20121121Attachments.pdf

BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 1
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FIRM ENERGY SALES AGREEMENT
BETWEEN
TITLE
Definitions
IDAHO POWER COMPANY
AND
NEW ENERGY THREE, LLC
TABLE OF CONTENTS
No Reliance on Idaho Power
Warranties
Conditions to Acceptance of Energy
Term and Operation Date
Purchase and Sale of Net Energy
Purchase Price and Method of Payment
Environmental Attributes
Facility and Interconnection
Metering and Telemetry
Records
Operations
Indemnification and Insurance
Force Majeure
Liability; Dedication
Several Obligations
Waiver
Choice of Laws and Venue
Disputes and Default
Governmental Authorization
Commission Order
Successors and Assigns
Modification
Taxes
Notices
Additional Terms and Conditions
Severability
Counterparts
Entire Agreement Signatures
Appendix A
Appendix B
Appendix C
Appendix D
FIRM ENERGY SALES AGREEMENT
(10 aMW or Less)
Project Name: Double B Dairy
Project Number: 31616120
THIS AGREEMENT, entered into on this J_ ¥taay of fh 4f 20 I 0 between NEW ENERGY
THREE, LLC, an Idaho limited liabil.ity company (Seller), and IDAHO POWER COMPANY, an Idaho
corporation (Idaho Power), hereinafter sometimes referred to collectively as "Parties" or individually as "Party."
WITNESSETH:
WHEREAS, Seller will design, construct, own, maintain and operate an electric generation facility; and
WHEREAS, Seller wishes to sell, and Idaho Power is willing to purchase, firm electric energy produced
by the Seller's Facility.
THEREFORE, In consideration of the mutual covenants and agreements hereinafter set forth, the
Parties agree as follows:
ARTICLE I: DEFINITIONS
As used in this Agreement and the appendices attached hereto, the following terms
shall have the following meanings:
1.1 "Base Energy"-Monthly Net Energy less than L l 0% of the monthly Net Energy Amount as specified
in paragraph 6.2 of this Agreement.
1.2 "Commission"-The Idaho Public Utilities Commission.
I .3 "Contract Year"-The period commencing each calendar year on the same calendar date as the
Operation Date and ending 364 days thereafter.
1.4 "Delay Liquidated Damages"-Damages payable to Idaho Power as calculated in paragraph 5.3, 5.4,
5.5, 5.6 and 5.8.
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1.5 "Delay Period"-All days past the Scheduled Operation Date until the Seller's Facility achieves the
Operation Date.
1.6 "Delay Price"-The current month's Mid-Columbia Market Energy Cost minus the current month's All
Hours Energy Price specified in paragraph 7.3 of this Agreement. If this calculation results in a value
less than 0, the result of this calculation will be 0.
1.7 "Designated Dispatch Facility"-Idaho Power's Systems Operations Group, or any subsequent group
designated by Idaho Power.
1.8 "Facility"-That electric generation facility described in Appendix B of this Agreement.
1.9 "First Energy Date"-The day commencing at 00:01 hours, Mountain Time, following the day that
Seller has satisfied the requirements of Article IV and the Seller begins delivering energy to Idaho
Power's system at the Point of Delivery.
1.10 "Heavy Load Hours"-The daily hours beginning at 7:00 am, ending at 11 :00 pm Mountain Time, ( 16
hours) excluding all hours on all Sundays, New Years Day, Memorial Day, Independence Day, Labor
Day, Thanksgiving and Christmas.
1.11 "Inadvertent Energy" -Electric energy Seller does not intend to generate. Inadvertent energy is more
particularly described in paragraph 7.5 of this Agreement.
1.12 "Interconnection Facilities" -All equipment specified in Schedule 72.
1.13 "Initial Capacity Determination"-The process by which Idaho Power confirms that under normal or
average design conditions the Facility will generate at no more than 10 average MW per month and is
therefore eligible to be paid the published rates in accordance with Commission Order No. 29632.
1.14 "Light Load Hours" -The daily hours beginning at 11 :00 pm, ending at 7:00 am Mountain Time (8
hours), plus all other hours on all Sundays, New Years Day, Memorial Day, Independence Day, Labor
Day, Thanksgiving and Christmas.
1.15 "Losses"-The loss of electrical energy expressed in kilowatt hours (kWh) occurring as a result of the
transformation and transmission of energy between the point where the Facility's energy is metered and
the point the Facility's energy is delivered to the Idaho Power electrical system. The loss calculation
formula will be as specified in Appendix B of this Agreement.
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1.16 "Market Energy Reference Price"-Eighty-five percent (85%) of the Mid-Columbia Market Energy
Cost.
1.17 "Material Breach"-A Default (paragraph 19.2.1) suhject to p;m1e;r::~ph 1 Q.?. ?.
1.18 "Maximum Capacity Amount"-The maximum capacity (MW) of the Facility will be as specified in
Appendix B of this Agreement.
1.19 "Metering Equipment" -All equipment specified in Schedule 72, this Agreement and any additional
equipment specified in Appendix B required to measure, record and telemeter bi directional power
flows between the Seller's electric generation plant and Idaho Power's system.
1.20 "Mid-Columbia Market Energy Cost" -The monthly weighted average of the daily on-peak and off­
peak Dow Jones Mid-Columbia Index (Dow Jones Mid-C Index) prices for non-firm energy. If the Dow
Jones Mid-Columbia Index price is discontinued by the reporting agency, both Parties will mutually
agree upon a replacement index, which is similar to the Dow Jones Mid-Columbia Index. The selected
replacement index will be consistent with other similar agreements and a commonly used index by the
electrical industry.
1.21 "Nameplate Capacity"-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, kilovolt-amperers, kilowatts, volts or other appropriate
units. Usually indicated on a nameplate attached to the individual machine or device.
1.22 "Net Energy"-All of the electric energy produced by the Facility, less Station Use, less Losses,
expressed in kilowatt hours (kWh). Subject to the terms of this Agreement, Seller commits to deliver all
Net Energy to Idaho Power at the Point of Delivery for the full tenn of the Agreement. Net Energy does
not include Inadvertent Energy.
1.23 "Operation Date"-The day commencing at 00:01 hours, Mountain Time, following the day that all
requirements of paragraph 5.2 have been completed.
1.24 "Point of Delivery"-The location specified in Appendix B, where Idaho Power's and the Seller's
electrical facilities are interconnected and the energy from this Facility is delivered to the Idaho Power
electrical system.
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1.25 "Prudent Electrical Practices"-Those practices, methods and equipment that are commonly and
ordinarily used in electrical engineering and operations to operate electric equipment lawfully, safely,
dependably, efficiently and economically.
1.26 "Scheduled Operation Date" -The date specified in Appendix B when Seller anticipates achieving the
Operation Date. It is expected that the Scheduled Operation Date provided by the Seller shall be a
reasonable estimate of the date that the Seller anticipates that the Seller's Facility shall achieve the
Operation Date.
1.27 "Schedule 72"-Idaho Power's Tariff No 101, Schedule 72 or its successor schedules as approved by
the Commission. The Seller shall be responsible to pay all costs of interconnection and integration of
this Facility into the Idaho Power electrical system as specified within Schedule 72.
1.28 "Season"-The three periods identified in paragraph 6.2.1 of this Agreement.
1.29 "Special Facilities" -Additions or alterations of transmission and/or distribution lines and transformers
as described in Schedule 72.
1.30 "Station Use"-Electric energy that is used to operate equipment that is auxiliary or otherwise related to
the production of electricity by the Facility.
1.31 "Surplus Energy" -Is (1) Net Energy produced by the Seller's Facility and delivered to the Idaho Power
electrical system during the month which exceeds 110% of the monthly Net Energy Amount for the
corresponding month specified in paragraph 6.2. or (2) If the Net Energy produced by the Seller's
Facility and delivered to the Idaho Power electrical system during the month is less than 90% of the
monthly Net Energy Amount for the corresponding month specified in paragraph 6.2, then all Net
Energy delivered by the Facility to the Idaho Power electrical system for that given month or (3) All Net
Energy produced by the Seller's Facility and delivered by the Facility to the Idaho Power electrical
system prior to the Operation Date.
1.32 "Total Cost of the Facility" -The total cost of structures, equipment and appurtenances.
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ARTICLE II: NO RELIANCE ON IDAHO POWER
2.1 Seller Independent Investigation -Seller warrants and represents to Idaho Power that in entering into
this Agreement and the undertaking by Seller of the obligations set forth herein, Seller has investigated
and determined that it is capable of performing hereunder and has not relied upon the advice,
experience or expertise ofldaho Power in connection with the transactions contemplated by this
Agreement.
2.2 Seller Independent Experts -All professionals or experts including, but not limited to, engineers,
attorneys or accountants, that Seller may have consulted or relied on in undertaking the transactions
contemplated by this Agreement have been solely those of Seller.
ARTICLE III: WARRANTIES
3.1 No Warranty by Idaho Power-Any review, acceptance or failure to review Seller's design,
specifications, equipment or facilities shall not be an endorsement or a confirmation by Idaho Power and
Idaho Power makes no warranties, expressed or implied, regarding any aspect of Seller's design,
specifications, equipment or facilities, including, but not limited to, safety, durability, reliability,
strength, capacity, adequacy or economic feasibility.
3.2 Qualifying Facility Status-Seller warrants that the Facility is a "Qualifying Facility," as that term is
used and defined in 18 CFR 292.201 et seq. After initial qualification, Seller will take such steps as may
be required to maintain the Facility's Qualifying Facility status during the term of this Agreement and
Seller's failure to maintain Qualifying Facility status will be a Material Breach of this Agreement.
Idaho Power reserves the right to review the Facility's Qualifying Facility status and associated support
and compliance documents at anytime during the term of this Agreement.
ARTICLE IV: CONDITIONS TO ACCEPTANCE OF ENERGY
4.1 Prior to the First Energy Date and as a condition of Idaho Power's acceptance of deliveries of energy
from the Seller under this Agreement, Seller shall:
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4.1.1 Submit proof to Idaho Power that all licenses, permits or approvals necessary for Seller's
operations have been obtained from applicable federal, state or local authorities, including, but
not limited to, evidence of compliance with Subpart B, 18 CFR 292.201 et seq. as a certified
QualifYing Facility.
4.1.2 Opinion of Counsel -Submit to Idaho Power an Opinion Letter signed by an attorney admitted
to practice and in good standing in the State ofldaho providing an opinion that Seller's licenses,
permits and approvals as set forth in paragraph 4.1.1 above are legally and validly issued, are
held in the name of the Seller and, based on a reasonable independent review, counsel is of the
opinion that Seller is in substantial compliance with said permits as of the date of the Opinion
Letter. The Opinion Letter will be in a form acceptable to Idaho Power and will acknowledge
that the attorney rendering the opinion understands that Idaho Power is relying on said opinion.
Idaho Power's acceptance of the form will not be unreasonably withheld. The Opinion Letter
will be governed by and shall be interpreted in accordance with the legal opinion accord of the
American Bar Association Section of Business Law (1991).
4.1.3 Initial Capacity Determination -Submit to Idaho Power such data as Idaho Power may
reasonably require to perform the Initial Capacity Determination. Such data will include but not
be limited to, Nameplate Capacity, equipment specifications, prime mover data, resource
characteristics, normal and/or average operating design conditions and Station Use data. Upon
receipt of this information, Idaho Power will review the provided data and if necessary, request
additional data to complete the Initial Capacity Determination within a reasonable time.
4.1.3 .1 If the Maximum Capacity specified in Appendix B of this Agreement and the
cumulative manufacture Nameplate Capacity rating of the individual generation units at
this Facility is less than 10 MW. The Seller shall submit detailed, manufacturer,
verifiable data of the Nameplate Capacity ratings of the actual individual generation
units to be installed at this Facility. Upon verification by Idaho Power that the data
provided establishes the combined Nameplate Capacity rating of the generation units to
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be installed at this Facility is less than 10 MW, it will be deemed that the Seller has
satisfied the Initial Capacity Determination for this Facility.
4.1.4 Nameplate Capacity -Submit to Idaho Power manufacturer's and engineering documentation
that establishes the Nameplate Capacity of each individual generation unit that is included
within this entire Facility. Upon receipt of this data, Idaho Power shall review the provided data
and determine if the Nameplate Capacity specified is reasonable based upon the manufacturer's
specified generation ratings for the specific generation units.
4.1.5 Engineer's Certifications -Submit an executed Engineer's Certification of Design &
Construction Adequacy and an Engineer's Certification of Operations and Maintenance (O&M)
Policy as described in Commission Order No. 21690. These certificates will be in the form
specified in Appendix C but may be modified to the extent necessary to recognize the different
engineering disciplines providing the certificates.
4.1.6 Insurance -Submit written proof to Idaho Power of all insurance required in Article XIII.
4.1.7 Interconnection-Provide written confirmation from Idaho Power's delivery business unit that
Seller has satisfied all interconnection requirements.
4.1.8 Network Resource Designation-The Seller's Facility has been designated as a network
resource capable of delivering firm energy up to the amount of the Maximum Capacity.
4.1.9 Written Acceptance-Request and obtain written confirmation from Idaho Power that all
conditions to acceptance of energy have been fulfilled. Such written confirmation shall be
provided within a commercially reasonable time following the Seller's request and will not be
unreasonably withheld by Idaho Power.
ARTICLE V: TERM AND OPERATION DATE
5.1 Term-Subject to the provisions of paragraph 5.2 below, this Agreement shall become effective on the
date first written and shall continue in full force and effect for a period of 15 (not to exceed 20 years)
Contract Years from the Operation Date.
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5.2 Operation Date-The Operation Date may occur only after the Facility has achieved all of the following:
a) Achieved the First Energy Date.
b) Commission approval of this Agreement in a form acceptable to Idaho Power has been
received.
c) Seller has demonstrated to Idaho Power's satisfaction that the Facility is complete and able
to provide energy in a consistent, reliable and safe manner.
d) Seller has requested an Operation Date from Idaho Power in a written format.
e) Seller has received written confirmation from Idaho Power of the Operation Date. This
confirmation will not be unreasonably withheld by Idaho Power.
5.3 Operation Date Delay -Seller shall cause the Facility to achieve the Operation Date on or before the
Scheduled Operation Date. Delays in the interconnection and transmission network upgrade study, design
and construction process that are not Force Majeure events accepted by both Parties, shall not prevent
Delay Liquidated Damages from being due and owing as calculated in accordance with this Agreement.
5.3 .1 If the Operation Date occurs after the Scheduled Operation Date but on or prior to 90 days
following the Scheduled Operation Date, Seller shall pay Idaho Power Delay Liquidated
Damages calculated at the end of each calendar month after the Scheduled Operation Date as
follows:
Delay Liquidated Damages are equal to ((Current month's Initial Year Net Energy
Amount as specified in paragraph 6.2.1 divided by the number of days in the current
month) multiplied by the number of days in the Delay Period in the current month)
multiplied by the current month's Delay Price.
5.3.2 If the Operation Date does not occur within ninety (90) days following the Scheduled Operation
Date the Seller shall pay Idaho Power Delay Liquidated Damages, in addition to those provided
in paragraph 5 .3 .1, calculated as follows:
Forty five dollars ($45) multiplied by the Maximum Capacity with the Maximum
Capacity being measured in kW.
5.4 If Seller fails to achieve the Operation Date within ninety (90) days following the Scheduled Operation
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..
Date, such failure will be a Material Breach and Idaho Power may terminate this Agreement at any time
until the Seller cures the Material Breach. Additional Delay Liquidated Damages beyond those
calculated in 5.3.1 and 5.3.2 will be calculated and payable using the Delay Liquidated Damage
calculation described in 5.3.1 above for all days exceeding 90 days past the Scheduled Operation Date
until such time as the Seller cures this Material Breach or Idaho Power terminates this Agreement.
5.5 Seller shall pay Idaho Power any calculated Delay Damages or Delay Liquidated Damages within 7
days of when Idaho Power calculates and presents any Delay Damages or Delay Liquidated Damages
billings to the Seller. Seller's failure to pay these damages within the specified time will be a Material
Breach of this Agreement and Idaho Power shall draw funds from the Delay Security provided by the
Seller in an amount equal to the calculated Delay Damages or Delay Liquidated Damages.
5.6 The Parties agree that the damages Idaho Power would incur due to delay in the Facility achieving the
Operation Date on or before the Scheduled Operation Date would be difficult or impossible to predict
with certainty, and that the Delay Liquidated Damages are an appropriate approximation of such
damages.
5.7 Prior to the Seller executing this Agreement, the Seller shall have agreed to and executed a Letter of
Understanding with Idaho Power that contains at minimum the following requirements:
a) Seller has filed for interconnection and is in compliance with all payments and
requirements of the interconnection process
b) Seller has received and accepted an interconnection feasibility study for this
Facility.
c) Seller has provided all information required to enable Idaho Power to file an initial
transmission capacity request.
d) Results of the initial transmission capacity request are known and acceptable to the
Seller.
e) Seller acknowledges responsibility for all interconnection costs and any costs
associated with acquiring adequate firm transmission capacity to enable the project
to be classified as an Idaho Power firm network resource.
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f) If the Facility is located outside of the Idaho Power service territory, in addition to
the above requirements, the Seller must provide evidence that the Seller has
acquired firm transmission capacity from all required transmitting entities to deliver
the Facility's energy to an acceptable point of delivery on the Idaho Power
electrical system.
5.8 Within thirty (30) days of the date of a final non-appealable order as specified in Article XXI approving
this Agreement the Seller shall post liquid security ("Delay Security") in a form as described in
Appendix D equal to or exceeding the amount calculated in paragraph 5.8.1.
5.8.1 Delay Security The greater of forty five ($45) multiplied by the Maximum Capacity with the
Maximum Capacity being measured in kW or the sum of three month's estimated revenue.
Where the estimated three months of revenue is the estimated revenue associated with the first
three full months following the estimated Scheduled Operation Date, the estimated kWh of
energy production as specified in paragraph 6.2.1 for those three months multiplied by the All
Hours Energy Price specified in paragraph 7.3 for each of those three months.
5.8.1.1 In the event (a) Seller provides Idaho Power with certification that (1) a generation
interconnection agreement specifying a schedule that will enable this Facility to achieve
the Operation Date no later than the Scheduled Operation Date has been completed and
the Seller has paid all required interconnection costs or (2) a generation interconnection
agreement is substantially complete and all material costs of interconnection have been
identified and agreed upon and the Seller is in compliance with all terms and
conditions of the generation interconnection agreement, the Delay Security calculated
in accordance with paragraph 5.8.1 will be reduced by ten percent (10%).
5.8.1.2 If the Seller has received a reduction in the calculated Delay Security as specified in
paragraph 5.8.1.1 and subsequently (1) at Seller's request, the generation
interconnection agreement specified in paragraph 5.8.1.1 is revised and as a result the
Facility will not achieve its Operation Date by the Scheduled Operation Date or (2) if
the Seller does not maintain compliance with the generation interconnection agreement,
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the full amount of the Delay Security as calculated in paragraph 5.8.1 will be subject to
reinstatement and will be due and owing within 5 business days from the date Idaho
Power requests reinstatement. Failure to timely reinstate the Delay Security will be a
Material Breach of this Agreement.
5.8.2 Idaho Power shall release any remaining security posted hereunder after all calculated Delay Damages
and/or Delay Liquidated Damages are paid in full to Idaho Power and the earlier of (1) 30 days after the
Operation Date has been achieved or (2) 60 days after the Agreement has been terminated.
ARTICLE VI: PURCHASE AND SALE OF NET ENERGY
6.1 Delivery and Acceptance of Net Energy -Except when either Party's performance is excused as
provided herein, Idaho Power will purchase and Seller will sell all of the Net Energy to Idaho Power at
the Point of Delivery. All Inadvertent Energy produced by the Facility will also be delivered by the
Seller to Idaho Power at the Point of Delivery. At no time will the total amount of Net Energy and/or
Inadvertent Energy produced by the Facility and delivered by the Seller to the Point of Delivery exceed
the Maximum Capacity Amount.
6.2 Net Energy Amounts -Seller intends to produce and deliver Net Energy in the following monthly
amounts:
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6.2.1 Initial Year Monthly Net Energy Amounts:
Season I
Season 2
Season 3
March
April
May
July
August
November
December
June
September
October
January
February
648,000
648,000
648,000
648,000
648,000
648,000
648,000
648,000
648,000
648,000
648,000
648,000
6.2.2 Ongoing Monthly Net Energy Amounts -Seller shall initially provide Idaho Power with one
year of monthly generation estimates (Initial Year Monthly Net Energy Amounts) and
beginning at the end of month nine and every three months thereafter provide Idaho Power with
an additional three months of forward generation estimates beyond those generation estimates
previously provided. This information will be provided to Idaho Power by written notice in
accordance with paragraph 25.1, no later than 5:00PM of the 5th day following the end of the
previous month. If the Seller does not provide the Ongoing Monthly Net Energy Amounts in a
timely manner, Idaho Power will use the most recent 3 months of the Initial Year Monthly Net
Energy Amounts specified in paragraph 6.2. I for the next 3 months of monthly Net Energy
amounts.
6.2.3 Seller's Adjustment of Net Energy Amount
6.2.3.1 No later than the Operation Date, by written notice given to Idaho Power in accordance
with paragraph 25.1, the Seller may revise all of the previously provided Initial Year
Monthly Net Energy Amounts.
6.2.3.2 Beginning with the end of the 9th month after the Operation Date and at the end of
every third month thereafter: (I) the Seller may not revise the immediate next three
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months of previously provided Net Energy Amounts, (2) but by written notice given to
Idaho Power in accordance with paragraph 25.1, no later than 5:00PM of the 51h day
following the end of the previous month, the Seller may revise all other previously
provided Net Energy Amounts. Failure to provide timely written notice of changed
amounts will be deemed to be an election of no change.
6.2.4 Idaho Power Adjustment of Net Energy Amount-If Idaho Power is excused from accepting the
Seller's Net Energy as specified in paragraph 12.2.1 or if the Seller declares a Suspension of
Energy Deliveries as specified in paragraph 12.3.1 and the Seller's declared Suspension of
Energy Deliveries is accepted by Idaho Power, the Net Energy Amount as specified in
paragraph 6.2 for the specific month in which the reduction or suspension under paragraph
12.2.1 or 12.3.1 occurs will be reduced in accordance with the following:
Where:
NEA Current Month's Net Energy Amount (Paragraph 6.2)
SGU a.) Ifldaho Power is excused from accepting the Seller's Net
TGU
RSH
TH
Energy as specified in paragraph 12.2.1 this value will be
equal to the percentage of curtailment as specified by
Idaho Power multiplied by the TGU as defined below.
b.) If the Seller declares a Suspension of Energy Deliveries as
specified in paragraph 12.3.1 this value will be the sum of
the individual generation units size ratings as specified in
Appendix B that are impacted by the circumstances
causing the Seller to declare a Suspension of Energy
Deliveries.
Sum of all of the individual generator ratings of the generation
units at this Facility as specified in Appendix B of this
agreement.
Actual hours the Facility's Net Energy deliveries were either
reduced or suspended under paragraph 12.2.1 or 12.3.1
Actual total hours in the current month
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Resulting formula being:
Adjusted
Net Energy "" NEA
Amount
_ ( ( X NEA ) X ( TGU TH
This Adjusted Net Energy Amount will be used in applicable Surplus Energy calculations for only the
specific month in which Idaho Power was excused from accepting the Seller's Net Energy or the Seller
declared a Suspension of Energy.
6.3 Unless excused by an event of Force Majeure, Seller's failure to deliver Net Energy in any Contract
Year in an amount equal to at least ten percent (10%) of the sum of the Initial Year Net Energy
Amounts as specified in paragraph 6.2 shall constitute an event of default.
ARTICLE VII: PURCHASE PRICE AND METHOD OF PAYMENT
7.1 Base Energy Heavy Load Purchase Price -For all Base Energy received during Heavy Load Hours,
Idaho Power will pay the non-levelized energy price in accordance with Commission Order 30744,
30738 and adjusted in accordance with Commission Order 30415 for Heavy Load Hour Energy
deliveries with seasonalization factors applied:
Season 1 -(73.50 %) Season 2-(120.00 %) Season 3-(100.00 %)
Year Mills/kWh Mills/kWh Mills/kWh
2010 57.98 94.67 78.89
2011 59.54 97.21 81.01
2012 61.22 99.95 83.29
2013 62.62 102.23 85.19
2014 64.05 104.57 87.14
2015 65.52 106.97 89.14
2016 67.10 109.55 91.29
2017 68.63 112.05 93.38
2018 70.29 114.77 95.64
2019 71.91 117.40 97.83
2020 73.56 120.10 100.08
2021 75.26 122.87 102.39
2022 76.99 125.70 104.75
2023 78.78 128.61 107.18
2024 80.60 131.59 109.66
2025 82.47 134.65 112.21
2026 84.75 138.37 115.31
2027 87.10 142.21 118.51
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2028 89.53 146.17 121.81
2029 92.03 150.25 125.21
2030 94.60 154.45 128.71
2031 96.69 157.85 131.55
7.2 Base Energy Light Load Purchase Price-For all Base Energy received during Light Load Hours, Idaho
Power will pay the non-levelized energy price in accordance with Commission Order 30744, 30738 and
adjusted in accordance with Commission Order 30415 for Light Load Hour Energy deliveries with
seasonalization factors applied :
Season 1 -(73.50 %) Season 2-(120.00 %) Season 3-(100.00 %)
Year Mills/kWh Mills/kWh Mills/kWh
2010 52.63 85.93 71.61
2011 54.19 88.47 73.73
2012 55.87 91.21 76.01
2013 57.27 93.49 77.91
2014 58.70 95.83 79.86
2015 60.17 98.23 81.86
2016 61.75 100.81 84.01
2017 63.28 103.32 86.10
2018 64.94 106.03 88.36
2019 66.56 108.66 90.55
2020 68.21 111.36 92.80
2021 69.90 114.13 95.11
2022 71.64 116.97 97.47
2023 73.42 119.88 99.90
2024 75.25 122.86 102.38
2025 77.12 125.91 104.93
2026 79.40 129.64 108.03
2027 81.75 133.48 111.23
2028 84.18 137.43 114.53
2029 86.68 141.51 117.93
2030 89.25 145.71 121.43
2031 91.33 149.12 124.27
7.3 All Hours Energy Price -The price to be used in the calculation of the Surplus Energy Price and Delay
Damage Price shall be the non-levelized energy price in accordance with Commission Order 30744 and
30738 with seasonalization factors applied:
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Season 1 -(73.50 %) Season 2-(120.00 %) Season 3-(100.00 %)
Year Mills/kWh Mills/kWh Mills/kWh
2010 55.60 90.78 75.65
2011 57.16 93.32 77.77
2012 58.84 96.06 80.05
2013 60.24 98.34 81.95
2014 61.67 100.68 83.90
2015 63.14 103.08 85.90
2016 64.72 105.66 88.05
2017 66.25 108.17 90.14 I
2018 67.91 110.88 92.40
2019 69.53 113.51 94.59
2020 71.18 116.21 96.84
2021 72.87 118.98 99.15
2022 74.61 121.82 101.51
2023 76.39 124.72 103.94
2024 78.22 127.71 106.42
2025 80.09 130.76 108.97
2026 82.37 134.49 112.07
2027 84.72 138.32 115.27
2028 87.15 142.28 118.57
2029 89.64 146.36 121.97
2030 92.22 150.56 125.47
2031 94.30 153.97 128.31
7.4 Surplus Energy Price-For all Surplus Energy, Idaho Power shall pay to the Seller the current month's
Market Energy Reference Price or the All Hours Energy Price specified in paragraph 7.3, whichever is
lower.
7.5 Inadvertent Energy-
7.5.1 Inadvertent Energy is electric energy produced by the Facility, expressed in kWh, which the
Seller delivers to Idaho Power at the Point of Delivery that exceeds 10,000 kW multiplied
by the hours in the specific month in which the energy was delivered. (For example
January contains 744 hours. 744 hours times 10,000 kW = 7,440,000 kWh. Energy
delivered in January in excess of7,440, 000 kWh in this example would be Inadvertent
Energy.)
7.5.2 Although Seller intends to design and operate the Facility to generate no more than
10 average MW and therefore does not intend to generate Inadvertent Energy, Idaho Power
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will accept Inadvertent Energy that does not exceed the Maximum Capacity Amount but
will not purchase or pay for Inadvertent Energy.
7.6 Payment Due Date -Undisputed Energy payments, less any payments due to Idaho Power will be
disbursed to the Seller within 30 days of the date which Idaho Power receives and accepts the
documentation of the monthly Net Energy actually delivered to Idaho Power as specified in
Appendix A.
7.7 Continuing Jurisdiction of the Commission .This Agreement is a special contract and, as such, the rates,
terms and conditions contained in this Agreement will be construed in accordance with Idaho Power
Company v. Idaho Public Utilities Commission and Afton Energy, Inc., 107 Idaho 781, 693 P.2d 427
(1984), Idaho Power Company v. Idaho Public Utilities Commission, 107 Idaho 1122, 695 P.2d 1 261
(1985), Afton Energy, Inc, v. Idaho Power Company, 111 Idaho 925, 729 P.2d 400 (1986), Section 210
of the Public Utilities Regulatory Policies Act of 1978 and 18 CFR §292.303-308
ARTICLE VIII: ENVIRONMENTAL ATTRIBUTES
8.1 Seller retains ownership under this Agreement of Green Tags and Renewable Energy Certificate
(RECs), or the equivalent environmental attributes, directly associated with the production of energy
from the Seller's Facility sold to Idaho Power.
ARTICLE IX: FACTLITY AND INTERCONNECTION
9.1 Design of Facility-Seller will design, construct, install, own, operate and maintain the Facility and any
Seller-owned Interconnection Facilities so as to allow safe and reliable generation and delivery of Net
Energy and Inadvertent Energy to the Idaho Power Point of Delivery for the full term of the Agreement.
ARTICLE X: METERING AND TELEMETRY
10.1 Metering-Idaho Power shall, for the account of Seller, provide, install, and maintain Metering
Equipment to be located at a mutually agreed upon location to record and measure power flows to Idaho
Power in accordance with this Agreement and Schedule 72. The Metering Equipment will be at the
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location and the type required to measure, record and report the Facility's Net Energy, Station Use,
Inadvertent Energy and maximum energy deliveries (kW) at the Point of Delivery in a manner to
provide Idaho Power adequate energy measurement data to administer this Agreement and to integrate
this Facility's energy production into the Idaho Power electrical system.
10.2 Telemetry-Idaho Power will install, operate and maintain at Seller's expense communications and
telemetry equipment which will be capable of providing Idaho Power with continuous instantaneous
telemetry of Seller's Net Energy and Inadvertent Energy produced and delivered to the Idaho Power
Point of Delivery to Idaho Power's Designated Dispatch Facility.
ARTICLE XI-RECORDS
11.1 Maintenance of Records -Seller shall maintain at the Facility or such other location mutually acceptable
to the Parties adequate total generation, Net Energy, Station Use, Inadvertent Energy and maximum
generation (kW) records in a form and content acceptable to Idaho Power.
11.2 Inspection-Either Party, after reasonable notice to the other Party, shall have the right, during normal
business hours, to inspect and audit any or all generation, Net Energy, Station Use, Inadvertent Energy
and maximum generation (kW) records pertaining to the Seller's Facility.
ARTICLE XII: OPERATIONS
12 .1 Communications -Idaho Power and the Seller shall maintain appropriate operating communications
through Idaho Power's Designated Dispatch Facility in accordance with Appendix A of this Agreement.
12 .2 Energy Acceptance -
12.2.1 Idaho Power shall be excused from accepting and paying for Net Energy or accepting
Inadvertent Energy which would have otherwise been produced by the Facility and delivered by
the Seller to the Point of Delivery, if it is prevented from doing so by an event of Force
Majeure, or temporary disconnection of the Facility in accordance with Schedule 72. If, for
reasons other than an event of Force Majeure, a temporary disconnection under Schedule 72
exceeds twenty (20) days, beginning with the twenty-first day of such interruption, curtailment
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or reduction, Seller will be deemed to be delivering Net Energy at a rate equivalent to the pro
rata daily average of the amounts specified for the applicable month in paragraph 6.2. Idaho
Power will notifY Seller when the interruption, curtailment or reduction is terminated.
12.2.2 If, in the reasonable opinion ofldaho Power, Seller's operation of the Facility or Interconnection
Facilities is unsafe or may otherwise adversely affect Idaho Power's equipment, personnel or
service to its customers, Idaho Power may temporarily disconnect the Facility from Idaho
Power's transmission/distribution system as specified within Schedule 72 or take such other
reasonable steps as Idaho Power deems appropriate.
12.2.3 Under no circumstances will the Seller deliver Net Energy and/or Inadvertent Energy from the
Facility to the Point of Delivery in an amount that exceeds the Maximum Capacity Amount.
Seller's failure to limit deliveries to the Maximum Capacity Amount will be a Material Breach
of this Agreement.
12.2.4 If Idaho Power is unable to accept the energy from this Facility and is not excused from
accepting the Facility's energy, Idaho Power's damages shall be limited to only the value of the
estimated energy that Idaho Power was unable to accept. Idaho Power will have no
responsibility to pay for any other costs, lost revenue or consequential damages the Facility may
mcur.
12.3 Seller Declared Suspension of Energy Deliveries
12.3.1 If the Seller's Facility experiences a forced outage due to equipment failure which is not caused
by an event of Force Majeure or by neglect, disrepair or lack of adequate preventative
maintenance of the Seller's Facility, Seller may, after giving notice as provided in paragraph
12.3.2 below, temporarily suspend all deliveries of Net Energy to Idaho Power from the Facility
or from individual generation unit(s) within the Facility impacted by the forced outage for a
period of not less than 48 hours to correct the forced outage condition ("Declared Suspension of
Energy Deliveries"). The Seller's Declared Suspension of Energy Deliveries will begin at the
start of the next full hour following the Seller's telephone notification as specified in paragraph
12.3.2 and will continue for the time as specified (not Jess than 48 hours) in the written
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notification provided by the Seller. In the month(s) in which the Declared Suspension of Energy
occurred, the Net Energy Amount will be adjusted as specified in paragraph 6.2.4.
12.3.2 If the Seller desires to initiate a Declared Suspension of Energy Deliveries as provided in
paragraph 12.3.1, the Seller will notify the Designated Dispatch Facility by telephone. The
beginning hour of the Declared Suspension of Energy Deliveries will be at the earliest the next
full hour after making telephone contact with Idaho Power. The Seller will, within 24 hours
after the telephone contact, provide Idaho Power a written notice in accordance with XXIV that
will contain the beginning hour and duration of the Declared Suspension of Energy Deliveries
and a description of the conditions that caused the Seller to initiate a Declared Suspension of
Energy Deliveries. Idaho Power will review the documentation provided by the Seller to
determine Idaho Power's acceptance of the described forced outage as qualifying for a Declared
Suspension of Energy Deliveries as specified in paragraph 12.3.1. Idaho Power's acceptance of
the Seller's forced outage as an acceptable forced outage will be based upon the clear
documentation provided by the Seller that the forced outage is not due do an event of Force
Majeure or by neglect, disrepair or lack of adequate preventative maintenance of the Seller's
Facility.
12.4 Scheduled Maintenance-On or before January 31 of each calendar year, Seller shall submit a written
proposed maintenance schedule of significant Facility maintenance for that calendar year and Idaho
Power and Seller shall mutually agree as to the acceptability of the proposed schedule. The Parties
determination as to the acceptability of the Seller's timetable for scheduled maintenance will take into
consideration Prudent Electrical Practices, Idaho Power system requirements and the Seller's preferred
schedule. Neither Party shall umeasonably withhold acceptance of the proposed maintenance schedule.
12.5 Maintenance Coordination -The Seller and Idaho Power shall, to the extent practical, coordinate their
respective line and Facility maintenance schedules such that they occur simultaneously.
12.6 Contact Prior to Curtailment-Idaho Power will make a reasonable attempt to contact the Seller prior to
exercising its rights to interrupt interconnection or curtail deliveries from the Seller's Facility. Seller
understands that in the case of emergency circumstances, real time operations of the electrical system,
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and/or unplanned events Idaho Power may not be able to provide notice to the Seller prior to
interruption, curtailment, or reduction of electrical energy deliveries to Idaho Power.
ARTICLE XIII: INDEMNIFICATION AND INSURANCE
13.1 Indemnification -Each Party shall agree to hold harmless and to indemnify the other Party, its officers,
agents, affiliates, subsidiaries, parent company and employees against all Joss, damage, expense and
liability to third persons for injury to or death of person or injury to property, proximately caused by the
indemnifying Party's (a) construction, ownership, operation or maintenance of, or by failure of, any of
such Party's works or facilities used in connection with this Agreement or (b) negligent or intentional
acts, errors or omissions. The indemnifying Party shall, on the other Party's request, defend any suit
asserting a claim covered by this indemnity. The indemnifying Party shall pay all documented costs,
including reasonable attorney fees that may be incurred by the other Party in enforcing this indemnity.
13.2 Insurance-During the term of this Agreement, Seller shall secure and continuously carry the following
insurance coverage:
13.2.1 Comprehensive General Liability Insurance for both bodily injury and property damage with
limits equal to $1,000,000, each occurrence, combined single limit. The deductible for such
insurance shall be consistent with cun·ent Insurance Industry Utility practices for similar
property.
13.2.2 The above insurance coverage shall be placed with an insurance company with an A.M. Best
Company rating of A-or better and shall include:
(a) An endorsement naming Idaho Power as an additional insured and loss payee as
applicable; and
(b) A provision stating that such policy shall not be canceled or the limits of liability
reduced without sixty (60) days' prior written notice to Idaho Power.
l3 .3 Seller to Provide Certificate of Insurance -As required in paragraph 4.1.5 herein and annually
thereafter, Seller shall furnish Idaho Power a certificate of insurance, together with the endorsements
required therein, evidencing the coverage as set forth above.
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13.4 Seller to Notifv Idaho Power of Loss of Coverage -If the insurance coverage required by paragraph
13.2 shall lapse for any reason, Seller will immediately notify Idaho Power in writing. The notice will
advise Idaho Power of the specific reason for the lapse and the steps Seller is taking to reinstate the
coverage. Failure to provide this notice and to expeditiously reinstate or replace the coverage will
constitute a Material Breach of this Agreement.
ARTICLE XIV: FORCE MAJEURE
14.1 As used in this Agreement, "Force Majeure" or "an event of Force Majeure" means any cause beyond
the control of the Seller or of Idaho Power which, despite the exercise of due diligence, such Party is
unable to prevent or overcome. Force Majeure includes, but is not limited to, acts of God, fire, flood,
storms, wars, hostilities, civil strife, strikes and other labor disturbances, earthquakes, fires, lightning,
epidemics, sabotage, or changes in law or regulation occurring after the effective date, which, by the
exercise of reasonable foresight such party could not reasonably have been expected to avoid and by the
exercise of due diligence, it shall be unable to overcome. If either Party is rendered wholly or in part
unable to perform its obligations under this Agreement because of an event of Force Majeure, both
Parties shall be excused from whatever performance is affected by the event of Force Majeure, provided
that:
(1) The non-performing Party shall, as soon as is reasonably possible after the occurrence
of the Force Majeure, give the other Party written notice describing the particulars of
the occurrence.
(2) The suspension of performance shall be of no greater scope and of no longer duration
than is required by the event of Force Majeure.
(3) No obligations of either Party which arose before the occurrence causing the suspension
of performance and which could and should have been fully performed before such
occurrence shall be excused as a result of such occurrence.
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ARTICLE XV: LIABILITY; DEDICATION
15.1 Limitation of Liability. Nothing in this Agreement shall be construed to create any duty to, any
standard of care with reference to, or any liability to any person not a Party to this Agreement. Neither
party shall be liable to the other for any indirect, special, consequential, nor punitive damages, except as
expressly authorized by this Agreement. Consequential damages will include, but not be limited to, the
value of renewable energy certificate and, ifthe Facility is fueled by gas produced by an anaerobic
digester system, any diminution or loss of anaerobic activity due to the inability of Idaho Power to
accept energy from the Facility.
15.2 Dedication. No undertaking by one Party to the other under any provision of this Agreement shall
constitute the dedication of that Party's system or any portion thereof to the Party or the public or affect
the status ofldaho Power as an independent public utility corporation or Seller as an independent
individual or entity.
ARTICLE XVI: SEVERAL OBLIGATIONS
16.1 Except where specifically stated in this Agreement to be otherwise, the duties, obligations and liabilities
of the Parties are intended to be several and not joint or collective. Nothing contained in this Agreement
shall ever be construed to create an association, tlust, partnership or joint venture or impose a trust or
partnership duty, obligation or liability on or with regard to either Party. Each Party shall be
individually and severally liable for its own obligations under this Agreement.
ARTICLEXVII: WAIVER
17 .I Any waiver at any time by either Party of its rights with respect to a default under this Agreement or
with respect to any other matters arising in connection with this Agreement shall not be deemed a
waiver with respect to any subsequent default or other matter.
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ARTICLE XVIII: CHOICE OF LAWS AND VENUE
18.1 This Agreement shall be construed and interpreted in accordance with the laws of the State ofldaho
without reference to its choice of law provisions.
18.2 Venue for any litigation arising out of or related to this Agreement will lie in the District Court of the
Fourth Judicial District of Idaho in and for the County of Ada.
ARTICLE XIX: DISPUTES AND DEFAULT
19.1 Disputes -All disputes related to or arising under this Agreement, including, but not limited to, the
interpretation of the terms and conditions of this Agreement, will be submitted to the Commission for
resolution.
19.2 Notice ofDefault
19.2.1 Defaults. If either Party fails to perform any ofthe terms or conditions ofthis Agreement
(an "event of default"), the nondefaulting Party shall cause notice in writing to be given to
the defaulting Party, specii)ting the manner in which such default occurred. If the defaulting
Party shall fail to cure such default within the sixty (60) days after service of such notice, or
if the defaulting Party reasonably demonstrates to the other Party that the default can be
cured within a commercially reasonable time but not within such sixty (60) day period and
then fails to diligently pur~ue such cure, then, the nondefaulting Party may, at its option,
tenninate this Agreement and/or pursue its legal or equitable remedies.
19.2.2 Material Breaches -The notice and cure provisions in paragraph 19 .2.1 do not apply to
defaults identified in this Agreement as Material Breaches. Material Breaches must be cured
as expeditiously as possible following occurrence of the breach.
19.3 Security for Performance -Prior to the Operation Date and thereafter for the full term of this
Agreement, Seller will provide Idaho Power with the following:
19.3.1 Insurance-Evidence of compliance with the provisions of paragraph 13.2. If Seller fails to
comply, such failure will be a Material Breach and may only be cured by Seller supplying
evidence that the required insurance coverage has been replaced or reinstated;
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19.3.2 Engineer's Certifications-Every three (3) years after the Operation Date, Seller will supply
Idaho Power with a Certification of Ongoing Operations and Maintenance (O&M) from a
Registered Professional Engineer licensed in the State of Idaho, which Certification of
Ongoing 0 & M shall be in the form specified in Appendix C. Seller's failure to supply the
required certificate will be an event of default. Such a default may only be cured by Seller
providing the required certificate; and
19.3 .3 Licenses and Permits -During the full term of this Agreement, Seller shall maintain
compliance with all permits and licenses described in paragraph 4.1.1 of this Agreement. In
addition, Seller will supply Idaho Power with copies of any new or additional permits or
licenses. At least every fifth Contract Year, Seller will update the documentation described
in Paragraph 4.1.1. If at any time Seller fails to maintain compliance with the permits and
licenses described in paragraph 4.1.1 or to provide the documentation required by this
paragraph, such failure will be an event of default and may only be cured by Seller
submitting to Idaho Power evidence of compliance from the permitting agency.
ARTICLE XX: GOVERNMENTAL AUTHORIZATION
20.1 This Agreement is subject to the jurisdiction of those governmental agencies having control over either
Party of this Agreement.
ARTICLE XXI: COMMISSION ORDER
21.1 This Agreement shall become finally effective upon the Commission's approval of all terms and
provisions hereof without change or condition and declaration that all payments to be made to Seller
hereunder shall be allowed as prudently incurred expenses for ratemaking purposes.
ARTICLE XXII: SUCCESSORS AND ASSIGNS
22.1 This Agreement and all of the terms and provisions hereof shall be binding upon and inure to the benefit
of the respective successors and assigns of the Parties hereto, except that no assignment hereof by either
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Party shall become effective without the written consent of both Parties being first obtained. Such
consent shall not be unreasonably withheld. Notwithstanding the foregoing, any party which Idaho
Power may consolidate, or into which it may merge, or to which it may convey or transfer substantially
all of its electric utility assets, shall automatically, without further act, and without need of consent or
approval by the Seller, succeed to all of Idaho Power's rights, obligations and interests under this
Agreement. This article shall not prevent a financing entity with recorded or secured rights from
exercising all rights and remedies available to it under law or contract. Idaho Power shall have the right
to be notified by the financing entity that it is exercising such rights or remedies.
ARTICLE XXIII: MODIFICATION
23 .I No modification to this Agreement shall be valid unless it is in writing and signed by both Parties and
subsequently approved by the Commission.
ARTICLE XXIV: TAXES
24.1 Each Party shall pay before delinquency all taxes and other governmental charges which, if failed to be
paid when due, could result in a lien upon the Facility or the Interconnection Facilities.
ARTICLE XXV: NOTICES
25.1 All written notices under this Agreement shall be directed as follows and shall be considered
delivered when faxed, e-mailed and confirmed with deposit in the U.S. Mail, first-class,
postage prepaid, as follows:
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To Seller:
To Idaho Power:
Original document to:
Laura Knothe, PE
New Energy Three, LLC
8720 Vic Lane
Middleton ID 83644
Telephone:
Cell:
FAX:
[phone]
[phone]
E-mail: [e-mail]
Original document to:
Vice President, Power Supply
Idaho Power Company
PO Box 70
Boise, Idaho 83707
Email: [e-mail]
Copy of document to:
Cogeneration and Small Power Production
Idaho Power Company
POBox 70
Boise, Idaho 83707
E-mail: [e-mail]
Either Party may change the contact person and/or address information listed above, by providing written notice
from an authorized person representing the Party.
ARTICLE XXVl: ADDITIONAL TERMS AND CONDITIONS
26.1 This Agreement includes the following appendices, which are attached hereto and included by
reference:
Appendix A
AppendixB
AppendixC
AppendixD
Generation Scheduling and Reporting
Facility and Point of Delivery
Engineer's Certifications
Forms of Liquid Security
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ARTICLE XXVII: SEVERABILITY
27. l The invalidity or unenforceability of any term or provision of this Agreement shall not affect the
validity or enforceability of any other tenns or provisions and this Agreement shall be construed in all
other respects as iftbe invalid or unenforceable term or provision were omitted.
ARTICLE XXVIII: COUNTERPARTS
28. 1 This Agreement may be executed in two or more counterparts, each of which shall be deemed an
original but all of which together shall constitute one and the same instrument.
ARTICLE XXIX: ENTIRE AGREEMENT
29.1 This Agreement constitutes the entire Agreement of the Parties concerning the subject matter hereof and
supersedes all prior or contemporaneous oral or written agreements between the Parties concerning the
subject matter hereof.
IN WITNESS WHEREOF, The Parties hereto have caused this Agreement to be executed in
their respective names on the dates set forth below:
Idaho Power Company New Energy Three, LLC
By ~5JLL9.AGro~JW By ~.
Laura Knothc, PE
Sr. Vice President, Power Supply
Dated 5·2-Lf-lO Dated sJ ;;u /1 D
"Idaho Power" "Seller"
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APPENDIX A
A -1 MONTHLY POWER PRODUCTION AND SWITCHING REPORT
At the end of each month the following required documentation will be submitted to:
Idaho Power Company
Attn: Cogeneration and Small Power Production
POBox 70
Boise, Idaho 83707
The meter readings required on this report will be the readings on the Idaho Power Meter Equipment measuring
the Facility's total energy production and Station Usage delivered to Idaho Power and the maximum generated
energy (kW) as recorded on the Metering Equipment and/or any other required energy measurements to
adequately administer this Agreement. This document shall be the document to enable Idaho Power to begin the
energy payment calculation and payment process. The meter readings on this report shall not be used to
calculate the actual payment, but instead will be a check of the automated meter reading information that will be
gathered as described in item A-2 below:
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Idaho Power Company
Cogeneration and Small Power Production
MONTHLY POWER PRODUCTION AND SWITCHING REPORT
Project Name
Address
City
Meter Number:
End of Month kWh Meter Reading:
Beginning of Month kWh Meter:
Difference:
Times Meter Constant:
kWh for the Month:
Metered Demand:
Breaker Opening Record
* Breaker O~ening Reason Codes
1 Lack of Adequate Prime Mover
2 Forced Outage of Facility
3 Disturbance of IPCo System
4 Scheduled Maintenance
5 Testing of Protection Systems
6 Cause Unknown
7 Other (Explain)
State
*
Facility
Out~ut
Month
Zip
Station
Usage
Year
Project Number:
Phone Number:
Station
Usage
Metered
Maximum Generation
kW
Net Generation
Breaker Closing Record
I hereby certify that the above meter readings are
true and correct as of Midnight on the last day of the
above month and that the switching record is accurate
and complete as required by the Firm Energy Sales
Agreement to which I am a Party.
Signature Date
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A-2 AUTOMATED METER READING COLLECTION PROCESS
Monthly, Idaho Power will use the provided Metering and Telemetry equipment and processes to collect the
meter reading information from the Idaho Power provided Metering Equipment that measures the Net Energy
and energy delivered to supply Station Use for the Facility recorded at 12:00 AM (Midnight) of the last day of
the month ..
The meter information collected will include but not be limited to energy production, Station Use, the maximum
generated power (kW) and any other required energy measurements to adequately administer this Agreement.
A-3 ROUTINE REPORTING
Once the Facility has achieved its Operation Date and has operated in a reliable and consistent manner
for a reasonable period of time, the Parties may mutually agree to modify this Routine Reporting
requirement.
Idaho Power Contact Information
Daily Energy Production Reporting
Call daily by 10 a.m., 1-800-356-4328 or 1-800-635-1093 and leave the following information:
• Project Identification -Project Name and Project Number
• Current Meter Reading
• Estimated Generation for the cuiTent day
• Estimated Generation for the next day
Planned and Unplanned Project outages
Call 1-800-345-1319 and leave the following information:
• Project Identification-Project Name and Project Number
• Approximate time outage occurred
• Estimated day and time of project coming back online
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Seller's Contact Information
24-Hour Project Operational Contact
Name:
Telephone Number:
Cell Phone:
Jay Kesting
[phone]
[phone]
Project On-site Contact information
Name:
Telephone Number:
Kurt Standley
[phone]
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APPENDIXB
FACILITY AND POINT OF DELIVERY
Project Name: Double B Dairy
Project Number: 31616120
B-1 DESCRIPTION OF FACILITY
(Must include the Nameplate Capacity rating and VAR capability (both leading and lagging) of all generation
units to be included in the Facility.)
The facility consists of an anaerobic digester, gen sets and waste handling equipment. The total
nameplate capacity of the three generators is 2000 kW.
Var Capability (Both leading and lagging) Leading is .98 Lagging is .8.
B-2 LOCATION OF FACILITY
Near: Murtaugh, ID
Sections: 33 Township: ~ Range: 21E Milner ID Quadrangle County: Cassia ID.
Description oflnterconnection Location: Near 1250 West 1100 South Murtaugh, ID
Nearest Idaho Power Substation: Buckhorn Substation
B-3 SCHEDULED FIRST ENERGY AND OPERATION DATE
Seller has selected October 1, 2011 as the Scheduled First Energy Date.
Seller has selected December 1. 2012 as the Scheduled Operation Date.
In making these selections, Seller recognizes that adequate testing of the Facility and completion of all
requirements in paragraph 5.2 of this Agreement must be completed prior to the project being granted
an Operation Date.
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B-4 MAXIMUM CAPACITY AMOUNT:
This value will be _2_MW which is consistent with the value provided by the Seller to Idaho Power in
accordance with Schedule 72. This value is the maximum energy (MW) that potentially could be
delivered by the Seller's Facility to the Idaho Power electrical system at any moment in time.
B-5 POINT OF DELIVERY
"Point of Delivery" means, unless otherwise agreed by both Parties, the point of where the Sellers
Facility's energy is delivered to the Idaho Power electrical system. Schedule 72 will determine the
specific Point of Delivery for this Facility. The Point of Delivery identified by Schedule 72 will become
an integral part of this Agreement.
B-6 LOSSES
If the Idaho Power Metering equipment is capable of measuring the exact energy deliveries by the Seller
to the Idaho Power electrical system at the Point of Delivery, no Losses will be calculated for this
Facility. If the Idaho Power Metering is unable to measure the exact energy deliveries by the Seller to
the Idaho Power electrical system at the Point of Delivery, a Losses calculation will be established to
measure the energy losses (kWh) between the Seller's Facility and the Idaho Power Point of Delivery.
This loss calculation will be initially set at 2% of the kWh energy production recorded on the Facility
generation metering equipment. At such time as Seller provides Idaho Power with the electrical
equipment specifications (transformer loss specifications, conductor sizes, etc) of all of the electrical
equipment between the Facility and the Idaho Power electrical system, Idaho Power will configure a
revised loss calculation formula to be agreed to by both parties and used to calculate the kWh Losses for
the remaining term of the Agreement. If at any time during the term of this Agreement, Idaho Power
determines that the loss calculation does not correctly reflect the actual kWh losses attributed to the
electrical equipment between the Facility and the Idaho Power electrical system, Idaho Power may
adjust the calculation and retroactively adjust the previous months kWh loss calculations.
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511912010
B-7 METERING AND TELEMETRY
Schedule 72 will determine the specific metering and telemetry requirements for this Facility. At the
minimum the Metering Equipment and Telemetry equipment must be able to provide and record hourly
energy deliveries to the Point of Delivery and any other energy measurements required to administer
this Agreement. These specifications will include but not be limited to equipment specifications,
equipment location, Idaho Power provided equipment, Seller provided equipment, and all costs
associated with the equipment, design and installation of the Idaho Power provided equipment. Seller
will arrange for and make available at Seller's cost communication circuit(s) compatible with Idaho
Power's communications equipment and dedicated to Idaho Power's use te1minating at the Idaho Power
facilities capable of providing Idaho Power with continuous instantaneous information on the Facilities
energy production. Idaho Power provided equipment will be owned and maintained by Idaho Power,
with total cost of purchase, installation, operation, and maintenance, including administrative cost to be
reimbursed to Idaho Power by the Seller. Payment of these costs will be in accordance with Schedule
72 and the total metering cost will be included in the calculation of the Monthly Operation and
Maintenance Charges specified in Schedule 72.
B-8 NETWORK RESOURCE DESIGNATION
Idaho Power cannot accept or pay for generation from this Facility until a Network Resource
Designation ("NRD") application has been accepted by Idaho Power's delivery business unit. Federal
Energy Regulatory Commission ("FERC") Rules require Idaho Power to prepare and submit the NRD.
Because much of the infmmation Idaho Power needs to prepare the NRD is specific to the Seller's
Facility, Idaho Power's ability to file the NRD in a timely manner is contingent upon timely receipt of
the required information from the Seller. Prior to Idaho Power beginning the process to enable Idaho
Power to submit a request for NRD status for this Facility, the Seller shall have completed all
requirements as specified in Paragraph 5.7 of this Agreement. Seller's failure to provide complete
and accurate information in a timely manner can significantly impact Idaho Power's ability and
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cost to attain the NRD designation for the Seller's Facility and the Seller shall bear the costs of
any of these delays that are a result of any action or inaction by the Seller.
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APPENDIX C
ENGINEER'S CERTIFICATION
OF
OPERATIONS & MAINTENANCE POLICY
on behalf of himself and The undersigned ----------------_J -----
hereinafter collectively referred to as "Engineer," hereby states and certifies to the Seller as follows:
1. That Engineer is a Licensed Professional Engineer in good standing in the State ofldaho.
2. That Engineer has reviewed the Energy Sales Agreement, hereinafter "Agreement," between Idaho
Power as Buyer, and _______ as Seller, dated __________ _
3. That the cogeneration or small power production project which is the subject of the Agreement and this
Statement is identified as IPCo Facility No. _______ and is hereinafter referred to as the "Project."
4. That the Project, which is commonly known as the _________ Project, is located in
Section __ Township ____ Range ____ , Boise Meridian, _____ County, Idaho.
5. That Engineer recognizes that the Agreement provides for the Project to furnish electrical energy to
Idaho Power for a ____ year period.
6. That Engineer has substantial experience in the design, construction and operation of electric power
plants of the same type as this Project.
7. That Engineer has no economic relationship to the Design Engineer of this Project.
8. That Engineer has reviewed and/or supervised the review of the Policy for Operation and Maintenance
("O&M") for this Project and it is his professional opinion that, provided said Project has been designed and
built to appropriate standards, adherence to said O&M Policy will result in the Project's producing at or near the
design electrical output, efficiency and plant factor for a fifteen (15) year period.
9. That Engineer recognizes that Idaho Power, in accordance with paragraph 5.2 of the Agreement, is
relying on Engineer's representations and opinions contained in this Statement.
-37-
5/19/2010
10. That Engineer certifies that the above statements are complete, true and accurate to the best of his
knowledge and therefore sets his hand and seal below.
By ______________________ __
(P .E. Stamp)
Date --------------------------
-38-
5/19/2010
APPENDIX C
ENGINEER'S CERTIFICATION
OF
ONGOING OPERATIONS AND MAINTENANCE
The undersigned on behalf of himself and
___________ hereinafter collectively referred to as "Engineer," hereby states and certifies to
the Seller as follows:
1. That Engineer is a Licensed Professional Engineer in good standing in the State of Idaho.
2. That Engineer has reviewed the Energy Sales Agreement, hereinafter "Agreement," between Idaho
Power as Buyer, and ________ as Seller, dated ------------'
3. That the cogeneration or small power production project which is the subject of the Agreement and this
Statement is identified as IPCo Facility No. ______ and hereinafter referred to as the "Project".
4. That the Project, which is commonly known as the _________ P.roject, is located in
Section __ Township ____ Range ____ , Boise Meridian, ____ County, Idaho.
5. That Engineer recognizes that the Agreement provides for the Project to furnish electrical energy to
Idaho Power for a fifteen (15) year period.
6. That Engineer has substantial experience in the design, construction and operation of electric power
plants ofthe same type as this Project.
7. That Engineer has no economic relationship to the Design Engineer of this Project.
-39-
5119/2010
8. That Engineer has made a physical inspection of said Project, its operations and maintenance records
since the last previous certified inspection. It is Engineer's professional opinion, based on the Project's
appearance, that its ongoing O&M has been substantially in accordance with said O&M Policy; that it is in
reasonably good operating condition; and that if adherence to said O&M Policy continues, the Project will
continue producing at or near its design electrical output, efficiency and plant factor for the remaining __ _
years of the Agreement.
9. That Engineer recognizes that Idaho Power, in accordance with paragraph 5.2 of the Agreement, is
relying on Engineer's representations and opinions contained in this Statement.
10. That Engineer certifies that the above statements are complete, true and accurate to the best of his
knowledge and therefore sets his hand and seal below.
By ____________________ __
(P .E. Stamp)
Date ---------------------------
-40-
5/19/2010
The undersigned
APPENDIXC
ENGINEER'S CERTIFICATION
OF
DESIGN & CONSTRUCTION ADEQUACY
on behalf of himself and
___________ hereinafter collectively referred to as "Engineer", hereby states and certifies to
Idaho Power as follows:
1.
2.
That Engineer is a Licensed Professional Engineer in good standing in the State ofldaho.
That Engineer has reviewed the Firm Energy Sales Agreement, hereinafter "Agreement",
between Idaho Power as Buyer, and ____________ __,as Seller, dated
3. That the cogeneration or small power production project, which is the subject of the Agreement
and this Statement, is identified as IPCo Facility No _______ and is hereinafter referred to as the
"Project".
4. That the Project, which is commonly known as the _________ Project, is located in
Section __ Township ____ Range ____ , Boise Meridian, _____ County, Idaho.
5. That Engineer recognizes that the Agreement provides for the Project to furnish electrical
energy to Idaho Power for a fifteen ( 15) year period.
6. That Engineer has substantial experience in the design, construction and operation of electric
power plants of the same type as this Project.
7. That Engineer has no economic relationship to the Design Engineer of this Project and has
made the analysis of the plans and specifications independently.
8. That Engineer has reviewed the engineering design and construction of the Project, including
the civil work, electrical work, generating equipment, prime mover conveyance system, Seller furnished
Interconnection Facilities and other Project facilities and equipment.
-41-
5/19/2010
9. That the Project has been constructed in accordance with said plans and specifications, all
applicable codes and consistent with Prudent Electrical Practices as that term is described in the Agreement.
10. That the design and construction of the Project is such that with reasonable and prudent
operation and maintenance practices by Seller, the Project is capable of performing in accordance with the terms
of the Agreement and with Prudent Electrical Practices for a year period.
11. That Engineer recognizes that Idaho Power, in accordance with paragraph 5.2 of the Agreement,
in interconnecting the Project with its system, is relying on Engineer's representations and opinions contained in
this Statement.
12. That Engineer certifies that the above statements are complete, true and accurate to the best of
his knowledge and therefore sets his hand and seal below.
By ________________________ _
(P.E. Stamp)
Date -------------------------
-42-
5/19/2010
APPENDIXD
FORMS OF LIQUID SECURITY
The Seller shall provide Idaho Power with commercially reasonable security instruments such as Cash
Escrow Security, Guarantee or Letter of Credit as those terms are defined below or other forms of liquid
financial security that would provide readily available cash to Idaho Power to satisfy the Delay Security
requirement within this Agreement.
For the purpose of this Appendix D, the term "Credit Requirements" shall mean acceptable financial
creditworthiness of the entity providing the security instrument in relation to the term of the obligation
in the reasonable judgment of Idaho Power, provided that any guarantee and/or letter of credit issued by
any other entity with a short-term or long-term investment grade credit rating by Standard & Poor's
Corporation or Moody's Investor Services, Inc. shall be deemed to have acceptable financial
creditworthiness.
I. Cash Escrow Security-Seller shall deposit funds in an escrow account established by the Seller in
a banking institution acceptable to both Parties equal to the Delay Security.
2. Guarantee or Letter of Credit Security-Seller shall post and maintain in an amount equal
to the Delay Security: (a) a guaranty from a party that satisfies the Credit Requirements, in
a form acceptable to Idaho Power at its discretion, or (b) a Letter of Credit in a form
acceptable to Idaho Power, in favor ofldaho Power. The Letter of Credit will be issued by
a financial institution acceptable to both parties.
-43-
5/19/2010
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 2
The New Energy Company, LLC
October 12, 2009
Rowena Bishop
Idaho Power Company
1221 W. State Street
Boise ID 83702
Re: Small Generator Interconnection Applications for 2 Locations
Dear Rowena:
Please fmd enclosed Small Generator Interconnection Request Applica­
tion Forms for two locations:
1. Double B Dairy
1250 West 1100 South
Murtaugh, ID 83344
2. Swager Farms
1707E3800N
Buhl, ID 83316
New Energy plans to complete anaerobic digesters at both facilities in
2010. Please find enclosed the $1000 deposit for each project for a to­
tal of$2000. Please call me at 208.890.8783 with questions or if more
information is required.
Thank you,
Laura Knothe, PE
The New Energy Company, LLC
8720 Vic Lane
Middleton, ID 8366
Phone: [phone]
Fax: [phone]
E-mail:
[e-mail]
SMALL GENERATOR INTERCONNECTION REQUEST
(Application Form)
Transmission Provider: IDAHO POWER COMPANY
Designated Contact Person:
Address:
Telephone Number:
Fax:
E-Mail Address:
Rowena Bishop
1221 W. Idaho Street, Boise ID 83702
208-388-2658
208-388-6647
[e-mail]
An Interconnection Request is considered complete when it provides all applicable and correct
information required below.
Preamble and Instructions
An Interconnection Customers who request interconnection must submit this Interconnection Request by
hand delivery, mail, e-mail, or fax to the Transmission Provider.
Processing Fee or Deposit:
If the Interconnection Request passes ALL screens of SGIP Section 2.2.1, the application may be
submitted under the Fast Track Process, and the non-refundable processing fee is $500. Please contact
Idaho Power if you have any questions.
All Interconnection Requsts submitted under the Study Process, whether a new submission or an
Interconnection Request that did not pass the Fast Track Process, shall submit to the Transmission
Provider a deposit not to exceed $1 ,ooo·towards the cost ofthe feasibilitY study.
Interconnection Customer Information
Legal Name of the Interconnection Customer {or, if an individual, individual's name)
Name: -----'O""'w~nc::::e"-'-r/-'=O::..tp:..::e::..ra=t::::o::..r...:C::..::o~m~pa=n~v~bc::::e!!.in"'g'-'fc::::o"-'rm-'-'-"=e.::.d~ . ...:.P...:.Ie:::::a:::::s:::e::..:::.se::::;e:::...:::c.::.o!..!nt::a:.:c:.:.t ~in~f.::.o!..!rm!..!a=t~io::..:n.:....::.be:::::l:=o...:.wc:.. __ _
Contact Person:---------------------------------
Mailing Address: _____________________ .;____ ________ _
Cizy: ___________________ _ State:------Zip:------------
Facility Location {if different from above):------------------------
Telephone (Day):---------Telephone (Evening): ________ _
Fax:------------.,...---E~Mail Address:--------------
'I
Alternative Contact Infonnatiou (if different from the Interconnection Customer)
Contact Name: Laura Knothe PE
Title: project Manager
Address: 8720 Vic Lane
Middleton 10 63644
Telephone (Day): 20& 890.8783 Telephone (Evening): 20B 890 8783
Fax: _ _,2"'0,8,...5.,8,5"".9"'0'-'-1""6 _________ E-Mail Address: [e-mail]
Application is for: X New-Small Generating Facility
___ Capacity 8ddition to Existing Small Generating Facility
If capacity addition to existing f~cility, please describe: --"N,_At-. ------------:--
Will the Small Generating Facility be· used for any of the following?
To Supply Power to the Interconnection·customer? Yes _No ..x_
To Supply Power to Others? Yes __ No _x_
For installations at locations with existing electric service to which the proposed Small Generating
Facility will interconnect, provide:
· Idaho Power Company
(Local Electric Service Provider*) (Existing Account Number*)
[*To be provided by the Interconnection Customer if the local electric service provider is differe,nt from
the Transmission Provider]
ConmmName: __________________________________________________________ __
Title:---------------------------------------
Address: _____________________________________________________ ___
Telephone (Day): ______________ Telephone (Evening):-------------
Fax: __________________ E-Mail Address:-----------
Requested Point of Interconnection: 1250 West 1100 South Murtaugh ID 83344
Interconneption Customer's Requested i-n-Service Date: _ __....l""u~lyc...2~0"-1u.OL-. ____________ _
2
I t I l
I
I I I
1 I
Small Generating Facilitv Information
Data apply only to the Small Generating Facility, not the Interconnection Facilities.
Energy Source: __ Solar __ Wind __ Hydro _Hydro Type (e.g. Run-of-River): ____ _
_ Diesel _Natural Gas __ Fuel Oil __x Other (state type) .... M...,e,...t..,ha..,_n,e'-'G,.,a,s,__ ___ _
Prime Mover: _Fuel Cell _x_Recip Engine
· _Microturbine
_GasTurb
_PV
Type of Generator: .0_synchronous __ Induction Inverter
-.-Steani Turb
_Other
Generator Nameplate Rating: 1200 kW (Typical) Generator Nameplate kV AR: __ _
Interconnection Customer or Customer-Site Load: _ ___:_N::...:o:.:.n.:..:e:.__ ___ kW {if none, so state}
Typical Reactive Load (if known): _:..:N:..:A ____ _
Maximum Physical Export Capability Requested: _12_0_0 ____ kW
List components of the Small Generating Facility equipment package that are currently certified:
Equipment Type
1. -----------2.
3.
4.
5.
Certifying Entity
Is the prime mover compatible with the certified protective relay package? __ Yes
Generator (or solar collector)
Manufacturer, Model Name & Number: (2) Caterpillar G3512 Gas Gensets@ 600kW
Version Number:-----------
No
Nameplate Oulpul Power Rating in kW: (Summer) _1""2:.:.0.::...0 _· ~·--(Winter) _1:.::2c=.oo:;__ __ _
Nameplate Output PO\ver Rating in.kVA: (Summer) 1500 (Wint\lr) _ ...... ·1""50""'0"'------
Individual Generator ·Power. F;tctor
Rated Power Factor: Leading: ------'Lagging:· _:_·o __ a ____ _
Total Number of Generators in wind farm to be interconnected pursuant to this NA
Interconnection Request: Elevation: __ Single phase _Three phase
Inverter Manufacturer, Model Name & Number (if used): _ ___,N"-'-A_,__ ___________ _
List of adjustable set points for the protective equipment or software: _ __:_N::.A..:._ _______ _
NQte: A completed Powur Systems Luad Fluw !lala Hl1uct IIIUHL htJ suJmlitJt.l will1 Llu:: Inlcrcollllcctiou
Reguest.
3
Small Generating Facility Characteristic Data (for inverter-based machines)
Max design fault contribution current: __..N.!.!.A_,__ __ Instantaneous_ or RMS? __
Harmonics Characteristics: _r!N~Al..._ ____________________ _
Start-up requirements: __ ,.!N!':A~---------------------
Small Generating Facility Characteristic Data (for mtating machines)
RPM Frequency: 1200160Hz
(*)Neutral Grounding Resistor (If Applicable): ____ _
Synchronous Generators:
Direct Axis Synchronous Reactance, Xd: ___ P. U.
Direct Axis Transient Reactance, X'd: P.U.
Direct Axis Subtransient Reactance, X" d: --------'P. U.
Negative Sequence Reactance,.X2: P.U.
Zero Sequence Reactance, Xo: P.U.
KV A Base:-----------
Field Volts:------
Field Amperes:------
Induction Generators:
Motoring Power (kW): ------
Ilt or K (Heating Time Constant): -----­
Rotor Resistance, Rr: ------
Stator Resistance, Rs: _____ _
Stator Reactance, Xs: _____ _
Rotor Reactance, Xr: _____ _
Magnetizing Reactance, Xm: _____ _
Short Circuit Reactance, Xd'': _____ _
Exciting Current:-----­
Temperature Rise:------
Frame Size: ------Design Letter: _____ _
Reactive Power Required In Vars (No Load): _____ _
Reactive Power Required In Vars (Full Load): _____ _
Total Rotating Ine11ia, H: Per Unil on kVA Base
Note: Please contact tbe TransmiSsion Provider grior to submitting the Interconnection Request to
detem1ine if the specified infonnation above is required.
4
l I I i I
f l I I I I i
I !
Excitation and Governor System Data for Synchronous Generators Only
Provide appropriate IEEE model block diagram of excitation system, governor system and power system
stabilizer (PSS) in accordance with the regional reliability council criteria. A PSS may be detennined to
be required by applicable studies. A copy of the manufacturer's block diagram may not be substituted.
Interconnection Facilities Information
Will a transformer be used betw~en the generator and the point of common coupling? 0_ Yes _No
Will the transformer be provided by the Interconnection Customer? _0_ Yes __ No
Transformer Data Of Applicable, for Interconnection Customer-Owned Transformer):
Is the transformer: __ single phase __ three phase? Size: -------'kVA
Transformer hnpedance: ___ %on kVA Base
If Three Phase:
Transformer Primary: __ Volts __ Delta __ Wye __ Wye Grounded
Transformer Secondary: __ Volts __ Delta __ Wye __ Wye Grounded
Transformer Tertiary: __ Volts __ Delta __ Wye __ Wye Grounded
Transformer Fuse Data Of Applicable. for lnters;onnection Customer-Owned Fuse):
(Attach copy of fuse manufachrrer's Minimum Melt and Total Clearing Time-Current Curves)
Manufacturer: ________ Type: _______ Size: ___ _:Speed:------
Interconnecting Circuit Breaker (if applicable):
Manufucrurer: __ ~------~--------~---TJpe: ________ _
Load Rating (Amps): Interrupting Rating (Amps): Trip Speed (Cycles): ___ _
Interconnection Protective Relays (If Applicable):
If Microprocessor-Controlled:
List of Functions and Adjustable Setpoints for the protective equipment or software:
Setpoint Function Minimum Maximum
1, See attached SEL-547 Relay Settings Sheet
2.
3.
4.
5.
6.
If Discrete Components:
(Enclose Copy of any Proposed Time-Overcurrent Coordination Curves)
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Current Transformer Data {If Applicable):
(Enclose Copy of Manufacturer's Excitation and Ratio Correction Curves)
Nillnufucrurer: ________________________________________ ___
Type: -------------Accuracy Class: _ Proposed Ratio Connection: __
Manufacturer:------------------------------------
Type: ------------Accuracy Class: _ Proposed Ratio Connection: __
Potential Transformer Data Clf Applicable):
Manufacturer:----------------------------
Type: ---------Accuracy Class: _ Proposed Ratio Connection: __
Manufacturer. _______________________________ _
Type: ------------Accuracy Class: _ Proposed Ratio Connection: __
6
General Information
Enclose copy of site electrical one-line diagram showing the configumtion of all Small Generating
Facility equipment, current and potential circuits, and protection and control schemes. 1bis one-line
diagram must be signed and stamped by a licensed Professional Engineer if the Small Generating Facility
is larger than 50 kW. Is One-Line Diagram Enclosed? ill_ Yes __ No
Enclose copy of any site documentation that indicates the precise physical location of the proposed Small
Generating Facility ~' USGS topographic map or other diagram or documentation).
Proposed location of protective interface equipment on property (include address if different from the
Interconnection Customer's address) 1250 West 1100 South: Murtaugh ID 83344
Enclose copy of any site documentation that describes and details the operation of the protection and
control schemes. Is Available Documentation Enclosed? _Yes _x_No
Enclose copies of schematic drawings for all protection and control circuits, relay current circuits, relay
potential circuits, and alarm/monitoring circuits (if applicable).
Are Schematic Drawings Enclosed? _Yes ~No
Applicant Signature
I hereby certify that, to the best of my knowledge, ali the information provided in this Interconnection
Request is true and correct.
For Interc01mection Customer:
Signed
,a,, // L....J.:-L ----· Dt ., /c./ r.c, -=_.-f[__;.......:;::=G'--':.:..=~~...J........J!:::!:.ia.....::...:...-...!::"~~==---------' a .e: o. , _ r" '-l
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7
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Date ___ _ SEL-547 Relay EZ Settings Sheet 11 of 4
Appendix C
SEL-547 Relay EZ Settings Sheet
EZ Settings (use SHOE and SET E commands)
General Settings
Relay Identifier (30 characters)
Terminal Identifier (30 characters)
Current Transformer Ratio (1-1000)
Nominal Input Voltage, line-to-line (208-480 Vac}
Three-Phase Voltage Connection (WYE); fixed setting
NominaJ System Frequency (50, 60Hz)
Phase Rotation (ABC, ACB)
Date Format (MDY, YMD)
LED Flash Interval (OFF, 5, 10, 15, 30, 60 sec.)
Voltage Element Settings (device 27/59; 4 elements}
Undervoltage I Pickup (OFF, 50-100%); see Note 1
Undervoltage 1 Time Delay (0.00-16000 eye)
Undervoltage 2 Pickup (OFF, 50-100%); see Note 1
Undervoltage 2 Time Delay (0.00-16000 eye)
Overvoltage 1 Pickup (OFF, 50-144%); see Nme 1
Overvoltage 1 Time Delay (0.00-16000 eye)
Overvoltage 2 Pickup (OFF, 50-144%); see Nore I
Overvoltage 2 Time Delay (0.00-16000 eye)
Frequency Element Settings (device 81; 4 elements)
Undervoltage Block Pickup (50-100%); see Note 1
Over-and Underfreqnenc:y l 'Piclq1p (OFF, 40.1-69.9 H;o;)
Ov~r-and Unde.rfrequency I Time Delay (5.00-1 flOOOcyc)
Over-and Underfrequency 2 Pickup (OFF, 40.1--69.9 Hz)
Date Code 20080922 User's Guide
RELID
TERMID
CRATIO
NOMV ;:
3PCONN =
FREQ
ROTATE ;:
DATE
LEDFL =
27UV1P
27UV1D
27UV2P
27UV2D =
590VIP
S90V1D ;:
590V2P
590V2D
27BLKP
!'110U1P
810U1D = ------------------
8IOU2P :: ------------------
SEl-547 Relay
2 of 41 SEL-547 Relay EZ Settings Sheet Date _____ _
Over-and Underfrequency 2 Time Delay (5.0~16000 eye)
Over-and Undecfrequency 3 Pickup (OFF, 40.1-69.9 Hz)
Over-and Underfrequency 3 Time Delay (5.00-16000 eye)
Over-and Uuderfrequency 4 Pickup (OFF, 40.1-69.9 Hz)
Over-and Underfrequency4 Time Delay (5.00-16000cyc)
810U2D ::
SEL·547 Relay
810U3P
810U3D
810U4P
810U4D
Directional Power Element Settings (device 32; 1 element)
Three-Phase Power Pickup (OFF, 40-900 Watts, secondary)
Power Element, Forward or Reverse (F, R)
Power Element Time Delay (0.00-16000 eye)
32P
32FR
320
Synchronism Check Element Settings (device 25; 1 element)
Difference Voltage Pickup (OFF, 1-50%); see Nore 1
Maximum Slip Frequency (0.1-0.5 Hz)
Maximum Angle (2-60 degrees)
User's Guide
2SDIFP
25SLP
25ANG
------------------
=
=
=
=
Dale Code 20080922
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 3
Laura Knothe, PE
The New Energy Company
8720 Vic Lane
Middleton, ID 83644
Re: Double B Dairy-Project# 308
Dear Laura:
October 19, 2009
®
An IOACORP Comparw
Thank you for your Generator Interconnection application for the Rock Creek Dairy Project to be
connected to the Idaho Power system at Twin Falls County, Idaho (see attached copy). Since we
have received all of the required materials, this application is now considered complete. As you
may be aware, we are required to post certain infonnation to our OASIS (Open Access Same
Time Infmmation) website. Please refer to the website periodically to view a list of current
projects at http://www.oatioasis.com/IPCO!index.html under GENERATOR
INTERCONNECTION INFORMATION folder, on the left side ofthe screen.
For your reference, enclosed is a copy of Idaho Power Company's Requirements for Generation
Interconnection which may or may not apply to your project. More information about the
Generation Interconnection process can be found on the Idaho Power website at:
http://www. idahopower. com/ AboutU s/BusinessToBusiness/Generationinterconnect/default.cfm
At this time, Idaho Power Company will assign a planning engineer for this project, and we will
contact you in the near future to schedule a Scoping Meeting. For your review, I am attaching a
copy of the standard Interconnection Feasibility Study Agreement that needs to be executed by
you soon after our Scoping Meeting. Please feel free to contact me with your questions about the
Generator Interconnection Process anytime.
I will forward this application to our T &D Planning Leader, Marc Patterson, who will be
evaluating your request.
Encl Application
Sincerely,
1
\..J /) !~.~~
Operations Analyst
Ph 208-388-2658
ldaho Power Company's Requirements for Generation Interconnection
Standard Interconnection Feasibility Study Agreement
Cc: Marc Patterson/IPC (via email)
1221 \fiJ id~ho St. (83702)
P.O. Box 70
Boise, ID 83707
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 4
Small Gen Feasibility Study Agreement
Double B Dairy Project# 308
Feasibility Study Agreement
THIS AGREEMENT is made and entered into this_2]_day of Dc+okr 2009 by and
between llv 1\t?-l.U E:n.e~§ I (fln, ert V)~::.l ' I c 'a _ ___,L=.!cL,_,C_.-=---------
organized and existing under tlidlaws of 'the Stffte of -=t=-d a b o ,
("Interconnection Customer,") and Idaho Power Company a Corporation existing under the laws
of the State ofldaho ("Transmission Provider"). Interconnection Customer and Transmission
Provider each may be referred to as a "Party," or collectively as the "Parties."
RECITALS
WHEREAS, Interconnection Customer is proposing to develop a Small Generating Facility or
generating capacity addition to an existing Small Generating Facility consistent with the
Interconnection Request completed by Interconnection Customer on October 12, 2009, also
known as Project# 308; and
WHEREAS, Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Provider's Transmission System; and
WHEREAS, Interconnection Customer has requested the Transmission Provider to perform a
feasibility study to assess the feasibility of interconnecting the proposed Small Generating
Facility with-the Transmission Provider's Transmission System, and of any Affected Systems;
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Pmties agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the terms specified shall have
the meanings .indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause to be
perfmmed an interconnection feasibility study consistent the standard Small Generator
Interconnection Procedures in accordance with the Open Access Transmission Tariff.
3.0 The scope ofthe feasibility study shall be subject to the assumptions set forth in
Attachment A to this Agreement.
4.0 The feasibility study shall be based on the technical information provided by the
Interconnection Customer in the Interconnection Request, as may be modified as the
result of the scoping meeting. The Transmission Provider reserves the right to request
additional technical information from the Interconnection Customer as may reasonably
become necessary consistent with Good Utility Practice during the course of the
feasibility study and as designated in accordance with the standard Small Generator
Interconnection Procedures. If the Interconnection Customer modifies its Interconnection
Request, the time to complete the feasibility study may be extended by agreement of the
Parties.
Page 1 of3
Small Gen Feasibility Study Agreement
Double B Dairy Project# 308
5.0 In perfmming the study, the Transmission Provider shall rely, to the extent reasonably
practicable, on existing studies of recent vintage. The Interconnection Customer shall not
be charged for such existing studies; however, the Interconnection Customer shall be
responsible for charges associated with any new study or modifications to existing studies
that are reasonably necessary to perform the feasibility study.
6.0 The feasibility study report shall provide the following analyses for the purpose of
identifying any potential adverse system impacts that would result from the
interconnection of the Small Generating Facility as proposed:
6.1 Initial identification of any circuit breaker short circuit capability limits exceeded
as a result of the interconnection;
6.2 Initial identification of any thermal overload or voltage limit violations resulting
from the interconnection;
6.3 Initial review of grounding requirements and electric system protection; and
6.4 Description and non-bonding estimated cost of facilities required to interconnect
the proposed Small Generating Facility and to address the identified short circuit
·and power flow issues.
'7 .0 The feasibility study shall model the impact of the Small Generating Facility regardless
of purpose in order to avoid the further expense and intelTUption of operation for
reexamination of feasibility and impacts ifthe Interconnection Customer later changes
the purpose for which the Small Generating Facility is being installed.
8.0 The study shall include the feasibility of any interconnection at a proposed project site
where there could be multiple potential Points of Interconnection, as requested by the
Interconnection Customer and at the Interconnection Customer's cost.
9.0 In lieu of Feasibility Study deposit, Interconnection Customer agrees that study funds
will be drawn ·from the application fee for the performance of the Interconnection
Feasibility Study.
Transmission Provider shall charge and Interconnection Customer shall pay the actual
costs of the Interconnection Feasibility Study. Any difference between the deposit and
the actual cost of the study shall be paid by or refunded to Interconnection Customer, as
appropriate.
Page 2 of3
Small Gen Feasibility Study Agreement
Double B Dairy Project# 308
10.0 Once the feasibility study is completed, a feasibility study report shall be prepared and
transmitted to the Interconnection Customer. Barring unusual circumstances, the
feasibility study must be completed and the feasibility study report transmitted within 30
business days of the Interconnection Customer's agreement to conduct a feasibility study.
11.0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
12.0 The Interconnection Customer must pay any study costs that exceed the deposit without
interest within 30 calendar days on receipt of the invoice or resolution of any dispute. If
the deposit exceeds the invoiced fees, the Transmission Provider shall refund such excess
within 30 calendar days of the invoice without interest.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written.
Transmission Provider:
Idaho Power Company-Delivery
Signed___,_l(/t-+-~-=--· _e-4--A§-=--~-'-'f::I_//~=====--
Printed--=-/11...:....!....=4::..:..t"""L"'-'-8_--=cx--=·-=-fh.:....-e:::....;.,r.s .... ·=-on,_,· ,____ __ _
Title __ C:::._-1_,_/+9'-'-Jh--'-'e=c:....:fi..:....? n~·~,___~L'---e_Ct-_d_'C_v-__
Date 16 /2-7 /bf ----------~~--------------
Inter·connection Customer:
1he. -{)eu; ~ev-8~ C'evn~ JJd:C
Signed ~.~...ckv ., Ft-
Printed la.,u__v--c-. \sYl o:h ::@ . ." Ph
Title M.a..Nl.. o.g-< 4 ~c1 ,.fn t.t--
Date l o 1-;;J "l I a~
Page 3 of3
Small Gen Feasibility Study Agreement
Double B Dairy Project# 308
Attachment A to Feasibility Study Agreement
Assumptions Used in Conducting the Feasibility Study
The feasibility study will be based upon the information set forth in the Interconnection Request
and agreed upon in the scoping meeting held on l C I ?-.'1 I rf1 :
1) Designation ofPoint of Interconnection and configuration to be studied.
" ?2t.l .t; tv ~0
2) Designation of alternative Points of Interconnection and configuration.
1) and 2) are to be completed by the Interconnection Customer. Other assumptions (listed
below) are to be provided by the Interconnection Customer and the Transmission Provider.
Page 1 ofl
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 5
GENERATOR INTERCONNECTION
FEASIBILITY STUDY
for integration of the proposed
PROJECT #308
to the
IDAHO POWER COMPANY ELECTRICAL SYSTEM
for the
INTERCONNECTION CUSTOMER
DRAFT REPORT
DECEMBER 9, 2009
CP
•'
1.0 Introduction
The Generation Interconnection Customer has contracted with Idaho Power Company (IPCo) to
perform a Generator Interconnection Feasibility Study for the integration of a proposed 1.2 MW
dairy digester project (project #308). The location of the project is in Idaho Power's Southern
Idaho service territory in Cassia County, Idaho.
This report documents the basis for and the results of this Feasibility Study for the Generation
Interconnection Customer. It describes the proposed project, the study cases used, the impact of
associated projects, and results of all work in the areas of concern.
2.0 Summary
The proposed small generation project is a 1.2 MW biogas generation project. The proposed
Point of Interconnection (POI) for the generating facility with the IPCo system is in Cassia
County, Idaho at the 12.5 kV distribution level near the generating facility.
This feasibility study indicates the existing local transmission system does currently have the
capacity for the 1.2 MW output of the digester project
The installation of a generation interconnection and protection package is the only upgrade
needed. The estimated cost to interconnect this generation project to Idaho Power's system is
$225,000.
3.0 Scope of Interconnection Feasibility Study
The Interconnection Feasibility Study was done and prepared in accordance with Idaho Power
Company Standard Generator Interconnection Procedures, to provide a preliminary evaluation of
the feasibility of the interconnection of the proposed generating project to the Idaho Power
system. As listed in the Interconnection Feasibility Study agreement, the Interconnection
Feasibility Study report provides the following information:
preliminary identification of any circuit breaker short circuit capability
limits exceeded as a result of the interconnection;
preliminary identification of any thermal overload or voltage limit
violations resulting from the interconnection; and
preliminary description and non-binding estimated cost of facilities
required to interconnect the Small Generating Facility to the Distribution
System and to address the identified short circuit and power flow issues.
-2-
All other proposed Generation projects prior to this project in the Generator Interconnect queue
were considered in this study. A current list ofthese projects can be found on the Idaho Power
web site as follows:
http://www.oatioasis.com/ipco/index.html.
4.0 Description of Proposed Generating Project
Project #308 proposes to connect to the IPCo distribution system for an injection of 1.2 MW
(maximum project output).
5.0 Description of Existing Substation Facilities
The distribution substation that serves this area is located approximately two and a half miles
south and east of the POI. The existing substation transformer is a 69:34.5 kV transformer that
has adequate capacity for this project.
The associated feeder breaker at the substation is rated for use at 34.5 kV. This breaker's
interrupting capabilities are not exceeded with the added generation.
6.0 Description of Existing Distribution Facilities
The distribution feeder serving this area is grounded wye and operates at both 34.5 kV and 12.5
kV. At the location of generation the feeder is at the 12.5 kV voltage level. There is adequate
capacity on this distribution line to serve this project. The project will be required to run at unity
power factor during full output. This facility cannot have a leading power factor (produce
VARs) during periods of light loading (fall through spring) or a lagging power factor during
summer peak.
Since the biogas generation project is served by a feeder that also serves other Idaho Power
customers, and to minimize the risk of islanding the generator with local load, a generation
interconnection and protection package will be required at the POL This package includes a 12.5
kV recloser, controls, CTs, PTs, and communications per Idaho Power's standard for generators
connected to the distribution system.
7.0 Description of Existing Transmission Facilities
The transmission line that serves this area is a 69 kV radial tap. With the addition of this
generation project no capacity related problems occur on this tap. Therefore, no improvements
need to be made on the immediate transmission system.
-3-
8.0 Description and Cost Estimate of Required Facility Upgrades
The estimated costs to interconnect the 1.2 MW biogas generation project in Twin Falls County,
Idaho is $225,000. These upgrades are listed in the following Table.
Description Estimated Cost
Generation Interconnection Protection Package
(Includes 12.5 kV recloser, controls, CTs, PTs, and
communications $225,000
Total Estimated Cost $225,000
Table 1: Cost Estimates
These cost estimates include direct equipment and installation labor costs, indirect labor costs
and overheads. (Tax Gross Up has not been included presuming construction of interconnection
facilities will not qualify under IRS rules as a taxable event. Allowance for funds used during
construction (AFUDC) has not been included in the cost estimates since it is assumed that IPC
will be provided up-front funding by the Project). These are cost estimates only and final
charges to the customer will be based on the actual construction costs incurred.
9.0 Description of Operating Requirements
In addition to the upgrades listed in section 9.0 of this report, the proposed project must meet
several operating requirements. The project must be controlled to operate at a unity power factor
or meet the voltage schedule provided by Idaho Power. If this requirement cannot be met,
further voltage studies will be necessary. Voltage flicker at startup and during operation will be
limited to less than 5% as measured at the point of interconnection. For this to occur, the current
cannot exceed 65 Amps during start up at the 12.5 kV voltage level. The project is required to
comply with the applicable Voltage and Current Distortion Limits found in IEEE Standard 519-
1992 IEEE Recommended Practices and Requirements for Harmonic Control in Electrical
Power Systems. The project must also limit the ground fault current at the point of
interconnection to 20 Amps. See Appendix A for more details
10.0 Conclusions
The requested interconnection of project #308 to IPCo's system was studied. The results ofthis
study indicate that it is feasible to connect this project to the existing IPCo system with the
upgrades outlined above.
-4-
APPENDIX A
A-1.0 Method of Study
The Feasibility Study plan inserts the Project up to the maximum requested injection into the
selected Western Electric Coordinating Council (WECC) power flow case and then, using Power
World Simulator Version 12, examines the impacts ofthe new resource on Idaho Power's
transmission system (lines, transformers, etc.) within the study area under various
operating/outage scenarios. The WECC and Idaho Power reliability criteria and Idaho Power
operating procedures were used to determine the acceptability of the configurations considered.
The WECC case is a recent case modified to simulate stressed but reasonable pre-contingency
energy transfers utilizing the IPC system. For distribution feeder analysis, Idaho Power utilizes
Advantica's SynerGEE Software.
A-2.0 Acceptability Criteria
The following acceptability criteria were used in the power flow analysis to determine under
which system configuration modifications may be required:
The continuous rating of equipment is assumed to be the normal thermal rating of the
equipment. This rating will be as determined by the manufacturer of the equipment or as
determined by Idaho Power. Less than or equal to 100% of continuous rating is
acceptable.
Idaho Power's Voltage Operating Guidelines were used to determine voltage
requirements on the system. This states, in part, that distribution voltages, under normal
operating conditions, are to be maintained within plus or minus 5% (0.05 per unit) of
nominal everywhere on the feeder. Therefore, voltages greater than or equal to 0.95 pu
voltage and less than or equal to 1.05 pu voltage are acceptable.
Voltage flicker during starting or stopping the generator is limited to 5% as measured at
the point of interconnection, per Idaho Power's T&D Advisory Information Manual.
Idaho Power's Reliability Criteria for System Planning was used to determine proper
transmission system operation.
All customer generation must meet IEEE 519 and ANSI C84.1 Standards.
All other applicable national and Idaho Power standards and prudent utility practices
were used to determine the acceptability of the configurations considered.
The stable operation ofthe system requires an adequate supply of volt-amperes reactive
(VARs) to maintain a stable voltage profile under both steady-state and dynamic system
conditions. An inadequate supply of V ARs will result in voltage decay or even collapse
under the worst conditions.
-5-
Equipment/line/path ratings used will be those that are in use at the time of the study or that are
represented by IPC upgrade projects that are either currently under construction or whose
budgets have been approved for construction in the near future. All other potential future ratings
are outside the scope of this study. Future transmission changes may, however, affect current
facility ratings used in the study.
A-3.0 Grounding Guidance
Idaho Power Company (IPC) requires interconnected transformers to limit their ground fault
current to 20 amps at the point of interconnection.
A-4.0 Electrical System Protection Guidance
IPC requires electrical system protection per Requirements for Generation Interconnections
found on the Idaho Power Web site,
http://www .idaho power .com/aboutuslbusiness/generationlnterconnect/.
A-5.0 WECC Coordinated Off-Nominal Frequency Load Shedding and Restoration
Requirements
IPC requires frequency operational limits to adhere to WECC Under-frequency and Over­
frequency Limits per the WECC Coordinated Off-Nominal Frequency Load Shedding and
Restoration Requirements available upon request.
-6-
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 6
December 15, 2009
Mr. Laura Knothe
The New Energy Company
8720 Vic Lane
Middleton, ID 83644
RE: Project #s 307, 308, and 309
Dear Ms. Knothe:
An IDACORP Company
Enclosed are the Draft Feasibility Study Reports (DFeSR) for the above-referenced projects. The
feasibility analysis indicates that modification/addition of some facilities will be required to integrate the
network/energy resource capacity addition of your projects into the Idaho Power system.
Please schedule a technical meeting with Candace Gentry at 208.388.2276 if you wish to discuss the
DFeSR. Under the generator interconnection process, you must schedule a technical meeting and/or
provide your comments about the DFeSR within 10 business days upon receipt of the DFeSR. After
which time (unless notified by you of your intention to withdraw your project) we will issue the Final
Feasibility Study Report, and offer a signed System Impact Study Agreement for execution.
If you have any questions, please contact me.
Sincerely,
Marc Patterson
Engineering Leader, T &D Planning
208.388.2712
Enclosure: Draft Feasibility Study Report-December 15, 2009
C: Rowena Bishop/IPC
1221 W. Idaho St. (83702)
P.O. Box 70
Boise, ID ~3707
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 7
GENERATOR INTERCONNECTION
FEASIBILITY STUDY
for integration ofthe proposed
PROJECT #308
to the
IDAHO POWER COMPANY ELECTRICAL SYSTEM
for the
INTERCONNECTION CUSTOMER
I
FINAL REPORT
JANUARY 13, 2010
CP
1.0 Introduction
The Generation Interconnection Customer has contracted with Idaho Power Company (IPCo) to
perform a Generator Interconnection Feasibility Study for the integration of a proposed 1.2 MW
dairy digester project (project #308). The location of the project is in Idaho Power's Southern
Idaho service territory in Cassia County, Idaho.
This report documents the basis for and the results of this Feasibility Study for the Generation
Interconnection Customer. It describes the proposed project, the study cases used, the impact of
associated projects, and results of all work in the areas of concern.
2.0 Summary
generation project consisting of.
The proposed Point of Interconnection
(POI) for the generating facility with the IPCo system is in Cassia County, Idaho at the 12.5 kV
distribution level near the generating facility.
This feasibility study indicates the existing local transmission system does currently have the
capacity for the 1.2 MW output ofthe digester project
The installation of a generation interconnection and protection package is the only upgrade
needed. The estimated cost to interconnect this generation project to Idaho Power's system is
$225,000.
3.0 Scope of Interconnection Feasibility Study
The Interconnection Feasibility Study was done and prepared in accordance with Idaho Power
Company Standard Generator Interconnection Procedures, to provide a preliminary evaluation of
the feasibility of the interconnection of the proposed generating project to the Idaho Power
system. As listed in the Interconnection Feasibility Study agreement, the Interconnection
Feasibility Study report provides the following information:
preliminary identification of any circuit breaker short circuit capability
limits exceeded as a result of the interconnection;
preliminary identification of any thermal overload or voltage limit
violations resulting from the interconnection; and
preliminary description and non-binding estimated cost of facilities
required to interconnect the Small Generating Facility to the Distribution
System and to address the identified short circuit and power flow issues.
-2-
All other proposed Generation projects prior to this project in the Generator Interconnect queue
were considered in this study. A current list ofthese projects can be found on the Idaho Power
web site as follows:
http://www .oatioasis.com/ipco/index.html.
4.0 Description of Proposed Generating Project
Project #308 proposes to connect to the IPCo distribution .,-u.,,r"'"'
(maximum project output) using
5.0 Description of Existing Substation Facilities
The distribution substation that serves this area is located approximately two and a half miles
south and east of the POI. The existing substation transformer is a 69:34.5 kV transformer that
has adequate capacity for this project.
The associated feeder breaker at the substation is rated for use at 34.5 kV. This breaker's
interrupting capabilities are not exceeded with the added generation.
6.0 Description of Existing Distribution Facilities
The distribution feeder serving this area is grounded wye and operates at both 34.5 kV and 12.5
kV. At the location of generation the feeder is at the 12.5 kV voltage level. There is adequate
capacity on this distribution line to serve this project. The project will be required to run at unity
power factor during full output. This facility cannot have a leading power factor (produce
VARs) during periods of light loading (fall through spring) or a lagging power factor during
summer peak.
Since the biogas generation project is served by a feeder that also serves other Idaho Power
customers, and to minimize the risk of islanding the generator with local load, a generation
interconnection and protection package will be required at the POI. This package includes a 12.5
kV recloser, controls, CTs, PTs, and communications per Idaho Power's standard for generators
connected to the distribution system.
7.0 Description of Existing Transmission Facilities
The transmission line that serves this area is a 69 kV radial tap. With the addition of this
generation project no capacity related problems occur on this tap. Therefore, no improvements
need to be made on the immediate transmission system.
-3-
8.0 Description and Cost Estimate of Required Facility Upgrades
The estimated costs to interconnect the 1.2 MW biogas generation project in Twin Falls County,
Idaho is $225,000. These upgrades are listed in the following Table.
Description Estimated Cost
Generation Interconnection Protection Package
(Includes 12.5 kV recloser, controls, CTs, PTs, and
communications $225,000
Total Estimated Cost $225,000
Table 1: Cost Estimates
These cost estimates include direct equipment and installation labor costs, indirect labor costs
and overheads. (Tax Gross Up has not been included presuming construction of interconnection
facilities will not qualify under IRS rules as a taxable event. Allowance for funds used during
construction (AFUDC) has not been included in the cost estimates since it is assumed that IPC
will be provided up-front funding by the Project). These are cost estimates only and final
charges to the customer will be based on the actual construction costs incurred.
9.0 Description of Operating Requirements
In addition to the upgrades listed in section 9.0 of this report, the proposed project must meet
several operating requirements. The project must be controlled to operate at a unity power factor
or meet the voltage schedule provided by Idaho Power. If this requirement cannot be met,
further voltage studies will be necessary. Voltage flicker at startup and during operation will be
limited to less than 5% as measured at the point of interconnection. For this to occur, the current
cannot exceed 65 Amps during start up at the 12.5 kV voltage level. The project is required to
comply with the applicable Voltage and Current Distortion Limits found in IEEE Standard 519-
1992 IEEE Recommended Practices and Requirements for Harmonic Control in Electrical
Power Systems. The project must also limit the ground fault current at the point of
interconnection to 20 Amps. See Appendix A for more details
10.0 Conclusions
The requested interconnection of project #308 to IPCo's system was studied. The results of this
study indicate that it is feasible to connect this project to the existing IPCo system with the
upgrades outlined above.
-4-
APPENDIX A
A-1.0 Method of Study
The Feasibility Study plan inserts the Project up to the maximum requested injection into the
selected Western Electric Coordinating Council (WECC) power flow case and then, using Power
World Simulator Version 12, examines the impacts of the new resource on Idaho Power's
transmission system (lines, transformers, etc.) within the study area under various
operating/outage scenarios. The WECC and Idaho Power reliability criteria and Idaho Power
operating procedures were used to determine the acceptability of the configurations considered.
The WECC case is a recent case modified to simulate stressed but reasonable pre-contingency
energy transfers utilizing the IPC system. For distribution feeder analysis, Idaho Power utilizes
Advantica's SynerGEE Software.
A-2.0 Acceptability Criteria
The following acceptability criteria were used in the power flow analysis to determine under
which system configuration modifications may be required:
The continuous rating of equipment is assumed to be the normal thermal rating of the
equipment. This rating will be as determined by the manufacturer of the equipment or as
determined by Idaho Power. Less than or equal to 100% of continuous rating is
acceptable.
Idaho Power's Voltage Operating Guidelines were used to determine voltage
requirements on the system. This states, in part, that distribution voltages, under normal
operating conditions, are to be maintained within plus or minus 5% (0.05 per unit) of
nominal everywhere on the feeder. Therefore, voltages greater than or equal to 0.95 pu
voltage and less than or equal to 1.05 pu voltage are acceptable.
Voltage flicker during starting or stopping the generator is limited to 5% as measured at
the point of interconnection, per Idaho Power's T &D Advisory Information Manual.
Idaho Power's Reliability Criteria for System Planning was used to determine proper
transmission system operation.
All customer generation must meet IEEE 519 and ANSI C84.1 Standards.
All other applicable national and Idaho Power standards and prudent utility practices
were used to determine the acceptability of the configurations considered.
The stable operation ofthe system requires an adequate supply of volt-amperes reactive
(VARs) to maintain a stable voltage profile under both steady-state and dynamic system
conditions. An inadequate supply ofVARs will result in voltage decay or even collapse
under the worst conditions.
-5-
Equipment/line/path ratings used will be those that are in use at the time of the study or that are
represented by IPC upgrade projects that are either currently under construction or whose
budgets have been approved for construction in the near future. All other potential future ratings
are outside the scope of this study. Future transmission changes may, however, affect current
facility ratings used in the study.
A-3.0 Grounding Guidance
Idaho Power Company (IPC) requires interconnected transformers to limit their ground fault
current to 20 amps at the point of interconnection.
A-4.0 Electrical System Protection Guidance
IPC requires electrical system protection per Requirements for Generation Jnterconnecti,ons
found on the Idaho Power Web site,
http://www.idahopower.com/aboutus/business/generationlnterconnect/.
A-5.0 WECC Coordinated Off-Nominal Frequency Load Shedding and Restoration
Requirements
IPC requires frequency operational limits to adhere to WECC Under-frequency and Over­
frequency Limits per the WECC Coordinated Off-Nominal ·reguency Load Shedding and
Restoration Requirements available upon request.
-6-
BEFORE THE'
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 8
Laura Knothe
The New Energy Company
8720 Vic Lane
Middleton, ID 83644
An IDACORP Company
January 13, 2010
RE: Swager Farms, Double B Dairy and Rock Creek Dairy-Project #s 307, 308, 309
Dear Ms. Knothe:
Enclosed are the Final Feasibility Study Reports for the above-referenced projects. The feasibility
analysis indicates that the system is capable of integrating your generator at the proposed location.
However, the study does not provide any transmission rights which may be required for the sale of
energy from this project. It is recommended that you contact Idaho Power's Power Supply Department
to begin the study process for the delivery of energy from this project. Additional network upgrades
may be required which could have a significant financial impact. If you have any comments to the draft
report, please contact me as soon as possible.
Since no System Impact Study is required, I have enclosed two (2) copies of the Facility Study
Agreement (FSA) for the above-referenced projects. In order to proceed with these applications, Idaho
Power must receive your agreement to proceed with a Facility Study by executing both copies of each
FSA and submitting completed Attachments, along with the required deposit in order to remain in the
Generator Interconnection queue. The deposit under the FSA is based on the estimated engineering
costs provided to you in the Feasibility Study Reports. The required deposits are:
#307 $11,740.00 #308 $11,250.00 #309 $17,760.00
If you wish to proceed, please sign both copies of each FSA and submit them along with the deposit(s)
to Idaho Power Company, attn: Rowena Bishop by March 1, 2010, otherwise your application will be
deemed withdrawn. Please contact me if you have any questions.
Sincerely,
Marc Patterson
Engineering Leader, T &D Planning
Ph. 208.388.2712
Encl: Final Feasibility Study Reports-#307, #308, #309
2 copies -Facility Study Agreement #307
2 copies-Facility Study Agreement #308
2 copies -Facility Study Agreement #309
C: Chris Punt/IPC
Ed Kosydar/IPC
1221 W. Idaho St. (83702)
P.O. Box 70
Boise, ID 83707
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 9
March 2, 2010
The New Energy Company LLC
Attn: Laura Knothe
8720 Vic Lane
Middleton ID 83644
E-mail Copy: [e-mail]
··-··--....
Randy C. Allphin
®
An IDACORP Company
Sr. Energy Contract Coordinator
Tel: [phone]
[e-mail]
RE: Double B Dairy -Proposed Anaerobic Digester Project
Ms. Knotl1e,
Summarized below is a brief outline of the purchase power agreement, interconnection process
and transmission capacity requirements for your proposed generation project.
Purchase Power Agreement
The project you have described appears to be eligible for a purchase power agreement under the
guidelines for a Qualifying Facility as defined by the Public Utilities Regulatory Policies Act of 1978
(PURP A). At the time you are ready to proceed with a purchase power agreement for tllis project,
Idaho Power will prepare a purchase power agreement that complies with the current rules and
regulations that govern these PURP A agreements, any draft purchase power agreements previously
provided to you for review must be updated to include current rules and regulations.
Prior to Idaho Power executing a purchase power agreement it will be required that you have:
1.) Provided documentation that substantiates that the project has filed for Interconnection
and is in compliance with any payments and/or other requirements specified in the
Interconnection process for this project and;
Page I of4
P 0 Box 70 Boise, .Idaho 83707 1221 W Idaho St. Boise, Idaho 83702
..
2.) Received and accepted an Interconnection feasibility study for this project and;
3.) Returned a signed copy of this letter of understanding and all of the required
information to enable Idaho Power to file an application requesting transmission
capacity for this project.
4.) Results of the initial transmission capacity application are known and the project
accepts these results and intends to continue with the development of the project.
Interconnection and Transmission Capacity
Your project will be responsible for all costs of physically interconnecting the project to the
Idaho Power electrical system and any costs associated with acquiring adequate finn transmission
capacity on the Idaho Power transmission system to enable the project's energy to be delivered to
Idaho Power customers.
Interconnection
Your project will be required to complete the interconnection process and execute a
Generation Interconnection Agreement ("GIA'').
Transmission Capacity
By requesting to sell your project's energy to Idaho Power, it will be required that
your project be designated as a Network Resource ("DNR").
In order for this project to achieve DNR status, Idaho Power is required to make a
request (complete and file an application) and be granted firm transmission capacity
from the Idaho Power delivery business unit ("Delivery") to move your project's energy
from the physical interconnection point to Idaho Power customers. In accordance with
various .rules and regulations, the project must be granted DNR status no later than
60 days prior to the project delivering any energy to Idaho Power.
Idaho Power will begin this firm transmission capacity application process only after
the project has returned a signed copy of this letter of understanding and all of the
information required for Idaho Power to file this application (see attached list of
required information).
Page2 of4
P 0 Box 70 Boise, Idaho 83707 1221 W Idaho St. Boise, Idaho 83702
After filing the finn transmission capacity application with Delivery, Idaho Power
will receive notification back from Delivery that: a) adequate transmission capacity is
available for this project, b) a transmission capacity system impact study is required to
determine the available transmission capacity and/or required upgrades, or c) of the
required transmission upgrades and the associated costs. Idaho Power will notify the
project of this response to the transmission capacity application in a timely manner after
the response is received from Delivery.
If the response from Delivery is as specified in item a (transmission capacity is
available), the project will be required to execute a purchase power agreement with
Idaho Power within 30 days in order to retain this transmission capacity reservation.
If the response from Delivery is as specified in items b or c (studies required and/or
upgrades required), the project will be required to execute a Network Resource
Integration Study Agreement (sample copy attached for your information) in order for
Idaho Power to continue the transmission capacity request. This Network Resource
Integration Study Agreement will specify that the project will be responsible for costs
incurred by Idaho Power to perform any required studies. If, after the studies are
concluded the project wishes to continue the pursuit of transmission capacity, the project
will also be responsible for all transmission system upgrade costs identified within the
studies. The fees and costs will be in the form of both initial deposits as well as actual
costs. If at any time after executing the Network Resource Integration Study Agreement
the project does not pay any required fees, or elects to stop the transmission study or
upgrade process, the project shall be responsible for all costs incurred by Idaho Power in
performing the studies or upgrades up to the point of termination of the Network
Resource Integration Study Agreement.
Upon successful completion of the transmission capacity upgrade process, a
transmission capacity reservation will exist for this project. However, in order to
finalize this transmission capacity reservation, a purchase power agreement with
Idaho Power must be executed no later than 30 days after the transmission capacity
upgrades are completed. If the purchase power agreement is not executed by this
deadline, the transmission capacity reservation will be released and this process will
have to be repeated if the project later requests transmission capacity.
As noted earlier, this transmission capacity acquisition and associated Network
Resource designation must be completed, at the minimum, 60 days prior to the project
delivering any energy to Idaho Power. In addition, the project must provide routine
updates to Idaho Power of the expected online date of the generation project to ensure
Idaho Power is capable of accepting the energy from the project on the actual date the
project comes online.
Page 3 of4
P 0 Box 70 Boise, Idaho 83707 1221 W Idaho St. Boise, Idaho 83702
Please return all required information to:
Idaho Power Company
Attn: Randy C. Allphin
POBox 70
Boise, ID 83 707
E-mail: rallphin@idahopower .com
Sincerely,
Randy C Allphin
Idaho Power Company
Understood and accepted this __ day of __________ _, 2010
Signature
Print Name
Title
Pnge4 of4
P 0 Box 70 Boise, Idaho 83707 1221 W Idaho SL Boise; Idaho 83702
An IDACORP ComPJnV
Transmission Capacity Application Questionnaire
This list is the known information requirements as of the date of the letter transmitting this request. If additional information
is required, Idaho Power will promptly notify the project developer of the additional information requirements.
A. Project Name
B. Project Location
C. Project Developer
Name
Address
City I State I Zip
Phone Number
E-mail
D. Idaho Power Delivery Business unit Interconnection "Que" reference number (if not known,
please contact the Idaho Power Interconnection group)
E. Evidence of the Project's good standing status in the Idaho Power Interconnection Process
F. Copy of the Idaho Power Interconnection feasibility study and a statement from the project that
the project has accepted the results of the interconnection feasibility study and is continuing
the process of interconnecting and developing the generation project.
G. Maximum Capacity (MW) _____ _
Page I of3
H. Beginning day and time of energy deliveries
Day (mm/dd/yyyy) __________ _
Time _____________ _
I. Ending day and time of energy deliveries
Day (mm/dd/yyyy}, _________ _
Time ____________ _
J. VAR capability (both leading and lagging) of all generators ----------
K. Identification of the control area(s) from which the energy will originate
L. List any periods of restricted operations throughout the year
M. Maintenance schedule
N. Minimum loading level of each generation unit -----------------
0 . Normal operating level of each generation unit. -----------------
P. Any must-run generation unit designations required for system reliability or contractual reason
Page2of3
Q. Approximate variable generation cost ($/MWh) Note-/his will be estimated energy pricing from a potential
purchase power agreement that this project may be eligible for.
R. lf the generation resource is to be located in the Idaho Power Balancing Authority Area and if
only a portion of the resource output is to be designated as a Network Resource, then explain
arrangements governing sale and delivery of additional output to third parties.
S. If the project is not directly interconnected to the Idaho Power transmission system, provide
the transmission provider(s) name, Point of Receipt, Point of Delivery and the transmission
reservation number for all of the transmission providers required to deliver the project's energy
to Idaho Power.
Transmission Provider(s) Name -------------------------
Point of Receipt _____________________________ _
Point of Delivery _____________________________ _
Transmission Reservation Number(s) ------------------------
T. If the project is directly interconnected to the Idaho Power transmission system, provide the
Point of Receipt, physical location and voltage.
Point of Receipt,_ ____________________________ _
Physical Location _____________________________ _
Voltage. _______ _
U. Is the project committed to execute a purchase power agreement with Idaho Power upon a
favorable resolution of the identified interconnection and transmission costs?
Yes D No 0
V. Is any portion of the maximum capacity identified for this project committed to any other party?
Yes 0 NoD
Signature -------------------~Date _______________ _
Page 3 of3
NETWORK RESOURCE INTEGRATION STUDY AGREEMENT
THIS Agreement is made and entered into this __ day of ____ 20_
between Idaho Power Company ("Idaho Power" or "Company") through its Power
Supply business unit ("Power Supply") and
("Developer"). Power Supply and Developer may here_in,~n~r be referred to individually
~-4_;r
as "Party" or collectively as "Parties." _._.}<" .,.1, -~)· lj~i~tJ· ~-~~~~ RECITAhs :11·~;-····~1:~.
to the Company's load centers. The Federal Energy Regulatory Commission's rules
require that Power Supply make the request to Delivery to perform the SIS. Delivery
will bill Power Supply for the costs incurred to perform the SIS.
NETWORK RESOURCE INTEGRATION STUDY AGREEMENT -1
AGREEMENTS:
1. Developer hereby requests that Power Supply initiate the process for
Delivery to conduct a SIS for determining the cost of the QF's becoming a DNR for the
Company. Developer agrees to pay all charges associated with any analyses that
Delivery determines are reasonably necessary to evaluate the impact of the QF on
Developer's reasonable requests for information regarding an estimated completion
date for the SIS and, if necessary, with an explanation of why additional time is required
to complete the SIS.
NETWORK RESOURCE INTEGRATION STUDY AGREEMENT-2
4. Following completion of the SIS, a copy of the completed SIS shall be
provided to Developer. Power Supply and Developer shall then reconcile the payments
made for the SIS and "true-up" any over or under payments made by Developer. The
total charge to Developer for the SIS will not exceed the actual cost of the SIS as billed
by Delivery to Power Supply.
NETWORK RESOURCE INTEGRATION STUDY AGREEMENT-3
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 10
I '
March 3, 2010
The New Energy Company LLC
Attn: Laura Knothe
8720 Vic Lane
Middleton ID 83644
E-mail Copy: [e-mail]
RE: Letter of Understanding
An IDA.CORP Company
Randy C. Allphin
Sr. Energy Contract Coordinator
Tel: [phone]
[e-mail]
Double B Dairy-Proposed Anaerobic Digester Project
Ms. Knothe,
Summarized below is a brief outline of the purchase power agreement, interconnection process
and transmission capacity requirements for your proposed generation project.
Purchase Power Agreement
The project you have described appears to be eligible for a purchase power agreement under the
guidelines for a Qualifying Facility as defined by the Public Utilities Regulatory Policies Act of 1978
(PURP A). At the time you are ready to proceed with a purchase power agreement for this project,
Idaho Power will prepare a purchase power agreement that complies with the current rules and
regulations that govern these PURP A agreements, any draft purchase power agreements previously
provided to you for review must be updated to include current rules and regulations.
Prior to Idaho Power executing a purchase power agreement it will be required that you have:
1.) Provided documentation that substantiates that the project has filed for interconnection
and is in compliance with any payments and/or other requirements specified in the
Interconnection process for this project and;
Page I of4
P 0 Box 70 Boise, Idaho 83707 1221 W Idaho St. Boise, Idaho 83702
2.) Received and accepted an interconnection feasibility study for this project and;
3.) Returned a signed copy of this letter of understanding and all of the required
information to enable Idaho Power to file an application requesting transmission
capacity for this project. Completion of the enclosed Transmission Capacity
Application Questionnaire will provide the majority of this information and;
4.) Confirmation that the results of the initial transmission capacity application are known
and the project accepts these results and intends to continue with the development of
the project including, if applicable, execution of a Network Resource Integration
Study Agreement in the form enclosed herein.
Interconnection and Transmission Capacity
Your project will be responsible for all costs of physically interconnecting the project to the
Idaho Power electrical system and any costs associated with acquiring adequate finn transmission
capacity on the Idaho Power transmission system to enable the project's energy to be delivered to
Idaho Power customers.
Interconnection
Your project will be required to complete the interconnection process and execute a
Generation Interconnection Agreement ("GIA'').
Transmission Capacity
To sell your project's energy to Idaho Power, your project must be designated as a
Network Resource ("DNR").
In orde1· for this project to achieve DNR status, Idaho Power is required to make a
request (complete and file an application) and he granted fir.-m. transmission capacity
from the ldaho Power delivery business unit ("Delivery'') to move your project's energy
from the physical interconnection point to Idaho Power customers. In accordance with
valious rules and regulations, the project must be granted DNR status no later than
60 days prior to the project delivering any energy to Idaho Power.
Idaho Power will begin this firm transmission capacity application process only after
the project has returned a signed copy of this letter of understanding and all of the
infonnation required for Idaho Power to :file this application (see attached Transmission
Capacity Application Questionnaire).
After filing a complete fum transmission capacity application with Delivery, Idaho
Power will receive notification back from Delivery within 30 days that: (a) adequate
transmission capacity is available for this project without the need to construct upgrades;
or (b) a transmission capacity system impact study is required to detennine the available
transmission capacity and/or required upgrades; or (c) a statement of the required
transmission upgrades and the associated costs. Idaho Power will notify the project of
this response to the transmission capacity application in a timely manner after the
response is received from Delivery.
Page2 of4
P 0 Box 70 Boise, Idaho 83707 1221 W Idaho St. Boise, Idaho 83702
If the response from Delivery is as specified in item (a) (transmission capacity is
available), the project will be required to execute a purchase power agreement with
Idaho Power within 30 days in order to retain this transmission capacity reservation.
If the response from Delivery is as specified in items (b) or (c) (studies required
and/or upgrades required), the project will be required to execute a Network Resource
Integration Study Agreement (sample copy attached for your information) and submit all
required deposits or fees within 15 days after receiving notification of this requirement
in order for Idaho Power to continue the transmission capacity request. This Network
Resource hltegration Study Agreement will specify that the project will be responsible
for costs incurred by Idaho Power to perform any required studies. If, after the studies
are concluded the project wishes to continue the pursuit of transmission capacity, the
project will also be responsible for all transmission system upgrade costs identified
within the studies. The fees and costs will be in the form of both initial deposits as well
as actual costs. If at any time after executing the Network Resource Integration Study
Agreement the project does not pay any required fees, or elects to stop the transmission
study or upgrade process, the project shall be responsible for all costs incurred by Idaho
Power in performing the studies or upgrades up to the point of termination of the
Network Resource hltegration Study Agreement.
Upon successful completion of the above described transmission capacity upgrade
process, a transmission capacity reservation will exist for this project. However, in
order to finalize this transmission capacity reservation, a purchase power agreement
with Idaho Power must be executed no later than 30 days after the transmission capacity
upgrades are completed. If the purchase power agreement is not executed by this
deadline, the transmission capacity reservation will be released and this process will
have to be repeated if the project later requests transmission capacity.
As noted earlier, this transmission capacity acquisition and associated Network
Resource designation must be completed, at the minimum, 60 days prior to the project
delivering any energy to Idaho Power. hl addition, the project must provide routine
updates to Idaho Power of the expected online date of the generation project to ensure
Idaho Power is capable of accepting the energy from the project on the actual date the
project comes online.
Page 3 of4
P 0 Box 70 Boise, Idaho 83707 122'1 W Idaho St. Boise, Idaho 83702
Please return all required information to:
Idaho Power Company
Attn: Randy C. Allphin
POBox 70
Boise, ID 83707
E-mail: [e-mail]
Sincerely,
Randy C Allphin
Idaho Power Company
Understood and accepted this __J_ day of t\p r: \ , 2010
Signature ~ ~~d s .>
Print Name \~0-LL.'r-C:t. k n t5..\-~ } fJ f:-
Title
Page 4 of4
P 0 Box 70 Boise, ldaho 83707 1221 W Idaho St. Boise, Idaho 83702
·'
M IDACXJRP company
Transmission Capacity Application Questionnaire
This list is the known information requirements as of the date of the letter transmitting this request. If additional information
Is required, Idaho Power will promptly notify the project developer of the additional information requirements.
A. Project Name
D av..ble.. B Da.tt:J D~~ster-
B. Project Location
L2.5D \;/ liOD S
C. Project Developer
Name
Address
City I State I Zip
Phone Number
E-mail
D. Idaho Power Delivery Business unit Interconnection "Que" reference number (if not known,
please contact the Idaho Power Interconnection group)
5 0'6
E. Evidence of the Project's good standing status in the Idaho Power Interconnection Process
'~~:f'~j~~tt&~iffuu 1.~ Stud~
F. Copy of the Idaho Power Interconnection feasibility study and a statement from the project that
the project has accepted the results of the interconnection feasibility study and is continuing
the process of interconnecting and developing the generation project.
G. Maximum Capacity (MW) -'--1..__2......._. __ _
Page I of3
H. Beginning day and time of energy deliveries
Day (mm/dd/yyyy) 9) I I I a 0 I I
Time <3 ~ 0 0 (1_, o'\
I. Ending day and time of energy deliveries
Day (mm/dd/yyyy) £ I \ I d 03 (o
Time 5~ 0 0 1l M ·
J. VAR capability (both leading and lagging) of all generators , q2 !eacL\g 1 , g I c;s~i'tJ
K. Identification of the control area(s) from which the energy will originate
Po-..utr p \ a.M± toti h Q. ~nb' c ~ sAev
L. List any periods of restricted operations throughout the year
1Jt=rkL a n:h<"' l ~ d
M. Maintenance schedule
N. Minimum loading level of each generation unit ________ ___,(._c:D~O_.h"""O"'-----
0. Normal operating level of each generation unit. _ _,_ ______ __._/ _,_D0~0_.i ...... a.___ __ _
P. Any must-run generation unit designations required for system reliability or contractual reason
sg:;~_r~~::~' ~~~= =~~~=~%:t=i~.&~c~f~ C£~iP\
W~s-k ~ +1-,e dcu'Y~ o.."'d vv..usl-~ ~~,_-<TYJaJ cc\ a_l\
-hvY"leS"
Page 2 of3
Q. Approximate variable generation cost ($/MWh) Note -this will be estimated energy pricing from a potential
purchase power agreement that this project may be eligible for.
11o.f O~YJ.'~,-~R d vc;u-~ cLb/e... 8 Qt)e v"a..-b @
R. If the generation resource is to be located in the Idaho Power Balancing Authority Area and if
only a portion of the resource output is to be designated as a Network Resource, then explain
arrangements governing sale and delivery of additional output to third parties.
S. If the project is not directly interconnected to the Idaho Power transmission system, provide
the transmission provider(s) name, Point of Receipt, Point of Delivery and the transmission
reservation number for all of the transmission providers required to deliver the project's energy
to Idaho Power.
Transmission Provider(s) Name ------J.JV.1..LA4---------------------
PointofRecelpt _____________________________ _
Point of Delivery _____________________________ _
Transmission Reservation Number(s) ------------------------
T. If the project is directly interconnected to the Idaho Power transmission system, provide the
Point of Receipt, physical location and voltage.
Point of Recelpl'--_.._.,~-----------------,--------...,....----
Physlcal Location I'd. '50 W \I 0 0 S M..u...v-fa_ tt.&-:tQ J' 'b~?t( '-(
Voltage /d., • '5 l. V
U. Is the project committed to execute a purchase power agreement with Idaho Power upon a
favorab)-resolution of the identified Interconnection and transmission costs?
Yes m/ No 0
V. Is any portion of the maximum capacity identified for this project committed to any other party?
YesD No~
Signature ~~~~~~=-====---'Date -~--'-'--~)-+1-=-;)_0....:.....\ 0 ___ _
Page 3 of3
NETWORK RESOURCE INTEGRATION STUDY AGREEMENT
THIS Agreement is made and entered into this __ day of ____ 20_
between Idaho Power Company ("Idaho Power" or "Company") through its Power
Supply business unit ("Power Supply"} and
to the Company's load centers. The Federal Energy Regulatory Commission's rules
require that Power Supply make the request to Delivery to perform the SIS. Delivery
will bill Power Supply for the costs incurred to perform the SIS.
NETWORK RESOURCE INTEGRATION STUDY AGREEMENT-1
..
AGREEMENTS:
1. Developer hereby requests that Power Supply initiate the process for
Delivery to conduct a SIS for determining the cost of the OF's becoming a DNR for the
Company. Developer agrees to pay all charges associated with any analyses that
Developer's reasonable requests for information regarding an estimated completion
date for the SIS and, if necessary, with an explanation of why additional time is required
to complete the SIS.
NETWORK RESOURCE INTEGRATION STUDY AGREEMENT-2
. '
4. Following completion of the SIS, a copy of the completed SIS shall be
provided to Developer. Power Supply and Developer shall then reconcile the payments
made for the SIS and "true-up" any over or under payments made by Developer. The
total charge to Developer for the SIS will not exceed the actual cost of the SIS as billed
by Delivery to Power Supply.
NETWORK RESOURCE INTEGRATION STUDY AGREEMENT - 3
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 11
The New Energy Company, LLC
April 2, 2010
Rowena Bishop
Idaho Power Company
1221 W Idaho Street
Boise ID 83702
Re: Facility Study Agreements for Projects 307 and 308 and Interconnec­
tion Application for additional capacity for Project 309
Dear Ms. Bishop:
Please find enclosed the following applications and applicable deposits:
Facility Study Agreement and deposit in the amount of
$11,740 for Project 307, Swager Dairy Digester
Facility Study Agreement and deposit in the amount of
$11,250 for Project 308, Double B Dairy Digester
Interconnection Application and deposit in the amount of
$1000 for additional capacity of 1.6 MW (for a total of 4.0
MW) for Project 309, Rock Creek Dairy Digester.
Please contact me at 208.890.8783 if additional information is required.
Thank you,
Laura Knothe, PE
The New Energy Company, LLC
ano Vic Lane
Middleton, ID 8366
Phone: [phone]
Fax: [phone]
E-mail:
[e-mail]
Facilities Study Agreement
TillS AGREEMENT is made and entered into this 2"d day of April2010 by and between The
New Energy Company, a Limited Liability Company organized and existing under the laws of
the State of Idaho, ("Interconnection Customer,") and Idaho Power Company, a Corporation
existing under the laws of the State of Idaho ("Transmission Provider"). Interconnection
Customer and Transmission Provider each may be referred to as a "Party," or collectively as the
"Parties."
RECITALS
WHEREAS, the Interconnection Customer is proposing to develop a Small Generating Facility
or generating capacity addition to an existing Small Generating Facility consistent with the
Interconnection Request completed by the Interconnection Customer on October 12. 2009, and
WHEREAS, the Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Provider's Transmission System;
WHEREAS, the Transmission Provider has completed a system impact study and provided the
results of said study to the Interconnection Customer; and
WHEREAS, the Interconnection Customer has requested the Transmission Provider to perform
a facilities study to specify and estimate the cost of the equipment, engineering, procurement and
construction work needed to implement the conclusions of the system impact study in
accordance with Good Utility Practice to physically and electrically connect the Small
Generating Facility with the Transmission Provider's Transmission System.
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1. 0 When used in this Agreement, with initial capitalization, the terms specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause a
facilities study consistent with the standard Small Generator Interconnection Procedures
to be performed in accordance with the Open Access Transmission Tariff.
3.0 The scope of the facilities study shall be subject to data provided in Attachment A to this
Agreement.
4.0 The facilities study shall specify and estimate the cost of the equipment, engineering,
procurement and construction work (including overheads) needed to implement the
conclusions of the system impact study(s). 1
The facilities study shall also identify (1) the electrical switching configuration of the
equipment, including, without limitation, transformer, switchgear, meters, and other
station equipment, (2) the nature and estimated cost of the Transmission Provider's
D o~l-e. B -3 o'B
Interconnection Facilities and Upgrades necessary to accomplish the interconnection, and
(3) an estimate of the time required to complete the construction and installation of such
facilities.
5.0 The Transmission Provider may propose to group facilities required for more than one
Interconnection Customer in order to minimize facilities costs through economies of
scale, but any Interconnection Customer may require the installation of facilities required
for its own Small Generating Facility if it is willing to pay the costs of those facilities.
6.0 A deposit of $11,250.00 is due upon execution of this agreement by the Interconnection
customer.
7.0 In cases where Upgrades are required, the facilities study must be completed within 45
Business Days of the receipt of this Agreement. In cases where no Upgrades are
necessary, and the required facilities are limited to Interconnection Facilities, the
facilities study must he completed within 30 Business Days.
8.0 Once the facilities study is completed, a facilities study report shall be prepared and
transmitted to the Interconnection Customer. Barring unusual circumstances, the
facilities study must be completed and the facilities study report transmitted within 30
Business Days of the Interconnection Customer's agreement to conduct a facilities study.
9.0 Any study fees shall be based on the Ttansmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
10.0 The Interconnection Customer must pay any study costs that exceed the deposit without
interest within 30 calendar days on receipt of the invoice or resolution of any dispute. If
the deposit exceeds the invoiced fees, the Transmission Provider shall refund such excess
within 30 calendar days of the invoice without interest
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written.
Transmission Provider:
Idaho Power Company -Delivery
Signed: z;Jd.i' 4Jl
Printed Name: 6"Dt-vPJ-~~ L <as 'i[Nr&_
Title: PAA 'S4P6'Jt..v fr><:ll(,
4/rr..!/r o
Interconnection Customer:
Signed:~
Printed Name: Lo.....c...~k.M+t-.e. ) Pb-
'.
Attachment A to
Facilities Study Agreement
Data to Be Provided by the Interconnection Customer
With the Facilities Study Agreement
1. Provide location plan and simplified one-line diagram of the plant and station facilities.
For staged projects, please indicate future generation, transmission circuits, etc.
On the one-line diagram, indicate the generation capacity attached at each metering
location. (Maximum load on CT/PT)
On the one-line diagram, indicate the location of auxiliary power. (Minimum load on
CT/PT) Amps
2. One set of metering is required for each generation connection to the new ring bus or
existing Transmission Provider station. Number of generation connections:
1 connection
3. Will an alternate source of auxiliary power be available during CT/PT maintenance?
Yes No NIA
4. Will a transfer bus on the generation side of the metering require that each meter set be
designed for the total plant generation? Yes No _x_
(Please indicate on the one-line diagram).
5. What type of control system or PLC will be located at the Small Generating Facility?
Automation Direct
6. What protocol does the control system or PLC use?
Modbus or other if required
7. Please provide a 7.5-minute quadrangle map of the site. Indicate the plant, station,
transmission line, and property lines.
8. Physical dimensions of the proposed interconnection station:
NE Comer of 1250 Wand 1100 S with approximate coordinates: 42° 47'3" N,
114° 38'39" w
9. Bus length from generation to interconnection station:
__ TBD -less than 250' anticipated, ____________________ _
10. Line length from interconnection station to Transmission Provider's Transmission
System.
___ TBD. __________________________________________________ _
11. Tower number observed in the field. (Painted on tower leg)*:
___________ TBD ______________ ~-------------------------------
12. Number of third party easements required for transmission lines*:
_____ None anticipated. ____________________ _
* To be completed in coordination with Transmission Provider.
13. Is the Small Generating Facility located in Transmission Provider's service area?
Yes x No ___ If No, please provide name oflocal provider:
14. Please provide the following proposed schedule dates:
Begin Construction Date: October l, 2010
Generator Step-Up Transformers Date: March 15. 2011
Receive Back Feed Power
Generation Testing Date: April15, 2011
Commercial Operation Date: July 15, 2011
Legend * POl
Project #308 Double B Dairy
• Buckhorn
-69kV
-BKHr-.142
-BKHN41
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 12
May 7, 2010
The New Energy Company LLC
Attn: Laura Knothe
8720 Vic Lane
Middleton, ID 83644
Original and Attachments: Scheduled for Pick up at Idaho Power on May 7, 2010
Cover letter E-mail copy:
Laure Knothe
Dean J. (Joe) Miller
laura@thenewenergycompany .com
joe.mcdevitt-miller.com
Re: Double B Dairy, Project #21615150
Ms. Knothe,
®
An IDACORP Company
As you are aware on March 16, 2010, the Idaho Public Utilities Commission (IPUC) issued Order
31025 which revised the Published Avoided Cost rates. These rates are the energy prices Idaho
Power is required to include in PURP A purchase power agreements for projects less than I 0
average MW. This Order was very specific in stating that any contracts executed after March 16,
2010, must have the new energy pricing.
However, in regards to the Double B Dairy Digester project, our records indicate that prior to
March 16, 2010:
a.) The interconnection feasibility study had been completed and the project was continuing to
progress through the interconnection process.
b.) Information from the project required to complete and file the transmission capacity
application had been provided. Subsequently the transmission applications were filed and
Idaho Power received confirmation that contingent upon execution of both a Generation
Interconnection Agreement (GIA) and purchase power agreement, transmission capacity is
available for this project.
c.) A PURP A purchase power agreement was materially complete and except for routine final
processing, an agreement would have been executed prior to March 16, 2010.
P.O. Box 70 (83707)
1n1 W lri~hn ~t
At this time Idaho Power is willing to execute the attached PURP A purchase power agreement that
contains the energy prices that were in effect prior to IPUC order 31025 issued on March 16, 2010
contingent upon the project returning fully executed agreements to Idaho Power prior to 5 PM
Mountain time, on May 24, 2010.
Upon receipt from you of the three signed copies of the PURP A purchase power agreement
enclosed with this letter by the above due date, I will arrange for and present the agreement to
Idaho Power Company management for their signature. I will return to you one fully executed
copy for your records, and Idaho Power will prepare and file a copy with the Idaho Public Utilities
Commission (IPUC) requesting approval of the agreement. Idaho Power will keep the third copy
for our records.
If all three copies of the PURP A purchase power agreement are not executed and received by Idaho
Power by the time and date specified above, this specific agreement (which includes the pre March
16, 2010 PURPA energy prices) will no longer be available for this project. Idaho Power will
update any future proposed PURP A agreements for this project to be in accordance with all current
and applicable rules, regulations and energy pricing.
Please use one of the following addresses to return the executed agreements to Idaho Power:
US Mail:
Idaho Power Company
Attn: Randy Allphin
POBox70
Boise, ID 83707
Overnight Mailing Address:
Idaho Power Company
Attn: Randy Allphin
1221 Widaho
Boise, ID 83702
This agreement as with all PURP A purchase power agreement will require Idaho Public Utilities
Commission (IPUC) approval. Only after both parties have executed this agreement and the !PUC
has approved the agreement, as specified within the agreement, shall the agreement be considered
to be effective and a binding commitment shall exist between the parties.
If you have any questions please do not hesitate to contact me.
Sincerely,
J1e~·
Randy c. Allphin
Senior Energy Contract Coordinator
(208) 388~2614
E-mail: [e-mail]
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 13
Laura Knothe
The New Energy Company
8720 Vic Lane
Middleton, ID 83644
Re: Double B Dairy Digester Project Facility Study Report -Project #308
Dear Ms. Knothe:
An IDACORP Company
Idaho Power Company (IPC) has completed the Facility Study"'cost estiin<Ue for your Generator
Interconnection project. Attached please fmd a Draft Facility Study Report (FSR ). I am
available to discuss the FSR, and begin Con truction an·angements for the project.
In order to proceed with this project, please pro vide yOl,If cpmments to the FacilitY,. Study Report
to me by September 17, 2010 and indicate whether you w.isb to proceed with final design and
construction. The fmal report will be use<;i to prepare a draft Generator Interconnection
Agreement in preparation for Construction. Rowena Bishop will be working with you to finalize
the Interconnection Agreement.
Before we can begin Construction or order material you ar responsible for contacting Idaho
Power's credit department-to d.ise;u s credit requirement for con truction funding. Please
contact Kelley Noe (208-388-5736) at your earlie t convenience. Once we receive funding, or
the credit requirement is met we can proceed with construction of the project.
The actual construction and labor charges wi U be fi nalized approximately 90 days subsequent to
project completion. We will rec0ncile any over-or underpayment at that time.
I look forward to hearing from you soon.
Sincerely,
Eric Hackett
Project Leader
Attachment: Double B Dairy Digester Project Draft Facility Study Report with Drawings
Cc: R Bishop/IPC
KNoe/IPC
A Sloan!IPC
DRAFT
Generator Interconnection
Facility Study Report
for the
Double B Dairy Digester Project-Project #308
for
The New· j nergy Group
Twin Falls County Idaho
August 17,2010
An IDACORP Company
DRAFT-FACILITY STUDY REPORT (FSR)
Double B Dairy Digester
Project #308
August 17, 2010
1. General Facility Description
The proposed project will consist of Idaho Power's standard ove:r~~ad generation interconnection
package including an overhead recloser, metering package, local. service power transformer,
disconnect switches, and a relay/control box. Additionally, one 1500J~YA 277/480 to 12.47 kV
Grounded Wye I Grounded Wye padmounted transforJl1er. ~ill be instalied;·:including the associated
underground cabling and vaults. The project is located i~ Cassia County, Id~hQ ,and connects to the
12.5 kV system on Idaho Power Company's Buckhorn (BKHN-041) distributio111ine. The total
project output is 1.2 MW. -., · -· ·
Interconnection Customer:
Laura Knothe
The New Energy Company
8720 Vic Lane
Middleton, ID 83644
A Standard Generator In:terconnection Agreement under Idaho Power Company's Open Access
Transmission Tariff (O:A.TT) or SChedule 72 between Interconnection Customer and Idaho Power
Company -Delivery (Tran.smissi_:Q Owner) for the Double B Dairy Digester Project, specifically
Generator Interconnection Project' #-308, ~ill be prepared for this project. Final drawings will be
produced in the tiro,eline shown below in Nlll.ESTONES.
2. lnten~onnection· Point
The 1nterconnection Po.int for the Double B Dairy Digester Project will be the low-side bushings on
the padmounted transformer (DBl). The project's location is in T12S R21E Section 18 of Cassia
County, Idaho. A d.J·awing identifying the Point of Interconnection is attached.
3. Point of Change of Ownership
The Point of Change M Ownership for the Double B Dairy Digester Project will be the low-side
bushings on the padmounted transformer (DBl).
4. Interconnection Details
In general, interconnection equipment includes, but is not limited to, switching/disconnection,
metering, system protection and control, and communications/telemetry. All interconnection
equipment electrically located on the generator side of the Point of Change Ownership shall be
owned and maintained by the Generator. All interconnection equipment electrically located on the
utility side of the Point of Change Ownership shall be owned, operated, and maintained by Idaho
Power.
1
4.1 Project Team
An Idaho Power Company project team was assembled to investigate the proposed project,
and develop cost estimates and a project schedule to construct Idaho Power facilities required
for the interconnection. The project team consisted of the following employees:
Engineer --"P_r_:_ot_e_c_ti....:.o.::::n:__ ______ _
Area A aratus Leader
Stations Desig_n_er ________ _
4.2 Customer's Interconnection Facilities
The Interconnection Customer wjlJ install ge~ra rs, low-sid tl connect switches, all
wiring and conduit between the generators ,and the padmounted tran former, appropriate
grounding measmes, and associated auxiliary equipment. Interconnecri n Qustorner will
build underground facilities to the Point of Change of O~rship for the generator facility.
The low-side disconnect witch b uJd be visible, lockable, within ten (10) feet of the
padmounted transformer , and actessjble to Idaho Power 'personnel
4.3 Other Facilities Provided by Interconnection Customer
4.3. 1 Telecommunications
The In~e.rconnectiOJl Cu tomer wiU provide two communication circuits between the
generation· interconnoction site and a location, or locations, specified by Idaho Power.
One of the circuit& will be a dedicated 4-wire leased analog circuit connected to the
SEL 311C relay ana the other will be a POTS cfjaJ-up circuit to the revenue meter.
IJbe Interconnection Customer is respon ible for supplying and coordinating the
.installation of the phone unes and paying the monthly service charges. The
communication circuit will need to be installed and operational prior to generating
jnto the Idaho Power sy tern.
4.3.2 Ground Fauft Equipment
The customer will install ground fault limiting equipment that will limit the zero
sequericeJault current to 20 amps at the Interconnection Point.
4.3.3 Monitoring Information
If the Interconnection Customer requires the ability to monitor information related to
the Idaho Power recloser in the generation interconnection package they are required
to supply their own communications circuit to the control box.
4.3.4 Easements
The Interconnection Customer will secure underground and overhead easements with
Double B Dairy once a specific route is determined. Idaho Power will provide the
documentation.
2
4.4 Idaho Power Company's Interconnection Facilities
Idaho Power will install a standard generation interconnection package on the ex1stmg
distribution feeder (BKHN-041) on private property northwest of the intersection of 1200
South and 1100 West in Cassia County, ID. See the attached work order maps (WO
27328097, sheet 1 of 1) for details.
The new interconnection package will include four distribution poles to mount a local service
transformer, solid blade disconnects, primary metering package, recloser, relays, fuses and
riser necessary for the package. The interconnection will be cpntrolled by a SEL-311C line
protection relay. The relay will be located in a pole mounted enclosure and will also contain
a test switch (TS4), SLSS, modems, isolation interface, pow¢r supply, DC converter, control
switch and surge protector.
Idaho Power will install (and subsequently own,. ~nd fuaintain) 'bne 1500 kVA 277/480 to
12.47 kV Grounded Wye I Grounded Wye -padmounted transfottner on top of a vault.
Conduit and underground cables will be installed from the interconri~t!Qn package to
padmounted transformer. Protective posts will.be instilled to protect th~ ground mounted
equipment from damage. · · ··
A 2" conduit will be installed along_side the underground primary to facilitate information
exchange to the customer about the .ceclO$er. (The Interconnecti n Customer is responsible
for providing and installing the appmpriate"Gable.)
4.5 Operational Limitations
Interconnectio.n ,Customer will be able to niOdify power plant facilities on the generator side
of the Interconnection Point with no impact upon the operation of the transmission system
whenever the generation facilities are electrically isolated from the transmission system.
The pmject rnus~ be controlled to operate at unity power factor. Voltage flicker at startup
and during operation will be limited to less than 5% as measured at the point of
interconnection. For this to occur, the current cannot exceed 65 Amps during start up at the
f2.5 kV voltage level. This forces the generating facility to start the generators separately.
The project is required to comply with the applicable Voltage and Current Distortion Limits
found in IEEE Standard 519-1992 IEEE Recommended Practices and Requirements for
Harmonic Control in Electrical Power Systems.
3
5. Budget
The following good faith estimates are provided in 2010 dollars:
Estimated Cost & Ownership:
------t-----
Provided b¥_ the customer (Including low-side disconnect swit~h) ---+---­
TOTAL
nterconnection Facilities:
Overhead Generation Interconnection Packa e $200,000
Underground E9uipment and 1590 kVA Tran_s_fo_r_m_e_r ------r-----::------:---+--------'-$4_5....:.,_00--;0
___________ T_OT~~--~-----------­
I--------------------------G-RA_N_D~TO~
9117110
10/5110
11/20110
1/15111
2/15/11 1----
3/t/J L 1----.....
3/10/11
Construction Budget Timeline:
GRAND TOTAL
4
$245,000
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BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 14
Spokane,WA
509-535-1744
Western States Equipment Company
500 East Overland Road
Meridian, ID 83642
208-888·2287 (office)
208-884-2308 (fax)
LETTER OF GUARANTEE
Reference: Double B Dairy
Subject: Financial guarantee for the payment of Liquidated Damages payable under the Firm
Energy Sales Agreement for Double B Dairy, Project Number 31616120.
We, the undersigned, Western States Equipment Company, an Idaho corporation ("Guarantor") hereby
declare that we irrevocably and unconditionally guarantee as primary guarantor on behalf of New Energy
Three, LLC ("Customer") with its place of business at 8720 Vic Lane, Middleton 10, the full and prompt
payment when due of the payment obligations of Customer to Idaho Power Company ("Idaho Power") in the
amount of eighty-one thousand dollars ($81,000.00). This Guarantee is provided to cover Customer's
payment obligations to Idaho Power under paragraph 5.3 and 5.4 of the Firm Energy Sales Agreement for
the Double B Dairy, Project Number 31616120 (hereafter referred to as "the Agreement").
Payment shall be made by Guarantor to Idaho Power hereunder when demand for such payment is made
by Idaho Power upon the failure of Customer to meet its obligations under paragraph 5.8 of the Agreement
regarding the failure to meet the scheduled operation date as defined in Appendix "8". Payment shall be
unconditional and absolute and without objection or legal proceedings and, without limiting the generality of
the foregoing, shall not be released, discharged or otherwise affected by any modification, amendment,
waiver, extension of or supplement to the Agreement, any change in the corporate existence of the
Customer or Guarantor, or any insolvency, bankruptcy, reorganization or other similar proceedings affecting
the Customer or its assets, or the Guarantor .. This Guarantee is a guarantee of payment and not merely of
collection and Guarantor agrees that its obligations hereunder are of a primary obligor and not merely of a
surety. The Guarantor agrees that Idaho Power may resort to the Guarantor for payment of the obligation
whether or not Idaho Power has resorted to any collateral security, or shall have proceeded against
Customer or any other obligor principally or secondarily obligated with respect to the obligation. All
payments hereunder by Guarantor shall be mad1~ without set-off or counterclaim in U.S. dollars in
immediately available funds.
This Guarantee shall remain in force until New Energy has, to the satisfaction of Idaho Power, under the
terms of paragraph 5.2 of the Agreement, achieved the Operation Date or until Guarantor is released from
this Guarantee pursuant to paragraph 5.8.2 of the Agreement
Meridian,ID
208-888-2287
Pasco,WA
509-547-9541
Twin Falls.ID
208-734-7330
Pendleton, OR
541·276-5812
Pocatello,ID
208-232.2640
LaGrande, OR
541-963-3101
Idaho Falls, ID
208-552-2287
Missoula, MT
40&-721-4050
lewiston,ID
208-746-3301
Kalispeii,MT
406-752-3030
This Guarantee is governed by the law applicable to the Agreement The courts having jurisdiction for
matters relating to the Agreement shall have jurisdiction in respect of matters relating to this guarantee.
This Guarantee may not be amended, supplemented or modified, nor any of the terms and conditions
hereof waived, except by a written instrument executed by the Guarantor and Idaho Power.
This Guarantee is effective as of the date executed below.
Done at Meridian, ID on August 30, 2010
Tom Harris
President
Western States Equipment Company
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 15
September 16, 2010
Laura Knothe
The New Energy Company
8720 Vic Lane
Middleton, ID 83644
Re: Double B Dairy Digester Project Final Facility Study Report -Project #308
Dear Ms. Knothe:
An IDACORP Company
Idaho Power Company (IPC) has completed the Facility Study cost estimate for your Generator
Interconnection project. Attached please find a Final Facility Study Report (FSR). I am
available to discuss the FSR, and begin Construction arrangements for the project.
This report will be used to prepare a draft Generator Interconnection Agreement in preparation
for Construction. Rowena Bishop will be working with you to finalize the Interconnection
Agreement.
Before we can begin Construction or order materials, you are responsible for contacting Idaho
Power's credit department to discuss credit requirements for construction funding. Please
contact Kelley Noe (208-388-5736) at your earliest convenience. Once we receive funding, or
the credit requirement is met, we can proceed with construction of the project.
The actual construction and labor charges will be finalized approximately 90 days subsequent to
project completion. We will reconcile any over-or underpayment at that time.
I look forward to hearing from you soon.
Sincerely,
Eric Hackett
Project Leader
Attachment: Double B Dairy Digester Project Final Facility Study Report with Drawings
Cc: R Bishop!IPC
KNoe/IPC
A Sloan/IPC
FINAL
Generator Interconnection
Facility Study Report
for the
Double B Dairy Digester Project-Project #308
for
The New Energy Group
in
Twin Falls County, Idaho
September 16,2010
FINAL -FACILITY STUDY REPORT (FSR)
Double B Dairy Digester
Project #308
September 16,2010
1. General Facility Description
The proposed project will consist of Idaho Power's standard overhead generation interconnection
package including an overhead recloser, metering package, local service power transformer,
disconnect switches, and a relay/control box. Additionally, one 1500 kVA 277/480 to 12.47 kV
Grounded Wye I Grounded Wye padmounted transformer will be installed, including the associated
underground cabling and vaults. The project is located in Cassia County, Idaho and connects to the
12.5 kV system on Idaho Power Company's Buckhorn (BKHN-041) distribution line. The total
project output is 1.2 MW.
Interconnection Customer:
Laura Knothe
The New Energy Company
8720 Vic Lane
Middleton, ID 83644
A Standard Generator Interconnection Agreement under Idaho Power Company's Open Access
Transmission Tariff (OATT) or Schedule 72 between Interconnection Customer and Idaho Power
Company -Delivery (Transmission Owner) for the Double B Dairy Digester Project, specifically
Generator Interconnection Project #308, will be prepared for this project. Final drawings will be
produced in the timeline shown below in MILESTONES.
2. Interconnection Point
The Interconnection Point for the Double B Dairy Digester Project will be the low-side bushings on
the padmounted transformer (DB1). The project's location is in T12S R21E Section 18 of Cassia
County, Idaho. A drawing identifying the Point of Interconnection is attached.
3. Point of Change of Ownership
The Point of Change of Ownership for the Double B Dairy Digester Project will be the low-side
bushings on the padmounted transformer (DB 1 ).
4. Interconnection Details
In general, interconnection equipment includes, but is not limited to, switching/disconnection,
metering, system protection and control, and communications/telemetry. All interconnection
equipment electrically located on the generator side of the Point of Change Ownership shall be
owned and maintained by the Generator. All interconnection equipment electrically located on the
utility side of the Point of Change Ownership shall be owned, operated, and maintained by Idaho
Power.
1
4.1 Project Team
An Idaho Power Company project team was assembled to investigate the proposed project,
and develop cost estimates and a project schedule to construct Idaho Power facilities required
for the interconnection. The project team consisted of the following employees:
--I Senior Engineer -I Project Manager
Princ!_pal Engineer " l Relay & Communications Leader
Engineer-Protection l Metering Technical Advisor
Area A Raratus Leader Right ofWay Agent
Desigt'! Engineer Distribution Line Designer
Stations Designer
4.2 Customer's Interconnection Facilities
The Interconnection Customer will install generators, low-side disconnect switches, all
wiring and conduit between the generators and the padmounted transformer, appropriate
grounding measures, and associated auxiliary equipment. Interconnection Customer will
build underground facilities to the Point of Change of Ownership for the generator facility.
The low-side disconnect switch should be visible, lockable, within ten (1 0) feet of the
padmounted transformers, and accessible to Idaho Power personnel.
4.3 Other Facilities Provided by Interconnection Customer
4.3.1 Telecommunications
The Interconnection Customer will provide two communication circuits between the
generation interconnection site and a location, or locations, specified by Idaho Power.
One of the circuits will be a dedicated 4-wire leased analog circuit connected to the
SEL 311 C relay and the other will be a POTS dial-up circuit to the revenue meter.
The Interconnection Customer is responsible for supplying and coordinating the
installation of the phone lines and paying the monthly service charges. The
communication circuits will need to be installed and operational prior to generating
into the Idaho Power system.
4.3.2 Ground Fault Equipment
The customer will install ground fault limiting equipment that will limit the zero
sequence fault current to 20 amps at the Interconnection Point.
4.3.3 Monitoring Information
If the Interconnection Customer requires the ability to monitor information related to
the Idaho Power recloser in the generation interconnection package they are required
to supply their own communications circuit to the control box.
4.3.4 Easements
The Interconnection Customer will secure underground and overhead easements with
Double B Dairy once a specific route is determined. Idaho Power will provide the
documentation.
2
4.4 Idaho Power Company's Interconnection Facilities
Idaho Power will install a standard generation interconnection package on the existing
distribution feeder (BKHN-041) on private property northwest of the intersection of 1200
South and 1100 West in Cassia County, ID. See the attached work order maps (WO
27328097, sheet 1 of 1) for details.
The new interconnection package will include four distribution poles to mount a local service
transformer, solid blade disconnects, primary metering package, recloser, relays, fuses and
riser necessary for the package. The interconnection will be controlled by a SEL-311C line
protection relay. The relay will be located in a pole mounted enclosure and will also contain
a test switch (TS4), SLSS, modems, isolation interface, power supply, DC converter, control
switch and surge protector.
Idaho Power will install (and subsequently own and maintain) one 1500 kVA 277/480 to
12.47 kV Grounded Wye I Grounded Wye padmounted transformer on top of a vault.
Conduit and underground cables will be installed from the interconnection package to
padmounted transformer. Protective posts will be installed to protect the ground mounted
equipment from damage.
A 2" conduit will be installed alongside the underground primary to facilitate information
exchange to the customer about the recloser. (The Interconnection Customer is responsible
for providing and installing the appropriate cable.)
4.5 Operational Limitations
Interconnection Customer will be able to modify power plant facilities on the generator side
of the Interconnection Point with no impact upon the operation of the transmission system
whenever the generation facilities are electrically isolated from the transmission system.
The project must be controlled to operate at unity power factor. Voltage flicker at startup
and during operation will be limited to less than 5% as measured at the point of
interconnection. For this to occur, the current cannot exceed 65 Amps during start up at the
12.5 kV voltage level. This forces the generating facility to start the generators separately.
The project is required to comply with the applicable Voltage and Current Distortion Limits
found in IEEE Standard 519-1992 IEEE Recommended Practices and Requirements for
Harmonic Control in Electrical Power Systems.
3
i
5. Budget
The following good faith estimates are provided in 2010 dollars:
Estimated Cost & Ownership:
Customer
TOTAL
Overhead Generation Interconnection Package 1IPC
Underground Equipment and 1500 kV A Transformer PC
TOT ALi
GRAND TOTALI
Milestones:
$200,000
$45,000
--+----·-$}45,000
$245,000
'•.':,,l'.,t,,r:-"''''~"~~~~~t fl . ~~' .. , .,,·,..,.;•~ ·~:.,r '', •]' t ·,•• I.-,+ • ·fu·-~;"'.!"'1/'t(•, .. I:'_:-._: ..• ::• .: .. :·•~'.1' ~· -=-~·. ;"-~.' ,~• .. : •J'·~,."'· ··4 ·.\:.-· j/ <-·,., ~-•..•. •'""·~~/, ·' •• -.\~ ~il ~m~'··!.--:y}L."'' ...... ,.,._,_,_ .. •>~.•.~r1 "\.-... ~-~• ....-••<~ .... -r'-.. _-~-• ~.\., • • '4 .... ·--~ .. • • , •• .,. •-_ ,. • ~ _ " ,. ._ .. •. •, • r·~··
09/16/10 Final Facility Study Report Submitted to Customer
10/17/10 Construction Funds Received by /PC
11/5/10 Order Materials
3/15/11 ~PCO Construction Completion
4/1/11 ~PCO Test and Commission Equipment Completion
TBD Commercial Operation
Construction Budget Timeline:
Feb 2010-April2011
GRAND TOTAL ------L-----------
4
$245,000
$245,000
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 16
Bishop, Rowena
From:
Sent:
To:
Cc:
Subject:
Attachments:
Hi Laura,
Bishop, Rowena
Monday, October 25, 2010 4:01 PM
'Laura Knothe'
Hackett, Eric; Bauer, Rich; Sprenger, Jill; Allphin, Randy
Gl307 & 308
cover offer dgia 307 308.pdf; draft GIA 307.doc; draft GIA 308.doc
Please review the attached draft GIA & cover letter for Swager Farms & Double B projects. Note that
the project owner information needs to be included in the GIA. Please contact me or Eric if you have
any questions.
I look forward to hearing from you soon!
Rowena Bishop
Operations Analyst
ph 208.388.2658
1
Laura Knothe
The New Energy Company
8720 Vic Lane
Middleton, ID 83644
An IDACORP Company
October 25, 2010
Via email & ---· ---
Certified Mail # 7006 0810 0006 5511 2990
Re: Swager Fanns Project #307 & Double B Dairy Project #308
Dear Laura:
Attached please find a copy of the final Facility Study Report (FSR) and a draft Generator
Interconnection Agreement (GIA) for your Generator Interconnection projects. This GIA is part
of Idaho Power Company's Rate Schedule 72 tariff approved by the Idaho Public Utilities
Commission (IPUC). The IPUC has the authority to review and modify these schedules
periodically. You may view the most current tariff at Idaho Power's website at:
http://www.idahopower.com/aboutus/regulatoryinfo/tariffs.asp . If you would like to schedule a
meeting or conference call to discuss the GIA please contact me as soon as possible.
Under the Generator Interconnection process, the following items must be provided to me on or
before execution ofthe GIA:
Proof of Site Control for the project
Insurance certification
Financial arrangements/construction funding
Although the preferred method of funding is full deposit upfront; payment arrangements may be
requested. If you have not already done so, please contact Jill Sprenger (208-388-6424), Finance
at your earliest convenience to discuss Idaho Power's credit requirements for construction
funding. Once we receive funding, or the credit requirement is met, we can proceed with
construction of the project. The actual construction and labor charges will be reconciled
approximately 90 days subsequent to proje_ct completion.
PLEASE NOTE-While the Generator Interconnection process (Feasibility, System Impact, and
Facility studies) we are going through identifies any necessary Network Upgrades that may have
to be made to move your Project energy to load, it does not secure the transmission rights to do
so. The GIA only provides for the physical connection of the project output to the generator side
of the point of interconnection with Idaho Power's grid. It does not cover the transmission
service to transfer your project output across the connection point or to the ultimate load.
An additional agreement providing for transmission of the energy is required to be secured to
deliver your energy from the point of interconnection with your project to Idaho Power load.
You or the energy purchaser must arrange for transmission, and provide the necessary
documentation prior to commercial operation. This would include either a Transmission Service
P.O. Box 70 (83707)
1221 W. Idaho St.
Boise, ID 83702
Page 2 of2
Request (TSR) or a Network Designation from the energy purchaser. My records show that this
has already been done.
You may have noticed that we have drafted the GIA Attachments based on the Facility Study
Report provided to you on September 16, 2010. Please review the Attachments to make sure
they are comprehensive and accurate and advise me of any changes as soon as possible. The
completed Attachments must be sent to me by close ofbusiness on November 29, 2010, so that
we may prepare the GIA for execution.
Failure to respond to this letter will be considered as an election not to proceed with the proiect,
and we will consider your Generator Interconnection request to have been withdrawn and
terminated. If you have any further questions, please don't hesitate to contact me.
Encl: Final Facility Study Reports - # 307 & #308
draft GIA for Swager Farms Project# 307
draft GIA for Double B Dairy Project # 308
Cc: (via email)
Eric Hackett IIPC
Rich Bauer/IPC
Jill Sprenger/IPC
Randy Allphin/IPC
Sincerely,
&~:,:f¥J
Operations Analyst
[e-mail]
ph 208.388.2658
Idaho Power Company Generator lnterconne m Agreement# 308
I.P.U.C. No. 29 Tariff No. 101
October 25, 2010
Idaho Power Company Generator Intel · :1nection Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 1
TABLE OF CONTENTS .
RECITALS ...................................................... : ....................................................................................... 1
AGREEMENTS ...................................................................................................................................... 1
1. Capitalized Terms ................................................................................................................ 1
2. Terms and Conditions .......................................................................................................... 1
3. This Agreement is not an agreement to purchase Seller's power ......................................... 1
4. Attachments ......................................................................................................................... 1
5. Effective Date, Term, Termination and Disconnection .......................................................... 1
5. 1 Term of Agreement. . ............................................................... ; ~~;.,. ..................................... 2
5.2 Termination .......................................................................... ,:.·;;?:.: ...................................... 2
53 • D' t' ·· · ·•7 2 . , emporarv tsconnec ton ................................................ ;·J}.·;_,cJ< ........................................... .
6. Assignment. Liability. Indemnity, Force majeure. ConseqtJehfmL Damages and Default. ...... 5
7. Insurance ................................................................. ,;;--;~;;.l'.' ... :.'~l:·:"~:, ....................................... 7
8 M. 'I /.'/ .. ff·-. 7 . tsce,, aneous ........................................................ , ........................ ~., ................................ . ~0. ~~t~~~~~~~: :::::::::::::::::::::::::::::::::::::::::::::::::: ::?~i~t::::: ::::::::::::::::: ::::~~~t~-~-:::::::::::::::::::::::::: ~ fl'~·~ ~.Ph Attachment 1 .............................................................. (~.',~ ...................... Error! Boolqbark not defined.
Att h t 2 .~-?".·;{ . E I B k /~,;,'1.-t d f" d ac men .......................................................... · .,..... .. .. .. .. . .. .. . .. .. ... ... .. rror. oo m.,..'ll\· no e 1ne . ~/ / j· A"~-). , ,.'-.. "~!--Attachment 3 .............................................................. ;,_,.: ............... : .. c-:~Error! Bookmai'K~not defined. "!Pz• ~!£fA. . Attachment 4 ................................................................. '!:,::{: ...... .-:~:~~: ..... Error! Bookmark not defmed.
A h .. ~-':;.' .,/·-...'-' f' d ttac ment 5 .................................................................... :~i' ·"<(' .......... Error! Bookmark not de me .
Att h t 6 /~~:>' -~x_; E I B k k t d f" d ac men .... ....... ... .. .......... ............. ... •. •. .. .............. .......... ,;;_ ...... .... rror. oo mar no e 1ne .
0· : /'':.(.,-., ;~ I/. /,o /. ;(l.;.Y,_ "'1. ,r~,-'.1_ . . .., -~7 ,}!'.... , ./~,., · Y.;l"'' · ~;;:~r~~.&~. .;<i1-· • .. ,.:;/.. z-.~p:{'_,_ . • ,. : >'> ~;~~; "z-...;;'~ • ·~ ........ ~~··· . ;.;,Pz''h/.· .:~-/. -~>< • ~0"-x• :rz ~~}.: ·~.,:.q..,... ..:~ •• · -m ~wM~-· ···. · ,, >'l ~-~ ~ A,6>{~;{0 11 ,, . v )'"'~--'-~' ~~~: ·•xf~ w«.J-. •r~-~ ;t:/,-~,Y, . Pl~-' ~-/~~if, ,~. ~.. ~ ... /.>/-,.:-, ,t:,% E._,:;f/-, y~ ~·;:--~ .'df ~1f~ .• .r:/',.. ;.-/x'/ 'r ~" ~~Zi~. t:f;..V , .·./ ~;f'/..· .. '•/ _.;·;,. /~'.;h.(. Wd,,zY."~· ,J,,. <..,:-9// •.• ,., .· . .. v· . " .>'•// '%:~> .,,. w:;r"' r. q .·;(.[:lp:_,;:;'' 4':tj·'" · ' V-40'/. •.-:.1 -;,;'.!'/.,~-. 1/ . "'" ' ,, ' .. ,.....,, .... ~ ~ '/ ·. . .. ..,.~~~ ~ !f;;_;·~ . ~~ /
"-!· _/ ....::~· -~~~­·'·?$: ... ::, .. f;~i· -,,J.{y:.­._1_/·.; ..
·.;-/..·· -~</
Idaho Power Company Generator lnterconn£ '>n Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 9
This Generator Interconnection Agreement ("Agreement") under Idaho Power Company's
Schedule 72 is effective as of the day of , 2010 between
------------• ("Seller" or "The Project") and Idaho Power Company -Delivery
("Company", or "Transmission Owner").
RECITALS
AGREEMENTS
1. Capitalized Terms
Capitalized terms used herein shall have the sam
of this Agreement.
12f~~eJ,er may require will be covered under separate
Tcru-..arr to affect any other agreement between the
and Costs of the Generation Facility, Interconnection
Diagram Depicting the Generation Facility, Interconnection
and Upgrades.
:....:.:..:=:...:..:...:...-=....:.=--=-" -Additional Operating Requirements for the Company's Transmission
System Needed to Support the Seller's Generation Facility.
Attachment 5-Reactive Power.
Attachment 6-Description of Upgrades required to integrate the Generation Facility and
Best Estimate of Upgrade Costs.
5. Effective Date. Term. Termination and Disconnection.
Idaho Power Company Generator Inter · nnection Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 2 of 9
5.1 Term of Agreement. Unless terminated earlier in accordance with the provisions
of this Agreement, this Agreement shall become effective on the date specified above and
remain effective as long as Seller's Generation Facility is eligible for service under Schedule 72.
5.2 Termination.
5.2.1 Seller may voluntarily terminate this Agreement upon expiration or
termination of an agreement to sell power to the Company.
5. 2. 2 After a Default, either Party may terminate this Agreement pursuant to
Section 6. 5.
5.2.3 Upon termination or expiration of this Agreement, the Seller's Generation
Facility will be disconnected from the transmission/distribution system. The
termination or expiration of this not relieve either Party of its liabilities
and obligations, owed or continuing at of the termination. The provisions of this
Section shall survive termination or of this Agreement.
5.3 Temporarv Disconnection. shall continue only for so
long as reasonably necessary under "Good Utility Practice means any of
the practices, methods and acts engaged in or a significant portion of the electric
industry during the relevant time period, or any of , methods and acts which, in the
exercise of reasonable judgment in light of the facts the time the decision was made,
could have been expected to accomplish the desired reasonable cost consistent with
good business practices, reliability, safety and expedition. Practice is not intended
to be limited to the , method, or act to the of all others, but rather to
be acceptable or acts generally accepted in the region. . Good Utility
Practice WECC or NERC requirements. Payment of lost revenue
resulting shall be governed by the power purchase agreement.
"Emergency Condition" means a condition or
Party making the claim is imminently likely to
case of the Company, is imminently likely (as
manner) to cause a material adverse effect on the
Company's transmission/distribution system, the
Facilities or the equipment of the Company's customers; or
Seller, is imminently likely (as determined in a non­
a material adverse effect on the reliability and security
e Generation Facility or the Seller's Interconnection Facilities. Under
either the Company or the Seller may immediately suspend
and temporarily disconnect the Generation Facility. The
notify the Seller promptly when it becomes aware of an Emergency
may reasonably be expected to affect the Seller's operation of the
Facility. The Seller shall notify the Company promptly when it becomes
aware of an Emergency Condition that may reasonably be expected to affect the
Company's equipment or service to the Company's customers. To the extent
information is known, the notification shall describe the Emergency Condition, the extent
of the damage or deficiency, the expected effect on the operation of both Parties'
facilities and operations, its anticipated duration, and the necessary corrective action.
5.3.2 Routine Maintenance, Construction. and Repair. The Company may
interrupt interconnection service or curtail the output of the Seller's Generation Facility
Idaho Power Company Generator lnterconne m Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 3 of 9
and temporarily disconnect the Generation Facility from the Company's
transmission/distribution system when necessary for routine maintenance, construction,
and repairs on the Company's transmission/distribution system. The Company will
make a reasonable attempt to contact the Seller prior to exercising its rights to interrupt
interconnection or curtail deliveries from the Seller's Facility. Seller understands that in
the case of emergency circumstances, real time operations of the electrical system,
and/or unplanned events, the Company may not be able to provide notice to the Seller
prior to interruption, curtailment or reduction of electrical energy deliveries to the
Company. The Company shall use reasonable efforts to coordinate such reduction or
temporary disconnection with the Seller.
5.3.3 Scheduled Maintenance. On or
Seller shall submit a written proposed
maintenance for that calendar year and the
to the acceptability of the proposed schedule.
acceptability of the Seller's timetable for scheduled
consideration Good Utility Practices, Idaho Power system
preferred schedule. Neither Party shall unreasonably
proposed maintenance schedule.
31 of each calendar year,
of significant Facility
shall mutually agree as
tot.:.rn,;n,:>tirln as to the
will take into
and the Seller's
of the
5.3.4. Maintenance Coordination. The Seller and the Company shall, to the
extent practical, their respective transmission/distribution system and
Generation Facility such that they occur simultaneously. Seller
shall provide and equipment sufficient to prevent damage
to the Generation Facility Interconnection Facilities. In some cases,
some of Seller's protective back-up protection for Idaho Power's
facilities. In that event, Idaho annually and Seller will pay the
actual cost of such annual
5.3.5 Forced Outages. any forced outage, the Company may suspend
interconnection service to immediate repairs on the Company's
transmission/distribution system. shall use reasonable efforts to provide
the Seller with prior notice. If prior not given, the Company shall, upon request,
the Seller written documentation after the fact explaining the circumstances of
The Company shall notify the Seller as soon
based on Good Utility Practice, operation of the Seller's Generation
disruption or deterioration of service to other customers served from
or if operating the Generation Facility could cause damage to
system or other affected systems. Supporting
to reach the decision to disconnect shall be provided to the Seller
after notice, the Seller fails to remedy the adverse operating effect
~n""n'P time, the Company may disconnect the Generation Facility. The
provide the Seller with reasonable notice of such disconnection, unless
the provisions of Article 5. 3. 1 apply.
5.3. 7 Modification of the Generation Facility. The Seller must receive written
authorization from the Company before making any change to the Generation Facility
that may have a material impact on the safety or reliability of the Company's
transmission/distribution system. Such authorization shall not be unreasonably withheld.
Modifications shall be done in accordance with Good Utility Practice. If the Seller makes
such modification without the Company's prior written authorization, the latter shall have
the right to temporarily disconnect the Generation Facility.
Idaho Power Company Generator I nte nnection Agreement # 308
I.P.U.C. No. 29, Tariff No. 101 Page 4 of9
5.3.8 Reconnection. The Parties shall cooperate with each other to restore the
Generation Facility, Interconnection Facilities, and the Company's
transmission/distribution system to their normal operating state as soon as reasonably
practicable following a temporary disconnection.
5. 3. 9 Voltage Levels. Seller, in accordance with Good Utility Practices, shall
minimize voltage fluctuations and maintain voltage levels acceptable to Idaho Power.
Idaho Power may, in accordance with Good Utility Practices, upon one hundred eighty
(180) days' notice to the Sell~r, chang~ its n~mina~ opera!JP:.~~>yoltage level b.y more than
ten percent (10%) at the Pomt of Delivery, m wh1ch CCJ.~r;,tsifiler shall mod1fy, at Idaho
Power's expense, Seller's equipment as necessa_p~~accommodate the modified
nominal operating voltage level. Ji{~~~.
5.4
{#~·~· . ;~J%~
,,.,~~ ··::c;#.#~ '-@'r.;:··: /~~~d~ ..
Land Rights.
"'~·· ~r!m:.JQ.~~~lQQ~t:.A~fler hereby grants td:#JJCJhO Power for the
and easemenfs~1e.-install, operate,
5.4.1
Equipme;;G!f.J~terconnection
and other Spllcial Facilities
and continuing access rights
procured sufficient easements and
nrl'1\lll"fi:W.rr.t~lnn Power with the access described
C:,t:JrYit:J11t:ei:<T!lr rights-of-way shall be subject to
·-~~~#J~~~~~~~~~~ agree that it is necessary to a1 r.~"''""r'"'"nn 1rnti.~t:!t·.~ that would occur as a result of
in close proximity. Therefore, subject to Idaho
4.4, Seller agrees that should Seller seek and
ea~9'~1/;,g·ov,err,rmEmr.at body the right to erect, construct
'ter·co<rftfl~ct.ion Facilities upon, along and over any and all
rnt:.•R~.;.-;.z~jfrt:J~~,C>'::!:o~lgf,(flitf)!Kf:~~-" the use by Seller of such public right-of-way
by Idaho Power of such public right-of-way for
of electric distribution and transmission facilities and
use of such public right-of-way for such purposes at any time.
Paragraph 5. 4. 4, Idaho Power shall not be required to
"'"'"'r"·'""'r•n its rights under this Paragraph 5.4.2.
Subject to Idaho Power's compliance with
Power may use and attach its distribution and/or transmission
,.,.,,,.,. ... C' Interconnection Facilities, may reconstruct Seller's Interconnection
Fa•clfllr(~~M~~)~~ct>m,mo,date Idaho Power's usage or Idaho Power may construct its own
transmission facilities along, over and above any public right-of-way
Seller pursuant to Paragraph 5.4.2, attaching Seller's Interconnection
Facilities to such newly constructed facilities. Except as required by Paragraph 5.4.4,
Idaho Power shall not be required to compensate Seller for exercising its rights under
this Paragraph 5.4.3.
5.4.4 Conditions of Use. It is the intention of the Parties that the Seller be left in
substantially the same condition, both financially and electrically, as Seller existed prior
to Idaho Power's exercising its rights under this Paragraph 5.4. Therefore, the Parties
agree that the exercise by Idaho Power of any of the rights enumerated in Paragraphs
Idaho Power Company Generator lnterconne >n Agreement # 308
LP.U.C. No. 29, Tariff No. 101 Page 5 of 9
5.4.2 and 5.4.3 shall: (1) comply with all applicable laws, codes and Good Utility
Practices, (2) equitably share the costs of installing, owning and operating jointly used
facilities and rights-of-way. If the Parties are unable to agree on the method of
apportioning these costs, the dispute will be submitted to the Commission for resolution
and the decision of the Commission will be binding on the Parties, and (3) shall provide
Seller with an interconnection to Idaho Power's system of equal capacity and durability
as existed prior to Idaho Power exercising its rights under this Paragraph 5.4.
6. Assignment. Liability, Indemnity, Force majeure. Consequential Damages and Default.
6. 1 Assignment. This Agreement may be assigned r:un=rn:onar Party upon twenty-one
{21) calendar days prior written notice and opportunity to the other Party; provided
that:
6.1.1 Either Party may assign this Ma1re~:une~nc the consent of the other
Party to any affiliate of the assigning Party with. credit rating and with
the legal authority and operational ability t~ ~''Jtpfy the obl'iga,tib~1S~lOf the assigning Party
under this Agreement. /~ .dfi.~ft·· I?P . . 6.1.2 The Seller shall have,}JJJlf right to c9,J)Jmgently .· Agreement,
without the consent of the Company,· tQfr;;pllateraf;i,~rity purposes to in providing
financing for the Generation Facility, pfqWJJ~d ,..?a· Wf'he Seller will promptly notify the
Company of any such assignment~ ~~-
6.1.3 Any that v'i~k~ this article is void and ineffective.
Assignment shall not ob/igat1b~ or shall a Party's obligations be
enlarged, in whole or in part, An as_jJffJ.Dee is responsible for meeting
the same . credit, H§ the Seller. Where required,
~R-/<'~"";.!.:;;w;r:t· not conditioned or delayed.
6.2 liability to the other Party for ahy loss, cost,
claim, injury, attorney's fees, relating to or arising from
~~~~~~~t~;h;;,~=r•:oarna . .,T shall be limited to the amount of direct
ii Party be liable to the other Party for any
any act or om11SS.W--l!~JI
damage actually
indi~Jifl~C 'a/, rnn~I:Yf'fi~ ~¥·•~-except as authorized by this Agreement.
,,, 6.3 rritiemnitv. '
.,;,, 6.~~1!1is . protects each Party from liability incurred to third parlies as '-:~}-:;;.'.a result of ca~fl,g out provisions of this Agreement. Liability under this provision is
'·if:,]pxempt from th§}~f?nerallimitations on liability found in Article 6.2. ·~··, ..-:;;~ ~¥'?.;~ 9//$ ·-;.:7~h 6.3.2,·":-;' .1)~ Parties shall at all times indemnify, defend, and hold the other Party har~~~.)}: .. rf~Vany and all damages, losses, claims, including claims and actions
relatingffj'&tjfi.Jury to or death of any person or damage to property, demand, suits, recoveriJ§;~osts and expenses, court costs, attorney fees, and all other obligations by
or to third parties, arising out of or resulting from the other Party's action or failure to
meet its obligations under this Agreement on behalf of the indemnifying Party, except in
cases of gross negligence or intentional wrongdoing by the indemnified Party.
6. 3. 3 If an indemnified person is entitled to indemnification under this article as
a result of a claim by a third party, and the indemnifying Party fails, after notice and
reasonable opportunity to proceed under this article, to assume the defense of such
claim, such indemnified person may at the expense of the indemnifying Party contest,
Idaho Power Company Generator lnte:: · _nnection Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 6 of 9
settle or consent to the entry of any judgment with respect to, or pay in full, such claim.
Failure to defend is a Material Breach.
6.3.4 If an indemnifying party is obligated to indemnify and hold any
indemnified person harmless under this article, the amount owing to the indemnified
person shall be the amount of such indemnified person's actual Joss, net of any
insurance or other recovery.
6.3.5 Promptly after receipt by an indemnified person of any claim or notice of
the commencement of any action or administrative or /egaP,P,toceeding or investigation
as to which the indemnity provided for in this article ma~f5/y, the indemnified person
shall notify the indemnifying party of such fact. Any fa 'Ju:JN{f or delay in such notification
shall be_ a Material B~each an_d shall ~ot_a_ffect a P~rtj:~>f4-g_~mnification obligation unless
such failure or delay 1s matenally preJUdiCial to~~~~'f~}J:"'cfemmtrJf~J;arty.
6.4 Force Majeure. As used in this ljgPpgment, "Force 'M}fieure" or "an event of
Force Majeure" means any cause beyond the c;;qp1:rlf of the Seller or 'tfftih~ Company which,
despite the exercise of due diligence, such ,R..aryf is unable to prevent 6 ·,ay~rcome. Force
Majeure includes, but is not limited to, act.Syj,j God, fire, flp.od, storms, wtirs./!J9stilities, civil
strife, strikes and other labor disturbances, ear(q~.{:lkes, fir(d:~ftghtning, epidemi~t'sabotage, or
changes in law or regulation occurring after the;;OPE!ffJ(Jiiifi Date, which, by the exercise of
reasonable foresight such party CQJ!Id not reasonablft/;f,~.Ve been expected to avoid and by the
exercise of due diligence, it shall f/e::UJ]aple to overco#rp: . (f either Party is rendered wholly or in
part_ unable to pe'!orm its obligaq]JJft~fJJfJJJ;, this Agre~m~r,t beca~se of an event of Force
Majeure, both Part1es shall be excrl(€1(1 from{.W.b<j(ever pefflfiJl:l~ance 1s affected by the event of
c::: M . "d d h t ··:f:/.· ' . ·:/ . ~?!:~ rorce ajeure, prov1 e t a: ~~-. ''·".:i:;~<. ~ · -::4~· ·?,<·,,., .-~v--.. "z. .-, ,....,, ~~ :Z,."/.".;g'¥/)/,:/':7~. '
{1) ~4qjb~";ififJ!J;Performit{"tf'~tJl~ha/l, ~s~@'n as is reasonably possible after
the occursej[Je of the.'f.?rce Maji/~f./fglve the othef Party written notice describing the
particyLS.K {@f the occurtt_ence. ~-.f.;~-.f)' Z"l'A; •?.o?'/-· ~~2. f::.;!f'"' ~~:;.-, 'r2J't:~. , The .~tf:~pf#q~f.9[1.. of perf~frr.ance shall be of no greater scope and of no
longer duratj¢b~,th,.a,ilW t'et[~i{fj,ti}?YJ.I)e._e'{!ent of Force Majeure .
. _g;..pj7//.~---·-~@f&f.:6 / ·---1':'~{/0'~"' ··.r.-:,t_'-1-'•h'y}!'' ~·. ''f<l.~~, ~)'.< / ._,_}-;:·3·· · _-!' ·(,} C~L . . No: :~l)figations of either P_arty which arose before the occurrence causing
/,i.;·~/ the suspep,rJon of Pf!rJprmance and wh1ch could and should have been fully performed ·.'y;/~· before sucH6cpurrehce/shall be excused as a result of such occurrence. y~;.; . Wjf,;.; <··f>~,_
•,} ., • ; /f· f//z ,.~ . ..)',. z '-~~-~~i~i;;-,, ~~~;
~i0 .f(·'j;.;. ~' . /.;10.x ·~~ .~ ~ /; «:;~;·· ?,/,Jl'~ .,.{'" ~?.-~/ ·.y#:; ";'··L·'· ,. .i!:/ "#;,-(:tz 4-;r~~f;·~'/,
... ~ "J
Idaho Power Company Generator lnterconn• on Agreement# 308
I.P.U.C. No. 29. Tariff No. 101 Page 7 of9
6. 5 Default and Material Breaches.
6. 5. 1 Defaults. If either Party fails to perform any of the terms or conditions of
this Agreement (a "Default" or an "Event of Default'?, the nondefaulting Party shall cause
notice in writing to be given to the defaulting Party, specifying the manner in which such
default occurred. If the defaulting Party shall fail to cure such Default within the sixty
(60) days after service of such notice, or if the defaulting Party reasonably demonstrates
to the other Party that the Default can be cured within a commercially reasonable time
but not within such sixty (60) day period and then fails to diligently pursue such cure,
then, the nondefaulting Party may, at its option, terminate th~ Agreement and/or pursue
its legal or equitable remedies. -.')/~
-.... -::,.-/·' ~-:;.7~r•'
6. 5. 2 Material Breaches. The notice and. CJji~fJiR:~_isions in Paragraph 6. 6. 1 do
not apply to Defaults identified in t~!s Agree.ct,fftjt·~· ~s· {f~W.-ria_l Breaches. Material
Breaches must be cured as exped1t1ous/y/}~. ~ssible fo!(~¥'f!.~g occurrence of the
breach. ./J_. ~ \/:~, if·"-';~·'" ·,.~~-/;./ .• / :j:. '' 7. Insurance. /--:·: , ;;:A.• •. <' j/_. _;;;//. .•
£?uring the term of this Agreement, Seller.;~p$11 secure a~~ continuously ca~ Jhe following
msurance coverage: --~;/.k. . ·lf;;tf· ~{.,.· ··-:.-~::-?-~. • /'' ..... ,,. ,. •'%;'' -<'/ q;:
7. 1 Comprehensive G~e_ral Liability 'f~;!.fiJe for both bodily injury and property ·
damage with limits equal to $1,oofat~. each occurrd,. combined single limit. The deductible
for such insurance shall be consisfri}Jl :IJ,pf~r~nt lnsu~~~'/~~dustry Utility practices for similar
property. ;;;-._ ·-~""-. %~~---~? '".r·~ >;.;~.
7.2 The a~?,~~4fksurance -~~age"_'· ,:blfktEJP-~;J(J;[h an insurance company with
an A.M. Best ComR.~: i ·1.'a:ri!f&.of A-or b'if((~ a ~hall incitift(i{
1 :~'1/.4" ;.-~-;;. ~\~~~~· •/n ')~/ ~~;-: ''/ffr£'/ /f4f:!7 An endJfiement na~p ldaho Power as an additional insured and loss
payee.-tJf.?.pplicable; a •. ;~~ ~~J'> <~, ~ • ~A;·~ ·~~ ~ Wg-p,@.-.;;;-~ ~~
(b} ~it'~~tlf,j.:.· on:sf')f}QV,?J!)f)lJ4i16h policy shall not be canceled or the limits of
_, ;rjf)j#P,/J~f.J:;;~educf~'ffJiout sixty (60)·fffty§Pprior written notice to Idaho Power.
;{$?/ .. :{~;b, ~ ./~.~:~.'? 7.3 s&ffer to Pro'Wde Certificate of Insurance. As required in Paragraph 7 herein and
.-J,p;ifnual/y thereaftiitflBJier s'IM}JJfi ~nish the Company a certificate of insurance, together with the "'~J]!1_grsements reqwr~~~ereiri; ~fpencing the coverage as set forth above.
"'"'~.~/,. @',:i: r::~r11f'.,4 Seller trft.KJotify Idaho Power of Loss of Coverage -If the insurance coverage
requiri&;,tJYEparagraph;_{ljff shall/apse for any reason, Seller will immediately notify Idaho Power
in writi'!g~~f/!J~;'otic~M(advise Idaho Power o~ the specifi~ reas~n for_the lapse and th~ ~teps
Seller 1s takroJJJlei-!J..fistate the coverage. Farlure to prov1de thts nottce and to exped1t1ous/y
reinstate or re;Jl?J,¢}-:the coverage will constitute grounds for a temporary disconnection under
Section 5. 3 and ~II be a Material Breach.
8. Miscellaneous.
8. 1 Governing Law. The validity, interpretation and enforcement of this Agreement
and each of its provisions shall be governed by the laws of the state of Idaho without regard to
its conflicts of law principles.
8.2 Salvage. No later than sixty (60) days after the termination or expiration of this
Agreement, Idaho Power will prepare and forward to Seller an estimate of the remaining value
Idaho Power Company Generator Intel nnection Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 8 of 9
of those Idaho Power furnished Interconnection Facilities as required under Schedule 72 and/or
described in this Agreement, less the cost of removal and transfer to Idaho Power's nearest
warehouse, if the Interconnection Facilities will be removed. If Seller elects not to obtain
ownership of the Interconnection Facilities but instead wishes that Idaho Power reimburse the
Seller for said Facilities the Seller may invoice Idaho Power for the net salvage value as
estimated by Idaho Power and Idaho Power shall pay such amount to Seller within thirty (30)
days after receipt of the invoice. Seller shall have the right to offset the invoice amount against
any present or future payments due Idaho Power.
9.
9.3 Designated Operating Representative. The Parties may also designate
operating representatives to conduct the communications which may be necessary or
convenient for the administration of this Agreement. This person will also serve as the point of
contact with respect to operations and maintenance of the Party's facilities.
Idaho Power Company Generator lnterconne m Agreement# 308
I.P.U.C. No. 29. Tariff No. 101 Page 9 of9
Seller's Operating Representative:
Seller:------------------------
Attention:--------------------------
Address: _________ ~------=------------City: ___________ State: ____ Zip: -------
Phone: Fax: ----------
Company's Operating Representative:
Idaho Power Company-Delivery /.,{_}:.~-·
Attention: Regional Outage Coordinator-Regional Dispatch ,·, .
12~1 W. Idaho Street ./&'
8o1se, Idaho 83702 ~Jfo'4_6', .
Phone: [phone], or 388-5175 during regpj:t.f£u sl ~.~~-hours
(after hours Southern Region 208-388-5190). "f'. .,,Y.~1P,..,
:«~· ..
9.5
.. ,._
Party may chan~~his information by
effective date of the~tfa.~:nge. 1f.P&R
. ~h~ 10. Signatures.
IN WITNESS WHEREOF, the
respective duly authorized represen
For the Seller
< /.-~~--··, -:;~. ~ ~ fi~:~~t~
',}':
.;zy
Idaho Power Company ! .•
I.P.U.C. No. 29, Tariff No. 101
Generator lnte·· _nnection Agreement# 308
Page 1 of 3
Attachment 1
Description and Costs of the Generation Facility, Interconnection Facilities and Metering
Equipment
In this attachment the Generation Facility and Interconnection Facilities, including Special
Facilities and upgrades, are itemized and identified as being owned by the Seller or the Company. As
provided in Schedule 72, Pavment For Interconnection Facilities, the Company will provide a best
estimate itemized cost of its Interconnection Facilities, including Special Facilities, upgrades and
Metering Equipment.
'-,~-:,...
General Facility Description .-.,{J.;p/</
The proposed project will connect to Idaho Power's 12.5kV sx~}~J1f, on Idaho Power Company's
Buckhorn (BKHN-041) distribution line. The total project output i%f~'¥" :.,;_.~, ..
-7M7%fP '· ,~/..
Interconnection P~!!Jt·.;;,~ "":t$~:-
The Interconnection Point for the Double B Dairy Digest~~;~fdJect will be the i6~l~-!de bushings on the
padmounted transformer (081). The project's locatiOIJ.?J ~fl'12S R21E Sectiorf"j§/of Cassia County,
Idaho. A drawing identifying the Point of lnterconi)~{Ff\ is included as Attachmt3fi'f~~ The Point of
Change of Ownership will be the low-side bushings orf:¥J.:e padmount~~"tJ:ansformer (DB4 ). ;·, ''./:{«-., . ;/'·.-, ?-,-/ ··z, .-;.---,
Seller's lnterconne~ti~Jl~~ .),j~t~s
The Seller will install generators, low-si e disconnect s~(fv.if1, all wiring and conduit between the
generators and the padmounted transf(fijj;er-,_ appropriat~~~~nding measures, and associated
auxiliary equipment. The Seller will build u~_!3f~t~~.D£}acilities f~~~_Point of Change of Ownership for
the generator facility. The low-side disconn~C"t swlf&~~~9, ld be v1silj!~ _lockable, within ten (1 0) feet of
the padmounted transformers, and accessibi~Q. Idaho -p' ~f.:P-rrsonn~~;;-
,1(;;'/;._-y, :~ #fjJf·Z.-;f;#/&.}~ ':· •
Th S II ·11 ·d Y/-////2;(»'~ c;ar,_ ~.,17 .... "'" • '¥.*/~ d b d e e er w1 prov1 e P.Ji~e : se"r~!f:? to IP g~~enerator lntettonnect package as escri e in
Telecommunications below;;v -/~---~;.. /.*'' . •/ / ~';:f/•. ··~ ;»Jt' .~_/ ,..~ -'-/N/ ~:, .. / ;;/./,·-.;9:·
All interconnection ect~!pment ele~tJj9§llly located :_glj: the generator side of the Point of Change
Ownership shall be owflep~~ ma!~~~)Qi9t.~),)~1~,,Seii~J?; - . . "-;, ·-ifi~ /,-,(~'to/}~-
:::·:. /;/ .·: : .· ·""J~0ther Facilities· P~ovided by Seller
Te/ecot:9vf_yhica tiC1n~K·1· ·~ ?~~/,.
The Jf-!~Ej.f..connection CtJ~t_s.>mer wiJJ'·· provide two communication circuits between the generation intercqri:n~ction site and a !<{~!ion , ~-toq~tions , specified by Idaho Power. One of the circuits will be a
dedicated;.~::wire leased analc;ig_ circuit·c~pnected to the SEL 311 C relay and the other will be a POTS
dial-up circU.~Jo the revenue~fb.;~ter. The Interconnection Customer is responsible for supplying and
coordinatin{;f'<f~e,., installation 6f~the phone lines and paying the monthly service charges. The
communication'"¢fr2.yits will ne~-to be installed and operational prior to generating into the Idaho Power
system. ·· <, .·: · ~~ . // / -~ -'• '·:~:{(/.. ·:?;' ....
Ground Fault Equipment -
;'·
The Seller will install ground fault limiting equipment that will limit the zero sequence fault current to 20
amps at the Interconnection Point.
Monitoring Information
If the Interconnection Customer requires the ability to monitor information related to the Idaho Power
recloser in the generation interconnection package they are required to supply their own
communications circuit to the control box.
Idaho Power Company Generator lnterconm on Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 2 of 3
Easements
The Seller will secure underground and overhead easements with Double B Dairy once a specific route
is determined. Idaho Power will provide the documentation.
Idaho Power Company's Interconnection Facilities
Idaho Power will install a standard generation interconnection package on the existing distribution
feeder (BKHN-041) on private property southwest of the intersection of 1200 South and 1100 West in
Cassia County, Idaho. The new interconnection package will include fm~r.Sl~tribution poles to mount a
local service transformer, solid blade disconnects, primary metering g7~ ~ge, recloser, relays, fuses
and ri~er necessary for the ~ackage. Th~ interconnection will J~~J¥jntrolled .by a SEL-3~ 1C line
protection relay. The relay w1ll be located 1n a pole mounted ~J)P~~!'J;, and w1ll also contain a test
switch (TS4), SLSS, modems, isolation interface, power supply~~,conVe~~·']; control switch and surge
protector. ~ ., '·0:·~:· b. ·~;:~/-
Idaho Power will install (and subsequently own and_JJt~:tain) one 1500 kV~?l.7!480 to 12.47 kV
Grounded Wye I Grounded Wye pad mounted transfQ.~~ on top of a vault. ConaGtt:.~IJd underground c~bles .will be installed from the interconnection p~4lf~? to padmou~~ed transformer:¥--ft!ptective posts
w1ll be Installed to protect the ground mounted eqUipilf~~!om da~:'1< ~~-·~
·-~~ ~~
A 2" conduit will be installed alongside the round pff~ · :~o'f~cilitate information exchange to the
customer about the recloser. (The In Custome" ~J~ponsible for providing and installing
the appropriate cable). ~~~~;.
"':'$-~ ~42'·· .M'D.~:<?S,'?"4 .... __ side . ef~ Point of Change Ownership
$N/Al
~~~~1:~~~~~~;{?..:..._ ___ ~~~-_j___ ___ _J_ ____ ···---i
Billing for constructio
rrnnr '-,rn accordance with Section 9, unless payment arrangements are
·Pt~f\N£~r Delivery Finance.
will be based upon actual expenditures.
Billing and Payment during Construction
Transmission Provider will prepare monthly invoices for services performed in accordance with this
Agreement and deliver the invoices to Seller. Seller will transmit payment to Transmission Provider no
later than 30 days after receiving the invoice. In the event any monthly payment is missed, Idaho
Power Company may revoke the unsecured nature of the construction funding and will require security
for the remaining funds. In the event of payment default construction will cease until remediation is
made by the Seller.
Idaho Power Company Generator Inter· · 1nection Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 3 of 3
Invoices are to be addressed to Seller as follows:
Idaho Power Company Generator lnterconnE .)n Agreement# 307
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 1
Attachment 2
One-line Diagram Depicting the Small Generation Facility, Interconnection Facilities, Metering
Equipment and Upgrades
Idaho Power Company Generator Intel ,1nection Agreement# 307
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 1
Attachment 3
Milestones:
9/16/10 !Final FSR submitted to Seller ------------------------1 !construction Funds received by IPCO 10/17/10
11/5/10 Order Materials
3/15/11 IPCO Construction Complete .;:-.. ,t. J,.i'
Agreed to by:
For the Seller:
For the Transmission Provider
Idaho Power Company, Delivery
Idaho Power Company Generator lnterconne >n Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 2
Attachment 4
Additional Operating Requirements for the Company's Transmission System and Affected
Systems Needed to Support the Seller's Needs
The Company shall also provide requirements that must be met by the Seller prior to initiating
parallel operation with the Company's Transmission System.
Operating Requirements
The project is required to comply with the applicable Voltage and Cu ~:t-_Distortion Limits found in
IEEE Standard 519-1992 IEEE Recommended Practices and Requi:~;.'· ts for Harmonic Control in
Electrical Power Systems or any subsequent standards as they mayJi~ .... ;pdated from time to time.
#/I·•· Seller will be able to modify power plant facilities on the generat __ >§lae o .-~_pterconnection Point with
no impact upon the operation of the transmission syst~ 0, _whenever fflEi'~rneration facilities are
electrically isolated from the transmission system and a Je ·lifinal clearance ~~~ed by Idaho Power "#}!/}{ > o/,~ Company's Grid Operator. :i>\:f;·' · · ~:··. ~-~ Voltage flicker at startup and during operation will..JW~. limited to )~~~ than 5% as · ~sured at the
Interconnection Point. For this to occur, the current t£'nnq~ excee<;t;f:?,~'Amps during starf.Ifip at the 12.5
kV voltage leveL This forces the generating facility to sta:'t,f_ ~~:<~~wrators separately.
, ·~i<:M~z.v/ ~-·-w~ ~.&~· -~"'~ Low Voltage Ride Through :~·t·:w~~ . · ,.~ ·;-._ .
The Project shall remain interconnected Tr~n t~~~C';jrrence of ~,·three phase or single phase to
ground fault down to a voltage. of zero at IJ7~_ions cWW~l;l..9: PowcifO~~ystem as close to the Seller's fa?i~ities a~ Idaho Power ~9ID.$Cl"~'s. Clov"(r~su~ pdn1{f(~?f ~.t~ tne fault being cleared for the
m1mmum t1mes stated bel~~,~~ffl'~ ,..Je_ptng off-~~~· . ._,.
• Three phase fau)~(f"rmal c Ef~ppg that ta., , p to 9 cycles.
• Single phase -:_~~~fOund fault: 9j..Pyed clea -~~-that takes up to 50 cycles. -~~--/;j~ Y.~. ;w,-~ %7..~ t~q· Ground Fault Equipmeq,J~ . -;;-'-l~nM.!~~~· . '~i.:>.
The Seller will)~stall trafl~~,-'Ue~etffiftgutat@"~~~t,~MProvide a ground source to the transmission
system. ,~1(p~,1 . ~~:P':;~· ·W· ?ffffl'/dj~-' ' , ,?_/,,: ~"?. ... h ~; • '"%.-'U,t;r./ ·~ ··/, · Comfqjfbt~l Operati~,i(!guir~~hJ;s
The -:$~flfir will be grantett:]f.(r,eq ue:-%flf~J,:;ommercial Operation date only when all requirements have
been -m:~t.~Mnder this GIA "~6~,--Idaho ~~pwer Company's Power Sales Agreement. A transmission
service. (e~~t ("TSR") for ~-~ generation has been submitted to Idaho Power Company's Grid
Operat1ons gr~p under TSR ~1:;:17864.
~~7 ,:f':f:< ,;;(;;,; z. /)(-:;:( -"l.~f~J:: ""'Z~·-· "'bifJi1~ ,;fh.;~,
'.:-(tp;p#r ~·~:r-t~t ·.<Jv
Idaho Power Company Generator Intel :. ·.mection Agreement # 307
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 1
Attachment 5
Reactive Power Requirements
Idaho Power will determine the reactive power required to be supplied by the Company to the
Seller, based upon information provided by the Seller. The Company will specify the equipment
required on the Company's system to meet the Facility's reactive power requirements. These
specifications will include but not be limited to equipment specifications, equipment location, Company~
provided equipment, Seller provided equipment, and all costs associate8%VY.ith the equipment, design
and installation of the Company~provided equipment. The equipme~~~i.i!Jfi'fications and requirements
will become an integral part of this Agreement. The Company-oWf1:.fA"€t .6guipment will be maintained by
the .c?mp~ny, with total .cost of purchase, installation, opt[j~(or{~~J]d maintenance, in~ludin.g
admtmstratJVe cost to be retmbursed to the Company by the S#_!fe7 :' Payf1e_{l.! of these costs will be m
accordance with Schedule 72 and the total reactive power QQ!i( wlll be inctrtd{i?J:in the calculation of the
Monthly Operation and Maintenance Charges specified in /~®~Clute 72. · \1~}; ·
.:,;x_;.._ -~/ '':i .. ~~-, ..
The project must be controlled to operate at unity pg_h:e.&tcf~tor. ... ··::;·:> ..
. ; .. """"-.. ;.., ~hi';...
..
# ... ,.·~.. ...... /J: ,.. Vif:.ti.. ' / ';.i(;-n.-Y. / ~~_,~0,;,~
v,;~r, ;/, . /~V. ;';/' -,; ... :~. y·. ~, ..
/-<"; • ;.;-;>)}
~,.,!'/. ·>';)f ',~,.:: .,1, .. •" . ~· .. . ' ~ ··' .. ;• '.':/ . ./' ... ;,_. .. ,, "'-"' . ·"f_)',. ··,;· .:;J_;J?, • .
fi't • ~,.-/,W..~· ~ /:.i·f:1;;,. .. ~';~ . -: .. / ~~~;-~:· ~ -(~' , •. %'~~ "'-'/~'f/,/ i'!-. .,;:,, ·1'.· . . £·~. ;.-·'/ .• ~· '~-£~ 4:;;.'/:-->-· 'V/ -.W.{-:. ..... =?·; z ·t . . -'/.;{ . ·1§?:&~; . //~~~7
,.,;,~>f' . ;:~ .
.. 1?/.? ...
~ ? .. · ..
· .
Idaho Power Company Generator lnterconn( ~n Agreement# 307
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 1
Attachment 6
Companv's Description of Special Facilities and Upgrades Required to Integrate the Generation
Facility and Best Estimate of Costs
As provided in Schedule 72 this Attachment describes Upgrades, Special Facilities, including
Network Upgrades, and provides an itemized best estimate of the cost of the required facilities.
Distribution Upgrades
n/a
Upgrades
IInt~-;onnection costs (from Atta_chment l.L__ _____ _,...,.,~7.""":-fwz:7.>..:_·-------t----$245,0QQl
~----------------------------~~~~o/~~------~~k--------~_!24~ooJ
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 17
Bishop, Rowena
From: Hackett, Eric
Sent:
To:
Monday, January 03, 2011 9:53 AM
Laura Knothe
Cc: Bishop, Rowena
Subject: RE: Gl 307 & 308 -Swager Farms and Double B Dairy
Great to hear from you Laura. As you can see if the FSR for both, it is approximately 6 months from the time we receive
construction funding to the time we can have the project in-service on our end. We are still in good shape for meeting a
late slimmer or early fall date. However, as you mentioned, the sooner funding is received and I can order materials and
get the designers going on final design the better. I would anticipate material orders being placed within a couple weeks
of payment and design to start a month or so after that based on current workload and resource availability. I think
payment in the next 4-6 weeks would be best so we can schedule construction resources as well for this summer.
Thanks again.
Eric Hackett, P.E.
Project Leader
Idaho Power Company
PO Box 70, 83707
1221 West Idaho St.
Boise, ID 83702
Office Phone: [phone]
Cell Phone: [phone]
From: Laura Knothe [mailto:[e-mail]
Sent: Monday, January 03, 2011 9:43 AM
To: Hackett, Eric
Cc: Bishop, Rowena
Subject: GI 307 & 308 -Swager Farms and Double B Dairy
Good morning Eric and Happy New Year! I just wanted to check in with you regarding the above referenced projects.
We have an investor on board and will proceed with the GIA in the next week or so. We have several meetings this
week, so I should know more by the end of the week. How is your work load at this point? We are looking at
construction this spring/summer and an operation date in September or October. I'm sure we need to get this
proceeding right away. Please advise!
Thank you.
Laura Knothe, PE, LEED AP
The New Energy Company
www.thenewenergycompany.com
208.890.8783
1
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 18
SMALL GENERATOR INTERCONNECTION REQUEST
(Application Form)
Transmission Provider: IDAHO POWER COMPANY
Designated Contact Person:
Address:
Telephone Number:
Fax:
E-Mail Address:
Rowena Bishop
1221 W. Idaho Street, Boise lD 83702
208-388-2658
208-388-6647
[e-mail]
An Interconnection Request is considered complete when it provides all applicable and correct
information required below.
Preamble a.nd Instructions
An Interconnection Customers who request interconnection must submit this Interconnection Request by
hand delivery, mail, e-mail, or fax to the Transmission Provider.
Processing Jt'ee or Deposit:
If the Interconnection Request passes ALL screens ofSGIP Section 2.2.1, the application may be
submitted under the Fast Track Process, and the non-refundable processing fee is $500. Please contact
Idaho Power if you have any questions.
All Interconnection Requsts submitted under the Study Process, whether a new submission or an
Interconnection Request that did not. pass the Fast Track Process, shall submit to the Transmission
Provider a deposit not to exceed $1,000 towards the cost of the feasibility study.
Interconnection Customer Information
Legal Name of the Interconnection Customer (or, if an individual, individual's name)
Name: New Energy Three, LLC
Contact Person: Laura Knothe PE
Mailing Address: "'8-'-7""'20"--'V'--'i"'-c-"L"'ao!.!n_,_e ___________________________ _
City: Middleton State: ""ID"------Zip: 83644
Facility Location (if different from above):------------------------
Telephone (Day): _.;.2=0-""8.=8=90=·=87""'8'""3, ______ Telephone (Evening): ---=2=08=·=58=5=.9'-"0"""1"'-6 __ _
Fax: ----"2"""0'""8:.:.:.5<->8"-"5'"".9~0""'1,_,6'---------E-Mail Address: laura(lv,thenewenergycompany.com
DOUBLE B DAIRY PROJECT
Altermltive Contact Information (if different from the [nterconnection Customer) NA
Contact Name: _____________________________________________________________ __
Title: --------------------------------------------------------------------
Address: __________________________________________________________________ __
Telephone (Day): ____________ Telephone (Evening):-------------------
Fax:--------------------------------E-Mail Address:--------------------
Application is for: ___ New Small Generating Facility
x Capacity addition to Existing Small Generating Facility
If capacity addition to existing facility, please describe: Project has completed Facility Study and
Draft GIA1 b11t no phvsical work has been completed-Project Number 308. This application is
for an additional 800kW to bring the total request to 2000kW. The values below indicate tbe
total project capacity and not the additional capacity for this specific request.
Will the Small Generating Facility be used for any of the following?
To Supply Power to the Interconnection Customer? Yes _No _x_
To Supply Power to Others? Yes __ No _x __
For installations at locations with existing electric service to which the proposed Small Generating
Facility will interconnect, provide:
(Local Electric Service Provider*) (Existing Account Number*)
[*To be provided by the Interconnection Customer if the local electric service provider is different from
the Transmission Provider]
Contact Name: ______________________________________________________________ __
Title:-----------------------------------------------------------
Address: __________________________________________________________________ __
Telephone (Day):-----------------Telephone (Evening):-----------------
Fax:----------------------------E-Mail Address:-----------------
Requested Point of Interconnection: See previous studies-Proiect Nmnber 308
Interconnection Customer's Requested In-Service Date: _,S"""ep~t..,.e .... m.,b'""e"-r_.,2""0_._1.!..1 ______________________ _
DOUBLE B DAIRY PROJECT
Small Generating Facility Information
Data apply only to the Small Generating Facility, not the Interconnection Facilities.
Energy Source:_ Solar _Wind _Hydro _Hydro Type (e.g. Run-of-River): _____ _
_ Diesel _Natural Gas _Fuel Oil _x_ Other (state type) methane gas
Prime Mover: _Fuel Cell LRecip Engine _Gas Turb
_Microturbine _PV
Type of Generator: -~Synchronous __ Induction Inverter
_Steam Turb
_Other
Generator Nameplate Rating: up to2000
up to 1500
kW (Typical) Generator Nameplate kV AR:
Interconnection Customer or Customer-Site Load: .__;n'""o""'n"'e'--------·kW (ifnone, so state)
Typical Reactive Load (if known):-------
Maximum Physical Export Capability Requested: 2000 kW (total for both applications; 800kW
Additional for this application)
List components of the Small Generating Facility equipment package that are currently certi-fied:
Equipment Type Certifying Entity
1. ---------------
2. ----------------3.
4. ----------------5.
Is the prime mover compatible with the certified protective relay package? Yes No
Generator (or solar collector)
Manufacturer, Model Name & Number: MWM TCG 2016 Vl6 C-800kW
Ve~ionNumber: ________________________________________ _
Nameplate Output Power Rating in kW: (Summer) ------=2""-00~0"-------, (Winter) _...;2::..>0'""0""0 ___ _
Nameplate Output Power Rating in kV A: (Summer) 2500 (Winter) ___ ..=:2=5=00"'-------
Individual Generator Power Factor
Rated Power Factor: Leading: _______ Lagging: _."'8'----------
Total Number of Generators in wind farm to be interconnected pursuant to this
Interconnection Request: Elevation: _Single phase _Three phase
Inverter Manufacturer, Model Name & Number (if used): --------------------------
List of adjustable set points for the protective equipment or software:------------------
Note: A completed Power Systems Load Flow data sheet must be supplied with the Interconnection
Reguest.
DOUBLE B DAIRY PROJECT
Small Generating Facility Characteristic Data (for inverter~based machines)
Max design fault contribution current: Instantaneous or RMS?
Harmonics Characteristics:-------------------------
Start-up requirements:--------------------------
Small Generating Facility Characteristic Data (for rotating machines)
RPM Frequency: _____ _
(*) Neutral Grounding Resistor (If Applicable): ____ _
Synchronous Generators:
Direct Axis Synchronous Reactance, Xd: ___ P.U.
Direct Axis Transient Reactance, X'd: P.U.
Direct Axis Subtransient Reactance, X" d: -----~P.U.
Negative Sequence Reactance, X2: ____ P.U.
Zero Sequence Reactance, X0: P.U.
KVA Base:-----------
Field Volts: _____ _
Field Amperes: _____ _
Induction Generators: NA
Motoring Power (kW): _____ _
I/t or K (Heating Time Constant): ------Rotor Resistance, Rr: _____ _
Stator Resistance, Rs: ------Stator Reactance, Xs: _____ _
Rotor Reactance, Xr: ------Magnetizing Reactance, Xm: _____ _
Short Circuit Reactance, Xd": ------Exciting Current: _____ _
Temperature Rise: _____ _
Frame Size: _____ _
Design Letter: ---,--,---
Reactive Power Required In Vars (No Load): _____ _
Reactive Power Required In Vars (Full Load): _____ _
Total Rotating Inertia, H: Per Unit on kVA Base
Note: Please contact the Transmission Provider prior to submitting the Interconnection Request to
determine if the specified information above is required.
DOUBLE B DAIRY PROJECT
Excitation and Governor System Data for Synchronous Generators Only
Provide appropriate IEEE model block diagram of excitation system, governor system and power system
stabilizer (PSS) in accordance with the regional reliability council criteria. A PSS may be determined to
be required by applicable sh1dies. A copy of the manufacturer's block diagram may not be substituted.
Interconnection Facilities Information
Will a transformer be used between the generator and the point of common coupling? _x_Yes _No
Will the transformer be provided by the Interconnection Customer? __ Yes _x_No
Transfmmer Data Qf Applicable, for Iotercorulection Customer-Owned l'ransformer):
Is the transformer: __ single phase __ three phase? Size: _____ kVA
Transformer Impedance: %on kVA Base
IfThree Phase:
Transformer Primary: __ Volts __ Delta __ Wye __ Wye Grounded
Transformer Secondary: __ Volts ___ Delta __ Wye __ Wye Grounded
Transformer Tertiary: __ Volts __ Delta __ Wye __ Wye Grounded
Transformer Fuse Data {If Applicable. for Interconnection Customer-Owned Fuse):
(Attach copy of fuse manufacturer's Minimum Melt and Total Clearing Time-Current Curves)
Manufacturer: ________ Type: _______ Size: ____ .Speed: _____ _
Interconnecting Circuit Breaker (if applicable):
Manufacturer: _____________ Type: ____ _
Load Rating (Amps): Interrupting Rating (Amps): Trip Speed (Cycles): ____ _
Interconnection Protective Relays (If Applicable):
If Microprocessor-Controlled:
List of Functions and Adjustable Setpoints for the protective equipment or software:
Setpoint Function Minimum Maximum
l.
2.
3.
4.
5.
6.
DOUBLE B DAIRY PROJECT
If Discrete Components:
(Enclose Copy of any Proposed Time-Overcurrent Coordination Curves)
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Current Transformer Data (If Applicable):
(Enclose Copy of Manufacturer's Excitation and Ratio Correction Curves)
Manufacturer:----------------------
Type: _______ Accuracy Class: _ Proposed Ratio Connection: __
Manufacturer:----------------------
Type: _______ Accuracy Class: _ Proposed Ratio Connection: __
Potential Transformer Data (If Applicable):
Manufacturer:----------------------
Type: _______ Accuracy Class: _ Proposed Ratio Connection: __
Manufacturer:----------------------
Type: _______ Accuracy Class:_ Proposed Ratio Connection: __
DOUBLE B DAIRY PROJECT
General Information
Enclose copy of site electrical one-line diagram showing the configuration of all Small Generating
Facility equipment, current and potential circuits, and protection and control schemes. This one-line
diagram must be signed and stamped by a licensed Professional Engineer if the Small Generating Facility
is larger than 50 kW. Is One-Line Diagram Enclosed? _X_ Yes __ No
Enclose copy of any site documentation that indicates the precise physical location of the proposed Small
Generating Facility~' USGS topographic map or other diagram or documentation). See earlier
applications.
Proposed location of protective interface equipment on property (include address if different from the
Interconnection Customer's address) 1250 W 1100 S Murtaugh ID 83344
Enclose copy of any site documentation that describes and details the operation of the protection and
control schemes. Is Available Documentation Enclosed? __ Yes __ No
Enclose copies of schematic drawings for all protection and control circuits, relay current circuits, relay
potential circuits, and alann/monitoring circuits (if applicable).
Are Schematic Drawings Enclosed'! _Yes __ No
Applicant Signature
I hereby certify that, to the best of my knowledge, all the infonnation provided in this Interconnection
Request is true and correct.
For Interconnection Customer:
Signed
_______________ Date: 1112/11
Printed
Laura Knothe
DOUBLE B DAIRY PROJECT
DATE: D1111n1
JOe NO.
SCALE
NTS
400KW
GENERATOR
~
800KW
GENERATOR
~
BOOKW
GENERATOR
~
I TRANSFORMER I PAD
.~ +
1 ' 2500KVA 1 BY
I ~ .j,. XFMR I UTILITY
L _______ _j
~-----I -----I -----~-----~
: ) : ) : ) : ).3.QQQh : I 1 I 1 I ! I ! 3P I
: l_.3000A BUS, 480V, 3GI,l_3W : :
L_____ -----_____ _L _____ _j
*PARALLELING GEAR *PARALLELING GEAR
SKE-1
&KETCH NO.
REF.SHTS:·
DOUBLEB
ONE-LINE DIAGRAM
·~ 25rr-J~ER~fV<;J
440 East Corporate Or., Sta. 10~
Meridian 10 83642
ph 208-288-2181
fa~ 206-288··2182 P~'l""' Ot."'OO
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 19
January 20, 2011
via email and
An IDACORP Company
Certified Mail# 70060810000655113157
Laura Knothe
8720 Vic Lane
Middleton, ID 83694
Re: Expansion Projects # 364 (Swager Farms) and# 365 (001~ble B)
Dear Laura:
T4ank you for yot1r Generator Interconnection applications for the expansion projects shown above
(see attached copy). :Since we haveteceived :all of the Fequired ll1aterlais, the~>e applications are now
considered complete.. As you may be aware, w~ are required to post certain infonmitio:h to our
OASIS (Open Access Same Time Information) website. Please. refer to the website periqdically to
view a list of c'UtrYI)t Proje¢rs at http://www.oatioasis.com/IPCO/index.html under GENERATOR
INTERCONNECTION INFORMATION folder, on the left side ofthe screen.
Sfuce you will be sellit),g the :project output to Idaho Power Company-Power Supply (as a. NetWork
Resource-NR, or·as a-PURPA),. transmission studies for moving this energy t(! the load or .a p9~tof
deliveiy inside of out system wiU be included in the Generator Interconnection studies. If ·you
haven't already done so, please contact Randy Allphin for your Power $al~s con_tract und~r 11 parallel
process. He can be it:eached at 208;.,388·2614.
At this time, Idaho P:<iwer Company will as$ign a pl~g engirieer Jor this project, and we wijl
c;ont~~:;t you i:p. the neat mtute to schedule a-Scoping Meeting_. If your projectpasses s.cree:hlng for the.
FAST TRACK process, which means yom project output ·can be· accoilllll.o.dated into ow system
without fadlity upgrades or fm'the.r studi.es, we will im'mediately notify you of next steps to proceed.
Fot yow review, lam attaching· a copy of the standard Interconnec.tion Feasibility Study Agreement
that needs to be executed by you soon after our S.coping Meeting. Please feel :free to contact me with
your questions aboutthe Generator Interconnectiori Process anytime,
I will forward tbis application to our T&D Plarining Leader, Mate Patterson, who will be evaluating
yo\lrrequest,
Encl .Application
Sincerely,
f~-Mv
Rowena: Bishop
Ph 208.;388-2658
Idaho Power Company's Facility Connection Requirements
Standard Interconnection Feasibility Study Agreement
Cc (via email):
Marc Patterson:IIPC
Randy Allphin!IPC
BEFORE THE
IDAHO PUBLIC UTILITIES -cOMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 20
Small Generator Feasibility Study Agr~e~ent
'J)ou\o le.... fS Project# 3f)£
Feasibility Study Agreement
THIS AGREEMENT is made and entered into this ·L... day of ~c..brtA-tll'tr 2011, by and
between -#.e N~t.J CY)e r C.0 a.u...c L.LC-, a '-L c._
--~--~~~--------------organized and existing un er the law of the State of Ida. he ,
("Interconnection Customer,") and Idaho Power Company a Corporation existing under the laws
of the State of Idaho ("Transmission Provider"). Interconnection Customer and Transmission
Provider each may be referred to as a "Party," or collectively as the "Parties."
RECITALS
WHEREAS, Interconnection Customer is proposing to develop a Small Generating Facility or
generating capacity addition to an existing Small Generating Facility consistent with the
Interconnection Request completed by Interconnection Customer on January 14, 2011; also
known as Project# 3w5" ; and
WHEREAS, Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Provider's Transmission System; and
WHEREAS, Interconnection Customer has requested the Transmission Provider to perform a
feasibility study to assess the feasibility of interconnecting the proposed Small Generating
Facility with the Transmission Provider's Transmission System, and of any Affected Systems;
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the terms specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause to be
performed an interconnection feasibility study consistent the standard Small Generator
Interconnection Procedures in accordance with the Open Access Transmission Tariff.
3.0 The scope of the feasibility study shall be subject to the assumptions set forth m
Attachment A to this Agreement.
4.0 The feasibility study shall be based on the technical information provided by the
Interconnection Customer in the Interconnection Request, as may be modified as the
result of the scoping meeting. The Transmission Provider reserves the right to request
additional technical information from the Interconnection Customer as may reasonably
become necessary consistent with Good Utility Practice during the course of the
feasibility study and as designated in accordance with the standard Small Generator
Small Generator Feasibility Study Agreement
Dodo lL 8 Project# '3b5
Interconnection Procedures. If the Interconnection Customer modifies its Interconnection
Request, the time to complete the feasibility study may be extended by agreement of the
Parties.
5.0 In performing the study, the Transmission Provider shall rely, to the extent reasonably
practicable, on existing studies of recent vintage. The Interconnection Customer shall not
be charged for such existing studies; however, the Interconnection Customer shall be
responsible for charges associated with any new study or modifications to existing studies
that are reasonably necessary to perform the feasibility study.
6.0 The feasibility study report shall provide the following analyses for the purpose of
identifying any potential adverse system impacts that would result from the
interconnection of the Small Generating Facility as proposed:
6.1 Initial identification of any circuit breaker short circuit capability limits exceeded
as a result of the interconnection;
6.2 Initial identification of any thermal overload or voltage limit violations resulting
from the interconnection;
6.3 Initial review of grounding requirements and electric system protection; and
6.4 Description and non-bonding estimated cost of facilities required to interconnect
the proposed Small Generating Facility and to address the identified short circuit
and po~er flow issues.
7.0 The feasibility study shall model the impact of the Small Generating Facility regardless
of purpose in order to avoid the further expense and interruption of operation for
reexamination of feasibility and impacts if the Interconnection Customer later changes
the purpose for which the Small Generating Facility is being installed.
8.0 The study shall include the feasibility of any interconnection at a proposed project site
where there could be multiple potential Points of Interconnection, as requested by the
Interconnection Customer and at the Interconnection Customer's cost.
9.0 In lieu of Feasibility Study deposit, Interconnection Customer agrees that study funds
will be drawn from the application fee for the performance of the Interconnection
Feasibility Study.
Transmission Provider shall charge and Interconnection Customer shall pay the actual
costs of the Interconnection Feasibility Study. Any difference between the deposit and
the actual cost of the study shall be paid by or refunded to Interconnection Customer, as
appropriate.
Small Generator Feasibility Study Agreement
Do '-' b {I! B Project # Z ""{'
10.0 Once the feasibility study is completed, a feasibility study report shall be prepared and
transmitted to the Interconnection Customer. Barring unusual circumstances, the
feasibility study must be completed and the feasibility study report transmitted within 30
business days of the Interconnection Customer's agreement to conduct a feasibility study.
11.0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
12.0 The Interconnection Customer must pay any study costs that exceed the deposit without
interest within 30 calendar days on receipt of the invoice or resolution of any dispute. If
the deposit exceeds the invoiced fees, the Transmission Provider shall refund such excess
within 30 calendar days of the invoice without interest.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written.
Transmission Provider:
Idaho Power Company-Delivery
Printed: Marc Patterson
Title: Engineering Leader, T &D Planning
Date: Fe..b 2, 2.Dll
Interconnection Customer:
1bo~ b1R , i:J f:b. • to. 7rj Co 1 LL~
Signed:~~
Printed: L~1rc. l~o~
Title: .AJ fLV\ o 9:} " J Th..e. 11! 11) flAA"<J~ Co) L.lf
Date: a.b-\ "?-0 \ t
~k~ ~,-rk tJ~ ~1"\c_., u..c__,
l /2./UJ ' I
Small Generator Feasibility Study Agreement
DoubLe & Project#;?"5
Attachment A to Feasibility Study Agreement
Assumptions Used in Conducting the Feasibility Study
The feasibility study will be based upon the information set forth in the Interconnection Request
and agreed upon in the scoping meeting held on t:='c.la -z..-7 Z.0 1 r
1) Designation ofPoint of Interconnection and configuration to be studied.
IZ,S
~~~~ u.:v. a.___~Ct_u.l/\.f ~ I I oo Sovf~ . Mw fCA..Ut'-1
8D::Jk-w
2) Designation of alternative Points of Interconnection and configuration.
1) and 2) are to be completed by the Interconnection Customer. Other assumptions (listed
below) are to be provided by the Interconnection Customer and the Transmission Provider.
Page 1 of 1
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 21
BH
GENERATOR INTERCONNECTION
FEASIBILITY STUDY
For integration of the proposed
DOUBLE B DAIRY DIGESTER EXPANSION PROJECT
In
CASSIA COUNTY, IDAHO
To the
IDAHO POWER COMPANY ELECTRICAL SYSTEM
For
NEW ENERGY THREE, LLC
The
INTERCONNECTION CUSTOMER
DRAFT REPORT
MARCH 16, 2011
Generator Interconnection Feasibility Study
General Interconnection Information
Station or
Date of Total Trans Line
Queue Request Location (MW) for POl
34.5 kV
through
Buckhorn
Cassia (BKHN)
#365 January 2011 County 2.0 substation
Short Circuit Analysis Results
System Changes Required: DYes rgjNo
Power Flow Analysis Results
System Changes Required: rgjYes DNo
Projected
In-Service
Date
September
2011
Type of facility
(combined cycle,
base load, CT, fuel
type)
Biogas
System upgrades are required to the Idaho Power substation and to the existing distribution system to
interconnect the 2 MW dairy digester generation project at Double B Dairy. These upgrades are shown in
the Table 1 below:
Description Estimated Cost
Distribution Upgrades including 1/2 mile new 34.5 kV line and
cutover of existing line near Double B Dairy to 34.5 kV $151,000
Generation Interconnection Protection Package (Includes 34.5 kV
recloser, controls, CTs, PTs, and communications $225,000
Total Estimated Cost $376,000
Good Faith Cost Estimate
Interconnection cost estimate for 2 MW generator project: $376,000.
System Impact Study Required? DYes rgJ No
This Feasibility Study only addresses the work required to interconnect the Double B Dairy digester project
to the Idaho Power system. There are no transmission rights secured for the project until a transmission
system request is submitted by the corresponding transmission customer. The required transmission
facilities, if any, to support energy transfers will then be determined based on first come first serve basis
(queue order).
Operating Requirements:
Project #365 will be controlled to operate at unity power factor with an operating bandwidth of± 300
kVAR.
-1-
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 22
BH
GENERATOR INTERCONNECTION
FEASIBILITY STUDY
For integration ofthe proposed
DOUBLE B DAIRY DIGESTER EXPANSION PROJECT
In
CASSIA COUNTY, IDAHO
To the
IDAHO POWER COMPANY ELECTRICAL SYSTEM
For
NEW ENERGY THREE, LLC
The
INTERCONNECTION CUSTOMER
FINAL REPORT
APRIL 26, 2011
Generator Interconnection Feasibility Study
General Interconnection Information
Station or
Date of Total Trans Line
Queue Request Location (MW) for POl
34.5 kV
through
Buckhorn
Cassia (BKHN)
#365 January 2011 County 2.0 substation
Short Circuit Analysis Results
System Changes Required: DYes ~No
Power Flow Analysis Results
System Changes Required: ~Yes DNo
Projected
In-Service
Date
September
2011
Type of facility
(combined cycle,
base load, CT, fuel
_type)
Biogas
System upgrades are required to the Idaho Power substation and to the existing distribution system to
interconnect the 2 MW dairy digester generation project at Double B Dairy. These upgrades are shown in
the Table 1 below:
Description Estimated Cost
Distribution Upgrades including 112 mile new 34.5 kV line and
cutover of existing line near Double B Dairy to 34.5 kV $151,000
Generation Interconnection Protection Package (Includes 34.5 kV
recloser, controls, CTs, PTs, and communications $225,000
Total Estimated Cost $376,000
Good Faith Cost Estimate
Interconnection cost estimate for 2 MW generator project: $376,000.
System Impact Study Required? DYes ~ No
This Feasibility Study only addresses the work required to interconnect the Double B Dairy digester project
to the Idaho Power system. There are no transmission rights secured for the project until a transmission
system request is submitted by the corresponding transmission customer. The required transmission
facilities, if any, to support energy transfers will then be determined based on first come first serve basis
(queue order).
Operating Requirements:
Project #365 will be controlled to operate at unity power factor with an operating bandwidth of± 300
kVAR.
-1 -
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 23
April27, 2011
Certified Mail #70092820000284567176
Laura Knothe
8720 Vic Lane
Middleton, ID 83694
RE: Swager Farms expansion (GI 364) and Double B expansion (GI 365)
Dear Laura:
IDAHO
POU\IER
An IDACO!lP tomptnv
Enclosed is the Final Feasibility Study Report for each of the above-referenced projects. The feasibility
analysis indicates that modification/addition of some facilities will not be required to integrate the
network resource capacity addition of your project into the Idaho Power system.
Since no System Impact Study is required, I have enclosed two (2) copies of the Facility Study
Agreement (FSA) for each project. In order to proceed, Idaho Power must receive your agreement to
proceed with the project(s) by executing both copies of the FSA and submitting completed Attachments,
along with the deposit in order to remain in the Generator Interconnection queue. The deposit under
each FSA is based on the estimated engineering costs.
For GI 364-Swager Farms, the deposit is $30,000;
For GI 365-Double B Dairy, the deposit is $18,800.00.
In order for your application to remain in the Generator Interconnection study queue, Idaho Power must
receive all of these items by June 9, 2011; otherwise the application will be deemed withdrawn:
1. the executed Facility Study Agreement,
2. the completed Attachment A, and
3. the corresponding deposit.
Please submit to: Idaho Power Company, Attention: Rowena Bishop, 1221 West Idaho Street, Boise, ID
83702. Please contact me if you have questions.
Sincerely,
-::=:-, -....
Marc Patterson
Engineering Leader, T &D Planning
Ph. 208.388.2712
Enclosures: Final Feasibility Study Report (2) GI 364 & 365
Facility Study Agreements (s) GI 364 & 365
C: Rowena Bishop/IPC
1221 w. Idaho St. (8370~)
P.o. llo:a 70
!lobe, 10 8l701
Facilities Study Agreement
THIS AGREEMENT is made and entered into this __ day of 2011 by and
between a organized
and existing under the laws of the State of ("Interconnection
Customer,") and Idaho Power Company, a Corporation existing under the laws of the State of
Idaho ("Transmission Provider"). Interconnection Customer and Transmission Provider each
may be referred to as a "Party," or collectively as the "Parties."
RECITALS
WHEREAS, the Interconnection Customer is proposing to develop a Small Generating Facility
or generating capacity addition to an existing Small Generating Facility consistent with the
Interconnection Request completed by the Interconnection Customer on 1/14/11; and
WHEREAS, the Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Provider's Transmission System;
WHEREAS, the Transmission Provider has completed a system impact study and provided the
results of said study to the Interconnection Customer; and
WHEREAS, the Interconnection Customer has requested the Transmission Provider to perform
a facilities study to specify and estimate the cost of the equipment, engineering, procurement and
construction work needed to implement the conclusions of the system impact study in
accordance with Good Utility Practice to physically and electrically connect the Small
Generating Facility with the Transmission Provider's Transmission System.
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the terms specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause a
facilities study consistent with the standard Small Generator Interconnection Procedures
to be performed in accordance with the Open Access Transmission Tariff.
3. 0 The scope of the facilities study shall be subject to data provided in Attachment A to this
Agreement.
4.0 The facilities study shall specify and estimate the cost of the equipment, engineering,
procurement and construction work (including overheads) needed to implement the
conclusions of the system impact study(s).
The facilities study shall also identify (1) the electrical switching configuration ofthe
equipment, including, without limitation, transformer, switchgear, meters, and other
station equipment, (2) the nature and estimated cost of the Transmission Provider's
Small Generator Facilities Study Agreement - 1 -Double B Dairy Expansion Project #365
Intercmmection Facilities and Upgrades necessary to accomplish the interconnection, and
(3) an estimate of the time required to complete the construction and installation of such
facilities.
5.0 The Transmission Provider may propose to group facilities required for more than one
Interconnection Customer in order to minimize facilities costs through economies of
scale, but any Interconnection Customer may require the installation of facilities required
for its own Small Generating Facility if it is willing to pay the costs of those facilities.
6.0 A deposit of $18,800.00 is due upon execution of this agreement by the Interconnection
customer.
7.0 In cases where Upgrades are required, the facilities study must be completed within 45
Business Days of the receipt of this Agreement. In cases where no Upgrades are
necessary, and the required facilities are limited to Interconnection Facilities, the
facilities study must be completed within 30 Business Days.
8.0 Once the facilities study is completed, a facilities study report shall be prepared and
transmitted to the Interconnection Customer. Barring unusual circumstances, the
facilities study must be completed and the facilities study report transmitted within 30
Business Days of the Interconnection Customer's agreement to conduct a facilities study.
9.0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
10.0 The Interconnection Customer must pay any study costs that exceed the deposit without
interest within 30 calendar days on receipt of the invoice or resolution of any dispute. If
the deposit exceeds the invoiced fees, the Transmission Provider shall refund such excess
within 30 calendar days of the invoice without interest.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written.
Transmission Provider: Interconnection Customer:
Idaho Power Company -Delivery
Signed: Signed: ____________ _
Printed Name: Printed Name: ---------------------
Title: Title: ----------------------------
Date: Date: ----------------------------
Small Generator Facilities Study Agreement -2-Double B Dairy Expansion Project #365
Attachment A to
Facilities Study Agreement
Data to Be Provided by the Interconnection Customer
With the Facilities Study Agreement
1. Provide location plan and simplified one-line diagram of the plant and station facilities.
For staged projects, please indicate future generation, transmission circuits, etc.
On the one-line diagram, indicate the generation capacity attached at each metering
location. (Maximum load on CT/PT)
On the one-line diagram, indicate the location of auxiliary power. (Minimum load on
CT/PT) Amps
2. One set of metering is required for each generation connection to the new ring bus or
existing Transmission Provider station. Number of generation connections:
3. Will an alternate source of auxiliary power be available during CT IPT maintenance?
Yes No ---
4. Will a transfer bus on the generation side of the metering require that each meter set be
designed for the total plant generation? Yes No
(Please indicate on the one-line diagram).
5. What type of control system or PLC will be located at the Small Generating Facility?
6. What protocol does the control system or PLC use?
7. Please provide a 7.5-minute quadrangle map of the site. Indicate the plant, station,
transmission line, and property lines.
8. Physical dimensions of the proposed interconnection station:
Small Generator Facilities Study Agreement -3-Double B Dairy Expansion Project #365
9. Bus length from generation to interconnection station:
10. Line length from interconnection station to Transmission Provider's Transmission
System.
11. Tower number observed in the field. (Painted on tower leg)*:
12. Number of third party easements required for transmission lines*:
* To be completed in coordination with Transmission Provider.
13. Is the Small Generating Facility located in Transmission Provider's service area?
Yes ___ No ___ If No, please provide name of local provider:
14. Please provide the following proposed schedule dates:
Begin Construction Date: ____________ _
Generator Step-Up Transformers Date: ____________ _
Receive Back Feed Power
Generation Testing Date: ____________ _
Commercial Operation Date: ____________ _
Small Generator Facilities Study Agreement -4-Double B Dairy Expansion Project #365
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 24
Laura Knothe
8720 Vic Lane
Middleton, ID 83694
JunelO, 2011
VIA email &
An IOACORP Company
Certified mail# 70090820000123019190
Subject: Double B expansion Project #365 -FINAL NOTICE
Dear Laura:
By letter dated April 27, 2011 Idaho Power provided you with a Facility Study Agreement for
interconnection of the proposed Double B expansion to be hiterconnected in .Cassia County,
Idaho.
Interconnection Customer was to execute and retum to me the Facility Study Agreement with the
required $18',800.00 deposit by June 9, 2011. That time period has now expired. Your
application for Generation Interconnection has now been deemed withdrawn.
Failure to submit the deficient it~s to me by June 24, 2011 will cause your Generator
Interconnection request to be terminat~d. lf you have any further questions, please cion't hesitate
to contact me.
cc (via email):
Orlando Ciniglio/IPC
Marc Patterson!IPC
Eric Hackett/IPC
Aubrae Sloan/IPC
Sincerely, ~ /) b.:~~
Operations Analyst
Ph 208.388.2658
[e-mail]
P.O. Box 70 (83707)
1221 W. idaho St
Boise, ID 83702
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 25
Bishop, Rowena
From:
Sent:
To:
Cc:
Subject:
Attachments:
Hi Laura,
Bishop, Rowena
Wednesday, September 28, 2011 2:23 PM
'Laura Knothe'
Hackett, Eric; Bauer, Rich; Sloan, Aubrae; Allphin, Randy
DRAFT GIA for Double B Dairy-Gl 308
coverDGIA308.pdf; DGIA308.doc
The attached is being mailed today. Please note response due date.
We need proof of Site Control for the physical property from the landowner on record before we can
sign. This can be a deed, lease, etc.
I look forward to hearing from you soon!
Rowena Bishop
Operations Analyst
ph 208.388.2658
1
Laura Knothe
8720 Vic Lane
Middleton, ID 83644
208-890-8783
Re: Double B Dairy Project# 308
Dear Laura:
September 28, 2011
Via email & Certified Mail
70090080000182635485
An IDACORP Collipany
Attached please find a draft Generator Interconnection Agreement (GIA) for your Generator
Interconnection project. This Agreement is part of Idaho Power Company's Rate Schedule 72 tariff
approved by the Idaho Public Utilities Commission (IPUC). The !PUC has the authority to review and
modify these schedules periodically. You may view the most current tariff at Idaho Power's website at:
http://www.idahopower.com/aboutus/regulatoryinfo/tariffs.asp . If you would like to schedule a meeting
or conference call to discuss the GIA please contact me as soon as possible.
Under the Generator Interconnection process, the following items must be provided to me on or before
execution of the GIA:
Proof of Site Control for the project and financial arrangements/construction funding
Although the preferred method of funding is full deposit upfront; payment arrangements may be
requested. If you have not already done so, please contact Aubrae Sloan (208-388-5697). Operations
Finance at your earliest convenience to discuss Idaho Power's credit requirements for construction
funding. Once we receive funding, or the credit requirement is met, we can proceed with construction of
the project. The actual construction and labor charges will be reconciled approximately 90 days
subsequent to project completion.
You may have noticed that we have drafted the GIA Attachments based on the Facility Study Report
dated September 16, 2010. Please review the GIA Attachments to make sure they are comprehensive and
accurate and contact Edc Hackett with any questions as soon as possible.
Failure to respond to this letter by November 28. 2011 will cause your Generator Interconnection request
to have been deemed withdrawn and terminated. If you have any further questions, please don't hesitate
to contact me at 208-388-2658.
Encl: draft GIA for Double B Dairy Project# 308
Cc: (via email)
Eric Hackett Project Leader/IPC
Rich Bauer/IPC
Aubrae Sloan/IPC
:?~6¥
Operations Analyst
[e-mail]
P.o. Box 70 (83707)
1221 W. Idaho St.
Boise, ID 83702
Idaho Power Company Generator Interet. .ection Agreement# 308
I.P.U.C. No. 29 Tariff No. 101
September 28, 2011
GENERATOR INTERCONNECTJO~N AGREEMENT
Schedule 7fJi:::o; . '.
DOUBLE 8 DAIRY DIGESTER PROJECT
1.2 MW
Idaho Power Company Generator Inter c • mection Agreement# 308
.
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 1
TABLE OF CONTENTS
REC/TALS .............................................................................................................................................. 1
AGREEMENTS ...................................................................................................................................... 1
1. Capitalized Terms ................................................................................................................. 1
2. Terms and Conditions .......................................................................................................... 1
3. This Agreement is not an agreement to purchase Seller's power ......................................... 1
4. Attachments ......................................................................................................................... 1
5. Effective Date. Term, Termination and Disconnection .......................................................... 1
5. 1 Term of Agreement. ........................................................................................................... 2
5.2 Termination .......................................................................................................................... 2
5.3 Temporary Disconnection ................................................................................................... 2
6. Assignment. Uabilitv. lndemnitv. Force majeure, Consequential Damages and Default. ...... 5
7. Insurance ............................................................................................................................. 7
8. Miscellaneous. .. ................................................................................................................... 7
9. Notices ................................................................................................................................. 8
10. Signatures ............................................................................................................................ 9
Attachment 1 ........................................................................................... Error! Bookmark not defined.
Attachment 2 .......................................................... : ................................ Error! Bookmark not defined.
Attachment 3 ........................................................................................... Error! Bookmark not defined.
Attachment 4 ............................................................................... , ........... Error! Bookmark not defined.
Attachment 5 ........................................................................................... Error! Bookmark not defined.
Attachment 6 .......................................................................................... Error! Bookmark not defined.
Idaho Power Company Generator lnterconnl on Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 9
This Generator Interconnection Agreement ("Agreement") under Idaho Power Company's
Schedule 72 is effective as of the day of , 2011 between
____________ _, ("Seller" or 'The Project") and Idaho Power Company -Delivery
("Company", or "Transmission Owner").
RECITALS
A. Seller will own or operate a Generation Facility that qualifies for service under Idaho
Power's Commission-approved Schedule 72 and any successor schedule.
B. The Generation Facility covered by this Agreement is more particularly described in
Attachment 1.
AGREEMENTS
1. Capitalized Terms
Capitalized terms used herein shall have the same meanings as defined in Schedule 72 or in the body
of this Agreement.
2. Terms and Conditions
This Agreement and Schedule 72 provide the rates, charges., terms and conditions under which the
Seller's Generation Facility will interconnect witb, and operate in parallel with, the Company's
transmission/distribution system. Terms defined inSchedule 72 will have the same defined meaning in
this Agreement. If there is any conflict between the '(E:rms of this Agreement and Schedule 72,
Schedule 72 shall prevail.
3. This Agreement is not an agreement to purchase Seller's power.
Purchase of Seller's power and other services that Seller may require will be covered under separate
agreements. Nothing in this Agreement is intended to affect any other agreement between the
Company and Seller.
4. Attachments
Attached to this Agreement and included by reference are the following:
Attachment 1 -Description and Costs of the Generation Facility, Interconnection
Facilities, and Metering Equipment.
Attachment 2 -One-line Diagram Depicting the Generation Facility, Interconnection
Facilities, Metering Equipment and Upgrades.
Attachment 3-Milestones For Interconnecting the Generation Facility.
Attachment 4 -Additional Operating Requirements for the Company's Transmission
System Needed to Support the Seller's Generation Facility.
Attachment 5 -Reactive Power.
Attachment 6 -Description of Upgrades required to integrate the Generation Facility and
Best Estimate of Upgrade Costs.
5. Effective Date. Term. Termination ana Disconnection.
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I.P.U.C. No. 29, Tariff No. 101 Page 2 of 9
5.1 Term of Agreement. Unless terminated earlier in accordance with the provisions
of this Agreement, this Agreement shall become effective on the date specified above and
remain effective as long as Seller's Generation Facility is eligible for service under Schedule 72.
5.2 Termination.
5.2.1 Seller may voluntarily terminate this Agreement upon expiration or
termination of an agreement to sell power to the Company.
5.2.2 After a Default, either Party may termina e t is Agreement pursuant to
Section 6. 5.
5. 2. 3 Upon termination or expiration of th s · greeme t, the Seller's Generation
Facility will be disconnected from the Company's t ansmissi nk.fstribution system. The
termination or expiration of this Agreement shall not relieve either. Party of its liabilities
and obligations, owed or continuing at the time of the termination. The provisions of this
Section shall survive termination or expiration of this Agreement.
5.3 Temporary Disconnection. Temporary disconnection shall contmue only for so
long as reasonably necessary under "Good Utility Practice." Good Utility Practice means any of
the practices, methods and acts e ~aged in or approved by a significant portion of the electric
industry during the relevant time e 10d or any of the practices, methods and acts which, in the
exercise of reasonable judgment i Ugh o t e facts known at the time the decision was made,
could have been expected to accorh >1i h he si ed result at a reasonable cost consistent with
good business practices, reliability, sa ty ana expe ition. Good Utility Practice is not intended
to be limited to the optimum practice, ethod, r . ct to lhfJ exclusion of all others, but rather to
be acceptable practices, methods, or ac s. g eral/y eoe ted in the region. Good Utility
Practice includes compliance with WECO o 'NERC requirements. Payment of lost revenue
resulting from temporary disconnection sha I governed by the power purchase agreement.
5.3.1 Emergency Conditions. ' mergency Condition" means a condition or
situation: (1) that in the judgment oft Party making the claim is imminently likely to
ClaRger life or property; or (2) that, in the case of the Company, is imminently likely (as
detet:mmed in a non-discriminatory manner) to cause a material adverse effect on the
security of, or damage to the Company's transmission/distribution system, the
Company s '11 rconnection Facilities or the equipment of the Company's customers; or
(3) that, in fhe case of the Seller, is imminently likely (as determined in a non­
discriminatory ner) to cause a material adverse effect on the reliability and security
f or damage t·, he Generation Facility or the Seller's Interconnection Facilities. Under
1Emergency Cond ions, either the Company or the Seller may immediately suspend
in erconnectie . ervice and temporarily disconnect the Generation Facility. The
Compan s a// notify the Seller promptly when it becomes aware of an Emergency
CondiUO(J tbat may reasonably be expected to affect the Seller's operation of the
Generation Facility. The Seller shall notify the Company promptly when it becomes
aware of an Emergency Condition that may reasonably be expected to affect the
Company's equipment or service to the Company's customers. To the extent
information is known, the notification shall describe the Emergency Condition, the extent
of the damage or deficiency, the expected effect on the operation of both Parties'
facilities and operations, its anticipated duration, and the necessary corrective action.
5.3.2 Routine Maintenance, Construction, and Repair. The Company may
interrupt interconnection service or curtail the output of the Seller's Generation Facility
Idaho Power Company Generator lnterconnf. "" Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 3 of 9
and temporarily disconnect the Generation Facility from the Company's
transmission/distribution system when necessary for routine maintenance, construction,
and repairs on the Company's transmission/distribution system. The Company will
make a reasonable attempt to contact the Seller prior to exercising its rights to interrupt
interconnection or curtail deliveries from the Seller's Facility. Seller understands that in
the case of emergency circumstances, real time operations of the electrical system,
and/or unplanned events, the Company may not be able to provide notice to the Seller
prior to interruption, curtailment or reduction of electrical energy deliveries to the
Company. The Company shall use reasonable efforts to coordinate such reduction or
temporary disconnection with the Seller.
5.3.3 Scheduled Maintenance. On or before January 31 of each calendar year,
Seller shall submit a written proposed maintenance schedule of significant Facility
maintenance for that calendar year and the Company and Seller shall mutually agree as
to the acceptability of the proposed sched lP.,. The Parties determination as to the
acceptability of the Seller's timetable for heduled maintenance will take into
consideration Good Utility Practices, ld ho Rower system requirements and the Seller's
preferred schedule. Neither Party s a/~ unreasonably withhold acceptance of the
proposed maintenance schedule.
5.3.4. Maintenance Coordination-... e Se r and the Company shall, to the
extent practical, coordinate their respJetive ansmissionldistribution system and
Generation Facility maintenance schedules such at they occur simultaneously. Seller
shall provide and maintain adequate protective Ul · ment sufficient to prevent damage
to the Generation Facility and Seller-furnished lnten n ction Facilities. In some cases,
some of Seller's protective relays will provide back-rotection for Idaho Power's
facilities. In that v.ent, Idaho Power will test such relay annually and Seller will pay the
actual cost o sue a a/ testing.
5. 3. 6 Adverse. Ggerating Effects. The Company shall notify the Seller as soon
as practicable if, base1:J o Good Utility Practice, operation of the Seller's Generation
Facility may cause disrup 10n or deterioration of service to other customers served from
the same electric system, or if operating the Generation Facility could cause damage to
the Company's transmission/distribution system or other affected systems. Supporting
documentation used to reach the decision to disconnect shall be provided to the Seller
upon request. If, after notice, the Seller fails to remedy the adverse operating effect
within a reasonable time, the Company may disconnect the Generation Facility. The
Company shall provide the Seller with reasonable notice of such disconnection, unless
the provisions of Article 5.3.1 apply.
5.3. 7 Modification of the Generation Facilitv. The Seller must receive written
authorization from the Company before making any change to the Generation Facility
that may have a material impact on the safety or reliability of the Company's
transmission/distribution system. Such authorization shall not be unreasonably withheld.
Modifications shall be done in accordance with Good Utility Practice. If the Seller makes
such modification without the Company's prior written authorization, the latter shall have
the right to temporarily disconnect the Generation Facility.
Idaho Power Company Generator Inter · · mection Agreement # 308
I.P.U.C. No. 29, Tariff No. 101 Page 4 of 9
5.3.8 Reconnection. The Parties shall cooperate with each other to restore the
Generation Facility, Interconnection Facilities, and the Company's
transmission/distribution system to their normal operating state as soon as reasonably
practicable following a temporary disconnection.
5.3.9 Voltage Levels. Seller, in accordance with Good Utility Practices, shall
minimize voltage fluctuations and maintain voltage levels acceptable to Idaho Power.
Idaho Power may, in accordance with Good Utility Practices, upon one hundred eighty
(180) days' notice to the Seller, change its nominal operating voltage level by more than
ten percent (10%) at the Point of Delivery, in which case Seller shall modify, at Idaho
Power's expense, Seller's equipment as necessary to accommodate the modified
nominal operating voltage level.
5. 4 Land Rights.
5.4.1 Seller to Provide Access. Seller hereby grants to ./daho Power for the
term of this Agreement all necessary rights-of-way and easements to install, operate,
maintain, replace, and remove Idaho Power's Metering Equipment, Interconnection
Equipment, Disconnection Equipment, Protection Eqf.!ipment and other Special Facilities
necessary or useful to this Agreement, including adequate and continuing access rights
on property of Seller. Seller warrants that lt has procured sufficient easements and
rights-of-way from third parties so as to provide Idaho Power with the access described
above. All documents granting such easements or rights-of-way shall be subject to
Idaho Power's approval and in recordable form.
5.4.2 Use of Public Rights-of-Way; The Parties agree that it is necessary to
avoid the adverse imvironmentai and operating impacts that would occur as a result of
duplicate electric lines being constructed in close proximity. Therefore, subject to Idaho
Power's compliance with Paragraph 5.4.4, Seller agrees that should Seller seek and
receive from any local, state or federal governmental body the right to erect, construct
and maintain Seller-furnished Interconnection Facilities upon, along and over any and all
public roads, streets and highways, then the use by Seller of such public right-of-way
shall be subordinate to any future use by Idaho Power of such public right-of-way for
construction and/or maintenance of electric distribution and transmission facilities and
Idaho Power may claim use of such public right-of-way for such purposes at any time.
Except as required by Paragraph 5.4.4, Idaho Power shall not be required to
compensate Seller for exercising its rights under this Paragraph 5.4.2.
5.4.3 Joint Use of Facilities. Subject to Idaho Power's compliance with
Paragraph 15.4.4, Idaho Power may use and attach its distribution and/or transmission
facilities to Seller's Interconnection Facilities, may reconstruct Seller's Interconnection
Facilities to accommodate Idaho Power's usage or Idaho Power may construct its own
distribution or transmission facilities along, over and above any public right-of-way
acquired from Seller pursuant to Paragraph 5.4.2, attaching Seller's Interconnection
Facilities to such newly constructed facilities. Except as required by Paragraph 5.4.4,
Idaho Power shall not be required to compensate Seller for exercising its rights under
this Paragraph 5.4. 3.
5.4.4 Conditions of Use. It is the intention of the Parties that the Seller be left in
substantially the same condition, both financially and electrically, as Seller existed prior
to Idaho Power's exercising its rights under this Paragraph 5.4. Therefore, the Parties
agree that the exercise by Idaho Power of any of the rights enumerated in Paragraphs
Idaho Power Company Generator lnterconne .>n Agreement# 308
I.P.U.C. No. 29. Tariff No. 101 Page 5 of9
5.4.2 and 5.4.3 shall: (1) comply with all applicable laws, codes and Good Utility
Practices, (2) equitably share the costs of installing, owning and operating jointly used
facilities and rights-of-way. If the Parties are unable to agree on the method of
apportioning these costs, the dispute will be submitted to the Commission for resolution
and the decision of the Commission will be binding on the Parties, and (3) shall provide
Seller with an interconnection to Idaho Power's system of equal capacity and durability
as existed prior to Idaho Power exercising its rights under this Paragraph 5.4.
6. Assignment. Liabilitv. lndemnitv, Force majeure. Consequential Damages and Default.
6. 1 Assignment. This Agreement may be assigned e · er Party upon twenty-one
(21) calendar days prior written notice and opportunity to o ifec by the other Party; provided
that:
6. 1. 1 Either Party may assign this Agr m t i 'h t the consent of the other
Party to any affiliate of the assigning Party with an qual or grea er credit rating and with
the legal authority and operational ability to satisfy the obliga r s f the assigning Party
under this Agreement.
6.1.2 The Seller shalf have the right to contingently assig
without the consent of the Company, for collateral security purposes to • in providing
financing for the Generation Facility, provided that the Seller wi/1 promptly notify the
Company of any such contingent assignment.
6.2 Limitation of Liabilitv. Each rty's liability to the other Party for any Joss, cost,
claim, injury, liability, or expense, including rea onable attorney's fees, relating to or arising from
any act or omission in its performance of this gr~ement, shall be limited to the amount of direct
damage actually incurred. In no event shall ·~her Party be liable to the other Party for any
indirect, special, consequential, or punitive damages, except as authorized by this Agreement.
6.3 Indemnity.
6.3.1 This provision protects each Party from liability incurred to third parties as
a result of carrying out the provisions of this Agreement. Liability under this provision is
exempt from the genera/limitations on liability found in Article 6. 2.
6. 3. 2 The Parties shall at all times indemnify, defend, and hold the other Party
harmless from, any and all damages, losses, claims, including claims and actions
relating to injury to or death of any person or damage to property, demand, suits,
recoveries, costs and expenses, court costs, attorney fees, and all other obligations by
or to third parties, arising out of or resulting from the other Party's action or failure to
meet its obligations under this Agreement on behalf of the indemnifying Party, except in
cases of gross negligence or intentional wrongdoing by the indemnified Party.
6.3.3 If an indemnified person is entitled to indemnification under this article as
a result of a claim by a third party, and the indemnifying Party fails, after notice and
reasonable opportunity to proceed under this article, to assume the defense of such
claim, such indemnified person may at the expense of the indemnifying Party contest,
Idaho Power Company Generator lnte1 . · mection Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 6 of 9
settle or consent to the entry of any judgment with respect to, or pay in full, such claim.
Failure to defend is a Material Breach.
6.3.4 If an indemnifying party is obligated to indemnify and hold any
indemnified person harmless under this article, the amount owing to the indemnified
person shall be the amount of such indemnified person's actual loss, net of any
insurance or other recovery.
6.3.5 Promptly after receipt by an indemnified person of any claim or notice of
the commencement of any action or administrative or legal proceeding or investigation
as to which the indemnity provided for in this article may apply, the indemnified person
shall notify the indemnifying party of such fact. Any failure of or delay in such notification
shall be a Material Breach and shall not affect a Party's indemnification obligation unless
such failure or delay is materially prejudicial to the indemnifying party.
6.4 Force Majeure. As used in this Agreement, "Force Majeure" or "an event of
Force Majeure" means any cause beyond the control of the Seller or bf the Company which,
despite the exercise of due diligence, such Party is unable to prevent or overcome. Force
Majeure includes, but is not limited to, acts of God, fire, flood, storms, wars, hostilities, civil
strife, strikes and other labor disturbances, earthquakes, fires, lightning, epidemics, sabotage, or
changes in law or regulation occurring after th~ Operation Date, which, by the exercise of
reasonable foresight such party could not reasonably have been expected to avoid and by the
exercise of due diligence, it shall be unable to overcome. If either Party is rendered wholly or in
part unable to perform its obligations under this Agreement because of an event of Force
Majeure, both Parties shall be excused from ·whatever pei1orinance is affected by the event of
Force Majeure, provided that:
(1) The non-performing Party shall, as soon as is reasonably possible after
the occurrence of the Force Majeure~ give the other Party written notice describing the
particulars of the occurrence.
(2) The suspension of performance shall be of no greater scope and of no
longer duration than is required by the event of Force Majeure.
(3) No obligations of either Party which arose before the occurrence causing
the suspension of performance and which could and should have been fully performed
before such occurrence shall be excused as a result of such occurrence.
Idaho Power Company Generator lnterconne m Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 7 of 9
6. 5 Default and Material Breaches.
6. 5. 1 Defaults. If either Party fails to perform any of the terms or conditions of
this Agreement (a "Default" or an "Event of Default'?, the nondefaulting Party shall cause
notice in writing to be given to the defaulting Party, specifying the manner in which such
default occurred. If the defaulting Party shall fail to cure such Default within the sixty
(60) days after service of such notice, or if the defaulting Party reasonably demonstrates
to the other Party that the Default can be cured within a commercially reasonable time
but not within such sixty (60) day period and then fails to diligently pursue such cure,
then, the nondefaulting Party may, at its option, terminate ht Agreement and/or pursue
its legal or equitable remedies.
6. 5. 2 Material Breaches. The notice and a re nro isions in Paragraph 6. 6. 1 do
not apply to Defaults identified in this Agree e as at rial Breaches. Material
Breaches must be cured as expeditiously as ossible 'folio ing occurrence of the
breach.
7. Insurance.
During the term of this Agreement, Seller shall secure and continuously
insurance coverage:
the following
7. 1 Comprehensive Ge era/ Liability Insurance for both bodily injury and property
damage with limits equal to $1,00D,OOG each occurrence, combined single limit. The deductible
for such insurance shall be consiste w·t G rrent Insurance Industry Utility practices for similar
property.
7. 2 The above insurance c v:
an A.M. Best Company rating of A-or be
(a) An endorsement na i g Idaho Power as an additional insured and loss
payee as applicable; and
(b) A provision stating that s'-'ch policy shall not be canceled or the limits of
lta11i/ity, reduced without sixty (60) days' prior written notice to Idaho Power.
Seller to otifv Idaho Power of Loss of Coverage -If the insurance coverage
Paragraph 7. shall lapse for any reason, Seller will immediately notify Idaho Power
in writing. e notice wil advise Idaho Power of the specific reason for the lapse and the steps
Seller is taking o rei state the coverage. Failure to provide this notice and to expeditiously
reinstate or rep/aGe he coverage will constitute grounds for a temporary disconnection under
Section 5.3 and wl/ be a Material Breach.
8. Miscellaneous.
8. 1 Governing Law. The validity, interpretation and enforcement of this Agreement
and each of its provisions shall be governed by the laws of the state of Idaho without regard to
its conflicts of law principles.
8.2 Salvage. No later than sixty (60) days after the termination or expiration of this
Agreement, Idaho Power will prepare and forward to Seller an estimate of the remaining value
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I.P.U.C. No. 29, Tariff No. 101 Page 8 of 9
of those Idaho Power furnished Interconnection Facilities as required under Schedule 72 and/or
described in this Agreement, less the cost of removal and transfer to Idaho Power's nearest
warehouse, if the Interconnection Facilities will be removed. If Seller elects not to obtain
ownership of the Interconnection Facilities but instead wishes that Idaho Power reimburse the
Seller for said Facilities the Seller may invoice Idaho Power for the net salvage value as
estimated by Idaho Power and Idaho Power shall pay such amount to Seller within thirty (30)
days after receipt of the invoice. Seller shall have the right to offset the invoice amount against
any present or future payments due Idaho Power.
9. Notices.
9.1 General. Unless otherwise provided in this Agreement, any written notice,
demand, or request required or authorized in connection with this Agreement ("Notice") shall be
deemed properly given if delivered in person, delivered by recognized national currier service,
or sent by first class mail, postage prepaid, to the person specified below:
If to the Seller:
Seller:-------------------------
Attention:---------------------------Address: _______________________________ _
City: ____________ S.tate: ____ .Zip: ________ _
Phone: Fax:
If to the Company:
Idaho Power Company -Delivery
Attention: Operations Manager
1221 W. Idaho Street
Boise: Idaho 83702
--------------
Phone: [phone] Fax: [phone]
9.2 Billing and Payment. Billings and payments shall be sent to the addresses set
out below:
Seller: ---------------------------------------------
Attehtion: ---------------------------Address: _______________________________ _
City: ______________ State: _____ .Zip: _________ _
Phone: Fax:
Idaho Power Company -Delivery
Attention: Corporate Cashier
PO Box 447
Salt Lake City Utah 8411 0-044 7
---------------
Phone: [phone] email: [e-mail]
9.3 Designated Operating Representative. The Parties may also designate
operating representatives to conduct the communications which may be necessary or
convenient for the administration of this Agreement. This person will also serve as the point of
contact with respect to operations and maintenance of the Party's facilities.
Idaho Power Company Generator lnterconne Jn Agreement# 308
I.P.U.C. No. 29, Tariff No. 101
Seller's Operating Representative:
Seller:-----------------------­
Attention:
Page 9 of 9
----------------------------Address: __________________________ __
City: ____________ S.tate: ____ ,Zip: ____ _
Phone: Fax: ---------
Company's Operating Representative:
Idaho Power Company -Delivery
Attention: Regional Outage Coordinator-Regional Dispatch
1221 W. Idaho Street
Boise, Idaho 83702
Phone: [phone], or 388-5175 during regular business hours
(after hours Southern Region 208-388-5190).
9.5 Changes to the Notice Information,
giving five (5) Business Days written notice pr:"cfr t
10. Signatures.
IN WITNESS WHEREOF, the Parties have caus d
respective duly authorized representatives.
For the Seller
For the Compa y
Name:
Title: Manager, Grid Operatic· s
Date:
Idaho Power Company Generator Intel .mection Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 3
Attachment 1
Description and Costs of the Generation Facility, Interconnection Facilities and Metering
Equipment
In this attachment the Generation Facility and Interconnection Facilities, including Special
Facilities and upgrades, are itemized and identified as being owned by the Seller or the Company. As
provided in Schedule 72, Payment For Interconnection Facilities, the Company will provide a best
estimate itemized cost of its Interconnection Facilities, including Special Facilities, upgrades and
Metering Equipment.
General Facility Description
The proposed project will connect to Idaho Power's 12.5kV system on Idaho Power Company's
Buckhorn (BKHN-041) distribution line. The total project output is 1.2 MW.
Interconnection Point
The Interconnection Point for the Double B Dairy Digester Project will be the low-side bushings on the
pad mounted transformer (DB 1 ). The project's location is iil T12S R21 E Section 18 of Cassia County,
Idaho. A drawing identifying the Point of Interconnection is included as Attachment 2. The Point of
Change of Ownership will be the low-side bushings on the pad mounted transformer (DB 1 ).
Seller's Interconnection Facilities
The Seller will install generators, low-side disconnect switches, all wiring and conduit between the
generators and the padmounted transformer, appropriate grounding measures, and associated
auxiliary equipment. The Seller will build underground facilities to the Point of Change of Ownership for
the generator facility. The low-side disconnect switch should be visible, lockable, within ten (1 0) feet of
the padmounted transformers, and accessible to Idaho Power personnel.
The Seller will install equipment to receive signals from Idaho Power Company Grid Operations for
Generator Output Limit Control ("GOLC") -see Attachment 4 Operating Requirements.
The Seller will provide phone service to IPCo's generator interconnect package as described in
Telecommunications below.
All interconnection equipment electrically located on the generator side of the Point of Change
Ownership shall be owned and maintained by the Seller.
Other Facilities Provided by Seller
Telecommunications
In addition to communication circuits that may be needed by the Seller, the Seller shall provide the
following communication circuits for Idaho Power's use:
1. One POTS (Plain Old Telephone Service) dial-up circuit for revenue metering at the generation
interconnection site.
2. One DDS (Digital Data Service) circuit guaranteed minimum data rate of 19,200 bits per second for
SCADA between the generation interconnection site and a point designated by Idaho Power
Company.
The Seller is required to coordinate with the local communications provider to provide the
communications circuits and pay the associated monthly charges. The communication circuits will
need to be installed and operational prior to generating into Idaho Power system. Note that installation
by the local communications provider may take several months and should be ordered in advance to
avoid delaying the project. If the communication circuit types listed above are not available at the site
by the local communications provider, the Seller shall confer with Idaho Power.
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I.P.U.C. No. 29, Tariff No. 101 Page 2 of 3
If high voltage protection is required by the local communications provider for the incoming cable, the
high voltage protection assembly shall be engineered and supplied by the Seller. Options are available
for indoor or outdoor mounting. The high voltage protection assembly shall be located in a manner that
provides Idaho Power 24-hour access to the assembly for communications trouble-shooting of Idaho
Power owned equipment.
Ground Fault Equipment
The Seller will install ground fault limiting equipment that will limit the zero sequence fault current to 20
amps at the Interconnection Point.
Monitoring Information
If the Interconnection Customer requires the ability to monitor i
recloser in the generation interconnection package th
communications circuit to the control box.
Easements
related to the Idaho Power
to supply their own
The Seller will secure underground and overhead easements with Double B Dairy o route
is determined. The Seller will provide to IPCO a surveyed (Metes & Bounds) legal d ption along
with exhibit map for IPCO's facilities. After the legal description has been delivered to IPCO for review,
IPCO will supply to the Seller a completed IPCO easement for signature by the land owner of record.
Once the signatures have been secured, the Seller will return the signed easement to IPCO for
recording. IPCO construction will not proceed until the appropriate easements are secured.
Idaho Power Company's Interconnection Facilities
Idaho Power will install a stangard generation interconnection package on the existing distribution
feeder (BKHN-041) on priva e rop-eFty southwest of the intersection of 1200 South and 1100 West in
Cassia County, Idaho. tie ew intercb nection package will include four distribution poles to mount a
local service transformer olid blade d1 connects, primary metering package, recloser, relays, fuses
and riser necessary fo the package. The interconnection will be controlled by a SEL-311 C line
protection relay. The rea will be lc:>cate in a pole mounted enclosure and will also contain a test
switch (TS4), SLSS, mo em ispJati n iht rfac , power supply, DC converter, control switch and surge
protector.
Idaho Power will install (and subsequently own and maintain) one 1500 kVA 277/480 to 12.47 kV
Grounded Wye I Grounded Wye padmeunted transformer on top of a vault. Conduit and underground
cables will be installed from the intercen ction package to padmounted transformer. Protective posts
will be installed to protect the ground mo nted equipment from damage.
A 2" conduit will be installed alongside the underground primary to facilitate information exchange to the
customer about the recloser. (The Interconnection Customer is responsible for providing and installing
the appropriate cable).
All interconnection equipment electrically located on the utility side of the Point of Change Ownership
shall be owned, operated, and maintained by Idaho Power.
Idaho Power Company Generator lntea · · -.1nection Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 3 of 3
Estimated Cost & Ownership: The following good faith estimates are provided in 2010 dollars
--===='""-----_____ ......... .......,..._-¥~=h~·... Cost Estimate
,Ge1Zp ·«!:Jo'! f.acilit]!s~ _ r­seller
I Jl!O~~ed by Seller $NIA'
fnterconnection FaciJitie_s:
I iQyer~e(ld_G~ne!atio~ IJ?.!e!C~!lll:ec;ticm P!ic;~_(lg~ . _.
U!l4t:rgrounA_~q~ip~en~_and.1~90 kY A: Tr(lll~fo~er
liP CO
:IPCO
-~2Q0!9Q9!
$45,000
TOTAfr-~ -~~===~ ...... ~==.;,$2=4=slk:,o~oo
-~ ___ _!!__JJOJECTGRAND TOTAL . S_~E.A-_TT~CHMENT 6:
Full payment is required up front in accordance with Section 9; unless payment arrangements are
made in advance with Idaho Power Operations Finance.
Billing for construction activities will be based upon actual expenditures.
Idaho Power Company Generator lnterconnE. on Agreement# 307
I.P.U.C. No. 29. Tariff No. 101 Page 1 of 1
Attachment 2
One-line Diagram Depicting the Small Generation Facility, Interconnection Facilities, Metering
Equipment and Upgrades
Idaho Power Company Generator Inter . · .mection Agreement# 307
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 1
Attachment 3
Milestones:
ate ilel)tones
9/16/10 !Final FSR submitted to Seller
I TBD !Construction Funds received by IPCO
------· -~ ·-__ __,
,_ . --·----------·---.. ----···--·----------·--·----··-···---.,
I 5 Months from Construction Funds i/PCO Construction Complete
_ __ _ _R~ce!v_e~ ~y_I_~_QQ __ __ , _ .. ____ _. . .... _ .. ·------. ________ _
1 Month from IPCO Construction 11PCO Commissioning Complete
[' ____ !~o b'e_p~ovi-dedcb~m~~~~~ at a later datef-comme--rc;iii Op-;,.atioii -----·= -~-~~~-~-~-_ . ~--·----· 1
Agreed to by:
For the Seller: ___________________________ Date ____________ _
For the Transmission Provider
Idaho Power Company, Delivery ___________________________ Date ____________ _
Idaho Power Company Generator lnterconm on Agreement# 307
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 1
Attachment 4
Additional Operating Requirements for the Company's Transmission System and Affected
Systems Needed to Support the Seller's Needs
The Company shall a/so provide requirements that must be met by the Seller prior to initiating
parallel operation with the Company's Transmission System.
Operating Requirements
The project is required to comply with the applicable Voltage and Current Distortion Limits found in
IEEE Standard 519-1992 IEEE Recommended Practices and Requirements for Harmonic Control in
Electrical Power Systems or any subsequent standards as they may be updated from time to time.
Seller will be able to modify power plant facilities on the generator side of the Interconnection Point with
no impact upon the operation of the transmission syste whenever the generation facilities are
electrically isolated from the transmission system and a te inal clearance is issued by Idaho Power
Company's Grid Operator.
Voltage flicker at startup and during operation wi I b limited to ess than 5% as measured at the
Interconnection Point. For this to occur, the current nnot exceed 657\.mps during start up at the 12.5
kV voltage level. This forces the generating facility to start he en· raters separately.
Low Voltage Ride Through
The Project must be capable of riding through faults on adjacent section of the power system without
tripping due to low voltage. It has been determined, through study, ~:tat e Project must be capable of
remaining interconnected for flY ·ngle phase voltage as low as 0. 7 P for 30 cycles, and for all three
phase voltages as low as 0. P or cycles.
that provide a ground source to the transmission
Generator Output Limit Co UQI Re-dispatch" or. GOLC")
The Project will be subject to eCiuctions directed y Idaho Power Company Grid Operations during
transmission system contingenci and other reliability events. When these conditions occur, the
Project will be subject to Generat r Qutput Limit Control ("GOLC") and have equipment capable of
receiving signals from Idaho Power for: QLC. Generator Output Limit Control will be a setpoint from
Idaho Power to the Project indicating maximum output allowed during transmission contingencies.
Commercial Operation Requirements
The Seller will be granted a requested Commercial Operation date only when all requirements have
been met under this GIA and Idaho Power Company's Power Sales Agreement.
Idaho Power Company Generator Inter· . mection Agreement# 307
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 1
Attachment 5
Reactive Power Requirements
The project must be controlled to operate at unity power factor +/-XXX kVar. Voltage flicker at startup
and during operation will be limited to less than 5% as measured at the Interconnection Point.
Idaho Power Company Generator lnterconne >n Agreement# 307
I.P.U.C. No. 29. Tariff No. 101 Page 1 of 1
Attachment 6
Company's Description of Special Facilities and Upgrades Required to Integrate the Generation
Facility and Best Estimate of Costs
As provided in Schedule 72 this Attachment describes Upgrades, Special Facilities, including
Network Upgrades, and provides an itemized best estimate of the cost of the required facilities.
Distribution Upgrades
n/a
Distribution Uf!g_rades.~. ___ .
na
Ifl~er~o_n~~:ect!~n . Cf!_Sts_ (fro!" Attachme'!:t_l)
Upgrades
$245,0001
---1
·-·------·----------' --------
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 26
CERTIFICATION OF AUTHORITY FOR AGENTS
I, LAURA KNOTHE, the duly authorized and appointed MANAGER of The New Energy
Company, LLC ("Company"), HEREBY REPRESENT, WARRANT, AND CERTIFY to Idaho Power
Company that the following are authorized and empowered, for and on behalf of the Company, to execute
instruments, agreements, certificates, and other documents (collectively ''Documents") and to take actions
on behalf of the Company, and that Idaho Power Company and its direetors, officers, employees, and
agents are entitled to consider and deal with such persons as agents of the Company for all purposes, until
such time as an authorized officer of the Company shall have delivered to Idaho Power Company a notice
in writing stating that such person is and shall not longer be an agent on behalf of the Company. Any
Documents executed by such persons shall be deemed duly authorized by the Company for all purposes.
Name of Company:
Name ofProject(s):
Three, LLC)
The New Energy Company, LLC
8720 Vic Lane
Middleton, ID 83644
Swager Farms (New Energy Two, LLC) and Double B Dairy (New Energy
Leslie White Manager
Laura Knothe Manager
IN WITNESS WHEREOF, I have hereunto signed my name this _1_8_ day of October
.:1
Print Name: Laura Knothe
Title: Manager
I, Kara Godfrey, HEREBY CERTIFY, that Laura Knothe is the duly elected and acting
Manager of the Company and that the signature appearing above is his/her signature.
IN WITNESS WHEREOF, I have hereunto signed my name this J.C-Jtay of Cd-obv-..2o..Q_.
~ ; ) { t/ V . ~ ]
Print Name: nAt< A 6 [.i'J>~G1
Title: ~ .Q\1\$)\.L~.J:.
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 27
Clark, Danielle
From: Bauer, Rich
Sent:
To:
Cc:
Tuesday, November 29, 2011 10:31 AM
'lwh ite@exergydevelopment. com'
Bishop, Rowena
Subject: RE: Double B GIA
Attachments: Attachment XX -Gen lnt Control Req.docx
As to 5.3.9, we would give you notice that we are going to change the nominal voltage in 180 days. You would have the
180 days to modify your facilities if required. As you have indicated, since Idaho will own the transformer, the only effect
on you would be if we changed the secondary voltage level. I cannot think of a reason that we would change the
secondary voltage level on this project. In some older installations, if we were to upgrade the primary voltage level, we
would have to change the secondary voltage configuration to a 277/480 volt configuration. You already have that
configuration, so no change would be required.
As to the GOLC. We will give you a analog setpoint via DNP 3.0 protocol that will indicate the maximum MW allowed.
The reliability events include transmission /distribution outages and excess generation on the system. I am including a
attachment that gives a little more detail on the GOLC control.
Rich Bauer
Manager Grid Operations
Idaho Power Company
208-388-5669
IDAHO POWER
M IDAC~P comcanv
From: Bishop, Rowena
Sent: Monday, November 28, 2011 4:21PM
To: Bauer, Rich
Subject: FW: Double B GIA
Rich,
Will you respond to Leslie White about her GIA questions below? thx
Rowena Bishop
Oyerations .J\.na{yst
Intercfiange Oyerations -cfiq 4
'Ext. 388-2658
From: Leslie White [mailto:[e-mail]]
Sent: Monday, November 28, 201112:04 PM
To: Bishop, Rowena
Cc: Josh Gunderson
Subject: Double B GIA
Hello Rowena,
1
Can you provide some insight on the wording in section 5.3.9. Does the section copied below mean that Idaho
Power may upgrade the voltage on the line and at that time IP would provide us with 6 months notice and we
would be responsible to make the changes to our facility, but at IP's expense. (What is the timeframe we are
allowed to make the required changes?) Does it appear that since Idaho Power owns the transformer, this type
of change may require some protection changes or grounding changes but relatively minor upgrades within our
battery limits?
5.3.9 Voltage Levels. Seller, in accordance with Good Utility Practices, shall mm1m1ze voltage
fluctuations and maintain voltage levels acceptable to Idaho Power. Idaho Power may,
in accordance with Good Utility Practices, upon one hundred eighty {180} days' notice to
the Seller, change its nominal operating voltage level by more than ten percent (10%} at
the Point of Delivery, in which case Seller shall modify, at Idaho Power's expense, Seller's
equipment as necessary to accommodate the modified nominal operating voltage level.
Also Rowena the requirements around GOLC seem to be new. Can you give some detail about the setpoint (as I
need to make sure this type of control is inherent in our engine control package) and what other reliability
events we can expect.
Generator Output Limit Control ("Re-dispatch" or "GOLC")
The Project will be subject to reductions directed by Idaho Power Company Grid Operations during transmission
system contingencies and other reliability events. When these conditions occur, the Project will be subject to
Generator Output Limit Control ("GOLC") and have equipment capable of receiving signals from Idaho Power for
GOLC. Generator Output Limit Control will be a setpoint from Idaho Power to the Project indicating maximum
output allowed during transmission contingencies.
Thank you for your time and consideration on these points.
Leslie
Leslie White
802 W Bannock, 12th Floor Boise, 10 83702
Office: 208.336.9793 [ Mobile: [phone]
W.W~Y/2.?<:~WYGeY.£?!9P.DJ..~D.t.09.m
This e!ect:onic or printed document contains information which (a) may be LEGALLY PRIVILEGED, PROPRIETARY IN NATURE, OR OTHERWISE PROTECTED
BY LAW FROM DISCLOSURE, and (b) :s intended only for the use of the Addressee(s) named above. If the reader of this message is not tl1e intended recipient
or the employee or agent responsible to deliver it to the intended recipient. you a1e hereby notified that any dissemination, distribution or copying of this
cornmunicat!on is strictly prohibit\'ld If you have received this communication in en or, please immediately notify \IS by telephone. and return tile original message
to us at the above emaii address. Thank you.
2
Generation Interconnection Control Requirements
Generator Output Limit Control (GOLC)
• IPC requires Interconnected Power Producers to accept GOLC signals from our EMS.
• The GOLC signals will consist of two points shared between the IPC EMS and the Customer's Generator
Controller:
1. GOLC Setpoint: An analog output that contains the MW value the Customer should curtail to, should a
GOLC request be made via the GOLC On/Off discrete output Control point.
• An Analog Input feedback point must be updated (to reflect the GOLC setpoint value) by the
Customer Controller upon the Controller's receipt of the GOLC setpoint change, with no intentional
delay.
2. GOLC On/Off: A discrete output (DO) control point with latching Off/On states. Following a "GOLC On"
control, the Customer Controller will run power output back to the MW value specified in the GOLC
Setpoint. Following a "GOLC Off" control, the Customer is free to run to maximum possible output.
• A Discrete Input feedback point must be updated (to reflect the GOLC DO state) by the Customer
Controller upon the Controller's receipt of the GOLC DO state change, with no intentional delay.
• If a GOLC control is issued, it is expected to see MW reductions start within 1 minute and plant output to be
below the GOLC Setpoint value within 10 minutes.
Voltage Control
• IPC requires Interconnected Power Producers to accept Voltage Control signals from our EMS when they are
connected to our transmission system.
• The voltage control will consist of one setpoint shared between the IPC EMS and the Customer Controller.
• The setpoint will contain the desired target voltage for the plant to operate at.
• The control will always be active, there is no digital supervisory point like the Curtail On/Off control above.
• When a setpoint change is issued an Analog Input feedback point must be updated (to reflect the
Voltage Control setpoint value) by the Customer Controller upon the Controller's receipt ofthe
Voltage Control setpoint change, with no intentional delay.
• When a set point change is received by the Customer Controller, the Voltage Control system should
react with no intentional delay.
• The voltage control system should operate in a dead band of +/-5% of the control setting range.
• The wind parks should supervise this control by setting up "reasonability limits", i.e. configure a reasonable
range of values for this control to be valid. As an example, they will accept anything between .95 and 1.05 for
the set point. In the case they are fed an erroneous value outside this range, their control system defaults to
the last known, good value.
Generation Interconnection Data Points Requirements
Digital Inputs (DNP Obj. 01 , Var. 2)
Index Description State (0/1) Comments:
0 52A Customer Total Breaker Open/Closed Sourced at substation
1 GOLC Off/On Control Received (Feedback) Off/On Provided bv Customer
Digital Outputs (DNP Obj. 10, Var. 1)
Index Description Comments:
0 GOLC Off/On Provided by I PCO
NOTE: GOLC Setpoint indicates MW value to curtail to when GOLC Off/On DO is ON.
Analog Inputs (DNP Obj. 30, Var. 2)
Raw Raw EU EU
Index Description High Low High EU Low Units Comments:
0 GOLC Setpoint Value Received (Feedback) 32767 -32768 TBD TBD MW Provided by Customer
1 Voltage Control Setpoint Value Rec'd (Feedback) 32767 -32768 TBD TBD kV Provided by Customer
2 Maximum Park Generating Capacity* 32767 -32768 TBD TBD MW Provided by Customer
v2 11/02/2011
..
3 Number of Turbines In High Speed Cutout* 32767 -32768 32767 -32768 Units Provided by Customer
4 Ambient Temperature* 32767 -32768 327.67 -327.68 Fore Provided by Customer
5 Wind Direction* 32767 -32768 3276.7 -3276.8 Deg Provided by Customer
MPH
6 Wind S_p_eed* 32767 -32768 327.67 -327.68 or m/s Provided by Customer
Analog Outputs (DNP Obj. 40, Var. 2)
Raw Raw EU EU
Index Description High Low High EU Low Units Comments:
0 GOLC Setpoint 32767 -32768 TBD TBD MW Provided by IPCO
1 Voltage Control Setpoint 32767 -32768 TBD TBD kV Provided by IPCO
NOTE: Curtailment Setpoint indicates MW value to Curtail to when Curtailment Off/On DO is ON.
*-Data requ1red from W1nd Customers
v2 11/02/2011
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 28
Clark, Danielle
From: Bishop, Rowena
Sent:
To:
Wednesday, February 29, 2012 11:24 AM
'Leslie White'
Cc:
Subject:
Hi Leslie)
Bauer, Rich; Hackett, Eric
RE: Double B status??
The GI process requires Idaho Power to finalize the GIAJ and that is why I am asking for the
in service date. To clarify) I am asking when you want to begin to put test energy on our
system) and the milestones are based on the date you provide. I'm sure the Project Leader
is waiting for this information to schedule our resources) consider outages in the areaJ etc.
Thank you.
Rowena Bishop
Operations Analyst
Interchange Operations -chq 4
Ext. 388-2658
-----Original Message-----
From: Leslie White [mailto:[e-mail]]
Sent: Tuesday) February 28J 2e12 12:41 PM
To: Bishop) Rowena
Subject: RE: Double B status??
Hello Rowena)
I appreciate your attention given to the schedule. Is the verific~tion of the milestones and
inservice date needed for scheduling of construction within Idaho Power or with IP
contractors?
Leslie White
8e2 W Bannock) 12th Floor BoiseJ ID 837e2
Office: 2e8.336.9793 Mobile: 2e8.89e.466e www.exergydevelopment.com
This electronic or printed document contains information which (a) may be LEGALLY PRIVILEGED)
PROPRIETARY IN NATUREJ OR OTHERWISE PROTECTED BY LAW FROM DISCLOSURE) and (b) is intended
only for the use of the Addressee(s) named above. If the reader of this message is not the
intended recipient) or the employee or agent responsible to deliver it to the intended
recipient) you are hereby notified that any dissemination) distribution or copying of this
communication is strictly prohibited. If you have received this communication in errorJ
please immediately notify us by telephone) and return the original message to us at the above
email address. Thank you.
-----Original Message-----
From: Bishop) Rowena [mailto:[e-mail]]
Sent: Friday) February 24J 2e12 3:e3 PM
To: Leslie White
Cc: Hackett) Eric
Subject: Double B status??
Leslie)
1
Please bring me up to speed on Double B Dairy-I've attached one of the messages Rich
responded to you about questions to the GIA. I'd like to verify the milestones and determine
your inservice date for Double B Dairy.
I am available next week. I look forward to hearing from you soon!
Rowena Bishop
Operations Analyst-Grid Operations
Idaho Power Company/ CHQ 4/1221 W. Idaho Street Boise, ID 837B2
Ph: 2B8-388-2658 Fax: 2B8-388-SSB4
2
Bishop, Rowena
From: Bauer, Rich
Sent:
To:
Cc:
Tuesday, November 29, 201110:31 AM
'[e-mail]'
Bishop, Rowena
Subject: RE: Double B GIA
Attachments: Attachment XX -Gen lnt Control Req.docx
As to 5.3.9, we would give you notice that we are going to change the nominal voltage in 180 days. You would have the
180 days to modify your facilities if required. As you have indicated, since Idaho will own the transformer, the only effect
on you would be if we changed the secondary voltage level. I cannot think of a reason that we would change the
secondary voltage level on this project. In some older installations, if we were to upgrade the primary voltage level, we
would have to change the secondary voltage configuration to a 277/480 volt configuration. You already have that
configuration, so no change would be required.
As to the GOLC. We will give you a analog setpoint via DNP 3.0 protocol that will indicate the maximum MW allowed.
The reliability events include transmission /distribution outages and excess generation on the system. I am including a
attachment that gives a little more detail on the GOLC control.
Rich Bauer
Manager Grid Operations
Idaho Power Company
208-388-5669
lr:w«J POWER .
From: Bishop, Rowena
Sent: Monday, November 28, 2011 4:21 PM
To: Bauer, Rich
Subject: FW: Double B GIA
Rich,
Will you respond to Leslie White about her GIA questions below? thx
Rowena Bishop
Oyera.tions .Jlna.{yst
Intercfia.nge Oyerations -cfiq 4
Xxt. 388-2658
From: Leslie White [mailto:[e-mail]
Sent: Monday, November 28, 2011 12:04 PM
To: Bishop, Rowena
Cc: Josh Gunderson
Subject: Double B GIA
Hello Rowena,
1
Can you provide some insight on the wording in section 5.3.9. Does the section copied below mean that Idaho
Power may upgrade the voltage on the line and at that time IP would provide us with 6 months notice and we
would be responsible to make the changes to our facility, but at IP's expense. (What is the timeframe we are
allowed to make the required changes?) Does it appear that since Idaho Power owns the transformer, this type
of change may require some protection changes or grounding changes but relatively minor upgrades within our
battery limits?
5.3.9 Voltage Levels. Seller, in accordance with Good Utility Practices, shall mm1m1ze voltage
fluctuations and maintain voltage levels acceptable to Idaho Power. Idaho Power may,
in accordance with Good Utility Practices, upon one hundred eighty (180) days' notice to
the Seller, change its nominal operating voltage level by more than ten percent (10%) at
the Point of Delivery, in which case Seller shall modify, at Idaho Power's expense, Seller's
equipment as necessary to accommodate the modified nominal operating voltage level.
Also Rowena the requirements around GOLC seem to be new. Can you give some detail about the setpoint (as I
need to make sure this type of contrails inherent in our engine control package) and what other reliability
events we can expect.
Generator Output Limit Control ("Re-dispatch" or "GOLC")
The Project will be subject to reductions directed by Idaho Power Company Grid Operations during transmission
system contingencies and other reliability events. When these conditions occur, the Project will be subject to
Generator Output Limit Control ("GOLC") and have equipment capable of receiving signals from Idaho Power for
GOLC. Generator Output Limit Control will be a setpoint from Idaho Power to the Project indicating maximum
output allowed during transmission contingencies.
Thank you for your time and consideration on these points.
Leslie
Leslie White
802 W Bannock, 12th Floor Boise, ID 83702
Office: 208.336.9793 I Mobile: [phone]
'!!f.':t"fV_,_~~~r9YQ~1Je!qgm~n_t9_9_1'!.1
Thts electronic or printed document contains information which (a) may be LEGALLY PRIVILEGED, PROPRIETARY IN NATURE, OR OTHERWISE PROTECTED
BY LAW FROM DISCLOSURE, and (b) is Intended only for the use of the Addressee(s) named above. If lhe reader of this message is not the intended recipient.
or the employee or agent responsible to deliver il to the intended recipient, you are hereby notified that any dissemination, distribution or copying of this
communication is striclly prohibited. If you have received this communication in error. please immediately notify us by telephone, and return the original message
to us at the above email address, Thank you.
2
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 29
Leslie White
Exergy Development Group of Idaho, LLC
802 W Bannock, Suite 1200
Boise, ID 83702
Re: Double B Dairy Project-GI# 308
Dear Leslie:
An IOACORP Company
May 9, 2012
Via Email I Certified 70111150000201961878
As you are aware, Idaho Power offered a Draft GIA ("DGIA") to the Double B Dairy project by letter
dated September 28, 2011. Since then, Idaho Power received and responded to your technical questions
to the DGIA for GOLC ("Generator Output Limit Control") among others. Idaho Power was also notified
by you that Exergy was working on the financial arrangements for the project. The next step in the
Generator Interconnection process is to finalize the Generator Interconnection Agreement.
Attached please find a draft Generator Interconnection Agreement (GIA) for your Generator
Interconnection project. Please review the GIA Attachments to make sure they are comprehensive and
accurate and advise me of any changes as soon as possible.
Although the preferred method of funding is full payment upfront; payment arrangements may be
requested. If you have not already done so, please contact Aubrae Sloan (208-388-5697), Operations
Finance at your earliest convenience to discuss Idaho Power's credit requirements for construction
funding. Once we receive funding, or the credit requirement is met, we can proceed with construction of
the project. The actual construction and labor charges will be reconciled approximately 90 days
subsequent to project completion.
In order to prepare the GIA for execution, please provide the following items to me as soon as possible:
I. Your requested in service date to complete Attachment 3 of the GIA.
2.Insurance certification pursuant to Section 7 of the GIA (certificate, I endorsement for Additional
insured, and I for the cancellation notice)
3.Proof of Site Control for the project
4. Financ,ial arrangements approved by Idaho Power credit department, or full payment for construction
Failure to submit all of the requested items to me by June 11, 2012 will cause your Generator
Interconnection request to have been deemed withdrawn. Please contact me at your earliest convenience
with any questions at 208-388-2658.
Encl: Draft GIA for Double B Dairy Project# 308
Cc: (via email) Eric Hackett/IPC
Rich Bauer/IPC
Aubrae Sloan/IPC
Sincerely,
Josh Harris
Operations Analyst
[e-mail]
P.O. Box 70 (83707)
122 1 w. Idaho St.
Boise, 10 83702
Idaho Power Company Generator lnten ·nection Agreement# 308
I.P.U.C. No. 29 Tariff No. 101
·May 9, 2012
GENERATOR INTERCONNECTION AGREEMENT
Schedule 72
DOUBLE B DAIRY DIGESTE·R PROJECT
1.2MW
Idaho Power Company Generator lnt· ~onnection Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 1
TABLE OF CONTENTS
RECITALS .............................................................................................................................................. 1
AGREEMENTS ...................................................................................................................................... 1
1. Capitalized Terms ................................................................................................................ 1
2. Terms and Conditions .......................................................................................................... 1
3. This Agreement is not an agreement to purchase Seller's power ......................................... 1
4. Attachments ......................................................................................................................... 1
5. Effective Date, Term, Termination and Disconnection .......................................................... 1
6. Assignment, Liabilitv. lndemnitv. Force majeure, Consequential Damages and Default. ...... 5
7. Insurance ............................................................................................................................. 7
8. Miscellaneous ...................................................................................................................... 7
9. Notices ................................................................................................................................. 8
1 0. Signatures ............................................................................................................................ 9
Attachment 1 .......................................................................................................................................... 1
Attachment 2 .......................................................................................................................................... 1
Attachment 3 .......................................................................................................................................... 1
Attachment 4 .......................................................................................................................................... 1
Attachment 5 .......................................................................................................................................... 1
Attachment 6 .......................................................................................................................................... 1
Idaho Power Company Generator lnterconn 'ion Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 9
This Generator Interconnection Agreement ("Agreement") under Idaho Power Company's
Schedule 72 is effective as of the day of , 2012 between
_____________ , ("Seller", "Customer" or "The Project") and Idaho Power Company
("Company", "Idaho Power", "I PC", "IPCO" or "Transmission Owner").
RECITALS
A. Seller will own or operate a Generation Facility that qualifies for service under Idaho
Power's Commission-approved Schedule 72 and any successor schedule.
B. The Generation Facility covered by this Agreement is more particularly described in
Attachment 1.
AGREEMENTS
1. Capitalized Terms
Capitalized terms used herein shall have the same meanings as defined in Schedule 72 or in the body
of this Agreement. ·
2. Terms and Conditions
This Agreement and Schedule 72 provi&e me rates, charges, terms and conditions under which the
Seller's Generation Facility will intercOTil(itfct with, and oper, te in parallel with, the Company's
transmission/distribution system. Terms defi.lft.d tn Sene ule 72 will ve the same defined meaning in
this Agreement. If there is any conflict betWeen the fe_ ms of this ~greement and Schedule 72,
Schedule 72 shall prevail.
3. This Agreement is not an,aqreemePit te purchase Sellers power.
Purchase of Seller's power and other services that Seller may require will be covered under separate
agreements. Nothing in this Agreement is intended to affect any other agreement between the
Company and Seller.
4. Attachments
Attached to this Agreement and included by reference are the following:
Attachment 1 -Description and Costs of the Generation Facility, Interconnection
Facilities, and Metering Equipment.
Attachment 2 -One-line Diagram Depicting the Generation Facility, Interconnection
Facilities, Metering Equipment and Upgrades.
Attachment 3-Milestones For Interconnecting the Generation Facility.
Attachment 4 -Additional Operating Requirements for the Company's Transmission
System Needed to Support the Seller's Generation Facility.
Attachment 5 -Reactive Power.
Attachment 6-Description of Upgrades required to integrate the Generation Facility and
Best Estimate of Upgrade Costs.
5. Effective Date, Tem1, Termination and Disconnection.
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5. 1 Term of Agreement. Unless terminated earlier in accordance with the provisions
of this Agreement, this Agreement shall become effective on the date specified above and
remain effective as long as Seller's Generation Facility is eligible for service under Schedule 72.
5.2 Termination.
5. 2. 1 Seller may voluntarily terminate this Agreement upon expiration or
termination of an agreement to sell power to the Company.
5.2.2 After a Default, either Party may terminate this Agreement pursuant to
Section 6.5.
5.2.3 Upon termination or expiration of this Agreement, the Seller's Generation
Facility will be disconnected from the Company's transmission/distribution system. The
termination or expiration of this Agreementshall not relieve either Party of its liabilities
and obligations, owed or continuing at the· time of the termination. The provisions of this
Section shall survive termination or expiration of this Agreement.
5.3 Temporary Disconnection. iemp'orary disconnection shall continue only for so
long as reasonably necessary under "Good Utility Practice." Good Utility Practice means any of
the practices, methods and acts engaged in or appro'ved,by a significant portion of the electric
industry during the relevant time ·period, or any of the practices, methods and acts which, in the
exercise of reasonable judgment in light of.th.e facts known at the time the decision was made,
could have been expected to accomplish thi3_?i1€lsired resu/t.at .aJeasonable cost consistent with
good business practices, reliability, sa,fety and expeditipn. G0od Utility Practice is not intended
to be limited to the optimum practice, method,,o(act to the exclusion of all others, but rather to
be acceptable practices, m..ethods, or ._acts.·,·generally ·accepted in the region. Good Utility
Practice includes compliance with WECC..}o/;-·NERC requirements. Payment of lost revenue
resulting from temporary disconnection shall be governed by the power purchase agreement.
I
5. 3. 1 Emergency Conditions. "Emergency Condition" means a condition or
situation: (1) that in the judgment of the 'Party making the claim is imminently likely to
endanger life or property; or (2) that, in the case of the Company, is imminently likely (as
determined in a nqn-discriminatory manner) to cause a material adverse effect on the
security of, or damage to the Company's transmission/distribution system, the
Company's Interconnection Facilities or the equipment of the Company's customers; or
(3) that, in the case of the Seller, is imminently likely (as determined in a non­
discriminatory manner) to cause a material adverse effect on the reliability and security
of, or damage to, the Generation Facility or the Seller's Interconnection Facilities. Under
Emergency Conditions, either the Company or the Seller may immediately suspend
interconnection service and temporarily disconnect the Generation Facility. The
Company shall notify the Seller promptly when it becomes aware of an Emergency
Condition that may reasonably be expected to affect the Seller's operation of the
Generation Facility. The Seller shall notify the Company promptly when it becomes
aware of an Emergency Condition that may reasonably be expected to affect the
Company's equipment or service to the Company's customers. To the extent
information is known, the notification shall describe the Emergency Condition, the extent
of the damage or deficiency, the expected effect on the operation of both Parties'
facilities and operations, its anticipated duration, and the necessary corrective action.
5. 3. 2 Routine Maintenance, Construction, and Repair. The Company may
interrupt interconnection service or curtail the output of the Seller's Generation Facility
Idaho Power Company Generator lnterconn '·ion Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 3 of 9
and temporarily disconnect the Generation Facility from the Company's
transmission/distribution system when necessary for routine maintenance, construction,
and repairs on the Company's transmission/distribution system. The Company will
make a reasonable attempt to contact the Seller prior to exercising its rights to interrupt
interconnection or curtail deliveries from the Seller's Facility. Seller understands that in
the case of emergency circumstances, real time operations of the electrical system,
and/or unplanned events, the Company may not be able to provide notice to the Seller
prior to interruption, curtailment or reduction of electrical energy deliveries to the
Company. The Company shall use reasonable efforts to coordinate such reduction or
temporary disconnection with the Seller.
5.3.3 Scheduled Maintenance. On or before January 31 of each calendar year,
Seller shall submit a written proposed maintenance schedule of significant Facility
maintenance for that calendar year and the Company and Seller shall mutually agree as
to the acceptability of the proposed schedule. The Parties determination as to the
acceptability of the Seller's timetable for scheduled maintenance will take into
consideration Good Utility Practices, Idaho Power system requirements and the Seller's
preferred schedule. Neither Party shall unreasonably withhold acceptance of the
proposed maintenance schedule.
5. 3. 4. Maintenance Coordination. The Seller and the Company shall, to the
extent practical, coordinate their respective transmission/distribution system and
Generation Facility mainteoance schedules such that they occur simultaneously. Seller
shall provide and maintain adequate protective equipment sufficient to prevent damage
to the Generation Facility and Selhir.:..fufhisb.ed lntemonnection Facilities. In some cases,
some of Seller's protective refays will pi·ovide back-up protection for Idaho Power's
facilities. In that event, Idaho Power wiiNest ·such relays~ annually and Seller will pay the
actual cost of such annual testing .. ·.\. ·.·' ,. . . .
5.3.5 Forced Outages. During any forced outage, the Company may suspend
interconnection service to effect · immediate repairs on the Company's
transmission/distribution system. The .cor:npany shall use reasonable efforts to provide
the Seller with prior notice. If priGr no(ice is not given, the Company shall, upon request,
provide the Seller written documentation after the fact explaining the circumstances of
the disconnection.
5. 3. 6 Adverse Operating Effects. The Company shall notify the Seller as soon
as practicable if, based on Good Utility Practice, operation of the Seller's Generation
Facility may cause disruption or deterioration of service to other customers served from
the same electric system, or if operating the Generation Facility could cause damage to
the Company's transmission/distribution system or other affected systems. Supporting
documentation used to reach the decision to disconnect shall be provided to the Seller
upon request. If, after notice, the Seller fails to remedy the adverse operating effect
within a reasonable time, the Company may disconnect the Generation Facility. The
Company shall provide the Seller with reasonable notice of such disconnection, unless
the provisions of Article 5. 3. 1 apply.
5. 3. 7 Modification of the Generation Facility. The Seller must receive written
authorization from the Company before making any change to the Generation Facility
that may have a material impact on the safety or reliability of the Company's
transmission/distribution system. Such authorization shall not be unreasonably withheld.
Modifications shall be done in accordance with Good Utility Practice. If the Seller makes
such modification without the Company's prior written authorization, the latter shall have
the right to temporarily disconnect the Generation Facility.
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I.P.U.C. No. 29, Tariff No. 101 Page 4 of 9
5. 3. 8 Reconnection. The Parties shall cooperate with each other to restore the
Generation Facility, Interconnection Facilities, and the Company's
transmission/distribution system to their normal operating state as soon as reasonably
practicable following a temporary disconnection.
5. 3. 9 Voltage Levels. Seller, in accordance with Good Utility Practices, shall
minimize voltage fluctuations and maintain voltage levels acceptable to Idaho Power.
Idaho Power may, in accordance with Good Utility Practices, upon one hundred eighty
(180) days' notice to the Seller, change its nominal operating voltage level by more than
ten percent (10%) at the Point of Delivery, in which case Seller shall modify, at Idaho
Power's expense, Seller's equipment as necessary to accommodate the modified
nominal operating voltage level.
5. 4 Land Rights.
5. 4. 1 Seller to Provide Access. Seller hereby grants to .Idaho Power for the
term of this Agreement all necessary rights-of-way and easements to install, operate,
maintain, replace, and remove Idaho Power's Meter}ng Equipment, Interconnection
Equipment, Disconnection Equipment, Protection Equipment and other Special Facilities
necessary or useful to this Agreement, including adequate and continuing access rights
on property of Seller. Seller warrants that it has procured sufficient easements and
rights-of-way from third pahies so as to provide Idaho Power with the access described
above. All documents granting sf!.cf} easements or rights-of-way shall be subject to
Idaho Power's approval and in recordable form. .·· ·. \ .
5. 4. 2 Use of Public Rigt/ts-of-Way. The Parties agree that it is necessary to
avoid the adverse ehvironmentatand operating impacts that would occur as a result of
duplicate electric lines being const(uc.ted in close proximity. Therefore, subject to Idaho
Power's compliance with ,Paragraph' 5.4.4, Seller agrees that should Seller seek and
receive from any local,. state or federal governmental body the right to erect, construct
and maintain Seller-fumish;e,d Interconnection Facilities upon, along and over any and all
public road$, streets and•highways, then the use by Seller of such public right-of-way
shall be subordinate to any future Lise by Idaho Power of such public right-of-way for
construction and/or maintenance of electric distribution and transmission facilities and
Idaho Power may claim use of such public right-of-way for such purposes at any time.
Except as required by Paragraph 5. 4. 4, Idaho Power shall not be required to
compensate Seller for exercising its rights under this Paragraph 5. 4. 2.
5. 4. 3 Joint Use of Facilities. Subject to Idaho Power's compliance with
Paragraph 15.4.4, Idaho Power may use and attach its distribution and/or transmission
facilities to $eller's Interconnection Facilities, may reconstruct Seller's Interconnection
Facilities to accommodate Idaho Power's usage or Idaho Power may construct its own
distribution or transmission facilities along, over and above any public right-of-way
acquired from Seller pursuant to Paragraph 5. 4. 2, attaching Seller's Interconnection
Facilities to such newly constructed facilities. Except as required by Paragraph 5. 4. 4,
Idaho Power shall not be required to compensate Seller for exercising its rights under
this Paragraph 5. 4. 3.
5. 4. 4 Conditions of Use. It is the intention of the Parties that the Seller be left in
substantially the same condition, both financially and electrically, as Seller existed prior
to Idaho Power's exercising its rights under this Paragraph 5. 4. Therefore, the Parties
agree that the exercise by Idaho Power of any of the rights enumerated in Paragraphs
Idaho Power Company Generator lnterconr ~ion Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 5 of 9
5.4.2 and 5.4.3 shall: (1) comply with all applicable laws, codes and Good Utility
Practices, (2) equitably share the costs of installing, owning and operating jointly used
facilities and rights-of-way. If the Parties are unable to agree on the method of
apportioning these costs, the dispute will be submitted to the Commission for resolution
and the decision of the Commission will be binding on the Parties, and (3) shall provide
Seller with an interconnection to Idaho Power's system of equal capacity and durability
as existed prior to Idaho Power exercising its rights under this Paragraph 5.4.
6. Assignment. Liability, Indemnity, Force majeure, Consequential Damages and Default.
6.1 Assignment. This Agreement may be assigned by either Party upon twenty-one
(21) calendar days prior written notice and opportunity to object by the other Party; provided
that:
6. 1. 1 Either Party may assign this Agreement without the consent of the other
Party to any affiliate of the assigning Party with an equal or greater credit rating and with
the legal authority and operational ability to satisfy the obligations of the assigning Party
under this Agreement.
6.1.2 The Seller shall have the right to contingently assign this Agreement,
without the consent of the Company, for collateral security purposes to aid in providing
financing for the Generation Facility, provided that the Seller will promptly notify the
Company of any such contiogent assignment.
6. 1. 3 Any attempted assignment that violates this article is void and ineffective.
Assignment shall not relieve aParty of its obligations, 'nor shall a Party's obligations be
enlarged, in whole or in part, by reason thereof. An assignee is responsible for meeting
the same financial, . credit, and insurance obligations as the Seller. Where required,
consent to assignment will not be unreasonably withheld, conditioned or delayed.
6. 2 Limitation of Liability. Each Party's liability to the other Party for any loss, cost,
claim, injury, liability, or expense, including reasonable attorney's fees, relating to or arising from
any act or omission in its performance of this Agreement, shall be limited to the amount of direct
damage actually incurred. In no event shall either Party be liable to the other Party for any
indirect, special, consequential, or punitive damages, except as authorized by this Agreement.
6.3
6. 3. 1 This provision protects each Party from liability incurred to third parties as
a result of carrying out the provisions of this Agreement. Liability under this provision is
exempt from the genera/limitations on liability found in Article 6. 2.
6. 3. 2 The Parties shall at all times indemnify, defend, and hold the other Party
harmless from, any and all damages, losses, claims, including claims and actions
relating to injury to or death of any person or damage to property, demand, suits,
recoveries, costs and expenses, court costs, attorney fees, and all other obligations by
or to third parties, arising out of or resulting from the other Party's action or failure to
meet its obligations under this Agreement on behalf of the indemnifying Party, except in
cases of gross negligence or intentional wrongdoing by the indemnified Party.
6. 3. 3 If an indemnified person is entitled to indemnification under this article as
a result of a claim by a third party, and the indemnifying Party fails, after notice and
reasonable opportunity to proceed under this article, to assume the defense of such
claim, such indemnified person may at the expense of the indemnifying Party contest,
Idaho Power Company Generator lnt-~onnection Agreement# 308
I.P,U.C. No. 29 , Tariff No. 101 Page 6 of9
settle or consent to the entry of any judgment with respect to, or pay in full, such claim.
Failure to defend is a Material Breach.
6.3.4 If an indemnifying party is obligated to indemnify and hold any
indemnified person harmless under this article, the amount owing to the indemnified
person shall be the amount of such indemnified person's actual loss, net of any
insurance or other recovery.
6. 3. 5 Promptly after receipt by an indemnified person of any claim or notice of
the commencement of any action or administrative or legafproceeding or investigation
as to which the indemnity provided for in this article may: apply, the indemnified person
shall notify the indemnifying party of such fact. Any failure of or delay in such notification
shall be a Material Breach and shall not affect a Party's indemnification obligation unless
such failure or delay is materially prejudicial to the indemnifying party.
; :,
6.4 Force Majeure. As used in this Agreement, "Force Majewe" or "an event of
Force Majeure" means any cause beyond the control of the Seller or ·a~ th~" Company which,
despite the exercise of due diligence, such Party is unable to prevent or overcome. Force
Majeure includes, but is not limited to, acts of God, fire, flopd, storms, wars; hqstilities, civil
strife, strikes and other labor disturbances, earthquakes, fires,Jightning, epidemics, sabotage, or
changes in law or regulation occurring after the Operation Date, which, by the exercise of
reasonable foresight such party could not reasonably have been expected to avoid and by the
exercise of due diligence, it shall be unable to overcome. If either Party is rendered wholly or in
part unable to perform its obligations under this Agreemert because of an event of Force
Majeure, both Parties shall be excused from whatever performance is affected by the event of
Force Majeure, provided that:
(1) The)l.on:-performing Party shall, as soon as is reasonably possible after
the occurrence of the Force Majeure, give the other Party written notice describing the
particulars of the occurr:.~nce.
(2) The suspension of performance shall be of no greater scope and of no
longer duration than is required by the event of Force Majeure.
(3) No obligations of either Party which arose before the occurrence causing
the suspension of performance and which could and should have been fully performed
before such occurrence shall be excused as a result of such occurrence.
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6. 5 Default and Material Breaches.
6. 5. 1 Defaults. If either Party fails to perform any of the terms or conditions of
this Agreement (a "Default" or an "Event of Default"), the nondefaulting Party shall cause
notice in writing to be given to the defaulting Party, specifying the manner in which such
default occurred. If the defaulting Party shall fail to cure such Default within the sixty
(60) days after service of such notice, or if the defaulting Party reasonably demonstrates
to the other Party that the Default can be cured within a commercially reasonable time
but not within such sixty (60) day period and then fails to diligently pursue such cure,
then, the nondefaulting Party may, at its option, terminate this Agreement and/or pursue
its legal or equitable remedies.
6. 5. 2 Material Breaches. The notice and cure provisions in Paragraph 6. 6. 1 do
not apply to Defaults identified in this Agreement as Material Breaches. Material
Breaches must be cured as expeditiously as possible following occurrence of the
breach.
7. Insurance.
During the term of this Agreement, Seller shall secure and continuously carry the following
insurance coverage:
7.1 Comprehensive General Liability Insurance for both bodily injury and property
damage with limits equal to $1,060,000, each occurrence, combined single limit. The deductible
for such insurance shall be consistent with current Insurance Industry Utility practices for similar
property.
7. 2 The above insurance c0verage shall be placed with an insurance company with
an A.M. Best Company rating of A-or better and shall incf11de:
(a) An endorsement naming Idaho Power as an additional insured and loss
payee as applicable; and
(b) . A provision stating that such policy shall not be canceled or the limits of
liability reduced without sixty (60) days' prior written notice to Idaho Power.
7. 3 Seller to Provide Certificate of Insurance. As required in Paragraph 7 herein and
annually thereafter, Seller shall furnish the Company a certificate of insurance, together with the
endorsements requir~d therein, evidencing the coverage as set forth above.
7.4 Seller to Notifv Idaho Power of Loss of Coverage -If the insurance coverage
required by Paragraph 7. 1 shall lapse for any reason, Seller will immediately notify Idaho Power
in writing. The notice will advise Idaho Power of the specific reason for the lapse and the steps
Seller is taking to reinstate the coverage. Failure to provide this notice and to expeditiously
reinstate or replace the coverage will constitute grounds for a temporary disconnection under
Section 5. 3 and will be a Material Breach.
8. Miscellaneous.
8. 1 Governing Law. The validity, interpretation and enforcement of this Agreement
and each of its provisions shall be governed by the laws of the state of Idaho without regard to
its conflicts of law principles.
8.2 Salvage. No later than sixty (60) days after the termination or expiration of this
Agreement, Idaho Power will prepare and forward to Seller an estimate of the remaining value
Idaho Power Company Generator lnt'" 'onnection Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 8 of 9
of those Idaho Power furnished Interconnection Facilities as required under Schedule 72 and/or
described in this Agreement, less the cost of removal and transfer to Idaho Power's nearest
warehouse, if the Interconnection Facilities will be removed. If Seller elects not to obtain
ownership of the Interconnection Facilities but instead wishes that Idaho Power reimburse the
Seller for said Facilities the Seller may invoice Idaho Power for the net salvage value as
estimated by Idaho Power and Idaho Power shall pay such amount to Seller within thirty (30)
days after receipt of the invoice. Seller shall have the right to offset the invoice amount against
any present or future payments due Idaho Power.
9. Notices.
9.1 General. Unless otherwise provided in this Agreement, any written notice,
demand, or request required or authorized in connection with this Agreement ("Notice") shall be
deemed properly given if delivered in person, delivered by recognized national currier service,
or sent by first class mail, postage prepaid, to the person specified below:
If to the Seller:
Seller:--------------'------....,...:;--:----­
Attention:---------------------------'-Address: __________________________ _
City: ___________ State: ____ .,Sip: -"'-----
Phone: Fax: --------
If to the Company:
Idaho Power Company -Delivery
Attention: Operations Manager
1221 W. Idaho Stree( · ·
Boise: Idaho 83702
Phone: 208-388,9.669 Fax: [phone]
9.2 Billing and Payment. Billings and payments shall be sent to the addresses set
out below:
Seller:-----'-----------------------Attention: __ ...:.._......:.;:_ __ ___;: ___________________ _
Address: ___ ___;:~--~-------------------City: ______ ..:...__...:.._ ___ State: ____ .Zip: _____ _
Phone: Fax:
Idaho Power Company -Delivery
Attention: Corporate Cashier
PO Box 447
Salt Lake City Utah 84110-0447
---------
Phone: [phone] email: [e-mail]
9.3 Designated Operating Representative. The Parties may also designate
operating representatives to conduct the communications which may be necessary or
convenient for the administration of this Agreement. This person will also serve as the point of
contact with respect to operations and maintenance of the Party's facilities .
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I.P.U.C. No. 29, Tariff No. 101 Page 9 of 9
Seller's Operating Representative:
Seller:----------------------­
Attention:--------------------------Address: _________________________ _
City: __________ State: ____ .Zip: ____ _
Phone: Fax: --------
Company's Operating Representative:
Idaho Power Company -Delivery
Attention: Regional Outage Coordinator-Regional Dispatch
1221 W. Idaho Street
Boise, Idaho 83702
Phone: [phone], or 388-5175 during regular business hours
(after hours Southern Region 208-388-5190).
9.5 Changes to the Notice Information. Either Party may change this information by
giving five (5) Business Days written notice pr,ior t~ the effective date of the change.
1 0. Signatures.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their
respective duly authorized representatives.
For the Seller
For the Company
Name:
Title: Manager, Grid Operations -Idaho Power Company, Delivery
Date:
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I.P.U.C. No. 29. Tariff No. 101 Page 1 of 3
Attachment 1
Description and Costs of the Generation Facility, Interconnection Facilities and Metering
Equipment
Type of Interconnection Service:
Full Output:
Nominal Delivery Voltage:
Interconnection Details
Studied as an Idaho Power Network Resource under PURPA
1.2 MW
12.5kV
General Facility Description
The proposed project will connect to Idaho Power's 12.5kV system on Idaho Power Company's
Buckhorn (BKHN-041) distribution line. The total project output is 1.2 MW.
Interconnection Point
The Interconnection Point for the Double B Dairy Digester Proj~ct will be the low-side bushings on the
pad mounted transformer (081 ). The project's location is in T12S R21 E Section 18 of Cassia County,
Idaho. A drawing identifying the Point of lnterconne<;;tionoJs included as Attachment 2. The Point of
Change of Ownership will be the low-side bushings qn:the padmounted transformer (081 ).
Seller's Interconnection Facilities
The Seller will install generators, low-side disconnect switches, all wiring and conduit between the
generators and the padmounted transformer, appropriate grounding measures, and associated
auxiliary equipment. The Seller will build underground facilities:to··the Point of Change of Ownership for
the generator facility. The low-side disconnect switch shall be visible, lockable, within ten (1 0) feet of
the pad mounted transformers, and accessible to ldah·6 power personnel:
The Seller will install equipment to receive sigJials from Idaho Pow.er Company Grid Operations for
Generator Output Limit Control ("GOLC'') -see Attachment 4 Operating Requirements.
The Seller will provide phone service to IPCo's generator interconnect package as described in
Telecommunications below.
All interconnection equipment electrically located oh the generator side of the Point of Change
Ownership shall be owned and maintained by the Seller.
Other Facilities Provided by Seller
Telecommunications
In addition to communication circuits that may be needed by the Seller, the Seller shall provide the
following communication circuits for Idaho Power's use:
1. One POTS (Plain Old Telephone Service) dial-up circuit for revenue metering at the generation
interconnection site.
2. One DDS (Digital Data Service) circuit guaranteed minimum data rate of 19,200 bits per second for
SCAOA between the generation interconnection site and a point designated by Idaho Power
Company.
The Seller is required to coordinate with the local communications provider to provide the
communications circuits and pay the associated monthly charges. The communication circuits will
need to be installed and operational prior to generating into Idaho Power system. Note that installation
by the local communications provider may take several months and should be ordered in advance to
avoid delaying the project. If the communication circuit types listed above are not available at the site
by the local communications provider, the Seller shall confer with Idaho Power.
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I.P.U.C. No. 29, Tariff No. 101 Page 2 of 3
If high voltage protection is required by the local communications provider for the incoming cable, the
high voltage protection assembly shall be engineered and supplied by the Seller. Options are available
for indoor or outdoor mounting. The high voltage protection assembly shall be located in a manner that
provides Idaho Power 24-hour access to the assembly for communications trouble-shooting of Idaho
Power owned equipment.
Ground Fault Equipment
The Seller will install ground fault limiting equipment that will limit the zero sequence fault current to 20
amps at the Interconnection Point.
Monitoring Information
If the Interconnection Customer requires the ability to monitor information related to the Idaho Power
recloser in the generation interconnection package they are required to supply their own
communications circuit to the control box.
Local Service
The Seller is responsible to arrange for local service to their site, as necessary.
Easements
The Seller will secure underground and overhead easements with Double B Dairy once a specific route
is determined. The Seller will provide to IPCO a surveyed (Metes & Bounds) legal description along
with exhibit map for IPCO's facilities. After the legal description has been delivered to IPCO for review,
IPCO will supply to the Seller a completed IPCO easement for signature by the land owner of record.
Once the signatures have been secured, ·the Seller will return the signed easement to IPCO for
recording. IPCO construction will not proceed unfil the appropriate easements are secured.
Idaho Power Compan;y's Interconnection Facilities
Idaho Power will install a standard generatian inter en , eofion P.ackage on the existing distribution
feeder (BKHN-041) on private property south est of the intersection ·of 1200 South and 1100 West in
Cassia County, Idaho. The new interconnection ~ae ·age will include four distribution poles to mount a
local service transformer, solid blade disconnects, primary metering package, recloser, relays, fuses
and riser necessary for the package. The interc::onr:tection will be controlled by a SEL-311 C line
protection relay. The relay will be located in a pole mounted enclosure and will also contain a test
switch (TS4), SLSS, modems, isolation interface, power supply, DC converter, control switch and surge -.. ··!·.' ,.,... protector. · ·
Idaho Power will install (and subsequently own and maintain) one 1500 kVA 277/480 to 12.47 kV
Grounded Wye I Grounded Wye padmounted transformer on top of a vault. Conduit and underground
cables will be installed from the interconnection package to padmounted transformer. Protective posts
will be installed to protect the ground mounted equipment from damage.
A 2" conduit will be installed alongside the underground primary to facilitate information exchange to the
customer about the recloser. (The Interconnection Customer is responsible for providing and installing
the appropriate cable).
All interconnection equipment electrically located on the utility side of the Point of Change Ownership
shall be owned, operated, and maintained by Idaho Power.
Idaho Power Company Generator lntr 'onnection Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 3 of 3
-Generation Facilities:
~~~ercO/~~;:~~~!d ;~c~~:;;:~ ---.. ------Seller --····--·-----~~-~ -: , -_ $20$0N,O/O~O
!overhead Generation Interconnecti~E. . .f.~ckage -··--·······---lPCO ___
1
1l}~f!d_e_!-g.E~~E~}~quipment and 1500 kV A Transforme_!: ____ 1_[P_C_O _______ f--------'-$_4-'5,'---0_______,00
____ TO_TAL+-=---==~=----,;;,$;;..24.;..;;5..:.;,0...;.0~0~--
1 __ f'ROJECT_§RAND TOTAL[ SEE ATTACHMENT 61
Full payment is required up front in accordance with Schedule 72; unless payment arrangements are
made in advance with Idaho Power Operations Finance (see Attachment 3).
Billing for construction activities will be based upon actuaL expenditures . .-:: .''
Idaho Power Company Generator lntercon :tion Agreement# 307
I.P.U.C. No. 29. Tariff No. 101 Page 1 of 1
Attachment 2
One-line Diagram Depicting the Small Generation Facility, Interconnection Facilities, Metering
Equipment and Upgrades
Idaho Power Company Generator lntf "lnnection Agreement# 307
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 1
Attachment 3
Milestones:
1. Idaho Power Company agrees only to the Construction timelines under its direct control
provided in the Facility Study Report for this Project.
2. These milestones will begin, and the construction schedule referenced below, will only be valid
upon receipt of funding in full from the Seller or their authorized third party no later than the date
set forth below for such payment. Additionally, failure by Seller to make the required payments
as set forth in this Agreement by the date(s) specified below will be a material breach of this
Agreement, which may result in any or all of the following: (i) loss of milestone dates and
construction schedules set forth below: (ii) immediate termination of this Agreement by Idaho
Power; (iii) removal from the generator interconnection queue.
Critical milestones and responsibility as agreed to by the Parties:
5/31/12 Seller IPCO receives the remaining balance of Construction
estimate $245,000 OR Credit arrangements are approve
b IPCO
10/11/12 Seller Customer GOLC ready to connect & customer telecomm
re uirements are complete
10/31/12 IPCO IPCO Construction Complete
11/15/12 IPCO IPc;o Commissioning Complete
12/12/12 /PeG> Project Leader issues Construction Complete Letter . . .
12/12/12 Seiler Customer testing begins
Seller Customer's requested In-Service Date
Agreed to by:
For the Seller: ___________________________ Date ____________ _
For the Transmission Provider
Idaho Power Company, Delivery ___________________________ Date ____________ _
Idaho Power Company Generator lntercon :tion Agreement# 307
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 1
Attachment 4
Additional Operating Requirements for the Company's Transmission System and Affected
Systems Needed to Support the Seller's Needs
The Company shall also provide requirements that must be met by the Seller prior to initiating
parallel operation with the Company's Transmission System.
Operating Requirements
The project is required to comply with the applicable Voltage and Current Distortion Limits found in
IEEE Standard 519-1992 IEEE Recommended Practices and Requirements for Harmonic Control in
Electrical Power Systems or any subsequent standards as they may be updated from time to time.
Seller will be able to modify power plant facilities on the generator side of the Interconnection Point with
no impact upon the operation of the transmission system whenever the generation facilities are
electrically isolated from the transmission system and a terminal clearance is issued by Idaho Power
Company's Grid Operator.
Generator Output Limit Control ("Re-dispatch" or "GOLC'J
The Project will be subject to reductions directed by Idaho Power Company Grid Operations during
transmission system contingencies and other reliability events. When these conditions occur, the
Project will be subject to Generator Output Limit Control ("GOLC") and have equipment capable of
receiving signals from Idaho Power for GOLC. Generator Output Limit Control will be a setpoint from
Idaho Power to the Project indicating maximum output allowed.
Voltage flicker at startup and during operation will be limited to less than 5% as measured at the
Interconnection Point. For thts t9 o.ccur, the current cannot exceed 65 Amps during start up at the 12.5
kV voltage level. This forcE3s the generating facility to start the generators separately.
Low Voltage Ride Through
The Project must be capable of riding through faults on adjacent section of the power system without
tripping due to low voltage. It has been determined, through study, that the Project must be capable of
remaining interconnected fbr 'any single phase voltage as low as 0.7 PU for 30 cycles, and for all three
phase voltages as low as 0.8 PU for 30 cycles.
Ground Fault Equipment
The Seller will install transformer configurations that provide a ground source to the transmission
system.
Idaho Power Company Generator lntr 'lnnection Agreement# 307
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 1
Attachment 5
Reactive Power Requirements
The project must be controlled to operate at unity power factor +/-400 kVar. Voltage flicker at startup
and during operation will be limited to less than 5% as measured at the Interconnection Point. Voltage
flicker at startup and during operation will be limited to less than 5% as measured at the Interconnection
Point.
r '
Idaho Power Company Generator lntercon tion Agreement# 307
I.P. U.C. No. 29, Tariff No. 101 Page 1 of 1
Attachment 6
Companv's Description of Special Facilities and Upgrades Required to Integrate the Generation
Facilitv and Best Estimate of Costs
As provided in Schedule 72 this Attachment describes Upgrades, Special Facilities, including
Network Upgrades, and provides an itemized best estimate of the cost of the required facilities.
Distribution Upgrades
n/a
Upgrades
1-_ _ _ ~TAL,__ j
!fnterconnection costs__([rom Attachff!efl:t 1)____ :"-:--~_-_]-+ -_ -_ --~--~~":="!!:-:>:=5~,0=0=q1 ~..__-_· __________ .. --~-.. ==-.. -·-_···_P~roJ~ct GRA.Hb_·itOTA.L ....... _ _: -'_ -_ -_ -_ --+-'--1 ====$=2=4=5=,o=o:o
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BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 30
Harris, Joshua
From:
Sent:
Leslie White [[e-mail]]
Monday, June 11, 2012 6:06 PM
To: Harris, Joshua
Subject: RE: Draft GIA-Project #308 Double B Dairy
Hello Josh,
I will give you a call tomorrow to follow up.
Thanks,
Leslie
Leslie White
802 W Bannock, 12th Floor Boise, 10 83702
Office: 208.336.9793 1 Mobile: [phone]
wwy_y.ex~~velonment.com
This electronic or printed document contains information which (a) may be LEGALLY PRIVILEGED. PROPRIETARY IN NATURE. OR OTHERWISE PROTECTED BY LAW
FROM DISCLOSURE and (bj is intended only for the use of the .1\ddressee(s) named above. If the reader of this message is not the Intended recipient, or the employee or
agent responsible to deliver •t to the intended rec1p1enl. you are hereby notified that any dissemination, distribution or copying of this communication IS strictly prohibited If you
have received this communication in error, please immediately notify us by telephone, and return the original message to us at the above email address Thank you.
From: Harris, Joshua [mailto:[e-mail]]
Sent: Monday, June 11, 2012 2:26 PM
To: Leslie White
Subject: RE: Draft GIA-Project #308 Double B Dairy
Leslie,
I left you a v-mail. How much time do you need? I am bound by some time constraints in order to keep projects
progressing th.rough our queue.
Thanks,
Josh Harris I Operations Analyst I Idaho Power Company
208.388.5751
From: Leslie White [mailto:[e-mail]]
Sent: Monday, June 11, 2012 1:39 PM
To: Harris, Joshua
Subject: RE: Draft GIA -Project #308 Double B Dairy
Josh,
I would prefer to have a period of time to solidify with the dairyman that in fact this is the case with his dairy.
Thanks,
Leslie
1
Leslie White
802 W Bannock, 12tli Floor Boise, 10 83702
Office: 208 336.9793 I Mobile: [phone]
This electronic or printed document contains information which (aj may be LEGALLY PRIVILEGED. PROPRIETARY IN NATURE. OR OTHERWISE PROTECTED BY LAW
FROM DISCLOSURE, and (b) 1s intended only for the use of the Addressee(s) named above If the reader of this message is not the intended recipient. or the employee or
agent responsible to deliver it to the 1ntended recipient. you are hereby notified that any dissemination, distribution or copying of tllis communication is strictly prohibited If you
have received this commumcation 1n error please immediately notify us by telephone and return the original message to us at the above email address. Thank you
--··------------------
From: Harris, Joshua [mailto:[e-mail]]
Sent: Monday, June 11, 2012 1:37PM
To: Leslie White
Subject: RE: Draft GIA-Project #308 Double B Dairy
Leslie,
Thanks for the information. So to clarify, your are choosing not to proceed with this project, correct? If so, I'll send out
an official withdrawal letter.
Thanks,
Josh Harris I Operations Analyst I Idaho Power Company
208.388.5751
---------------------------·------
From: Leslie White [mailto:[e-mail]]
Sent: Monday, June 11, 2012 8:14AM
To: Harris, Joshua
Cc: Hackett, Eric; Bauer, Rich; Sloan, Aubrae
Subject: RE: Draft GIA -Project #308 Double B Dairy
Good morning Josh,
Mr. Bettencourt, the dairy owner, has indicated that he is having difficulty with this dairy or may be selling it. With that
indication we are not ready to execute these documents.
Thank you,
Leslie
Leslie White
802 W Bannock, 12th Floor Boise, 10 83702
Office: 208.336 9793 j tvlobiie: 208.890.4660
This elect10nic or printed document contains tnlormalion w~ich (a) may be LEGALLY PRIVILEGED. PROPRIETARY IN NATURE, OR OTHERWISE PROTECTED BY LAW
FROM DISCLOSURE. and (b) 1s intended only for the use of the Addressee(s) named above If the reader of this message is 11ot the intended recipient. or the employee or
agent responsible to deliver it to the 1ntended recipient \IOU are nereby notifierJ that any dissemination. distribution or cop~;ing of this communicalion is strictly prohibned. If you
ha•1e received thiS cornmunrca!ion in error. please Immediately notify us by telephone and return the orig1nalmessage to us at the above email address Thank you
From: Harris, Joshua [mailto:[e-mail]]
Sent: Wednesday, May 09, 2012 2:52 PM
To: Leslie White
2
Cc: Hackett, Eric; Bauer, Rich; Sloan, Aubrae
Subject: Draft GIA -Project #308 Double B Dairy
Leslie,
The attached is being mailed to you today. Please provide the contact information for Section 9 and items listed in cover
letter by date outlined. Please let me know if you have any questions.
Thanks,
Josh Harris I Operations Analyst !Idaho Power Company
1221 W. Idaho Street, Boise, Idaho 83702 I ir: [phone]
~: {208) 433-3571 I [8]: [e-mail]
This transmission may contain information that is privileged, confidential and/or exempt from disclosure Wlder applicable law. If you are not the intended recipient, you are hereby
notified that any disclosure, copying, distribution, or use of the information contained herein (including any reliance thereon) is STRIClL Y PROHffiiTED. If you received this
transmission in error, please immediately contact the sender and destroy the material in its entirety, whether in electronic or hard copy format. Thank you.
3
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E·12-26
IDAHO POWER COMPANY
ATTACHMENT 31
Clark, Danielle
From: Harris, Joshua
Sent:
To:
Friday, September 07, 2012 9:54AM
Clark, Danielle
Subject:
Attachments:
FW: Final GIA-Double B Dairy Gl308
CoverLetter_FinaiGIA_308.pdf; FinaiGIA_308.pdf; Single line 308.pdf
FYI
Thanks,
Josh Harris
OPERATIONS ANALYST
Idaho Power I Generator Interconnection
208-388-5751
Email [e-mail]
From: Harris, Joshua
Sent: Tuesday, June 19, 2012 3:49 PM
To: 'Leslie White'
Cc: Park, Tessia
Subject: Final GIA -Double B Dairy GI308
Leslie,
The attached was sent to you in the mail today, please note the time line in the Jetter for document execution (7 /20/12).
Please let me know if you have any questions.
Thanks,
Josh Harris
OPERATIONS ANALYST
Idaho Power I Generator Interconnection
1221 W. Idaho Street I Boise, Idaho I 83702
Work 208-388-5751
Fax [phone]
Email [e-mail]
1
An IDACOR!' Company
June 19, 2012
Via email & Certified Mail# 70113500000156449105
Leslie White
Exergy Development Group ofldaho, LLC
802 W Bannock, Suite 1200
Boise, ID 83 702
Re: Double B Dairy Digester Project-Generator Interconnection Agreement (GIA) #308
Dear Leslie:
Attached is the Final GIA. Please complete the NOTICES information, and sign and return both
sets as soon as possible. We will return a fully executed copy of the signature pages for your
files. These need to be returned to me by July 20, 2012, otherwise your Generator
Interconnection Application will be deemed withdrawn.
Please provide written notification to Idaho Power Company ATTN: Tess Park at least 30 days
prior to testing so that we may prepare software updates for preschedule and real time operations.
When you are ready for testing please contact Idaho Power's Outage Coordinator's desk during
normal business hours at least seven (7) days in advance, at 208-388-2633, 5125 or 5175. If
contact needs to be made after hours, please call Southern Regional Dispatch 208-388-5190.
If you have any further questions, please don't hesitate to call.
Sincerely,
Josh Harris
Operations Analyst
Ph 208-388-2658
[e-mail]
Encl: 2 copies-Final GIA for Double B Dairy Digester Project
Cc: Tess Park/ IPC
P.O. Box 70 (83707)
1221 W. Idaho St.
Boise, ID 83702
Idaho Power Company Generator Interconnection Agreement# 308
I.P.U.C. No. 29 Tariff No. 101
June 19, 2012
GENERATOR INTERCONNECTION AGREEMENT
Schedule 72
DOUBLE 8 DAIRY DIGESTER PROJECT
1.2 MW
Idaho Power Company Generator Interconnection Agreement# 308
I.P.U.C. No. 29. Tariff No. 101 Page 1 of 1
TABLE OF CONTENTS
RECITALS .............................................................................................................................................. 1
AGREEMENTS ....................... ·-· ............................................................................................................. 1
1. Capitalized Terms ................................................................................................................ 1
2. Terms and Conditions .......................................................................................................... 1
3. This Agreement is not an agreement to purchase Seller's power ......................................... 1
4. Attachments ......................................................................................................................... 1
5. Effective Date. Term, Termination and Disconnection .......................................................... 1
6. Assignment. Liabilitv. Indemnity, Force majeure. Consequential Damages and Default ....... 5
7. Insurance ............................................................................................................................. 7
8. Miscellaneous ............................................ _ .... _ ... _ ................................................................. 7
9. Notices ................................................................................................................................. 8
10. Signatures ............................................................................................................................ 9
Attachment 1 ....................... ·-· ................................................................................................................. 1
Attachment 2 ......................................................................................................................................... 1
Attachment 3 ......................................................................................................................................... 1
Attachment 4 ......................................................................................................................................... 1
Attachment 5 ......................................................................................................................................... 1
Attachment 6 ........................................................................................................................................... 1
Idaho Power Company Generator Interconnection Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 9
This Generator Interconnection Agreement ("Agreement") under Idaho Power Company's
Schedule 72 is effective as of the day of , 2012 between
____________ ,,("Seller", "Customer" or "The Project") and Idaho Power Company
("Company", "Idaho Power", "I PC", "IPCO" or "Transmission Owner").
RECITALS
A. Seller will own or operate a Generation Facility that qualifies for service under Idaho
Power's Commission-approved Schedule 72 and any successor schedule.
B. The Generation Facility covered by this Agreement is more particularly described in
Attachment 1.
AGREEMENTS
1. Capitalized Terms
Capitalized terms used herein shall have the same meanings as defined in Schedule 72 or in the body
of this Agreement.
2. Terms and Conditions
This Agreement and Schedule 72 provide the rates, charges, terms and conditions under which the
Seller's Generation Facility will interconnect with, and operate in parallel with, the Company's
transmission/distribution system. Terms defined in Schedule 72 will have the same defined meaning in
this Agreement. If there is any conflict between the terms of this Agreement and Schedule 72,
Schedule 72 shalf prevail.
3. This Agreement is not an agreement to purchase Seller's power.
Purchase of Seller's power and other services that Seller may require will be covered under separate
agreements. Nothing in this Agreement is intended to affect any other agreement between the
Company and Seller.
4. Attachments
Attached to this Agreement and included by reference are the following:
Attachment 1 -Description and Costs of the Generation Facility, Interconnection
Facilities, and Metering Equipment.
Attachment 2 -One-line Diagram Depicting the Generation Facility, Interconnection
Facilities, Metering Equipment and Upgrades.
Attachment 3 -Milestones For Interconnecting the Generation Facility.
Attachment 4 -Additional Operating Requirements for the Company's Transmission
System Needed to Support the Seller's Generation Facility.
Attachment 5 -Reactive Power.
Attachment 6 -Description of Upgrades required to integrate the Generation Facility and
Best Estimate of Upgrade Costs.
5. Effective Date. Term. Termination and Disconnection.
Idaho Power Company Generator Interconnection Agreement# 308
I.P.U.C. No. 29. Tariff No. 101 Page 2 of 9
5.1 Term of Agreement. Unless terminated earlier in accordance with the provisions
of this Agreement, this Agreement shall become effective on the date specified above and
remain effective as long as Seller's Generation Facility is eligible for service under Schedule 72.
5.2 Termination.
5.2. 1 Seller may voluntarily terminate this Agreement upon expiration or
termination of an agreement to sell power to the Company.
5.2.2 After a Default, either Party may terminate this Agreement pursuant to
Section 6.5.
5.2.3 Upon termination or expiration of this Agreement, the Seller's Generation
Facility will be disconnected from the Company's transmission/distribution system. The
termination or expiration of this Agreement shall not relieve either Party of its liabilities
and obligations, owed or continuing at the time of the termination. The provisions of this
Section shall survive termination or expiration of this Agreement.
5.3 Temporary Disconnection. Temporary disconnection shall continue only for so
long as reasonably necessary under "Good Utility Practice." Good Utility Practice means any of
the practices, methods and acts engaged in or approved by a significant portion of the electric
industry during the relevant time period, or any of the practices, methods and acts which, in the
exercise of reasonable judgment in light of the facts known at the time the decision was made,
could have been expected to accomplish the desired result at a reasonable cost consistent with
good business practices, reliability, safety and expedition. Good Utility Practice is not intended
to be limited to the optimum practice, method, or act to the exclusion of all others, but rather to
be acceptable practices, methods, or acts generally accepted in the region. Good Utility
Practice includes compliance with WECC or NERC requirements. Payment of lost revenue
resulting from temporary disconnection shall be governed by the power purchase agreement.
5.3.1 Emergency Conditions. "Emergency Condition" means a condition or
situation: (1) that in the judgment of the Party making the claim is imminently likely to
endanger life or property; or (2) that, in the case of the Company, is imminently likely (as
determined in a non-discriminatory manner) to cause a material adverse effect on the
security of, or damage to the Company's transmission/distribution system, the
Company's Interconnection Facilities or the equipment of the Company's customers; or
(3) that, in the case of the Seller, is imminently likely (as determined in a non­
discriminatory manner) to cause a material adverse effect on the reliability and security
of, or damage to, the Generation Facility or the Seller's Interconnection Facilities. Under
Emergency Conditions, either the Company or the Seller may immediately suspend
interconnection service and temporarily disconnect the Generation Facility. The
Company shall notify the Seller promptly when it becomes aware of an Emergency
Condition that may reasonably be expected to affect the Seller's operation of the
Generation Facility. The Seller shall notify the Company promptly when it becomes
aware of an Emergency Condition that may reasonably be expected to affect the
Company's equipment or service to the Company's customers. To the extent
information is known, the notification shall describe the Emergency Condition, the extent
of the damage or deficiency, the expected effect on the operation of both Parties'
facilities and operations, its anticipated duration, and the necessary corrective action.
5.3.2 Routine Maintenance, Construction, and Repair. The Company may
interrupt interconnection service or curtail the output of the Seller's Generation Facility
Idaho Power Company Generator Interconnection Agreement # 308
I.P.U.C. No. 29, Tariff No. 101 Page 3 of 9
and temporarily disconnect the Generation Facility from the Company's
transmission/distribution system when necessary for routine maintenance, construction,
and repairs on the Company's transmission/distribution system. The Company will
make a reasonable attempt to contact the Seller prior to exercising its rights to interrupt
interconnection or curtail deliveries from the Seller's Facility. Seller understands that in
the case of emergency circumstances, real time operations of the electrical system,
and/or unplanned events, the Company may not be able to provide notice to the Seller
prior to interruption, curtailment or reduction of electrical energy deliveries to the
Company. The Company shall use reasonable efforts to coordinate such reduction or
temporary disconnection with the Seller.
5.3.3 Scheduled Maintenance. On or before January 31 of each calendar year,
Seller shall submit a written proposed maintenance schedule of significant Facility
maintenance for that calendar year and the Company and Seller shall mutually agree as
to the acceptability of the proposed schedule. The Parties determination as to the
acceptability of the Seller's timetable for scheduled maintenance will take into
consideration Good Utility Practices, Idaho Power system requirements and the Seller's
preferred schedule. Neither Party shall unreasonably withhold acceptance of the
proposed maintenance schedule.
5.3.4. Maintenance Coordination. The Seller and the Company shall, to the
extent practical, coordinate their respective transmission/distribution system and
Generation Facility maintenance schedules such that they occur simultaneously. Seller
shall provide and maintain adequate protective equipment sufficient to prevent damage
to the Generation Facility and Seller-furnished Interconnection Facilities. In some cases,
some of Seller's protective relays will provide back-up protection for Idaho Power's
facilities. In that event, Idaho Power will test such relays annually and Seller will pay the
actual cost of such annual testing.
5.3.5 Forced Outages. During any forced outage, the Company may suspend
interconnection service to effect immediate repairs on the Company's
transmission/distribution system. The Company shall use reasonable efforts to provide
the Seller with prior notice. If prior notice is not given, the Company shall, upon request,
provide the Seller written documentation after the fact explaining the circumstances of
the disconnection.
5.3. 6 Adverse Operating Effects. The Company shall notify the Seller as soon
as practicable if, based on Good Utility Practice, operation of the Seller's Generation
Facility may cause disruption or deterioration of service to other customers served from
the same electric system, or if operating the Generation Facility could cause damage to
the Company's transmission/distribution system or other affected systems. Supporting
documentation used to reach the decision to disconnect shall be provided to the Seller
upon request. If, after notice, the Seller fails to remedy the adverse operating effect
within a reasonable time, the Company may disconnect the Generation Facility. The
Company shall provide the Seller with reasonable notice of such disconnection, unless
the provisions of Article 5.3.1 apply.
5.3. 7 Modification of the Generation Facilitv. The Seller must receive written
authorization from the Company before making any change to the Generation Facility
that may have a material impact on the safety or reliability of the Company's
transmission/distribution system. Such authorization shall not be unreasonably withheld.
Modifications shall be done in accordance with Good Utility Practice. If the Seller makes
such modification without the Company's prior written authorization, the latter shall have
the right to temporarily disconnect the Generation Facility.
Idaho Power Company Generator Interconnection Agreement# 308
I.P.U.C. No. 29. Tariff No. 101 Page 4 of 9
5.3.8 Reconnection. The Parties shall cooperate with each other to restore the
Generation Facility, Interconnection Facilities, and the Company's
transmission/distribution system to their normal operating state as soon as reasonably
practicable following a temporary disconnection.
5.3.9 Voltage Levels. Seller, in accordance with Good Utility Practices, shall
minimize voltage fluctuations and maintain voltage levels acceptable to Idaho Power.
Idaho Power may, in accordance with Good Utility Practices, upon one hundred eighty
(180) days' notice to the Seller, change its nominal operating voltage level by more than
ten percent (10%) at the Point of Delivery, in which case Seller shall modify, at Idaho
Power's expense, Seller's equipment as necessary to accommodate the modified
nominal operating voltage level.
5.4 Land Rights.
5.4. 1 Seller to Provide Access. Seller hereby grants to Idaho Power for the
term of this Agreement all necessary rights-of-way and easements to install, operate,
maintain, replace, and remove Idaho Powers Metering Equipment, Interconnection
Equipment, Disconnection Equipment, Protection Equipment and other Special Facilities
necessary or useful to this Agreement, including adequate and continuing access rights
on property of Seller. Seller warrants that it has procured sufficient easements and
rights-of-way from third parties so as to provide Idaho Power with the access described
above. All documents granting such easements or rights-of-way shall be subject to
Idaho Powers approval and in recordable form.
5.4.2 Use of Public Rights-of-Wav. The Parties agree that it is necessary to
avoid the adverse environmental and operating impacts that would occur as a result of
duplicate electric lines being constructed in close proximity. Therefore, subject to Idaho
Power's compliance with Paragraph 5.4.4, Seller agrees that should Seller seek and
receive from any local, state or federal governmental body the right to erect, construct
and maintain Seller-furnished Interconnection Facilities upon, along and over any and all
public roads, streets and highways, then the use by Seller of such public right-of-way
shall be subordinate to any future use by Idaho Power of such public right-of-way for
construction and/or maintenance of electric distribution and transmission facilities and
Idaho Power may claim use of such public right-of-way for such purposes at any time.
Except as required by Paragraph 5.4.4, Idaho Power shall not be required to
compensate Seller for exercising its rights under this Paragraph 5.4.2.
5.4.3 Joint Use of Facilities. Subject to Idaho Power's compliance with
Paragraph 15.4.4, Idaho Power may use and attach its distribution and/or transmission
facilities to Seller's Interconnection Facilities, may reconstruct Seller's Interconnection
Facilities to accommodate Idaho Power's usage or Idaho Power may construct its own
distribution or transmission facilities along, over and above any public right-of-way
acquired from Seller pursuant to Paragraph 5.4.2, attaching Seller's Interconnection
Facilities to such newly constructed facilities. Except as required by Paragraph 5. 4.4,
Idaho Power shall not be required to compensate Seller for exercising its rights under
this Paragraph 5.4.3.
5.4.4 Conditions of Use. It is the intention of the Parties that the Seller be left in
substantially the same condition, both financially and electrically, as Seller existed prior
to Idaho Power's exercising its rights under this Paragraph 5.4. Therefore, the Parties
agree that the exercise by Idaho Power of any of the rights enumerated in Paragraphs
Idaho Power Company Generator Interconnection Agreement# 308
I.P.U.C. No. 29. Tariff No. 101 Page 5 of 9
5.4.2 and 5.4.3 shall: (1) comply with all applicable laws, codes and Good Utility
Practices, (2) equitably share the costs of installing, owning and operating jointly used
facilities and rights-of-way. If the Parties are unable to agree on the method of
apportioning these costs, the dispute will be submitted to the Commission for resolution
and the decision of the Commission will be binding on the Parties, and (3) shall provide
Seller with an interconnection to Idaho Power's system of equal capacity and durability
as existed prior to Idaho Power exercising its rights under this Paragraph 5. 4.
6. Assignment. Liabilitv. lndemnitv. Force majeure, Consequential Damages and Default.
6. 1 Assignment. This Agreement may be assigned by either Party upon twenty-one
(21) calendar days prior written notice and opportunity to object by the other Party; provided
that:
6.1.1 Either Party may assign this Agreement without the consent of the other
Party to any affiliate of the assigning Party with an equal or greater credit rating and with
the legal authority and operational ability to satisfy the obligations of the assigning Party
under this Agreement.
6.1.2 The Seller shall have the right to contingently assign this Agreement,
without the consent of the Company, for collateral security purposes to aid in providing
financing for the Generation Facility, provided that the Seller will promptly notify the
Company of any such contingent assignment.
6. 1.3 Any attempted assignment that violates this article is void and ineffective.
Assignment shall not relieve a Party of its obligations, nor shall a Party's obligations be
enlarged, in whole or in part, by reason thereof. An assignee is responsible for meeting
the same financial, credit, and insurance obligations as the Seller. Where required,
consent to assignment will not be unreasonably withheld, conditioned or delayed.
6.2 Limitation of Liabilitv. Each Party's liability to the other Party for any loss, cost,
claim, injury, liability, or expense, including reasonable attorney's fees, relating to or arising from
any act or omission in its performance of this Agreement, shall be limited to the amount of direct
damage actually incurred. In no event shall either Party be liable to the other Party for any
indirect, special, consequential, or punitive damages, except as authorized by this Agreement.
6.3 lndemnitv.
6.3.1 This provision protects each Party from liability incurred to third parties as
a result of carrying out the provisions of this Agreement. Liability under this provision is
exempt from the genera/limitations on liability found in Article 6.2.
6.3.2 The Parties shall at all times indemnify, defend, and hold the other Party
harmless from, any and all damages, losses, claims, including claims and actions
relating to injury to or death of any person or damage to property, demand, suits,
recoveries, costs and expenses, court costs, attorney fees, and all other obligations by
or to third parties, arising out of or resulting from the other Party's action or failure to
meet its obligations under this Agreement on behalf of the indemnifying Party, except in
cases of gross negligence or intentional wrongdoing by the indemnified Party.
6.3.3 If an indemnified person is entitled to indemnification under this article as
a result of a claim by a third party, and the indemnifying Party fails, after notice and
reasonable opportunity to proceed under this article, to assume the defense of such
claim, such indemnified person may at the expense of the indemnifying Party contest,
Idaho Power Company Generator Interconnection Agreement# 308
I.P.U.C. No. 29 , Tariff No. 101 Page 6 of9
settle or consent to the entry of any judgment with respect to, or pay in full, such claim.
Failure to defend is a Material Breach.
6.3.4 If an indemnifying party is obligated to indemnify and hold any
indemnified person harmless under this article, the amount owing to the indemnified
person shall be the amount of such indemnified person's actual loss, net of any
insurance or other recovery.
6.3.5 Promptly after receipt by an indemnified person of any claim or notice of
the commencement of any action or administrative or legal proceeding or investigation
as to which the indemnity provided for in this article may apply, the indemnified person
shall notify the indemnifying party of such fact. Any failure of or delay in such notification
shall be a Material Breach and shall not affect a Party's indemnification obligation unless
such failure or delay is materially prejudicial to the indemnifying party.
6.4 Force Majeure. As used in this Agreement, "Force Majeure" or "an event of
Force Majeure" means any cause beyond the control of the Seller or of the Company which,
despite the exercise of due diligence, such Party is unable to prevent or overcome. Force
Majeure includes, but is not limited to, acts of God, fire, flood, storms, wars, hostilities, civil
strife, strikes and other labor disturbances, earthquakes, fires, lightning, epidemics, sabotage, or
changes in Jaw or regulation occurring after the Operation Date, which, by the exercise of
reasonable foresight such party could not reasonably have been expected to avoid and by the
exercise of due diligence, it shall be unable to overcome. If either Party is rendered wholly or in
part unable to perform its obligations under this Agreement because of an event of Force
Majeure, both Parties shall be excused from whatever performance is affected by the event of
Force Majeure, provided that:
(1) The non-performing Party shall, as soon as is reasonably possible after
the occurrence of the Force Majeure, give the other Party written notice describing the
particulars of the occurrence.
(2) The suspension of performance shall be of no greater scope and of no
longer duration than is required by the event of Force Majeure.
(3) No obligations of either Party which arose before the occurrence causing
the suspension of performance and which could and should have been fully performed
before such occurrence shall be excused as a result of such occurrence.
Idaho Power Company Generator Interconnection Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 7 of 9
6. 5 Default and Material Breaches.
6. 5. 1 Defaults. If either Party fails to perform any of the terms or conditions of
this Agreement (a "Default" or an "Event of Default'?, the nondefaulting Party shall cause
notice in writing to be given to the defaulting Party, specifying the manner in which such
default occurred. If the defaulting Party shall fail to cure such Default within the sixty
(60) days after service of such notice, or if the defaulting Party reasonably demonstrates
to the other Party that the Default can be cured within a commercially reasonable time
but not within such sixty (60) day period and then fails to diligently pursue such cure,
then, the nondefaulting Party may, at its option, terminate this Agreement and/or pursue
its legal or equitable remedies.
6.5.2 Material Breaches. The notice and cure provisions in Paragraph 6.6.1 do
not apply to Defaults identified in this Agreement as Material Breaches. Material
Breaches must be cured as expeditiously as possible following occurrence of the
breach.
7. Insurance.
During the term of this Agreement, Seller shall secure and continuously carry the following
insurance coverage:
7. 1 Comprehensive General Liability Insurance for both bodily injury and property
damage with limits equal to $1,000,000, each occurrence, combined single limit. The deductible
for such insurance shall be consistent with current Insurance Industry Utility practices for similar
property.
7.2 The above insurance coverage shall be placed with an insurance company with
an A.M. Best Company rating of A-or better and shall include:
(a) An endorsement naming Idaho Power as an additional insured and loss
payee as applicable; and
(b) A provision stating that such policy shall not be canceled or the limits of
liability reduced without sixty (60) days' prior written notice to Idaho Power.
7.3 Seller to Provide Certificate of Insurance. As required in Paragraph 7 herein and
annually thereafter, Seller shall furnish the Company a certificate of insurance, together with the
endorsements required therein, evidencing the coverage as set forth above.
7.4 Seller to Notify Idaho Power of Loss of Coverage -If the insurance coverage
required by Paragraph 7. 1 shall lapse for any reason, Seller will immediately notify Idaho Power
in writing. The notice will advise Idaho Power of the specific reason for the lapse and the steps
Seller is taking to reinstate the coverage. Failure to provide this notice and to expeditiously
reinstate or replace the coverage will constitute grounds for a temporary disconnection under
Section 5.3 and will be a Material Breach.
8. Miscellaneous.
8. 1 Governing Law. The validity, interpretation and enforcement of this Agreement
and each of its provisions shall be governed by the laws of the state of Idaho without regard to
its conflicts of law principles.
8.2 Salvage. No later than sixty (60) days after the termination or expiration of this
Agreement, Idaho Power will prepare and forward to Seller an estimate of the remaining value
Idaho Power Company Generator Interconnection Agreement# 308
I.P.U.C. No. 29. Tariff No. 101 Page 8 of 9
of those Idaho Power furnished Interconnection Facilities as required under Schedule 72 and/or
described in this Agreement, less the cost of removal and transfer to Idaho Power's nearest
warehouse, if the Interconnection Facilities will be removed. If Seller elects not to obtain
ownership of the Interconnection Facilities but instead wishes that Idaho Power reimburse the
Seller for said Facilities the Seller may invoice Idaho Power for the net salvage value as
estimated by Idaho Power and Idaho Power shall pay such amount to Seller within thirty (30)
days after receipt of the invoice. Seller shall have the right to offset the invoice amount against
any present or future payments due Idaho Power.
9. Notices.
9.1 General. Unless otherwise provided in this Agreement, any written notice,
demand, or request required or authorized in connection with this Agreement ("Notice") shall be
deemed properly given if delivered in person, delivered by recognized national currier service,
or sent by first class mail, postage prepaid , to the person specified below:
If to the Seller:
Seller:------------------------
Attention:--------------------------Address: _________________________ _
City: _________ --=-State: ____ Zip: ____ _
Phone: Fax:
If to the Company:
Idaho Power Company-Delivery
Attention: Operations Manager
1221 W. Idaho Street
Boise: Idaho 83702
--------
Phone: [phone] Fax: [phone]
9.2
out below:
Billing and Payment. Billings and payments shall be sent to the addresses set
Seller:----------------------­
Attention:--------------------------Address: _______________ ~----------
City: ___________ State: ___ ~Zip : ____ _
Phone: Fax:
Idaho Power Company -Delivery
Attention: Corporate Cashier
PO Box 447
Salt Lake City Utah 8411 0-044 7
--------
Phone: [phone] email: [e-mail]
9.3 Designated Operating Representative. The Parties may also designate
operating representatives to conduct the communications which may be necessary or
convenient for the administration of this Agreement. This person will also serve as the point of
contact with respect to operations and maintenance of the Party's facilities.
Idaho Power Company Generator Interconnection Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 9 of 9
Seller's Operating Representative:
Seller:-----------------------
Attention:------------------------­
Address: ------------,----------==-=-----------City: __________ State: ___ ----'Zip: ____ _
Phone: Fax: --------
Company's Operating Representative:
Idaho Power Company-Delivery
Attention: Regional Outage Coordinator-Regional Dispatch
1221 W. Idaho Street
Boise, Idaho 83702
Phone: [phone], or 388-5175 during regular business hours
(after hours Southern Region 208-388-5190).
9.5 Changes to the Notice Information. Either Party may change this information by
giving five (5) Business Days written notice prior to the effective date of the change.
10. Signatures.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their
respective duly authorized representatives.
For the Seller
Name: ---------------------------
Title: __________________ _
Date: ----------
For the Company
Name: --------------------------
Title: Director, Load Serving Operations -Idaho Power Company, Delivery
Date: ---------------------
Idaho Power Company Generator Interconnection Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 3
Attachment 1
Description and Costs of the Generation FacilitY. Interconnection Facilities and Metering
Equipment
Type of Interconnection Service:
Full Output:
Nominal Delivery Voltage:
Interconnection Details
Studied as an Idaho Power Network Resource under PURPA
1.2 MW
12.5kV
General Facility Description
The proposed project will connect to Idaho Power's 12.5kV system on Idaho Power Company's
Buckhorn (BKHN-041) distribution line. The total project output is 1.2 MW.
Interconnection Point
The Interconnection Point for the Double B Dairy Digester Project will be the low-side bushings on the
padmounted transformer (DB1). The project's location is in T12S R21E Section 18 of Cassia County,
Idaho. A drawing identifying the Point of Interconnection is included as Attachment 2. The Point of
Change of Ownership will be the low-side bushings on the pad mounted transformer (DB 1 ).
Seller's Interconnection Facilities
The Seller will install generators, low-side disconnect switches, all wiring and conduit between the
generators and the padmounted transformer, appropriate grounding measures, and associated
auxiliary equipment. The Seller will build underground facilities to the Point of Change of Ownership for
the generator facility. The low-side disconnect switch shall be visible, lockable, within ten (1 0) feet of
the padmounted transformers, and accessible to Idaho Power personnel.
The Seller will install equipment to receive signals from Idaho Power Company Grid Operations for
Generator Output Limit Control ("GOLC") -see Attachment 4 Operating Requirements.
The Seller will provide phone service to IPCo's generator interconnect package as described in
Telecommunications below.
All interconnection equipment electrically located on the generator side of the Point of Change
Ownership shall be owned and maintained by the Seller.
Other Facilities Provided by Seller
Telecommunications
In addition to communication circuits that may be needed by the Seller, the Seller shall provide the
following communication circuits for Idaho Power's use:
1. One POTS (Plain Old Telephone Service) dial-up circuit for revenue metering at the generation
interconnection site.
2. One DDS (Digital Data Service) circuit guaranteed minimum data rate of 19,200 bits per second for
SCADA between the generation interconnection site and a point designated by Idaho Power
Company.
The Seller is required to coordinate with the local communications provider to provide the
communications circuits and pay the associated monthly charges. The communication circuits will
need to be installed and operational prior to generating into Idaho Power system. Note that installation
by the local communications provider may take several months and should be ordered in advance to
avoid delaying the project. If the communication circuit types listed above are not available at the site
by the local communications provider, the Seller shall confer with Idaho Power.
Idaho Power Company Generator Interconnection Agreement# 308
I.P.U.C. No. 29, Tariff No. 101 Page 2 of 3
If high voltage protection is required by the local communications provider for the incoming cable, the
high voltage protection assembly shall be engineered and supplied by the Seller. Options are available
for indoor or outdoor mounting. The high voltage protection assembly shall be located in a manner that
provides Idaho Power 24-hour access to the assembly for communications trouble-shooting of Idaho
Power owned equipment.
Ground Fault Equipment
The Seller will install ground fault limiting equipment that will limit the zero sequence fault current to 20
amps at the Interconnection Point.
Monitoring Information
If the Interconnection Customer requires the ability to monitor information related to the Idaho Power
recloser in the generation interconnection package they are required to supply their own
communications circuit to the control box.
Local Service
The Seller is responsible to arrange for local service to their site, as necessary.
Easements
The Seller will secure underground and overhead easements with Double B Dairy once a specific route
is determined. The Seller will provide to IPCO a surveyed (Metes & Bounds) legal description along
with exhibit map for IPCO's facilities. After the legal description has been delivered to IPCO for review,
IPCO will supply to the Seller a completed IPCO easement for signature by the land owner of record.
Once the signatures have been secured, the Seller will return the signed easement to IPCO for
recording. IPCO construction will not proceed until the appropriate easements are secured.
Idaho Power Company's Interconnection Facilities
Idaho Power will install a standard generation interconnection package on the existing distribution
feeder (BKHN-041) on private property southwest of the intersection of 1200 South and 1100 West in
Cassia County, Idaho. The new interconnection package will include four distribution poles to mount a
local service transformer, solid blade disconnects, primary metering package, recloser, relays, fuses
and riser necessary for the package. The interconnection will be controlled by a SEL-311C line
protection relay. The relay will be located in a pole mounted enclosure and will also contain a test
switch (TS4), SLSS, modems, isolation interface, power supply, DC converter, control switch and surge
protector.
Idaho Power will install (and subsequently own and maintain) one 1500 kVA 277/480 to 12.47 kV
Grounded Wye I Grounded Wye padmounted transformer on top of a vault. Conduit and underground
cables will be installed from the interconnection package to padmounted transformer. Protective posts
will be installed to protect the ground mounted equipment from damage.
A 2" conduit will be installed alongside the underground primary to facilitate information exchange to the
customer about the recloser. (The Interconnection Customer is responsible for providing and installing
the appropriate cable).
All interconnection equipment electrically located on the utility side of the Point of Change Ownership
shall be owned, operated, and maintained by Idaho Power.
Idaho Power Company Generator Interconnection Agreement# 308
I.P.U.C. No. 29. Tariff No. 101 Page 3 of 3
Estimated Cost & Ownership: The following good faith estimates are
. __ _,De~·
Generation Facilities: I L -------
Provided by Seller __ __ _ b~ner J $NIA
nterconnection Facilities: I
Overhead Generation Interconnection Packa e f[PCO __ J $200,000
nderground E uipment af!_d 1500 kV A Transformer----jr-IP_C_O ____ -~~------=-$4..:..:52,0:....:0:....:.,0
TOTAL! $245,000.
PROJECT GRAND TOTAL! SEE ATTACH=M=E=N.:_:T:__6::.,__ ___ _
Full payment is required up front in accordance with Schedule 72, unless payment arrangements are
made in advance with Idaho Power Operations Finance (see Attachment 3).
Billing for construction activities will be based upon actual expenditures.
Idaho Power Company Generator Interconnection Agreement# 307
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 1
Attachment 2
One-line Diagram Depicting the Small Generation Facility, Interconnection Facilities, Metering
Equipment and Upgrades
Idaho Power Company Generator Interconnection Agreement# 307
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 1
Attachment 3
Milestones:
1. Idaho Power Company agrees only to the Construction timelines under its direct control
provided in the Facility Study Report for this Project.
2. These milestones will begin, and the construction schedule referenced below, will only be valid
upon receipt of funding in full from the Seller or their authorized third party no later than the date
set forth below for such payment. Additionally, failure by Seller to make the required payments
as set forth in this Agreement by the date(s) specified below will be a material breach of this
Agreement, which may result in any or all of the following: (i) loss of milestone dates and
construction schedules set forth below: (ii) immediate termination of this Agreement by Idaho
Power; (iii) removal from the generator interconnection queue.
Critical milestones and responsibility as agreed to by the Parties:
11/11/12
11/30/12
12/15/12 ---1/12/13
1/12/13
Agreed to by:
p,.,,;a.~t Leader issues Construction Complete Letter
testing begins
jCustomer's requested ln:_Service Da~
For the Seller: _____________ ,Date _____ _
For the Transmission Provider
Idaho Power Company, Delivery _____________ Date _____ _
Idaho Power Company Generator Interconnection Agreement# 307
I.P.U.C. No. 29. Tariff No. 101 Page 1 of 1
Attachment 4
Additional Operating Requirements for the Company's Transmission System and Affected
Systems Needed to Support the Seller's Needs
The Company shall also provide requirements that must be met by the Seller prior to initiating
parallel operation with the Company's Transmission System.
Operating Requirements
The project is required to comply with the applicable Voltage and Current Distortion Limits found in
IEEE Standard 519-1992 IEEE Recommended Practices and Requirements for Harmonic Control in
Electrical Power Systems or any subsequent standards as they may be updated from time to time.
Seller will be able to modify power plant facilities on the generator side of the Interconnection Point with
no impact upon the operation of the transmission system whenever the generation facilities are
electrically isolated from the transmission system and a terminal clearance is issued by Idaho Power
Company's Grid Operator.
Generator Output Limit Control ("Re-dispatch" or "GOLC'?
The Project will be subject to reductions directed by Idaho Power Company Grid Operations during
transmission system contingencies and other reliability events. When these conditions occur, the
Project will be subject to Generator Output Limit Control ("GOLC") and have equipment capable of
receiving signals from Idaho Power for GOLC. Generator Output Limit Control will be a setpoint from
Idaho Power to the Project indicating maximum output allowed.
Voltage flicker at startup and during operation will be limited to less thari 5% as measured at the
Interconnection Point. For this to occur, the current cannot exceed 65 Amps during start up at the 12.5
kV voltage level. This forces the generating facility to start the generators separately.
Low Voltage Ride Through
The Project must be capable of riding through faults on adjacent section of the power system without
tripping due to low voltage. It has been determined, through study, that the Project must be capable of
remaining interconnected for any single phase voltage as low as 0. 7 PU for 30 cycles, and for all three
phase voltages as low as 0.8 PU for 30 cycles.
Ground Fault Equipment
The Seller will install transformer configurations that provide a ground source to the transmission
system.
Idaho Power Company Generator Interconnection Agreement# 307
I.P.U.C. No. 29. Tariff No. 101 Page 1 of 1
Attachment 5
Reactive Power Requirements
The project must be controlled to operate at unity power factor +/-400 kVar. Voltage flicker at startup
and during operation will be limited to less than 5% as measured at the Interconnection Point. Voltage
flicker at startup and during operation will be limited to less than 5% as measured at the Interconnection
Point.
Idaho Power Company Generator Interconnection Agreement# 307
I.P.U.C. No. 29, Tariff No. 101 Page 1 of 1
Attachment 6
Company's Description of Special Facilities and Upgrades Required to Integrate the Generation
Facility and Best Estimate of Costs
As provided in Schedule 72 this Attachment describes Upgrades, Special Facilities, including
Network Upgrades, and provides an itemized best estimate of the cost of the required facilities.
Distribution Upgrades
n/a
Upgrades
--~ costs (fl'Ol_n_A_t_ta_c_h_m_e_n_t_;l, _______ _
_________ frqjectGRAND
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01
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 32
An IDACORP Company
July 27, 2012
VIA Email & Certified Mail #70113500000156449044
Leslie White
Exergy Development Group of Idaho, LLC
802 W Bannock, Suite 1200
Boise, ID 83 702
Subject: Double B Dairy Project # 308 -FINAL/DEFICIENCY NOTICE
Dear Leslie White:
By letter dated June 19, 2012 Idaho Power provided you with a Final Generator Interconnection
Agreement for the proposed Double B Dairy project to be interconnected in Cassia County,
Idaho.
Exergy Development Group of Idaho was to execute and return to me the Agreement with the
required deposit by July 20, 2012. That time period has now expired. Your application for
Generation Interconnection has now been deemed withdrawn and this project has been removed
for Idaho Power's Generator Interconnection Queue. If you wish to proceed with this project,
you must submit a new application for Generator Interconnection.
CC (via email):
Tess Park/IPC
Orlando Ciniglio/IPC
Eric Hackett/IPC
Aubrae Sloan/IPC
Donovan Walker/IPC
Sincerely,
Josh Harris
Operations Analyst
Ph 208.388.2658
[e-mail]
P.O. Box 70 (83707)
1221 W. Idaho St.
Boise, 10 83702
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
'
ATTACHMENT 33
August 28, 2012
Exergy Development Group of Idaho, LLC
Attn: Leslie White
802 W. Bannock Street, 12th Floor
Boise, ID 83702
Re: Double B Dairy GI #308 FSA Refund
Dear Ms. White:
An IDACORP Company
The above project has been withdrawn. As a result, we are refunding your deposit of$11,250,
less costs of $4,733 .34, plus interest of $521.10. Please find enclosed a check in the amount of
$7,037.76.
If I can be of any further assistance, please call [phone].
Sincerely,
~~JL-J
Aubrae N. Sloan
CC: Joshua Harris, IPC
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 34
Clark, Danielle
From: Walker, Donovan
Sent:
To:
Monday, October 08, 2012 11:31 AM
Clark, Danielle
Subject: FW: digester meeting on Friday
From: James Carkulis [mailto:[e-mail]]
Sent: Thursday, September 27, 2012 1:46 PM
To: Walker, Donovan; Leslie White; Laura Knothe; Harris, Joshua
Cc: Blackburn, Rex; Allphin, Randy; Darrington, Michael; [e-mail]; [e-mail]
Subject: Re: digester meeting on Friday
Thanks.
From: Walker, Donovan [mailto:[e-mail]]
Sent: Thursday, September 27, 2012 01:43 PM
To: James Carkulis; Leslie White; Laura Knothe; Harris, Joshua <[e-mail]>
Cc: Blackburn, Rex <[e-mail]>; Allphin, Randy <[e-mail]>; Darrington, Michael
<[e-mail]>; '[e-mail]' <[e-mail]>;
'rriley@ hawleytroxell.com' < [e-mail] >
Subject: Re: digester meeting on Friday
I have us scheduled for 9:30a.m. tomorrow. See you then.
Donovan.
From: James Carkulis [mailto:[e-mail]]
Sent: Thursday, September 27, 2012 01:03 PM
To: Walker, Donovan; Leslie White <[e-mail]>; Laura Knothe
<[e-mail]>; Harris, Joshua
Cc: Blackburn, Rex; Allphin, Randy; Darrington, Michael; [e-mail] <[e-mail]>;
rriley@ hawleytroxell.com < [e-mail] >
Subject: Re: digester meeting on Friday
We shall meet tomorrow.
From: Walker, Donovan [mailto:[e-mail]]
Sent: Thursday, September 27, 2012 11:43 AM
To: James Carkulis; Leslie White; Laura Knothe; Harris, Joshua <[e-mail]>
Cc: Blackburn, Rex <[e-mail]>; Allphin, Randy <[e-mail]>; Darrington, Michael
<[e-mail]>; '[e-mail]' <[e-mail]>;
'[e-mail]' <[e-mail] >
Subject: RE: digester meeting on Friday
James,
Idaho Power takes significant issue with your "first I heard" statement below. Your statement and inferences that there
was some kind of agreement to move the dates in the PPA for the digesters, as part of the agreement reached with
regard to the wind projects is absolutely not correct. Mr. Eiguren and Mr. Riley were both present as your attorneys at a
meeting on August 14, 2012, with myself and Mr. Williams, on behalf of Idaho Power, to finalize the paperwork on the
1
settlement agreement for the wind projects. Mr. Riley attempted to present terms in those agreements related to the
digesters. When I questioned him about it and informed him that there had been no agreement and no discussion
related to the digesters, Mr. Eiguren stepped in and told Mr. Riley that the digesters were not part ofthe discussions
that he and Rex Blackburn had previously had regarding termination of the wind PPAs, were not part of the agreement
and settlement reached related to the wind projects, and were separate matters that had not been discussed, much less
agreed to by the parties. In addition, Mr. Blackburn and myself again informed Mr. Eiguren on September 24, 2012, that
there had been no discussion and no agreement to change the PPA dates for the digesters, and further that Idaho Power
was not willing to agree to changes in those dates.
Simply put, your agents-Messrs. Eiguren and Riley-will confirm that there was no agreement reached to modify the
digester PPA agreements, and that Idaho Power expressly rejected any proposal to do so. If the purpose of your
requested meeting tomorrow is to discuss modification oft he terms of the digester PPAs, the meeting is not necessary.
I previously advised Exergy, in writing, on September 20, 2012, that Idaho Power is not in agreement to amending these
agreements. Additionally, as stated below, Idaho Power has offered Exergy an expedited schedule that would allow us
to complete the required interconnection facilities prior to the end of this year-contingent upon Exergy authorizing
Idaho Power to proceed with such work no later than Monday October 1, by paying the required deposit and executing
the GIA.
With the above in mind, please advise as to whether there is a need for us to meet tomorrow.
-Donovan
From: James Carkulis [mailto:[e-mail]]
Sent: Thursday, September 27, 2012 9:35AM
To: Walker, Donovan; Leslie White; Laura Knothe; Harris, Joshua
Cc: Blackburn, Rex; Allphin, Randy; Darrington, Michael
Subject: Re: digester meeting on Friday
Meeting tomorrow at 9:30 shall be fine. I should be back from North Carolina by then .
However, first I heard about something different than what was agreed to as the Term Sheet presented for settlement
was an email to Leslie last Friday.
Thanks
James
From: Walker, Donovan [mailto:[e-mail]]
Sent: Thursday, September 27, 2012 08:48AM
To: James Carkulis; Leslie White; Laura Knothe; Harris, Joshua <[e-mail]>
Cc: Blackburn, Rex <[e-mail]>; Allphin, Randy <[e-mail]>; Darrington, Michael
<[e-mail]>
Subject: RE: digester meeting on Friday
James,
Idaho Power can meet with you on Friday. Could we make it at either 9:00 or 9:30a.m.? Also, as previously indicated,
Idaho Power has been clear that it will not agree to change the dates in the PPA. Idaho Power has offered an expedited
schedule for the construction of the required interconnection facilities, and will commit to completing that work by the
end of the year IF you authorize Idaho Power to proceed no later than Monday, October 1, by paying the required
deposit and executing the GIA.
2
Please let me know if you can make it at 9:00 or 9:30a.m. tomorrow.
Thanks,
-Donovan
-------
From: James Carkulis [mailto:[e-mail]]
Sent: Thursday, September 27, 2012 5:38 AM
To: Walker, Donovan; Leslie White; Laura Knothe; Harris, Joshua
Subject: digester meeting on Friday
Donovan:
------------------
I would like to request a digester meeting on Friday around 10 AM please to sort this out.
Thanks.
James
James T Carkulis
802 W Bannock, 12th Floor Boise, ID 83702
Office: 208.336.9793 1 Mobile: [phone]
jcar'r<[e-mail]
wvvw.exergydeveioprnent.com
This electronic or printed document contains information which (a) may be LEGALLY PRIVILEGED, PROPRIETARY IN NATURE, OR OTHERWISE PROTECTED BY LAW
FROM DISCLOSURE, and (b) is intended only for the use of the Addressee(s) named above. If the reader of this message is not the intended recipient, or the employee or
agent responsible to deliver it to the intended recipient, you are hereby notified that any dissemination, distribution or copying of this communication is strictiy prohibited_ If you
have received this communication in error, please immediately notify us by telephone, and return !he originai message to us att11e above email address. Thank you.
This transmission may contain information that is privileged, confidential and/or exempt from disclosure under applicable law. If you are not the intended recipient, you are hereby
notified that any disclosure, copying, distribution, or use of the information contained herein (including any reliance thereon) is STRICTLY PROHIBITED. If you received this
transmission in error, please immediately contact the sender and destroy the material in its entirety, whether in electronic or hard copy format. Thank you.
3
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 35
Clark, Danielle
From:
Sent:
To:
Subject:
Walker, Donovan
Monday, October 08, 2012 11 :29 AM
Clark, Danielle
FW: New Energy 2 and New Energy 3
From: James Carkulis [mailto:[e-mail]]
Sent: Friday, September 28, 2012 11:40 AM
To: Walker, Donovan; Harris, Joshua; Leslie White; Laura Knothe
Subject: New Energy 2 and New Energy 3
Donovan :
Thank you for the time today. Not sure I will stand for more insults though. I would venture to say Rex's reputation also
precedes him.
So we shall not be taking the expedited interconnection process for Swager. let's proceed under normal circumstances.
As to the PPAs, I think it best that we file our force majeure positions on those based on the generic PURPA docket going
on. Hopefully, we can resolve both of these outside ofthe courtroom.
Thanks.
James
)-.
A · ).... 1 James T Carkulis ~ -"( I 802 W Bannock, 12th Floor Boise, ID 83702 . .9.?SQrgy 1 ;;r.~~~E~E~:~tt~~:-:~~06·593013
This electronic or p1inted document contains inionnation which (a) may be LEGALLY PRIVILEGED. PROPRIETARY IN NATURE, OR OTHERWISE PROTECTED BY LAW
FROM DISCLOSURE, and (bj is intended only tor the use of the Addressee(s) named above. If the reader of this message is not the intended recipient, or the employee or
agent responsible to deliver it to the intended recipient, you are hereby notified that any dissemination, distribution or copying ol this communication is strictly prohibited. If you
have received t11is communication in error, please immediately notify us by telephone, and retum the originai message to us at the above email address. Thank you.
1
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-26
IDAHO POWER COMPANY
ATTACHMENT 36
From Seller:
NOTICE OF F0RCE MAJEURE
UNDER
FIRM ENERGY SALES AGREEMENTS DATED MAY 24, 2010
RE:
SWAGER FARMS PROJECT (#31616130)
DOUBLE B DAIRY PROJECT (#31616120)
New Energy Two, LLC
New Energy Three, LLC
c/o Exergy Development Group of Idaho, LLC
802 W. Bannock Ste. 1200
Boise, ID 83702
Attn: James Carkulis
Email: jcaik.ulis·®exel}gydeveloprnent.co_m
To Idaho Power: Vice President, Power Supply
Idaho Power Company
With copy to:
PO Box 70
Boise, Idaho 83707
Email: [e-mail]
Cogeneration and Small Power Production
Idaho Power Company
POBox 70
Boise, Idaho 83707
Email: rallphin@ idahopower.com
Date: September 28,2012
VIA EMAIL, HAND DELIVERY AND REGULAR MAIL
In accordance with Article XIV (Force Majeure) of the Firm Energy Sale Agreements referenced
above (hereinafter, collectively, the "FESA"), Seller hereby gives Idaho Power written notice of the
occmTence of a Force M<tieure event, in the following particulars:
1. There are currently ongoing proceedings upon the IPUC docket, the issues in which
include pricing, size, duration and curtailment. (See, e.g., IPC-E-11-15.)
2. The pending proceedings concern, among other things, the unilateral amendment by
Idaho Power of FESA provisions regarding (i) ownership of Green Tags and Renewable Energy
Certificate(s) (RECs), or equivalent environmental attributes, and (ii) Suspension of Energy
Deliveries (Curtailment).
Exergy Development Group 802 W Bannock, 12<h Floor Bo1se. ID 83702 P 208.336 9793 F 208.336.9431
3. The overall effect of the pending proceedings is that until such proceedings are finally
resolved, the entire citcumstance of continued viability of all renewable energy projects in Idaho is
undecided and beyond the control of Seller. Indeed, the ultimate decisions made may render Seller
wholly or in part unable to perform its obligations under the FESA.
4. A consequence of the pending proceedings, perhaps unintended, but certainly beyond
the control of Seller, is that renewable energy project lenders are unwilling to lend in Idaho pending
the outcome of these proceedings. There is, therefore, no financing available, making it impossible
for Seller to pelform its obligation under the FESA.
Accordingly, by this written notice to Idaho Power, Idaho Power is advised that a Force Majeure
event has occurred, thereby creating a suspension of performance for the duration of the event, as
further described in Article XIV of the FESA.
Further, pursuant to Section 19.1 (Disputes) of Article XIX of the FESA, if Idaho Power disputes
this matter, Seller reserves the right to submlt the same to the Idaho Public Utilities Commission
and/or pursue any resolution to which it may be entitled before the appropriate Idaho district court,
FERC and/or any other applicable tribunal or governing body.
Further, Seller asserts that it is protected from any default under the FESA pending resolution of the
asserted Force Majeure issues, including, without limitation, any dispute or litigation as to whether
said Force Majeure Event does protect Seller from any such default.
SELLER:
New Energy T~o. LLC
::~,~~
Leslie White
Member
cc: Donovan E. Walker. Esq.
James CarkuJis
Laura Knothe
Brian L. Ballard, Esq.
Exergy Development Group 802 W Bannock, 12th Floor Boise, 10 83702 P 208.336.9793 F 208.336.94 31