20110711Application.pdf

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'1IDA~POR~
An 10ACORP Company
DONOVAN E. WALKER
Lead Counsel
dwalker(ëidahopower.com
July 8,2011
VIA HAND DELIVERY
Jean D. Jewell, Secretary
Idaho Public Utilties Commission
472 West Washington Street
P.O. Box 83720
Boise, Idaho 83720-0074
Re: Case No. IPC-E-11-14
IN THE MATTER OF IDAHO POWER COMPANY'S PETITION FOR
DECLARATORY ORDER REGARDING PURPA JURISDICTION
Dear Ms. Jewell:
Enclosed for filing please find an original and seven (7) copies of Idaho Power
Company's Petition for Declaratory Order in the above matter.
Donovan E. Walker
DEW:csb
Enclosures
1221 W. Idaho St. (83702)
P.O. Box 70
Boise, 10 83707
DONOVAN E. WALKER (ISB No. 5921)
JASON B. WILLIAMS
Idaho Power Company
1221 West Idaho Street (83702)
P.O. Box 70
Boise, Idaho 83707
Telephone: [phone]
Facsimile: [phone]
dwalker((idahopower.com
jwilliams((idahopower.com
RECEIVED
lOl I JUl -8 PH 4: 42
Attorneys for Idaho Power Company
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF IDAHO POWER )
COMPANY'S PETITION FOR ) CASE NO.IPC-E-11-14
DECLARATORY ORDER REGARDING )
PURPA JURISDICTION. ) PETITION FOR DECLARATORY
) ORDER
)
Idaho Power Company ("Idaho Powet' or "Company"), pursuant to RP 101,
hereby petitions the Idaho Public Utilities Commission ("IPUC" or "Commission") to
issue an Order determining that the Commission wil exercise its jurisdiction over the
proposed Public Utilty Regulatory Policies Act of 1978 ("PURPA") Qualifying Facilty
("QF") transactions proposed by Western Desert Energy 1, LLC ("Western Desert") and
Tumbleweed Energy II, LLC ("Tumbleweed").
In support of this request, Idaho Power states as follows:
I. BACKGROUND
A. Tumbleweed Energy U. LLC.
Tumbleweed is a proposed 10 megawatt ("MW") wind QF project located in
Elmore County, Idaho. On June 24, 2011, Tumbleweed hand delivered to Idaho Power
PETITION FOR DECLARATORY ORDER - 1
three documents: (1) June 23, 2011, letter to Donovan Walker from Pete Richardson,
attached hereto as Attachment No.1; (2) June 24, 2011, letter to Idaho Power
Company Cogeneration and Small Power Production from Richard Hansen, attached
hereto as Attachment No.2; and (3) June 24, 2011, letter to Manager Grid Operations
Idaho Power Company from Richard Hansen, attached hereto as Attachment No.3.
With Attachment No.1, Tumbleweed simply forwarded to Idaho Power a copy of
FERC Form 556, which is the Certification of QF Status for a Small Power Production or
Cogeneration Facilty. Attachment No.2 is a request to Idaho Power for a PURPA QF
contract in the state of Oregon, more specifically, for an Energy Sales Agreement
pursuant to the Public Utility Commission of Oregon's rate Schedule 85-4. Attachment
No. 3 is a request to Idaho Power for "Firm Point-to-Point Transmission Service" for 10
MW of capacity from its interconnection with Idaho Power in the state of Idaho for
delivery to "Idaho Power's Oregon jurisdiction."
Idaho Power responded to both the request for an Oregon Energy Sales
Agreement and the request for point-to-point transmission from the project's Idaho
interconnection to Idaho Power's Oregon service territory with July 8, 2011, letters
stating that both requests were received, but are invalid. See Attachment No.4, July 8,
2011, letter from Donovan E. Walker regarding the request for an Oregon Energy Sales
Agreement and July 8, 2011, letter from Beth Ryan regarding the request for point-to-
point transmission.
B. Western Desert Energy 1. LLC.
Western Desert is a proposed 5 MW wind QF project located in Owyhee County,
Idaho. It is the same proposed project as that which was the subject of Commission
PETITION FOR DECLARATORY ORDER - 2
Case No. IPC-E-11-01. In that case, Western Desert and Idaho Power executed a
PURPA Firm Energy Sales Agreement containing published avoided cost rates for
PURPA QFs up to 10 average megawatts ("aMW"). That contract was disapproved by
the Commission as it exceeded the 1 00 kilowatt ("kW") published rate eligibilty cap for
QF wind projects. Order No. 32258 (June 8, 2011).
On June 27, 2011, Western Desert hand delivered to Idaho Power three
documents: (1) June 27, 2011, letter to Donovan Walker from Pete Richardson,
attached hereto as Attachment No.5; (2) June 24, 2011, letter to Idaho Power
Company Cogeneration and Small Power Production from Sandy Sanderson, attached
hereto as Attachment No.6; and (3) June 27, 2011, letter to Manager Grid Operations
Idaho Power Company from Sandy Sanderson, attached hereto as Attachment NO.7.
With Attachment NO.5, Western Desert simply forwarded to Idaho Power a copy
of FERC Form 556, which is the Certification of QF Status for a Small Power Production
or Cogeneration Facilty. Attachment No. 6 is a request to Idaho Power for a PURPA
QF contract in the state of Oregon, more specifically, for an Energy Sales Agreement
pursuant to the Public Utilty Commission of Oregon's rate Schedule 85-4. Attachment
No. 7 is a request to Idaho Power for "Firm Point-to-Point Transmission Service" for 10
MW of capacity from its interconnection with Idaho Power in the state of Idaho for
delivery to "Idaho Powets Oregon jurisdiction."
Idaho Power responded to both the request for an Oregon Ener"gy Sales
Agreement and the request for point-to-point transmission from the project's Idaho
interconnection to Idaho Powets Oregon service territory with July 8, 2011, letters
stating that both requests were received, but are invalid. See Attachment NO.8, July 8,
PETITION FOR DECLARATORY ORDER - 3
2011, letter from Donovan E. Walker regarding the request for an Oregon Energy Sales
Agreement and July 8, 2011, letter from Beth Ryan regarding the request for point-to-
point transmission.
C. Avoided Cost Rates in Idaho and Oregon.
In Idaho, the avoided cost rate that a QF project receives in a PURPA power
sales agreement is determined by the size of the QF generator. A QF is entitled to
either the published avoided cost rate, which is based upon the Surrogate Avoidable
Resource ("SAR") avoided cost methodology with the surrogate avoided resource being
a natural gas-fired combined-cycle combustion turbine, or a negotiated rate which is
based upon the Integrated Resource Plan ("IRP")-based avoided cost methodology
using the AURORA power supply modeling program. The Commission has recently
determined that the published rate eligibility cap for wind and solar QFs is 100 kW and
10 aMW for all other QFs. Order No. 32262, Order No. 32176, and Order No. 32212.
Consequently, any wind and solar QFs over 100 kW are only eligible for avoided cost
rates in their PURPA power sales agreements determined pursuant to the IRP
methodology.
In Oregon, the avoided cost rate that a QF project receives in a PURPA power
sales agreement is similarly determined by the size of the QF generator. Similar to
Idaho, there are two avoided cost calculations: (1) the SAR methodology based upon
the cost of a natural gas-fired combined-cycle combustion turbine or (2) the IRP
methodology based upon AURORA modeling. However, the eligibility for published
rates is determined differently. Currently, QFs with a nameplate capacity of 10 MW or
PETITION FOR DECLARATORY ORDER - 4
lass are eligible for a standard contract with SAR-based published rates 1. All QFs with a
nameplate capacity greater then 10 MW are eligible for a negotiated, non-standard
contract with IRP-based avoided cost rates. See Attachment NO.9, Idaho Powets
Oregon Tariff Schedule 85, Cogeneration and Small Power Production Standard
Contract Rates (March 1,2010).
II. DISCUSSION
The Commission has addressed the issue of QF projects proposing to wheel
power across state lines, and has given clear direction as to which state's PURPA rules
wil apply to such transactions. Earth Power Energy and Minerals, Inc. VS. Idaho Power
Company, Case No. IPC-E-92-29, Order Nos. 25174, 25249 (1993); Island Power
Company, Inc. vs. PacifiCorp, dba Utah Power & Light Company, Case No. UPL-E-93-
4, Order Nos. 25245 (1993), 25528 (1994); Vaagen Bros. Lumber, Inc. VS. The
Washington Water Power Company, Case No. WWP-E-94-6, Order No. 25176 (1994).
The Commission has established that it has federally derived jurisdiction
pursuant to PURPA over any utility that it has ratemaking authority over. Order No.
25245 p. 5; Order No. 25174 p. 6-7. Additionally, the Commission has stated that this
federally derived jurisdiction over a multi-state utility may exist concurrently with other
state regulatory authorities that also have ratemaking authority over the utilty. Order
No. 25249 p. 2. Through the cases cited above, the Commission has discussed certain
circumstances where it determines whether it wil elect to exercise that jurisdiction or
not. What necessarily follows the Commission's exercise, or deferral, of its jurisdiction
is whether the Idaho Commission's PURPA rules, regulations, and procedures -
1 In Oregon Docket No. UM 1396, Idaho Power has asked that it be authorized to establish its
avoided cost for PURPA QFs in Oregon using the IRP-based methodology, similar to its Idaho
jurisdiction. This docket is stil pending.
PETITION FOR DECLARATORY ORDER - 5
including which states avoided cost rates and contract - wil apply to the proposed QF
transaction.
The Earth Power case, IPC-E-92-29, Order Nos. 25174 and 25249, concerned a
proposed QF project located in the state of Nevada, with a proposed interconnection to
Idaho Powets system in the state of Nevada, attempting to enter into a PURPA contract
with Idaho Power pursuant to the Idaho Commission's rules, regulations, and rates for
PURPA QFs. Order No. 25174, p. 1. At that time, Idaho Power had retail electric
service territory in both the state of Idaho and Nevada, and was under the regulatory
jurisdiction of both the Idaho and Nevada Commissions. Id. The Idaho Commission
stated that it had concurrent jurisdiction with the Nevada Commission. Id. The
Commission discussed that its PURPA jurisdiction is derived from federal law, which is
not bounded by geographic limits. Id. at pp. 6-7. The Commission also referenced the
series of four different Idaho Supreme Court Afton Energy cases as support for its
decision. Id. at p. 7, citing Afton Energy, Inc., v. Idaho Power Co., 107 Idaho 781, 693
P.2d 427 (1984); 111 Idaho 925, 729 P.2d 400 (1986); 114 Idaho 852, 761 P.2d 1204
(1988); 122 Idaho 333, 834, P.2d 850 (1992). Noting Afton's location in the state of
Wyoming, the Commission stated:
The circumstances were different in Afton as compared to
Earth Power because Idaho Power Company did not have a
service territory in Wyoming that was regulated by the
Wyoming Public Service Commission. Therefore, the
Wyoming Commission did not have the jurisdiction conferred
by PURPA. This distinction does not relate to the question
whether we have jurisdiction. However, it did mean that
there could be no issue of whether we should exercise our
jurisdiction in that case.
PETITION FOR DECLARATORY ORDER - 6
Both parties agree, and we concur, that the Nevada Public
Service Commission has jurisdiction concurrent with ours to
determine the rates for the Earth Power project and to
resolve disputes between the parties. Our record shows that
the Nevada PSC is actively asserting its jurisdiction. In this
circumstance, when a project is located within another state
and when the commission in that state is exercising the
jurisdiction conferred upon it by PURPA, we find that we
should decline to assert our jurisdiction. In circumstances
such as these we wil assert our jurisdiction only if the
commission of the other state declined for some reason to
exercise its jurisdiction. We also emphasize that we wil not
be a forum for relitigation of issues ultimately decided by the
Nevada PSC. We wil not entertain requests that we
second-guess the decision of another commission.
Id. at pp. 7-8 (emphasis in original). Because the Nevada Commission was actively
asserting its PURPA jurisdiction, the Idaho Commission initially declined to exercise
such jurisdiction and deferred to the Nevada Commission. Id. Upon the Nevada
Commission's subsequent dismissal of Earth Powets pending case before it and its
deferral to the Idaho Commission, Idaho chose to then exercise its jurisdiction. Order
No. 25249, pp. 4-5.
The Island Power case, UPL-E-93-4, Order Nos. 25245 and 25528, concerned a
Montana QF proposing to sell its output to PacifiCorp ("UP&L") pursuant to the Idaho
Commission's rules, regulations, and rates for PURPA QFs. Order No. 25245, p. 1.
Similar to the facts in Earth Power, UP&L had retail electric service territory in both the
state of Montana and Idaho, and was under the regulatory jurisdiction of both the Idaho
and Montana Commissions. Id. However, unlike Earth Power, Island Power did not
interconnect with UP&L in the state of Montana, but instead proposed to wheel its
output from Montana to either the Jefferson or Goshen substations, and make delivery
to UP&L's system inside the state of Idaho. Id. The Idaho Commission found that it
PETITION FOR DECLARATORY ORDER - 7
had jurisdiction, and under these facts, that it would exercise such jurisdiction to require
UP&L to contract with the QF pursuant to Idaho rules, regulations, and rates. Id. at p. 5.
The Commission stated that it found it reasonable to exercise its jurisdiction in this
matter because, although the project is sited in Montana, the proposed point of delivery
to UP&L is in Idaho where the Idaho Commission has established avoided cost rates for
UP&L. Id.
The Vaagen Brothers case, WWP-E-94-6, concerned a QF project located in the
state of Washington, with an interconnection to Washington Water Power ("WWP") in
the state of Washington. Order No. 25716, p. 1. Vaagen Brothers had a 1979 power
sales agreement with WWP that had expired in 1994. Id. Vaagen Brothers filed a
complaint with the Idaho Commission seeking a new contract with WWP pursuant to the
Idaho avoided cost methodology and rates. Id. WWP had retail electric service territory
in both the states of Washington and Idaho, and was under the regulatory jurisdiction of
both the Idaho and Washington Commissions. Id. at pp. 6-7. Under the facts of this
case, the Commission found that it had concurrent jurisdiction with Washington, but that
it would decline to exercise such jurisdiction and defer to Washington, and thus the
project must contract pursuant Washington's PURPA rules, rates, and regulations. Id.
The Commission distinguished this case from the Earth Power and Island Power cases
stating, "Vaagen is an existing facilty sited in the Washington service territory of the
utilty that it wishes to sell to, the Washington Water Power Company. The established
point of delivery is in the state of Washington." Id. at p. 6. The Commission further
stated that the Washington Commission had established a regulatory framework for
PURPA in Washington, and that although Idaho did have concurrent jurisdiction with the
PETITION FOR DECLARATORY ORDER - 8
Washington Commission, "common sense dictates that there are some instances when
we should elect not to exercise our jurisdiction." Id. at pp. 6-7.
Here, both Tumbleweed and Western Desert are PURPA QF projects located in
the state of Idaho. Both proposed projects have interconnections with Idaho Power's
system in the state of Idaho. It naturally follows that a QF power sales agreement
between the projects and Idaho Power would be governed and controlled and entered
into pursuant to the Idaho Commission's rules, regulations, and rates for Idaho.
Although the cases in which the Commission has addressed similar factual scenarios all
deal with QF projects located outside the state of Idaho, trying to obtain PURPA
contracts pursuant to Idaho's rules and rates, the principles and rules set forth by the
Commission apply equally as strong to the factual situation here, where an Idaho QF is
attempting to "cherr pick" a different jurisdiction's rates for its QF project in Idaho.
The facts of this case are most closely related to those in Vaagen Brothers, Case
No. WWP-E-94-6. Just as the Commission found that "common sense dictates" that the
Vaagen Brothers project should be required to contract with Avista pursuant to
Washington's QF rates and rules, common sense dictates that an Idaho QF, with an
Idaho interconnect, seeking a contract with an Idaho utilty should be under Idaho's
rates and rules. More specifically, in Vaagen Brothers, the QF was located in
Washington, it interconnected with Avista in Washington, and Avista provides retail
electric service in Washington and is regulated by the Washington Commission.
Moreover, the Washington Commission has a regulatory framework for PURPA QF
projects for Avista in Washington. This was an obvious choice for the Idaho
PETITION FOR DECLARATORY ORDER - 9
Commission to decline to exercise its jurisdiction and to require the QF to contract with
Avista, not pursuant to Idaho rates and regulations, but pursuant to Washington's.
Similarly, with both Tumbleweed and Western Desert, the QF is located in the
state of Idaho, they interconnect with Idaho Power in the state of Idaho, and Idaho
Power provides retail electric service in Idaho and is regulated by the Idaho
Commission. Obviously, the Idaho Commission has a regulatory framework for PURPA
QF projects for Idaho Power in Idaho. Just like the obvious choice in Vaagen Brothers,
common sense dictates that Tumbleweed and Western Desert must contract with Idaho
Power under the Idaho Commission's PURPA rates, rules, and regulations.
Additionally, both proposed projects exceed the Commission's 100 kW eligibilty
cap for receiving published avoided cost rates in the state of Idaho. Consequently,
these proposed projects must negotiate a PURPA QF power sales contract pursuant to
Idaho's approved IRP-based avoided cost methodology. Despite the fact that Western
Desert and Idaho Power actually entered into an Idaho QF power sales agreement for
this project, and although both projects have contacted Idaho Power and had
discussions with Idaho Power about entering into an Idaho QF power sales agreement,
neither project has requested IRP-based pricing from Idaho Power. As stated above,
Western Desert's previously executed contract with Idaho Power contained published
avoided cost rates for projects up to 10 aMW, which was disapproved by the
Commission as containing the incorrect avoided cost rates. Rather than request IRP
pricing based contracts with Idaho Power, these projects instead submit this veiled
attempt to seek the same published rate SAR-based contracts that they are ineligible for
in Idaho by concocting a scheme to attempt delivery to Idaho Power in its Oregon
PETITION FOR DECLARATORY ORDER - 10
service territory, from Idaho Powets Idaho service territory, entirely over Idaho Powets
own system. This is a blatant attempt to manipulate and avoid the Idaho Commission's
rates, rules, and regulations that are designed to implement PURPA and protect Idaho
Power's customers. This is an example, just as argued by Idaho Power in Case No.
GNR-E-10-04 and Case No. GNR-E-11-01, of how QF projects will seek to manipulate
and game the system, and go to creative and great lengths to do so, when there is a
perceived economic incentive driving them. The Commission recognized this incentive
to manipulate and game the system when it ordered the continued application of the
100 kW published rate eligibility cap for wind and solar QFs:
Based upon the record in this case and after careful
consideration of the positions presented, the Commission
finds it appropriate to maintain the 100 kW eligibilty cap for
published avoided cost rate for wind and solar QFs. We find
that any attempt to implement criteria in an effort to prevent
disaggregation would be met by attempts to circumvent such
criteria. The economic incentive for the projects is obvious.
QF developers are working within the current structure
provided by this Commission. However, we emphasize that
PURPA and our published rate structure were never
intended to promote large scale wind and solar development
to the detriment of utilty customers. Avoided cost rates are
to be just and reasonable to the utilty's ratepayers. 18
C.F.R. § 292.304(a)(1). PURPA entitles QFs to a rate
equivalent to the utilty's avoided cost, a rate that holds utilty
customers harmless - not a rate at which a project may be
viable. 18 C.F.R. § 292.304(a)(2). If we allow the current
trend to continue, customers may be forced to pay for
resources at an inflated rate and, potentially, before the
energy is actually needed by the utility to serve its
customers. This is clearly not in the public interest.
Case No. GNR-E-11-01, Order No. 32262, p. 8. The Commission in exercising its
jurisdiction in these matters wil preserve and protect the public interest that its recent
Orders regarding the published rate eligibilty cap are aimed at upholding.
PETITION FOR DECLARATORY ORDER - 11
II. CONCLUSION
Idaho Power respectfully requests that the Commission issue a Declaratory
Order finding that under the facts of these two proposed PURA QF transactions, the
Idaho Commission wil exercise its jurisdiction in implementing PURPA regulations and
require that such transactions be conducted pursuant to Idaho's PURPA rules, rates,
and regulations. More specifically, Idaho Power requests findings by the Commission
stating that a QF located in Idaho Powets service territory in the state of Idaho,
interconnecting with Idaho Power's system in the state of Idaho, must contract with
Idaho Power pursuant to the Idaho Commission's PURPA rules, rates, and regulations.
Such a QF project cannot avoid the application of Idaho's rates, rules, and regulations
by proposing to wheel its power across Idaho Power's system purportedly to make a
delivery back to Idaho Power in Idaho Powets Oregon service territory, and demand
different PURPA rates, rules, and regulations established by the Oregon Commission.
To allow such a circumstance to take place would allow a gross manipulation and
avoidance of the Idaho Commission's rules and regulations designed and implemented
to protect the customers of Idaho Power and the public interest.
Respectfully submitted at Boise, Idaho, this 8th day of July 2011.
¿(t!
PETITION FOR DECLARATORY ORDER - 12
CERTIFICATE OF SERVICE
I HEREBY CERTIFY that on this 8th day of July 2011 I served a true and correct
copy of the within and foregoing PETITION FOR DECLARATORY ORDER upon the
following named parties by the method indicated below, and addressed to the following:
Sandy Sanderson, Consultant
Western Desert Energy 1, LLC
1770 West State Street #317
Boise, Idaho 83702
Hand Delivered
-- U.S. Mail
_ Overnight Mail
FAX
-- Email sandycægreenenergywest.com
Richard Hansen, Manager
Tumbleweed Energy II, LLC
7154 W. State Street #330
Boise, Idaho 83714
Hand Delivered
-- U.S. Mail
_ Overnight Mail
FAX
-- Email engrwevrcæhotmail.com
Peter J. Richardson
RICHARDSON & O'LEARY, PLLC
515 North 2th Street
P.O. Box 7218
Boise, Idaho 83702
Hand Delivered
-- U.S. Mail
_ Overnight Mail
FAX
-- Email petercærichardsonandoleary.com
&r¿(cL
PETITION FOR DECLARATORY ORDER - 13
BEFORE THE
IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-E-11-14
IDAHO POWER COMPANY
ATTACHMENT NO.1
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Peter Richardson
Tel: [phone] Fax: [phone]
pete rli richardson and olea ry. co m
P.O. Box 7218 Boise, ID 83707 - 515 N. 27th St. Boise, ID 83702
June 23, 2011
Donovan Walker
Idaho Power Company
1221 West Idaho Street
Boise, Idaho
Via hand delivery
Re: FERC Form 556 - Tumbleweed Energy
Dear Donovan:
Enclosed please find a competed FERC Form 556 for the Tumbleweed Wind Energy
project located in Elmore County, Idaho.
This form is being provided to you pursuat to FERC's rules that require a copy be
provided to all utilties with which the filing QF will interconnect and/or transact. Idaho
Power will provide both services to Tumbleweed.
Please feel free to give me a call if you have any questions.
Since~~:dJ .~6!~/~ .
Pete Richardson
Attorney for Tumbleweed Energy
Form 556
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTONt DC
Certification of Qualifying Facility (OF) Status for a Small Power
Production or Cogeneration Facilty
OMB Control # 1902-075
Expiration 5/31/2013
General
Questions about completing this form should be sent to Form556Leferc.gov. Information about the Commission's QF
program, answers to frequently asked questions about QF requirements or completing this form, and contact information for
QF program staff are available at the Commission's QF website, ww.ferc.gov/QF. The Commission's QF website also
provides links to the Commission's QF regulations (18 C.F.R. § 131.80 and Part 292), as well as other statues and orders
pertaining to the Commission's QF program.
Who Must File
Any applicant seeking QF status or recertification of QF status for a generating facilty with a net power production capacity
(as determined in lines 7a through 7g below) greater than 1000 kW must file a self-certifcation or an application for
Commission certifcation of QF sttus, which includes a properly completed Form 556. Any applicant seeking QF status for a
generating facilit wit a net power production capacity 1000 kW or less is exempt from the certification requirement, and is
therefore not required to complete or file a Form 556. See 18 C.F.R. § 292.203.
How to Complete the Form 556
This form is intended to be completed by responding to the items in the order they are presented, according to the
instructions given. If you need to back-track, you may need to clear certain responses before you wil be allowed to change
other responses made previously in the form. If you experience problems, click on the nearest help button (.) for
assistance, or contact Commission staff at Form556eferc.gov.
Certain lines in this form wil be automatically calculated based on responses to previous lines, with the relevant formulas
shown. You must respond to all ofthe previous lines within a section before the results of an automatically calculated field
wil be displayed. If you disagree with the results of any automatic calculation on this form, contact Commission staff at
Form55ó(áercgoy to discuss the discrepancy before filing.
You must complete aU lines in this form unless instructed otherwise. Do not alter this form or save this form in a different
format Incomplete or altered forms, or forms saved in formats other than PDF, wil be rejeced.
How to File a Completed Form 556
Applicants are required to file their Form 556 electronically through the Commission's eFiling website (see instructions on
page 2). By filing eleconically, you wil reduce your filing burden, save paper resources, save postage or courier charges,
help keep Commission expenses to a minimum, and receive a much faster confirmation (via an email containing the docket
number assigned to your facilit) that the Commission has received your filing.
If you are simultaneously filing both a waiver request and a Form 556 as part of an application for Commission certifcation,
see the 'Waiver Requests" secion on page 3 for more information on how to file.
Paperwork Reduction Act Notice
This form is approved by the Ofce of Management and Budget (OMB Control No. 1902-0075, expiration 05/31/2013).
Compliance with the information requirements established by the FERC Form No. 556 is required to obtain or maintain status
as a QF. See 18 C.F.R. § 131.80 and Part 292. An agency may not conduct or sponsor, and a person is not required to respond
to, a collecion of information unless it displays a currently valid OMB control number. The estimated burden for completing
the FERC Form No. 556, including gathering and reporting information, is as follows: 3 hours for self-certifcation of a small
power production facilty, 8 hours for self-certifcations of a cogeneration facilty, 6 hours for an application for Commission
certification of a small power production facilit, and 50 hours for an application for Commission certification of a
cogeneration facility. Send comments regarding this burden estimate or any aspect of this collection of information,
including suggestions for reducing this burden, to the following: Information Clearance Ofcer, Ofce of the Executive
Direcor (ED-32), Federal Energy Regulatory Commission, 888 First Street N.E., Washington, DC 20426; and Desk Ofcer for
FERC, Ofce of Information and Regulatory Affairs, Offce of Management and Budget, Washington, DC 20503
(oira submissioneomb.eop.gov). Include the Control No. 1902-0075 in any correspondence.
FERC Form 556 Page 2 - Instructions
Electronic Filng (eFilng)
To elecronically file your Form 556, visit the Commission's QF website at ww,ferc.govIQF and click the eFilng link.
If you are eFiling your first document, you wil need to register with your name, email address, mailng address, and phone
number. If you are registering on behalf of an employer, then you wil also need to provide the employer name, alternate
contact name, alternate contact phone number and and alternate contact emaiL.
Once you are registered, log in to eFilng with your registered email address and the password that you created at
registration. Follow the instructions. When prompted, selec one of the following QF-related.filing types, as appropriate,
from the Electric or General filing category.
Filng category Filng Type as listed in eFilng Description
Use to submit an application for
(Fee) Application for Commission Cert. as Cogeneration QF Commission certificàtion or
Commission recertification of a
cogeneration facility as a QF.
Use to submit an application for
Commission certifcation or
(Fee) Application for Commission Cert. as Small Power QF Commission recertifcation of a
small power production facilty as a
QF.
Use to submit a notice of self-
Self-eertification Notice (QF, EG, Fq certifcation of your facilty
(cogeneration or small power
production) as a QF.
Electric Use to submit a notice of self-
Self-Recertification of Qualifying Facility (QF)
recertification of your facility
(cogeneration or small power
production) as a QF.
Use to correc or supplement a
Form 556 that was submited with
errors or omissions, or for which
Commission staff has requested
additional information. Do not use
Supplemental Information or Request this filing type to report new
changes to a facilty or its
ownership; rather, use a self-
recertifcation or Commission
recertification to report such
changes.
Use to submit a petition for
declaratory order granting a waiver
of Commission QF regulations
pursuant to 18 C.F.R. §§ 292.204(a)
General (Fee) Petition for Declaratory Order (not under FPA Part 1)(3) and/or 292.205(c). A Form 556 is
not required for a petition for
declaratory order unless
Commission recertification is being
requested as part of the petition.
You wil be prompted to submit your filing fee, if applicable, during the electronic submission process. Filing fees can be paid
via electronic bank account debit or credit card.
During the eFilng process, you wil be prompted to selec your file(s) for upload from your computer.
FERC Form 556 Page 3 - Instructions
Filng Fee
NQ filing fee is required if you are submiting a self-eertification or self-recertification of your facility as a QF pursuant to 18
C.F.R. § 292.207(a).
A filing fee is required if you are filing either of the following:
(1) an appUcation for COmmission certification or recertification of your facilty as a QF pursuant to 18 C.F.R. § 292.207(b), or
(2) a petition for declaratory order granting waiver pursuant to 18 C.F.R. §§ 292.204(aH3) and/or 292.205(c).
The current fees for applications for Commission certifcations and petitions for declaratory order can be found by visiting the
Commission's QF website at ww.ferc.govIOF and clicking the Fee Schedule link.
You wil be prompted to submit your filing fee, if applicable, during the elecronic filing process desribed on page 2.
Required Notice to Utilties and State Regulatory Authorities
Pursuant to 18 C.F.R § 292.207(aHii), you must provide a copy of your self-eertification or request for Commission certification
to the utilties with which the facilty wil interconnec and/or transact as well as to the State regulatory authorities of the
states in which your facility and those utilties reside. Links to information about the regulatory authorities in various states
can be found by visiting the Commission's QF website at wwJerc.govlOf and clicking the Notice Requirements link.
What to Expect From the Commission After You File
An applitantfiling a Form 556 electronically will receive an email message àcknowledging receipt of the filing and showng
the dockèt number assigned to the filing. Such email is typically sent Within one bUsiness day, but may be delayed pending
confirmation by the Secreary of the Commission of the contents of the filing.
An applicant submitting a self-certification of QF status should expec to receive no documents from the Commission, other
than the elecronic acknowledgement of receipt described above. Consistent with its name, a self-eertification is a
certiftion by the appJicant ittelfthatthefaciJity meets the relevant requirements for QF status, and does not involve a
determination by the Commission as to the status of the facilty. An acknowledgement of receipt of a self-eertifcation, in
particular, does not represent a determination by the Commission with regard to the QF status of the failty. An applicant
self-eertifingmay, hQwever, recE!ive a rejection, revocation or defciency letter if its appJic;tion is found, during periodic
compliance reviews, not to comply with the relevant requirements.
An applicant submiting a request for Commission certification wil receive an order either granting or denying certification of
QF status, or a letter requesting additional information or rejecing the application. Pursuant to 18 C.F.R. § 292.207(b)(3), the
Commission must act on an application for Commission certifcation within 90 days of the later of the filing date of the
application or the filing date of a supplement, amendment or other change to the application.
Waiver Requests
18 C.F.R. § 292.204(aH3) allows an applicant to request a waiver to modify the method of calculation pursuant to 18 C.F.R. §
292.204(aH2) to dètermine if two facilities are considered to be located at the same site, for 990Q cause. 18 C.F.R. § 292.205(c)
allows an applicant to request waiver of the requirements of 18 C.F.R §§ 292.205(a) and (b) for operating and efciency upon
a showing that the facility wil produce signifcant energy savings. A request for waiver of these requirements must be
submitted as a petition for declaratory order, with the appropriate filing fee for a petition for declaratory order. Applicants
requesting Commission recertification as part of a request for waiver of one of these requirements should eleconically
submit their completed Form 556 along with their petition for declaratory order, rather than filing their Form 556 as a
separate request for Commission recertification. Only the filing fee for the petition for declaratory order must be paid to
cover both the waiver request and the request for recertification if such requests are made simultaneously.
18 C.F.R. § 292.203(dH2) allows an applicant to request a waiver of the Form 556 filing requirements, for good cause.
Applicants filing a petition for declaratory order requesting a waiver under 18 C.F.R. § 292.203(d)(2) do not need to complete
or submit a Form 556 with their petition.
FERC Form 556 Page 4 - Instructions
Geographic Coordinates
If a street address does not exist for your facilty, then line 3c of the Form 556 requires you to report your facility's geographic
coordinates (latitude and longitude). Geographic coordinates may be obtained from several different sources. You can find
links to online services that show latitude and longitude coordinates on online maps by visiting the Commission's QF
web page at www.ferc.gov/QF and clicking the Geographic Coordinates link. You may also be able to obtain your geographic
coordinates from a GPS device, Google Earth (available free at http://earth.google.com), a propert survey, various
engineering or construction drawings, a propert deed, or a municipal or county map showing propert lines.
Filing Privileged Data or Critical Energy Infrastructure Information in a Form 556
The Commission's regulations provide procedures for applicants to either (1) request that any information submitted with a
Form 556 be given privileged treatment because the information is exempt from the mandatory public disclosure
requirements of the Freedom of Information Act, 5 U.S.C § 552, and should be withheld from public disclosure; or (2) identify
any documents containing critical energy infrastructure information (CEil) as defined in 18 CF.R. § 388.113 that should not be
made public.
If you are seeking privileged treatment or CEil status for any data in your Form 556, then you must follow the procedures in 18
CF.R. § 388.112. See www.ferc.gov/help/filng-guidelfile-eii.aspfor more information.
Among other things (see 18 CF.R. § 388.112 for other requirements), applicants seeking privleged treatment or CEil status for
data submitted in a Form 556 must prepare and file both (1) a complete version of the Form 556 (containing the privileged
and/or CEil data), and (2) a public version of the Form 556 (with the privileged and/or CEil data redacted). Applicants
preparing and filing these different versions of their Form 556 must indicate below the security designation of this version of
their document. If you are not seeking privileged treatment or CEil status for any of your Form 556 data, then you should not
respond to any of the items on this page.
Non-Public: Applicant is seeking privileged treatment and/or CEil status for data contained in the Form 556 lines
o indicate below. This non-public version of the applicant's Form 556 contains all data, including the data that is redacted
in the (separate) public version ofthe applicant's Form 556.
Public (redacted): Applicant is seeking privileged treatment and/or CEil status for data contained in the Form 556 lines
o indicated below. This public version of the applicants's Form 556 contains all data except for data from the lines
indicated below, which has been redacted.
Privileged: Indicate below which lines of your form contain data for which you are seeking privileged treatment
Criical Energy Infrastructure Information (CEil): Indicate below which lines of your form contain data for which you are
seeking CEil status
The eFilng process described on page 2 wil allow you to identify which versions of the electronic documents you submit are
public, privileged and/or CEil. The filenames for such documents should begin with "Public", "Priv", or "CEil", as applicable, to
clearly indicate the security designation of the file. Both versions of the Form 556 should be unaltered PDF copies of the Form
556, as available for download from www.ferc.gov/QF. To redact data from the public copy of the submital, simply omit the
relevant data from the Form. For numerical fields, leave the redacted fields blank. For text fields, complete as much of the
field as possible, and replace the redacted portions of the field with the word "REDAGED" in brackets. Be sure to identify
above.i fields which contain data for which you are seeking non-public status.
The Commission is not responsible for detecting or correcting filer errors, including those errors related to security
designation. If your documents contain sensitive information, make sure they are filed using the proper security designation.
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, DC
F 0 r m 5 5 6 Certification of
Qualifying Facilty (QF) Status for a Small Power
Production or Cogeneration Facility
OMB Control ## 1902-0075
Expiration 5/31/2013
1 a Full name of applicant (legal entit on whose behalf qualifng facility status is sought for this facility)
Tumleweed Energy,LLC
1b Applicant street address
1801 Radcliffe Way
1c City 1 d State/province
Eagle Idaho
1 e Postal code 1f Country (if not United States)1 9 Telephone number
83616 [phone]
1h Has the instant facilit ever previously been certified as a QF?Yes 0 No f8
1i if yes, provide the docket number of the last known QF filing pertaining to this facilty QF -----
1j Under which certification process is the applicant making this filing?
I: Notice of self-certification o Application for Commission certifcation (requires filings:(se note below)fee; see "Filng Fee" secion on page 3)
0 Note: a notice of self-certifcation is a notice by the applicant itself that its facility complies with the requirements for.p
rt QF status. A notice of self-certification does not establish a proceeding, and the Commission does not review a
E notice of self-eertification to verify compliance. See the "What to Expect From the Commission After You File""-section on page 3 for more information.
J2 1k What type(s) of QF sttus is the applicant seeking for its facility? (check all that apply)s:
s:~ Qualifng small ¡:ower production facilit status o Qualifying cogeneration facilit status0'P 11 What is the purpose and expeced efecve date(s) ofthis filing?rt.~I: Original certification; facility expeed to be installed by 11/1/12 and to begin operation on 1/1/13õ.
o Change(s) to a previously certified facilty to be effecive onC-o:(identif type(s) of change(s) below, and describe change(s) in the Miscellaneous section starting on page 19)
o Name change and/or other administrative change(s)
o Change in ownership
o Change(s) afecting plant equipment, fuel use, power production capacit and/or cogeneration thermal output
o Supplement or correcion to a previous filing submitted on
(describe the supplement or correction in the Miscellaneous secion starting on page 19)
1 m If any of the following three statements is true, check the box(es) that describe your situation and complete the form
to th,e exent possible, explaining any special circumstances in the Miscellaneous section strting on page 19.
o The instant facility complies with the Commission's QF requirements by virtue of a waiver of certain regulationspreviously granted by the Commission in an order dated (specif any other relevant waiver
orders in the Miscellaneous section starting on page 19)
o The instant facility would comply with the Commission's QF requirements if a petition for waiver submittedconcurrently with this application is granted
The instant facility complies with the Commission's regulations, but has special circumstances, such as the
o employment of unique or innovative technologies not contemplated by the structure of this form, that make
the demonstration of compliance via this form difcult or impossible (describe in Misc. secion starting on p. 19)
o
o
o
o
o
o
FERC Form 556 Page 6 - All Facilities
2a Name of contact person 2b Telephone number
Richard Hansen [phone]
2c Which of the following describes the contact person's relationship to the applicant? (check one)
i:o Applicant (self)I2 Employee, owner or partner of applicant authorized to represent the applicant
0 o Employee of a company affliated with the applicant authorized to represent the applicant on this matter.'¡
ct o Lawyer, consultant, or other representative authorized to represent the applicant on this matterE2d Company or organization name (if applicant is an individual, check here and skip to line 2e) 0ii~Tumleweed Energy i LLCi:-
2e Street address (if same as Applicant, check here and skip to line 3alD~iUct 1801 Radcliffe~iC0U
2f City 29 State/province
Eagle Idaho
2h Postal code 2i Country (if not United States)
83616
3a Facilty namei:Tumbleweed Energy Development0".3b Street address (if a street address does not exist for the facilty, check here and skip to line 3c)!:ctU0..
"'i:ct 3c Geographic coordinates: If you indicated that no street address exists for your facilty by checking the box in line 3b,C then you must specfy the latitude and longitude coordinates of theiacilityin degree (to threedecmatplaces). Use0the following formula to convert to decimal degrees from degrees, minutes and seconds: decimal degrees =''¡
ct degrees + (minutes/60) + (seconds/3600).See the "Geographic Coordinates" secion on page 4 for help. If youUprovided a street address for your facilty in line 3b, then specifying the geographic coordinates below is optional.q:''¡
o East (+)I2 North (+)i:Longitude 115.420 degrees Latitude 43 . 14 2 degreesOJI2 West (-)o South (-)"';:3d City (if unincorporated, check here and enter nearest city) 0 3e State/province
.t=Mountain Home Idaho
U 3f County (or check here for independent city) 0ct 3g Country (if not United States)u.
Elmore
Identify the electric utilities that are contemplated to transact with the facility.
(,4a Identify utility interconnecting with the facilityOJ
:-e Idaho Power Company.'¡::4b Identify utilties providing wheeling service or check here if none 0
Ol Idaho Power CompanyC~i 4c Identify utilties purchasing the useful electric power output or check here if none 0UctIdaho Power CompanyV)i:ct 4d Identify utilties providing supplementary power, backup power, maintenance power, and/or interruptible poweriii-service or check here if none 0
Idaho Power Company
o
o
o
o
o
o
FERC Form 556 Page 7 - All Facilties
Sa Direc ownership as of effecive date or operation date: Identify all direct owners of the facility holding at least 10
percent equit interest. For each identified owner, also (1) indicate whether that owner is an electric utilty, as
defined in secion 3(22) of the Federal Power Act (16 U.S.c. 796(22)), or a holding company, as defined in secion
1262(8) of the Public Utilty Holding Company Act of 2005 (42 U.S.c. 16451 (8)), and (2) for owners which are electric
utilties or holding companies, provide the percentage of equity interest in the facilty held by that owner. If no
direc owners hold at least 10 percent equity interest in the facility, then provide the required information for the
two direc owners with the largest equity interest in the facilty.
Electric utilty or If Yes,
holding % equity
Full legal names of direc owners company interest
1) Richard W.Hansen YesD No IZ %
2)Nick Troche YesD No IZ %
3)YesD No D %
4)YesD No D %
5)YesD No D %
6)YesD No D %
7)YesD No D %
8)YesD No D %C0 9)YesD No D %.p
ro 10)YesD No D %'-
Q)0.D Check here and continue in the Miscellaneous secion starting on page 19 if additional space is needed0.
'"$b Upstream (i.e., indirec) owñership as of effece date or operation date: Identify all upstream (i.e., indirect) ownersc:of the facilty that both (1) hold at least 10 percent equit interest in the facility, and (2) are electric utilties, asro0.defined in section ~(22) of the Federal Power Act (16 U.s.c. 796(22)), or holding companies, as defined in section
:e 1262(8) of the. PubliC; Utilty Holding Company Act of ~005 (42 U.s.c. 16451 (8)). Also provide the percentage of
~equity interest in the facilty held by such owners. (Note that, because upstream owners may be subsidiaries of one
(J another, total percent equity interest reported may excee 1 00 percent.)
c:
~Check here if no such upstream owners exist. IZ0 % equity
Full legal names of elecric utilty or holding company upstream owners interest
1 )%
2)%
3)%
4)%
5)%
6)%
7)%
8)%
9)%
10)%
D Check here and continue in the Miscellaneous secion starting on page 19 if additional space is needed
Se Identify the facility operator
Tumleweed Energy,LLC
o
FERC Form 556 Page 8 - All Facilties
6a Describe the primary energy input: (check one main category and, if applicable, one subcategory)
o Biomass (specify)
o landfill gas
o Manure digester gas
o Municipal solid waste
o Geothermal
o Fossil fuel (specify)
o Coal (not waste)
o Fuel oil/diesel
o Natural gas (not waste)
Other fossil fuel
o (describe on page i 9)
!8 Renewable resources (specify)
o Hydro power - river
o Hydro power - tidal
o Hydro power - wave
o Solar - photovoltaic
o Solar - thermal
o Other biomass (describe on page i 9) 18 Wind
o Other renewable resource 0 Other (describe on page i 9)(describe on page i 9)
6b If you specified "waste" as the primary energy input in line 6a, indicate the type of waste fuel used: (check one)
o Sewage digester gas
o Wood
o Waste (specify type below in line 6b)
..::c.
c:~
ei(Jc:w
o Waste fuel listed in i 8 CF.R. § 292.202(b) (specify one of the following)
o Anthracite culm produced prior to July 23, i 985
o Anthracite refuse that has an average heat content of 6,000 Btu or less per pound and has an averageash content of 45 percent or more
o Bituminous coal refuse that has an average heat content of 9,500 Btu per pound or less and has anaverage ash content of 25 percent or more
Top or bottom subbituminous coal produced on Federal lands or on Indian lands that has been
o determined to be waste by the United States Department of the Interior's Bureau of land Management(BLM) or that is located on non-Federal or non-Indian lands outside of BLM's jurisdietion, provided that
the applicant shows that the latter coal is an exension of that determined by BLM to be waste
Coal refuse produced on Federal lands or on Indian lands that has ben determined to be waste by the
o BlM or that is located on non- Federal or non-Indian lands outside of BLM's jurisdietion, provided that
applicant shows that the latter is an exension of that determined by BLM to be waste
o Lignite produced in association with the production of montan wax and lignite that becomes exposedas a result of such a mining operation
o Gaseous fuels (except natural gas and synthetic gas from coal) (describe on page i 9)
Waste natural gas from gas or oil wells (describe on page i 9 how the gas meets the requirements of i 8
o CF.R. § 2.400 for waste natural gas; include with your filing any materials necessary to demonstrate
compliance with i 8 CF.R. § 2.400)
o Materials that a government agency has certified for disposal by combustion (describe on page i 9)
o Heat from exothermic reactions (describe on page i 9) 0 Residual heat (describe on page i 9)
o Used rubber tires 0 Plastic materials 0 Refinery off-gas 0 Petroleum coke
Other waste energy input that has little or no commercial value and exists in the absence of the qualifying
o facilty industry (describe in the Miscellaneous section starting on page i 9; include a discussion of the fuel's
lack of commercial value and existence in the absence of the qualifying facility industry)
6c Provide the average energy input, calculated on a calendar year basis, in terms of Btu/h for the following fossil fuel
energy inputs, and provide the related percentage of the total average annual energy input to the facilty (18 CF.R. §
292.2020)). For any oil or natural gas fuel, use lower heating value (i 8 CF.R. § 292.202(m)).
Fuel
Natural gas
Oil-based fuels
Coal
Annual average energy
input for specified fuel
Percentage of total
annual energy input
0%
0%
0%
o Btu/h
o Btu/h
o Btu/h
FERC Form 556 Page 9 - All Facilities
Indicate the maximum gross and maximum net electric power production capacity of the facilty at the point(s) of
delivery by completing the worksheet below. Respond to all items. If any of the parasitic loads and/or losses identifed in
lines 7b through 7e are negligible, enter zero for those lines.
7a The maximum gross power production capacity at the terminals of the individual generator(s)
under the most favorble anticipated design conditions
7bParasitic station power used at the facility to run equipment which is necessary and integral to
the power production process (boiler feed pumps, fanslblowers, offce or maintenance buildings
direcly related to the operation of the power generating facilty, etc.). If this facilty includes non-
power prouction processes (for insnce, power consumed by a cogeneration facility's thermal
host) , do not include any power consumed by the non-power production activities in your
reported parasitic station power.
2,500 kW
6.2 kW
7c Elecrical losses in interconnecion transformers
18.7 kW
7d Electrical losses in AC/DC conversion equipment, if any
o kW
7e Other interconnecion losses in power lines or facilities (other than transformers and AC/DC
conversion equipment) between the terminals of the generator(s) and the point of interconnecion
with the utilit
7f Total deductions from gross power production capacity = 7b + 7c + 7d + 7e
25 kW
49.9 kW 0i:o''¡
n:
E~
Jli:
.è
.0n:LL-n:u...i:..u
~
7g Maximum net power production capacity = 7a - 7f
2,450.1 kW
7h Description of facilty and primary components: Describe the facility and its operation. Identify all boilers, heat
recovery steam generators, prime movers (any mechanical equipment driving an elecric generator), electrical
generators, photovoltaic solar equipment, fuel cell equipment and/or other primary pOwer generation equipment
used in the facilty. Descriptions of components should include (as applicable) specifcations of the nominal
capacities for mechanical output elecrical output, or steam generation of the identifed equipment. For each piece
of equipment identifed, clearl indicate how many pieces of that type of equipment are included in the plant, and
which components are normally operating or normally in standby mode. Provide a description of how the
components operate as a system. Applicants for cogeneration facilities do not need to describe operations of
syems that are clearly depicted on and easily undersandable from a cogeneration facility's attached mass and
heat balance diagram; however, such applicants should provide any necessary description needed to understand
the sequential operation of the facilty depicted in their mass and heat balance diagram. If additional space is
needed, continue in the Miscellaneous section starting on page 19.
The Tumleweed Energy facility will consist of four 2.5 MW Nordex wind generating
turbines and will connect to Idaho Power's existing 34.5 kv line that is adjacent
to the project.
FERC Form 556 Page 10 - Small Power Production
Information Required for Small Power Production Facility
If you indicated in line 1 k that you are seeking qualifying small power production facility status for your facility, then you
must respond to the items on this page. Otherwise, skip page 10.
Pursuant to 18 CF.R. § 292.204(a), the power production capacity of any small power production facility, together
with the power production capacit of any other small power production facilties that use the same energy
resource, are owned by the same person(s) or its affliates, and are located at the same site, may not exceed 80
megawatts. To demonstrate compliance with this size limitation, or to demonstrate that your facility is exempt
from this size limitation under the Solar, Wind, Waste, and Geothermal Power Production Incentives Act of 1990
(Pub. L. 101-575, 104 Stat. 2834 (1990) as amended by Pub. L. 102-4, 105 Stat. 249 (1991)), respond to lines 8a
through 8e below (as applicable).
QJUC
.~ ~- 0a. ._
E 10
(3 '~\0o ::
C QJo .!:
''¡ V'
G .c
q: +-''¡ '§i.
QJU
QJ II+-U CCQJcoEa.QJ
E i..-:J00-U QJ\0 e:0 QJCII0~+-co QJu:Jq:u.''¡.ci.
QJ ,'tU~
8a Identify any facilties with electrical generating equipment located within 1 mile of the elecrical generating
equipment of the instant facility, and for which any of the entities identified in lines 5a or 5b, or their affliates, holds
at least a 5 percent equity interest.
Check here if no such facilities exist. I:o
Facilty location
(city or county, state)Common owner(s)
Maximum net power
production capacity
kW
kW
kW
Root docket #
(if any)
1)
2)
3)
QF
QF
QF
o Check here and continue in the Miscellaneous secion starting on page 19 if additional space is needed
8b The Solar, Wind, Waste, and Geothermal Power Production Incentives Act of 1990 (Incentives Act) provides
exemption from the size limitations in 18 CF.R. § 292.204(a) for certain facilties that were certified prior to 1995.
Are you seeking exemption from the size limitations in 18 CF.R. § 292.204(a) by virtlle of the Incentives Act?
o Yes (continue at line 8c below) I: No (skip lines 8c through 8e)
8e Was the original notice of self-eertification or application for Commission certification of the facility filed on or
before December 31, 1994? YesD No 0
8d Did construction ofthe facility commence on or before December 31, 1999? Yes 0 No 0
8e If you answered No in line 8d, indicate whether reasonable dilgence was exercised toward the completion of
the facilty, taking into account all factors relevant to construction? Yes 0 No 0 If you answered Yes, provide
a brief narrative explanation in the Miscellaneous section starting on page 19 of the construction timeline (in
particular, describe why construction started so long after the facility was certified) and the dilgence exercised
toward completion of the facility.
Pursuant to 18 CF.R. § 292.204(b), qualifying small power production facilities may use fossil fuels, in minimal
amounts, for only the following purposes: ignition; start-up; testing; flame stabilzation; control use; alleviation or
prevention of unanticipated equipment outages; and alleviation or prevention of emergencies, directly affecing
the public health, safety, or welfare, which would result from electric power outages. The amount of fossil fuels
used for these purposes may not exceed 25 percent of the total energy input of the facility during the 12-month
period beginning with the date the facility first produces electric energy or any calendar year thereafter.
o
9a Certification of compliance with 18 CF.R. § 292.204(b) with respec to uses offossil fuel:
I: Applicant certifies that the facility wil use fossil fuels exclusively for the purposes listed above.
9b Certification of compliance with 18 CF.R. § 292.204(b) with respect to amount of fossil fuel used annually:
Applicant certifies that the amount of fossil fuel used at the facilty wil not, in aggregate, exceed 25
I: percent of the total energy input of the facilty during the 12-month period beginning with the date the
facility first produces electric energy or any calendar year thereafter.
FERC Form 556 Page 11 - Cogeneration Facilities
Information Required for Cogeneration Facility
If you indicated in line 1 k that you are seeking qualifyin~ cogeneration facilty status for your facilit, then you must respond
to the items on pages 11 through 13. Otherwise, skip pages 11 through 13.
Puruant to 18 C.F.R. § 292.202(c), a cogeneration facility produces elecnc energy and forms of useful thermal
energy (such as heat or steam) use. for industnal, commercial, heating, or cooling purpses, through the sequential
use of energy. Pursuant to 18 C.F.R. § 29U02(s), "sequential use" of energy means the following: (1) for a topping-
cycle cogeneration facilty, the use of rejec heat from a power production process in suffcient amounts in a
thermal application or process to conform to the requirements of the operating standard contained in 18 C.F.R. §
292.205(a); or (2) for a bottoming-ecle cogeneration facility, the use of at least some rejec heat from a thermal
appliction or process for power production.
1 Da What type(s) of cogeneration technology does the facility represent? (check all that apply)
o Topping-ecle cogeneration o Bottoming-cycle cogeneration
1 Db To help demonstrate the sequential operation of the cogeneration process, and to support compliance with
other requirements such as the operating and effciency standards, include with y(;)Ur filing a mass and heat
balance diagram depicting average annual operating conditions. This diagram must include certain items and
meet certain requirements, as described below. You must check next to the description of each requirement
below to certify that you have complied with these requirements.
Check to certify
compliance with
.indicated requirement Requirement
Diagram must show orientation within syem piping and/or duet of all pnme movers,C heat recovery steam generators, boilers, elecric generators, and condensers (as00''¡applicable), as well as any other primary equipment relevant to the cogeneration
to process.i-c:Q)0 Any average annual values required ¡to be reported .in lines 10b, 12a, 13a, 13b, 13d, 13f,C -JJ 0Q)14a, 15b, 15d and/or 15f must be computed over the anticipated hours of operation.0'to
0 E Diagram must specify all fuel input by fuel ty and average annua.1 rate in Btuth. FuelUi-
'7 2 0 for SuPPlementary firing should be specified separately and clearly labeled. All
c:specifications of fuel inputs should use lower heating values.i--Q)C 0 Diagram must specify average gross electric output in kW or MW for each generator.Q)\.
Diagram must specif average mechanical output (that is, any mechanical energy taken
0 off of the shaft of the prime movers for purposes not direly related to electnc power
generation) in horsepower, if any. Typically, a cogeneration facilty has no mechanical
output.
At each point for which working fluid flow conditions are required to be speified (see
below), such flow condition data must include mass flow rate (in Ibth or kg/s),
temperature (in OF, R, °C or K), absolute pressure (in psia or kPa) and enthalpy (in Btu/lb
or kJ/kg). Exception: For systems where the working fluid is liquid only (no vapor at any0point in the cycle) and where the type of liquid and specific heat of that liquid are clearly
indicated on the diagram or in the Mistellaneous secion starting on page 19, only mass
flow ráte and temperature (not preure and enthalpy) need be specifed. For reference,
specifc heat at standard conditions for pure liquid water is approximately 1.002 Btu/
(Ib*R) or4.195 kJ/(kg*K).
0 Diagram must specify working fluid flow conditions at input to and output from each
steam turbine or other expansion turbine or back-pressure turbine.
0 Diagram must specify working fluid flow conditions at delivery to and return from each
thermal application.
0 Diagram must specify working fluid flow conditions at make-up water inputs.
o
o
FERC Form 556 Page 12 - Cogeneration Facilities
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EPAct 2005 cogeneration facilities: The Energy Policy Act of 2005 (EPAct 2005) established a new secton 21 O(n) of
the Public Utilty Regulatory Policies Act of 1978 (PURPA), 16 USC 824a-3(n), with additional requirements for any
qualifing cogeneration facility that (1) is seeking to sell electnc energy pursuant to section 210 of PURPA and (2)
was either not a cogeneration facility on August 8, 2005, or had not filed a self-eertification or application for
Commission certification of QF status on or before February 1, 2006. These requirements were implemented by the
Commission in 18 CF.R. § 292.205(d). Complete the lines below, carefully following the instructions, to demonstrate
whether these additional requirements apply to your cogeneration facility and, if so, whether your facilty complies
with such requirements.
11 a Was your facilty operating as a qualifyng cogeneration facilty on or before August 8, 2005? Yes 0 No 0 0
11 b Was the initial filing seeking certification of your facilty (whether a notice of self-eertification or an application 0
for Commission certification) filed on or before February 1, 2006? Yes 0 No 0
Ifthe answer to either line 11a or 11b is Yes, then continue at line 11c below. Otherwise, if the answers to both lines
11 a and 11 b are No, skip to line 11 e below.
11 c With respec to the design and operation of the facilty, have any changes been implemented on or after 0
February 2, 2006 that affect general plant operation, affect use of thermal output, and/or increase net power
production capacity from the plant's capacity on February 1, 2006?
o Yes (continue at line 11 d below)
No. Your facility is not subject to the requirements of 18 CF.R. § 292.205(d) at this time. However, it may be
o subject to to these requirements in the future if changes are made to the facility. At such time, the applicant
would need to recertify the facilty to determine eligibilty. Skip lines 11 d through 11 j.
11 d Does the applicant contend that the changes identified in line 11 c are not so significant as to make the facility 0
a "new" cogeneration facility that would be subject to the 18 CF .R. § 292.205(d) cogeneration requirements?
Yes. Provide in the Miscellaneous section starting on page 19 a description of any relevant changes made to
o the facilty (including the purpose of the changes) and a discussion of why the facility should not be
considered a "new" cogeneration facilit in light of these changes. Skip lines 11 e through 11 j.
No. Applicant stipulates to the fact that it is a "new" cogeneration facilty (for purposes of determining the
o applicabilty of the requiremènts of 18 CF.R. § 292.205(d)) by virte of modifications to the facilty that were
initiated on or after February 2, 2006. Continue below at line 11 e.
11e Wil electric energy from the facilty be sold pursuantto section 210 ofPURPA? 0
o Yes. The facility is an EPAct 2005 cogeneration facilit. You must demonstrate compliance with 18 CF.R. §292.205(d)(2) by continuing at line 11 f below.
No. Applicant certifies that energy wil not be sold pursuant to section 210 of PURPA. Applicant also certifies
o its understanding that it must recertify its facility in order to determine compliance with the requirements of18 CF.R. § 292.205(d) before sellng energy pursuant to secion 210 of PURPA in the future. Skip lines 111
through 11j.
11 f Is the net power production capacity of your cogeneration facilty, as indicated in line 7g above, less than or 0
equal to 5,000 kW?
Yes, the net power production capacity is less than or equal to 5,000 kW. 18 CF.R. § 292.205(d)(4) provides a
rebuttable presumption that cogeneration facilities of 5,000 kW and smaller capacity comply with the
o requirements for fundamental use of the faciltys energy output in 18 CF.R. § 292.205(d)(2). Applicantcertifies its understanding that, should the power production capacity of the facilty increase above 5,000
kW, then the facilty must be recertified to (among other things) demonstrate compliance with 18 CF.R. §
292.205(d)(2). Skip lines 11 g through 11 j.
No, the net power production capacity is greater than 5,000 kW. Demonstrate compliance with the
o requirements for fundamental use of the faciltys energy output in 18 CF.R. § 292.205(d)(2) by continuing on
the next page at line 11 g.
FERC Form 556 Page 13 - Cogeneration Facilities
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~ . cUnes 11 g through 11 k below guide the applicant through the process of demonstrating compliance with the
requirements for "fndamental use" of the facilitys energy output. 18 C.F.R. § 292.205(d)(2). Only respond to the
lines on this page if the instructions on the previous page direc you to do so. Otherwise, skip this page.
18 C.F.R. § 292.205(d)(2) requires that the electrical, thermal, chemical and mechanical output of an EPAct 2005
cogenetion facility is used fundamentally for industrial, commercial, residential or institutional purposes and is
not intended fundamentally for sale to an electric utilty, taking into account technological, efciency, economic,
and variable thermal energ requirements, as well as stte laws applicable to sales of elecc energy from a
qualngfacilit to it hos facilit. If you were direced on the previous pageto repond to the items on this page,
then your facilit is an EPAct 2005 cogeneration facilit that is subjecto this "fndamental use" reuirement.
The Commission's regulations provide a two-pronged approach to demonstrating compliance with the
requirements fOf fundamental use of tlie facilit's energy output. First the Commission has established In 18 C.F.R.
§ 292.205(d)(3) a "fundamental use test" that can be used to demonstrate compliance with 18 C.F.R. § 292.205(d)(2).
Under the fundamental use test, a facilit is considered to comply with 18 C.F.R. § 292.205(d)(2) if at least 50 percent
ofthe facilty's total annual energy output (including electrical, thermal, chemical and mechanical energy output) is
used for industrial, commercial, residential or institutional purposes.
Secc)Ot., an. applicant for ël facility that does not pass the fundamental use test may provide a narrative explanation
of ëlnd support for its contention that the facilty nonetheless meets the requirement that the electrical, thermal,
chemical and mechanical output of an EPAct 2005 cogeneration facilty is used fundamentally for industrial,
commercial, residential or institional purposes and is not intended fundamentally for sale to an elecric utilty,
taking into account technological, effciency, economic, and variable thermal energy requirements, as well as state
laws applicable to sales of electric energy from a qualifying fadlity to its host facilty.
Complete lines llg through 11 j below to determine compliance with the fundamental use test in 18 C.F.R. §
292.205(d)(3). Complete lines llg through llj even if you do not intend to rely upon the fundamental use test to
demonstrate compliance with 18 C.F.R. § 292.205(d)(2).
11 9 Amount of electrical, thermal, chemical and mechanical energy output (net of internal
generation plant losses and parasitic loads) expeced to be used annually for industrial,
commercial, residential or instituional purpses and not sold to an electric utilty MWh
11 h Total amount of elecrical, thermal, chemical and mechanicl energy expected to besold to an elecri utilty MWh
11 i Percentage of total annual energy output expected to be used for industrial, 0
commercial, residential or institional purposes and not sold to a utilty= 100 * 11 g l(llg + 11 h) 0 %
11j Is the response in line 11 i greater than or equal to SO percent?
Yes. Your fadlity complies with 18 C.F.R. § 292.205(d)(2)by virtue of passing the fundamental use test
provided in 18 C.F.R. § 292.205(d)(3). Applicant certifes its understanding that, if it is to rely upon passing
o the fundamental use test as a basis for complying with 18 c.F.R. § 292.205(d)(2), then the facilty must
comply with the fundamental use test both in the 12-month period beginning With the date the facilty first
produces elecric energy, and in all subsequent calendar years.
No. Your facilty does not pass the fundamental use tes. Instead, you must provide in the Miscellaneous
secon starting on page 19 a narrative explanation of and support .for why your facilty mee the
requirement that the electrical, thermal, chemical and mechanicl output of an EPAct 2005 cogeneration
facilty is used fundamentally for industrial, commercial, residential or institional purp and is not
intended fundamentally for sale to an elecric utilit, taking into account technological, effciency, economic,
and variable thermal energy requirements, as well as state laws applicable to sales of elecric energy from a
QF to its host facility. Applicants providing a narrative explanation of why their facility should be found to
o comply with 18 C.F.R. § 292.205(d)(2) in spite of non-eompliance with the fundamental use test may want to
review paragraphs 47 through 61 of Order No. 671 (accessible from the Commission's QF website at
ww.ferc.gov/QF), which provide discussion of the facts and circumstances that may support their
explanation. Applicant should also note that the percentage reported above wil establish the standard that
that facility must comply with, both for the 12-month period beginning with the date the facilit first
produces electric energy, and in all subsequent calendar years. See Order No. 671 at paragraph 51. As such,
the applicant should make sure that it reports appropriate values on lines 11 g and 11 h above to serve as the
relevant annual standard, taking into account expeced variations in production conditions.
FERC Form 556 Page 14 - Topping-Çycle Cogeneration Facilities
Information Required for Topping~Cycle Cogeneration Facility
If you indicated in line lOa that your facilty represents topping-cycle cogeneration technology, then you must respond to
the items on pages 14 and 15 Otherwise skip pages 14 and 15,
The thermal energy output of a topping-eycle cogeneration facility is the net energy made available to an industrial
or commercial process or used in a heating or cooling application. Pursuant to secions 292.202(c), (d) and (h) of the
Commission's regulations (18 C.F.R. §§ 292.202(c), (d) and (h)), the thermal energy output of a qualifyng topping-
cycle cogeneration facility must be usefuL. In connecion with this requirement, descnbe the thermal output of the
topping-ecle cogeneration facilty by responding to lines 12a and 12b below.
12a Identify and describe each thermal host, and specify the annual average rate of thermal output made available
to each host for each use. For hosts with multiple uses of thermal output, provide the data for each use in
separate rows.Average annual rate of
thermal output
attributable to use (net of
Name of entity (thermal host)Thermal hosts relationship to facility heat contained in process
taking thermal output Thermal hosts use of thermal output return or make-up water)
1)Select thermal hosts relationship to facilit
Select thermal hosts use of thermal output Btu/h
2)Select thermal hosts relationship to facilit
Cl Selec thermal hosts use of thermal output BtulhuSelect thermal hosts relationship to facilit~3)U
i Select thermal hosts use of thermal output BtuhC) ..C ::Selec thermal hosts relationship to facility.- C.4)C. ..C. ::Select thermal hosts use of thermal output Btu/h~ 0
5)Select thermal hosts relationship to faciltyl+to0E Select thermal hosts use of thermal output Btu/hVli.
Vl Cl Select thermal hosts relationship to facility(1 .c 6)of i-Select thermal hosts use of thermal output Btu/h~I+o Check here and continue in the Miscellaneous section starting on page 19 if additional space is needed(1Vl~12b Demonstration of usefulness of thermal output: At a minimum, provide a brief description of each use of the
thermal output identified above. In some cases, this brief description is suffcient to demonstrate usefulness.
However, if your faciltys use of thermal output is not common, and/or if the usefulness of such thermal output is
not reasonably clear, then you must provide additional details as necessary to demonstrate usefulness. Your
application may be rejected and/or additional information may be required if an insufcient showing of usefulness
is made. (Exception: If you have previously received a Commission certification approving a specific use of thermal
output related to the instant facility; then you need only provide a brief description of that use and a reference by
date and docket number to the order certifying your facilty with the indicated use. Such exemption may not be
used if any change creates a material deviation from the previously authorized use.) If additional space is needed,
continue in the Miscellaneous section starting on page 19.
o
FERC Form 556 Page 15 - Topping-Cycle Cogeneration Facilities
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Applicants for facilties repreSenting topping-eycle technology must demonstrate compliance with the topping- 0
cycle operating standard and, if applicable, effciency standard. Section 292.205(a)(1) of the Commission's
regulations (18 C.F.R. § 292.205(a)(1)) establishes the operating standard for topping-ecle cogeneration facilites:
the usefl thermal energy output must be no less than 5 percent of the total energy outut Secion 292.205(a)(2)
(1,8 Ç.F,R. § 292,405(a)(2)) establishes the efciency standard for topping-ecle cogeneration facilities for which
installation commenced on or after March 13, 1980: the useful power output of the facilty plus one-half the useful
tl:erl energ.y output must (A) be nO less than 42.5 percent of the total energy input of natural gas and oil to the
façilty ,and (a) if tl:e lIseful thermal energy output is less than 15 percent of the total energy output of the facility,
Re nO i~s t~an 45 perçent of ihe totëllenergy input of natural gas and oil to the facilty. To demonstrate
compliance with the topping-ecle operating and/or effciency standards, or to demonstrate that your facilty is
e)empt frm the effciency stndard based on the date that installation commenced, respond to lines 13a through
13lbelów.
If you indicated in line 10a that your facilty represents both topping-ecle and bottoming-ecle cogeneration
technology, then respond to lines 13a through 131 below considering only the energy inputs and outputs
attbutable to the topping-ecle portion of your facility. Your mass and heat balance diagram must make clear
which mass and energy flow values and system components are for which porton (topping or bottoming) of the
cogeneration system.
13a IndiCate the annual average rate of usefl thermal energy output made available
to the host(s), net of any heat êontaitled in condensate retrn or make-up water Btulh
13b Indicate the an nual average rate of net electrical energy output
13c Multiply line 13b by 3,412 to convert from kW to Btu/h
kW
o Btu/h 0
hp
o Btu/h 0
Btulh
0%0
13d Indicate the annual average rate of mechanical energy output taken directly off
of the shaft of a prime mover for purposes nöt direcly related to power production
(this value is usually zero)
13e Multiply line 13d by 2,54 to convert from hp to Btu/h
13f Indicate the annual average rate of energy input from natural gas and oil
13g Topping-ele operating value"= 100 * 13a /(13a + 13c + 13e)
1'9h Topping-eleefdency value"" 1 00 * (0.5*13a + 13c + 13e) /13f
0%
13j Compliance with operating standard: Is the operating value shown in line 13g greater than or equal to 5%?
o Yes (complies wit operating standard)o No (does not comply with operating standard)
13j Did installation of the facilty in its current form commence on or after March 13, 1980?
DYes. Your facilty Is subjec to the effciency requirements of 18 C.F.R. § 292.205(a)(2). Demonstratecompliance with the effciency requirement by responding to line 13k or 131, as applicable, below.
o No. Your facilty is exempt from the effciency standard. Skip lines 13k and 131.
o
13k Compliance with effciency standard (for low operating value): If the operating value shown in line 13g is less
than 15%, then indicate below whether the effciency value shown in line 13hgreater than or equal to 45%:
o Yes (complies with effciency standard) 0 No (does not comply with effciency standard)
131 Compliance with effdency standard (for high operating value): If the operating value shown in line 13g is
greater than or equal to 15%, then indicate below whether the effciency value shown in line 13h is greater than or
equal to 42.5%:
o Yes (complies with effciency standard) 0 No (does not comply with effciency standard)
FERC Form 556 Page 16 - Bottoming-eycle Cogeneration Facilties
Information Required for Bottoming-Cycle Cogeneration Facility
If you indicated in line lOa that your facility represents bottoming-ecle cogeneration technology, then you must respond
to the items on pages 16 and 17. Otherwise, skip pages 16 and 17.
The thermal energy output of a bottoming-cycle cogeneration facilit is the energy related to the process(es) from 0
which at least some of the reject heat is then used for power production. Pursuant to secions 292.202(c) and (e) of
the Commission's regulations (18 C.F.R § 292.202(c) and (e)) , the thermal energy output of a qualifyng bottoming-
cycle cogeneration facilty must be usefuL. In connection with this requirement, descnbe the process(es) from which
at least some of the rejec heat is used for power production by responding to lines 14a and 14b below.
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14a Identif and describe each thermal host and each bottoming-ecle cogeneration process engaged in by each
host. For hosts with multiple bottoming-cycle cogeneration processes, provide the data for each process in
separate rows.
Name of entit (thermal host)
performing the process from
which at least some of the
rejec heat is used for power
production
Has the energy input to
the thermal host been
augmented for purposes
of increasing power
production capacity?
(if Yes, describe on p. 19)
Thermal host's relationship to facility
Thermal host's process type
1) Select thermal host's relationship to facilty Yes 0 No 0
Select thermal host's process type
2) Selec thermal host's relationship to facility Yes 0 No 0
Select thermal host's process type
3) Select thermal host's relationship to facility Yes 0 No 0
Select thermal host's process type
o Check here and continue in the Miscellaneous secion starting on page 19 if additional space is needed
14b Demonstration of usefulness of thermal output: At a minimum, provide a brief description of each pro.cess
identified above. In some cases, this brief description is suffcient to demonstrate usefulness. However, if your
facility's process is not common, and/or if the usefulness of such thermal output is not reasonably clear, then you
must provide additional details as necessary to demonstrate usefulness. Your application may be rejeced and/or
additional information may be required if an insuffcient showing of usefulness is made. (Exception: If you have
previously received a Commission certification approving a specific bottoming-ecle process related to the instant
facilty, then you need only provide a brief description of that process and a reference by date and docket number
to the order certifying your facility with the indicated process. Such exemption may not be used if any material
changes to the process have been made.) If additional space is needed, continue in the Miscellaneous section
starting on page 19.
FERC Form 556 Page 17 - Bottoming-Cycle Cogeneration Facilities
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Applicants for facilties representing bottoming-eycle technology and for which installation commenced on or after
March 13, 1990 must demonstrate compliance with the bottoming-ecle effciency standards. Section 292.205(b) of
the Commission's regulations (18 C.F.R. § 292.205(b)) establishes the effciency standard for bottoming-ecle
cogeneration facilites: the useful power output of the facility must be no less than 4S pecent of the energy input
of natural gas and oil for supplementary firing. To demonstrate compliance with the bottoming-ecle effciency
standard (if applicable), or to demonstrate that your facilty is exempt from this standard based on the date that
,installation of the facilit began, respond to lines 15a through 15h below.
If you indicated in line 10a that your facility represents both topping-ecle and bottoming-ecle cogeneration
technology, then respond to lines 15a through 15h below considering only the energy inputs and output
attributable to the bottoming-cycle portion of your facility. Your mass and heat balance diagram must make clear
which mass and energy flow values and system components are for which portion of the cogeneration system
(topping or pøttoming).
1 Sa Did instllation of the facility in it current form commence on or after March 13, 19801
o Yes. Your facilty is subject to the effciency requirement of 18 C.F.R. § 292.205(b). Demonstrate compliancewith the effciency requirement by responding to lines 15b through 15h below.
o No. Your facility is exempt from the effciency standard. Skip the rest of page 17.
1Sb Indicate the annual averagE! rate of net elecrical energy output
1Se Multiply line 15b by 3,412 tp cpnvert from kW to Btulh
1Sd Indicate the annual average rate of mechanical energy output taken direcly off
of the shaf of a prime mover for purposes not directly related to power production
(this value is usually zero)
1.$ Multiply line 15d by 2,.S4 to. convert from hp to Bt
1 Sf Indicate the annual average rate of supplementary energy input from natural gas
oroil
159 Bottming-ecle effciency value = 100 * (15c + 15e) /15f ooo %
1 ShCompliance with effcienèY standard: Indicate below whether the effciency valUE! shown in line 15g is greater
than or equal to 45%:
o Yes (complies with effciency standard)o No (does not comply with effciency standard)
FERC Form 556 Page 18 - All Facilties
Certificate of Completeness, Accuracy and Authority
Applicant must certify compliance with and understanding of filing requirements by checking nex to each item below and
signing at the bottom of this section. Forms with incomplete Certificates of Completeness, Accuracy and Authority wil be
rejeced by the Secretary of the Commission.
Signer identified below certifes the following: (check all items and applicable subitems)
He or she has read the filing, including any information contained in any attached documents, such as cogeneration
t8 mass and heat balance diagrams, and any information contained in the Miscellaneous section starting on page 19, and
knows its contents.
IZ He or she has provided all of the required information for certification, and the provided information is true as stated,to the best of his or her knowledge and belief.
IZ He or she possess full power and authority to sign the filing; as required by Rule 2005(a)(3) of the Commission's Rules ofPractice and Procedure (18 C.F.R. § 385.2005(a)(3)), he or she is one of the following: (check one)
o The person on whose behalf the filing is made
o An offcer of the corporation, trust, association, or other organized group on behalf of which the filing is made
o An offcer, agent, or employe of the governmental authority, agency, or instrumentality on behalf of which thefiling is made
18 A representative qualified to practice before the Commission under Rule 2101 of the Commission's Rules ofPractice and Procedure (18 C.F.R. § 385.2101) and who possesses authority to sign
t8 He or she has reviewed all automatic calculations and agrees with their resultsiunless otherwise
noted in the
Miscellaneous section starting on page 19.
He or she has provided a copy of this Form 556 and all attachments to the utilties with which the facilit wil
IZ interconnect and transact (see lines 4a through 4d), as well as to the regulatory authorities of the states in which thefacilty and those utilties reside. See the Required Notice to Public Utilties and State Regulatory Authorities secion on
page 3 for more information.
Provide your signature, address and signature date below. Rule 2005(c) of the Commission's Rules of Praice and
Procedure (18 C.F.R. § 385.2005(c)) provides that persons filing their documents electronically may use typed characters
representing his or her name to sign the filed documents. A person filing this document electronically should sign (by
typing his or her name) in the space provided below.
Peter Richardson
Your address
515 N. 27th Street
Boise, Idaho 83702
DateYour Signature
06/23/2011
Audit Notes
Commission Staff Use Only:o
FERC Form 556 Page 19 - All Facilities
Miscellaneous
Use this space to provide any information for which there was not suffcient space in the previous sections of the form to
provide. For each such item of information clearly identify the fine number that the information belongs to. You may also use
this space to provide any additional information you believe is relevant to the certification of your facilty.
Your response below is not limited to one page. Additional page(s) wil automatically be inserted into this form if the
length of your response exceeds the space on this page. Use as many pages as you require.
BEFORE THE
IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-E-11-14
IDAHO POWER COMPANY
ATTACHMENT NO.2
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WJ JUN 2 4 2011 IJ)
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Richard Hansen, Manager
Tumbleweed Energy ", LLC
7154 W. State Street #330
Boise, Idaho 83714
[phone]
Engr wevrCâhotmail.com
l'v
June 24, 2011
Idaho Power Company
Cogeneration and Small Power Production
P.O. Box 70
Boise, Idaho 83707
1221 West Idaho
Boise, Idaho 83702
(via U.S. Mail and Hand delivery)
Re: 10 MW Wind QF Contract Request - Oregon Off-System Project
Dear Sir or Madam:
Please accept this request for an Energy Sales Agreement pursuant to Oregon PUC rate
Schedule 85-4 "Cogeneration and Small Power Production Standard Contract Rates". We are
interested in obtaining a final execution ready Energy Sales Agreement for the Tumbleweed
Energy Wind Farm ten MW project located in Elmore County, Idaho for delivery to Idaho
Power's service territory in Oregon pursuant to the above referenced tari. Section 2(b) of
Schedule 85-4 requires the following information to be provided in order for you to provide a
draft Energy Sales Agreement within fifteen business days (see § 2 (d)):
a. Date of Request: June 22, 2011;
b. Company/Organization that wil be the contracting Party: Tumbleweed Energy, LLC;
c. Contact Notifcation information including, name, address and telephone: See above
address and phone contact information;
d. Verication that the Qualifying Facilty meets the "Eligibilty for Standard Rates and
Contract" criteria; I hereby verify that the Tumbleweed project is a small power
production facilty which meets the PURPA criteria for qualification set forth in Subpart B
of Part 292, subchapter K, Chapter 1, Title 18 of the Code of Federal Regulations;
e. Copy of the Qualifying Facilty's QF certificate: Attached;
f. Copy of FERC license (applicable to hydro projects only): N/A;
g. Location of the proposed project including specific equipment models, types, sizes and
configurations: Canyon Creek Ranch, Township 2, South, Range 6 East, Boise Meridian,
Elmore County, Idaho. Four 2.5 MW Nordic manufactured 80 meter wind turbines.
h. Description of the proposed project including specific equipment models, types, sizes
and configurations; see "g";
i. Type of project (wind, hydro, geothermal etc.): Wind;
j. Nameplate capacity of the Qualifying Factility: 10 MW;
k. Schedule 85 pricing option selected: Option 1, Fixed Price Method;
i. Desired term of the Energy Sales Agreement: Fifteen (15) years;
m. Annual net energy amount: 27,156,000 kwh;
n. Maximum capacity of the Qualifying Facility: 10,000 kw
o. Estimated first energy date: December 1,2012;
p. Estimated first operation date: January 1, 2013;
q. Point of Delivery: Idaho Power service territory in Oregon, likely the Ontario or Nyssa
Substation, with the final Point of Delivery to be determined by Idaho Power
Transmission Business Line;
r. Status of the Generation Interconnection Process: Interconnection Process is complete
with the Final Feasibilty Study executed on December 10, 2010 for Project No. 332 in
the Idaho Power Interconnection Queue.
It is our understanding that, pursuant to Schedule 85 that we may expect a draft Energy Sales
Agreement fifteen busines days from today. ase do not hesitate to give me a call if you
have any questions.
Sincerely yours,
Richard Hansen, Manger
Tumbleweed Energy LLC
BEFORE THE
IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-E-11-14
IDAHO POWER COMPANY
ATTACHMENT NO.3
\J k~ Y\úfl clx \ hJ lU..L\
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W JUN 2 4 2011 W
CS
Richard Hansen, Manager
Tumbleweed Energy II, LLC
7154 W. State Street #330
Boise, Idaho 83714
[phone]
Enegr wevr~hotmail.com
By
June 24,2011
Manager Grid Operations
Idaho Power Company
1221 West Idaho
Boise, Idaho 83702
(via U.S. Mail and Hand delivery)
Idaho Power Company
Re: 10 MW Wind Firm Point-to-Point Transmission Service Request
Dear Sir or Madam:
Please accept this request for a Firm Point-to-Point transmission agreement pursuant to Idaho
Powets Open Access Transmission Tariff, FERC Electric Tariff First Revised Volume
No.6, Section 17, "Procedures for Arranging Firm Point-to-Point Transmission Service.
Service is to begin on December 1,2012.
a. Identity of the entity requesting service: Tumbleweed Energy, see above address and
phone contact information;
b. Tumbleweed Energy is, or wil be upon commencement of service, an Eligible Customer
under the Tariff:
c. The Point of Receipt is the 138 mV system at a new substation (Station 331) located
under the Mountain Home Junction (MNJ1) Lucky Peak (LYPK) 138 sub-transmission
line. Copy of FERC license (applicable to hydro projects only): N/A;
d. The project wil supply wind energy and capcity from four 2.5 MW Nordic manufactured
80 meter wind turbines.
e. The receiving part, Idaho Powets Oregon jurisdiction, wil receive approximately
27,000,000 kwh of energy and capacity associated with a 10 MW wind project.
f. The Commencement Date of the requested transmission service is December 1, 2012;
g. The transmission capacit requested for the Point of Receipt and the Point of Delivery is
10MW.
h. Tumbleweed Energy is committed to executing a Service Agreement upon notification
that the Transmission Provider can provide the requested Transmission Serivce.
i. Tumbleweed Energy wil provide such additional information as requested by the
Transmission Provider.
It is our understanding that, pursuant to the OA IT that we may expect a response within fifteen
business days from today as to whether this application for Firm Point-to-Point Transmission
Service is complet. Tumbleweed stands ready to post necessary deposit equal to one month's
transmission service charge. That said, we respectfully request that Idaho Power waive said
charge in the even that Tumbelweed meets applicable credit worthiness requirements.
Sincerely yours,
Richard Hansen, i(anger
Tumbleweed Energy LLC
BEFORE THE
IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-E-11-14
IDAHO POWER COMPANY
ATTACHMENT NO.4
An 10ACORP Company
DONOVAN E. WALKER
Lead Counsel
dwalker(idahopower.com
June 8,2011
VIA ELECTRONIC MAIL & U.S. MAIL .
engrwevr(âhotmail.com
Richard Hansen, Manager
Tumbleweed Energy II, LLC
7154 W. State Street #330
Boise, Idaho 83714
Re: Invalid Request - Your June 24, 2011, Ten Megawatt Wind Qualified
Facilty ("QF") Contract Request - Oregon Off-S.ystem Project
Dear Mr. Hansen:
This letter is in response to your request for an Energy Sales Agreement
pursuant to Idaho Power Company's ("Idaho Powet') Oregon Tariff Schedule 85,
Cogeneration and Small Power Production Standard Contract Rates (March 1, 2010).
Because your proposed QF project is located in the state of Idaho, with an
interconnection to Idaho Powets system in the state of Idaho, if your project wishes to
obtain a power sales agreement pursuant to the Public Utilty Regulatory Policies Act of
1978 ("PURPA"), it must do so according to the Idaho Public Utilties Commission's
PURPA rates, rules, and regulations - not Oregon's.
Idaho Power intends to file a case with the Idaho Public Utilities Commission
determining the same on today's date. Idaho Power wil forward a copy of said filing to
you under separate cover.
uJ fX
Donovan E. Walker
DEW:csb
cc: Peter J. Richardson
1221 W. Idaho St. (83702)
P.O. Box 70
Boise. 10 83707
~IDA~PO~
An IOACORP company
July 8,2011
Richard Hansen, Manager
Tumbleweed Energy II, LLC
7154 W State Streed #330
Boise, ID 83714
Re: Invalid Application - 10MW FIRM PTP TSR reques for TumbleWeed Energy
Dear Mr. Hansen:
This letter is to serve as formal notification that we have received your request for Firm Point-to-Point (PT)
transmission. However, due to the method of submittal, it has been considered as an invalid application.
All Transmisison Service Request (TSRs), short term or long term, must be made on OASIS to estblish a
queue position. The information provided in your letter wil also need to accompany the OASIS reqeust. To
make a request on OASIS, you wil need to become an actve Idaho Power trnsmission customer. The
customer reistation proes can be found in secton 1 of our Busines Practces. Our Business Practces
are located on OASIS witin the Business Practce folder, All other required documents for customer
registration are also locted on OASIS under the Customer service-Transmission folder.
Please let me know if you have any questions or need any assistnce in the customer registation proess.
Beth Ryan
Operations Analyst
208.388.2846
BRyan(iidahopower .com
cc: Kathy Andersn
Donovan Walker
P.O. Box 70 (83707)
1221 W. Idaho St.
Boise, 10 83702
BEFORE THE
IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-E-11-14
IDAHO POWER COMPANY
ATTACHMENT NO.5
\ lÀ cU' \\)~
mæ (l æ 0 \T æ~i
ilu JUN 27 2011 ~
~:ß ~r~((I~l'ATTORNEYS AT LAW
By Peter Richardson
Tel: [phone] Fax: [phone]
peterli richardson and oJ eary. com
P.O. Box 7218 Boise, 10 83707 - 515 N. 27th St. Boise. ID 83702
June 27, 2011
Donovan Walker
Idaho Power Company
1221 West Idaho Street
Boise, Idaho
Via hand delivery
Re: FERC Form 556 - Western Desert Energy 1, LLC
Dear Donovan:
Enclosed please find a competed FERC Form 556 for the Western Desert Energy 1,
LLCproject located in Owwee County, Idaho.
This form is being provided to you pursuat to FERC's rues that require a copy be
provided to all utilties with which the fiing QF will interconnect and/or transact. Idaho
Power will provide both services to Western Desert Energy 1, LLC.
Please feel free to give me a call if you have any questions.
Sincerely:d~
PÍ!e Richardson
Attorney for Western Desert Energy 1, LLC
Form 556
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, DC
Certification of Qualifying Facility (QF) Status for a Small Power
Production or Cogeneration Facilty
OMB Control # 1902-0075
Expiration 5/31/2013
General
Questions about completing this form should be sent to form556(Gferc.gov. Information about the Commission's QF
program, answers to frequently asked questions about QF requirements or completing this form, and contact information for
QF program stff are available at the Commission's QF website, ww.ferc.gov/QF. The Commission's QF website also
provides links to the Commission's QF regulations (18 C.F.R. § 131.80 and Part 292), as well as other statutes and orders
pertining to the Commission's QF program.
Who Must File
Any applicant seeking QF status or recertification of QF status for a generating facilty with a net power production capacity
(as determined in lines 7a through 7g below) greater than 1000 kW must file a self-certification or an application for
Commission certifcation of QF status, which includes a properly completed Form 556. Any applicant seeking QF status for a
generati"f facilit with a net power production capacity 1000 kW or less is exempt from the certification requirement and is
therefore not required to complete or file a Form 556. See 18 C.F.R. § 292.203.
How to Complete the Form 556
This form is intended to be completed by responding to the items in the order they are presented, according to the
instructions given. If you need to back-track, you may need to clear certain responses before you wil be allowed to change
other responses made previously in the form. If you experience problems, click on the nearest help button (.) for
asistance, or contact Commission staff at FormS56Øferc.gov.
Certin lines in this form wil be automatically calculated based on responses to previous lines, with the relevant formulas
shown. You must respond to all of the previous lines within a section before the results of an automatically calculated field
wil be displayed. if you disagree with the results of any automatic calculation on this form, contact Commission staff at
Form556erc.gov to discuss the discrepancy before filing.
You must complete a'ilines in this form unless instructed otherwise. Do not alter this form or save this form in a different
format. Incomplete or altered forms, or forms saved in formats other than PDF, wil be rejected.
How to File a Completed Form 556
Applicants are reuired to file their Form 556 electronically through the Commission's eFilng website (see instructions on
page 2). By filing elecronically, you wil reduce your filing burden, save paper resources, save postage or courier charges,
help keep Commission expenses to a minimum, and receive a much faster confirmation (via an email containing the docket
number assigned to your facilit) that the Commission has received your filing.
If you are simultneously filing both a waiver request and a Form 556 as part of an application for Commission certification,
see the "Waiver Request" section on page 3 for more information on how to file.
Paperwork Reduction Act Notice
This form is approved by the Ofce of Management and Budget (OMB Control No. 1902..075, expiration 05/31/2013).
Compliance with the information requirements established by the FERC Form No. 556 is required to obtain or maintain status
as a OF. See 18 CJ.R. § 131.80 and Part 292. An agency may not conduct or sponsor, and a person is not required to respond
to, a collecon of information unless it displays a currently valid OMB control number. The estimated burden for completing
the FERC Form No. 556, including gathering and reporting information, is as follows: 3 hours for self-certification of a small
power produetonfacilty, S hours for self-certifcations of a cogeneration facilty, 6 hours for an application for Commission
certification of a small power production facilty, and 50 hours for an application for Commission certification of a
cogeneration facilty. Send comments regarding this burden estimate or any aspect of this collection ofinformation,
including suggestions for reducing this burden, to the following: Information Clearance Ofcer, Ofce of the Executive
Direcor (ED-32), Federal Energy Regulatory Commission, 888 First Street N.E., Washington, DC 20426; and Desk Ofcer for
FERC, Ofce of Information and Regulatory Affairs, Offce of Management and Budget Washington, DC 20503
(oira submission(âomb.eop.gov). Include the Control No. 1902..075 in any correspondence.
FERC Form 556 Page 2 -Instructions
Electronic Filing (eFiling)
To electronically file your Form 556, visit the Commission's QF website at ww.ferc.govIOF and click the eFilng link.
If you are eFilng your first document, you wil need to register with your name, email address.mailng address, and phone
number. If you are registering on behalf of an employer, then you wil also need to provide the employer name, alternate
contact name, alternate contact phone number and and alternate contact email.
Once you are registered, log in to eFilng with your registered email address and the password that you created at
registration. Follow the instructions. When prompted, selec one of the following Qr-related filing types, as appropriate,
from the Electric or General filing category.
Filng category Filng Type as listed in eFilng Description
Use to submit an application for
(Fee) Application for Commission Cert. as. Cogeneration QF Commission certifcation or
Commission recertification of a
cogeneration facilty as a QF.
Use to submit an application for
Commission certification or
(Fee) Application for Commission Cert. as Small Power QF Commission recertification of a
small power production facility as a
QF.
Use to submit a notice of self-
Self-Certification Notice (QF, EG, FQ certification of your facilty
(cogeneration or small power
production) as a QF.
Electric Use to submit a notice of self-
Self-Recertification of Qualifying Facility (QF)
recertification of your facility
(cogeneration or small power
production) as a QF.
Use to corre or supplement a
Form 556 that was submitted with
errors or omissions, or for which
Commission staff has requested
additional information. Do not use
Supplemental Information or Request this filing type to report new
changes to a facility or its
ownership; rather, use a self-
recertifcation or Commission
recertifcation to report such
changes.
Use to submit a petition for
declaratory order granting a waiver
of Commission QF regulations
pursuant to 18 C.F.R. §§ 292.204(a)
General (Fee) Petition for Declaratory Order (not under FPA Part 1)(3) and/or 292.205(c). A Form 556 is
not required for a petition for
declaratory order unless
Commission recertification is being
requested as part of the petition.
You wil be prompted to submit your filing fee, if applicable, during the elecronic submission process. Filng fees can be paid
via electronic bank account debit or credit card.
During the eFilng process, you wil be prompted to selec your file(s) for upload from your computer.
FERC Form 556 Page 3 - Instructions
Filng Fee
No filing fee is required if you are submitting a self-eertification or self-recertification of your facilit as a QF pursuant to i 8
c.F.R. § 292.207(a).
A filing fee is required if you are filing either of the following:
(1) an application for Commission certification or reertification of your facilty as a QF pursuant to i 8 C.F.R. § 292.207(b), or
(2) a petition for declaratory order granting waiver pursuant to i 8 C.F.R. §§ 292.204(a)(3) and/or 292.205(c).
The current fees for applications for Commission certifcations and petitions for declaratory order can be found by visiting the
Commissi.on's QF website at ww,ferç.gov¿çF and clicking the Fee SChedule link.
You wil be prompted to submit your filing fee, if applicable, during the electronic filing process described on page 2.
Required Notice to Utilties and State Regulatory Authorities
Pursant to 18 C.F.R. § 292.207(a)(ii), you must provde a copy of your self-eertification or request for Commission certifcation
to the utilties with which the facility wil interconnec and/or transact, as well as to the State regulatory authorities of the
states in which yourfacilit and those utilties reside. Links to information about the regulatory authorities in various states
can be found by visiting the Commission's QF website at ww,ferc.gov¿çF and clicking the Notice Requirements link.
What to Expect From the Commission After You File
An applicant filing a Form 556 elecronically wil receive an email message acknowledging receipt of the filing and shoing
the docke number assigned to the filing. Such email is typically sent within one business day, but may be delayed pending
confirmation by the Secretary of the Commission of the contents of the filing.
An applicant submitting a self-eertification of QF status should expect to receive no documents from the Commission, other
than the elecronic ackowledement of receipt described above. Consistent with its name, a self-eertifcation is a
certification by the applicant itself that the facilty meets the relevant requirements for QF status, and does not involve a
determination by the Commission as to the status of the facilty. An ackowledgement of receipt of a self-ertlfication, in
particular, does not represent a determination by the Commission with regard to the QF status of the facilty. An applicant
self-eertifng may, howev, receive a rejection, revocation or defiiency letter if its application is found, during periodic
compliance reviews, not to comply with the relevant requirements.
An applicant submittng a request for Commission certifcation wil receive an order either granting or denying certification of
QF status, or a leter requesting additional information or rejecting the application. Pursuant to 18 C.F.R. § 292.207(b)(3), the
Commission must act on an application for Commission certification within 90 days of the later of the filing date of the
application or the filing date of a supplement, amendment or other change to the application.
Waiver Requests
i 8 C.F.R. § 292.204(a)(3) allows an applicant to request a waiver to modify the method of calculation pursuant to i 8 C.F.R. §
292.204a)(2) to determine if two facilties are considered to be locted at the same site, for good cause. i 8 C.F.R. § 292.205(c)
allows an applicant to request waiver of the requirements of i 8 C.F.R. §§ 292.205(a) and (b) for operating and efciency upon
a showing that the facilty wil produce signifcant energy savings. A request for waiver of these requirements must be
submitted as a petition for declaratory order, with the appropriate filing fee for a petition for declaratory order. Applicants
requesting Commission recertcation as part of a request for waiver of one of these requirements should electronically
submit their completed Form 556 along with their petition for declaratory order, rather than filing their Form 556 as a
separate request for Commission recertification. Only the filing fee for the petition for declaratory order must be paid to
cover both the waiver request and the request for recertification if such requests are made simultaneously.
i 8 C.F.R. § 292.203(d)(2) allows an applicant to request a waiver of the Form 556 filing requirements, for good cause.
Applicants filing a petiton for declaratory order requesting a waiver under 18 C.F.R. § 292.203(d)(2) do not nee to complete
or submit a Form 556 with their peition.
FERC Form 556 page 4 -Instructions
Geographic Coordinates
If a street address does not exist for your facility, then line 3c of the Form 556 requires you to report your faciltys geographic
coordinates (latitude and longitude). Geographic coordinates may be obtained from several different sources. You can find
links to online services that show latitude and longitude coordinates on online maps by visiting the Commission's QF
webpage at ww.ferc.govtOF and clicking the Geographic Coordinates link. You may also be able to obtain your geographic
coordinates from a GPS device, Google Earth (available free at http:/earth.google.com), a propert survey, various
engineering or construction drawings, a propert deed, or a municipal or county map showing propert lines.
Filng Privileged Data or Critical Energy Infrastructure Information in a Form 556
The Commission's regulations provide procedures for applicants to either (1) request that any information submitted with a
Form 556 be given privileged treatment because the information is exempt from the mandatory public disclosyre
requirements of the Freeom of Information Act, 5 U.S.C § 552, and should be withheld from public disclosure; or (2) identif
any documents containing critical energy infrastructure information (CEil as defined in 18 CF.R. § 388.113 that should not be
made public.
If you are seeking privileged treatment or CEil status for any data in your Form 556, then you must follow the procedures in 18
CF.R. § 388.112. See ww.ferc.gov/help/fiing=guidetfle-eii.aspfor more information.
Among other things (see 18 CF.R. § 388.112 for other requirements), applicants seeking privileged treatment or CEil status for
data submitted in a Form 556 must prepare and file both (l a complete version ofthe Form 556 (containing the privileged
and/or CEil data), and (2) a public version of the Form 556 (with the privileged and/or CEil data redacted). Applicants
preparing and filing these diferent versions of their Form 556 must indicate below the securit designation of this version of
their document. If you are not seeking privileged treatment or CEil status for any of your Form 556 data, then you should not
respond to any of the items on this page.
Non-Public: Applicant is seeking privileged treatment and/or CEil status for data contained in the Form 556 lines
o inciicated below. This non-public version of the applicant's Form 556 contains all data, including the data that is redacted
in the (separate) public version of the applicant's Form 556.
Public (reacted): Applicant is seeking privileged treatment and/or CEil sttus for data contained in the Form 556 lines
o indicated below. This public version of the applicants's Form 556 contains ¡!II data except for data from the lines
indicated below, which has been redacted.
Priileged: Indicate below which lines of your form contain data for which you are seeking pnvileged treatment
Critical Energy Infrastructure Information (CEIl): Indicate below which lines of your form contain data for which you are
seeking CEil status
The eFilng process described on page 2 wil allow you to identif which versions of the elecronic documents you submit are
public, privileged and/or CEil. The filenames for such documents should begin with "Public", "Priv", or "CEIl", as applicable, to
clearly indicate the security designation of the file. Both versions of the Form 556 should be unaltered PDF copies of the Form
556, as available for download from www.ferc.gov/OF. To redact data from the public copy of the submital, simply omit the
relevant data from the Form. For numerical fields, leave the redacted fields blank. For text fields, complete as much of the
field as possible, and replace the redacted portions of the field with the word "REDACTED" in brackets. Be sure to identify
above all fields which contain data for which you are seeking non-public status.
The Commission is not responsible for detecting or correcting filer errors, including those errors related to security
designation. If your documents contain sensitive information, make sure they are filed using the proper security designation.
FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, DC
F 0 r m. 5 5 6 Certification of Qualifying Facility (QF) Status for a Small PowerProduction or Cogeneration Facility
OMS Control # 1902-0075
Expiration 5/3112013
1a Full name of applicant (legal entity on whose behalf qualifyng facilty status is sought for this facilty)
Western Desert Energy 1,LLC
1 b Applicant street address
1770 West State Street #317
1c City 1d State/province
Boise Idaho
1e Postl code 1f Country (if not United States)1 9 Telephone number
83702 [phone]
1h Has the instant facilit ever previously been certified as a QF?Yes 0 No iz
1i if yes, provide the docket number of the last known QF filing perining to this facilty QF -----
1j Under which certifcation process is the applicant making this filing?
iz Notice of self"Certification o Application for Commission certifcation (requires filingc:(see note below)fee; see "Filng Fee" secon on page 3)
0 Note: a notice of self..rtifieaion is a notice by the applicat itslf that its facili complies with the requirements for..¡
QF statUs. A notice of self "Certification does not establish a proceeing, and the Commission does not review a('
E notice of self-certification to verify compliance. See the "What to Expect From the Commission After You File"
"-secion on page 3 for more information.
J2 1k What ty(s) of QF statusis the applicant seeking for its fadlity? (check all that apply)c:-
c:iz Qualifng small power production facilit status o Qualifing cogeneration fadlit status0"P 1. What i$the purpose and expeced efecive date(s) ofthis filing?('.~iz Original certcation; facilit expeced to be installed by 12/1/12 and to begin operation on 12/1/12
1S
o Change(s) to a previously certifed facilit to be effecive on0-c:(identify type(s) of change(s) below, and describe change(s) in the Miscellaneous secion starting on page 19)
o Name change and/or other administrative change(s)
o Change in ownership
o Change(s) affecting plant equipment, fuel use, power production capàcit and/or cogeneration thermal output
o Supplement or correction to a previous filing submitted on
(describe the supplement or correcion in the Miscellaneous secion starting on page 19)
1m If any of the following three statements is true, check the box(es) that describe your situation and complete the form
to the exent possible, explaining any special circumstances in the Miscellaneous section starting on page 19.
o The instant facilty complies with the Commission's QF requirements by virte of a waiver of certain regulationspreviously granted by the Commission in an order dated (specify any other relevant waiver
orders in the Miscellaneous secion starting on page 19)
o The instant facilit would comply with the Commission's QF requirements if a petition for waiver submitedconcurrently with this application is granted
The instant facility complies with the Commission's regulations, but has special circumstances, such as the
o employment of unique or innovative technologies not contemplated by thé structure of this form, that make
the demonstration of compliance via this form diffcult or impossible (describe in Misc. section starting on p. 19)
o
o
oo
o
o
FERC Form 556 Page 6 - All Facilties
2a Name of contact person 2b Telephone number
Sandy Sanderson [phone]
2c Which of the following describes the cont¡:ct person's relationship to the applicant? (check one)
i:o Applicant (self)o Employee, owner or partner of applicant authorized to represent the applicant
0 i; Employee of a company affliated with the applicant authorized to represent the applicant on this matter+:ra o Lawyer, consultant, or other representative authorized to represent the applicant on this matterE
2d Company or organization name (if applicant is an individual, check here and skip to line 2e) 0~
J2 Western Desert Energy 1,LLCi:-,¡2e Street address (if same as Applicant, check here and skip to line 3a) i;Ura,¡i:0U
2f City 29 State/province
2h Postal code 2i Country (if not United States)
3a Facilty namei:Western Desert Energy 1,Wind Proj ect0+:3b Street address (if a street address does not exist for the facilty, check here and skipto line 3c)i;raU0..
'"i:ra 3c Geographic coordinates: If you indicated that no street address exists for your facilty by checking the box in line 3b,i:then. you must spec, tbelatitude and longitude coordinates of the facilty in degre (to three deçimal places). Use0the following formula to convert to decimal degrees from degrees, minutes and seconds: deçimal degres =''¡
ra degrees + (minutes/60) + (seconds/3600).See the "Geographic Coordinates" secion on page 4 for help. If youUprovided a street address for your facilty in line 3b, then specifing the geographic coordinates below is optional.~''¡
o East(+)i; North (+)i:Longitude 116.960 degrees Latitude 43.130 degreesQ)i; WestH o Soutb(-)'"~3d City (if unincorporated, check here and enter nearest city) C8 3e State/province
,,!Jordan Valley Oregon
.0
3f County (or cheçk here for independent city) 0 ra 39 Country (if not United States)LL
Owyhee County,Idaho .
Identify the electric utilties that are contemplated to transact with the facility.
VI .
Q)4a Identify utilty interconnecting with the facilty
:€Idaho Power Company
+::)4b Identify utilties providing wheeling service or check here if none 0
O'Idaho Power Companyi:,¡4c Identif utilties purchasing the useful elecric power output or check here if none 0uroIdaho Power CompanyVIi:ra 4d Identify utilties providing supplementary power, backup power, maintenance power, and/or interruptible power~i-service or check here if none 0
Idaho Power Company
o
o
o
o
o
o
FERC Form 556 Page 7 - All Facilties
Sa Direct ownt!rship as of efecive date or operation date: Identify all direc owners of the facility holding at least 10
percent equity interest. For each identified owner, also (1) indicate whether that owner is an electric utilty, as
defned in seion 3(22) of the Federal Power Act (16 U.S.c. 796(22)), or a holding company, as defned in secion
1262(8) of the Public Utilty Holding Company Act of 2005 (42 U.S.c. 16451(8)), and (2) for .owners which are elecric
utilties or holding companies, provide the percentage of equity interest in the facilit held by that owner. It no
direc owners hold at least 10 percent equity interest in the facility, then provide the required information for the
two direc owners with the largest equit interest in the facilty.
Elecric utilty or It Yes,
holding % equity
Full legal names of direc owners company interest
1)Brad Christianson YesD No ~%
2)Craig Christianson YesD No ~%
3) Mike Chase YesD No~%
4)YesD NoD %
5)YesD NoD %
6)YesD NoD %
7)YesD No D %
8)YesD No D %i:0 9)YesD No D %.'¡
(0 10)YesD No D %-(J
o Check here and continue in the. Miscellaneous section starting on page 19 ifadditional space is neededc.0
"'Sb UPsream (i.e., indirec) ownership as of èffective date or operation date: Identifall upstream (i.e., indirect) ownersc:of the facilit that both (1) hold at least 10 percent equity interest in the facilit, and (2) are elecric utilties, as(0c.defint! in seign3(22) of the Federal PowerAct (16 U.S.C. 796(22)), or holding companies, as defined in section.-1262(8) of thep;ublic Utlity Holding Company Act of 2005 (42 U.s.c. 16451 (8)). Also provide the percentage of.iII equity interest in the facilit held by such owners. (Note that, because upsream owners may be subsidiaries of one-another, total percent equity interest reported may excee 100 percent.)(Jc:
~Check here if no such upstream owners exist. ~0 % equity
Full legal names of elecric utilty or holding company upstream owners interest
1 )%
2)%
3)%
4)%
5)%
6)%
7)%
8)%
9)%
10)%
D Check here and continue in the Miscellaneous section starting on page 19 if additional space is needed
Se Identify the facility operator
Western Desert Energy i,LLC
o
FERC Form 556 Page 8 - All Facilities
6a Describe the primary energy input (check one main category and, if applicable, one subcategory)
o Biomass (specify)
o Landfill gas
o Geothermal
o Fossil fuel (specify)
o Coal (not waste)
o Fuel oil/diesel
o Natural gas (not waste)
rg Renewable resources (specify)
o Hydro power - river
o Hydro power - tidal
o Hydro power - wave
o Solar - photovoltaic
o Solar - thermal
o Other biomass (describe on page 19) 18 Wind
o Other renewable resource 0 Other (describe on page 19)(describe on page 19)
6b If you specifed "waste" as the primary energy input in line 6a, indicate the type of waste fuel used: (check one)
o Manure digester gas
o Municipal solid waste
o Sewage digester gas
o Wood Other fossil fuel
o (describe on page 19)
o Waste (specify tye below in line 6b)
+-::0-C~01i.
QJc:W
o Waste fuel listed in 18 CF.R. § 292.202(b) (specif one of the following)
o Anthracite culm produced prior to July 23, 1985
o Anthracite refuse that has an average heat content of 6,000 Btu or less per pound and has an averageash content of 45 percent or more
o Bituminous coal refuse that has an average heat content of 9,500 Btu per pound or less and has anaverage ash content of 25 percent or more .
Top or bottom subbituminous coal produced on Federal lands or on Indian lands that has been
determined to be waste by the United States Department of the Interiots Bureau of land Managemento (BLM) or that is located on non-Federal or non-lndian lands outside of BLM's jurisdiction, provided that
the applicant shows that the latter coal is an exension of that determined by BLM to be waste
Coal refuse produced on Federal lands or on Indian lands that has ben determined to be waste by the
o BlM or that is located on non- Federal or non-Indian hands outside of BLM's jurisdiction, provided that
applicant shows that the latter is an exension of that determined by BLM to be waste
o lignite produced in association with the production of montan wax and lignite that becomes exposeas a result of such a mining operation
o Gaseous fuels (except natural gas and synthetic gas from coal) (describe on page 19)
Waste natural gas from gas or oil wells (describe on page 19 how the gas meets the requirements of 18
o C.F.R. § 2.400 for waste natural gas; include with your filing any materials necessary to demonstrate
compliance with 18 C.F.R. § 2.400)
o Materials that a government agency has certified for disposal by combustion (describe on page 19)
o Heat from exothermic reactions (describe on page 19) 0 Residual heat (describe on page 19)
o Used rubber tires 0 Plastic materials 0 Refinery off-gas 0 Petroleum coke
Other waste energy input that has little or no commercial value and exists in the absence of the qualifing
o facility industry (describe in the Miscellaneous section starting on page 19; include a discussion of the fuel's
lack of commercial value and existence in the absence of the qualifying facilit industry)
6c Provide the average energy input, calculated on a calendar year basis, in terms of Btulh for the following fossil fuel
energy inputs, and provide the related percentage of the total average annual energy inputto the facilty (18 C.F.R. §
292.2020)). For any oil or natural gas fuel, use lower heating value (18 C.F.R. § 292.202(m)).
Fuel
Natural gas
Oil-based fuels
Coal
Annual average energy
input for specified fuel
Percentage of total
annual energy input
0%o Btulh
o Btu/h
o Btu/h
0%
0%
FERC Form 556 Page 9 - All Facilties
Indicate the maximum gross and maximum net elecric power production capacity of the facility at the point(s) of
delivery by completing the worksheet below. Respond to all items. If any of the parasitic loads and/or losses identifed in
lines 7b through 7e are negligible, enter zero for those lines.
7a The maximum gross power production capacity at the terminals of the individual generator(s)
under the most favorable anticipated design conditions 2,500 kW
7b Parasitic station power used at the facility to run equipment which is necessary and integral to
the power production process (boiler feed pumps, fans/blowers, offce or maintenance buildings
direcly related to the operation of the power generating facility, etc.). If this facility indudes non-
power prpuction processe (for instnce, power consumed by a cogeneration facilty's thermal
host , do not indude any power consumed by the non-power production activities in yourreported parasitic station power. 6 . 2 kW
7c Eleciiallosses in interconnection transformers
18.7 kW
7d Elecrical losses in ACIDC conversion equipment, if any
o kW
7e Other interconnecion losses in power lines or facilities (other than transformers and ACIC
conversion equipment) between the terminals of the generator(s) and the point of interconnection
with the utilit
7f Total deductions from gross power production capacity = 7b + 7c + 7d + 7e
25 kW
49.9 kW 0i:o+:ta
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7g Maximum net power production capacity = 7a - 7f
2,450.1 kW
7h Description of facilty and primary components: Describe the facility and its operation. Identify all boilers, heat
recovery steam generators, prime movers (any mechanical equipment driving an elecric generator), elecrical
generators, photovoitaic solar equipment, fuel cell equipment and/or other primary power generation equipment
osed in the facilit. Descptions of components should include (as applicable) specifcations of the nominal
capacites for mechanical output, elecrical output or steam generation of the identifed equipment. For each piece
of equipment identifed, clearl indicate how many pieces of that type of equipment are included in the plant, and
which components are normally operating or normally in standby mode. Provide a descripton of how the
components operate as a system. Applicants for cogeneration facilities do not need to describe operations of
sysems that are c1early depicted on and easily understandable from a cogeneration facilitys attached mass and
heat balance diagram; however, such applicants should provide any necessary description neeed to understand
the sequential operation of the facility depicted in their mass and heat balance diagram. If additional space is
needed, continue in the Miscellaneous section starting on page 19.
Western Desert Energy 1f LLC will consist of two 2.5 MW GE 100 meter wind
turbines.
FERC Form 556 Page 10 - Small Power Production
Information Required for Small Power Production Facility
If you indicated in line 1 k that you are seeking qualifying small power production facilty status for your facility, then you
must respond to the items on this page Otherwise, skip page 10
Pursuant to 18 C.F.R. § 292.204(a), the power production capacity of any small power production facility, together
with the power production capacity of any other small power production facilties that use the same energy
resource, are owned by the same person(s) or its affliates, and are located at the same site, may not exceed 80
megawatts. To demonstrate compliance with this size limitation, or to demonstrate that your facility is exempt
from this size limitation under the Solar, Wind, Waste, and Geothermal Power Production Incentives Act of 1990
(Pub. L. 101-575,104 Stat. 2834 (1990) as amended by Pub. L.l02-4, 105 Stat. 249 (1991)), respond to lines 8a
through 8e below (as applicable).
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8a Identify any facilities with elecrical generating equipment located within 1 mile of the elecrical generating
equipment of the instant facility, and for which any of the entities identified in lines 5a or 5b, or their affliates, holds
at least a 5 percent equity interest.
Check here if no such facilties exist. I:
Facility location
(city or county, state)
o
Root docket #
(if any)
Maximum net power
production capacitCommon owner(s)
1 )QF -kW--
2)QF -kW--
3)QF -kW--
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o Check here and continue in the Miscellaneous section starting on page 19 if additional space is neeed
8b The Solar, Wind, Waste, and Geothermal Power Production Incentives Act of 1990 (Incentives Act) provides
exemption from the size limitations in 18 C.F.R. § 292.204a) for certin facilties that were certifed prir to 1995.
Are you seeking exemption from the size limitations in 18 C.F.R. § 292204(a) by virtue of the Incentives Act?
o Yes (continue at line 8c below) I: No (skip lines Bc through 8e)
8e Was the original notice of self-certification or application for Commission certification of the facility filed on or
before December 31, 19941 YesD No 0
8d Did construction of the facility commence on or before December 31, 1999? Yes 0 No 0
8e If you answered No in line 8d, indicate whether reasonable dilgence was .exercised toward the completion of
the facility, taking into account all factors relevant to construction? Yes 0 No 0 If you answered Yes, provide
a brief narrative explanation in the Miscellaneous section starting on page 19 of the construction timeline (in
particular, describe why construction started so long after the facilty was certified) and the dilgence exercised
toward completion of the facility.
Pursuant to 18 C.F.R. § 292.204(b), qualifying small power production facilties may use fossil fuels, in minimal
amounts, for only the following purposes: ignition; start-up; testing; flame stabilzation; control use; alleviation or
prevention of unanticipated equipment outages; and alleviation or prevention of emergencies, direcly affecting
the public health, safety, or welfare, which would result from electric power outages. The amount of fossil fuels
used for these purposes may not exceed 25 percent of the total energy input of the facilty during the 12-month
period beginning with the date the facilty first produces electric energy or any calendar year thereafter.
o
9a Certification of compliance with 18 C.F.R. § 292.204(b) with respect to uses offossil fuel:
I: Applicant certifies that the facilty wil use fossil fuels exclusively for the purposes listed above.
9b Certification of compliance with 18 C.F.R. § 292.204(b) with respect to amount of fossil fuel used annually:
Applicant certifies that the amount of fossil fuel used at the facilty wil not, in aggregate, exceed 25
I: percent of the total energy input of the facilty during the 12-month period beginning with the date the
facility first produces electric energy or any calendar year thereafter.
FERC Form 556 Page 11 - Cogeneration Facilities
Informati,onRequired for Cogeneration Facilty
If you incficated in line lk that you are seeking qualifying cogeneration facilty status for your facilty, then you must respond
to the items on paes 11 through 13. Otherwise, skip pages 11 through 13.
Pursuant to 18 C.F .R. § 292.202((;), a cogeneration facilit produces elecric energy and forms of useful thermal
energy (such as heat or steam) usec for industrial, commercial, heating, or cooling purposes, through the sequential
us of energy. Pursuant to 18 C.F.R. § 292.202(s), "sequential use" of energy means the following: (1) for a topping-
cycle cogeneration facilty, the use of rejec heat from a power production process in suffcient amounts in a
thermal application or process to conform to the requirements of the operating standard contained in 18 C.F.R. §
292.205(a)¡ or (2) for a pottoming-ecle cogeneration facilit, the use of at least some rejec heat from a thermal
application or process for power production.
10a What type(s) of cogeneration technology does the facility represent? (check all that apply)
o Topping-ccle cogeneration o Bottoming-ccle cogeneration
10b To help demonstrate the sequential operation of the cogeneration process, and to support compliance with
other requirements such as the operating and efciency standards, include wit your filing a mass and heat
balance diagram depicting average annual operating conditions. This diagram must include cerain items and
meet certain requirements, as describe below. You must check nex to the description of each requirement
below to certif that you have complied with these requirements.
Check to certify
compliance wih
indicaed requirement Requirement
Diagram must show orientation witin sysem piping and/or duet of all prime movers,
c:heat recovery steam generators, boilers, elecric generators, and condensers (as0D-.¡applicable), as well as any other primary equipment relevant to the cogeneration
et process.:i i:c:0 Any average annual values required to be reported in lines 10b, 12a, 13a, 13b, 13d, 13f,c:+:Dc:14a, 15b, 15d and/or 15f must be computed over the anticipated hours of operation.C'et
0 E Diagram must specify all fuel inputs by fuel type and average annual rate in Btul. FuelU:i-J2 D for supplemertary firing should be specified seParately and clearly labeled. Alleti:specifcaions of fuel inputs should use lower heating values.:i -c:c:D Diagram must specif average gross electric output in kW or MW for each generator.c:'"Diagram must specify average mechanical output (that is, any mechanical energy taken
D off of the shaft of the prime movers for purposes not direcly related to elecric power
generation) in horsepower, if any. Typically, a cogeneration facilty has no mechanical
output.
At each point for which working fluid flow conditions are required to be specified (see
below), such flow condition data must include mass flow rate (in Ib/h or kg/s),
temperature (in OF, R, °C or K), absolute pressure (in psia or kPa) and enthalpy (in Btullb
or kJ/kg). Exception: For systems where the working fluid is liquid only (no vapor at any
D point in the cycle) and where the type of liquid and specific heat of that liquid are clearl
indicated on the diagram or in the Miscellaneous secion starting on page 19, only mass
flow rate and temperature (not pressure and enthalpy) need be specifed. For reference,
specifc heat at standard conditions for pure liquid water is approximately 1.002 Btu/
(Ib*R) or 4.195 kJ/(kg*K).
D Diagram must specif working fluid flow conditions at input to and output from each
steam turbine or other expansion turbine or back-pressure turbine.
D Diagram must specify working fluid flow conditions at delivery to and return from each
thermal application.
D Diagram must specify working fluid flow conditions at make-up water inputs.
o
o
FERC Form 556 ... Page 12 - Cogeneration Facilities
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EPAct 2005 cogeneration facilities: The Energy Policy Act of 2005 (EPAct 2005) established a new.secion 210(n) of
the Public Utilty Regulatory Policies Act of 1978 (PURPA), 16 USC 824a-3(n), with additional reqlJirements for any
qualifing cogeneration facility that (1) is seeking to sell electric energy pursuant to section 210 of PURPA and (2)
was either not a cogeneration facility on August 8, 2005, or had not filed a self-eertificat10n or application for
Commission certifcation of QF status on or before February 1, 2006. These requirements were implemented by the
Commission in 18 C.F.R. § 292.205(d). Complete the lines below, carefully following the instructions, to demonstrate
whether these additional requirements apply to your cogeneration facilty and, if so, whether your facilit complies
with such requirements.
11 a Was your facility operating as a qualifying cogeneration facilty on or before August 8, 2oo5? Yes D No D 0
11 b Was the initial filing seeking certification of your facilit (whether a notice of self-eertification or an application 0
for Commission certification) filed on or before February 1, 2006? Yes D No D
If the answer to either line 11aor 11b is Yes, then continue at line 11c below. Otherwise, if the answers to both lines
11 a and 11 b are No, skip to line 11 e below.
11 c With respect to the design and operation of the facilty, have any changes been implemented on or after 0
February 2, 2006 that affect general plant operation, affect use of thermal output, and/or increase net power
production capacity from the plant's capacity on February 1, 2006?
D Yes (continue at line 11 d below)
No. Your facility is not subjec to the requirements of 18 C.F.R. § 292.205(d) at this time. However, it may be
D subjec to to these requirements in the future if changes are made to the facilty. At such time, the applicant
would need to recertif the facilty to determine eligibilty. Skip lines 11 d through 11j.
11d Does the applicant contend that the changes identified in line 11 c are not so signifcant as to make the facility 0
a "new" cogeneration facility that would be subjec to the 18 C.F.R. § 292.205(d) cogeneration requirements?
Yes. Provide in the Miscellaneous secion starting on page 19 a description of any relevant changes made to
D the facilty (including the purpose of the changes) and a discussion of why the facility should not be
considered a "new" cogeneration fadlit in light ofthese changes. Skip lines 11e through 11j.
No. Applicant stipulates to the fact that it is a "new" cogeneration fadlity (for purposes of determining the
D applicabilit of the requirements of 18c.F.R. § 292.205(d)) by virtue of modifications to the facilit that were
initiated on or after February 2, 2006. Continue below at line 11 e.
11 e Wil elecric energy from the facilty be sold pursuant to section 210 of PURPA? 0
D Yes. The facilty is an EPAct 2005 cogeneration fadlity. You must demonstrate compliance with 18 C.F.R. §292.205(d)(2) by continuing at line 11f below.
No. Applicant certifies that energy wil not be sold pursuant to secion 210 of PURPA. Applicant also certifes
D its understanding that it must recertify its facility in order to determine compliance with the requirements of18 C.F.R. § 292.205(d) before sellng energy pursuant to section 210 ofPURPA in the future. Skip lines 11f
through 11j.
11f Is the net power production capacit of your cogeneration facility, as indicated in line 7g above, less than or 0
equal to 5,00 kW?
Yes, the net power production capacity is less than or equal to 5,000 kW. 18 C.F.R. § 292.205(d)(4) provides a
rebuttable presumption that cogeneration facilties of 5,000 kW and smaller capacity comply with the
D requirements for fundamental use of the faciltys energy output in 18 C.F.R. § 292.205(d)(2). Applicantcertifies its understanding that, should the power production capacity of the facilty increase above 5,000
kW, then the facilty must be recertified to (among other things) demonstrate compliance with 18 C.F.R. §
292.205 (d)(2). Skip lines 11 g through 11 j.
No, the net power production capacity is greater than 5,000 kW. Demonstrate compliance with the
D requirements for fundamental use of the facilitys energy output in 18 C.F.R. § 292.205(d)(2) by continuing on
the next page at line 11 g.
FERC Form 556 Page 13 - Cogeneration Facilities
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Unesi 1 gthrough 11 k below guide the applicant through the process of demonstrating compliance with the
requirements for "fndamental use" of the faciltys energy output. 18 C.F.R. § 292.205(d)(2). Only respond to the
lines on this page if the instructions on the previous page direct you to do so. Otherwise, skip this page.
18 C.F.R. § 292.205(d)(2) requires thatthe elecrical, thermal, chemical and mechanical output of an EPAct 2005
cogenertion facilit is used fundamentally for indusrial, commercial, residential or instituional purposes and is
not intended fundamentally for sale to an elecric utilty, taking into account technological, efciency, economic,
and varible thermal energ requirements, as well as stte laws applicable to sales of elecic energy from a
qualifngfacility to its hos facilit. If you were directed on the previous page to respond to the items on this page,
then your facilit is an EPAct 2005 cogeneration facilit that is subjec to this "fndamental use" requirement.
The Commission's regulations provide a two-pronged approach to demonstrating compliance with the
reqHire.ients for fundamental i.se of the facilits energy outpiJ. First the Commission has established in 18 C.F.R.
§ 29í.205(d)(3) a "fundamental use test" that can be used to demonstrate compliance with 18 C.F.R. § 292.205(d)(2).
Under the fundamental use test, a facilit is considered to comply with 18 C.F.R. § 292.205(d)(2) if at least 50 percent
of the facilits total annual energy output (including elecrical, thermal, chemical and mechanical energy output) is
'used for industrial, commercial, residential or institutional purposes.
Second, an applicant for a f~cility that does not pass the fundamental use test may provide a narrative explanation
of and support for its contention that the facility nonetheless meets the requirement that the electrical, thermal,
chemical and mechanical output of an EPAct 2005 cogeneration facilit is used fundamentally for industrial,
commercial, residential or institonal purposes and is not intended fundamentally for sale to an elecic utilty,
taking into account tecnólógical,efcieiicy, economic, and variable thermal energy requirements, as well as state
laws applicable to sales of elecric .energy from a qualifyng facilty to its host facilty.
Complete lines 11 g through 1.1j below to determine compliance with the fundamental use test in 18 C.F.R. §
292.205(d)(3). Complete lines 11 g through 11 j even if you do not intend to rely upon the fundamental use test to
demonstrate compliance with 78 C.F.R. § 292.205(d)(2).
11 g Amount of elecrical, thermal; chemicl and mechanical ellrgy output (net of internal
generation plant losses and parasitic loads) expeçted to be used anlually for industrial,
commercial, residential or instittional purpses and not sold to an elecric utilit MWh
11 h Total amount of elecrical, therral, chemical and mechanical energy eXpeced to besold to an electric utilit MWh
11i Percentage of total annual energy output execed to be used for industrial, 0
commercial, residential or instituional purposes and not sold to a utilty= 100 * 11 g 1(11 g + 11 h) 0 %
11j Is the response in line 11 i greater than or equal to 50 percent?
Yes. Yourfalit complies wi 18 C.F.R. § 292.205(d)(2) by virtue of passing the fundamental use test
provided in 18 c.F.R. § 292.205(d)(3). Applicant certifes it undersanding that, if it is to rely upon passing
o thefundamenta.1 use test as a basis for complying with 18 C.F.R.§ 292.20S(d)(2),then the facilty must
comply with the fundamental use te both in the 12-month periOd beginning with the date the facility first
produces elecric enérgy, and in all subsequent calendar years.
No. Your facilit does not pass the fundamental use test Instead,you-rl'ust provide in the Miscellaneous
secion starting on page 19 a narrtive explanation of and support for why your facilit mee the
reuirementthcl the eleccal; thermal, chemical and meanical out of an EPAct 2005 cogeneration
facilit is used fundamentally for Industrial, commerCial, residential or institutonal purposes and is not
intended fundarrntaUyfor saleto an electric utilty, taking into accounttehnological¡ efciency, economic,
and vanable thermal energy requirement, as well as state laws applicble to sales oi elecncenergy from a
QF to its host facility. Applicants providing a narrative explanation of why their facilty should be found to
o comply with 18 C.F.R. § 292.205(d)(2) in spite of non-eompliance with the fundamental use test may want to
review paragraphs 47 through 61 of Order No. 671 (accessible from the Commission's QF website at
ww.ferc.gov/QF), which provide discussion of the fact and circumstances that may support their
explanation. Applicant should also note that the percentage reported àbove wil establish the standard that
that facilty must comply with, both for the 12-month period beginning with the date the facilit first
produces electric energy, and in all subsequent calendar years. See Order No. 671 at paragraph 51. As such,
the applicant should make sure that it reports appropriate values on lines 11g and 11 h above to serve as the
relevant annual standard, taking into account expeced variations In production conditions.
FERC Form 556 Page 14 - Topping-CyçleCqgeneration Façilties
Information Requ.ired for Topping-Cycle Cogeneration Facility
If you indicated in line lOa that your facilty represents topping-ecle cogeneration technology, then you must respond to
the items on pages 14 and 15. Otherwise, skip pages 14 and 15.
The thermal energy output of a topping-ecle cogeneration facility is the net energy made available to an industrial
or commercial process or used in a heating or cooling application. Pursuantto secions 292.202(c), (d) and (h) of the
Commission's regulations (18 C.F.R. §§ 292.202(c), (d) and (h)), the thermal energy output of a qualifing topping-
cycle cogeneration facilit must be usefuL. In connection with this requirement, describe the thermal output of the
topping-ecle cogeneration facilit by responding to lines 12a and 12b below.
12a Identif and describe each thermal host, and specify the annual average rate of thenral output made available
to each host for each use. For hosts with multiple uses of thermal output, provide the data for each use in
separate rows.Average annual rate of
thermal output
attribuable to use.(net of
Name of entity (thermal host)Thermal host's relationship to facility heat contained in process
taking thermal output Thermal host's use of thermal Output return or make-upwater)
1)
Select thermal host's relationshipto facility
Select thermal host's use of thermal O!.tput Btulh
2)Select thermal host's relationship to facilit
Q)Select thermal host's use of thermal output BtuhÜSelect thermal host's relationship to facility;:3)Ui Select thermal host's use of thermal output Btulh01 +oc: :;Select thermal host's relationship to facilit.- 0.4)0. +o0. :;Selec thermal host's use of thermal output Btuh~ 0
5)Selec thermal host's relationship to facilit\f ro0E Select thermal host's use of thermal output BtuhII~II Q)Select thermal host's relationship to faciltyQ).r 6)c:i-Selec thermal host's use of thermal output Btu/h
~D Check here and continue in the Miscellaneous section starting on page 19 ifadditional space is neededII::12b Demonstration of usefulness of thermal output: At a minimum, provide a brief description of each use of the
thermal output identified above. In some cases, this brief description is suffcient to demonstrate usefulness;
However, if your facilty's use of thermal output is not common, and/or if the usefulness of such thermal output is
not reasonably clear, then you must provide additional details as necessary to demonstrate usefulness. Your
application may be rejeced and/or additional information may be required if an insufcient showing of useflness
is made. (Exception: If you have previously received a Commission certifcation approving a specific use of thermal
output related to the instant facilit, then you need only provide a brief description of that use and a reference by
date and docket number to the order certifying your facility with the indicated use. Such exemption may not be
used if any change creates a material deviation from the previously authorized use.) If additional space is needed,
continue in the Miscellaneous section starting on page 19,
o
FERC Form 556 Page 15 . Topping-Cycle Cogeneration Facilties
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Applicants fòr facilities representing topping-ecle technology must demonstrate compliance with the topping- 0
cycle operating stndard and; if applicable, effciency standárd. Secion 292.205(a)(1) of the Commission's
regulations (18 C.F.R. § 292.205(a)(1)) establishes the operating standard for topping-ecle cogeneration facilities:
the useful thermal energy output must be no less than 5 pércent of the total energy output Section 292205(a)(2)
(1 S C.F.R. § 29,2.205(a)(2)) establishes the effciency standatdfor topping;.cycle cogeneration failities for Which
Inslaion ~mmenced on or after Marçh 13, 1980: the useful power output of the facility plus one-half the useful
tllermal energy output must (A) be no less than 42.5 percent of the total energy input of natural gas i,nd oil to the
fii/it .a'1d(B) if the useful thermal energ output is less than 15 percent of the total energy output of the facility,
be no i~~s than 45 percent of the total energy input of natural gas and oil to the facilty. To demonstrate
compliance with the topping-ecle operating and/or effciency stndards, or to demonstrate that your facilit is
exempt from the effciency standardbas on the date that installation commenced, respond to lines 13a through
131 below.
if you indicated in line lOa that your facilty represnts both topping-ecle and bottoming-ecle cogeneration
téChnoløgy, then respond to lines 13a through 131 below considering only the energy input and outputs
atttable to the topping-ccle portion of your facilty. Your mass and heat balance diagram must make clear
which mass and energy flow values and system components are for which portion (topping or bottoming) of the
cogenation system.
13á Indicae the annual average rate of usefl thermal energy output made available
to the host(s), net of any heat contined in condensate return or make-up water Btuth
lIb Indicate the annual average rate of net electcal energy output
13c Multiply line 13b by 3,412 to convert from iN to Btulh
kW
o Btuth 0
hl)
o Btuth 0
Btuth
0%0
13d Indicate the annual average rate of mechanical energy outut taken directly off
of the shaft of a prime mover for purposes not direcly related to power production
(this value is usually zero)
13e Multiply line 13d by 2,54 to convert from hp to Btlh
13f Indicate the annual average rate of energy input from natural gas and oil
..
1.3g Topping-ecle operaing value = 100 * 13a / (13a + 13c + 13e)
.
l3h Topplng-ce effciency value = 100 * (05*13a + 13c + 13e) 113f
o %
13i Compliance with operating standard: Is the operating value shown in line 13g greter than or equal to 5%?
o Yes (compiles with operating standard) 0 No (does not comply wih operaing standard)o13j Did installation of the facilty in its current form commence on or after March 13, 1980?
DYes. Your facilty is subject to the effciency requirements of 18 C.F.R. § 292.205(a)(2). Demonstratecompliance with the efciency requirement by responding to line 13k or 131, as applicable, below.
o No. Your facilty is exempt from the effciency standard. Skip lines 13k and 131.
13k Compliance with efciency standard (for low operating value): If the operating value shown in line 13g is less
than 15%, then indicate below whether the efciency value shown in line 13h greater than or equal to 45%:
o Yes (complies with effciency standard)o No (does not comply with efciency standard)
131 Compliance with effciency standard (for high operating value): If the operating value shown in line 13g is
greater than or equal to 15%, then indicate below whether the effciency value shown in line 13h is greater than or
equal to 42.5%:
o Yes (complies with effciency standard) 0 No (does not comply with efciency standard)
FERC Form 556 Page 16 - Bottoming~Çycle Cogener~tion Facilities
Information Required for Bottoming-Cycle Cogeneration Facility
If you indicated in line 10a that your facilit represents bottoming-ccle cogeneration technology, then you must respond
to the items on pages 16 and 17. Otherwise, skip pages 16 and 17.
The thermal energy outputof a bottoming-ccle cogeneration facility is the energy related to the process(es) from
which at least some of the rejec heat is then used for power production. Pursuant to secions 292.202(c) and (e) of
the Commission's regulations (18 C.F.R. § 292.202(c) and (e)) , thethermal energy output of a qualifyng bottoming-
cycle cogeneration facilit must be usefuL. In connecion with this requirement, describe the process(es) from which
at least some of the reject heat is used for power production by responding to lines 14a and 14b below.. ..
14a Identify and describe each thermal host and each bottoming-ecle cogeneration process engaged in by each
host. For hosts with multiple bottoming-cycle cogeneration processes, provide the data for each process in
separate rows.
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Name of entity (thermal host)
performing the process from
which at least some of the
rejec heat is used for power
production
Has the energy input to
the thermal host been
augmented for purposes
of increasing power
production capacity?
(if Yes, describe on p. 19)
Thermal host's relationship to facility
Thermal host's process type
1 )
select thermal host's relationship to facility Yes 0 No 0
Select thermal host's process type
select thermal host's relationship to facility Yes 0 No 0
Selec thermal host's procss type
Select thermal host's relationship to facilty Yes 0 No 0
Select thermal host's proess type
o Check here and continue in the Miscellaneous secion starting on page 19 if additional space is needed
2)
3)
14b Demonstration of usefulness of thermal output: At a minimum, provide a brief description of each process
identified above. In some cases, this brief description is sufcient to demonstate useflness. However, if your
facilty's process is not common, and/or if the usefulness of such thermal output is not reasonably clear, then you
must provide additional details as necessary to demonstrate usefulness. Your application may be rejeced and/or
additional information may be required if an insuffcient showing of usefulness is made. (Exception: If you have
previously received a Commission certifcation approving a specific bottoming-ecle process related to the instant
facilty, then you need only provide a brief description of that process and a reference by date and docket number
to the order certifing your facilty with the indicated process. Such exemption may not be used if any material
changes to the process have been made.) If additional space is needed, continue in the Miscellaneous secion
starting on page 19.
FERC Form 556 Page 17 - Bottoming-Cycle Cogeneration Facilities
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ÄppíiCants for facilties representing bpttaming-gcle technology and for which instaUation corrmenced on or after
March 13, 1990 must demonstrate compliance with the botoming-gcle effciency standards. Section 292.205(b) of
the Commission's regulations (18 C.F.R § 292.205(b)) establishes the eficiency standard for bottoming-gcle
cogenertion facilies; the usefl power output of the facilty must be no less than 45 percent of the energy input
of natral gas and oil for supplementary firing. To demonstrate compliance with the bottoming--le efciency
stndard (if applicable), or to demonstrate that your facility is exempt from this stndard based on the date that
instllation of the facility began, respond to lines 15a through 15h below.
If yau indicated in Hne 10a that your facility represents both topping-gcle and bottoming-gcle cogeneration
technology, then respond to Hnes 15a through 15h below considering only the energy inputs and outputs
attributable to the bottoming-gcle portion of your facility. Your mass and heat balance diagram must make clear
which mass and energy flow values and system components are for which portion of the cogeneration system
(topping or bottoming).
15a Did installation of the faciHty in its currt form commence on or after March 13, 19801
o Yes. Your facility is subjec to the effciency requirement of 18 C.F.R § 292.205(b). Demonstrate compliancewith the effciency requirement by responding to lines 15b through 15h below.
o No. Your facilty is exempt from the efciency standard.. Skip the rest of page 17.
15b Indicte the annual average rate of net electrical energy output
15c Multiply Hne 15b by SA 12 to convert from kW to I;tulh
1Sd Indicate the annual average rate of mechanical energy output taken directly off
of the shaft of a prime mover for purposes not direcly related to power production
(this value is usually zero)
15e. Multply line 15d by 2,54 to convert from hp to Btulh
15f Indicate the annual average rate of supplementary energy input from natural gas
or oil
159 Bottoming-gcle efciency value = 100 * (15e + 15e) /15f oo0%
15h Compliance with effciency standard: Inclicate below whether the efciency value shown in line 159 is greater
than or equal to 45%:
o Yes (complies with effciency standard)o No (does not comply with effciency standard)
FERC Form 556 Page 18 - AUFacilities
Certificate of Completeness, Accuracy and Authority
Applicant must certify compliance with and understanding of filing requirements by checking nex to each item below and
signing at the bottom of this seion. Forms with incomplete Certifcates of Completeness, Accuracy and Authority wil be
rejeced by the Secretary of the Commission.
Signer identified below certifies the following: (check all items and applicable subitems)
He or she has read the filing, including any information contained in any attached documents, such as cogeneration
iz mass and heat balance diagrams, and any information contained in the Miscellaneous secion starting on page 19, and
knows its contents.
iz He or she has provided all of the required information for certcation, and the provided information Îstrue as stated,to the best of his or her knowledge and belief.
iz He or she possess full power and authority to sign the filing; as required by Rule 2oo5(a)(3) of the Commission's Rules ofPractice and Procedure (18 C.F.R. § 385.2005(a)(3)), he or she is one of the following: (check one)
o The person on whose behalf the filing is made
o An offcer of the corporation, trust, association, or other organized group on behalf of which the filing is made
o An offcer, agent, or employe of the governmental authority, agency, or instrumentality on behalf of which thefiling is made
t8 A representative qualified to practice before
the Commission under Rule 2101 of the Commission's Rules of
Practice and Procedure (18 C.F.R. § 385.2101) and who possesses authority to sign
iz He or she has reviewed. all automatic calculations and agrees with their results, unless otherwise noted in theMiscellaneous section starting on page 19. .
He or she has provided a copy of this Form 556 and all attachments to the utilites with which the facilit wil
iz interconnec and transact (see lines 4a through 4d), as well as to the regulatory authorities of the states in which thefacilty and those utilties reside. See the Required Notice to Public Utilties and State Regulatory Authorities section on
page 3 for more information.
Provide your signature, address and signature date below. Rule 2oo5(c) of the Commission's Rule of Praeiceand
Procedure (18 C.F.R. § 385.2005(c)) provides that persons filing their documents elecronically may use tyed characters
representing his or her name to sign the filed documents. A person filing this document elecronically should sign (by
typing his or her name) in the space provided below.
Peter Richarsdson
Your address
515 N. 27th Street
Boise, Idaho 83702
DateYour Signature
6/27/2011
Audit Notes
Commission Staff Use Only:o
FERC Form 556 Page 19 . All Facilities
Miscellaneous
Use this space to provide any information for which there was not suffcient space in the previous sections of the form to
provide. For each such item of information clearly identify the line number that the information belongs to. You may also use
this space to provide any additional information you believe is relevant to the certification of your facilty.
Your response below is not limited to one page. Additional page(s) wil automatically be inserted into this form if the
length of your response exceeds the space on this page. Use as many pages as you require.
BEFORE THE
IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-E-11-14
IDAHO POWER COMPANY
ATTACHMENT NO.6
V to. no.lVLÀ ct ie \ ;oULtl
fõ æ ~ æ 0 il æ f¡ O.
til JUN 27 2011 ~c;B~
Sandy Sanderson, Consultant
Western Desert Energy I, LLC
1770 W. State Street #330
Boise, Idaho 837024
[phone]
sandyaRgreenenergvwest. com
June 24, 2011
Idaho Power Company
Cogeneration and Small Power Production
P.O. Box 70
Boise, Idaho 83707
1221 West Idaho
Boise, Idaho 83702
(via U.S. Mail and Hand delivery)
Re: 5 MW Wind QF Contract Request - Oregon Off-System Project
Dear Sir or Madam:
Please accept this request for an Energy Sales Agreement pursuant to Oregon PUC rate
Schedule 85-4 "Cogeneration and Small Power Production Standard Contract Rates". We are
. interested in obtaining a final execution ready Energy Sales Agreement for the Western Desert
Energy Wind Farm five MW project located in Owyhee County, Idaho for delivery to Idaho
Power's service territory in Oregon pursuant to the above referenced tariff. Section 2(b) of
Schedule 85-4 requires the following information to be provided in order for you to provide a
draft Energy Sales Agreement within fifteen business days (see § 2 (d)):
a. Date of Request: June 27, 2011;
b. Company/Organization that wil be the contracting Party: Western Desert Energy 1, LLC;
c. Contact Notification information including, name, address and telephone: See above
address and phone contact information;
d. Verification that the Qualifying Facilty meets the "Eligibility for Standard Rates and
Contract" criteria; i hereby verify that the Western Desert Energy 1, LLC project is a
small power production facility which meets the PURPA criteria for qualification set forth
in Subpart B of Part 292, subchapter K, Chapter 1, Title 18 of the Code of Federal
Regulations;
e. Copy of the Qualifying Facility's QF certificate: Attached;
f. Copy of FERC license (applicable to hydro projects only): N/A;
g. Location of the proposed project including specific equipment models, types, sizes and
configurations: Stanford Ranch, Owyhee County, Idaho. Two 2.5 MW GE manufactured
1 00 meter wind turbines.
h. Description of the proposed project including specific equipment models, types, sizes
and configurations; see "g";
i. Type of project (wind, hydro, geothermal etc.): Wind;
j. Nameplate capacity of the Qualifying Factility: 5 MW;
k. Schedule 85 pricing option selected: Option 1, Fixed Price Method;
i. Desired term of the Energy Sales Agreement: Fifteen (15) years;
m. Annual net energy amount: 13,500,000 kwh;
n. Maximum capacity of the Qualifying Facility: 5,000 kw
o. Estimated first energy date: December 1, 2012;
p. Estimated first operation date: January 1, 2013;
q. Point of Delivery: Idaho Power service territory in Oregon, likely the Ontario or Nyssa
Substation, with the final Point of Delivery to be determined by Idaho Power
Transmission Business Line;
r. Status of the Generation Interconnection Process: Interconnection Process is complete
with the Final Feasibilty Study executed for Project No. 318 in the Idaho Power
Interconnection Queue.
It is our understanding that, pursuant to Schedule 85 that we may expect a draft Energy Sales
Agreement fifteen business days from today. Please do not hesitate to give me a call if you
have any questions.
//'/ .
SinC"ly your ,
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-11-14
IDAHO POWER COMPANY
ATTACHMENT NO.7
\ . CÀQ II O(Q-ttj
~æ~æO\ìærm:
lin JUëß20\\ ~
By
Sandy Sanderson, Consultant
Western Desert Energy 1, LLC
1770 West State Street #317
Boise, Idaho 83702
(541) 521-55~?
sandy~greenenergywest.com
June 27,2011
Manager Grid Operations
Idaho Power Company
1221 West Idaho
Boise, Idaho 83702
(via U.S. Mail and Hand delivery)
Idaho Power Company
Re: 5 MW Wind Firm Point-to-Point Transmission Service Request
Dear Sir or Madam:
Please accept this request for a Firm Point-to-Point transmission agreement pursuant to Idaho
Power's Open Access Transmission Tariff, FERC Electric Tariff First Revised Volume
No.6, Section 17, "Procedures for Arranging Firm Point-to-Point Transmission Service.
Service is to begin on December 1, 2012.
a. Identity of the entity requesting service: Western Desert Energy 1, LLC, see above
address and phone contact information;
b. Western Desert Energy 1, LLC is, or wil be upon commencement of service, an Eligible
Customer under the Tariff:
c. The Point of Receipt is the Delamar Mine 69 kw system on the Stanford Ranch near
Jordan Valley, Oregon;
d. The project wil supply wind energy and capcity from two 2.5 MW GE manufactured 100
meter wind turbines.
e. The receiving party, Idaho Power's Oregon jurisdiction, wil receive approximately
13,500,000 kwh of energy and capacity associated with a 5 MW wind project.
f. The Commencement Date of the requested transmission service is December 1, 2012;
g. The transmission capacity requested for the Point of Receipt and the Point of Delivery is
10MW.
h. Western Desert Energy is committed to executing a Service Agreement upon notification
that the Transmission Provider can provide the requested Transmission Service.
i. Western Desert Energy wil provide such additional information as requested by the
Transmission Provider.
It is our understanding that, pursuant to the OA TT that we may expect a response within fifteen
business days from today as to whether this application for Firm Point-to-Point Transmission
Service is complete. Western Desert Energy, LLC stands ready to post necessary deposit
equal to one month's transmission service charge. That said, we respectfully request that Idaho
Power waive said charge in the event that Western Desert Energy, LLC meets applicable credit
worthiness requirements.
_,/lPlease ,db no hesitate to me a call if you have any questions.
BEFORE THE
IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-E-11-14
IDAHO POWER COMPANY
ATTACHMENT NO.8
1:
IDA~PO~
An 10ACORP company
DONOVAN E. WALKER
Lead Counsel .
dwalker(idahopower.com
June 8, 2011
VIA ELECTRONIC MAIL & U.S. MAIL
sandycægreenenergywest.com
Sandy Sanderson, Consultant
Western Desert Energy 1, LLC
1770 West State Street #317
Boise, Idaho 83702
Re: Invalid Request - Your June 27, 2011, Five Megawatt Wind Qualified
Facilty ("QF") Contract Request - Oregon Off-System Project
Dear Ms. Sanderson:
This letter is in response to your request for an Energy Sales Agreement
pursuant to Idaho Power Company's ("Idaho Powet') Oregon Tariff Schedule 85,
Cogeneration and Small Power Production Standard Contract Rates (March 1, 2010).
Because your proposed QF project is located in the state of Idaho, with an
interconnection to Idaho Powets system in the state of Idaho, if your project wishes to
obtain a power sales agreement pursuant to the Public Utilty Regulatory Policies Act of
1978 ("PURPA"), it must do so according to the Idaho Public Utilties Commission's
PURPA rates, rules, and regulations - not Oregon's.
Idaho Power intends to file a case with the Idaho Public Utilties Commission
determining the same on today's date. Idaho Power wil forward a copy of said filing to
you under separate cover.
quJ~
Donovan E. Walker
DEW:csb
cc: Peter J. Richardson
1221 W. Idaho St. (83702)
P.O. Box 70
Boise, ID 83707
øsIDA~PC~
An IOACOR Company
July 8,2011
Sandy Sanderson, Consultant
Western Deert Energy 1, LLC
1770 West State Street #317
Boise, ID 83702
Re: Invalid Application - SMW FIRM PTP TSR request for Western Desert Energy
Dear Ms. Sanderson:
This letter is to serve as formal notification that we have received your reques for Firm Point-toPoint (PTP)
transmission. However, due to the method of submittal, it has ben considered as an invalid application.
All Transmisison service Requests (TRs), short term or long term, must be made on OASIS to esblish a
queue position. The information provided in your letter wil also nee to accompany the OASIS reqeust. To
make a request on OASIS, you wil need to become an actve Idaho Power transmission customer. The
customer registation process can be found in Seon 1 of our Business Practices. Our Business Practces
are located on OASIS witin the Busines Practce folder. All other required docments for customer
registration are also located on OASIS under the Customer service-Transmission folder.
Please let me know if you have any questions or need any assistnce in the customer registration process.
Beth Ryan
Operations Analyst
208.388.2846
BRyan(§idahopower .com
cc: Kathy Andersn
Donovan Walker
P,O, Box 70 (B3707)
1221 W. Idaho St.
Boíse. ID 83702
BEFORE THE
IDAHO PUBLIC UTiliTIES COMMISSION
CASE NO. IPC-E-11-14
IDAHO POWER COMPANY
ATTACHMENT NO.9
IDAHO POWER COMPANY
P.U.C. ORE. NO. E-27 ORIGINAL SHEET NO. 85-1
SCHEDULE 85
COGENERATION AND SMALL POWER
PRODUCTION STANDARD
CONTRACT RATES
RECEIV¡O
MAR 0 12010
AVAILABILITY
pucUtilty Program
Service under this schedule is available for power delivered to the Company's control area within the State of
Oregon.
APPLICABILITY
Service under this schedule is applicable to any Seller that:
1. Owns or operates a Qualifyng Facilty wih a Nameplate Capacity rating of 10 MW or less and desires to
sell Energy generated by the Qualifying Facilty to the Company in compliance with all the terms and
conditions of the Standard Contrct;
2. Meets all applicable requirements of the Company's Generation Interconnection Process.
For Qualifying Facilties with a Nameplate Capacity rating greater than 10 MW, a negotiated Non-8tandard
Contract between the Seller and the Company is required.
DEFINITIONS
Energy means the electric energy, expressed in kWh, generate by the Qualifng Facilty and delivered by the
Seller to the Company in accordance with the conditions of this schedule and the Standard Contract. Energy is
measured net of Losses and Station Use.
Generation Interconnection Process is the Company's generation interconnecton 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. The Generation
Interconnection Process is managed by the Company's Delivery Business Unit.
Heat Rate Conversion Factor is 7,100 MMBTU divided by 1,000.
Intermittent describes a Qualifng Facilty that produces electrical energy from the use of wind, solar or run of
river hydro as the prime mover.
Losses are the loss of elecric energy occurring as a result of the transformation and trnsmission of electric
energy from the Qualifng Facilty to the Point of Delivery.
Nameplate Capacity means the full-load electrical quantities assigned by the designer to a generator and its
prime mover or other piece of electrical equipment, such as transformers and circuit breakers, under standardized
conditions, expressed in amperes, kUovolt amperes, kilowatts, volts, or other appropriate units. Usually indicated
on a nameplate attached to the individual machine or device.
Non-8tandard Contract is a negotiated contract between any Seller that owns or operates a Qualifing Facilty
with a nameplate capacity rating greater than 10 MWand desires to sell Energy generated by the Qualifng
Facilty to the Company. The starting point for negotiation of price is the Avoided Cost Components established
in this schedule and may be modifed to address specifc factors mandated by federal and state law, including
1. The utilits system cost data;
Issued by IDAHO POWER COMPANY
By John R. Gale, Vice President, Regulatory Affirs
1221 West Idaho Street, Boise, Idaho
OREGON
Issued: July 31, 2009
Effective with Service
Rendered on and after:
March 1, 2010Advice No. 10-02
IDAHO POWER COMPANY
P.U .C. ORE. NO. E-27 ORIGINAL SHEET NO. 85-2
SCHEDULE 85
COGENERATION AND SMALL POWER
PRODUCTION STANDARD
CONTRACT RATES
(Continued)
RECEIViD
MAR 0 12010
PUC
Utilty Program
DEFINITIONS (Continued)
2. The availabilty of capacity or energy frm a Qualifying Facilty during the system daily and sesonal peak
periods, including:
a. The abilty of the utilty to dispatch the qualifyng facilty;
b. The expected or demonstrted reliabilty of the qualifying facilty;
c. The terms of any contract or other legally enforceable obligation, including the duration of the
obligation, termination notice requirement and sanctions for non-compliance;
d. The extent to which scheduled outages of the qualifng facilty can be uselly codinated with
scheduled outages of the utilitýs facilties;
e. The usefulness of energy and capacity supplied from a qualifyng facility during system
emergencies, including its abilty to separate its load from its generation;
f. The individual and aggregate value of energy and capacity from qualifyng facilties on the electric
utility's system; and
g. The smaller capacity increments and the shorter lead times available with additions of capacity
from qualifying facilities; and
3. The relationship of the availabilty of energy or capacity from the Qualifying Facilty to the ability of the
electric utility to avoid costs, including the deferral of capacity additions and the reduction of fossil fuel
use; and
4. The costs or savings resulting from variations in line losses from those that would have existed in the
absence of purchases from a Qualifying Facilty, if the purchasing electic utilty generated an equivalent
amount of energy itself or purchased an equivalent amount of electric energy or capacity.
Non-Standard Contract is a negotiated contract between any Seller that owns or operates a Qualifying Facilty
with a Nameplate Capacity rating greter than 10 MW and desires to sell Energy generated by the Qualifng
Facilty to the Company. The guidelines for negotiating a Non-5tandard Contract are more specifcally descrbed
later in this schedule in Guidelines for Negotiation of Powe Purchases Agreements for Qualifyng Facilities with
Nameplate Capacity of 10 MW or Larger.
Point of Delivery is the location where the Companýs and the Seller's electrical facilties are Inter-connected or
where the Companýs and the Seller's host transmission provider's electrical facilities are interconnected.
Prudent Electrcal Practices are those practice, methods and equipment that are commonly used In prudent
electrical engineering and operations to operate electric equipment lawfully and with safety, dependabilty,
effciency and ecnomy.
PURPA means the Public Utilty Regulatory Policies Act of 1978.
Issued by IDAHO POWER COMPANY
By John R. Gale, Vice President, Regulatory Affairs
1221 West Idaho Street, Boise, Idaho
Advice No. 10-02
OREGON
Issued: July 31, 2009
Effective with Service
Rendered on and afer:
March 1, 2010
IDAHO POWER COMPANY
P.U.C. ORE. NO. E-27 ORIGINAL SHEET NO. 85-3
SCHEDULE 85
COGENERATION AND SMALL POWER
PRODUCTION STANDARD
CONTRACT RATES
(Continued)
RECEIVED
MAR 0 12010
PUC
Utilty Program
DEFINITIONS (Continued)
Qualifyng Facilty or QF is a cogeneration facilty or a small power producton facility which meets the PURPA
criteria for qualifcation set forth in Subpart B of Part 292, Subchapter K, Chapter I, Title 18, of the Code of
Federal Regulations.
Seasonality Factor is the factor used in determining the seasonal purchase price of energy. The applicable
factors are:
73.50% for Season 1 (March, April, May);
120.00% for Season 2 (July, August, November, December);
100.00% for Season 3 (June, September, October, January, February).
Seller is any entity that owns or operates a Qualifing Facilty and desires to sell Energy to the Company.
Standard Contracts are the pro forma Energy Sales Agreements the Company maintains on file with the Public
Utilty Commission of Oregon for Intermittent and non-intermittent on-system Qualifing Facilties and Intermittent
and non-intermittent off-system Qualifyng Facilties, with a Nameplate Capacity of 10 MW or less.
Station Use is electric energy used to operate the Qualifing Facilty which is auxiliary to or directly related to the
generation of electricity and which, but for the genertion of electricity, would not be consumed by the Seller.
QUALIFYING FACILITY INFORMATION INQUIRY PROCESS
There are two separate proceses required for a Seller to deliver and sell energy from a Qualifng Facility to the
Company. These processes may be completed separately or simultaneously.
1. Generation Interconnection Process
All generation project physically interconnecting to the Company's electrical system, regardless of size,
location or ownership, must successfully complete the Generation Interconnection Process prior to the
project delivering energy to the Company. A complete description of the Small Generator Interconnection
Procedures, the Interconnection Application and Company contact information is maintained on the Idaho
Power website at ww.idahopower.com. or Seller may contact the Company's Delivery Business Unit at
1-208-388-2658 for further information.
All generation projects delivering power under the off-system Energy Sales Agreement must successfully
complete a comparable Generation Interconnection Process with the Sellets host interconnection
provider and transmission provider.
2. Energy Sales Agreement
To begin the proces of completing a Standard Contrct or negotiating a Non-Standard Contrct, for a
proposed project, the Seller must submit to the Company a request for an Energy Sales Agreement. All
requests wil be processed in the order of receipt by the Company.
Issued by IDAHO POWER COMPANY
By John R. Gale, Vice President, Regulatory Affirs
1221 West Idaho Street, Boise, Idaho
Advice No. 10-02
OREGON
Issued: July 31, 2009
Effecive with Service
Rendered on and after:
March 1, 2010
ORIGINAL SHEET NO. 85-4
SCHEDULE 85
COGENERATION AND SMALL POWER
PRODUCTION STANDARD
CONTRACT RATES
(Continued)
QUALIFYING FACILITY INFORMATION INQUIRY PROCESS (ContinuedO
IDAHO POWER COMPANY
P.U.C. ORE. NO. E-27
RECEIV¡O
MAR 0 12Ò\O
pUC
Utilty program
a. Communications
2. Energy Sales Agreement (Continued)
Unless otherise directed by the Compány. all communications to the Company regarding an
Energy Sales Agreement should be directed in wrting as follows:
b. Procedures
Idaho Power Company
Cogeneration and Small Power Production
PO Box 70
Boise. Idaho 83707
i. The Company's approved Energy Sales Agreement may be obtained from the
Company's website at http://ww.idahopower.com or if the Seller is unable to obtain it
from the website, the Company wil send a copy within 10 business days of a wrtten
request.
ii. In order to obtain a project specific draft Energy Sales Agreement the Seller must provide
in writing to the Company, general project information required for the completion of an
Energy Sales Agreement, including, but not limited to:
a)
b)
c)
d)
e)
f)
g)
h)
Date of request
Company I Organization that wil be the contracting part
Contract notifcation information including name, address and telephone number
Verifcation that the Qualifng Facilty meets the "Eligibßity for Standard Rates
and Contrcl criteria
Copy of the Qualifing Faciltys QF certificate
Copy of the FERC license (applicable to hydro projects only)
Location of the proposed project including general area and specifc legal
property description
Description of the proposed project including specific equipment models, types,
sizes and configurations
Type of project (wind, hydro, geothermal etc)
Nameplate capacity of the proposed project
Schedule 85 pricing option selected
Desired term of the Energy Sales Agreement
Annual net energy amount
Maximum capacity of the Qualifying Facilty
Estimated first energy date
Estimated operation date
Point of Delivery
Status of the Generation Interconnection Proces
i)
j)
k)
I)
m)
n)
0)
p)
q)
r)
Issued by IDAHO POWER COMPANY
By John R. Gale, Vice President, Regulatory Affairs
1221 West Idaho Street, Boise, Idaho
Advice No. 10-02
OREGON
Issued: July 31, 2009
Effective with Service
Rendered on and after:
March 1, 2010
IDAHO POWER COMPANY
P.U.C. ORE. NO. E-27
REceIVi.D
ORIGINAL SHEET NO. 85-5
SCHEDULE 85
COGENERATION AND SMALL POWER
PRODUCTION STANDARD
CONTRACT RATES
(Continued)
QUALIFYING FACILITY INFORMATION INQUIRY PROCESS (Continued)
MAR 0 12010
pUC
Utilty Program
b. Procedures (Continued)
ii. The Company shall provide a dra Energy Sales Agreeent when all information
described in Paragraph 2 above has been receive in writing from the Seller. Within 15
business days following receipt of all information required in Pararaph 2, the Company
wil provide the Seller with a draft Energy Sales Agreement including current standard
avoided cost prices and/or other optional pricing mechanisms as approved by the Oregon
Public Utilty Commission in this Schedule.
iv. The Company wil respond within 15 business days to any written comment and
proposals that the Seller provides in response to the draft Energy Sales Agreement.
v. If the Seller desires to procee with the Energy Sales Agreement afer reiewing the
Company's draft Energy Sales Agreement, it may request in writing that the Company
prepare a final draft Energy Sales Agreement. In connection with such request, the Seller
must provide the Company with an updated status of the Generation Intercnection
Process which indicates that the Seller's provided information (i.e. first energy date,
operation date, etc.) are realistically attainable and any additional or claried project
information that the Company reasonably determines to be necssary for the preparation
of a final draft Energy Sales Agreement. Once the Company has received the written
request for a final draft Energy Sales Agrement and all additional or clarifed project
information that the Company reasonably determines to be necessary for the preparation
of a final draft Energy Sales Agreement, the Company wil provide Seller with a final draft
Energy Sales Agreement within 15 business days.
vi. After reviewing the final draft Energy Sales Agreement, the Seller may either prepare
another set of written comments and proposals or approve the final draft Energy Sales
Agreement. If the Seller prepares written comments and proposals, the Company wil
respond within 15 business days to those comments and proposals.
vii. When both parties are in full agreement as to all terms and conditions of the final draft
Energy Sales Agreement, the Company wil prepare and forwrd to the Seller within 15
business days a final executable version of the Energy Sales Agreement. Once the
Seller executes the Energy Sales Agreement and returns all copies to the Company. the
Company wil execute the Energy Sales Agreement. Following the Company's exection
a completely executed copy wil be returned to the Seller. Prices and other ters and
conditions in the Energy Sales Agreement wil not be final and binding until the Energy
Sales Agreement has been executed by both partes.
Issued by IDAHO POWER COMPANY
By John R. Gale, Vice President, Regulatory Affairs
1221 West Idaho Street, Boise, Idaho
OREGON
Issued: July 31,2009
Effective with Service
Rendered on and after:
March 1, 2010Advice No. 10-02
IDAHO POWER COMPANY
P.U.C. ORE. NO. E-27
AVOIDED COST COMPONENTS
FIRST REVISED SHEET NO 85-6
CANCELS
ORIGINAL SHEET NO. 85-6
SCHEDULE 85
COGENERATION AND SMALL POWER
PRODUCTION STANDARD
CONTRACT RATES
(Continued)
RECEIVED
NOV 1 22mO
P lJ "
Utilty Program
The Avoided Cost Components are calculated based upon the Surrogate Avoided Resource methodology (SAR)
for determining the Company's standard avoided costs.
Year
2010
2011
2012
2013
2014
2015
2016
2017
2018
2019
2020
2021
2022
2023
2024
2025
2026
2027
2028
2029
2030
2031
2032
2033
2034
2035
2036
2037
2038
2039
Capacity Cost
(millslWh)
37.72
38.29
38.87
39.46
40.05
40.66
41.27
41.89
42.53
43.17
43.82
44.49
45.16
45.84
46.54
47.24
47.96
48.69
49.43
50.18
50.94
51.71
52.50
53.30
54.11
54.93
55.76
56.61
57.48
58.35
Fuel Cost
(milS/kWh)
42.10
49.49
51.33
53.04
54.24
54.60
54.95
56.73
58.15
59.64
61.70
63.40
64.47
67.81
69.44
70.86
72.21
73.20
74.05
74.69
74.91
76.18
76.96
77.82
78.60
79.45
80.23
81.08
81.86
82.64
(C)
(C)
Issued by IDAHO POWER COMPANY
By Gregory W Said, General Manager. Regulatory Affirs
1221 West Idaho Street, Boise, Idaho
Advice No. 10-18
OREGON
Issued: November 9, 2010
Effecve with Service
Rendered on and after:
December 15, 2010
IDAHO POWER COMPANY
P.U.C. ORE. NO. E-27
RECEIVED
ORIGINAL SHEET NO. 85-7
SCHEDULE 85
COGENERATION AND SMALL POWER
PRODUCTION STANDARD
CONTRACT RATES
(Continued)
MAR 0 12010
PUC
Utilty Program
NET ENERGY PURCHASE PRICE
The Company wil pay the Seller monthly, for each kWh of Energy delivered and accepted at the Point of Delivery
during the preceding calendar month, in accordance with the Standard Contract, an amount determined by the
Sellets choice of one of the following options:
Option 1 - Fixed Price Method
Net Energy Purchase Price =
On-peak = (Fuel Cost + Capacity Cost) X Seasonality Factor
Off-peak = Fuel Cost X Seasonality Factor
where
Fuel Cost and Capacity Cost are the Avoided Cost Components established in this schedule for the
applicable calendar year of the actual Net Energy deliveries to the Company.
Option 2 - Dead Band Method
Net Energy Purchase Price =
On-peak = (AGPU + Capacity Cost) X Seasonality Factor
Of-peak = AGPU X Seasonality Factor
Actual Gas Price Used (AGPU) =
90% of Fuel Cost If
Indexed Fuel Cost is less than 90% Fuel Cost; else
110% of Fuel Cost if
Indexed Fuel Cost is greater than 110% Fuel Cost; else
Indexed Fuel Cost
where
Fuel Cost and Capacit Cost are the Avoided Cost Components established in this schedule for the
applicable calendar year of the actual Net Energy deliveries to the Company, and
Indexed Fuel Cost is the applicable weighted monthly average index price of natural gas at Sumas
multiplied by the Heat Rate Conversion Factor.
Issued by IDAHO POWER COMPANY
By John R. Gale, Vice President, Regulatory Affairs
1221 West Idaho Street, Boise, Idaho
Advice No. 10..2
OREGON
Issued: July 31, 2009
Effective with Service
Rendered on and after:
March 1, 2010
IDAHO POWER COMPANY
P.U.C. ORE. NO. E-27 ORIGINAL SHEET NO. 85-
AECÈIViD
SCHEDULE 85
COGENERATION AND SMALL POWER
PRODUCTION STANDARD
CONTRACT RATES
(Continued)
MAR 0 120\0
PUC
Utilty Program
NET ENERGY PURCHASE PRICE (Continued)
Option 3 - Gas Market Method
Net Energy Purchase Price =
On-peak = (AGPU + Capacity Cost) X Seasonality Factor
Off-peak = AGPU X Seasonality Factor
Actual Gas Price Used (AGPU) = Indexed Fuel Cost
where
Capacity Cost is the Avoided Cost Component established in this schedule for the applicable calendar
year of the actual Net Energy deliveries to the Company, and
Indexed Fuel Cost is the applicable weighted monthly average index price of natural gas at Sumas
multiplied by the Heat Rate Conversion Factor.
MISCELLANEOUS PROVISIONS
Insurance
Qualifying Facilities with a Nameplate Capacity of 200 kilowatts or smaller are not required to provide evidence of
liabilty insurance.
GUIDELINES FOR NEGOTIATION OF POWER PURCHASE AGREEMENTS
FOR QFS WITH A NAMEPLATE CAPACITY OF 10 MW OR LARGER
1. The Company wil not Impose terms and conditions beyond what Is standard practice. The Edison Electric
Institute master agreement and the Company's Standard Contracts are useful starting points in
negotiating QF agreements.
2. The Company wH/ provide an indicative pricing proposal for a QF that plans to provide firm energy or
capacity and chooses avoided cost rates calculated at the time of the obligation. The Company will
provide an indicative pricing proposal witin 30 days of recipt of the information the Company requires
from the QF. The proposal may include other terms and conditions, tailored to the individual
characteristics of the proposed project. The avoided cost rates in the indicative pricing proposal wil be
based on the following:
a. The starting point for negotiations is the avoided cost calculated under the modeling methodology
approved by the Idaho Public Utilties Commission for QFs over 10 MW, as refined by the Oregon
Public Utilty Commission to incorporate stochastic analyses of electric and natural gas prics,
loads, hydro and unplanned outages.
b. The prospective QF may request in writing that the Company prepare a draft power purchase
agreement to serve as the basis for negotiations. The Company may require additional
information from the QF necessary to prepare a draft agreement. .
Issued by IDAHO POWER COMPANY
By John R. Gale, Vice President, Regulatory Affairs
1221 West Idaho Street, Boise, Idaho
OREGON
Issued: July 31, 2009
Effective with Service
Rendered on and after:
March 1, 2010Advice No. 10-02
IDAHO POWER COMPANY
P.U.C. ORE. NO. E-27 ORIGINAL SHEET NO. 85-9
SCHEDULE 85
COGENERATION AND SMALL POWER
PRODUCTION STANDARD
CONTRACT RATES
(Continued)
GUIDELINES FOR NEGOTIATION OF POWER PURCHASE AGREEMENTS
FOR QFS WITH A NAMEPLATE CAPACITY OF 10 MW OR LARGER (Continued)
.AECEIViO
MAR 0 12010
PUC
Utilty Program
c. Within 30 days of receiving the required information. the Company will provide a draft power
purchase agreement containing a comprehensive set of proposed terms and conditions.
d. The QF must submit in writing a statement of its intention to begin negotiations with the Company
and may include written comments and proposals. The Company is not obligated to begin
negotiations until it receives writen notification from the QF. The Company wil not unreasonably
delay negotiations and wil respond in good faith to all proposals by the QF.
e. When the parties have agreed, the Company wil prepare a final version of the contract within 15
business days. A contra is not final and binding until signed by both parties.
f. At any time afer 60 days from the date the QF has provided its written notification pursuant to
paragraph d., the QF may file a complaint wih the Oregon Public Utility Commission asking the
Commission to adjudicate any unresolved contract terms and conditions.
3. QFs have the unilateral right to select a contract length of up to 20 years for a PURPA contract. The
contract lengt selected by the QF may impac other contractual issues including, but not limited to, the
avoided cost determination with respect to that QF.\
4. The Company should consider the QF to be providing firm energy or capacity if the contract requires
delivery of a specifed amount of energy or capacity over a specifed term and includes sanctions for non-
compliance under a legally enforceable obligation. The Company shall not determine that a QF provides
no capacity value simply because the Company did not select it through a competitive bidding process.
For a QF providing firm energy or capacity
a. The Company and the QF should negotiate the time periods when the QF may schedule outaes
and the advance notifcation requirement for such outages, using provisions in the Company's
partial requirements tarif as guidance.
b. The QF should be required to make best effort to meet its capacity obligations during Company
system emergencies.
c. The Company and the QF should negotiate secrity. default, damage and termination provisions
that keep the Company and its ratepayers whole in the event the QF fails to meet obligations
under the contract.
d. Delay of comercial operation should not be a cause of termination if the Company determines
at the time of contract execution that it will be resourcesuffcient as of the QF on-line date
specified In the contrct; however, damages may be appropriate.
e. Lack of natural motive force for testing to prove commercial operation should not be a cause of
termination.
f. The Company should include a provision in the contract that states the Company may require a
QF terminated due to it default and wishing to resume sellng to the Company be subject to the
terms of the original contract unti its end date.
Issued by IDAHO POWER COMPANY
By John R. Gale, Vice President, Regulator Affirs
1221 West Idaho Street, Boise, Idaho
OREGON
Issued: July 31. 2009
Effective with Service
Rendered on and afer:
March 1, 2010Advice NO.1 0-02
IDAHO POWER COMPANY
P.U.C. ORE. NO. E-27 ORIGINAL SHEET NO. 85-10
SCHEDULE 85
COGENERATION AND SMALL POWER
PRODUCTION STANDARD
CONTRACT RATES
(Continued)
GUIDELINES FOR NEGOTIATION OF POWER PURCHASE AGREEMENTS
FOR QFS WITH A NAMEPLATE CAPACITY OF 10 MW OR LARGER (Continued)
ReCEIV~D
MAR 0 12010
PUC
Utility Program
5. An "as availableu obligation for delivery of energy, including deliveries in excess of Nameplate Capacity or
the amount committed in the QF contrct, should be treated as a non-firm commitment. Non-firm
commitments should not be subject to minimum delivery requirements, default damages for construction
delay or under-delivery, default damages for the QF choosing to terminate the contract early, or default
security for these purposes.
6. For QFs unable to establish creditworthiness, the Company must at a minimum allow the QF to choose
either a letter of credit or cash escrow for providing default security. When determining security
requirements, the Company should take into account the risk associated with the QF based on such
factor as its size and tye of supply commitments.
7. When QF rates are based on avoided costs calculated at the time of delivery, the Company should use
day-ahead on- and off-peak market index prices at the appropriate market hub(s).
a. For QFs providing firm energy or capacity that chooe this option, avoided cost rates should be
based on day-ahead market index prices for firm purchases.
b. For QFs providing energy on an "as available" basis, avoided cost rates should be based on day-
. ahead market index prices for non-firm purchases.
8. The Company should not make adjustments to standard avoided cost rates other than those approved by
the Oregon Public Utility Commission and consistent with these guidelines.
9. The Company should make adjustments to avoided costs for reliability on an expected forward-looking
basis. The Company should design QF rates to provide an incentive for the QF to achieve the contracted
level and timing of energy deliveries.
10. The Company should make adjustments to avoided costs for dispatchabilty on a probabilistic, forwar
looking basis.
11. If avoided cost rates for a QF are calculated at the time of the obligation and the Company's avoided
resource is a fossil fuel plant, the Company should adjust avoided cost rates for the resource deficiency
period to take into account avoided fossil fuel price risk.
12. Avoided cot rates for wind QFs should be adjusted for integration cost estimates based on studies
conducted for the Company's system, unless the QF contracts for integration services with a third part.
a. The Company should use the most recent integration cost data available, consistent with its
evaluation of competitively bid and self-build wind resources.
b. The portion of integration costs attributable to reserves costs should be based on the diference in
such costs between the wind QF and the Company proxy plant.
Issued by IDAHO POWER COMPANY
By John R. Gale, Vice President, Regulatory Affairs
1221 West Idaho Street, Boise, Idaho
Advice No. 10-02
OREGON
Issued: July 31, 2009
Effective with Service
Rendered on and after:
March 1, 2010
IDAHO POWER COMPANY
P.U.C. ORE. NO. E-27 ORIGINAL SHEET NO. 85-11
.Recel~D
SCHEDULE 85
COGENERATION AND SMALL POWER
PRODUCTION STANDARD
CONTRACT RATES
(Continued)
GUIDELINES FOR NEGOTIATION OF POWER PURCHASE AGREEMENTS
FOR QFS WITH A NAMEPLATE CAPACITY OF 10 MW OR LARGER (Continued)
MAR 0 120\0
pUC
Utilty Program
c. The Company should base first-year integration costs on the actual level of wind resources in the
control area, plus the proposed QF. Integration costs for years two through five of the contrct
should be based on the expected level of wind resources in the control area each year, including
the new resources the Company expects to add. Integration cots should be fixed at the year-five
level, adjusted for inflation, for the remainder of the life of the wind projects in the control area.
d. The Company is prohibited from using a long-range planning target for wind resources as the
basis for integration costs. However, if the Company is subject to near-term targets under a
mandatory Renewable Portolio Standard, the Company may base its integration costs on the
level of renewable resources it must acquire over the next 10 years.
e. In determining integration costs, the Company should make reasonable estimates regarding the
portion of renewable resources to be acquired that wil be intermittent resources.
13. The Company should adjust avoided cost rates for QF line losses relative to the Company proxy plant
based on a proximity-based approach.
14. The Company should evaluate whether there are potential savings due to trnsmission and distribution
system upgrades that can be avoided or deferred as a result of the QFs location relative to the Company
proxy plant and adjust avoided cost rates accordingly.
15. The Company should not adjust avoided cost rates for any distribution or transmission system upgraes
needed to accept QF power. Such costs should be separately charged as part of the interconnection
process.
16. The Company should not adjust avoided cost rates based on it determination of the additional cost it
might incur for any debt imputation by a credit rating agency.
17. Regarding Surplus Sale and Simultaneous Purchase and Sale:
a. . QFs may either contrct with the Company for a .surplus sale" or for a .simultaneous purchase
and sale" provided, however, that the QFs selection of either such contractual arrangement shall
not be inconsistent with any retail tarif provision of the. Company then in effect or any agreement
between the QF and the Company;
b. The two sale/purchase arrangements described in paragraph 17. a will be available to QFs
regardless of whether they qualify for standard contracts and rates or non-standard contracts and
rates, however the .simultaneous purchase and sale" is not available to QFs not directly
connected to the Company's electrical system;
c. The negotiation parameters and guidelines should be the same for both sale/purchase
arrangeents described in paragraph 17. a; and
d. The avoided cost calculations by the Company do not require adjustment solely as a result of the
selection of one of the sale/purchase arrngements described in paragraph 17.a., rather than the
other.
Issued by IDAHO POWER COMPANY
By John R. Gale, Vice President, Regulatory Affirs
1221 West Idaho Street, Boise, Idaho
OREGON
Issued: July 31, 2009
Effective with Service
Rendered on and afer:
March 1, 2010Advice No. 10-02