 Local service
The Customer is responsible to arrange for local service to the control building for
use by Customer and Idaho Power.
4.3.2 Equipment
The Interconnection Customer will provide land clearing, site leveling, grounding,
and fencing and acquire property for the new substation. A building within the
substation will be provided by the Customer and space will be allocated for Idaho
Power Company facilities as described below. Idaho Power requires a separate room
within the control building that has its own separate locked entrance into the
substation yard.
4.4 Idaho Power Company's Interconnection Facilities
Idaho Power will design and build a new 138 kV transmission line tap and airbreak line
switch, a dead-end structure, 138 kV circuit breaker, two air-break switches, and associated
relaying, control and metering equipment in the substation yard and building up to the
Interconnection Point. Metering will be accomplished at the 138 kV side of the transformer.
4.4.1 Transmission Line
A new 138 kV transmission tap, limited to 1500 feet in length, will be built between the
proposed new substation and the existing Midpoint -Wood River line #440. The tap point is
not yet selected pending a Customer selected substation location. A single line airbreak
switch will be installed at the tap point. At the Customer's request and cost, additional line
2
switches could be located on the existing 138 kV line on either side ofthe tap point to add
operational sectionalizing.
4.4.2 Communications
Idaho Power will be responsible for providing the communication circuits necessary for
revenue metering, power quality, and SCADA. Any additional communications
requirements for Customer owned equipment is the responsibility of the Customer.
4.5 Operational Limitations
Interconnection Customer will be able to modify power plant facilities on the generator side
of the Interconnection Point with no impact upon the operation of the transmission system
whenever the generation facilities are electrically isolated from the transmission system.
The project must be controlled to operate within +/-6MVAR. Voltage flicker at startup and
during operation will be limited to less than 5% as measured at the Interconnection Point.
The project is required to comply with the applicable Voltage and Current Distortion Limits
found in IEEE Standard 519-1992 IEEE Recommended Practices and Requirements for
Harmonic Control in Electrical Power Systems.
4.6 Other Requirements
In order to minimize interconnection costs to the Customer, Idaho Power has chosen to
operate the new substation terminal without line relaying communication. To accomplish
this operating scheme, the transformer must be a 138/34.5 kV grounded wye -delta
configuration. It cannot be a three winding transformer or an auto transformer with a delta
tertiary.
4.7 Scope of Transmission Network Upgrades (If Required)
Network Upgrades for this project will be detailed in a separate Facility Study Report for the
Joint Study Group identified in the March 19, 2008 System Impact Study Report for up to
353 MW of New Generation n the 1 8kV Transmission System in the Twin Falls Area.
It should be noted that there are other proposed interconnection projects in the same area that
will be using the same facilities that this project will need. This will affect the cost allocation
of the proposed facilities. IPC is unable at this time to estimate your pro rata share of the
overall costs, as the total cost is dependent on the level of participation of other parties in the
Generator Interconnection queue.
The Interconnection Customer has elected for the project to be subject to Generation Output
Limit Control under IPUC Order No. 30419.
3
5. Budget
The following good faith estimates are provided in 2010 dollars:
Estimated Cost & Ownership:
Customer
TOTAL, r--1--
~-----+
N/A
Interconnection Facilities: I
!!ansmi si n Tap~ __ =========================~_--+IIPc ____ -~ I $285,000!
Substation IIPC I $900,000, I -~------TOTAfi=;-=~-=~--+===~~_-$-1,~18-5";',0~0~o.
Transmission Network Upgrades under the 3/2008 System
, mpact Study for the Joint Study Group (pro rata cost in
ac~ r~!lnce with IPUC Order 30419-"'.)_: __
1_ GRAND TOTA_L-+; ____ _
I(TraOSmi"'iOn Network Upgrades Funding will be requested I
'lJ[)d e~ se~~arate Facility Study Repol1:) __ _ __ _
Milestones:
Construction Documents & Order Materials
Provided unde
separate re~o _I
$1,18500
-
6/28/10
10/31/10
2/1111 Construction (Assuming Materials are Available-Otherwise as Materials
7/1111
8/1111 I -8/15/11
~C~'!:!L ____ _
Construction Budget TimeIine:
'PerIod __ .;...,.;. __ .......... -.J-..:....J~ ___ --.;Amount
June2010-Augu~2011 r~~~~~~~~~~~~~~~~~~~~~~_$_1_,1_8_5_,0_0~0 1.
GRAND TOTAL $1,185,000 1
4
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 25
Clark, Danielle
From:
jent:
To:
Cc:
Subject:
Angell, Dave
Wednesday, May 12, 20108:54 AM
Bishop, Rowena
Rechel, Kelley; Sloan, Aubrae; Bauer, Rich; Patterson, Marc; Hobson, Bryan
Status of Exergy Projects
Rowena, Exergy has failed to pay the outstanding transmission network upgrade invoice or provide a letter of credit for
the Notch Butte project. Please remove project number 158, Notch Butte, from the generator interconnection queue.
The queue status ofthe other projects has not changed.
Regarding the Thousand Springs Generation Interconnection Agreement, James has requested that we identify each of
the PURPA projects that will interconnect through Thousand Springs in the GIA. Please include the names of each in
Attachment 1.
Dave Angell
2701
1
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 26
Small Generator Feasibility Study Agreement
Notch Butte Wind Project #349
Feasibility Study Agreement
THIS AGREEMENT is made and entered into this 27 day of 4c,uj" sf 2010, by and
between ,;.x~JLg'" O~vSLoiJv116Nr c"gCJ\-t'" OF i O!'f1to , a _L--'...k-""--_________ _
organized and existing under the laws of the State of ---,-,I 0"'-'<..I.1.!.L11,,-0 _______ -'
("Interconnection Customer, ") and Idaho Power Company a Corporation existing under the laws
of the State of Idaho ("Transmission Provider"). Interconnection Customer and Transmission
Provider each may be referred to as a "Party," or collectively as the "Parties."
RECITALS
WHEREAS, Interconnection Customer is proposing to develop a Small Generating Facility or
generating capacity addition to an existing Small Generating Facility consistent with the
Interconnection Request completed by Interconnection Customer on August 16, 2010; also
known as Project #349, and
WHEREAS, Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Provider's Transmission System; and
WHEREAS, Interconnection Customer has requested the Transmission Provider to perfolTIl a
feasibility study to assess the feasibility of interconnecting the proposed Small Generating
Facility with the Transmission Provider's Transmission System, and of any Affected Systems;
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the terms specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause to be
performed an interconnection feasibility study consistent the standard Small Generator
Interconnection Procedures in accordance with the Open Access Transmission Tariff.
3.0 The scope of the feasibility study shall be subject to the assumptions set forth in
Attachment A to this Agreement.
4.0 The feasibility study shall be based on the technical information provided by the
Interconnection Customer in the Interconnection Request, as may be modified as the
result of the scoping meeting. The Transmission Provider reserves the right to request
additional technical information from the Interconnection Customer as may reasonably
become necessary consistent with Good Utility Practice during the course of the
feasibility study and as designated in accordance with the standard Small Generator
Small Generator Feasibility Study Agreement
Notch Butte Wind Project #349
Interconnection Procedures. If the Interconnection Customer modifies its Interconnection
Request, the time to complete the feasibility study may be extended by agreement of the
Parties.
5.0 In performing the study, the Transmission Provider shall rely, to the extent reasonably
practicable, on existing studies of recent vintage. The Interconnection Customer shall not
be charged for such existing studies; however, the Interconnection Customer shall be
responsible for charges associated with any new study or modifications to existing studies
that are reasonably necessary to perform the feasibility study.
6.0 The feasibility study report shall provide the following analyses for the purpose of
identifying any potential adverse system impacts that would result from the
interconnection of the Small Generating Facility as proposed:
6.1 Initial identification of any circuit breaker short circuit capability limits exceeded
as a result of the interconnection;
6.2 Initial identification of any thermal overload or voltage limit violations resulting
from the interconnection;
6.3 Initial review of grounding requirements and electric system protection; and
6.4 Description and non-bonding estimated cost of facilities required to interconnect
the proposed Small Generating Facility and to address the identified short circuit
and po.wer flow issues.
7.0 The feasibility study shall model the impact of the Small Generating Facility regardless
of purpose in order to avoid the further expense and interruption of operation for
reexamination of feasibility and impacts if the Interconnection Customer later changes
the purpose for which the Small Generating Facility is being installed.
8.0 The study shall include the feasibility of any interconnection at a proposed project site
where there could be multiple potential Points of Interconnection, as requested by the
Interconnection Customer and at the Interconnection Customer's cost.
9.0 In lieu of Feasibility Study deposit, Interconnection Customer agrees that study funds
will be drawn from the application fee for the performance of the Interconnection
Feasibility Study.
Transmission Provider shall charge and Interconnection Customer shall pay the actual
costs of the Interconnection Feasibility Study. Any difference between the deposit and
the actual cost of the study shall be paid by or refunded to Interconnection Customer, as
appropriate.
Small Generator Feasibility Study Agreement
Notch Butte Wind Project #349
10.0 Once the feasibility study is completed, a feasibility study report shall be prepared and
transmitted to the Interconnection Customer. Barring unusual circumstances, the
feasibility study must be completed and the feasibility study report transmitted within 30
business days of the Interconnection Customer's agreement to conduct a feasibility study.
11.0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
12.0 The Interconnection Customer must pay any study costs that exceed the deposit without
interest within 30 calendar days on receipt of the invoice or resolution of any dispute. If
the deposit exceeds the invoiced fees, the Transmission Provider shall refund such excess
within 30 calendar days ofthe invoice without interest.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written.
Transmission Provider: Interconnection Customer:
Idaho Power Company -Delivery ~'(f£Gfl.G,'-( f/l::\lI?l-q"ml:'(V, q(loc/(C> 0 P rp.A{fc>, LLc
Printed: Marc Patterson
Title: Engineering Leader, T &D Planning
Date: A~ 2. 7. 2-or 0 Date: ;;; F-due. -Z () (0
Small Generator Feasibility Study Agreement
Notch Butte Wind Project #349
Attachment A to Feasibility Study Agreement
Assumptions Used in Conducting the Feasibility Study
The feasibility study will be based upon the information set forth in the Interconnection Request
and agreed upon in the scoping meeting held on .4t~ '27r Z o ( () :
1) Designation of Point of Interconnection and configuration to be studied.
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2) Designation of alternative Points of Interconnection and configuration.
I)-and 2) are to be completed by the Interconnection Customer. Other assumptions (listed
below) are to be provided by the Interconnection Customer and the Transmission Provider.
Page 1 of 1
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 27
GENERATOR INTERCONNECTION
FEASIBILITY STUDY
for integration of the proposed
PROJECT #349
to the
IDAHO POWER COMPANY ELECTRICAL SYSTEM
for the
INTERCONNECTION CUSTOMER
FINAL REPORT
October 15,2010
1.0 Introduction
The Generation Interconnection Customer has contracted with Idaho Power Company (IPCo)
to perform a Generator Interconnection Feasibility Study for the integration of the proposed 6.5
MW Wind Park Project (project #349). The location of the project is in Idaho Power's
Southern Idaho service territory in Lincoln County, Idaho (see Appendix B).
This report documents the basis for and the results of this Feasibility Study for the Generation
Interconnection Customer. It describes the proposed project, the study cases used, the impact
of associated projects, and results of all work in the areas of concern.
2.0 Summary
The proposed project is a 6.5 MW wind farm consisting ofthree 2.05 MW REpower wind
turbines. The proposed Point ofInterconnection (POI) for the generating facility with the IPCo
system is at the wind park, where IPCO's distribution facilities connect to the wind park's
facilities.
A new four mile double circuited feeder will have to be constructed. This feeder will be on the
same poles as DTRC-OI2 and directly connect the facility to IPCo's distribution substation and
will not be connected to any customer loads. A generation interconnection and protection
package will be required at the POI which will be located at the end of the new four mile
feeder. At the substation a second transformer will also be added for operational and reactive
power reasons.
Voltage on the 46 kV bus at the distribution substation attains a level that is too high by IPCo
standards. In order for that voltage to be brought down to within those standards a four mile
transmission line upgrade will be necessary along with the requirement that the generation
facility will have to consume 2 MV AR during periods of light loading.
This project's Feasibility Study only addresses the ability of the project to interconnect to the
system, there are no transmission rights secured for the project until a transmission system
request is submitted by the corresponding transmission customer. The required transmission
facilities, if any, to support energy transfers will then be determined based on first come first
serve basis (queue order).
The estimated cost for all required upgrades ofIPCo owned facilities to serve the full project is
$3,700,000.
3.0 Scope of Interconnection Feasibility Study
The Interconnection Feasibility Study was done and prepared in accordance with Idaho Power
Company Standard Generator Interconnection Procedures, to provide a preliminary evaluation
of the feasibility of the interconnection of the proposed generating project to the Idaho Power
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system. As listed in the Interconnection Feasibility Study agreement, the Interconnection
Feasibility Study report provides the following information:
preliminary identification of any circuit breaker short circuit capability
limits exceeded as a result of the interconnection;
preliminary identification of any thermal overload or voltage limit
violations resulting from the interconnection; and
preliminary description and non-binding estimated cost of facilities
required to interconnect the Small Generating Facility to the Distribution
System and to address the identified short circuit and power flow issues.
All other proposed Generation projects prior to this project in the Generator Interconnect queue
were considered in this study. A current list of these projects can be found on the Idaho Power
web site as follows:
http://www.oatioasis.com/ipco/index.btml.
4.0 Description of Proposed Generating Project
Project #349 proposes to connect to the Idaho Power distribution system for an injection of 6.5
MW (maximum project output) using three REpower 2.05 MW wind turbines.
5.0 Description of Existing Transmission Facilities
The transmission line that serves this area is a 46 kV radial tap. This tap serves one
distribution substation, as well as a 5.3 MVA hydro generation facility. Voltage problems
occur under light loading conditions on the 46 kV system. With the addition of this project the
voltage is increased by over 0.04 p.u. This voltage must be brought down to at least 1.05 p.u.
To help bring the voltage down, the project will have to consume 2 MY AR during periods of
light load.
With the addition ofthis project the transmission line total load will not exceed its limitations.
There is enough capacity on this tap to serve this project during periods oflight load and high
generation. However, with the wind park consuming 2 MV AR, high voltage still exists. By
reconductoring a four mile stretch on transmission line with 397.5 ACSR the high voltage is
brought to an acceptable level.
This project's Feasibility Study only addresses the ability of the project to interconnect to the
system, there are no transmission rights secured for the project until a transmission system ·
request is submitted by the corresponding transmission customer. The required transmission
facilities, if any, to support energy transfers will then be determined based on first come first
serve basis (queue order).
-2-
6.0 Description of Existing Substation Facilities
The distribution substation that serves this area is located approximately four miles to the west
of the wind park. The existing substation transformer is a 46:12.5 kV transformer that does
have available capacity to serve the wind park. However, due to the large amount of reactive
power and increased voltages during trip/close events a new transformer is needed .
This new transformer will be a 12.5 MY A 46: 12.5 kV transformer and will only be connected
to the dedicated feeder that the generating facility will be on. In order to accommodate the
additional substation work required more land will need to be purchased around the existing
substation. This cost is not included in the estimates but will be necessary for this project to
proceed.
The feeder breakers on the adjacent feeders are Cooper type "VWVE38X" breakers which are
designed for 560 amps continuous load current and have a maximum fault current interrupting
rating of 12,000 amps. These feeder breakers will not be connected to the generating facility,
but this type of breaker would be acceptable for addition on the new dedicated feeder.
7.0 Description of Existing Distribution Facilities
The distribution feeder serving this area is a grounded wye feeder operating at 12.5 kV. There
is not adequate capacity on this feeder to serve this project. Also, the wind park should not be
connected directly to customer loads due to the high amount of reactive power that will need to
flow to the generating facility.
These two factors point to the reason why a dedicated distribution feeder is needed from the
substation to the generating facility. This feeder will need to be at 12.5 kV and constructed
with 336 AAC. It will also be double circuited along with DTRC-012. The heavily loaded
conductor consumes enough V ARs during light load and heavy generation at DTRC that the
transmission system sees nearly 3 MV AR along with the wind park's consumption. This VAR
output is enough to bring down the voltage on the 46 kV system to an acceptable level.
The proposed POI for the generating facility with the IPCo system is at the wind park, where
IPCo's distribution facilities connect to the wind park's facilities. Refer to Appendix A section
3 for additional grounding requirements.
8.0 Description and Cost Estimate of Required Facility Upgrades
At the transmission level four miles of conductor needs to be replaced with 397.5 ACSR for
voltage reduction reasons. Due to operational and reactive power concerns, a new 46: 12.5 kV
transformer is needed at the substation along with a transformer bay and feeder breaker. A
new double circuited 12.5 kV 336 AAC distribution feeder will have to be installed from the
substation to the wind park, and at the POI, a Generation Interconnection and Protection
-3 -
. '
package will be required. Also, more land will need to be purchased around IPCo's
distribution substation but is not reflected in the following estimated costs.
Description Estimated Cost
New 12.5 MVA 46:12.5 kV transformer, bay and
feeder breaker. $1,500,000
4 miles of double circuit distribution line at 336 AAC $1,000,000
Generation Interconnection Protection Package
(Includes 12.47 kV recloser, controls, CTs, PTs, and
communications). $200,000
4 miles of transmission line upgraded to 397.5 ACSR $1,000,000
Total Estimated Cost $3,700,000
Table 1: EstImated Costs for ReqUIred Upgrades
These cost estimates include direct equipment and installation labor costs, indirect labor costs
and overheads. (Tax Gross Up has not been included presuming construction of
interconnection facilities will not qualify under IRS rules as a taxable event. Allowance for
funds used during construction (AFUDC) has not been included in the cost estimates since it is
assumed that IPC will be provided up-front funding by the Project). These are cost estimates
only and final charges to the customer will be based on the actual construction costs incurred .
9.0 Description of Operating Requirements
In addition to these upgrades, there are also several operating requirements that must be met.
The project will have to be capable of producing and consuming up to 2 MVAR. The project
will also have to meet the V AR schedule provided by Idaho Power. If these requirements
cannot be met, further voltage studies will be necessary. The project is required to comply
with the applicable Voltage and Current Distortion Limits found in IEEE Standard 519-1992
IEEE Recommended Practices and Requirements for Harmonic Control in Electrical Power
Systems.
11.0 Conclusions
The requested interconnection of the Notch Butte Wind Park to Idaho Power's system was
studied. The results of this study work confirm that the existing Idaho Power system can be
upgraded to handle this project. The known required upgrades to the system are listed. An
IPCo Transmission System Impact Study is not required for this project. However, no
transmission rights have been reserved.
-4-
APPENDIX A
A-l.O Method of Study
The Feasibility Study plan inserts the Project up to the maximum requested injection into the
selected Western Electric Coordinating Council (WECC) power flow case and then, using
Power World Simulator Version 12, examines the impacts of the new resource on Idaho
Power's transmission system (lines, transformers, etc.) within the study area under various
operating/outage scenarios. The WECC and Idaho Power reliability criteria and Idaho Power
operating procedures were used to determine the acceptability of the configurations considered.
The WECC case is a recent case modified to simulate stressed but reasonable pre-contingency
energy transfers utilizing the IPC system. For distribution feeder analysis, Idaho Power
utilizes Advantica's SynerGEE Software.
A-2.0 Acceptability Criteria
The following acceptability criteria were used in the power flow analysis to determine under
which system configuration modifications may be required:
The continuous rating of equipment is assumed to be the normal thermal rating of the
equipment. This rating will be as determined by the manufacturer of the equipment or
as determined by Idaho Power. Less than or equal to 100% of continuous rating is
acceptable.
Idaho Power's Voltage Operating Guidelines were used to determine voltage
requirements on the system. This states, in part, that distribution voltages, under
normal operating conditions, are to be maintained within plus or minus 5% (0.05 per
unit) of nominal everywhere on the feeder. Therefore, voltages greater than or equal to
0.95 pu voltage and less than or equal to 1.05 pu voltage are acceptable.
Voltage flicker during starting or stopping the generator is limited to 5% as measured at
the point of interconnection, per Idaho Power's T&D Advisory Information Manual.
Idaho Power's Reliability Criteria for System Planning was used to determine proper
transmission system operation.
All customer generation must meet IEEE 519 and ANSI C84.1 Standards.
All other applicable national and Idaho Power standards and prudent utility practices
were used to determine the acceptability of the configurations considered.
The stable operation of the system requires an adequate supply of volt-amperes reactive
(V ARs) to maintain a stable voltage profile under both steady-state and dynamic
-5-
system conditions. An inadequate supply ofVARs will result in voltage decay or even
collapse under the worst conditions.
Equipment/line/path ratings used will be those that are in use at the time of the study or that are
represented by IPC upgrade projects that are either currently under construction or whose
budgets have been approved for construction in the near future. All other potential future
ratings are outside the scope of this study. Future transmission changes may, however, affect
current facility ratings used in the study.
A-3.0 Grounding Guidance
Idaho Power Company (IPC) requires interconnected transformers to limit their ground fault
current to 20 amps at the point of interconnection.
A-4.0 Electrical System Protection Guidance
IPC requires electrical system protection per Requirements for Generation Interconnections
found on the Idaho Power Web site,
http://www.idahopower.com/aboutus/business/generationInterc01llect/.
A-S.O WECC Coordinated Off-Nominal Frequency Load Shedding and Restoration
Req uirements
IPC requires frequency operational limits to adhere to WECC Under-frequency and Over­
frequency Limits per the WECC Coordinated Off-Nominal Frequency Load Shedding and
Restoration Requirements available upon request.
-6-
APPENDIXB
Proje'ct#349 Notch Butte
-7-
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 28
Small Generator Feasibility Study Agreement
Notch Butte Project #359
Feasibility Study Agreement
THIS AGREEMENT is made and entered into this ~day of IJtJJ02r~ber 2010, by and
between c:xe"''J1 'Dave (Of ",.v..vi 6.rovt J I c;ic,t,o, a __ ...J,L""'-"='-::....c.:.._· _______ _
orgar:tized and existing under the laws of the State of I da I". 0 ,
("Interconnection Customer,") and Idaho Power Company a Corporation existing under the laws
of the State of Idaho ("Transmission Provider"). Interconnection Customer and Transmission
Provider each may be referred to as a "Party," or collectively as the "Parties."
RECITALS
WHEREAS, Interconnection Customer is proposing to develop a Small Generating Facility or
generating capacity addition to an existing Small Generating Facility consistent with the
Interconnection Request completed by Interconnection Customer on November 11, 2010; also
lmown as Project #359, and
WHEREAS, Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmj.ssion Provider's Transmission System; and
WHEREAS, Interconnection Customer has requested the Transmission Provider to perform a
feasibility study to assess the fe~si~ility of interconnecting the proposed Small Generating
Facility with the Transmission Provider'S Transmission System, and of any Affected Systems;
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Paliies agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the terms specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause to be
performed an interconnection feasibility study consistent the standard Small Generator
IntercOlmection Procedures in accordance with the Open Access Transmission Tariff.
3.0 The scope of the feasibility study shall be subject to the assumptions set forth in
Attachment A to this Agreement.
4.0 The feasibility study shall be based on the technical information provided by the
Interconnection Customer in the Interconnection Request, as may be modified as the
result of the scoping meeting. The Transmission Provider reserves the right to request
additional technical information from the Interconnection Customer as may reasonably
become necessary consistent with Good Utility Practice dming the course of the
feasibility study and as designated in accordance with the standard Small Generator
Small Generator Feasibility Study Agreement
Notch Butte Project #359
Interconnection Procedures. If the Interconnection Customer modifies its Interconnection
Request, the time to complete the feasibility study may be extended by agreement of the
Parties.
5.0 In performing the study, the Transmission Provider shall rely, to the extent reasonably
practicable, on existing studies of recent vintage. The Interconnection Customer shall not
be charged for such existing studies; however, the Interconnection Customer shall be
responsible for charges associated with any new study or modifications to existing studies
that are reasonably necessary to perform the feasibility study.
6.0 The feasibility study l'epOlt shall provide the following analyses for the purpose of
identifying any potential adverse system impacts that would result from the
interconnection of the Small Generating Facility as proposed:
6.1 Initial identification of any circuit breaker short circuit capability limits exceeded
as a result of the interconnection;
6.2 Initial identification of any thermal overload or voltage limit violations resulting
fl.·om the interconnection;
6.3 Initial review of gro\ID~ing requirements and electric system protection; and
6.4 Description and non-bonding estimated cost of facilities required to interconnect
the proposed Small Generating Facility and to address the identified short circuit
and power flow issues.
7.0 The feasibility study shall model the impact of the Small Generating Facility regardless
of purpose in order to avoid the further expense and interruption of operation for
reexamination of feasibility and impacts if the Interconnection Customer later changes
the purpose for which the Small Generating Facility is being installed.
8.0 The study shall include the feasibility of any interconnection at a proposed project site
where there could be multiple potential Points of Interconnection, as requested by the
Interconnection Customer and at the Interconnection Customer's cost.
9.0 In lieu of Feasibility Study deposit, Interconnection Customer agrees that study funds
will be drawn fi:om the application fee for the perfonnance of the Interconnection
Feasibility Study.
Transmission Provider shall charge and Interconnection Customer shall pay the actual
costs of the Interconnection Feasibility Study. Any difference between the deposit and
the actual cost of the study shall be paid by or refunded to Interconnection Customer, as
appropliate.
Small Generator Feasibility Study Agreement
Notch Butte Project #359
10.0 Once the feasibility study is completed, a feasibility study repOlt shall be prepared and
transmitted to the Interconnection Customer. Barring unusual circumstances, the
feasibility study must be completed and the feasibility study report transmitted within 30
business days of the Interconnection Customer's agreement to conduct a feasibility study.
11.0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
12.0 The Interconnection Customer must pay any study costs that exceed the deposit without
interest within 30 calendar days on receipt of the invoice or resolution of any dispute. If
the deposit exceeds the invoiced fees, the Transmission Provider shall refund such excess
within 30 calendar days of the invoice without interest.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written.
Transmission Provider:
Idaho Power Company -Delive.ry
Printed: Marc Patterson
Title: Engineering Leader, T &D Planning
Date: Ai 0 v Z Or I 2 b I c
Interconnection Customer:
Printed: Co /,.U IV 12. !A t2 6 G IV
Title: t...-@"Pl.? f(U);J6q b(\J6/N65{2.
Date: \ II "Z-"'1 (2-D 10
Small Generator Feasibility Study Agreement
Notch Butte Project #359
Attachment A to Feasibility Study Agreement
Assumptions Used in Conducting the Feasibility Study
The feasibility study will be based upon the infonnation set forth in the Interconnection Request
and agreed upon in the scoping meeting held on IV 0 v Z. q I Z 0 I (0
1) Designation of Point of Interconnection and configuration to be studied .
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( 2.5 I,£: v' IV Lf2 53. I Z"I'1'¥ 3 W lit-; i o. 57
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(SCt.M.e uS G I/\lT *~7'''1J
2) Designation of alternative Points 'of Interconnection and configuration.
1) and 2) are to be completed by the Interconnection Customer. Other assmnptions (listed
below) are to be provided by the Interconnection Customer and the Transmission Provider.
Page 1 of 1
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 29
Facilities Study Agreement
THIS AGREEMENT is made and entered into this ~y Of~U M./lJ1.JOIO by and
between E'(£fL6..'( DEV~MC;r.rr C7R.oJP o r? IMIj0 " a l-LL organized
and existing under the laws of the State of IDAHo , ("Interconnection
Customer,lI) and Idaho Power Company, a Corporation ex.isting under the laws of the State of
Idaho ("Transmission Provider"). Interconnection CU$tomer an,d Transmission Provider each
may be referred to as a "Party," or collectively as the "Parties."
RECITALS
WHEREAS, the Interconnection Customer is proposing to develop 'a Sm,al.I Generating Facility
or generating capacity addition 'to an, existing Smrul Generating Facility consistent with the
Intl')rconnection Request completed by the Interconnection Customerori,B/161l0; and
WHEREAS, the Interconnedion CUstomer desires to' interconnect the, Small Generating Facility
with the Transmission Pro vid e:r's TransnJ,ission, System;
WHEJ,U:AS, the Transmission Provider has completed :a 'system impact studyanrl provided th~
results of said study to the Interconnection Customer; and
Wl!EREA,S, ~he Interconnection Customer has requeste4 the Transmission Provid,er to petfonn
a facilities study to .specify and estimate the cost ofthe equipinent, engiiIeering, procurement and
construction work needed to implement the concl4SiOhsof the~¥$tem impact s.~Wly in
accordance with Good Utility Practice to physically aQa electrically connect the Small
Generating' Facility with the transmission Provider's Transmission System.
NOW, THEREFORE, in consideration of and subject to the mut1;Ial coyena11ts contain¢d herein
the Parties agfeed as foliows:
1.0 When, uS'ed ill this Agreement, withiriitial capitalization, the terms speCified shall have
the meanings indicated or the meariings specified in the standard Smail Generator
Interconnection .Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause a
facilities study consistent with the standard Small Genera:tor Interconnection Proced\lres
to be performed in accordance with the Open Access Transmission Tariff.
3.0 The scope of the facilities study shall be subject to data ,provided in Attachment A to this
Agreement.
4.0 The facilities study Shall specify and estimate the cost of the equipment; engineering,
procurement and construction work (including overheads) needed to implement the
conclusions of the system impact study(s).
The facilities study shall also identify (1) the electrical switching configuration of the
equipment, including, without limitation, transfonner, switchgear, meters, and other
station equipment, (2) the nature and estimated cost ofthe Transmission Provider's
Small Generator Facilities Study Agreement -l -Notch Butte Wind Project #349
Interconnection Facilities and Upgrades necessary to accomplish the interconnection, and
(3) an estimate of the time required to complete the construction and installation of such
facilities.
5.0 The Transmission Provider may propose to group facilities required for more than one
Interconnection Customer in order to minimize facilities costs through economies of
scale, but any Interconnection Customer may require the installation of facilities required
fot its Own Small Generating Fi:lcility 'if it is willing to pay the costs of those facilities.
6.0 A deposit of $30,00.0.00 is due upon execution of this agreement by the Interconnection
customer.
7.0 In C4ses where Upgrades ate required, the facilities study m.ust be completed within 45
Business Days ofibe receipt of this Agreement. In cases where no Upgrades are
necessary; and the required facilities are limited to Interbonilection Facilities, the
facilities study must be completed within 30. Business Days.
8.Q Once tIle facilities study is completed, a faeilities-study report shall be prepared and
transmitted to the futerconnection Customer. Barring unusual circumstances, the
faCilities study must be completed and the faCilities study report trans:rnittedwithin 30.
Business Dilys of the Interconnection 'Cu$tometis agreel11entto conduct a facilities 'study;
9.0 Any study fees sh~l1 be based on the Transmission Provider's actual costs and will be
jnvoiced to the Interconrtection Customer after ,the study is compieted and delivered and
will include a summary ofptofessional time.
10.0 The Interconnection Cijstomet l]]ust pay any study costs that exceed the deposit without
interest within 30 calendar days on receipt 'of the invoice or resolution of any dispute. If
the deposit exceeds the invoiced fees, the Tr'ansmlssion Provider shall refund sUGh eXcess
within 3 o calendar days of the invoice without .interest. '
IN WITNESS WHEREOF.', the Parties have (mused this Agreement to he duly executed by their
duly authorized officers or agents on the day and year first above written.
Transmission Provider:
Idaho Power C upany -Delivel),
S igned: =P"'-~.-4::--~=-..q~~-"----­
Printed Name: 6v\J~v.:J t:;;2'ttJA;'{,
Title: P M s; "11'..::"1. v l-S.'-Oll, --------------------------
Date: ___ '_' ·....:J L-:../_0-lA-.!.(..,.:(J ______ _
Small Generator Facilities Study Agreement - 2 -
Printed Name: CelL-ltv 'il,vjJee/J "'" J3.f>l/ALE .:.1" :f(tr'le.'?
C/llll<.v~t? /~/I
Notch Butte Wind Project #349
Attachment A to
Facilities Study Agreement
Data to Be Provided by the Interconnection Customer
With the Facilities Study Agreement
1. Provide 10cation plan and simplified one-line diagram of the plant and station facilities .
For staged·projects1 please indicate future generation, transmission clre.tiits, etc.
On the one-line diagram, indicate the generation capacity attached at each metering
location. (Maximum load on CTIPT~
On the one~1ine diagram, :ihdiCate the location of auxiliary power: (Minimum load on ·
C'tiPt) .Am s . . . p
2. One set of metering is required for each generation connection to the new ring bus or
existing Transmission Provider statIon. Number of generation connections:
I
3. Will an alternate SOlll;ee of auxiliary power he available during CT/PT maihtenance?
Yes No X ,
4. Will a trahsJ~bus on thegene.ration side of the metering require that each meter set be
designed for the total plant generation? Yes No --X-
(please indicate on the one-line diagram).
5. What type ofconttol system or PLC will he located at the Small Generating Facility?
6. What protocol doe.s th~ control system or PLC use?
7. Please provide a 7.5-minute quadrangle map of the site. Indicate the plant, station,
transmission line, and property lines.
8. Physical dimensions of the proposed intercOlmection station:
Small Generator Facilities Study Agreement - 3 -Notch Butte Wind Project #349
9. Bus length from generation to interconnection station:
10. Line length from intercoilllection station to Transmission Provider's Transmission
System.
11. Tower number observed in the field. (Painted on tower leg)*:
12. Nun:iber of third party easemeIits reqUired for transmission llnes*:
* To be completed in coordination with TransrtJission Provider.
n. Is the S:mall GeIieratingFacility located in Transmission Provider's service area?
Yes X No ~~~ .. If No, please provide name oflocal provider:
14. Please providetlie following proposed schedule dates:
Begin Construction
Generator Step.,.Up TrlU1sformers
Receive Back Feed Powet
G¢neration. Testing
Commercial Operation
Small Generator Facilities Study Agreement ·4-
Date: l\VC::, J-o\(
Date: Av~ :J.Q \l
Date: 5c:rr. d,o tI
Date: S ~[lT. 20\\
Notch Butte Wind Project #349
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BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 30
.. -'
BH
GENERATOR INTERCONNECTION
FEASIBILITY STUDY
For integration of the proposed
GENERATION INTERCONNECTION PROJECT #359
Notch Butte Wind
In
LINCOLN COUNTY, IDAHO
To the
IDAHO POWER COMPANY ELECTRICAL SYSTEM
for
Exergy Development Group of Idaho, LLC
DRAFT REPORT
January 12,2011
Generator Interconnection Feasibility Study
General Interconnection Information
Station or
Date of Total Trans Line
Queue Request Location (MW) for POI
12.5 kV
connection
through
November Lincoln Dietrich
#359 2010 County 11.5 Substation
Short Circuit Analysis Results
System Changes Required: DYes ~No
Power Flow Analysis Results
System Changes Required: ~Yes DNo
Projected
In-Service
Date
September
2011
Type of facility
(combined cycle,
base load, CT, fuel
type)
Wind
Because project #359 and #349 (6.5 MW) are both part of the Notch Butte Wind project, they both connect
at the same point of interconnection (POI), and common facilities will serve both proj ects, the upgrade
costs to serve both of these projects are included in this report. The required system upgrades to serve
these projects include:
• A new 7 mile long 138 kV transmission line from Midpoint substation to Shoshone Substation.
• A new 138:46 kV transformer at Shoshone substation and associated equipment.
• Upgrade the existing Shoshone-Dietrich 46 kV line (11.25 miles).
• A new 46: 12.5 kV transformer at Dietrich substation and associated equipment including two new
12.5 kV distribution feeder terminals.
• A new double circuit 12.5 kV distribution line from Dietrich substation to the point of
interconnection ( 4 miles).
• A generation interconnection and protection package for each wind project (#349 and #359).
Good Faith Cost Estimate
Interconnection cost estimate: $14,220,000.
Description
46 kV line upgrades SHSH-DTRC (11.25 miles)
138 kV line MPSN-SHSH (7 miles)
DTRC Substation Upgrades
SHSH Substation Upgrades
MPSN Substation Upgrades
12.5 kV Distribution double circuit line (4 miles)
Two Generation Interconnection Protection Packages (Each includes 12.47 kV
recioser, controls, CTs, PTs, and communications).
Total
-/-
Estimated Cost
$3,325,000
$3,661,000
$2,851,000
$2,112,000
$563,000
$1,308,000
$400,000
$14,220,000
".
System Impact Study Required? DYes ~ No
This Feasibility Study only addresses the work required to interconnect Notch Butte Wind to the Idaho
Power system. There are no transmission rights secured for the project until a transmission system request
is submitted by the corresponding transmission customer. The required transmission facilities, if any, to
support energy transfers will then be determined based on first come first serve basis (queue order).
Operating Requirements:
Project #359 will be controlled to operate at unity power factor with an operating bandwidth of ± 500
kVAR.
During light system load conditions, an outage on the proposed 138 kV line from Midpoint to Shoshone or
the Shoshone 138:46 kV transformer will result in unacceptably high voltage on the 46 kV system in the
Dietrich-Shoshone area (up to 117% of nominal). Under these conditions, Notch Butte Wind projects will
be tripped offline to relieve the high voltage on the 46 kV system.
-2 -
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 31
~C4UJL~~r &0J'LJll~BE PllC
ATTORNEYS AT LAW
Peter Richardson
Tel: [phone] I Fax: [phone]
pete [e-mail]
P.O. Box 7218 Boise, ID 83707 -515 N. 27,h Sr. Boise. 10 83702
Via Electronic and U.S. Mail
Rowena Bishop
Idaho Power Company
P.O. Box 70
Boise, Idaho 83707
January 28,2011
Re: Notch Butte Wind Park Interconnection Request; Project Nos. 158,349, and 359
Dear Rowena:
I write on behalf of my client, Exergy Development Group of Idaho, LLC, regarding its request for
interconnection for the above-referenced PURP A qualifying facility project in Lincoln County,
Idaho, near Idaho Power's Dietrich substation. This project has had a fully executed and approved
power purchase agreement for some time now. In Exergy's attempts to bring the project online in a
timely manner, it has requested interconnection under Idaho Power's Schedule 72, but has received
interconnection studies with inconsistent engineering configurations and seemingly high cost
projections. Consequently, Exergy has been delayed in its ability to enter into an acceptable
interconnection agreement, and is now concerned that further delay will impede its ability bring the
project online in a timely manner.
The Feasibility Study for Project No. 158, dated January 22,2008, projected that interconnection of
the 18 MW projectwould cost $4.328 million. At this point, Idaho Power proposed to construct the
new substation "located at the wind park" in order to provide voltage transformation from ~4.5 kV
to 138 kV, so that the project could interconnect onto the 138 kV Midpoint-Wood line "by way bf a
5.5 mile transmission tap." This Study included a table with the following costs:
Description
5.5 mile 138 kV 397 ACSR transmission
tap from the Midpoint -Wood River line
and air breaks.
New Substation with 22 MVA 138:345
k V transformer and LTC
Cost
$1,530,000
- -.--$2 510 000 , ,
Ms. Rowena Bishop
January 28, 2011
Page 2
Point ofInterconnection (generation
interconnection and protection package).
Total Estimated Cost
$288,000
$4,328,000
This proposal seemed acceptable to Exergy, so Exergy paid to kept Project No. 158 in the study
queue and received a Facility Study Report on April 27, 2010.
That Facility Study, however, significantly changed the engineering of the interconnection facilities.
Rather than a 5.5 mile tap line that would allow the substation to be located onsite, it required
(without any explanation for the change) that the project's point of interconnection be within 1,500
feet of the Midpoint-Wood 138 k V line. Exergy was confused by the inconsistency in these two
studies and was unable to ensure it could accommodate the new location of the substation and the
collector lines in time to commit to the substantial upgrade expenditure. Idaho Power bumped
Exergy's Project No. 158 out ofthe interconnection queue.
Exergy then resubmitted interconnection requests for the Notch Butte Wind Park under Project No.
349 (6.5 MW) and No. 359 (11.5 MW). The engineering of the interconnection changed yet again,
and the final cost projection in the Feasibility Study for these cumulative requests was over three
times as high as initially projected --$14.22 million. This final recQn:figuration requires upgrades for
the route of the output from Notch Butte through both the Dietrich and the Shoshone substations
before reaching the 138 k V Midpoint-Wood line.
Exergy h~ a duty under contract to bring its Notch Butte project online in a manner as timely as
possible. Because we are unable to reconcile the conflicting interconnection studies for the project,
we wouid appreciate an opportunity for a meeting to discuss the interconnection of this project, in
order to bring it online in a timely manner. Please contact us at your earliest convenience to set up a
meeting, and please copy Mr. James Carkulis with any correspondence to my office.
Peter J. Richardson
Attorney for Exergy Development Group ofIdaho, LLC
cc: Donovan Walker, Attorney for Idaho Power (U.S. Mail and Electronic Mail)
James Carkulis, Exergy Development Group ofIdaho, LLC
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 32
DRAFT
Generator Interconnection
Facility Study Report
for the
Notch Butte -Project #349
for
Exergy Development Group of Idaho
in
Boise,ID
February 17, 2011
~IDAHO
POWER®
An IDACORP Company
DRAFT -FACILITY STUDY REPORT (FSR)
Notch Butte Wind Park
Project #349
February 17,2011
1. General Facility Description
The proposed generation project consist of 6.5 MW of power provided by three 2.05 MW Repower
win~ turbines .. The Interconnection Cqstomer (~C) will provi~irllw,J.generation a~d st.ation equi~ment
reqUIred to delIver ~ower at 12.5 kV to the Pamt of ~ter~~~~'etlDll (POI) whl,ch IS located 111 the
SW corner of Section 22, T6S., R19E. The IC wlll 'i~r~ll:'lae a telephone hne to the POI for
communication. A dedicated 12.5 kV feeder will ll.hltlftrW~lll e POI four miles west to the IPeo
Dietrich substation where the station will be expan~edl'l~cCOl "I:: date the new feeder bay and 12,5
kV to 46 kV power circuit transformer. Four '~i~s of 46 k li~mwmission line out of Dietrich
substation will be reconductored to resolve Vq~'fllW~~lissues brought o~l~mi!the interconnection with the
W· d P k It IIIH)1" 11[11[111 m ar. Iflli'. ,1[ijlll!!!. '~lil!II', 1:"'; 1:~I!l':lk
Interconnection Customer: , ' I • ·[I;/i\' I· 1!!'!llllt!!J!> 11!~,\i!ill::. 111'11~_I~1 Mr. Collin Rualllll.!.'-!II1'" "h • I IUllW"-lfIi\:II'l' " Exerg, I De\{#~ffiBment Group'i~~r~aho
80 ,11 ii', I' BM.1I~0k Suite ubW.\'III!I' , I I, "!!JlUII~i! I • i 11,
I ':bise ill I, , W,(i)2 '. :j.IIII' ':'lli'III!In::, I, 'I Ill:, ' ,lh'~lIlll""" ,I 11:;11; !'I'i'i\lllr!: ; 'i~lllillj'I"1 ~811!,(36f?I'li7l1Ii,(i:!H!rli\!iH!iI: J '1]1'
, IIil111 1 lll~ 1111!llliHI.1 "llhll,I!II' , A Standard Generat8!J.iJI iTlterconne0 'tiln Agrednm ,~(s) under Idaho Power Company's Open Access
•• • I [ilUl: III iT 'I lilli', , TransmIssIon T~nff (a~~!~~ ,~r ,S : ;~~~le 72 [j11~een Interconnect~on Customer .and Idaho Power
Company 1 ,:r.l{~l~~e~-v (Tran'&l~~ ~~1!lt !,@ll#r1iiI~r) for ISl!~'Noteh Butte Wmd Park, specifically Generator "llttl%;iflii!!: illi~1'".,·'l' ifd~'!TIlli ,-.' IJI[lIQfl'!' . U!,ffhlH . . IntercoW~'F~I'i01i lip. '<:>J~~h{~ 349;'i"fIJl ,need to(i}~I~fepar.~.(i for thIS project.
'f!:'h,n,jl1-II:lfllH!li,' i~111'III' , '!'!ll!li,'1' .!!I!'Pj' ':IIII~j'l 1" illl" "1,1 I<l,!( ;ti't. \lU lil;I~, :1 II!II ..
1.1 ' -ill ~t~rcon.necti?~ji~oint Ill,H:I'!!!, ,., . T~e Intei'~~~j~ctiem P01l1t'~~ -.lithe No :~~IB~tte Wmd Park Project wIll be the g~nerato.r SIde of ~he
dIsconnect SV\[~~~I? labeled ~~~~01mec~ S":lt~h ~ as shown on the attached smgle hne drawmg
21D-64299. T~~i,I';rntercoIl11~~~on Pomt 1S m Lmcoln County, ID -T6S, R19E, SW comer of
S t' 22 -oJ ,:If;, ,lImpL ec IOn. .l~~ir~!., 1"m.11I' "'Jj'j.':;,J::';,
q. :tH!JII:' Ii;;:' '
1.2 Point of Change of Ownership
The Point of Change of Ownership for the Notch Butte Wind Park Project is electrically the
same as the Interconnection Point.
1.3 Customer's Interconnection Facilities
The IntercOlmection Customer will install all generation and station equipment required to
deliver power at 12.5 kV to the intercOlmection point. The Intercolmection Customer will own
and maintain facilities electrically located on the Interconnection Customer side of the Point of
Change of Ownership, Idaho Power will own and maintain the facilities electrically located on
the IPCo side of the Point of Change of Ownership.
1
1.4 Other Facilities Provided by Interconnection Customer
1.4.1 Telecommunications
1.4.2
The Interconnection Customer will provide two cOlmnunication circuits between the
generation interconnection site and a location, or locations, specified by Idaho Power.
One of the circuits will be a dedicated 4-wire leased analog circuit connected to the
SEL 311 C relay and the other will be a POTS dial-up circuit to the revenue meter.
The Interconnection Customer will also provide a communication circuit for SCADA
to a location in Dietrich substation specified by Idaho Power. This circuit will be
either (a) a dedicated 4~wire leased analog circuit or (b) a DDS frame relay circuit.
Customer is responsible for supplying and
lines and paying the monthly service
to be installed and operational prior to
the installation of the phone
communication circuits will need
atn'lgll1!u,to the Idaho Power system.
that will limit
1.4.3 Easements
CO a surveyed (Metes & Bounds)
's facilities at the hlterconnection
to IPeO for review, IPCO will
easement for signature by
been secured, the Interconnection
for recording.
r::t1fnrjlm'il.f,rI"iI"f.IIIII' '''''~;'''rm;'c.mj~r'ijll'li~r< RleMcfisf)atch 11 or {JGOL C'?
Irm'J,"!II'~'lJUI net output of 6.S MW at the Interconnection
Idaho Power Company Grid Operations during
gencies. When outages occur, the Project will be subject
Control ("GOLe';) arid have equipment capable of
Power for GOLC. Generator Output Limit Control will
·~;Ii'~"'b~~~ ttonX"u.;i:l~lho Power to the Project indicating maximum output allowed
contingencies ,
1.5 Idaho Power Company'S Interconnection Facilities
Idaho Power will install a standard 4 pole distribution interconnect package in the SW cotner
of Section 22, T6S, R19E. This package consists of a recloser, two disconnect switches,
metering, operating relays, and local service.
Idaho Power will build a 12.5 kV distribution feeder (DTRC-013) from the Interconnection
Facilities to Dietrich Substation 4 miles west.
Idaho Power will enlarge the Diehich substation to accommodate a new feeder bay with its
own 12.5 kV to 46 kV transfonner.
2
1.5.1 Communications
The Interconnection Customer is providing the communication circuits necessary for
Idaho Power system protection, revenue metering, power quality, and SCADA as
indicated above. Any additional communications requirements for Interconnection
Customer owned equipment is the responsibility of the Interconnection Customer.
1.5.2 Metering
Idaho Power will install a 12.5 kV metering tJU,\JJ>,.Ll.!=.\J at the point of interconnection.
1.6 Interconnection Facilities Cost
The following good faith estimates ate
IntercoTlnection Facilities: 1----'--
I1nterconnection Package , ---,-..... ~ .......... -.... _ ... ~-. --.... .
IPistrib'L~tio!!""Feeder to Pietrieh SubstatioI?J !2TRC-O.l_.
:Die!Ti9h I ubstati<?~ .. Additions --'II]IIIIIWI _,,_ _ .
$1~9199ql
_ $?60,OQO!
___ $941,0001
~-~-__ --. ----_.. . 11111
[See Section Uo!" :'~:!"·'.:-'~'~"'11lll[flilift!llr
\
---~-----------._ .. \ -"H'i~lIilr-----""'..,IIIIIIII-___ ..... ,_ .. ____ D_a_te_l_tbd ?!!...se~!:rJ _~_-:-!
,':\'I,'\';~\JJ'la.l can be procured and that outages to the existing transm.issio
lline are available to be y, any pennitting issues outside the immedi.ate oontrol of J
_;Id_a_hc:Yo~er could also lntJ,.'!,.!';~;!'P,iu:.::=-C~omm= . .:::.~ ercial Operatioi1})ate. ____ .. _ __ ~
*There is approximately 1.5 miles of the 46 kV transmission line which is located on BLM land. A
penuit will be required from the BLM in order to reconductor this pOliion of the line. Depending upon
the response from the BLM, the penuitting process could take from 14-24 months in itself.
3. Operating Requirements
The project is required to comply with the applicable Voltage and Current Distortion Limits found in
IEEE Standard 519-1992 IEEE Recommended Practices and requirements for harmonic Control in
Electrical Power Systems or any subsequent standards as they may be updated from time to time.
3
4.
5.
6.
The Notch Butte Wind Park Project will be allowed to deliver the net output of 6.5 MW at the
Interconnection Point subject to reductions directed by Idaho Power Grid Operations during
transmission system contingencies.
Interconnection Customer will be able to modify facilities on the Interconnection Customer side of
the Interconnection Point with no impact upon the operation of the transmission or distribution
system whenever the generation facilities are electrically isolated from the system via the Disconnect
Switch A or other approved methods by Idaho Power system operations.
Reactive Power .
The project must be controlled to operate near unity power!,' :~~or with a tolerance of +300 kVAR
and -2 MY AR. The project will be controlled to operat~'lf~ll~ \'oltage schedule provided by Idaho
Power. Voltage flicker at startup and during operation'll ;~UI I1!Jb!.~ ited to less than 5% as measured at l'II'Ii\ <I! I!i' the Point of Interconnection. III '.ii:' . I ",[!'II'
1
1l!illl!ll' j 11(!!jjllii .
Upgrades '11[111 ]:,1 11t111W'i: I,
, Itll: II!:!!!!'
5.1 Transmission Upgrades I )!I!III!II, ''''';'1,111111, l:hl!;ljii!ll'
Idaho Power will miles of 4~111~\:I,ll@fuJSmiSSion (T -1 ~~~O with 397 ACSR runningl~~ rho
SUBTOTALI . ' .. -I
GRAND TOTALi ------'---
1"llj'lll "11: II' I .• 1.
·:!lilll.II'lli
II ,rill! 11 '1' .1
I j ..
_____ i
.~ $970,000!
$75,000:
$1,045,0001
$2,976,000,
*There is approximately 1.5 miles of the 46 kV transmission line which is located on BLM land. A
permit will be required from the BLM in order to reconductor this portion of the line. The costs for this
pennitting can vary widely and have been estimated at $75K.
4
Note Regarding Transmission Service:
Transmission system improvements and associated costs outside the scope of this Generator
IntercOlmection Facility Study Report may be required for the delivery of energy from this project.
Generator intercOlmection service does not in any way convey transmission rights nor determine other
transmission system improvements to deliver your project energy to any specific customer or point of
delivery in our system.
5
Site Map
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BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 33
TRANSMISSION SERVICE REQUEST
SYSTEM IMPACT STUDY REPORT
for the
12.5 kV INTERCONNECTION of the
NOTCH BUTTE WIND (Q#349 & Q#359) PROJECTs
for connection of
18 MW OF WIND TURBINES
in
LINCOLN COUNTY, IDAHO
to
IDAHO POWER COMPANY, Transmission Provider
TRANSMISSION SYSTEM
FINAL REPORT
March 4,2011
OFFICIAL USE ONLY
DO NOT DUPLICATE, DISTRIBUTE, PUBLISH OR SHARE
This report contains Idaho Power Company Critical Energy Infrastructure Information (CEIl).
Distribution of this report must be limited to parties that have entered into a non-disclosure
agreement with Idaho Power Company and have a need to know.
1.0 Introduction
Idaho Power -Power Supply has contracted with Idaho Power Company ("IPC") to perform a
Transmission Service System Impact Study for Network Transmission Service on Idaho
Power's transmission system. The generation integration is for 18 MW of wind turbines, the
Notch Butte Wind Projects (IPC Queue #349 & Queue #359). The transmission service
request Point of Receipt (POR) is Mid-Snake and the Point of Delivery (POD) is Idaho Power
(IPCo). The transmission service request is OASIS Ref. Number 74993330.
The project is located east of Dietrich, Idaho, and the property associated with the project lies
in Lincoln County, Idaho.
This report documents the basis for and the results for the Transmission Service System
Impact Study. This report satisfies the system impact study requirements of the Idaho Power
Tariff.
2.0 Scope of Transmission Service System Impact Study
The Network Transmission Service System Impact Study was done and prepared in
accordance with Idaho Power Company's Tariff-Transmission Service, to provide an
evaluation if the existing transmission system can accommodate the requested transmission
service and, if necessary, determines the required network upgrades to the transmission
system to provide the requested transmission service. This study will only be concerned with
the capabilities of the Idaho Power system to provide transmission from the generation's
POR to the POD ofIdaho Power (IPCo).
The Network Transmission Service System Impact Study evaluated the West of Midpoint and
Boise East transfer paths' available transmission capacity (ATC) to accommodate the full
output of the 18 MW Notch Butte Wind Projects for the specified POR and POD. The Point
ofInterconnection (POI) is on Idaho Power's 12.5 kV distribution system and 46 kV sub­
transmission system which integrate into the Magic Valley 138 kV transmission system east
of the West of Midpoint transfer path.
3.0 Summary
From the analysis on the West of Midpoint and Boise East transmission paths, both
transmission paths have sufficient available transmission capacity to accommodate the 18
MW Network Transmission Service Request for the Notch Butte Wind Projects.
4.0 Description of Existing Transmission Facilities and Commitments
For the Transmission Service System Impact Study, the following two internal Idaho Power
transmission paths were evaluated to determine if they could accommodate the requested 18
MW oftransmission service, and if necessary determine the required network upgrades to
provide the transmission service.
OFFICL4L USE ONLY
This nlport contains Idaho Power Compa1!Jl Critical Energy Infrastructure Information (CEIl). Distribution of this report must
be limited to parties that have entered into a nondiscfosurr: agmment with Idaho Power Compa1!Jl and have a need to know.
The West of Midpoint transmission path is defined as the sum of the flows on the following five
lines:
• Midpoint-Boise Bench (#3) 230 kV
• Midpoint-Rattlesnake (#2) 230 kV
• King-Dram (#1) 230 kV
• Lower Malad-Mt Home Jct 138 kV
• Upper Salmon-Mt Home Jct 138 kV
The Boise East transmission path is defined as the sum of the flows on the following seven lines
and transformer:
• Boise Bench-Midpoint (#3) 230 kV
• Boise Bench-Rattlesnake (#2) 230 kV
• Dram-King (#1) 230 kV
• Hubbard-Danskin 230 kV
• Dram-Lucky Peak 138 kV
• Bowmont-Swan Falls-Strike 138 kV
• Boise Bench-Elmore 69 kV
• Hemingway 230/500 kV Transformer
From the load, resource, and existing commitment analysis performed for these two transfer
paths, both the West of Midpoint and Boise East transmission paths have sufficient available
transmission capacity to accommodate the 18 MW Network Transmission Service Request
for the Notch Butte Wind Projects.
However, the sum of the Existing Transmission Commitments (ETC's), the Transmission
Service Requests (TSR's) in the Transmission Service Queue which precedes this request and
this TSR request for an additional 18 MW has virtually fully subscribed the Total Transfer
Capacity (TIC) of the West of Midpoint transmission path. The Boise East transmission
path's TTC (which assumes the natural gas peaking plants in the Mountain Home area are
off-line) still has available transmission capacity.
OFFICIAL USE ONLY
This report contains Idaho Power Company Critical Energy Infrastructure Information (CEIl). Distriblltion of this nport must
be limited to parties that have en/end into a nondisclosun agnement with Idaho Power Company and have a need to know.
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 34
DONOVAN E. WALKER
Lead Counsel
[e-mail]
March 14, 2011
VIA E-MAIL AND U.S. MAIL
Peter J. Richardson
RICHARDSON & O'LEARY, PLLC
515 North 27th Street
P.O. Box 7218
Boise, Idaho 83702
IDAHO POWER®
An IOACORP company
Re: Your January 28, 2011, Letter Concerning Exergy Development Group of
Idaho LLC's (ICExergy") Notch Butte Wind Park Generator Interconnection
Project Nos. 158, 349, and 359.
Dear Mr. Richardson:
Thank you for your January 28, 2011, letter regarding the Notch Butte
Generation Interconnection project.
You are correct that this particular project has had an executed PURPA power
purchase agreement ("Agreement") approved by the Idaho Public Utilities Commission
("Commission") for quite some time. That Agreement was approved by the Commission
on January 10, 2006. Idaho Power Company ("Idaho Power") takes exception to your
inference that the failure of Exergy to bring its project on-line in a timely manner is
attributable to Idaho Power. It was Exergy's choice to move forward with obligating
itself to perform, pursuant the Agreement that it signed, prior to such time that it had
sufficient knowledge, information, and/or assurance regarding what would be required
for the interconnection of such project, what it is estimated to cost, and how long
interconnection facilities and potential transmission upgrades may take to construct.
Exergy has requested numerous feasibility studies with varying locations,
interconnection voltages, and project capacities for the generation interconnection
project Nos. 159, 349, and 359, all of which Exergy has referred to as their Notch Butte
project. For these various projects, the following feasibility studies have been
completed:
1221 W. Idaho St. (83702)
P.O. Box 70
Boise, ID 83707
Peter J. Richardson
March 14,2011
Page 2 of3
• January 3, 2007, Feasibility Study Report ("FeSR") for GI No. 158
located south of Shoshone, for 19.92 megawatts (UMW") at a 34.5
kilovolts ("kV") connection, estimated interconnection cost was
$2,114,000.
• October 21, 2008, FeSR for GI No. 158 near Dietrich, for 10.5 MW
at a 12.5 kV connection, estimated interconnection cost was
$3,675,000.
• January 22, 2009, FeSR for GI No. 158 near Dietrich, for 18 MW at
a 138 kV connection with a substation to transform to 34.5 kV,
estimated interconnection cost was $4,328,000.
• April 16, 2009, FeSR for GI No. 158 near Dietrich, for 9 MW at a
12.5 kV connection, estimated interconnection cost was
$3,500,000.
• October 11, 2010, FeSR for GI No. 349 near Dietrich, for 6.5 MW at
a 12.5 kV connection, estimated interconnection cost was
$3,700,000.
• January 12, 2011, FeSR for GI No. 359 near Dietrich, for 11.5 MW
at a 12.5 kV connection, estimated cost interconnection was
$14,220,000.
The varying interconnection costs found in these studies have been the result of
Exergy's requests to study various project sizes in terms of requested generation
capacity, various project locations, and various interconnection voltages.
Specifically, the January 22, 2009, report that your letter references was based
on Exergy's request to interconnect its project to Idaho Power's 138 kV system. The
Feasibility Study Report included cost estimates for a transmission fine from Idaho
Power's system to the project site and a new substation. Exergy then signed a Facility
Study Agreement to complete the more detailed Facility Study. The cover letter sent
with the Facility Study Report explained that because the new substation would be for
the sole purpose of Exergy's project, and would thus not be required to serve any other
Idaho Power customers, that Idaho Power would not build the station nor build more
than the first 1,500 feet of the transmission line from Idaho Power facilities to the project
substation. Those facilities were left to Exergy to determine its costs to install in order
to complete the project interconnection. The project lost its position in the
interconnection queue because it failed to make the required payment in order to
remain, and was removed as required of Idaho Power in its non-discriminatory
administration of the interconnection queue process.
Peter J. Richardson
March 14, 2011
Page 3 of 3
Idaho Power would be happy to meet to discuss and address your concems as
outlined in your letter and any other questions you might have regarding the Generator
Interconnection portion of this project. Please contact Rowena Bishop at (208) 388-
2658 or Marc Patterson at [phone] at your earliest convenience to coordinate a
meeting to discuss these issues and proceed with the project.
Donovan E. Walker
DEW:csb
cc: Dave Angell, Idaho Power Company (via e-mail)
Marc Patterson, Idaho Power Company (via e-mail)
Rowena Bishop, Idaho Power Company (via e-mail)
James Carkulis, Exergy Development Group (via e-mail)
Collin Rudeen, Exergy Development Group (via e-mail)
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 35
Via Electronic Mail
Rowena Bishop
Idaho Power Company
P.O. Box 70
Boise, Idaho 83707
April 12, 2011
Re: Notch Butte Wind Park Interconnection Request; Project Nos. 349 and 359
Dear Rowena:
Thank you for meeting with Exergy yesterday regarding the above-referenced small generator
interconnection projects. As we discussed, I write to provide comments and requests on the
most recent studies performed by Idaho Power for these projects. Specifically, we request that
Idaho Power perform the following actions:
Project No. 359
In response to the Draft Feasibility Study completed January 12, 2011 which studied
interconnection of 18 MW for both Nos. 349 and 359, please study the follOwing
reconfiguration we discussed. The project would connect on-site at 12.5 kV to the Dietrich
substation, continuing straight north on the existing 46 kV line, and tying in to the 138 kV
Midpoint-Wood River line. Please also reconsider the transformer costs as we discussed
yesterday for this reconfiguration.
Project No. 349
In response to the Draft Facility Study sent to us February 17,2011, please hold this project
without removing it from the queue while the additional study in conjunction with No. 359 is
performed, as described above. We will decide how to proceed with No. 349 once the
additional study on No. 359 and No. 349 together is complete.
Very truly yours,
1<------
Collin Rudeen
Exergy Development Group of Idaho, LLC
cc: Donovan Walker, Attorney for Idaho Power (U.S. Mail and Electronic Mail)
Greg Adams, Richardson and O'Leary, PLLC
~xergy Development Group 802 W Bannock. 12lh r=loor Boise.ID 83702 P 208.336.9793 r= 208.336.9431
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 36
Generator Interconnection
Facility Study Report
for the
Notch Butte -Project #349
for
Exergy Development Group of Idaho
in
.Boise,ID
May 3, 2011
An IDACORP Company
FACILITY STUDY REPORT (FSR)
Notch Butte Wind Park
Project #349
May 3,2011
1. General Facility Description
The proposed generation project consist of 6.5 MW of power provided by three 2.05 MW Repower
wind turbines. The Interconnection Customer (IC) will provide all generation and station equipment
required to deliver power at 12.5 kV to the Point of Interconnection (POI) which is located in the
SW comer of Section 22, T6S., R19E. The IC will provide a telephone line to the POI for
communication. A dedicated 12.5 kV feeder wi111U11 from the POI four miles west to the IPCo
Dietrich substation where the station will be expanded to accommodate the new feeder bay and 12.5
kV to 46 kV power circuit transformer. Four miles of 46 kV transmission line out of Dietrich
substation will be reconductored to refiolve voltage issues brought on by the interconnection with the
Wind Park.
Interconnection Customer:
Mr. Collin Rudeen
Exergy Development Group of Idaho
802 W. Bannock Suite 1200
Boise, ill 83702
208336-9793
A Standard Generator IntercOlUlection Agreement(s) under Idaho Power Company's Open Access
Transmission Tariff (OATT) or Schedule 72 between Interconnection Customer and Idaho Power
Company -Delivery (Transmission Owner) for the Notch Butte Wind Park, specifically Generator
Interconnection Project # 349, will need to be prepared for this project.
1.1 Interconnection Point
The Interconnection Point for the Notch Butte Wind Park Project will be the generator side of the
disconnect switch labeled DiscOlmect Switch A as shown on the attached single line drawing
21D-64299. The Interconnection Point is in Lincoln County, ID -T6S, RI9E, SW comer of
Section 22.
1.2 Point of Change of Ownership
The Point of Change of Ownership for the Notch Butte Wind Park Project is electrically the
same as the Interconnection Point.
1.3 Customer's Interconnection Facilities
The Interconnection Customer will install all generation and station equipment required to
deliver power at 12.5 kV to the interconnection point. The Interconnection Customer will own
and maintain facilities electrically located on the Interconnection Customer side of the Point of
Change of Ownership. Idaho Power will own and maintain the facilities electrically located on
the IPCo side of the Point of Change of Ownership.
1
"
1.4 Other Facilities Provided by Interconnection Customer
1.4.1 Telecommunications
The Interconnection Customer will provide two communication circuits between the
generation interconne~tion site and a location, or locations, specified by Idaho Power.
One POTS (Plain Old Telephone Service) dial-up circuit for revenue meteling at the
generation interconnection site.
One DDS data circuit (guaranteed minimum data rate of 19,200 bits per second) for
SCADA between the generation interconnection site and a site to be detennined by
Idaho Power.
Customer is responsible for supplying and coordinating the installation of the phone
lines and paying the monthly service charges. The communication circuits will need
to be installed and operational prior to generating into the Idaho Power system.
1.4.2 Ground Fault Equipment
The Intercoooection Customer will -iIistall transformer cOIifigurations that will limit
the contribution of ground fault current to 20 amps or less at the Interconnection
Point. Additionally, the high side of the step-up transfonners must be grounded-wye.
1.4.3 Easements
The Interconnection Customer will provide to IPCO a surveyed (Metes & Bounds)
legal description along with exhibit map for IPCO's facilities at the Interconnection
Point. After the legal de~cription has been delivered to IPeo for review, IPCO will
supply to the futetconnectioIi CUstomer a completed IPCO easement for signature by
the land owner of record. Once the signatures have been secured, the Interconnection
Customer will return the signed easement to IPCO for recording.
1.4.4 Generator Output Limit Control (liRe-dispatch" or flGOLC',
The Project will be allowed to deliver the net output of 6.5 MW at the Interconnection
Point subject to reductions directed by Idaho Power Company Grid Operations during
transmission system contingencies, When outages occur, the Project will be subject
to Generator Output Limit Control ("GOLe") and have equipment capable of
receiving signals from Idaho Power for GOLe. Generator Output Limit Control will
be a signal from Idaho Power to the Project indicating maximum output allowed
dUling transmission contingencies.
1.5 Idaho Power Company~s Interconnection Facilities
Idaho Power will install a standard 4 pole distribution interconnect package in the SW comer
of Section 22, T6S, R19E. This package consists of a rec1oser, two disconnect switches,
metering, operating relays, and local service.
Idaho Power will build a 12.5 kV distribution feeder (DTRC-013) from the Interconnection
Facilities to Dietrich Substation 4 miles west.
2
Idaho Power will enlarge the Dietrich substation to accommodate a new feeder bay with its
own 12.5 kV to 46 leV transfonner.
1.5.1 Communications
The Intercomiection Customer is providing the communication circuits necessary for
Idaho Power system protection, revenue metering, power quality, and SCADA as
indicated above. Any additional communications requirements for Interconnection
Customer owned equipment is therespollsibility of the Interconnection Customer.
1.5.2 Metering
Idaho Power will install a 12.5 kV metering package at the point of interconnection.
1.6 Interconnection Facilities Cost Estimate
The following good faith estimates are' provided in 2011 dollars:
;lI_,t_terc_of._'l1'1._e.,f,tiofl Facilit!.'!§: __ ,~ _ ...... _' ___ ~_!--_" __________ I _____ "'''~ ___ ~
'Interconnection Pack&ge $1301.000' ,---.. -----.:.~ ...
[Pistri.p_~!ion Feeder to Dietrich Su,bstation me-Ot ~t .. _ +-'.:..._. ___ . __ . ______ -i ____ . ___ .. ~60,s>00
!pietri<2!t~ub~~~~.u AddiHons_________ $941 ,000, , ... -----~
I j ,._.-._,,_._-----------_.,.,,,-_ ... _-----.--_ ... ,,-... , --... ----~
1_ _ _ . __ , __________ ... ____ ~.'___.:;.. .. $1,931,00°1
:§..~'!~~~c.Ji~!l_ 6 for ProjectGr~,!:.tJ. '{o!C!:!. _____ , ____ :
2. Milestones
I
TBD Construction Funds Received bJ!.. [peO _________ _
*24 Months after Conslluction [peO Construction Complete
!FundB Received by IPCO _____ "' ___ _
11 Month after IPCO Construction [pea Commi~sioning Complete j
~~~!l!I'lete . ~ _....... _
Commercial Operation Date [tbd by seller] i-·-hese m ilestone dates assume that material can be procured and that outages to the existing transmissio '
iline are available to be scheduled. Additionally, any permitting issues outside the immediate control of'l
;Jdah:.<? Pow~r could also influence the Commercial Operation Date. __ , _____ J
*There is approximately 1.5 miles of the 46 kV transmission line which is located on BLM land_ A
pemlit will be required from the BLM in order to reconductor this portion ofthe line. Depending upon
the response from the BLM, the pennitting process could take fi'om 14-24 months in itself
3
3. Operating Requirements
The project is required to comply with the applicable Voltage and Current Distortion Limits found in
IEEE Standard 519-1992 IEEE Recommended Practices and requirements for harmonic Control in
Electrical Power Systems or any subsequent standards as they may be updated from time to time.
The Notch Butte Wind Park Project will be allowed to deliver the net output of 6.5 MW at the
Interconnection Point subject to reductions directed by Idaho Power Grid Operations during
transmission system contingencies.
IntercOlU1ection Customer will be able to modify facilities on the Interconnection Customer side of
the Interconnection Point with no impact upon the opetation of the transmission or distribution
system whenever the generation facilities are electrically isolated from the system via the Disconnect
Switch A or other approved methods by Idaho Powet system operations.
4. Reactive Power
The project must be controlled to operate near unity power factor with a tolerance of +300 kV AR
and -2 MVAR. Voltage flicker at staltup and during operation will be limited to less than 5% as
measured at the Point of Interconnection.
5. Upgrades
5.1 Transmission Upgrades
Idaho Power will reconductor 4 miles of 46 kV transmission (T-128) with 397 ACSR
conductor starting at Dietrich substation, running north.
6. Total Estimated Costs
The following good faith estimates are provided in 2011 dollars;
lbiterconnection Facilities:
ii;~r~~·~~cti9·~· Ea-_ c-ka-g-e-----._ _ . ________ ., . -.. -r--__ ----'---'-'--
:P.istribution Feed~r to J~ietrU!.~ Substation C!?TRC-013) .... ~9 .-----=--==1-------'--'--
:Dietrich Substation Additions iIPC ; $941 .--= .. --.~ ---=-.~-'=--=--~~--.-:-. -.. ------i---~-=----i SUB TO TAD $1,931 00 "" --_ .. -----------~-' --"---'--"-.. _--.,-
! Cjp t"ades to Transmission: __ ~ ___ ._. !
~Recond..u~tor_~ miles of 46 kV_TEE-n~mission (T-12! _. __ .~~~=~
J?~M f~~i~~i~g __ . . ____ ._ _ _ _. ___ ""_ I
SUBTOTAL: ... -----I
I I ___ .~I=-= -$~~76,OOOj -GRAND TOTAL
4
*There is approximately 1.5 miles of the 46 kV transmission line which is located 011 BLM land. A
penuit will be required from the BLM in order to reconductor this pOltion of the line. The costs for this
penuitting can vary widely and have been estimated at $75K.
Note Regarding Transmission Service:
Transmission system improvements and associated costs outside the scope of this Generator
Interconnection Facility Study Report may be required for the delivery of energy from this project.
Generator interconnection service does not in any way convey transmission rights nor detennine other
transmission system improvements to deliver your project energy to any specific customer or point of
delivery in our system.
5
Site Map
Project #349 Notch Butte
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BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 37
Collin Rudeen
Exergy Development Group ofIdaho
802 W Bannock, Suite 1200
Boise, ID 83702
RE: Notch Butte GI Project 359
Dear Collin:
May 11,2011
Via email & Certified Mail #
70093410000236312506
All lOI\CORP campa" '
This letter is a follow up to my April 27, 2011 email and your request for a restudy for Notch
Butte. Attached are two copies of the Feasibility Study Agreement for this restudy that need to be
signed and returned for execution.
In order to proceed, and for your application to remain in the Generator Interconnection study
queue, Idaho Power must receive the signed FeSA and the deposit by June 2, 2011, otherwise
your application will be deemed withdrawn. The deposit under this FeSA is $1,000.
The submittal should be sent to: Idaho Power Company, Attention: Rowena Bishop, 1221 West
Idaho Street, Boise, ID 83702. Please contact me if you have questions.
Sincerely,
Marc Patterson
Engineering Leader, T &D Planning
Ph. 208.388.2712
Enc1: two Feasibility Study Agreements-to be signed and returned for execution
c: Rowena Bishop/IPC
1211 W, IdJl10 5( (H371l2)
p,o, Om 711
Boise, 10 an07
Small Generator Feasibility Study Agreement
Notch Butte RESTUDY GI Project #359
Feasibility Study Agreement
THIS AGREEMENT is made and entered into this __ day of 2011, by and
between a
organized and existing under the laws of the State of
("Interconnection Customer,") and Idaho Power Company a Corporation existing under the laws
of the State of Idaho ("Transmission Provider"). Interconnection Customer and Trar:smission
Provider each may be referred to as a "Party," or collectively as the "Parties."
RECITALS
WHEREAS, Interconnection Customer is proposing to develop a Small Generating Facility or
generating capacity addition to an existing Small Generating Facility consistent with the
Interconnection Request completed by Interconnection Customer on November 8, 2010; also
known as Project #359; and
WHEREAS, Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Provider's Transmission System; and
WHEREAS, Interconnection Customer has requested the Transmission Provider to perform a
feasibility study to assess the feasibility of interconnecting the proposed Small Generating
Facility with the Transmission Provider's Transmission System, and of any Affected Systems;
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the terms specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause to be
performed an interconnection feasibility study consistent the standard Small Generator
Interconnection Procedures in accordance with the Open Access Transmission Tariff.
3.0 The scope of the feasibility study shall be subject to the assumptions set forth III
Attachment A to this Agreement.
4.0 The feasibility study shall be based on the technical information provided by the
Interconnection Customer in the Interconnection Request, as may be modified as the
result of the scoping meeting. The Transmission Provider reserves the right to request
additional technical information from the Interconnection Customer as may reasonably
become necessary consistent with Good Utility Practice during the course of the
feasibility study and as designated in accordance with the standard Small Generator
Small Generator Feasibility Study Agreement
Notch Butte RESTUDY GI Project #359
Interconnection Procedures. If the Interconnection Customer modifies its Interconnection
Request, the time to complete the feasibility study may be extended by agreement of the
Parties.
5.0 In performing the study, the Transmission Provider shall rely, to the extent reasonably
practicable, on existing studies of recent vintage. The Interconnection Customer shall not
be charged for such existing studies; however, the Interconnection Customer shall be
responsible for charges associated with any new study or modifications to existing studies
that are reasonably necessary to perform the feasibility study.
6.0 The feasibility study report shall provide the following analyses for the purpose of
identifying any potential adverse system impacts that would result from the
interconnection of the Small Generating Facility as proposed:
6.1 Initial identification of any circuit breaker short circuit capability limits exceeded
as a result of the interconnection;
62 Initial identification of any thermal overload or voltage limit violations resulting
from the interconnection;
6.3 Initial review of grounding requirements and electric system protection; and
6.4 Description and non-bonding estimated cost of facilities required to interconnect
the proposed Small Generating Facility and to address the identified short circuit
and power flow issues.
7.0 The feasibility study shall model the impact of the Small Generating Facility regardless
of purpose in order to avoid the further expense and interruption of operation for
reexamination of feasibility and impacts if the Interconnection Customer later changes
the purpose for which the Small Generating Facility is being installed.
8.0 The study shall include the feasibility of any interconnection at a proposed project site
where there could be multiple potential Points of Interconnection, as requested by the
Interconnection Customer and at the Interconnection Customer's cost.
9.0 A $1,000.00 deposit will be required from the Interconnection Customer upon execution
of this Feasibility Study Agreement by the Interconnection Customer.
Transmission Provider shall charge and Interconnection Customer shall pay the actual
costs of the Interconnection Feasibility Study. Any difference between the deposit and
the actual cost of the study shall be paid by or refunded to Interconnection Customer, as
appropriate.
Small Generator Feasibility Study Agreement
Notch Butte RESTUDY GI Project #359
10.0 Once the feasibility study is completed, a feasibility study report shall be prepared and
transmitted to the Interconnection Customer. Barring unusual circumstances, the
feasibility study must be completed and the feasibility study report transmitted within 30
business days of the Interconnection Customer's agreement to conduct a feasibility study.
11.0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
12.0 The Interconnection Customer must pay any study costs that exceed the deposit without
interest within 30 calendar days on receipt of the invoice or resolution of any dispute. If
the deposit exceeds the invoiced fees, the Transmission Provider shall refund such excess
within 30 calendar days of the invoice without interest.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written.
Transmission Provider: Interconnection Customer:
Idaho Power Company
Signed: ___________ _ Signed: ________________________ _
Printed: Printed: ---------------------------------------
Title: Title: -------------------------------------------------
Date: Date: ------------------------
Small Generator Feasibility Study Agreement
Notch Butte RESTUDY GI Project #359
Attachment A to Feasibility Study Agreement
Assumptions Used in Conducting the Feasibility Study
The feasibility study will be based upon the information set forth in the Interconnection Request
and agreed upon in the technical review meeting held on April 11, 2011:
1) Designation of Point of Interconnection and configuration to be studied.
12.5 kV interconnection of 11.5 MW to Idaho Power Company's Dietrich Substation; continuing
north on existing 46kV and tying into the 138kV MidpointIWood River line.
Please consider transformer costs for this reconfiguration. The specific interconnection will be
on a 12.5kV feeder at N42° 53.13'; W114° 10.57' in Lincoln County, Idaho.
Page 1 of 1
".,
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 38
Small Generator Feasibility Study Agreement
Notch Butte RESTUDY GI Project #359
Feasibility Study Agreement
THIS AGREEMENT!s made and entered into this ~ay of (f/o1 2011, by and
betweenEKmUY PEY~LpfHtEfJT GeoVP of (PlfI9.' a L1Mftef> U I4BrUTY co~f,4t-JY'
organized and existing under the laws of the State of (DArb ,
("Interconnection Customer, ") and Idaho Power Company a Corporation existing under the laws
of the State; of Idaho ("Transmission Provider"). Interconnection Customer and Transmission
Provider each may be referred to as a "Party," or QoUectlvdyas the "Parties~"
RECITALS
WHEREAS~ Interconnection Customer is proposing to develop a Small Generating Facility or
generating capacity additioh to an existing Small Generating Facility consistent with the
InterCOnilection RequeSt completed by irtterconhection Customer on November 8, 2010; 'also
known as Project #359; and
WHEREAS, Interconnection Customer desires to interconnect the Small Generating 'Facility
with the Ttansmissi<Jl1 ptovidds Transmission System; and
WHEREAS, Interconnection Customer has requested the Transmission Provider to perform a
feasibility study to assess the feasibility of interconnecting the proposed Small Gene.r:ating
Facility with the Transmission Provider's Transmission Syst~m, and of any Affect~d Sy~tems;
NOW, THEREFORE, in consideration 'of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1.0 When l1sed in this Agreement, with initial capitalization, the terms specified shall have
the meanings indicated or the meanings specified in: the standard Sniall Generator
Interconnection PrOcedures.
2.0 The mtercormection Customer elects and the Tral1smission Provider shall cause to be
p¢rfotmeq an interconnection feasibility study consistent the standard Small Generator
Iiiterconpection Proced1.ltes in accordance with the Open Access Transmission Tariff.
3.0 The scope of the feasibility study shall be subject to the assumptions set forth III
Attachment A to this Agreement.
4.0 The feasibility study shall be based on the technical information provided by the
Interconnection Customer in. the Interconnection Request, as may be modified as the
result of the scoping meeting. The Transmission Provider reserves the right to request
additional technical information from the Interconnection Customer as may reasonably
become necessary consistent with Good Utility Practice during the course of the
feasibility study and as designated in accordance with the standard Small Generator
Small Generator Feasibility Study Agreement
Notch Butte RESTUDY GI Project #359
Interconnection Procedures. If the Intercolmection Customer modifies its Interconnection
Request, the time to complete the feasibility study may be extended by agreement of the
Parties.
5.0 In performing the study, the Transmission Provider shall rely, to the extent reasonably
practicable, on existing studies of recent vintage. The Interconnection Customer shall not
be charged for such existing studies; however, the Interconnection Customer shall be
responsible for charges associated with any new study or modifications to existing studies
that are reasonably necessary to perform the feasibility study.
6.0 The feasibility study report shall provide the following analyses for the purpose of
identifying any potential adverse system impacts that would result from the
interconnection of the Small Generating Facility as proposed:
6.1 Initial identification of any circuit breaker short circuit capability limits exceeded
as a result of the interconnection;
6.2 Initial identification of any thermal overload or voltage limit violations resulting
from the interconnection;
6.3 Initial review of grounding requirements and electric system protection; and
6.4 Description and non-bonding estimated cost of facilities required to interconnect
the proposed Small Generating Facility and to address the identified short circuit
and power flow issues.
7.0 The feasibility study shall model the impact of the Small Generating Facility regardless
of purpose in order to avoid the further expense and intenuption of operation for
reexamination of feasibility and impacts if the Interconnection Customer later changes
the purpose for which the Small Generating Facility is being installed.
8.0 The study shall include the feasibility of any interconnection at a proposed project site
where there could be multiple potential Points of Interconnection, as requested by the
Interconnection Customer and at the Interconnection Customer's cost.
9.0 A $1,000.00 deposit will be required from the Interconnection Customer upon execution
ofthis Feasibility Study Agreement by the Interconnection Customer.
Transmission Provider shall charge and Interconnection Customer shall pay the actual
costs of the Interconnection Feasibility Study. Any difference between the deposit and
the actual cost of the study shall be paid by or refunded to Interconnection Customer, as
appropriate.
Small Generator Feasibility Study Agreement
Notch Butte RESTUDY GI Project #359
10.0 Once the feasibility study is completed, a feasibility study report shall be prepared and
transmitted to the Interconnection Customer. Barring unusual circumstances, the
feasibility study must be completed and the feasibility study report transmitted within 30
business daysbfthe Interconnection Customer's a,greement to conduct a feasibility study.
11,0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
12.0 The. Interconnection Customer must pay any study costs that exceed the deposit without
intere.st within 30 calendar days all receipt of the iiwoite ()r resohitiou of atlY disput~. If
.the deposit exceeds the invoic.ed fees, the Transmission Provider shall refund such exceSs
within 3() calendllr -days of the invoice without interest.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year fust above written.
Trtm'slIlissiQD Provider:
Idaho Power Company
Sigued: --&t-4..!:::~~~---=--===~===-
Printed: N\ ct'rL-?c.. t h: r S D .-­
Title: ?nj Pf'!SlJ c.<-J-Lec;-df!.-V"
Date:
Interconnection Custom.er: ::y z;;e:;~~L
Printed: CoU-W ((Vf>f.£f.J
Title.: 1-£40 A<c(fEC-T EtVEi!JffiZ
Date: 3Jr/ClQl[
Small Generator Feasibility Study Agreement
Notch Butte RESTUDY G1 Project #359
Attachment A to Feasibility Study Agreement
Assumptions Used in Conducting the Feasibility Study
The feasibility study will be based upon the information set forth in the Interconnection Request
and agreed upon in the technical review meeting held on April 11, 2011 :
1) Designation of Point of Interconnection and configuration to be studied.
12.5 kV interconnection of 11.5 MW to Idaho Power Company's Dietrich Substation; continuing
north on existing 46kV and tying into the 138kV MidpointlWood River line.
Please consider transfonner costs for this reconfiguration. The specific interconnection will be
on a 12.SkV feeder at N42° 53.13'; W114° 10.57' in Lincoln County, Idaho.
Page 1 of 1
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 39
BH
GENERATOR INTERCONNECTION
FEASIBILITY Re-STUDY
For integration of the proposed
GENERATION INTERCONNECTION PROJECT #359
Notch Butte Wind
In
LINCOLN COUNTY, IDAHO
To the
IDAHO POWER COMPANY ELECTRICAL SYSTEM
for
Exergy Development Group of Idaho, LLC
FINAL REPORT
June 29, 2011
Ge~erator Interconnection Feasibility Study
General Interconnection Information
Station or
Date of Total Trans Line
Queue Request Location (MW) for POI
12.5 kV
connection
through
November Lincoln Dietrich
#359 2010 County 11.5 Substation
Short Circuit Analysis Results
System Changes Required: DYes ~No
Power Flow Analysis Results
System Changes Required: ~Yes DNo
Projected
In-Service
Date
September
2011
Type of facility
(combined cycle,
base load, CT, fuel
type)
Wind
Because project #359 and #349 (6.5 MW) are both part ofthe Notch Butte Wind project, they both connect
at the same point of interconnection (POI), and common facilities will serve both proj ects, the upgrade
costs to serve both of these projects are included in this report. The required system upgrades in this option
to serve these projects include:
• A new substation near the location where the 138 kV and 46 kV transmission lines cross. This is
approximately 4 miles north of Dietrich Substation and is known as "Dietrich Tap".
• A 138:46 kV transformer at new "Dietrich Tap" substation and associated equipment.
• Digital communication path from Midpoint Substation to the new Dietrich Tap Substation.
• Upgrade the existing Dietrich Tap-Dietrich 46 kV line (4 miles).
• A new 46: 12.5 kV transformer at Dietrich substation and associated equipment including two new
12.5 kV distribution feeder terminals.
• A new double circuit 12.5 kV distribution line from Dietrich substation to the point of
interconnection (4 miles).
• A generation interconnection and protection package for each wind project (#349 and #359).
The total generation output for the two Notch Butte Wind projects (#349 and #359) is 18 MW. To better
balance the generation output between the two new distribution feeders and limit the voltage rise on the
12.5 kV feeders, it is recommended that the total 18 MW be split more evenly between the two projects.
For example, if the 2.05 MW wind turbines are used, then there could be a 10 MW and an 8 MW project.
If the 1.5 MW GE turbines are used, then two 9 MW parks are preferred.
-J -
\.
Good Faith Cost Estimate
Interconnection cost estimate: $7,978,000.
Description
46 kV line upgrades New Substation -DTRC
Communication upgrades to MPSN-DTRC Tap 138 kV line
Substation Upgrades
New 138:46 kV Substation
12.5 kV Distribution double circuit line (4 miles)
Two Generation Interconnection Protection Packages (Each includes 12.47 kV
recloser, controls, CTs, PTs, and communications).
Total
Estimated Cost
$1,126,000
$750,000
$1,816,000
$2,546,000
$1,340,000
$400,000
$7,978,000
The proposed location for the new "Dietrich Tap" substation is located on and surrounded by BLM land.
All siting and permitting costs will be paid by the wind developer and are not included in this report. These
costs and timelines will be determined in a future Facility Study.
System Impact Study Required? DYes cgj No
This Feasibility Study only addresses the work required to interconnect Notch Butte Wind to the Idaho
Power system. The transmission rights for this project were addressed in a previous transmission service
request.
Operating Requirements:
Project #359 will be controlled to operate at unity power factor with an operating bandwidth of ± 500
kVAR (assuming a maximum 11.5 MW output).
During certain system conditions, the Notch Butte Wind generation must be curtailed (generator protection
package opened). Two separate conditions that require wind generation curtailment identified in this study
are:
• An outage at the new Burmah Tap substation on the 138:46 kV transformer any time of year.
• An outage on the 138 kV line between Midpoint and the new Dietrich Tap substation during
heavy 138 kV system loading.
-2 -
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 40
a.~H!AWllS.0Nr & 0l1'~Y; pu.c
ATTORNEYS AT LAW
Peter Richardson
Tel: [phone] I'H; 208-938-7904
pet<r@rich .. dion.ndoleary.com
r.o. Box 7218 80;, •• ID 83707 -51'; N. 27th St. 80i ••. ID 83702
June 30, 2011 -HAND DELIVERY
Donovan Walker, Lead Counsel
Idaho Power Company
1221 West Idaho St.
Boise, Idaho 83702
Re: Notch Butte Wind Project and Lava Beds Wind Project Progress
Dear Donovan:
I am writing to provide you with an update on the progress Exergy Development Group
of Idaho is making on bringing these projects on line. As you know, the original on line
date was extended for these projects to September of2010. As the agreement has a ten
month 'grace period' the default commercial on line date looks to be July 1,2011.
Assuming the project does not meet the default commercial on line date by July first, the
project is allowed to cure if it can do so in a commercially reasonable time. See
Paragraphs 5 and 22 of the power purchase agreements.
Exergy anticipates these projects will reach their commercial on line date by the end of
this year. In order to achieve that goal, it is planning on beginning construction in
approximately forty-five days. All of the normal near-term pre construction activity is
fully underway and Exergy sees no roadblocks to its successfully bringing these projects
on line pursuant to a slightly modified timeline from that contained in the Power
Purchase Agreement.
I just wanted to advise you of the progress that is being made to achieve commercial
operations within a reasonable time of the deadline contained in the power purchase
agreements. If you would like to discuss or if you disagree with the conclusion that
Exergy is, indeed making commercially reasonable efforts to achieve commercial
operations please give me a call so we can discuss in more detail.
Cc: Randy Allphin
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 41
~lC~S:fi)lN. &: ([)J~Y; PUC
ATTOltNEYS AT LAW
Peter Richardson
Tel: [phone] Fax: 208·938-7904
per. [e-mail]
P.O. Box 7218 Boise.1D 83707 -515 N. 27th St. Boise,ID 83702
August 5, 2011
Via Electronic and U.S. Mail
Donovan Walker, Lead Counsel
Randy Allphin, PURP A Contracts Administrator
Idaho Power Company
P.O. Box 70
Boise, Idaho 83707
Re: Notch Butte Wind Park and Lava Bed Wind Park Request to Extend Cure Period
Dear Donovan and Randy:
This letter may serve as acknowledgement that we have received yOW" letters dated July 26, 2011,
each of which states that it provides "Notice of Default as of the date of this letter." Section 22.2.1
of the two firm energy sales agreements ("FESAs") applicable to these projects does not limit the
projects to a rigid 60-day cure period after such Notice. Rather, the FESAs provide that the
defaulting party may cure the default within a commercially reasonable time if it is able to do so
and diligently pursues that cure.
Your letters appear to state that the projects must cure the default in achieving the commercial
online date within 60 days of the Notice of Default, which calculates to be September 24,2011,
because Idaho Power believes the projects have failed to demonstrate they are diligently attempting
to cure any potential default within a commercially reasonable time. Specifically, your letters state,
"If the default is not cured within said sixty (60) days, then Idaho Power may exercise its rights to
terminate andlor pursue its legal or equitable remedies unless the project demonstrates that it is
diligently pursuing cure of the default by the commercially reasonable time period of year end,
2011."
To be clear, my letter to you dated June 30, 2011 did not state that Exergy Development Group of
Idaho considered year-end 2011 to be the outer limit of a commercially reasonable period to cure
the online date default. Exergy does not agree with the following statement in your letters: "If the
project is not online by year end 2011, the parties agree that the commercially reasonable period to
cure this default has expired .... " My letter merely stated that Exergy expected to be able to bring
each project online by the end of the year because all of the normal near-term preconstruction
activity was underway. Exergy believes that a time frame beyond year end 2011 could be a
conunercially reasonable period within which to bring the projects online.
Mr. Walker and Mr. Allphin
August 5, 2011
Page 2
Nevertheless, Exergy still intends to energize each of these projects by year end 2011. Exergy has
brought many wind projects online in Idaho, and based on its commercial experience and
knowledge that all nonnal preconstruction activities are complete for each of these projects, it
expects that it will be able to energize these projects by year end 2011. Exergy is diligently
pursuing achievement of the year end 2011 energized date for each project.
However, completion of the interconnection construction required to fully meet the online status
deflned in the FESAs is largely in Idaho Power's hands. Based on communications with Idaho
Power's transmission! interconnection personnel, Idaho Power should be able to complete the
interconnection construction for the Lava Beds project by year end 2011, but the Notch Butte
project may not be fully interconnected until June 2012. Because interconnection construction is
largely beyond Exergy's control, Exergy will have cured any default caused by it by energizing the
projects. In short, Exergy believes it would be acting well within a commercially reasonable time
frame to have both projects energized by year end 2011. To the extent that interconnection delays
are the cause of a continued delay default, Exergy cannot accept responsibility or liability for such
delays, and such delays would not be the basis for termination of either FESA.
If Idaho Power believes that the FESAs require Exergy to provide additional items or information to
demonstrate that Exergy can meet its obligations in the time frame referenced above, could you
please explain in detail what items or infonnation Idaho Power would deem sufficient to extend the
cure period beyond September 24.2011? Otherwise, would you please confirm that Idaho Power
considers Exergy to have established that year end 2011 will be a commercially reasonable time
within which Exergy must meet the online date obligations within Exergy's control, as that term is
used in section 22.2.1 of the FESAs?
Also, if Idaho Power believes that Exergy must provide items or information demonstrating that it is
diligently pursuing the cure after expiration of the 60-day period on September 24, 2011, could you
please provide guidance on the type, extent, and timing of items and information Idaho Power
believes necessary?
Thank you for your attention to this matter. Please copy Mr. James Carkulis with any
correspondence to my office regarding this matter.
very f!i?&
Peter J. Richardson
Attorney for Exergy Development Group of Idaho, LLC
cc: James Carkulis, Exergy Development Group of Idaho, LLC
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 42
Facilities Study Agreement
THIS AGREEMENT is made and entered into this ~day of August 2011 by and
between Exergy Development Group of Idaho. LLC ,a Limited Liability Company organized
and existing lUlder the laws of the State of Idaho , ("Interconnection
Customer,") and Idaho Power Company, a Corporation existing under the laws of the State of
Idaho ("Transmission Provider"). Interconnection Customer and Transmission Provider each
may be referred to as a "Party," or collectively as the "Parties."
RECITALS
WHEREAS, the Interconnection Customer is proposing to develop a Small Generating Facility
or generating capacity addition to an existing Small Generating Facility consistent with the
Interconnection Request completed by the Interconnection Customer on November 8, 2010; and
WHEREAS, the Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Provider's Transmission System;
WHEREAS, the Transmission Provider has completed a system impact study and provided the
results of said study to the Interconnection Customer; and
WHEREAS, the Interconnection Customer has requested the Transmission Provider to perfonn
a facilities study to specify and estimate the cost of the equipment, engineering, procurement and
construction work needed to implement the conclusions of the system impact study in
accordance with Good Utility Practice to physically and electrically connect the Small
Generating Facility with the Transmission Provider's Transmission System.
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
/1:0 When used in this Agreement, with initial capitalization, the tenns specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause a
facilities study consistent with the standard Small Generator Interconnection Procedures
to be performed in accordance with the Open Access Transmission Tariff.
3.0 The scope of the facilities study shall be subject to data provided in Attachment A to this
Agreement.
4.0 The facilities study shall specify and estimate the cost of the equipment, engineering,
procurement and construction work (including overheads) needed to implement the
conclusions of the system impact study( s).
The facilities study shall also identify (1) the electrical switching configuration of the
equipment, including, without limitation, transformer, switchgear, meters, and other
station equipment, (2) the nature and estimated cost of the Transmission Provider's
Small Generator Facilities Study Agreement - 1 -Notch Butte Wind Project #359 (11 .5MW)
Interconnection Facilities and Upgrades necessary to accomplish the interconnection, and
(3) an estimate of the time required to complete the construction and installation of such
facilities.
5.0 The Transmission Provider may propose to group facilities required for more than one
Interconnecticin Customer in order to minimize facilities costs through economies of
scale, but any Interconnection Customer may require the installation of facilities required
for its own Small Generating Facility if it is willing to pay the costs ofthosefacilides.
6.0 A deposit of $30,000.00 is due upon execu.lion of this agreement by the Interconnection
customer.
7.0 Tn cases where Upgrades are required, the faCilities study must becornpleted within 45
Business Days of the receipt of this Agr.eement. In case$ where np Upgrades~e
'necessary, mid th¢ require:d facilities are limited to Interconne.ction Fapilities, the
facilitie,s stucJymust be completed within 30 Business Days.
8.0 Once the facilities study is completed, a facilities study report shall be prepared and
transmitted to the Interconnection Customer. Barring 'u11U$u.al eircu111sta,nces" tpe
facilities study inust be completec:l and the faciiities study report transmitted wit:hln 30
Business Days of the Interconnection Customeris agreement to conduct a facilities stUdy.
9.0 Any study fees shall he baSed on the Transmission Providet'S.acttial costs and will be
invoiced to ' the Intercoll11ection CustOiner after the study iscomph~t~d apd: delivered and
Will Inpludea ~Unll:nary of professional time.
10.0 The Interconnection Customer must pay any study costs that exceed the. deposit without
interest within 30 .calendar days on receipt ·of the~ invoice or resoilltion qf any disp\lte.. If
the d¢posit exceeds the invoiced fees, the Transmission Provider shall refund such excess
within 30 'calendar days of the invoice without interest.
IN WITNESS WHEREOF,the Parties have caused this Agreement to he di!:Iy executed by their
duly authorized officers or agents on the day and year first above written.
Signed: C=~~~+--+--77'<:""'---.L.
Printed Name: 6~vlt-/t..IJ /\ru y.;)/)-r(
Title: P /0 St.tf <{ I"llt.ro/'
Date: ~/'--,f,L-/----
Small Generator Facilities Study Agreement
Interconnection Customer:
Signed:£I~~
Printed Name:~IIZt8lJt-ih (;)tJ5Is1enhu.Ift7-(!.
Title: t/ f ~p;4./f~aC
Date: ~~/ ~.
-2 -Notch Butte Wind Project #359 (11.SMW)
Attachment A to
Facilities Study Agreement
Data to Be Provided by the Interconnection Customer
With the Facilities Study Agreement
1. Provide location plan and simplified one-line diagram of the plant and station facilities.
For staged projects, please indicate future generation, transmission circuits, etc.
On the one-line diagram, indicate the generation capacity attached at each metering
location. (Maximum load on CTIPT)
On the one-line diagram, indicate the location of auxiliary power. (Minimum load on
CT/PT) Amps
2. One set of metering is required for each generation connection to the new ring bus or
existing Transmission Provider station. Number of generation connections:
1
3. Will an alternate source of auxiliary power be available during CTIPT maintenance?
Yes No --,-,X,--_
4. Will a transfer bus on the generation side of the metering require that each meter set be
designed for the total plant generation? Yes No _X __
(please indicate on the one-line diagram).
5. What type of control system or PLC will be located at the Small Generating Facility?
Wind Turbine Generator SCADA Management System
6. What protocol does the control system or PLC use?
Modbus or OPC
7. Please provide a 7.5-minute quadrangle map of the site. Indicate the plant, station,
transmission line, and property lines.
8. Physical dimensions of the proposed intercoIlllection station:
There will be no substation. IPCo typical 4-pole distribution connected
interconnection / metering arrangement should be used.
Small Generator Facilities Study Agreement - 3 -Notch Butte Wind Project #359 (ll.5MW)
9. Bus length from generation to interconnection station:
Wind Turbine Generators are distributed and connected with underground cable. (see one-line)
10. Line length from interconnection station to Transmission Provider's Transmission
System.
N/A -TypicallPCo Distribution connected 4-pole POI/ metering connection should be used .
11. Tower number observed in the field. (Painted on tower leg)*:
N/A -New distribution circuit must be built from Dietrich substation.
12. Number of third party easements required for transmission lines*:
1 (country road)
* To be completed in coordination with Transmission Provider.
13. Is the Small Generating Facility located in Transmission Provider's service area?
Yes X No ___ lfNo, please provide name oflocal provider:
14. Please provide the following proposed schedule dates:
Begin Construction
Generator Step-Up Transformers
Receive Back Feed Power
Generation Testing
Commercial Operation
Date: ~/-.o/5~/--,-1 ..... 1 _______ _
Date: 12/1/11
Date: 12/15/11
Date: 12/31/11
Small Generator Facilities Study Agreement - 4 -Notch Butte Wind Project #359 (11.5MW)
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BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 43
Dustin Shively
Exergy Development Group of Idaho LLC
802 W Bannock, Suite 1200
Boise,ID 83702
August 26, 2011
Via email & Certified Mail
70090820000123019626
Subject: Notch Butte Wind Project -GJ Project # 359 (11.5MW)
Dear Dustin:
IDAHO
POUVER ..
An IDACORP company
This is to acknowledge receipt of the signed Facility Study Agreement (FSA) and your deposit for
the requested studies for the Notch Butte Wind Project. Enclosed is a copy of the FSA for your
records.
Idaho Power Company's GI process requires a Generator Interconnection Agreement (OIA) to be in
place before Commercial Operation may begin. The OIA describes the operating requirements, the
estimated cost and payment responsibility for the project to be connected, and the projected
construction timelines. I will be in touch with you to finalize the OIA when the Facility Studies are
complete.
We expect the Facility Study to be completed by November 21,2011. During the study period,
we will keep you apprised of our progress. If you have any questions in the meantime, please
contact Ed Kosydar Project Leader, directly at 208-388-2747.
Enclosure: Executed FSA (copy)
c: Ed Kosydar/IPC
Sinc.crely, W
kJAU
Rowena Bishop
Operations Analyst
Ph 208-388-2658
AUG19;~
Facilities Study Agreement
THIS AGREEMENT is made and entered into this ~day of August 2011 by and
between Exergy Development Group of Idaho, LLC ,a Limited Liability Company organized
and existing under the laws of the State of Idaho , ("Interconnection
Customer,'I) and Idaho Power Company, a Corporation existing under the laws of the State of
Idaho ("Transmission Provider"). Interconnection Customer and Transmission Provider each
may be referred to as a "Party," or collectively as the I1Parties,"
RECITALS
WHEREAS, the Interconnection Customer is proposing to develop a Small Generating Facility
or generating capacity addition to an existing Small Generating Facility consistent with the
Interconnection Request completed by the Interconnection Customer on November 8, 2010; and
WHEREAS, the Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Pro"0der's Transmission System;
WHEREAS, the Transmission Provider has completed' a system impact study and provided the
results of said study to the Interconnection Customer; and
WHEREAS, the Interconnection Customer has requested the Transmission Provider to perfonn
a facilities study to specify and estimate the cost of the equipment, engineering, procurement and
construction work needed to implement the conclusions of the system impact study in
accordance with Good Utility Practice to physically and electrically connect the Small
Generating Facility with the Transmission Provider's Transmission System.
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
i 1 :0 When used in this Agreement, with initial capitalization, the terms specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause a
facilities study consistent with the standard Small Generator Interconnection Procedures
to be performed in accordance with the Open Access Transmission Tariff.
3.0 The scope of the facilities study shall be subject to data provided in Attachment A to this
Agreement.
4.0 The facilities study shall specify and estimate the cost of the equipment, engineering,
procurement and construction work (including overheads) needed to implement the
conclusions of the system impact study( s).
The facilities study shall also identifY (1) the electrical switching configuration of the
equipment, induding, without limitation, transformer, switchgear, meters, and other
station equipment, (2) the nature and estimated cost of the Transmission Provider's
Small Generator Facilities Study Agreement - 1 -Notch Butte Wind Project #359 (ll.5MW)
Interconnection Facilities and Upgrades necessary to accomplish the interconnection, and
(3) an estimate of the time required to complete the construction and installation of such
facilities.
5.0 The Transmission Provider may propose to group facilities required for more than one
Interconnection Customer in order to minimize facilities costs through economies of
scale, but any Interconnection Customer may require the installation of facilities required
for its own Small Generating Facility if it is willing to pay the costs of those facilities.
6.0 A deposit of $30,000.00 is due upon execution of this agreement by the Interconnection
customer.
7.0 In cases where Upgrades are required, the facilities study must be completed within 45
Business Days of the receipt of this Agreement. In cases where no Upgrades are
necessary, and the required facilities are limited to Interconnection Facilities, the
facilities study must be completed within 30 Business Days.
8.0 Once the facilities study is completed, a facilities study report shall be prepared and
transmitted to the Interconnection Customer. Barring unusual circumstances, the
facilities study must be completed and the facilities study report transmitted within 30
Business Days of the Interconnection Customer's agreement to conduct a facilities study.
9.0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
10.0 The Interconnection Customer must pay any study costs that exceed the deposit without
interest within 30 calendar days on receipt of the invoice or resolution of a,ny dispute. If
the deposit exceeds the invoiced fees, the Transmission Provider shall refund such excess
within 30 calendar days of the invoice without interest.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written.
Title: PM Si-1rIP '( /l //t..!'o /" r
Date: '8"/Z & U/ r Z f
Interconnection Customer:
Signed:£~~
Printed Name:6/lz4-/J(.Lh (})65is1enhtLlt'1-t-
Title: il ~L,4:/f~o C
Date: §}/ &///
~.
Sml111 (ip.nP.TMnr F~cilities Study AQTeement -2 -Notch Butte Wind Proiect #359 (lI.5MW)
Attachment A to
Facilities Study Agreement
Data to Be Provided by the Interconnection Customer
With the Facilities Study Agreement
1. Provide location plan and simplified one-line diagram of the plant and station facilities.
For staged projects, please indicate future generation, transmission circuits, etc.
On the one-line diagram, indicate the generation capacity attached at each metering
location. (Maximum load on CTIPT)
On the one-line diagram, indicate the location of auxiliary power. (Minimwn load on
CTIPT) Amps
2. One set of metering is required for each generation connection to the new ring bus or
existing Transmission Provider station. Number of generation connections:
1
3. Will an alternate source of auxiliary power be available during CTIPT maintenance?
Yes No --,-,x,--_
4. Will a transfer bus on the generation side of the metering require that each meter set be
designed for the total plant generation? Yes ___ No _X __
(please indicate on the one-line diagram).
5. What type of control system or PLC will be located at the Small Generating Facility?
Wind Turbine Generator SCADA Management System
6. What protocol does the control system or PLC use?
Modbus or OPC
7. Please provide a 7.S-minute quadrangle map of the site. Indicate the plant., station,
transmission line, and property lines.
8. Physical dimensions of the proposed interconnection station:
There will be no substation. IPCo typical4-pole distribution connected
interconnection / metering arrangement should be used.
~mll1J ('~np.rat()l· Filcilities Study AQTeement - 3 -Notch Butte Wind Pro;ect #359 (11.5MW)
9. Bus length from generation to interconnection station:
Wind Turbine Generators are distributed and connected with underground cable. (see one-line)
10. Line length from interconnection station to Transmission Provider's Transmission
System.
N/A -TypicallPeo Distribution connected 4-pole POI/ metering connection sheuld be used.
11. Tower number observed in the field. (Painted on tower leg)*:
N/A -New distribution circuit must be built from Dietrich substation.
12. Number of third party easements required for transmission lines*:
1 (COUfltry road)
* To be completed in coordination with Transmission Provider.
13. Is the Sinall Generating Facility located in Transmission Provider's service area?
Yes X No ___ If No, please provide name oflocal provider:
14. Please provide the following proposed schedule dates:
Begin Construction
Generator Step-Up Transformers
Receive Back Feed Power
Generation Testing
Date: ~/I--ol .... l,,---~ _____ _
Date: 12/1/11
Date: 12/15/11
Commercial Operation Date: ~1~2!L::.3~1"-/1",-,1,,,---______ _
Small Generator Facilities Studv Agreement -4 -Notch Butte Wind Project #359 (l1.5MW)
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 44
RICHARDSON & O'L .. :ARY, PILC
ATTORNEYS AT LAW
Pecer Richardson
1<1: !O~-9\R·'9()1 In, 2011·'1)R.~90~
P"" {t: r@rll.:hJr(hun;lndolf:.l n', co m
1'.0 Box "21 ~ Boise. III F.FO-. ) I)" rrh Sr. BOISe. II) Rr02
September 1,2011 -HAND DELIVERY
Donovan Walker, Lead Counsel
Idaho Power Company
1221 West Idaho St.
Boise, Idaho 83702
Re: Notch Butte Wind Project and Lava Beds Wind Project Update
Dear Donovan:
I am writing to provide you with an update on the progress Exergy Development Group
of Idaho is making on bringing these projects on line. As you know, the original on line
date was extended for these projects to September of 20 1 O. As the agreement has a ten
month 'grace period' the default commercial on line date was be July 1,2011. Although
the project has not met the default commercial on line date of July first, the project is
allowed to cure if it can do so in a commercially reasonable time. See Paragraphs 5 and
22 of the power purchase agreements.
As I last reported to you, Exergy continues making progress with a goal of achieving
commercial on line date for these two projects by the end of this year. All the ground
work, soil bores and geotechnical work is completed. Turbines have been ordered and
the heavy construction work will commence as soon as the irrigation water is off and the
soil has dried and firmed after the growing season is over. The engineering, construction
and procurement contracts are in place and the projects are ready to go.
I just wanted to keep you in the loop and fully advised of the progress that is being made
to achieve commercial operations within a reasonable time of the deadline contained in
the power purchase agreements. If you would like to discuss or if you disagree with the
conclusion that Exergy is, indeed making commercially reasonable efforts to achieve
commercial operations please give me a call so we can discuss in more detail.
Sincerely yo~s;--. '// _ /:/~, ~t ·L--­
PeteVRichar son {SB # 3195
RICHARDSON & O'LEARY PL
Cc: Randy Allphin
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 45
Walker. Donovan
From:
Sent:
To:
Cc:
Subject:
Attachments:
Patterson, Marc
Friday, November 18, 2011 4:42 PM
'[e-mail]'
Bishop, Rowena; Angell, Dave; Walker, Donovan; Schultz, Trevor; Kosydar, Ed
RE: Revised Feasibility Study Report -GINT0359 Notch Butte
FeSR Customer Report #359 Nov2011 .pdf
Attached is the revised re-study Feasibility Report for project GINT #359. Formal correspondence to follow.
Marc Patterson, P, E.
Idaho Power -Engineering Leader -T&D Planning
208-388-2712 office
208-861-5309 mobile
208-388-6647 Fax
[e-mail]
1
MP
GENERATOR INTERCONNECTION
REVISED FEASIBILITY Re-STUDY
For integration of the proposed
GENERATION INTERCONNECTION PROJECT #359
Notch Butte Wind
In
LINCOLN COUNTY, IDAHO
To the
IDAHO POWER COMPANY ELECTRICAL SYSTEM
for
Exergy Development Group of Idaho, LLC
REVISED FINAL REPORT
November 18, 2011
Generator Interconnection Feasibility Study
General Interconnection Information
Station or
Date of Total Trans Line
Queue Request Location (MW) for POI
12.5 kV
connection
through
November Lincoln Dietrich
#359 2010 County 11.5 Substation
Short Circuit Analysis Results
System Changes Required: DYes I2]No
Power Flow Analysis Results
System Changes Required: I2]Yes DNo
Projected
In-Service
Date
September
2011
Type of facility
(combined cycle,
base load, CT, fuel
type)
Wind
Because project #359 and #349 (6.5 MW) are both part of the Notch Butte Wind project, they both connect
at the same point of interconnection (POI), and common facilities will serve both projects, the upgrade
costs to serve both of these projects are included in this report. The required system upgrades in this
revised option to serve these projects include:
• Upgrade the existing Dietrich Tap-Dietrich 46 kV line (4 miles) to a double circuit 138kV and
46kV line. The 138kV source will be the existing 138kV line near the Dietrich Tap.
• Digital communication path from Midpoint Substation to the Dietrich Substation.
• A new 138: 12.5 kV transformer at Dietrich substation and associated equipment including two
new 12.5 kV distribution feeder terminals.
• A new double circuit 12.5 kV distribution line from Dietrich substation to the point of
interconnection (4 miles).
• A generation interconnection and protection package for each wind project (#349 and #359).
The total generation output for the two Notch Butte Wind projects (#349 and #359) is 18 MW. To better
balance the generation output between the two new distribution feeders and limit the voltage rise on the
12.5 kV feeders, it is recommended that the total 18 MW be split more evenly between the two projects.
For example, if the 2.05 MW wind turbines are used, then there could be a 10 MW and an 8 MW project.
If the 1.5 MW GE turbines are used, then two 9 MW parks are preferred.
-1-
Good Faith Cost Estimate
Interconnection cost estimate: $6,540,000.
Description
138kV and 46 kV double circuit line DTRC tap to DTRC
Substation Upgrades
12.5 kV Distribution double circuit line (4 miles)
Two Generation Interconnection Protection Packages (Each includes 12.47 kV
recloser, controls, CTs, PTs, and communications).
Total
Estimated Cost
$2,440,000
$2,360,000
$1,340,000
$400,000
$6,540,000
The proposed double circuit 138kV and 46kV line is from the "Dietrich Tap" to the Dietrich substation. A
portion of this new line is located on BLM land. All siting and permitting costs will be paid by the wind
developer and are not included in this report. These costs and timelines will be determined in a future
Facility Study.
System Impact Study Required? DYes ~ No
This Feasibility Study only addresses the work required to interconnect Notch Butte Wind to the Idaho
Power system. The transmission rights for this project were addressed in a previous transmission service
request.
Operating Requirements:
Project #359 will be controlled to operate at unity power factor with an operating bandwidth of ± 500
kVAR (assuming a maximum 11.5 MW output).
-2-
November 23, 2011
Certified Mail # 70102780000090951304
Exergy Development Group of Idaho
Attn: Dustin Shively
802 W Bannock Suite 1200
Boise, Id 83702
RE: Project # 359 -Notch Butte Wind 11.SMW
Dear Dustin:
IIlCU«l
POUVER®
An IDACORP company
Enclosed is the REVISED Final Feasibility Study Report for the above-referenced project. The
feasibility analysis indicates that modification/addition of some facilities will be required to integrate the
network resource capacity addition of your project into the Idaho Power system. Please note, the
Feasibility Study alone does not provide any transmission rights nor determines the necessary network
upgrades to move the project energy to the load or a point of delivery in our system.
Since no SYSTEM IMP ACT STUDY is needed, enclosed is a Facility Study Agreement (FSA) for the
next phase of the project. In order to proceed, and for your application to remain in the Generator
Interconnection study queue, Idaho Power must receive the 2 copies of the signed FSA, the completed
Attachments, and the deposit by January 9, 2012 otherwise your application will be deemed withdrawn.
The deposit under this FSA is $30,000 based on the estimated engineering costs.
The submittal should be sent to: Idaho Power Company, Attention: Rowena Bishop, 1221 West Idaho
Street, Boise, ID 83702. Please contact me if you have questions.
Sincerely,
Marc Patterson
Engineering Leader, T &D Planning
208.388.2712
[e-mail]
Encl: Final REVISED Feasibility Study Report dated 11/18/11
two FSAs for signature
C (via email):
Rowena Bishop/IPC
Ed Kosydar/IPC
1221 W. Idaho St (83702)
P.O. Box 70
Boise. ID 83707
Facilities Study Agreement
THIS AGREEMENT is made and entered into this day of 2011 by and
between , a organized
and existing under the laws of the State of , ("Interconnection
Customer,") and Idaho Power Company, a Corporation existing under the laws of the State of
Idaho ("Transmission Provider"). Interconnection Customer and Transmission Provider each
may be referred to as a "Party," or collectively as the "Parties."
RECITALS
WHEREAS, the Interconnection Customer is proposing to develop a Small Generating Facility
or generating capacity addition to an existing Small Generating Facility consistent with the
Interconnection Request completed by the Interconnection Customer on 11/8/10; and
WHEREAS, the Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Provider's Transmission System;
WHEREAS, the Transmission Provider has completed a system impact study and provided the
results of said study to the Interconnection Customer; and
WHEREAS, the Interconnection Customer has requested the Transmission Provider to perform
a facilities study to specify and estimate the cost of the equipment, engineering, procurement and
construction work needed to implement the conclusions of the system impact study in
accordance with Good Utility Practice to physically and electrically connect the Small
Generating Facility wit~ the Transmission Provider's Transmission System.
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the terms specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause a
facilities study consistent with the standard Small Generator Interconnection Procedures
to be performed in accordance with the Open Access Transmission Tariff.
3.0 The scope of the facilities study shall be subject to data provided in Attachment A to this
Agreement.
4.0 The facilities study shall specify and estimate the cost of the equipment, engineering,
procurement and construction work (including overheads) needed to implement the
conclusions of the system impact study(s).
The facilities study shall also identify (1) the electrical switching configuration of the
equipment, including, without limitation, transformer, switchgear, meters, and other
station equipment, (2) the nature and estimated cost of the Transmission Provider's
Small Generator Facilities Study Agreement - I -Notch Butte Wind Project #359
Interconnection Facilities and Upgrades necessary to accomplish the interconnection, and
(3) an estimate of the time required to complete the construction and installation of such
facilities.
5.0 The Transmission Provider may propose to group facilities required for more than one
Interconnection Customer in order to minimize facilities costs through economies of
scale, but any Interconnection Customer may require the installation of facilities required
for its own Small Generating Facility if it is willing to pay the costs of those facilities.
6.0 A deposit of $ _____ _ is due upon execution of this agreement by the
Interconnection customer.
7.0 In cases where Upgrades are required, the facilities study must be completed within 45
Business Days of the receipt of this Agreement. In cases where no Upgrades are
necessary, and the required facilities are limited to Interconnection Facilities, the
facilities study must be completed within 30 Business Days.
8.0 Once the facilities study is completed, a facilities study report shall be prepared and
transmitted to the Interconnection Customer. Barring unusual circumstances, the
facilities study must be completed and the facilities s~dy report transmitted within 30
Business Days of the Interconnection Customer's agreement to conduct a facilities study.
9.0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
10.0 The Interconnection Customer must pay any study costs that exceed the deposit without
interest within 30 calendar days on receipt of the invoice or resolution of any dispute. If
the deposit exceeds the invoiced fees, the Transmission Provider shall refimd such excess
within 30 calendar days of the invoice without interest.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written.
Transmission Provider: Interconnection Customer:
Idaho Power Company -Delivery
Signed: Signed: ___________ _
Printed Name: Printed Name: ---------------------
Title: Title: ----------------------------
Date: Date: ---------------------------
Small Generator Facilities Study Agreement - 2 -Notch Butte Wind Project #359
Attachment A to
Facilities Study Agreement
Data to Be Provided by the Interconnection Customer
With the Facilities Study Agreement
1. Provide location plan and simplified one-line diagram of the plant and station facilities.
For staged projects, please indicate future generation, transmission circuits, etc.
On the one-line diagram, indicate the generation capacity attached at each metering
location. (Maximum load on CT IPT)
On the one-line diagram, indicate the location of auxiliary power. (Minimum load on
CTIPT) Amps
2. One set of metering is required for each generation connection to the new ring bus or
existing Transmission Provider station. Number of generation connections:
3. Will an alternate source of auxiliary power be available during CTIPT maintenance?
Yes No ---
4. Will a transfer bus on the generation side ofthe metering require that each meter set be
designed for the total plant generation? Yes ' No --(Please indicate on the one-line diagram).
5. What type of control system or PLC will be located at the Small Generating Facility?
6. What protocol does the control system or PLC use?
7. Please provide a 7.S-minute quadrangle map ofthe site. Indicate the plant, station,
transmission line, and property lines.
8. Physical dimensions of the proposed interconnection station:
Small Generator Facilities Study Agreement - 3 -Notch Butte Wind Project #359
9. Bus length from generation to interconnection station:
10. Line length from interconnection station to Transmission Provider's Transmission
System.
11. Tower number observed in the field. (Painted on tower leg)*:
12. Number of third party easements required for transmission lines*:
* To be completed in coordination with Transmission Provider.
13. Is the Small Generating Facility located in Transmission Provider's service area?
Yes ___ No ___ If No, please provide name oflocal provider:
14. Please provide the following proposed schedule dates:
Begin Construction Date: ____________ _
Generator Step-Up TransfolTIlers Date: ____________ _
Receive Back Feed Power
Generation Testing Date: ____________ _
Commercial Operation Date: ____________ _
Small Generator Facilities Study Agreement - 4 -Notch Butte Wind Project #359
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 46
Facilities Study Agreement
TillS AGREEMENT is made and entered into this 9th day of January 2012 by and between
EXERGY DEVELOPMENT GROUP OF IDAHO, a LLC organized and existing under the laws
of the State of IDAHO, ("Interconnection Customer,") and Idaho Power Company, a Corporation
existing under the laws of the State of Idaho ("Transmission Provider"). Interconnection
Customer and Transmission Provider each may be referred to as a "Party," or collectively as the
"Parties."
RECITALS
WHEREAS, the Interconnection Customer is proposing to develop a Small Generating Facility
or generating capacity addition to an existing Small Generating Facility consistent with the
Interconnection Request completed by the Interconnection Customer on 11/8/10; and
WHEREAS, the Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Provider's Transmission System;
WHEREAS, the Transmission Provider has completed a system impact study and provided the
results of said study to the Interconnection Customer; and
WHEREAS, the Interconnection Customer has requested the Transmission Provider to perform
a facilities study to specify and estimate the cost of the equipment, engineering, procurement and
construction work needed to implement the conclusions of the system impact study in
accordance with Good Utility Practice to physically and electrically connect the Small
Generating Facility with the Transmission Provider's Transmission System.
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the terms specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause a
facilities study consistent with the standard Small Generator Interconnection Procedures
to be performed in accordance with the Open Access Transmission Tariff.
3.0 The scope of the facilities study shall be subject to data provided in Attachment A to this
Agreement.
4.0 The facilities study shall specify and estimate the cost of the equipment, engineering,
procurement and construction work (including overheads) needed to implement the
conclusions of the system impact study(s).
The facilities study shall also identify (1) the electrical switching configuration of the
equipment, including, without limitation, transformer, switchgear, meters, and other
station equipment, (2) the nature and estimated cost of the Transmission Provider's
Small Generator Facilities Study Agreement - 1 -Notch Butte Wind Project #359
Interconnection Facilities and Upgrades necessary to accomplish the interconnection, and
(3) an estimate of the time required to complete the construction and installation of such
facilities.
5.0 The Transmission Provider may propose to group facilities required for more than one
Interconnection Customer in order to minimize facilities costs through economies of
scale, but any Interconnection Customer may require the installation of facilities required
for its own Small Generating Facility if it is willing to pay the costs ofthose facilities.
6.0 A deposit of $30,000.00 is due upon execution of this agreement by the Interconnection
customer.
7.0 In cases where Upgrades are required, the facilities study must be completed within 45
Business Days of the receipt of this Agreement. In cases where no Upgrades are
necessary, and the required facilities are limited to Interconnection Facilities, the
facilities study must he completed within 30 Business Days.
8.0 Once the facilities study is completed, a facilities study report shall be prepared and
transmitted to the Interconnection Customer. Barring unusual circumstances, the
facilities study must he completed and the facilities study report transmitted within 30
Business Days of the Interconnection Customer's agreement to conduct a facilities study.
9.0 Any study fees shall be based on the Transmission Provider's actual costs and will he
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
10.0 The Interconnection Customer must pay any study costs that exceed the deposit without
interest within 30 calendar days on receipt of the invoice or resolution of any dispute. If
the deposit exceeds the invoiced fees, the Transmission Provider shall refund such excess
within 30 calendar days of the invoice without interest.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written. '
Transmission Provider: Interconnection Customer:
Idaho 3i>'~X -,Delivery . YlYa Signed:. " /fY L ;,~
Z '"7-/,-'-
PrintedName: 6?iW11,~b' Is os'ym~
EXERGY DEVELOPMENT GROUP
Signed: Z~ Printed ~~.m (
l'i2A/I ,;/ . Title: -:..._' _/_ K,...l..,.., ( ,.,./,7c,:I~''-' =---t-~?:;;;. ,...,' ,='-fo(~d.!~"!::;f.:z7.._ .e-~l:....., __ Title: --P 1"?( r"f?~
Date: ill .3 /1 :2---~~I~~I~,~~~-------Date: , 1/ g 1.1 8-I
Small Generator Facilities Study Agreement - 2 -Notch Butte Wind Project #359
Attachment A to
Facilities Study Agreement
Data to Be Provided by the Interconnection Customer
With the Facilities Study Agreement
.1. Provide location plan and simplified one-line diagram of the plant and station facilities.
For staged projects, please indicate future generation, transmission circuits, etc. -
On the one-line diagram, indicate the generation capacity attached at each metering
location. (Maximum load on CTIPT)
18 MW rated capacity
On the one-line diagram, indicate the location of auxiliary power. (Minimwn load on
CTIPT) Amps
2. One set of metering is required for each generation connection to the new ring bus or
existing Transmission Provider station. Number of generation connections:
1
3. Will an alternate source of auxiliary power be available during CTIPT maintenance?
Yes No X
4. Will a transfer bus on the generation side of the metering require that each meter set be
designed for the total plant generation? Yes No X
(please indicate on the one-line diagram).
5. What type of control system or PLC will be located at the Small Generating Facility?
TED, Gamesa...
6. What protocol does the control system or PLC use?
TBD, G!;lmeSa
7. Please provide a 7.S-minute quadrangle map of the site. Indicate the plant, station,
transmission line, and property lines. See attachments.
8. Physical dimensions of the proposed interconnection station:
TBD
Small Generator Facilities Study Agreement -3 -Notch Butte Wind Project #359
9., Bus length from generation to interconnection station:
Varies by turbine location, approximately 2,500 -8,000 feet
10. Line length from interconnection station to Transmission Provider's Transmission
System.
4 miles frolJl POI to Dietrich Substation
11. Tower number observed in the field. (painted on tower leg)*:
12. Number ofthird party easements required for transmission lines*:
* To be completed in coordination with Transmission Provider.
13, Is the Small Generating Facility located in Transmission Provider's service area?
Yes X .No ___ If No, please provide name of local provider:
14. Please provide the following proposed schedule dates::
Begin Construction Date: December I 9 ,20 f 1
Generator Step-Up Transformers Date: August 30,2012
Receive Back Feed Power
Generation Testing Date: September 30, 2012
Commercial Operation Date: October 30, 2012
Small Generator Facilities Study Agreement - 4 -Notch Butte Wind Project #359
~DELORME
Confidential and Proprietary
Exergy Development Group
January 09, 2012
Data use subject to license.
© Delorme. XMap® 7.
www.delorme.com
Notch Butte Wind Park
~MN IU""I
XMap®7
,. Permanent Met Towers
Interconnection
e Point of Inlerconnection
• Gamesa G97 2.0 MW
Notch Butte Wind Park
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 47
Clark. Danielle
From:
Sent:
To:
Cc:
Subject:
Attachments :
Good Morning Mr. Shively,
Kosydar, Ed
Tuesday, March 06,20129:58 AM
'[e-mail]'
Bishop, Rowena; Angell, Dave; Walker, Donovan; Sloan, Aubrae; Patterson, Marc; Schultz,
Trevor; Arjona, Daniel; Stewart, Lance
Draft Facility Study Report -GINT120349 Notch Butte
GINT120349 DFSR.pdf; GINT120349 Attachments.pdf
Attached is a cover letter, the Draft Facility Study Report (DFSR) and attachments for the interconnection of 18 MW of
wind generation to the Idaho Power system through Dietrich substation. Please be mindful that part of the transmission
upgrade requirements for this project are to reconstruct a portion of the T-128 transmission line (46 kV) as well as install
transmission line switches -both of these activities are on BLM property. Obtaining a ROW grant (permit) from the
BLM is never guaranteed and our recent experience indicates that this will be a 20-30 month process. If the ROW grant
is denied by the BLM, then a new interconnection solution would be required which could drastically change both cost
and schedule.
As stated in the cover letter, in order to proceed with this project, please provide your comments to the DFSR to me
April 6, 2012 and indicate whether you wish to proceed with final design and construction.
Sincerely,
Edward Kosydar, PE
Project Leader
Idaho Power Company
[e-mail]
208-388-2747
March 6; 2012
Mr. Dlistin Shively
Exergy Development Group ofIdaho
802 W. Bannock Suite] 200
Boise, Idaho 83702
An IOACORP company
Re: Draft Facility Study Report (DFSR) for Notch Butte Wind Park -#349 &: 3'59.
Dear Mr. Shively:
Idaho Power Company (IPC) hali completed the Facility,
Interco,nnection project (#349 & #359) entitled Notch
Attached you will find the DFSR" two Interconnect
Dietrich Substation Yard Plan (21D-64340) ~d S iilg!e
Please note that the interconnection voltage is, 1
this project is 34 months from the time. that ~""i,"'.+~,'F.
required to obtain a BLM right-of-way (ROW)
work is on BLM land. 'Obtailiinga ROW grant from
.20-30 monili process .. I ani. .a.vailabie
In order to proceed with this project,
April 6, 2012 and indicate whether you
repOlt will be used to a draft
Construction. Rowena
(FSR) for ,Your Generator
Park for 18 MW of generation.
(2.1D~64299, shts 1 & 2), a
076).
'ULLl<"""U time to complete
~~",,,,,''''''~ the anticipated time
line reconstruction
now typically a
infom1ation.
'VOIPv,·,,,Lble for contacting Idaho Power's
. n funding. Please contact Aubrae Sloan
Before we can begin
credit department to
(208-388-569?).,~t,.Y0U1·
""1"'1' i:J"~"1 e:1iIUi:1Y"Ii!}I,;t i' we canpl:o"'ill~f!tt., .. ,;;W!.~.,
funding, 9r the credit requirement is met,
project.
.-.. "" I'
The 80 '
compleif
Proj ect Leader
.LLU.~·uC<JU approximately 90 days subsequent to project
n:derpayment.at that time.
Attach: Notch Butte DFSR, Dwgs'21D"64299 shU; 1 & 2, 21D-64340, 21D-17076 -'
Cc: IPC - R Bishop, A Sloan, R Bauer, D Angell, D Walker, M Patterson, T Schultz ..
Generator IntercQJl.~ec.tion
Draft Facility :§.~lItR~P9.rt
-'nil ..
Notch Butte Wind Park ..... _oject$ #349& #.359·
Exergy· Develapm~t:Groqp' (jfld,ahQ
Boise,ID
March 6, 2012
IDAHO POWER®
An IDACORP company
DRAFT FACILITY STUDY REPORT (DFSR)
Notch Butte Wind Park
Projects #349 & #359
March 6,2012
1. General Facility Description
The Notch Butte Wind Park project includes both Projects #349 and #359 for a total of 18 MWof
power provided by nine 2.0 MW Gamesa wind turbines. The Interconnection Customer (IC) will
provide all generation and station equipment required to deliver power at 12.5 kV to the Point of
Interconnection (POI) which is located at the coordinates North 420 53.12948' West 1140 10.57'.
The IC will provide one POTS line and one DDS circuit to the POI for communication. Two 12.5
kV feeders will run from the POI four miles west to the IPCo Dietri<;h substation where the station
will be expanded to accommodate the two new feeders. The power will be converted to 138 kV via
a 12.5 kV to 138 kV power circuit transformer. A new double circuit transmission line, consisting of
a new 138 kV line and the existing 46 kV line, will run four miles due north our of the Dietrich
substation. The new 138 kV line will connect to the existing Midpoint-Silver 138 kV line.
Interconnection Customer:
Mr. Dustin Shively
Exergy Development Group of Idaho
802 W. Bannock Suite 1200
Boise, ID 83702
208 336-9793
A Standard Generator Interconnection Agreement(s) under Idaho Power Company's Open Access
Transmission Tariff (OATT) or Schedule 72 between Interconnection Customer and Idaho Power
Company -Delivery (Transmission Owner) for the Notch Butte Wind Park, specifically Generator
Interconnection Project #359, will need to be prepared for this project.
1.1 Interconnection Point
The Interconnection Point for the Notch Butte Wind Park Project will be the generator side of the
disconnect switches labeled Disconnect Switches A-13 and A-14 (one for each feeder) as shown
on the attached Single Line drawings 21D-64299, sheets 1 & 2. This Interconnection Point is in
Lincoln County, ID -T6S, R19E, SW comer of Section 22.
1.2 Point of Change of Ownership
The Point of Change of Ownership for the Notch Butte Wind Park Project is electrically the
same as the Interconnection Point.
1.3 Customer's Interconnection Facilities
The Interconnection Customer will install all generation and station equipment required to
deliver power at 12.5 kV to the interconnection point. Transmitting 18 MW of power at 12.5 kV
requires two distribution feeders. The Interconnection Customer needs to balance the generation
between these two feeder connections with no more than 11 MW of power flowing on either
1
feeder. The Interconnection Customer will own and maintain facilities electrically located on the
Interconnection Customer side of the Point of Change of Ownership. Idaho Power will own and
maintain the facilities electrically located on the IPCo side of the Point of Change of Ownership.
1.4 Other Facilities Provided by Interconnection Customer
1.4.1 Telecommunications
In addition to communication circuits that may be needed by the Interconnection
Customer, the Interconnection Customer shall provide the following communication
circuits for Idaho Power's use:
1. One POTS (Plain Old Telephone Service) dial-up circuit for querying the
revenue meter at the generation interconnection site.
2. One leased DDS (Digital Data Service) circuit for SCADA between the
generation interconnection site and Twin Falls Service Building (273 Blue
Lakes Blvd. S., Twin Falls, ID 83301) This circuit must operate at 19.2 kbps
data rate or higher. Please note that Frame Relay service is not acceptable.
The Interconnection Customer is required to coordinate with a communications
provider to provide the communications circuits and pay the associated one time
setup and periodic charges. The communication circuits will need to be installed and
operational prior to generating into the Idaho Power system. Note that installation by
communications provider may take several months and should be ordered in advance
to avoid delaying the project. If the communication circuit types listed above are not
available at the site by a communications provider, the Interconnection Customer
shall confer with Idaho Power.
If high voltage protection is required by the communications provider for the
incoming communications provider cable, the high voltage protection assembly shall
be engineered and supplied by the Interconnect Customer. Options are available for
indoor or outdoor mounting. The high voltage protection assembly shall be located in
a manner that provides Idaho Power 24-hour access to the assembly for trouble­
shooting of Idaho Power owned equipment.
1.4.2 Meteorological Data
In order to integrate the wind energy into the Idaho Power system, the
IntercOlU1ection Customer will provide weather data to IPCO from the proposed
Facility Site or from a location within two miles of the Facility site consisting of the
following near real-time weather parameters that will be collected via each
meteorological observation tower at 10 m & 80 m above ground: Wind Speed (m/s),
Wind Direction, Air Temperature (degrees Cent), along with Relative Humidity, and
Barometric Pressure. This data shall be provided to IPCo hourly via commonly
accepted electronic web service standards or similar communication method.
Specific meteorological data must also be, sent over the DDS communication circuit
as identified in Appendix A. The Customer will provide relevant historical
meteorological data to IPC. Aqditionally, the Customer shall submit to Idaho Power
the physical and technical specifications for all meteorological measurement devices,
geographic locations and technical specifications of all turbines. The associated cost
for obtaining this data is the Customers responsibility and therefore not included in
the Facility Study estimate.
2
1.4.3 Ground Fault Equipment
The Interconnection customer will install transformer configurations that are
Grounded-WYE to Grounded-WYE and will limit the contribution of the ground fault
current to 20 amps or less at the Interconnection Point.
1.4.4 Easements
The Interconnection Customer will provide to IPCO a surveyed (Metes & Bounds)
legal description along with exhibit map for IPCO's facilities at the Interconnection
Point. After the legal description has been delivered to IPCO for review, IPCO will
supply to the Interconnection Customer a completed IPCO easement for signature by
the land owner of record. Once the signatures have been secured, the ffiterconnection
Customer will return the signed easement to IPCO for recording.
1.4.5 Generator Output Limit Control t'Re-dispatch" or "GOLC'?
The Interconnection Customer will install equipment to receive signals from Idaho
Power Grid Operations for Generation Output Limit Control ("GOLC") -see Section
3 Operating Requirements and Appendix A.
1.4.6 Local Service
The Interconnection Customer is responsible to arrange for local service to their site,
as necessary.
1.4.7 Monitoring Information
If the Interconnection Customer requires the ability to monitor information related to
the Idaho Power rec10sers in the generation interconnection package they are required
to supply their own communications circuit to the control box.
1.5 Idaho Power Company's Interconnection Facilities at the Site
Idaho Power will install two standard generation interconnection packages, one for each
feeder. For each package, if the Interconnection customer is going underground to the
Interconnection Point, Idaho Power will include a pole riser for the Generator to install
cables to interconnect to the Idaho Power system. If the interconnection customer is
going overhead to the Interconnection Point, it will be at a tension not to exceed the
design tension specified by Idaho Power.
The new interconnection packages each will include four distribution poles to mount a
local service transformer, solid blade disconnects, primary metering package, recloser,
relays, RTU, fuses and riser necessary for the package. The interconnection will be
controlled by a SEL-311C line protection relay and a GE iBox RTU. The relay and RTU
will be located in a pole mounted enclosure and will also contain a test switch (TS4),
SLSS, dialup modem, DDS CSU/DSU, isolation interface, power supply, DC converter,
control switch and surge protector.
Concrete barriers may be necessary to protect this equipment from local area traffic.
A 2" conduit will be installed alongside the underground primary to facilitate information
exchange to the customer about the recloser. (The Interconnection Customer is
responsible for providing and installing the appropriate cable.)
3
1.5.1 Communications
The Interconnection Customer is providing the communication circuits necessary for
Idaho Power system protection, revenue metering, power quality, and SCADA as
indicated above in the Telecommunications section. Any additional communications
requirements for Interconnection Customer owned equipment is the responsibility of
the Interconnection Customer.
1.5.2 Metering
Idaho Power will install two 12.5 kV metering packages at the point of
interconnection -one for each feeder.
1.6 Interconnection Facilities Cost Estimate
The following good faith estimates are provided in 2011 dollars:
,Inte;'connec:tilm.-Facilities:
lipt~~~o~~c_ti·~~·.~~~~~g~:(~) -. .!
_ . !W,c I ! ______ 7 , •• __ _
!S:UBTOTAL
. ·0-----1 $440,000 t ----·~-t-· --. ----, j ___ ·_··.-.00 _____ -__ ., ___ ... ____ . ________ .
IS.~~ s.e_~t£01'l_6for I:otal §s.t!mate Co~ts
2. Timeline
Idaho Power requires approximately thirty-four (34) months to complete design, procurement,
construction, permitting, and corrunissioning of the necessary interconnection facilities and required
upgrades associated with the Notch Butte Wind Park Project prior to the Commercial Operation Date.
This timeframe will be further detailed and specified in the Generator Interconnection Agreement and
assumes that material can be procured, labor resources are available, and that outages to the existing
system are available to be scheduled.
There is approximately 1.5 miles of the existing 46 kV transmission line which is located on BLM
land. A permit (ROW grant) will be required from the BLM in order to re-build this portion of the
line for the double circuit transmission as well as the 138 kV transmission line switches where the
new 138 kV line connects to the existing transmission line. Obtaining a ROW grant from the BLM is
never guaranteed and is typically a 20-30 month process at this point in time. Please recognize that this is
outside ofIdaho Power's control. If the ROW grant is denied then a new mterconnection solution would be
required and this could drastically alter project costs and timeline.
3. Operating Requirements
The project is required to comply with the applicable Voltage and Current Distortion Limits found in
IEEE Standard 519-1992 IEEE Recommended Practices and requirements for harmonic Control in
Electrical Power Systems or any subsequent standards as they may be updated from time to time.
4
Voltage flicker at startup and during operation must be limited to less than 5% as measured at the
Point of Interconnection.
Notch Butte Wind Park Project will be subject to reductions directed by Idaho Power Grid
Operations during transmission system contingencies and other reliability events. When these
conditions occur, the Project will be subject to Generator Output Limit Control ("GOLC") and will
have equipment capable of receiving an analog setpoint via DNP 3.0 from Idaho Power for GOLC.
Generator Output Limit Control will be accomplished with a setpoint and discrete output control
from Idaho Power to the Project indicating maximum output allowed. For more detail see Appendix
A.
Low Voltage Ride Through: The Project must be capable of riding through faults on adjacent
section of the power system without tripping due to low voltage. It has been determined, through
study, that the Project must be capable of remaining interconnected for any single phase voltage as
low as 0.7 PU for.30 cycles, ar;d for all three phase voltages as low as 0.8 PU for 30 cycles.
Interconnection Customer will be able to modify power plant facilities on the Interconnection
Customer side of the Interconnection Point with no impact upon the operation of the transmission or
distribution system whenever the generation facilities are electrically isolated from the system via
the air break switches A-13 and A-14 and a terminal clearance is issued by Idaho Power Company's
Grid Operator.
Please see Appendix B for details on a Limited Generation Output request made by the
Interconnect Customer.
4. Reactive Power
Notch Butte Wind Park must be controlled to operate as a V Ar neutral system with a total ± 500
kV Ar operating band.
5. Upgrades
5.1 Upgrades to Distribution Facilities
A new double circuit (DTRC-013 and 014) 12.5 kV distribution line from Dietrich substation
to the point of interconnection (4 miles). This new distribution line will be built with 795
AAC conductor on both circuits with ADSS underbuild.
5.2 Upgrades to Station Facilities
• Two new 12.5 kV feeder bays with associated switches, breakers, relays etc at Dietrich
substation
• A new 138:12.5 kV power transformer and associated equipment at Dietrich substation
with protection package, control building.
• Line relay and microwave upgrades at Midpoint substation
• DTRC-MPSN microwave reflector site (near Notch Butte)
5
5.3 Upgrades to Transmission Facilities
Idaho Power will rebuild 4 miles of the existing 46 kV transmission line (T-128) with a
double circuit transmission line that will accommodate both the existing 46 kV line as well as
the new 138 kV line. The new 138 kV line will then tap into the existing Midpoint-Silver
138 kV line with line switches on all three sides of the tap.
6. Total Estimated Costs
The following good faith estimates are provided in 2012 dollars:
:/ItlUcomU!cti(J.I1 Facilities: I ... .. __
lInteroonnclition Paekages (2) ! ---,' ........ .-.. :.:.-.. , .. reC -
!JJ.Str!buJil!it lJpg!;ililes: ._ .. _. .... .._
iDistribution Feeders to Dietrich Substation (DTRC-013
'&,~!~~~014) w!th Ap~_~iib~~
!Substation Upflrades: 1.-.. ---.. _-'-......... __ K.~ .... : ..... , ... c. '._ •..•
i1?J~t#~h: S~b~t~!!2.11.A~diti~ns
iMldpoint Relay 1.1 'ades
l~~~p~i~t Ml~rC?wa~e ~p~(ld~ . -
.DTRC;.MPSONMlCfOwave Reflector Slte . .
~tr.a1i'shUssi'Oli Upgrades: I -,. .,
!Re.nr~ve.4 ~il~' ~ij~ k;V lin~ ..y~th~~de~l>liild
'Build 4 miles of line to double circuit
13' -138 kV Line Switches I ..... ". .. . .
:*BUyf PerinittingtROW Grant . . -. . . .. -.~... . . ...... ..•. ..' , ..... -.... .
. -~ .. Q!01YD. TOTAL
,IPC I -.
i
Iwe' . --l!pC
, -,
IIPC -lw'e
rIPe' :-
jIPC
1[PC' I IIPC •
I ----~ . _.
. __ .. __ .. $"~O m~oo _
1$9~5.QOQ. _
:~Z&:~5;OOp __
,$65,000 • f ........ --.
.. i$1.90~OOO _.
:$32S 'OOO~ . ....:. ~~ -
,
-I
--~
*There is approximately 1.5 miles of the existing 46 kV transmission line which is located on BLM
land. A permit will be required from the BLM in order to rebuild this portion of the line to double
circuit as well as install the transmission line switches. The costs for this permitting can vary widely
and have been estimated at a combined $75K.
Note Regarding Transmission Service:
This Facility Study is a Network Resource Interconnection Facility Study. This study identifies the
facilities necessary to integrate the Generating Facility into Idaho Power's network to serve load within
Idaho Power's balancing area. Network Resource Interconnection Service in and of itself does not
convey any right to deliver electricity to any specific customer or Point of Delivery.
6
I
Appendix A
Generation Interconnection Control Requirements
A.1 Generator Output Limit Control (GOle)
A.1.1 IPC requires Interconnected Power Producers to accept GOLC signals from our EMS,
A.1.2 The GOLC signals will consist of two points shared between the IPC EMS and the Customer's
Generator Controller:
A.1.2.1 GOLC Setpoint: An analog output that contains the MW value the Customer should curtail
to, should a GOLC request be made via the GOLC On/Off discrete output Control point.
A.1.2.1.1 An Analog Input feedback point must be updated (to reflect the GOLC setpoint value)
by the Customer Controller upon the Controller's receipt of the GOLC setpoint change, with no
intentional delay.
A.1.2.2 GOLC On/Off: A discrete output (DO) control point with latching Off/On states. Following
a "GOLC On" control, the Customer Controller will run power output back to the MW value
specified in the GOLC Setpoint. Following a "GOLC Off' control, the Customer is free to run to
maximum possible output.
A.1.2.2.1 A Discrete Input feedback point must be updated (to reflect the GOLC DO state) by
the Customer Controller upon the Controller's receipt of the GOLC DO state change, with no
intentional delay.
A.1.3 If a GOLC control is issued, it is expected to see MW reductions start within 1 minute and plant
output to be below the GOLC Setpoint value within 10 minutes.
A.2 Voltage Control -Does not Apply to a Distribution connection.
A.3 Generation Interconnection Data Points ReqUirements
Digital Inputs to IPCQ (DNP Q~j. 01, Var. 21
Index --Descnption State {OIl} I Comments:'
0 52A Customer Capacitor Breaker {if present) . OpeillClosed Sourced at ~u.pstation
1 OfflOn '. GOLC Off/On Control Received (Feedback) Provided b~ Customer
Digital O utputs to Customer (DNP Obl . .10, Var. f)
Index Description I -=-Comments:
0 GOLC Off/On I Provided ~ IPCO
NOTE: GOLC Setpoint indicates MW value to curtail to when GOLC Off/On DO is ON.
7
Analog Inputs to IPCo JUNP Obj. 30, Var. 2)
Raw Raw EU EU EU
Index Description High Low High Low Units Comments:
GOLC Setpoint Value'Received -Provided by ,
0 (Feedback) 32767 32768 TBD TBD MW Customer
Voltage Control Setpoint Value Rec'd -Provided by
1 I (Feedback) 32767 32768 TBD TBD kV Customer
-Provided by
2 Maximum Park Generating Capacity* 32767 32768 TBD TBD MW Customer
Number of Turbines In High Speed -i Provided by
3 ' Cutout* 3276.7 32768.' 32767 -32768 Units Customer -i For Provided by
4 Ambient Temperature* 32767; 32768 327.67 -327.68 C Customer
--Provided by
5. WinJi Direction* , ' 32767 ,32768 3276.7 -3276.8 Deg ,Customer
MPH
-or Provided by
_ 6 __ Wind Speed* . 32767 .32768 327.67 -327.68 mls ' Customer
An,alog Outputs to Cu~t.!lJDer (DNP Ob.i. 40, Var._2)
I Raw Raw ED I EU EU
Index Description High Low -High Low Units ___ Comments:
~
0 GOLC Setpoint '32767 32768 TBD ' TBD MW Provided by IPCO
-
1 Voltage Control Setpoint _ 32767 32768 TBD _TBD kV PrQvideg by IPCO -NOTE: Curtailment Sewoint indicates MW value ,to Curtail. to_ when Curtailment Off/OuDQ is ON.
* -Data reqUIred from Wmd Customers
8
AppendixB
Limited Generation Output
In response to the IntercoIUlection Customer's (IC) request to corne on line by the end of the year with a
limited generation output, IPC conducted additional power flow models. It was determined that
acceptable voltage on the 46 kV system could be maintained with 4.0 MW of generation from Notch
Butte Wind Park if the generators have the ability to absorb 3.0 MV Ar. The installation of a 46 kV
potential transformer transfer/trip package-would have to be added to the scope/costs of the work at
Dietrich substation. The Ie will be responsible for absorbing the V Ars (3.0 maximum) necessary to
maintain a 1.075 p.u. maximum 46 kV bus voltage at Dietrich substation. A voltage level above 1.075
p.u. will cause the generator to be tripped offline.
IPC will need 8 months to get the resources and materials necessary to design and construct that portion
of the interconnection facilities necessary to accommodate this limited generation output.
9
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IDAHO POWER COMPANY
ATTACHMENT 48
,
Walker, Donovan
From:
Sent:
To:
Cc:
Subject:
Josh,
Kosydar, Ed
Monday, April 09,20123:18 PM
'Josh Gunderson'
Bauer, Rich; Harris, Joshua; Schultz, Trevor; Arjona, Daniel; Williams, Jason; James Carkulis;
Dustin Shively; Walker, Donovan; Cyr, Nancy; Patterson, Marc; Patteson, Morgan; Simons,
Patrick; Stewart, Darrin
RE: Notch Butte Wind Park -Appendix B
When the GIA is signed and the project is funded, I will execute this project with all haste!!
©Ed
--_._------_ .. _._------_._--..
From: Josh Gunderson [mailto:[e-mail]]
Sent: Monday, April 09, 2012 1:28 PM
To: Kosydar, Ed
Cc: Bauer, Rich; Harris, Joshua; Schultz, Trevor; Arjona, Daniel; Williams, Jason; James Carkulis; Dustin Shively; Walker,
Donovan; Cyr, Nancy; Patterson, Marc; Patteson, Morgan; Simons, Patrick; Stewart, Darrin
Subject: RE: Notch Butte Wind Park -Appendix B
Ed,
I would like to reiterate that we appreciate the work you have done to determine the available capacity and necessary
equipment to facilitate a limited output scenario at Notch Butte prior to the end of the year_ James had asked me last
week to suggest a mid-October timeframe with the idea that we would all feel better about the consequences of any
schedule slip if we were able to come up with a path to energizing earlier. I hear you loud and clear that 10/15/2012 is
not achievable and I appreciate your desire to help me understand the constraints that you face_ Would it be possible
instead to set the energization date as 12/15/2012 so that we leave ourselves just a few weeks of cushion?
Best Regards,
-Josh
)--
A ~ .", )...
exergy
Joshua Gunderson
Project Engineer
802 W Bannock, 12th Floor Boise, 10 83702
Office: 208 .336.9793 Cell: 208.230.2683
'.!/'N~y. e xe rQ.ill~'L~.Q1;:LDen t.earn
fhis electronic or priGted document oontains information which (a) may be LEGALLY PRIVILEGED PROPRIETARY IN NATURE. OR OTHERWISE PROTECTED BY LAW
FROM DISCLOSURE. and (b) is intended only for ihe use of the Addressee(s) narned aOo'le. If the reader of this message is not the intended recipient, or the employee or
agent responsible to deliver it to the :nte;:ded recipient, you are hereby notified that any dissemination, distribution or copying of thiS communicati0n is strictly prohibited. It you
ha';e received lhis communication in error. please ir.-,mediately notify uS by telephone. and return the onginai message to us at the above email address Thank you .
... _---_ ... -.-.. _---.. _------------_. -----_.-----
From: Kosydar, Ed [mailto:EKosydar@idahopower_com]
Sent: Friday, April 06, 20122:25 PM
To: Josh Gunderson
Cc: Bauer, Rich; Harris, Joshua; Schultz, Trevor; Arjona, Daniel; Williams, Jason; James Carkulis; Dustin Shively; Walker,
1
Donovan; Cyr, Nancy; Patterson, Marc; Patteson, Morgan; Simons, Patrick; Stewart, Darrin
Subject: RE: Notch Butte Wind Park -Appendix B
Good Afternoon Josh,
This is not a temporary interconnection. I am building the facilities necessary to interconnect 18 MW per your request.
In order to accommodate the limited output, we will need to add a 46 kV PT and transfer/trip controls at Dietrich
substation. 1 expect this to add about $75K to the project.
What you are asking of Idaho Power goes beyond standard industry practice in executing projects. We have a
responsibility to maintain safe, reliable power to our customers. To this end, we have hundreds of projects that must be
executed each year. Our resources are laid out to accomplish this. For you to come and push your project to the front
of the line is not right or fair. What would be right and fair would be, once funding is received, to look at resource
availability as well as project need from a customer standpoint (priority) and schedule the work accordingly. That is
standard industry practice for executing projects. We have accommodated numerous modifications to your original
request for this project. Each iteration taking more and more engineering and design resource time away from the care
and feeding projects for our system. Then came the limited generation output in order to be on-line by the end of the
request. Once again, we found a way to accommodate you. Now you want to help me find a way to make this happen
by 10/15?
We want to meet your needs. We are bending over backwards to try to get a limited output interconnection
constructed by the end of the year. To this end, ! l..vill be stealing Design and Engineering resources off of other projects
in order to make this happen. This is true whether we design in-house or contract it out. Outsourcing design work is no
easy feat and rarely saves time except on large projects. The design of this interconnection touches hundreds of our
facility drawings. The process of identifying the work that needs to be done, conveying our standard design practices
and equipment specifications, gathering up all the existing facility drawings that need to be worked on (in addition to
the new drawings that will need to be created), iterations of reviewing and approving drawings, then compiling all the
material lists so we can order them from our system (so they go into our Asset Database), etc. etc., -outsourcing the
design is time consuming and rarely helps the schedule for smaller projects like this (but we .can get more projects
done).
My expectation is that I will finalize the Facility Study Report next week. A GIA will be produced based on this FSR.
There will be a deadline for you to sign and fund the $7,950,000 ($7,875,000 + $75,000). If you sign and fund the project
before May 1st, then I will get you on line with limited generation output before December 31st, 2012. If it happens after
May 1st, no guarantees. If the deadline passes without a signature and funding, then in my mind the project is
cancelled.
Ed
From: Josh Gunderson [mailto:[e-mail]]
Sent: Friday, April 06, 2012 12:24 PM
To: Kosydar, Ed
Cc: Bauer, Rich; Harris, Joshua; Schultz, Trevor; Arjona, Daniel; Williams, Jason; James Carkulis; Dustin Shively
Subject: RE: Notch Butte Wind Park -Appendix B
Ed,
Thank you for pulling together the estimate of the available capacity on the existing distribution system for a temporary
interconnection in 2012. We have reviewed the information provided in Appendix B and would like to request that the
following additional information be added to Appendix B prior to considering the Facility Study complete:
2
1. Good faith estimate of costs associated with the additional scope that would be necessary to facilitate the 4.0
MW temporary interconnection discussed in Appendix B.
2. Additional detail regarding schedule milestones and critical path items relating to the
design/procurement/construction schedule for the temporary facilities. We believe that an expected temporary
interconnection energization date of 10/15/2012 is feasible and we are prepared to cooperate with you with
respect to design, procurement, and construction in order to address any perceived obstacles related to this
energization date.
Please contact me with any questions.
Best Regards,
-Josh
Joshua Gunderson
Project Engineer
802 W Bannock, 12th Floor Boise, ID 83702
Office: 208 336.9793 Cell: 208.230.2683
,!:!:NN.~xer!;lLge'lf'lopment.c.QDJ
Tllis electronic or primed document contains information '",hich (a) may be LEGALLY PRIVILEGED PROPRIETARY IN NATURE, OR OTHERWISE PROTECTED BY LAW
FROf;! DI;5CLOSURE, and (b) IS intended oniy for the use cf the Addressee(s) named above If the reader of this message IS not the intended recipient. or the employee or
agent responSible to deliver it to the intended recipiem you are c,ereby notified that any dissemination, distribution or copying of this communication is strictly prohibited. If you
have recei'Jer) this communication in error, please immediately notify us by telephone. and retum the onginal message to us at the above emaii address. Thank you.
----~---------------------_._-._----_._ .... ---_ .. _. _._--_ ... _-_ .. _---_.------_._--"._--------
From: Kosydar, Ed [mailto:[e-mail]]
Sent: Thursday, April OS, 20123:52 PM
To: Josh Gunderson; Dustin Shively
Cc: Bauer, Rich; Harris, Joshua; Schultz, Trevor; Arjona, Daniel; Williams, Jason
Subject: Notch Butte Wind Park -Appendix B
Good Afternoon Josh and Dustin,
I added Appendix B to the DFSR in response to your request to come on-line by the end of the year with limited output.
If you have any other comments on the DFSR, please send them over by EOB tomorrow. Looking to finalize the report
on Monday.
Thanks,
Ed
... _-
This transmission may contain information that is privileged, confidential and/or exempt from disclosure under applicable law. If you are not the intended recipient, you are hereby
notified that any disclosure, copying, distribution, or use of the information contained herein (including any reliance thereon) is STRICTLY PROHIBITED. If you received this
transmission in error, please immediately contact the sender and destroy the material in its entirety, whether in electronic or hard copy fonnat. Thank you.
3
4
Walker, Donovan
From:
Sent:
To:
Cc:
Subject:
Good Morning Dustin,
Kosydar, Ed
Thursday, March 08, 2012 11 :49 AM
'Dustin Shively'
Bishop, Rowena; Angell, Dave; Walker, Donovan; Sloan, Aubrae; Patterson, Marc; Schultz,
Trevor; Arjona, Daniel; Stewart, Lance; James Carkulis; Elizabeth Woolstenhulme; Josh
Gunderson; Bauer, Rich
RE: Draft Facility Study Report -GINT120349 Notch BuUe
Is 3:00 pm Friday going to work? Still hoping I can get the people I need to participate in this discussion.
Thanks,
ed
-. -----_. __ .----_ ...... ,----_ •. _--
From: Kosydar, Ed
Sent: Wednesday, March 07, 20124:04 PM
To: 'Dustin Shively'
Subject: RE: Draft Facility Study Report -GINT120349 Notch Butte
How is 3:00 pm?
. --_ ... -_ ... _. --"'-' ----, -.-.. -~---------------... _ ... _-------_._._--------_ .... __ .. -
From: Dustin Shively [mailto:dshively@exergydevelopment,com]
Sent: Wednesday, March 07, 2012 3:16 PM
To: Kosydar, Ed
Cc: Bishop, Rowena; Angell, Dave; Walker, Donovan; Sloan, Aubrae; Patterson, Marc; Schultz, Trevor; Arjona, Daniel;
Stewart, Lance; James Carkulis; Elizabeth Woolstenhulme; Josh Gunderson
Subject: RE: Draft Facility Study Report -GINT120349 Notch Butte
Ed:
I think it would be advantageous to discuss the situation in person, are you available for a meeting? I propose this Friday
morning at 10:00am if you are available.
Please let us know,
Thanks,
Dustin
.... A ~ .~( ~
exergy
Dustin Shively
Energy Systems Engineer
802 IN 88nnock, 12th Floor Boise. 10 83702 .
Office: 208.336 9793
This electronic or printea document c;onlains information which (al ma,! be LEGALLY PRIVILEGED, PROPRIETARY IN NATURE. OR OTHERWISE PROTECTED BY LAW
FRQ,lA DISCLOSURE and (b) is intend,~d only for the use of the Addressee(s) named above If the reader of this message is not the intended recipient. or th'l employee or
age(1( '-e;pons:b!'110 ,j"II'.!ei it to '.Ile intended leclp;enl. yOIJ ar'l Ileleby notified that an'! disseminatio(1. distribution or copying of this communication is strictly prorlibiled. If you
halle rscei led thiS COmnlUl'lc",r.;OI1 In siror, please immediately cotlf',' us by telephone, and return the original message to us at the above email address Thank you
1
--_. __ ._------.. --_._-_._----
From: Kosydar, Ed [mailto:[e-mail]]
Sent: Wednesday, March 07, 2012 1:31 PM
To: Dustin Shively
----_._----------------
Cc: Bishop, Rowena; Angell, Dave; Walker, Donovan; Sloan, Aubrae; Patterson, Marc; Schultz, Trevor; Arjona, Daniel;
Stewart, Lance; James Carkulis; Elizabeth Woolstenhulme; Josh Gunderson
Subject: RE: Draft Facility Study Report -GINT120349 Notch Butte
Dustin,
I will check with the Planning department, but this sounds like a new Feasibility Study needs to take place. Quite
honestly, I don't believe that is how the Generation Interconnect process works. How much power can we feed into
Dietrich substation via a 12.5 kV feeder such that 1} we can effectively operate our system and 2}no transmission line
upgrades are required on the existing 46 kV system? Obviously this would require a completely different design
compared to the previous versions of this project.
ed
From: Dustin Shively [mailto:[e-mail])
Sent: Wednesday, March 07, 2012 12:18 PM
To: Kosydar, Ed
Cc: Bishop, Rowena; Angell, Dave; Walker, Donovan; Sloan, Aubrae; Patterson, Marc; Schultz, Trevor; Arjona, Daniel;
Stewart, Lance; James Carkulis; Elizabeth Wooistenhulme; Josh Gunderson
Subject: RE: Draft Facility Study Report -GINT120349 Notch Butte
Ed:
We do not want to reduce the generating capacity of Notch Butte to 6 MW, nor do we want to change the configuration
for interconnection onto the 138kV line. While the permitting and construction is completed, what capacity is available
for Notch Butte to interconnect and be energized?
Thank you,
Dustin
)-
A..A.. -""( )....
exergy
Dustin Shively
Energy Systems Engineer
802 VII Bannock, 12th Floor Boise, 10 83702
Office: 208.336.9793
This electronic or printed document contains information which (9) ma~, be LEGALl Y PRIV!lEGED. PROPRIETARY IN NATURE. OR OTHERW!SE PROTECTED BY lAW
FROM DISCLOSURE. and (0) is intended only for the use of !he Addre~see(s) named abOV9. if the reader ot this message IS not the Intended recipie01\ or the employee or
agent responsible to deii'ler It to the i0tended reCIpient. you are hereby rotified that any dissemination. distribution or copying of this communrcation is smelly prohibited If IOU
have received this communication in error pleaSe i('1mediately notify us by telephone. and return the onginal message to us at the above email address. Thank ~ou
From: Kosydar, Ed [mailto:[e-mail]]
Sent: Wednesday, March 07, 2012 11:48 AM
To: Dustin Shively
Cc: Bishop, Rowena; Angell, Dave; Walker, Donovan; Sloan, Aubrae; Patterson, Marc; Schultz, Trevor; Arjona, Daniel;
Stewart, Lance; James carkulis; Elizabeth Woolstenhulme; Josh Gunderson
Subject: RE: Draft Facility Study Report -GINT120349 Notch Butte
Good Morning Dustin,
2
Last Spring Idaho Power produced both a Feasibility Study Report (FeR) and Facility Study Report (FSR) looking at
incorporating 6 MW of generation from Notch Butte Wind Park. Attached is a copy of the FSR dated May 3,2011. The 6
MW of generation would come into the Dietrich Substation via a 12.5 kV distribution line and then would be stepped up
to 46 kV. Adding this generation creates voltage issues for the 46 kV system. In order to resolve these issues, the 46 kV
transmission line out of Dietrich which crosses BLM land, would need to be reconductored. This requires a BLM permit
with the same estimated 20-30 month process -and no guaranteed result. Reducing the Notch Butte Wind Park
generation to 6.0 MW will not allow the timeline of the interconnect to be shortened.
Your latest request was to connect to the 138 kV system and that is what the Draft FSR that I sent you yesterday spoke
to. Until the 138kV system has been extended to the Dietrich Substation and the station work is completed, we won't
be able to connect the generation from Notch Butte Wind Park to our system.
Ed
From: Dustin Shively [mailto:[e-mail]]
Sent: Tuesday, March 06, 2012 4:00 PM
To: Kosydar, Ed
-------_. __ ._--_.
Cc: Bishop, Rowena; Angell, Dave; Walker, Donovan; Sloan, Aubrae; Patterson, Marc; Schultz, Trevor; Arjona, Daniel;
Stewart, Lance; James Carkulis; Elizabeth Woolstenhulme; Josh Gunderson
Subject: RE: Draft Facility Study Report -GINT120349 Notch Butte
Ed:
Thank you for the Notch Butte Facility Study. We would like to make a request based off this DFSR in preparation for the
draft GIA. Given the anticipated BLM permitting schedule of 20-30 months, we suggest that this project be allowed to
interconnect at 12.SkV and go online with limited capacity until the permitting process is complete. Given the voltage
and point of interconnection, this is estimated to be 6 MW of power. The project can accommodate an energization
date of 12/12/2012.
Please let us know what information and specifications you need from Exergy to firm up the details for a situation such
as this,
Thank you,
Dustin
Dustin Shively
Energy Systems Engineer
802 W Bannock, 12th Floor Boise, ID 83702
Office: 208.336 9793
ThiS eiectr::>nic or printed documenl ccntalnS :r,iO'f"ClBtioro '"hreh (3) may be LEGfl,LL Y PRIVILEGED, PROPRIETARi IN NATURE. OR OTHERWISE PROTECTED B'r LAW
FRCHvl DISCLOSURE and (b) is inte~ded ;)nll for the use of the Addressee(s) named above. If the reader of this message is not the intended r<!ciplenl. or the emplo,!ee or
agent responsibie to dell'/er it to the intencled reCIpient you ere hereby notif;ed that any dissemination, distribution or copying of this communlsalioll IS sirrct!y pro!libited If /Oll
hal,e r::celv:3d Ui!S communication i;l errOl' please ~r1medlatel)1 notIfy us by telepl10ne and return the onglnal message t.o us at the abolJe email addr8SS Thank you
From: Kosydar, Ed [mailto:[e-mail]]
Sent: Tuesday, March 06, 20129:58 AM
To: Dustin Shively
Cc: Bishop, Rowena; Angell, Dave; Walker, Donovan; Sloan, Aubrae; Patterson, Marc; Schultz, Trevor; Arjona, Daniel;
3
Stewart. Lance
Subject: Draft Facility Study Report -GINT120349 Notch Butte
Good Morning Mr. Shively,
Attached is a cover letter, the Draft Facility Study Report (DFSR) and attachments for the interconnection of 18 MW of
wind generation to the Idaho Power system through Dietrich substation. Please be mindful that part ofthe transmission
upgrade requirements for this project are to reconstruct a portion of the T-128 transmission line (46 kV) as well as install
transmission line switches -both of these activities are on BLM property. Obtaining a ROW grant (permit) from the
BLM is never guaranteed and our recent experience indicates that this will be a 20-30 month process. If the ROW grant
is denied by the BLM, then a new interconnection solution would be required which could drastically change both cost
and schedule.
As stated in the cover letter, in order to proceed with this project, please provide your comments to the DFSR to me
April 6, 2012 and indicate whether you wish to proceed with final design and construction.
Sincerely,
Edward Kosydar, PE
Project Leader
Idaho Power Company
[e-mail]
208-388-2747
This transmission may contain information that is privileged, confidential andlor exempt from disclosure under applicable law. If you are not the intended recipient, you are hereby
notified that any disclosure, copying, distribution, or use of the information contained herein (including any reliance thereon) is STRICTLY PROHffilTED. If you received this
transmission in error, please immediately contact the sender and destroy the material in its entirety, whether in electronic or hard copy format. Thank you.
4
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 49
Walker. Donovan
From:
Sent:
To:
Cc:
Subject:
Attachments:
Kosydar, Ed
Monday, April 09, 2012 6:15 PM
'[e-mail]'
Bishop, Rowena; Angell, Dave; Walker, Donovan; Sloan, Aubrae; Schultz, Trevor; Arjona,
Daniel; Stewart, Lance; 'Josh Gunderson'; Harris, Joshua; Williams, Jason; Bauer, Rich
Final Facility Study Report -GINT120349 Notch Butte
GINT120349 FSR.pdf; GINT120349 FSR Attachments. pdf
Good Afternoon Mr. Shively,
Attached·is a cover letter, the final Facility Study Report (FSR) and attachments (dwgs 21D-64299 shts 1&2, 21D-64340,
21D-17076) for the interconnection of the 18 MW Notch Butte Wind Park project to the Idaho Power system. You will
be working with Josh Harris ([e-mail]) to get a Generator Interconnect Agreement in place and Aubrae
Sloan ([e-mail]) regarding project funding. As soon as funding has been received, we will proceed with
final design and material acquisition.
Sincerely,
Edward Kosydar, PE
Project Leader
Idaho Power Company
[e-mail]
208-388-2747
1
April 9, 2012
e;llrwtO ~POUVER®
Mr. Dustin Shively
Exergy Development Group of Idaho
802 W. Bannock Suite 1200
Boise, Idaho 83702
Re: Final Facility Study Report (FSR) for Notch Butte Wind Park -#349 & 359.
Dear Mr. Shively:
An IDACORP Company
The estimated interconnection cost for this project is $7,875,000 requiring approximately 34
months to complete the design, procurement, permitting, construction, and commissioning of
these facilities. This includes the permitting of the transmission line across BLM land which is
typically a 20-30 month process, with no guaranteed outcome.
The response to your request to interconnect with limited generation output and a shorter
timeline is addressed in Appendix B. Idaho Power accommodated this irregular request. Please
see Appendix B for the additional work ($) and stipulations required of the futerconnection
Customer to execute this scenario. The funding necessary to execute this project, including the
work stipulated for the limited generation output, is $7,950,000. If the Generation futerconnect
Agreement (GIA) is signed and funding received by May 1, 2012, then the interconnection
facilities will be ready for up to 4.0 MW of generation by December 31, 2012.
Attached is the final Facility Study Report (FSR). This final report will be used to prepare a
draft Generator Interconnection Agreement( s) in preparation for construction. Josh Harris (208-
388-2658) will be working with you to finalize the Interconnection Agreement(s).
Before we can begin final design or order materials, you are responsible for contacting Idaho
Power's credit department to discuss credit requirements for construction funding. Please
contact Aubrae Sloan (208-388-5697) at your earliest convenience. Once we receive funding, or
the credit requirement is met, we can proceed with the project.
The actual construction and labor charges will be finalized approximately 90 days subsequent to
project completion. Since you are obligated to pay actual costs, we will reconcile any over-or
underpayment at that time.
Sincerely, ~ ~
Edward Kosydar, PE
Project Leader
Attach: Notch Butte DFSR, Dwgs 21D-64299 shts 1 & 2, 21D-64340, 21D-17076
Cc: !PC -J Harris, A Sloan, R Bauer, D Angell, J Williams, D Arjona, T Schultz
Generator Interconnection
Facility Study Report
Notch Butte Wind Park-Projects #349 & #359
for
Exergy Development Group Qf Idaho
in
Boise, ID
April 9, 2012
An IDACORP Company
FACILITY STUDY REPORT (FSR)
Notch Butte Wind Park
Projects #349 & #359
April 9, 2012
1. General Facility Description
The Notch Butte Wind Park project includes both Projects #349 and #359 for a total of 18 MW of
power provided by seven 2.5Mw Nordex Turbines. The Interconnection Customer (IC) will provide
all generation and station equipment required to deliver power at 12.5 kV to the Point of
Interconnection (POI) which is located at the coordinates North 42° 53.12948' West 1140 10.57'.
The IC will provide two POTS lines and two DDS circuits to the POls (one pair for each feeder
connection) for communication. Two 12.5 kV feeders will run from the POI four miles west to the
IPCo Dietrich substation where the station will be expanded to accommodate the two new feeders.
The power will be converted to 138 kV via a 12.5 kV to 138 kV power circuit transformer. A new
double circuit transmission line, consisting of a new 138 kV line and the existing 46 kV line, will run
four miles due north our of the Dietrich substation. The new 138 kV line will connect to the existing
Midpoint-Silver 138 kV line.
Interconnection Customer:
Mr. Dustin Shively
Exergy Development Group of Idaho
802 W. Bannock Suite 1200
Boise, ill 83702
208 336-9793
A Standard Generator Interconnection Agreement(s) under Idaho Power Company's Open Access
Transmission Tariff (OATT) or Schedule 72 between Interconnection Customer and Idaho Power
Company -Delivery (Transmission Owner) for the Notch Butte Wind Park, specifically Generator
Interconnection Projects #349 and #359, will need to be prepared for this project.
1.1 Interconnection Point
The Interconnection Point for the Notch Butte Wind Park Project will be the generator side of the
disconnect switches labeled Disconnect Switches A-13 and A-14 (one for each feeder) as shown
on the attached Single Line drawings 21D-64299, sheets 1 & 2. This Interconnection Point is in
Lincoln County, ID -T6S, R19E, SW comer of Section 22.
1.2 Point of Change of Ownership
The Point of Change of Ownership for the Notch Butte Wind Park Project is electrically the
same as the Interconnection Point.
1.3 Customer's Interconnection Facilities
The Interconnection Customer will install all generation and station equipment required to
deliver power at 12.5 kV to the interconnection point. Transmitting 18 MW of power at 12.5 kV
requires two distribution feeders. The Interconnection Customer needs to balance the generation
1
between these two feeder connections with no more than 11 MW of power flowing on either
feeder. The Interconnection Customer will own and maintain facilities electrically located on the
Interconnection Customer side of the Point of Change of Ownership. Idaho Power will own and
maintain the facilities electrically located on the IPCo side of the Point of Change of Ownership.
1.4 Other Facilities Provided by Interconnection Customer
1.4.1 Telecommunications
In addition to communication circuits that may be needed by the Interconnection
Customer, the Interconnection Customer shall provide the following communication
circuits for Idaho Power's use:
1. Two POTS (Plain Old Telephone Service) dial-up circuit for querying the
revenue meter at the generation interconnection site. One for each 4-pole
feeder connection.
2. Two leased DDS (Digital Data Service) circuit for SCADA between the
generation interconnection site and Twin Falls Service Building (273 Blue
Lakes Blvd. S., Twin Falls, ill 83301). One for each 4-pole feeder connection.
These circuits must operate at 19.2 kbps data rate. Please note that Frame
Relay service is not acceptable.
The Interconnection Customer is required to coordinate with a communications
provider to provide the communications circuits and pay the associated one time
setup and periodic charges. The communication circuits will need to be installed and
operational prior to generating into the Idaho Power system. Note that installation by
communications provider may take several months and should be ordered in advance
to avoid delaying the project. If the communication circuit types listed above are not
available at the site by a communications provider, the Interconnection Customer
shall confer with Idaho Power.
If high voltage protection is required by the communications provider for the
incoming communications provider cable, the high voltage protection assembly shall
be engineered and supplied by the Interconnect Customer. Options are available for
indoor or outdoor mounting. The high voltage protection assembly shall be located in
a manner that provides Idaho Power 24-hour access to the assembly for trouble­
shooting ofIdaho Power owned equipment.
1.4.2 Meteorological Data
In order to integrate the wind energy into the Idaho Power system, the
Interconnection Customer will provide weather data to IPCO from the proposed
Facility Site or from a location within two miles of the Facility site consisting of the
following near real-time weather parameters that will be collected via each
meteorological observation tower at 10 m & 80 m above ground: Wind Speed (mls),
Wind Direction, Air Temperature (degrees Cent), along with Relative Humidity, and
Barometric Pressure. This data shall be provided to IPCo hourly via commonly
accepted electronic web service standards or similar communication method.
Specific meteorological data must also be sent over the DDS communication circuit
as identified in Appendix A. The Customer will provide relevant historical
meteorological data to IPC. Additionally, the Customer shall submit to Idaho Power
the physical and technical specifications for all meteorological measurement devices,
geographic locations and technical specifications of all turbines. The associated cost
2
for obtaining this data is the Customers responsibility and therefore not included in
the Facility Study estimate.
1.4.3 Ground Fault Equipment
The Interconnection customer will install transformer configurations that are
Grounded-WYE to Grounded-WYE and wi11limit the contribution of the ground fault
current to 20 amps or less at the Interconnection Point.
1.4.4 Easements
The Interconnection Customer will provide to IPCO a surveyed (Metes & Bounds)
legal description along with exhibit map for IPCO's facilities at the Interconnection
Point. After the legal description has been delivered to IPCO for review, IPCO will
supply to the Interconnection Customer a completed IPCO easement for signature by
the land owner of record. Once the signatures have been secured, the Interconnection
Customer will return the signed easement to IPCO for recording.
1.4.5 Generator Output Limit Control (URe-dispatch" or' "GOLe'?
The Interconnection Customer will install equipment to receive signals from Idaho
Power Grid Operations for Generation Output Limit Control ("GOLe") -see Section
3 Operating Requirements and Appendix A.
1.4.6 Local Service
The Interconnection Customer is responsible to arrange for local service to their site,
as necessary.
1.4.7 Monitoring Information
If the Interconnection Customer requires the ability to monitor information related to
the Idaho Power reclosers in the generation interconnection package they are required
to supply their own communications circuit to the control box.
1.5 Idaho Power Company's Interconnection Facilities at the Site
Idaho Power will install two standard generation interconnection packages, one for each
feeder. For each package, if the Interconnection customer is going underground to the
Interconnection Point, Idaho Power will include a pole riser for the Generator to install
cables to interconnect to the Idaho Power system. If the interconnection customer is
going overhead to the Interconnection Point, it will be at a tension not to exceed the
design tension specified by Idaho Power.
The new interconnection packages each will include four distribution poles to mount a
local service transformer, solid blade disconnects, primary metering package, recloser,
relays, RTU, fuses and riser necessary for the package. The interconnection will be
controlled by a SEL-311 C line protection relay and a GE iBox RTD. The relay and RTU
will be located in a pole mounted enclosure and will also contain a test switch (TS4),
SLSS, dialup modem, DDS CSU/DSU, isolation interface, power supply, DC converter,
control switch and surge protector.
Concrete barriers may be necessary to protect this equipment from local area traffic.
3
A 2" conduit will be installed alongside the underground primary to facilitate information
e~change to the customer about the recloser. (The Interconnection Customer is
responsible for providing and installing the appropriate cable.)
1.5.1 Communications
The Interconnection Customer is providing the communication circuits necessary for
Idaho Power system protection, revenue metering, power quality, and SCADA as
indicated above in the Teleconununications section. Any additional communications
requirements for Interconnection Customer owned equipment is the responsibility of
the Interconnection Customer.
1.5.2 Metering
Idaho Power will install two 12.5 kV metering packages at the point of
interconnection -one for each feeder.
1.6 Interconnection Facilities Cost Estimate
The following good faith estimates are provided in 2011 dollars:
Im:e1'(~or.I1Ui~CClon Facilities:
i~~t~i~~~~!i~~R~£(;~~(ii-~ __
SU8TOTAL '$440-000 -.-~ "'-' :See. Section 6 for Total Estimate ,costs
2. Timeline
Idaho Power require!? approximately thirty-four (34) months to complete design, procurement,
construction, pennitting, and commissioning of the necessary interconnection facilities and required
upgrades associated with the Notch Butte Wind Park Project prior to the Conunercial Operation Date.
This timeframe will be further detailed and specified in the Generator Interconnection Agreement and
assumes that material can be procured, labor resources are available, and that outages to the existing
system are available to be scheduled.
There is approximately 1.5 miles of the existing 46 kV transmission line which is located on BLM
land. A permit (ROW grant) will be required from the BLM in order to re-build this portion of the
line for the double circuit transmission as well as the 138 kV transmission line switches where the
new 138 kV line connects to the existing transmission line. Obtaining a ROW grant from the BLM is
never guaranteed and is typically a 20-30 month process at this point in time. Please recognize that this is
outside of Idaho Power's control. If the ROW grant is denied then a new interconnection solution would be
required and this could drastically alter project costs and timeline.
4
3. Operating Requirements
The project is required to comply with the applicable Voltage and Current Distortion Limits found in
IEEE Standard 519-1992 IEEE Recommended Practices and requirements for harmonic Control in
Electrical Power Systems or any subsequent standards as they may be updated from time to time.
I
Voltage flicker at startup and during operation must be limited to less than 5% as measured at the
Point of Interconnection.
Notch Butte Wind Park Project will be subject to reductions directed by Idaho Power Grid
Operations during transmission system contingencies and other reliability events. When these
conditions occur, the Project will be subject to Generator Output Limit Control ("GaLe") and will
have equipment capable of receiving an analog setpoint via DNP 3.0 from Idaho Power for GOLC.
Generator Output Limit Control will be accomplished with a setpoint and discrete output control
from Idaho Power to the Project indicating maximum output allowed. For more detail see Appendix
A.
Low Voltage Ride Through: The Project must be capable of riding through faults on adjacent
section ofthe power system without tripping due to low voltage. It has been determined, through
study, that the Project must be capable of remaining interconnected for any single phase voltage as
low as 0.7 PU for 30 cycles, and for all three phase voltages as low as 0.8 PU for 30 cycles.
Interconnection Customer will be able to modify power plant facilities on the Interconnection
Customer side of the Interconnection Point with no impact upon the operation of the transmission or
distribution system whenever the generation facilities are electrically isolated from the system via
the air break switches A-13 and A-14 and a terminal clearance is issued by Idaho Power Company's
Grid Operator.
Please see Appendix B for details on a Limited Generation Output request made by the
Interconnect Customer.
4. Reactive Power
Notch Butte Wind Park must be controlled to operate as a V Ar neutral system with a total ± 500
kV Ar operating band.
5. Upgrades
5.1 Upgrades to Distribution Facilities
A new double circuit (DTRC-013 and 014) 12.5 kV distribution line from Dietrich substation
to the point of interconnection (4 miles). This new distribution line will be built with 795
MC conductor on both circuits with ADSS underbuild.
5.2 Upgrades to Station Facilities
• Two new 12.5 kV feeder bays with associated switches, breakers, relays' etc at Dietrich
substation
• A new 138:12.5 kV power transformer and associated equipment at Dietrich substation
with protection package, control building.
S
• Line relay and microwave upgrades at Midpoint substation
• DTRC-MPSN microwave reflector site (near Notch Butte)
5.3 Upgrades to Transmission Facilities
Idaho Power will rebuild 4 miles of the existing 46 kV transmission line (T-128) with a
double circuit transmission line that will accommodate both the existing 46 kV line as well as
the new 138 kV line. The new 138 kV line will then tap into the existing Midpoint-Silver
138 kV line with line switches on all three sides of the tap.
6. Total Estimated Costs
The following good faith estimates are provided in 2012 dollars:
I· .". . J '''!!!I'coJ''':c.ecti()11 F .. ~ciljii.es:.
,IntercQn~~~iQB ?~~~ag~~ (?} .. _. __ _
l?Jist':i!u.f7(Jn U, .'C!.aa9: _
;Distribution Feeders to Dietrich Substation (DTRC-013
l§c DTR~-01~2 ~ith.AI?~~ flber
SUbSliitioiJ UJ . tildes.: ~ ............................... 'Pg~ ............. c .................. _ •••
;Dietrich Substation Additions
:Midpoint Relay u)J~~d.~.,s .
M~~p':~int Mi~rowave up~ad~ __
iDTRC-MPSON Microwave Reflector Site _ ._ A •• , • __ # • _ _ A '" _
:!.r.lI:n.s11r~s.sion Upg~ades:
RemOYe4 ,miles of 46 kV line ~it!I !!p'-derbuild
Build 4 miles of line to double circuit -._-.. ..: .. .:..-.
:3 -138 kV Line Switches
l~:aLM~en:oifti.nWR'OW (jiant
;GRAND TOTAL
'!PC ~ ..
I .. _ '. __ ~
1$440,(jCYO
I -.~-.---
• I
,$~.~835,000 I
;$05'000 I .' .. ' .. '.' -----1
[$) ~~()dP ,I
1$32S,()(i6; . ! ." -.. , .. " .. ,,--.~ -.-
---
:$130,000
;$i3§Q~oOO -
i$;J.OO,OOO I . .. .
($.75,000
-\
'$7,875,000
*There is approximately 1.5 miles of the existing 46 kV transmission line which is located on BLM
land. A permit will be required from the BLM in order to rebuild this portion of the line to double
circuit as well as install the transmission line switches. The costs for this pennitting can vary widely
and have been estimated at a combined $75K.
Note Regarding Transmission Service:
This Facility Study is a Network Resource Interconnection Facility Study. This study identifies the
facilities necessary to integrate the Generating Facility into Idaho Power's network to serve load within
Idaho Power's balancing area. Network Resource Interconnection Service in and of itself does not
convey any right to deliver electricity to any specific customer or Point of Delivery.
6
Appendix A
Generation Interconnection Control Requirements
A.1 Generator Output Limit Control (GOlC)
A.1.1 IPC requires Interconnected Power Producers to accept GOLC signals from our EMS.
A.1.2 The GOLC signals will consist of four points shared between the IPC EMS and the Customer's
Generator Controller:
A.1.2.1 GOLC Setpoint: An analog output that contains the MW value the Customer should curtail
to, should a GOLC request be made via the GOLC On/Off discrete output Control point.
A.1.2.1.1 An Analog Input feedback point must be updated (to reflect the GOLC setpoint value)
by the Customer Controller upon the Controller's receipt of the GOLC setpoint change, with no
intentional delay.
A.1.2.2 GOLC On/Off: A discrete output (DO) control point with latching Off/On states. Following
a "GOLC On" control, the Customer Controller will run power output back to the MW value
specified in the GOLC Setpoint. Following a "GOLC Off' control, the Customer is free to run to
maximum possible output.
A.1.2.2.1 A Discrete Input feedback point must be updated (to reflect the GOLC DO state) by
the Customer Controller upon the Controller's receipt of the GOLC DO state change, with no
intentional delay.
A.1.3 If a GOLC control is issued, it is expected to see MW reductions start within 1 minute and plant
output to be below the GOLe Setpoint value within 10 minutes.
A.2 Generation Interconnection Data Points Requirements
~ .......
'" Digital [np'l~ts to IPCo (D~ Ob.i. 01, Var. 2)
i Index Description . State (0111 Comments~·.
0 52A Customer Capacitor Break~r (ifpresent) Open/Closed Sourced at substation
1 GOLC OfflOn Control Re.ceived (Fe,edback) Off/On Provided by Customer ... -,
Digital Outputs to C ustomer (DNP Obj. 10, Val'. 1)
Index Description_ I Comments:
" .0 GOLCOff/On I Provided QY !PCO
NOTE: GOLe. Setpoint indicates MW value to curtail to when,GOLC Off tOn DO is ON,
-Analog Inputs to IPCo (DNP Ob.i. 30, Var. 2)
Raw Raw EU EU EU
Index, Description High Low High Low Units Comments:'
GOLC Setpoint Value Received -Provided by
0 (Feedback) 32767 32768 TBD TBD MW Customer
Spare -Reserved for Voltage Control -Provided by
1 Feedback 32767 32768 TBD TBD kV Custom~r
2 Maximum Park Generating Capacity 32767 -TBD TBD MW Provided by
7
32768 Customer
-Provided by
3 Number of Turbines In High Speed Cutout 32767 32768 32767 -32768 Units Customer
-For Provided by
4 Ambient Temperature 32767 32768 327.67 -327.68 C Customer
i -Provided by
5 Wind Direction 32767 '32768 327.6.7 -3276.8 Deg Customer
MPH
-or Provided by
! 6 Wind Speed 32767 32768 327.67 -327.68 mls Customer
Analog Outputs to Customer (DNP Obi. 40 Var. 2)
Raw Raw ED EO ED
Index Description High Low High I Low Units Comments:
•• < -.
0 GOLC Setpoint 32767 32768 TBD TBD MW Provided by IPCO
Spare -Reserved for Voltage Control -.
1 Setpoint 32767 32768 TBD TaD kV Provided b)' IPCO ..
NOTE: Curtailment Setpoint indic.aJes MW yalue to Curtail to when Curtailment Off/On DO is ON . . -
8
Appendix B
Limited Generation Output
In response to the Interconnection Customer's (IC) request to come on line by the end of the year with a
limited generation output, IPC conducted additional power flow models. It was determined that
acceptable voltage on the 46 kV system could be maintained with 4.0 MW of generation from Notch
Butte Wind Park if the generators have the ability to absorb 3.0 MV Ar. The installation of a 46 kV
potential transformer transfer/trip package would have to be a.dded to the scope/costs of the work at
Dietrich substation. The IC will be responsible for absorbing the V Ars (3.0 maximum) necessary to
maintain a 1.075 p.u. maximum 46 kV bus voltage at Dietrich substation. A voltage level above 1.075
p.u. will cause the generator to be tripped offline.
Idaho Power will provide the magnitude of the 46kV bus voltage at Dietrich station to the customer's
control system. The voltage value will be made available to the customer's control system via the
measurement device at Dietrich (e.g. meter or relay) and a direct, serial connection via the new feeder
ADSS fiber optics. Data protocol and point formatting to be determined.
The estimated cost of this additional work is $75,000. This brings the total estimated project cost to
$7,950,000. If the Generation Interconnection Agreement is signed and the project is funded before
May 1st, 2012, then IPCo will have the facilities necessary for this limited generation output in place by
December 31st, 2012.
9
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BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 50
Mr. Dustin Shively
Exergy Development Group of Idaho
802 W. Bannock Suite 1200
Boise, Idaho 83702
April 20, 2012
¥FIIMHO ~POWER®
An IOACORP Company
Via email & Certified Mail#70102780000090951625
Re: Draft GIA for Notch Butte Wind Park Project -GI# 349 & 359
Dear Mr. Shively:
Attached please fmd a copy of the fmal Facility Study Report (FSR) dated April 9, 2012, and a draft
Generator Interconnection Agreement (GIA) for your Generator Interconnection project. The GIA is part
of Idaho Power Company's Rate Schedule 72 tariff approved by the Idaho Public Utilities Commission
(IPUC). The IPUC has the authority to review and modify these schedules periodically. You may view
the most current tariff at Idaho Power's website:
http://www.idahopower.com/aboutus/regulatoryinfo/tariffs.asp The GIA Attachments are based on the
Facility Study Report. Please review the GIA Attachments to make sure they are comprehensive and
accurate and advise me of any changes as soon as possible.
Although the preferred method of funding is full payment up front; payment arrangements may be
requested. If you have not already done so, please contact Aubrae Sloan (208-388-5697), Operations
Finance at your earliest convenience to discuss Idaho Power's credit requirements for construction
funding. Once we receive funding, or the credit requirement is met, we can proceed with construction of
the project. The actual construction and labor charges will be reconciled approximately 90 days
subsequent to project completion.
Under the Generator Interconnection process, the following items must be provided to me on or before
execution of the GIA: ,
1. Your requested in service date to complete Attachment 3 of the GIA.
2.Proof of Site Control for the project
3.Insurance certification pursuant to Section 7 of the GIA (certificate, 1 endorsement for Additional
insured, and 1 for the cancellation notice)
4.Financial arrangements approved by Idaho Power credit department, or full payment for construction
Please note the dates in Attachment 3 to the GIA. In order for you to come on line with limited output by
December 15, 2012 we must have this agreement executed by May 1, 2012.
Failure to submit all of the requested items above by May 21, 2012 will cause your Generator
Interconnection request to have been deemed withdrawn and terminated. Please contact me at your
earliest convenience with any questions.
Sincerely,
Josh Harris
Operations Analyst
[e-mail]
1221 W. Idaho St. (83702)
P.O. Box 70
Dustin Shively, Exergy Page 2 of2
End: Final Facility Study Report
Draft GIA for Notch Butte Project # 349 & 359
Cc: (via email) Ed Kosydar Project LeaderlIPC
Rich BauerlIPC
Aubrae SloanlIPC
April 20. 2012
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u.C. No. 29, Tariff No. 101
April 20, 2012
, ,
GENERATOR INTERCONNECTION AGREEMENT -:: -,
Soh,edule .72
Notch Butte Wind Parks···PROJECTS #349 & #359
: '6.5 / 11.5 MW
" .. ,
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101
TABLE OF CONTENTS
RECiTALS .............................................................................................................................................. 1
AGREEMENTS ...................................................................................................................................... 1
1. Capitalized Terms ................................................................................................................ 1
2. Terms and Conditions .......................................................................................................... 1
3. This Agreement is not an agreement to purchase Seller's power. ........................................ 1
4. Attachments ......................................................................................................................... 1
5. Effective Date, Term, Termination and Disconnection .......................................................... 2
5.2 Termination ............................................................................... : ........................................... 2
6. Assignment, Liability, Indemnitv. Force majeure. Conseguentia/ -Damages and Default. ...... 5
7. Insurance .......................................................................... ;.;.,:, ... ; ........................................... 7
8. Miscellaneous ....................................................................................................................... 7
9. Notices ........................................................................ _ ............. , .............................................. 8
10. Signatures ................................................................................... ::." ...................................... 9
Attachment 1 .......................................................................................................................................... 1
Attachment 2 ..................................................................... ;.: ................................... ·:,., ... , .......................... 1
Attachment 3 .................................................................. ': ........................................... ; .. " ....................... 1
Attachment 4 ............................................................ " ................................................... : ... , ..................... 1
Attachment 6 ................................................................................... , ....................................................... 1
Attachment 7 .......................................................................................................................................... 1
.i· "
, ' .-,
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Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 9
This Generator Interconnection Agreement ("Agreement") under Idaho Power Company's
Schedule 72 is effective as of the 19 day of April, 2012 between Exergy Development Group of Idaho,
("Seller", "Customer" or "The Project") and Idaho Power Company ("Company","Transmission Owner",
"Idaho Power", "IPC" or "IPCO").
RECITALS
A. Seller will own or operate a Generation Facility that qualifies for service under Idaho \. Power's Commission-approved Schedule 72 and any successor schedule. :
B. The Generation Facility covered by this Agreement i$ more particularly described in
Attachment 1.
AGREEMENTS . .' ., .... ,~
1. Capitalized Terms < '-.
Capitalized terms used herein shall have the same meanings as defined in SchedtJ/~.;;;72 or in the body
of this Agreement. ,'; ','
2. Terms and Conditions . .
This Agreement and Schedule 72 provide the rates, char-ge's/"'te-"'ms and conditions under which the
Seller's Generation Facility will intercdhnect with, and cif:jpr;ate in parallel with, the Company's
transmission/distribution system. Terms defimiJd'jn Schedule 72 -liJiII have the same defined meaning in
this Agreement. If there is any conflict be(ween .!he terms of: this Agreement and Schedule 72,
Schedule 72 shall prevail. , , r ~~. .,:. ,,1 •
3. This Agreement is-not an agreement to parchase Seller's power.
Purchase of Seller's power and other'services that:rSeller may require will be covered under separate
agreements. Nothing in this Agreement is intended to affect any other agreement between the
Company and Seller;'
4. Attachments
Attached to this AgrfJement af}d inrcluded by reference are the following:
" Attachment 1 -Description and Costs of the Generation Facility, Interconnection
Facilities, and Metering Equipment
" Attachment 2 ...;;, JOne-line Diagram Depicting the Generation Facility, Interconnection
Facilities, Metering Equipment and Upgrades.
:::: ,"
Atta.chment ~;,Milestones for Interconnecting the Generation Facility
AttachmentA -Additional Operating Requirements for the Company's Transmission
System Needed td Support the Seller's Generation Facility
Attachment 5 -Reactive Power
Attachment 6 -Description of Upgrades required to integrate the Generation Facility and
Best Estimate of Upgrade Costs
Attachment 7 -Generator Interconnection Control Requirements
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u.C. No. 29, Tariff No. 101 Page 20f9
5. Effective Date, Term, Termination and Disconnection.
5.1 Term of Agreement. Unless terminated earlier in accordance with the provisions
of this Agreement, this Agreement shall become effective on the date specified above and remain
effective as long as Seller's Generation Facility is eligible for service under Schedule 72.
5.2 Termination.
5.2.1 Seller may voluntarily terminate this Agreement upon expiration or
termination of an agreement to sell power to the Company. ,:t" ,
5.2.2 After a Default, either Party may termina:t~this Agreement pursuant to
Section 6.5. ;.
5.2.3 Upon termination or expiration Qfthis Agreen1efit~Jhe Seller's Generation
Facility will be disconnected from the Company's transmission/distribution system;, The termination or
expiration of this Agreement shall not relieve e;ther Party orlt'S liabilities and obl/ggfit![,!s, owed or
continuing at the time of the termination. The provisions of this Section shall survivjjterrnination or
expiration of this Agreement.' . ':. .
' .. ,
5.3 Temporary Disconnection. Temporary dis_cqlinection shall continue only for so
long as reasonably necessary under "Good Utility Practice. :'($Qod Utility Practice means any of the
practices, methods and acts engaged in (fit,,,,§pprpved by a sigtJ£t!J~~nt portion of the electric industry
during the relevant time period, or any of the-practices, methods"'af/~ acts which, in the exercise of
reasonable judgment in light of the facts knGi.wn at the. time the deciSion was made, could have been
expected to accomplish the desired result at a reasonabl(} ;cost consist~nt with good business practices,
reliability, safety and expeditiofJ .. Good Utility P@ctice is.. Clot ;~ief1ctf)!i to ~be limited to the optimum
practice, method, or act to th.1;t ,f)Xcl'ls.i.on of all oth~r§; b.i!t rather r(!),it;~.acceptable practices, methods, or
acts generally accepted indhif region; :Good Utility..Rractice includes compliance with WECC or NERC
requirements. Paymeniioffost revenue resulting fr0rh temporary disconnection shall be governed by
the power purchase agi~ement.· ~
5.3.1.' Emergency 'Cbn.ditions.;'Emergency Condition" means a condition or
sit/jation: (1 J tli~t 'ih the judgmehl ~6f -the Party making the claim is imminently likely to
. endanger life or pr.qperly; or (2) that, in the case of the Company, is imminently likely (as
,;." determlnetj, in a non-qiscriminatory manner) to cause a material adverse effect on the
security of; or da'fnage to the Company's transmission/distribution system, the
Company's tntf)rconnectlqh Facilities or the equipment of the Company's customers; or
:, (3) that, in th(]case of the Seller, is imminently likely (as determined in a non­
discriminatory manner) to cause a material adverse effect on the reliability and security
of, or damage to, the Generation Facility or the Seller's Interconnection Facilities. Under
Emergency GOhd/tions, either the Company or the Seller may immediately suspend
interconnectio.tJ service and temporarily disconnect the Generation Facility. The
Company ,s,hall notify the Seller promptly when it becomes aware of an Emergency
Condition that may reasonably be expected to affect the Seller's operation of the
Generation Facility. The Seller shall notify the Company promptly when it becomes
aware of an Emergency Condition that may reasonably be expected to affect the
Company's equipment or service to the Company's customers. To the extent
information is known, the notification shall describe the Emergency Condition, the extent
of the damage or deficiency, the expected effect on the operation of both Parties'
facilities and operations, its anticipated duration, and the necessary corrective action.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 3 of 9
5.3.2 Routine Maintenance, Construction, and Repair. The Company may
interrupt interconnection service or curtail the output of the Seller's Generation Facility
and temporarily disconnect the Generation Facility from the Company's
transmission/distribution system when necessary for routine maintenance, construction,
and repairs on the Company's transmission/distribution system. The Company will
make a reasonable attempt to contact the Seller prior to exercising its rights to interrupt
interconnection or curtail deliveries from the Seller's Facility. Seller understands that in
the case of emergency circumstances, real time operations of the electrical system,
and/or unplanned events, the Company may not be able to provide notice to the Seller
prior to interruption, curtailment or reduction of electrical energy deliveries to the
Company. The Company shall use reasonable efforts to coordinate such reduction or
temporary disconnection with the Seller.
5.3.3 Scheduled Maintenance. On or before January 31 of each calendar year,
Seller shall submit a written proposed schedule of significant Facility
maintenance for that calendar year and and Seller shall mutually agree as
to the. acceptability of the proposed The Parties determination as to the
acceptability of the Seller's scheduled maintenance will take into
consideration Good Utility Practice Power requirements and the Seller's
preferred schedule. Neither Party withhold acceptance of the
proposed maintenance schedule.
5.3.4. Maintenance Coordination. and the Company shall, to the
extent practical, coordinate their respective system and
Generation Facility maintenance schedules such occur simultaneously. Seller
shall provide and maintain adequate protective sufficient to prevent damage
to the and Seller-furnished Facilities. In some cases,
relays will provide back-up protection for Idaho Power's
ve1ltlllfriRh( Power will test such relays annually and Seller will pay the
;.or"" ....... testing.
During any forced outage, the Company may suspend
~~~~g,'n~im~~m:~e~~diate repairs on the Company's
1/' shall use reasonable efforts to provide
If prior notice is not given, the Company shall, upon request,
S~fI~/~'i'ltJ'~n documentation after the fact explaining the circumstances of
5.3.6 The Company shall notify the Seller as soon
as practicable if, based on Good Utility Practice, operation of the Seller's Generation
Facility may cause disruption or deterioration of service to other customers served from
the same electric system, or if operating the Generation Facility could cause damage to
the Company's transmission/distribution system or other affected systems. Supporting
documentation used to reach the decision to disconnect shall be provided to the Seller
upon request. If, after notice, the Seller fails to remedy the adverse operating effect
within a reasonable time, the Company may disconnect the Generation Facility. The
Company shall provide the Seller with reasonable notice of such disconnection, unless
the provisions of Article 5.3. 1 apply.
5.3. 7 Modification of the Generation Facilitv. The Seller must receive written
authorization from the Company before making any change to the Generation Facility
that may have a material impact on the safety or reliability of the Company's
transmission/distribution system. Such authorization shall not be unreasonably withheld.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 4of9
. ...., ' ...
Modifications shall be done in accordance with Good Utility Practice. If the Seller makes
such modification without the Company's prior written authorization, the latter shall have
the right to temporarily disconnect the Generation Facility.
5.3.8 Reconnection. The Parties shall cooperate with each other to restore the
Generation Facility, Interconnection Facilities, and the Company's
transmission/distribution system to their normal operating state as soon as reasonably
practicable following a temporary disconnection.
5.3.9 Voltage Levels. Seller, in accordance with Good Utility Practices, shall
minimize voltage fluctuations and maintain voltage level$;acceptable to Idaho Power.
Idaho Power may, in accordance with Good Utility Praqtir;;~s, upon one hundred eighty
(180) days' notice to the Seller, change its nominal ope/tilting voltage level by more than
ten perc(!Jnt (10%) at the Point of Delivery, in whichc§~~ Seller shall modify, at Idaho
Power's expense, Seller's equipment as nec~~$CJfy to" ac;commodate the modified
nominal operating voltage level.
5.4 Land Rights.
504. 1 Seller to Provide Access. Seller here.by grants to Idaho, power for the
term of this Agreement all necessary .r:ights-of-way and easements to Install, operate,
maintain, replace, and remove Idaho Power's -Metering Equipment, Interconnection
Equipment, Disconnection €guipment, Proteqtibh Equipment and other Special Facilities
necessary or useful to this)Agree.ment, including: .?flequate and continuing access rights
on property of Seller. Sellf?r W~f:lJmts that it na$ ,procured sufficient easements and
rights-of-way from third partie$'''so as~Jli? pr:.ovide Idaho Power with the access described
above. All documents granfing such easements or ;;r{ghts-of-way shall be subject to
Idaho Power's approval and in r~p~rdable.if(J·tih... ;:, ' ','
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5.4~. Use ofBublic Rights:..,of1Wav. The Parties agree that -it is necessary to
avoid the adverse environmental and operating impacts that would occur as a result of
duplicate. electric lines being constru¢t(fd in close proximity. Therefore, subject to Idaho
Power's -c.qrT?pllance with Paragraph 5;404, Seller agrees that should Seller seek and
receive frCif.b, ~f1Y Iqc.~/,-state 'or fe .. cJf!(flf.:governmental body the right to erect, construct
. . "a,n,q_ rn:a!ntain $~!Ie.t~furnished IntercbO.nection Facilities upon, along and over any and all
.. ' publiC f!!eaqs, st"'e~ts. and highways, then the use by Seller of such public right-of-way
shall be suqordinate to any future use by Idaho Power of such public right-of-way for
construction and/or maintenance of electric distribution and transmission facilities and
Idaho Power m.~y claim use of such public right-of-way for such purposes at any time.
'f Except as reql.!lred by Paragraph 5.4.4, Idaho Power shall not be required to
:t .ompensate Sell$r, for exercising its rights under this Paragraph 5.4.2.
-504.3 :Joint Use of Facilities. Subject to Idaho Power's compliance with
Paragr:a,ph "tp.4A, Idaho Power may use and attach its distribution andlor transmission
facilities t~ Sel/er's Interconnection Facilities, may reconstruct Seller's Interconnection
Facilities to accommodate Idaho Power's usage or Idaho Power may construct its own
distribution or transmission facilities along, over and above any public right-of-way
acquired from Seller pursuant to Paragraph 5.4.2, attaching Seller's Interconnection
Facilities to such newly constructed facilities. Except as required by Paragraph 504.4,
Idaho Power shall not be required to compensate Seller for exercising its rights under
this Paragraph 504.3.
50404 Conditions of Use. It is the intention of the Parties that the Seller be left in .
substantially the same condition, both finanCially and electrically, as Seller existed prior
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u.C. No. 29, Tariff No. 101 Page 5 of 9
to Idaho Power's exercising its rights under this Paragraph 5.4. Therefore, the Parties
agree that the exercise by Idaho Power of any of the rights enumerated in Paragraphs
5.4.2 and 5.4.3 shall: (1) comply with all applicable laws, codes and Good Utility
Practices, (2) equitably share the costs of installing, owning and operating jointly used
facilities and rights-of-way. If the Parties are unable to agree on the method of
apportioning these costs, the dispute will be submitted to the Commission for resolution
and the decision of the Commission will be binding on the Parties, and (3) shall provide
Seller with an interconnection to Idaho Power's system of equal capacity and durability
as existed prior to Idaho Power exercising its rights under this Paragraph 5.4.
6. Assignment. Liability, Indemnitv, Force majeure, Consequential Damages and Default.
6. 1 Assignment. This Agreement may be assignee! by either Party upon twenty-one
(21) calendar days prior written notice and opportunity.tqobjectbythe other Party; provided
that:
6. 1. 1 Either Party may assign this, Agreement withoUt.:the consent of the other
Party to any affiliate of the assigning Party 'With an equal or greaterprfjJdit rating and with
the legal authority and operational ability-to satisfy the obligations of (he assigning Party
under this Agreement. ", ":,"\
6.1.2 The Seller shall have the ,fight to pontingently assign this Agreement,
without the consent of the c;ompany, for collEltefiJ.1 security purposes to aid in providing
financing for the Generation 'F..acility, provided,that the Seller will promptly notify the
Company of any such contfngent·a;;signment. . ...
,--S:, '.,!
6. 1.3 Any attempted a,$~ignment Ith~t violates;tfji§ article is void and ineffective.
Assignment sh?/1 npt relieve a !'Rarty oUts' ebliga(ions, nor shall a Party's obligations be
enlarged, in Wr91e or in part, by reasorf thereor An ,assignee is responsible for meeting
the same. ,financial, credit, and insurance obligations as the Seller. Where required,
consent ·te,assignment will not be unreasonably withheld, conditioned or delayed.
6.2 Limitation of Liability. Each Pa,rty's liability to the other Party for any loss, cost,
claim, injury, liability, or expense, including reas¢hable attorney's fees, relating to or arising from
any f!,9,tJ!)r.omlssion in its'performance of this Agreement, shall be limited to the amount of direct
damage actually incurred. In no event shall either Party be liable to the other Party for any
Indirect, special, cqnsequential, or punitive damages, except as authorized by this Agreement.
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6.3 Inden-mitY-.
.:.: '
6.3.1 Thi§ provision protects each Party from liability incurred to third parties as
~result of carrYing out the provisions of this Agreement. Liability under this provision is
exempt from tbe general limitations on liability found in Article 6.2.
t13.2 The Parties shall at all times indemnify, defend, and hold the other Party
harmless from, any and all damages, losses, claims, including claims and actions
relating to injury to or death of any person or damage to property, demand, suits,
recoveries, costs and expenses, court costs, attorney fees, and all other obligations by
or to third parties, arising out of or resulting from the other Party's action or failure to
meet its obligations under this Agreement on behalf of the indemnifying Party, except in
cases of gross negligence or intentional wrongdoing by the indemnified Party.
6.3.3 If an indemnified person is entitled to indemnification under this article as
a result of a claim by a third party, and the indemnifying Party fails, after notice and
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 6 of 9
reasonable opportunity to proceed under this article, to assume the defense of such
claim, such indemnified person may at the expense of the indemnifying Party contest,
settle or consent to the entry of any judgment with respect to, or pay in full, such claim.
Failure to defend is a Material Breach.
6.3.4 If an indemnifying party is obligated to indemnify and hold any
indemnified person harmless under this article, the amount owing to the indemnified
person shall be the amount of such indemnified person's actual loss, net of any
insurance or other recovery.
6.3.5 Promptly after receipt by an indemnified persCiJn of any claim or notice of
the commencement of any action or administrative or legal proceeding or investigation
as to which the indemnity provided for in this article-may apply, the indemnified persQn
shall notify the indemnifying party of such fact. Any-failure' af or delay in such notification
shall be a Material Breach and shalf not affect a Party's indemnification obligation unless
such failure or delay is materially prejudicial fifthe indemnifying PfJ'!Y.
" , ,. -
6.4 Force Majeure. As used in this Agreement, "Force Majeure'~I. Qr "an event of
Force Majeure" means any cause beyond the ,control of the Seller or of the 'Company which,
despite the exercise of due diligence, such Party is unable to prevent or overcome. Force
Majeure includes, but is not limited to, acts of 'God, fire, .flood, storms, wars, hostilities, civil
strife, strikes and other labor disturbances, earthquakes,~fi;'es. lightning, epidemics. sabotage, or
changes in law or regulation occurring after the Ope.ration Date, which, by the exercise of
reasonable foresight such party could 'notire.asonably Halle -been expected to avoid and by the
exercise of due diligence, it shall be unable to overcome. If either Party is rendered wholly or in
part unable to perform its obligatior1$ _under thi's·-/lgreement pecause of an event of Force
Majeure. both Parties sbJII! be excused-· from o"yhfitertet-'performance is affected by the event of
Force Majeure, proyide-d ,that
,I, ':,
(J1Y ' The non-performing Party shall. as soon as is reasonably possible after
the occ~rrence of the Force Majeure, ,give the other Party written notice describing the
particular$:. of the occuf[enc;a..
'I .r ~:..' ,-; '..
(2) . 'Th~ suspension of pfqFrdrmance shall be of no greater scope and of no
longer dip:ation tflEJn is required by the event of Force Majeure.
(3) No obligations of either Party which arose before the occurrence causing
the suspension of performance and which could and should have been fully performed
before such occurrence shall be excused as a result of such occurrence.
-.I
Idaho Power Company Generator Interconnection Agreement # 349/359
I,P.U.C. No. 29. Tariff No. 101 Page 7 of 9
6.5 Default and Material Breaches.
6.5. 1 Defaults. If either Party fails to perform any of the terms or conditions of
this Agreement (a "Default" or an "Event of Default'?, the nondefaulting Party shall cause
notice in writing to be given to the defaulting Party, specifying the manner in which such
default occurred. If the defaulting Party shall fail to cure such Default within the sixty
(60) days after service of such notice, or if the defaulting Party reasonably demonstrates
to the other Party that the Default can be cured within a commercially reasonable time
but not within such sixty (60) day period and then fails to diligently pursue such cure,
then, the nondefaulting Party may, at its option, terminate this Agreement and/or pursue
its legal or equitable remedies.
6.5.2 Material Breaches. The notice and ctJ.ie:Pt()visions in Paragraph 6.6.1 do
not apply to Defaults identified in this Agreemetifas" Matf:]rial Breaches. Material
Breaches must be cured as expeditiously .. as . possible foikJwing occurrence of the breach. ... ... "
".
7. Insurance.
During the term of this Agreement, Seller ~~h.all secure and continuously caqy ,the following
insurance coverage: <t-'
,-\ .... -: -,,:,.-;
7. 1 Comprehensive Gef)eral Liability Insu"~fiI(;e for both bodily injury and property
damage with limits equal to $1,OQQ,9pg,each occurreTi~e, .combined single limit. The deductible
for such insurance shall be consist-erifilVithr;urrent Insural)i;e Industry Utility practices for similar
property. :'; ';':;/;:<CJ ".,
\' .' .' .
7.2 The abqve insurance c(.)v.~rage sljail6i3plaqed with an insurance company with
an A.M. Best Compatwratinj;jpf A-or bett~rfirig'shall inClt.iCJ~.;
(a) . An endorsement namih,g Idaho Power as an additional insured and loss
payee ~s applicable; a,nd '
;:' "'
(bj ':, A ptov;sidhst~t;rig, tha( such policy shall not be canceled or the limits of
liability reduced 'IV/thout sixty (00) days' prior written notice to Idaho Power . . " .. ,,-.'
7.3 Seller to Provide Certificate of Insurance. As required in Paragraph 7 herein and
annually thereafter, S€!lIer shailfl!..rnish the Company a certificate of insurance, together with the
endorsements required therein, 'i.!videncing the coverage as set forth above.
7.4 Seller to ,Notifv Idaho Power of Loss of Coverage -If the insurance coverage
required by Paragraph 7.1 shall lapse for any reason, Seller will immediately notify Idaho Power
in writing. 'The notice will advise Idaho Power of the specific reason for the lapse and the steps
Seller is taking to reinstate the coverage. Failure to provide this notice and to expeditiously
reinstate or replace the coverage will constitute grounds for a temporary disconnection under
Section 5.3 and will be a Material Breach.
8. Miscellaneous.
8. 1 Governing Law. The validity, interpretation and enforcement of this Agreement
and each of its provisions shall be governed by the laws of the state of Idaho without regard to
its conflicts of law principles.
8.2 Salvage. No later than sixty (60) days after the termination or expiration of this
Agreement, Idaho Power will prepare and forward to Seller an estimate of the remaining value
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 80f9
of those Idaho Power furnished Interconnection Facilities as required under Schedule 72 and/or
described in this Agreement, less the cost of removal and transfer to Idaho Power's nearest
warehouse, if the Interconnection Facilities will be removed. If Seller elects not to obtain
ownership of the Interconnection Facilities but instead wishes that Idaho Power reimburse the
Seller for said Facilities the Seller may invoice Idaho Power for the net salvage value as
estimated by Idaho Power and Idaho Power shall pay such amount to Seller within thirty (30)
days after receipt of the invoice. Seller shall have the right to offset the invoice amount against
any present or future payments due Idaho Power.
9. Notices.
9.1 General. Unless otherwise provided in this, Agreement, any written notice,
demand, or request required or authorized in connection ~i!p fhi§ Agreement ("Notice") shall be
deemed properly given if delivered in person, delivered by·,recogr;lized national currier service,
or sent by first class mail, postage prepaid, to the per$on specified below:
If to the Seller:
Seller: ___ ---'---''----'---'-...;;.....--:.::......-"'---=---':.:..:.....-___ -=-----' ____ _
Attention: _____________________ --'-"'--___ _
Address: _______________________________ _
City: __ --=--.:....::....:...:..._~c.......:....._'__~.State:___..,....:.:.:o;..=----'Zip: ___ --'--_
Phone: F~X.:.:-.!o:,,-i',.,.,._~----__
If to the Company:
Idaho Power Company -Delivery
Attention: Operations ~1;1D.a.ger
1221 W. Idaho Street' .;.;.'
Boise: Idaho 83702
... '.' ,;'
. ' " ,
Phone: 208-3~8:;qp69 Fax: 208~388-5504 ... '
,I •
9.2
out below:
Biliing and Payment, Billings and payments shall be sent to the addresses set
-) _', "~ .1 , \,'.
.' . ! ,~~ & !-••
Seller: _________________________ _
Attention: ________ .....;---'_~.:_.._~ ______ ....:...._....;:.... ___ _
Addre.ss: _.!--_--=--__ '---~.:.....-___: _______ ___''__ ___ __'_ ___ '__ __
City: ___ --'--__ ....:.....>. ___ S,tate: ____ .Zip: ____ _
Phorie: Fax:
Idaho POI,-yE;lr Company' ~0elivery
Attention: G,orporate Ca-shier
PO Box 447'
Salt Lake City Utah 84110-0447
------------
Phone: [phone] email: [e-mail]
9.3 Designated Operating Representative. The Parties may also designate
operating representatives to conduct the communications which may be necessary or
convenient for the administration of this Agreement. This person will also serve as the point of
contact with respect to operations and maintenance of the Party's facilities.
Idaho Power Company Generator Interconnection Agreement # 349/359
I,P.U.C. No. 29, Tariff No. 101 Page 9 of 9
Seller's Operating Representative:
Seller: ______ ..:..:....-___ ---..,;:......-----:-__ -,.-''-'--______ _
Attention: -----------------------------------Address: ______________________________ ~=-__
City: _______ ----'---'-_-'-___ State: ___ -=-----'Zip: ---:.;.:' .~_----=-_
Phone: Fa~ -----------
Company's Operating Representative:
Idaho Power Company -Delivery
Attention: Outage Coordinator -System/Regional Dispatch
1221 W. Idaho Street
Boise, Idaho 83702 k
Over 138kV phone [phone] during regular business h9~rs
Under 138kV Phone: [phone], or 388"-"5175
After hours -System Dispatch 388 2826 ';
Regional Dispatch
Southern Region 208-388-519Q .'
I • t
during ·regular business hours
9.5 Changes to the Notice Information. , Either,J?,8rtY may change this 'j'nformation by
giving five (5) Business Days written notice prior to ,the eff$ctlve date of the change.
10. Signatures.
" ' :~.',;.~... '." .. ' '. ; :~~~~~:~ ". "
IN WITNESS WHEREOF, the Partie,$ have,¢a.,,",~ed this Agr~ement to be executed by their
respective duly authorized representatives. '!:-, " ',' " "
For the Seller ; -
,-Name: __________ ~ ________ ~ _____ '~'~ ________ __
Title: _______ -.,.-____ --.---,-----------
Date: _~~-__ --~~~';
.: -t;:
for the Compat.:y
Name:':: ' ,
Title: Ma~ager, Grid OperatiOns -Idaho Ppwer Company, Delivery
Date: __ ~~ _____ ~-,--_
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No.1 01 Page 1 of 3
Attachment 1
Description and Costs of the Generation Facilitv. Interconnection Facilities and Metering Equipment
Interconnection Details
Type of Interconnection Service: Studied as an Idaho Power Network Resource under PURPA
Full Output: 18 MW (both projects)
Nominal Delivery Voltage: 12.5 kV
General Facility Description
The Notch Butte Wind Park project includes both Projects #349 and #359J6f a total of 18 MW of power
provided by seven 2.5Mw Nordex Turbines. The Interconhection Custome'r (IC) will provide all
generation and station equipment required to deliver power at 12.~,.kV tq the Point of Interconnection
(POI) which is located at the coordinates North 420 53.12948' West 1140 1'0:57'. The Seller will provide
two POTS lines and two DDS circuits to the POls (one pair for. ~ath feederddliliection) for
communication. Two 12.5 kV feeders will run from the POI ,four miles west to tHe JPCo Dietrich
substation where the station will be expanded to accommod~ate the two new feeders: The power will be
converted to 138 kV via a 12.5 kV to 138 kV power cirdJit'transformer. A new double circuit
transmission line, consisting of a new 138 kV line and. th~ existing 46 kV line, will run four miles due
north out of the Dietrich substation. The new 138 kV Iiristwill comlectr. to the existing Midpoint-Silver
138 kV line. ..
Interconnection Point : . ." "
The Interconnection Point for the Notch B~ttE~ WinclPark Project w.iII be the generator side of the
disconnect switches labeled Disconnect SWl1¢hes A~'1'~;~ndA-14 (oti.e',for each feeder) as shown on the
attached Single Line drawings 21 0-64299, sh$~ts 1 & 2. This :Intercdiiiiection Point is in Lincoln
County, 10 -T6S, R19E, SW gomer of Section ~2. .," .... .
'.:
A drawing identifying the Point of Interconnection is<inCiuded as Attachment 2. The Point of Change of
Ownership is electricall{the same as the Interconnection Point.
Seller's Interconnection' Facilities . . .
The Seller will install all generationandst~tidri 'eqUipment required to deliver power at 12.5 kV to the
interconnection point. Transmitting 18 MW of power at 12.5 kV requires two distribution feeders. The
Seller shaUbalance the generation between these two feeder connections with no more than 11 MW of
power flqwing on either feeder. THe ,Seller will own and maintain facilities electrically located on the
Interconilection Customer side of the?qir:tt of Change of Ownership. Idaho Power will own and
maintainlhe facilities electrically located 'On the IPCo side of the Point of Change of Ownership.
The Seller will ihstall equipment to receive signals from Idaho Power Company Grid Operations for
Generator Output Limit Control (i~GOlC") -see Attachment 4 Operating Requirements.
The Seller will provide .phone service to IPCo's generator interconnect package as described in
Telecommunications below.
The Seller will provide a DNP 3.0 serial data connection to the local Idaho Power Company SCADA
RTU when any communication with Seller-owned and maintained equipment is required for GOlC,
voltage control or other plant monitoring or control. Preliminary points lists and functional description
were provided to the Seller in the Facility Study Report.
All interconnection equipment electrically located on the generator side of the Point of Change
Ownership shall be owned and maintained by the Seller.
Idaho Power Company Generator Interconnection Agreement # 349/359
I,P.U.C. No. 29, Tariff No. 101 Page 2 of 3
Other Facilities Provided by Seller
In addition to communication circuits that may be needed by the Seller, the Seller shall provide the
following communication circuits for Idaho Power's use:
Two POTS (Plain Old Telephone Service) dial-up circuit for querying the revenue meter at the
generation interconnection site. One for each 4-pole feeder connection.
Two leased DDS (Digital Data Service) circuit for SCADA between the generation interconnection site
and Twin Falls Service Building (273 Blue lakes Blvd. S., Twin Falls, ID 83301). One for each 4-pole
feeder connection. These circuits must operate at 19.2 kbps data rate. Please note that Frame Relay
service is not acceptable.
The Interconnection Customer/communications provider shall provide c:iq~marcation box and terminate
the specified communications circuits at the demarcation box. Thelpgcitiqn of the demarcation box will
be determined by Idaho Power. The demarcation box shall meet,tne'f6I1oWing requirements:
.. ". ;'. . ", ~ . ~,:, :':
• Be accessible by both the communications provider and IdahQ,f>9wer
.. ,.,': :., ":"f'~' ;.
• The location shall be near Idaho Power's equipment and shall be supject to approval by
Idaho Power
• The communications cable pairs shall b$labeled/tagged accordingly (i.e. circuit number,
phone number, transmit, receive, etc.) " . ',.. ..
The Seller is required to coordinate with a communications proVi~er to provide the communications
circuits and pay the associated one timesetlJP ~nd periodic charges. The communication circuits will
need to be installed and operational prior to generating into thel~aho Power system. Note that
installation by communications provider may takesev~r~1 monthsal1d should be ordered in advance to
avoid delaying the project. If the communication circuittYpes ,llsted ab'c:ive are not available at the site
by a communications provider, the Seller shall'confer with iltfl:lnQPower:;
If high voltage protection isrecjuiredby the corrirn'unic~H6ns pr6vlct~rfor the incoming communications
provider cable, the high voltage protection assembllyshall be engineered and supplied by the Seller.
Options are available for indoor or outd()or mounting;: The high voltage protection assembly shall be
located in a manner that provides IdahqPower 24-htiur access to the assembly for trouble-shooting of
Idaho Power owned equipment.
Ground Faf:l/t Equipment
The Seller will install transformer configurations that are Grounded-WYE to Grounded-WYE and will
limit the·GOhtribution of the ground faI,Jlt current to 20 amps or less at the Interconnection Point. .. ~ '. .
~. ..0
~ .-
Monitoring Information
If the Selier requires the ability to monitor information related to the Idaho Power reclasers in the
generation irit~rconnection package they are required to supply their own communications circuit to the
control box.
Easements
The Seller will provide to IPCO a surveyed (Metes & Bounds) legal description along with exhibit map
for IPCO's facilities at the Interconnection Point. After the legal description has been delivered to IPCO
for review, IPCO will supply to the Interconnection Customer a completed IPCO easement for signature
by the land owner of record. Once the signatures have been secured, the Seller will return the signed
easement to IPCO for recording.
Generator Output Limit Control
The Seller will install equipment to receive signals from Idaho Power Grid Operations for Generation
Output Limit Control ("GOlC") -see Attachment 4 Operating Requirements.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u.C. No. 29, Tariff No. 101 Page 3 of 3
Local Service
The Seller is responsible to arrange for local service to their site, as necessary.
Idaho Power Company's Interconnection Facilities
Idaho Power will install two standard generation interconnection packages, one for each feeder. For
each package, if the Seller is going underground to the Interconnection Point, Idaho Power will include
a pole riser for the Generator to install cables to interconnect to the Idaho Power system. If the Seller is
going overhead to the Interconnection Point, it will be at a tension not to exceed the design tension
specified by Idaho Power.
The new interconnection packages each will include four distribution PClI~~Jo mount a local service
transformer, solid blade disconnects, primary metering package, recI9s~r.j 'relays, RTU, fuses and riser
necessary for the package. The interconnection will be controlled ~y,fSEL-311C line protection relay
and a GE iBox RTU. The relay and RTU will be located in a poterm0tmtecf'enclosure and will also
contain a test switch (TS4) , SLSS, dialup modem, DDS CSl)tPSU, isolatiohJJjt~rface, power supply,
DC converter, control switch and surge protector. ~'.' ,
Concrete barriers may be necessary to protect this eq!Jiljrnent from local area trafflt:> '
A 2" conduit will be installed alongside the undergroJri~:,p~i~ary to_ta~liitate information;~kchange to the
customer about the recloser. (The Interconnection Cusldmer is. re-spbnsible for providing and installing
the appropriate cable.) .. .' .
See single line drawing as Attachment 2 .. ' ...•.. ::: '.
-;-
All interconnection equipment electrically locat~o on the ,ufllity .. ,side ofth~_lnterconnection Point shall be
owned, operated, and maintain~d by Idaho power. ' .'/ ."'," .
>.
Maintenance Coordina.ti~ifE'xcepti~n ·i·,;·
The Seller's protective >r~l~ys will not pr6Yide back-lJPprotection for Idaho Power facilities, therefore the
last 2 sentences in Se~tion 5.3.4 of this Generator Int~rconnection Agreement do not apply to this
Generation Facility. .
Estimated Cos~ .$ Ownership
The following 'gbod f~itb. ~stimat-¢s: are provided in 2011 dollars: , ,
;'ntercoilltection Facilities: ---.. .... _ •• _._. ___ --o,L _______ • ____ ••• ' _______ • ____ • __
l_n~~r~.2.f1n~C!!f9 1iLP~ckages J?l_ ''!' .• _._ _ _._,,,
SUBTOTAL
See Attachment 6 for rota/Estimate Costs ----.-... -..... -------_ .. -------'.., .. ; ;'';-'-. --.... _.'
!
i
t--.. ------.-; ----
IPC _ _ . ___ _ :$4_~O,OOO .. _. ___
I -------
_:$440,000. __ _
Full payment is required up front in accordance with Schedule 72, unless payment arrangements are
made in advance with Idaho Power Operations Finance (see Attachment 3).
Billing for construction activities will be based upon actual expenditures.
Idaho Power Company Generator Interconnection Agreement # 349/359
I,P.u.C. No. 29, Tariff No. 101 Page 1 of 3
Attachment 2
One-line Diagram Depicting the Small Generation Facility, Interconnection Facilities, Metering
Equipment and Upgrades
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Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No.1 01 Page 2 of 3
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Idaho Power Company Generator Interconn~ction Agreement # 349/359
I.P.U.C. No. 29, Tariff No.1 01 Page 3 of 3
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Idaho Power Company Generator Interconnection Agreement # 349/359
I,P.u .C. No. 29, Tariff No. 101 Page 1 of 2
Attachment 3
Milestones for Interconnecting to the Generation Facility
Idaho Power Company agrees only to the Construction timelines under its direct control provided in the
Facility Study Report for this Project.
These milestones will begin, and the construction schedule referenced below, will only be valid upon
receipt of funding in full from the Seller or their authorized third party no later than the date set forth
below for such payment. Additionally, failure by Seller to make the required payments as set forth in
this Agreement by the date(s) specified below will be a material breach Of this Agreement, which may
result in any or all of the following: (i) loss of milestone dates and construction schedules set forth
below: (ii) immediate termination of this Agreement by Idaho Powerr niiJremoval from the generator
interconnection queue. . ..... .
Limited Generation Output
In response to the Seller's request to come on line by the end of the year with a limited generation
output, IPC conducted additional power flow models. It was determined that acceptable voltage on the
46 kV system could be maintained with 4.0 MW .,of generation from Notch Butte Wind Park if the
generators have the ability to absorb 3.0 MVAr. The installation of a 46 kV potential transformer
transfer/trip package would have to be added to the scope/costs of the work at Dietrich substation. The
Seller will be responsible for absorbing the VArs (3.0 maximum) necessary to maintain a 1.075 p.u.
maximum 46 kV bus voltage at Dietrich .. sup_station. A voltage level above 1.075 p.u. will cause the
generator to be tripped offline . '
Idaho Power will provide the magnitude ohhe 46kv:'bul? voltage ~'t Dietrich station to the customer's
control system. The voltage value will be ilittade available ,fo the seller's control system via the
measurement device at Dietri ¢!1 (~'.9 .. meter or 'reJay) an~ a direct, s~rial connection via the new feeder
ADSS fiber optics. Data Pfotocol '~n'tl point format,tiIl9':{0 be determined.
The estimated cost of ' this additional work is $75,000. This brings the total estimated project cost to
$7,950,000. If the Gefleration Interconnection Agreement is signed and the project is funded before
May 1st. 2012, then IPC6 will have tfleJi:rciliti.es neces§ary for this limited generation output in place by
December 15th, :2012. .• C " ••
Critical. 'milestones and responsibility as agreed to by the Parties:
Under ihnited above
12/1/2012
12/15/2012
'12i15i2012 --
IIPCO receives the remaining balance of Construction
iestimate $7,950,000 OR Credit arrangements are approved
___ __ i!!y.H~£9 __ ._. __ ."",, .. _._._. ___ . _ ... _________ .. __ -._ -.. --... 1
,Seller :Customer GOLC ready to connect & customer telecomm
_ __ , ./equiremenls a!f!. E~.'!}E/~f! ___ _ ~ ___ . . _ . __ .. __ .. __
'IPCO ,1PCO Construction Complete
•••• --•• _._-----.. --•• -•• --_I. _._ ______ __ ___ -
1PCO i1PCO Commissioning Complete
:12115/2012 _. :/PCO -"-;Project Le~d-;r issues Co~stru~tion Complete-Letter
:12/15J2012------_.-, ----JPCO -'--iM~~ager-;'-Grid operidTons-~~;thori~~s proje~t to be
!energized, upon verification that Seller has previously met
~ct!~~ule 72, Sec 7 In~,!ra[2c!!. rf!..gu!rf}mf}nts
12/15/2012 :Seller :Customer testing begins _. 1 ____ -__ • ___ • _____ .. _ __ _
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u.C. No. 29, Tariff No. 101 Page 2 of 2
. --~~-.. ---------... ---.------,._ .. -------... _--
iTBP by Seller-usually 1 iSeller !Customer's requested In-Service Date
!1l!9.n.1b.J?_t~!1-9E.I().Q.9~~ ._ .. __ ..L •..•.••• _ .• _! .• __ ___ _ _. __ ••.•. _____ w ••
Critical milestones and responsibility as agreed to by the Parties:
Under full out ut
r eller IPca receives the remaining balance of Construction i
jestimate $XXX OR Credit arrangements are approved by I
j IPCO 1-I I :~~:~:~~~ ~ __ ~ .. -~_-_~. . =-_lse~er·-=~~t,';;;::~;~;:~f~hr/e~&·CIJStOmer tel.com~=
14/1/2015 IPCO I/PCa Construction Complete · ,
r3415/201 5 --. "---ripco IIPCO CommisS{QQjng Compiete--;, -. -:, .--'--'---'--
~i15i2015---." -.. ---.--i ipc6·----1 pro}ect Leader js~-U~;·'Consti-ucti~n C"amplete Lett~;----'. ----. --. ---.. --"--'---I --_.-.. -I '---"-. --_._. ---..... -'-~'-------.-.-.
14/15/2015 I'PCO Manage~'Rff?iid Operations authorizes proje~r to be ;
, I lenerg;zeo, l/po..n verific~~tQI'J 'that Se~/er has pr~viously met I ___ ____ I Schedule 72, -Sec 7 In~urpt1ce reqUfr..~_ments I
14/15/2015 ;Seller Customer tesilrig);ygins , t-~.--. ---.--~-... .--,,,------.------.-.. ---.----1 i~~~t~J?~::~e~~);~;Z_~. __ . !S~/:~~ ... __ :" ~~~~~mer~ re~ue~~:~.~:~.~_~:i.~~_~.~t: .. _. __ ... ____ ..... _ ..... ____ .J
Idaho Power requires apprOXimately ftljilty-four {~4r months 'to "complete design, procurement,
construction, permitting, pnd commissioning of the necessary interconnection facilities and required
upgrades associated with the Notch Butte Wind Park Project prior to the Commercial Operation Date
for full output. This thTleframe will be further d~talled and specified in the Generator Interconnection
Agreement and assumes that material can be procured , labor resources are available, and that
outages to the existing system are available to be.scheduled.
'j,
There is apprOXimately 1.5 triiles of the existlng.-46 kV transmission line which is located on BLM
land. A permit (ROW grant).wi.1I be required from the BLM in order to re-build this portion of the line
for the double circUit transmission as well as the 138 kV transmission line switches where the new
1,3~, kV line connects ·tQ. the existing transmission line. Obtaining a ROW grant from the BLM is
never guaranteed and is"jo/pically a.';W-30 month process at this point in time. This is outside of
Idaho Power's control. If the ROW glrant is denied then a new interconnection solution would be
required and this could drastically alter project costs and timeline.
Agreed to by:
For the Seller:
For the Transmission Provider
Idaho Power Company
Oate ______ _
Oate ______ _
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No.1 01 Page 1 of 2
Attachment 4
Additional Operating Requirements for the Company's Transmission System and Affected Systems
Needed to Support the Seller's Needs
The Company shall also provide requirements that must be met by the Seller prior to initiating
parallel operation with the Company's Transmission System.
Operating Requirements
The project is required to comply with the applicable Voltage and CurrentDi$tortion Limits found in
IEEE Standard 519-1992 IEEE Recommended Practices and Requirements for Harmonic Control in
Electrical Power Systems or any subsequent standards as they may!?~updated from time to time.
Seller will be able to modify power plant facilities on the generator Side ofttJe Interconnection Point with
no impact upon the operation of the transmission system wh~never the generatiqn facilities are
electrically isolated from the transmission system via the A~13',and A-14 switches 'and a terminal
clearance is issued by Idaho Power Company's Grid Op~Q:!tbr. "
Generator Output Limit Control (liRe-dispatch" or '~GOLC") The Project will be subject to
reductions directed by Idaho Power Company Grid 6p~r~tions during transmission system
contingencies and other reliability events. When these con"Clitions 'occur, the Project will be subject to
Generator Output Limit Control ("GOle") ~nd have equipme dt capable of receiving signals from Idaho
Power for GOlC. Generator Output LimWG<:>t!trol will be a setpJ)int from Idaho Power to the Project
indicating maximum output allowed. See Af!abhm.ent 7 for details.-
Voltage flicker at startupand during operation \;iill be Ilmi~~(HQ,I~ss than;~% as measured at the
Interconnection Point. It is pr.eferable to bring '~a~h gef1~ratin~f4JJlqnline separately to minimize
voltage flicker on the distribqtioff &y.st~Q1. !. i:" ' ,:'
" ......
• : :,.. ~;:: !"t . ';: ~:;. :
Low Voltage Ride T/JrQu:gh . '"
The Project must be capable of riding thr.ough faults 'on adjacent section of the power system without
tripping due to low voltage. It has ~eEmdet~rmined, thto~gh study, that the Project must be capable of
remaining interconnect for $.ny single phase voltage~s low as 0.7 PU for 30 cycles, and for all three
phase volt~ge.~q3S loW, as 0.s:rp4 '(Or 30 cycles.:'," "
.. , " . J
Grou~.(1 Fa''ult Equipn1-eiit .. :' -
The Seller will install tranSfqr:mer co'nfrgyrations that are Grounded-Wye to Grounded-Wye and will limit
the contl,lbl,ltion of the ground-J~~lt curre'm.t'to 20 amps or less at the Interconnection Point.
Meteorloglei/} Qata
Historical wind data -Within 60 days after execution of this Agreement, the Seller shall provide Idaho
Power with the following: ,
a) historical wind dat~ in an electronic format from the proposed Facility site or for a location within
two miles of the Facility site.
b) a third party wind assessment study report used by Seller to value investment in the Facility.
No later than 30 days prior to the Commercial Operation Date, the Seller shall have:
a) Erected at the site at least one (1) high quality, approximate hub-height (plus or minus 20
meters), permanent, meteorological wind measurement tower(s) at location(s) on the site equipped
with:
(i)
(ii)
(iii)
(iv)
Two (2) anemometers per tower;
Two (2) air temperature sensors per tower;
One (1) barometric pressure sensor (with DCP sensor); and
Two (2) wind vanes per tower.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 2 of 2
Facility availability status shall be provided as described in the Final Facility Study no later than within
the calendar month following the month of the Commercial Operation Date. Failure by the Seller to
operate and maintain this equipment to provide such meteorological and turbine availability data in a
manner to provide reasonably accurate and dependable data for the full term of this Agreement shall be
an event of Default under paragraph 6.5.1.
"
• ,1-
.... :..... . .....
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u.C. No. 29, Tariff No.1 01 Page 1 of 1
Attachment 5
Reactive Power Requirements
The project must be controlled to operate at unity power factor +/-500 kVar .
Voltage flicker at startup and during operation will be limited to less than 5% as measured at the
Interconnection Point.
;"
,,"
" ,
Idaho Power Company Generator Interconnection Agreement # 349/359
I,P.U.C. No. 29, Tariff No. 101 Page 1 of 2
Attachment 6
Company's Description of Special Facilities and Upgrades Required to Integrate the Generation Facility
and Best Estimate of Costs
As provided in Schedule 72 this Attachment describes Upgrades, Special Facilities, including
Network Upgrades, and provides an itemized best estimate of the cost of the required facilities.
Upgrades
Upgrades to Substation Facilities
Two new 12.5 kV feeder bays with associated switches, breakers, relays etc at Dietrich substation
A new 138:12,5 kV power transformer and associated equipment at Dietrich substation with protection
package, control building.
Line relay and microwave upgrades at Midpoint substation
DTRC-MPSN microwave reflector site (near Notch Butte)
Upgrades to Distribution Facilities ....
A new double circuit (DTRC-013 and 014) 12.5 kV distribution line from Dietrich subs'a.tion to the point
of interconnection (4 miles). This new distribution lihEUNill be built with 795 MC conductor on both
circuits with ADSS underbuild.
Upgrades to Transmission Facilities
Idaho Power will rebuild 4 miles of the ex'isting 46 kV transmis~ion line (T-128) with a double circuit
transmission line that will accommodate both the existing 46 kV lin,e ,~s well as the new 138 kV line.
The new 138 kV line will then tap into the existing Midpoint-Silver 138 kV line with line switches on all
three sides of the tap, .
The following good faith estimates are provided in 201 Z dollars:
I ;lnt~.r~C!~!J..eclj,~1J. F~c!!~!~~~.L . __ "_" __ .
J!1~~.r.9olJn_ec~<?!!.f.9 ck~.ges J~-) _ . _, _ ._._ ~~_~._ .. 'j1P9 -_.'~".~~,'==~~ ~~MO,OOO '-=-~' ... :~~~
,~js.!r[~'!_tLC?'!.!Jp'g!.C!ct..e.!§.: . _ _ .__ _ _
Distributloil' Feeders to· bietrich 'Substation (DTRC-013
& 121J~.Q~~.1 ~2 wit~t\DS§.· fib,~r ._. .' __ .
I i ~ _, __ ' __ ~ ___ • ____ -••• __ II ,
_$y'b~'C!!i.~~ !!egraq~~: .. _ _ __ --.-. -" .................. _._...... _ .. , ..... _ .. _ ...... _-
:Dietrich SUbstation Additions -<-----.--~ .-~:.. .-. -----. -~ ... _ .... , ... _. _ __ ;!P9 _ _._._ _ ... _:$2,~~5,0Q.9
~idp_~inJ_ Relay:.ypgrades. , __ . _ ... __ . . J!Pg _." ___ ", ___ .!~.6~!Q9.Q._, _
iIP.~ _ .... _._ ............ ;~J~Q1Q.Q_Q .. __ .... __ ",
IPC . ___ .. _ .... __ 1$~~~~Q.00 ___ . _ •
~J.g.p.<?jl'lt. Miqr9\,\1~Y~. !:Jpgra.9~$_:
DTRC-MPSON Microwave Reflector Site • __ -0-__ __ .. _.!. __ o_ __
rriJ.lJs!!,i~sion Upgr~~e.~: .. _ ..
Remove 4 miles of 46 kV line with underbuild 'IPC
:IPC
!IPC
IPC
$130,000 -. . . . --_.
Build 4 miles of line to double circuit :$2,550,000 -. .... . . _. -. . ~ ... -. -~ .. -.... ----
3 -138 kV Line Switches :$300,000 . .. -:$75,000
GRAND TOTAL :$7 ,8~.s,OOO
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 2 of 2
*There is approximately 1.5 miles of the existing 46 kV transmission line which is located on BLM land.
A permit will be required from the BLM in order to rebuild this portion of the line to double circuit as well
as install the transmission line switches. The costs for this permitting can vary widely and have been
estimated at a combined $75K.
Note Regarding Transmission Service:
This Facility Study is a Network Resource Interconnection Facility Study. This study identifies the
facilities necessary to integrate the Generating Facility into Idaho Pow~r's. network to serve load
within Idaho Power's balancing area. Network Resource Interconneq1ion Service in and of itself
does not convey any right to deliver electricity to any specific custol')1er or Point of Delivery.
~ .
, 'J I .~. • ••
..
'.
, '"
. . ·-'~ .. 'l"
I!l
, .... 1
Idaho Power Company Generator Interconnection Agreement # 349/359
LP.U.C. No. 29. Tariff No. 101 Page 1 of 2
Attachment 7
Generation Interconnection Control Requirements
Generator Output Limit Control (GOLC)
IPC requires Interconnected Power Producers to accept GOlC signals from our EMS.
The GOlC signals will consist of two points shared between the IPC EMS and the Customer's
Generator Controller:
GOlC Setpoint: An analog output that contains the MW value the Customer should curtail to. should a
GOlC request be made via the GOlC On/Off discrete output Control.pOjht. /. ,.' I" ", An Analog Input feedback point must be updated (to reflect the GOl.,;C setppint value) by the Customer
Controller upon the Controller's receipt of the GOlC setpoint change, with no intentional delay, .-:. .. •• )1..' , ·'fl-
GOlC On/Off: A discrete output (~O) control point with latching Off/On states. FolI(:>"Ying a "GOlC On"
control, the Customer Controller will run power output back to the MW value specifj~d'J.n the GOlC
Setpoint. Following a "GOlC Off' control. the Custorne'r is free to run to maximum pcisslble output.
A Discrete Input feedback point must be updated (to reflect the GOlCpO state) by the Cl.tfstomer
Controller upon the Controller's receipt of the GOlC DO state change": with no intentional delay.
If a GOlC control is issued, it is expecteq to~s~e MW reductj'on.~ start within 1 minute and plant output
to be below the GOlC Setpoint value witflln', 1 0 min\Jtes. '\, ~
Voltage Control .r:-~~ .'~-.e". : . ~j
Idaho Power Company requires Transmission-interconne<;:teq PQ'vjIer p'roducers to accept Voltage
Control signals from our EMS;,:Whentbey are conn~cted to our transmission system,
The voltage control will ,coilsist of one '$etpoint shat~d between the IPC EMS and the Customer Controller. . .... . " '.'
The setpoint will contain th¢desir~JJJargetVqlt~ge for the plant to operate at.
The contrQI \.\'i'II '~IW~YS be act;v~,there is no digital '~uperviSOry point like the Curtail On/Off control
above. ' , '
When c;:I setpoint change i~ ,issued '~[r A,nalog Input feedback point must be updated (to reflect the
Voltage Control setpoint vaiue) by the CI.J~tomer Controller upon the Controller's receipt of the Voltage
Control s9,tpoint change, with no intentional delay.
When a se~point change is re~ived by the Customer Controller, the Voltage Control system should
react with no'iM~lltional delay.
The voltage coritrQl $ystemSh6i.Jld operate in a dead band of +/-5% of the control setting range.
',-".:.:, ,'r .',:,:'
The customer should slJpervise this control by setting up "reasonability limits", I.e, configure a
reasonable range of values for this control to be valid. As an example, they will accept anything
between ,95 and 1.05 for the set point. In the case they are fed an erroneous value outside this range,
their control system defaults to the last known, good value.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 2 of 2
Generation Interconnection Data Points Requirements
Digital Inputs to IPCo (DNP Obj. 01, Var. 2)
Index Description State (0/1) Comments:
0 52A Customer Capacitor Breaker (if present) Open/Closed Sourced at substation
1 GOlC Off/On Control Received (Feedback) Off/On Provided by Customer
Digital Outputs to Customer ('DNP Obj. 10, Var.1)
Index Description Comments:
0 GOlC Off/On Provided fjy IPCO
NOTE: GOlC Setpoint indicates MW value to curtail to_when Gale Off/On DO is ON.
-
Analog Inputs to IPCo (DNP Obj. 30, Var, 2)
Raw ·Raw EU .. EU
Index Description . -',I .. ,-
Hig/:l Low High EU loW ,Units Comments:
Gale Setpoint Value Received -Provided by
0 (Feedback) 32767 32768 TSD TBD MW Customer
Voltage Control Setpoint Value Rec'd -Provided by
1 (Feedback) 32767 3~768 ;TBD TBD kV Customer
. ;<-; -". -'f Provided by
2 Maximum Park Generating CapaCity . -~' TBD MW Customer 32767 3276.~ TBD .. .. Provided by , " -
3 Number of Turbines In High Speed Cgtgut 327,6.1. ,~2768 3276.7 -32768 Units Customer
:!:. :-:" :' -" For Provided by ! •
4 Ambient Temperatur,E:t,:, '"i;; ,;). '. 32767 32768 :327.67 -327.68 C Customer , .. ->:." :':' , Provided by , . -
5 Wind Direction ,:;·.i··' '<32767 32768 3276.7 -3276.8 Deg Customer , MPH
-or Provided by
6 Wind Soeed , -~: .;,': 32V67 32768 327.67 -327.68 m/s Customer .. . , .: 1 ~ -
'" . ,-,,,
Analog ,(ljutPlits't'o ~OQstomer..car·W Obj. 40, Var. 2)
c Raw Raw EU EU EU
Index' ~Pescription .. High low High low Units Comments:
, -
0 Gole Setpoint ~.-32767 32768 TBD TBD MW Provided by IPeo
.' -
1 Voltage CPJltrol Setpoih.t , 32767 32768 TBD TBD kV Provided by IPCO .. --,
NOTE: CLirtailment Setpoint indicates MW value to Curtail to when Curtailment Off/On DO is ON . .. ..
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 51
Walker, Donovan
From: Harris, Joshua
Sent:
To:
Thursday, July 26,20121 :18 PM
Walker, Donovan
Subject:
Attachments:
FW: Draft GIA -Notch Butte # 349 & 359
DGIA349_Cover.pdf; DGIA349_359.doc; FSR349_359.pdf
Thanks,
Josh Harris
OPERATIONS ANALYST
Idaho Power I Generator Interconnection
208-388-5751
Email [e-mail]
From: Harris, Joshua
Sent: Friday, April 27, 2012 5:19 PM
To: '[e-mail]'
Cc: Kosydar, Ed
Subject: FW: Draft GIA -Notch Butte # 349 & 359
Dustin,
As per the email below and attached cover letter, we need this agreement executed by May 1,2012 in order to have
your project come on line with limited output by December 15, 2012. As of today, I have not heard from you regarding
this GIA.
Thanks,
Josh Harris I Operations Analyst I Idaho Power Company
208.388.5751
From: Harris, Joshua
Sent: Friday, April 20, 20124:29 PM
To: '[e-mail]'
Cc: Kosydar, Ed; Bauer, Rich; Sloan, Aubrae
Subject: Draft GIA -Notch Butte # 349 & 359
Dustin,
The attached is being mailed to you today. Please provide the contact information for section 9 and the items listed in
the cover letter to me by dates outlined. Please also note that we must have this agreement executed by May 1, 2012 in
order for you to come on line with limited output by December 15, 2012. .
I look forward to hearing from you soon.
Thanks,
1
Josh Harris I Operations Analyst I Idaho Power Company
1221 W. Idaho Street, Boise, Idaho 83702 I it: [phone]
~: [phone] I [;8]: [e-mail]
2
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER' COMPANY
ATTACHMENT 52
Walker, Donovan
From: Harris, Joshua
Sent:
To:
Thursday, July 26, 2012 1: 16 PM
Walker, Donovan
Subject: FW: Draft GIA -Notch Butte # 349 & 359
Thanks,
Josh Harris
OPERATIONS ANALYST
Idaho Power I Generator Interconnection
208-388-5751
Email [e-mail]
From: Dustin Shively [mailto:[e-mail]]
Sent: Monday, April 30, 2012 7:11 AM
To: Harris, Joshua; Kosydar, Ed
Cc: James carkulis; Elizabeth Woolstenhulme; Lawrence R. Leib; Josh Gunderson
Subject: RE: Draft GIA -Notch Butte # 349 & 359
Ed/Josh:
Before we continue forward to execute and fund the GIA, we need to inform IPCo of a configuration change for the
Notch Butte Project. We will be moving the POI from the project site to the Dietrich substation and providing 34.SkV at
that point.
Please let us know what steps need to be taken for this modification to be in place.
Thank you,
Dustin
Dustin Shively
Energv Systems Engineer ~
exergy 802 '1'./ Bannock, 12th Fio!]I' Boise ID 83702
Office: 208.336.9793
ThiS ele·;t,ronic or pr::!te·j ::oc!jrr.en~ CGntai()~ 'ntG;r~<:lt;(jP '\.·;";!:~h 31 --Po'! :)8 ~EGALL Y PRi\flLEG:::-D PROPRIET '~R'f ;;-..1 ~,J .:\';-uHE OR \:1 rr~'::R\N:::;:: :>R0T,:::~-, rEO ~;~; L/ll/'/
FRO~"I DISCLOSljRE and It.i IS ;nlended 0(':/ lor .:ne uSe of Ule f-'\ddnsss;;s(:j) na('-'ed a~)G ;'; 1f fi1i:; ri~:v:12( c: iJ'""1l:': :"''3,)3399 \s r:ot (he ;":;r:r:;.:-;(J ('3,:t"C'-=!"'i. 'Jr ~re ~~rO;G /"~S C ..
:1qe:"t responSiole to de!tver it :0 lile In'-e.:ded reGIO!9nt yeu are he:,eby ;,.otlflAd t~lai arw ,j15S,:(7'i[~ar~""jr Cisir;;::ut;cn,:.( ce'p/:i1y c:f ~r\1~ c(:r ...... ,""nui"C.:3tiCn :s str'I.:~i'! o:criOlled ii '(:) .....
h8\'-9 1'9celv~d ti:IS comrnUr!Catlon \'-', errOl pieas.~ rn'·1T'8dl=3tel:-, flolfr'·,' LIS b,/ lelcphc!':B ard rar".1ii": :i'e ::.r~gl""3! l.,eSff.:ge f/) liS 3t 'i~e .:'t,.)",~ ,=,r:-.:;,;i =3:'~CYc5:; i :"0";: ;,:1,
From: HarriS, Joshua [mailto:[e-mail]]
Sent: Friday, April 27, 2012 5:19 PM
To: Dustin Shively
Cc: Kosydar, Ed
Subject: FW: Draft GIA -Notch Butte # 349 & 359
1
Dustin.
As per the email below and attached cover letter, we need this agreement executed by May 1, 2012 in order to have
your project come on line with limited output by December 15, 2012. As of today, I have not heard from you regarding
this GIA.
Thanks,
Josh Harris I Operations Analyst I Idaho Power Company
208.388.5751
From: Harris, Joshua
Sent: Friday, April 20, 2012 4:29 PM
To: '[e-mail]'
Cc: Kosydar, Ed; Bauer, Rich; Sloan, Aubrae
Subject: Draft GIA -Notch Butte # 349 & 359
Dustin,
The attached is being mailed to you today. Please provide the contact information for section 9 and the items listed in
the cover letter to me by dates outlined. Please also note that we must have this agreement executed by May 1, 2012 in
order for you to come on line with limited output by December 15, 2012.
I look forward to hearing from you soon.
Thanks,
Josh Harris I Operations Analyst I Idaho Power Company
1221 W. Idaho Street, Boise, Idaho 83702 I .: (20B) 388-5751
~: (20B) 433-3571 I [8]: [e-mail]
This transmission may contain information that is privileged, confidential andlor exempt from disclosure Wlder applicable law. If you are not the intended recipient, you are hereby
notified that any disclosure, copying, distribution, or use of the information contained herein (including any reliance thereon) is STRICTLY PROHIBITED. If you received this
transmission in error, please immediately contact the sender and destroy the material in its entirety, whether in electronic or bard copy format. Thank you.
2
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 53
May 23, 2012
Mr. Dustin Shively
Exergy Development Group of Idaho
802 W. Bannock, Suite 1200
Boise, Idaho 83702
Subject: Notch Butte Wind Park Projects -GI #349 & #359
Dear Mr. Shively,
An IDACORP company
This letter is in response to your email dated April 30, 2012, requesting a change in both the
Point of Interconnection and the interconnection voltage for the Notch Butte Wind Park Projects
(GI 349 & 01 359). As you will recall, these projects are at the final facility study stage and
Idaho Power included specific accommodations for this interconnection -at your request -to
allow the projects to come online with limited output prior to completion of the remaining
upgrades required to interconnect the entire project. We had informed you that in order to bring
the limited output online by December 15, 2012, that you must execute the OIA and pay the
required construction funding no later than May 1, 2012, to allow the necessary time to bring the
limited output online prior to the end of the year. Rather than paying the required construction
deposit and authorizing the work to move forward, Idaho Power received from you on April 30
your request to change the point of interconnection and to change the interconnection voltage,
both of which are different than that which was contained in the facility study for the project. As
you have been informed, the interconnection may be made to voltage levels that are present on,
or planned for, on Idaho Power's system near the point of interconnection. The available
interconnection voltages at Dietrich substation are 12.5 kV, 46 kV (both present) and 138 kV
(planned for the future). Idaho Power is not planning for 34.5 kV voltage in this area, which you
have now requested. Changing the Point of Interconnection and/or voltage level will require
you to submit a new generation interconnection application.
As we have communicated to you previously, because you have not paid the required
construction funding nor executed the required OIA, we are unable to bring your submitted
project online by your requested date of December 15, 2012. As stated above, in order to have
connected you by such date at reduced/limited output, we needed an executed OIA and funding
by May 1, 2012. As of May 23, 2012, we do not have an executed GIA nor funding for this
project. At this point your requested interconnection date of December 15,2012, cannot be met -
even under the limited output scenario described in the Facility Study Report.
I have included with this letter a final copy of the OIA for this project. Failure to submit an
executed copy and have funding in place by June 23, 2012 will result in Idaho Power
terminating the present generator interconnection request and withdrawing the Notch Butte Wind
Park Projects from the generator interconnection queue. If you wish to proceed forward with the
interconnection as set forth in the final facility study, and OIA, you must execute the orA by
signing and submitting both copies and pay the required funding by June 23, 2012. In addition,
1221 W. Idaho St. (33702)
P.O. Box 70
C,..'r .... In Q1?n7
Dustin Shively Page 2 of2 May 23,2012
Idaho Power must receive your proof of site control and insurance certification pursuant to
Section 7 of the agreement. Please let me know if you have any further questions.
Sincerely,
Josh Harris
Operations Analyst
Idaho Power Company
208-388-5751
cc: Donovan Wa1ker~C
Ed Kosydar/JPC
Tess ParklIPC
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101
May 23,2012
GENERATOR INTERCONNECTION AGREEMENT
Schedule 72
Notch Butte Wind Park PROJECTS #349 & #359
6.5/ 11.5 MW
Idaho Power Company Generator Interconnection Agreement # 349/359
I,P.U.C. No. 29, Tariff No. 101
TABLE OF CONTENTS
RECiTALS .............................................................................................................................................. 1
AGREEMENTS ...................................................................................................................................... 1
1. Capitalized Terms................................................................................................................ 1
2. Terms and Conditions .......................................................................................................... 1
3. This Agreement is not an agreement to purchase Seller's power ......................................... 1
4. Attachments ......................................................................................................................... 1
5. Effective Date, Term, Termination and Disconnection .......................................................... 2
5. 2 Termination .......................................................................................................................... 2
6. Assignment. Liability, Indemnity. Force majeure, Consequential Damages and Default. ...... 5
7. Insurance ............................................................................................................................. 7
8. Miscellaneous ...................................................................................................................... 7
9. Notices ................................................................................................................................. 8
10. Signatures ............................................................................................................................ 9
Attachment 1 .......................................................................................................................................... 1
Attachment 2 .......................................................................................................................................... 1
Attachment 3 ................................................................................................................................ 0 ......... 1
Attachment 4 ................................................................................................ ~ ... 0 ..................................... 1
Attachment 5 .......................................................................................................................................... 2
Attachment 6 .......................................................................................................................................... 1
Attachment 7 .......................................................................................................................................... 1
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u .C. No. 29, Tariff No. 101 Page 1 of 9
This Generator Interconnection Agreement ("Agreement") under Idaho Power Company's
Schedule 72 is effective as of the 19 day of April, 2012 between Exergy Development Group of Idaho,
("Seller", "Customer" or "The Project") and Idaho Power Company ("Compant,"Transmission Owner',
"Idaho Power", "IPC" or "IPCO").
RECITALS
A. Seller will own or operate a Generation Facility that qualifies for service under Idaho
Power's Commission-approved Schedule 72 and any successor schedule.
B. The Generation Facility covered by this Agreement is more particularly described in
Attachment 1.
AGREEMENTS
1. Capitalized Terms
Capitalized terms used herein shall have the same meanings as defined in Schedule 72 or in the body
of this Agreement.
2. Terms and Conditions
This Agreement and Schedule 72 provide the rates, charges, terms and conditions under which the
Seller's Generation Facility will interconnect with, and operate in parallel with, the Company's
transmission/distribution system. Terms defined in Schedule 72 will have the same defined meaning in
this Agreement. If there is any conflict between the terms of this Agreement and Schedule 72,
Schedule 72 shall prevail.
3. This Agreement is not an agreement to purchase Seller's power.
Purchase of Seller's power and other services that Seller may require will be covered under separate
agreements. Nothing in this Agreement is intended to affect any other agreement between the
Company and Seller.
4. Attachments
Attached to this Agreement and included by reference are the following:
Attachment 1 -Description and Costs of the Generation Facility, Interconnection
Facilities, and Metering Equipment
Attachment 2 -One-line Diagram Depicting the Generation Facility, Interconnection
Facilities, Metering Equipment and Upgrades.
Attachment 3 -Milestones for Interconnecting the Generation Facility
Attachment 4 -Additional Operating Requirements for the Company's Transmission
System Needed to Support the Seller's Generation Facility
Attachment 5 -Reactive Power
Attachment 6 -Description of Upgrades required to integrate the Generation Facility and
Best Estimate of Upgrade Costs
Attachment 7 -Generator Interconnection Control Requirements
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U .C. No. 29, Tariff No.1 01 Page 2 of 9
5. Effective Date, Term, Termination and Disconnection.
5.1 Term of Agreement. Unless terminated earlier in accordance with the provisions
of this Agreement, this Agreement shall become effective on the date specified above and remain
effective as long as Seller's Generation Facility is eligible for service under Schedule 72.
5. 2 Termination.
5.2. 1 Seller may voluntarily terminate this Agreement upon expiration or
termination of an agreement to sell power to the Company.
5.2.2 After a Default, either Party may terminate this Agreement pursuant to
Section 6.5.
5.2.3 Upon termination or expiration of this Agreement, the Seller's Generation
Facility will be disconnected from the Company's transmission/distribution system. The termination or
expiration of this Agreement shall not relieve either Party of its liabilities and obligations, owed or
continuing at the time of the termination. The provisions of this Section shall survive termination or
expiration of this Agreement.
5.3 Temporary Disconnection. Temporary disconnection shall continue only for so
long as reasonably necessary under "Good Utility Practice. 11 Good Utility Practice means any of the
practices, methods and acts engaged in or approved by a significant portion of the electric industry
during the relevant time period, or any of the practices, methods and acts which, in the exercise of
reasonable judgment in light of the facts known at the time the decision was made, could have been
expected to accomplish the desired result at a reasonable cost consistent with good business practices,
reliability, safety and expedition. Good Utility Practice is not intended to be limited to the optimum
practice, method, or act to the exclusion of all others, but rather to be acceptable practices, methods, or
acts generally accepted in the region. Good Utility Practice includes compliance with WECC or NERC
requirements. Payment of lost revenue resulting from temporary disconnection shall be governed by
the power purchase agreement.
5.3.1 Emergency Conditions. "Emergency Condition" means a condition or
situation: (1) that in the judgment of the Party making the claim is imminently likely to
endanger life or property; or (2) that, in the case of the Company, is imminently likely (as
determined in a non-discriminatory manner) to cause a material adverse effect on the
security of, or damage to the Company's transmission/distribution system, the
Company's Interconnection Facilities or the equipment of the Company's customers; or
(3) that, in the case of the Seller, is imminently likely (as determined in a non­
discriminatory manner) to cause a material adverse effect on the reliability and security
of, or damage to, the Generation Facility or the Seller's Interconnection Facilities. Under
Emergency Conditions, either the Company or the Seller may immediately suspend
interconnection service and temporarily disconnect the Generation Facility. The
Company shall notify the Seller promptly when it becomes aware of an Emergency
Condition that may reasonably be expected to affect the Seller's operation of the
Generation Facility. The Seller shall notify the Company promptly when it becomes
aware of an Emergency Condition that may reasonably be expected to affect the
Company's equipment or service to the Company's customers. To the extent
information is known, the notification shall describe the Emergency Condition, the extent
of the damage or deficiency, the expected effect on the operation of both Parties'
facilities and operations, its anticipated duration, and the necessary corrective action.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 3 of 9
5.3.2 Routine Maintenance, Construction, and Repair. The Company may
interrupt interconnection service or curtail the output of the Seller's Generation Facility
and temporarily disconnect the Generation Facility from the Company's
transmission/distribution system when necessary for routine maintenance, construction,
and repairs on the Company's transmission/distribution system. The Company will
make a reasonable attempt to contact the Seller prior to exercising its rights to interrupt
interconnection or curtail deliveries from the Seller's Facility. Seller understands that in
the case of emergency circumstances, real time operations of the electrical system,
and/or unplanned events, the Company may not be able to provide notice to the Seller
prior to interruption, curtailment or reduction of electrical energy deliveries to the
Company. The Company shall use reasonable efforts to coordinate such reduction or
temporary disconnection with the Seller.
5.3.3 Scheduled Maintenance. On or before January 31 of each calendar year,
Seller shall submit a written proposed maintenance schedule of significant Facility
maintenance for that calendar year and the Company and Seller shall mutually agree as
to the acceptability of the proposed schedule. The Parties determination as to the
acceptability of the Seller's timetable for scheduled maintenance will take into
consideration Good Utility Practices, Idaho Power system requirements and the Seller's
preferred schedule. Neither Party shall unreasonably withhold acceptance of the
proposed maintenance schedule.
5.3.4. Maintenance Coordination. The Seller and the Company shall, to the
extent practical, coordinate their respective transmission/distribution system and
Generation Facility maintenance schedules such that they occur simultaneously. Seller
shall provide and maintain adequate protective equipment sufficient to prevent damage
to the Generation Facility and Seller-furnished Interconnection Facilities. In some cases,
some of Seller's protective relays will provide back-up protection for Idaho Power's
facilities. In that event, Idaho Power will test such relays annually and Seller will pay the
actual cost of such annual testing.
5.3.5 Forced Outages. During any forced outage, the Company may suspend
interconnection service to effect immediate repairs on the Company's
transmission/distribution system. The Company shall use reasonable efforts to provide
the Seller with prior notice. If prior notice is not given, the Company shall, upon request,
provide the Seller written documentation after the fact explaining the circumstances of
the disconnection.
5.3.6 Adverse Operating Effects. The Company shall notify the Seller as soon
as practicable if, based on Good Utility Practice, operation of the Seller's Generation
Facility may cause disruption or deterioration of service to other customers served from
the same electric system, or if operating the Generation Facility could cause damage to
the Company's transmission/distribution system or other affected systems. Supporting
documentation used to reach the decision to disconnect shall be provided to the Seller
upon request. If, after notice, the Seller fails to remedy the adverse operating effect
within a reasonable time, the Company may disconnect the Generation Facility. The
Company shall provide the Seller with reasonable notice of such disconnection, unless
the provisions of Article 5.3. 1 apply.
5.3. 7 Modification of the Generation Facility. The Seller must receive written
authorization from the Company before making any change to the Generation Facility
that may have a material impact on the safety or reliability of the Company's
transmission/distribution system. Such authorization shall not be unreasonably withheld.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 4 of 9
Modifications shall be done in accordance with Good Utility Practice. If the Seller makes
such modification without the Company's prior written authorization, the latter shall have
the right to temporarily disconnect the Generation Facility.
5.3.8 Reconnection. The Parties shall cooperate with each other to restore the
Generation Facility, Interconnection Facilities, and the Company's
transmission/distribution system to their normal operating state as soon as reasonably
practicable following a temporary disconnection.
5.3.9 Voltage Levels. Seller, in accordance with Good Utility Practices, shall
minimize voltage fluctuations and maintain voltage levels acceptable to Idaho Power.
Idaho Power may, in accordance with Good Utility Practices, upon one hundred eighty
(180) days' notice to the Seller, change its nominal operating voltage level by more than
ten percent (10%) at the Point of Delivery, in which case Seller shall modify, at Idaho
Power's expense, Seller's equipment as necessary to accommodate the modified
nominal operating voltage level.
5.4 Land Rights.
5.4.1 Seller to Provide Access. Seller hereby grants to Idaho Power for the
term of this Agreement all necessary rights-of-way and easements to install, operate,
maintain, replace, and remove Idaho Power's Metering Equipment, Interconnection
Equipment, Disconnection Equipment, Protection Equipment and other Special Facilities
necessary or useful to this Agreement, including adequate and continuing access rights
on property of Seller. Seller warrants that it has procured sufficient easements and
rights-of-way from third parties so as to provide Idaho Power with the access described
above. All documents granting such easements or rights-of-way shall be subject to
Idaho Power's approval and in recordable form.
5.4.2 Use of Public Rights-of-Wav. The Parties agree that it is necessary to
avoid the adverse environmental and operating impacts that would occur as a result of
duplicate electric lines being constructed in close proximity. Therefore, subject to Idaho
Power's compliance with Paragraph 5.4.4, Seller agrees that should Seller seek and
receive from any local, state or federal governmental body the right to erect, construct
and maintain Seller-furnished Interconnection Facilities upon, along and over any and all
public roads, streets and highways, then the use by Seller of such public right-of-way
shall be subordinate to any future use by Idaho Power of such public right-of-way for
construction and/or maintenance of electric distribution and transmission facilities and
Idaho Power may claim use of such public right-of-way for such purposes at any time.
Except as required by Paragraph 5.4.4, Idaho Power shall not be required to
compensate Seller for exercising its rights under this Paragraph 5.4.2.
5.4.3 Joint Use of Facilities. Subject to Idaho Power's compliance with
Paragraph 15.4.4, Idaho Power may use and attach its distribution and/or transmission
facilities to Seller's Interconnection Facilities, may reconstruct Seller's Interconnection
Facilities to accommodate Idaho Power's usage or Idaho Power may construct its own
distribution or transmission facilities along, over and above any public right-of-way
acquired from Seller pursuant to Paragraph 5.4.2, attaching Seller's Interconnection
Facilities to such newly constructed facilities. Except as required by Paragraph 5.4.4,
Idaho Power shall not be required to compensate Seller for exercising its rights under
this Paragraph 5.4.3.
5.4.4 Conditions of Use. It is the intention of the Parties that the Seller be left in
substantially the same condition, both financially and electrically, as Seller existed prior
Idaho Power Company Generator Interconnection Agreement # 349/359
LP.U.C. No. 29, Tariff No. 101 Page 5 of 9
to Idaho Power's exercising its rights under this Paragraph 5.4. Therefore, the Parties
agree that the exercise by Idaho Power of any of the rights enumerated in Paragraphs
5.4.2 and 5.4.3 shall: (1) comply with all applicable laws, codes and Good Utility
Practices, (2) equitably share the costs of installing, owning and operating jointly used
facilities and rights-of-way. If the Parties are unable to agree on the method of
apportioning these costs, the dispute will be submitted to the Commission for resolution
and the decision of the Commission will be binding on the Parties, and (3) shall provide
Seller with an interconnection to Idaho Power's system of equal capacity and durability
as existed prior to Idaho Power exercising its rights under this Paragraph 5.4.
6. ASSignment. Liability. Indemnity. Force majeure, Consequential Damages and Default.
6. 1 Assignment. This Agreement may be assigned by either Party upon twenty-one
(21) calendar days prior written notice and opportunity to object by the other Party; provided
that:
6.1.1 Either Party may assign this Agreement without the consent of the other
Party to any affiliate of the assigning Party with an equal or greater credit rating and with
the legal authority and operational ability to satisfy the obligations of the assigning Party
under this Agreement.
6.1.2 The Seller shall have the right to contingently assign this Agreement,
without the consent of the Company, for collateral security purposes to aid in providing
financing for the Generation Facility, provided that the Seller will promptly notify the
Company of any such contingent assignment.
6.1.3 Any attempted assignment that violates this article is void and ineffective.
Assignment shall not relieve a Party of its obligations, nor shall a Party's obligations be
enlarged, in whole or in part, by reason thereof. An assignee is responsible for meeting
the same financial, credit, and insurance obligations as the Seller. Where required,
consent to assignment will not be unreasonably withheld, conditioned or delayed.
6.2 Limitation of Liability. Each Party's liability to the other Party for any loss, cost,
claim, injury, liability, or expense, including reasonable attorney's fees, relating to or arising from
any act or omission in its performance of this Agreement, shall be limited to the amount of direct
damage actually incurred. In no event shall either Party be liable to the other Party for any
indirect, special, consequential, or punitive damages, except as authorized by this Agreement.
6.3 Indemnitv.
6.3. 1 This provision protects each Party from liability incurred to third parties as
a result of carrying out the provisions of this Agreement. Liability under this provision is
exempt from the general limitations on liability found in Article 6.2.
6.3.2 The Parties shall at all times indemnify, defend, and hold the other Party
harmless from, any and all damages, losses, claims, including claims and actions
relating to injury to or death of any person or damage to property, demand, suits,
recoveries, costs and expenses, court costs, attorney fees, and all other obligations by
or to third parties, arising out of or resulting from the other Party's action or failure to
meet its obligations under this Agreement on behalf of the indemnifying Party, except in
cases of gross negligence or intentional wrongdoing by the indemnified Party.
6.3.3 If an indemnified person is entitled to indemnification under this article as
a result of a claim by a third party, and the indemnifying Party fails, after notice and
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 6 of 9
reasonable opportunity to proceed under this article, to assume the defense of such
claim, such indemnified person may at the expense of the indemnifying Party contest,
settle or consent to the entry of any judgment with respect to, or pay in full, such claim.
Failure to defend is a Material Breach.
6.3.4 If an indemnifying party is obligated to indemnify and hold any
indemnified person harmless under this article, the amount owing to the indemnified
person shall be the amount of such indemnified person's actual loss, net of any
insurance or other recovery.
6.3.5 Promptly after receipt by an indemnified person of any claim or notice of
the commencement of any action or administrative or legal proceeding or investigation
as to which the indemnity provided for in this article may apply, the indemnified person
shall notify the indemnifying party of such fact. Any failure of or delay in such notification
shall be a Material Breach and shall not affect a Party's indemnification obligation unless
such failure or delay is materially prejudicial to the indemnifying party.
6.4 Force Majeure. As used in this Agreement, "Force Majeure" or "an event of
Force Majeure" means any cause beyond the control of the Seller or of the Company which,
despite the exercise of due diligence, such Party is unable to prevent or overcome. Force
Majeure includes, but is not limited to, acts of God, fire, flood, storms, wars, hostilities, civil
strife, strikes and other labor disturbances, earthquakes, fires, lightning, epidemics, sabotage, or
changes in law or regulation occurring after the Operation Date, which, by the exercise of
reasonable foresight such party could not reasonably have been expected to avoid and by the
exercise of due diligence, it shall be unable to overcome. If either Party is rendered wholly or in
part unable to perform its obligations under this Agreement because of an event of Force
Majeure, both Parties shall be excused from whatever performance is affected by the event of
Force Majeure, provided that:
(1) The non-performing Party shall, as soon as is reasonably possible after
the occurrence of the Force Majeure, give the other Party written notice describing the
particulars of the occurrence.
(2) The suspension of performance shall be of no greater scope and of no
longer duration than is required by the event of Force Majeure.
(3) No obligations of either Party which arose before the occurrence causing
the suspension of performance and which could and should have been fully performed
before such occurrence shall be excused as a result of such occurrence.
Idaho Power Company Generator Interconnection Agreement # 349/359
I,P.u .C. No. 29, Tariff No. 101 Page 7 of 9
6.5 Default and Material Breaches.
6.5. 1 Defaults. If either Party fails to perform any of the terms or conditions of
this Agreement (a "Default" or an "Event of Default'?, the nondefaulting Party shall cause
notice in writing to be given to the defaulting Party, specifying the manner in which such
default occurred. If the defaulting Party shall fail to cure such Default within the sixty
(60) days after service of such notice, or if the defaulting Party reasonably demonstrates
to the other Party that the Default can be cured within a commercially reasonable time
but not within such sixty (60) day period and then fails to diligently pursue such cure,
then, the nondefaulting Party may, at its option, terminate this Agreement and/or pursue
its legal or equitable remedies.
6.5.2 Material Breaches. The notice and cure provisions in Paragraph 6.6. 1 do
not apply to Defaults identified in this Agreement as Material Breaches. Material
Breaches must be cured as expeditiously as possible following occurrence of the
breach.
7. Insurance.
During the term of this Agreement, Seller shall secure and continuously carry the following
insurance coverage:
7. 1 Comprehensive General Uability Insurance for both bodily injury and property
damage with limits equal to $1,000,000, each occurrence, combined single limit. The deductible
for such insurance shall be consistent with current Insurance Industry Utility practices for similar
property.
7.2 The above insurance coverage shall be placed with an insurance company with
an A.M. Best Company rating of A-or better and shall include:
(a) An endorsement naming Idaho Power as an additional insured and loss
payee as applicable; and
(b) A provision stating that such policy shall not be canceled or the limits of
liability reduced without sixty (60) days' prior written notice to Idaho Power.
7.3 Seller to Provide Certificate of Insurance. As required in Paragraph 7 herein and
annually thereafter, Seller shall furnish the Company a certificate of insurance, together with the
endorsements required therein, evidencing the coverage as set forth above.
7.4 Seller to Notify Idaho Power of Loss of Coverage -If the insurance coverage
required by Paragraph 7.1 shall lapse for any reason, Seller will immediately notify Idaho Power
in writing. The notice will advise Idaho Power of the specific reason for the lapse and the steps
Seller is taking to reinstate the coverage. Failure to provide this notice and to expeditiously
reinstate or replace the coverage will constitute grounds for a temporary disconnection under
Section 5.3 and will be a Material Breach.
8. Miscellaneous.
8. 1 Governing Law. The validity, interpretation and enforcement of this Agreement
and each of its proviSions shall be governed by the laws of the state of Idaho without regard to
its conflicts of law principles.
8.2 Salvage. No later than sixty (60) days after the termination or expiration of this
Agreement, Idaho Power will prepare and forward to Seller an estimate of the remaining value
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 8 of 9
of those Idaho Power furnished Interconnection Facilities as required under Schedule 72 and/or
described in this Agreement, less the cost of removal and transfer to Idaho Power's nearest
warehouse, if the Interconnection Facilities will be removed. If Seller elects not to obtain
ownership of the Interconnection Facilities but instead wishes that Idaho Power reimburse the
Seller for said Facilities the Seller may invoice Idaho Power for the net salvage value as
estimated by Idaho Power and Idaho Power shall pay such amount to Seller within thirty (30)
days after receipt of the invoice. Seller shall have the right to offset the invoice amount against
any present or future payments due Idaho Power.
9. Notices.
9.1 General. Unless otherwise provided in this Agreement, any written notice,
demand, or request required or authorized in connection with this Agreement ("Notice") shall be
deemed properly given if delivered in person, delivered by recognized national currier service,
or sent by first class mail, postage prepaid, to the person specified below:
If to the Seller:
Seller: ----------~~----~-----------------------------Attention: -----------------------------------------------------Address: -----------------------------------------------------City: State: Zip: --------~~~---------------------------Phone: Fax:
If to the Co~pany:
Idaho Power Company -Delivery
Attention: Operations Manager
1221 W. Idaho Street
Boise: Idaho 83702
----------------
Phone: [phone] Fax: [phone]
9.2 Billing and Payment. Billings and payments shall be sent to the addresses set
out below:
Seller: -------------------------------------------------Attention: Address: -----------------------------------------------------
City: ___________ ----' ________ State: ______ ----'Zip: __________ _
Phone: Fax:
Idaho Power Company -Delivery
Attention: Corporate Cashier
PO Box 447
Salt Lake City Utah 84110-0447
----------------
Phone: [phone] email: [e-mail]
9.3 Designated Operating Representative. The Parties may also designate
operating representatives to conduct the communications which may be necessary or
convenient for the administration of this Agreement. This person will also serve as the point of
contact with respect to operations and maintenance of the Party's facilities.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 9 of 9
Seller's Operating Representative:
Seller: ___ ~ ________ ;"""' ______ ---':"' _______ "'-----:'-'--_
Attention: ------------------------------------------------Address: ______________________________________________ ~ __ __
City: __________________ St~te:. ____ Zip: ____ _
Phone: Fax: ---------------
Company's Operating Representative:
Idaho Power Company -Delivery
Attention: Outage Coordinator -System/Regional Dispatch
1221 W. Idaho Street
Boise, Idaho 83702
Over 138kV phone [phone] during regular business hours
Under 138kV Phone: [phone], or 388-5175 during regular business hours
After hours -System Dispatch 388 2826
Regional Dispatch
Southern Region 208-388-5190
9.5 Changes to the Notice Information. Either Party may change this information by
giving five (5) Business Days written notice prior to the effective date of the change.
10. Signatures.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their
respective duly authorized representatives.
For the Seller
Name: ______________________________________________ __
Title: _____________________________________ _
Date:
For the Company
Name: -----------------------------------------------
Title: Director, Load Serving Operations -Idaho Power Company
Date: ____________________ _
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29. Tariff No. 101 Page 1 of 3
Attachment 1
Description and Costs of the Generation Facilitv. Interconnection Facilities and Metering Equipment
Interconnection Details
Type of Interconnection Service: Studied as an Idaho Power Network Resource under PURPA
Full Output: 18 MW (both projects)
Nominal Delivery Voltage: 12.5 kV
General Facility Description
The Notch Butte Wind Park project includes both Projects #349 and #359 for a total of 18 MW of power
provided by seven 2.5Mw Nordex Turbines. The Interconnection Customer (IC) will provide all
generation and station equipment required to deliver power at 12.5 kV to the Point of Interconnection
(POI) which is located at the coordinates North 420 53.12948' West 1140 10.57'. The Seller will provide
two POTS lines and two DDS circuits to the POls (one pair for each feeder connection) for
communication. Two 12.5 kV feeders will run from the POI four miles west to the IPCo Dietrich
substation where the station will be expanded to accommodate the two new feeders. The power will be
converted to 138 kV via a 12.5 kV to 138 kV power circuit transformer. A new double circuit
transmission line, consisting of a new 138 kV line and the existing 46 kV line, will run four miles due
north out of the Dietrich substation. The new 138 kV line will connect to the existing Midpoint-Silver
138 kV line.
Interconnection Point
The Interconnection Point for the Notch Butte Wind Park Project will be the generator side of the
disconnect switches labeled Disconnect Switches A-13 and A-14 (one for each feeder) as shown on the
attached Single Line drawings 21 D-64299, sheets 1 & 2. This Interconnection Point is in Lincoln
County, ID -T6S, R19E, SW corner of Section 22.
A drawing identifying the Point of Interconnection is included as Attachment 2. The Point of Change of
Ownership is electrically the same as the Interconnection Point.
Seller's Interconnection Facilities
The Seller will install all generation and station equipment required to deliver power at 12.5 kV to the
interconnection point. Transmitting 18 MW of power at 12.5 kV requires two distribution feeders. The
Seller shall balance the generation between these two feeder connections with no more than 11 MW of
power flowing on either feeder. The Seller will own and maintain facilities electrically located on the
Interconnection Customer side of the Point of Change of Ownership. Idaho Power will own and
maintain the facilities electrically located on the IPCo side of the Point of Change of Ownership.
The Seller will install equipment to receive signals from Idaho Power Company Grid Operations for
Generator Output Limit Control ("GOlC") -see Attachment 4 Operating Requirements.
The Seller will provide phone service to IPCo's generator interconnect package as described in
Telecommunications below.
The Seller will provide a DNP 3.0 serial data connection to the local Idaho Power Company SCADA
RTU when any communication with Seller-owned and maintained equipment is required for GOlC,
voltage control or other plant monitoring or control. Preliminary points lists and functional description
were provided to the Seller in the Facility Study Report.
All interconnection equipment electrically located on the generator side of the Point of Change
Ownership shall be owned and maintained by the Seller.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u.C. No. 29, Tariff No. 101 Page 2 of 3
Other Facilities Provided by Seller
In addition to communication circuits that may be needed by the Seller, the Seller shall provide the
following communication circuits for Idaho Power's use:
Two POTS (Plain Old Telephone Service) dial-up circuit for querying the revenue meter at the
generation interconnection site. One for each 4-pole feeder connection.
Two leased DDS (Digital Data Service) circuit for SCADA between the generation interconnection site
and Twin Falls Service Building (273 Blue lakes Blvd. S., Twin Falls, 1083301). One for each 4-pole
feeder connection. These circuits must operate at 19.2 kbps data rate. Please note that Frame Relay
service is not acceptable.
The Interconnection Customer/communications provider shall provide a demarcation box and terminate
the specified communications circuits at the demarcation box. The location of the demarcation box will
be determined by Idaho Power. The demarcation box shall meet the following requirements:
• Be accessible by both the communications provider and Idaho Power
• The location shall be near Idaho Power's equipment and shall be subject to approval by
Idaho Power
• The communications cable pairs shall be labeled/tagged accordingly (Le. circuit number,
phone number, transmit, receive, etc.)
The Seller is required to coordinate with a communications provider to provide the communications
circuits and pay the associated one time setup and periodic charges. The communication circuits will
need to be installed and operational prior to generating into the Idaho Power system. Note that
installation by communications provider may take several months and should be ordered in advance to
avoid delaying the project. If the communication circuit types listed above are not available at the site
by a communications provider, the Seller shall confer with Idaho Power.
If high voltage protection is required by the communications provider for the incoming communications
provider cable, the high voltage protection assembly shall be engineered and supplied by the Seller.
Options are available for indoor or outdoor mounting. The high voltage protection assembly shall be
located in a manner that provides Idaho Power 24-hour access to the assembly for trouble-shooting of
Idaho Power owned equipment.
Ground Fault Equipment
The Seller will install transformer configurations that are Grounded-WYE to Grounded-WYE and will
limit the contribution of the ground fault current to 20 amps or less at the Interconnection Point.
Monitoring Information
If the Seller requires the ability to monitor information related to the Idaho Power reclosers in the
generation interconnection package they are required to supply their own communications circuit to the
control box.
Easements
The Seller will provide to IPCO a surveyed (Metes & Bounds) legal description along with exhibit map
for IPCO's facilities at the Interconnection Point. After the legal description has been delivered to IPCO
for review, IPCO will supply to the Interconnection Customer a completed IPCO easement for signature
by the land owner of record. Once the signatures have been secured, the Seller will return the signed
easement to IPCO for recording.
Generator Output Limit Control
The Seller will install equipment to receive signals from Idaho Power Grid Operations for Generation
Output Limit Control ("GOlC") -see Attachment 4 Operating Requirements.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 3 of 3
Local Service
The Seller is responsible to arrange for local service to their site, as necessary.
Idaho Power Company's Interconnection Facilities
Idaho Power will install two standard generation interconnection packages, one for each feeder. For
each package, if the Seller is going underground to the Interconnection Point, Idaho Power will include
a pole riser for the Generator to install cables to interconnect to the Idaho Power system. If the Seller is
going overhead to the Interconnection Point, it will be at a tension not to exceed the design tension
specified by Idaho Power.
The new interconnection packages each will include four distribution poles to mount a local service
transformer, solid blade disconnects, primary metering package, recloser, relays, RTU, fuses and riser
necessary for the package. The interconnection will be controlled by a SEL-311 C line protection relay
and a GE iBox RTU. The relay and RTU will be located in a pole mounted enclosure and will also
contain a test switch (TS4), SLSS, dialup modem, DDS CSUlDSU, isolation interface, power supply,
DC converter, control switch and surge protector.
Concrete barriers may be necessary to protect this equipment from local area traffic.
A 2" conduit will be installed alongside the underground primary to facilitate information exchange to the
customer about the recloser. (The Interconnection Customer is responsible for providing and installing
the appropriate cable.)
See single line drawing as Attachment 2.
All interconnection equipment electrically located on the utility side, of the Interconnection Point shall be
owned, operated, and maintained by Idaho Power.
Maintenance Coordination Exception
The Seller's protective relays will not provide back-up protection for Idaho Power facilities, therefore the
last 2 sentences in Section 5.3.4 of this Generator Interconnection Agreement do not apply to this
Generation Facility.
Estimated Cost & Ownership
The following good faith estimates are provided in 2011 dollars:
Interconnection Facilities: ,-------------------'~ ----.---,------
1~!er~ol1!1.~~tigl) p.~_~~~g~~ (~} ,IPC !$440,OO~
SUBTOTAL -$440,QO,! _
See Attachment 6 for Total Estimate Costs ---. -. ------
Full payment is required up front in accordance with Schedule 72, unless payment arrangements are
made in advance with Idaho Power Operations Finance (see Attachment 3).
Billing for construction activities will be based upon actual expenditures.
Idaho Power Company Generator Interconnection Agreement # 349/359
I,P.U.C. No. 29, Tariff No. 101 Page 1 of 3
Attachment 2
One-line Diagram Depicting the Small Generation Facility, Interconnection Facilities, Metering
Equipment and Upgrades
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I.P.U.C. No. 29, Tariff No. 101 Page 2 of 3
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Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 3 of 3
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u.C. No. 29, Tariff No.1 01 Page 1 of 2
Attachment 3
Milestones for Interconnecting to the Generation Facility
Idaho Power Company agrees only to the Construction timelines under its direct control provided in the
Facility Study Report for this Project.
These milestones will begin, and the construction schedule referenced below, will only be valid upon
receipt of funding in full from the Seller or their authorized third party no later than the date set forth
below for such payment. Additionally, failure by Seller to make the required payments as set forth in
this Agreement by the date(s) specified below will be a material breach of this Agreement, which may
result in any or all of the following: (i) loss of milestone dates and construction schedules set forth
below: (ii) immediate termination of this Agreement by Idaho Power; (iii) removal from the generator
interconnection queue.
Critical milestones and responsibility as agreed to by the Parties:
!IPCO receives the remaining balance of Construction
'estimate $7,875, 000 OR Credit arrangements are approved
,..-_ .-.-.------1--_ ~!?CO ___ ____ _ _________ . __ ._,
;3/15/2015 tSeller lCustomer GOLC ready to connect & customer telecomm
. 're uirements are com lete ~~~~~~:--=-~=~~I;:~~ j;:~~~:::'::i,i~:":;~~e~e ~-==-~-~---
~:~~.-=~=---~~~~
!energized, upon verification that Seller has previously met
_. _ ____ "+.. __ ..:§cheduje. 7~~..§.e.E JJ.~.J!~nc_e reguiremen!s _" __
ISeller Customer testing begins ______ ". _____ .l. .. "_. _ .. _ __. ____ .. _____ . __ . __ .•. ___ .. _ .
--4/15/2015
6/20/2015 ISeller :Customer's requested In-Service Date
--~ _ .... '--~ ... ---.,-
Idaho Power requires approximately thirty-four (34) months to complete design, procurement,
construction, permitting, and commissioning of the necessary interconnection facilities and required
upgrades associated with the Notch Butte Wind Park Project prior to the Commercial Operation Date.
This timeframe assumes that material can be procured, labor resources are available, and that
outages to the existing system are available to be scheduled.
There is approximately 1.5 miles of the existing 46 kV transmission line which is located on BlM
land. A permit (ROW grant) will be required from the BlM in order to re-build this portion of the line
for the double circuit transmission as well as the 138 kV transmission line switches where the new
138 kV line connects to the existing transmission line. Obtaining a ROW grant from the BlM is
never guaranteed and is typically a 20-30 month process at this point in time. This is outside of
Idaho Power's control. If the ROW grant is denied then a new interconnection solution would be
required and this could drastically alter project costs and timeline.
Idaho Power Company
I.P.U.C. No. 29, Tariff No. 101
Agreed to by:
For the Seller:
For the Transmission Provider
Idaho Power Company
Generator Interconnection Agreement # 349/359
Page 2 of 2
Oate _____ _
Oate _____ _
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 2
Attachment 4
Additional Operating Requirements for the Company's Transmission System and Affected Systems
Needed to Support the Seller's Needs
The Company shall also provide requirements that must be met by the Seller prior to initiating
parallel operation with the Company's Transmission System.
Operating Requirements
The project is required to comply with the applicable Voltage and Current Distortion Limits found in
IEEE Standard 519-1992 IEEE Recommended Practices and Requirements for Harmonic Control in
Electrical Power Systems or any subsequent standards as they may be updated from time to time.
Seller will be able to modify power plant facilities on the generator side of the Interconnection Point with
no impact upon the operation of the transmission system whenever the generation facilities are
electrically isolated from the transmission system via the A-13 and A-14 switches and a terminal
clearance is issued by Idaho Power Company's Grid Operator.
Generator Output Limit Control (liRe-dispatch" or "GOLC") The Project will be subject to
reductions directed by Idaho Power Company Grid Operations during transmission system
contingencies and other reliability events. When these conditions occur, the Project will be subject to
Generator Output Limit Control ("GOlC") and have equipment capable of receiving signals from Idaho
Power for GOlC. Generator Output Limit Control will be a setpoint from Idaho Power to the Project
indicating maximum output allowed. See Attachment 7 for details.
Voltage flicker at startupand during operation will be limited to less than 5% as measured at the
Interconnection Point. It is preferable to bring each generating unit online separately to minimize
voltage flicker on the distribution system.
Low Voltage Ride Through
The Project must be capable of riding through faults on adjacent section of the power system without
tripping due to low voltage. It has been determined, through study, that the Project must be capable of
remaining interconnect for any single phase voltage as low as 0.7 PU for 30 cycles, and for all three
phase voltages as low as 0.8 PU for 30 cycles.
Ground Fault Equipment
The Seller will install transformer configurations that are Grounded-Wye to Grounded-Wye and will limit
the contribution of the ground fault current to 20 amps or less at the Interconnection Point.
Meteorlogical Data
Historical wind data -Within 60 days after execution of this Agreement, the Seller shall provide Idaho
Power with the following:
a) historical wind data in an electronic format from the proposed Facility site or for a location within
two miles of the Facility site.
b) a third party wind assessment study report used by Seller to value investment in the Facility.
No later than 30 days prior to the Commercial Operation Date, the Seller shall have:
a) Erected at the site at least one (1) high quality, approximate hub-height (plus or minus 20
meters), permanent. meteorological wind measurement tower(s) at location(s) on the site equipped
with:
(i)
(ii)
(iii)
(iv)
Two (2) anemometers per tower;
Two (2) air temperature sensors per tower;
One (1) barometric pressure sensor (with DCP sensor); and
Two (2) wind vanes per tower.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 2 of 2
Facility availability status shall be provided as described in the Final Facility Study no later than within
the calendar month following the month of the Commercial Operation Date. Failure by the Seller to
operate and maintain this equipment to provide such meteorological and turbine availability data in a
manner to provide reasonably accurate and dependable data for the full term of this Agreement shall be
an event of Default under paragraph 6.5.1.
Idaho Power Company Generator Interconnection Agreement # 3491359
I.P.U.C. No. 29. Tariff No. 101 Page 1 of 1
Attachment 5
Reactive Power Requirements
The project must be controlled to operate at unity power factor +/-500 kVar ..
Voltage flicker at startup and during operation will be limited to less than 5% as measured at the
Interconnection Point.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 2
Attachment 6
Company's Description of Special Facilities and Upgrades Required to Integrate the Generation Facility
and Best Estimate of Costs
As provided in Schedule 72 this Attachment describes Upgrades, Special Facilities, including
Network Upgrades, and provides an itemized best estimate of the cost of the required facilities.
Upgrades
Upgrades to Substation Facilities
Two new 12.5 kV feeder bays with associated switches, breakers, relays etc at Dietrich substation
A new 138: 12.5 kV power transformer and associated equipment at Dietrich substation with protection
package, control building.
Line relay and microwave upgrades at Midpoint substation
DTRC-MPSN microwave reflector site (near Notch Butte)
Upgrades to Distribution Facilities
A new double circuit (DTRC-013 and 014) 12.5 kV distribution line from Dietrich substation to the point
of interconnection (4 miles). This new distribution line will be built with 795 AAC conductor on both
circuits with ADSS underbuild.
Upgrades to Transmission Facilities
Idaho Power will rebuild 4 miles of the existing 46 kV transmission line (T-128) with a double circuit
transmission line that will accommodate both the existing 46 kV line as well as the new 138 kV line.
The new 138 kV line will then tap into the existing Midpoint-Silver 138 kV line with line switches on all
three sides of the tap.
The following good faith estimates are provided in 2012 dollars:
Interconnection Facilities: ----------_. ---
.Jnte.rcol1necti~~ Pac_~?_ges (2)_ IPC
Plstrfbution _l!pgrCJc!~s: _ _ __ _ _
Distribution Feeders to Dietrich Substation (DTRC-013
& DTRC-014) with ADSS fiber IPC
Su~stat!CJnUpgr..!lt:!f!I~: _ _ _ _ _
Dietrich Substation Additions ;IPC
Midpoin_t Re.I~y upgrades ilPC
~idpoint_ Mic:~owaye ~pgrades :IPC
DTRC-MPSON Microwave Reflector Site lPC
Transrniss.io~ !lpgr:~cle.s_:__ __
Remove 4 miles of 46 kV line with underbuild IPC .----
Build 4 miles of line to double circuit IPC
.3 -138 kV Line Switches IPC --
*BLM Permitting/ROW ~r~_n~ IPC
GRAND TOTAL
-.-
;$440,000
_ :j96,5,OOg
~2,835,OOO
:$65,009
$190,OQ,0
_ ~32~,OOO
-
:$130,000
;$2,550,000
:$300,000
$75,000
;$7,875,000
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u .C. No. 29, Tariff No. 101 Page 2 of 2
*There is approximately 1.5 miles of the existing 46 kV transmission line which is located on BLM land.
A permit will be required from the BLM in order to rebuild this portion of the line to double circuit as well
as install the transmission line switches. The costs for this permitting can vary widely and have been
estimated at a combined $75K.
Note Regarding Transmission Service:
This Facility Study is a Network Resource Interconnection Facility Study. This study identifies the
facilities necessary to integrate the Generating Facility into Idaho Power's network to serve load
within Idaho Power's balancing area. Network Resource Interconnection Service in and of itself
does not convey any right to deliver electricity to any specific customer or Point of Delivery.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 2
Attachment 7
Generation Interconnection Control Requirements
Generator Output Limit Control (GOLC)
IPC requires Interconnected Power Producers to accept GOlC signals from our EMS.
The GOlC signals will consist of four points shared between the IPC EMS and the Customer's
Generator Controller:
GOlC Setpoint: An analog output that contains the MW value the Customer should curtail to, should a
GOlC request be made via the GOlC On/Off discrete output Control point.
An Analog Input feedback point must be updated (to reflect the GOlC setpoint value) by the Customer
Controller upon the Controller's receipt of the GOlC setpoint change, with no intentional delay.
GOlC On/Off: A discrete output (DO) control point with latching Off/On states. Following a "GOlC On"
control, the Customer Controller will run power output back to the MW value specified in the GOlC
Setpoint. Following a "GOlC Off' control, the Customer is free to run to maximum possible output.
A Discrete Input feedback point must be updated (to reflect the GOlC DO state) by the Customer
Controller upon the Controller's receipt of the GOlC DO state change, with no intentional delay.
If a GOlC control is issued, it is expected to see MW reductions start within 1 minute and plant output
to be below the GOlC Setpoint value within 10 minutes.
Voltage Control
Idaho Power Company requires Transmission-Interconnected Power Producers to accept Voltage
Control signals from our EMS when they are connected to our transmission system.
The voltage control will consist of one setpoint and one feedback point shared between the IPC EMS
and the Customer Controller.
The setpoint will contain the desired target voltage for the plant to operate at.
The control will always be active, there is no digital supervisory point like the Curtail On/Off control
above.
When a setpoint change is issued an Analog Input feedback point must be updated (to reflect the
Voltage Control setpoint value) by the Customer Controller upon the Controller's receipt of the Voltage
Control setpoint change, with no intentional delay.
When a setpoint change is received by the Customer Controller, the Voltage Control system should
react with no intentional delay.
The voltage control system should operate in a dead band of +/-5% of the control setting range.
The customer should supervise this control by setting up "reasonability limits", i.e. configure a
reasonable range of values for this control to be valid. As an example, they will accept anything
between .95 and 1.05 for the set point. In the case they are fed an erroneous value outside this range,
their control system defaults to the last known, good value.
Idaho Power Company Generator Interconn6ction Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 2 of 2
Generation Interconnection Data Points Requirements
Digital Inputs to IPCo (DNP Obj. 01, Var. 2)
Index Description StatelO/11 Comments:
0 52A Customer Capacitor Breaker (if present) Open/Closed Sourced at substation
1 GOlC Off/On Control Received (Feedback) Off/On Provided by Customer
Digital Outputs to Customer (DNP Obj. 10, Var.1)
Index Description Comments:
0 GOlC Off/On Provided by IPCO
NOTE: GOlC Setpoint indicates MW value to curtail to when GOlC Off/On DO is ON.
Analog Inputs to IPCo (DNP Obj. 30, Var. 2)
Raw Raw EU EU
Index Description High low High EU low Units Comments:
GOlC Setpoint Value Received -Provided by
0 , (Feedback) 32767 32768 TBD TBD MW Customer
Voltage Control Setpoint Value Rec'd -PiOvided by
1 (Feedback) 32767 32768 TBD TSD kV Customer
-Provided by
2 Maximum Park Generating Capacity 32767 32768 TBD TSD MW Customer
-Provided by
3 Number of Turbines In High Speed Cutout 32767 32768 32767 -32768 Units Customer
-For Provided by
4 Ambient Temperature 32767 32768 327.67 -327.68 C Customer
-Provided by
5 Wind Direction 32767 32768 3276.7 -3276.8 Deg Customer
MPH
-or Provided by
6 Wind Speed 32767 32768 327.67 -327.68 m/s Customer
Analog Outputs to Customer (DNP Obj. 40, Var. 2)
Raw Raw EU EU EU
Index Description High low High low Units Comments:
-
0 GOlC Setpoint 32767 32768 TBD TBD MW Provided by IPCO
-
1 Voltage Control Setpoint 32767 32768 TSD TBD kV Provided by IPCO
NOTE: Curtailment Setpoint indicates MW value to Curtail to when Curtailment Off/On DO is ON.
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 54
June 20, 2012
Idaho Power Company
Attn: Josh Hams
1221 West Idaho Street
Boise, ID 83702
RE: Notch Butte Wind Park Projects -GI #349 and GI #359
Dear Mr. Hams,
Exergy has received your letter dated May 23, 2012 in which you explained that [dabo Power is unwilling to allow the
Notch Butte project to interconnect at a common distribution voltage level of34.5 kV. It was explained that 34.5 kV is
not an available interconnection voltage because existing or pLanned 34.5 kV distribution is an undisclosed distance from
the Notch Butte site and that this distance exceeds an undisdosed threshold, making 34.5 kV an unavailable
interconnection voltage for our project. Your letter went on to explain that there are three available interconnection
voltages at the current and accepted POI and that these are: 12.5 kV, 46 kV, and 138 kV. Your letter also stated that our
request to move the POI oloser to the substation, along the same route that was previously studied, would require a new
Generation Intercolmection Application. Exet·gy rightly believes your response regarding the slight change in POI to be
prejudicial with respect to our request to move the POI to a point along the same distribution corridor studied previously
and 4 miles closer to the substation that was also studied previously.
Policies regarding the relocation of project POI in the course of negotiating interconnection details between customers
and transmission providers are intended to prevent serious material modification and resulting liab:ilities to providers -
they are not intended to allow providers to arbitrarily impede the development of projects as appears to have occurred in
the case of Notch Butte. Nevertheless, since it required twenty-three days to provide a response to our email of April 30
requesting this minor change in POI location, far exceeding the da'[e given in your letter beyond which you stated that
any guarantee of a December 15,2012 In-Service Date would be infeasible our team has worked to identifY a solution
that you may be willing to accept and that would also allow Notch Butte to successfully achieve a Dece.mber J 5, 2012
In-Service Date.
Exergy would like to accept your offer, extended in your May 23 letter, of a l38 kV interconnection at the current and
accepted POI. In return for this concession, we kindly ask that Idaho Power expedite the drafting of a revised Generator
Interconnection Agreement and avail themselve,s of aU available means to provide a temporary and reduced connection
to existing distribution at the current and accepted POI and not exceeding 4 MW. In the interest of time, Exergy requests
also an Engineering and Procurement agreement from Idaho Power, the scope of which is limited to the work necessary
to achieve the 4 MW temporary connection to existing 12.5 kV distribution at the current and accepted POI.
Exergy is fully capable of engineering and constructing a project substation to provide both 18 MW at 138 kV as well as
4 MW at 12.5 kV at the current and accepted POI prior to December 15, 2012. Furthermore, Exergy is willing to support
Idaho Power with engineering and procurement activities to the extent Idaho Power will allow in order to facilitate the
temporary connection with limited output of 4 MW no later than December 15,2012.
Best Regards,
Joshua Gunderson, Project Engineer
phone: [phone]
email: [e-mail]
Exergy Development Group, 802 W. Bannock, 12th Floor, BOise, ID phone: [phone] fax: [phone]
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 55
DONOVAN E. WALKER
Lead Counsel
[e-mail]
June 26,2012
VIA ELECTRONIC & U.S. MAIL
Joshua Gunderson, Project Engineer
Exergy Development Group
802 West Bannock Street, 1ih Floor
Boise, Idaho 83702
An IDACORP Company
Re: Final Generator Interconnection Agreement for Notch Butte Wind Park -
GI#349 & 359
Dear Mr. Gunderson:
This letter responds to your letter to Idaho Power Company's ("Idaho Power")
Josh Harris dated June 20, 2012, regarding the generator interconnection facilities for
the Notch Butte Wind Park (the "Project").
As you are well aware, Idaho Power has been working diligently with Exergy
Development Group ("Exergyn) over an extended period of time to accommodate the
interconnection and integration of the Project onto Idaho Power's system. On March 6,
2012, Exergy requested that Idaho Power explore ways in which a portion of the
Project's generation could come on-line with limited output prior to the end of 2012.
Idaho Power explored a number of options and, based upon the interconnection
configuration requested by Exergy, Idaho Power was able to meet Exergy's request.
Specifically, in a letter dated April 9, 2012, from Idaho Power's Ed Kosydar to Exergy's
Dustin Shively, Idaho Power provided Exergy a Final Facility Study Report ("FSR") for
the Project, which provided an option to bring a reduced and limited output of 4
megawatts ("Mwn) on-line by December 31, 2012, prior to completion of the remaining
required upgrades and construction necessary to connect the Project's full output. More
specifically, the letter and the FSR sent to Exergy clearly stated that the generator
interconnection agreement ("GIA") must be executed and the approximately $7.9 million
in construction funding must be received by May 1, 2012, in order for the necessary
work to proceed to bring the limited outPl,Jt on-line by December 31, 2012, prior to the
other required facilities being completed.
Immediately thereafter, Idaho Power began preparing a GIA based upon the
contents of the FSR so that Exergy would be in a position to meet its request to have
limited output for the Project on-line prior to the end of 2012 with the remainder of the
Project's output on-line after completion of the remaining necessary system upgrades.
By letter dated April 20, 2012, Idaho Power sent Exergy a draft GIA, which reiterated
1221 W. Idaho St. (83702)
P.O. Box 70
Boise, ID B3707
Joshua Gunderson, Project Engineer
June 26, 2012
Page 2 of 4
what was previously stated in Ed Kosydar's April 9 letter: "In order for you to come
online with limited output by December 15, 2012 we must have this agreement
executed by May 1! 2012." (Emphasis in original.)
Instead of executing the GIA and making the necessary financial arrangements,
on April 30, 2012, Exergy's Dustin Shively sent Idaho Power's Ed Kosydar and Josh
Harris an e-mail stating that Exergy was going to "be moving the POI from the project
site to the Dietrich substation and providing 34.5kV at that point." This is a request to
change the point of interconnection and the voltage and is completely different than
what Exergy had requested, what had been discussed previously, and, thus, completely
different than what was contained in the FSR and the draft GIA provided to Exergy on
April 20. In addition, Idaho Power had previously communicated to Exergy that 34.5
kilovolts ("kV") was not an available voltage at the Deitrich substation. By letter dated
May 23, 2012, Idaho Power's Josh Harris sent Exergy a letter communicating once
again that a voltage level of 34.5 kV at the Dietrich substation is not available.
As a result, Idaho Power provided a revised GIA to Exergy on May 23, 2012,
which contained the original interconnection configuration requested by Exergy except
that it removed the section in Attachment 3 related to "Limited Generation Output."
Based on Idaho Power's extensive conversations with Exergy, Idaho Power was under
the impression that Exergy did not desire to have the ability to do limited generation
output if such output could not be achieved prior to the end of 2012. As Idaho Power
has previously communicated in two separate, written communications, the only way for
the Project to achieve limited generation output by the end of 2012 was if Idaho Power
received a signed GIA and the necessary construction funding by May 1, 2012. Since
Exergy did not sign the GIA, nor pay the construction funding, Idaho Power removed
this language from the draft GIA and presented Exergy with a final GIA on May 23,
2012. That correspondence requested that Exergy sign the GIA and provide the
necessary construction funding by no later than June 23, 2012, in order to proceed.
This leads us to your letter dated June 20, 2012. Idaho Power is compelled to
respond to the inaccurate factual representations contained in that letter related to the
current status of the discussions between Idaho Power and Exergy related to the
Project. As an initial matter, Josh Harris's May 23 letter and the accompanying GIA was
not an "offer ... of a 138 kV interconnection at the current and accepted POL" It simply
reiterated to Exergy what was previously communicated-Le., that the currently
available voltages at the Deitrich substation are 12.5 kV and 46 kV and that 138 kV
would be available to the Dietrich substation in the future, which was part of the studied
interconnection upgrades for the Project. As you know, Exergy's previous request,
which was the request that was studied in the FSR and which was provided to Exergy in
the April 20 draft GIA, was for the Project to interconnect at 12.5 kV with a point of
interconnection ("POI") at the Project location. Double circuit 12.5 kV would need to be
constructed from the POI to the Dietrich substation. Idaho Power would then "step-up"
the power from 12.5 kV to 138 kV at the Deitrich substation, but the necessary
transmission upgrades to move that power from the Deitrich SUbstation to Idaho
Joshua Gunderson, Project Engineer
June 26, 2012
Page 3 of 4
Power's system (construction of 138 kV line from Dietrich to Idaho Power's existing 138
kV line) would require an estimated 34 months to complete.
Now, it appears from your June 20 correspondence that Exergy is requesting a
138 kV interconnection at the present POI, which is at the Project location. If this is
indeed the case, this is a material change from what Exergy had originally requested, it
has not been studied and, accordingly, if this is the configuration Exergy seeks, then
Exergy will need to submit a new interconnection request and Idaho Power will need to
conduct a new study for the Project.
If that is not the case and Exergy wishes to proceed with the original
interconnection configuration that was requested by Exergy and studied by Idaho
Power-Le., connect with the POI at the Project location at a voltage of 12.5 kV-then
Idaho Power is able to immediately proceed with designing, engineering, and
constructing that interconnection configuration as soon as Exergy signs a GIA and
provides the necessary construction funding. Since it appears (based on the June 20
letter) that Exergy is still seeking limited generation output as soon as possible, Idaho
Power is enclosing a revised GIA which adds back the limited generation output
language that was included in the April 20 draft GIA. Idaho Power has determined that
it may still be possible to construct temporary facilities to enable the connection of the 4
MW of limited output by December 15, 2012, if Exergy authorizes Idaho Power to
proceed with the studied interconnection configuration by executing the enclosed GIA
and funding the construction.
In an additional effort to accommodate Exergy's request for limited output by
December 15, 2012, and consistent with concessions Idaho Power has previously
provided to Exergy for other projects and other similarly situated Qualifying Facilities
("QF), Idaho Power has included language in the enclosed GIA which allows Exergy to
authorize Idaho Power to incur additional expenses, including additional overtime,
lodging, travel, and other expenses needed to bring in other Idaho Power resources and
personnel from other Idaho Power regions, or to utilize third-party contractors, as
necessary, to work on this interconnection.
Lastly, Idaho Power must respond to your unfounded accusation that Idaho
Power has engaged in conduct lito arbitrarily impede the development of projects as
appears to have occurred in the case of No1tch Butte." Nothing could be further from the
truth. Idaho Power has been nondiscriminatory and accommodating in the Project's
many requests and different proposed configurations . Idaho Power has in no way acted
arbitrarily in dealing with the Project or any other QF project or other generator
connecting to its system nor has it acted with any intention or design to impede any
project's development. On the contrary, Idaho Power has serious concerns with
Exergy's course of conduct in dealing with generator interconnection issues. Exergy is
engaged in a pattern of behavior that, from Idaho Power's perspective, appears to be an
attempt to "game" the generator interconnection process by maintaining pOSitions in the
generator interconnection queue for its various projects, and to the detriment of other
Joshua Gunderson, Project Engineer
June 26, 2012
Page 4 of 4
generators in Idaho Power's interconnection queue, by making last-minute changes to
interconnection configurations or unauthorized changes to generator interconnection
agreements. Exergy must respect the integrity of Idaho Power's generator
interconnection process so as to not disadvantage other generators in its
interconnection queue and discontinue this pattern of behavior.
Enclosed is the final version of the GIA for the Project, which includes an option
for temporary facilities that would allow the connection of limited output of 4 MW to be
completed by December 15, 2012. Every day that passes without a signed GIA and the
required funding is another day that places the December 15, 2012, date and Idaho
Power's ability to complete the temporary limited output connection in jeopardy. As
described above, this final GIA contains the interconnection configuration requested by
Exergy and studied by Idaho Power. It also includes the same language Idaho Power
has provided other Exergy projects and other QFs that wish to expedite the
interconnection facilities process.
In order to meet your requested December 15, 2012, date for the connection of
the 4 MW of limited output, and to maintain the schedule set forth in the GIA for the
remaining required upgrades and facilities, you must authorize Idaho Power to move
forward with the work identified in the GIA. Consequently, the enclosed GIA, including
the milestone date estimates set forth therein, are contingent upon Idaho Power
receiving an executed GIA, that has not been modified or changed unilaterally by
Exergy, and the payment of the required construction deposit of approximately $7.9
million by the close of business, 5:00 p.m. Mountain Time, on Monday, July 9, 2012. If
Idaho Power does not receive an executed copy of this GIA, and the necessary
financing arrangements for construction by this deadline, your generator interconnection
request for this Project will be terminated and the Project will be withdrawn from the
generator interconnection queue. As further explained above, if Exergy wishes to
connect at a different voltage and location than what it has previously requested, Idaho
Power will need to restudy the new requested configuration, which may also result in
this generator interconnection request being terminated and Project moving back in the
generator interconnection queue.
DEW:csb
Enclosure: Final GIA /
cc: James Carkulis, Exergy (w/encl.) -via e-mail ~ ,/
Josh Harris, Idaho Power (w/encl.) -via e-mail /
Jason Williams, Idaho Power (w/encl.) -via e-mail
Tess Park, Idaho Power (w/encl.) -via e-mail v ' .
Ed Kosydar, Idaho Power (w/encl.) -via e-mail V
Idaho Power Company Generator Interconnection Agreement # 349/359
I,P.U.C. No. 29, Tariff No. 101
June 26, 2012
GENERATOR INTERCONNECTION AGREEMENT
Schedule 72
Notch Butte Wind Park PROJECTS #349 & #359
6.5/11.5 MW
Idaho Power Company Generator Interconnection Agreement # 349/359
!,P.U.C. No. 29, Tariff No. 101
TABLE OF CONTENTS
RECITALS ............................................................................................................................................. 1
AGREEMENTS ..................................................................................................................................... 1
1. Capitalized Terms ................................................................................................................ 1
2. Terms and Conditions .......................................................................................................... 1
3. This Agreement is not an agreement to purchase Seller's power ......................................... 1
4. Attachments ......................................................................................................................... 1
5. Effective Date, Term, Termination and Disconnection .......................................................... 2
5.2 Termination .......................................................................................................................... 2
6. Assignment. Liability. Indemnity. Force majeure, Consequential Damaqes and Default ....... 5
7. Insurance ............................................................................................................................. 7
8. Miscellaneous ....................................................................................................................... 7
9. Notices ................................................................................................................................. 8
10. Signatures ............................................................................................................................ 9
Attachment 1 .......................................................................................................................................... 1
Attachment 2 ......................................................................................................................................... 1
Attachment 3 ......................................................................................................................................... 1
Attachment 4 ......................... , ............................................................................................................... 1
Attachment 5 ......................................................................................................................................... 2
Attachment 6 ......................................................................................................................................... 1
Attachment 7 ......................................................................................................................................... 1
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u .C. No. 29, Tariff No. 101 Page 1 of9
This Generator Interconnection Agreement ("Agreement") under Idaho Power Company's
Schedule 72 is effective as of the 26 day of June, 2012 between Exergy Development Group of Idaho,
("Seller", "Customer" or "The Project") and Idaho Power Company ("Company","Transmission Owner",
"Idaho Power", "IPC" or "IPCO").
RECITALS
A. Seller will own or operate a Generation Facility that qualifies for service under Idaho
Power's Commission-approved Schedule 72 and any successor schedule.
B. The Generation Facility covered by this Agreement is more particularly described in
Attachment 1.
AGREEMENTS
1. Capitalized Terms
Capitalized terms used herein shall have the same meanings as defined in Schedule 72 or in the body
of this Agreement.
2. Terms and Conditions
This Agreement and Schedule 72 provide the rates, charges, terms and conditions under which the
Seller's Generation Facility wl1/ interconnect with, and operate in parallel with, the Company's
transmission/distribution system. Terms defined in Schedule 72 will have the same defined meaning in
this Agreement. If there is any conflict between the terms of this Agreement and Schedule 72,
Schedule 72 shall prevail.
3. This Agreement is not an agreement to purchase Seller's power.
Purchase of Seller's power and other services that Seller may require wl1/ be covered under separate
agreements. Nothing in this Agreement is intended to affect any other agreement between the
Company and Seller.
4. Attachments
Attached to this Agreement and included by reference are the following:
Attachment 1 -Description and Costs of the Generation Facility, Interconnection
Facilities, and Metering Equipment
Attachment 2 -One-line Diagram Depicting the Generation Facility, Interconnection
Facilities, Metering Equipment and Upgrades.
Attachment 3 -Milestones for Interconnecting the Generation Facility
Attachment 4 -Additional Operating Requirements for the Company's Transmission
System Needed to Support the Seller's Generation Facility
Attachment 5 -Reactive Power
Attachment 6 -Description of Upgrades required to integrate the Generation Facility and
Best Estimate of Upgrade Costs
Attachment 7 -Generator Interconnection Control Requirements
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u .C. No. 29, Tariff No.1 01 Page 2 of 9
5. Effective Date, Term, Termination and Disconnection.
5.1 Term of Agreement. Unless terminated earlier in accordance with the provisions
of this Agreement, this Agreement shall become effective on the date specified above and remain
effective as long as Seller's Generation Facility is eligible for service under Schedule 72.
5.2 Termination.
5.2.1 Seller may voluntarily terminate this Agreement upon expiration or
termination of an agreement to sell power to the Company.
5.2.2 After a Default, either Party may terminate this Agreement pursuant to
Section 6.5.
5.2.3 Upon termination or expiration of this Agreement, the Seller's Generation
Facility will be disconnected from the Company's transmission/distribution system. The termination or
expiration of this Agreement shall not relieve either Party of its liabilities and obligations, owed or
continuing at the time of the termination. The provisions of this Section shall survive termination or
expiration of this Agreement.
5.3 Temporary Disconnection. Temporary disconnection shall continue only for so
long as reasonably necessary under "Good Utility Practice." Good Utility Practice means any of the
practices, methods and acts engaged in or approved by a significant portion of the electric industry
during the relevant time period, or any of the practices, methods and acts which, in the exercise of
reasonable judgment in light of the facts known at the time the decision was made, could have been
expected to accomplish the desired result at a reasonable cost consistent with good business practices,
reliability, safety and expedition. Good Utility Practice is not intended to be limited to the optimum
practice, method, or act to the exclusion of all others, but rather to be acceptable practices, methods, or
acts generally accepted in the region. Good Utility Practice includes compliance with WECC or NERC
requirements. Payment of lost revenue resulting from temporary disconnection shall be governed by
the power purchase agreement.
5.3.1 Emergency Conditions. "Emergency Condition" means a condition or
situation: (1) that in the judgment of the Party making the claim is imminently likely to
endanger life or property; or (2) that, in the case of the Company, is imminently likely (as
determined in a non-discriminatory manner) to cause a material adverse effect on the
security of, or damage to the Company's transmission/distribution system, the
Company's Interconnection Facilities or the equipment of the Company's customers; or
(3) that, in the case of the Seller, is imminently likely (as determined in a non­
discriminatory manner) to cause a material adverse effect on the reliability and security
of, or damage to, the Generation Facility or the Seller's Interconnection Facilities. Under
Emergency Conditions, either the Company or the Seller may immediately suspend
interconnection service and temporarily disconnect the Generation Facility. The
Company shall notify the Seller promptly when it becomes aware of an Emergency
Condition that may reasonably be expected to affect the Seller's operation of the
Generation Facility. The Seller shall notify the Company promptly when it becomes
aware of an Emergency Condition that may reasonably be expected to affect the
Company's equipment or service to the Company's customers. To the extent
information is known, the notification shall describe the Emergency Condition, the extent
of the damage or deficiency, the expected effect on the operation of both Parties'
facilities and operations, its anticipated duration, and the necessary corrective action.
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I.P.U.C. No. 29, Tariff No.1 01 Page 3 of 9
5.3.2 Routine Maintenance, Construction, and Repair. The Company may
interrupt interconnection service or curtail the output of the Seller's Generation Facility
and temporarily disconnect the Generation Facility from the Company's
transmission/distribution system when necessary for routine maintenance, construction,
and repairs on the Company's transmission/distribution system. The Company will
make a reasonable attempt to contact the Seller prior to exercising its rights to interrupt
interconnection or curtail deliveries from the Seller's Facility. Seller understands that in
the case of emergency circumstances, real time operations of the electrical system,
and/or unplanned events, the Company may not be able to provide notice to the Seller
prior to interruption, curtailment or reduction of electrical energy deliveries to the
Company. The Company shall use reasonable efforts to coordinate such reduction or
temporary disconnection with the Seller.
5.3.3 Scheduled Maintenance. On or before January 31 of each calendar year,
Seller shall submit a written proposed maintenance schedule of significant Facility
maintenance for that calendar year and the Company and Seller shall mutually agree as
to the acceptability of the proposed schedule. The Parties determination as to the
acceptability of the Seller's timetable for scheduled maintenance will take into
consideration Good Utility Practices, Idaho Power system requirements and the Seller's
preferred schedule. Neither Party shall unreasonably withhold acceptance of the
proposed maintenance schedule.
5.3.4. Maintenance Coordination. The Seller and the Company shall, to the
extent practical, coordinate their respective transmission/distribution system and
Generation Facility maintenance schedules such that they occur simultaneously. Seller
shall provide and maintain adequate protective equipment sufficient to prevent damage
to the Generation Facility and Seller-furnished Interconnection Facilities. In some cases,
some of Seller's protective relays will provide back-up protection for Idaho Power's
facilities. In that event, Idaho Power will test such relays annually and Seller will pay the
actual cost of such annual testing.
5.3.5 Forced Outages. During any forced outage, the Company may suspend
interconnection service to effect immediate repairs on the Company's
transmission/distribution system. The Company shall use reasonable efforts to provide
the Seller with prior notice. If prior notice is not given, the Company shall, upon request,
provide the Seller written documentation after the fact explaining the circumstances of
the disconnection.
5.3.6 Adverse Operating Effects. The Company shall notify the Seller as soon
as practicable if, based on Good Utility Practice, operation of the Seller's Generation
Facility may cause disruption or deterioration of service to other customers served from
the same electric system, or if operating the Generation Facility could cause damage to
the Company's transmission/distribution system or other affected systems. Supporting
documentation used to reach the decision to disconnect shall be provided to the Seller
upon request. If, after notice, the Seller fails to remedy the adverse operating effect
within a reasonable time, the Company may disconnect the Generation Facility. The
Company shall provide the Seller with reasonable notice of such disconnection, unless
the provisions of Article 5.3.1 apply.
5.3.7 Modification of the Generation Facilitv. The Seller must receive written
authorization from the Company before making any change to the Generation Facility
that may have a material impact on the safety or reliability of the Company's
transmission/distribution system. Such authorization shall not be unreasonably withheld.
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I.P.u.C. No. 29. Tariff No. 101 Page 4 of 9
Modifications shall be done in accordance with Good Utility Practice. If the Seller makes
such modification without the Company's prior written authorization, the latter shall have
the right to temporarily disconnect the Generation Facility.
5.3.8 Reconnection. The Parties shall cooperate with each other to restore the
Generation Facility, Interconnection Facilities, and the Company's
transmission/distribution system to their normal operating state as soon as reasonably
practicable following a temporary disconnection.
5.3.9 Voltage Levels. Seller, in accordance with Good Utility Practices, shall
minimize voltage fluctuations and maintain voltage levels acceptable to Idaho Power.
Idaho Power may, in accordance with Good Utility Practices, upon one hundred eighty
(180) days' notice to the Seller, change its nominal operating voltage level by more than
ten percent (10%) at the Point of Delivery, in which case Seller shall modify, at Idaho
Power's expense, Seller's equipment as necessary to accommodate the modified
nominal operating voltage level.
5.4 Land Rights.
5.4.1 Seller to Provide Access. Seller hereby grants to Idaho Power for the
term of this Agreement all necessary rights-of-way and easements to install, operate,
maintain, replace, and remove Idaho Power's Metering Equipment, Interconnection
Equipment, Disconnection Equipment, Protection Equipment and other Special Facilities
necessary or useful to this Agreement, including adequate and continuing access rights
on property of Seller. Seller warrants that it has procured sufficient easements and
rights-of-way from third parties so as to provide Idaho Power with the access described
above. All documents granting such easements or rights-of-way shall be subject to
Idaho Power's approval and in recordable form.
5.4.2 Use of Public Rights-of-Way. The Parties agree that it is necessary to
avoid the adverse environmental and operating impacts that would occur as a result of
duplicate electric lines being constructed in close proximity. Therefore, subject to Idaho
Power's compliance with Paragraph 5.4.4, Seller agrees that should Seller seek and
receive from any local, state or federal governmental body the right to erect, construct
and maintain Seller-furnished Interconnection Facilities upon, along and over any and all
public roads, streets and highways, then the use by Seller of such public right-of-way
shall be subordinate to any future use by Idaho Power of such public right-of-way for
construction and/or maintenance of electric distribution and transmission facilities and
Idaho Power may claim use of such public right-of-way for such purposes at any time.
Except as required by Paragraph 5.4.4, Idaho Power shall not be required to
compensate Seller for exercising its rights under this Paragraph 5.4.2.
5.4.3 Joint Use of Facilities. Subject to Idaho Power's compliance with
Paragraph 15.4.4, Idaho Power may use and attach its distribution and/or transmission
facilities to Seller's Interconnection Facilities, may reconstruct Seller's Interconnection
Facilities to accommodate Idaho Power's usage or Idaho Power may construct its own
distribution or transmission facilities along, over and above any public right-of-way
acquired from Seller pursuant to Paragraph 5.4.2, attaching Seller's Interconnection
Facilities to such newly constructed facilities. Except as required by Paragraph 5.4.4,
Idaho Power shall not be required to compensate Seller for exercising its rights under
this Paragraph 5.4.3.
5.4.4 Conditions of Use. It is the intention of the Parties that the Seller be left in
substantially the same condition, both financially and electrically, as Seller existed prior
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I,P.u .C. No. 29, Tariff No.1 01 Page 5 of 9
to Idaho Power's exercising its rights under this Paragraph 5.4. Therefore, the Parties
agree that the exercise by Idaho Power of any of the rights enumerated in Paragraphs
5.4.2 and 5.4.3 shall: (1) comply with all applicable laws, codes and Good Utility
Practices, (2) equitably share the costs of installing, owning and operating jointly used
facilities and rights-of-way. If the Parties are unable to agree on the method of
apportioning these costs, the dispute will be submitted to the Commission for resolution
and the decision of the Commission will be binding on the Parties, and (3) shall provide
Seller with an interconnection to Idaho Power's system of equal capacity and durability
as existed prior to Idaho Power exercising its rights under this Paragraph 5.4.
6. Assignment. Liability, Indemnity. Force majeure. Consequential Damages and Default.
6.1 Assignment. This Agreement may be assigned by either Party upon twenty-one
(21) calendar days prior written notice and opportunity to object by the other Party; provided
that:
6.1.1 Either Party may assign this Agreement without the consent of the other
Party to any affiliate of the assigning Party with an equal or greater credit rating and with
the legal authority and operational ability to satisfy the obligations of the assigning Party
under this Agreement.
6.1.2 The Seller shall have the right to contingently assign this Agreement,
without the consent of the Company, for collateral security purposes to aid in providing
financing for the Generation Facility, provided that the Seller will promptly notify the
Company of any such contingent assignment.
6.1.3 Any attempted assignment that violates this article is void and ineffective.
Assignment shall not relieve a Party of its obligations, nor shall a Party's obligations be
enlarged, in whole or in part, by reason thereof. An assignee is responsible for meeting
the same financial, credit, and insurance obligations as the Seller. Where required,
consent to assignment will not be unreasonably withheld, conditioned or delayed.
6.2 Limitation of Liability. Each Party's liability to the other Party for any loss, cost,
claim, injury, liability, or expense, including reasonable attorney's fees, relating to or arising from
any act or omission in its performance of this Agreement, shall be limited to the amount of direct
damage actually incurred. In no event shall either Party be liable to the other Party for any
indirect, special, consequential, or punitive damages, except as authorized by this Agreement.
6.3 Indemnity.
6.3.1 This provision protects each Party from liability incurred to third parties as
a result of carrying out the provisions of this Agreement. Liability under this provision is
exempt from the general limitations on liability found in Article 6.2.
6.3.2 The Parties shall at all times indemnify, defend, and hold the other Party
harmless from, any and all damages, losses, claims, including claims and actions
relating to injury to or death of any person or damage to property, demand, suits,
recoveries, costs and expenses, court costs, attorney fees, and all other obligations by
or to third parties, arising out of or resulting from the other Party's action or failure to
meet its obligations under this Agreement on behalf of the indemnifying Party, except in
cases of gross negligence or intentional wrongdoing by the indemnified Party.
6.3.3 If an indemnified person is entitled to indemnification under this article as
a result of a claim by a third party, and the indemnifying Party fails, after notice and
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I.P.u.C. No. 29, Tariff No. 101 Page 6 of 9
reasonable opportunity to proceed under this article, to assume the defense of such
claim, such indemnified person may at the expense of the indemnifying Party contest,
settle or consent to the entry of any judgment with respect to, or pay in full, such claim.
Failure to defend is a Material Breach.
6.3.4 If an indemnifying party is obligated to indemnify and hold any
indemnified person harmless under this article, the amount owing to the indemnified
person shall be the amount of such indemnified person's actual loss, net of any
insurance or other recovery.
6.3.5 Promptly after receipt by an indemnified person of any claim or notice of
the commencement of any action or administrative or legal proceeding or investigation
as to which the indemnity provided for in this article may apply, the indemnified person
shall notify the indemnifying party of such fact. Any failure of or delay in such notification
shall be a Material Breach and shall not affect a Party's indemnification obligation unless
such failure or delay is materially prejudicial to the indemnifying party.
6.4 Force Majeure. As used in this Agreement, "Force Majeure" or "an event of
Force Majeure" means any cause beyond the control of the Seller or of the Company which,
despite the exercise of due diligence, such Party is unable to prevent or overcome. Force
Majeure includes, but is not limited to, acts of God, fire, flood, storms, wars, hostHities, civil
strife, strikes and other labor disturbances, earthquakes, fires, lightning, epidemics, sabotage, or
changes in law or regulation occurring after the Operation Date, which, by the exercise of
reasonable foresight such party could not reasonably have been expected to avoid and by the
exercise of due diligence, it shall be unable to overcome. If either Party is rendered wholly or in
part unable to perform its obligations under this Agreement because of an event of Force
Majeure, both Parties shall be excused from whatever performance is affected by the event of
Force Majeure, provided that:
(1) The non-performing Party shall, as soon as is reasonably possible after
the occurrence of the Force Majeure, give the other Party written notice describing the
particulars of the occurrence.
(2) The suspension of performance shall be of no greater scope and of no
longer duration than is required by the event of Force Majeure.
(3) No obligations of either Party which arose before the occurrence causing
the suspension of performance and which could and should have been fully performed
before such occurrence shall be excused as a result of such occurrence.
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I,P.U.C. No. 29. Tariff No. 101 Page 7 of 9
6.5 Default and Material Breaches.
6.5.1 Defaults. If either Party fails to perform any of the terms or conditions of
this Agreement (a "Default" or an "Event of Oefau/t'J, the nondefaulting Party shall cause
notice in writing to be given to the defaulting Party, specifying the manner in which such
defal.!lt occurred. If the defaulting Party shall fail to cure such Default within the sixty
(60) days after service of such notice, or if the defaulting Party reasonably demonstrates
to the other Party that the Default can be cured within a commercially reasonable time
but not within such sixty (60) day period and then fails to diligently pursue such cure,
then, the nondefaulting Party may, at its option, terminate this Agreement and/or pursue
its legal or equitable remedies.
6.5.2 Material Breaches. The notice and cure provisions in Paragraph 6.6.1 do
not apply to Defaults identified in this Agreement as Material Breaches. Material
Breaches must be cured as expeditiously as possible following occurrence of the
breach.
7. Insurance.
During the term of this Agreement, Seller shall secure and continuously carry the following
insurance coverage:
7.1 Comprehensive General Liability Insurance for both bodily injury and property
damage with limits equal to $1,000,000, each occurrence, combined single limit. The deductible
for such insurance shall be consistent with current Insurance Industry Utility practices for similar
property.
7.2 The above insurance coverage shall be placed with an insurance company with
an A.M. Best Company rating of A-or better and shall include:
(a) An endorsement naming Idaho Power as an additional insured and loss
payee as applicable; and
(b) A proVision stating that such policy shall not be canceled or the limits of
liability reduced without sixty (60) days' prior written notice to Idaho Power.
I
7.3 Seller to Provide Certificate of Insurance. As required in Paragraph 7 herein and
annually thereafter, Seller shall furnish the Company a certificate of insurance, together with the
endorsements required therein, evidencing the coverage as set forth above.
7.4 Seller to Notify Idaho Power of Loss of Coverage -If the insurance coverage
required by Paragraph 7.1 shall lapse for any reason, Seller will immediately notify Idaho Power
in writing. The notice will advise Idaho Power of the specific reason for the lapse and the steps
Seller is taking to reinstate the coverage. Failure to provide this notice and to expeditiously
reinstate or replace the coverage will constitute grounds for a temporary disconnection under
Section 5.3 and will be a Material Breach.
B. Miscellaneous.
B.1 Governing Law. The validity, interpretation and enforcement of this Agreement
and each of its provisions shall be governed by the laws of the state of Idaho without regard to
its conflicts of law principles.
B.2 Salvage. No later than sixty (60) days after the termination or expiration of this
Agreement, Idaho Power will prepare and forward to Seller an estimate of the remaining value
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29. Tariff No.1 01 Page 8 of 9
of those Idaho Power furnished Interconnection Facilities as required under Schedule 72 and/or
described in this Agreement, less the cost of removal and transfer to Idaho Power's nearest
warehouse, if the Interconnection Facilities will be removed. If Seller elects not to obtain
ownership of the Interconnection Facilities but instead wishes that Idaho Power reimburse the
Seller for said Facilities the Seller may invoice Idaho Power for the net salvage value as
estimated by Idaho Power and Idaho Power shall pay such amount to Seller within thirty (30)
days after receipt of the invoice. Seller shall have the right to offset the invoice amount against
any present or future payments due Idaho Power.
9. Notices.
9.1 General. Unless otherwise provided in this Agreement, any written notice,
demand, or request required or authorized in connection with this Agreement ("Notice") shall be
deemed properly given if delivered in person, delivered by recognized national currier service,
or sent by first class mail, postage prepaid, to the person specified below:
If to the Seller:
Seller: ------------------------------------------------Attention: Address: ---------------------------------------------------
City: __________ State: ____ Zip: ____ _
Phone: Fax:
If to the Company:
Idaho Power Company -Delivery
Attention: Operations Manager
1221 W. Idaho Street
Boise: Idaho 83702
--------------
Phone: [phone] Fax: [phone]
9.2
out below:
Billing and Payment. Billings and payments shall be sent to the addresses set
Seller: _____________________________________________ _
Attention: _________________________________________________ _
Address: _________________________________________________ _
City: State: Zip: Phon-e-:--------~F~ax: ----~ ------
Idaho Power Company -Delivery
Attention: Corporate Cashier
PO Box 447
Salt Lake City Utah 84110-0447
Phone: [phone] email: [e-mail]
9.3 Designated Operating Representative. The Parties may also designate
operating representatives to conduct the communications which may be necessary or
convenient for the administration of this Agreement. This person will also serve as the point of
contact with respect to operations and maintenance of the Party's facilities.
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I.P.U.C. No. 29, Tariff No.1 01 Page 9 of 9
Seller's Operating Representative:
Seller: _____________________ _
Attention: ________________________ _
Address: ________________________ _
City: _________ ~State:----.:Zip: ____ _
Phone: Fax: --------
Company's Operating Representative:
Idaho Power Company -Delivery
Attention: Outage Coordinator -System/Regional Dispatch
1221 W. Idaho Street
Boise, Idaho 83702
Over 138kV phone [phone] during regular business hours
Under 138kV Phone: [phone], or 388-5175 during regular business hours
After hours -System Dispatch 388 2826
Regional Dispatch
Southern Region 208-388-5190
9.5 Changes to the Notice Information. Either Party may change this information by
giving five (5) Business Days written notice prior to the effective date of the change.
10. Signatures.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their
respective duly authorized representatives.
For the Seller
Name: ______________________ __
Tit/e: ___________________ __
Date: _________ _
For the Company
Name:
Title: Director, Load Serving Operations -Idaho Power Company
Date: __________ _
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u.C. No. 29, Tariff No.1 01 Page 1 of 3
Attachment 1
Description and Costs of the Generation Facility, Interconnection Facilities and Metering Equipment
Interconnection Details
Type of Interconnection Service: Studied as an Idaho Power Network Resource under PURPA
Full Output: 18 MW (both projects)
Nominal Delivery Voltage: 12.5 kV
General Facility Description
The Notch Butte Wind Park project includes both Projects #349 and #359 for a total of 18 MW of power
provided by seven 2.5Mw Nordex Turbines. The Interconnection Customer (IC) will provide all
generation and station equipment required to deliver power at 12.5 kV to the Point of Interconnection
(POI) which is located at the coordinates North 420 53.12948' West 1140 10.57'. The Seller will provide
two POTS lines and two DDS circuits to the POls (one pair for each feeder connection) for
communication. Two 12.5 kV feeders will run from the POI four miles west to the IPCo Dietrich
SUbstation where the station will be expanded to accommodate the two new feeders. The power will be
converted to 138 kV via a 12.5 kV to 138 kV power circuit transformer. A new double circuit
transmission line, consisting of a new 138 kV line and the existing 46 kV line, will run four miles due
north out of the Dietrich substation. The new 138 kV line will connect to the existing Midpoint-Silver
138 kV line.
Interconnection Point
The Interconnection Point for the Notch Butte Wind Park Project will be the generator side of the
disconnect switches labeled Disconnect Switches A-13 and A-14 (one for each feeder) as shown on the
attached Single Line drawings 210-64299, sheets 1 & 2. This Interconnection Point is in Lincoln
County, 10 -T6S, R19E, SW corner of Section 22.
A drawing identifying the Point of Interconnection is included as Attachment 2. The Point of Change of
Ownership is electrically the same as the Interconnection Point.
Seller's Interconnection Facilities
The Seller will install all generation and station equipment required to deliver power at 12.5 kV to the
interconnection point. Transmitting 18 MW of power at 12.5 kV requires two distribution feeders. The
Seller shall balance the generation between these two feeder connections with no more than 11 MWof
power flowing on either feeder. The Seller will own and maintain facilities electrically located on the
Interconnection Customer side of the Point of Change of Ownership. Idaho Power will own and
maintain the facilities electrically located on the IPCo side of the Point of Change of Ownership.
The Seller will install equipment to receive signals from Idaho Power Company Grid Operations for
Generator Output Limit Control ("GOlC") -see Attachment 4 Operating Requirements.
The Seller will provide phone service to IPCo's generator interconnect package as described in
Telecommunications below.
The Seller will provide a DNP 3.0 serial data connection to the local Idaho Power Company SCADA
RTU when any communication with Seller-owned and maintained equipment is required for GOlC,
voltage control or other plant monitoring or control. Preliminary points lists and functional description
were provided to the Seller in the Facility Study Report.
All interconnection equipment electrically located on the generator side of the Point of Change
Ownership shall be owned and maintained by the Seller.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29. Tariff No.1 01 Page 2 of 3
Other Facilities Provided by Seller
In addition to communication circuits that may be needed by the Seller, the Seller shall provide the
following communication circuits for Idaho Power's use:
Two POTS (Plain Old Telephone Service) dial-up circuit for querying the revenue meter at the
generation interconnection site. One for each 4-pole feeder connection.
Two leased DDS (Digital Data Service) circuit for SCADA between the generation interconnection site
and Twin Falls Service Building (273 Blue Lakes Blvd. S., Twin Falls, ID 83301). One for each 4-pole
feeder connection. These circuits must operate at 19.2 kbps data rate. Please note that Frame Relay
service is not acceptable.
The Interconnection Customer/communications provider shall provide a demarcation box and terminate
the specified communications circuits at the demarcation box. The location of the demarcation box will
be determined by Idaho Power. The demarcation box shall meet the following requirements:
• Be accessible by both the communications provider and Idaho Power
• The location shall be near Idaho Power's equipment and shall be subject to approval by
Idaho Power
• The communications cable pairs shall be labeled/tagged accordingly (Le. circuit number,
phone number, transmit, receive, etc.)
The Seller is required to coordinate with a communications provider to provide the communications
circuits and pay the associated one time setup and periodic charges. The communication circuits will
need to be installed and operational prior to generating into the Idaho Power system. Note that
installation by communications provider may take several months and should be ordered in advance to
avoid delaying the project. If the communication circuit types listed above are not available at the site
by a communications provider, the Seller shall confer with Idaho Power.
If high voltage protection is required by the communications provider for the incoming communications
provider cable, the high voltage protection assembly shall be engineered and supplied by the Seller.
Options are available for indoor or outdoor mounting. The high voltage protection assembly shall be
located in a manner that provides Idaho Power 24-hour access to the assembly for trouble-shooting of
Idaho Power owned equipment.
Ground Fault Equipment
The Seller will install transformer configurations that are Grounded-WYE to Grounded-WYE and will
limit the contribution of the ground fault current to 20 amps or less at the Interconnection Point.
Monitoring Information
If the Seller requires the ability to monitor information related to the Idaho Power reclosers in the
generation interconnection package they are required to supply their own communications circuit to the
control box.
Easements
The Seller will provide to IPCO a surveyed (Metes & Bounds) legal description along with exhibit map
for IPCO's facilities at the Interconnection Point. After the legal description has been delivered to IPCO
for review, IPCO will supply to the Interconnection Customer a completed IPCO easement for signature
by the land owner of record. Once the signatures have been secured, the Seller will return the signed
easement to IPCO for recording.
Generator Output Limit Control
The Seller will install equipment to receive signals from Idaho Power Grid Operations for Generation
Output Limit Control ("GOLCn
) -see Attachment 4 Operating Requirements.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No.1 01 Page 3 of 3
Local Service
The Seller is responsible to arrange for local service to their site, as necessary.
Idaho Power Company's Interconnection Facilities
Idaho Power will install two standard generation interconnection packages, one for each feeder. For
each package, if the Seller is going underground to the Interconnection Point, Idaho Power will include
a pole riser for the Generator to install cables to interconnect to the Idaho Power system. If the Seller is
going overhead to the Interconnection Point, it will be at a tension not to exceed the design tension
specified by Idaho Power.
The new interconnection packages each will include four distribution poles to mount a local service
transformer, solid blade disconnects, primary metering package, recloser, relays, RTU, fuses and riser
necessary for the package. The interconnection will be controlled by a SEL-311 C line protection relay
and a GE iBox RTU. The relay and RTU will be located in a pole mounted enclosure and will also
contain a test switch (TS4), SLSS, dialup modem, DDS CSU/DSU, isolation interface, power supply,
DC converter, control switch and surge protector.
Concrete barriers may be necessary to protect this equipment from local area traffic.
A 2" conduit will be installed alongside the underground primary to facilitate information exchange to the
customer about the recloser. (The Interconnection Customer is responsible for providing and installing
the appropriate cable.)
See single line drawing as Attachment 2.
All interconnection equipment electrically located on the utility side of the Interconnection Point shall be
owned, operated, and maintained by Idaho Power.
Maintenance Coordination Exception
The Seller's protective relays will not provide back-up protection for Idaho Power facilities, therefore the
last 2 sentences in Section 5.3.4 of this Generator Interconnection Agreement do not apply to this
Generation Facility.
Estimated Cost & Ownership
The following good faith estimates are provided in 2011 dollars:
'Interconnection Facilities: -----
:Ir:!!.~rcor:!ru:l<:tion P§I~k§l9~l?_ (~t __ :IPC 1$440,000
SUBTOTAL $440,000 ___ ~_
Sef!... Atl achment 6 for Total Estima~e Costs
Full payment is required up front in accordance with Schedule 72, unless payment arrangements are
made in advance with Idaho Power Operations Finance (see Attachment 3).
Billing for construction activities will be based upon actual expenditures.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u .C. No. 29, Tariff No.1 01 Page 1 of 3
Attachment 2
One-line Diagram Depicting the Small Generation Facility, Interconnection Facilities, Metering
Equipment and Upgrades
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I.P.U.C. No. 29, Tariff No. 101 Page 3 of 3
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Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 1 of3
Attachment 3
Milestones for Interconnecting to the Generation Facilitv
Idaho Power Company agrees only to the Construction timelines under its direct control provided in the
Facility Study Report for this Project.
These milestones will begin, and the construction schedule referenced below, will only be valid upon
receipt of funding in full from the Seller or their authorized third party no later than the date set forth
below for such payment. Additionally, failure by Seller to make the required payments as set forth in
this Agreement by the date(s) specified below will be a material breach of this Agreement, which may
result in any or all of the following: (i) loss of milestone dates and construction schedules set forth
below: (ii) immediate termination of this Agreement by Idaho Power; (iii) removal from the generator
interconnection queue.
Limited Generation Output
In response to the Seller's request to come on line by December 15, 2012 with a limited generation
output, IPC conducted additional power flow models. It was determined that acceptable voltage on the
46 kV system could be maintained with 4.0 MW of generation from Notch Butte Wind Park if the
generators have the ability to absorb 3.0 MVAr. The installation of a 46 kV potential transformer
transfer/trip package would have to be added to the scope/costs of the work at Dietrich substation. The
Seller will be responsible for absorbing the VArs (3.0 maximum) necessary to maintain a 1.075 p.u.
maximum 46 kV bus voltage at Dietrich substation. A voltage level above 1.075 p.u. will cause the
generator to be tripped offline.
Idaho Power will provide the magnitude of the 46kV bus voltage at Dietrich station to the customer's
control system. The voltage value will be made available to the seller's control system via the
measurement device at Dietrich (e.g. meter or relay) and a direct, serial connection via the new feeder
ADSS fiber optics. Data protocol and point formatting to be determined.
The estimated cost of this additional work is $75,000. This brings the total estimated project cost to
$7,950,000. If the Generator Interconnection Agreement is signed and the project is funded before
July 9,2012, then temporary facilities can be constructed in order to bring project, at limited output of 4
MW, on line by December 15, 2012.
Critical milestones and responsibility as agreed to by the Parties under limited ouput:
12/1/2012 'Seller
'IPCO receives the remaining balance of Construction
'estimate $7,950,000 OR Credit arrangements are approved
:by IPCO
Customer GOLC ready to connect & customer telecomm
.. :~~guJ!~'!!~(lt~. ~~f! cqrfJ.plete _ _
112/15/2012 IPca ./PCO Construction Complete _.--- -~ ---12/15/2012 IPca
12/15/2012 IPca -'12/15/2012 IPCO
12/15/2012 :Seller
-
12/31/2012 :Seller
-IPCO Commissioning Complete
- -
Project Leader issues Construction Complete Letter
:Manager of Grid Operations authorizes project to be
energized, upon verification that Seller has previously met
Schedule 72, Sec 7 !!!surance requirements
Customer testing begins
-
Customers requested In-Service Date
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 2 of 3
NOTE REGARDING LIMITED OUTPUT MILESTONES:
* Seller has requested an in-seNice date of 12/15/2012. Idaho Power will use reasonable efforts to
have commissioning complete by this time if funding for project is received by July 9, 2012. This
date is contingent upon all materials being delivered in a timely manner, as well as other factors,
some of which are described above. The parties hereby acknowledge that Idaho Power shall not be
liable to for any possible damages associated in any way with Renewable Energy Credits or
Attributes, tax credits, the firm energy sales agreements, and the like, attributable to Customer, or
any of the various projects named on page one of this GIA, should the 12/15/2012 date not be met.
Under normal efforts to bring the projects online a normal amount of overtime is utilized. Because of
the Seiler'S desire to meet an IPC commissioning prior to 12/15/2012, Seller hereby authorizes IPC
to incur additional expenses, including additional overtime, lodging, travel, and other expenses
needed to bring in other IPC resources and personnel from other IPC regions, or to utilize third party
contractors, as necessary to work on this interconnection.
Critical milestones and responsibility as agreed to by the Parties under full output:
i/PCO receives the remaining balance of Construction
'esUmate $7,875,000 OR Credit arrangements are approved I
by IPCO __ _ _ _
,Customer GOLC ready to connect & customer telecomm
:[~gLlJ!~f!1~f1!§ ?~e c0f!1p/~Jf!_ .
:5/112015 'IPCO ;IPCO Construction Complete
'IPCO Commissioning Complete --1
, -----:5/15/2015 IPCO
,IPCO
;IPCO
I -511512015 1 _. __ _
15/15/2015
-'5/15/2015 ISellec
7/20/2015 iSeller
----:Project Leader issues Construction Complete Letter
Manager of Grid Operations authorizes project to be
energized, upon verification that Seller has previously met
_Sche~ule 72, .§~~ 7 !f!stJr~nc~ r~quir~m.elJt~
: Customer testing begins --Customer's requested In-Service Date I __ I
Idaho Power requires approximately thirty-four (34) months to complete design, procurement,
construction, permitting, and commissioning of the necessary interconnection facilities and required
upgrades associated with the Notch Butte Wind Park Project prior to the Commercial Operation Date.
This timeframe assumes that material can be procured, labor resources are available, and that
outages to the existing system are available to be scheduled.
There is approximately 1.5 miles of the existing 46 kV transmission line which is located on BLM
land. A permit (ROW grant) will be required from the BLM in order to re-build this portion of the line
for the double circuit transmission as well as the 138 kV transmission line switches where the new
138 kV line connects to the existing transmission line. Obtaining a ROW grant from the BLM is
never guaranteed and is typically a 20-30 month process at this point in time. This is outside of
Idaho Power's control. If the ROW grant is denied then a new interconnection solution would be
required and this could drastically alter project costs and timeline.
Idaho Power Company
I.P.U.C. No. 29, Tariff No.1 01
Agreed to by:
For the Seller:
For the Transmission Provider
Idaho Power Company
Generator Interconnection Agreement # 349/359
Page 3 of 3
Date. _____ _
Date ._-----
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u.C. No. 29, Tariff No. 101 Page 1 of 2
Attachment 4
Additional Operating Requirements for the Company's Transmission System and Affected Systems
Needed to Support the Seller's Needs
The Company shall also provide requirements that must be met by the Seller prior to initiating
parallel operation with the Company's Transmission System.
Operating Requirements
The project is required to comply with the applicable Voltage and Current Distortion Limits found in
I EEE Standard 519-1992 IEEE Recommended Practices and Requirements for Harmonic Control in
Electrical Power Systems or any subsequent standards as they may be updated from time to time.
Seller will be able to modify power plant facilities on the generator side of the Interconnection Point with
no impact upon the operation of the transmission system whenever the generation facilities are
electrically isolated from the transmission system via the A-13 and A-14 switches and a terminal
clearance is issued by Idaho Power Company's Grid Operator.
Generator Output Limit Control (liRe-dispatch" or "GOLC'1 The Project will be subject to
reductions directed by Idaho Power Company Grid Operations during transmission system
contingencies and other reliability events. When these conditions occur, the Project will be subject to
Generator Output Limit Control ("GOlC") and have equipment capable of receiving signals from Idaho
Power for GOlC. Generator Output Limit Control will be a setpoint from Idaho Power to the Project
indicating maximum output allowed. See Attachment 7 for details.
Voltage flicker at startupand during operation will be limited to less than 5% as measured at the
Interconnection Point. It is preferable to bring each generating unit online separately to minimize
voltage flicker on the distribution system.
Low Voltage Ride Through
The Project must be capable of riding through faults on adjacent section of the power system without
tripping due to low voltage. It has been determined, through study, that the Project must be capable of
remaining interconnect for any single phase voltage as low as 0.7 PU for 30 cycles, and for all three
phase voltages as low as 0.8 PU for 30 cycles.
Ground Fault Equipment
The Seller will install transformer configurations that are Grounded-Wye to Grounded-Wye and will limit
the contribution of the ground fault current to 20 amps or less at the Interconnection Point.
Meteorlogical Data
Historical wind data -Within 60 days after execution of this Agreement, the Seller shall provide Idaho
Power with the following:
a) historical wind data in an electronic format from the proposed Facility site or for a location within
two miles of the Facility site.
b) a third party wind assessment study report used by Seller to value investment in the Facility.
No later than 30 days prior to the Commercial Operation Date, the Seller shall have:
a) Erected at the site at least one (1) high quality, approximate hub-height (plus or minus 20
meters), permanent, meteorological wind measurement tower(s) at location(s) on the site equipped
with:
(i)
(ii)
(iii)
(iv)
Two (2) anemometers per tower;
Two (2) air temperature sensors per tower;
One (1) barometric pressure sensor (with OCP sensor); and
Two (2) wind vanes per tower.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 2 of 2
Facility availability status shall be provided as described in the Final Facility Study no later than within
the calendar month following the month of the Commercial Operation Date. Failure by the Seller to
operate and maintain this equipment to provide such meteorological and turbine availability data in a
manner to provide reasonably accurate and dependable data for the full term of this Agreement shall be
an event of Default under paragraph 6.5.1.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 1
Attachment 5
Reactive Power Requirements
The project must be controlled to operate at unity power factor +/-500 kVar.
Voltage flicker at startup and during operation will be limited to less than 5% as measured at the
Interconnection Point.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 2
Attachment 6
Company's Description of Special Facilities and Upgrades Required to Inteqrate the Generation Facilitv
and Best Estimate of Costs
As provided in Schedule 72 this Attachment describes Upgrades, Special Facilities, including
Network Upgrades, and provides an itemized best estimate of the cost of the required facilities.
Upgrades
Upgrades to Substation Facilities
Two new 12.5 kV feeder bays with associated switches, breakers, relays etc at Dietrich substation
A new 138: 12.5 kV power transformer and associated equipment at Dietrich SUbstation with protection
package, control building.
Line relay and microwave upgrades at Midpoint SUbstation
DTRC-MPSN microwave reflector site (near Notch Butte)
Upgrades to Distribution Facilities
A new double circuit (DTRC-013 and 014) 12.5 kV distribution line from Dietrich SUbstation to the point
of interconnection (4 miles). This new distribution line will be built with 795 MC conductor on both
circuits with ADSS underbuild.
Upgrades to Transmission Facilities
Idaho Power will rebuild 4 miles of the existing 46 kV transmission line (T-128) with a double circuit
transmission line that will accommodate both the existing 46 kV line as well as the new 138 kV line.
The new 138 kV line will then tap into the existing Midpoint-Silver 138 kV line with line switches on all
three sides of the tap.
The following good faith estimates are provided in 2012 dollars:
Descri iQ=" ________ ~ _ __':;....._..,;.;.. ........ _____ ...... ,&.:,:~=.~_ ......... __ ....;i..:;;:.c..:=_::.c'=_ .. ~
Interconnection Facilities: -----
'-rl!~!c::gnnection fJCick_ag~~ .(2)IPC
:CJi.~~~ib..utiolJ l!pgrad~~:. _
'Distribution Feeders to Dietrich SUbstation (DTRC-013
~~ 9-.IR9~91-4.L~!th ApSS fib13r 'IPC
$.'!.b~tCl.(iCJTJ.l.!pg!ad.~s; .
'Dietrich SUbstation Additions -. ----.--
)'v1[gpoint ~elay upgrade~
~M!9poi~ ~iGrowCi.v~lJ!?gr~d~~._
DTRC·MPSON Microwave Reflector Site
Transmission Upgr..ades:
Hemove 4 miles of 46 kV line with underbuild
:Build 4 miles of line to double circuit
3 -138 kV Line Switches
'*BLf'A Per_mittir:lg/RqW Grant
GRAND TOTAL
IPC
'IPC
.IPC
IPC
IPC
IPC
IPC
IPC
'$440 ,000
$2,835,000
'$.~5,OQ9
$1 ~9.,QOO
~325 ,9Q.O
.$130,000
$2 ,550,000
;$300,000
$75,000
$7,875,000
Idaho Power Company Generator Interconnection Agreement # 349/359
I,P.U.C. No. 29, Tariff No.1 01 Page 2 of 2
*There is approximately 1.5 miles of the existing 46 kV transmission line which is located on BLM land.
A permit will be required from the BLM in order to rebuild this portion of the line to double circuit as well
as install the transmission line switches. The costs for this permitting can vary widely and have been
estimated at a combined $75K.
Note Regarding Transmission Service:
This Facility Study is a Network Resource Interconnection Facility Study. This study identifies the
facilities necessary to integrate the Generating Facility into Idaho Power's network to serve load
within Idaho Power's balancing area. Network Resource Interconnection Service in and of itself
does not convey any right to deliver electricity to any specific customer or Point of Delivery.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u.C. No. 29. Tariff No.1 01 Page 1 of 2
Attachment 7
Generation Interconnection Control Requirements
Generator Output Limit Control (GOLC)
IPC requires Interconnected Power Producers to accept GOlC signals from our EMS.
The GOlC signals will consist of four points shared between the IPC EMS and the Customer's
Generator Controller:
GOlC Setpoint: An analog output that contains the MW value the Customer should curtail to, should a
GOlC request be made via the GOlC On/Off discrete output Control point.
An Analog Input feedback point must be updated (to reflect the GOlC setpoint value) by the Customer
Controller upon the Controller's receipt of the GOlC setpoint change, with no intentional delay.
GOlC On/Off: A discrete output (DO) control point with latching Off/On states. Following a "GOlC On"
control, the Customer Controller will run power output back to the MW value specified in the GOlC
Setpoint. Following a "GOlC Off' control, the Customer is free to run to maximum possible output.
A Discrete Input feedback point must be updated (to reflect the GOLC DO state) by the Customer
Controller upon the Controller's receipt of the GOlC DO state change, with no intentional delay.
If a GOlC control is issued, it is expected to see MW reductions start within 1 minute and plant output
to be below the GOLC Setpoint value within 10 minutes.
Voltage Control
Idaho Power Company requires Transmission-Interconnected Power Producers to accept Voltage
Control signals from our EMS when they are connected to our transmission system.
The voltage control will consist of one setpoint and one feedback point shared between the IPC EMS
and the Customer Controller.
The setpoint will contain the desired target voltage for the plant to operate at.
The control will always be active, there is no digital supervisory point like the Curtail On/Off control
above.
When a setpoint change is issued an Analog Input feedback point must be updated (to reflect the
Voltage Control setpoint value) by the Customer Controller upon the Controller's receipt of the Voltage
Control setpoint change, with no intentional delay.
When a setpoint change is received by the Customer Controller, the Voltage Control system should
react with no intentional delay.
The voltage control system should operate in a dead band of +/-5% of the control setting range.
The customer should supervise this control by setting up "reasonability limits", i.e. configure a
reasonable range of values for this control to be valid. As an example, they will accept anything
between .95 and 1.05 for the set point. In the case they are fed an erroneous value outside this range,
their control system defaults to the last known, good value.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No.1 01 Page 2 of 2
Generation Interconnection Data Points Requirements
Digital Inputs to IPCo (DNP Obj. 01, Var. 2)
Index Description State (0/1) Comments:
0 52A Customer Capacitor Breaker (if present) Open/Closed Sourced at SUbstation
1 GOlC Off/On Control Received (Feedback) Off/On Provided by Customer
Digital Outputs to Customer (DNP Obj. 10, Var. 1)
Index Description Comments:
0 GOlC Off/On Provided by IPCO
NOTE: GOlC Setpoint indicates MW value to curtail to when GOlC Off/On DO is ON.
Analog Inputs to IPCo (DNP Obj. 30, Var. 2)
Raw Raw EU EU
Index Description High low High EU low Units Comments:
GOlC Setpoint Value Received -Provided by
0 (Feedback) 32767 32768 TBD TBD MW Customer
Voltage Control Setpoint Value Rec'd -Provided by
1 (Feedback) 32767 32768 TBD TBD kV Customer
-Provided by
2 Maximum Park Generating Capacity 32767 32768 TBD TBD MW Customer
-Provided by
3 Number of Turbines In High Speed Cutout 32767 32768 32767 -32768 Units Customer
-For Provided by
4 Ambient Temperature 32767 32768 327.67 -327.68 C Customer
-Provided by
5 Wind Direction 32767 32768 3276.7 -3276.8 Deg Customer
MPH
-or Provided by
6 Wind Speed 32767 32768 327.67 -327.68 m/s Customer
Analog Outputs to Customer (DNP Obj. 40, Var. 2)
Raw Raw EU EU EU
Index Description High low High low Units Comments:,
-
0 GOlC Setpoint 32767 32768 TBD TBD MW Provided by IPCO
-
1 Voltage Control Setpoint 32767 32768 TBD TBD kV Provided by IPCO
NOTE: Curtailment Setpoint indicates MW value to Curtail to when Curtailment Off/On DO is ON.
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
•
ATTACHMENT 56
NOTICE OF FORCE MAJEURE
UNDER
FIRM ENERGY SALE AGREEMENTS DATED OCTOBER 14,2005
RE:
LA VA BEDS PROJECT (#41455200) AND NOTCH BUTTE PROJECT (#31615300)
From Seller: Exergy Development Group of Idaho, LLC
802 W. Bannock Ste. 1200
To Idaho Power:
With copy to:
Date:
Boise, ID 83702
Attn: James Carkulis, Managing Member
Email: [e-mail]
Vice President, Power Supply
Idaho Power Company
PO Box 70
Boise, Idaho 83707
Email: [e-mail]
Cogeneration and Small Power Production
Idaho Power Company
PO Box 70
Boise, Idaho 83707
Email: [e-mail]
July 2,2012
VIA EMAIL, HAND DELIVERY AND REGULAR MAIL
In accordance with Article XVI (Force Majeure) of the Firm Energy Sale Agreements referenced
above (hereinafter, collectively, the "FESA"), and Section 6.4 of their respective corresponding
Generator Interconnection Agreements, Seller hereby gives Idaho Power written notice of the
OCCUlTence of Force Majeure events, in the following particulars:
1. This Notice of Force Majeure is directly tied to that certain other Notice of Force
Majeure, dated June 28, 2012, e-mailed on June 29, 2012, and followed up my regular mail,
regarding the JACK RANCH PROJECTS (DEEP CREEK - # 31721200; ROGERSON FLATS -
#31721300; SALMON CREEK -#31721400; and COTTONWOOD -#31721100. A copy of that
Notice of Force Majeure is attached hereto, and incorporated herein by this reference as if set fOlth
in full.
2. Idaho Power, with the understanding, as communicated in various meetings and e-
mails between Idaho Power and Seller, that both the Lava Beds Project and the Notch Butte Project
are integrally related to the Jack Ranch Projects for purposes of combined financing, has caused the
Exergy Development Group 802 W Bannock, 12[h Floor Boise, 10 83702 P 208.336.9793 F 208.336.9431
A .-.(~"( J..-
"~""'I G,orgy interconnection facilities and upgrade construction completion dates for the Jack Ranch Projects to
change to a date that is after Seller's Scheduled Operation Date under the FESA for the Jack Ranch
Projects, thereby creating an impossibility of performance on the part of Seller, in a manner beyond
the control of Seller, all as more fully set forth in the attached Notice of Force Majeure for Jack
Ranch Project.
3. The impossibility of performance under the Jack Ranch Projects FESA creates an
event of Force Majeure not only with respect to the Jack Ranch Projects, but also the Lava Beds
Project and Notch Butte Project, as follows:
(i) Plainly and simply, without the Jack Ranch Project, both the Lava Beds
Project and the Notch Butte Project are not financeable. All the Projects are packaged together for
financing purposes. If one or the Projects is caused to be eliminated from the package, for reasons
beyond the control of Seller, then all of the Projects will be eliminated, again for reasons beyond the
control of Seller.
(ii) Because Idaho Power has moved the interconnection facilities and upgrade
construction completion dates under the Jack Ranch Projects to a date that is after Seller's Scheduled
Operation Date, Idaho Power has created impossibility of performance on the part of Seller, and, as a
direct consequence, has also caused impossibility of performance and frustration of purpose under
all the Projects.
4. Notwithstanding the foregoing, other events of Force Majeure have arisen, to wit:
(i) Per the IPUC docket, in a decision released June 30, 2012, the IPUC has
denied Grand View Solar's request for a summary judgment ruling that a developer, not Idaho
Power, owns RECs associated with a renewable project.
(ii) Also per the IPUC docket are the issues of pricing, SIze, duration and
curtailment, all of which are pending.
Accordingly, as all of the foregoing will affect not only the Jack Ranch, Notch Butte and Lava Beds
Projects, but also any other renewable energy project, the entire circumstance of continued viability
of all renewable energy projects is undecided and beyond the control of Seller, the ultimate decisions
upon which may render Seller wholly or in part unable to perform its obligations under the FESA.
Accordingly, by this written notice to Idaho Power, Idaho Power is advised that its actions have
created a Force Majeure event, thereby creating a suspension of performance for the duration of the
event, as further described in Article XVI of the FESA.
Further, pursuant to Section 19.1 (Disputes) of Article XXII of the FESA, if Idaho Power disputes
this matter, Seller reserves the right to submit the same to the Idaho Public Utilities Commission
and/or pursue any resolution to which it may be entitled before the appropriate Idaho district court,
FERC and/or any other applicable tribunal or governing body.
Exergy Development Group 802 W Bannock, 12th Floor Boise, 10 83702 P 208.336.9793 F 208.336.9431
Further, Seller asserts that it is protected from any default under the FESA pending resolution of any
the asserted Force Majeure issues, including, without limitation, any dispute or litigation as to
whether said Force Majeure Event does protect Seller from any such default.
SELLER:
Exergy Development Group of Idaho, LLC
cc: Donovan E. Walker (hand delivery)
Peter J. Richardson (email)
Peter A. del Vecchio (email)
Walter J. Dunn (email)
Richard A. Riley (email)
Brian L. Ballard (email)
Exergy Development Group 802 W Bannock, 12th Floor Boise, 10 83702 P 208.336.9793 F 208.336.9431
, .
NOTICE OF FORCE MAJEURE
UNDER
FIRM ENERGY SALE AGREEMENTS DATED DECEMBER 10, 2010
RE: JACK RANCH PROJECTS:
From Seller:
To Idaho Power:
With copy to:
Date: June 28, 2012
DEEP CREEK (# 31721200)
ROGERSON FLATS (#31721300)
SALMON CREEK (#31721400)
COTTONWOOD (#31721100)
Exergy Development Group of Idaho, LLC
802 W. Bannock Ste. 1200
Boise, ID 83702
Attn: James Carkulis, Managing Member
Email: [e-mail]
Vice President, Power Supply.
Idaho Power Company
POBox 70
Boise, Idaho 83707
Email: [e-mail]
Cogeneration and Small Power Production
Idaho Power Company
PO Box 70
Boise, Idaho 83707
Email: [e-mail]
VIA EMAIL AND REGULAR MAIL
In accordance with Article XIV (Force Majeure) of the Film Energy Sale Agreements referenced
above (hereinafter, collectively, the "FESA"), Seller hereby gives Idaho Power written notice of the
occurrence of Force Majeure events, in the following particulars:
1. Pursuant to studies, Idaho Power established interconnection facilities and upgrade
construction completion dates as occurring in December 2011. Idaho Power communicated same to
Seller, and Seller, in reliance, and in discussions with Idaho Power, established June 20, 2012, as the
Scheduled Operation Date under the FESA.
Exergy Deve lopment Group 802 W Bannock, 12th Floor BOise,ID 83702 P 208 .336.9793
F 208.336.943 1
)..A. ~( )...
exeg~J~)ry~1t
OEVElOI'MENf GROUP 5 .
2. Unilaterally, Idaho Power then decided to conduct further studies and based thereon,
unilaterally moved its interconnection facilities and upgrade construction completion dates forward,
most recently settling on dates in June 2014.
3. Despite repeated requests from Seller, Idaho Power has refused to amend the FESA to
allow Seller to change its Scheduled Operation Date to reasonably accommodate Idaho Power's
change of its interconnection facilities and upgrade construction completion dates to June 2014.
4. Because Idaho Power has arbitrarily moved its interconnection facilities and upgrade
construction completion dates to a date that is after Seller's Scheduled Operation Date, Idaho Power
has unilaterally created the absolute impossibility of performance on the part of Seller. This
intentional and intended consequence has been repeatedly brought to the attention of Idaho Power
and is well known to Idaho Power.
5. The intentional and intended consequences ofIdaho Power's unilateral manipulation
of dates within its sole control, serves to have created, by Idaho Power's own actions, the cause of
the looming, certain and impossible achievement by Seller of the Scheduled Operation Date of June
30,2012. Idaho Power's refusal to agree to a reasonable change in the Scheduled Operation Date is
clearly "beyond the control of the Seller ... despite the exercise of due diligence ... [that Seller] is
unable to prevent or overcome ... " and is, therefore within the definition of Force Majeure as set
forth in Article XIV the FESA.
6. This is not a case of Seller failing to post delay security (such has been posted). This
is not a case of Seller's reliance upon the actions of third party permitting agencies (such as, by way
of example, and not limitation, the BLM). This is not a case where there are events or issues arising
outside of the control of Idaho Power. To the contrary, this is a case where there has been, and
continues to be, unilateral and intentional delay and manipulation by Idaho Power of events and
issues solely with the control of Idaho Power, the intent of which is to cause the default to Seller.
For example, Idaho Power could easily agree to amend the FESA to a reasonable date that correlates
to the revised Idaho Power dates (changed after Seller has relied upon originally established dates).
Idaho Power refuses to do so.
7. Further, Idaho Power has also set the stage for impossibility of performance on the
part of Seller with respect to the condition imposed by Section 4.1.7 (Interconnection) of the FESA,
that Seller provide written confirmation by Idaho Power to Idaho Power of the satisfaction of all
interconnection requirements. Pursuant to the chain of letter correspondence attached
(notwithstanding that there are fundamental disagreements between Seller and Idaho Power
regarding the matters set forth therein), Idaho Power has chosen not to countersign the GIA signed
and submitted to Idaho Power, thereby making satisfaction of this condition impossible. Seller
reserves all rights to contest the position of Idaho Power regarding the GIA as set forth in the
attached correspondence (in particular the incorrect recollection of Donovan Walker regarding the
circumstances of how the insertion of the Section 8.3 Option to Build per OATT was brought to his
attention). However, for purposes of describing with particularity the occurrence of an event of
Force Majeure, the attached is submitted as such description, and as forming the basis for Seller's
Exergy Development Group 802 W Bannock, 121h Floor Boise, 10 83702 P 208.336.9793
F 208.336.9431
~.-( ~ J.­
exer~p'\~! D"VELO"MEI~T GROUP 0 I
notice to Idaho Power that Idaho Power's unilateral refusal to sign a contract creates an event
beyond the control of Seller within the definition of Force Majeure as set forth in the FESA.
Accordingly, by this written notice to Idaho Power, Idaho Power is advised that its actions have
created a Force Majeure event, thereby creating a suspension of performance for the duration of the
event, as further described in Article XIV of the FESA.
Further, pursuant to Section 19.1 (Disputes) of Article XIX of the FESA, if Idaho Power disputes
this matter, Seller reserves the right to submit the same to the Idaho Public Utilities Commission
and/or pursue any resolution to which it may be entitled before the appropriate Idaho district court,
FERC and/or any other applicable tribunal or governing body.
Further, Seller asserts that it is protected from any default under the FESA pending resolution of the
asserted Force Majeure issues, including, without limitation, any dispute or litigation as to whether
said Force Majeure Event does protect Seller from any such default.
SELLER:
Exergy Develop ~ Group of Idaho, LLC
By:?/Y 0
mes T. Carkylis ----------.-----Managitrg~ber
cc (via email): Donovan E. Walker
Peter J. Richardson
Peter A. del Vecchio
Richard A. Riley
Brian L. Ballard
Exergy Development Group 802 W Bannock, 12th Floor Boise, ID 83702 P 208.336.9793
F 208.336.9431
DONOVAN E. WALKER
Lead Counsel
[e-mail]
June 18, 2012
VIA ELECTRONIC & U.S. MAIL
Peter J. Richardson
RICHARDSON & O'LEARY, PLLC
515 North 27th Street
P.O. Box 7218
Boise, Idaho 83702
~~IDAHO
POWER®
An IDACORP Company
Re: Jack Ranch Projects -Your June 15, 2012, letter to Tess Park
Dear Mr. Richardson:
This letter responds to your letter of June 15, 2012, to Idaho Power's Tess Park.
In that letter you represent that Mr. Carkulis did, "in fact" sign the Final GIA for the Jack
Ranch Projects. This is factually incorrect. Mr. Carkulis delivered to Idaho Power, at
4:57 p.m . on Wednesday, June 13, 2012, versions of the Final GIA that had been
modified, and then signed by Mr. Carkulis. The modification(s) to the document were
not red-lined or otherwise identified in the document. In fact, the modification(s) were
not even pointed out until the two representatives of Exergy that made the delivery were
asked directly if there were any changes made to the documents. At that time the
Exergy representatives pointed out some additional language that was added to the
pro-forma portion of the Final GIA, in Section 8, where a subsection 8.3 was added to
include language allowing Exergy to self build all required interconnection facilities and
upgrades.
As you are well aware, this particular issue was expressly addressed in my June
12, 2012, letter to Mr. Carkulis, and was expressly discussed on the phone conference
that you organized on June 13,2012, attended by myself and Jason Williams for Idaho
Power, as well as you and your associate, Greg Adams, several attorneys from
McGuire Woods from across the country, and the two representatives of Exergy that
hand delivered the modified documents directly after the call. The unambiguous
communication from both the June 12, 2012~ letter as well as the June 13 conference
call is that the requested self-build language is not an appropriate, nor an acceptable
term in the Final GIA. Contrary to these communications, Mr. Carkulis unilaterally
inserted the inappropriate language into the Final GIA before signing and returning the
1221 W Idaho St. (83702)
P.O. Box 70
Boise. ID 83707
James Carkulis
June 12, 2012
Page 2 of 2
same to Idaho Power. Consequently, Mr. Carkulis failed to sign and return the Final
GIA that was sent to Exergy on May 14, 2012, by the June 13, 2012, deadline.
Additionally, Mr. Carkulis did not pay the required deposit by the close of business on
June 13,2012.
As previously communicated to Exergy by letter dated June 14, 2012, because
Exergy did not return an executed copy of the Final GIA, nor pay the required deposit
funds by the June 13, 2012, deadline, the Projects have been removed from Idaho
Power's generator interconnection queue.
Sincerely,
Donovan E. Walker
DEW:csb
cc: Lisa Grow, Idaho Power (via e-mail)
Tess Park, Idaho Power (via e-mail)
Randy Allphin, Idaho Power (via e-mail)
Jason Williams, Idaho Power Corporate Counsel (via e-mail)
James Carkulis, Exergy (via e-mail)
D.l!€~li).S.J[)iNr & (1)JlL~lr~ PUC
ATTORNEYS .... T lAW
Perer Richardson
T.I: 208-938-7901 fn: lOR-938-7904
p t: 't"t'f@richntIso n a ilJ 0 f COl ry. cum
r.o. Box 7218 Bois •• I D 83707 -SIS N. 27th St. Bai,e, [I) 83702
June 15,2012
Tess Park, Load Serving Operations Director
Idaho Power Company
1221 West Idaho Street
Boise, Idaho 83702
HAND DELIVERY
Re: Jack Ranch Projects, Project No_ 325/327
Dear Ms_ Park:
I am in receipt of your letter dated June 14,2012 addressed to Mr, Carkulis, You must
have realized by now that your statement that "Exergy did not provide Idaho Power an
executed copy of the Final GIA, nor was a deposit for the Projects received" is in error.
An Exergy employee delivered a signed GIA directly and ~ersonally to Mr, Donovan
Walker at five minutes of five p,m, on Wednesday the 13t _ That GIA was, in fact
executed by Mr_ Carkulis and Mr. Carkulis is prepared to post the deposit when the
agreement is fully executed by Idaho Power.
I therefore respectfully request that you replace these projects to their rightful place in the
queue.
Siucer6b~~
Peter Richardson
Cc: Donovan Walker, Senior Attorney -Idaho Power Company
James Carkulis
Exergy Development Group
802 West Bannock Street, 12th Floor
Boise, Idaho 83702
June 14,201 2
IDAHO
POWER®
An IDACORP CDfllP~rW
VIA email & Certified Mail # 70113500000156449112
Subject: Jack Ranch Projects Project # 325/327 -FINAL NOTICE
Dear James Carkulis:
By letter dated May 14, 2012, Idaho Power Company ("Idaho Power") provided the Exergy
Development Group ("Exergy") with a Final Generator Interconnection Agreement ("Final
GIA") for the proposed Jack Ranch Projects ("Projects") to be interconnected in Twin Falls
County, Idaho. Exergy was to execute and return the Final GIA with the required deposit by
June 13, 2012. That time period has now expired. Exergy did not provide Idaho Power an
executed copy of the Final GIA, nor was a deposit for the Projects received. Therefore, the
Projects have been removed from Idaho Power's generator interconnection queue.
Should you wish to continue to pursue generator interconnection for the Projects, you may re­
submit an application that can be found on www.idahopower.com.
cc (via email):
Donovan WalkerllPC
Nancy Cyr/IPC
Aubrae Sloan/IPC
Josh Harris/IPC
Sincerely,
~' (\ { RAil K:01'--'"
Tess Park
Load Serving Operations Director
Ph 208.388.2360
P.O. 60x 70 (83707)
1221 W Idaho 5t.
8ois~, ID 83702
McGufreW()od, llP
600 Travis Street
Suite 7500
Houslon, TX 77002·2906
Phone: [phone]
Fax: [phone]
www.mcgulrewoods.~om
( ...
Peler A. dd Vc<chlo
Direct: 713.353.6672 McGUIREWCDDS
JUne 13,2012
Donovan Walker
Legal Department
Idaho Power Company
1221 WestIdaho Street
Boise, ID 83702
f ~---'
RE: Exergy Development Group of Idaho, LLC's Jack Ranch ProjectB
Dear Donovan:
[e-mail]
Direct Fax: [phone]
[ am writing on behalf of Exergy Development Group of Idaho, LLC, in response to your letter
to Mr. James Carkulis dated June 12, 2012. That letter rejected Exergy's ongoing attempts to
seek from Idaho Power reasonable use of fair and well-established interconnection procedures
that Exergy believes would allow it to in:tercoIUlect its :projects in a timely manner. ;>Idall9
FoWer' $ pqsition has pl~,t?d Ex~gy :In 4 yery. difficult position, ,and may pomp~l E~ergy to
pursue E!1) available legal ,aM' eq4itaBIe ,relD~dre~ lot' what 'am6~1s io.'ll breach of good f~th ami
.fait dealing u~d~r .Idalio cQn~Qt law., !:IS well fig rliscrimhmtory 1l'eatm~nt Under implementing
rules of)he'PllblibUtili~es Re,~atonrPo1icyAct'of 1'978.
As you know, Exergy is the developer of four qualifying facility (QF) projects referred to as the
Deep Creek, Rogerson Flats, Cottonwood, and Salmon 'Creek projects (the "Projects"). Exergy
executed finn energy sales agreements (FESAs) with Idaho Power for each of these Projects in
late 2010. Ida40 Power r~uired 'Ute b:r~lusion in the~e FESAs of &.' delay 'liq1;1ioa,teq. damage's '
provision th~t reg).rired EXetgy 1q p.oS(' $A'5/lcllowatt qf~epHi.tec?lpacij:y·t6 :el1~e that the
Projects wO'\.ild meet a SchedciIed QPfu:a:\ion Date'of June ')'O? :2612. ,tc1aho Power.lnch.iaed in the
delay default proVision the requrrement in Aitide 4,1.7 ~fExergy be ~ble to '~'Provid'e written
cbnfumation ftbm tdaho fower's deliv¥tY bit~ip.eS& ,~tth~t $'e)1er .has sansnyd an
interconnecfioil reSluirements." Jd{3.ho Power drafted those provisions' and -othe.r1han. the .
projecte4 date 1ts~if -prQ'videdExergy with no opportUnity'fol' input.
As Exergy bas communicated to Idaho Power, Exergy believed it would be able to achieve the
interconnection component by the Scheduled Operation Date by interconnecting these four
Projects at the point of interconnection on the 345 kV line used in Interconnection Request No,
327. From the well-advanced interconnection process initiated under Idaho Power Open Access
Transmission Tariff eOA IT) for Interconnection No. 327, Exergy expected that there would be
no issue with completing the interconnection of the lesser 80-MW output by the required date.
Your accusations that the Projects had been moved forward by Exergy with a blind eye to
Atlanta I Austin I Baltimore I Brus.sels I Charlotte I Charlotte,ville I Chicago I Hooslon I Jacksonville I London
Los Angeles I New York I Norfolk I Pittsburgh I Raleigh I Richmond I Tysons Camer I Washington, D.C I Wilmington
Donovan Walker
June 13,2012
Page 2
\" .-(-
intercOJlllection risk is simply wrong, The interconnect feasibility study for this interconnect
request was completed by Idaho Powe[ on July 28,2010. That study, which was completed six
m9pths PRJ:O~ ~o <?l,Cecution of the Jack RanchFESAs, provides: ''rhe p~op6sed ip~se~cedaty
is P.ecember 20lJ.h The Projects, in reliance on Idaho Power's owri study, tlLen requested an on
line date in July 2012, on the assumption that the interconnection work to be perfonned by Idaho
Power would take no more than a year. This assumption was collaborated by the System Impact
Study which was ~mpleted in December of201O. That study also states that: "The proposed in­
service date for this Project is December 201]." Exergy reasonably and in good faith relied upon
Idaho Power to make an informed decision as to the appropriate on line date.
Idaho Power worked with Exergy Wlder the terms of the OATT to make modifications to the
initial 200MW Energy Resource designation for Interconnection Request No. 327 to allow for
these four QF Projects to interconnect at the same location on the applicable 345 kV line.
Exergy consequently understood Idaho Power to be proceeding under the terms of the OA IT for
this interconnection. Exergy considers the terms of the OATT to allow for a quicker progression
to a fully completed interconnection process. Exergy maintains that, had Idaho Power
consistently adhered to the principles of the OAIT, it could have progressed much more quickly
to a reasonable and fully executed Large Generator Interconnection Agreement. But Idaho
Power has failed to do so.
F or example, the OA IT section 32.1 reguU·.es that irthe ''J1'at:iSUlission P.fovider det~tJi).in.es that, a
syste~ 'il.I,l.pact study ~s ,ue~~~it ·sb.a1\ sQ iliform the ti~sfrllssi:0n .¢\Tstbmer-'f1a$ "soOn a's
practicable/' 'but ~ "any ~vent "will prov'ide a system impact study agreement within 30 days of a
completed application for network resource designation. Exergy's letter initiating the revised
network transmission request from the revised point of interconnection was sent June 3, 2011,
and it took 75 days for Idaho Power to respond on August 17,2011 that a system impact study
would be needed. For a much more complicated process of actually completing a system impact
study or a facility study, the OATT only allows only 60 days, and under sections 19.9 and 32.5
requires Idaho Power to file a notice and possibly incur penalties with FERC if a significant
nwnber of studies for non-affiliates exceed that 60-day deadline, Additionally, Idaho Power's
August 17, 2011 letter provided Exergy with six days to execute the included network
transmission study agreement regarding the system impact study and deposit $10,000, but Idaho
Power's OATT section 32.1 provides a transmission customer with 15 days to execute a system
impact study agreement.
The 75-day response period for Idaho Power (compared to 30 days in the OATT) and the 6-day
response requirement for Exergy (compared to 15 days in the OA TT) are flatly discriminatory to
Exergy's QF Projects as compared to others who are attempting to use the transmission system.
This is only one such example of Idaho Power's delays and unreasonable requirements placed
upon Exergy with regard to the interconnection and network transmission components of these
Projects.
In fact, Idaho Power has unilaterally imposed short response times for Exergy and allowed itself
generous amounts ()f time achieve various tasks throughout this process. To put it simply,
Donovan Walker
June 13,2012
Page 3
(-
Exergy has made clear its intent to proceed un,per the reasonable tunelines s~t forth in the OAIT
in order to avoid being in ,default of'1dahp 'Powet~s"-1,$e~(mabledelay dBina.gespl1ovisionmthe
.. FESA;s, Yet Idaho Power bas refused to follow that process, and instead has materially
fru:sfrated Exergy's ability to complete the interconnection.
Your letter sent June 12, 2012 is yet another example. Idaho Power Transmission apparently
believes it is not capable of having the interconnection complete in time for the deadline in the
FESAs, or the 90 days thereafter Idaho Power has provided for Exergy to cure any delay
"default" priQr to Idaho Power's fight (ag~,/ llncier the;: FESAs it drafted) to t~rminate the
FESAs. Exergy re,~~Mbly Pki>]0~~ to us,e' .c;!. eQm:mon..pr.q,ce:~W'-e from Section 5 J J of Idahb
'POWer's 0 A IT to self bUild ·tbe inl(:erc0im~CtiQn. That would at least place Exergy in control of
the intercoirnection construction, and consequently the related ability to achieve online status
accordance with the FESAs. There is no basis for denial of this request. Exergy and its partners
clearly have the capacity to self construct the interconnection process.
Your reliance on the terms and provisiqIl$pf .~ s~te-jurisdictional Schedule n are unavailing.
FiIst,rc1anoPpwerl)as 'cOASent~d to use 'thep~'ooed)J!~ of ·the Q.A.TT rb:y course Qf conduct.
Those prm;isions were used in correspondence between Exergy and Idaho Power to make the
necessary modifications to the Interconnection Request No. 327 beginning in April 2011. You
claim that Exergy failed to adhere to some I'comment period" that Idaho Power has created.
However, even if Idaho Power could foist an unfair process on an interconnecting generator for
some failure to provide comments, we understand that Exergy has communicated its intent to use
the OATT provisions consistently from the start. Idaho Power cannot indiscriminately "cherry
pick", using some provisions of the OATT favorable to itself at some points and completely
ignoring OATT at other times whenever Idaho Power chooses.
Second, and more importantly, t):1e Scb¢~le 72 proce~s as applied is inconsistent with, federal
and state QF regulations. la-aho POWer is &scl'inrlnating againsJ anp providing less protection to
the interoonnection rights of QFs 'than those -aYfJ.ila;'ple for ,nQn~QF .. ~eg.eratoi-s! A~ you ~e well
aware.> "a state IDay only '·take rilCtion,. under PURPA ttl_ tb~ ~)Gte)Jt tAat tltat actibp. is ·copsistent
witf)..EfeR-C'sl ru1~~.'1 Cecipr Cfeek Wind, fiLe. 137 FERC 61,006, 1f 27 (2011). Federal Energy
Regulatory Commission (FERC) regulations and case precedent is abW1dantly clear that well­
established interconnection protections afforded under PURPA are i;!ltend~d 'toptevent th¢type
6fdi~CJinllP.lltory. tteal:fnent ~xbiQiled by I4!lho Powe,r'b,ere (e~g. 18 C.F .R. § 29i.30 1 -314). By
prohibiting Exergy from self-bUilding its QFs' interconnection in the same mEUl+ler Idaho power
is required to allow non-QF generators unqer the DATI, Idaho Power i;:; 'usmg theSched41e 12
proceSs :as anWtr¢asonable shield to 9iilc~te ~gaiIist Exc:'t,gy. subverting and contorting the
Yeryplirposeof Schedule 72. .
Finally, a duty of good faith and fair dealing is implied in any cOntract. Indep, Sch. Dist, of Boise
City v, Harris Family Ltd P'ship, 150 Idaho 583, 589, 249 P.3d 382, 388 (2011). The four
FESAs at issue here are no exception .. Idaho Power has unreasonably demanded that, in order
for Exergy to exercise its state and federal right to sell to Idaho Power as a QF, Exergy must
agree to a delay defa1.llt damages provision tPat required Ex.ergy t9 posts1.lbstantial security 1n
Donovan Walker
June 13,2012
Page 4
/' 1."-f· -
ef'ce.i:i~oftbree rr.ti1liQILdollars fQr these Projd;ts. Idaho Power claims in other forums that it does
nbtneedthe ciutput from wind projects at this time. Yet hen~ Iq~o .EQwer refuses to slightly
extend the online qa~t; ir) Exergy's FESAs. f9t i~p' 'WQW§l' tQi'i1~i$t I;lpon bUUcliJ!g ,the.
interecmneclipt]. Ifse1f UQd~r. d~adllnes 'Ural' Will "not me.et ,tl!~ 'de~~e.S l~Q =P'Qwer te~ep "t~
·rhOy¢ 111 the,PESA is 'a trru,ispareilt f(tt~~~t to ' ~ermi.nate ~~-FESAs. Idaho 'Power cannot pretend as tllougb it is two different entitie~. Idaho Power's intent is clear. No court would view Idaho
Power's conduct as anything other than a monopolist utility's attempt to terminate the FESAs.
As such, Idaho Power's actions are a clear breach of the implied covenant of good faith and fair
dealing.
Idaho Power's entire course of conduct including its actions, inactions and interactions with
Exergy regarding the interconnection procedures with respect to its four QF Projects and the
related FESAs has the potential to cause tremendous harm to Exergy and seriously threatens the
viability of these Projects. Earlier today, Exergy had delivered to Idaho Power executed
counterparts of the relevant Interconnection Agreements. We are expecting Idaho Power to
execute and deliver counterparts of Interconnection Agreement to 'Exergy as soon as possible. If
this is not completed by the close of business 9n Monday, June 18th or jf Idaho Power form<ll1Y
or informally _removes any of the Project~ from its interconnection queue, ~te~gy Weods" to
pursrie"all ava:i1able le-gal and 'equitable.:remedt~s ~grunst lda,ho -power .for all ifi.tect and -indireot
~Qst~ associi'lted Witl). fuese PJlojects, tnclu~g the return C?f an s.eguri.1Y pjl.ym~~ts made Pnrler the
FES'O:;s, all hard and $Q:ft .de:vel~pm~nt ·apd CO~1nl¢1:iali C!t~~~s~,oci~tecl_ with thJi' .P]:oj~~ts, the
v~ue. 9f all non-reftm.dable depo~its p!£j.ced On wind turbines anq. cit.h,er ~quipmeIlt, as well as
otl:ie):' CQia~qti~n:tiaLa:na pttilitive damilges.
Peter A. del Vecchio
cc. James Carkulis, Exergy Development Group of Idaho, LLC
Peter Richardson, Richardson & O'Leary
DONOVAN E. WALKER
Lead Counsel
[e-mail]
June 12,2012
VIA ELECTRONIC & U.S. CERTIFIED MAIL
RETURN RECEIPT REQUESTED
James Carkulis
Exergy Development Group
802 West Bannock Street, 12th Floor
Boise, Idaho 83702
An IDACORP Company
Re: Jack Ranch Projects -Your June 12, 2012, E-Mail to Josh Harris
Dear Mr. Carkulis:
This letter responds to your e-mail of June 12,2012,toldaho Power's Josh
Harris. As we have discussed several times and as you are fully aware, Idaho Power's
Tariff Schedule 72 is the governing Tariff/document for PURPA OF Generator
Interconnections to Idaho Power's system. Schedule 72 provides that "The Company
[Idaho Power] will construct, own, operate and maintain all equipment, Upgrades and
Relocations on the Company's electrical side of the Interconnection Point." IPUC No.
29, Tariff No.1 01, Sheet No. 72-7. Schedule 72 does incorporate many provisions of
the FERC-approved Large Generator and Small Generator Interconnection Procedures
in the State Schedule 72 process. See IPUC No. 29, Tariff No. 101, Sheet No. 72-3,
sub. 2. Only those provisions of the LGIA and SGIA that are not addressed by
Schedule 72 are applicable in this state jurisdictional generator interconnection process.
Any provisions of the LGIA and/or SGIA that purport to allow a OF project to construct
any facilities used in any way to serve any other Idaho Power customer "on the
Company's electrical side of the Interconnection Point" are not applicable as Schedule
72 requires such facilities to be constructed, owned, operated, and maintained by Idaho
Power. We have specifically discussed this requirement on more than one occasion in
our face-to-face meetings regarding your Jack Ranch projects, as well as several of
your other projects with Idaho Power.
Additionally, the provision you cite to in the LGIA (5 .1.3) -if it were applicable in
this situation -applies only to Stand Alone Network Upgrades. As mentioned above,
and as discussed with you previously, any facilities that are involved with the provision
of service by Idaho Power to any other customers are not Stand Alone Upgrades, and
1221 w, Ideho St (83702)
P.O Box 70
Boise. 1083707
James Carkulis
June 12,2012
Page 2 of 4
must be constructed by Idaho Power pursuant to Schedule 72. This includes the
interconnection facilities and upgrades for the Jack Ranch projects.
Further, as we discussed and as you requested, specific language consistent
with what Idaho Power has contracted for with other OF interconnections -specifically
the Thousand Springs GIA -was included in the final GIA, which we provided to you on
May 14, 2012. Those additional provisions would allow Idaho Power to work
cooperatively with you and bring to bear the assistance of third-party contractors and
other methods to reasonably expedite the required work for your interconnection and
upgrades. The Thousand Springs GIA language that you referenced is as follows:
This is a revised date, upward in time from 1/15/11, based
upon Interconnection Customer's needs and requests.
Idaho Power will use reasonable efforts to have IPC's
commissioning completed by 12/31/10. This revised
completion date is contingent upon all materials being
delivered on their scheduled delivery dates, the transmission
line outage occurring as scheduled, receiving all necessary
local, state and federal permits, including FERC and NEPA,
and construction & regional resources being available.
The parties hereby acknowledge that Idaho Power shall not
be liable for any possible damages associated in any way
with Renewable Energy Credits or Attributes, the firm energy
sales agreements, and the like, attributable to
Interconnection Customer, or any of the various projects
named on page one of the GIA, should the 12/30/10 date not
be met.
Under normal efforts to bring the projects online a normal
amount of overtime is utilized. Because of the
Interconnection Customer's desire to meet an IPC
commissioning date of 12/31/10, Interconnection Customer
hereby authorizes IPC to incur additional expenses,
including additional overtime, lodging, travel, and other
expenses needed to bring in other IPC resources and
personnel from other I PC regions as necessary to work on
this interconnection.
The corresponding language that appears in the Jack Ranch GIA is as follows :
Customer has requested an in-service date of 12/15/2012.
Idaho Power does not commit to this date but will use
reasonable efforts to have commissioning complete by
James Carkulis
June 12,2012
Page 3 of 4
6/9/2014. This date is contingent upon all materials being
delivered in a timely manner, as well as other factors, some
of which are described above. The parties hereby
acknowledge that Idaho Power shall not be liable to for any
possible damages associated in any way with Renewable
Energy Credits or Attributes, tax credits, the firm energy
sales agreements, and the like, attributable to Customer, or
any of the various projects named on page one of this GIA,
should the 6/9/2014 date not be met.
Under normal efforts to bring the projects online a normal
amount of overtime is utilized. Because of the Customer's
desire to meet an IPC commissioning prior to 6/9/2014,
Customer hereby authorizes IPC to incur additional
expenses, including additional overtime, lodging, travel, and
other expenses needed to bring in other IPC resources and
personnel from other IPC regions, or to utilize third party
contractors, as necessary to work on this interconnection.
As evidenced by the language quoted above and included in the Final GIA for the
Jack Ranch projects, as long as Exergy is willing to pay the associated additional cost,
Idaho Power will use commercially reasonable efforts -including additional resources of
its own, third-party contractors, and other steps to expedite the required interconnection
work. However, as has been previously communicated to you in writing, even with the
use of such measures to expedite, Idaho Power's estimate is a minimum of 18 months
from payment of funds and execution of the Final GIA to complete the necessary
system upgrades and interconnection facilities. As stated in Idaho Power's April 13,
2012, letter to you:
As stated, Idaho Power will use commercially reasonable
efforts, and work with you to expedite the construction of
your interconnection facilities, including the use of third-party
contractors -and including additional costs -if authorized
and borne entirely by Exergy -to expedite the work required
to interconnect your project to Idaho Power's system,
allowing its energization. However, so as to be clear, I must
reiterate that this does not change Idaho Power's estimate of
a minimum of 18 months from payment of funds and
execution of the GIA to complete the necessary system
upgrades and interconnection facilities required to energize
your project on Idaho Power's system, and even given the
other uncertainties involved, it could take longer than 18
months still.
James Carkulis
June 12, 2012
Page 4 of 4
Your comment and request to include a provision consistent with the Thousand
Springs GIA was received by Idaho Power during the appropriate 30-day comment
period on the Jack Ranch Draft GIA. Idaho Power has incorporated your requested
language into the Jack Ranch Final GIA to extent that Schedule allows. Your additional
request at this late hour to include language from Idaho Power's LGIA is not only
inappropriate, as the time for comment on the Draft GIA has passed, but it also has
been previously and specifically discussed, addressed, resolved. Unfortunately, your
request in your most recent e-mail appears to be another transparent attempt to now set
up legal claims against Idaho Power that have no merit, while purporting to proceed in
good faith and in a commercially reasonable manner -similar to those referenced in
Idaho Power's June 8 letter to you.
Finally, as a reminder, pursuant to the May 14, 2012, letter to you from Idaho
Power's Tess Park, and confirmed by Idaho Power's leUer dated June 8,2012, and now
this letter as well, "Failure to submit an executed copy of the enclosed Final GIA, which
includes the estimated milestones for the completion of construction, and complete the
necessary financing arrangements for the Jack Ranch Projects by June 13, 2012, will
result in Idaho Power terminating your generator interconnection request and
withdrawing the Jack Ranch Projects from the generator interconnection queue."
S' ~ ~C(/a/L
DEW:csb
cc: Lisa Grow, Idaho Power (via e-mail)
Tess Park, Idaho Power (via e-mail)
Randy Allphin, Idaho Power (via e-mail)
Jason Williams, Idaho Power Corporate Counsel (via e-mail)
DONOVAN E. WALKER
Lead C.ounsel
[e-mail]
June 8,2012
VIA ELECTRONIC & U.S. CERTIFIED MAIL
RETURN RECEIPT REQUESTED
James Carkulis
Exergy Development Group
802 West Bannock Street, 12th Floor
Boise, Idaho 83702
Re: Jack Ranch Projects -Your Letter Dated June 1, 2012
Dear Mr. Carkulis:
An IDACDRP Company
This letter responds to your letter dated June 1, 2012, to Lisa Grow wherein you
again make a request that Idaho Power Company ("Idaho Power") agree to extend the
June 3D, 2012, Scheduled Operation Dates that you selected and obligated your
projects to in the Firm Energy Sales Agreements ("FESAs") for each of the Jack Ranch
Projects (Le., Cottonwood Wind Park, Deep Creek Wind Park, Rogerson Flats Wind
Park, and Salmon Creek Wind Park). As we have previously communicated to you,
Idaho Power does not agree to extend those dates.
Your most recent allegation that Idaho Power agreed to a December 2011 on­
line date from a generator interconnection standpoint and that you relied on Idaho
Power's representation of a December 2011 generator interconnection date is
absolutely without merit. December 2011 was the date selected by the Exergy
Development Group ("Exergy") when it submitted its Small Generator Interconnection
Request Application Forms and the Interconnection Request for a Large Generating
Facility on March 12, 2010. Importantly, Exergy submitted five generator
interconnection requests on March 12, 2010. GI 322, 223, 324, and 235 were each for
20 megawatt ("MW") projects and GI 327 was for a single 200 MW project. Exergy
subsequently withdrew the requests for GI 322, 323, and 324, leaving GI 325 and GI
327.
The Generator Interconnection Feasibility Study provided to Exergy for GI 325
and 327 by Idaho Power on July 28, 2010 ("Feasibility Study"), states "The proposed in­
service date is December, 2011." This statement is merely a factual recital of the in-
1221 \IV Idaho 5t (83702)
P.O. Box 70
Boise, 10 B3707
James Carkulis
June 8, 2012
Page 2 of 6
service date requested by Exergy when it submitted its generator interconnection
application forms for the Jack Ranch Projects. The same is true with the Generator
Interconnection System Impact Study provided to you by Idaho Power on December 29,
2010 ("System Impact Study"), which states, "The proposed in-service date for this
project is December, 2011." Again, this language was included as a mere recitation of
what Exergy requested when it submitted its generator interconnection forms. Nowhere
in those documents does Idaho Power represent, let alone agree, that the generator
interconnection facilities for the Jack Ranch Projects would be constructed and on-line
by December 2011. Indeed, Idaho Power has never represented to Exergy that the
Jack Ranch Projects would be on-line by December 2011.
In fact, Idaho Power communicated to you on multiple occasions, both verbally
and in writing, that Exergy was proceeding at its own risk in signing FESAs in December
2010 with a Scheduled Operation Date of June 30, 2012, prior to Idaho Power
completing the necessary generator interconnection and transmission studies to
determine how long it would take to construct and/or upgrade such facilities as well as
the cost of such facilities. Specifically, in a letter dated November 17, 2010 (nearly one
month prior to you executing the FESAs) to Exergy's attorney, Peter J. Richardson,
Idaho Power told Exergy that:
It was Idaho Power's understanding that Mr. Carkulis wished
to get the results of the required interconnection and
transmission studies, which will identify the need for and cost
of interconnection facilities and possible transmission
upgrades, prior to the time at which he would sign a Firm
Energy Sales Agreement ("FESA") which would obligate the
projects to a Scheduled Operation Date. As you are aware,
the FESA contains provisions providing for delay damages
should the projects fail to meet the Scheduled Operation
Date set forth in the FESA. These delay damages are
secured by the requirement to post liquid delay damage
security thirty (30) days subsequent to IPUC approval of the
FESA. As you are also aware, it is your client's
responsibility to work with Idaho Power's Delivery business
unit to ensure that sufficient time and resources will be
available for Delivery to construct the interconnection
facilities, and transmission upgrades if required, in time to
allow the projects to achieve the Scheduled Operation Date
set forth in the FESA. As Mr. Carkulis has previously been
advised, delays in the interconnection or transmission
process do not constitute excusable delays in achieving the
Scheduled Operation Date, and, if the projects fail to achieve
the Scheduled Operation Date at the times specified in the
FESA, delay damages will be assessed. It was for this
James Carkulis
June 8, 2012
Page 3 of 6
reason that Idaho Power was of the understanding that your
client was not yet ready to commit to the execution of a
FESA.
If this is not the case, and if your client wishes to proceed
forward with the execution of a FESA prior to completion of
the interconnection and transmission studies and accept the
associated risk thereto, then Idaho Power can send you a
draft PURPA Wind FESA that contains the most recent and
up-to-date "standard" terms and conditions that have been
approved by the IPUC.
Letter from Donovan E. Walker to Peter J. Richardson dated November 17,2010, at pp.
1-2. '
On November 23, 2010, Exergy's attorney responded to Idaho Power's
November 17, 2010, letter by stating:
As you requested, I write to confirm that Exergy, as the
developer for [the Jack Ranch Projects], is willing to sign
contracts including the standard $45/kw delay liquidated
damages clause prior to completion of the entire
interconnection and transmission process for these projects,
including Idaho Power internal processes required to
designate the resource as a network resource. Exergy
understands that, under the current standard contract Idaho
Power would agree to enter into, a delay in achieving the
online date caused by the interconnection or transmission
processes is a delay which will not excuse a possible trigger
in the delay damages clause.
Letter from Peter J. Richardson to Donovan E. Walker dated November 23,2010.
The very next day, on November 24, 2010, Idaho Power sent draft FESAs to
Exergy's attorney, including a cover letter which stated, in part:
Your letter also confirms and acknowledges that your client
wishes to move forward with the FESA, including the
standard, Idaho Public Utilities Commission ("Commission")
approved $45 per kilowatt of project capacity delay security,
prior to completion of the interconnection and transmission
studies and processes . Further, that your client understands
it is their responsibility to work with Idaho Power's Delivery
business unit to ensure that sufficient time and resources will
James Carkulis
June 8,2012
Page 4 of6
be available for Delivery to construct the interconnection
facilities, and transmission upgrades if required, in time to
allow the projects to achieve the Scheduled Operation Date
that the projects will commit themselves to in the FESA. In
addition, your client has been advised, and accepts the risk,
that delays in the interconnection or transmission process do
not constitute excusable delays in achieving the Scheduled
Operation Date, and if the projects fail to achieve the
Scheduled Operation Date at the times specified in the
FESA, delay damages will be assessed, and delay security
applied. Please allow me to suggest that special
consideration be given to the Scheduled Operation Date
selected by the projects for inclusion and the FESA, such
that with the information available at this time a date is
chosen that has a good probability of providing time for the
anticipated interconnection and possible transmission
upgrades to be completed.
Letter from Donovan E. Walker to Peter J. Richardson dated November 24,2010.
In response, Exergy's attorney sent a leUer stating, in part:
Exergy is fully aware of the contracts' provisions and, as you
know has successfully developed many projects using the
standard Idaho Power contract. Exergy is also fully aware of
transmission and interconnection risks, as well as the liquid
security provision.
Letter from Peter J. Richardson to Donovan E. Walker dated November 29,2010.
This series of correspondence demonstrates that not only did Exergy have actual
notice of the risks associated with selecting a Scheduled Operation Date in the FESAs
without knowing the time frames or costs associated with interconnection and
transmission facilities for the Jack Ranch Projects, Exergy affirmatively acknowledged
and accepted those risks. With actual knowledge and affirmative acceptance of these
risks, Exergy selected a Scheduled Operation Date of June 30, 2012, in each of the
FESAs, which Exergy executed on December 10, 2010, and which were ultimately
approved by the Idaho Public Utilities Commission on February ii, 2011.
In addition, as a sophisticated developer of generation projects and having
previously developed more than a dozen other PURPA QF wind projects on Idaho
Power's system, Exergy is fully aware of the stUdies Idaho Power must conduct as well
as the processes necessary for generators, such as the Jack Ranch Projects, to
connect to Idaho Power's system. In addition, Exergy is fully aware from its previous
James Carkulis
June 8,2012
Page 5 of5
development projects with Idaho Power that the factual recitation of the proposed dates
by a generator contained in the Feasibility Study and System Impact Study are in no
way a guarantee by Idaho Power nor even a representation by Idaho Power as to when
generator interconnection facilities will be on-line.
Further, after executing the FESAs, but prior to Idaho Power issuing the Facilities
Study for the Jack Ranch Projects, Exergy requested that Idaho Power make significant
changes to the generator interconnection facilities configuration for the Jack Ranch
Projects, which required Idaho Power to restudy a large portion of the Jack Ranch
Projects. Specifically, on April 12, 2011, Exergy sent Idaho Power a letter requesting
several revisions to the Jack Ranch Projects, including reducing Exergy's GI 327 from
200 MW to 84 MW with an option to reduce the interconnection even further to 53 MW
at some pOint in the future. Further, Exergy requested that the point of interconnection
for the Cottonwood Wind Park, Deep Creek Wind Park and Rogerson Flats Wind Park
be changed from an Idaho Power 138 kilovolt (UkV") line to a 345 kV line. Idaho Power
responded via letter dated April 27, 2011, that a request of this type required Idaho
Power to conduct a material modification review under Idaho Power's Large Generator
Interconnection Procedures. Idaho Power further clarified that the change in the
voltages from 138 kV to 345 kV for three of the four Jack Ranch Projects would require
a restudy of the Facilities Study that was then in progress due to the different integration
voltages and the associated different Idaho Power transmission lines. See letter dated
May 20, 2011, from Dave Angell to James Carkulis. These significant changes
requested by Exergy caused delays in the Jack Ranch Project's generator
interconnection process.
Idaho Power is disappointed in reviewing your June 1, 2012, letter in that it
contains many known misstatements of fact in an attempt to contend that Idaho Power,
and not Exergy, was responsible for any delay that has occurred and the ultimate failure
of Exergy to meet the Scheduled Operation Date that Exergy set for itself. Your letter is
a transparent attempt to now, at this late hour, set up legal claims against Idaho Power
that have no merit, while purporting to proceed in good faith and in a commercially
reasonable manner. For example, at the end of your June 1 letter you state "each of
the Project Companies has made, in good faith and based on the information provided
by Idaho Power Company in the aforementioned studies, the applicable security
deposits with the assumption that Idaho Power Company would be able to construct the
interconnection facilities on the schedule originally set by the interconnection studies."
This statement is incorrect.
First, Exergy has completely failed to, and has not to this day, paid the required
construction deposit, nor executed the required Generator Interconnection Agreement
("GIA") in order for Idaho Power to proceed with any of the required detailed design,
engineering, ordering of materials, and construction of the interconnection facilities
and/or transmission upgrades. What Exergy has paid are the required deposits for
Idaho Power to conduct the mandatory studies (Feasibility Study, System Impact Study,
James Carkulis
June 8, 2012
Page 6 of 6
and Facilities Study), none of which provide a valid time line unless and until Exergy
executes the required GIA and pays the requisite construction deposit for work to begin.
Second, as stated above, as a sophisticated developer of generation projects and
having previously developed more than a dozen other PURPA OF wind projects on
Idaho Power's system, Exergy is fully aware of the studies Idaho Power must conduct
as well as the processes necessary for generators, such as the Jack Ranch Projects, to
connect to Idaho Power's system. Exergy is fully aware that the recitation in Section 4
of the Feasibility Study Report of what Exergy requested as an on-line date in its
Generator Interconnection Application (December 2011) is not a representation by
Idaho Power that the required work -which at the Feasibility Study stage is still
unknown -can be accomplished by any date certain.
Additionally, even if Idaho Power were to agree, which it certainly does not, to
change the Scheduled Operation Date in the FESAs, you have requested December 1,
2012, as the new Scheduled Operation Date. Further you state that this December
2012 date is consistent with the interconnection agreements applicable to each Project.
The December 2012 date is most definitely NOT consistent with the anticipated time
line, construction, and upgrades required of the interconnection of the Jack Ranch
Projects. As clearly stated in the final GIA transmitted to you on May 14, 2012, "Idaho
Power does not commit to this date [December 15, 2012] but will use reasonable efforts
to have commissioning complete by 6/9/2014." Consequently, your requested change
in the Scheduled Operation Date, even if agreeable to Idaho Power, would not resolve
the problem that exists today, with Exergy insisting upon a Scheduled Operation Date
that is before the time at which the Jack Ranch Projects' interconnection could be
completed.
Lastly, as a reminder, per the May 14, 2012, letter to you from Idaho Power's
Tess Park, "Failure to submit an executed copy of the enclosed Final GIA, which
includes the estimated milestones for the completion of construction, and complete the
necessary financing arrangements for the Jack Ranch Projects by June 13, 2012, will
result in Idaho Power terminating your generator interconnection request and
withdrawing the Jack Ranch Projects from the generator interconnection queue."
Donovan E. Walker
DEW:csb
cc: Lisa Grow, Idaho Power (via e-mail)
Tess Park, Idaho Power (via e-mail)
Randy, Allphin, Idaho Power (via e-mail)
Jason Williams, Idaho Power Corporate Counsel (via e-mail)
01 June 2012
Lisa A. Grow
Senior Vice President, Power Supply
Idaho Power Company
PO Box 70
Boise, Idaho 83707
Re: Cottonwood \Vind Park -Project #31 T1 1100. Deep Creek Wind Park -Project # 31721200,
Rogerson Flats Wind Park --Project # 3 I 721300 and Salmon Creek \Vind Park -Project # 31721400
Dear Ms. Oro\,,,,
Each of Cottonwood \Vind Park, LLC, Deep Creek Wind Park, LLC. Rogerson Flats Wind Park.
LLC and Salmon Creck Wind Park LLC (collectively, the "Project Companies") has entered into an
indi vidual Firm Energy Sales Agreement with Idaho Power Company dated December 10, 2010
(collectively, the "Project PPAs'·).
J till1 \witing this letter on behalf of the Project Companies to ask that Idaho Power Company amend
Appendix B (Facility and Poinl of Delivery) of each of the Project PP/\s such that Section B-3
(Scheduled First Energy ami Operation Date) reads as follows:
"Seller has selected Novcmbel' 1,2012 as the Scheduled First Energy Date
Seller has selected December t 2012 as the Schedllled Operation Date"
The current schedule glven by Idaho Pow-er TnUlsmissioll is December 2013.
This amendment will result in the schedule of the Project PPAs being consistent \vilh each of the
intercOlU1cctioll agreements applicable to each o[the projects.
The parties originally agreed to June 30. 2012 as the Schedukd Operation Date because Idaho PO\vcr
Company had originally provided the Project CompElllies with all initial on-line date of December
J 1,2011 based on Ihe intcrconnectillll studies. Specifically, the Generator Connector Feasibility
Study final report elated .luI; ~8, 20 10 for projects queue #-325 and queue #327 completed by Tdaho
Po\\"er Company is premised upon a proposed in-service date of December 2011 (See Section 4.0 of
the final report). 1vloreover, the Generator Connector System Impact Study final report dated
December 29, 2010 for projects queue #325 and queue #327 completed by Idaho Power Company is
also based on the same proposed in-service dale (1 f Decenlbcr 2011 (See Section 4.0 0 r the final
report).
The information we've received from Idaho PO'wer Company in these studies has triggered many
evenls. The project companies left sufticient rool11 to build hom the energization date of December
2011 of the substation to completion under the PPA. The project companies have been in continuous
construction of these proj eets since December of 20 11 based in large part on the information frol11
Idaho Power Company contained in these studies. For example, the project companies have ordered
substation equipment. readied the transfollner to ship, built roads and excavated foundations. among
other things. It \vas reasonable for the project companies to take these actions based on the fact that
we were getting this information from Idaho Po\ver Company. We hope that we have not relied on
this information to OUl" detriment.
Based on the results the studies delivered from Idaho Power Company. the parties included six
months of contingency (should Iclaho PO\\-cr Company experience any delays in the construction of
the necessary interconnection facilities) and, thus. the June 30, 2012 date was included in each of the
Project PPAs. The Project Companies entered into the Project PPAs (with tile aforementioned dates)
hased in large pan on the information provided by Idaho Power Company. The Project Companies
acted in :;oocl Caith and in a commercially reasonable manner based on the information that Idaho
Power Company provided.
Now that Idaho Power Company has made the Project Companics aware that the interconnection
facilities will not be completed in order to allow the Project Companies to meet the Scheduled
Operation Date. I am asking simply to have the elates in the Project PPAs reHeet what Idaho Power
Company is telling LIS that they will accomplish regarding the interconnection L~lCilities.
Please note, each of the Project Companies has made. in good faith and based 011 the information
provided by Idaho Po\\"er Company in ihe aforementioned studies, thl! applicable stlcllrity deposits
with the assumption that Idaho PO\ver Company would he able to construct the interconnection
facilities 011 the schedule originally set by the interconnection studies. The Project Companies have
been diligently trying to '.york with Idaho Power Company to overcome this delay. but it is beyond
the control of the Project Companies.
Tf you agree with the amendment. please respond appropriately and r ''lill bave the appropriate
amendments drafted for each of the Project PPAs. I am very appreciative OfYOLIl' consideration and
w·Quld ask for a resolution as soon as possible.
Sincerely/
.. -: ~ (~~~~/
,.-/J~~nes T . .cark.l~J.i&i;--·
'.. p,,"ranag6:oJ each <.lethe Project Companies
Cc: Idaho Power Comp:U1Y. Cogeneration and Small Power Procluclion
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 57
July 9,2012
Idaho Power Company
Attn: Josh Harris
1221 West Idaho Street
Boise, ID 83702
RE: Notch Butte Wind Park -GI #349 & #359
Dear Mr. Harris,
Exergy has received and executed the final Generator Interconnection Agreement (GIA) prepared by
Idaho Power and dated June 26, 2012. Exergy is pleased to submit the enclosed and executed GIA
and will submit the funds described in the enclosed GIA at such time as Idaho Power countersigns
and returns a copy of the document to our office.
Best Regards,
0~
Joshua Gunderson, Project Engineer
phone: [phone]
email: [e-mail]
Exergy Development Group, 802 W. Bannock, 12th FlOOf, Boise, lD phone: [phone] fax: [phone]
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101
June 26, 2012
GENERATOR INTERCONNECTION AGREEMENT
Schedule 72
Notch Butte Wind Park PROJECTS #349 & #359
6.5/11.5 MW
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u .C. No. 29, Tariff No. 101
TABLE OF CONTENTS
RECITALS ............................................................................................................................................. 1
AGREEMENTS ..................................................................................................................................... 1
1. Capitalized Terms ................................................................................................................ 1
2. Terms and Conditions ................................................................................... , ...................... 1
3. This Agreement is not an agreement to purchase Sellers power. ........................................ 1
4. Attachments ......................................................................................................................... 1
5. Effective Date, Term. Termination and Disconnection .......................................................... 2
5.2 Termination .......................................................................................................................... 2
6. Assignment. Liability, Indemnity, Force majeure, Consequential Damaqes and Default ....... 5
7. Insurance ............................................................................................................................. 7
8. Miscellaneous ....................................................................................................................... 7
9. Notices ................................................................................................................................. 8
10. Signatures ............................................................................................................................ 9
Attachment 1 ......................................................................................................................................... 1
Attachment 2 ......................................................................................................................................... 1
Attachment 3 ......................................................................................................................................... 1
Attachment 4 ......................................................................................................................................... 1
Attachment 5 ......................................................................................................................................... 2
Attachment 6 ......................................................................................................................................... 1
Attachment 7 .......................................................................................................................................... 1
Idaho Power Company Generator Interconnection Agreement # 349/359
I,P.U.C. No. 29. Tariff No. 101 Page 1 of 9
This Generator Interconnection Agreement ("Agreement") under Idaho Power Company's
Schedule 72 is effective as of the 26 day of June, 2012 between Exergy Development Group of Idaho,
("Seller", "Customer" or "The Project") and Idaho Power Company ("Company","Transmission Owner",
"Idaho Power", "IPC" or "IPCO").
RECITALS
A. Seller will own or operate a Generation Facility that qualifies for service under Idaho
Power's Commission-approved Schedule 72 and any successor schedule.
B. The Generation Facility covered by this Agreement is more particularly described in
Attachment 1.
AGREEMENTS
1. Capitalized Terms
Capitalized terms used herein shall have the same meanings as defined in Schedule 72 or in the body
of this Agreement.
.2. Terms and Conditions
This Agreement and Schedule 72 provide the rates, charges, terms and conditions under which the
Seller's Generation Facility will interconnect with, and operate in parallel with, the Company's
transmission/distribution system. Terms defined in Schedule 72 will have the same defined meaning in
this Agreement. If there is any conflict between the terms of this Agreement and Schedule 72,
Schedule 72 shall prevail. .
3. This Agreement is not an agreement to purchase Seller's power.
Purchase of Seller's power and other services that Seller may require will be covered under separate
agreements. Nothing in this Agreement is intended to affect any other agreement between the
Company and Seller.
4. Attachments
Attached to this Agreement and included by reference are the following:
Attachment 1 -Description and Costs of the Generation Facility, Interconnection
Facilities, and Metering Equipment
Attachment 2 -One-line Diagram Depicting the Generation Facility, Interconnection
Facilities, Metering Equipment and Upgrades.
Attachment 3 -Milestones for Interconnecting the Generation Facility
Attachment 4 -Additional Operating Requirements for the Company's Transmission
System Needed to Support the Seller's Generation Facility
Attachment 5 -Reactive Power
Attachment 6 -Description of Upgrades required to integrate the Generation Facility and
Best Estimate of Upgrade Costs
Attachment 7 -Generator Interconnection Control Requirements
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 2 of 9
5. Effective Date, Term, Termination and Disconnection.
5.1 Term of Agreement. Unless terminated earfier in accordance with the provisions
of this Agreement, this Agreement shall become effective on the date specified above and remain
effective as long as Seller's Generation Facility is eligible for service under Schedule 72.
5.2 Termination.
5.2.1 Seller may voluntarily terminate this Agreement upon expiration or
termination of an agreement to sell power to the Company.
5.2.2 After a Default, either Party may terminate this Agreement pursuant to
Section 6.5.
5.2.3 Upon termination or expiration of this Agreement, the Seller's Generation
Facility will be disconnected from the Company's transmission/distribution system. The termination or
expiration of this Agreement shall not relieve either Party of its liabilities and obligations, owed or
continuing at the time of the termination. The provisions of this Section shall survive termination or
expiration of this Agreement.
5.3 Temporary Disconnection. Temporary disconnection shall continue only for so
long as reasonably necessary under "Good Utility Practice." Good Utility Practice means any of the
practices, methods and acts engaged in or approved by a significant portion of the electric industry
during the relevant time period, or any of the practices, methods and acts which, in the exercise of
reasonable judgment in light of the facts known at the time the decision was made, could have been
expected to accomplish the desired result at a reasonable cost consistent with good business practices,
reliability, safety and expedition. Good Utility Practice is not intended to be limited to the optimum
practice, method, or act to the exclusion of all others, but rather to be acceptable practices, methods, or
acts generally accepted in the region. Good Utility Practice includes compliance with WECC or NERC
requirements. Payment of lost revenue resulting from temporary disconnection shall be governed by
the power purchase agreement.
5.3.1 Emergencv Conditions. "Emergency Condition" means a condition or
situation: (1) that in the judgment of the Party making the claim is imminently likely to
endanger life or property; or (2) that, in the case of the Company, is imminently likely (as
determined in a non-discriminatory manner) to cause a material adverse effect on the
security of, or damage to the Company's transmission/distribution system, the
Company's Interconnection Facilities or the equipment of the Company's customers; or
(3) that, in the case of the Seller, is imminently likely (as determined in a non­
discriminatory manner) to cause a material adverse effect on the reliability and security
of, or damage to, the Generation Facility or the Seller's Interconnection Facilities. Under
Emergency Conditions, either the Company or the Seller may immediately suspend
interconnection service and temporarily disconnect the Generation Facility. The
Company shall notify the Seller promptly when it becomes aware of an Emergency
Condition that may reasonably be expected to affect the Seller'S operation of the
Generation Facility. The Seller shall notify the Company promptly when it becomes
aware of an Emergency Condition that may reasonably be expected to affect the
Company's eqUipment or service to the Company's customers. To the extent
information is known, the notification shall describe the Emergency Condition, the extent
of the damage or deficiency, the expected effect on the operation of both Parties'
facilities and operations, its anticipated duration, and the necessary corrective action.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29. Tariff No.1 01 Page 3 of9
5.3.2 Routine Maintenance, Construction, and Repair. The Company may
interrupt interconnection service or curtail the output of the Seller's Generation Facility
and temporarily disconnect the Generation Facility from the Company's
transmission/distribution system when necessary for routine maintenance, construction,
and repairs on the Company's transmission/distribution system. The Company will
make a reasonable attempt to contact the Seller prior to exercising its rights to interrupt
interconnection or curtail deliveries from the Seller'S Facility. Seller understands that in
the case of emergency circumstances, real time operations of the electrical system,
and/or unplanned events, the Company may not be able to provide notice to the Seller
prior to interruption, curtailment or reduction of electrical energy deliveries to the
Company. The Company shall use reasonable efforts to coordinate such reduction or
temporary disconnection with the Seller.
5.3.3 Scheduled Maintenance. On or before January 31 of each calendar year,
Seller shall submit a written proposed maintenance schedule of Significant Facility
maintenance for that calendar year and the Company and Seller shall mutually agree as
to the acceptability of the proposed schedule. The Parties determination as to the
acceptability of the Seiler'S timetable for scheduled maintenance will take into
consideration Good Utility Practices, Idaho Power system requirements and the Seller's
preferred schedule. Neither Party shall unreasonably withhold acceptance of the
proposed maintenance schedule.
5.3.4. Maintenance Coordination. The Seller and the Company shall, to the
extent practical, coordinate their respective transmission/distribution system and
Generation Facility maintenance schedules such that they occur simultaneously. Seller
shall provide and maintain adequate protective equipment sufficient to prevent damage
to the Generation Facility and Seller-fumished Interconnection Facilities. In some cases,
some of Seller's protective relays will provide back-up protection for Idaho Power's
facilities. In that event, Idaho Power will test such relays annually and Seller will pay the
actual cost of such annual testing.
5.3.5 Forced Outages. During any forced outage, the Company may suspend
interconnection service to effect immediate repairs on the Company's
transmission/distribution system. The Company shall use reasonable efforts to provide
the Seller with prior notice. If prior notice is not given, the Company shall, upon request,
provide the Seller written documentation after the fact explaining the circumstances of
the disconnection.
5.3.6 Adverse Operating Effects. The Company shall notify the Seller as soon
as practicable if, based on Good Utility Practice, operation of the Seiler's Generation
Facility may cause disruption or deten'oration of service to other customers served from
the same electric system, or if operating the Generation Facility could cause damage to
the Company's transmission/distribution system or other affected systems. Supporting
documentation used to reach the decision to disconnect shall be provided to the Seller
upon request. If, after notice, the Seller fails to remedy the adverse operating effect
within a reasonable time, the Company may disconnect the Generation Facility. The
Company shall provide the Seller with reasonable notice of such disconnection, unless
the provisions of Article 5.3.1 apply.
5.3.7 Modification of the Generation Facilitv. The Seller must receive written
authorization from the Company before making any change to the Generation Facility
that may have a material impact on the safety or reliability of the Company's
transmission/distribution system. Such authorization shall not be unreasonably withheld.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 4 of9
Modifications shall be done in accordance with Good Utility Practice. If the Seller makes
such modification without the Company's prior written authorization, the latter shall have
the right to temporarily disconnect the Generation Facility.
5.3.8 Reconnection. The Parties shall cooperate with each other to restore the
Generation Facility, Interconnection Facilities, and the Company's
transmission/distribution system to their normal operating state as soon as reasonably
practicable following a temporary disconnection.
5.3.9 Voltage Levels. Seller, in accordance with Good Utility Practices, shall
minimize voltage fluctuations and maintain voltage levels acceptable to Idaho Power.
Idaho Power may, in accordance with Good Utility Practices, upon one hundred eighty
(180) days' notice to the Seller, change its nominal operating voltage level by more than
ten percent (10%) at the Point of Delivery, in which case Seller shall modify, at Idaho
Powers expense, Sellers eqUipment as necessary to accommodate the modified
nominal operating voltage level.
5.4 Land Rights.
5.4.1 Seller to Provide Access. Seller hereby grants to Idaho Power for the
term of this Agreement all necessary rights-of-way and easements to install, operate,
maintain, replace, and remove Idaho Powers Metering Equipment, Interconnection
Equipment, Disconnection Equipment, Protection Equipment and other Special Facilities
necessary or useful to this Agreement, including adequate and continuing access rights
on property of Seller. Seller warrants that it has procured sufficient easements and
rights-of-way from third parties so as to provide Idaho Power with the access described
above. All documents granting such easements or rights-of-way shall be subject to
Idaho Powers approval and in recordable form.
5.4.2 Use of Public Rights-of-Way. The Parties agree that it is necessary to
avoid the adverse environmental and operating impacts that would occur as a result of
duplicate electric lines being constructed in close proximity. Therefore, subject to Idaho
Power's compliance with Paragraph 5.4.4, Seller agrees that should Seller seek and
receive from any local, state or federal governmental body the right to erect, construct
and maintain Seller-furnished Interconnection Facilities upon, along and over any and all
public roads, streets and highways, then the use by Seller of such public right-of-way
shall be subordinate to any future use by Idaho Power of such public right-of-way for
construction and/or maintenance of electric distribution and transmission facilities and
Idaho Power may claim use of such public right-of-way for such purposes at any time.
Except as required by Paragraph 5.4.4, Idaho Power shall not be required to
compensate Seller for exercising its rights under this Paragraph 5.4.2.
5.4.3 Joint Use of Facilities. Subject to Idaho Power's compliance with
Paragraph 15.4.4, Idaho Power may use and attach its distribution and/or transmission
facilities to Sellers Interconnection Facilities, may reconstruct Seller's Interconnection
Facilities to accommodate Idaho Powers usage or Idaho Power may construct its own
distribution or transmission facilities along, over and above any public right-of-way
acquired from Seller pursuant to Paragraph 5.4.2, attaching Seiler's Interconnection
Facilities to such newly constructed facilities. Except as required by Paragraph 5.4.4,
Idaho Power shall not be required to compensate Seller for exercising its rights under
this Paragraph 5.4.3.
5.4.4 Conditions of Use. It is the intention of the Parties that the Seller be left in
substantially the same condition, both financially and electrically, as Seller existed prior
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 5 of 9
to Idaho Powers exercising its rights under this Paragraph 5.4. Therefore, the Parties
agree that the exercise by Idaho Power of any of the rights enumerated in Paragraphs
5.4.2 and 5.4.3 shall: (1) comply with' all applicable laws, codes and Good Utility
Practices, (2) equitably share the costs of installing, owning and operating jointly used
facilities and rights-of-way. If the Parties are unable to agree on the method of
apportioning these costs, the dispute will be submitted to the Commission for resolution
and the decision of the Commission will be binding on the Parties, and (3) shall provide
Seller with an interconnection to Idaho Powers system of equal capacity and durability
as existed prior to Idaho Power exercising its rights under this Paragraph 5.4.
6. Assignment, Liability. Indemnity, Force majeure, Consequential Damages and Default.
6.1 Assignment. This Agreement may be assigned by either Party upon twenty-one
(21) calendar days prior written notice and opportunity to object by the other Party; provided
that:
6.1.1 Either Party may assign this Agreement without the consent of the other
Party to any affiliate of the assigning Party with an equal or greater credit rating and with
the legal authority and operational ability to satisfy the obligations of the assigning Party
under this Agreement.
6.1.2 The Seller shall have the right to contingently assign this Agreement,
without the consent of the Company, for collateral security purposes to aid in providing
financing for the Generation Facility, provided that the Seller will promptly notify the
Company of any such contingent assignment.
6.1.3 Any attempted assignment that violates this article is void and ineffective.
Assignment shall not relieve a Party of its obligations, nor shall a Party's obligations be
enlarged, in whole or in part, by reason thereof. An assignee is responsible for meeting
the same financial, credit, and insurance obligations as the Seller. Where required,
consent to assignment will not be unrea,sonably withheld, conditioned or delayed.
6.2 Limitation of Liabilitv. Each Party's liability to the other Party for any loss, cost,
claim, injury, liability, or expense, including reasonable attorney's fees, relating to or arising from
any act or omission in its performance of this Agreement, shall be limited to the amount of direct
damage actually incurred. In no event shall either Party be liable to the other Party for any
indirect, special, consequential, or punitive damages, except as authorized by this Agreement.
6.3 Indemnitv.
6.3.1 This provision protects each Party from liability incurred to third parties as
a result of carrying out the provisions of this Agreement. Liability under this provision is
exempt from the general limitations on liability found in Article 6.2.
6.3.2 The Parties shall at all times indemnify, defend, and hold the other Party
harmless from, any and all damages, losses, claims, including claims and actions
relating to injury to or death of any person or damage to property, demand, suits,
recoveries, costs and expenses, court costs, attorney fees, and aI/ other obligations by
or to third parties, arising out of or resulting from the other Party's action or failure to
meet its obligations under this Agreement on behalf of the indemnifying Party, except in
cases of gross negligence or intentional wrongdoing by the indemnified Party.
6.3.3 If an indemnified person is entitled to indemnification under this article as
a result of a claim by a third party, and the indemnifying Party fails, after notice and
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 6 of 9
reasonable opportunity to proceed under this article, to assume the defense of such
claim, such indemnified person may at the expense of the indemnifying Party contest,
settle or consent to the entry of any judgment with respect to, or pay in full, such claim.
Failure to defend is a Material Breach.
6.3.4 If an indemnifying party is obligated to indemnify and hold any
indemnified person harmless under this article, the amount owing to the indemnified
person shall be the amount of such indemnified person's actual loss, net of any
insurance or other recovery.
6.3.5 Promptly after receipt by an indemnified person of any claim or notice of
the commencement of any action or administrative or legal proceeding or investigation
as to which the indemnity provided for in this arlicle may apply, the indemnified person
shall notify the indemnifying party of such fact. Any failure of or delay in such notification
shall be a Material Breach and shall not affect a Parly's indemnification obligation unless
such failure or delay is materially prejudicial to the indemnifying party.
6.4 Force Majeure. As used in this Agreement, "Force Majeure" or "an event of
Force Majeure" means any cause beyond the control of the Seller or of the Company which,
despite the exercise of due diligence, such Party is unable to prevent or overcome. Force
Majeure includes, but is not limited to, acts of God, fire, flood, storms, wars, hostilities, civil
strife, strikes and other labor disturbances, earlhquakes, fires, lightning, epidemics, sabotage, or
changes in law or regulation occurring after the Operation Date, which, by the exercise of
reasonable foreSight such party could not reasonably have been expected to avoid and by the
exercise of due diligence, it shall be unable to overcome. If either Party is rendered wholly or in
part unable to perform its obligations under this Agreement because of an event of Force
Majeure, both Parlies shall be excused from whatever performance is affected by the event of
Force Majeure, provided that:
(1) The non-performing Parly shall, as soon as is reasonably possible after
the occurrence of the Force Majeure, give the other Parly written notice describing the
parliculars of the occurrence.
(2) The suspension of performance shall be of no greater scope and of no
longer duration than is required by the event of Force Majeure.
(3) No obligations of either Parly which arose before the occurrence causing
the suspension of performance and which could and should have been fully performed
before such occurrence shall be excused as a result of such occurrence.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 7 of 9
6.5 Default and Material Breaches.
6.5. 1 Defaults. If either Party fails to perform any of the terms or conditions of
this Agreement (a "Default" or an "Event of Default'), the nondefaulting Party shall cause
notice in writing to be given to the defaulting Party, specifying the manner in which such
default occurred. If the defaulting Party shall fail to cure such Default within the sixty
(60) days after service of such notice, or if the defaulting Party reasonably demonstrates
to the other Party that the Default can be cured within a commercially reasonable time
but not within such sixty (60) day period and then fails to diligently pursue such cure,
then, the nondefaulting Party may, at its option, terminate this Agreement and/or pursue
its legal or equitable remedies.
6.5.2 Material Breaches. The notice and cure provisions in Paragraph 6.6. 1 do
not apply to Defaults identified in this Agreement as Material Breaches. Material
Breaches must be cured as expeditiously as possible following occurrence of the
breach.
7. Insurance.
During the term of this Agreement, Seller shall secure and continuously carry the following
insurance coverage:
7.1 Comprehensive General Liability Insurance for both bodily injury and property
damage with limits equal to $1,000,000, each occurrence, combined single limit. The deductible
for such insurance shall be consistent with current Insurance Industry Utility practices for similar
property.
7.2 The above insurance coverage shall be placed with an insurance company with
an A.M. Best Company rating of A-or better and shall include:
(a) An endorsement naming Idaho Power as an additional insured and loss
payee as applicable; and
(b) A provision stating that such policy shall not be canceled or the limits of
liability reduced without sixty (60) days' prior written notice to Idaho Power.
7.3 Seller to Provide Certificate of Insurance. As required in Paragraph 7 herein and
annually thereafter, Seller shall furnish the Company a certificate of insurance, together with the
endorsements required therein, evidencing the coverage as set forth above.
7.4 Seller to Notify Idaho Power of Loss of Coverage -If the insurance coverage
required by Paragraph 7.1 shall lapse for any reason, Seller will immediately notify Idaho Power
in writing. The notice will advise Idaho Power of the specific reason for the lapse and the steps
Seller is taking to reinstate the coverage. Failure to provide this notice and to expeditiously
reinstate or replace the coverage will constitute grounds for a temporary disconnection under
Section 5.3 and will be a Material Breach.
8. Miscellaneous.
8. 1 Governing Law. The validity, interpretation and enforcement of this Agreement
and each of its proviSions shall be governed by the laws of the state of Idaho without regard to
its conflicts of law principles.
8.2 Salvage. No later than sixty (60) days after the termination or expiration of this
Agreement, Idaho Power will prepare and forward to Seller an estimate of the remaining value
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 8 of 9
of those Idaho Power furnished Interconnection Facilities as required under Schedule 72 and/or
described in this Agreement, less the cost of removal and transfer to Idaho Powers nearest
warehouse, if the Interconnection Facilities will be removed. If Seller elects not to obtain
ownership of the Interconnection Facilities but instead wishes that Idaho Power reimburse the
Seller for said Facilities the Seller may invoice Idaho Power for the net salvage value as
estimated by Idaho Power and Idaho Power shall pay such amount to Seller within thirty (30)
days after receipt of the invoice. Seller shall have the right to offset the invoice amount against
any present or future payments due Idaho Power.
9. Notices.
9.1 General. Unless otherwise provided in this Agreement, any written notice,
demand, or request required or authorized in connection with this Agreement ("Notice") shall be
deemed properly given if delivered in person, delivered by recognized national currier service,
or sent by first class mail, postage prepaid, to the person specified below:
If to the Seller:
Seller: Exergy Development Group of Idaho LLC
Attention: Elizabeth Wooistenhulme
Address: 802 West Bannock, 12th Floor
City: Boise State: Idaho Zip: -"8,,,,"3~70=2,--__ _
Phone: [phone] Fax: [phone]
If to the Company:
Idaho Power Company -Delivery
Attention: Operations Manager
1221 W. Idaho Street
Boise: Idaho 83702
Phone: [phone] Fax: [phone]
9.2 Billing and Payment. Billings and payments shall be sent to the addresses set
out below:
SeIJer: Exergy Development Group ofldaho, LLC
Attention: Elizabeth Wooistenhuhne
Address: 802 West Bannock, 12th Floor
City: Boise State: 1daho Zip: .,!;!8~37~0:=2 ___ _
Phone: [phone] Fax: [phone]
Idaho Power Company -Delivery
Attention: Corporate Cashier
PO Box 447
Salt Lake City Utah 84110-0447
Phone: [phone] email: [e-mail]
9.3 Designated Operating Representative. The Parties may also designate
operating representatives to conduct the communications which may be necessary or
convenient for the administration of this Agreement. This person will also serve as the point of
contact with respect to operations and maintenance of the Party's facilities.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101
Seller's Operating Representative:
Seller: Exergy Development Group ofIdaho, LLC
Attention: Elizabeth Wooistenhulme
Address: 802 West Bannock, 12th Floor
City: Boise State: Idaho Zip: =83'-'-7=02=----__ _
Phone: [phone] Fax: 2;;;.;0""'8...,;:-3;.::,3.::..,6-..:,.94..:.,:3:...;:1 ___ _
Company's Operating Representative:
Idaho Power Company -Delivery
Attention: Outage Coordinator -System/Regional Dispatch
1221 W. Idaho Street
Boise, Idaho 83702
Over 138kV phone [phone] during regular business hours
Page 9 of 9
Under 138kV Phone: [phone], or 388-5175 during regular business hours
After hours -System Dispatch 388 2826
Regional Dispatch
Southern Region 208-388-5190
9.5 Changes to the Notice Information. Either Party may change this information by
giving five (5) Business Days written notice prior to the effective date of the change.
10. Signatures.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their
respective duly authorized representatives.
For the Seller ,
/ /iJ >
Name: ,0-/''''' l~
/"
Title: Ma n~gjng Member
Date: July 9, 2012
Name:
Title: D .... T~ss 'f4~k.. ctor, Load Serving Operations -Idaho Power Company
?-((-( A Date: __________ _
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29. Tariff No. 101 Page 1 of 3
Attachment 1
Description and Costs of the Generation Facilitv. Interconnection Facilities and Metering Equipment
Interconnection Details
Type of Interconnection Service: Studied as an Idaho Power Network Resource under PURPA
Full Output: 18 MW (both projects)
Nominal Delivery Voltage: 12.5 kV
General Facility Description
The Notch Butte Wind Park project includes both Projects #349 and #359 for a total of 18 MW of power
provided by seven 2.5Mw Nordex Turbines. The Interconnection Customer (IC) will provide all
generation and station equipment required to deliver power at 12.5 kV to the Point of Interconnection
(POI) which is located at the coordinates North 420 53.12948' West 1140 10.57'. The Seller will provide
two POTS lines and two DDS circuits to the POls (one pair for each feeder connection) for
communication. Two 12.5 kV feeders will run from the POI four miles west to the IPCo Dietrich
substation where the station will be expanded to accommodate the two new feeders. The power will be
converted to 138 kV via a 12.5 kV to 138 kV power circuit transformer. A new double circuit
transmission line, consisting of a new 138 kV line and the existing 46 kV line, will run four miles due
north out of the Dietrich SUbstation. The new 138 kV line will connect to the existing Midpoint-Silver
138 kV line.
Interconnection Point
The Interconnection Point for the Notch Butte Wind Park Project will be the generator side of the
disconnect switches labeled Disconnect Switches A-13 and A-14 (one for each feeder) as shown on the
attached Single Line drawings 210-64299, sheets 1 & 2. This Interconnection Point is in Lincoln
County, 10 -T6S, R19E, SW corner of Section 22.
A drawing identifying the Point'of Interconnection is included as Attachment 2. The Point of Change of
Ownership is electrically the same as the Interconnection Point.
Seller's Interconnection Facilities
The Seller will install all generation and station equipment required to deliver power at 12.5 kV to the
interconnection point. Transmitting 18 MW of power at 12.5 kV requires two distribution feeders. The
Seller shall balance the generation between these two feeder connections with no more than 11 MW of
power flowing on either feeder. The Seller will own and maintain facilities electrically located on the
Interconnection Customer side of the Point of Change of Ownership. Idaho Power will own and
maintain the facilities electrically located on the IPCo side of the Point of Change of Ownership.
The Seller will install equipment to receive signals from Idaho Power Company Grid Operations for
Generator Output Limit Control ("GOLC") -see Attachment 4 Operating Requirements.
The Seller will provide phone service to IPCo's generator interconnect package as described in
Telecommunications below.
The Seller will provide a DNP 3.0 serial data connection to the local Idaho Power Company SCADA
RTU when any communication with Seller-owned and maintained equipment is required for GOLC,
voltage control or other plant monitoring or control. Preliminary points lists and functional description
were provided to the Seller in the Facility Study Report.
All interconnection equipment electrically located on the generator side of the Point of Change
Ownership shall be owned and maintained by the Seller.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 2 of 3
Other Facilities Provided by Seller
In addition to communication circuits that may be needed by the Seller, the Seller shall provide the
following communication circuits for Idaho Power's use:
Two POTS (Plain Old Telephone Service) dial-up circuit for querying the revenue meter at the
generation interconnection site. One for each 4-pole feeder connection.
Two leased DDS (Digital Data Service) circuit for SCADA between the generation interconnection site
and Twin Falls Service Building (273 Blue Lakes Blvd. S., Twin Falls, ID 83301). One for each 4-pole
feeder connection. These circuits must operate at 19.2 kbps data rate. Please note that Frame Relay
service is not acceptable.
The Interconnection Customer/communications provider shall provide a demarcation box and terminate
the specified communications circuits at the demarcation box. The location of the demarcation box will
be determined by Idaho Power. The demarcation box shall meet the following requirements:
• Be accessible by both the communications provider and Idaho Power
• The location shall be near Idaho Power's equipment and shall be subject to approval by
Idaho Power
• The communications cable pairs shall be labeled/tagged accordingly (Le. circuit number,
phone number, transmit, receive, etc.)
The Seller is required to coordinate with a communications provider to provide the communications
circuits and pay the associated one time setup and periodic charges. The communication circuits will
need to be installed and operational prior to generating into the Idaho Power system. Note that
installation by communications provider may take several months and should be ordered in advance to
avoid delaying the project. If the communication circuit types listed above are not available at the site
by a communications provider, the Seller shall confer with Idaho Power.
If high voltage protection is required by the communications provider for the incoming communications
provider cable, the high voltage protection assembly shall be engineered and supplied by the Seller.
Options are available for indoor or outdoor mounting. The high voltage protection assembly shall be
located in a manner that provides Idaho Power 24-hour access to the assembly for trouble-shooting of
Idaho Power owned equipment.
Ground Fault Equipment
The Seller will install transformer configurations that are Grounded-WYE to Grounded-WYE and will
limit the contribution of the ground fault current to 20 amps or less at the Interconnection Point.
Monitoring Information
If the Seller requires the ability to monitor information related to the Idaho Power reclosers in the
generation interconnection package they are required to supply their own communications circuit to the
control box.
Easements
The Seller will provide to IPCO a surveyed (Metes & Bounds) legal description along with exhibit map
for IPCO's facilities at the Interconnection Point. After the legal description has been delivered to IPCO
for review, IPCO will supply to the Interconnection Customer a completed IPCO easement for signature
by the land owner of record. Once the signatures have been secured, the Seller will return the signed
easement to IPCO for recording.
Generator Output Limit Control
The Seller will install equipment to receive signals from Idaho Power Grid Operations for Generation
Output Limit Control ("GOLC") -see Attachment 4 Operating Requirements.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 3 of 3
Local Service
The Seller is responsible to arrange for local service to their site, as necessary.
Idaho Power Company's Interconnection Facilities
Idaho Power will install two standard generation interconnection packages, one for each feeder. For
each package, if the Seller is going underground to the Interconnection Point, Idaho Power will include
a pole riser for the Generator to install cables to interconnect to the Idaho Power system. If the Seller is
going overhead to the Interconnection Point, it will be at a tension not to exceed the design tension
specified by Idaho Power.
The new interconnection packages each will include four distribution poles to mount a local service
transformer, solid blade disconnects, primary metering package, recloser, relays, RTU, fuses and riser
necessary for the package. The interconnection will be controlled by a SEL-311C line protection relay
and a GE iBox RTU. The relay and RTU will be located in a pole mounted enclosure and will also
contain a test switch (TS4) , SLSS, dialup modem, DDS CSU/DSU, isolation interface, power supply,
DC converter, control switch and surge protector.
Concrete barriers may be necessary to protect this equipment from local area traffic.
A 2" conduit will be installed alongside the underground primary to facilitate information exchange to the
customer about the recloser. (The Interconnection Customer is responsible for providing and installing
the appropriate cable.)
See single line drawing as Attachment 2.
All interconnection equipment electrically located on the utility side of the Interconnection Point shall be
owned, operated, and maintained by Idaho Power.
Maintenance Coordination Exception
The Seller's protective relays will not provide back-up protection for Idaho Power facilities, therefore the
last 2 sentences in Section 5.3.4 of this Generator Interconnection Agreement do not apply to this
Generation Facility.
Estimated Cost & Ownership
The following good faith estimates are provided in 2011 dollars:
Interconnection Facilities:
'-~~ef~gnn~g!J9_n_p~9.I<Cl_g~§ (21 . __
SUBTOTAL
See Attachment 6 for Total Estimate Costs
~ -- - -
IPC $¥9,OOO
$440,(~OO
Full payment is required up front in accordance with Schedule 72, unless payment arrangements are
made in advance with Idaho Power Operations Finance (see Attachment 3).
Billing for construction activities will be based upon actual expenditures.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 3
Attachment 2
One-line Diagram Depicting the Small Generation Facility, Interconnection Facilities, Metering
Equipment and Upgrades
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Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u.C. No. 29. Tariff No. 101 Page 2 of 3
.
Il:
-1--.--'--+...,---r--+-.--o--r---·--+--L..[l----l.----.-----------1 1
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Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 3 of 3
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u.C. No. 29, Tariff No. 101 Page 1 of 3
Attachment 3
Milestones for Interconnecting to the Generation Facility
Idaho Power Company agrees only to the Construction timelines under its direct control provided in the
Facility Study Report for this Project.
These milestones will begin, and the construction schedule referenced below, will only be valid upon
receipt of funding in full from the Seller or their authorized third party no later than the date set forth
below for such payment. Additionally, failure by Seller to make the required payments as set forth in
this Agreement by the date(s) specified below will be a material breach of this Agreement, which may
result in any or all of the following: (i) loss of milestone dates and construction schedules set forth
below: (ii) immediate termination of this Agreement by Idaho Power; (iii) removal from the generator
interconnection queue.
Limited Generation Output
In response to the Seller's request to come on line by December 15, 2012 with a limited generation
output, IPC conducted additional power flow models. It was determined that acceptable voltage on the
46 kV system could be maintained with 4.0 MW of generation from Notch Butte Wind Park if the
generators have the ability to absorb 3.0 MVAr. The installation of a 46 kV potential transformer
transferltrip package would have to be added to the scopelcosts of the work at Dietrich substation. The
Seller will be responsible for absorbing the VArs (3.0 maximum) necessary to maintain a 1.075 p.u.
maximum 46 kV bus voltage at Dietrich SUbstation. A voltage level above 1.075 p.u. will cause the
generator to be tripped offline.
Idaho Power will provide the magnitude of the 46kV bus voltage at Dietrich station to the customer's
control system. The voltage value will be made available to the seller's controi system via the
measurement device at Dietrich (e.g. meter or relay) and a direct, serial connection via the new feeder
ADSS fiber optics. Data protocol and point formatting to be determined.
The estimated cost of this additional work is $75,000. This brings the total estimated project cost to
$7,950,000. If the Generator Interconnection Agreement is signed and the project is funded before
July 9, 2012, then temporary facilities can be constructed in order to bring project, at limited output of 4
MW, on line by December 15, 2012.
Critical milestones and responsibility as agreed to by the Parties under limited ouput:
7/9/2012
1211/2012
12/15/2012
12/15/2012
12/15/2012
12/15/2012
12/15/2012
12/31/2012
Seller
:Seller
1PCO
lPCO ---.-
/PCO
IPCO
Seller
Seller
IPca receives the remaining balance of Construction
,estimate $7,950, 000 OR Credit arrangements are approved
b IPCO
Customer GOLC ready to connect & customer.telecomm
_ /f!ql!{C~fTJ~J!J~ .9-'!!_ ~~'!!P-'l!.!!! ... _. . _ ._.
IPCO Construction Complete
IPCO Commissioning Complete ------.. Project Leader issues Construction Complete Letter . -
Manager of Grid Operations authorizes project to be
energized, upon verification that Seller has previously met
.$..C.tLl!.f}..'I/.eJ ... ?!.§f!g ! Il]sl!.r.a!!.~f!. regYl[e'!!fJ.f}ts
Customer testing begins -Customer's requested In-Service Date
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 2 of 3
NOTE REGARDING LIMITED OUTPUT MILESTONES:
* Seller has requested an in-service date of 12115/2012. Idaho Power will use reasonable efforts to
have commissioning complete by this time if funding for project is received by July 9, 2012. This
date is contingent upon all materials being delivered in a timely manner, as well as other factors,
some of which are described above. The parties hereby acknowledge that Idaho Power shall not be
liable to for any possible damages associated in any way with Renewable Energy Credits or
Attributes, tax credits, the firm energy sales agreements, and the like, attributable to Customer, or
any of the various projects named on page one of this GIA, should the 12/15/2012 date not be met.
Under normal efforts to bring the projects online a normal amount of overtime is utilized. Because of
the Seller's desire to meet an IPC commissioning prior to 12/15/2012, Seller hereby authorizes IPC
to incur additional expenses, including additional overtime, lodging, travel, and other expenses
needed to bring in other IPC resources and personnel from other IPC regions, or to utilize third party
contractors, as necessary to work on this interconnection.
Critical milestones and responsibility as agreed to by the Parties under full output:
7/9/2012
4/15/2015
5/1/2015
5/15/2015
,5/15/2015
5/1512015
-5/15/2015
7/20/2015
:Seller
---._---
;Seller
1PCO
IPCO
/PCO ----._--
:/PCO
:Seller
'seller
IPCO receives the remaining balance of Construction
:estimate $7,875,000 OR Credit arrangements are approved
:EY IPCO _ ____ _ _ _ ... __
:Customer GOLC ready to connect & customer telecomm
.... {~!:!!!~!!1~!!.t~ .~~~ 9_Qr!.'e!~!f!..."" _. _ .. ____ . ____ .....
"PCO Construction Complete
IPCO Commissioning Complete
-' ----- - ---Project Leader issues Construction Complete Letter
--Manager o'-Grid OperEitions authorizesproject tobe
:energized, upon verification that Seller has previously met
:Schedule 7~ Sec 7 Insurance .requir~ments
·Customer testing begins r ____ • ____ ._____ _ _______ _
Customer's requested In-Service Date
--I
Idaho Power requires approximately thirty-four (34) months to complete design, procurement,
construction, permitting, and commissioning of the necessary interconnection facilities and required
upgrades associated with the Notch Butte Wind Park Project prior to the Commercial Operation Date.
This timeframe assumes that material can be procured, labor resources are available, and that
outages to the existing system are available to be scheduled.
There is approximately 1.5 miles of the existing 46 kV transmission line which is located on BlM
land. A permit (ROW grant) will be required from the BlM in order to re-build this portion of the line
for the double circuit transmission as well as the 138 kV transmission line switches where the new
138 kV line connects to the eXisting transmission line. Obtaining a ROW grant from the BlM is
never guaranteed and is typically a 20-30 month process at this point in time. This is outside of
Idaho Power's control. If the ROW grant is denied then a new interconnection solution would be
required and this could drastically alter project costs and timeline.
Idaho Power Company
I.P.U.C. No. 29, Tariff No. 101
Agreed to by:
For the Seller:
For the Transmission Provider
Idaho Power Company
Generator Interconnection Agreement # 349/359
Page 3 of 3
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 2
Attachment 4
Additional Operating Requirements for the Company's Transmission System and Affected Systems
Needed to Support the Seller's Needs
The Company shall also provide requirements that must be met by the Seller prior to initiating
parallel operation with the Company's Transmission System.
Operating Requirements
The project is required to comply with the applicable Voltage and Current Distortion Limits found in
IEEE Standard 519-1992 IEEE Recommended Practices and Requirements for Harmonic Control in
Electrical Power Systems or any subsequent standards as they may be updated from time to time.
Seller will be able to modify power plant facilities on the generator side of the Interconnection Point with
no impact upon the operation of the transmission system whenever the generation facilities are
electrically isolated from the transmission system via the A-13 and A-14 switches and a terminal
clearance is issued by Idaho Power Company's Grid Operator.
Generator Output Limit Control (liRe-dispatch" or "GOLC'~ The Project will be subject to
reductions directed by Idaho Power Company Grid Operations during transmission system
contingencies and other reliability events. When these conditions occur, the Project will be subject to
Generator Output Limit Control ("GOlC") and have equipment capable of receiving signals from Idaho
Power for GOlC. Generator Output Limit Control will be a setpoint from Idaho Power to the Project
indicating maximum output allowed. See Attachment 7 for details.
Voltage flicker at startupand during operation wi!! be limited to less than 5% as measured at the
Interconnection Point. It is preferable to bring each generating unit online separately to minimize
voltage flicker on the distribution system.
Low Voltage Ride Through
The Project must be capable of riding through faults on adjacent section of the power system without
tripping due to low voltage. It has been determined, through study, that the Project must be capable of
remaining interconnect for any single phase voltage as low as 0.7 PU for 30 cycles, and for all three
phase voltages as low as 0.8 PU for 30 cycles.
Ground Fault Equipment
The Seller will install transformer configurations that are Grounded-Wye to Grounded-Wye and will limit
the contribution of the ground fault current to 20 amps or less at the Interconnection Point.
Meteorlogical Data
Historical wind data -Within 60 days after execution of this Agreement, the Seller shall provide Idaho
Power with the following:
a) historical wind data in an electronic format from the proposed Facility site or for a location within
two miles of the Facility site.
b) a third party wind assessment study report used by Seller to value investment in the Facility.
No later than 30 days prior to the Commercial Operation Date, the Seller shall have:
a) Erected at the site at least one (1) high quality, approximate hub-height (plus or minus 20
meters), permanent, meteorological wind measurement tower(s) at location(s) on the site equipped
with:
(i)
(ii)
(iii)
(iv)
Two (2) anemometers per tower;
Two (2) air temperature sensors per tower;
One (1) barometric pressure sensor (with DCP sensor); and
Two (2) wind vanes per tower.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 20f2
Facility availability status shall be provided as described in the Final Facility Study no later than within
the calendar month following the month of the Commercial Operation Date. Failure by the Seller to
operate and maintain this equipment to provide such meteorological and turbine availability data in a
manner to provide reasonably accurate and dependable data for the full term of this Agreement shall be
an event of Default under paragraph 6.5.1.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 1
Attachment 5
Reactive Power Requirements
The project must be controlled to operate at unity power factor +1-500 kVar.
Voltage flicker at startup and during operation will be limited to less than 5% as measured at the
Interconnection Point.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 2
Attachment 6
Company's Description of Special Facilities and Upgrades Required to Integrate the Generation Facility
and Best Estimate of Costs
As provided in Schedule 72 this Attachment describes Upgrades, Special Facilities, including
Network Upgrades, and provides an itemized best estimate of the cost of the required facilities.
Upgrades
Upgrades to Substation Facilities
Two new 12.5 kV feeder bays with associated switches, breakers, relays etc at Dietrich substation
A new 138:12.5 kV power transformer and associated equipment at Dietrich substation with protection
package, control building.
Line relay and microwave upgrades at Midpoint substation
DTRC-MPSN microwave reflector site (near Notch Butte)
Upgrades to Distribution Facilities
A new double circuit (DTRC-013 and 014) 12.5 kV distribution line from Dietrich substation to the point
of interconnection (4 miles). This new distribution line will be built with 795 AAC conductor on both
circuits with ADSS underbuild.
Upgrades to Transmission Facilities
Idaho Power will rebuild 4 miles of the existing 46 kV transmission Une (T-128) with a double circuit
transmission line that will accommodate both the existing 46 kV line as well as the new 138 kV line.
The new 138 kV line will then tap into the existing Midpoint-Silver 138 kV line with line switches on all
three sides of the tap.
The following good faith estimates are provided in 2012 dollars:
Interconnection Facilities: ---------... -,.--
_In!~!99~1]~~~i9n __ P~~~_a.ges -<21 IPC
.Di.~~~~I:!'!.tJ.~HJ._IJ.P_g!~,,-e.~~ ___ . _. _ _ _ . ____ .
Distribution Feeders to Dietrich Substation (DTRC-013
~QT_RC:014) ~~!h ADSS li~~r IPC
Su...b!!tatiEn _ypgt~c!e.~:
Dietrich Substation Additions IPC -------_ .. _--
~!c;lP91rt! .R~!a_LuE9.ra..Q~s _.. IPC
~h:tP9ItltJ~~,!i~~()way~ up9I.a..c;I~~. _ IPC
DTRC-MPSON Microwave Reflector Site IPC
Tr~'1~!!!~~!!Lo!, _ypgra_c!es;. _ __
Remove 4 miles of 46 kV line with underbuild IPC
Build 4 miles of line to double circuit IPC
3 -138 kV Line Switches 'IPC
*B~M PermittingjROW Grat:)t IPC
GRAND TOTAL
$440,000
$965,000
,$2,835,000
~65,OOO
$190,09Q _
$325,000
$130,000
$2,550,000
$300,000
.$75,000
$7,875,000
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 2 of 2
*There is approximately 1.5 miles of the existing 46 kV transmission line which is located on BLM land.
A permit will be required from the BLM in order to rebuild this portion of the line to double circuit as well
as install the transmission line switches. The costs for this permitting can vary widely and have been
estimated at a combined $75K.
Note Regarding Transmission Service:
This Facility Study is a Network Resource Interconnection Facility Study. This study identifies the
facilities necessary to integrate the Generating Facility into Idaho Power's network to serve load
within Idaho Power's balancing area. Network Resource Interconnection Service in and of itself
does not convey any right to deliver electricity to any specific customer or Point of Delivery.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29. Tariff No. 101 Page 1 of 2
Attachment 7
Generation Interconnection Control Requirements
Generator Output Limit Control (GOLC)
IPC requires Interconnected Power Producers to accept GOlC signals from our EMS.
The GOlC signals will consist of four points shared between the IPC EMS and the Customer's
Generator Controller:
GOlC Setpoint: An analog output that contains the MW value the Customer should curtail to, should a
GOlC request be made via the GOlC On/Off discrete output Control point.
An Analog Input feedback point must be updated (to reflect the GOlC setpoint value) by the Customer
Controller upon the Controller's receipt of the GOlC setpoint change, with no intentional delay.
GOlC On/Off: A discrete output (DO) control point with latching Off/On states. Following a "GOlC On"
control, the Customer Controller will run power output back to the MW value specified in the GOlC
Setpoint. Following a "GOlC Off' control, the Customer is free to run to maximum possible output.
A Discrete Input feedback point must be updated (to reflect the GOlC DO state) by the Customer
Controller upon the Controller's receipt of the GOlC DO state change, with no intentional delay.
If a GOlC control is issued, it is expected to see MW reductions start within 1 minute and plant output
to be below the GOlC Setpoint value within 10 minutes.
Voltage Control
Idaho Power Company requires Transmission-Interconnected Power Producers to accept Voltage
Control signals from our EMS when they are connected to our transmission system.
The voltage control will consist of one setpoint and one feedback point shared between the IPC EMS
and the Customer Controller.
The setpoint will contain the desired target voltage for the plant to operate at.
The control will always be active, there is no digital supervisory point like the Curtail On/Off control
above.
When a setpoint change is issued an Analog Input feedback point must be updated (to reflect the
Voltage Control setpoint value) by the Customer Controller upon the Controller's receipt of the Voltage
Control setpoint change, with no intentional delay.
When a setpoint change is received by the Customer Controller, the Voltage Control system should
react with no intentional delay.
The voltage control system should operate in a dead band of +/-5% of the control setting range.
The customer should supervise this control by setting up "reasonability limits", i.e. configure a
reasonable range of values for this control to be valid. As an example, they will accept anything
between .95 and 1.05 for the set point. In the case they are fed an erroneous value outside this range,
their control system defaults to the last known, good value.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 2 of 2
Generation Interconnection Data Points Requirements
Digital Inputs to IPCo (DNP Obj. 01, Var. 2)
Index Description State (0/1) Comments:
0 52A Customer Capacitor Breaker (if present) Open/Closed Sourced at substation
1 GOlC Off/On Control Received (Feedback) Off/On Provided by Customer
Digital Outputs to Customer (DNP Obj. 1O, Var.1)
Index Description Comments:
0 GOlC OfflOn Provided b'i IPCO
NOTE: GOlC Setpoint indicates MW value to curtail to when GOlC OfflOn DO is ON.
Analog Inputs to IPCo (DNP Obj. 30, Var. 2)
Raw Raw EU EU
Index Description High low High EU low Units Comments:
GOlC Setpoint Value Received -Provided by
0 (Feedback) 32767 32768 TSD TSD MW Customer
Voltage Control Setpoint Value Rec'd -Provided by
1 (Feedback) 32767 32768 TSD TBD kV Customer
-Provided by
2 Maximum Park Generating Capacity 32767 32768 TSD TBD MW Customer
-Provided by
3 Number of Turbines In High Speed Cutout 32767 32768 32767 -32768 Units Customer
-For Provided by
4 Ambient Temperature 32767 32768 327.67 -327.68 C Customer
-Provided by
5 Wind Direction 32767 32768 3276.7 -3276.8 Deg Customer
MPH
-or Provided by
6 Wind Speed 32767 32768 327.67 -327.68 mls Customer
Analog Outputs to Customer (DNP Obj. 40, Var. 2)
Raw Raw EU EU EU
Index Description High low High low Units Comments:
-
0 GOlC Setpoint 32767 32768 TBD TSD MW Provided by IPCO
-
1 Voltage Control Setpoint 32767 32768 TBD TSD kV Provided by IPCO
. NOTE: Curtailment Setpoint indicates MW value to Curtail to when Curtailment Off/On DO is ON.
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 58
DONOVAN E. WALKER
Lead Counsel
[e-mail]
July 11, 2012
VIA ELECTRONIC & U.S. MAIL
[e-mail]
Joshua Gunderson, Project Engineer
Exergy Development Group
802 West Bannock Street, 12th Floor
Boise, Idaho 83702
Re: Notch Butte Wind Park - G IA #349 & #359
Final GIA and Your Letter Dated July 9,2012
Dear Mr. Gunderson:
An IDACDRP company
In response to your letter dated July 9, 2012, which accompanied the final
Generator Interconnection Agreement ("GIA") that was forwarded to Exergy
Development Group ("Exergy") on June 26, 2012, signed by Exergy, Idaho Power
Company ("Idaho Power") encloses herewith a countersigned copy of the same to you.
Your letter states, "Exergy is pleased to submit the enclosed and executed GIA
and will submit the funds described in the enclosed GIA at such time as Idaho Power
countersigns and returns a copy of the document to our office." Idaho Power has
returned the countersigned GIA, and now expects immediate payment of the required
funds ($7,950,000) that were due no later than July 9, 2012. As you indicated in your
letter, because Idaho Power has now returned the countersigned GIA, Idaho Power
expects the required funding to be paid immediately. Idaho Power needs the required
funding from Exergy in order to proceed .
.
As clearly stated in the GIA itself, "If the Generator Interconnection Agreement is
signed and the project is fund~d before July 9, 2012, then temporary facilities can be
constructed in order to bring the project, at limited output of 4 MW, on line by December
15,2012." In addition, the GIA further provides: .
These milestones will begin, and the construction schedule
referenced below, will only be valid upon receipt of funding in
full from the Seller or their authorized third party no later than
the date set forth below for such payment. Additionally,
1221 W. Idaho St. (S3702)
P.O, Box 70
Boise, 10 83707
Joshua Gunderson, Project Engineer
July 11,2012
Page 2 of 2
failure by Seller to make the required payments as set forth
in this Agreement by the date(s) specified below will be a
material breach of this Agreement, which may result in any
or all of the following: (i) loss of milestone dates and
construction schedules set forth below: (ii) immediate
termination of this Agreement by Idaho Power; (iii) removal
from the generator interconnection queue.
Idaho Power will exercise its rights to terminate this GIA and to remove the
project from the generator interconnection queue if the required payment is not received
by close of business, 5:00 p.m. Mountain Time, on Friday July 13, 2012
Idaho Power acknowledges receipt of Exergy's "Notice of Force Majeure" for
Notch Butte on July 2, 2012. Idaho Power, however, does not agree with Exergy's
contentions in the "Notice of Force Majeure," including, but not limited to, the notice of
force majeure event and allegations of impossibility of performance, claim of force
majeure, and Idaho Power will be responding to the same separately. By
acknowledging receipt of the "Notice of Force Majeure" and executing the enclosed
GIA, Idaho Power hereby does not waive and expressly reserves all rights and
remedies under the Firm Energy Sales Agreement ("FESA") and/or GIA, as well as any
and all rights and remedies otherwise available to Idaho Power, including by statute,
tort, or contract law. Idaho Power hereby specifically reserves, and does not waive, any
and all claims or rights it may have pursuant the FESA, GIA, or otherwise, both in law
and in equity, related to this project.
Idaho Power looks forward to the receipt of the required funding.
DEW:csb
Enclosure: Signed GIA /
cc: James Carkulis, Exergy (w/encl.) -via e-mail v /
Josh Harris, Idaho Power (w/encr.) -via e-mail /
Jason Williams, Idaho Power (w/encr.) -via e-mail
Tess Park, Idaho Power (w/encl.) -via e-mail //
Ed Kosydar, Idaho Power (w/encl.) -via e-mail
Peter Richardson (w/encl.) -via e-mail.l.
Idaho Power Company Generator Interconnection Agreement # 349/359
I,P.u.C. No. 29, Tariff No. 101
June 26,2012
GENERATOR INTERCONNECTION AGREEMENT
Schedule 72
Notch Butte Wind Park PROJECTS #349 & #359
6.5/11.5 MW
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No.1 01
TABLE OF CONTENTS
RECITALS ......................................................................................................................................... ~ ... 1
AGREEMENTS ............................................................................... _ ....................................................... 1
1. Capitalized Terms ................................................................................................................ 1
2. Terms and Conditions .......................................................................................................... 1
3. This Agreement is not an agreement to purchase Seller's power ......................................... 1
4. Attachments ......................................................................................................................... 1
5. Effective Date, Term, Termination and Disconnection .......................................................... 2
5.2 Termination .......................................................................................................................... 2
6. Assignment. Liability, Indemnity. Force majeure, Consequential Damages and Default. ...... 5
7. Insurance ............................................................................................................................. 7
8. Miscellaneous ....................................................................................................................... 7
9. Notices ................................................................................................................................. 8
10. Signatures ............................................................................................................................ 9
Attachment 1 ......................................................................................................................................... 1
Attachment 2 ......................................................................................................................................... 1
Attachment 3 ......................................................................................................................................... 1
Attachment 4 .......................................................................................................................................... 1
Attachment 5 ......................................................................................................................................... 2
Attachment 6 ......................................................................................................................................... 1
Attachment 7 ......................................................................................................................................... 1
Idaho Power Company Generator Interconnection Agreement # 349/359
I,P.u.C. No. 29. Tariff No. 101 Page 1 of 9
This Generator Interconnection Agreement ("Agreement") under Idaho Power Company's
Schedule 72 is effective as of the 26 day of June, 2012 between Exergy Development Group of Idaho,
("Seller", "Customer" or "The Project") and Idaho Power Company ("Company","Transmission Owner",
"Idaho Power", "I PC" or "IPCO").
RECITALS
A. Seller will own or operate a Generation Facility that qualifies for service under Idaho
Power's Commission-approved Schedule 72 and any successor schedule.
B. The Generation Facility covered by this Agreement is more particularly described in
Attachment 1.
AGREEMENTS
1. Capitalized Terms
Capitalized terms used herein shall have the same meanings as defined in Schedule 72 or in the body
of this Agreement.
2. Terms and Conditions
This ·Agreement and Schedule 72 provide the rates, charges, terms and conditions under which the
Seller's Generation Facility will interconnect with, and operate in parallel with, the Company's
transmission/distribution system. Terms defined in Schedule 72 will have the same defined meaning in
this Agreement. If there is any conflict between the terms of this Agreement and Schedule 72,
Schedule 72 shalf prevail.
3. This Agreement is not an agreement to purchase Seller's power.
Purchase of Seller's power and otber services that Seller may require will be covered under separate
agreements. Nothing in this Agreement is intended to affect any other agreement between the
Company and Seller.
4. Attachments
Attached to this Agreement and included by reference are the following:
Attachment 1 -Description and Costs of the Generation Facility, Interconnection
Facilities, and Metering Equipment
Attachment 2 -One-line Diagram Depicting the Generation Facility, Interconnection
Facilities, Metering Equipment and Upgrades.
Attachment 3 -Milestones for Interconnecting the Generation Facility
Attachment 4 -Additional Operating Requirements for the Company's Transmission
System Needed to Support the Seller's Generation Facility
Attachment 5 -Reactive Power
Attachment 6 -Description of Upgrades required to integrate the Generation Facility and
Best Estimate of Upgrade Costs
Attachment 7 -Generator Interconnection Control Requirements
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u.C. No. 29, Tariff No. 101 Page 2 of9
5. Effective Date, Term, Termination and Disconnection.
5.1 Term of Agreement. Unless terminated earlier in accordance with the provisions
of this Agreement, this Agreement shall become effective on the date specified above and remain
effective as long as Seiler's Generation Facility is eligible for service under Schedule 72.
5.2 Termination.
5.2.1 Seller may voluntarily terminate this Agreement upon expiration or
termination of an agreement to sell power to the Company.
5.2.2 After a Default, either Party may terminate this Agreement pursuant to
Section 6.5.
5.2.3 Upon termination or expiration of this Agreement, the Seller's Generation
Facility will be disconnected from the Company's transmission/distribution system. The termination or
expiration of this Agreement shall not relieve either Party of its liabilities and obligations, owed or
continuing at the time of the termination. The provisions of this Section shall survive termination or
expiration of this Agreement.
5.3 Temporarv Disconnection. Temporary disconnection shall continue only for so
long as reasonably necessary under "Good Utility Practice." Good Utility Practice means any of the
practices, methods and acts engaged in or approved by a significant portion of the electric industry
during the relevant time period, or any of the practices, methods and acts which, in the exercise of
reasonable judgment in light of the facts known at the time the decision was made, could have been
expected to accomplish the desired result at a reasonable cost consistent v'Iith good business practices,
reliability, safety and expedition. Good Utility Practice is not intended to be limited to the optimum
practice, method, or act to the exclusion of all others, but rather to be acceptable practices, methods, or
acts generally accepted in the region. Good Utility Practice includes compliance with WECC or NERC
requirements. Payment of lost revenue resulting from temporary disconnection shall be governed by
the power purchase agreement.
5.3.1 Emergencv Conditions. "Emergency Condition" means a condition or
situation: (1) that in the judgment of the Party making the claim is imminently likely to
endanger life or property; or (2) that, in the case of the Company, is imminently likely (as
determined in a non-discriminatory manner) to cause a material adverse effect on the
security of, or damage to the Company's transmission/distribution system, the
Company's Interconnection Facilities or the equipment of the Company's customers; or
(3) that, in the case of the Seller, is imminently likely (as determined in a non­
discriminatory manner) to cause a material adverse effect on the reliability and security
of, or damage to, the Generation Facility or the Seller's Interconnection Facilities. Under
Emergency Conditions, either the Company or the Seller may immediately suspend
interconnection service and temporarily disconnect the Generation Facility. The
Company shall notify the Seller promptly when it becomes aware of an Emergency
Condition that may reasonably be expected to affect the Seller's operation of the
Generation Facility. The Seller shall notify the Company promptly when it becomes
aware of an Emergency Condition that may reasonably be expected to affect the
Company's equipment or service to the Company's customers. To the extent
information is known, the notification shall describe the Emergency Condition, the extent
of the damage or deficiency, the expected effect on the operation of both Parties'
facilities and operations, its anticipated duration, and the necessary corrective action.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29. Tariff No. 101 Page 3 of 9
5.3.2 Routine Maintenance, Construction, and Repair. The Company may
interrupt interconnection service or curtail the output of the Seiler's Generation Facility
and temporarily disconnect the Generation Facility from the Company's
transmission/distribution system when necessary for routine maintenance, construction,
and repairs on the Company's transmission/distribution system. The Company will
make a reasonable attempt to contact the Seller prior to exercising its rights to interrupt
interconnection or curtail deliveries from the Seller's Facility. Seller understands that in
the case of emergency circumstances, real time operations of the electrical system,
and/or unplanned events, the Company may not be able to provide notice to the Seller
prior to interruption, curtailment or reduction of electrical energy deliveries to the
Company. The Company shall use reasonable efforts to coordinate such reduction or
temporary disconnection with the Seller.
5.3.3 Scheduled Maintenance. On or before January 31 of each calendar year;
Seller shall submit a written proposed maintenance schedule of significant Facility
maintenance for that calendar year and the Company and Seller shall mutually agree as
to the acceptability of the proposed schedule. The Parties determination as to the
acceptability of the Seiler's timetable for scheduled maintenance will take into
consideration Good Utility Practices, Idaho Power system requirements and the Seller's
preferred schedule. Neither Party shall unreasonably withhold acceptance of the
proposed maintenance schedule.
5.3.4. Maintenance Coordination. The Seller and the Company shall, to the
extent practical, coordinate their respective transmission/distribution system and
Generation Facility maintenance schedules such that they occur simultaneously. Seller
shall provide and maintain adequate protective equipment sufficient to prevent damage
to the Generation Facility and Seller-furnished Interconnection Facilities. In some cases,
some of Seiler'S protective relays will provide back-up protection for Idaho Power's
facilities. In that event, Idaho Power will test such relays annually and Seller will pay the
actual cost of such annual testing.
5.3.5 Forced Outages. During any forced outage, the Company may suspend
interconnection service to effect immediate repairs on the Company's
transmission/distribution system. The Company shall use reasonable efforts to provide
the Seller with prior notice. If prior notice is not given, the Company shall, upon request,
provide the Seller wn"tten documentation after the fact explaining the circumstances of
the disconnection.
5.3.6 Adverse Operating Effects. The Company shall notify the Seller as soon
as practicable if, based on Good Utility Practice, operation of the Seller'S Generation
Facility may cause disruption or deterioration of service to other customers served from
the same electric system, or if operating the Generation Facility could cause damage to
the Company's transmission/distribution system or other affected systems. Supporting
documentation used to reach the decision to disconnect shall be provided to the Seller
upon request. If, after notice, the Seller fails to remedy the adverse operating effect
within a reasonable time, the Company may disconnect the Generation Facility. The
Company shall provide the Seller with reasonable notice of such disconnection, unless
the provisions of Article 5.3.1 apply.
5.3.7 Modification of the Generation Facility The Seller must receive written
authorization from the Company before making any change to the Generation Facility
that may have a material impact on the safety or reliability of the Company's
transmission/distribution system. Such authorization shall not be unreasonably withheld.
Idaho Power Company Geneiatoi Inteiconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 4 of 9
Modifications shall be done in accordance with Good Utility Practice. If the Seller makes
such modification without the Company's prior written authorization, the latter shall have
the right to temporarily disconnect the Generation Facility.
5.3.8 Reconnection. The Parties shall cooperate with each other to restore the
Generation Facility, Interconnection Facilities, and the Company's
transmission/distribution system to their normal operating state as soon as reasonably
practicable fol/owing a temporary disconnection.
5.3.9 Voltage Levels. Seller, in accordance with Good Utility Practices, shall
minimize voltage fluctuations and maintain voltage levels acceptable to Idaho Power.
Idaho Power may, in accordance with Good Utility Practices, upon one hundred eighty
(180) days' notice to the Sel/er, change its nominal operating voltage level by more than
ten percent (10%) at the Point of Delivery, in which case Seller shall modify, at Idaho
Power's expense, Seller's equipment as necessary to accommodate the modified
nominal operating voltage level.
5.4 Land Rights.
5.4.1 Seller to Provide Access. Seller hereby grants to Idaho Power for the
term of this Agreement all necessary rights-of-way and easements to install, operate,
maintain, replace, and remove Idaho Power's Metering Equipment, Interconnection
Equipment, Disconnection Equipment, Protection Equipment and other Special Facilities
necessary or useful to this Agreement, including adequate and continuing access rights
on property of Seller. Seller warrants that it has procured sufficient easements and
rights-of-way from third parties so as to provide Idaho Power with the access described
above. All documents granting suc,'1 easements or rights-of-way shall be subject to
Idaho Power's approval and in recordable form.
5.4.2 Use of Public Rights-of-Wav. The Parties agree that it is necessary to
avoid the adverse environmental and operating impacts that would occur as a result of
duplicate electric lines being constructed in close proximity. Therefore, subject to Idaho
Power's compliance with Paragraph 5.4.4, Seller agrees that should Seller seek and
receive from any local, state or federal governmental body the right to erect, construct
and maintain Seller-furnished Interconnection Facilities upon, along and over any and all
public roads, streets and highways, then the use by Seller of such public right-of-way
shall be subordinate to any future use by Idaho Power of such public right-of-way for
construction andlor maintenance of electric distribution and transmission facilities and
Idaho Power may claim use of such public right-of-way for such purposes at any time.
Except as required by Paragraph 5.4.4, Idaho Power shall not be required to
compensate Seller for exercising its rights under this Paragraph 5.4.2.
5.4.3 Joint Use of Facilities. SubJect to Idaho Power's compliance with
Paragraph 15.4.4, Idaho Power may use and attach its distribution and/or transmission
facilities to Seller's Interconnection Facilities, may reconstruct Seller'S Interconnection
Facilities to accommodate Idaho Power's usage or Idaho Power may construct its own
distribution or transmission facilities along, over and above any public right-of-way
acquired from Seller pursuant to Paragraph 5.4.2, attaching Seller's Interconnection
Facilities to such newly constructed facilities. Except as required by Paragraph 5.4.4,
Idaho Power shall not be required to compensate Seller for exercising its rights under
this Paragraph 5.4.3.
5.4.4 Conditions of Use. It is the intention of the Parties that the Seller be left in
substantially the same condition, both financially and electrically, as Seller existed prior
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u.C. No. 29. Tariff No. 101 Page 5 of9
to Idaho Powers exercising its rights under this Paragraph 5.4. Therefore, the Parties
agree that the exercise by Idaho Power of any of the rights enumerated in Paragraphs
5.4.2 and 5.4.3 shall: (1) comply with all applicable laws, codes and Good Utility
Practices, (2) equitably share the costs of installing, owning and operating jointly used
facilities and rights-of-way. If the Parties are unable to agree on the method of
apportioning these costs, the dispute will be submitted to the Commission for resolution
and the decision of the Commission will be binding on the Parties, and (3) shall provide
Seller with an interconnection to Idaho Powers system of equal capacity and durability
as existed prior to Idaho Power exercising its rights under this Paragraph 5.4.
6. Assiqnment. Liability, Indemnity, Force majeure. Consequential Damages and Default.
6. 1 Assignment. This Agreement may be assigned by either Party upon twenty-one
(21) calendar days prior written notice and opportunity to object by the other Party; provided
that:
6.1.1 Either Party may assign this Agreement without the consent of the other
Party to any affiliate of the assigning Party with an equal or greater credit rating and with
the legal authority and operational ability to satisfy the obligations of the assigning Party
under this Agreement.
6.1.2 The Seller shall have the right to contingently assign this Agreement,
without the consent of the Company, for collateral security purposes to aid in providing
financing for the Generation Facility, provided that the Seller will promptly notify the
Company of any such contingent assignment.
6.1.3 Any attempted assignment that violates this article is void and ineffective.
Assignment shall not relieve a Party of its obligations, nor shall a Party's obligations be
enlarged, in whole or in part, by reason thereof. An assignee is responsible for meeting
the same financial, credit, and insurance obligations as the Seller. Where required,
consent to assignment will not be unreasonably withheld, conditioned or delayed.
6.2 Lim;tation of Uabilitv. Each Party's liabNlty to the other Party for any loss, cost
claim, injury, liability, or expense, including reasonable attorney's fees, relating to or arising from
any act or omission in its performance of this Agreement, shall be limited to the amount of direct
damage actually incurred. In no event shall either Party be liable to the other Party for any
indirect, special, consequential, or punitive damages, except as authorized by this Agreement.
6.3 Indemnity.
6.3. 1 This provision protects each Party from liability incurred to third parties as
a result of carrying out the provisions of this Agreement. Liability under this provision is
exempt from the general limitations on liability found in Article 6.2.
6.3.2 The Parties shall at all times indemnify, defend, and hold the other Party
harmless from, any and all damages, losses, claims, including claims and actions
relating to injury to or death of any person or damage to property, demand, suits,
recoveries, costs and expenses, court costs, attorney fees, and all other obligations by
or to third parties, arising out of or resulting from the other Party's action or failure to
meet its obligations under this Agreement on behalf of the indemnifying Party, except in
cases of gross negligence or intentional wrongdoing by the indemnified Party.
6.3.3 If an indemnified person is entitled to indemnification under this article as
a result of a claim by a third party, and the indemnifying Party fails, after notice and
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 6 of 9
reasonable opportunity to proceed under this article, to assume the defense of such
claim, such indemnified person may at the expense of the indemnifying Party contest,
settle or consent to the entry of any judgment with respect to, or pay in full, such claim.
Failure to defend is a Material Breach.
6.3.4 If an indemnifying party is obligated to indemnify and hold any
indemnified person harmless under this article, the amount owing to the indemnified
person shall be the amount of such indemnified person's actual loss, net of any
insurance or other recovery.
6.3.5 Promptly after receipt by an indemnified person of any claim or notice of
the commencement of any action or administrative or legal proceeding or investigation
as to which the indemnity provided for in this article may apply, the indemnified person
shall notify the indemnifying party of such fact. Any failure of or delay in such notification
shall be a Material Breach and shall not affect a Party's indemnification obligation unless
such failure or delay is materially prejudicial to the indemnifying party.
6.4 Force Majeure. As used in this Agreement, "Force Majeure" or "an event of
Force Majeure" means any cause beyond the control of the Seller or of the Company which,
despite the exercise of due diligence, such Party is unable to prevent or overcome. Force
Majeure includes, but is not limited to, acts of God, fire, flood, storms, wars, hostilities, civil
strife, strikes and other labor disturbances, earthquakes, fires, lightning, epidemics, sabotage, or
changes in law or regulation occurring after the Operation Date, which, by the exercise of
reasonable foresight such party could not reasonably have been expected to avoid and by the
exercise of due diligence, it shall be unable to overcome. If either Party is rendered wholly or in
part unable to perform its obligations under this Agreement because of an event of Force
Majeure, both Parties shall be excused from whatever performance is affected by the event of
Force Majeure, provided that:
(1) The non-performing Party shall, as soon as is reasonably possible after
the occurrence of the Force Majeure, give the other Party written notice describing the
particulars of the occurrence.
(2) The suspension of performance shall be of no greater scope and of no
longer duration than is required by the event of Force Majeure.
(3) No obligations of either Party which arose before the occurrence causing
the suspension of performance and which could and should have been fully performed
before such occurrence shall be excused as a result of such occurrence.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 7 of9
6.5 Default and Material Breaches.
6.5. 1 Defaults. If either Party fails to perform any of the terms or conditions of
this Agreement (a "Default" or an "Event of Default'J, the nondefaulting Party shall cause
notice in writing to be given to the defaulting Party, specifying the manner in which such
default occurred. If the defaulting Party shall fail to cure such Default within the sixty
(60) days after service of such notice, or if the defaulting Party reasonably demonstrates
to the other Party that the Default can be cured within a commercially reasonable time
but not within such sixty (60) day period and then fails to diligently pursue such cure,
then, the nondefaulting Party may, at its option, terminate this Agreement and/or pursue
its legal or equitable remedies.
6.5.2 Material Breaches. The notice and cure proVisions in Paragraph 6.6.1 do
not apply to Defaults identified in this Agreement as Material Breaches. Material
Breaches must be cured as expeditiously as possible following occurrence of the
breach.
7. Insurance.
During the term of this Agreement, Seller shall secure and continuously carry the following
insurance coverage:
7.1 Comprehensive General Liability Insurance for both bodily injury and property
damage with limits equal to $1,000,000, each occurrence, combined single limit. The deductible
for such insurance shall be consistent with current Insurance Industry Utility practices for similar
property.
7.2 The above insurance coverage shall be placed with an insurance company with
an A.M. Best Company rating of A-or better and shall include:
(a) An endorsement naming Idaho Power as an additional insured and loss
payee as applicable; and
(b) A provision stating that such policy shall not be canceled or the limits of
liability reduced without sixty (60) days' prior written notice to Idaho Power.
7.3 Seller to Provide Cerlificate of Insurance. As required in Paragraph 7 herein and
annually thereafter, Seller shall fumish the Company a certificate of insurance, together with the
endorsements required therein, evidencing the coverage as set forth above.
7.4 Seller to Notify Idaho Power of Loss of Coverage -If the insurance coverage
required by Paragraph 7.1 shall lapse for any reason, Seller will immediately notify Idaho Power
in writing. The notice will advise Idaho Power of the specific reason for the lapse and the steps
Seller is taking to reinstate the coverage. Failure to provide this notice and to expeditiously
reinstate or replace the coverage will constitute grounds for a temporary disconnection under
Section 5.3 and will be a Material Breach.
8. Miscellaneous.
8.1 Goveming Law. The validity, interpretation and enforcement of this Agreement
and each of its provisions shall be governed by the laws of the state of Idaho without regard to
its conflicts of law principles.
8.2 Salvage. No later than sixty (60) days after the termination or expiration of this
Agreement, Idaho Power will prepare and forward to Seller an estimate of the remaining value
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u.C. No. 29, Tariff No. 101 Page B of9
of those Idaho Power furnished Interconnection Facilities as required under Schedule 72 andlor
described in this Agreement, less the cost of removal and transfer to Idaho Powers nearest
warehouse, if the Interconnection Facilities will be removed. If Seller elects not to obtain
ownership of the Interconnection Facilities but instead wishes that Idaho Power reimburse the
Seller for said Facilities the Seller may invoice Idaho Power for the net salvage value as
estimated by Idaho Power and Idaho Power shall pay such amount to Seller within thirty (30)
days after receipt of the invoice. Seller shall have the right to offset the invoice amount against
any present or future payments due Idaho Power.
9. Notices.
9.1 General. Unless otherwise provided in this Agreement, any written notice,
demand, or request required or authorized in connection with this Agreement ("Notice") shall be
deemed properly given if delivered in person, delivered by recognized national currier service,
or sent by first class mail, postage prepaid, to the person specified below:
If to the Seller:
Seller: Eurgy btjvelopp:tent Group of Idaho, LLC
Attention: Elizabeth Woolstenhulme
Address: 802 West Bannock, 12th F loor
City: Boise, State: IdahQ Zip: ...::8=37.:....;0=2:.....-__ _
Phone: 2Q&-3~6:-9793 Fax: [phone]
If to the Company:
Idaho Pov.;er Company -Delivery
Attention: Operations Manager
1221 W. Idaho Street
Boise: Idaho 83702
Phone: [phone] Fax: [phone]
9.2
out below:
Billing and Payment. Billings and payments shall be sent to the addresses set
Seller: Exergy Development Group ofIdaho, LLC
Attention, EliiabethWQOlst4:$1ilme .
Addres~:802 Wfi:StBannock.12fuFloor .
City: Boise State: Idaho Zip: ""8«..37,.,0 .... .2'--__ _
Phone: 208-336"9793 Fax: 20R-336-9431 ;;..;;...:;....;.:;-=------
Idaho Power Company -Delivery
Attention: Corporate Cashier
PO Box 447
Salt Lake City Utah 84110-0447
Phone: [phone] email: [e-mail]
9.3 Designated Operating Representative. The Parties may also designate
operating representatives to conduct the communications which may be necessary or
convenient for the administration of this Agreement. This person will also serve as the point of
contact with respect to operations and maintenance of the Party's facilities.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29. Tariff No. 101
Seller's Operating Representative:
Seller: ~~ D,eveIQp-lllent GJ;oup ofIdaho. LLC
Attention: ElizabeTh_ W oolstenhulme
Address: 802-West Bannock., 12th Floor
City: Boise State:ldaho Zip: :;:.,83::..:7=02:::.-__ _
Phone: [phone] Fax: ::.:20:..=8~-3;.;:.3=-6-..:;..94~3:..::1 ___ _
Company's Operating Representative:
Idaho Power Company -Delivery
Attention: Outage Coordinator -System/Regional Dispatch
1221 W. Idaho Street
Boise, Idaho 83702
Over 138kV phone [phone] during regular business hours
Page 9 of 9
Under 138kV Phone: [phone], or 388-5175 during regular business hours
After hours -System Dispatch 388 2826
Regional Dispatch
Southern Region 208-388-5190
9.5 Changes to the Notice Information. Either Party may change this information by
giving five (5) Business Days written notice prior to the effective date of the change.
10. Signatures.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their
respective duly authorized representatives.
For the Seller ,
Name:»~ z~
,,/' " :::.-----------
Title: Man~ging Member
Date: July 9, 2012
For t,l;Je compafl D ~
Name: (jJ',', )i). (l Ll. C5'(D\A )
! :Z;r 7-t"'ss 'e"",...!< Title: D -ctor, Load Serving Operations -Idaho Power Company
?-t(-( A Date: __________ _
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 3
Attachment 1
Description and Costs of the Generation Facility, Interconnection FaciHties and Metering Equipment
Interconnection Details
Type of Interconnection Service: Studied as an Idaho Power Network Resource under PURPA
Full Output: 18 MW (both projects)
Nominal Delivery Voltage: 12.5 kV
General Facility Description
The Notch Butte Wind Park project includes both Projects #349 and #359 for a total of 18 MW of power
provided by seven 2.5Mw Nordex Turbines. The Interconnection Customer (IC) will provide all
generation and station equipment required to deliver power at 12.5 kV to the Point of Interconnection
(POI) which is located at the coordinates North 42" 53.12948' West 114" 10.57'. The Seller will provide
two POTS lines and two DDS circuits to the POls (one pair for each feeder connection) for
communication. Two 12.5 kV feeders will run from the POI four miles west to the IPCo Dietrich
SUbstation where the station will be expanded to accommodate the two new feeders. The power will be
converted to 138 kV via a 12.5 kV to 138 kV power circuit transformer. A new double circuit
transmission line, consisting of a new 138 kV line and the existing 46 kV line, will run four miles due
north out of the Dietrich substation. The new 138 kV line will connect to the existing Midpoint-Silver
138 kV line.
Interconnection Point
The Interconnection Point for the Notch Butte Wind Park Project will be the generator side of the
disconnect switches labeled Disconnect Switches A-13 and A-14 (one for each feeder) as shown on the
attached Single Line drawings 210-64299, sheets 1 & 2. This interconnection Point is in Lincoin
County, 10 -T6S, R19E, SW corner of Section 22.
A drawing identifying the Point of Interconnection is included as Attachment 2. The Point of Change of
Ownership is electrically the same as the Interconnection Point.
Seller's Interconnection Facilities
The Seller will install all generation and station equipment required to deliver power at 12.5 kV to the
interconnection point. Transmitting 18 MW of power at 12.5 kV requires two distribution feeders. The
Seller shall balance the generation between these two fe~der connections with no more than 11 MW of
power flowing on either feeder. The Seller will own and maintain facilities electrically located on the
Interconnection Customer side of the Point of Change of Ownership. Idaho Power will own and
maintain the facilities electrically located on the IPCo side of the Point of Change of Ownership.
The Seller will install equipment to receive signals from Idaho Power Company Grid Operations for
Generator Output Limit Control ("GOlC") -see Attachment 4 Operating Requirements.
The Seller will provide phone service to IPCo's generator interconnect package as described in
Telecommunications below.
The Seller will provide a DNP 3.0 serial data connection to the local Idaho Power Company SCADA
RTU when any communication with Seller-owned and maintained equipment is required for GOlC,
voltage control or other plant monitoring or control. Preliminary points lists and functional description
were provided to the Seller in the Facility Study Report.
All interconnection equipment electrically located on the generator side of the Point of Change
Ownership shall be owned and maintained by the Seller.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u .c. No. 29. Tariff No. 101 Page 2 of 3
Other Facilities Provided by Seller
In addition to communication circuits that may be needed by the Seller, the Seller shall provide the
following communication circuits for Idaho Power's use:
Two POTS (Plain Old Telephone Service) dial-up circuit for querying the revenue meter at the
generation interconnection site. One for each 4-pole feeder connection.
Two leased DDS (Digital Data Service) circuit for SCADA between the generation interconnection site
and Twin Falls Service Building (273 Blue Lakes Blvd. S., Twin Falls, 1083301). One for each 4-pole
feeder connection. These circuits must operate at 19.2 kbps data rate. Please note that Frame Relay
service is not acceptable.
The Interconnection Customer/communications provider shall provide a demarcation box and terminate
the specified communications circuits at the demarcation box. The location of the demarcation box will
be determined by Idaho Power. The demarcation box shall meet the following requirements:
• Be accessible by both the communications provider and Idaho Power
• The location shall be near Idaho Power's equipment and shall be subject to approval by
Idaho Power
• The communications cable pairs shall be labeled/tagged accordingly (Le. circuit number,
phone number, transmit, receive, etc.)
The Seller is required to coordinate with a communications provider to provide the communications
circuits and pay the associated one time setup and periodic charges. The communication circuits will
need to be installed and operational prior to generating into the Idaho Power system. Note that
installation by communications provider may take several months and should be ordered in advance to
avoid delaying the project. If the communication circuit types listed above are not available at the site
by a communications provider, the Seller shall confer with Idaho Power.
If high voltage protection is required by the communications provider for the incoming communications
provider cable, the high voltage protection assembly shall be engineered and supplied by the Seller.
Options are available for indoor or outdoor mounting. The high voltage protection assembly shall be
located in a manner that provides Idaho Power 24-hour access to the assembly for trouble-shooting of
Idaho Power owned equipment.
Ground Fault Equipment
The Seller will install transformer configurations that are Grounded-WYE to Grounded-WYE and will
limit the contribution of the ground fault current to 20 amps or less at the Interconnection Point.
Monitoring Information
If the Seller requires the ability to monitor information related to the Idaho Power reclosers in the
generation interconnection package they are required to supply their own communications circuit to the
control box.
Easements
The Seller will provide to IPCO a surveyed (Metes & Bounds) legal description along with exhibit map
for IPCO's facilities at the Interconnection Point. After the legal description has been delivered to IPCO
for review, IPCO will supply to the Interconnection Customer a completed IPCO easement for signature
by the land owner of record. Once the signatures have been secured, the Seller will return the signed
easement to IPCO for recording.
Generator Output Limit Control
The Seller will install equipment to receive signals from Idaho Power Grid Operations for Generation
Output Limit Control ("GOlC") -see Attachment 4 Operating Requirements.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 3 of 3
Local Service
The Seller is responsible to arrange for local service to their site, as necessary.
Idaho Power Company's Interconnection Facilities
Idaho Power will install two standard generation interconnection packages, one for each feeder. For
each package, if the Seller is going underground to the Interconnection Point, Idaho Power will include
a pole riser for the Generator to install cables to interconnect to the Idaho Power system. If the Seller is
going overhead to the Interconnection Point, it will be at a tension not to exceed the design tension
specified by Idaho Power.
The new interconnection packages each will include four distribution poles to mount a local service
transformer, solid blade disconnects, primary metering package, recloser, relays, RTU, fuses and riser
necessary for the package. The interconnection will be controlled by a SEL-311 C line protection relay
and a GE iBox RTU. The relay and RTU will be located in a pole mounted enclosure and will also
contain a test switch (TS4) , SLSS, dialup modem, DDS CSU/DSU, isolation interface, power supply,
DC converter, control switch and surge protector.
Concrete barriers may be necessary to protect this equipment from local area traffic.
A 2" conduit will be installed alongside the underground primary to facilitate information exchange to the
customer about the recloser. (The Interconnection Customer is responsible for providing and installing
the appropriate cable.)
See single line drawing as Attachment 2.
All interconnection equipment electrically located on the utility side of the Interconnection Point shall be
owned, operated, and maintained by Idaho Power.
Maintenance Coordination Exception
The Seller's protective relays will not provide back-up protection for Idaho Power facilities, therefore the
last 2 sentences in Section 5.3.4 of this Generator Interconnection Agreement do not apply to this
Generation Facility.
Estimated Cost & Ownership
The following good faith estimates are provided in 2011 dollars:
Interconnection Facilities:
!Dt~rconnection P,!ck~~~_L~
SUBTOTAL
See Attachment 6 for Total Estimate Costs ---.--
IPC $440 ,OOQ _
$440,,900
Full payment is required up front in accordance with Schedule 72, unless payment arrangements are
made in advance with Idaho Power Operations Finance (see Attachment 3).
Billing for construction activities will be based upon actual expenditures.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29. Tariff No. 101 Page 1 of 3
Attachment 2
One-line Diagram Depicting the Small Generation Facility, Interconnection Facilities, Metering
Equipment and Upgrades
~ ,
ID I
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No.1 01 Page 2 of 3
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Idaho Power Company Generator Interconnection Agreement # 349/359
I,P.u.C. No. 29, Tariff No. 101 Page 3 of 3
~~~~~~-~I·~lr~'·q;J T
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Idaho Power Company Generator Interconnection Agreement # 349/359
I,P.U.C. No. 29. Tariff No. 101 Page 1 of 3
Attachment 3
Milestones for Interconnecting to the Generation Facility
Idaho Power Company agrees only to the Construction timelines under its direct control provided in the
Facility Study Report for this Project.
These milestones will begin, and the construction schedule referenced below, will only be valid upon
receipt of funding in full from the Seller or their authorized third party no later than the date set forth
below for such payment. Additionally, failure by Seller to make the required payments as set forth in
this Agreement by the date(s) specified below will be a material breach of this Agreement, which may
result in any or all of the following: (i) loss of milestone dates and construction schedules set forth
below: (ii) immediate termination of this Agreement by Idaho Power; (iii) removal from the generator
interconnection queue.
Limited Generation Output
In response to the Seller's request to come on line by December 15, 2012 with a limited generation
output, IPC conducted additional power flow models. It was determined that acceptable voltage on the
46 kV system could be maintained with 4.0 MW of generation from Notch Butte Wind Park if the
generators have the ability to absorb 3.0 MVAr. The installation of a 46 kV potential transformer
transferltrip package would have to be added to the scopelcosts of the work at Dietrich SUbstation. The
Seller will be responsible for absorbing the VArs (3.0 maximum) necessary to maintain a 1.075 p.u.
maximum 46 kV bus voltage at Dietrich substation. A voltage level above 1.075 p.u. will cause the
generator to be tripped offline.
Idaho Power will provide the magnitude of the 46kV bus voltage at Dietrich station to the customer's
control system. The voltage value will be made available to the seller's control system via the
measurement device at Dietrich (e.g. meter or relay) and a direct, serial connection via the new feeder
ADSS fiber optics. Data protocol and point formatting to be determined.
The estimated cost of this additional work is $75,000. This brings the total estimated project cost to
$7,950,000. If the Generator Interconnection Agreement is signed and the project is funded before
July 9. 2012, then temporary facilities can be constructed in order to bring project, at limited output of 4
MW, on line by December 15, 2012.
Critical milestones and responsibility as agreed to by the Parties under limited ouput:
7/9/2012 ,Seller IPCO receives the remaining balance of Construction
,estimate $7,950,000 OR Credit arrangements are approved
_by IP~O ____ _ ..
12/1/2012 Seller Customer GOLC ready to connect & customer telecomm
_____________________________________ req'!!'-~'!!en..t~_~~_ ~C?mplete __ _
12/15/2012 IPCO IPCO Construction Complete
12/15/2012
12/15/2012
12/15/2012
12/15/2012 -12/31/2012
-----~--}PCO
IPCO
lPCO
Seller
IPCO Commissioning Complete -_.--
Project Leader issues Construction Complete Letter ---------------.~--~ ..
Manager of Grid Operations authorizes project to be
energized, upon verification that Seller has previously met
_ §chedu!e ]2, §.e_c ! Ins,,'!r:C!n9f! r~ql!j'--f!ITI~nt~
Customer testing begins
Seller Customer's requested In-Service Date
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 2 of 3
NOTE REGARDING LIMITED OUTPUT MILESTONES:
* Seller has requested an in-service date of 12/15/2012. Idaho Power will use reasonable efforts to
have commissioning complete by this time if funding for project is received by July 9, 2012. This
date is contingent upon all materials being delivered in a timely manner, as well as other factors,
some of which are described above. The parties hereby acknowledge that Idaho Power shall not be
liable to for any possible damages associated in any way with Renewable Energy Credits or
Attributes, tax credits, the firm energy sales agreements, and the like, attributable to Customer, or
any of the various projects named on page one of this GIA, should the 12/15/2012 date not be met.
Under normal efforts to bring the projects online a normal amount of overtime is utilized. Because of
the Seller's desire to meet an IPC commissioning prior to 12/15/2012, Seller hereby authorizes IPC
to incur additional expenses, including additional overtime, lodging, travel, and other expenses
needed to bring in other IPC resources and personnel from other IPC regions, or to utilize third party
contractors, as necessary to work on this interconnection.
Critical milestones and responsibility as agreed to by the Parties under full output:
'7/912012 :Seller "PCO receives the remaining balance of Construction
estimate $7,875, 000 OR Credit arrangements are approved
b IPCO ---------------
:4/15/2015 :Seller Customer GOLC ready to connect & customer telecomm
____ • __ . _____ •.•. ' ._._I __ . ____ ...r.e..q'!.!ri!f!!ent~C}re.. ~91T!E.L~!...~_. _ ___ ... __
5/1/2015 lPCO IPCO Construction Complete -----. __ ._--------.----~------------._-
5/15/2015 /PCO IPCO Commissioning Complete
5/15/2015 JPCO Project Leader issues Construction Complete Letter -----.-----_. ----------
5/15/2015 1PCO Manager of Grid Operations authorizes project to be
-
energized, upon verification that Seller has previously met
____ §.chedule 72, Seq,J..J.nsuraJ!ce re uire~ts __ .
5/15/2015 Seller Customer testing begins
7/20/2015 ,Seller Customer's requested In-Service Date ------------
Idaho Power requires approximately thirty-four (34) months to complete design, procurement,
construction, permitting, and commissioning of the necessary interconnection facilities and required
upgrades associated with the Notch Butte Wind Park Project prior to the Commercial Operation Date.
This timeframe assumes that material can be procured, labor resources are available, and that
outages to the existing system are available to be scheduled.
There is approximately 1.5 miles of the existing 46 kV transmission line which is located on BLM
land. A permit (ROW grant) will be required from the BLM in order to re-build this portion ofthe line
for the double circuit transmission as well as the 138 kV transmission line switches where the new
138 kV line connects to the existing transmission line. Obtaining a ROW grant from the BLM is
never guaranteed and is typically a 20-30 month process at this point in time. This is outside of
Idaho Power's control. If the ROW grant is denied then a new interconnection solution would be
required and this could drastically alter project costs and timeline.
Idaho Power Company
I,P.U.C. No. 29, Tariff No. 101
Agreed to by:
For the Seller:
For the Transmission Provider
Idaho 'Power Company
Generator Interconnection Agreement # 349/359
Page 3 of 3
/ __ ~ ~ 0 Date July 9, 2012
1AcirA~ Date 7-1/ -r ~
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u.C. No. 29, Tariff No. 101 Page 1 of 2
Attachment 4
Additional Operating Requirements for the Company's Transmission System and Affected Systems
Needed to Support the Seller's Needs
The Company shall also provide requirements that must be met by the Seller prior to initiating
parallel operation with the Company's Transmission System.
Operating Requirements
The project is required to comply with the applicable Voltage and Current Distortion Limits found in
IEEE Standard 519-1992 IEEE Recommended Practices and Requirements for Hannonic Control in
Electrical Power Systems or any subsequent standards as they may be updated from time to time.
Seller will be able to modify power plant facilities on the generator side of the Interconnection Point with
no impact upon the operation ofthe transmission system whenever the generation facilities are
electrically isolated from the transmission system via the A-13 and A-14 switches and a terminal
clearance is issued by Idaho Power Company's Grid Operator.
Generator Output Limit Control ("R~dispatch" or "GOLC") The Project will be subject to
reductions directed by Idaho Power Company Grid Operations during transmission system
contingencies and other reliability events. When these conditions occur, the Project will be subject to
Generator Output Limit Control ("GOlC") and have eqUipment capable of receiving signals from Idaho
Power for GOlC. Generator Output Limit Control will be a setpoint from Idaho Power to the Project
indicating maximum output allowed. See Attachment 7 for details.
Voltage flicker at startupand during operation wi!! be limited to less than 5% as measured at the
Interconnection Point. It is preferable to bring each generating unit online separately to minimize
voltage flicker on the distribution system.
Low Voltage Ride Through
The Project must be capable of riding through faults on adjacent section of the power system without
tripping due to low voltage. It has been determined, through study, that the Project must be capable of
remaining interconnect for any single phase voltage as low as 0.7 PU for 30 cycles, and for all three
phase voltages as low as 0.8 PU for 30 cycles.
Ground Fault Equipment
The Seller will install transformer configurations that are Grounded-Wye to Grounded-Wye and will limit
the contribution of the ground fault current to 20 amps or less at the Interconnection Point.
Meteorlogical Data
Historical wind data -Within 60 days after execution of this Agreement, the Seller shall provide Idaho
Power with the following:
a) historical wind data in an electronic format from the proposed Facility site or for a location within
two miles of the Facility site.
b) a third party wind assessment study report used by Seller to value investment in the Facility.
No later than 30 days prior to the Commercial Operation Date. the Seller shall have:
a) Erected at the site at least one (1) high quality, approximate hub-height (plus or minus 20
meters), permanent, meteorological wind measurement tower(s) at location(s) on the site equipped
with:
(i)
(ii)
(iii)
(iv)
Two (2) anemometers per tower;
Two (2) air temperature sensors per tower;
One (1) barometric pressure sensor (with DCP sensor); and
Two (2) wind vanes per tower.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29. Tariff No. 101 Page 2 of 2
Facility availability status shall be provided as described in the Final Facility Study no later than within
the calendar month following the month of the Commercial Operation Date. Failure by the Seller to
operate and maintain this equipment to provide such meteorological and turbine availability data in a
manner to provide reasonably accurate and dependable data for the full term of this Agreement shall be
an event of Default under paragraph 6.5.1.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No.1 01 Page 1 of 1
Attachment 5
Reactive Power Requirements
The project must be controlled to operate at unity power factor +/-500 kVar.
Voltage flicker at startup and during operation will be limited to less than 5% as measured at the
Interconnection Point.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u.c. No. 29, Tariff No. 101 Page 1 of 2
Attachment 6
Company's Description of Special Facilities and Upgrades Required to Integrate the Generation Facilitv
and Best Estimate of Costs
As provided in Schedule 72 this Attachment describes Upgrades, Special Facilities, including
Network Upgrades, and provides an itemized best estimate of the cost of the required facilities.
Upgrades
Upgrades to Substation Facilities
Two new 12.5 kV feeder bays with associated switches, breakers, relays etc at Dietrich SUbstation r A new 138: 12.5 kV power transformer and associated equipment at Dietrich substation with protection
package, control building.
Line relay and microwave upgrades at Midpoint SUbstation
DTRC-MPSN microwave reflector site (near Notch Butte)
Upgrades to Distribution Facilities
A new double circuit (DTRC-013 and 014) 12.5 kV distribution line from Dietrich substation to the point
of interconnection (4 miles). This new distribution line will be built with 795 Me conductor on both
circuits with ADSS underbuild.
Upgrades to Transmission Facilities
Idaho Power will rebuild 4 miles of the existing 46 kV transmission line (T -128) with a double circuit
transmission line that will accommodate both the existing 46 kV line as well as the new 138 kV line.
The new 138 kV line will then tap into the existing Midpoint-Silver 138 kV line with line switches on all
three sides of the tap.
The following good faith estimates are provided in 2012 dollars:
Interconnection Facilities: . -----.----. --.--. ---.
l_n!~J:c:2nrl~~tiQIl P~~~Clfl~~_@) ._ _ _ _ IPC
Distribution Upgrades: _ __ _ _._ __ _ ___ _
Distribution Feeders to Dietrich Substation (DTRC-013
_~ _q-r:~_9-Q1~1 ~!th ~QSS m~~~ _ _ ___ _
Dietrich Substation Additions -------------------
Mic!P..91n.! Rela'y ~grades ___ . _ _ _ _ __
Mi~~!:Il fII1icro~~y~ ~grades ___ ._
DTRC-MPSON Microwave Reflector Site
Transmission Jle!1ra..d~.;. __ _ _ __
Remove 4 miles of 46 kV line with underbuild
Build 4 miles of line to double circuit
3 -138 kV Line Switches ---_ ..
*I?.LM Pe~mitting/!3qW GranJ
GRAND TOTAL
IPC
IPC
IPC
IPC
IPC
IPC
IPC
IPC
IPC
~440,000
$96?,gOQ
§~L~~~!QO.9
_ __ ~~5.!0_OQ _
_ _ l1~0,QOO _
$325,000
$130,000
$2,550,000
$300,000 _.
$75,000
$7,875,000
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.u .C. No. 29, Tariff No. 101 Page 2 of 2
*There is approximately 1.5 miles of the existing 46 kV transmission line which is located on BLM land.
A permit will be required from the BLM in order to rebuild this portion of the line to double circuit as well
as install the transmission line switches. The costs for this permitting can vary widely and have been
estimated at a combined $75K.
Note Regarding Transmission Service:
This Facility Study is a Network Resource Interconnection Facility Study. This study identifies the
facilities necessary to integrate the Generating Facility into Idaho Power's network to serve load
within Idaho Power's balancing area. Network Resource Interconnection Service in and of itself
does not convey any right to deliver electricity to any specific customer or Point of Delivery.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 2
Attachment 7
Generation Interconnection Control Requirements
Generator Output Limit Control (GOLC)
IPC requires Interconnected Power Producers to accept GOlC signals from our EMS.
The GOlC signals will consist of four points shared between the IPC EMS and the Customer's
Generator Controller:
GOlC Setpoint: An analog output that contains the MW value the Customer should curtail to, should a
GOlC request be made via the GOlC On/Off discrete output Control point.
An Analog Input feedback point must be updated (to reflect the GOlC setpoint value) by the Customer
Controller upon the Controller's receipt of the GOlC setpoint change, with no intentional delay.
GOlC On/Off: A discrete output (DO) control point with latching Off/On states. Following a "GOlC On"
control, the Customer Controller will run power output back to the MW value specified in the GOlC
Setpoint. Following a "GOlC Off' control, the Customer is free to run to maximum possible output.
A Discrete Input feedback point must be updated (to reflect the GOlC DO state) by the Customer
Controller upon the Controller's receipt of the GOlC DO state change, with no intentional delay.
If a GOlC control is issued, it is expected to see MW reductions start within 1 minute and plant output
to be below the GOlC Setpoint value within 10 minutes.
Voltage Control
Idaho Power Company requires Transmission-Interconnected Power Producers to accept Voltage
Control signals from our EMS when they are connected to our transmission system.
The voltage control will consist of one setpoint and one feedback point shared between the IPC EMS
and the Customer Controller.
The setpoint will contain the desired target voltage for the plant to operate at.
The control will always be active, there is no digital supervisory point like the Curtail On/Off control
above.
When a setpoint change is issued an Analog Input feedback point must be updated (to reflect the
Voltage Control setpoint value) by the Customer Controller upon the Controller's receipt of the Voltage
Control setpoint change, with no intentional delay.
When a setpoint change is received by the Customer Controller, the Voltage Control system should
react with no intentional delay.
The voltage control system should operate in a dead band of +/-5% of the control setting range.
The customer should supervise this control by setting up "reasonability limits", i.e. configure a
reasonable range of values for this control to be valid. As an example, they will accept anything
between .95 and 1.05 for the set point. In the case they are fed an erroneous value outside this range,
their control system defaults to the last known, good value.
Idaho Power Company Generator Interconnection Agreement # 349/359
I.P.U.C. No. 29, Tariff No. 101 Page 2 of 2
Generation Interconnection Data Points Requirements
bigitallnputs to IPCo (DNP Obj. 01 , Var. 2)
Index Description State (0/1) Comments:
0 52A Customer Capacitor Breaker (if present) Open/Closed Sourced at substation
1 GOLC Off/On Control Received (Feedback) Off/On Provided by Customer
Digital Outputs to Customer (DNP ObI. 10, Var. 11
Index Descrigtion Comments:
0 GOLC Off/On Provided by IPCO
NOTE: GOLC Setpoint indicates MW value to curtail to when GOLC Off/On DO is ON.
Analog Inputs to IPCo (DNP Obj. 30, Var. 2)
Raw Raw EU EU
Index Description High Low High EU Low Units Comments:
GOLC Setpoint Value Received -Provided by
0 JFeedback) 32767 32768 TBD TBD MW Customer
Voltage Control Setpoint Value Rec'd -Provided by
1 (Feedback) 32767 32768 TBD TBD kV Customer
-Provided by
2 Maximum Park Generating Capacity 32767 32768 TBD TBD MW Customer
-Provided by
3 Number of Turbines In High Speed Cutout 32767 32768 32767 -32768 Units Customer
-For Provided by
4 Ambient Temperature 32767 32768 327.67 -327.68 C Customer
-Provided by
5 Wind Direction 32767 32768 3276.7 -3276.8 Deg Customer
MPH
-or Provided by
6 Wind Speed 32767 32768 327.67 -327.68 m/s Customer
Analog Outputs to Customer (DNP Obj. 40, Var. 2)
Raw Raw EU EU EU
Index Description High Low High Low Units Comments:
-
0 GOLC Setpoint 32767 32768 TBD TBD MW Provided by IPCO
-
1 Voltage Control Setpoint 32767 32768 TBD TBD kV Provided by IPCO
NOTE: Curtailment Setpoint indicates MW value to Curtail to when Curtailment Off/On DO is ON.
BEFORE THE
.
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 59
July 13,2012
Donovan Walker
Legal Department
Idaho Power Company
1221 West Idaho Street
Boise, ID 83702
RE: Notch Butte Wind Park's Notice of Force Majeure
Dear Donovan:
With reference to your letter of July 11, 2012, to Josh Gunderson (re: Notch Butte Wind Park
-GIA #349 & #359 and Final GIA and Your Letter Dated July 9, 2012), on behalf of Notch Butte
Wind Park LLC ("Notch Butte"), the undersigned responds as follows:
1. Thank you for acknowledging your receipt of Notch Butte's Notice of Force Majeure
on July 2, 2012. Notch Butte respectfully acknowledges your stated position of disagreement
therewith. However, it is Notch Butte's position that your receipt of the Notice of Force Majeure,
regardless your disagreement therewith, nonetheless imposes a suspension of both parties'
performance for the duration of the event of force majeure.
This is not a case of Notch Butte being in default of its FESA prior to giving the Notice of
Force Majeure.
This is not a case where Notch Butte's tender or posting of a security is conditioned upon a
requested performance by Idaho Power.
This is a case, however, where the Notice of Force Majeure has been given in compliance
with Article XVI of the FESA, with the particulars of the occurrence of Force Majeure set forth
therein.
2. Without limitation upon the foregoing, and with the express non-waiver of and the
express reservation of any and all rights and remedies under the FESA, as well as any and all rights
and remedies otherwise available to Notch Butte, including pursuant to FERC intervention with
respect to FERC jurisdictional matters, and including by statute, tort or contract law, the following is
specifically called to your further attention:
(i) The Notice of Force Majeure previous given and received by you is
incorporated herein by this reference thereto, in all respects as if fully set forth herein. A suspension
of both parties' performance has been put into effect. Idaho Power's disagreement with respect
thereto does not affect that suspension. If Idaho Power disputes this, then pursuant to Section 22.1
of the FESA, Idaho Power is contractually obligated to submit the matter to the Commission for
~xergy Development Group 802 W Bannock, 12+ I=!oor Boise, ID 83702 P 208336.97931= 208336.9431
resolution. Idaho Power has no ability to resolve the matter in its own favor simply by unilateral
fiat.
(ii) Of particular note is the fact that pending IPUC Case No. GNR-E-ll-03
discloses, among other things, the ongoing attempt by Idaho Power to modify provisions of the
FE SA with respect to curtailment and REC ownership, thereby engaging in what is perceived by
Notch Butte to be anticipatory breach by Idaho Power of Section 26.1 of the FESA which disallows
modification without a writing signed by both Notch Butte and Idaho Power. The unilateral attempt
by Idaho Power to obtain through Commission intervention substantive modification of the FESA
makes it impossible for Notch Butte to further perform with any certainty its obligations under the
FESA. Accordingly, in addition to the unilateral activities ofIdaho Power (which are beyond the
control of Notch Butte and clearly not within the reasonable foresight of Notch Butte so as to have
been avoided by the exercise of due diligence by Notch Butte) being within the definition of Force
Majeure, the unilateral activities of Idaho Power also create grounds for the declaration by Notch
Butte of anticipatory breach by Idaho Power of its obligations under the FESA, not only with respect
to Section 26.1, but also, without limitation, with respect to Idaho Power's implicit obligation of
good faith and fair dealing under the FESA. Notch Butte therefore reserves the right to give formal
Notice of Default under Section 22.2 of the FESA with respect to the foregoing anticipatory breach
of Idaho Power, pending its further consideration of same.
Please be guided accordingly.
Sincerey
a~~~~ JamesCark~
Notch Butte Wind Park, LLC
Exergy Development Group 802 W Bannock. 12ih Floor Boise,ID 83702 P 208.336.9793 F 208 336.9431
July 13, 2012
Idaho Power Company
Attn: Donovan Walker
1221 West Idaho Street
Boise, 1083702
RE: Notch Butte Wind Park Projects -GI #349 and GI #359
Dear Mr. Walker,
Notch Butte Wind Park, llC (flNotch Butte"), submitted an executed Generator Interconnection
Agreement (GIA) to Idaho Power on July 9,2012. When signing this GIA, I was under the impression
that Idaho Power had accepted Notch Butte's and Exergy's request for a 138kV interconnection
rather than the dual circuit 12.5kV interconnection previously offered by Idaho Power and
previously rejected by Exergy. If this is not the case, a misunderstanding has occurred, and Exergy
must respectfully reiterate our request to Idaho Power for a revised GIA describing a 138kV
interconnection voltage rather than double-circuit, project dedicated 12.5kV.
Idaho Power rejected Exergy's requested interconnection voltage of 138kV, indicating that it would
be a "material modification" and would require a new Interconnection Application. Exergy
disagreed, and continues to disagree with this position taken by Idaho Power because 1) the Point
of Interconnection remains the same, 2) the originally studied transmission path included a step up
to 138kV at the Dietrich substation and from this point onward the transmission path is virtually
identical, 3) the affected line that changes from 12.5kV to 138kV is a new, rather than existing, line
and would be constructed in precisely the same location as the proposed double-circuit 12.SkV
line, 4) the short distance of new transmission line is a mere 4 miles that would be required to be
constructed, and most importantly, 5) the double-circuit 12.5kV option is inefficient and no reason
has been given for choosing this voltage instead of other "available" voltages for this area. As you
wi" recall, Exergy expressed repeatedly that a 12.5kV double-circuit transmission path is not a
feasible interconnection solution for the Notch Butte Wind Park.
Idaho Power has offered no explanation justifying its statement that changing the voltage of a 4
mile segment of new transmission path constitutes "material modification" requiring a new
Generator Interconnection Application. Idaho Power has taken a more reasonable stance
regarding "material modification" on numerous other occasions and it appears that in this instance
Exergy Development Group, 802 W. Bannock, 12th Floor, BOise, ID phone: [phone] fax: [phone]
A ~~' )....
exe
DE"VElO?MHIT GROUP
Idaho Power wishes either to reject all attempts by Exergy to seek viable alternatives in the
interconnection details or to withhold a full and detailed explanation of its stance to the extent
possible. In either case it appears Idaho Power is employing a strategy to frustrate the
development effort of Notch Butte Wind Park -otherwise, positions taken by Idaho Power would
be consistent with other projects and reasoning for these positions would be clearly elucidated
without repeated requests for explanation by Exergy.
Notwithstanding the topic of full output interconnection voltage, there remains the desire to place
in service the approximate 4 MW prior to December 31, 2012 facilitated by a temporary
interconnection to the existing 12.SkV distribution line. This option has been approved by Idaho
Power and Notch Butte remains willing to execute an E&P agreement for the $75,000 described by
Idaho Power in the final GIA. Exergy requests that an E&P agreement be prepared by Idaho Power
and submitted to Exergy so that work may begin on the limited output interconnection while Idaho
Power accepts the rational solution of a 138kV interconnection at the project site.
Best Regards,
~~~a~rk-'-L-LC---------
(/ ~~: Exergy Development Group of Idaho, LLC
James Carkulis, Managing Member
Exergy Development Group, 802 W. Bannock, 12th Floor, Boise, ID phone: [phone] fax: [phone]
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-22
IDAHO POWER COMPANY
ATTACHMENT 60
DONOVAN E. WALKER
Lead Counsel
[e-mail]
July 30, 2012
VIA E·MAIL AND U.S. MAIL
[e-mail]
Josh Gunderson, Project Engineer
Exergy Development Group of Idaho
802 West Bannock, Suite 1200
Boise, Idaho 83702
[e-mail]
Peter J. Richardson
RICHARDSON & O'LEARY, PLLC
515 North 27th Street
P.O. Box 7218
Boise, Idaho 83707
An IDACORP Company
Re: Notch Butte Wind Park Projects, GI #349 and #359 ("Notch Butte") -
Termination of Generator Interconnection Agreement and Removal from
the Generator Interconnection Queue
Messrs. Gunderson and Richardson:
This letter responds to the three letters dated July 13, 2012, from Exergy
Development Group of Idaho's ("Exergy") James Carkulis to Idaho Power Company
("Idaho Power").
As for the generator interconnection for the Notch Butte (GI #349 and #359) and
as explained in detail below, Idaho Power has terminated the Generator Interconnection
Agreement for Notch Butte and removed Notch Butte from Idaho Power's generator
interconnection queue.
As you may recall, based upon a specific request from Exergy in March of 2012,
Idaho Power revised the previously prepared Facility Study for Notch Butte to
accommodate bringing a limited generation output option on-line before the end of 2012
and prior to completing the remaining required construction and upgrades to bring on
Notch Butte's full output. This requested alternative and additional configuration was
1221 W Idaho St. (83702)
PO,Box70
Boise, ID 83707
Josh Gunderson
Peter J. Richardson
July 30, 2012
Page 2 of 4
included in the April 9, 2012, Facility Study Report, which specifically disclosed that in
order to have the facilities in place to allow for limited generation output by year end
2012, the Generator Interconnection Agreement ("GIA") had to be signed and funded by
no later than May 1 , 2012.
By letter dated April 20, 2012, Idaho Power forwarded to Exergy a Final GIA,
which included the limited output by year-end option, for execution. This letter advises
that, "In order for you to come online with limited output by December 15, 2012 we must
have this agreement executed by May 1, 2012." (Emphasis in original.) Additionally,
this letter advised that, "Failure to submit all of the requested items above [including
payment] by May 21, 2012 will cause your Generator Interconnection request to have
been deemed withdrawn and terminated."
Rather than execute the GIA and pay the required funding by May 1, 2012, in
order to proceed with the interconnection, including the option to be operational at
limited output by the end of the year as Exergy had requested, Exergy instead, on Apri!
30, 2012, sent a communication indicating, "Before we continue forward to execute and
fund the GIA, we need to inform IPeo of a configuration change for the Notch Butte
Project. We will be moving the POI [point of interconnection] from the project site to the
Dietrick substation and providing 34.5 kV at that point."
By letter dated May 23, 2012, Idaho Power responded to Exergy that as Exergy
had previously been informed, among other things, the requested interconnection
voltage of 34.5 kilovlts ("kV") was not physically available in the geographic area of this
project, and that because the Notch Butte project was past the final facility study stage,
that had studied a specific configuration-which included at Exergy's request
accommodation for limited output by the end of the year-that a change in the point of
interconnection and/or voltage such as that requested by Exergy on April 30 would
require new studies and require Exergy to submit a new generator interconnection
application. This May 23, 2012, letter also sent to Exergya final GIA, with the limited
output option removed as Exergy had failed to sign and fund the previously sent GIA by
the time necessary to achieve limited generation output prior to the end of 2012, for
Exergy's execution and payment by no later than June 23, 2012, if Exergy wished to
proceed forward with the studied configuration.
Rather than Signing the GIA and paying the required funding, on June 20, 2012,
Exergy wrote to Idaho Power requesting (1) interconnection at 138 kV, another change
from that which had been studied and/or (2) renewing its request to connect at limited
output (12.5 kV) by December 15,2012.
Idaho Power responded to Exergy by letter dated June 26, 2012, recounting the
above history; responding to the inaccurate factual representations in Exergy's June 20,
2012, letter; explaining again that a request for interconnection at a new voltage and a
new configuration (138 kV from the project site to Idaho Power's existing 138 kV) would
Josh Gunderson
Peter J. Richardson
July 30,2012
Page 3 of 4
require a new facility study; and once again accommodating Exergy's request to bring
back the formerly studied interconnection configuration which included the limited output
facilities by year end 2012. This letter, once again, sent to Exergy a final GIA for the
configuration contained in the final Facility Study for the project, and extended the time
for Exergy to execute and fund the GIA to July 9, 2012.
By letter dated July 9, 2012, and hand delivered to Idaho Power (received July
10,2012) Exergy returned the final GIA, signed by James Carkulis on behalf of Exergy,
but with no payment. Instead, Exergy's cover letter stated:
Exergy has received and executed the final Generator
Interconnection Agreement (GIA) prepared by Idaho Power
and dated June 26, 2012. Exergy is pleased to submit the
enclosed and executed GIA and will submit the funds
described in the enclosed GIA at such time as Idaho
Power countersigns and returns a copy of the document
to our office.
(Emphasis added.) Consequently, Idaho Power then signed the GIA and returned the
same to Exergy on July 11, 2012, and reiterated that the GIA itself, as well as previous
Idaho Power communications, clearly states that in order for the temporary facilities to
be constructed in time to bring the limited output on-line by December 15, 2012, that
payment had to be immediately received in order to proceed and meet that date. Idaho
Power, again, extended that deadline to the close of business on Friday July 13, 2012,
by which Exergy had to fund the GIA, which Exergy had agreed to do upon Idaho Power
executing the GIA, which Idaho Power did. That letter stated, "Idaho Power will
exercise its rights to terminate this GIA and to remove the project from the generator
interconnection queue if the required payment is not received by close of business, 5:00
p.m. Mountain Time, on Friday July 13, 2012."
However, rather than paying the required funds, as Exergy said it would both in
its July 9, 2012, letter, and by its execution of the GIA requiring the same, Exergy
instead sent a letter dated July 13, 2012, whereby it claimed that it was under the
impreSSion that the GIA it had signed just four days earlier provided for a different
interconnection configuration and voltage (138 kV) rather than the configuration and
voltage that was studied through the final Facility Study stage including the limited
output by year end option (12.5 kV). Exergy's letter insists upon a revised GIA at a
different voltage level, which was previously communicated to Exergy as, at a minimum,
requiring a new facility study process to be conducted. To this date, Exergy has made
no payment or other financial arrangements with Idaho Power to pay the required
construction funding (approximately $7.9 million) necessary to move forward with the
interconnection and the executed GIA for Notch Butte.
Josh Gunderson
Peter J. Richardson
July 30,2012
Page 4 of 4
The GIA executed by both Idaho Power and Mr. Carkulis, on behalf of Exergy,
provides:
These milestones will begin, and the construction schedule
referenced below, will only be valid upon receipt of funding in
full from the Seller [Exergy] or their authorized third party no
later than the date set forth below [July 9, 2012] for such
payment. Additionally, failure by Seller to make the required
payments as set forth in this Agreement by the date(s)
specified below will be a material breach of this Agreement,
which may result in any or all of the following: (i) loss of
milestone dates and construction schedules set forth below;
(ii) immediate termination of this Agreement by Idaho Power;
(iii) removal from the generator interconnection queue.
As described above, Exergy failed to make the required payments set forth in
the GIA and, thus, materially breached the GIA. Per the language quoted from the GIA
above, as a result of Exergy's material breach, Idaho Power has hereby immediately
terminated the GIA and removed the Notch Butte project from Idaho Power's generator
interconnection queue.
As for the alleged force majeure event sent for the Notch Butte project via letters
dated July 2, 2012, and July 13, 2012, Idaho Power categorically denies that a force
majeure event has occurred and hereby rejects Exergy's allegation of force majeure.
PLEASE BE ADVISED: Because of Exergy's failure to make the required
construction deposit payment pursuant to the executed GIA between Exergy and Idaho
Power for the Notch Butte Wind Park Projects, the GIA is now hereby terminated.
Additionally, Notch Butte's application for generator interconnection has been deemed
withdrawn, and this project has been removed from Idaho Power's Generation
Interconnection queue. You will receive, under separate cover, Idaho Power's
Complaint and Petition for Declaratory Order filed with the Idaho Public Utilities
Commission related to this matter and the termination of the Firm Energy Sales
Agreement between Notch Butte and Idaho Power.
Sinc~YI
~r«lC(~_
Donovan E. Walker
DEW:evp