20121114Attachments.pdf

BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 1
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FIRM ENERGY SALES AGREEMENT
BETWEEN
TITLE
Definitions
IDAHO POWER COMPANY
AND
NEW ENERGY TWO, LLC
TABLE OF CONTENTS
No Reliance on Idaho Power
Warranties
Conditions to Acceptance ofEnergy
Term and Operation Date
Purchase and Sale ofNet 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 ofLaws 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
AppendixB
AppendixC
AppendixD
FIRM ENERGY SALES AGREEMENT
(10 aMW or Less)
Project Name: Swager Farms
Project Number: 31616130
THIS AGREEMENT, entered into on this 2. c.(tday of fhec..r 2010 between NEW ENERGY
TWO, LLC, an Idaho limited liability company (Seller), and IDAHO POWER COMPANY, an Idaho
corporation (Idaho Power), hereinafter sometimes referred to collectively as "Parties'' or individually as "Party."
WITNESSETH:
WHEREAS, SeHer will design, construct, own, maintain and operate an electric generation facility; and
WHEREAS, Seller wishes to sell, and Idaho Power is willing to purchase, finn 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 1: 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 110% of the monthly Net Energy Amount as specified
in paragraph 6.2 of this Agreement.
1.2 "Commission" -The Idaho Public Utilities Commission.
1.3 "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 ofthis 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 7:00am 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) subject to paragraph 19.2.2.
1.18 "Maximum Capacity Amount"-The maximum capacity (MW) ofthe 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 term 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 ofthis 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 11 0% 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 of Idaho Power in connection with the transactions contemplated by this
Agreement.
2.2 Seller Independent Experts -All professionals or experts including, but not limited to, engineers,
attorneys or accountants, that Seller may have consulted or relied on in undertaking the transactions
contemplated by this Agreement have been solely those of Seller.
ARTICLE 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 ofBusiness 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 confmnation 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 ofthose 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 (1 0% ).
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 1s 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 1
Season 2
Season 3
Month
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 51h day following the end of the
previous month. If the Seller does not provide the Ongoing Monthly Net Energy Amounts in a
timely manner, Idaho Power will use the most recent 3 months of the Initial Year Monthly Net
Energy Amounts specified in paragraph 6.2.1 for the next 3 months of monthly Net Energy
amounts.
6.2.3 Seller's Adjustment ofNet 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: ( 1) 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 5:00 PM of the 5111 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 ofNet Energy Amount-Ifldaho 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
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.
TGU = Sum of all of the individual generator ratings of the generation
units at this Facility as specified in Appendix B of this
agreement.
RSH
TH
= 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 ofEnergy.
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 Heayy 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
2029
2030
2031
89.53
92.03
94.60
96.69
146.17
150.25
154.45
157.85
121.81
125.21
128.71
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 3 07 44, 3 073 8 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
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 Vill: ENVIRONMENTAL ATTRIBUTES
8.1 Seller retains ownership under this Agreement of Green Tags and Renewable Energy Certificates
(RECs ), or the equivalent environmental attributes, directly associated with the production of energy
from the Seller's Facility sold to Idaho Power.
ARTICLE IX: FACILITY 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 Bre~ch
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 DeclaJ'ecl Suspension ofEnergy 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 ofNet 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 less 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 unreasonably 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 loss, damage, expense and
liability to third persons for injury to or death of person or injury to property, proximately caused by the
indemnifying Party's (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 current 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.
13.3 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 Notify 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 certificates and, ifthe Facility is fueled by gas produced by an anaerobic
digester system, any diminution or loss of anaerobic activity due to the inability ofldaho 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 of Idaho 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, trust, partnership or joint venture or impose a trust or
partnership duty, obligation or liability on or with regard to either Party. Each Party shall be
individually and severally liable for its own obligations under this Agreement.
ARTICLE XVII: WAIVER
17.1 Any waiver at any time by either Party of its rights with respect to a default under this Agreement or
with respect to any other matters arising in connection with this Agreement shall not be deemed a
waiver with respect to any subsequent default or other matter.
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ARTICLE XVlll: CHOICE OF LAWS Al\TD VENUE
18.1 This Agreement shall be construed and interpreted in accordance with the laws of the State of Idaho
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 ofldaho 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 of the terms or conditions of this Agreement
(an "event of default"), the nondefaulting Party shall cause notice in writing to be given to
the defaulting Party, specifying the manner in which such default occurred. If the defaulting
Party shall fail to cure such default within the sixty (60) days after service of such notice, or
if the defaulting Party 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.
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
19.3.3
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
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 pennits 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 A UTIIORrZATION
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 .1 No modification to this Agreement shall be valid unless it is in writing and signed by both Parties and
subsequently approved by the Commission.
ARTICLE 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 Two, 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
POBox 70
Boise, Idaho 83707
Email: [e-mail]
Copy of document to:
Cogeneration and Small Power Production
Idaho Power Company
PO Box 70
Boise, Idaho 83 707
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 XXVI: ADDITIONAL TERMS AND CONDITIONS
26.1 This Agreement includes the following appendices, which are attached hereto and included by
reference:
Appendix A
AppendixB
Appendix C
AppendixD
Generation Scheduling and Reporting
Facility and Point of Delivery
Engineer's Certifications
Forms ofLiquid Security
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ARTICLE XXVII: SEVERABILITY
27.1 The invalidity or unenforceability of any term or provision of this Agreement shaH not affect the
validity or enforceability of any other tenns or provisions and this Agreement shall be construed in all
other respects as if the invalid or unenforceable term or provision were omitted.
ARTICLE XXVTII: COUNTERPARTS
28.1 This Agreement may be executed in two or more counterparts, each of which shall be deemed an
miginal but all of which together shall constitute one and the same instrument.
ARTICLE XXlX: 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 Two, LLC
By {firsn LL tkuJ By ~
Lisa A Grow Laura Knothc, PE
Sr. Vice President, Power Supply
Dated 5· 2'-l ·tO Dated 5 J 2--l[to
"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
Reason
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 current day
• Estimated Generation for the next day
Planned and Unplanned Project outages
Call 1-800-345-1319 and leave the following information:
• Project Identification-Project Name and Project Number
• Approximate time outage occurred
• Estimated day and time of project coming back online
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Seller's Contact Information
24-Hour Project Operational Contact
Name:
Telephone Number:
Cell Phone:
Jay Kesting
(208) 94 7-4519
[phone]
Project On-site Contact information
Name:
Telephone Number:
Kurt Standley
[phone]
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APPENDIXB
FACILITY AND POINT OF DELIVERY
Project Name: Swager Farms
Project Number: 31616130
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: Buhl, ID
Sections: _11_ Township: __lQ_S_ Range: 15E Clover Quadrangle County: Twin Falls ID.
Description oflnterconnection Location: Near 1707 E 3800 N, Buhl, ID 83316
Nearest Idaho Power Substation: Clover Substation
B-3 SCHEDULED FIRST ENERGY AND OPERATION DATE
Seller has selected September l, 2011 as the Scheduled First Energy Date.
Seller has selected October 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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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
I 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 terminating at the Idaho Power
facilities capable of providing Idaho Power with continuous instantaneous information on the Facilities
energy production. Idaho Power provided equipment will be owned and maintained by Idaho Power,
with total cost of purchase, installation, operation, and rnaintenance, 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 information 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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APPENDIXC
ENGINEER'S CERTIFICATION
OF
OPERATIONS & MAINTENANCE POLICY
on behalf of himself and The undersigned -----
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 m
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
I 0. 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)
Dme ________________________ ___
-38-
5/19/2010
APPENDIXC
ENGINEER'S CERTIFICATION
OF
ONGOING OPERATIONS AND MAINTENANCE
The undersigned on behalf of himself and
____________ hereinafter collectively referred to as "Engineer," hereby states and certifies to
the Seller as follows:
1. That Engineer is a Licensed Professional Engineer in good standing in the State of Idaho.
2. That Engineer has reviewed the Energy Sales Agreement, hereinafter "Agreement," between Idaho
Power as Buyer, and _________ as Seller, dated------------
3. That the cogeneration or small power production project which is the subject of the Agreement and this
Statement is identified as IPCo Facility No. and hereinafter referred to as the "Project".
4. That the Project, which is commonly known as the _________ P.roject, is located m
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.
-39-
5/19/2010
8. That Engineer has made a physical inspection of said Project, its operations and maintenance records
smce 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-
5119/2010
APPENDIXC
ENGINEER'S CERTIFICATION
OF
DESIGN & CONSTRUCTION ADEQUACY
The undersigned on behalf of himself and
____________ hereinafter collectively referred to as "Engineer", hereby states and certifies to
Idaho Power as follows:
1.
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 ________ _____cProject, is located m
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)
Dme ____________________ __
-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.
1. 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 of Idaho 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-12-25
IDAHO POWER COMPANY
· ATTACHMENT 2
MECHANICAL Heating Ventilation Air Conditioning
Plumbing Radiant Heating
Refrigeration
• design, sales & installation • preventative maintenance • service & repair
ARCHITECTURAL METALS Flashing Metal Roofing Metal Siding
• design, fabrication &.
installation
METAL FABRICATION Structural Stairs, Railings Stainless Steel Specialty Fabrication Custom Product Manufacturing
• design, fabrication &.
installation
FOOD SERVICE Commercial Kitchens Institutional Kitchens Restaurant Kitchens
• design, fabrication &
installation
FOOD PROCESSING EQUIPMENT Food Manufacturing Equip. Sorting & Sizing Washing & Conveying Packaging Custom Equipment
• design, fabrication,
sales & installation
BIOGAS DIGESTERS
• design, fabrication
sales & installation
6920 Salashan Pkwy, A·1 02
P.O. Box 2708
Ferndale, WA 98248
Office: 360.366.9900
Fax: [phone]
[e-mail]
http :1 /www andgar.com
May 27,2009
Idaho Power Compani
1221 W. Idaho Street
Boise, ID 83702
ATTN: Rowena Bishop
RE: Swager Farms #268
Dear Rowena,
Due to project uncertainties, we are no longer willing to proceed with the
Facility Study for the Swager Farms project #268. We may want to pursue this
project again in the future but feel that it is not in our best interest to do so at
this time. Thank you for your work on this so far. We look forward to working
with you more in the near future.
Sincerely,
Eric Powell
ANDGAR CORPORATION
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 3
SMALL GENERATOR INTERCONNECTION REQUEST
(Application Form)
Transmission Pro\ider: 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 and Instructions
An Interconnection Customers who request interconnection must submit this Interconnection Request by
hand delivery, mail, e-mail, or fax to the Transmission Provider.
Processing Fee or Deposit:
If the Interconnection Request is submitted under the Fast Track Process, the non-refundable processing
fee is $500.
If the Interconnection Request is submitted under the Study Process, whether a new submission or an
Interconnection Request that did not pass the Fast Track Process, the Interconnection Customer shall
submit to the Transmission Provider a (lb-p®.\ttl"!a~: i;:.~<,;t;,e:.,:l $1;000 t\'iwards the cost of the feasibility
study. '
Interconnection Customer Information
Legal Name of the Interconnection Customer (or, if an individual, individual's name)
N'";rn~: <An,clj{AY Lovporo.hoV\
:C¢,i~t:t.1'~;!:~c:n: ~...,'t-'t-1 _,_\-e."""---'0""--'\""A_,~_,V''-:-~+'""e....,V'\...,..,><--------------------­
Mamn~(Addtess; Po Bo x '}_Jog ~U~(A;,hc-.VJ Pt'-wy A-lu?.
.Sta.ce: \/JA...:..· __ _ Z:ip: · .. if~24Q
l~~telHty Lopation {ifdttferent from above): '?. l/l.. 1\1 i] Ob
TdepJwne (Bvening): ---------
Cont~tNrume: ____________________________________________________________ _
Title:-------------------------,---------------
Ad&ess: _________________________________________________________ __
Telephone (Day): ________________ Telephone (Evening): _______________ _
Fax: _____________________ E-Mail Address:------------
Apl1liUJ.ti6i.i :ls for: ' · X New Small Generating Facility
___ Capacity addition to Existing Small Generating Facility
.. If capacity additiqn t6 existing facility, please describe:----------------
Net Metering? Yes_ No_
To Supply Power to the Interconnection Customer? Yes _No_
To Supply Power to Others? Yes .)S_No __ To Ltt-1\i-\)'
For installations at locations with existing electric service to which the proposed Small Generating
Facility will interconnect, provide:
(Local Electric Service Provider*) (Existing Account Number*)
[*To be provided by the Interconnection Customer if the local electric service provider is different from
the Transmission Provider]
ContactNrune: ________________________________________________________ ___
Title: _______________________________________________ __
Address: ______________________________________________________________ ___
Telephone (Day): -------------------Telephone (Evening):---------------
Fax:----------------------------E-Mail Address:-----------
Re:<l t)ei;:i'ed }Joint ef iuterconiwl;t\(,n: See Ire£~(}..~ Dva.w ,·VI q ..,./
lnt<:<rco•mJe:bmt CDntrJlT:er'.;: Itequ.ested In-Service Date:: ___ Cf,__,_/_~_._/-'-2» __ 1 [:;..) _________________ _
2
Small Generating Facility Information
Data apply only to the Small Generating Facility, not the Interconnection Facilities.
,l?.nergy Sonn:t'; _· Solar _Wind _Hydro _Hydro Type (e.g. Run-of-River):. ____ _
Diesel _Natural Gas _Fuel Oil 4 Other (state type) ~B ..... to..,.,"'·o'-"5"-----------
}';J.irt.ut· ?-riovc:i: _Fuel Cell >\ Recip Engine _Gas Turb Steam Turb
_Microturbine _PV _Other
__ Induction Inverter
kW (Typical) Generator Nameplate kV AR: c.r~g
Interconnection Customer or Customer-Site Load: _____ ___.__.kW (if none, so state)
Typical Reactive Load (if known): ______ _
List components of the Small Generating Facility equipment package that are currently certified:
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: _.S._r+:....o......;.vn~f--='e;.;..o.f-"'~=-----?.__I:=.;_'l...:.......3=b.=D'-1;(::-'~=~=--~.:...J· '-"'=:i""'c._,__ha.~J)-+-­
Version Number:-----------
l(,d ~ -'.ih~~\ O~rl~l:.'tJor j:~.,·~/etF&t~ol' tz~ted:l'(ll·l'~r :~~~cto-.·: tiFt:~hJ:tg\ -·--~---"Lagging: _....;.•-~-=-· -~--
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
Request.
3
Small Generating Facility Characteristic Data (for inverter~based machines)
Max design fau1t contribution current: ___ _ Instantaneous orRMS?
Harmonics Characteristics:------------------------
Small Generating Facility Characteristic Data (for rotating machines)
RPM Frequency: 12-oo
(*)Neutral Grounding Resistor.(If Applicable): ____ _
Synchronous Generators: $€e, A-ffcu:.hed
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.
KVABase: Field Volts:-----------
Field Amperes: _____ _
Induction Generators:
Motoring Power (kW): -=------,,----
lit 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: ___,..,.......,,------,--
Rs;ar,tivd'pw~)t ,ltequ:i.i:"?(j Ip v ~~:t (NO. LO!ld) .. _~ _____ _
Riail-t1'ie !>o\vcr Rcqhlied 111 V!ii·.s (.fW:ll.{,!<.d): ··-=::-:--c:-:::c::-:-=-
Total Rotating Inertia, H: Per Unit on kV A Base
Note: Please contact the Transmission Provider prior to submitting the Interconnection Request to
determine if the specified information above is required.
4
Excitation and Governor System Data for Synchronous Generators Only
Provide appropriate IEEE model block diagram of excitation system, governor system and powe~ 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 . tAt :\l:1 y S' (je_
Willa t:ransfon~ler be used between the generator and tbe point of common coupling·l ~ ii~~ XN o
Will the transformer be provided by the Interconnection Custome::r'? • ~Ye$ XN 6
Transformer Data (If Appllcable. for Interconnection Customer-Owned Transformer):
Is the transformer: __ single phase __ three phase? Size: kVA -------" TrB.DSformer Impedance: % on kVA Base
If Three Phase:
Transformer Primary: __ Volts __ Delta __ Wye __ Wye Grounded
Transformer Secondary: __ Volts __ Delta __ Wye __ Wye Grounded
Transformer Tertiary: __ Volts __ Delta __ Vfye __ Wye Grounded
Transformer Fuse Data Of Applicable, for Interconnection Customer-Owned Fuse):
(Attach copy of fuse manufacturer's Minimum Melt and Total Clearing Time-Current Curves)
Manufacturer:--------Type: ______ Size: ____ Speed: _____ _
Interconnecting Circuit Breaker (ifaoplicable):
Manufacturer: A B ¥:. Type: fC '2.-
Load Rating (Amps): I bDo Interrupting Rating (Amps): '$S' ILA Trip Speed (Cycles): l D Y'I\S
Interconnection Protective Relays (If APPlicable):
If Microprocessor-Controlled:
tsecJ:w; ~~ Wl ~'+lOA' C s.R.e cd-tM-~tl)
List of Functions and Adjustable Setpoints for the protective equipment or software:
Setpoint Function Minimum Maximum
1.
2.
3.
4.
5.
6.
5
IfDiscrete 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: £L .. :~ S
Type: A-· \'1oo Accuracy Class:_ Proposed Ratio Connection: \'200 : '>"'
Manufacturer:-------------------­
Type:-------Accuracy Class: _ Proposed Ratio Connection: __
Potential Transformer Data af Applicable):
Manufacturer:--------------------Type: _______ Accuracy Class:_ Proposed Ratio Connection: __
Manufacturer:----------------:----­
Type:-------Accuracy Class: _ Proposed Ratio Connection: __
6
General Information
,En.do.se <.:P.PY of .site tle:c;trk<Jl tme-Jjut: i:li~gram .showing the configuration of all Small Generating
.f'acility 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\~: . ..:.c'Yts . ..::..:.:.:....No · · ·.
F,oclos~: ,iop:y ~~f nny :iiie:d6t~i1opentation that indicates the precise physical location of the proposed Small
Generating Facility ~.USGS topographic map or other diagram or documentation).
Proposed location of protective interface equipment on property (include address if different from the
Interconnection Customer's address)----------------------
Enclose copy of any site documentation that 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 alarm/monitoring circuits (if applicable).
Are Schematic Dmwings Enclosed? _Yes __ No
Applicant Signature
I hereby certify that, to the best of my knowledge, all the information provided in this Interconnection
Request is true and correct.
For Interconnection Customer:
Siq;_ff e.d.L. . -~~~=~-------Ditt6: 9h-k
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PI736D-Technical Data Sheet ,----· -------~~-----------···---·---~ I . i i
----..1
PI736D
SPECIFICATIONS & OPTIONS
STAMFORD
STANDARDS
Newage Stamford industrial generators meet the requirements of BS EN 60034 and the relevant sections
of other national and international standards such as BS5000, VDE 0530, NEMA MG1-32, IEC60034, CSA
C22.2-100, AS1359. Other standards and certifications can be considered on
request.
DESCRIPTION
The STAMFORD PE range of synchronous ac generators are brushless with a rotating field. They are separately
excited by the STAMFORD Permanent Magnet Generator (PMG). This is a shaft mounted, high frequency, pilot
exciter which provides a constant supply of clean power via the Automatic Voltage Regulator (AVR) to the main
exciter. The main exciter output is fed to the main rotor,
through a full wave bridge rectifier, protected by surge suppression.
VOLTAGE REGULATORS
The PE range of generators, complete with a PMG, are
available with one of two AVRs. Each AVR has soft start voltage build up and built in protection against sustained
over-excitation, which will de-excite the generator after a
minimum of B seconds.
Underspeed protection (UFRO), is also provided on both
AVRs. The UFRO will reduce the generator output voltage
proportional to the speed of the generator below a pre-
satiable level.
The MX341 AVR Is two phase sensed with a voltage
regulation of :1: 1 %. (see the note on regulation).
The MX321 AVR is 3 phase rms sensed with a voltage
regulation of 0.5% rms (see the note on regulation). The UFRO circuit has adjustable slope and dwell, for
controlled recovery from step loads. An over voltage protection circuit will shutdown the output device of the
AVR, it can also trip an optional excitation circuit breaker if required. As an option, short circuit current limiting is
available with the addition of current transformers.
Both the MX341 and the MX321 need a generator
mounted current transformer to provide quadrature droop
characteristics for load sharing during parallel operation. Provision is also made for the connection of the
STAMFORD power factor controller, for embedded
applications, and a remote voltage trimmer.
2
WINDINGS & ELECTRICAL PERFORMANCE
All generator stators are wound to 2/3 pitch. This eliminates triplen (3rd, 9th, 15th ... ) harmonics on the
voltage waveform and is found to be the optimum design for trouble-free supply of non-linear loads. The 2/3 pitch
design avoids excessive neutral currents sometimes seen with higher winding pitches. A fully connected damper
winding reduces oscillations during paralleling. This
winding, with the 2/3 pitch and carefully selected pole and
tooth designs, ensures very low levels of voltage waveform
distortion.
TERMINALS & TERMINAL BOX
Standard generators feature a main stator with 6 ends brought out to the terminals, which are mounted on the
frame at the non-drive end of the generator. A sheet steel
terminal box contains the AVR and provides ample space for the customers' wiring and gland arrangements. It has
removable panels for easy access.
SHAFT &KEYS
All generator rotors are dynamically balanced to better than BS6861 :Part 1 Grade 2.5 for minimum vibration in
operation. Two bearing generators are balanced with a
half key.
INSULATION/IMPREGNATION
The Insulation system is class 'H', and meets the requirements of UL 1446.
All wound components are impregnated with materials and
processes designed specifically to provide the high build required for static windings and the high mechanical
strength required for rotating components.
QUALITY ASSURANCE
Generators are manufactured using production procedures
having a quality assurance level to
BS EN ISO 9001.
NOTE ON REGULATION
The stated voltage regulation may not be maintained in the
presence of certain radio transmitted signals. Any change in performance will fall within the limits of Criteria 'B' of EN
61000-6-2:2001. At no time will the steady-state voltage
regulation exceed 2%.
Note: Continuous development of our products entitles us to change specification details without notice, therefore they must not be regarded as binding.
Front cover drawing is typical of the product range.
CONTROL SYSTEM
A.V.R.
VOLTAGE REGULATION
SUSTAINED SHORT CIRCUIT
INSULATION SYSTEM
PROTECTION
RATED POWER FACTOR
STATOR WINDING
IJVINDING PITCH
IJVINDING LEADS
MAIN STATOR RESISTANCE
MAIN ROTOR RESISTANCE
EXCITER STATOR RESISTANCE
EXCITER ROTOR RESISTANCE
R.F.I. SUPPRESSION
WAVEFORM DISTORTION
MAXIMUM OVERSPEED
BEARING DRIVE END
BEARING NON-DRIVE END
WEIGHT COMP. GENERATOR
WEIGHT WOUND STATOR
WEIGHT WOUND ROTOR
WR2 1NERTIA
SHIPPING WEIGHTS In a craie
PACKING CRATE SIZE
TELEPHONE INTERFERENCE
COOLING AIR
VOLTAGE STAR
kVA BASE RATING FOR REACTANCE
VALUES
Xd DIR. AXIS SYNCHRONOUS
X'd DIR. AXIS TRANSIENT
X"d OIR. AXIS SUBTRANSIENT
Xq QUAD. AXIS REACTANCE
X"q QUAD. AXIS SUBTRANSIENT
XL LEAKAGE REACTANCE
Xz NEGATIVE SEQUENCE
Xo ZERO SEQUENCE
P1736D
WINDING 312
STAMFORD
SEPARATELY EXCITED BY P.M.G.
MX341 I MX321 I
:t1% ' :t 0.5 % jiNith 4% ENGINE GOVERNING
Fl.EFER TO SHORT CIRCUIT DECREMENT CURVES (page 7)
CLASS H
IP23
O.B
DOUBLE LAYER LAP -.. TWO THIRDS
6
0.0018 Ohms PER PHASE AT 22•c STAR CONNECTED
2.69 Ohms at 22•c
17 Ohms at zz•c
~ .. 0.1 Ohms PER PHASE AT 22•c
as EN 61000~-2 & as EN 61000-6-4,VDE 0875G, VDE 0875N. refer to factory for others
NO LOAD< 1.5% NON-DISTORTING BALANCED LINEAR LOAD< 5.0%
1500 ReviMin
BALL. 6228 C3
---~---·-BALL. 6319 C3
1 BEARING 2BEARING
3233 kg 3182 kg
1368 kg 1368 kg
1548 kg 1486 kg -53.5769 kgm2 52.578 kgm2
3350kg 3372kg
194 X 105 X 154(cm) 194 x 105 x 154(cm)
50 Hz 60Hz
THF<2% TIF<50
1.79 m'lsec 3793 elm 2.3 m'lsac 4874 elm
3801220 I 4001231 4151240 l 4401254 418/240 440/254 4601266 480/277
920 920 920 ~ 920 1050 1150 1150 1150
2.11 1.90 1.77 I 1.57 2.49 2.44 2.23 2.05
0.16 0.14 0.13 I 0.12 0.18 0.18 0.16 0.15 I
0.11 ! 0.10 0.09 i I 0.08 0.13 0.13 0.12 0.11
1.35 1.22 1.13 I 1.01 1.59 1.56 1.43 1.31
0.34 I 0.31 0.29 I 0.26 0.40 0.39 0.36 0.33
0.04 0.04 0.03 I 0.03 0.05 0.05 0.04 0.04
0.20 ' 0.18 0.17 I 0,15 0.23 0.23 0.21 0.19
0.02 0.02 0.02 0.02 0.02 0.02 0.02 0.02
REACTANCES ARE SATURATED VALUES ARE PER UNIT AT RATING AND VOLTAGE INDICATED
T'd TRANSIENT TIME CONST. 0.162s
T"d SUB-TRANSTIME CONST. 0.015s
T'do O.C. FIELD TIME CON ST. 2.17s
Ta ARMATURE TIME CONST. 0.0163s
SHORT CIRCUIT RATIO 1/Xd
3
[;] z
416 v
%
ga
97
96
95
94
0.20
440 v ga
97
% 96
95
94
0.20
460 v 98
97
% 96
94
0 20
480 v 99
97
% 96
95
9J
0.20
PI736D
Winding 312
THREE PHASE EFFICIENCY CURVES
/~ !--~ / v
/
0 30 0.40 0 50 0 60 0 70 0 60 0.90
~ I--""
./ !-----" I
~ v
/
0 30 0 40 0 50 0 60 0 70 0 30 0 90
~ ----:..---
/ v
/'
0 30 0 40 0 50 0 GO 0 70 o ao 0 9•)
~ t::=--/ / 1--
/
0 30 0.40 0 50 o eo 0 70 0 90
5
1.00
1.00
1 00
1 00
STAMFORD
--
P.F.
1.0
0.9
0.8
1 10
1050 KVA
-
P.F.
1.0
0.9
0.8
1 10
1150 KVA
PF.
-1.0
0.9
0.8
110
1150 KVA
P.F.
1.0
0.9
0.8
1 10
50 -Hz 30 ,
I
25
n. iS
~20
~ g 11 .... z ~15 z ~ .... 1/ .... z ~10 I n:: w 2 ...
?~-
5 ,
~ I
/If
0 " 0 200 400
60 r---Hz 30
25
n. iS W20 ~ I
~ g .... z
l*15 z ~ .... .... z ~10 ' 0! w n. "'
5 I
~ .... lllh 'Ill
~I
0
0 200 400
PI736D
Winding 312
Locked Rotor Motor Starting Curve
346V 380V 400V 415V
-
I I I
{ ~ -
I I
L., ~
L I I
I '
600 800 1000 1200 1400 1600 1600 2000
LOCKED ROTOR kVA
380V d16V 440V
I I I
tl v
.
II'
1/ I I
~ ~
I
I I I I I I
I
I
600 800 1000 1200 1400 1600 1800 2000
LOCKED ROTOR kVA
6
STAMFORD
440V
I
2200 2400 2600
4GOV 480V
I
I
I
2200 2400 2600
PI736D STAMFORD
Three-phase Short Circuit Decrement Curve. No-load Excitation at Rated Speed
Based on star (wye) connection.
100000
! SVJIME.'hi::AL
• • •ASYUUElRJ:.Al ... .. . . . • ._ . . :$. . ~10000 1--.. I il ' ~ ' I I I"-I
1000 I I
0.001 0.01 11M~-,~ 1 10
Sustamed Short Ctrcutt = 3,000 Amps
100000
i
... . .
i . .. .
ffi10000 .
i .
-
I
1000 I
0.001 0.01
:::;ustalneu _,n011 vlrCUil-<+,..:uu '"'m
Note 1
The following multiplication factors should be
used to adjust the values from curve between
time 0.001 seconds and the minimum current
point in respect of nominal operating voltage :
50Hz 60 Hz Voltage I-' actor Voltage Factor
380v X 1.00 416V X 1.00
4UUV X 1.00 440v X 1.06
415v X 1.09 46Uv X 1.10
440v X 1.16 480v X 1.15 The sustained current value is constant lrrespectjve
of voltage level
p
SYMMETRCAI...
• • •ASYMUETM:AL
I
• I
r..... I .......... I -
n•~ll .. , 1 10
s
Note 2
The following multiplication factor should be used to convert the
values calculated in accordance with NOTE 1 to those applicable
to the various types of short circuit :
3-phase 2-phase L-L 1-phase L-N nstantaneous X 1.00 X 0.87 X 1.30
Minimum X 1.00 X 1.80 x3.20 :sustamea X 1.00 X 1.50 X2.50
Max. sustamea auration 10 sec. 5 sec. 2sec. All other times are unchanged
Note 3
Curves are drawn for Star (Wye) connected machines.
7
PI736D STAMFORD
Winding 312/ 0.8 Power Factor
RATINGS
Class-Temp Rise Cont. F - 1 05/4o•c Cont. H -125t4o•c Standby -150/40"C Standby -163/27·c
50Hz Star (V) 380 400 415 440 380 400 415 440 380 400 415 440 380 400 415 440
...... ,_,,, ......................... ,.,_,,, ..... ········-·······················-············-.. · .,,.,,,u,.-o., ... ,,,,,.,,,_, .. ,,,,,, .. ,,.,,,,,,,,,,, ·····-····················· ............................ ..........................................................
kVA 850 850 850 850 920 920 920 920 960 960 960 960 985 985 985 985
kW 680 680 680 680 736 736 736 736 768 768 768 768 788 788 788 786
Efficiency(%) 96.0 96.1 96.2 96.3 95.9 96.0 96.1 96.3 95.8 96.0 96.1 96.2 95.8 95.9 96.1 96.2
kWinput 708 708 707 706 767 767 766 764 802 BOO 799 798 823 822 820 819
60Hz Star (V) 416 440 460 480 416 440 460 480 416 440 460 480 416 440 460 480
...................................................... .......................................................... .. ..................................................... '" .................................................... ........... " ...........................................
kVA 970 1065 1065 1065 1050 1150 1150 1150 1095 1200 1200 1200 1125 1230 1230 1230
kW 776 852 852 852 840 920 920 920 876 960 960 960 900 984 984 984
Efficiency (%) 96.0 96.0 96.2 96.2 95.9 95.9 96.1 96.2 95.8 95.9 96.0 96.1 95.7 95.8 96.0 96.1
kWinput 808 888 886 886 876 959 957 956 914 1001 1000 999 940 1027 1025 1024
DIMENSIONS
1793 970 OVER COVERS
639
.
_...,.-) .. .
1-
........,
1/
6-HOLES 035 _/
COUPLING DISC 'AN'
S.A.ENo 18 16,7
S.A.E No21 D
S.A.ENo24 0
©2006
928.5
-
~ ~~ D
10
lr--1 I ~:T-435cr 365
830 errs I
830
1-BRG AOAPTOR S.A.ENoO
S.A.ENoOO
858,5 2.23
18"1
~
6 SPIGOT 476 GSPIGOT
296 &SPIGOT
2.SRQ ADM>TORS S.A.ENoO
S.A.E No 00
STAMFORD
Barnack Road • Stamford • Lincolnshire • PE9 2NB
Tel: [phone] • Fax: oo 44 (0)1780 484100
--r :
1330
TD_PI736D.GB_10.06_03_GB
lntertie/Generator
Protection Relay
M·3410A
Integrated Protection System®
M-341 OA Standard Panel I
M-341 DA Horizontal Panel (Optional)
M-3410A Vertical Panel
(Optional)
• Facilitates standardization for small/medium intertie and generator protection applications
• Microprocessor-based relay provides 15 protective relay functions, including Sync-Check, 2 programmable outputs and 2 programmable inputs
• Relay voltage inputs can be directly connected (no VT required) for voltages 480 V or less
PROTECTION
• Local and remote serial communications (MODBUS protocol) capability for monitoring and control functions
M-341 OA lntertie/Generator Protection Relay
Protective Functions
• Sync-check with Phase Angle, l1 V and !iF with dead line/dead bus options (25)
• Phase undervoltage (27) protection
• Ground undervoltage (27G) protection
• Dual-setpoint, single or three phase, directional power detection that can be selected as over/
under power protection (32)
• Dual-zone, offset-mho loss-of-field for generator protection {40)
• Sensitive negative sequence overcurrent protection and alarm {46)
• Negative sequence overvoltage {47)
• Inverse time neutral overcurrent (51 N)
• Phase overcurrent with voltage restraint/control (51 V) protection
• Phase overvoltage (59) protection
• Ground overvoltage (59G) protection
• Peak overvoltage (591) protection
• VT fuse-loss detection and blocking (60FL)
• Reconnect enable for intertie protection (79)
• Four-step over/under frequency (81) protection
Standard Features
• 2 programmable outputs, 2 programmable inputs, and 1 self-test output
• Oscillographic recording (COMTRADE file format)
• Time-stamped sequence of events recording for 32 events
• Metering of Voltage, Current, real and reactive Power, Power Factor, Frequency, and Positive Sequence Impedance
• One RS-232 port (COM1) on front and one RS-232 or 485 port (COM2) on rear
• M-381 OA IPScom~ For Windows™ Communications Software
• M-3811A IPScom For Palm OS® Communications Software
• MODBUS protocol
• Supports both 50 and 60 Hz applications
• Accepts 1 A or 5 A rated CT inputs
• Relay voltage Inputs can be directly connected (no VT required) for voltages ~480 V ac
• Continuous Self-Diagnostics
Optional Features
• M-3801 C IPSplo~ Oscillograph Analysis Software
• Horizontal and Vertical panel mount versions available (see Figures 2 and 4)
-2-
M-341 OA lntertie/Generator Protection Relay
Tests and Standards
The M-341 OA Generator/lntertie Protection Relay complies with the following type tests and standards:
Voltage Withstand
Dielectric Withstand
All terminals except power supply and status input contacts, 2500 V ac/3500 V de
Power Supply and Status Input Contacts:
IEC 60255-5 1 ,500 V de for power supply voltages (12, 24, 48 V inputs)
2500 V ac/3500 V de for power supply voltages (120 V ac/125 V de input)
• NOTE: Digital data circuits (RS-232/485 communication ports) are excluded.
Impulse Voltage
Power Supply Input Voltages, 120 V ac/125 V de:
IEC 60255-5 5,000 V pk, +1-polarity applied to each independent circuit to earth 5,000 V pk, +I· polarity applied between independent circuits
1 .2 j.IS by 50 j.IS, 500 ohms impedance, three surges at every 5 second Interval
• NOTE: Digital data circuits (RS-232/485 communication ports) are excluded.
Power Supply Input Voltages, 12, 24,48 V de:
IEC 60255-5 3,000 V pk, +1-polarity applied to each independent circuit to earth
3,000 V pk, +I· polarity applied between independent circuits
1.2 j.IS by 50 j.IS, 500 ohms impedance, three surges at every 5 second interval
• NOTE: Digital data circuits (RS-232/485 communication ports) are excluded.
Insulation Resistance
IEC 60255-5 > 40 Megaohms
• NOTE: Digital data circuits (RS-232/485 communication ports) are excluded.
Electrical Environment
Electrostatic Discharge Test
IEC 61000-4-2 Class 4 ( ± 8 kV) -point contact discharge and air discharge
• NOTE: Digital data circuits (RS-232/485 communication ports) are excluded.
Fast Transient Disturbance Test
I EC 61000-4-4 ( ± 2 kV, 5 kHz) AC Power Supply Input
( ± 1 kV, 5 kHz) RS-232, RS-485 and ground
Surge
IEC 61000-4-5 (±2 kV, 1.2 J.1.S by 50 j.IS line to ground) AC Power Supply Input
( ± 1 kV, 1.2 J.1.S by 50 JlS line to line) AC Power Supply Input
( ± 1 kV, 1.2 j.IS by 50 JlS line to ground) RS-485 Port
Surge Withstand Capability
ANSI/IEEE 2,500 V pk-pk Oscillatory each independent circuit to earth
C37.90.1 2,500 V pk-pk Oscillatory between each independent circuit
1989 5,000 V pk Fast Transient each independent circuit to earth
5,000 V pk Fast Transient between each Independent circuit
• NOTE: Digital data circuits (RS-232/485 communication ports) are excluded.
, 0
ElEHilill 1 0 lllillllll!l ~ [1!]00 liJ[]00
0 0
> •
0
lstruzioni di instatlazione
ed esercizio
Instructions for installation
and service
ITSCB601933/001 it-en 6-97
ABBSACE
lstruzfoni di installazione, di esercizio e di manutenzione per interruttori automatici aperti di bassa tensione
Installation, service and
maintenance instructions for
low voltage air circuit-breaker
SACE Emax
12. Unita di protezione PR111/LI-LSI-LSIG 12. PR111/LI-LSI-LSIG protection unit
12.1 Generafita 12. 1 General
L'unita SAGE PR 111/P realizza le seguenti funzioni di protezione: The SAGE PR111/P unit carries out /he following protecl/on functions: L -protezione da sovraccarico a tempo lungo inverse L -protection against overload with inverse long time-delay S -protezione da corte circulto a tempo breve S -protection against short-t/me short-circuit I -protezione da corte circuito istantaneo I protection against instantaneous short-circuit
G -protezione da guasto a terra G -protection against earth fault linst -protezione a soglia Iissa da corto circuito linst -rapid protection against instantaneous short-circuit
Le unita SACE PR111 disponibill all'utente sorJo: The SAGE PR111 units available to the user are:
PR1111L+I+Iinst
PR1111L+S+I+Ilnst
PR1111L +S+f+G+IInst
Fig. 47
Le protezioni possono essere realizzate In modo trifase o trifase con neutro a second a del tipo di interruttore impiegato (tripolare, tetra pol are o tripolare con neutro estemo). L'unita, e autoalimentata·e garantisce il corretto funzionamento delle
funzioni di proteziona in presenza di una corrente maggiore o uguale al 18% del valore nominale del trasformatore amperometrico di fase (TA). L'assieme sgancietore di protezione e cosi composto:
- 3 o 4 trasforrnatori di corrente (TA) -unita di proteziane SACE PR111 -un solenoide di epertura (SA) della sganciatore di massima corrente
che aglsce direttamente sui comando dell'interruttore_
Mod. LM4379 I I Rev. I I I
The protections can be made either in three-phase or three-ph<~se with
neutral mode, depending on the type of circuit-breaker used (three-pole,
four-pole or three-pole with external neutral}.
The unit is self-powered and ensures correct operation of the protec­
tion functions when there is a current higher than or equal to 18% of the
rated phase current transformer value (CT).
The protection release assembly consists of the fol/owlng:
-3 or 4 current transformers (GT} -SAGE PR111 protection unit -an opening solenoid (OS) of the overcurrenl release which acts
directly on the circuit-breaker operating mec/Janism_
Apparecchio
Apparatus SACE Emax Scala
Scale
N" Doc-601933/001 ~~'::?.: Doc. No-521100
12.8 Curve di intervento
12.8.1 Curve dllntervento protezione "L"
JOO?;:)
200 .. I
' 4 50
2
20 o'
10 e 0
0
•
D • '
2
I .. ·'
0. ,
,I ....
P,O<
1
I r ~:
~
12.8 Trip curves
12.8.1 Trip curves of protection "L"
I ~
I
"' "' ['-..
' I'. .U ' ', "' 1'-..1 ~~
.... ' ""'
A.O 0.1 .., IU Q._~ 0.5 0.& 6.70.80.91 1,2 1,5 $ 6 1 e: It 10 11 15 zg 25. ;~tl,..
12.8.2 Curve dl lntervento protezlone "I" 12.8.2 Trip curves of protection "I"
olo'
10 0 0
'
D
10
• .
•
I
• -0.2 ., 1,0 .. ,,...._ 1,) 2 l. ~····10 11 " 20 " ...
Mod. IM4379 I I Apparecchlo Rev. I I I Apparatus SACEEmax
WDoc. 601933/001 Doc. No
Tolleranza sulle soglle di intervento L ~ ± Sgancio tra 1,05 e
1,3 11 (secondo le Norme IEC 947 -2) I = ±20%
Trip threshold tolerance
L = Releasebetwean 1.05
and 1.311 (In conform­
ity with IEC 947-2
standards)
=.t20%
Tolleranza sui tempi di in-
tervento
l ~ :1: 10% (20% per 1~2 x In) I = ± 20%
Trip time talerarn;es
L = :1: 10% (20% par 1>2 x
In) I =.t20%
Legenda
In~ Correntanominaladei trasformalorl di car-
rente t =tempo dllntervento
caption
In = Raled currsnt of cur­
rent transformers I =triptime
Scala
Scale
N' Pag S.ll Nc.
1131100
12.8.3 Curve di intervento protezione "S"
t(s(
lOO'
100 • . ,o
2
>0
·~ 10
i'..: ......
• •
' " I -. r-... '
~·
D ~1 '~ 0,3 Q4 0,5 0,8 O.fDJUI.,I!1 I.:Z 1,'!1
• I(J
,..,
100 fj . ;o
:!()
10
• '
2 I I
, ... ,_
' 02 ., 0,.. C.S 0.6 0,?0,1Q.JJ1 1,7 , ..
Mod. IM4379 I I Rev. I I I
12.8.3 Trip curves of protection "S"
.. 4. 0 Ul4 ~
' ' " ~ '
1'.. .......
1'-' ' ,,
• . . • • 189~0 \~ •• :JO ~
0 u c~ 0 ~
• 3 • 5 1J 1 I If~ 11: " lO ,.
Apparecchlo Apparatus SACE Emax
N' Doc 601933/001 Doc. No.
Tolleranza sulla soglie di
intervenlo s = t 10%
Trip threshold tolerance s = :t 10%
Tolleranza sui tempi dl in-lervento s = t 20%
Tn'p Ume tolerances s = ~20%
Legend a In= Corrente nominaledei trasformatori dl cor-rente t = tempo dl inlervento
CapUon
In= Rated current of cur­
rant lrensformers
r = lripttm ..
Scala
Scale
N'Pao-Sh.ND,
64(100
12.8.4 Curve di intervento protezione "G"
•[" . s: I ,. ~~ (~ ~ ~ (~ ~ ) ••' -·--·--· -100 • ' ' 20 !O' ~
6() -•• ,.
10 ··---·---' ' .
'
1 •..
OA
0,2 ~""" ....... I" ' ~ •..
0..04
lOJ
0.111 0,.& G~ G.9 o,70.a0.91 1,1 1.5
Mod. jM4379 I I Rev. I I I
I
12.8.4 Trip curves of protection "G"
I J ..
'
I
I ...
Tolleranza sulle soglie di
intervenlo
G = t20%
Trip threshold tolerance \··'!:> = ± 20% . '··•.::·., >
T ol/eranza sui lempl di in­lervenlo
G = ± 20%
Tnp lime tolerances
G= ±20%
Legend a
~ c--
In = Corrente nominole dei
trasformatori di Cor­
rente
I s 6 7 • Iii l~ 12 10 " ...
Appruecchio
Appar.,tus SACE Emax
N" Doc 601933/001 Doc. No.
= tempo di lntervento
Caption
In= Rated current of cur­
rent transformers t =trip time
Scala
Scale
N'PIIIJ Sh. t-lo
65/100
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 4
Kyle Juergens
Andgar Corporation
6920 Salashan Parkway A-102
Ferndale, W A 98248
Ph 360-366-9900
Re: Swager Fanns-Project# 268
Dear Kyle:
An IDACORP Company
September 17, 2008
Thank you for your Generator Interconnection application for the Swager Farms 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 information to our OASIS (Open Access Same
Time Infonnation) website. Please refer to the website petiodically to view a list of current
projects at http://oatioasis.com/ipco/index.html under GENERATOR INTERCONNECTION
INFORMATION folder, on the left side ofthe screen.
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, ~ /aulvn ~r .
Rowena Bishop
Operations Analyst
Ph 208-388-2658
Standard Interconnection Feasibility Study Agreement
Cc: Marc Patterson/IPC
Small Gen Feasibility Study Agreement
Swager Farms Project# 268
Feasibility Study Agreement
THIS AGREEMENT is made and entered into this __ day of ______ 2008 by and
between _____________ , a _____________ organized and
existing under the laws of the State of ________________ _J
("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 9/10/08, also known as
Project# 268; and ·
WHEREAS, Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Provider's Transmission System; and
WHEREAS, Interconnection Customer has requested the Transmission Provider to perform a
feasibility study to assess the feasibility of interconnecting the proposed Small Generating
Facility with the Transmission Provider's Transmission System, and of any Affected Systems;
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1. 0 When used in this Agreement, with initial capitalization, the terms specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause to be
performed an interconnection feasibility study consistent the standard Small Generator
Interconnection Procedures in accordance with the Open Access Transmission Tariff.
3.0 The scope of the feasibility study shall be subject to the assumptions set forth in
Attachment A to this Agreement.
4.0 The feasibility study shall be based on the technical information provided by the
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.
Small Gen Feasibility Study Agreement
Swager Farms Project# 268
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 propose9. Small Generating Facility and to address the identified short circuit
and power flow issues.
7.0 The feasibility study shall model the impact of the Small Generating Facility regardless
of purpose in order to avoid the further expense and interruption of operation for
reexamination of feasibility and impacts if the Interconnection Customer later changes
the purpose for which the Small Generating Facility is being installed.
8.0 The study shall include the feasibility of any interconnection at a proposed project site
where there could be multiple potential Points of Interconnection, as requested by the
Interconnection Customer and at the Interconnection Customer's cost.
9.0 In lieu of Feasibility Study deposit, Interconnection Customer agrees that study funds
will be drawn 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
Swager Farms Project# 268
10.0 Once the feasibility study is completed, a feasibility study report shall be prepared and
transmitted to the Interconnection Customer. Barring unusual circumstances, the
feasibility study must be completed and the feasibility study report transmitted within 30
business days of the Interconnection Customer's agreement to conduct a feasibility study.
11.0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
12.0 The Interconnection Customer must pay any study costs that exceed the deposit without
interest within 30 calendar days on receipt of the invoice or resolution of any dispute. If
the deposit exceeds the invoiced fees, the Transmission Provider shall refund such excess
within 30 calendar days of the invoice without interest.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written.
Transmission Provider: Interconnection Customer:
Idaho Power Company-Delivery
Signed ________________________ ___ Signed ______________________ __
Printed Printed -----------------------------------------------------
Title Title ---------------------------------------------------------
Date Date ----------------------------------------------------------
Small Gen Feasibility Study Agreement
Swager Farms Project # 268
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 seeping meeting held on _________ _
1) Designation ofPoint oflnterconnection and configuration to be studied.
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-12-25
IDAHO POWER COMPANY
ATTACHMENT 5
AND GAR"'
LETTER OF TRANSMITTAL
TO: Idaho Power
Rowena BishoQ
1221 W. Idaho Street
Boise, ID 83702
WE ARE SENDING YOU:
[g)
0 Shop Drawings D 0 Submittals D 0 Specifications D 0 Contract D
DATE: 9/18/2008
ATTN: -=-R....:o_:w:....:e:..:...n:..:.a:....:B=-•==· s-=h:..:.o..~:.2 ___________ _
RE: _S
7
m_a....,.II_G=-e.:....n_e:....:r_;_a_;_to_;_r_I_n...;..te_;_r....:c...::.o.:....n_n_ec_tt_· o.:....n=.=R.::..:e:..:cqLu....:e...::.s.:....t __ 'Pen.) <:c 1 #-26 "b
Attached
Copy of Letter
Change Order
Plans
Details
0 Under separate cover via
the following:
[g) Mail
0 Fax
0 UPS
OOvernight
00ther
COPIES DATE DESCRIPTI ON
1 9/18/2008 Small Gener ator Interconnection Re uest
THESE ARE TRANSMITTED AS CHECKED BELOW:
0 For approval
0 For your use D
REMARKS:
Rowena,
D D D
'
As requested
For review
0 Approved as submitted
0 Returned for correction
0
Attatched an updated interconnection r equest. Please let us know if you have any questions.
Thanks,
Eric Powell
Andgar Corporation
COPY TO: File
6920 Salashan Pkwy, A-1 02-P .0. Box 2708
corporate@an
SIGNED: Eric Powell
-Ferndale WA 98248-Office: 360.366.9900-Fax: [phone]
dgar.com-http://www.andgar.com
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
band delivery, mail, e-mail, or fax to the Transmission Provider.
Processing Fee or Deposit:
If the Interconnection Request is submitted under the Fast Track Process, the non-refundable processing
fee is $500.
If the Intercoimection Request is submitted under the Study Process, whether a new submission or an
Interconnection Request that did not pass the Fast Track Process~ the Interconnection Customer shall
BUbmit to the Transmission Provide:: ade}i(i:,;.-ii lWttl) e,'J:~id :.$!.GOO il(,wards the cost of the feasibility
study.
Interconnection Customer Information
Legal Name of the Interconnection Customer (or, if an individual, individual's name)
Nan:te: A tV'{o-.v' "
Ootit~c~P~~~:"': -....l:~='i*""!.:2"'-_:U-'-'·""'J..::..:0=-)('".=,.jr:<."'" .. "'"V\ .... s"'-------------------­
Mailins' A.ddrc~;s;~. -'.P._.· ...._C.L?.:.-· __,_B"'"'o""'x"---_·..._z.-'r'-=D'-'o,__ _ ____,6,_CfL.:~'-D~--=~=.:.•...:-.!et_~,_h.....:.d.,_,,'"'"'h~-PJ-..!:k..::..:w"""'-'y'f--'-A_-...!.IV-=-="l.
$t.tlte: ~~ 'Z:ip: _q+-· .... ~_...?"-8.L...lol\ __ _
F<tcilityLQ>?.1ti:vll(if dhferentfromabove): ~]7 L tJ f]QQ E R .. A\--.1 1 I-0 ~"633L6
't~leph<.>~ie (01ty)! (3f;.r;i)~t£ -1'160 ...:;....:::·:re:Jt-.phane (!!v&tii..ug):' ________ _
F.'a.~: (3(.-o) ~::,cG ~--:r-eoo :a.-Mail Adcix~-~$:· IL\Jii:?.j@.c71.v'c..~.r~v-. (CivV\. v \)
1
ContactNwne: ____________________________________________________________ _
Title: ________ _:_ _______________________ _
Ad~ess: ________________________________________________________ __
Telephone (Day): ___________ Telephone (Evening):---------
Fax:-------------------E-Mail Ad~ess: -----------
Appl itatio1i'J.s :foi·; · ~New Small Generating Facility
____ Capacity addition to Existing Small Generating Facility
If capacity addition I<'J existing facility, please describe:--------------
Net Metering? Yes _No_
To Supply Power to the Interconnection Customer? Yes _No _
To Supply Power to Others? Yes _.X_ No__ lo ~~~--~ 1;+-y
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:-----------------------------------------
Adiliess: ___________________________________________ _
Telephone (Day):---------------Telephone (Evening):--------'-----
Fax: ---------------------E-Mail Ad~ess: -------------
.R.~q}ie~~d. J?o.int oflo~er®mwcti()rl. __ S..;._e_e.._--'.4-€:-.r_: "'-__ \ ___ V.::..:_{",~!I..w.:.::..,;;:;;7:':v·7•f ____________ _
l·,t•nM)'i1•j'<>,.:f:nTj ('.,:,.,\)..t'L''"'''1~ 'f,''•'(.<UL'Sttd. ''l·l"·s•:.l.;jj';,,~ ]);~'l~· crl $" J Z,oto •« '~..,. ... .,,..A ~.-'..;o .... •.v. -'~~l ,_,.,, ~~:-... ·-'V 1 ,.,. l '""' Y "''""' u. -------!-----------------------
2
Small Generating Factlitv rnforDUltion
Data apply only to the Smlill Generating Facility, not the Interconnection Facilities.
Enetgy Sourt<~: ·-Solar _Wind _Hydro _Hydro Type (e.g. Run-of-River): ____ _
Diesel _Natural Gas _Fuel Oil J( Other (state type) ~E.__·,_., c-,:j'J-''."-'"+S ______ _
Jjri.n:ie.:Mi:)ye:t: _Fuel Cell X Recip Engine _Gas Turb _Steam Turb
_Microtwbine _PV _Other
T.Yr•e ~rd~u~~·a1or:_!(_Synchronous __ Induction Inverter
Gt~nehttw: Narr.re_p.T~ite R<ltirig: 1 DO kW (Typical) Generator Nameplate kV AR: ~61Y
Interconnection Customer or Customer-Site Load: _______ kW (if none, so state)
Typical Reactive Load (if known);-------
ktaxitrmm ~lrys1~~l E>..-po~t Capa~Hity ·kequestcd: _J.I..r::UXJ'-='""". :.....-_kW
List components of the Small Generating Facility equipment package that are currently certified:
Equipment Type CertifYing Entity
1. -------------
2. ------------------
3. ---------------
4. -----------------
5. -------------
Is the prime mover compatible with the certified protective relay package? __ Yes
Generator (or solar collector)
Manufacturer, Model Name & Number:
Version Number:--------------
lndi vkh.wl Oeru~rator J'qw.cr :FM:::to.r ·
·r. •• ,;.,P.d. ·J>r;·,,.~.-.~a.~r·L.,t:. ':e;.,,:n"' 'lo:.l.t. .•. -· 1¥'1;.1~ :\ v .. I.; ~'""·"'t."J" ,......._ __ _ Lagging: ---'-' 1J-=--·
Total Number of Generators in wind farm to be interconnected pursuant to this
__ No
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 L<>ad Flow data sheet must be supplied with the Interconnection
Request.
3
Small Generating Facility Characteristic Data (for inverter-based machines)
Max design fault contribution current: ___ _ Instantaneous orRMS?
Harmonics Characteristics:-----------------------
St;.ut,-up teq:Jir<i:men:is: __ . ·------------------------
Small Generating Facility Characteristic Data (for rotating machines)
RPM Frequency: \·zoo
(*)Neutral Grounding Resistor (If Applicable): ____ _
Synchronous Generators: ~·e a+-+tt1clred
Direct Axis Synchronous Reactance, Xd: ·z.o~ P.U.
Direct Axis Transient Reactance, X'd: 0 • 1 ~ P .U.
Direct Axis SubtransientReactance, X" d: D, 1\ P.U.
Negative Sequence Reactance, X1: 0. ;1 P.U.
Zero Sequence Reactance, X0: o. o 2 P.U.
KVA Base: -___,~'6~1-;:..S· _____ _
Field Volts: 4~0 .
Field Amperes: ~It IE'., . ~~ f'F
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 Lotter; ._
:R,flfLClt'flil 'Pe>Vf~ld\eg;uh"io lu V ~tts (N 'J_.,f:u~cl): . ._ ____ _
Rr,acti'l"¢ l'ower Re(ttlliidlri Varfl {itt\tl t.oatD1 ------
Total Rotating Inertia, H: Per Unit on kVA Base
Note: Please contact the Trans:mjssion Provider prior to submitting the Interconnection Request to
detennine jfthe specified infonnation above is required.
4
Excitation and Governor System Data for Svncbronous 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 deteniuned to
be required by applicable studies. A copy of the manufacturer's block diagram may not be substituted.
Intereon.nectiun Facilities Information . . .. • . lt·t\ \~'t~ Si.JL-
Will a tt1lJlsfonner be used between the generator and the point of common coupling? -~.:::_''(e~ 'LNo
Will the transformer be provided by the Interconnection CustomE;r? ~~--Y~~ K ~'i:'!()
TrllilSforrner Data (If Applicable. for Interconnection Cnstomer-OWDcd Transformer):
Ls the transfonner: __ single phase __ three pbase? Size: _____ k.VA
Transfonner Impedance; % on kV A Base
If Three Phase:
Transfonner Primary: __ Volts __ Delta __ Wye __ Wye Grounded
Transformer Secondary; __ Volts __ Delta __ Wye __ Wye Grounded
Transformer Tertiary: __ Volts __ Delta __ Vfye __ Wye Grounded
Transformer Fuse Data (If Amlicable. for Interconnection Customet·Qwned Fuse):
(Attach copy of fuse manufacturer's Minimum Melt and Total Clearing Time-Current Curves)
Manufacturer: ________ Type: ______ Size: ___ Speed:------
1nterconnecting Circuit Breaker (if applicable):
Manufacturer: A'\?:?. B Type: _ C],
Load Rating (Amps): 16CrO ,Interrupting Rating (Amps): 5~5 MTrip Speed (Cycles): __ l_rJ_~-~-
Interconnection Protective Relays lliAppJicablel:
If Microprocessor-Controlled:
List of Functions and Adjustable Setpoints for the protective equipment or software:
Setpoint Function Minimum Maximum
1.
2.
3.
4.
5.
6.
5
If Discrete Components:
(Enclose Copy of any Proposed Time-Overcurrcnt Coordination Curves)
Manufacturer: ____ Type: ___ Style/Catalog No.: ____ Proposed Setting:-----
Manufautucer: Type: Style/Catalog No.: Proposed Setting:-----
Manufacturer: Type: Style/Cam log No.: Proposed Setting: -----
Manufacturer: Type: Style!Cntalog No.: Proposed Setting:-----
Manufacturer: type: Style/Catalog No.: Proposed Setting:-----
Current Transformer Data af Applicable):
(Encl.ose Copy of Manufacturer's Excitation and Ratio Correction Curves)
Manufacturer: PC:;... f.:..S.:<:---------------
Type: A -l ~t.'O Accuracy Class: _ Proposed Ratio Connection: i '1-00 f-1$"
Manufacturer:---------------------~­
Type:-------Accuracy Class:_ Proposed Ratio Connection: __
Potential Transformer Data af Applicable):
Manufacturer:--------------------­
Type:-------Accuracy Class:_ Proposed Ratio Connection: __
Manufacturer:--------------------­
Type:-------Accuracy Class:_ Proposed Ratio Connection: __
6
General Information
Enc.lm;e .:.r.l:jl}' p iL~ el~ctrdt.:ill.-one~line: diegrnm , h9wing 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 tlum 50 kW. Is One-Line Diagram Enclosed~' .:..K_ Y e$ _:_No -
;'E\iiC.l,{)$t) copy (~:ta:l1'}~· *:iia t'k1cii~:tr.,~i'ltation that indicates the precise physical location of the proposed Small
Generating Facility ~ USGS topographic map or other diagram or documentation).
Proposed location of protective interface equipment on property (include address if different from the
Interconnection Customer's address)----------------------
Enclose copy of any site documentation that describes and details the operation of the protection and
control schemes. Is Available Documentatio:11 Enclosed? _Yes __ No
Enclose copies of schematic drawings for all protection and control circuits, relay current circuits, relay
potential circuits, and alarm/monitoring cin;uits (if applicable).
Are Schematic Dr.1wings Enclosed? _Yes __ No
Applicant Signature
I hereby certify that, to the best of my knowledge, all the information provided in this Interconnection
Request is true and co.rrect.
For Interconnection Customer:
Signed
~~::...:·~-~'?J"""9'F==---_....,_......;__;_,'t><J1e:
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8
PI736B ~Technical Data Sheet
PI 73GB
SPECIFICATIONS & OPTIONS STAMFORD
f.j.@§l grnsntiwfl
STANDARDS
Newage Stamford industrial generators meet the
requirements of BS EN 60034 and the relevant sections
of other national and International standards such as
B$5000, VDE 0530, NEMA MG1-32, IEC60034, CSA
C22.2-100, AS1359.
Other standards and certifications can be considered on
request.
DESCRIPTION
The STAMFORD PI range of synchronous ac generators
are brushless with a rotating field .. They are separately
excited by the STAMFORD Permanent Magnet
Generator (PMG). This Is a shaft mounted, high
frequency, pilot exciter which provides a constant supply
of clean power via the Automatic Vollage Regulator (AVR)
to the main exciter. The main exciter output is fed to the
main rotor, through a full wave bridge rectifier, protected
by surge suppression.
VOLTAGE REGULATORS
The PI range of generators, complete with a PMG, are
available with one of two AVRs. Each AVR has soft start
voltage build up and built in protection against sustained
over-excitation, which will de-excite the generator after a
minimum of 8 seconds. Underspeed protection (UFRO), is also provided on both
AVRs. The UFRO will reduce the generator output voltage proportional to the speed of the generator below a pre-
sellable level.
The MX341 AVR is two phase sensed with a voltage
regulation oft 1 %. (see the note on regulation).
The MX321 AVR is 3 phase rms sensed with a voltage
regulation of 0.5% nns (see the note on regulation}. The
UFRO circuit has adjustable slope and dwell, for
controlled recovery from step loads. An over voltage
protection circuit will shutdown the output device of the
AVR, it can also trip an optional excitation circuit breaker if required. As an option, short circuit current limiting Is
available with the addition of current transformers.
Both the MX341 and the MX321 need a generator
mounted current transformer to provide quadrature droop
characteristics for load sharing during parallel operation.
Provision Is also made for the connection of the
STAMFORD power factor controller, for embedded
applications, and a remote voHage trimmer.
WINDINGS & ELECTRICAL PERFORMANCE
All generator sta.tors are wound to 2/3 pitch. This
eliminates triplen (3rd, 9th, 15th ... ) harmonics on the
voltage waveform and Is found to be the optimum design
for trouble-free supply of non-linear loads. The 2/3 pitch
design avoids excessive neutral currents sometimes seen
with higher winding pitches. A fully connected damper
winding reduces oscillations during paralleling. This
winding, with the 2/3 pitch and carefully selected pole and
tooth designs, ensures very low levels of voltage waveform
distortion.
TERMINALS & TERMINAL BOX
Standard generators feature a main stator with 6 ends
brought out to the terminals, which are mounted on the
frame at the non-drive end of the generator. A sheet steel terminal box contains the AVR and provides ample space
for the customers' wiring and gland arrangements. It has
removable panels for easy access.
SHAFT& KEYS
All generator rotors are dynamically balanced to better
than B$6861 :Part 1 Grade 2.5 for minimum vibration in
operation. Two bearing generators are balanced with a
half key.
INSULA TIONnMPREGNATION
The insulation system is class 'H', and meets the requirements of UL 1446.
All wound components are impregnated with materials and
processes designed specifically to provide the high build
required for static windings and the high mechanical strength required for rotating components.
QUALITY ASSURANCE
Generators are manufactured using production procedures
having a quality assurance level to
BS EN ISO 9001.
NOTE ON REGULATION
The stated voltage regulation may not be maintained in the
presence of certain radio transmitted signals. Any change
in performance will fall within the limits of Criteria 'B' of EN
61 000-6-2:2001. At no time will the steady-state voltage
regulation exceed 2%.
Note: Continuous development of our products entiUes us to
change speclflcaUon details without notice, therefore they must
not be regarded as binding.
Front cover drawing is lypical of the product range.
2
STAMfORD
l,f.BQ§§ grmllrarfan J
CONTROL SYSTEM
A.V.R.
VOLTAGE REGULATION
SUSTAINED SHORT CIRCUIT
INSULATION SYSTEM
PROTECTION
RATED POWER FACTOR
STATOR WINDING
WINDING PITCH
WINDING LEADS
MAIN STATOR RESISTANCE
MAIN ROTOR RESISTANCE
EXCITER STATOR RESISTANCE
EXCITER ROTOR RESISTANCE
R.F.I. SUPPRESSION
WAVEFORM DISTORTION
MAXIMUM OVERSPEED
BEARING DRIVE END
BEARING NON-DRIVE END
WBGHT COMP. GENERATOR
WEIGHT WOUND STATOR
WEIGHT WOUND ROTOR
WR'INERTIA
SHIPPING WEIGHTS in a crate
PACKING CRATE SIZE
TELEPHONE INTERFERENCE
COOUNGAIR
VOLTAGE STAR
kVA BASE RATING FOR REACTANCE
VAW ES
Xd DIR. AXIS SYNCHRONOUS
X'd DlR. AXIS TRANSIENT
X"d OIR. AXIS SUBTRANSIENT
Xq QUAD. AXIS REACTANCE
X"q QUAD. AXIS SUBTRANSIENT
XL LEAKAGE REACTANCE
X2 NEGATIVE SEQUENCE
Xo ZERO SEQUENCE
PI736B
WINDING 312
SEPARATELY EXCITED BY P.M.G.
MX341 I MX321 I
± 1% r :t 0.5% jWlth 4% ENGINE GOVERNING
REFER TO SHORT CIRCUIT DECREMENT CURVES (page 7)
CLASS H
IP23
0.8
DOUBLE LAYER LAP
TWO THIRDS
6
0.0027 Ohms PER PHASEAT22"C STAR CONNECTED
2.33 Ohms at22'C
17 Ohms at 22'C
0.1 Ohms PER PHASE AT 22'C
BS EN 61000-6-2 8o BS EN 61000-B-4,VDE 0875G, VOE 0875N. refer to factory for others
NO LOAD < 1.5% NON-DISTORTING BALANCED LINEAR LOAD < 5.0%
1500 Rev/Min
BALL. 6228 C3
BALL. 6319 C3
1 BEARING 2 BEARING
2680 kg 2830 kg
1108 kg 1106 kg
1260 kg 1197 kg
42.2755 kgm2 41 .2746 kgm~
2876kg 2900kg
194 x 105 x 154(cm) 194 x 105 x 154(cm)
so Hz 60Hz
THF<2% TIF<50
1. 79 m•isec 3793 crm 2.3 m'/sec 4874 cfm
380/220 400/231 415/240 440/254 416/240 4401254 460/266 480/277
700 700 700 700 815 875 675 675
2.14 1.93 1.79 1.60 2.58 2.48 2.26 2.08
0.16 0.14 0.13 0.12 0.19 0.18 0.16 0.15
0.11 0.10 0.09 008 0.14 0.13 0.12 0.11
1.37 1.24 1.15 1.02 1.65 1.56 1.45 1.33
0,35 0.32 0.29 0.26 0.42 0.40 0.37 0.34
0.04 0.04 0.03 0.03 0.05 0.05 0.04 0.04
0.20 0.18 0.17 0.15 0.24 0.23 0.21 0.19
0.03 0 02 0.02 0.02 0.02 0.02 0.02 0.02
REACTANCES ARE SATURATED VALUES ARE PER UNIT AT RATING AND VOLTAGE INDICATED
T'd TRANSIENT 11ME CONST. 0.144s
T"d SUB-TRANSTIME CON ST. 0.0135
T'do O.C. FIELD TIME CONST 1.93s
Ta ARMATURE TIME CON ST. o.0163s
SHORT CIRCUIT RATIO 1/Xct
3
!Sol ~
/
/
*"
PI736B
Winding 312
THREE PHASE EFFICIENCY CURVES
v I--:~ ~ -1--. v v ~ --:1---
I'.F.
r--1.0
~ r--
U\) '030 ~40 UO O&G U-G !ll40 UO i€oil ;:'!0
STAMfORD
l.).b'tgQ genet"atlon I
TOO KVA
400 v 91 I /: ~ I I I =t==:i::j !-----/ ·v t..---~ -:.. / / %
/
~
1.1211 4).30 0 ~ Q.!o l)El) 0 71! O.el! U\9 I~ t to
L-------------------------------------------~700K~A
415 v 97 I .. :.. PJ:.
~ 1-' J ./ --_...--~ -~ ~ v--!--" --
..__._ /v I
% o.s
'!Iii -~~ -~ P• ~M 0~ ON ~U ~~ 1~ 1a
440 v ~~
..,.;,-~ -~ ~ l--
/ v /.
9!!
-
!--"
10il
4
700 KvA
P.l<.
70
f.lt
0.9
O.B
STAMFORD f.J.U@j gener11eion I
416 v tt
/. / ·-_/ % %
!I')
PI736B
Winding 312
THREE PHASE EFFICIENCY CURVES
_.,... ~
~ f--
v
,. I -
_,_ 1.0
0.9
u· --
Ui:l UO ~AO Uo ~-€i) ln'G D ~ UO UO l '19
8 5KVA
440 v 97 -· -
/ !--~ r--..-
~ ~ -~ ! -r---r--% .u
I v
'
!a
u~ <1~ e.-o M~ 4$9 or4 oHID uo si!Q t 10
460 V !H
../"' ~ ---~ ~ I.--t-
/ r --
93-1)~ 0::10 0:40 OM H~ itl'o
480 v ~t
% ~­-> /;
~ ,
.,..,..... 1--:::: ~ r---1--
/ -v
5
·~-
i
B7$ KVA
-
'Ul
0.9
o.e
875 KVA
P.F'.
-1 ~~
1601 ~
50 r--Hz 30
25'
!!> 0
~ -.: ... 1/ ..# ~ ·!;; I
;;~s .... ~ ....
~ ~10 / !/ v / "' tl." ...
1
5 1/. jf,
(I ,
0 200 400
r--60
30 Hz
I
2.5 ' I !
i. 0
~0 oc ... g 1.1 .... ~5 lf
"" r; ~ s ~1()
w ... ;.,._
11
e lf '/
rA
:M~ I ,._
(;I ,
0 200 .tOO
PI 73GB
Winding 312
Locked Rotor Motor Starting Curve
'l.~i 3!10V .oli):()\1 <liSV
l/ ..... ...... ~ L' v ~ """ i.o'. ,r I' J ,.
.. '" I~ v 1.' ~ 1/. "' ' .....
I lJ' r/ '/ 1/ I
I -~
-
I
.,
600 800 1000 1201) 1400 1600 t.004UHfOTOfU~
:!2{/'1 ;!,;'.,. .I.Ajm' ~
""' I 1/
! ..,.. 1.1" ...... I
!
t/
~
!;.<'
t..-I
' I I
!
'
6(1() BOO tOOO 1200 Ll:ICKEOAOT-CAkiq. 1400 1Mtl 1000
:
6
STAMfORD
~
I
1800 20..1l(i
q;roy
:.--1.
I
'
I
I
2000 22Co!J
STAMfORD PI736B
f,J.h'l§i gen~atlonl
Three-phase Short Circuit Decrement Curve. No-load Excitation at Rated Speed
Based on star (wye) connection.
100000
-1-.. ---SYWAElRf('.AL --1---· --• • •A&"""'ETmC.U
-... t . .. ..
~ -r oooo . . . .
r--. -
"'-· " ....... t-I 1000
0.001 0.01 0.1 'llME{&•nl 1 10
Sustained Short Circuit = 2,400 Amps
100000 -
---r· --.. r--sYMMETRtCAl -·---'-... --· ----.,
• • •ASVJ.t.IETRICI\l.
t ... . . . .
1;;10000 .
~ . ~ -.
.............. r-r--f-'
1000
0.001 0.01 0.1 TM(I«t] 1 10
Sustained Short Circuit = 3,400 Amps
Note 1
The following multiplication factors should be used to adjust the values from curve between
time 0.001 seconds and the minimum current point in respect of nominal operating voltage :
50Hz 60Hz Voltage Factor v oltage t-aclor
380v X 1.00 416_v X 1.00
400v X 1.()5 440V X 1.06
415v X 1.09 460v X 1.10
440v X 1.16 4BOv X 1.15 .. The suslalrled current value Is constant lrresp~ci!Ve of voltage level
Note 2
The following multiplication factor should be used to convert the values calculated in accordance wilh NOTE 1 to those applicable to the various types of short circuit :
3-phase 2-phase L-L 1-phase L-N llnstantaneous X 1.00 x0.87 X 1.30
1\111nlmum X 1.00 X 1.80 x3.20
@!StBine_Q_ X 1.00 X 1.50 x2.50 I Max. susta~nea aurat1on 10 sec. 5 sec. 2sec.
All otner times are uncnangea
Note 3
Curves are drawn for Star (Wye) connected machines.
7
P1736B SJAifDBD
Winding 312/ 0.8 Power Factor lli&ii~J
RATINGS
Class -Temp Rise Con!. F -1 05t4o•c Cont. H -125/4o·c Standby -1S0/4o•c Standby-163/27"C
50Hz Star (V) 380 400 415 440 380 400 415 440 380 400
-..vA 650 650 650 650 700 700 700 700 730 730
kW 520 520 520 520 . 560 560 560 560 584 584
Efficiency (%) 95.5 95.7 95.8 95.9 95.4 95.6 95.7 95.9 95.3 95.5
kWinput 545 543 543 542 587 586 585 584 613 612
60Hz StarM 416 440 460 480 416 440 460 480 416 440
kVA 750 815 815 815 815 875 875 875 845 910
kW 600 652 652 652 652 700 700 700 676 728
Efficiency(%) 95.5 95.5 95.7 95.8 95.3 95.4 95.6 95.8 95.3 95.4
kWinpul 628 683 681 681 684 734 732 731 709 763
DIMENSIONS
&3g 77~-S
-~
/ . ~ tr ---
.......... H
ji..--..J ,,.....,
I/ ~ 1-
-tiO~ESD35 _/ 435 c ... 365 &SPIGOT 47& &SPIGOT
6'30 C:l'r.
830
COUPLING DISC 'AN'
S.A.EHo18 15,7
S.A.ENo21 0
S.A.ENo24 0
© 2004 Newage lnternalional Limiled.
Reprinted wilh permission of N.l. only.
Prtnted In England.
1·BRG ADAPTORS
S.ii.ENoD
S.A.E No DO
295 &SPIGOT
2-BRG ADAPTORS S.A.e NoO
SA.ENoOO
Bamack Road • Stamford • Lincolnshire • PE9 2NB
Tel: [phone] • Fax: [phone]
Website: www.newage-avkseg.com
415 440 380 400 415 440
730 730 750 750 750 750
584 584 600 600 600 600
95.7 95.8 95.3 95.5 95.6 95.8
610 610 630 628 628 626
460 480 416 440 460 480
910 910 870 940 940 940
728 728 696 752 752 752
95.6 95.7 95.2 95.3 95.5 95.7
762 761 731 789 787 786
970 OVER COVERS
TD_PI736B.GB_06.04_01_GB
lntertie/Generator
Protection Relay
M·3410A
Integrated Protection System®
M-3410A Standard Panel
• ~=?> ~~· ED """'-\~--~· 0 0P'.;!"U<JI" •3• ~.1~"-""'· 0 a .. :o.r .... .,, ..
M·3UO•\ ">-~:~.-.~,,., ... c C.':ll.Tr.:-.:.~
~~~QTt&/O~~OR L:;;u·~..! 0 Q ltQVrT:!'.t'~~ .PHOttC'nON eo~ ~:.&;o~'l"' Q Cc.:c,~:~ ~!bii~iiO:t\i"i;,ttr;n·.j ""''"~"-T'I 0 (IH,...-.,;,•,t:. :;:::;;[)-·"-{;"-:.~::. ·::_ ,: I•'''' 0 OrL..>ouo • p,-, -~ ... 0 1:1....-JTIO OlOJ""-"'f
M-3410A Horizontal Panel (Optional)
CD
(0!
M-3410A Vertical Panel
(OptlonaO
•
.,.,_.,,;-r.~r·"\10
@ •
• Facilitates standardization for small/medium intertle and generator protection applications
• Microprocessor-based relay provides 15 protective relay functions, Including Sync-Check, 2 programmable outputs and 2 programmable inputs
• Relay voltage inputs can be directly connected (no VT required) for voltages 480 V or less
PROTECTION
• Local and remote serial communications {MOD BUS protocol) capability for monitoring and control functions
M·3410A lntertie/Generator Protection Relay
Protective Functions
• Sync-check wtth Phase Angle, tJ. V and ilF with dead line/dead bus options (25)
• Phase undervoltage (27) protection
• Ground undervoltage (27G) protection
• Dual-setpolnt, single or three phase, directional power detection that can be selected as over/ under power protection (32)
• Dual-zone, oHset·mho loss-of-field for generator protection (40)
• Sensitive negative sequ~nce overcurrent protection and alarm (46)
• Negative sequence ovarvoltage (47)
• Inverse time neutral overcurrent (51 N)
• Phase overcurrent with voltage restralnVcontrol (51 V) protection
• Phase overvoltage (59) protection
• Ground overvoltage (59G) protection
• Peak overvoltage (591) protection
• VTfuse-loss detection and blocking (60FL)
• Reconnect enable for intertie protection (79)
• Four-step over/under frequency (81) protection
Standard Features
• 2 programmable outputs, 2 programmable inputs, and 1 self-test output
• OsciUographlc recording (COMTRADE file format)
• Time-stamped sequence of events recording for 32 events
• Metering of Voltage, Current, real and reactive Power, Power Factor, Frequency, and Positive Sequence Impedance
• One RS-232 port (COM1) on front and one RS-232 or485 port (COM2) on rear
• M-381 OA I PScome For Windowsm Communications Software
• M-3811 A IPScom For Palm os• Communications Software
• MODBUS protocol
• Supports both 50 and 60 Hz applications
• Accepts 1 A or 5 A rated CT inputs
• Relay voltage Inputs can be directly connected (no VT requfred) for voltages ~480 V ac
• Continuous Self-Diagnostics
Optional Features
• M-3801C IPSploPOscillographAnalyslsSoftware
• Horizontal and Vertical panel mount versions available (see Figures 2 and 4)
-2-
M-3410A lntertleiGeneratorProtectlon Relay
Tests and Standards
The M-341 OA Generator/Jntertie Protection Relay complies with the following type tests and standards:
Voltage Withstand
Dielectric Withstand
All terminals except power supply and status Input contacts, 2500 V ac/3500 V de Power Supply and Status Input Contacts:
IEC 60255-5 i ,500 V de for power supply voltages (12, 24, 48 V Inputs)
2500 V ac/3500 V de for power supply voltages ( 120 V ac/125 V de Input)
• NOTE: Digital data circuits {RS-232/485 communication ports) are excluded.
Impulse Voltage
Power Supply Input Voltages, 120 Vac/125 V de:
IEC 60255-5 5,000 V pk, +1-polarity applied to each Independent circuit to earth
5,000 V pk, +1-polarity applied between lndepandentcircults
1.2 )lS by 50 J.LS, 500 ohms Impedance, three surges at every 5 second interval
• NOTE: Digital data circuits (RS-23~1485 communication ports) are excluded.
Power Supply Input Voltages1 12, 24,48 V de: IEC 60255-5 3,000 v pk, +1-polarity applied to each Independent circuit to earth
3.000 V pi<, +1-polarity applied between independent circuits
1.2 fJS by 50 flS. 500 ohms Impedance, three surges at every 5 second Interval
• NOTE: Digital data circuits (RS-2321485 communication ports) are excluded.
Insulation Resistance
IEC 60255-5 > 40 Megaohms
• NOTE: Digital ~ata circuits (RS-232/485 communication ports) are excluded.
Electrical Environment
Electrostatic Discharge Test
IEC 61000-4-2 Class 4 ( :t8 kV) -point contact discharge and all' discharge
a NOTE: Digital data circuits (RS-232/485 communication ports) are excluded.
Fast Transient Disturbance Test
IEC 61000-4-4 (±2 kV, 5kHz) AC Power Supply Input
( ± 1 kV, 5 kHz) RS-232, RS-485 and ground
Surge
IEC 61000-4-5 (±2 kV, 1 .. 2 fJS by 50 fJS line to ground) AC Power Supply lnput
( ± 1 kV, 1 .2 J.1S by 50 fJS line to line) AC Power Supply Input (± 1 kV, 1.2 fJS by 50 JlS line to ground) RS-485 Port
Surge Withstand Capability
ANSIIIEEE 2,500 V pk-pk Oscillatory each independent circuit to earth
C37 90.1 2,500 V pk-pk Oscillat<;>ry between each independent circuit 1989 5,000 V pk FastTransient each independent circuit to earth
5,000 V pk Fast Transient between each Independent circuit
• NOTE: Digital data circuits (RS-232/485 communication ports} are excluded ..
II
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lstruzioni di installazione ed esercizio
Instructions for installation
and service
ITSCB 601933/001 il-en 6-97
ABBSACE
lstruzioni di installazione, di esercizio e di manutenzione per interruttori automatici aperti di bassa tensione
Installation, service and
maintenance instructions for
low voltage air circuit-breaker
SACE Emax
Alii II jl I'll'
12. Unita di protezione PR111 /LI -LSI -LSIG
12.1 Generalita
L'unita SACE PR 111/P reatizza Ia seguenll runzionl di protezione:
l -prolezlone da so~~~accerico a tempo lungo lnverso S -proteziona da corto circullo a tempo breve I -protezione da curto clrculto lstantaneo G -protezlone da guasto a terra finst -pratezlone a soglia Iissa da corte circu~o
Le unita SACE PR111 dlspo:llbl\1 all'utente sono:
PR111/L+l+llnst
12. PR111/LI-LSI-LSIG protection unit
12.1 General
The SA CE PR1111P tm/1 carries out tho following protection functions:
L. prolfJction against overload with /nYat5·e long trme-detay
S protection ogainsL short-tim" short-cirt:uit
I -protection against Instantaneous short-circuit
G -ptotecOon ligalnsl earth fault lfnst -mpfd protection agalnsl inslllntaneol.ls shorl-cfrcu/1
The SACE PR 111 units FWBilabla to the user are:
PR111/L+S+I+llnst
PR111/L+S+I+G+llnst
Fig. 47
Le prolezioni possono essere realizzate in modo lrifase o trifase con
neutm a secom!a del lipo dllnterruttore lmplegato (lrlpolara. tetrepotare
o lripolare ao11 neutro e!llemo).
~unltA, e autoalltnentata·e garenfisce il corretto 1Wi21onainento c!elle runzlonl dl protaziono In p•esenza di una oommte maggiore·o uguale-af 1 8% del val<;>re nominate del trasformatore amperomelrico dl lose (T A). L'assleme sgancialcru c,li Jlfoleztone e c:osl composto: -3 o d trasfarmalori di cortontc (T A) -unitil dt prowzlone SACE PR1 11 -un solenoids dl apertura (SA) dello sganciatore (j\ mas sima corrente che aglsce direttamente sui comando de!l'interrunore _
Mod. IM4379 I I Rev. I I I
Thlil proleallons C81J·bo marie either In lhre&-phass or tl'lre&-ph"ifSB wflh
neutral modo, depending on the /yfHlof drcvlt-bteakerusod (thrGR-!JOI9,
fuur-pole or three-pole IVith extamalneutml),
Thli unit Is self-powen>d .:~nd ensur~ correcl opera/ion of /he prolec­
tiOn flm~lfons whrurlllete Is a cummt lrlgl•errflan oroquatro 18% of!/1e
rattJd phase currant lr.tnsloJmer il:~tua (CT).
Tho proleclion releasll asssmbly consists of lfte following: -3 or 4 CUm1nr /ronsforrooro /CT) -SACE PR111 protectt1111 un/1 -an opening solenoid (OS) of the overcumml release which ac/s
direclly an the c;irr;uit-breaker aperaling mechanism.
Apparocchio SACE Emax Sc<lla
Apparatus Scala
N'Doc 601933/001 N' ppa.
Dor:.NO-$1r.l-JD.
~lJUJI
12.S Curve di lntervento
12.8.1 Curve dllntervenlo protezlone "L"
'
0
100 • '
.. -
10 .,
.
I
3Cittt.1 '·' l)
12.8.2 Curve dllntervento protozlone "I"
~I • : ..
1110
' .0
!0 ID'
tO
'
·-
• ~1 ,, ·~
Mod. IM•I379 I Rov. f I
12.8 Trip curves
12.8.1 Trip curves of protection "L"
~
!'..
i'~ !'.. I'.: !'., -....._
I' " "'!'..'~
"' I"
.. . •
12.8.2 Trip curves of protecllon nl"
•
-t.• D.t M 0 I 0,10.01 l,t '·' > ' . ' I I f: Iii tO ~~ " "' " ''
I Appouocc,liO
I Appar~lus SACEEmax
N"OI)C.
Doc. No 601933/001
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BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 6
Small Gen Feasibility Study Agreement
Swager Fanns Project# 268
Feasibility Study Agreement
THIS AGREEMENT is made and entered into this __ day of S:?y -\em0e( 2008 by and
between 1-\-VIdgotf (onp<li'D\.-t-.'on , a Cocfl'>lfc'-h.\)V' organizedand
existing under the laws of the State of __ ..I.(IA.v.L .... I{\...,(....._b-"'u'~~J-\-zl-'-=v'-'"=----------~
("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 refened 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 9/10/08, also known as
Project# 268; 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 perfonn a
feasibility study to assess the feasibility of interconnecting the proposed Small Generating
Facility with the Transmission Provider's Transmission System, and of any Affected Systems;
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the 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
perfonned 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 infonnation 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 teclmical infonnation 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
Swager Fanns Project# 268
5.0 In perfonning the study, the Transmission Provider shall rely, to the extent reasonably
practicable, on existing studies of recent vintage. The Interconnection Customer shall not
be charged for such existing studies; however, the Interconnection Customer shall be
responsible for charges associated with any new study or modifications to existing studies
that are reasonably necessary to perfonn 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 thennal 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 inten-uption 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 perfonnance of the Interconnection
Feasibility Study.
Transmission Provider shall charge and Interconnection Customer shall pay the actual
costs of the Interconnection Feasibility Study. Any difference between the deposit and
the actual cost of the study shall be paid by or refunded to Interconnection Customer, as
appropriate.
Page 2 of3
·.
Small Gen Feasibility Study Agreement
Swager Fanns Project # 268
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 3 0 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----'---~-a-v._<::_. -~--·· __ -----.._ ____ _ Signed._-?~~. ~2:5;:;::• :;::2~===-------
Printed Ma-rc (o.:t1-e r .SovJ Printed f vk -::::J.U"'C~ S
Title .t;_, ata:rry i.eaelc." ~Ti D f'611tr~ Title tktM f1~1ol#nfYn-f /!);.,....-~ v I ?
Date 7/zr/o ,}'
Page 3 of3
Small Gen Feasibility Study Agreement
Swager;_farms Project# 268
Attachment A to Feasibility Study Agreement
Assumptions Used in Conducting the Feasibility Study
The feasibility study will be based upon the inform ation set forth in the Interconnection Request
and agreed upon in the scoping meeting held on 9 I.Z.'l/C!8 , :
1) Designation ofPoint of Interconnection and configuration to be studied.
~l(t(r ~ -~~'A.\(<'\~ ~i~.!.iry ·nb 7 e 5 [{troA.( ): B(.L/t/J ID ~ 350 r tl'!·.e ex/<MJid"t..
.OV\ Afil ,d --~il.loro • · ..... J .t/'a,.._ )2h.vcC<.,iskbufn ... ?eech/' Ct.<Jvt~rtJI.<..
2) Designation of altemative 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.
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BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 7
CP
GENERATOR INTERCONNECTION
FEASIBILITY STUDY
For integration of the proposed
SWAGER FARMS DAIRY DIGESTER PROJECT
In
TWIN FALLS COUNTY, IDAHO
To the
IDAHO POWER COMPANY ELECTRICAL SYSTEM
For
ANDGAR CORPORATION
The
INTERCONNECTION CUSTOMER
FINAL REPORT
NOVEMBER 13, 2008
LO Introduction
Andgar Corporation has contracted with Idaho Power Company (IPCO) to perform a Generator
Interconnection Feasibility Study for the integration of the proposed 1.2 MW digester project at
Swager Farms (project #268). The proposed location of the project is in Idaho Power's southern
Idaho service territory in Twin Falls County at 3800 North 1707 East. See Appendix B for
general location map of project area.
This report documents the basis for and the results ofthe Feasibility Study for the Swager Farms
Project. It describes the proposed project, the study cases used; estimated costs for
interconnection and determination of project interconnect feasibility.
2.0 Summary
The proposed small generation project is a 1.2 MW biogas generation project consisting of two
600 kW Stamford PI736B synchronous generator units. The generation project will connect to
the IPCO owned Clover 012 (COVR-0 12) 12.5 kV distribution feeder. The upgrades to this
feeder needed to connect this project include a 350' line extension, transformer and capacitor
bank installations, as well as a generation interconnection and protection package. The estimated
cost to interconnect this generation project to Idaho Power's system is $316,250.
This feasibility study indicates the existing 46 kV transmission system does currently have the
capacity for the 1.2 MW output of the digester project. However, there are limitations in the
Midpoint West transmission system to the north and west of this area. There is no available
transmission capacity for this project in the Midpoint West system when considering other
proposed generation projects ahead of this one in the queue. An existing study is attached as
Appendix C which details the existing system limitations and describes the improvements
necessary to increase the capacity of this system another 330 MW. However, this proposed
capacity is already committed to other proposed generation projects currently ahead of this one
in the queue.
3.0 Scope of Interconnection Feasibility Study
The Interconnection Feasibility Study was done and prepared in accordance with Idaho Power
Company Standard Generator Intercotlllection 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 Section 5.0 of 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 of these projects can be found on the Idaho Power
web site as follows:
http://www.oatioasis.com/ipco/index.html.
4.0 Description of Proposed Generating Project
The Swager Farms biogas project proposes to connect to the Idaho Power distribution system for
an injection of 1.2 MW (maximum project output) using two 600 kW Stamford PI736B
synchronous generator units.
5.0 Description of Transmission Facilities
The 1.2 MW Andgar biogas generation project at Swager Farms Dairy in Twin Falls County,
Idaho will connect IPCO's Clover 012 (COVR-012) 12.5 kV distribution line. The Clover
substation is served by Idaho Power's Dale -Twin Falls 46 kV transmission system. There is
adequate capacity on this 46 kV transmission system to serve this project.
This feasibility study has identified limitations in the Midpoint West transmission system to the
north and west of this area. There is no available transmission capacity for this project in the
Midpoint West system when considering other proposed generation projects ahead of this one in
the queue. An existing study is attached as Appendix C which details the existing system
limitations and describes the improvements necessary to increase the capacity of this system
another 330 MW. However, this proposed capacity is already committed to other proposed
generation projects currently ahead of this one in the queue.
6.0 Description of Substation Facilities
The substation serving the area around Swager Farms Dairy is IPCO's Clover (COVR)
substation, which is located near the intersection of 3350 N. and 1950 E. in Twin Falls County.
The existing substation transformer is a 46:12.5 kV, 4.69 MVA transformer. This study
indicates there is adequate capacity at COVR substation for the 1.2 MW biogas project.
7.0 Description of Distribution Facilities
The 1.2 MW Andgar biogas generation project at Swager Fanus Dairy in Twin Falls County,
Idaho will connect to IPCO's COVR-012 12.5 kV distribution line. There is adequate capacity
on this distribution line to serve this project. However, the project will have to run at a power
factor between 80% and 88%, lagging. In other words, it will have to absorb between 650 kV AR
and 900 kV AR, especially during periods of light loading.
A capacitor bank will have to be added for compensation purposes due to the facilities lagging
power factor. Since it will be running between 80% and 88% power factor, 650 kV AR to 900
kV AR will need to be generated. That V AR flow will come from a 900 leV AR capacitor bank
located near the intersection of 3550 N. and 1700 E. This location eliminates high voltage
3
concerns which would have become an issue if the bank were placed closer to Swager Fanns
Dairy.
Other additions include a line extension and transfonner addition at the POI. The line extension
will be 350' long and comprised of#4 ACSR conductor. The transformer will be a 1500 kVA
12.47 kV:480 V padmount transformer.
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 point of interconnection (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.
8.0 Circuit Breaker Short Circuit Limits
The maximum available fault current with the Andgar 1.2 MW project connected is about 6000
Amps at the POI. The 12.5 kV breakers at COVR substation are rated for 18 KAIC. This
feasibility study ·indicates that there is adequate short circuit interrupting capability on these
breakers for the addition of this generation project.
9.0 Site Load
At the generating site, 75 kW of load has been studied for insertion prior to generation. There
will be no required upgrades to add the 75 kW of load at Swager Fanns.
10.0 Cost Estimate
The estimated costs to interconnect the 1.2 MW biogas generation project by Andgar at Swager
Farms Dairy in Twin Falls County is $316,250. These upgrades are listed in the following ·
Table.
Description Estimated Cost
One 1500 kVA 12.47kV:480 V padmount
transformer, 900 kV AR capacitor bank and 350' of
new line at POI $91,250
Generation Interconnection Protection Package
(Includes 12.47 kV recloser, controls, CTs, PTs, and
communications $225,000
Total Estimated Cost $316,250
Table 1: Cost Estimates
11.0 Description of Operating Requirements
In addition to the upgrades listed in section 8.0 of this report, the proposed project must meet
several operating requirements. The project must be controlled to operate at a lagging power
4
factor between 80% and 88% or meet the voltage schedule provided by Idaho Power. If this
requirement can not be met, further voltage studies will be necessary. Voltage flicker at startup
and during operation will be limited to less than 5% as measured at the point of interconnection.
For this to occur, the generation facility can not exceed 50 Amps during start up at the 12.5 kV
voltage level. This forces the generating facility to start their 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. The project must also limit the ground fault current at the point of
interconnection to 20 Amps. See Appendix A for more details
12.0 Conclusion
The requested interconnection of the 1.2 MW And gar Biogas project located at Swager Farms
Dairy in Twin Falls County to Idaho Power's system was studied. The results of this study
indicate that it is feasible to connect this project to the existing Idaho Power system. A
transmission system impact study is required for this project to determine any additional
transmission system upgrades required but not detailed in this feasibility study report.
5
APPENDIX A
A-1.0 Method of Study
The Feasibility Study plan inserts the Project up to the maximum requested injection into the
selected Western Electric Coordinating Council (WECC) power flow case and then, using Power
World Simulator Version 11, 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 that voltages, under normal operating conditions,
are to be maintained within plus or minus 5% (0.05 per unit) of norriinal. Therefore,
voltages greater than or equal to 0.95 p.u. voltage and less than or equal to 1.05 p.u.
voltage are acceptable.
Voltage flicker during starting, stopping or operation of 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 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 ofV ARs will result in voltage decay or even collapse
under the worst conditions.
All customer generation must meet IEEE 519 and ANSI C84.1 Standards.
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
6
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 Requirements
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://ww.w.idahopower.com/aboulus/business/generationlnterconnectl.
A-5.0 WECC Coordinated Off~Nominal Frequency Load Shedding and Restoration
Requirements
IPC requires frequyncy operational limits to adhere to WECC Under-frequency and Over­
frequency Limits per the WECC Coordinated Off-Nominal Frequency Load Shedding and
Restoration Requirements available upon request.
7
APPENDIXB
Project #268 Swager Farms
A Clover Substation * POl e Capacitor Bank
APPENDIXC
GENERATOR INTERCONNECTION
SYSTEM IMPACT STUDY REPORT
for
Up to 330 MW of New Generation
On the 138 kV Transmission System
In the Twin Falls Area
to
IDAHO POWER COMPANY, Transmission Provider
TRANSMISSION SYSTEM
FINAL REPORT
June 29, 2007
-1-
1.0 Introduction
Multiple new generation projects have contacted Idaho Power Company (IPC) to perform
Generator Interconnection System Impact Studies for Network Resource Interconnection
Service at 138 kV for the integration of new generation projects in the Twin Falls area.
This report documents the basis for and the results of this System Impact Study. Previous
studies were performed with these new generation projects being non-dispatchable. This
System Impact Study will document the transmission system improvements required if the new
generation projects are dispatchable. It describes the backbone transmission system
improvements required for Network Resource Interconnection Service of the new generation
proposed, the study cases used, outage scenarios assumed, redispatch requirements, and results
of all work in the areas of concern.
2.0 Summary
The performance of the backbone transmission system was evalu!lted to integrate up to 304
MW of new generation on the 138 kV transmission system in the Twin Falls area. Five phases
of transmission system improvements are required to provide 304 MW of new generation
Network Resource Interconnection Service.
Phase #1:
Phase #2:
Phase #3:
Install an 8 ohm 138 kV Series Reactor on the Upper Salmon-Mountain Home
Junction 138 kV transmission line. Without this improvement, the outage of
the Midpoint-Rattlesnake 230 kV transmission line results in an overload of
the Upper Salmon-Mountain Home Junction 138 kV line with no new
generation in the Twin Falls area. This improvement is necessitated by the
transmission improvements associated with Generation Project 88, and as a
result should be funded by Idaho Power Company-Delivery. This phase of
improvements is estimated at approximately $290,000.
Install a 4 ohm 138 kV Series Reactor on the Mountain Home Junction-Lucky
Peak 138 kV transmission line. Without this improvement, the outage ofthe
Rattlesnake-Boise Bench 230 kV transmission line results in an overload
exceeding the 30 minute emergency rating of the Mountain Home Junction­
Lucky Peak 138 kV line with new generation levels greater than 42 MW in
the Twin Falls area. This phase of improvements is estimated at
approximately $290,000.
Install a 12.35 ohm 138 kV Series Reactor on the Lower Malad-Mountain
Home Junction 138lcV transmission line and increase the impedance of the
existing Upper Salmon-Mountain Home Junction 138 kV Series Reactor to
26.2 ohms. Without this improvement, the outage of the Midpoint­
Rattlesnake 230 kV transmission line results in an overload exceeding the 30
minute emergency rating of the Lower Malad-Mountain Home Junction 138
kV line with new generation levels greater than 94 MW in the Twin Falls
area. This phase of improvements is estimated at approximately $290,000.
-2-
Phase#4:
Phase#S:
Re-configure the Midpoint-Rattlesnake 230 kV series capacitor bank to allow
1/3 of the compensation to be bypassed via IPC's SCADA system and install
a "automatic 1/3 bypass scheme" for overloads exceeding series capacitor's
30 minute emergency equipment rating of 135%. Without this improvement,
the outage of the Midpoint-Boise Bench #3 230 kV transmission line results
in an overload exceeding the 30 minute emergency rating of the Midpoint­
Rattlesnake 230 kV Series Capacitor Bank with new generation levels greater
than 153 MW in the Twin Falls area. This phase of improvements is
estimated at approximately $100,000.
Fold the Midpoint-DRAM #1 230 kV transmission line into the King
Substation and install a 230/138 kV 300 MVA transformer. Without this
improvement, the outage of the Rattlesnake-Boise Bench 230 kV transmission
line results in an overload exceeding the 30 minute emergency rating of the
Mountain Home Junction-Lucky Peak 138 kV line with new generation levels
greater than 156 MW in the Twin Falls area. This phase of improvements is
estimated at $10,320,000.
Once all five phases of improvements have been completed, the transmission system is capable
of interconnecting approximately 330 MW of new generation in the Twin Falls area and
serving them on a dispatchable basis.
Section 8.0 of this report details the results of studies to quantify generation redispatch
requirements following single contingencies on the transmission system. Reductions in the
amount of generation which may be redispatched following contingencies, are possible by
completing Phase #4 improvements earlier than required or funding optional modifications on
the Midpoint-Boise Bench #3 series capacitor bank.
These cost estimates include direct equipment and installation labor costs, indirect labor costs
and overheads, and allowance for funds used during construction (AFUDC). The proposed
cost allocation is subject to change, as more information is known. These are cost estimates
only and final charges to the customer will be based on the actual construction costs incurred.
3.0 Summary of Interconnection Requests
Requests were made to Idaho Power Co. by multiple generation projects in the Twin Falls area
to study the interconnection of the proposed generation projects to Idaho Power's transmission
system at the 138 kV level for Network Resource Interconnection Service.
4.0 Scope of Interconnection System Impact Study
The Interc01mection System Impact Study was done and prepared in accordance with the
FERC Order 2003-A, Standard Large Generator Interconnection Procedures, to provide a
preliminary evaluation of the System Impact of the interconnection of the proposed large
generating project to the Idaho Power transmission system. This study will only be concerned
with the capabilities of the Idaho Power system to manage this new resource within the study
area of the proposed interconnection.
-3-
5.0 Description of Existing Transmission Facilities
As shown in Figure 1 of Section 7.0, Midpoint Substation, north of Twin Falls, has three 230 kV
lines that carry bulk power westward to the Boise area. Midpoint-DRAM #1 line utilizes single
715.5 MCM conductor and has a continuous rating of339 MVA. The Midpoint-Rattlesnake-Boise
Bench #2line utilizes a 2 conductor bundle of715.5 MCM. This line has a continuous rating of
677 MV A. The Midpoint-Boise Bench #3 line has similar conductors and the same rating as the
Rattlesnake-Boise Bench #2 line. In the Mountain Home area, an additional230 kV line is
planned to carry bulk power westward. The Rattlesnake-Bennett Mountain-Danskin-Mora line
utilizes single 1272 MCM conductors ( 4 78 MV A) from Rattlesnake-Bennett Mountain, single
1590 MCM conductors (550 MV A) from Bennett Mountain-Danskin and Danskin-Mora. The
Bennett Mountain-Danskin-Mora transmission lines are required for the interconnection of
Generation Project 88; scheduled to be in-service Spring of2008.
In addition to the Midpoint to the Boise area 230 kV lines previously mentioned, there are two
138 kV circuits which can carry power from the Twin Falls area to the Mountain Home area.
They are:
• King-Lower Malad-Mountain Home Junction 138 kV Line
• King-Upper Salmon-Mountain Home Junction 138 kV Line
Generators located in the Twin Falls area which are intended to serve load growth in the Treasure
Valley area, will be adding new incremental flows on top of existing committed east-to-west
transactions across the Midpoint West transmission cutplane. This System Impact study will
model approximately 1100 MW of transfers across the Midpoint West cutplane, prior to this
proposed generator addition. For these studies, the flow level of the Midpoint west cutplane is
defined as the sum of the flows on the following lines:
• Midpoint-DRAM #1 230 kV line
• Midpoint-Rattlesnake 230 kV Line
• Midpoint-Boise Bench #3 230 kV Line
• Lower Malad-Mountain Home Junction 138 kV Line
• Upper Salmon-Mountain Home Junction 138 kV Line
6.0 Description of Configurations Studied
Since the most limiting operating conditions are expected during heavy production on the
upper and middle Snake and Boise River hydro plants, with heavy east-west transfers across
the Idaho Power transmission system, the injection of the new generation at King 13 8 kV bus
was inserted into a power flow case that would simulate committed (approximately 1100 MW)
pre-contingency flows on the Midpoint West transmission path.
7.0 Post-transient Study Results
This Interconnection System Impact Study Report is for Network Resource Interconnection
Service at 138 kV, for numerous proposed generation additions in the Twin Falls area. System
transfers across the Midpoint West cutplane are modeled at approximately 1100 MW prior to
-4-
the proposed transmission improvements or the proposed generators producing any power.
Hydro generation production for the Boise & Snake plants, were modeled at heavy, but
realistic levels. Output levels for the existing peakers at Dans kin and Bennett Mountain were
varied over their operating ranges as appropriate. N-0 and N-1 outage performance for the
existing system are recorded. For generation projects which will be dispatchable, generation
levels at King 138 kV bus are increased until a transmission system component reaches its 30
minute emergency equipment ratings during N-1 outages. IPC's 30 minute emergency
equipment ratings are 115% of continuous thermal ratings on transmission lines and
transformers, and 135% on Midpoint series capacitors. The most effective and cost-efficient
transmission system improvements are then added to the model and King generation is then
increased until30 minute emergency equipment ratings are reached during N-1 outages.
Following any N-1 outage, transmission line and transformer loadings which are less than or
equal to the 30 minute emergency equipment ratings (115%), but greater than the equipment
continuous ratings (100%), must be reduced to the continuous ratings by generation
curtailments, redispatch, or some other operating procedure. For the Midpoint series capacitor
bankS, following any N-1 outage, similar corrective actions are required for loadings which are
less than or equal to the 30 minute emergency equipment ratings (135%), but greater than the
equipment 8 hour rating (110%). Various options to correct overloads following N-1 outages
will be explored.
System following Generation Project 88
The following one line diagram depicts the transmission system with no outages, after the
addition of Generation Project 88 and its associated improvements.
Midpoint WGst = 1109 MW
System following Generation Project 88-No Outages
Figure 1
-5-
System following Generation Project 88 with N-1 Outages
The following one line diagram depicts the transmission system following the addition of
Generation Project 88 and its associated improvements in 2008, with no new generation in the
Twin Falls area, and the only N-1 outage between Midpoint and the Mountain Home area that
results in loadings above continuous thermal ratings on the 138 kV transmission system.
Midpoint West"' 1038 MW
System following Generation Project 88 -Midpoint-Rattlesnake 230 kV Outage
Figure 2
Phase #I Transmission Improvements
The Midpoint Series Capacitor banks are capable of 110% of thermal rating for eight ho~rs. A
prolonged outage of the Midpoint-Rattlesnake 230 kV line will require a reduction o{transfers
across the Midpoint West cutplane to prepare for the next contingency. The overload of the
Midpoint-Boise Bench #3 Series Capacitor is less than its 8 hour rating, and will be resolved
with the reduction in transfers. As a result, only the overloads on the 138 kV lines between
Upper Salmon and Mountain Home Junction are problematic. The most effective and cost­
efficient transmission improvement to alleviate these overloads is the installation of a series
reactor on the Upper Salmon-Mountain Home Junction 138 kV line to better balance flows on
the transmission network. A series reactor with an impedance of .042 p.u. (8 ohms) alleviates
the overloads. Since this N-1 overload condition pre-exists the addition of any new generation
in the Twin Falls area, Idaho Power Company will take responsibility to fund this series reactor
installation.
The following one line diagram depicts the system with Phase #1 improvements added, no new
generation in the Twin Falls area, and the same N-1 as Figure 2.
-6-
Midpoint West= 1038 MW
Phase #1 Transmission Improvements -Midpoint~Rattlesnake 230 leV Outage
No New Generation
Figure 3
Phase #2 Transmission Improvements
The following one line diagram depicts Phase #1 transmission improvements and 42 MW of
new generation in the Twin Falls area, and the only N-1 outage that results in loadings at or
above 30 minute equipment ratings.
Mldooint Wast= 1077 MW
Phase #1 Transmission Improvements-Rattlesnake-Boise Bench #2 230 kV Outage
42 MW of New Generation
Figure 4
-7-
The most effective and costMefficient transmission improvement to alleviate this overload is the
installation of a series reactor on the Mountain Home JunctionMLucky Peak 138 kV line to
better balance flows on the transmission network. A series reactor with an impedance of .021
p.u. (4 ohms) was determined to be the optimal size considering future generation additions.
This overload is the result of the addition of new generation in the Twin Falls area, and as a
result the costs of this improvement will be allocated to new generation interconnections.
The following one line diagram depicts the system with Phase #2 improvements added, 42
MW of new generation in the Twin Falls area, and the same N-1 as Figure 4. Please note that
generation redispatch will be required following this contingency to reduce loadings to levels
which can be acconunodated continuously.
Midpoint We!!t = 1075 MW
Phase #2 Transmission Improvements-Rattlesnake-Boise Bench #2 230 kV Ou~age
42 MW of New Generation
Figure 5
Phase #3 Transmission Improvements
The following one line diagram depicts Phase #2 transmission improvements and 94 MW of
new generation in the Twin Falls area, and the only NM I outage that results in loadings at or
above 30 minute equipment ratings.
M8-
Mldpp!nl West" 1106 MW
Phase #2 Transmission Improvements -Midpoint-Rattlesnake 230 kV Outage
94 MW of New Generation
Figure 6
To interconnect generation quantities greater than 94 MW will require additional transmission
system improvements. The most effective and cost-efficient transmission improvements to
alleviate these overloads are the installation of a new series reactor on the Lower Malad­
Mountain Home Junction 138 kV line and an increase in the impedance of the Upper Salmon­
Mountain Home Junction 138 kV line series reactor. These improvements, referred to as Phase
#3, will better balance flows on the transmission network. A Lower Malad-Mountain Home
Junction series reactor impedance of .065 p.u. (12.35 ohms) was determined to be the optimal
size considering future generation additions. The impedance of the Upper Salmon-Mountain
Home Junction series reactor should be increased to .138 p.u. (26.2 ohms). This overload is
the result of the addition of new generation in the Twin Falls area, and as a result the costs of
this improvement will be allocated to new generation interconnections.
The following one line diagram depicts the system with Phase #3 improvements added, 94
MW of new generation in the Twin Falls area, and the same N-1 as Figure 6.
-9-
Midpoint West"' 1099 MW
Phase #3 Transmission Improvements-MidpointMRattlesnake 230 kV Outage
94 MW of New Generation
Figure7
Phase #4 Transmission Improvements
The following one line diagram depicts Phase #3 transmission improvements and 153 MW of
new generation in the Twin Falls area, and the only N-1 outage that results in loadings at or
above 30 minute equipment ratings.
Midpoint WM t : H72 MW
Phase #3 Transmission Improvements -Midpoint~Boise Bench #3 230 kV Outage
153 MWofNew Generation
Figure 8
-10-
To interconnect generation quantities greater than 153 MW will require additional transmission
system improvements. If new generation levels exceed 153 MW, and the Midpoint-Boise
Bench #3 230 kV line opens, the series capacitor bank on the Midpoint-Rattlesnake 230 kV
transmission line may exceed its 30 minute overload capability of 135%. Presently, both the
230 kV series capacitor banks at Midpoint are configured to operate either fully in-service or
fully by-passed. The most effective and cost-efficient transmission improvement to alleviate
this overload is there-configuration of the Midpoint-Rattlesnake 230 kV series capacitor bank
to allow one third of the compensation to be bypassed. In addition, an automatic control
scheme should be employed to bypass one third of the series capacitor bank when appropriate
system conditions are detected. The re-configuration of the series capacitor bank and the
addition of the automatic control scheme is referred to as Phase #4.
The following one line diagram depicts the system with Phase #4 improvements added, 153
MW of new generation in the Twin Falls area, and the same N-1 as Figure 8.
Midpoint West= 1145 MW
Phase #4 Transmission Improvements-Midpoint-Boise Bench #3 230 kV Outage
153 MW of New Generation
Figure 9
Phase #5 Transmission Improvements
The following one line diagram depicts Phase #4 transmission improvements and 156 MW of
new generation in the Twin Falls area, and the only N-1 outage that results in loadings at or
above 30 minute equipment ratings.
-11-
Midoolnt Wast "' 1151 MW
Phase #4 Transmission Improvements-Rattlesnake-Boise Bench #2 230 kV Outage
156 MW of New Generation
·Figure 10
To interconnect generation quantities greater than 156 MW will require additional transmission
system improvements. If new generation levels exceed 156 MW, and the Rattlesnake-Boise
Bench #2 230 kV line opens, the Mountain Home Junction-Lucky Peak 13 8 kV transmission
line may exceed its 30 minute overload capability of 115%. The required system
improvements are referred to as "Phase #5" and include folding the Midpoint-DRAM #1 230
kV transmission line into and back out of the King Substation and installing a 230/138 kV 300
MV A transformer. This overload is the result of the addition of new generation in the Twin
Falls area, and as a result the costs of this improvement will be allocated to new generation
intercoooections.
The following one line diagram depicts the system with Phase #5 improvements added, 156
MW of new generation in the Twin Falls area, and the same N-1 as Figure 10.
-12-
Midpoint w.,sr = 1165 MW
Phase #5 Transmission Improvements-Rattlesnake-Boise Bench #2 230 kV Outage
156 MW of New Generation
Figure 11
Phase #5 transmission improvements are capable of accommodating approximately 330 MW
of new generation in the Twin Falls area. The following one line diagram depicts the system
with Phase #5 improvements added, 330 MW of new generation in the Twin Falls area, and the
loss of the Midpoint-Rattlesnake 230 kV transmission line. At 330 MW of new generation in
the Twin Falls area, two other outages also result in transmission system components loaded at
their 30 minute emergency equipment ratings.
Midpoint West ,. 1272 MW
Phase #5 Transmission Improvements-Midpoint-Rattlesnake #2 230 kV Outage
330 MW of New Generation
Figure 12
-13-
8.0 Generation Redispatch Requirements
Generators which have chosen to be dispatchable are allowed to operate at levels which may
create overloads at or below 30 minute emergency equipment ratings following N-1
contingencies. Following any N-1 outage, transmission line and transformer loadings which
are less than or equal to the 30 minute emergency equipment ratings (115%), but greater than
the equipment continuous ratings (100%), must be reduced to the continuous ratings by
generation curtailments, redispatch, or some other operating procedure. For the Midpoint
series capacitor banks, following any N-1 outage, similar corrective actions are required for
loadings which are less than or equal to the 30 minute emergency equipment ratings (135%),
but greater than the equipment 8 hour rating (110%).
The following table summarizes generation curtailment requirements for the proposed
generation projects modeled at King 138 kV Substation; for various timeframes, and for
numerous transmission system single contingencies.
The fourth column ofthe table provides information regarding potential benefits of requesting
and funding an optional improvement. The improvement evaluated is the re-configuration of
the Midpoint-Boise Bench #3 230 kV series capacitor bank to allow one third of the
compensation to be bypassed. Unlike Phase #4, no automatic control scheme is contemplated.
This Optional Improvement may reduce the magnitude of generation which must be
redispatched during a Midpoint-Rattlesnake 230 kV Transmission Line outage. The Optional
Improvement is estimated at approximately $50,000.
The fifth column of the table provides information regarding potential benefits of completing a
portion of Phase #4 improvements early. Phase #4 improvements can be separated into two
components. The first component is the "re-configuration" of the Midpoint-Rattlesnake 230
kV series capacitor so it can be operated "fully in-service", "113 bypassed", "2/3 bypassed", or
"fully bypassed". The second component was the "automatic control scheme". The Phase #4a
improvement contained in the fifth column is for expediting only the "re-configuration"
component. Expediting the phase #4a improvement may reduce the magnitude of generation
which must be redispatched during a Midpoint-Boise Bench #3 230 kV Transmission Line
outage. The Phase #4a improvement is estimated at approximately $50,000.
-14-
Maximum Maximum
Maximum Allowable Allowable
Allowable Maximum Generation Generation
Generation Allowable After N-1 After N-1
Before Generation w/Optional w/Phase #4a
Contingency N-1 After N-1 Improvement Improvement
After Phase #1, but before Phase #2
Midpoint-Boise Bench #3 230 kV Line 42MW OMW OMW 42MW
Midpoint-Rattlesnake 230 kV Line 42MW 7MW 7MW 7MW
Rattlesnake-Boise Bench 230 kV Line, also
open Mountain Home Junction-Danskin 138 42MW 9MW 9MW 9MW
kVLine
Danskin-Mora 230 kV Line, also open
Mountain Home Junction-Danskin 138 kV 42MW 42MW 42MW 42MW
Line
After Phase #2, but before Phase #3
Midpoint-Boise Bench #3 230 kV Line 94MW OMW OMW 94MW
Midpoint-Rattlesnake 230 kV Line 94MW 9MW 9MW 9MW
Rattlesnake-Boise Bench 230 kV Line, also
open Mountain Home Junction-Danskin 138 94MW 32MW 32MW 32MW
kV Line
Danskin-Mora 230 kV Line, also open
Mountain Home Junction-Danskin 138 kV 94MW 80MW 80MW 80MW
Line
Mountain Home Junction-Lower Malad 138 94MW 49MW 49MW .49MW kVLine
Lucky Peak-Micron 138 kV Line 94MW 45MW 45MW 45MW
Danskin 230/138 kV Transformer 94MW 90MW 90MW 90MW'
After Phase #3, but before Phase #4
Midpoint-Boise Bench #3 230 kV Line 153MW OMW OMW 153MW
Midpoint-Rattlesnake 230 kV Line 153MW 17MW 53MW 17MW
Rattlesnake-Boise Bench 230 kV Line, also
open Mountain Home Junction-Dansldn 138 153MW 71MW 71MW 71MW
kVLine
Danskin-Mora 230 kV Line, also open
Mountain Home Junction-Danskin 138 kV 153MW 120MW 120MW 120MW
Line
Mountain Home Junction-Lower Malad 138 153MW 129MW 129MW 129MW kV Line
Lucky Peak-Micron 138 kV Line 153 MW 84MW 84MW 84MW
Danskin 230/138 kV Transformer 153MW 125MW 125MW 125MW
Maximum Maximum
Maximum Allowable Allowable
Allowable Maximum Generation Generation
Generation Allowable After NMI After N-1
Before Generation w/Optional w/Phase #4a
Contingency NMl After N-1 Improvement Improvement
After Phase #4, but before Phase #5
Midpoint-Boise Bench #3 230 kV Line 156MW 156MW 156MW N/A
MidiJoint-Rattlesnake 230 kV Line 156MW 18MW 53MW N/A
Rattlesnake-Boise Bench 230 kV Line, also
open Mountain Home Junction-Danskin 138 156MW 71MW 71MW N/A
kVLine
Danskin-Mora 230 kV Line, also open
Mountain Home Junction-Danskin 138 kV 156MW 120MW 120MW N/A
Line
Mountain Home Junction-Lower Malad 138 156MW 129MW 129MW N/A kV Line
Lucky Peak-Micron 138 kV Line 156MW 84MW 84MW N/A
Danskin 230/138 kV Transformer 156MW 125MW 125MW N/A
After Phase #5
Midpoint-Boise Bench #3 230 kV Line 330MW 140MW 140MW N/A
Midpoint-Rattlesnake 230 kV Line 330MW 25MW 123MW N/A
Rattlesnake-Boise Bench 230 kV Line, also
open Mountain Home Junction-Danskin 138 330MW 254MW 254MW N/A
kV Line
Danskin-Mora 230 kV Line, also open
Mountain Home Junction-Danskin 138 kV 330MW 3lOMW 310MW N/A
Line
Mountain Home Junction-Lower Malad 138 330MW 280MW 280MW N/A kVLine
Lucky Peak-Micron 138 kV Line 330MW 265MW 265MW N/A
Danskin 230/138 kV Transformer 330MW 295MW 295MW N/A
King 230/138 kV Transformer 330MW 245MW 245MW N/A
-16-
9.0 Fault Study Results
Since this System Impact Study lumps all the proposed generation additions at King 138 kV bus, this Draft
Report makes no attempt to address fault study concerns. Each proposed generation project will have to be
evaluated individually based on its specific location.
10.0 Transient Stability Study Results
The Midpoint West Transmission System is not transient stability limited. Therefore, no transient stability
studies were performed.
11.0 Conclusions
The System Impact of interconnecting up to304 MW of new generation in the Twin Falls area to Idaho Power's
138 kV transmission system was studied. Five phases of transmission system improvements are required to
provide Network Resource Interconnection Service to 304 MW of new generation, on a dispatchable basis.
Phase #1 is the installation of an 8 ohm 138 kV Series Reactor on the Upper Salmon-Mountain Home Junction
138 kV transmission line. This improvement corrects an N-1 overload that exists before any new generation is
added in the Twin Falls area. As a result, the estimated $290,000 cost of this improvement will be borne by
Idaho Power Company. After approximately 42 MW of new generation is added, Phase # 1 improvements are
no longer sufficient. Phase #2 improvements require the installation of a 4 ohm 138 kV Series Reactor on the
Mountain Home Junction-Lucky Peak 138 kV transmission line. The estimated $290,000 cost of this
improvement should be allocated to new generator interconnections. Following the addition of approximately
94 MW of new generation, Phase #3 transmission improvements are required. Phase #3 improvements require
the installation a 12.35 ohm 138 kV Series Reactor on the Lower Malad-Mountain Home Junction 138 kV
transmission line, and increasing the impedance of the existing Upper Salmon-Mountain Home Junction 138 kV
Series Reactor to 26.2 ohms. The estimated $290,000 cost of Phase #3 improvements should be allocated to
new generator interconnections. Following the addition of approximately 153 MW of new generation, Phase #4
transmission improvements are required. Phase #4 involves re-configuring the Midpoint-Rattlesnake 230 kV
series capacitor bank to allow 1/3 of the compensation to be bypassed via IPC's SCAD A system and install a
"automatic 1/3 bypass scheme" for overloads exceeding the series capacitor's 30 minute emergency equipment
rating of135%. The estimated $100,000 cost of this improvement should be allocated to new generator
interconnections. Following the addition of approximately 156 MW of new generation, Phase #5 transmission
improvements are required. Phase #5 involves folding the Midpoint-DRAM #1 230 kV transmission line into
and back out of the King Substation and installing a 230/13 8 kV 300 MVA transformer. The estimated
$10,320,000 cost of this improvement should be allocated to new generator interconnections. Phase #5
transmission improvements are adequate to interconnect approximately 330 MW of new generation in the Twin
Falls area, on a dispatchable basis, before additional improvements are required.
APPENDIX A
1.0 Method of Study
The study methodology inserts the proposed generators up to the maximum requested output of 304 MW into
the selected WECC power flow case and then, using the PowerWorld Simulator powerflow program, examines
the impacts of the new resource on Idaho Power's transmission system (lines, transformers, etc.) within the
study area under various operating/outage scenarios. The WECC and Idaho Power reliability criteria and Idaho
Power operating procedures were used to determine the acceptability of the alternatives considered. The
WECC case is a recent case modified to simulate stressed but reasonable pre-contingency energy transfers
utilizing the IPC system.
2.0 Acceptability Criteria
The following acceptability criteria were used in the power flow analysis to determine the acceptability of the
alternatives:
Loadings on transmission lines and transformers should not exceed 115% of the continuous rating,
immediately following any N-1 outage. Loading on the Midpoint 230 kV series capacitors should not
exceed 135% ofthe continuous rating, immediately following anyN-1 outage. These loadings levels of
115% on transmission lines and transformers and 135% on Midpoint series capacitors correspond to
IPC's 30 minute emergency equipment ratings. Any loadings immediately following an N-1 outage,
less than the 30 minute emergency rating is acceptable.
Loadings which are less than the 30 minute emergency equipment ratings, but greater than the
equipment continuous ratings, must be reduced to the continuous ratings by generation curtailments, re­
dispatch, or some other operating procedure. Any remedial action schemes (RAS) or other transmission
switching, must be judged to be reasonable before the alternatives performance can be deemed
acceptable.
The continuous rating of equipment is assumed to be the normal thermal rating of the equipment. This
rating will be as determined by the manufacturer of the equipment or as determined by Idaho Power.
Less than or equal to 100% of continuous rating for transmission lines and transformers is acceptable.
Less than or equal to 110% of continuous rating for the Midpoint 230 kV series capacitors is acceptable.
Transmission voltages, under normal operating conditions, are maintained within plus or minus 5%
(0.05 per unit) of nominal. Therefore, voltages greater than or equal to 0.95 p.u. voltage and less than or
equal to 1.05 p.u. voltage are acceptable.
The stable operation of the transmission system requires an adequate supply of volt-amperes reactive
(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.
Idaho Power designs its system to integrate Network Resources at full capability during specified outage
conditions.
Equipment/line/path ratings used will be those that are in use at the time of the study or that are represented by
IPC upgrade projects that are either currently under construction or whose budgets have been approved for
-18-
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.
-19-
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 8
November 1 7, 2008
Re: Project# 268, Swager Farms
Dear Mr. Juergens:.
®
An IDACORP Company
Enclosed is a signed System Impact Study Agreement (SISA) for the above-referenced generator
interconnection project. Please provide all technical data, if you have not already done so, when
you deliver the executed Agreement. Please review the Point oflnterconnection, sign, and return
all pages to Candace Gentry, 1221 West Idaho Street, Boise, ID 83702.
In order to proceed, we must receive the executed System Impact Study Agreement, and a
required $2,000 deposit from you by January 2, 2009, otherwise your application will be deemed
withdrawn.
The studies will begin on the date we receive your deposit, the signed System Impact Study
Agreement, and all required technical data. If the technical data is not provided or if it is
deficient, you will be notified and must cure the deficiency within ten (l 0) Business Days,
provided, however, such deficiency does not include failure to deliver the executed SISA or
deposit.
Upon receipt of the executed System Impact Study Agreement, the System Impact Study will be
completed within 30 calendar days. During the study period, we will keep you apprised Of our
progress. If you have any questions in the meantime, please contact me.
Marc Patterson
C: R Bishop/IPC
Enclosure: Two Signed SISAs (one for your records)
P.O. Box 70 (83707)
1221 W.ldaho St.
Boise, ID 83702
r,
Small Generator System Impact Study Agreement
Project# 268, Swager Farms
System Impact Study Agreement
THIS AGREEMENT is made and entered into this __ day of ______ 2008, 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!daho, ("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 September 10, 2008,
and
WHEREAS, the Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Provider's Transmission System;
WHEREAS, the Transmission Provider has completed a feasibility study and provided the
results of said study to the Interconnection Customer (This recital to be omitted if the Parties
have agreed to forego the feasibility study.); and
WHEREAS, the Interconnection Customer has requested the Transmission Provider to perform
a system impact study(s) to assess the impact of interconnecting the Small Generating Facility
with the Transmission Provider's Transmission System, and of any Affected Systems;
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the terms specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause to be
performed a system impact study(s) consistent with the standard Small Generator
Interconnection Procedures in accordance with the Open Access Transmission Tariff.
3.0 The scope of a system impact study shall be subject to the assumptions set forth in
Attaclunent A to this Agreement.
4.0 A system impact study will be based upon the results of the feasibility study and the
technical information provided by Interconnection Customer in the Interconnection
Request. 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 system impact study. If the
Small Generator System Impact Study Agreement
Project# 268, Swager Fatms
Interconnection Customer modifies its designated Point of Interconnection,
Interconnection Request, or the technical information provided therein is modified, the
time to complete the system impact study may be extended.
5.0 A system impact study shall consist of a short circuit analysis, a stability analysis, a
power flow analysis, voltage drop and flicker studies, protection and set point
coordination studies, and grounding reviews, as necessary. A system impact study shall
state the assumptions upon which it is based, state the results of the analyses, and provide
the requirement or potential impediments to providing the requested interconnection
service, including a preliminary indication of the cost and length of time that would be
necessary to correct any problems identified in those analyses and implement the
interconnection. A system impact study shall provide a list of facilities that are required
as a result of the Interconnection Request and non-binding good faith estimates of cost
responsibility and time to construct.
6.0 A distribution system impact study shall incorporate a distribution load flow study, an
analysis of equipment interrupting ratings, protection coordination study, voltage drop
and flicker studies, protection and set point coordination studies, grounding reviews, and
the impact on electric system operation, as necessary.
7.0 Affected Systems may participate in the preparation of a system impact study, with a
division of costs among such entities as they may agree. All Affected Systems shall be
afforded an opportunity to review and comment upon a system impact study that covers
potential adverse system impacts on their electric systems, and the Transmission Provider
has 20 additional Business Days to complete a system impact study requiring review by
Affected Systems.
8.0 If the Transmission Provider uses a queuing procedure for sorting or prioritizing projects
and their associated cost responsibilities for any required Network Upgrades, the system
impact study shall consider all generating facilities (and with respect to paragraph 8.3
below, any identified Upgrades associated with such higher queued interconnection) that,
on the date the system impact study is commenced -
8.1 Are directly interconnected with the Transmission Provider's electric system; or
8.2 Are interconnected with Affected Systems and may have an impact on the
proposed interconnection; and
8.3 Have a pending higher queued Interconnection Request to interconnect with the
Transmission Provider's electric system.
9.0 A distribution system impact study, if required, shall be completed and the results
transmitted to the Interconnection Customer within 30 Business Days after this
Agreement is signed by the Parties. A transmission system impact study, if required,
shall be completed and the results transmitted to the Interconnection Customer within 45
Small Generator System Impact Study Agreement
Project# 268, Swager Fanus
Business Days after this Agreement is signed by the Parties, or in accordance with the
Transmission Provider's queuing procedures.
10.0 A $2,000 deposit will be required from the Interconnection Customer upon execution of
this agreement by the Interconnection Customer.
11.0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
12.0 The Interconnection Customer must pay any study costs that exceed the deposit without
interest within 3 0 calendar days on receipt of the invoice or resolution of any dispute. If
the deposit exceeds the invoiced fees, the Transmission Provider shall refund such excess
within 30 calendar days of the invoice without interest.
IN WITNESS THEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written.
Transmission Provider: Idaho Power Company
Signed: /J.f~~~*$~ ::=:::::::"7=;::::,...,....,
Printed: Marc Patterson
Title: Leader, T &D Planning
Date: November 17, 2008
Interconnection Customer: --------------------------
Signed'---------------
Printed --------------------------
Title _____________ _
Date ____________________ _
Small Generator System Impact Study Agreement
Project# 268, Swager Farms
Attachment A
Assumptions Used in Conducting the System Impact Study
The system impact study shall be based upon the results of the feasibility study, subject to any
modifications in accordance with the standard Sl1rlall Generator Interconnection Procedures, and
the following assumptions:
1) Designation ofPoint of Interconnection and configuration to be studied.
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.
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 9
Small Generator System Impact Study Agreement
Project# 268, Swager Fanns
System Impact Study Agreement
THIS AGREEMENT is made and entered into this 11£\Vl day of <'S;tJ...IA..\J..ct(y 200~y and
between A-roj?-1"" [ol'~or t'\h. OVI • , a c m eo,'-ct b" c v• organized
and existing under the laws ofthe State of ll )l!shfV\'d-vV) ,
("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 refe1red 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 September 10, 2008,
and
WHEREAS, the Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Provider's Transmission System;
WHEREAS, the Transmission Provider has completed a feasibility study and provided the
results of said study to the Interconnection Customer (This recital to be omitted if the Parties
have agreed to forego the feasibility study.); and
WHEREAS, the Interconnection Customer has requested the Transmission Provider to perform
a system impact study(s) to assess the impact of interconnecting the Small Generating Facility
with the Transmission Provider's Transmission System, and of any Affected Systems;
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the terms specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause to be
performed a system impact study(s) consistent with the standard Small Generator
Interconnection Procedures in accordance with the Open Access Transmission Tariff
3.0 The scope of a system impact study shall be subject to the assumptions set forth in
Attachment A to this Agreement.
4.0 A system impact study will be based upon the results of the feasibility study and the
technical inf01mation provided by Interconnection Customer in the Interconnection
Request. 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 system impact study. If the
Small Generator System Impact Study Agreement
Project# 268, Swager Farms
Interconnection Customer modifies its designated Point oflnterconnection,
Interconnection Request, or the technical infonnation provided therein is modified, the
time to complete the system impact study may be extended.
5.0 A system impact study shall consist of a short circuit analysis, a stability analysis, a
power flow analysis, voltage drop and flicker studies, protection and set point
coordination studies, and grounding reviews, as necessary. A system impact study shall
state the assumptions upon which it is based, state the results of the analyses, and provide
the requirement or potential impediments to providing the requested interconnection
service, including a preliminary indication of the cost and length oftime that would be
necessary to correct any problems identified in those analyses and implement the
interconnection. A system impact study shall provide a list of facilities that are required
as a result of the Interconnection Request and non-binding good faith estimates of cost
responsibility and time to construct.
6.0 A distribution system impact study shall incorporate a distribution load flow study, an
analysis of equipment interrupting ratings, protection coordination study, voltage drop
and flicker studies, protection and set point coordination studies, grounding reviews, and
the impact on electric system operation, as necessary.
7.0 Affected Systems may participate in the preparation of a system impact study, with a
division of costs among such entities as they may agree. All Affected Systems shall be
afforded an opportunity to review and comment upon a system impact study that covers
potential adverse system impacts on their electric systems, and the Transmission Provider
has 20 additional Business Days to complete a system impact study requiring review by
Affected Systems.
8.0 If the Transmission Provider uses a queuing procedure for sorting or prioritizing projects
and their associated cost responsibilities for any required Network Upgrades, the system
impact study shall consider all generating facilities (and with respect to paragraph 8.3
below, any identified Upgrades associated with such higher queued interconnection) that,
on the date the system impact study is commenced-
8.1 Are directly interconnected with the Transmission Provider's electric system; or
8.2 Are interconnected with Affected Systems and may have an impact on the
proposed interconnection; and
8.3 Have a pending higher queued Interconnection Request to interconnect with the
Transmission Provider's electric system.
9.0 A distribution system impact study, if required, shall be completed and the results
transmitted to the Interconnection Customer within 30 Business Days after this
Agreement is signed by the Parties. A transmission system impact study, if required,
shall be completed and the results transmitted to the Interconnection Customer within 45
Small Generator System Impact Study Agreement
Project# 268, Swager Farms
Business Days after this Agreement is signed by the Parties, or in accordance with the
Transmission Provider's queuing procedures.
10.0 A $2,000 deposit will be required from the Interconnection Customer upon execution of
this agreement by the Interconnection Customer.
11.0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
12.0 The Interconnection Customer must pay any study costs that exceed the deposit without
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 THEREOF, 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
Signed:
Printed: Marc Patterson
Title: Leader, T &D Planning
Date: November 17,2008
Interconnection Customer: ~ttr {orpur()l-h'vf\
Signed ~~~
Printed f?ri c \?nwe 1/
Title 1'rru a t
' ' Small Generator System Impact Study Agreement
Project# 268, Swager Farms
Attachment A
Assumptions Used in Conducting the System Impact Study
The system impact study shall be based upon the results of the feasibility study, subject to any
modifications in accordance with the standard Small Generator Interconnection Procedures, and
the following assumptions:
1) Designation ofPoint of Interconnection and configuration to be studied.
~ oV\ 1-\'e. ~rifh"vn IV\ t~ -Peu5ihi ll'+v gfVtdy.
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.
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 10
February 2, 2009
Eric Powell
Andgar Corporation
6920 Salashan Pkwy. A102
Ferndale, WA 98428
360.366.9900
Re: Swager Farms Generator Interconnection Project# 268
Dear Eric:
An IDACORP Compan1
Enclosed is an Executed System Impact Study Agreement between you and Idaho Power
Company for the above-referenced Generator Interconnection project. Please provide any
technical data required for the study, if you have not already done so.
We expect the System Impact Study to be completed by March 18, 2009. During the study
period, we will keep you apprised of our progress. If you have any questions in the meantime,
please contact me.
Sincerely,
Marc Patterson
Engineering Leader, T &D Planning
208.388.2712
marcpatterson@idahopower. com
Enclosure: Executed System Impact Study Agreement
C: R Bishop/IPC
P.O. Box 70 (83707)
1221 W. Idaho St.
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 11
April 10,2009
Eric Powell
Andgar Corporation
6920 Salashan Pkwy. A 1 02
Fendale, W A 98428
306.366.9900
Subject: GINT#268 System hnpact Study
Dear Mr. Powell:
An IDACORP Company
The Generator Interconnect Projecf (GINT) #268 was reviewed for system impacts. This review
identified other projects as well as other transmission system requests (TSR's) ahead of this in
the queue. The results of this review determined that the impact of this project were
inconclusive without the associated TSR :from the energy provider.
At this time, no additional transmission system upgrades have been identified that are associated
with this project, other than those upgrades identified in the Feasibility Study Report. After a
contract is reached between this project and the energy provider, any required TSR will be
submitted by the energy provider and a more detailed study will occur.
Sincerely,
Marc Patterson
Engineer Leader, T &D Planning
208.388.2712
[e-mail]
C: R Bishop/IPC
1221 W. Idaho St. (83702)
P.O. Box 70
Boise, ID 83707
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 12
Eric Powell
Andgar Corporation
6920 Salashan Pkwy. Al02
Ferndale, WA 98428
306.366.9900
Re: Project# 268-Swager Farms Project
Dear Eric:
An IDACORP Company
"".
April 24, 2009
Attached please find two copies of the Facility Study Agreement (FSA) that describes the
design phase of the project, the responsibilities and obligations of both parties, and the
work schedules required. To proceed with this application, Idaho Power must receive
your executed FSA and the required deposit in order to remain in the Generator
Interconnection queue. The deposit under this FSA is $15,000 based on the estimated
engineering costs provided to you in the Feasibility Study Report.
If you wish to proceed, please complete Attachment A, sign both copies and submit them
along with the deposit to Idaho Power Company, attn: Rowena Bishop by June 8, 2009,
otherwise your application will be deemed withdrawn. Please contact me if you have any
questions.
Encl: Two Facility Study Agreements
Cc: Candace Gentry/IPC
Rowena Bishop/IPC
Ed Kosydar/IPC
Sincerely,
Marc Patterson
Leader, T &D Engineering
Ph 208.388.2712
1221 W. Idaho St. (83702)
P.O. Box 70
Facilities Study Agreement
THIS AGREEMENT is made and entered into this __ day of _____ __;2009, by and
b~~ 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
consistent with the Interconnection Request completed by the Interconnection Customer on
September 10, 2008, 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
Facilities Study Agreement -1 -Swager Farms Project #268
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 $15,000 is due upon execution of this agreement by the Interconnection
customer.
7.0 In cases where Upgrades are required, the facilities study must be completed within 45
Business Days of the receipt of this Agreement. In cases where no Upgrades are
necessary and the required facilities are limited to Interconnection Facilities, the facilities
study must be completed within 30 Business Days.
8.0 Once the facilities study is completed, a facilities study 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: ------------------------------------------------------
Facilities Study Agreement -2-Swager Farms Project #268
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/PT maintenance?
Yes No ---
4. Will a transfer bus on the generation side of the metering require that each meter set be
designed for the total plant generation? Yes ___ No __
(Please indicate on the one-line diagram).
5. What type of control system or PLC will be located at the Small Generating Facility?
6. What protocol does the control system or PLC use?
7. Please provide a 7.5-minute quadrangle map of the site. Indicate the plant, station,
transmission line, and property lines.
8. Physical dimensions of the proposed interconnection station:
Facilities Study Agreement - 3 -Swager Farms Project #268
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 ___ IfNo, please provide name oflocal provider:
14. Please provide the following proposed schedule dates:
Begin Construction
Generator Step-Up Transformers
Receive Back Feed Power
Generation Testing
Commercial Operation
Facilities Study Agreement -4-
Date: -------------------------
Drue: ________________________ __
Date: -------------------------
Date: -------------------------
Swager Farms Project #268
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 13
June 8, 2009
Andgar Corporation
Attn: Eric Powell
6920 Salashan Parkway A-102
Ferndale, W A 98248
Re: Project #268 System Impact Study Refund
Dear Mr. Powell:
An IDACORP Company
Project #268 has completed the System Impact Study phase and the project has been withdrawn.
As a result, we are returning the original $2,000.00 deposit plus interest of $24.93. Please find
enclosed a check totaling $2,024.93.
Date of Request
Description of Requested Service
2/9/09 Project #268 Swager Farms System Impact Study
If I can be of any further assistance, please call [phone].
1221 W. Idaho St. {83702)
P.O. Box 70
Boise, ID 83707
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 14
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 find 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
1707 E 3800 N
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 P.erson:
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 lnstroctioos
An Interconnection Customers who request interconnection must submit this Interconnection Request by
hand delivery, mail, e-mail, or fax to the Transmission Provider.
Processiog Fee or Deposit:
If the Interconnection Request passes ALL screens of SOIP 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 djd not pass the Fast T!!ck Process. shall submit to the Transmission
Provider a deposit not to exceed $1 ,000 ·towards the cost of the feasibility study.
Interconne4:tion Castomer loformatioo
Legal Name of the Interconnection Customer (or, if an individual, individual's name)
Name: __ O~w~n~e~uO~pe~r~a~to~r~co~m~p~a~n~y~d~e~v~e~loLp~m~e~n~t~in~p~r~o~g~re~s~s _____________________ _
ConmmPc~on:-~S~e~e~B~e~lo~w~-----------------------------------------
Mailing Address:----------------------------_:._--------=-------
C~tr: ____________________ _ State:. _____ _ Zip:------------
Facility Location (if different from above):-----------------------=--------
Telephone (Day): __________ Telephone (Evenmg): _______ _
Fax:----------------------E·Mail Address:---------------------
1
I I I~
I
Alternative Contact Information (if different :from the Interconnection Customer)
Contact Name: · Laura Knothe PE
Title: Project Manager
Address: 8720 Vic Lane
Middleto"n ID 83644
Telephone (Day); 208 890.8783 Telephone (Evening): 20B 890 8783
Fax: _ _,2..,0.,.8..,58=5.'"".9'""'0"'"'16><--_________ E-Mail Address: [e-mail]
Application is for: x New-small Generating Facility
___ Capacity ru.Mition to Existing Small Generating Fac~lity
If capacity addition to existing facility, please describe: _.!.:N~A!-. ----------:--
Will the Small Generating Facility be· used for any of the following?
To SuppJy Power to the Interconnection ·customer? Yes _No _k_
To Supply Power to Others? Yes __ No _x_
For installations at locations with existing electric service to which the proposed Small Generating
Facility wil1 interconnect, provide:
· Idaho Power Company 2169397508
(Local Ele<:tric Service Provider*) (Existing Account Number*)
[*To be provided by the Interconnection Customer if the local electric service provider is different from
the Transmission Provider]
ConmctNIDne: ________________________________________________________ ___
Title:-------------------------------------------
Adm~s: __________________________________________________________ __
Te1ephone (Day): ------,-------------Telephone (Evening):----------
Fax: ______________________ E-Mail Address:---------------
Requested Point oflnterconnection: 1707 E 3800 N Buhl ·ID 83316 :
Interconneption Customer's Requested in-Service Date: ~J""u'-'-'lyt-2~0~1~0i.-_______________ _
2
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 1 Other (stafe type) ..JM:fie£lt.uha!ii!.!n.!le<..!G~ae;s!L.-._~--
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:..:.ne=--____ 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 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: (2) Caterpillar G3512 Gas Gensets@ 600kW
Version Number:-----------
Nameplate Output Power R~ng in kW: (Summer) _·..::12:::;0;,:,0....,.· .,......_,....--(Winter) ---'1:.:.20:.:0:....._ __ _
Nameplate Output Power Rating in.kVA; (Summer) 1500' · (Winre,r) _·...:.1.:::.50:::=:0~---
lndividuid Generator ·Power. F~ctor
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): --~!1-lA.~------------
List of adjustable set points for the protective equipment or software:-----------
.Mote; A completed Powul" Systems Luad Flow t.Jata sllu~::liiiWIL lJil IIUtJUiilltl with L11c lulcrconnection
RegueRt
3
Small Generating Facility Characteristic Data (for inverter-based machines)
Max design fault contribution current: --'N,_,A'--'----Instantaneous_ or RMS? __
Hannonics Characteristics: _ _.!.N~A~-------------------
Start-up requirements: __ _:...:N::_A:__ ___________________ _
Small Generating Facility Characteristic Data (for rotating machines)
RPM Frequency: 1200/60Hz
(*)Neutral Grounding Resistor (If Applicable): ____ _
Synchronous Generators:
Direct Axis Synchronous Reactance, Xd: ___ P. U.
Direct Axis Transient Reactmce, X'd: P.U.
Direct Axis Subtransient Reactance, X" d: -----------'P.U.
Negative Sequence Reactance, X2: P.U.
Zero Sequence Reactance, Xo: P.U.
KVA Base:-----------
Field Volts:------
Field Amperes: ------
Induction Generators:
Motoring Power (kW}: ------
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:-----­
FnuneS~e: --------
Design Letter:-------
Reactive Power Required In Vars (No Load):------
Reactive Power Required In Vars (Full Load): _____ _
Total Rotating Inertia, H: Per Unilon k. VA Base
Note: Please contact the Transmission Provider prior to submitting the Interconnection Request to
determine if the specified information above is reqyired.
4
I
I
I
I I
Excitation and Governor System Data for Svncbronous 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.
Interconuectiou Facilities luformatioo
Will a transformer be used betw~en the genemtor and the point of common coupling? 0 Yes _No
Will the tmnsformer 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 Impedance: ___ % 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 (If Applicable, for Inten;onnection 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 aoolicable):
Manufacturer:------------Type: ___ _
Load Rating (Amps): Interrupting Rating (Amps): Trip Speed (Cycles): ___ _
futerconnection Protective Relays Of 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.
I I
If Discrete Components:
(Enclose Copy of any Proposed Time-Overcurrent Coordination Curves)
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Manufacturer: Type: StyleJCatalog No.: Proposed Setting:
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Manufactur~r: 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: __
6
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. 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? 0_ 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) 1707 E 3800 N Byhl IP 83316
Enclose copy of any site documentation that describes and details the operation of the protection and
control schemes. Is Available Documentation Enclosed? ..Y._Yes __ 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, all the information provided in this Interconnection
Request is true and correct.
For Interconnection Customer:
Printed
I tLLUYO....
7
UNITED STATES
DEPARTMENT OF TliE INTERIOR
GEOLOOICAL SURVEY
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Date ___ _ SEL·547 Relay EZ Settings Sheet I' of 4
Appendix C
SEL-547 Relay EZ Settings Sheet
EZ Settings <use SHOE and SET E commands)
General Settings
Relay Identifier (30 characters) RELID
Terminal Identifier (30 characters) TERMID
Current Traosfonner Ratio (l-1000) CRATIO ""
Nominal Input Voltage, line-to-line (208-480 Vac) NOMV =
Three-Phase Voltage Connection (WYE); fixed setting 3PCONN =
Nominal System Frequency (50, 60 Hz) FREQ =
Phase Rotation (ABC, ACB) ROfATE =
Date Format (MDY, YMD) DATE =
LED Flash Interval (OFF, 5, 10, 15, 30,60 sec.) LEDFL =
Voltage Element Settings (device 27/59; 4 elements>
Undel'voltage l Pickup (OFF, 50-100%); see Note 1 27UV1P =
Undervoltage 1 Time Delay (0.00-16000 eye) 27UVID =
Undervoltage 2 Pickup (OFF, 50-100%); see Note 1 27UV2P =
Undervoltage 2 Time Delay (0.00-16000 eye) 27UVID ;;;
Overvoltage 1 Pickup (OFF, 50-144%); see Note 1 S90V1P =
Overvoltage 1 Time Delay (0.00-16000 eye) 590VID =
Overvoltage 2 Pickup (OFF, 50-144%); see Note 1 590VZP ;;;
Overvoltage 2 Time Delay (0.00-16000 eye) 590V2D =
Frequency Element Settings (device 81; 4 elements)
Undervoltage Block Pickup (50-100%); see Note 1 27BLKP =
Over-and Underfreqnency 1 Picklrp (OFF, 40.1-69.9 H.:) 810l11P =
Over-and Underfrequency I Time Delay Gi.00-1 0000 eye) 810U1D =
Over-and Underfrequency 2 Pickup (OFF, 40.1-69.9 Hz) 810U2P =
DatG Code 20080922 User's Guide SEL-547 Relay
2 of 41 SEL-547 Relay EZ Settings Sheet. Date. ___ _
-SEL-547 Relay
Over-and Undetfrequency 2 Time Delay (5.00-16000 eye)
Over-and Underfrequency 3 Pickup (OFF, 40.1-69.9 Hz)
Over-and Underfrequency 3 Tune Delay (5.00-16000 cyc)
Over-and Underfrequency 4 Pickup (OFF, 40.1-69.9 Hz)
Over-and Underfrequency 4 Time Delay (5.00-16000cyc)
810U2D = ----------
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 Note 1
Maximum Slip Frequency (0.1-0.5 Hz)
Maximum Angle (2-60 degrees)
User's Guide
25DIFP = ------------------
25SLP = ------------------
ZSANG
Dale Code 20080922.
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 15
Laura Knothe, PE
The New Energy Company
8720 Vic Lane
Middleton, ID 83644
Re: Swager Farms-Project# 307
Dear Laura:
October 19, 2009
®
An IDACORP Company
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 information to our OASIS (Open Access Same
Time Information) website. Please refer to the website periodically to view a list of current
projects at http://www.oatioasis.comfll>CO!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/ About U s/BusinessToB usiness/Generationlntercollllect/ default. cfin
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,
R~~B~sf::{J
Operations Analyst
Ph 208-388-2658
Idal1o Power Company's Requiren1.ents for Generation Interconnection
Standard Interconnection Feasibility Study Agreement
Cc: Marc Patterson/IPC (via email)
1221 W. Idaho St. (83702)
P.O. Box 70
Boise, ID 83707
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 16
Sma11 Gen Feasibility Study Agreement
Swager Farms Project# 307
Feasibility Study Agreement
THIS AGREEMENT is made and entered into this_2l_day of Dc-+-che v-2009 by and
between ..0 l.LQ_ a_-----=-=L=L=C.-=--------
organized and existing under tate of -T do b (,'\, ,
("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 11Party," 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# 307; 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 torth 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 lnterconnection 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
Intercoru1ection 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
Swager Farms Project# 307
5.0 In performing the study, the Transmission Provider shaH 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 rep01i 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;
I
6.3 Initial review of grounding requirements and electric system protection; and
6.4 Description and non-bonding estimated cost of facilities required to interconnect
the proposed Small Generating Facility and to address the identified short circuit
'and power flow issues.
7.0 The feasibility study shall model the impact of the Small Generating Facility regardless
of purpose in order to avoid the further expense and interruption of operation for
reexamination of feasibility and impacts if the Interconnection Customer later changes
the purpose for which the Small Generating Facility is being installed.
8.0 The study shall include the feasibility of any interconnection at a proposed project site
where there could be multiple potential Points of Interconnection, as requested by the
Interconnection Customer and at the Interconnection Customer's cost.
9.0 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 yharge 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
Swager Farms Project# 307
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 ~f1:.C./lg
Printed &fa trc f?d-/e YSor......
Title eh~i 1/>eenhj f-R~eJe r
Date I o/:z.:r /d1
Interconnection Customer:
""fbe f)e,"J t=De'=-g~ C(-¥Uf4-r::JJ LLC..
Signed~.< PE.
Printed la..u,~rcx_ k. no-±be P (;
Title HCUh~ ~ Pa.chuA
Date lo 1-:l-., lo1
Page 3 of3
Small Gen Feasibility Study Agreement
Swager Farms Project# 307
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 I c... I ::>...'7 I o 4
1) Designation of Point of Interconnection and configuration to be studied.
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-12-25
IDAHO POWER COMPANY
ATTACHMENT 17
)
I
GENERATOR INTERCONNECTION
FEASIBILITY STUDY
for integration of the proposed
PROJECT #307
to the
IDAHO POWER COMPANY ELECTRICAL SYSTEM
for the
INTERCONNECTION CUSTOMER
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 #307). The location of the project is in Idaho Power1s Southern
Idaho service territory in Twin Falls County, Idaho.
This report documents the basis for and the results of this Feasibility Study for the Generation
Interconnection Customer. It describes the proposed project, the study cases used, the impact of
associated projects, and results of all work in the areas of concern.
2.0 Summary
The proposed project is a 1.2 MW biogas generation project consisting of two 600 kW
synchronous generators. The proposed Point of Interconnection (POI) for the generating facility
with the IPCo system is in Twin Falls County, Idaho at the 12.5 kV distribution level.
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 upgrades to this feeder needed to connect this project include a capacitor bank installation,
as well as a generation interconnection and protection package. The estimated cost to
interconnect this generation project to Idaho Power's system is $234,800.
3.0 Scope oflnterconnection 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-
II
All other proposed Generation projects prior to this project in the Generator Interconnect queue
were considered in this study. A current list of these projects can be folllld on the Idaho Power
web site as follows:
http://www.oatioasis.com/ipco/index.html.
4.0 Description of Proposed Generating Project
Project #307 proposes to connect to the IPCo distribution system for an injection of 1.2 MW
(maximum project output) using two 600 kW synchronous generator.
5.0 Description of Existing Substation Facilities
The distribution substation that serves this area is located approximately three and a half miles
south and east of the POI. The existing substation transformer is a 46: 12.5 kV transformer that
has adequate capacity for this project.
The associated feeder breaker at the substation is rated for use at 12.5 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 12.5 kV. There is
adequate capacity on this feeder to serve this project. However, the project will have to run at a
power factor between 90% and 98% lagging when at full output. In other words, the generation
facility will have to absorb between 240 kVAR and 580 kV AR when operating at full output
(1200 kW) throughout the year.
A capacitor bank will have to be added for compensation pwposes due to the facilities lagging
power factor. Since it will be running at a max power factor of 90%, 600 k V AR will need to be
produced. That V AR flow will come from a 600 kV AR capacitor bank located a couple spans to
the west of COVR substation. This location eliminates high voltage concerns which would have
become an issue if the bank were placed closer to the POI.
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
~3-
The transmission line that serves this area is a 46 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. However, high voltage becomes a
problem during periods of light loading (fall and spring). To avoid this problem the generators
will need to lag at a 90% power factor at these times. In the summer and winter the generators
can lag up to a 98% power factor as indicated previously.
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 $234,800. These upgrades are listed in the following Table.
Description Estimated Cost
600 kV AR capacitor bank $9,800
Generation Interconnection Protection Package
(Includes 12.47 kV recloser, controls, CTs, PTs, and
communications) $225,000
Total Estimated Cost $234,800
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 8.0 of this report, the proposed project must meet
several operating requirements. The project must be controlled to operate at a lagging power
factor of90% during the fall and spring months and between 90% and 98% during the summer
and winter months or meet the voltage schedule provided by Idaho Power. 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 46 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. The project must also limit the ground fault current at the
point of interconnection to 20 Amps. See Appendix A for more details
-4-
)
10.0 Conclusions
The requested interconnection of project #307 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.
-5-
APPENDIX A
A-1.0 Method of Study
The Feasibility Study plan insects 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 determirie 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 intercOimection, per Idaho Power's T &D Advisory Infonnation 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.
AU other applicable national and Idaho Power standards and prudent utility practices
were used to determine the acceptability of the configurations considered.
The stable operation of the system requires an adequate supply of volt-amperes reactive
(VARs) to maintain a stable voltage profile under both steady-state and dynamic system
conditions. An inadequate supply ofVARs will result in voltage decay or even collapse
under the worst conditions.
-6-
II
/ Equipment/line/path ratings used will be those that are in use at the time of the study or that are
represented by !PC upgrade projects that are either currently under construction or whose
budgets have been approved for construction in the near future. All other potential future ratings
are outside the scope of this study. Future transmission changes may, however, affect current
facility ratings used in the study.
A~3.0 Grounding Guidance
Idaho Power Company (IPC) requires interconnected transformers to limit their ground fault
current to 20 amps at the point of interconnection.
A~4.0 Electrical System Protection Guidance
IPC requires electrical system protection per Requirements for Generation Interconnections
found on the Idaho Power Web site,
http://www.idahopower.com/aboutus/business/generationlntercmmect/.
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 Coord.inated Off-Nominal Frequency Load Shedding and
Restoration Requirements available upon request.
-7-
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 18
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-12-25
IDAHO POWER COMPANY
ATTACHMENT 19
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 IDACORP Company
-.... _ ....
----•!-------~---~-
-~-----~-~----~------·--
Randy C. Allphin
Sr. Energy Contract Coordinator
Tel: [phone]
[e-mail]
Swager Farms 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, lduho 83702
2.) Received and accepted an intercmmection 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.) Confinnation 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 Resomce Integration
Study Agreement in the fonn 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 firm 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 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 intercollllection 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 finn 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 Transmission
Capacity Application Questionnaire).
After filing a complete finn 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 determine 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.
Page2of4
P 0 Box 70 Boise, Idaho 83707 I 22 I 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 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 pmsuit of transmission capacity, the
project will also be responsible for ali 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 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 wiH
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 83707
E-mail: [e-mail]
Sincerely,
({f.~·
Randy C Allphin
Idaho Power Company
Understood and accepted this __ day of _______ __, 2010
Signature
Print Name
Title
Page 4 of4
P 0 Box 70 Boise, Idaho 83707 1221 W Idaho St. Boise, idaho 83702
M IOACORP ComParlV
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
Puge 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.
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.
TransmissionProvlder(s)Name ______ '---------------------
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 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 0 No 0
V. Is any portion of the maximum capacity identified for this project committed to any other party?
Yes D No 0
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
Delivery to install
Company's Schedule 72
.,w~~· ~~!~~t. 1: \I J ~,1 -~·"·""'·"'·· classified as a DNR and for Idaho Power to 'l[fl\ii] ''I~
QF on a firm basis, a network resource
must be performed by Idaho Power's delivery
SIS will identify the need and associated costs for
ng "upgrades" (as that term is defined in Idaho Power
allow the QF to operate as a DNR and deliver firm energy
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 of the
3. cuted by Developer, payment of the
required to enable Power Supply to
d ce the SIS. Subject to Developer's providing
any requested supplemental payments in a timely
the SIS with due diligence. Power Supply will respond to
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.
IN WITNESS WHEREOF, the Parties have ..r&~~sed this Agreement to be ~/ ~·~
executed effective on the first day written above. , -·''1
.
NETWORK RESOURCE INTEGRATION STUDY AGREEMENT-3
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 20
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 IDACORP Company
Randy C. Allphin
Sr. Energy Contract Coordinator
Tel: {208) 388-2614
[e-mail]
Swager Farms 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 defmed by the Public Utilities Regulatory Policies Act of 1978
(PURPA). 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 intercolUlection
and is in compliance with any payments and/or other requirements specified in the
Interconnection process for this project and;
Page 1 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 firm 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 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 ftrm 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 Transmission
Capacity Application Questionnaire).
After filing a complete flllU 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 determine 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.
Page 2 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 Integration Study Agreement will specify that the project will be responsible
for costs incWTed 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 above described transmission capacity upgrade
process, a transmission capacity reservation will exist for this project. However, in
order to fmalize 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.
Page3 of4
P 0 Box 70 Boise, Idaho 83707 1221 W Idaho St. Boise, Idaho 83702
Please return all required infonnation to:
Idaho Power Company
Attn: Randy C. Allphin
P0Box70
Boise, ID 83707
E-mail: [e-mail]
Sincerely,
({f.~·
Randy C Allphin
Idaho Power Company
Understood and accepted this j_ day of__....::;A->t<-poL..;-.__.I ___ __,, 2010
Signature
Print Name
Title
Page4 of4
P 0 Box 70 Boise, Idaho 83707 1221 W Idaho St. Boise, Idaho 83702
An IIIACOAP torllpa'lV
Transmission Capacity Application Questionnaire
This fist Is the known information requirements as of the date of the letter transmitting this request. If add/tiona/Information
is required, Idaho Power will promptly notify the project developer of the additional information requirements.
A. Project Name
8 wa3er Dcu: reb , De 6-fBk r
B. Project Location
llol F B.. b.A..
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
~;;~~~i ~~~$ CI0-~~1tfp~
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) l, '2.. M.vJ
Page I of3
H.
I.
J.
Beginning day and time of energy deliveries
Day (mrn/dd/yyyy) $\ \ I a 0 l \
Time 1$~ 00 Clt ffi
Ending day and time of energy deliveries
Day (mm/ddtyyyy) 12\ \ \ 4-0Glle
Time 6 ~ 06 ~ ro
VAR capability (both leading and lagging) of all generators 1 q ~ lf(J._J~S 1 • fS(o..~
K. Identification of the control area( s) from which the energy will originate
~=~-h;! :~;~.:f~o :-if!:.ha fg ~
L. List any periods of restricted operations throughout the year
t'
-0 0':0 C! ... CMI\ =-b r ; pc< r ...R cl,
M. Maintenance schedule
N. Minimum loading level of each generation unit ___ _.::f.o:!:::..:=0:::...0....L.{_~..oL._ _______ _
0. Normal operating level of each generation unit. --.....l/_0.::...:=0:::...0+1-60~.-_______ _
Page2 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.
{)at (lqpS,ol"rr-Pcl va.t ,a.bl..e jentLrrJ"'~·
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 _:Q-1--.J..!A'-'------------------------
PolntofRecelpt ____________________________ _
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 D
Physical Location n 0 1 £. 3 <oOO [\)
Voltage \ d . 5 \:_ V
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~ NoD
V. Is any portion of the maximum capacity identified for this project committed to any other party?
Yes D No r:::J/
Signature ~c-~~' --'-~=--===---Date ----'-'-/ -'-/l-+-{--=--s.-o---=--t _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
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-12-25
IDAHO POWER COMPANY
ATTACHMENT 21
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
8720 Vic Lane
Middleton, ID 8366
Phone: [phone]
Fax: [phone]
E-mail:
[e-mail]
. I
Facilities Study Agreement
TIDS AGREEMENT is made and entered into this 2nd day of April, 2010 by and between
_The.New Energy Company, LLC_, a Limited Liability Company_ organized and existing
under the laws of the State of . .. Idaho. ("Interconnection Customer,11) 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 ofsaid 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 conc~usions of the system impact study in
accordance with Good Utility J>ractice 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 Provid~r· shall cause a
facilities study consistent with the standard Small Generator Interconnection Procedures
to he performed in accordance with the Open Access Transmission Tariff.
3.0 The scope of the facilities study shall be subject to data provided in Attachment A to this
Agreement.
4.0 The facilities study shall specify and estimate the cost of the equipment, engineering,
procurement and construction work (including overheads) needed to implement the
conclusions of the system impact study(s).
The facilities study shall also identify (1) the electrical switching configuration of the
equipment, including, without limitation, transformer, switchgear, meters> and other
station equipment, (2) the nature and estimated cost of the Transmission Provider's
I
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 ofthosefacilities.
6.0 A deposit of $11,740.00 is due upon execution of this agreement by the Interconnection
customer.
7.0 fu cases where Upgrades are required, the facilities study must be completed within 45
Business Days of tlle receipt of this Agreement. In cases where no Upgrades are
n~cessary, and the required facilities are litnited to Interconnection Facilitie$, 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 tran~J;D.itted within 30
Business Days of the futerconnection 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 futerconnection 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&/ &.-,~
PrintedName: 6u!AI?JP ~~~'tt>lrg_
Title: PM .Su~E/Ltl!.S'Ito f,
4/t~/ra
Interconnection Customer:
Signed:~
PrintedName: ~ ~vw+h, P{;;
Title: _f+Yi.:...l~~·b.:e c~i~~~-~~,__.==--
J
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 IPT maintenance?
Yes No NA
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 3900 N 1700 E
, I
9. Bus length from generation to interconnection station:
__________ TBD ________________________________________________ ~~
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 ease:ments 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 servic.e area?
Yes --=.:x'--__ No _____ lfNo, please provide name oflocal provider:
14. Please provide the following proposed schedule dates:
Begin Construction
Generator Step-Up Transformers
Receive Back Feed Power
Generation Testing
Commercial Operation
Dme: __ ~1=0/~1/=2=0=10~------------
Date:
4/15/2011
Date: ----=5/~1=5/-=2_,_01~1,_ _____ _
Date: __ ...;:8:!....:/1=/2=0"-"1'""'"1 __________ _
Project #307 Swager Farms
_. Clover Substation * POl e Capacitor Bank Addition
--COVR12
--46kV Transmission Line
--Roads
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 22
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
[e-mail]
joe.mcdevitt-miller.com
Re: Swager Fanns Digester, Project #31616130
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 10
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 Swager Farms 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 PURPA 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)
1??1 W ltl:>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 JPUC 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 (JPUC) 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 83 707
Overnight Mailing Address:
Idaho Power Company
Attn: Randy Allphin
1221 Widaho
Boise, ID 83 702
This agreement as with all PURP A purchase power agreement will require Idaho Public Utilities
Commission (JPUC) approval. Only after both parties have executed this agreement and the IPUC
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,
/?;f.~-
Randy C. Allphin
Senior Energy Contract Coordinator
[phone]
E-mail: rallphin@idahopower .com
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 23
August 17, '1010
Laura Knothe
The New Energy Company
8720 Vic Lane
Middleton, ID 83644
Re: Swager Farms Dairy Digester Project Facility Study Report -Project #307
Dear Ms. Knothe:
An IDACORP Company
Idaho Power Company (IPC) has completed the Facility S,t dy c.ost estim te for your Generator
Interconnection project. Attached please fmd a Draft Facility Study Report (PSR). I am
available to discuss the FSR, and begin Construction ·arrangements for the project.
In order to proceed with this project, please provide your comments to the Facility Study Report
to me by September 17, 2010 and indicate whether you wlsh to proceed with final design and
construction. The fmal report will be us~d to prepare a draft Generator Interconnection
Agreement in preparation for Construction. Rowena Bishop will be working with you to fmalize
the Interconnection Agreement.
Before we can begin Construction or order rna erials you are tesponsible for contacting Idaho
Power's credit departmen to cliseuss credit requirements for ·epnstruction funding. Please
contact Kelley Noe (208-38.8-5736} at your earlie t convenience. Once we receive funding, or
the credit Tequirement is et, we can proceed with c;on truction of the project.
The actual construction and litbor eharges w.ill.be finalized approximately 90 days subsequent to
project completion. We will reconcile any·ovet-or underpayment at that time.
I look forward to hearing from you soon.
Sincerely,
Eric Hackett
Project Leader
Attachment: Swager Farms Dairy Digester Project Draft Facility Study Report with Drawings
Cc: R Bishop/IPC
KNoe/IPC
A Sloan/IPC
DRAFT
Generator lnterconneQ'tion
Facility Study J{ep0rt
for lihe
Swager Farms Dairy Digester Proj;eet -Project #307
An IDACORP Company
DRAFT-FACILITY STUDY REPORT (FSR)
Swager Farms Dairy Digester
Project #307
August 17, 2010
1. General Facility Description
The proposed project will consist of Idaho Power's standard overh~ad 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 transform · w,nl be installecJ, including the associated
underground cabling and vaults. The project is locat;ed Twi n Falls County, Ida,ho and connects to
the 12.5 kV system on Idaho Power Company's @lover (CL:YR-012) distributldn 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 nte ·G<;)nn ction Agreement under r1::litho Power Company's Open Access
Transmission Tariff (OATT) or phedule 72 be'ftWeen Interconnection Customer and Idaho Power
Company -Delivery ~'FJ;ansrnis ion Owner) f6).; the Swager Farms Dairy Digester Project,
specifically Generator nterco · eal}i~n Project #3,07, will be prepared for this project. Final
drawings will1be pr9duced in•WJe · elin he~b below in MILESTONES.
~)
2. Interconnection Point ... The'"lniei·b~nnection Poinf.}'6r the ~Sw.ager Farms Dairy Digester Project will be the low-side
bushings on·the' padmounted'transformer (SW1). The project's location is in TlOS Rl5E Section 21
of Twin Falls 'Gounty, Idaho. A drawing identifying the Point of Interconnection is attached.
3. Point of Change of Ownership
The Point of Change of Ownership for the Swager Farms Dairy Digester Project will be the low-side
bushings on the padmounted transformer (SW1).
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:
-··--·-"-Senior Engineer
En ~in_e_er_--J~.r.s>J:.ect_io_n_ ........... -------1-M-~~e~ing Technical Advisor
1 Area Ap~atus Leader._ R~_ght ofWay .. ~e._n.t --···-.. -----I
I Design Engineer Distr~~ution ~iti~()Sesigner ------1
r-::----;'s · D · · tatlons est ner
4.2 Customer's Interconnection Facilities
switches, all
feet of the
4.3 Other Facilities Provided by
4.3.1
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
Swager Farms 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 (CLVR-012) on private property southwest of the intersection of 3800
North and 1700 East in Twin Falls County, ID. See the attached work order maps (WO
27328106, sheet 1 of2) 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 enclesure 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) oQ.~-,1500 kVA 277/480 to
12.47 kV Grounded Wye I Grounded Wye :;padmounted transfor~er .. on top of a vault.
Conduit and underground cables will be ~ installed from the intercohiiection package to
)\. -, •• · !~· ' ~--~·
padmounted transformer. Protective posts wi}l,.,be installed to protect the. ground mounted
equipment from damage. '· · ·' ·
A 2" conduit will be installed alo.ngs~de the undergrotina'primary to facilitate information
exchange to the customer about tlie recloser. (The Interconilectign Customer is responsible
for providing and installing the appropriate cable.) . '
4.5 Scope of Upgfaaes
Idaho Power ~iil;.J.install anew capacitor B~nk on the existing distribution feeder (CLVR-012)
just west of_Jh~:i,#~ting Clo~:er Substation; ~ee the attached work order maps (WO
27328106, sheet~2 ;~1:~) for d~tails. ~
' l.
The projec~·wpst be controlled to operate at a lagging power factor of 90% during the fall
and spring months and between 90% and 98% during the summer and winter months or meet
the voltage schedule provided by Idaho Power. 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 46 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
5. Budget
The following good faith estimates are provided in 2010 dollars:
Estimated Cost & Ownership:
and 1500 kVA Transformer
Milestones:
GRAND TOTAL
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01

BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 24
~WESTERN ., STATES
Spokane,WA
509-535-17 44
Western States Equipment Company
500 East Overland Road
Meridian, 10 a3642
208-888-2287loffice)
208-884-2308lfax)
Reference: Swager Farms
LETTER OF GUARANTEE
Subject: · Financial guarantee for the payment of Liquidated Damages payable under the Firm
Energy Sales Agreement for Swager Farms, Project Number 31616130.
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 Swager Farms, Project Number 31616130 (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 "B". 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 made 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
406-721-4050
Lewiston, ID
208-746-3301
Kalispell, 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-12-25
IDAHO POWER COMPANY
ATTACHMENT 25
September 16, 2010
Laura Knothe
The New Energy Company
8720 Vic Lane
Middleton, ID 83644
I MHO POWER®
An IDACORP Company
Re: Swager Farms Dairy Digester Project Final Facility Study Report -Project #307
Dear Ms. Knothe:
Idaho Power Company (IPC) has completed the Facility Study cost estimate for your Generator
Interconnection project. Attached please find the 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 fmalize 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: Swager Farills 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
Swager Farms Dairy Digester Project-Project #307
for
The New Energy Group
in
Twin Falls County, Idaho
September 16,2010
FINAL-FACILITY STUDY REPORT (FSR)
Swager Farms Dairy Digester
Project #307
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 Twin Falls County, Idaho and connects to
the 12.5 kV system on Idaho Power Company's Clover (CLVR-012) 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 Swager Farms Dairy Digester Project,
specifically Generator Interconnection Project #307, 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 Swager Farms Dairy Digester Project will be the low-side
bushings on the padmounted transformer (SW1). The project's location is in T10S R15E Section 21
of Twin Falls County, Idaho. A drawing identifying the Point oflnterconnection is attached.
3. Point of Change of Ownership
The Point of Change of Ownership for the Swager Farms Dairy Digester Project will be the low-side
bushings on the padmounted transformer (SW1 ).
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:
Project11anager Senior Engineer ! !
Principal Engineer Relay & Communications Leader
Engineer -Protection 11etering Technical Advisor --...
Area Apparatus Leader Right of Way Agent
Design 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
Swager Farms 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 (CLVR-012) on private property southwest of the intersection of 3800
North and 1700 East in Twin falls County, ID. See the attached work order maps (WO
27328106, sheet 1 of2) 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-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.)
4.5 Scope of Upgrades
Idaho Power will install a new capacitor bank on the existing distribution feeder (CLVR-012)
just west of the existing Clover Substation. See the attached work order maps (WO
27328106, sheet 2 of2) for details.
4.7 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 a lagging power factor of 90% during the fall
and spring months and between 90% and 98% during the summer and winter months or meet
the voltage schedule provided by Idaho Power. 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 46 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
5. Budget
The following good faith estimates are provided in 2010 dollars:
Estimated Cost & Ownership:
ltfY-;·ln-Jtl;..,~~·~,f :..•:1'' ·:.-:.• ""I ,,;,; :;•~ }:~.f:.'l~~mi~JJeil~ "' ...... :~~-~f-.t~·.:u .. Z!..!,·.t~:-d!:t~i!ito"TIWw~·2!J·~!J;.t':?!,!. ~ 'i .. rsh s
Generation Facilities:
~rovided by the customer (Including low-side d~.~~onnect switch) Customer N/A -· TOTAL N/A
~,Interconnection Facilities:
i--· I
!Overhead Generation Interconnection Package IPC $200,000
!underground Equipment and 1500 kVA Transformer PC $60,000
l TOTAL $260,000
!upgrades to Distribution: ~-· .
lrPC
--·
!New Capacitor $30,000
TOTAL $30,000
GRAND TOTAL $290,000
Milestones:
., I , " ' • • :~,(,.H'i I "' ,,·:,, .J1bl4?i0~ ·. ' ... ~ .. , I o " -..... •' ' ·~ ,. 'I •
09/16/10 Final Facility Study Report Submitted to Customer
10/17110 Construction Funds Received by /PC
11/5/10 Order Materials
3/15/11 IPCO Construction Completion
4/1/11 IPCO Test and Commission Equipment Completion
TBD Commercial Operation
Construction Budget Timeline:
Feb 2010 -April2011 $290,000
$290,000 ~------------------~---------------------------GRAND TOTAL
4
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 26
I •
Laura Knothe
The New Energy Company
8720 Vic Lane
Middleton, ID 83644
October 25, 2010
Via email &
®
An IOACORP Companv
Certified Mail # 7006 0810 0006 5511 2990
Re: Swager Farms 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 of the 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 project 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 (8370"7)
1221 \11/. 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 of business 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 pToceed with the project,
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 /IPC
Rich Bauer/IPC
Jill Sprenger/IPC
Randy Allphin/IPC
Sincerely,
&1J~o~
Operations Analyst
[e-mail]
ph 208.388.2658
Idaho Power Company Generator Interconnection Agreement# 307
I.P.U.C. No. 29 Tariff No. 101
October 25, 2010
Idaho Power Company Generator Interconnection Agreement# 307
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. T arms 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. .............................................. ,_. -:·.~f-:;~ ......................................... 2
6. Assignment. Liability, Indemnity, Force majeure. Consegh E;(jt(a/ Damages and Default. ...... 5
7. Insurance ................................................................. ,~4[{;"':( .. :X~~j;-..................................... 7
8. Miscellaneous ...................................................... · .... ~k'~ ............ :C:i-1?:-•................................. 7
9 N t. 1.26"-"'~'%;~ :-8 . o rces. . . . . .. . .. . . . .. . . . . . . . . . ... . . . . . . .. . . .. .. . . .. . .. . .. . . . . ... ... ·.-:r .......................... · · · . ·. ·. · · .. · · ·· · · · · ·· · · · · · · · · · ·· 1 o s· t ,} .• ~ .-·· ·t&~ 9 . rgna ures ................................................... -;.ft ~_,: .............................. ~~?;_£~~"~:············· .. ···:····
Attachment 1 ....... .... .. . .... ..... ....... ........ ..... .... ... ....... .... . '· r: ...................... Error! Bookm~rk not defmed . . ~,..,, ._. /_L
Attachment 2 .......................................................... !-):!{!.:' .................... -., .. Error! BookMf;Jif\_not defined.
Att h t 3 w.;z,r-. ·· £~ / ·?:· E I B k· . >tl~?. t d f' d ac men ............................................................... ---.'·;--........... , ~ ·f·.·.. rror oo mar"" no e 1ne •
Attachment 4 ......................................... -....................... ~~-•... i d.1f'~.~ ... Errorl Bookmark not defined.
:-o'"J"'; 7/"/. '<I 4)' Attachment 5 .................................................................... ~{ J: '(>:: ......... Error! Bookmark not defined.
Attachment 6 ........................................ :4-1 :;;~ :/ _ .•...•.•••......... ~~;. .• _ ......... Error! Bookmark not defined.
v1tJ;• ''~p~ %).{:~·' ?.4• >:W,f'?ffpa-, .; 'Z' ,. •i:.~« . ;~,#'~.-:-"'•¥ ,t/ -r~ · ~bK-'~ ./,;f.·h . . ;~-. --~ l"/,, . :,~?:'!-, .
. -~.t~!f~h .,~~~~4~~y~~~/ -"i1'·-~·"'·· ~-~~r" "'~a-, .', , .. ~, ,,;;:;;;.;.~; ~~ ·''" y.:· ··'diP /:'(./~:·. . /" (•··· . .
n'c;,;;•,;;. ::."!'.' -~. ~ ... ~d-:: t;y.~ ~~~-~ ,, ... .. ·z·,-
4 4;) ~~ -~>~~.(. . ·< .. ;.~:~, ,,,__, ~":/.:!".-:• .. ,P:;, _ _,_ -·~~~"-'J:-:t.;';<Y·Yjf;·}f. !:]!,·-,. ~[£~ ~ 1'~1--./Y:f'·· · ~-.'(f~(_fix~~~~ -~v ., ":t;; --z;~:e-? --~· '"·:.-w>@, · ~"'--~;;(~)'-... -~'11/~~~y f. .. ~;~~~ . ,'1'$''
·-;:ff7t~ -.:·'::!!.,-. ~1-¥-.. ·~·~h}t·· ,.,,_~·f·. '(}'/~-. ·~· , .. /. ·;r.p;/
Idaho Power Company Generator Interconnection Agreement# 307
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
A. Seller will own or operate a Generation Facility that
Power's Commission-approved Schedule 72 and any successor
B. The Generation Facility covered by this
Attachment 1.
AGREEMENTS
1. Capitalized Terms
Capitalized terms used herein shall have the ~~n.,a.".r.
of this Agreement.
2. Terms and Conditions
This Agreement and Schedule 72
Seller's Generation Facility will ,..,#..,_,.,..,..,
transmission/distribution system. Terms
this Agreement. If there is any conflict
Schedule 72 shall prevail.
3.
for service under Idaho
and conditions under which the
parallel with, the Company's
the same defined meaning in
u~~[_,n~•~rnBnl and Schedule 72,
may require will be covered under separate
to affect any other agreement between the
and Costs of the Generation Facility, Interconnection
Diagram Depicting the Generation Facility, Interconnection
,,,,.;)="'•n and Upgrades.
For Interconnecting the Generation Facility.
A -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# 307 ·
I.P.U.C. No. 29. Tariff No. 101 Page 2 qf 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
Section 6. 5.
5.2.3 Upon termination or expiration of
Facility will be disconnected from the
termination or expiration of this Agreement shall not relieve
and obligations, owed or continuing at the time of the ranrrur•<=>nn•
Section shall survive termination or expiration of this Agreement.
Agreement pursuant to
the Seller's Generation
ution system. The
of its liabilities
provisions of this
5.3 Temporary Disconnection. Temporary disconnection shall only for so
long as reasonably necessary under "Good Utility Practice." Good Utility Practice means any of
the practices, methods and acts in or approved by a significant portion of the electric
industry during the relevant time any of the practices, methods and acts which, in the
exercise of reasonable judgment facts known at the time the decision was made,
could have been expected to result at a reasonable cost consistent with
good business practices, reliability, Good Utility Practice is not intended
to be limited to the optimum practice, of all others, but rather to
be acceptable practices, methods, in the region. Good Utility
Practice includes compliance with Payment of lost revenue
resulting from temporary disconnection governed by the power purchase agreement.
5.3.1 Condition" means a condition or
situation: (1) that in the judgment of making the claim is imminently likely to
life or property; or (2) that, in the case of the Company, is imminently likely (as
in a non-discriminatory manner) to cause a material adverse effect on the
or damage to the Company's transmission/distribution system, the
"'"'""'""'''""'" Facilities or the equipment of the Company's customers; or
case of the Seller, is imminently likely (as determined in a non­
to cause a material adverse effect on the reliability and security
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 Interconnection Agreement# 307
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 The Parties determination as to the
acceptability of the Seller's timetable maintenance will take into
consideration Good Utility Practices, system requirements and the Seller's
preferred schedule. Neither Party withhold acceptance of the
proposed maintenance schedule.
5.3.4.
extent practical, coordinate their
Generation Facility maintenance schedules
shall provide and maintain adequate nrr•ro.~r"''""
to the Generation Facility and Seller-furnished
some of Seller's protective relays will provide
facilities. In Idaho Power will test such
actual cost testing.
During any forced outage, the Company may suspend
effect immediate repairs on the Company's
The Company shall use reasonable efforts to provide
is not given, the Company shall, upon request,
after the fact explaining the circumstances of
5.3.6 The Company shall notify the Seller as soon
Good Utility Practice, operation of the Seller's Generation
Facility may cause 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 # 30:r' ·
I.P.U.C. No. 29. Tariff No. 101 Page 4of9 '
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 level by more than
ten percent (10%) at the Point of Delivery, in which shall modify, at Idaho
Power's expense, Seller's equipment as accommodate the modified
nominal operating voltage level.
5.4 Land Rights.
5.4. 1 Seller to Provide Access. Seller hereby grants
term of this Agreement all necessary rights-of-way and 0 "'''"""'.an
maintain, replace, and remove Idaho Power's Metering L..l.f'''J'"''
Equipment, Disconnection Equipment, Protection Equipment and other Facilities
necessary or useful to this Agreement, including adequate and continuing access rights
on property of Seller. warrants that it has procured sufficient easements and
rights-of-way from third as to provide Idaho Power with the access described
above. All documents easements or rights-of-way shall be subject to
Idaho Power's approval
5.4.2 agree that it is necessary to
avoid the adverse that would occur as a result of
duplicate electric Jines being in close . Therefore, subject to Idaho
Power's compliance with 4, Seller agrees that should Seller seek and
receive from any local, state or body the right to erect, construct
and maintain Seller-furnished Facilities upon, along and over any and all
public roads, streets and highways, the use by Seller of such public right-of-way
subordinate to any future use by Idaho Power of such public right-of-way for
and/or maintenance of electric distribution and transmission facilities and
claim use of such public right-of-way for such purposes at any time.
by Paragraph 5.4.4, Idaho Power shall not be required to
for exercising 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
Interconnection Facilities, may reconstruct Seller's Interconnection
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 Interconnection Agreement# 307
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. Uabilitv. lndemnitv. Force majeure. Consequential Damages and Default.
6. 1 Assignment. This Agreement may be assigned
(21) calendar days prior written notice and opportunity to
Party upon twenty-one
y the other Party; provided
that:
6. 1. 1 Either Party may assign this
Party to any affiliate of the assigning Party
the legal authority and operational ability
the consent of the other
rlilrea!ter credit rating and with
the assigning Party
under this Agreement.
6.1.2 The Seller shall Agreement,
without the consent of the Company, 1Ql~.()/181Cer-al -'~ts"~,(Jril'" purposes to in providing
financing for the Generation Facility, Seller will promptly notify the
Company of any such
'"'-'l'l'-'"'p this article is void and ineffective.
obJif!JaltielrJm~nc)r shall a Party's obligations be
c::r.,., ... ""''-'"'"' is responsible for meeting
::f}~~~~~ the Seller. Where required,
conditioned or delayed.
liability to the other Party for any loss, cost,
.C!,.,,.,~n'"" attorney's fees, relating to or arising from
shall be limited to the amount of direct
·an;,,.,ar Party be liable to the other Party for any
except as authorized by this Agreement.
protects each Party from liability incurred to third parties as
provisions of this Agreement. Liability under this provision is
limitations on liability found in Article 6. 2.
Parties shall at all times indemnify, defend, and hold the other Party
any and all damages, losses, claims, including claims and actions
to or death of any person or damage to property, demand, suits,
· 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 # 307 ·
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 leg~· if!: 'f_oceeding or investigation
as to which the indemnity provided for in this article mq,fA~ -Jfiy, the indemnified person
shall notify the indemnifying party of such fact. Any fffj,ltf.¥f or delay in such notification
shall be a Material Breach and shall not affect a P9fi~ff4/:j}f~mnification obligation unless
such failure or delay is materially prejudicial to th,eft,·. · mritfiJ.n,g party . . ·~t.~ "~~f
6.4 Force Majeure. As used in this JM!I/4iment, "Forc;-~~9_ure" or "an event of
Force Majeure" means any cause beyond the pi!J1t/ol of the Seller or ({f{t]JJg Company which,
despite the exercise of due diligence, such..,P.'~J!_y is unable to prevent 61ft§Mercome. Force
Majeure includes, but is not limited to, act~(£ God, fire, f/gQd, storms, wii~Jl/lstilities, civil
strife, stri~es and other lab~r disturba~ces, eartlfil~;~kes, fi)~~~Jghtning, ~pidemuillsabota¥e, or
changes m law or regulatton occumng after rK'4'f;:9[!~!:?.{!¢H Date, whtch, by the exerctse of
reasonable foresight such party C?Jt..ld not reasonlfiJ!~~!Jl··~ been expected to avoid and by the
exercise of due diligence,_ it sha(11/ff.tf1221e to ov~rcclf«(!z'! either Party is rendered wholly or in
part unable to perform tts obltga l§lfs~cjgJ; thts AgreefiJ~J!f because of an event of Force
Majeure, both Parties shall be exc1 ,.,w lfilifr#...< . ..tJJever peffefiJI.ance is affected by the event of
Force Majeure, provided that: ' -~·~-·-;~}·~-/¥~. ~ /.~~f.:,_ ~/
(1) ~--~fJ!!)-~performt~EJIJ .. ~shall, '{f! ~ff0n as is reasonably possible after
the occuwJf{~~f thj-;_~1ce Majet{fitf'give the othef Party written notice describing the partie~!.~~ ffli the occui{f4,pe. ~-. ·¥~ -~)J ~-:s, ':7,:?!> ·.z..,-• .r.;;&-(g.J\ __ The ~t(pjliJ~!PJ?,p_f peff9!PJ,ance shall be .of no greater scope and of no
long.er du at[ptl.,~~ ~f{(Jfr.fi.tfJ!l?:;tbfl. &~nt of Force MaJeure .
. ;4?~'f:/, ,_., ·.·.-@~ff.P -;!~f!Jr·,:'*--7~·i-fi.£W, KJt{Jg/igations of either Party which arose before the occurrence causing
•. ;/j)fY the susp~!f_%9n of$£tJttrmance and which could and should have been fully performed ~~f-7( before sudh;,fJ,C_G,urrer(6-~~sfra11 be excused as a result of such occurrence. ~~/: {?~ ·~h v-y,~ :.. 7;@._ •·;;/}' ~id%~~. ~t ~y v,~¥:,... ~{,i; ~ //~ '?%:-~ ·•;rqt~><·· ~ ~;>!(//.'. ~:t ;?'q '·?A_-.-.., %:-if· ·-~ifjf ~-J#jf ~~-·-.~ --~~ ~!f/ . i:#'i({~;t~. ~;}#·"
·-.,~-
Idaho Power Company Generator Interconnection Agreement# 307
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'J, the nondefaulting Party shall cause
notice in writing to be given to the defaulting Party, specifying the manner in which such
default occurred. If the defaulting Party shall fail to cure such Default within the sixty
(60) days after service of such notice, or if the defaulting Party reasonably demonstrates
to the other Party that the Default can be cured within a commercially reasonable time
but not within such sixty (60) day period and then fails to diligently pursue such cure,
then, the nondefaulting Party may, at its option, terminate and/or pursue
its legal or equitable remedies.
6. 5. 2 Material Breaches. The notice and J;i!l~~if:}J'{.istoJ in Paragraph 6. 6. 1 do
not apply to Defaults identified in this Agreernrellv ... '',;;;"'"'""',..,.,.;...,, Breaches. Material
Breaches must be cured as expeditiously occurrence of the
breach.
7. Insurance.
During the term of this Agreement,
insurance coverage:
7. 1 Comprehensive
damage with limits equal to $1,
for such insurance shall be
property.
7.2
following
for both bodily injury and property
single limit. The deductible
Utility practices for similar
an insurance company with
policy shall not be canceled or the limits of
written notice to Idaho Power.
~.!.,L_~=~~::...!::.!...-=-==::......!::.:........:::=..:..:::.:..:=-If the insurance coverage
shall/apse for any reason, Seller will immediately notify Idaho Power
::~nt.n~P Idaho Power of the specific reason for the lapse and the steps
:.u.n:ncn.v the coverage. Failure to provide this notice and to expeditiously
coverage will constitute grounds for a temporary disconnection under
be a Material Breach.
8. Miscellaneous.
8. 1 Governing Law. The validity, interpretation and enforcement of this Agreement
and each of its provisions shall be governed by the laws of the state of Idaho without regard to
its conflicts of law principles.
8.2 Salvage. No later than sixty (60) days after the termination or expiration of this
Agreement, Idaho Power will prepare and forward to Seller an estimate of the remaining value
Idaho Power Company Generator Interconnection Agreement# 30-7 ·
I.P.U.C. No. 29. Tariff No. 101 Page 8 of 9
of those Idaho Power furnished Interconnection Facilities as required under Schedule 72 and/or
described in this Agreement, less the cost of removal and transfer to Idaho Power's nearest
warehouse, if the Interconnection Facilities will be removed. If Seller elects not to obtain
ownership of the Interconnection Facilities but instead wishes that Idaho Power reimburse the
Seller for said Facilities the Seller may invoice Idaho Power for the net salvage value as
estimated by Idaho Power and Idaho Power shall pay such amount to Seller within thirty (30)
days after receipt of the invoice. Seller shall have the right to offset the invoice amount against
any present or future payments due Idaho Power.
9. Notices. ~3';> (~·-?j/ 4~f? 9.1 General. Unless otherwise provided in thi~~$J;}feement, any written notice,
demand, or request required or authorized in connection vtlt;~jl~~_greement ("Notice") shall be
deemed properly given if delivered in person, delivered#.!Jrecog6J¥:.$l/9 national currier service,
or sent by first class mail, postage prepaid, to the pe~~~-n 'specified i5'eJ~W-~ P£. , /'ff.---' ----/~'Z/ •k ' •. ~ ... » ·.-.r-. '•/. J.· ; •
. ~.X:1~~i . '. ~~~~~., : ~t.::-.JY . {~_pz
If to the Seller:
Seller: 1/1~}/ .{/,-. -~&t~-~ ~~·· ~~ . .Zj{l ~~)..;. Attention: ,.:{:iJ}f' "-~
Address: ·· '<{{y, ,.)P~7•
City: __________ §tate: -:~. ·.~.~;.r-~-:,. ___ _
Phone: F~" ~/'<· ....... "~;~~~)j '?~·-If to the Company: v, ... ,_ . .,..:~(1 ••. ,. ·<ff:0~---. ~ ., .f'·· ~~·.. '• "A
Idaho Power Company-Delivery '7~i-· ·---~-?~~--·
Attention: Operations M~ -~er ' M~~i"tY.·., ·{;;'
1221 W. Idaho Stre~~$i.~. Vf~-~7 ·7,·
Boise: Idaho 8~&>"'" "7 --~~-~F
Phone: 208-3~1(; S9 Fax: 20:~;., 88-5504 '';-
.,.-,}'_ ' ~JI' ;.-:; 0p)t··. -~f';f ._ .
9.2 Bil_n"! and ~!(~Em~ ;~~!lings (99: payments shall be sent to the addresses set
out below: %'~?.-:..r A.' -~~R.('-. ~~ •/.;(~'{M0-,.~_· >t-~PZ~&~ .. ·,.,.w., r · 1.:-h~,~ ... q: 4'-'Zh': r~~.... :y ~h~;-:~·~~=-·t>._~{'~~rr:·~>-~.P:~~& ~~rition: -~~~-~~"-
.:f.ffJP-'dress· .,1#.&~ ·-~p.., ~*~{-/,U1
• ~~ w~,(
P'.ft·v: ~&~ 0fW,.,§tate: Zip: ~¥,4'~ '"/r• ~ 7 -------' ------PffQn~r <~%]" dJx· --~'~?:.--~74 . --------··i:t~ ~~~ Idaho P~~~[ Compan;f~~ eli very Attention:~~orat~d'~ ier
PO Box 447~fh-~./
Salt Lake City ~~, -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# 307
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
1221 W. Idaho Street
Boise, Idaho 83702
Phone: [phone], or 388-5175 during
(after hours Southern Region 208-388-5190).
9.5
10. Signatures.
IN WITNESS WHEREOF, the P<:>rtic~
respective duly authorized representati
For the Seller
Name:
Date: _____ __;:;;
For the
Name:
Title: ~~~~~j~JB[:)E3ra1:io
Idaho Power Company Generator Interconnection Agreement # 307 ·
I.P.U.C. No. 29. Tariff No. 101 Page 1 of 3
Attachment 1
Description and Costs of the Generation Facilitv. Interconnection Facilities and Metering
Equipment
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. 6 General Facility Description .. ~.IJII
The proposed project will connect to Idaho Power's 12.5kV system o -~ ~aho Power Company's Clover
(CLVR-012) distribution line. The total project output is 1.2 MW. ~,~~~1~:("" /##~ ~~
Interconnection P9Jp! .. t'r ·-~-· ..
The Interconnection Point for the Swager Farms Dairy Di~~t ('Project will be' t~jqw-side bushings on
the padmounted transformer (SW1). The project's lo~ ~~~-··ts in T10S R15E Sfi~_2p,21 of Twin Falls
County, Idaho. A dra~ing .identifying the_ Point of.ln~~{~-~ection is included as Attao~m,~nt 2. The Point
of Change of Ownership Will be the low-stde bushmggJpj._,Jhe padmOL!P!~d transformer (SW~:). ~:f.»·. P;#?' . _,. 'Y ~--~ .. y,~ J~"1,-W2J" " ,, /~y. :z 0':..o:7*·.
Seller's lnterconnectrog~~~jpes
The Seller will install generators, low-sp~ disconnect s~~,b:J.''~ all wiring and conduit between the
generators and the padmounted tran~t6J~! . appropriat~to!Jnding measures, and associated
auxiliary equipment. The Seller will build ff'~~~fg~jl}J,Q. facilities ~h~. Point of Change of Ownership for
the generator facility. The low-side discon~~ swff~.tJ,~ !d be vt~1~~-lockable, within ten (10) feet of
the padmounted transformers, and accessibl~; Idaho ,!?', '"~r-Hxrsori'n~!~· .v·~; ~ .## ;,fW?f~X.~7.; ' . /4,0-l>t%;: -~ /.Xl ~-/./}.),;&~ .. , The Seller ~ill provide p}:199B-.z-se.~J9r to IPcr~~. · erator tr1f~ \Connect package as described in
Telecommumcattons beJe~·' ,.J(0." ·:.?f%1? .. ~.';)· ;_/ :~~ -~
All interconnection ~:~.fpment eles_t-#lly locate~:?n the generator side of the Point of Change
Ownership shall be owne~;~pd m~JW~Aest~X)J:!.~ Sell~f~ ·-~:.'-'· .... ~:r-.w-,: .. ~,.u'.:¥~,. ,, ~r-
. ..;f#/i/l}!/.t.·. '7~.dther FacilitiErfi'~~ided by Seller Teleco9J!IJ.(fnica·tifins~ .;,-·... ·~>,
The /lp~efeonnection Cl.t.~t~mer 'Wf;provide two communication circuits between the generation inter'Ctt9p~ction site and al'if§~~ion, 'oWJ.~~~tions, specified by Idaho Power. One of the circuits will be a
dedicate9-~twire leased anatgJ;jdicircuit ·c.gJ1·nected to the SEL 311C relay and the other will be a POTS
dial-up cif~~i~Jo the revenue ·~'m~ter. The Interconnection Customer is responsible for supplying and
coordinating"'Jti~--installation 9}1fhe phone lines and paying the monthly service charges. The
communication ~re,uits will n~~d;fo be installed and operational prior to generating into the Idaho Power Y.~ X~ /i'" ··z system. · .. -,;~;_,~ ,y~P· ·
//'/ ·">"/ ·z{:t~_fj~·r.;;·
Ground Fault Equiprrie~
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 Interconnection Agreement# 307
I.P.U.C. No. 29. Tariff No. 101 Page 2 of 3
Easements
The Seller will secure underground and overhead easements with Swager Farms 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 (CLVR-012) on private property southwest of the intersection of 3800 North and 1700 East in
Twin Falls County, I D. The new interconnection package will include four distribution poles to mount a
local service transformer, solid blade disconnects, primary metering recloser, relays, fuses
and riser necessary for the package. The interconnection will be ed by a SEL-311 C line
protection relay. The relay will be located in a pole mounted e and will also contain a test
switch (TS4), SLSS, modems, isolation interface, power supply, , control switch and surge
protector.
Idaho Power will install (and subsequently own and
Grounded Wye I Grounded Wye padmounted ~nc:rnr·m-=•rmw
cables will be installed from the interconnection "'""'~.,.,,.,..
will be installed to protect the ground mounted equ•o!in'ftsl!i"t
A 2" conduit will be installed alongside the undergrou
customer about the recloser. (The I ection vu•::nu•
the appropriate cable).
All interconnection equipment electrically 1\;,lyj::I,Lo::.•u 1:11~~
shall be owned, operated, and maintained ""
and underground
Jr,.,.to:>r•t•"""' posts
J~);'~ ... litate information exchange to the
ponsible for providing and installing
the Point of Change Ownership
accordance with Section 9, unless payment arrangements are
IJ.C\(A'/'or 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 Interconnection Agreement# 30V ,.
I.P.U.C. No. 29. Tariff No. 101 Page 3 of 3
Invoices are to be addressed to Seller as follows:
In the event of a billing dispute, Seller must pay invoices when due subject to refund (without interest).
lnvoice·s must be accompanied by appropriate supporting documentation and proof ·of expenditures as
applicable.
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
I.P.U.C. No. 29. Tariff No. 101
Milestones:
Agreed to by:
For the Seller:
For the Transmission Provider
Idaho Power Company, Delivery
Generator Interconnection Agreement # 307 '
Page 1 of 1
Attachment 3
Idaho Power Company Generator Interconnection Agreement# 307
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
IEEE Standard 519-1992 IEEE Recommended Practices and
Electrical Power Systems or any subsequent standards as they
Seller will be able to modify power plant facilities on the Qelner·at¢1Jt$rde
no impact upon the operation of the transmission
electrically isolated from the transmission system and a t.:>rt"Wrr.,.,
Company's Grid Operator.
Voltage flicker at startup and during operation
Interconnection Point. For this to occur, the current ca.t110.Qt
kV voltage level. This forces the generating facility to
Low Voltage Ride Through
stortion Limits found in
for Harmonic Control in
"''"'"''.'"'""from time to time.
nterconnection Point with
or<:a1ftnn facilities are
by Idaho Power
"<M'~~<::ac:• red at the
... t..,w.'t'i .... at the 12.5
The Project shall remain interconnected
ground fault down to a voltage of zero at
arro:n,.o ONa~tnre~e phase or single phase to
t;)n••uo·,,..,;q (C,,,.,torn as close to the Seller's
facilities as Idaho Powe .• r~~~~~n~y1's C
minimum times stated belq
• Three phase
• Single phase
Ground Fault a... .... u.a."''
The Seller will
system.
fault being cleared for the
mmercial Operation date only when all requirements have
r Company's Power Sales Agreement. A transmission
has been submitted to Idaho Power Company's Grid
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
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
provi:Jed eq~ipment, Seller provided .equipme~t, and all costs ~ssocia~~!fi.th ~he equipment: design
and mstallat1on of the Company-provided eqwpment. The eqwpment s e~f1cat1ons and reqwrements
will become an integral part of this Agreement. The Company-own.,J?PJ'{(uipment will be maintained by
the Company, with total cost of purchase, installation, opefJiff&#tl't~ d maintenance, including
administrative cost to be reimbursed to the Company by the sfi{J.~'P/ PaPf((fM~j of these costs will be in
accordance with Schedule 72 and the total reactive power g~~t i$it be incllfO~f:l~· ·n the calculation of the
Monthly Operation and Maintenance Charges specified in .jJ}ffdule 72. 0t;:j~1'.,. ::~rp· -~~·~
The project must be controlled to operate at unity pq~wl~Jfii~tor. ·;'¥(< .. }~~.w ' ~-·XX;. ~~~-~'l,/; <~ ·~;t, --~,, /4:-J::/, .·. -~-r
·~~~t-~." (~Pf' :• ··~X:f•"·' ~1?-.~-. '':1$~. --9[:,;» ;-~;.. "/i#: .'
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lda)lQ.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.
Upgrades
Distribution Upgrades
Idaho Power will install a new capacitor bank on the existing d
the existing Clover Substation.
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 27
Bishop, Rowena
Hackett, Eric "=rom:
;ent:
To:
Monday, January 03, 2011 9:53AM
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 summer 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 83 702
Office Phone: [phone]
Cell Phone: [phone]
rom: 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-12-25
IDAHO POWER COMPANY
ATTACHMENT 28
SMALL GENERA TOR 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 $1,000 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 Two, LLC
Contact Person: Laura Knothe PE
Mailing Address: ;,:..87-'-'2=0"------'-V-"'ic"'--"=L"""an""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): ---=20"-"'8=.5=8"'-'5 . .:<_;90"-'IC.><6 __ _
Fax: ---'=2""0""'8'"".5'""'8""5"'"".9'""0'""1~6 _______ E-Mail Address: [e-mail]
SWAGER FARMS PROJECT
Al ternative Contact lnfonnation (if different from the lnterconnection Customer) NA
ContactNrune: ____________________________________________________________ __
Title: ---------------------------------------------------------------------
Addr~s: ______________________________________________________________ __
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 GIA, but no pbysical work has been completed-Project Number 307. This application is
for an additional800kW to bring the total request to 2000kW. The values below indicate the
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 -Project Number 307
Interconnection Customer's Requested In-Service Date: :::8-'<Jep~t~em~b""'"et""""· 2:.:0""1""1'----------------------
SWAGER FARMS 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 _!l._Recip Engine _Gas Turb
_Microturbine _PV
Type of Generator: _x_Synchronous __ Induction Inverter
_Steam Turb
_Other
Generator Nameplate Rating: up to2000 kW (Typical) Generator Nameplate kV AR:
___!ill to 1500
Interconnection Customer or Customer-Site Load: ___ n=o=n=e _____ --'kW (if none, 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 certified:
Equipment Type Certifying Entity
l. -----------------
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 V16 C-800kW
Version Number: ________ ,, _______________________ _
Nameplate Output Power Rating in kW: (Summer) ---=2=-00=0=--------, (Winter) ----=2=0=00"------
Nameplate Output Power Rating in kVA: (Summer) __ _.::2.::..50=0'------(Winter) --"""2~50 __ 0=-----
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
Request.
SWAGER FARMS PROJECT
Small Generating Facility Characteristic Data (for inverter-based machines)
Max design fault contribution current: Instantaneous orRMS?
Harmonics Characteristics: -------------------------
Start-up requirements:---------------------------
Small Generating Facility Characteristic Data (for rotating machines)
RPM Frequency: _____ _
(*)Neutral Grounding Resistor (If Applicable): ____ _
Synchronous Generators:
Direct Axis Synchronous 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): _____ _
i2
2t 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 kV A Base
Note: Please contact the Transn1ission Provider plior to submitting the Interconnection Request to
determine if the specified information above is required.
SWAGER FARMS PROJECT
ExcitatiQn and Governor System Data for Synchronous Generators Only
Provide appropriate IEEE model block diagram of excitation system, governor system and power system
stabilizer (PSS) in accordance with the regional reliability council criteria. A PSS may be determined to
be required by applicable studies. A copy of the manufacturer's block diagram may not be substituted.
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
Transfonner Data (If Appllcable, for lnterconneorion Customer-Owned Transfonner):
Is the trans former: __ single phase __ three phase? Size: kVA -----' Transformer Impedance: %on kV A Base
If Three Phase:
Transformer Primary: __ Volts __ Delta ___ Wye __ Wye Grounded
Transformer Secondary: __ Volts __ Delta __ Wye __ Wye Grounded
Transfonner Tertiary: __ Volts __ Delta __ Wye __ Wye Grounded
Transformer Fuse Data (If Applicable, for Interconnection Customer-Owned Furu:,
(Attach copy offuse 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 Qf 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.
SWAGER FARMS 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 Transfonner Data (If Applicable):
(Enclose Copy of Manufacturer's Excitation and Ratio Correction Curves)
Manufacturer: ---------------------------------------Type: ------------Accuracy Class: __ Proposed Ratio Connection: __
Manufacturer:--------------------------------
Type: ---------Accuracy Class: __ Proposed Ratio Connection: __
Potential Transfonner Data (If Applicable):
Manufacturer: ------------------------------
Type: _______ Accuracy Class: __ Proposed Ratio Connection: __
Manufacturer: --------------------------Type: _______ Accuracy Class: __ Proposed Ratio Connection: __
SWAGER FARMS 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) 1707 E 3800 N Buhl ID 83316
Enclose copy of any site documentation that describes and details the operation of the protection and
control schemes. Is Available Documentation Enclosed? _Yes __ No
Enclose copies of schematic drawings for all protection and control circuits, relay current circuits, relay
potential circuits, and alann/monitoring circuits (if applicable).
Are Schematic Drawings Enclosed? _Yes __ No
Applicant Signature
I hereby certify that, to the best of my knowledge, all the information provided in this Interconnection
Request is true and correct.
For Interconnection Customer:
~~.;::d. J/ .· --c.::'.:.tf.b:..,....:~r->"' ....... _.~-···· 'ON --\ ~
Signed
i _______________ Date: 1112/11
Printed
Laura Knothe
SWAGER FARMS PROJECT
DATE: 01/11111
J08 ... -a.
SCALE
NTS
'f'
..-TRANSFORMER
PAD
400KW 800KW 800KW
GENERATOR GENERATOR GENERATOR + + ~ ~ ~ I A. ~ 2500KVA 1 BY
I I r "Y -.,, f..I,.XFMR I UTILITY
L--_____ __]
~-----I -----I -----~-----~
: ) : ) : ) : ) 3000A :
I l I 1 I 1 I 1 JP I I
: _l3000A BUS, 480V, 3Ql,_l3W : :
L_____ -----_____ __L _____ _j
*PARALLELING GEAR •PARALLELING GEAR
SKE-1
SKETCH NO.
REF.SHTS:·
SWAGGER
ONE-LINE DIAGRAM
s J.::IC ~.E~~If r-.J..E .ER[ J'Y.Q
W 440 E:a'sl CorporalS Dr .• Ste. 103
Meridian ID 83642
ph 208-288-2181
lax 208-288-2182 pro)ott 00000
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 29
January 2 0, 20 11
via email and
An IDACORP Company
Certified Mail# 70060810000655113157
Law-a Knothe
8720 Vic Lane
Middleton, ID 83694
Re: Expansion Projects# 364 (Swager Fanns) and# 365 (Double B)
Dear Laura:
Thank you for your Generator Interconnection applications for the expansion ·projects shown above
(see attached copy). Since we have.xeceived all of the req\iit:c:l'd materials, these applications are now
consi4ered com,plete" As you may be aware, we are required to post certain information to our
OASIS (Open Access Same Time Information) website. Please refer to the website periodically to
view a list ·of currt!!lt pr.ojeGtS at http://www.oatioasis.corniiPCO/:index.html under GENERATOR
INTERCONNECTION INFORMA TIONJolder, on the left side of the screen.
Sinqe y<>u will be selli11g the project output to Idaho Power Company..:Power Supply (as .a Network
Resource-NR, or as a-PURPA), transmission studies for moving this energy to -~he ioad or a poi11t of
deHvezy Inside of our systettJ.: will be included in the. Generator Interconnection studies. If you
haven't already done so, please contact Randy Allphin for your Power Sales contrac~ un.der a parallel
process. He can he reached at 208;.388~2614.
At this time, Id'aho Power Company wifl as~ign a plan,ning ,engineer (ot; this project, and we will
.contilQt you it:t the • near :futur:e to schedule a-Scoping Meetiilg~ If your project passes screening for the
FAST TRACK process, which means your project output •can he acconunodated into our system
withoutfacilityupgrades or further·studies,.we will immediately notify you of next steps to proceed.
For yow review; I am attaching a copy of die stan,dard fntercoimection Feasibility Study Agreement
that :Qeeds to be executed by you soon after our Scoping Meeting; Please feel free to c.ontact me with
yo.ur questions· about the Generator Interconnection Process anytime,
I will forward this application to our T&D Planning Leader, Marc Patterson, who will he evaluating
your request
Sincerely,
R."'. Rowena Bishop
Ph 208-388-2658
Encl Application
Idaho Power Company's Facility Connection Requirements
Standard Interconnection Feasibility Study Agreement
Cc (via email):
Marc Patterson/IPC
Randy Allphin/IPC
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 30
Small Generator Feasibility Study Agree~~pt
5ata.§M &1ms Project # 36'1
Feasibility Study Agreement
THIS AGREEMENT is made and entered into this Z. day of f::'ebr ucr--; 2011, by and
between he.. J\)e._.tJ Ene r ' /1"-c t"t.fi..C L-L a Lz_C. --------------------------organized and existing und r the laws o State of --=-'-~d=a.:!:...L.:::..""-=--------------'
("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# 31P'i; 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
.5 w c!PjtYf Fa.,r~s Project# S--&'1'
'
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 power flow issues.
7.0 The feasibility study shall model the impact of the Small Generating Facility regardless
of purpose in order to avoid the further expense and interruption of operation for
reexamination of feasibility and impacts if the Interconnection Customer later changes
the purpose for which the Small Generating Facility is being installed.
8.0 The study shall include the feasibility of any interconnection at a proposed project site
where there could be multiple potential Points of Interconnection, as requested by the
Interconnection Customer and at the Interconnection Customer's cost.
9.0 In lieu of Feasibility Study deposit, Interconnection Customer agrees that study funds
will be drawn from the application fee for the perfonnance of the Interconnection
Feasibility Study.
Transmission Provider shall charge and Interconnection Customer shall pay the actual
costs of the Interconnection Feasibility Study. Any difference between the deposit and
the actual cost of the study shall be paid by or refunded to Interconnection Customer, as
appropriate.
Small Generator Feasibility Study Agreement
S '-"'tJt]u r-a.rrv~ s Project# 3?1
10.0 Once the feasibility study is completed, a feasibility study report shall be prepared and
transmitted to the Interconnection Customer. Barring unusual circumstances, the
feasibility study must be completed and the feasibility study report transmitted within 30
business days of the Interconnection Customer's agreement to conduct a feasibility study.
11.0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
12.0 The Interconnection Customer must pay any study costs that exceed the deposit without
interest within 30 calendar days on receipt of the invoice or resolution of any dispute. If
the deposit exceeds the invoiced fees, the Transmission Provider shall refund such excess
within 30 calendar days of the invoice without interest.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written.
Transmission Provider: Interconnection Customer:
Idaho Power Company-Delivery lh-L :D.u.0 fn.~~ Cb ) LL<!.
Signed:4~-
Printed: Marc Patterson Printed: la..u._ v-a_ ~ V'\ofu
Title: Engineering Leader, T &D Planning Title: 4CL.WL~ ,IYu? 1'-lwkv-~ ~
~ J':l. I 70 t I LL! Date: -z ( 2 I '2o I ( Date:
Small Generator Feasibility Study Agreement
S w~"je.-f nrm .s Project# '3-(p'/
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 Fe k:> ·z., zo t I
1) Designation ofPoint of Interconnection and configuration to be studied.
C.l oveK /2 1'2,51:V
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-12-25
IDAHO POWER COMPANY
ATTACHMENT 31
BH
GENERATOR INTERCONNECTION
FEASIBILITY STUDY
For integration of the proposed
SWAGER FARMS DIGESTER EXPANSION PROJECT
In
TWIN FALLS COUNTY, IDAHO
To the
IDAHO POWER COMPANY ELECTRICAL SYSTEM
For
NEW ENERGY TWO, 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
12.5 kV
through
Clover
Twin Falls (COVR)
#364 January 2011 County 2.0 substation
Short Circuit Analysis Results
System Changes Required: DYes 0No
Power Flow Analysis Results
System Changes Required: ~Yes 0No
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 Swager Farms. These upgrades are shown in
the Table 1 below:
Description Estimated Cost
4 total miles of distribution line upgrades $529,000
Substation upgrades to Clover Substation including new 7 MV A
46:12.5 kV transformer, associated bus reconfiguration and
SCADA upgrades. $959,000
Generation Interconnection Protection Package (Includes 12.47
kV recloser, controls, CTs, PTs, and communications $225,000
Total Estimated Cost $1,713,000
Table 1: Estimated interconnection costs for 2 MW project at Swager Farms
Idaho Power recently updated its operating requirements for generators interconnecting to the distribution
system. Because of these new requirements, there are upgrades required to the existing IPC distribution
system to interconnect the 1.2 MW generator project at Swager Farms. These estimates are shown in Table
2 below.
Description Estimated Cost
Distribution line upgrades (2.5 miles total) $350,000
Generation Interconnection Protection Package (Includes 12.47
kV recloser, controls, CTs, PTs, and communications $225,000
Total Estimated Cost $575 000
Table 2: Estimated interconnection costs for 1.2 MW project at Swager Farms
-1 -
/ . .
I
Good Faith Cost Estimate
Interconnection cost estimate for 2 MW generator project: $1,713,000.
Interconnection cost estimate for 1.2 MW generator project: $575,000.
System Impact Study Required? DYes ~ No
This Feasibility Study only addresses the work required to interconnect the Swager Farms digester projects
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 #364 will be controlled to operate at unity power factor with an operating bandwidth of± 300
kVAR.
-2-
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 32
BH
GENERATOR INTERCONNECTION
FEASIBILITY STUDY
For integration of the proposed
SWAGER FARMS DIGESTER EXPANSION PROJECT
In
TWIN FALLS COUNTY, IDAHO
To the
IDAHO POWER COMPANY ELECTRICAL SYSTEM
For
NEW ENERGY TWO, 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
12.5 kV
through
Clover
Twin Falls (COVR)
#364 January 2011 County 2.0 substation
Short Circuit Analysis Results
System Changes Required: DYes ~No
Power Flow Analysis Results
System Changes Required: ~Yes 0No
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 Swager Farms. These upgrades are shown in
the Table I below:
Description Estimated Cost
4 total miles of distribution line upgrades $529,000
Substation upgrades to Clover Substation including new 7 MV A
46:12.5 kV transformer, associated bus reconfiguration and
SCADA upgrades. $959,000
Generation Interconnection Protection Package (Includes 12.47
kV recloser, controls, CTs, PTs, and communications $225,000
Total Estimated Cost $1,713,000
Table 1: Estimated interconnection costs for 2 MW project at Swager Farms
Idaho Power recently updated its operating requirements for generators interconnecting to the distribution
system. Because of these new requirements, there are upgrades required to the existing IPC distribution
system to interconnect the 1.2 MW generator project at Swager Farms. These estimates are shown in Table
2 below.
Description Estimated Cost
Distribution line upgrades (2.5 miles total) $350~_000
Generation Interconnection Protection Package (Includes 12.47
kV recloser, controls, CTs, PTs, and communications $225,000
Total Estimated Cost $575,000
Table 2: Estimated interconnection costs for 1.2 MW project at Swager Farms
-I -
I
(·
Good Faith Cost Estimate
Interconnection cost estimate for 2 MW generator project: $1,713,000.
Interconnection cost estimate for 1.2 MW generator project: $575,000.
System Impact Study Required? DYes ~ No
This Feasibility Study only addresses the work required to interconnect the Swager Farms digester projects
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 #364 will be controlled to operate at unity power factor with an operating bandwidth of± 300
kVAR.
-2 -
, BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 33
April 27, 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:
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 ofthese 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
Jl21 W, klaM St. (B310l)
P.O. 8o:..70
l!olse, 10 8't1117
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 of the
equipment, including, without limitation, transformer, switchgear, meters, and other
st~tion equipment, (2) the nature and estimated cost of the Transmission Provider's
Small Generator Facilities Study Agreement - 1 -Swager Farms Expansion Project #364
Interconnection Facilities and Upgrades necessary to accomplish the interconnection, and
(3) an estimate of the time required to complete the construction and installation of such
facilities.
5.0 The Transmission Provider may propose to group facilities required for more than one
Interconnection Customer in order to minimize facilities costs through economies of
scale, but any Interconnection Customer may require the installation of facilities required
for its own Small Generating Facility if it is willing to pay the costs of those facilities.
6.0 A deposit of $30,00.00 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 Stlildy Agreement -2-Swager Farms Expansion Project #364
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 /PT maintenance?
Yes No ---
4. Will a transfer bus on the generation side of the metering require that each meter set be
designed for the total plant generation? Yes No __
(Please indicate on the one-line diagram).
5. What type of control system or PLC will be located at the Small Generating Facility?
6. What protocol does the control system or PLC use?
7. Please provide a 7 .5-minute quadrangle map of the site. Indicate the plant, station,
transmission line, and property lines.
8. Physical dimensions of the proposed interconnection station:
Small Generator Facil~ties Study Agreement -3-Swager Farms Expansion Project #364
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 ___ IfNo, 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 Fadlities Study Agreement -4-Swager Farms Expansion Project #364
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 34
Laura Knothe
8720 Vic Lane
Middleton, ID 83694
Junel 0, 2011
VIA email &
An IDACORP Company
Certified mail# 70090820000123019190
Subject: Swager Fa11llS expansion Project #364-FINAL NOTICE
Dear Laura:
By letter dated Apri1.27, 2011 Idaho Power provided you with a Facility Study Agreement for
interconnection of the proposed Swager Fanns expansion to be interconnected in Twin Falls
County, ldaho.
Interconnection Customer was to exe-cute and return to me the Facility Study Agreement with the
required $30,000.00 deposit by June 9, 2011. That time period has now expired. Your
application for Generation Interconnection has now be_en de.emed withdrawn.
Fai)ure to submit the deficient items to me l:>y June 24, 2011 will cause your deneratot
tnterconnection req11est to be tenninated. If you have any further questions, please don't hesitate
to contact me.
cc (via email):
Orlando Ciniglio/IPC
Marc Patterson/IPC
Eric Hackett/IPC
Aubrae Sloan/fPC
Sincerely,
Rw)!A1
Rowena Bishop
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-12-25
IDAHO POWER COMPANY
ATTACHMENT 35
MP
GENERATOR INTERCONNECTION
FEASIBILITY STUDY
For integration of the proposed
SWAGER FARMS DIGESTER PROJECT
In
TWIN FALLS COUNTY, IDAHO
To the
IDAHO POWER COMPANY ELECTRICAL SYSTEM
For
NEW ENERGY TWO, LLC
The
INTERCONNECTION CUSTOMER
REVISED REPORT
August 26, 2011
Generator Interconnection Feasibility Study
General Interconnection Information
Station or
Date of Total Trans Line
Queue Request Location (MW) for POl
12.5 kV
through
Clover
Twin Falls (COVR)
#307 January 2011 County 1.2 substation
Short Circuit Analysis Results
System Changes Required: DYes [giNo
Power Flow Analysis Results
System Changes Required: [g]Yes DNo
Projected
In-Service
Date
September
2011
Type of facility
(combined cycle,
base load, CT, fuel
type)
Biogas
Idaho Power recently updated its operating requirements for generators interconnecting to the distribution
system. Because of these new requirements, there are upgrades required to the existing IPC distribution
system to interconnect the 1.2 MW generator project at Swager Farms that were not identified in the
original January 2010 report. The cost estimates for those upgrades are shown in Table 1 below.
Description Estimated Cost
Distribution line upgrades (2.5 miles total) $350,000
Generation Interconnection Protection Package (Includes 12.47
kV recloser, controls, CTs, PTs, and communications $225,000
Total Estimated Cost $575,000
Table 1: Estimated interconnection costs for 1.2 MW project at Swager Farms
Good Faith Cost Estimate
Interconnection cost estimate for 1.2 MW generator project: $575,000.
System Impact Study Required? DYes [gJ No
This Feasibility Study only addresses the work required to interconnect the Swager Farms digester projects
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:
As part of the updated operating requirements, project #364 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-12-25
IDAHO POWER COMPANY
ATTACHMENT 36
September 9, 2011
Certified Mail# 70090820000123019695
LawaKnothe
The New Energy Company
8720 Vic Lane
Middleton, ID 83644
RE: Swager Farms Project# 307
Dear Laura:
An IDACORP Company
Sin<:e we issued your previous Feasibility Smdy Rtmort, some .ldMo Power -op~rating requirements
·changed that affect this project. The· additional modifications were previou~ly presented to you as part
of our April 26, 2011 Feasibility Report for GINT#346~ Enclosed is a Revised Feasibility Study Report
for lhe above-referenced proje_ct. The feasibility analysis indicates that nio.dification/addition of some
facilities will be requited to integrate the network tesowc_e capacity addition <>f your project into the
fqaho Power system.
Enclosed are two Facility -Study Agreements (FSAs) for the above-referenced generator interconnection.
In order to proceed with your project, and fot your ap:glication to r.emain in. the Generator
Inter:¢qhtlectit.ni study queue, Idaho_ Power must rec.eive 2 signed cppies of the FSA by October 21,
201 L otherwise your GI application will be deemed ·withdrawn. The d~posit urtdel' this FSA is .$30,000
based .on estimated engineering costs.
The submittal should be sent to: Idaho Power Company, Attention: Rowena Bishop, 1221 West Idaho
Street,_ Boise, lD 83702. Pleas~ contaqt m~ if you ha:V¢ questions.
Sincerely,
Marc Patterson
Engineering Leader, T&D Planning
Ph. 208.388.2712
Enclosures: two Facility Study Agreements
C: Rowena Bishop/IPC
Ed Kosydar/IPC
1221 W, Idaho St, (83702)
P.O. Box. 70
Boise, ID 83707
·.
Facilities Study Agreement
THIS AGREEMENT is made and entered into this __ day of 2011 by and
between , a organized
and existing under the laws of the State of , ("Interconnection
Customer,") and Idaho Power Company, a Corporation existing under the laws of the State of
Idaho ("Transmission Provider"). Interconnection Customer and Transmission Provider each
may be referred to as a "Party," or collectively as the "Parties."
RECITALS
WHEREAS, the Interconnection Customer is proposing to develop a Small Generating Facility
or generating capacity addition to an existing Small Generating Facility consistent with the
Interconnection Request completed by the Interconnection Customer on 10/12/09; 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 Revised Feasibility 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
4.0
The scope of the facilities study shall be subject to data provided in Attachment A to this
Agreement.
The facilities study shall specify and estimate the cost of the equipment, engineering,
procurement and construction work (including overheads) needed to implement the
conclusions ofthe 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 -Swager Farms Project #307
Interconnection Facilities and Upgrades necessary to accomplish the interconnection, and
(3) an estimate of the time required to complete the construction and installation of such
facilities.
5.0 The Transmission Provider may propose to group facilities required for more than one
Interconnection Customer in order to minimize facilities costs through economies of
scale, but any Interconnection Customer may require the installation of facilities required
for its own Small Generating Facility if it is willing to pay the costs of those facilities.
6.0 A deposit of $30,000 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 -Swager Farms Project #307
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/PT maintenance?
Yes No ---
4. Will a transfer bus on the generation side of the metering require that each meter set be
designed for the total plant generation? Yes No __
(Please indicate on the one-line diagram).
5. What type of control system or PLC will be located at the Small Generating Facility?
6. What protocol does the control system or PLC use?
7. Please provide a 7.5-minute quadrangle map of the site. Indicate the plant, station,
transmission line, and property lines.
8. Physical dimensions of the proposed interconnection station:
Small Generator Facilities Study Agreement - 3 -Swager Farms Project #307
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 ___ IfNo, 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-Swager Farms Project #307
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 37
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 directors, 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: The New Energy Company, LLC
8720 Vic Lane
Middleton, ID 83644
Name ofProject(s): Swager Fanns (New Energy Two, LLC) and Double B Dairy (New Energy
Three, LLC)
Leslie White Manager
Laura Knothe Manager
IN WITNESS WHEREOF, I have hereunto signed my name this _1_8_ day of October
2011.
Print Name: Laura Knothe
Title: Manager
I, Kara G()dfrey, HEREBY CERTIFY, that Laura Knothe is the duiy elected and acting
Manager of the Company and that the signature appearing above is his/her signature.
'""'•-...1"-:-rr,_ l.-( IN WITNESS WHEREOF, I have hereunto signed my name this ,jl.) day of vc:;roi@l-.. 20 .n_.
I 1/ v ' .~1 Print Name: nM< A 6 ()p~\21.
Title: \ P\~'.0&-ewt
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 38
Facilities Study Agreement
THIS AGREEMENT is made and entered into this 21 day of October, 2011 by and between
New Energy Two, LLC, 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 10112/09; 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 Revised Feasibility 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 T:r·ansmission Provider's Transmission System.
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the terms specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause a
facilities study consistent with the standard Small Generator Interconnection Procedures
to be performed in accordance with the Open Access Transmission Tariff.
3.0 The scope of the facilities study shall be subject to data provided in Attachment A to this
Agreement.
4.0 The facilities study shall specify and estimate the cost of the equipment, engineering,
procurement and construction work (including overheads) needed to implement the
conclusions of the system impact study(s).
The facilities study shall also identify (1) the electrical switching configuration of the
equipment, including, without limitation, transformer, switchgear, meters, and other
station equipment, (2) the nature and estimated cost of the Transmission Provider's
Small Generator Facilities Study Agreement - 1 -Swager Farms Project #307
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 $18,260 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 iflvoiced 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:_~~ ~
Printed Name: Leslie White -----
Title: _Project Manager _____ _
Date: 10/21/2011 --------
Small Generator Facilities Study Agreement - 2 -Swager Farms Project #307
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.
Submitted previously.
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 :NA.
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 A
(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?
_Mobus 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. Submitted previously.
8. Physical dimensions of the proposed interconnection station: NE Comer of 3900N 1700E
Small Generator Facilities Study Agreement - 3 -Swager Farms Project #307
9. Bus length from generation to interconnection station:
_______ TBD ______________________________ =-~--~~----~-----------
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*:
.i-------N one Anticipated:;_·· --------------------------..,....="-----~~~---~~----"""-
*To be completed in coordination with Transmission Provider.
13. Is the Small Generating Facility located in Transmission Provider's service area?
Yes ---:o.X~ __ No _____ If No, please provide name oflocal provider:
14. Please provide the following proposed schedule dates:
Begin Construction
Generator Step-Up Transformers
Receive Back Feed Power
Generation Testing
Commercial Operation
Date: 12/15/2011 __ '----"-"--"----
Date: _6/15/2012 ____ =-----
Date:. 7/15/2012:...,.._ _____ _
Date: 10/1/2012 ---------------
Small Generator Facilities Study Agreement -4-Swager Farms Project #307
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 39
Rowena Bishop
Idaho Power
1221 W. Idaho Street
Boise, Idaho 83702
[e-mail]
Re: Proof of Site Control
Swager Dairy
Dear Ms. Bishop:
The undersigned, Swager Farms, LLLP, is the Owner of Swager Dairy, as evidenced by copies
of the vesting deed and tax records attached. This is to acknowledge that New Energy Company
Two, LLC, is negotiating with Owner as regards the right to lease and occupy a site upon the
subject property for purposes of development of an anaerobic digester project. Please consider
this as Proof of Site Control as required to by Idaho Power to be submitted during the
interconnection process ongoing between Idaho Power and New' Energy Company Two, LLC.
Swager Farms, LLLP,
an Idaho limited liability partnership
Date: October _d__, 2011
t
i 45048.0004.25~554.1
TWIN f'ALLs COU:VTY
lfamflltl FRE"OER I CKSEN. WI Lll AMS
9:24:27 Am 12-22-2008
2008-026678
I. HCe': I III: IIi ••
II= IJf«< QUITCLAIM DEED
f.llll: aiEl
FOR VALUE RECEIVED, THE GERBEN AND MARIANSW AGERFAMILY TRUST,
under rrust agreement dated June 2l, 1991, Gerben Swager and Marian Swager, Trustees. hereby
remises, releases. and forever quitclaims unto SWAGER FARMS.. LLLP, an Idaho limited liability
partnership. 1707 East 3800 North, Buhl Idaho 83316-I 646. bereinafiercal1cd the "Grantee". all iiS
righL title and interest in the following dc:sc.ribcd rea.l property. to-on;t:
S~e EXHIBIT A atrach~d herdo.
Together with all water rights appurtenant thereto.
TO HAVE AND TO HOLD the premises. with their appurtenances unto said Grantee. and
the: Grantee's heirs and assigns forever.
DATED this I tit 1-l day of ~ • 2008.
"GRANTOR"
THE GERBEN AND MARlAN SWAGER
FAMJL Y TRUST. General Partner
STATE OF IDAHO
ss:
County of \J'~)
-1ft,_:_ .j., ~
MARIAN SWAG2Trustee
011 this~ day of Du~ , 2008, before me. the undersigned. a Notary Public in
and for said County and State, personally appe&Rd GERBEN SWAGER and MARIAN SWAGER.
husband and wife. Trustees oftheGerben and Marian Swager Family Trust ult/a did 6124/91. General
Partner. known to me to l'te such Trustees and thr: persons whose namc:s arr: subscribed to the within and
fo~going instrument. and who acknowledged to me that they executed the same on behalf of the Trust as
Geneml Partner of the Partnership.
upc;m NQ. 1
T ......... JO~ ..... lS~~,. rt• • 'l'tltla..U.c-s-, ...... s--.. :Ill: NB 114 Mil 114wiiXICal't .. w-10-....,...
....._11: N 112 NW 114
8VaiBC'I' 'J"'c Twill ..... mp_, E*ldllc .... o6 way
"'CZ! W).
T ........ l0 ............ 15 .... ..._N ''len Twtal'lln.~.lkWio
...._21: W 112 Mil U.. NW 114 88 114
suaDICT'tO: ...... hDI M'a' "" a.Mt~ .,~
fwin Fa1ls County Property Information Access
Twin Falls County Property Information Access
Parcel ID Number RP10S1SE212400A
1 Owner Information
!sWAGER FARMS, LLLP
b707E3800N ISl.;'HL ID 83316
I
Catca;ory
1-IRRGIDAG
10-RURAL HOMESITE
I 0 • RURAL HOMESITE
18 -OTHER LAND
19-WASTE
J l -RURAL RES BLDG
32 -RURAL IMP ON AG
[7 ·IMP TO MAN HSG
f48-MANUFHS W/SID
Propel't)' loformatioo
!377l 1700 E
!Tax Code: 620000 Zip: 0
isEC21 T lOR 15
INt/2 NW
Catcs!ory Information
L9.742
1.000
1.000
~4.226
14'.032
1:1.000
0.000
10.000
lo.OOO
Tu Information
Unit
AC
AC
AC
~c
lAC
Page 1 of .i
!Value
t21064
11480
11480
127539
08868
017670
17360
43433
Year Built 2000
Effective Year: 2000
Other rural land
Tax Year: 2006 ifax Year: 2007 tTax Year: 2008 Tax Year: 2009 Tax Year: 2010
Bill#: 28366 !Bill#: 29453 [BiU#: 30410 Bill#: 31365 Bill#: 32195
!Market: 2296090jMarlret: 2986733!f..wket: 29867331Market 23772041Market: 2377204
IImpr.Type: DWELL ic.B.: 0.00 lc.B.: 0.00 lc.B.: 0.00 lc.B.: 0.00 ~.B.: 0.00
!condition: AV IH.O.: o IJI.o.: o IFto.: o IJI.o.: 1.35331 lt-I.O.: 132014 I# Levels: 001 Special: 36.86 ~pecial: 36.86 !special: 36.86 ~pecial: 36.86 !special: 36.86
!Number Living Rooms: 1 ltax: 26246.90 ~ax: 29649.36 !Tax: 3023L88 ~ax: 23222.?:0 lr'Bx: 23987.08
!Number Bedrooms: 3
!Number Full Baths: 3 Half: 0 Fint Half: !First Half: !Fint Half: IFint Half: IFint Half:
tN"umber Family Rooms: 0 Cost: 0.00 Cost 0.00 !cost: 0.00 !cost 0.00 least: 0.00
!Number Dining Rooms: 0 oterest: 0.00 Interest: 0.00 lrnterest: 0.00 ~Interest: 0.00 Interest: 0.00
!Number Kitchens: I !Penalty; 0.00 'Penalty: 0.00 !Penalty: 0.00 jPenaity: 0.00 !Penalty: 0.00
ptber Rooms: 1 !Paid: 13123.45 Paid: 14824.68 Paid: 15115.94 ~aid: 11611.35 !Paid: 11993.54 ~~ Sinks:1 Wtr Heaters: I ConceDed: 0.00 Cancelled: 0.00 ~celled: 0.00 !cancelled: 0.00 lcaucened: 0.00
Number Fireplaces: I
n-otal Sq Feet: 2504 lsewnd Half: ISecood Half: lseeood Half: !second Half: !second Half:
rrotat Living Sq Feet: 2504 !cost: 0.00 ~ost 0.00 !cost: 0.00 !cost: 0.00 lcost: 0.00
IPri:m..Heat: Forced hot air-gas !Interest 0.00 nterest 0.00 llutet"est: 0.00 lfntercst: 0.00 !Interest: 0.00
!central Air: Y Penalty: 0.00 iPenalty: 0.00 !Penalty: 0.00 Penalty: 0.00 Wc:nalty: 0.00
RoofType:Hip !Paid: 13123.45 Paid: 14824.68 IPaid: 15115.94 Paid: 11611.35 1Paid: 11993.54
Roof Covering: Comp sh heavy lcanceUed: 0.00 Pmcelled.: 0.00 lcanceiJed: 0.00 !cancelled: 0.00 !{:anrelled.: 0.00
Int. Walls: Drywall
!Foundation: Formed cone
http://216.83.79.6:9951/resultdetail.php?parcel=RP10Sl5E212400A 10113/201 I
T\.\-in Falls County Property Information Access
Special Taxing Districts: AMER.FALLS
Page 2 of 4-
i)eed Refereuce Numben: 08-()26679 08-026678 02-009992 99-007758 TB88093489 Last Change Date: 12-22-2008
Relafed Parcel Numbers:
(none)
Parcel Commeuts:
ASSOC PARCEL -RPIOS15E210600; ASSOC PARCEL-RP10Sl5E213600; ASSOC PARCEL-RPl
OS15E214800; ASSOC PARCEL-RPIOSI5E216010; ASSOC PARCEL-RPIOSISE210010;
Owuership History:
2009 -2010 SWAGER FARMS, LLLP
2002 -2008 SWAGER, GERBEN
1999-2001 TRANSMUTATION PROPERTIES, INC
I 994 -1998 HAFLIGER, HENRY C JR
Scanned Worksheets:
1961 RURAL LAND APPRAISAL for: DROWN, LYNN R
1961 OUT BUILDING for: DROWN, LYNN R
1962 SUMMARY SHEET for: OPPLIGER, FRED
1970 SUMMARY SHEET for: SLIGAR, RODNEY L
1971 RURAL LAND APPRAISAL for: DROWN, LYNN R
1971 OUT BUILDING for: DROWN, LYNN R
1976 SUMMARY SHEET for: DROWN, LYNN R
1980 OUT BUILDING for: DROWN, LYNN R
1982 SUMMARY SHEET for: DROWN, LYNN R
1984 RURAL LAND APPRAISAL for: DROWN, LYNN R
1984 OUT BUILDING for: DROWN, LYNN R
1985 SUMMARY SHEET for: DROWN, LYNN R
1988 SUMMARY SHEET for: HAFLIGER, HENRY C JR
1989 OUT BUILDING for: DROWN, LYNN R
1989 MH APPRAISAL SHEET for: H&H DAIRY
1993 APPRAISAL HOUSE #1 for: HAFLIGER, HENRY C JR
1993 APPRAISAL HOUSE #2 for: HAFLIGER, HENRY C JR
1993 OUT BUILDING for: HAFUGER, HENRY C JR
1996 MH APPRAISAL SHEET for: H&H DAIRY
Additional Property Sheets:
Propettf Sheet: 2
Property Sheet: 3
Property Sheet: 4
Property Sheet: S
Property Sheet: 6
Property Sheet: 7
.Property Sheet: 8
Property Shc;et 9
Property Sheet-10
Property Sheet: 11
Property Sheet: 12
Property Sheet: 13
Property Sheet: 14
Property Sheet: 15
bttp://216.83.79.6:9951/resultdetail.php?parcel=RP10SI5E212400A 10/13/2011
Tv.in Falls County Property Infonnation Access
?:-operty Sheet 16
Property Sheet: l 7
?rooenv Sheec 18
£rooertv: Sheet: 19
Property Sheet: 20
Property Sheet; 21
Property Sheet 22
Property Sheet 23
Property Sheet 24
Property Sheet: 25
Pmoertv Sheet: 26
Prooerty Sheet 27
Property Sheet: 28
Property Sheet: 29
Property Sheet; 30
r rooerty Sheet: 31
Property Sheet 32
Property Sheet: 33
Property Sheet: 34
Property Sheet: 35
frooerty Sheet: 36
Property Sheet: 37
Property Sheet 38
Property Sheet; 39
Property Sheet: 40
Property Sheet: 41
Property Sheet: 42
Property Sheet: 43
Property Sheet: 44
Page 3 of4
Calculate taxes due-Interest as of date: I_ _ .. (do not use hyphens, enter as mmdd.yyyy) ~}~~j
Tax Payment History
Year_l!'ype_ ~ate !Hall IBatchiT_ranli rr~ IPenalJll In teres Total ~mArk :Payor User lfUP
~006 12-13-1 lso-35 13123.45 r.oo 0.00 13123.45 ~K4619-SWAGER BETHL IPa~ !£oo6 M FARMS I
~006 05-I7-~ 50-6 13123.45 0.00 0.00 13123.4~ CK 5027--SWAGER, IBETHL I IPaym_ent 2007 ~ Q_ERBEN
2007 i2-17-I 80-89 14824.6~ ~.00 ~.00 14824.6~ fcK 5632-SWAGER, !KAnnE Payment 2007 1M IGERBEN
I 2007 12-17-2 ~0. 89 L4824.6B ~-00 0.00 t4S24.6a ~KS632-fSWAGER, K.ATiflE Payment li007 1M P~RBEN
12008 12-29-50-19 Ull5.94 p.oo 0.00 15115.94 CK6718-SWAGER JERIE !Payment ~008 I M FARMS
rzoos 12-29-~ 50-19 15115.94 p.oo 0.00 15115.94 CK6718--SWAGER JERIE !Payment ~008 M FARMS
~009 12-17-CK 10008 !SWAGER ~AROL I 20-9 11611.35 0.00 0.00 11611.3~ if' ARMS, Payment 2009 I M !LLLP
12~17-2 ~0 ~9 11611.35 0.00 ~.00 I 161 L3'i ~K 10008
~WAGER ~OL i 2009 FARMS,
http:/1216.83. 79 .6:9951/resultdetail.php?parcel=RPl OS 15E212400A 10/13/2011
·i'>l.m Falls County Property Information Access Page4of4
:Pavment 12009 ~ ILLLP I
l !SWAGER i ~010 12-21-I 160-44 11993.54 ~.00 ~.00 ~K 11278-
aymenr 2010 I 1993.54 -M IF ARMS, fpEEKABOC ! IL..LLP
!zo10 06-17-~ SWAGER I
~0-51 11993.54 0.00 ~.00 I 1993.54 CK#ll882 !
;Payment 2011 FARMS, DEBBIE i M ILLLP I
use the browser BACK button to return to search results.
Begin New Parcel Search
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http:/1216.83. 79.6:995 1/resultdetail.php?parcel=RP 1 OS 15E212400A 10/13/2011
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 40
October 21, 2011
ldilho P.ower Company
A:ttn: Rowena Bishop
1221 W~ ldaho St.
Boise, ID &3702
RE; Swager FSA-GI 307
Dear Rowen~
We are pleasecl. tQ offer the e-!lo.los~d signed FaciHties Study. Agreement-for project #307 as well as the -deposit of
$18·,260. Additionally, we have reviewed correspondence. that has taken place since the draft Generation Intercomiection
Agreement issued by Idaho Eower on October 25 20 I 0 and we require your assistance in clarifying a few items
pertaining to the studies and ·the ·associated r.ewsions to the estimated iriter.connectiO'n costs for this project.
The priinaiy clarification We tequlre is the definition of the .new operating requirements which have caused a. significant
change .iri fue, ei)tjmated intercoi~J1ection cost for this proJect compared with the costs provided in the aforementioned
Pra~ Gei:t.er;ltio.n lri,terconnection A:greeJiletit s.till in our posseSsion. Please provide uummaTy, speci.fic to project-#.307,
ofthetelevantdiffererices between the:rtew op~ratingrequlrements which are now in effect.antl those that were in effect
when o:ur :gen¢ri):tiort intetcowec,:tion_ req\lest was accepted and .fimil studies wewsubm1tted by ldaho Power .
. Plea,se. als.Q review the tim:eline shoWii, In 'T~:t.ble 1 and ·provide .feedbaek con<:eming this table so ·that we can better
tinderstand tl!e evcm_ts that have ttahspire<l, siiice th¢ i$suan,ce of-the D.raft.GIA for project #307 ..
1'il~le :t:. Ti~eline
;1/~/11 Laura Knothe contacts Eric,
.Hackett
We provided art :updated of our progress on the Draft
G•A:and jnqutreg abour e"pected interconnection
t'rn,f'Hi'•n SChedUle,
Exergy Development Group, 802 W. Bannock, 12lh Floor, Boise, ID phone: [phone] fax: [phone]
A secondneed for clarificationhas to do with the"Operating.Requirements'section of the Al,lgust 26 Feasibility Study for
project #307 which reads; ''As part of the updated operating requirements, project #364 will be controlled to operate at
unity power factor with an operating bandwidth of± 300 kVAR~' Specifically, we would like to know if there hM Qeeil
some coirfusiort between the two different 'interconnection queue numbers being discussed early in. 2011, namely #307
and #364. TheJeasibility study is for project #307~ but some of the text is clearly referring to project #3M.
Plea5e do not hesitate to contact us with any questions regarding this letter or the enclosed. documents.
Leslie White
Project Manager, New Energy Two
Ph. 208.890A660
Enclosures: Executed Facility Study Agreements (2)
Deposit Check# 1571
Swager Site ControiDocumentation
Exergy Development Group, 802 W. Bannock, 12lh Floor, Boise, lD phone: [phone] fax: [phone]
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 41
Clark, Danielle
From:
Sent:
To:
Cc:
Subject:
Leslie-
Patterson, Marc
Thursday, December 08, 2011 4:35 PM
'Leslie White'
Bishop, Rowena; Hackett, Eric; Schultz, Trevor
FW: FSA for Project #307 Swager Farms
Idaho Power will not provide our detailed system information and customer load information to you. As indicated early,
when we completed the revised Feasibility Study we identified upgrades required to interconnect this project. In
addition, we reviewed the system changes suggested by Exergy at our November 3rd meeting, but those options had
already been considered in our study process. Therefore the upgrades identified in the Feasibility Study will be required
in order to connect this project.
In addition, because the project Facility Study will be completed next week, I suggest waiting for that study to be issued
before setting another meeting to discuss this project.
Marc Patterson
From: Leslie White [mailto:[e-mail]]
Sent: Wednesday, December 07, 2011 9:54AM
To: Patterson, Marc
; Subject: RE: FSA for Project #307 Swager Farms
Hello Marc,
Have you had time to consider this email and perhaps provide us with some direction with these concerns? Is there any
chance we can arrange to talk about this on Friday or Monday?
Warm regards,
Leslie
Leslie White
802 W Bannock, 12th Floor Boise, ID 83702
Office: 208.336.9793 1 Mobile: [phone]
Y.YJ.Vw ..,E~.&f£1Y_t;l?..veiQQ.tn~nt. <;:_Q_n.J
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 imended 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 deiiver it to the intended recipient, you are hereby notified that any dissemination. distribution or copying of this ccmmunication is strict!y prohibited If you
have received tl1is communication in el'rOJ, please immediately notify us by teiephone, and return ihe origina! message to us at the above emaii add1ess. Thank yoLI
From: Leslie White
Sent: Thursday, December 01, 2011 3:28 PM
To: 'Patterson, Marc'
Cc: 'Bishop, Rowena'; 'Hackett, Eric'; Josh Gunderson
Subject: FSA for Project #307 Swager Farms
1
Marc,
I spoke to Eric today and he has directed us back to you with regards to our questions surrounding #307. We continue to
struggle with depth of the upgrades required on the distribution line, but this is probably attributable to our lack of
familiarity with the line. In reviewing the two drawings presented under work order# 27328106, the single line (210-
62790) and the google earth map depicting the distribution line path and location of the POI and Substation, we are
wondering if you can fill in a few blanks and help us with defining the equipment and conductors on that line and perhaps
the line loads?
We recognize that your team is confident io the need to upgrade 2 miles of distribution line as a result of their analysis,
but I trust you can agree that the feasibility study does not provide the necessary details to support that conclusion. We are
in a position to want see the problem and the solution as you see it but we are unable to do so and thus you have been
peppered with questions as we seek to understand the situation better. Perhaps you are willing to share the details of your
system modeling and analysis, but if not, we would still find it useful to see the inputs to that model-namely drawings
that depict what infrastructure exists in the area shown on the google earth map provided previously. By allowing us to
see the problem as you see it, we can invest our time toward answering our own questions rather than infringing on your
time to answer them. If by some chance we come up with an alternative solution that works, all the better and then Exergy
will have to purchase further studies to investigate in detail. If we cannot find a such a solution, then at least your team
and our team will be seeing the same problem in the same way and we can move forward.
Warm regards,
Leslie
Leslie White
802 W Bannock, 12th Floor Boise, ID 83702
Office: 208.336.9793 1 Mobile: [phone]
'!!'/YYt.,~K~Y.<:i~Y-~.\.QQffi~Dl.G9~T1
This electronic or p1inted doclllnent 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. It the reader of this message is not the mtended recipient, or the employee or
agent responsible to deliver it to the intended recipient, you are hereby nO!ified that any dissemination. distribution or copying of this communication is strictly prohibited If you
have received this communication in error, please imrnediately 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-12-25
IDAHO POWER COMPANY
ATTACHMENT 42
December 15, 20fi
Leslie White
New Energy Two, LLC
802 W. Bannock
121h Floor
Boise, ID 83702
An IDACORP Company
Re: Swager Farms Dairy Digester Project Revised Draft Facility Study Rep0rt -Project #307
Dear Ms. White:
Idaho Power Company (IPC) has completed the Draft Facility,Study cost estimate for your Generator
Interconnection project based on the revised Feasibility Study Report dated August 26,, 2011. Attached
please fmd the Draft Facility Study Report (FSR). I am available to discuss the FS~ and begin
Construction arrangements for the project.
In order to proceed with this project, please provide your comme!1,ts to the Facility Study Report to me by
January 15, 2012 and indicate whether you wish to proceed with final design and construction. The final
report will be used to prepare a draft -.nerator Interconnection Agreement in preparation for
Construction. Rowena Bishop will be working with you=to fmalize the ln'ferconnection Agreement.
Before we can begin Constru.ct~o . or order materials .. you are responsible for contacting Idaho Power's
credit department to discuss credit r . uirements for construction funding. Please contact Aubrae Sloan
(208-388-5697) at your e liest conv ·ence. Once we receive funding, or the credit requirement is met,
we can proceed with construction oftl1eproject.
The actual cons..troction and labor charges-will b finalized approximately 90 days subsequent to project
completion. We will reeone,i]e any aver-or underpayment at that time.
I look forward to hearing from yqo soon.
Sincerely
Eric Hackett
Project Leader
Attachment: Swager Farms Dairy Digester Project Draft Facility Study Report with Drawings
Cc: R Bishop/IPC A Sloan/IPC RBauer/IPC D Walker/IPC
DRAFT
Generator Interconnection
Facility Study Report
for the
Swager Farms Dairy Digester Project-Project #307
for
New Energy Two, LLC
in
Twin Falls County, Idaho
December 15, 2011
An IDACORP Company
DRAFT-FACILITY STUDY REPORT (FSR)
Swager Farms Dairy Digester
Project #307
December 15, 2011
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 Twin Falls County, Idaho and connects to
the 12.5 kV system on Idaho Power Company's Clover (COVR-012) distribution line. The total
project output is 1.2 MW.
Interconnection Customer:
Leslie White
New Energy Two, LLC
802 W. Bannock
121h Floor
Boise, ID 83 702
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 Swager Farms Dairy Digester Project,
specifically Generator Interconnection Project #307, will be prepared for this project.
1.1 Interconnection Point
The Interconnection Point for the Swager Farms Dairy Digester Project will be the low-side
bushings on the padmounted transformer (SW1). The project's location is in T10S R15E Section
21 of Twin Falls County, Idaho. A drawing identifying the Interconnection Point is attached.
1.2 Point of Change of Ownership
The Point of Change of Ownership for the Swager Farms Dairy Digester Project will be the low­
side bushings on the padmounted transformer (SW1).
1.3 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.
1
The low-side disconnect switch shall be as specified or as determined by mutual agreement and
be readily accessible, operable, and lockable by Idaho Power personnel at all times.
1.4 Other Facilities Provided by Interconnection Customer
1.4.1 Telecommunications
In addition to communication circuits that may be needed by the Interconnection
Customer, the Interconnection Customer shall provide the, following communication
circuits for Idaho Power's use:
1. One POTS (Plain Old Telephone Service) dial-up circuit for querying the
revenue meter at the generation interconnection site.
2. One leased DDS (Digital Data Service) circuit for SCADA between the
generation interconnection site and the Twin Falls Service Building (273 Blue
Lakes Blvd. S., Twin Falls, ID 83301). This circuit must operate at 19.2 kbps
data rate or higher. Please note that Frame Relay service is not acceptable.
The Interconnection Customer is required to coordinate with a communications
provider to provide the communications circuits and pay the associated one time
setup and periodic charges. The communication circuits will need to be installed and
operational prior to generating into the Idaho Power system. Note that installation by
communications provider may take several months and should be ordered in advance
to avoid delaying the project. If the communication circuit types listed above are not
available at the site by a communications provider, the Interconnection Customer
shall confer with Idaho Power.
If high voltage protection is required by the communications provider for the
incoming communications provider cable, the high voltage protection assembly shall
be engineered and supplied by the Interconnect Customer. Options are available for
indoor or outdoor mounting. The high voltage protection assembly shall be located in
a manner that provides Idaho Power 24-hour access to the assembly for trouble­
shooting of Idaho Power owned equipment.
1.4.2 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.
1.4.3 Easements
The Interconnection Customer will provide to Idaho Power a surveyed (Metes &
Bounds) legal description along with exhibit map for Idaho Power's proposed
facilities. After the legal description has been delivered to IPCO for review, IPCO
will supply to the Interconnection Customer a completed IPCO easement for
signature by the land owner of record. Once the signatures have been secured, the
Interconnection Customer will return the signed easement to IPCO for recording.
1.4.4 Generator Output Limit Control
The Interconnection Customer will install equipment to receive signals from Idaho
Power Grid Operations for Generation Output Limit Control ("GOLC") -see Section
3 Operating Requirements.
2
1.4.5 Local Service
The Interconnection Customer is responsible to arrange for local service to their site,
as necessary.
1.4. 6 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.
1.5 Idaho Power Company's Interconnection Facilities
Idaho Power will install a standard generation interconnection package on the existing
distribution feeder (COVR-012) on private property southeast of the intersection of E. 3800
N. and N. 1700 E. in Twin Falls County, ID. See the attached work order maps (WO
27328106, sheet 1 of2) 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-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 if desired. (The Interconnection Customer is
responsible for providing and installing the appropriate cable.)
1.6 Facility Estimated Cost:
The following good faith estimates are provided in 2011 dollars:
nterconnectwn Facliltles: ;~
Overhead Gen~E~on InterconnectiC?E Package _-SU .. !J .. _~OT.'ALIIPIPCC ..... ,,,,,,,,,,, __ -------$200,000 '(J"~~~~ound Equipmen,! and 1500 kVA Trans_0_ryp.er _ $70,000
_,_,,_. ___ ,___ --~$2-'?,.Q_,OO~
~~.!:: Section. 6 for the Pr.f!Jl!ct Grand Total '
3
2. Milestones
lfR'¥-··,~·1{~":.-~· .. ,.;.:t,..~;-~~·li'!.i:-; ... 13~rnr~;;=':~"'•-·'r':4.."1! 1.f•!t•~·r.;·;~,~~~~~0~::-: ... ,·,:;(~P~.""~r!"Ill'lf})!t11 t;~ :~ .. to~ ·~. ·,,-~/!·'~!·_•,. · -~~~""-~~)i.-.' .. •~;Jriz;_.·,,Jl_~·l't.,, t:~ !t.-.,;.=:-l.,~· :~/'.-.).•.~ .. '.~ .... ~~=:'_.i~~·,~-'./ _>...::t!~iJ.f:1I\L"it-,.-}/r.:'-Jr -~-j ..... 1 ~t! -~-.._ .. ~1
TBD Construction Funds Received by IPCO
6 Months after Construction IPCO Construction Complete
Funds Received by IPCO
1 month after IPCO Construction VPCO Commissioning Complete
Complete
TBD by seller Commercial Operation Date
These milestone dates assume that material can be procured and labor resources are available.
Additionally, any permitting issues outside the immediate control of Idaho Power could also
influence the Commercial Operation Date.
3. Operating Requirements
The project is required to comply with the applicable Voltage and Current Distortion Limits found in
IEEE Standard 519-1992 IEEE Recommended Practices and requirements for harmonic Control in
Electrical Power Systems or any subsequent standards as they may be updated from time to time.
Voltage flicker at startup and during operation must be limited to less than 5% as measured at the
Interconnection Point.
The Project will be subject to reductions directed by Idaho Power Grid Operations during
transmission system contingencies and other reliability events. When these conditions occur, the
Project will be subject to Generator Output Limit Control ("GOLC") and will have equipment
capable of receiving an analog setpoint via DNP 3.0 from Idaho Power for GOLC. Generator
Output Limit Control will be a setpoint from Idaho Power to the Project indicating maximum output
allowed.
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.
Interconnection Customer will be able to modify power plant facilities on the Interconnection
Customer side of the Interconnection Point with no impact upon the operation of the transmission or
distribution system whenever the generation facilities are electrically isolated from the system and a
terminal clearance is issued by Idaho Power Company's Grid Operator.
4. Reactive Power
The Project must be controlled to operate as a VAr neutral system with a ± 300 kVAr operating
band.
4
5. Upgrades
5.1 Distribution Upgrades
Idaho Power will upgrade the existing distribution feeder (COVR-012) along E. 3550 N. from
the Clover Substation (approximately N. 1950 E.) west toN. 1700 E. The new conductor will be
336.4 All Aluminum (336AAC) and will require new support structures to accommodate the
larger wire.
Additionally, an existing fixed type capacitor bank on the feeder will be upgraded. In order to
avoid high voltage on the feeder during minimum load situations, the capacitor must have
automatic controls in order to switch on and off as necessary.
6. Estimated Costs
The following good faith estimates are provided in 2011 dollars:
Estimated Cost:
-•• ·,. 'i l!t.o;;~!~fw' ~:·· ·. ··:.~···r:··~-~ ··iffi·,., ·-·1~;.· i:f:5 _____ ,._ __ ,.,111 ...... •, • . ·:. -.1 · ·: :.,-:!:~~ .,·· '!-'J. (!Ailwltl ln '· .. " , ..•. ,. @!l:."U 3Silwc·.th
[17.terconnection Facilities (from section 1.6): --
Overhead Generation Interconnection Package IPC $200,000
,_OHUH ·-~·
Underground Equipment and 1500 kVA Transformer IPC $70,000 .. ,
TOTAL $270,000
-· ...
Upgrades to Distribution:
Reconductor Approximately 2.5 Miles to 336 AAC IPC $325,000
~ade C69 Capacitor IPC $30,000 .
TOTAL $355,000
GRAND TOTAL I $625,000
Note Regarding Transmission Service:
This Facility Study is a Network Resource Interconnection Facility Study. This study identifies the
facilities necessary to integrate the Generating Facility into Idaho Power's network to serve load within
Idaho Power's balancing area. Network Resource Interconnection Service in and of itself does not
convey any right to deliver electricity to any specific customer or Point of Delivery.
5
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01

BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 43
)
January 25, 2012
Leslie White
New Energy Two, LLC
802 W. Bannock
lth Floor
Boise, ID 83702
Re: Swager Farms Dairy Digester Project Revised Facility Study Report-Project #307
Dear Ms. White:
An IDACORP Company
Attached please fmd the Facility Study Report (FSR) based on the revised Feasibility Study Report dated
August 26, 2011. This report is considered fmal as no comments were received by IPCO from the draft
FSR sent December 15, 2011. Rowena Bishop will be using this FSR and 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 fimding. Please contact Aubrae Sloan
(208-388-5697) at your earliest convenience. Once we receive funding, or the credit requirement is met,
we can proceed with 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.
Sincerely,
Eric Hackett
Project Leader
Attachment: Swager Farms Dairy Digester Project Facility Study Report with Drawings
Cc: R Bishop/IPC A Sloan/IPC RBauer/IPC D Walker/IPC
Generator Interconnection
Facility Study Report
for the
Swager Farms Dairy Digester Project-Project #307
for
New Energy Two, LLC
in
Twin Falls County, Idaho
January 25, 2012
An IDACORP Company
FACILITY STUDY REPORT (FSR)
Swager Farms Dairy Digester
Project #307
January 25, 2012
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 Twin Falls County, Idaho and connects to
the 12.5 kV system on Idaho Power Company's Clover (COVR-012) distribution line. The total
project output is 1.2 MW.
Interconnection Customer:
Leslie White
New Energy Two, LLC
802 W. Bannock
1ih Floor
Boise, ID 83702
A Standard Generator Interconnection Agreement under Idaho Power Company's Open Access
Transmission Tariff (OATT) or Schedule 72 between Interconnection Customer and Idaho Power
Company -Delivery (Transmission Owner) for the Swager Farms Dairy Digester Project,
specifically Generator Interconnection Project #307, will be prepared for this project.
1.1 Interconnection Point
The Interconnection Point for the Swager Farms Dairy Digester Project will be the low-side
bushings on the padmounted transformer (SWl). The project's location is in T10S R15E Section
21 of Twin Falls County, Idaho. A drawing identifying the Interconnection Point is attached.
1.2 Point of Change of Ownership
The Point of Change of Ownership for the Swager Farms Dairy Digester Project will be the low­
side bushings on the padmounted transformer (SWl ).
1.3 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.
1
The low-side disconnect switch shall be as specified or as determined by mutual agreement and
be readily accessible, operable, and lockable by Idaho Power personnel at all times.
1.4 Other Facilities Provided by Interconnection Customer
1.4.1 Telecommunications
In addition to communication circuits that may be needed by the Interconnection
Customer, the Interconnection Customer shall provide the following communication
circuits for Idaho Power's use:
1. One POTS (Plain Old Telephone Service) dial-up circuit for querying the
revenue meter at the generation interconnection site.
2. One leased DDS (Digital Data Service) circuit for SCADA between the
generation interconnection site and the Twin Falls Service Building (273 Blue
Lakes Blvd. S., Twin Falls, ID 83301). This circuit must operate at 19.2 kbps
data rate or higher. Please note that Frame Relay service is not acceptable.
The Interconnection Customer is required to coordinate with a communications
provider to provide the communications circuits and pay the associated one time
setup and periodic charges. The communication circuits will need to be installed and
operational prior to generating into the Idaho Power system. Note that installation by
communications provider may take several months and should be ordered in advance
to avoid delaying the project. If the communication circuit types listed above are not
available at the site by a communications provider, the Interconnection Customer
shall confer with Idaho Power.
If high voltage protection is required by the communications provider for the
incoming communications provider cable, the high voltage protection assembly shall
be engineered and supplied by the Interconnect Customer. Options are available for
indoor or outdoor mounting. The high voltage protection assembly shall be located in
a manner that provides Idaho Power 24-hour access to the assembly for trouble­
shooting of Idaho Power owned equipment.
1.4.2 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.
1.4.3 Easements
The Interconnection Customer will provide to Idaho Power a surveyed (Metes &
Bounds) legal description along with exhibit map for Idaho Power's proposed
facilities. After the legal description has been delivered to IPCO for review, IPCO
will supply to the Interconnection Customer a completed IPCO easement for
signature by the land owner of record. Once the signatures have been secured, the
Interconnection Customer will return the signed easement to IPCO for recording.
1.4.4 Generator Output Limit Control
The Interconnection Customer will install equipment to receive signals from Idaho
Power Grid Operations for Generation Output Limit Control ("GOLC") -see Section
3 Operating Requirements.
2
1.4.5 Local Service
The Interconnection Customer is responsible to arrange for local service to their site,
as necessary.
1.4. 6 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.
1.5 Idaho Power Company's Interconnection Facilities
Idaho Power will install a standard generation interconnection package on the existing
distribution feeder (COVR-012) on private property southeast of the intersection of E. 3800
N. and N. 1700 E. in Twin Falls County, ID. See the attached work order maps (WO
27328106, sheet 1 of2) 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-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 if desired. (The Interconnection Customer is
responsible for providing and installing the appropriate cable.)
1.6 Facility Estimated Cost:
The following good faith estimates are provided in 2011 dollars:
Interconnection Facilities: ,_,.,,. .... ~ ...... , ________ _
Overhe~~. Generation Interconnectio~ Packa-""g_e --------1-IP_C _______ , _____ g OO,OQ_O
Underground E uipment and 1500 kV ~ J ransformer .. _ ···-IPC $70,000
SUBTOTAL $270,000] ----
.ee Section 6for the Project (]_rand Tot_a_l _______ _.___ _______ .. __ ._
3
2. Milestones
Commissioning Complete
TBD by seller Commercial Operation Date
These milestone dates assume that material can be procured and labor resources are available.
Additionally, any permitting issues outside the immediate control of Idaho Power could also
influence the Commercial eration Date.
3. Operating Requirements
The project is required to comply with the applicable Voltage and Current Distortion Limits found in
IEEE Standard 519-1992 IEEE Recommended Practices and requirements for harmonic Control in
Electrical Power Systems or any subsequent standards as they may be updated from time to time.
Voltage flicker at startup and during operation must be limited to less than 5% as measured at the
Interconnection Point.
The Project will be subject to reductions directed by Idaho Power Grid Operations during
transmission system contingencies and other reliability events. When these conditions occur, the
Project will be subject to Generator Output Limit Control ("GOLC") and will have equipment
capable of receiving an analog setpoint via DNP 3.0 from Idaho Power for GOLC. Generator
Output Limit Control will be a setpoint from Idaho Power to the Project indicating maximum output
allowed.
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.
Interconnection Customer will be able to modify power plant facilities on the Interconnection
Customer side of the Interconnection Point with no impact upon the operation of the transmission or
distribution system whenever the generation facilities are electrically isolated from the system and a
terminal clearance is issued by Idaho Power Company's Grid Operator.
4. Reactive Power
The Project must be controlled to operate as a V Ar neutral system with a ± 300 kVAr operating
band.
4
5. Upgrades
5.1 Distribution Upgrades
Idaho Power will upgrade the existing distribution feeder (COVR-012) along E. 3550 N. from
the Clover Substation (approximately N. 1950 E.) west toN. 1700 E. The new conductor will be
336.4 All Aluminum (336AAC) and will require new support structures to accommodate the
larger wire.
Additionally, an existing fixed type capacitor bank on the feeder will be upgraded. In order to
avoid high voltage on the feeder during minimum load situations, the capacitor must have
automatic controls in order to switch on and off as necessary.
6. Estimated Costs
The following good faith estimates are provided in 2011 dollars:
Estimated Cost:
I . ~hieihnt.t0·,~ .
.. I.; • ·. ~€}; oC.'•t7illi:i I • ·,.~·l~i·i:·.@i.a~@ffi~~"~ 0
I o'• '0'' ~ ' ...... •, .
n erconnec ton actttes rom sec ton . : ~--·
ll t t F, lt (fi t 1 6)
Overhead Generation Interconnection Package ..... ,_ .. ~c -$200,000 r-.,___ . .,_ ·-
Underground Equipment and 1500 kVA Transfo!iller IPC $70,000 ........... , .. _
TOTAL $2702000 l , ... ,_ .... __ ,.,, '-•·-·--·
Up_g_rades to Distribution:
Reconductor Approximately 2.5 Miles to 336 AAC IPC $325,000
Upgrade C69 Capacitor IPC $30,000
TOTAL! $355,00~
.,,,._, __ .
GRAND TOTAL $625,000
Note Regarding Transmission Service:
This Facility Study is a Network Resource Interconnection Facility Study. This study identifies the
facilities necessary to integrate the Generating Facility into Idaho Power's network to serve load within
Idaho Power's balancing area. Network Resource Interconnection Service in and of itself does not
convey any right to deliver electricity to any specific customer or Point of Delivery.
5
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BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 44
Clark, Danielle
from:
ent:
ro:
Leslie White [[e-mail]]
Tuesday, February 28, 2012 12:47 PM
Bishop, Rowena
Cc: Hackett, Eric
Subject: RE: Swager Farms-Gl 307
Hello Rowena,
I cannot as of yet confirm inservice dates but I appreciate knowing that construction is dependent upon receipt of funds
from Exergy.
James will be meeting with our technology provider within the next two weeks. I should be able to extract the pertinent
data to provide you with inservice dates at that point.
Thanks,
Leslie
Leslie White
802 W Bannock, 12th Floor Boise, 10 83702
Office: 208.336.9793 1 Mobile: [phone]
www.exergydevelopment.com
This electronic or printed document contains infonnation 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 strictly prohibited. If you
l1ave 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: Bishop, Rowena [mailto:[e-mail]]
Sent: Friday, February 24, 2012 2:51 PM
To: Leslie White
Cc: Hackett, Eric
Subject: RE: Swager Farms-GI 307
Leslie,
Please give me a call next week so we can finalize the milestones and determine your inservice
date. Note that construction may not begin until Idaho Power receives funding. Thank you.
Rowena Bishop
Oyerations .Jtna{yst
Interchange Oyerations -cliq 4
'Ext. 388-2658
From: Bishop, Rowena
Sent: Wednesday, February 15, 2012 11:54 AM
To: 'Leslie White'
;C.c: Hackett, Eric
Subject: RE: Swager Farms-timelines
Hi Leslie,
1
Just checking on you? Please let us know what your intended in service date is as soon as possible.
thx!
Rowena Bishop
Oyerations .:A.na[yst
Intercfiange Oyerations -cfiq 4
'Ext. 388-2658
From: Bishop, Rowena
Sent: Monday, February 06, 2012 3:08PM
To: 'Leslie White'
Cc: Hackett, Eric
Subject: Swager Farms-timelines
Hi Leslie,
I am ready to offer a Draft GIA for Swager Farms. Please review this milestone table and let us know
when you want to be in service so that we can proceed. Thank you.
Critical milestones and responsibility as agreed to by the Parties:
--:·,:~~!:I •,, __ ·: ', ,·,,;· \ 0 '1 .. \~
®:.."&1. . . : '. . . ; . . .
6mos(per FSR)
1 mo
Provided by Customer
Rowena
'Ext. 2658
i~(t~cjol't:ifjQ : ' ·1 '.'."'·".-" '' '.~•·i~-;.•, · . •.· .•. ·. ''/' ,_ ""'',· --~:~~.:',f'i ·,~I.;·. .-·. '• -,.._ :,.. _.., t,_,:..,, ~ , ,.. • \', • 0 • • ' ' J • ' ~ , I, 1, , , • • p, \o •; ~-, • ,-' • •• ' j~··", . 't'ii''l"'"'';~_t~;;:··."····· ··,:<·._,,, ... 1 ... :. '/ ·-•• \:•:,,· '.--~·,·~·;·. J"l.'. _l~:;·: oF'•'•' \, t-,2 '...... .., ... ~!_•~ ',l o I ,~'' 'r• ·"='· ,'?'.:·1!4, ~· I r•.,, '-o
Seller E&P funding received by IPCO $XXX
Seller Remaining Balance received by IPCO $XXX
Seller Customer GOLC ready to connect & customer telecomm
requirements are complete
~PCO IPCO Construction Complete
IJPCO IPCO Commissioning Complete
PCO Project Leader issues Construction Complete Letter
Seller Customer testing begins
'$eller Customer's requested In-Service Date
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 u'se of the information contained herein (including any reliance thereon) is STRICTLY PROHIBITED, If you received this
transmission in error, please immediately contact the sender and destroy the material in its entirety, whether in electronic or hard copy fonnat. Thank you.
2
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 45
Leslie White
Exergy Development Group of Idaho
802 W Bannock, Suite 1200
Boise, ID 83702
Re: Swager Farms Project-GI# 307
Dear Leslie:
March 22, 2012
IDAHO
POWER®
An IDA CORP Company
Via emaiVCertified 70102780000090951588
Attached please find a copy of the final Facility Study Report (FSR) dated January 25, 2012 and a draft
Generator Interconnection Agreement (GIA) for your Generator Interconnection project. The GIA is part
of Idaho Power Company's Rate Schedule 72 tariff approved by the Idaho Public Utilities Commission
(IPUC). The IPUC has the authority to review and modify these schedules periodically. You may view
the most current tariff at Idaho Power's website:
httpi'l/Www.idahop.awer~comlabeutus/regufatotvihf6/tMiffs.aS'fi The GIA Attaclunents are based on the
Facility Study Report. Please review the GIA Attaclunents 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 c_onyenience to discuss Idaho Power's credit requirements for construction
funding. Orice we receive funding, or the credit requirement is met, we can proceed with construction of
the project. The actual construction and labor charges will be reconciled approximately 90 days
subsequent to project completion.
Under the Generator Interconnection process, the following items must be provided to me on or before
execution of the GIA:
1. Your requested in service date to complete Attaclunent 3 of the GIA.
2.Insurance certification pursuant to Section 7 of the GIA (certificate, 1 endorsement for Additional
insured, and 1 for the cancellation notice)
3.Financial arrangements approved by Idaho Power credit department, or full payment for construction
Failure to submit all of the requested items above by April 23, 2012 will cause your Generator
Iriterconnection request to have been deemed withdrawn and terminated. Please contact me at your
earliest convenience with any questions.
Encl: Final Facility Study Report
draft GIA for Swager Farms Project# 307
Cc: (via email) Eric Hackett, Project Leader/IPC
Rich Bauer/IPC
Aubrae Sloan/IPC
Sincerely,
~L,~
Josh Harris
Operations Analyst
[e-mail]
P.O. Box 70 (83707)
1221 W. Idaho 5t.
Boise. ID 83702
Idaho Power Company Generator Interconnection Agreement# 307
I.P.U.C. No. 29 Tariff No. 101
March 22, 2012
GENERATOR INTERCONNECTION AGREEMENT
Schedule 72
SWAGER FARMS DAIRY DIGESTER PROJECT
1.2MW
Idaho Power Company Generator Interconnection Agreement# 307
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
5.3 Temporary Disconnection ................................................................................................... 2
6. Assignment. LiabilitY. Indemnity, Force majeure. Consequential Damages and Default ....... 5
7. Insurance ............................................................................................................................. 7
8. Miscellaneous ............................................................................... , ...................................... 7
9. Notices ................................................................................................................................. 8
10. Signatures ............................................................................................................................ 9
Attachment 1 ........................................................................................... 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 Interconnection Agreement# 307
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" 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 with, and operate in parallel with, the Company's
transmission/distribution system. Terms defined in Schedule 72 will have the same defined meaning in
this Agreement. If there is any conflict between the terms of this Agreement and Schedule 72,
Schedule 72 shall prevail.
3. This Agreement is not an agreement to purchase Seller's power.
Purchase of Seller's power and other services that Seller may require will be covered under separate
agreements. Nothing in this Agreement is intended to affect any other agreement between the
Company and Seller.
4. Attachments
Attached to this Agreement and included by reference are the following:
Attachment 1 -Description and Costs of the Generation Facility, Interconnection
Facilities, and Metering Equipment.
Attachment 2 ~ One-line Diagram Depicting the Generation Facility, Interconnection
Facilities, Metering Equipment and Upgrades.
Attachment 3-Milestones For Interconnecting the Generation Facility.
Attachment 4 -Additional Operating Requirements for the Company's Transmission
System Needed to Support the Seller's Generation Facility.
Attachment 5-Reactive Power.
Attachment 6 -Description of Upgrades required to integrate the Generation Facility and
Best Estimate of Upgrade Costs.
5. Effective Date. Term. Termination and Disconnection.
Idaho Power Company Generator Interconnection Agreement# 307
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 Pr-actice." 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, pr 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 ;n the judgrrii:mt 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 shalf 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# 307
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 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 Interconnection Agreement# 307
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 operatiRg voltage level by more than
ten percent (10%) at the Point of Delivery, in which ca~e 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 Fights-of-way and easements. to install, operate,
maintain, replace, and remove Idaho Power's Metering Equipment, Interconnection
Equipment, Disconnection Equipment, Protection EtjtJipment 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 p(;!rlies SQ as to provide Idaho Power with the access described
above. All documents graating such easements or rights-of-way shall be subject to
Idaho Power's approval and in r:.ecordable form.
5.4.2 Use of Public Rights-of-Way. The Parties agree that it is necessary to
avoid the adv.erse. 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-ft:Jmished 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 fu1ure 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# 307
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 maieure. Consequential Damages and Default.
6. 1 Assignment. This Agreement may be assigned by either Party upon twenty-one
(21) calendar days prior written notice and opportunity to object by the other Party; provided
that:
6. 1. 1 Either Party may assign this Agreement without the consent of the other
Party to any affiliate of the assigning Party with an equal or greater credit rating and with
the legal authority and operational ability to satisfy the obligations of the assigning Party
under this Agreement.
6.1.2 The Seller shall have the right to contingently assign this Agreement,
without the consent of the Company, for collateral 'Security purposes to aid in providing
financing for the Generation Facility, provided that the Seller will promptly notify the
Company of any such contingent assignment.
6. 1. 3 Any attempted assignment that violates this article is void and ineffective.
Assignment shall not relieve a Party of its obligations, nor shall a Party's obligations be
enlarged, in whole or in part, by reason thereof An assignee is responsible for meeting
the same financial, credit, and insurance obligations as the Seller. Where required,
consent to assignment will not be unreasonably withheld, conditioned or delayed.
6. 2 Limitation of Liability. Each Party's liability to the other Party for any loss, cost,
claim, injury, liability, or expense, including reasonable attorney's fees, relating to or arising from
any act or omission in its performance of this Agreement, shall be limited to the amount of direct
damage actually incurred. In no event shall either Party be liable to the other Party for any
indirect, special, consequential, or punitive damages, except as authorized by this Agreement.
6.3 Indemnity.
6. 3. 1 This provision protects each Party from liability incurred to third parties as
a result of carrying out the provisions of this Agreement. Liability under this provision is
exempt from the 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 # 307
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 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, floqd, storms, wars, hostilities, civil
strife, strikes and other labor disturbances, earthquakes, fires, lightning, epidemics, sabotage, or
changes in law or regulation occurring after the Operation Date, which, by the exercise of
reasonable foresight such party could not reasonably have been expected to avoid and by the
exercise of due diligence, it shall be unable to overcome. If either Party is rendered wholly or in
part unable to perform its obligations under this Agreement because of an event of Force
Majeure, both Parties shall be excused from whatever performance is affected by the event of
Force Majeure, provided that:
(1) The non-performing Party shall, as soon as is reasonably possible after
the occurrence of the Force Majeure, give the other Party written notice describing the
particulars of the occurrence.
(2) The suspension of performance shall be of no greater scope and of no
longer duration than is required by the event of Force Majeure.
(3) No obligations of either Party which arose before the occurrence causing
the suspension of performance and which could and should have been fully performed
before such occurrence shall be excused as a result of such occurrence.
Idaho Power Company Generator Interconnection Agreement# 307
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 nondefau/ting 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/apse 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 Jaws 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# 307
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:
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: -------------------------------------------------
Attention: -----------------------------------------------------
Address: ________ ~---------------------=---------------------City: _________________ ~State: ___ _cZip: ----------
Phone: Fax:
Idaho Power Company-Delivery
Attention: Corporate Cashier
PO Box 447
Salt Lake City Utah 84110-044 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# 307
I.P.U.C. No. 29. Tariff No. 101
Seller's Operating Representative:
Seller:-----------------------­Attention:
Page 9 of 9
--------------------------Address: ____________________________ _
City: __________ State: ____ Zip: ____ _
Phone: Fax: --------
Company's Operating Representative:
Idaho Power Company -Delivery
Attention: Outage Coordinator-System/Regional Dispatch
1221 W. Idaho Street
Boise, Idaho 83702
Phone: [phone], or 388-5175 during regtllar ltlusiness hours
(after hours-Regional Dispatch Southern Region 208-388-5190
9.5 Changes to the Notice Information. Either Party may change this information by
giving five (5) Business Days written notice pri0r to the effective date of the Ghange.
10. Signatures.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their
respective duly authorized representatives.
For the Seller
Name:
Date:
For the Company
Name:
Title: MC~nager, Grid Operations -Idaho Power Company, Delivery
Idaho Power Company Generator Interconnection Agreement# 307
I.P.U.C. No. 29. Tariff No. 101 Page 1 of 3
Attachment 1
Description and Costs of the Generation Facilitv. Interconnection Facilities and Metering
Equipment
Type of Interconnection Service:
Full Output:
Nominal Delivery Voltage:
Interconnection Details
Studied as an Idaho Power Network Resource under PURPA
1.2 MW
12.5 kV
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 Twim Falls County, Idaho and connects to the
12.5 kV system on Idaho Power Company's Clover (COVR-012) distribution line. The total project
output is 1.2 MW.
Interconnection Point
The Interconnection Point for the Swager Farms Dairy !Digester Project will be the low-side bushings on
the padmounted transformer (SW1). The project's location is in T10S R15E Section 21 of Twin Falls
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 padmounted transformer (SW1).
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 groundi171g measures, and associated
auxiliary equipment. Seller will bui,ld underground facilities to the Point of Change of Ownership for the
generator facility. The low-side disconnect switch snail be as specified or as determined by mutual
agreement and be readily accessible, operable, and lockable by Idaho Power personnel at all times.
The Seller will install equipment to receive signals from Idaho Power Company Grid Operations for
Generator Output Limit Control ("GOLC") -see Attachment 4 Operating Requirements.
The Seller will provide phone service to IPCo's generator interconnect package as described in
Telecommunications below.
The Seller will provide a DNP 3.0 serial data connection to the local Idaho Power Company SCADA
RTU when any communication with Seller-owned and maintained equipment is required for GOLC,
voltage control or other plant monitoring or control. Preliminary points lists and functional description
were provided to the Seller in the Facility Study Report.
All interconnection equipment electrically located on the generator side of the Point of Change
Ownership shall be owned and maintained by the Seller.
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.
Idaho Power Company Generator Interconnection Agreement# 307
I.P.U .C. No. 29, Tariff No. 101 Page 2 of 3
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 Idaho Power Company's Twin Falls
Service Building (273 Blue Lakes Blvd. S., Twin Falls, Idaho).
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.
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 customer will install ground fault limiting equipmenHhat will limit the zero sequence fault current to
20 amps at the Interconnection Point.
Easements
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 retum the signed easement to IPCO for recording. IPCO
construction will not proceed until the appropriate easements are secured.
Generator Output Limit Control
The Seller will install equipment to receive signals from Idaho Power Grid Operations for Generation
Output Limit Control ("GOLC") -see Attachment 4 Operating Requirements.
Local Service
The Seller is responsible to arrange for local service to their site, as necessary.
Idaho Power Company's Interconnection Facilities
Idaho Power will install a standard generation interconnection package on the existing distribution
feeder (COVR-012) on private prop.erty southeast of the intersection of E. 3800 N. and N. 1700 E. in
Twin Falls County, I D. See single line drawing as Attachment 2.
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-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 if desired. (The Interconnection Customer is responsible for providing and
installing the appropriate cable.)
Idaho Power Company Generator Interconnection Agreement# 307
I.P.U.C. No. 29, Tariff No. 101 Page 3 of 3
All interconnection equipment electrically located on the utility side of the Interconnection Point shall be
owned, operated, and maintained by Idaho Power.
Estimated Cost & Ownership
The following good faith estimates are provided in 2011 dollars
!overhead Generation Interconnection Packa e lPCO
lld"l1~~!g!<:)ll:!1:<:1. §g~J.}P!!lent and 1500 kV A Trans~ormer j1P9_0 __
, SUBTOTAL] L__-=· (See ATTACHMENT 6 ~-,. Pro}ect Grand TotaQj
$270,000 ..
$200,000
$70,000
Full payment is required up front in accordance with Schedule 72, unless payment arrangements are
made in advance with Idaho Power Operations Finance (see Attachment 3).
Billing for construction activities will be based upon actual expenditures.
Idaho Power Company Generator Interconnection Agreement # 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·:
Customer GOLC ready to connect & customer -rt=t•t=t,...nrnlrnl
1 ______________ , __ 1 ________ ~_n .. !~'~r·~""' ~areco~efete
Construction Complete
------------;--------+------~ -------------------------~ Commissioning Complete
1----------------~------~------~
rovided
Agreed to by:
For the Seller:
For the Transmission Provider
Idaho Power Company
Project Leader issues Const~uction Complete Letter
requested In-Service Date
--------------------~
Date ____________ _
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
Svstems 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 uGOLC'?
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 as
specified in the Facility Study Report.
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 as a VAr neutral system with a+/-300 kVAr operating band.
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
Comparw's Description of Special Facilities and Upgrades Required to Integrate the Generation
Facilitv and Best Estimate of Costs
As provided in Schedule 72 this Attachment describes Upgrades, Special Facilities, including
Network Upgrades, and provides an itemized best estimate of the cost of the required facilities.
Upgrades
Distribution Upgrades
Idaho Power will upgrade the existing distribution feeder (COVR-012) along E. 3550 N. from the Clover
Substation (approximately N. 1950 E.) west to N. 1700 E. The new c0nd~ctor will be 336.4 All Aluminum
(336AAC) and will require new support structures to accommodate ·the larger wire.
Additionally, an existing fixed type capacitor bank on the feeder will be upgraded. In order to avoid high
voltage on the feeder during minimum load situations, the capc:~citor must have automatic controls in order
to switch on and off as necessary.
f!pgrar._ies_: ___ _
approximate 2.5 mi~es to 336 AAC ____ ____,
C69 Capa~it_o_r __ -----...:.,
PROJECT GRAND $
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 46
•
Josh Harris
Operations Analyst
Idaho Power Company
1221 W. Idaho St
Boise, 10 83702
Re: Swager Farms Project-Gl #307
Dear Josh,
DEVELOPMENT GRO rgy
Regarding the Swager Farms GIA our electrical engineers are not able to link the project's
obligation to run at unity to Idaho Powers request to update your distribution capabilities
referenced in correspondence from Trevor Schultz, dated April 16th.
In light of the fact that the requirements and pricing established in the October 25, 2010
draft GIA, were substantially altered we believe it is necessary for Idaho Power to revisit the
upgrade requirements specific to the verified capacity of 800 kW.
We appreciate the information and the issues Trevor has identified, however, the study
cases presented and the type of equipment utilized invoke the following questions:
1. The use of a synchronous generator may increase the voltage stability of the line.
2. Do the regulators enable the steady state voltage without reconductoring? I believe
Cases 3 and 4 indicate the regulators fix the·problem.
3. We notice Case 4 is modeled without the capacitors, but if there is the requirement
to run at Unity Power Factor, the capacitors may not be intended for flicker control,
so why are they in the package?
The four cases presented seem to be incongruous with the present requirements, and as
James Carkulis pointed out in email correspondence today we intend to commence
construction in the 2nd quarter on this project, thus we need to obtain clarity on this issue
before signing the GIA.
Regards,
4 LL W£&
Leslie White
President, Exergy New Energy, Biogas Division
~xergy Development Group 802 W Bannock, 1lh ~loor Boise, ID 83702 P 208.336.9793 ~ 208.336.9431
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 47
Small Generator Feasibility Study Agreement
Swager Farms Project #307
Feasibility Study Agreement
THIS AGREEMENT is made and entered into this _J_day of 1'1aif 2012, by and
between £ 't ~ r'J r.; iJe vt../op rn~ ,_/ 6~ J-r d e..."-o , a ----=L=--=L.=C-.=--,-----------­
organized and existing 1under theiaws of the State of Lda..A o ,
("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 o:r;
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 #307, and
WHEREAS, Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Provider's Transmission System; and
WHEREAS, Interconnection Customer has requested the Transmission Provider to perform a
feasibility study to assess the feasibility of interconnecting the proposed Small Generating
Facility with the Transmission .Provider's Transmission System, and of any Affected Systems;
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the terms specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause to be
performed an interconnection feasibility study consistent the standard Small Generator
Interconnection Procedures in accordance with the Open Access Transmission Tariff.
3.0 The scope of the feasibility study shall be subject to the assumptions set forth in
Attachment A to this Agreement.
4.0 The feasibility study shall be based on the technical information provided by the
Interconnection Customer in the Interconne.ction 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
Small Generator Feasibility Study Agreement
Swager Farms Project #307
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 vi~1.tage: 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 systeni 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 thennal 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 lion-bonding estimated cost of facilities required to interconnect
the proposed Small Generating Facility and to address the identified short circuit
and power flow issues.
7.0 The feasibility study shall model the impact of the Small Generating Facility regardless
of purpose in order to avoid the further expense and interruption of operation for
reexamination of feasibility and impacts if the Interconnection Customer later changes
the purpose for which the Small Generating Facility is being installed.
8.0 The study shall include the feasibility of any interconnection at a proposed project site
where there could be multiple potential Points of Interconnection, as requested by the
Interconnection Customer and at the Interconnection Customer's cost.
9.0 In lieu of Feasibility Study deposit, Interconnection Customer agrees that study funds
will be drawn from the application fee for the perfonnance of the Interconnection
Feasibility Study.
Transmission Provider shall charge and Interconnection Customer shall pay the actual
costs ofthe 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.
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
Small Generator Feasibility Study Agreement
Swager Farms Project #307
feasibility study must be completed and the feasibility study report transmitted within 30
business days of the Interconnection Customer's agreement to conduct a feasibility study.
11.0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
12.0 The Interconnection Customer must pay any study costs that exceed the deposit without
interest within 30 calendar days on receipt of the invoice or resolution of any dispute. If
the deposit exceeds the invoiced fees; the Transmission Provider shall refund such excess
within 30 calendar days of the invoice without interest.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be duly executed by their
duly authorized officers or agents on the day and year first above written.
Transmission Provider: Interconnection Customer:
Idaho Power Company-Delivery
Si~OO: ~-fi:t Printe~~
Signed: __________ _
Printed: ------------------------
Title: ----'--JIIl-----'-"'CU\::..:....:.=..:t<:...,j~c...;e_r _____ _ Title: --------------------------
Date: s/9 I zot z. Date: ---------------------------------------------------
Small Generator Feasibility Study Agreement
Swager Farms Project #307
Attachment A to Feasibility Study Agreement
Assumptions Used in Conducting the Feasibility Study
The feasibility study will be based upon the infonnation set forth in the Interconnection Request
and agreed upon in the scoping meeting held on October 27, 2009:
The Feasibility Study will be completed no later than ~0 Business days after Idaho Power
receives the fully executed Interconnection Feasibility Study Agreement, unless any requested
study data in NOT received. Interconnection Customer will provide the requested study data as
soon as possible on or before the return of the executed Interconnection Feasibility Study
Agreem~nt.
1) Designation of Point of Interconnection and configuration to be studied.
2) Designation of alternative Points of Interconnection and cbnfj.gtJ.ration. . . ,
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-12-25
IDAHO POWER COMPANY
ATTACHMENT 48
TS
GENERATOR INTERCONNECTION
FEASIBILITY STUDY
For integration of the proposed
SWAGER FARMS DIGESTER PROJECT
In
TWIN FALLS COUNTY, IDAHO
To the
IDAHO POWER COMPANY ELECTRICAL SYSTEM
For
EXERGY
The
INTERCONNECTION CUSTOMER
RE-STUDY REPORT
June 1, 2012
Generator Interconnection Feasibility Study
General Interconnection Information
Station or
Date of Total Trans Line
Queue Request Location (MW) for POl
Original
Study: 12.5 kV
January 2010 through
Clover
Re-Study: Twin Falls (COVR)
#307 May 2012 County 0.8 substation
Short Circuit Analysis Results
System Changes Required: DYes [giNo
Power Flow Analysis Results
System Changes Required: (g!Yes DNo
The cost estimates for those upgrades are shown in Table 1 below.
Projected
In-Service
Date
2012
Type of facility
(combined cycle,
base load, CT, fuel
type)
Biofue1
Description Estimated Cost
Generation Interconnection Protection Package (Includes 12.47
kV recloser, controls, CTs, PTs) $225,000
Total Estimated Cost $225,000
Table 1: Estimated interconnection costs for 0.8 MW project at Swager Farms
Good Faith Cost Estimate
Interconnection cost estimate for 0.8 MW generator project: $225,000.
System Impact Study Required? DYes [gl No
This Feasibility Study only addresses the work required to interconnect the Swager Farms digester projects
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 #307 will be controlled to operate at unity power factor with an operating bandwidth of± 200
kVAR.
-1 -
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 49
June 4, 2012
Certified Mail# 70113500000156449143
Leslie White
Exergy
802 W Bannock, 121h Floor
Boise, ID 83 702
RE: Project# 307-Swager Farms
Dear Leslie:
An IOACORP Comp~ny
Enclosed is the Final Feasibility Study Report for the above-referenced project. The feasibility analysis
indicates that modification/addition of some facilities will be required to integrate the network resource
capacity addition of your project into the Idaho Power system. Please note, the Feasibility Study alone
does not provide any transmission rights nor determines the necessary network upgrades to move the
project energy to the load or a point of delivery in our system.
Since no SYSTEM IMPACT STUDY is needed, enclosed is a Facility Study Agreement (FSA) for the
next phase of the project. In order to proceed, and for your application to remain in the Generator
Interconnection study queue, Idaho Power must receive the 2 copies of the signed FSA, the completed
Attachments, and the deposit by July 9, 2012, otherwise your application will be deemed withdrawn.
The deposit under this FSA is $11,250.00, based on the estimated engineering costs.
The submittal should be sent to: Idaho Power Company, Attention: Josh Harris, 1221 West Idaho Street,
Boise, ID 83702. Please contact me if you have questions.
Sincerely,
Daniel Arjona
Engineering Leader, T &D Planning
208.3 88.2895
darjona@idahopower .com
•
Enclosures: Final Feasibility Study Report and FSA for signature (quantity 2)
CC (via email):
Josh Harris/IPC
Orlando Ciniglio/IPC
1221 W. Idaho St. (83702)
P.O. Box 70
Boise, ID 83707
Facilities Study Agreement
THIS AGREEMENT is made and entered into this __ day of 2012 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 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.
~OW, 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 ofthe 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 -Swager Farms Project #307
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 ofthose 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 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. BatTing 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.
1 0. 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 -Swager Farms Project #307
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/PT maintenance?
Yes No ---
4. Will a transfer bus on the generation side of the metering require that each meter set be
designed for the total plant generation? Yes No
(Please indicate on the one-line diagram).
5. What type of control system or PLC will be located at the Small Generating Facility?
6. What protocol does the control system or PLC use?
7. Please provide a 7.5-minute quadrangle map of the site. Indicate the plant, station,
transmission line, and property lines.
8. Physical dimensions ofthe proposed interconnection station:
Small Generator Facilities Study Agreement - 3 -Swager Farms Project #307
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 ___ IfNo, please provide name oflocal 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 -Swager Farms Project #307
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 50
July 9, 2012
Josh Harris
Idaho Power Company
1221 W. Idaho St
Boise, ID 83707
RE: FSA Project #307
Dear Josh,
y
Enclosed is the FSA and the attachment. With regards to our conversation this morning,
the Swager account with Idaho Power has a credit balance of $24,093 which will be used to
cover the deposit for this FSA and in part to cover the deposit for the FSA associated with
project #390, Eagle View Dairy.
:JLuJtL
Leslie White
The Biogas Division of Exergy New Energy
Exergy Development Group of Idaho
208-336-9793
[e-mail]
Enclosures: Completed FSA for project #307
kxergy Development Group 802 W Bannock, l21h r=loor Boise, ID 83702 P 208.336.9793 r= 208.336.9431
Facilities Study Agreement
TIDS AGREEMENT is made and entered into this _6th_day of_June 2012 by and
between Idaho Development Group of Idaho, a _LLC organized and
existing under the laws of the State of _Idaho , (''Interconnection Customer,11)
and Idaho Power Company, a Corporation existing under the laws of the State of Idaho
("Transmission Provider11). Interconnection Customer and Transmission Provider each may be
referred to as a 11Party, 11 or collectively as the 11Parties.11
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 Tmnsmission System;
WHEREAS, the Transmission Provider has completed a system impact study and provided the
results of said study to the Interconnection Customer; and
WHEREAS, the Interconnection Customer has requested the Transmission Provider to perform
a facilities study to specify and estimate the cost of the equipment, engineering, procurement and
construction work needed to implement the conclusions of the system impact study in
accordance with Good Utility Practice to physically and electrically connect the Small
Generating Facility with the Transmission Provider's Transmission System.
NOW, THEREFORE, in consideration of and subject to the mutual covenants contained herein
the Parties agreed as follows:
1.0 When used in this Agreement, with initial capitalization, the terms specified shall have
the meanings indicated or the meanings specified in the standard Small Generator
Interconnection Procedures.
2.0 The Interconnection Customer elects and the Transmission Provider shall cause a
facilities study consistent with the standard Small Generator Interconnection Procedures
to be performed in accordance with the Open Access Transmission Tariff.
3.0 The scope of the facilities study shall be subject to data provided in Attachment A to this
Agreement.
4.0 The facilities study shall specify and estimate the cost of the equipment, engineering,
procurement and construction work (including overheads) needed to implement the
conclusions of the system impact study(s).
The facilities study shall also identify (1) the electrical switching configuration of the
equipment, including, without limitation, transformer, switchgear, meters, and other
station equipment, (2) the nature and estimated cost of the Transmission Provider's
Small Generator Facilities Study Agreement - 1 -Swager Farms Project #307
Interconnection Facilities and Upgrades necessary to accomplish the interconnection, and
(3) an estimate ofthe·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 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:
Idaho Power Comp77:
Signed: 212.L~
Printed Name: £i,JU!VU2 Kos. Y/;24-1(._
Title: P JJ1 dey a..r .t.n&~
Date: 7 /z...~/;L
Small Generator Facilities Study Agreement
Interconnection Customer:
Sign~~ Pri~:;~----
Title: CEO ---------------------
Date: _June 6, 2012 ______ _
- 2 -Swager Farms Project #307
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:
One Connection c__ __ _
3. Will an alternate source of auxiliary power be available during CT/PT maintenance?
Yes No N/A
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. \Yhat 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:
Near 1707 E3800N,Buhl.ID 8331 6
Small Generator Facilities Study Agreement -3-Swager Farms Project #307
9. Bus length from generation to interconnection station:
___ To be determined, less than 300' anticipated ________________ _
I 0. Line length from interconnection station to Transmission Provider's Transmission
System.
_______ TBD ________________________________ ___
11. Tower number observed in the field. (Painted on tower leg)*:
____ Same as original study
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 _____ lfNo, please provide name oflocal provider:
14. Please provide the following proposed schedule dates:
Begin Construction Date: _August 15, 2012 _____ _
Generator Step-Up Transformers Date: _December 30, 2012 _____ _
Receive Back Feed Power
Generation Testing Date: _January 30, 2013 ______ _
Commercial Operation Date: _February 15, 2013 ____ _
Small Generator Facilities Study Agreement - 4 -Swager Farms Project #307
-------·--·--~ M -~r,;.:»ti.rt ~ lr;..~-- --- -~· ._ ...
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 51
September 10,2012
Leslie White
Exergy New Energy
802 W. Bannock
12th Floor
Boise, ID 83 702
An ID:ACOI!P Company
Re: Swager Farms Dairy Digester Project (0.8 MW Output) Facility Study Report-Project #307
Dear Ms. White:
Idaho Power Company (IPC) has completed the Facility Study cost estimate for your Generator
Interconnection project based on the revised Feasibility Study Report dated June 1, 2012. Attached
please find the Facility Study Report (FSR). Please note the FSR has different requirements than past
reports because the total output of the project is less than 1 megavoltampere (MV A), particularly there is
no requirement for you to provide telecommunications to the Idaho Power facilities.
In order to proceed with this project, please provide your comments to the Facility Study Report to me by
October 12, 2012 and indicate whether you wish to proceed with final design and construction. The final
report will be used to prepare a Generator Interconnection Agreement in preparation for Construction.
Josh Harris 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 Aubrae Sloan
(208-388-5697) 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: Swager Farms Dairy Digester Project Facility Study Report with Drawings
Cc: J Harris/IPC A Sloan/IPC D Walker/IPC
Generator Interconnection
Facility Study Report
for the
Swager Farms Dairy Digester Project-Project #307
for
Exergy New Energy
m
Twin Falls County, Idaho
September 10,2012
An IDACOI!P company
FACILITY STUDY REPORT (FSR)
Swager Farms Dairy Digester
Project #307
September 10,2012
1. General Facility Description
The proposed project will consist of a short three-phase distribution line extension and Idaho
Power's overhead generation interconnection package (for projects less than 1 MV A) including an
overhead recloser, metering package, local service power transformer, disconnect switches, and a
relay/control box. Additionally, one 1000 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 Twin Falls County, Idaho and connects to the 12.5 kV system on
Idaho Power Company's Clover (COVR-012) distribution line. The total project output is 0.8 MW.
Interconnection Customer:
Leslie White
Exergy New Energy
802 W. Bannock
12th Floor
Boise, ID 83702
A Standard Generator Interconnection Agreement under Idaho Power Company's Open Access
Transmission Tariff (OATT) or Schedule 72 between Interconnection Customer and Idaho Power
Company -Delivery (Transmission Owner) for the Swager Farms Dairy Digester Project,
specifically Generator Interconnection Project #307, will be prepared for this project.
1.1 Interconnection Point
The Interconnection Point for the Swager Farms Dairy Digester Project will be the low-side
bushings on the padmounted transformer (SW1). The project's location is in T10S R15E Section
21 of Twin Falls County, Idaho. A drawing identifying the Interconnection Point is attached.
1.2 Point of Change of Ownership
The Point of Change of Ownership for the Swager Farms Dairy Digester Project will be the low­
side bushings on the padmounted transformer (SWl).
1.3 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 shall be as specified or as determined by mutual agreement and
be readily accessible, operable, and lockable by Idaho Power personnel at all times.
1.4 Other Facilities Provided by Interconnection Customer
1.4.1 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.
1.4.2 Easements
The Interconnection Customer will provide to Idaho Power a surveyed (Metes &
Bounds) legal description along with exhibit map for Idaho Power's proposed
facilities. After the legal description has been delivered to IPCO for review, IPCO
will supply to the Interconnection Customer a completed IPCO easement for
signature by the land owner of record. Once the signatures have been secured, the
Interconnection Customer will return the signed easement to IPCO for recording.
1.4.3 Local Service
The Interconnection Customer is responsible to arrange for local service to their site,
as necessary.
1.4.4 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 cabling/wiring to the control box.
1.5 Idaho Power Company's Interconnection Facilities
Idaho Power will install a generation interconnection package on the existing distribution
feeder (COVR-012) on private property southeast of the intersection of E. 3800 N. and N.
1700 E. in Twin Falls County, ID. See the attached work order maps (WO 27328106, sheet
1 of2) 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-547 line
protection relay. The relay will be located in a pole mounted enclosure and will also contain
a test switch (TS4), isolation interface, power supply, DC converter, control switch and surge
protector.
Idaho Power will install (and subsequently own and maintain) one 1000 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 if desired. (The Interconnection Customer is
responsible for providing and installing the appropriate cable.)
2
1.6 Facility Estimated Cost:
The following good faith estimates are provided in 2011 dollars:
2. Milestones
12/10/12 Construction Funds Received by IPCO
6/10/13 IPCO Construction Complete
7110/13 IPCO Commissioning Complete
TBD by seller Commercial Operation Date
These milestone dates assume that material can be procured and labor resources are available.
Additionally, any permitting issues outside the immediate control of Idaho Power could also
influence the Commercial Date.
3. Operating Requirements
The project is required to comply with the applicable Voltage and Current Distortion Limits found in
IEEE Standard 519-1992 IEEE Recommended Practices and requirements for harmonic Control in
Electrical Power Systems or any subsequent standards as they may be updated from time to time.
Voltage flicker at startup and during operation must be limited to less than 5% as measured at the
Interconnection Point.
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.
Interconnection Customer will be able to modify power plant facilities on the Interconnection
Customer side ofthe Interconnection Point with no impact upon the operation of the transmission or
distribution system whenever the generation facilities are electrically isolated from the system and a
terminal clearance is issued by Idaho Power Company's Grid Operator.
3
4. Reactive Power
The Project must be controlled to operate as a VAr neutral system with a ± 200 kVAr operating
band.
5. Upgrades
5.1 Distribution Upgrades
Idaho Power will extend the existing distribution feeder (COVR-012) approximately 360 feet to
the east Gust north of the ponds) on private property to facilitate and locate the Interconnection
Facilities.
6. Estimated Costs
The following good faith estimates are provided in 2011 dollars:
Estimated Cost:
·~ :· .1IrBnl'2m;:rr'' ·. I .. I -• r ••
I . ·( c!l:~!TtltrilinJ · . (~;;.1@:1]!~:lti' .
!Interconnection Facilities (from section 1.6): -'"" -_,,._. -.. ,. __
Overhead Generation Interconnection Package & Line Extension IPC $145,000
Underground Equipment and 1000 kVA Transformer IPC $75,000
t=--SUBTOTAL $220,000
GRAND TOTAL $220,000,
l
Note Regarding Transmission Service:
This Facility Study is a Network Resource Interconnection Facility Study. This study identifies the
facilities necessary to integrate the Generating Facility into Idaho Power's network to serve load within
Idaho Power's balancing area. Network Resource Interconnection Service in and of itself does not
convey any right to deliver electricity to any specific customer or Point of Delivery.
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Proposed Location for Distribution Upgrades and Interconnection Facilities
Green = Distribution Upgrades
Yellow= Interconnection Facilities (Interconnection Package)
Red= Interconnection Facilities (Underground Cables and Vaults)
Purple= Interconnection Facilities (Padmounted Transformer)
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 52
Leslie White
Exergy
802 W. Bannock
12th Floor
Boise, ID 83702
An IOACORP company
September 14, 2012
Via email & Certified Mail #70 113500000156448948
Re: Swager Farms Dairy Digester Project-GI# 307
Dear Leslie:
Attached please find a copy of the final Facility Study Report (FSR) dated September 10, 2012, and a
Generator Interconnection Agreement (GIA) for the Swager Farms Dairy Digester Project. Pursuant to
our standard GIA process, you would normally be receiving a Draft GIA at this point in time with 30 days
to review and comment, after which time you would be offered a Final GIA which you would then have
30 days to execute and fund. The construction sequencing for this project, based upon Idaho Power's
current resources and scheduling would have Idaho Power construction completion sometime during
approximately May -June 2013, assuming you execute and fund the GIA by November. However,
because Idaho Power is aware of your need to bring this project online and operational before the end of
the year, and based upon the unique facts and circumstances of this project, Idaho Power was able to
rearrange some project scheduling and sequencing in an attempt to offer to you an opportunity to have the
interconnection work completed by the end of this year. In order for your project to come online by
December 31, 2012, we are providing you with a Final Facility Study Report and a Final GIA. Idaho
Power must have the executed GIA and funding no later than October 1, 2012, in order to complete
construction by this date.
Of course, if you wish to take time to review Draft versions of both the Facility Study and the GIA prior
to being offered a Final GIA, please let me know and I will provide you with those documents. This will
however push out the date by which we will have construction complete. I have provided you with a
Final GIA with this letter, which if acceptable upon your review, is ready for execution and funding. This
is being offered to you as a way to expedite the process so that Idaho Power may have the executed GIA
and funding by October 1, 20 12, in order for your project to come online by December 31, 2012.
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, if you wish to discuss Idaho Power's credit requirements for construction funding. Once we
receive funding, or the credit requirement is met, we will proceed with construction of the project. The
actual construction and labor charges will be reconciled approximately 90 days subsequent to project
completion.
Under the Generator Interconnection process, the following items must be provided to me on or before
execution of the GIA:
1. Proof of Site Control for the project
2. Insurance certification pursuant to Section 7 of the GIA (certificate, 1 endorsement for Additional
insured, and 1 for the cancellation notice)
3. Financial arrangements approved by Idaho Power credit department, or full payment for construction
P.O. 801< 70 (83707)
1221 W. Idaho St.
Boise, 10 8370i
Failure to submit all of the requested items above by October 1, 2012 will cause your Generator
Interconnection request to forgo the expedited process and construction completion will not be possible
by December 31 2012, and wilJ be schedule for approximately May/June 2013. We will then provide
you with a draft version of the Facility Study and work tlu·ough the Generator Interconnection Process as
per the normal schedule. Please contact me at your earliest convenience with any questions.
End: Final Facility Study Report
Sincerely,
Josh Harris
Operations Analyst
[e-mail]
GIA for Swager Farms Dairy Digester Project #307
Cc: (via email) Eric Hackett/IPC
Tess Park/IPC
Aubrae Sloan/IPC
Donovan Walker/IPC
Randy Allphin/IPC
Idaho Power Company Generator Interconnection Agreement# 307
I.P.U.C. No. 29 Tariff No. 101
September 14, 2012
GENERATOR INTERCONNECTION AGREEMENT
Schedule 72
Swager Farms Dairy Digester Project
O.BMW
Idaho Power Company Generator Interconnection Agreement# 307
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 .......................................................... 2
6. Assignment. Liability, Indemnity, Force majeure, Consequential Damages and Default. ...... 5
7. Insurance ............................................................................................................................. 7
B. 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# 307
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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","Transmission Owner",
"Idaho Power", "I PC" or "IPCO").
RECITALS
A. Seller will own or operate a Generation Facility that qualifies for service under Idaho
Power's Commission-approved Schedule 72 and any successor schedule.
B. The Generation Facility covered by this Agreement is more particularly described in
Attachment 1.
AGREEMENTS
1. Capitalized Terms
Capitalized terms used herein shall have the same meanings as defined in Schedule 72 or in the body
of this Agreement.
2. Terms and Conditions
This Agreement and Schedule 72 provide the rates, charges, terms and conditions under which the
Seller's Generation Facility will interconnect with, and operate in parallel with, the Company's
transmission/distribution system. Terms defined in Schedule 72 will have the same defined meaning in
this Agreement. If there is any conflict between the terms of this Agreement and Schedule 72,
Schedule 72 shall prevail.
3. This Agreement is not an agreement to purchase Seller's power.
Purchase of Seller's power and other services that Seller may require will be covered under separate
agreements. Nothing in this Agreement is intended to affect any other agreement between the
Company and Seller.
4. Attachments
Attached to this Agreement and included by reference are the following:
Attachment 1 -Description and Costs of the Generation Facility, Interconnection
Facilities, and Metering Equipment.
Attachment 2 -One-line Diagram Depicting the Generation Facility, Interconnection
Facilities, Metering Equipment and Upgrades.
Attachment 3-Milestones For Interconnecting the Generation Facility.
Attachment 4 -Additional Operating Requirements for the Company's Transmission
System Needed to Support the Seller's Generation Facility.
Attachment 5 -Reactive Power.
Attachment 6 -Description of Upgrades required to integrate the Generation Facility and
Best Estimate of Upgrade Costs.
Attachment 7-Generator Interconnection Control Requirements
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I.P.U.C. No. 29, Tariff No. 101 Page 2 of 9
5. Effective Date, Term, Termination and Disconnection.
5. 1 Term of Agreement. Unless terminated 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 Temporarv Disconnection. Temporary disconnection shall continue only for so
long as reasonably necessary under "Good Utility Practice." Good Utility Practice means any of the
practices, methods and acts engaged in or approved by a significant portion of the electric industry
during the relevant time period, or any of the practices, methods and acts which, in the exercise of
reasonable judgment in light of the facts known at the time the decision was made, could have been
expected to accomplish the desired result at a reasonable cost consistent with good business practices,
reliability, safety and expedition. Good Utility Practice is not intended to be limited to the optimum
practice, method, or act to the exclusion of all others, but rather to be acceptable practices, methods, or
acts generally accepted in the region. Good Utility Practice includes compliance with WECC or NERC
requirements. Payment of lost revenue resulting from temporary disconnection shall be governed by
the power purchase agreement.
5. 3. 1 Emergency Conditions. "Emergency Condition" means a condition or
situation: (1) that in the judgment of the Party making the claim is imminently likely to
endanger life or property; or (2) that, in the case of the Company, is imminently likely (as
determined in a non-discriminatory manner) to cause a material adverse effect on the
security of, or damage to the Company's transmission/distribution system, the
Company's Interconnection Facilities or the equipment of the Company's customers; or
(3) that, in the case of the Seller, is imminently likely (as determined in a non­
discriminatory manner) to cause a material adverse effect on the reliability and security
of, or damage to, the Generation Facility or the Seller's Interconnection Facilities. Under
Emergency Conditions, either the Company or the Seller may immediately suspend
interconnection service and temporarily disconnect the Generation Facility. The
Company shall notify the Seller promptly when it becomes aware of an Emergency
Condition that may reasonably be expected to affect the Seller's operation of the
Generation Facility. The Seller shall notify the Company promptly when it becomes
aware of an Emergency Condition that may reasonably be expected to affect the
Company's equipment or service to the Company's customers. To the extent
information is known, the notification shall describe the Emergency Condition, the extent
of the damage or deficiency, the expected effect on the operation of both Parties'
facilities and operations, its anticipated duration, and the necessary corrective action.
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5.3.2 Routine Maintenance. Construction, and Repair. The Company may
interrupt interconnection service or curtail the output of the Seller's Generation Facility
and temporarily disconnect the Generation Facility from the Company's
transmission/distribution system when necessary for routine maintenance, construction,
and repairs on the Company's transmission/distribution system. The Company will
make a reasonable attempt to contact the Seller prior to exercising its rights to interrupt
interconnection or curtail deliveries from the Seller's Facility. Seller understands that in
the case of emergency circumstances, real time operations of the electrical system,
and/or unplanned events, the Company may not be able to provide notice to the Seller
prior to interruption, curtailment or reduction of electrical energy deliveries to the
Company. The Company shall use reasonable efforts to coordinate such reduction or
temporary disconnection with the Seller.
5.3.3 Scheduled Maintenance. On or before January 31 of each calendar year,
Seller shall submit a written proposed maintenance schedule of significant Facility
maintenance for that calendar year and the Company and Seller shall mutually agree as
to the acceptability of the proposed schedule. The Parties determination as to the
acceptability of the Seller's timetable for scheduled maintenance will take into
consideration Good Utility Practices, Idaho Power system requirements and the Seller's
preferred schedule. Neither Party shall unreasonably withhold acceptance of the
proposed maintenance schedule.
5.3.4. Maintenance Coordination. The Seller and the Company shall, to the
extent practical, coordinate their respective transmission/distribution system and
Generation Facility maintenance schedules such that they occur simultaneously. Seller
shall provide and maintain adequate protective equipment sufficient to prevent damage
to the Generation Facility and Seller-furnished Interconnection Facilities. In some cases,
some of Seller's protective relays will provide back-up protection for Idaho Power's
facilities. In that event, Idaho Power will test such relays annually and Seller will pay the
actual cost of such annual testing.
5.3.5 Forced Outages. During any forced outage, the Company may suspend
interconnection service to effect immediate repairs on the Company's
transmission/distribution system. The Company shall use reasonable efforts to provide
the Seller with prior notice. If prior notice is not given, the Company shall, upon request,
provide the Seller written documentation after the fact explaining the circumstances of
the disconnection.
5.3.6 Adverse Operating Effects. The Company shall notify the Seller as soon
as practicable if, based on Good Utility Practice, operation of the Seller's Generation
Facility may cause disruption or deterioration of service to other customers served from
the same electric system, or if operating the Generation Facility could cause damage to
the Company's transmission/distribution system or other affected systems. Supporting
documentation used to reach the decision to disconnect shall be provided to the Seller
upon request. If, after notice, the Seller fails to remedy the adverse operating effect
within a reasonable time, the Company may disconnect the Generation Facility. The
Company shall provide the Seller with reasonable notice of such disconnection, unless
the provisions of Article 5.3.1 apply.
5.3. 7 Modification of the Generation Facilitv. The Seller must receive written
authorization from the Company before making any change to the Generation Facility
that may have a material impact on the safety or reliability of the Company's
transmission/distribution system. Such authorization shall not be unreasonably withheld.
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I.P.U.C. No. 29 , Tariff No. 101 Page 4 of 9
Modifications shall be done in accordance with Good Utility Practice. If the Seller makes
such modification without the Company's prior written authorization, the latter shall have
the right to temporarily disconnect the Generation Facility.
5.3. 8 Reconnection. The Parties shall cooperate with each other to restore the
Generation Facility, Interconnection Facilities, and the Company's
transmission/distribution system to their normal operating state as soon as reasonably
practicable following a temporary disconnection.
5.3.9 Voltage Levels. Seller, in accordance with Good Utility Practices, shall
minimize voltage fluctuations and maintain voltage levels acceptable to Idaho Power.
Idaho Power may, in accordance with Good Utility Practices, upon one hundred eighty
(180) days' notice to the Seller, change its nominal operating voltage level by more than
ten percent (10%) at the Point of Delivery, in which case Seller shall modify, at Idaho
Power's expense, Seller's equipment as necessary to accommodate the modified
nominal operating voltage level.
5. 4 Land Rights.
5.4. 1 Seller to Provide Access. Seller hereby grants to Idaho Power for the
term of this Agreement all necessary rights-of-way and easements to install, operate,
maintain, replace, and remove Idaho Power's Metering Equipment, Interconnection
Equipment, Disconnection Equipment, Protection Equipment and other Special Facilities
necessary or useful to this Agreement, including adequate and continuing access rights
on property of Seller. Seller warrants that it has procured sufficient easements and
rights-of-way from third parties so as to provide Idaho Power with the access described
above. All documents granting such easements or rights-of-way shall be subject to
Idaho Power's approval and in recordable form.
5.4.2 Use of Public Rights-of-Wav. The Parties agree that it is necessary to
avoid the adverse environmental and operating impacts that would occur as a result of
duplicate electric lines being constructed in close proximity. Therefore, subject to Idaho
Power's compliance with Paragraph 5.4.4, Seller agrees that should Seller seek and
receive from any local, state or federal governmental body the right to erect, construct
and maintain Seller-furnished Interconnection Facilities upon, along and over any and all
public roads, streets and highways, then the use by Seller of such public right-of-way
shall be subordinate to any future use by Idaho Power of such public right-of-way for
construction and/or maintenance of electric distribution and transmission facilities and
Idaho Power may claim use of such public right-of-way for such purposes at any time.
Except as required by Paragraph 5.4.4, Idaho Power shall not be required to
compensate Seller for exercising its rights under this Paragraph 5.4.2.
5.4.3 Joint Use of Facilities. Subject to Idaho Power's compliance with
Paragraph 15.4.4, Idaho Power may use and attach its distribution and/or transmission
facilities to Seller's Interconnection Facilities, may reconstruct Seller's Interconnection
Facilities to accommodate Idaho Power's usage or Idaho Power may construct its own
distribution or transmission facilities along, over and above any public right-of-way
acquired from Seller pursuant to Paragraph 5.4.2, attaching Seller's Interconnection
Facilities to such newly constructed facilities. Except as required by Paragraph 5.4.4,
Idaho Power shall not be required to compensate Seller for exercising its rights under
this Paragraph 5.4.3.
5.4. 4 Conditions of Use. It is the intention of the Parties that the Seller be left in
substantially the same condition, both financially and electrically, as Seller existed prior
Idaho Power Company Generator Interconnection Agreement# 307
I.P.U.C. No. 29, Tariff No. 101 Page 5 of 9
to Idaho Power's exercising its rights under this Paragraph 5.4. Therefore, the Parties
agree that the exercise by Idaho Power of any of the rights enumerated in Paragraphs
5.4.2 and 5.4.3 shall: (1) comply with all applicable laws, codes and Good Utility
Practices, (2) equitably share the costs of installing, owning and operating jointly used
facilities and rights-of-way. If the Parties are unable to agree on the method of
apportioning these costs, the dispute will be submitted to the Commission for resolution
and the decision of the Commission will be binding on the Parties, and (3) shall provide
Seller with an interconnection to Idaho Power's system of equal capacity and durability
as existed prior to Idaho Power exercising its rights under this Paragraph 5.4.
6. Assignment. Liability, Indemnity, Force majeure, Consequential Damages and Default.
6. 1 Assignment. This Agreement may be assigned by either Party upon twenty-one
(21) calendar days prior written notice and opportunity to object by the other Party; provided
that:
6.1.1 Either Party may assign this Agreement without the consent of the other
Party to any affiliate of the assigning Party with an equal or greater credit rating and with
the legal authority and operational ability to satisfy the obligations of the assigning Party
under this Agreement.
6.1.2 The Seller shall have the right to contingently assign this Agreement,
without the consent of the Company, for collateral security purposes to aid in providing
financing for the Generation Facility, provided that the Seller will promptly notify the
Company of any such contingent assignment.
6.1.3 Any attempted assignment that violates this article is void and ineffective.
Assignment shall not relieve a Party of its obligations, nor shall a Party's obligations be
enlarged, in whole or in part, by reason thereof. An assignee is responsible for meeting
the same financial, credit, and insurance obligations as the Seller. Where required,
consent to assignment will not be unreasonably withheld, conditioned or delayed.
6.2 Limitation of 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 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
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I .P.U.C. No. 29, Tariff No. 101 Page 6 of 9
reasonable opportunity to proceed under this article, to assume the defense of such
claim, such indemnified person may at the expense of the indemnifying Party contest,
settle or consent to the entry of any judgment with respect to, or pay in full, such claim.
Failure to defend is a Material Breach.
6.3.4 If an indemnifying party is obligated to indemnify and hold any
indemnified person harmless under this article, the amount owing to the indemnified
person shall be the amount of such indemnified person's actual loss, net of any
insurance or other recovery.
6.3.5 Promptly after receipt by an indemnified person of any claim or notice of
the commencement of any action or administrative or legal proceeding or investigation
as to which the indemnity provided for in this article may apply, the indemnified person
shall notify the indemnifying party of such fact. Any failure of or delay in such notification
shall be a Material Breach and shall not affect a Party's indemnification obligation unless
such failure or delay is materially prejudicial to the indemnifying party.
6.4 Force Majeure. As used in this Agreement, "Force Majeure" or "an event of
Force Majeure" means any cause beyond the control of the Seller or of the Company which,
despite the exercise of due diligence, such Party is unable to prevent or overcome. Force
Majeure includes, but is not limited to, acts of God, fire, flood, storms, wars, hostilities, civil
strife, strikes and other labor disturbances, earthquakes, fires, lightning, epidemics, sabotage, or
changes in law or regulation occurring after the Operation Date, which, by the exercise of
reasonable foresight such party could not reasonably have been expected to avoid and by the
exercise of due diligence, it shall be unable to overcome. If either Party is rendered wholly or in
part unable to perform its obligations under this Agreement because of an event of Force
Majeure, both Parties shall be excused from whatever performance is affected by the event of
Force Majeure, provided that:
(1) The non-performing Party shall, as soon as is reasonably possible after
the occurrence of the Force Majeure, give the other Party written notice describing the
particulars of the occurrence.
(2) The suspension of performance shall be of no greater scope and of no
longer duration than is required by the event of Force Majeure.
(3) No obligations of either Party which arose before the occurrence causing
the suspension of performance and which could and should have been fully performed
before such occurrence shall be excused as a result of such occurrence.
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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 6.5.1 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/apse 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
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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: _________ -=-State: ____ .Zip: ____ _
Phone: Fax: -----------
If to the Company:
Idaho Power Company -Delivery
Attention: Load Serving Operations Director
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 Box447
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.
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Seller's Operating Representative:
Seller:-----------------------­
Attention:--------------------------
Address: _______________ ~----------
City: ___________ State: ____ ,Zip: ____ _
Phone: Fax: --------
Company's Operating Representative:
Idaho Power Company -Delivery
Attention: Outage Coordinator-System/Regional Dispatch
1221 W. Idaho Street
Boise, Idaho 83702
Phone: [phone], or 388-5175 during regular business hours
(after hours-System Dispatch Southern Region 208-388-5190)
9.5 Changes to the Notice Information. Either Party may change this information by
giving five (5) Business Days written notice prior to the effective date of the change.
10. Signatures.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their
respective duly authorized representatives.
For the Seller
Name: --------------------------
Title: ____________________ _
Date: __________ _
For the Company
Name: -------------------------
Title: Director, Load Serving Operations-Idaho Power Company, Delivery
Date:
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I.P.U.C. No. 29, Tariff No. 101 Page 1 of 2
Attachment 1
Description and Costs of the Generation Facility, Interconnection Facilities and Metering Equipment
Interconnection Details
Type of Interconnection Service: Studied as an Idaho Power Network Resource under PURPA
Full Output: 0.8 MW
Nominal Delivery Voltage: 12.5 kV
General Facility Description
The proposed project will consist of a short three-phase distribution line extension and Idaho Power's
overhead generation interconnection package including an overhead recloser, metering package, local
service power transformer, disconnect switches, and a relay/control box. Additionally, one 1000 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 Twin Falls County,
Idaho and connects to the 12.5 kV system on Idaho Power Company's Clover (COVR-012) distribution
line. The total project output is 0.8 MW.
Interconnection Point
The Interconnection Point for the Swager Farms Dairy Digester Project will be the low-side bushings on
the padmounted transformer (SW1). The project's location is in T10S R15E Section 21 of Twin Falls
County, Idaho.
A drawing identifying the Point of Interconnection is included as Attachment 2. The Point of Change of
Ownership is electrically the same as the Interconnection Point.
Point of Change of Ownership
The Point of Change of Ownership for the Swager Farms Dairy Digester Project will be the low-side
bushings on the pad mounted transformer (SW1 ).
Seller's Interconnection Facilities
The Swager Farms Project 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. Seller will build underground facilities to the Point of Change of
Ownership for the generator facility.
The low-side disconnect switch shall be as specified or as determined by mutual agreement and be
readily accessible, operable, and lockable by Idaho Power personnel at all times.
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
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 Seller requires the ability to monitor information related to the Idaho Power recloser in the
generation interconnection package they are required to supply their own cabling/wiring to the control
box.
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Easements
The Seller will provide to Idaho Power a surveyed (Metes & Bounds) legal description along with exhibit
map for Idaho Power's proposed facilities. After the legal description has been delivered to I PCO 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.
Local Service
The Seller is responsible to arrange for local service to their site, as necessary.
Idaho Power Company's Interconnection Facilities
Idaho Power will install a generation interconnection package on the existing distribution feeder
(COVR-012) on private property southeast of the intersection of E. 3800 N. and N. 1700 E. in Twin
Falls County, ID.
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-547 line protection relay.
The relay will be located in a pole mounted enclosure and will also contain a test switch (TS4), isolation
interface, power supply, DC converter, control switch and surge protector.
Idaho Power will install (and subsequently own and maintain) one 1000 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
Seller about the recloser if desired. (The Seller is responsible for providing and installing the
appropriate cable.)
See single line drawing as Attachment 2.
All interconnection equipment electrically located on the utility side of the Interconnection Point shall be
owned, operated, and maintained by Idaho Power.
Estimated Cost & Ownership
The following good faith estimates are provided in 2012 dollars:
llnterconn~c~!,~,!?._Fa_c:_!Hties: --·-.. ~
hPc
-·--j
!overhead Generation Interconnection Packa.9e & Line Extension $145,0001
!underground Equiprr1ent and 1000 kVA Transformer hPc
-'I
$75,000i
! SUBTOTAL
--.I
i $220,000i -·----
lrsee ATTACHMENT 6for Project Grand Total) ! j
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
Idaho Power Company agrees only to the Construction timelines under its direct control provided in the
Facility Study Report for this Project.
These milestones will begin, and the construction schedule referenced below, will only be valid upon
receipt of funding in full from the Seller or their authorized third party no later than the date set forth
below for such payment. Additionally, failure by Seller to make the required payments as set forth in
this Agreement by the date(s) specified below will be a material breach of this Agreement, which may
result in any or all of the following: (i) loss of milestone dates and construction schedules set forth
below: (ii) immediate termination of this Agreement by Idaho Power; (iii) removal from the generator
interconnection queue.
Critical milestones and responsibility as agreed to by the Parties:
:D.'tl\'' ' '
10/1/2012
10/1/2012
12/10/2012
12/31/2012
12/31/2012
12/31/2012
12/31/2012
12/31/2012
Agreed to by:
For the Seller:
For the Transmission Provider
Idaho Power Company
w,:q;r11"\1tlr.!'l· . :filiW· l~llf'm•:lfl'O ·
Seller IPCO receives the remaining balance of Construction
estimate $220, 000 OR Credit arrangements are approved
by_IPCO
IPCO Long Lead Time Material Ordered (approximately 8-10 week
lead time)
IPCO IPCO Construction Complete
IPCO IPCO Commissioning Complete
IPCO Project Leader issues Construction Complete Letter
IPCO Director of Load Serving Operations authorizes project to be
energized, upon verification that Seller has previously met
Schedule 72, Sec 7 Insurance requirements
Seller Seller testing begins
Seller Seller's requested In-Service Date
Date. _____ _
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 Svstems
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 system and a terminal clearance is issued by Idaho Power Company's
Grid Operator.
Voltage flicker at startup and during operation will be limited to less than 5% as measured at the
Interconnection Point. It is preferable to bring each generating unit online separately to minimize
voltage flicker on the distribution system.
Low Voltage Ride Through
The Project must be capable of riding through faults on adjacent section of the power system without
tripping due to low voltage. It has been determined, through study, that the Project must be capable of
remaining interconnect for any single phase voltage as low as 0. 7 PU for 30 cycles, and for all three
phase voltages as low as 0.8 PU for 30 cycles.
"As-Built" Generation Interconnection Data
Modifications of the interconnection equipment or material changes for the Seller's generator facility
that results in changes to modeling data (steady state data and dynamics data) previously submitted by
the Seller for the System Impact Study requires prior approval from Idaho Power Company in order to
validate that the System Impact Study results remain valid for the modified equipment or material
changes to the facility. Validation of these results may require additional SIS re-study work. Should
Seller make any changes to facility that were not considered in any studies or outlined in this
agreement, Idaho Power reserves the right to delay interconnection until any applicable re-study work
has been completed and approval has been granted.
The Seller is encouraged to notify Idaho Power Company of such changes as soon as possible in order
to minimize potential delays in energization of the Project.
Equipment settings determined during final commissioning of the generator facility that are represented
in the Transmission Provider's network models shall be provided by the Seller within 30 days following
the date of commercial operations. Such settings include but are not limited to interconnection
transformer energized tap position, load tap changer control settings, control setpoints (pickup level and
time delay) of automatic switching schemes for static reactive power equipment, and final control
characteristics of dynamic reactive power equipment.
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+/-200 kVAr.
Voltage flicker at startup and during operation will be limited to less than 5% as measured at the
Interconnection Point.
Idaho Power Company Generator Interconnection Agreement# 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.
Substation Upgrades
$0
Distribution Upgrades
$0
Transmission Upgrades
$0
Upgrades
The following good faith estimates are provided in 2012 dollars:
·--·--·'---------
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 53
Clark, Danielle
From: Harris, Joshua
Sent:
To:
Monday, October 08, 2012 2:21 PM
Clark, Danielle
Subject: FW: Swager Farms (GI 307) Interconnection Agreement
Thanks,
Josh Harris
OPERATIONS ANALYST
Idaho Power I Generator Interconnection
208-388-5751
Email [e-mail]
From: Walker, Donovan
Sent: Thursday, September 20, 2012 4:39 PM
To: '[e-mail]'
Cc: Harris, Joshua; Blackburn, Rex; Allphin, Randy; Anderson, John; Park, Tessia
Subject: RE: 'Swager Farms (GI 307) Interconnection Agreement
Ms. White,
There has been no discussion, and absolutely no agreement from Idaho Power to extend the Scheduled Operation Date
from the PPA for this project, as you have referred to in conversation with Idaho Power's Josh Harris, and as you refer to
below. The Scheduled Operation Date for the project remains October 1, 2012. This date will obviously not be met, and
consequently under the terms of the PPA a 90 cure period will commence.
Idaho Power, through Josh Harris' communication and forwarding of a GIA to you last week, extended an option for the
project to proceed with the required interconnection work, and a commitment from Idaho Power that it would have its
required work completed by year end, 2012, IF the project executes the final GIA AND pays the required funding NO
LATER THAN OCTOBER 1, 2012. Mr. Harris' letter of September 14, 2012, states clearly that in order to take advantage
of this expedited process and construction, you must authorize Idaho Power to move forward by executing the GIA and
paying the required funding no later than October 1, 2012. If this date is missed, then it will not be possible to complete
the required interconnection work before the end of the year 2012.
We look forward to your response.
Donovan E. Walker
LEAD COUNSEL
Idaho Power I Legal
208-388-5317
--------------------
From: Harris, Joshua
Sent: Wednesday, September 19, 2012 9:55 AM
1
To: Darrington, Michael; Allphin, Randy; Walker, Donovan
Subject: FW: Swager Farms (GI 307) Interconnection Agreement
FYI.
Thanks,
Josh Harris
OPERATIONS ANALYST
Idaho Power I Generator Interconnection
208-388-5751
Email [e-mail]
From: Leslie White [mailto:[e-mail]]
Sent: Tuesday, September 18, 2012 9:54AM
To: Harris, Joshua
Subject: RE: Swager Farms (GI 307) Interconnection Agreement
Hello Josh,
Thank you for sending this offer. My understanding from talking to James this morning is that Roy Eiguren met with IP
yesterday on our behalf and that that discussion has been tabled for a few days. I'll need to see the outcome of that
conversation to give you some direction on this offer.
Regards,
Leslie
Leslie White
802 W Bannock, 12th Floor Boise, ID 83702
Office: 208.336.9793 1 Mobile: [phone]
~YY!Y:!..GXQT.gy(tQYQI9J!t!)f).TJL991I.\
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 tl1e 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 he1 eby 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: Friday, September 14, 2012 10:17 AM
To: Leslie White
Cc: Hackett, Eric; Park, Tessia; Sloan, Aubrae; Walker, Donovan; Allphin, Randy; Darrington, Michael
Subject: Swager Farms (GI 307) Interconnection Agreement
Leslie,
The attached is being sent to you in the mail today. Please let me know if you have any questions.
Thanks,
Josh Harris
OPERATIONS ANALYST
Idaho Power I Generator Interconnection
2
1221 W. Idaho Street I Boise, Idaho I 83702
Work 208-388-5751
Fax [phone]
Email [e-mail]
This transmis~ion 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-12-25
IDAHO POWER COMPANY
ATTACHMENT 54
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 1:46PM
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]>;
[e-mail] < [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]>;
'rriley@ hawleytroxell.com' < rriley@ hawleytroxell.com >
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 of the 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 les~
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 of the 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 5:38AM
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 I Mobile: [phone]
jca rkulis@exergydeve lopment. com
www .exer gydeveloprnent.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 strictly prohibited. If you
have received this communication in error, please immediately notify us by telephone. and return !he original message to us at the above ernaii 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-12-25
IDAHO POWER COMPANY
ATTACHMENT 55
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
)...
.x~rgy
• James T Carkulis
802 W Bannock, 12th Floor Boise, 10 83702
Office: 208.336.9793 I Mobile: [phone]
, [e-mail]
\Nifvw.exergydevelopment.com
This electronic or printed document contains information wl1ich (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) narned above If tile reader of this message is not the intended recipient, or lhe employee or
agent responsible to deliver it to the intended recipient. you are hereby notified that any dissemination, distribution or copyrng of this communication is strictly prohibited If you
have received this communication in error, please immediately notify us by telephone, and return the originai message to us at ttle above email address Thank you
1
-
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 56
From SeJier:
NOTICE OF F0RCE MAJEURE
UNDER
A .{>-)...._
, ~,~S~:,~ g y
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, II> 83702
Attn: James Carkulis
Email:. [e-mail]
To Idaho Power: Vice President, Power Supply
Idaho Power Company
With copy to:
PO Box 70
Boise, Idaho 83707
Email: I grow@ idahopower.com
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
occulTence of a Force Majeure 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, 1 2•h Floor Bo1se, ID 83 702 P 208.3 36 9793 F 2 08.3 36.94 31
;._ t t ).....
l/)/ .. ··~
3. The overall effect of the pending proceedings is that until such proceedings are finally
resolved, the entire circumstance 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 Two, LLC
::w ~~
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, ID 83702 P 208.336.9793 F 208.336.9431
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 57
·.
October 1, 2012
New Energy Two, LLC
c/o Exergy Development Group of Idaho, LLC
Attention: Laura Knothe
802 W. Bannock, 12th Floor
Boise, ID 83 702
Sent Via: Email, Certified Mail
Swager Farms Project Operation Date-Project #31616130
Dear Ms. Knothe:
IDAHO
POWER®
An IDACORP Company
The Finn Energy Sales Agreement (FESA) between Idaho Power Company and your Swager
Farms anaerobic digester project dated May 24, 2010 established a Scheduled Operation
Date of October 1, 2012.
As required in Article 5.3.1 ofthe FESA, "if the Operation Date occurs after the Scheduled
Operation Date but on or prior to 90 days following the Scheduled Operation Date, the seller
shall pay Idaho Power Delay Liquidated Damages calculated at the end of each calendar
month after the Scheduled Operation Date".
Article 5.3.2 states, "If the Operation Date does not occur within 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 ($45)
multiplied by the Maximum Capacity with the Maximum Capacity being measured in kW".
The FESA also stipulates in Article 5.4 that if New Energy Two fails to achieve the
Operation Date within 90 days following the Scheduled Operation Date, such failure will be
a Material Breach and Idaho Power may terminate the FESA at any time until the Seller
cures the Material Breach.
Idaho Power received your September 28, 2012, letter claiming a force majeure event has
occurred. Idaho Power does not agree with your claim-that pending matters at the Idaho PUC,
or your lack of ability to finance a project/projects are valid events of force majeure pursuant to
the FESA. As of October 1, 2012, Idaho Power has not received a request for an Operation Date
or any information that would allow Idaho Power to grant an Operation Date for the Swager
1 of2
Farms project from New Energy Two, LLC. Therefore, Idaho Power wiH begin calCulating
Delay Liquidated Damages as specified in the FESA.
If you have any question~ pleas·e do not h:esi tate to contact me.
Sincerely,
Michael Darrington
Energy Contracts
Idaho Power
(208)3 88-5946
[e-mail]
c;q: Dooov<:ttl: Wall<~r (TPC)
Randy AlLphin (fPC}
Josh Banis (JPC) ···
James Carktili$ (~,cergy)
Leslie White (New Ertergy Two)
2 of2
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 58
October 2, 2012
Leslie White
Exergy New Energy
802 W. Bannock
1th Floor
Boise, ID 83702
IDAHO POWER®
An IDACORP company
Re: Swager Farms Dairy Digester Project (0.8 MW Output) Draft Facility Study-Report-Project #307
Dear Ms. White: ' .
Given Exergy's recent election not to proceed with an expe,dited Generator Int~rconnection Agreement
(GIA) as offered by Josh Harris on September 14, 2012, I have attached the Draft Fa~ility Study Report
(FSR) for the subject project.
In order to proceed with this project, please provide your comments to the FSR to me by November 1, _....,'
2012 and indicate whether you wish to pro~eed with final design ;1p.d construction. The final report will
be used to prepare a draft GIA in preparatioif for Construction. Josh:Harris will be working with you to
finalize the Interconnection Agreement. ' -;c, ' · '
-'
Before we can begin Construction or order materials, you are responsible for contacting Idaho Power's
credit department to discuss GP~_w_t requirements for construction futl.ding. Please contact Aubrae Sloan
(208-388-5697) at your earliest con~enience. Once we receive funding, or the credit requirement is met,
we can proceed with conStruction of!he•project.
1 i .
The actual construction and hibor charges will be finalized approximately 90 days subsequent to project
completion. We will-r;econcile ·~y bv~r~ br l.inderpayment at that time.
I look forward to hearing from you soon.'
Sincerely,
Eric Hackett
Project Leader
Attachment: Swager Farms Dairy Digester Project Draft Facility Study Report with Drawings
Cc: J Harris/IPC A Sloan/IPC D W alker/IPC
An IDACORP Company
DRAFT
I Generator Interconnection
Facility Study Report
for the
Swager Farms Dairy Digester Project-Project #307
' · l oa:-
Exergy New Energ¥
ill
T,win Falls County, Idaho
October 2, 2012
1.
DRAFT-FACILITY STUDY REPORT (FSR)
Swager Farms Dairy Digester
Project #307
October 2, 2012
General Facility Description
The proposed project will consist of a short three-phase distr~bution ·line extension and Idaho
Power's overhead generation interconnection package (for projects less than 1 MVA) including an
overhead recloser, metering package, local service power transfornier-, disconnect switches, and a
relay/control box. Additionally, one 1000 kVA 277/480to 12.47 kV:Grounded Wye I Grounded
Wye padmounted transformer will be installed, including the 'associated··~derground cabling and
vaults. The project is located in Twin Falls County;,Jdaho a~d connects to. the 12.5 kV system on
Idaho Power Company's Clover (COVR-012) distribution line:. The total projeCt output is 0.8 MW.
Interconnection Customer:
Leslie White
Exergy New Energy
802 W. Bannock
121h Floor
Boise, ID 83 702
A Standard Generator JnterconnecJion Agreem.enl under Idaho Power Company's Open Access
Transmission Tariff.(OATT) or $chedule 72 between Interconnection Customer and Idaho Power
Company -Delivery (Transmission Owner) for the Swager Farms Dairy Digester Project,
specifically Generator Interconnection Project #30}, will be prepared for this project.
1.1 Interconnection Point
The interconnection Point for the Swager Farms Dairy Digester Project will be the low-side
bushings on the padmounted transformer (SWl). The project's location is in TlOS RISE Section
21 of Twin Falls County, Idaho. A drawing identifying the Interconnection Point is attached.
1.2 Point of Change of Ownership
The Point of Change of Ownership for the Swager Farms Dairy Digester Project will be the low­
side bushings on the padmounted transformer (SWl).
1.3 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.
1
The low-side disconnect switch shall be as specified or as determined by mutual agreement and
be readily accessible, operable, and lockable by Idaho Power personnel at all times.
1.4 Other Facilities Provided by Interconnection Customer
1.4.1 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.
1.4.2 Easements .
The Interconnection Customer will provide to Idaho' Pciwer a surveyed (Metes &
Bounds) legal description along with exhibit map. for Idaho Power's proposed
facilities. After the legal description ha been Clelivei-ect to IPCO for review, IPCO
will supply to the lnterconnection Cu tomet. a com leted IPCO easement for
signature by. the land owne~ of record. ~m.ce tlie signatures ~?lve been sec~red, the
lnterconnectwn Customer will return s1gned easement to tC@ for recordmg.
1.4.3 Local Service
The Interconnection Customer is responsible to arr~nge for local service to their site,
as necessary.
1.4.4 Monitoring Information ·.·. . . . . . .
If the Interconnection Custcnt~erTe · uires the abilitY'J~~~monitor information related to
the Idaho Power recloser in the generation intercon,nection package they are required
to supply their ?wn cabling/wir:in,g to•'the contto! hox.
1.5 Idaho Power Company's Interconnection Facilities
Idaho Power will install a generation intercoimection package on the existing distribution
feeder (COVR-012) on private property .southeast of the intersection of E. 3800 N. and N.
17QO .E~ in.Twin Falls County, ID. See'the attached work order maps (WO 27328106, sheet
1·of 1) for details.'
•··:• ., I
... The new interconnection packag~ 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-547 line
protection relay. The relay will be located in a pole mounted enclosure and will also contain
a test switch (TS4), isolation interface, power supply, DC converter, control switch and surge
protector.
Idaho Power will install (and subsequently own and maintain) one 1000 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 if desired. (The Interconnection Customer is
responsible for providing and installing the appropriate cable.)
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1.6 Facility Estimated Cost:
The following good faith estimates are provided in 2011 dollars:
~Overhead Q.ene!.~tion Interconnection Package & Line Extensio~ _ rP_g__ $145,000i ---t--------'-----·-·-1
$75,0_Q_Qj
$220,0.!!Qj
!Underground Equipment and 1000 kVA Transformer IPC
,.-~·----_, ___ ,
SUBTOTAL1 !$..'!.1!.&!..~.~~0...11. §for" the Project Grand Total ~--"--···-·---:----·· .. ···-·-.. ·"'" --"~
IPCO Commissioning Complete
TBD by seller Cornmercia/ Operation Date
These milestone dates assume that material ·can be ~pro.cured (\:IJd labor resources are available.
Additionally, any permitti ng )~ues outside ttle, inimediate control of Idaho Power could also
influence the Commercial 0penitio r • ate. ' .,_,, ---··· -.,.------.-,---·
3. Operating-Requiremeots " -
The project 1is' ~·~qn ired to~comply witl.1 the applicable Voltage and Current Distortion Limits found in
IEEE Standard 519-1992' )EEE Recommended Practices and requirements for harmonic Control in
ElectriCdl.f_o,wer Systems qt 'any subsequent standards as they may be updated from time to time.
Voltage fli&k~r at startup auq during'operatio.n must be limited to less than 5% as measured at the
Interconnecti6ri::-.roint.
' •.!·
The Project must b~c~'p?-bl{ofriding through faults on adjacent section of the power system without
tripping due to low vOft~ge. It has been determined, through study, that the Project must be capable
of remaining interconnected for any single phase voltage as low as 0.7 PU for 30 cycles, and for all
three phase voltages as low as 0.8 PU for 30 cycles.
Interconnection Customer will be able to modify power plant facilities on the Interconnection
Customer side of the Interconnection Point with no impact upon the operation of the transmission or
distribution system whenever the generation facilities are electrically isolated from the system and a
terminal clearance is issued by Idaho Power Company's Grid Operator.
3
4. Reactive Power
The Project must be controlled to operate as a VAr neutral system with a ± 200 kVAr operating
band.
5. Upgrades
5.1 Distribution Upgrades
Idaho Power will extend the existing distribution feeder (COVR-012) approximately 360 feet to
the east (just north of the ponds) on private property to facilitate ·and locate the Interconnection
Facilities. .
6. Estimated Costs
The following good faith estimates are provided in"10 12 dollars:
------
"::-::1
$145,000!
$75,000
$220,000
GRAND TOTAL $220,000J -~ ~--------------~~~~~~~~
____ ]
Note Regarding Transmissi'or;J :~~rvice: ... ··-. ·; .. ·, ·-
This FacilitY ·s:tudy is a Network Reso~~~ Interconnection Facility Study. This study identifies the
facilities necessary .to integrate the: Generating Facility into Idaho Power's network to serve load within
Idaho Power's balaricing area. Network Resource Interconnection Service in and of itself does not
convey any right to deliver electricity to any specific customer or Point of Delivery.
4
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Proposed Location for Distribution Upgrades and Interconnection Facilities
Green = Distribution Upgrades
Yellow = Interconnection Facilities (Interconnection Package)
Red= Interconnection Facilities (Underground Cables and Vaults)
Purple = Interconnection Facilities (Padmounted Transformer)
BEFORE THE
IDAHO PUBLIC UTILITIES COMMISSION
CASE NO. IPC-E-12-25
IDAHO POWER COMPANY
ATTACHMENT 59
Walker, Donovan
To:
Cc:
Subject:
From: Harris, Joshua
Harris, Joshua; Park, Tessia
Hackett, Eric; Georgeson, Keith; Darrington, Michael; Anderson, Kathleen
RE: Draft FSR for Swager Farms Gl#307
--------------
Sent: Thursday, November 01, 2012 10:27 AM
To: Walker, Donovan; Park, Tessia
Cc: Hackett, Eric; Georgeson, Keith; Darrington, Michael; Anderson, Kathleen
Subject: FW: Draft FSR for Swager Farms GI#307
From: Leslie White [mailto:[e-mail]]
Sent: Thursday, November 01, 2012 9:58AM
To: Hackett, Eric; Harris, Joshua
Cc: James Carkulis; Laura Knothe
Subject: RE: Draft FSR for Swager Farms GI#307
Good morning Josh and Eric,
With regards to the draft FSR for Gl #307 and the draft GIA for Gl #390, Exergy provided IPCo with a notice of Force
Majeure on September 281h. As mentioned in the notice a consequence of the pending I PUC proceedings is that
renewable energy project lenders are unwilling to lend in Idaho. Therefore with regards to the current status of Gl#307
and Gl#390 we will remain ready to proceed with both pending documents upon resolution of the matter at the I PUC, but
until that time I do not see the value in submitting comments to the FSR or GIA. I appreciate your continued work on
these projects and look forward to finding a path forward.
Please give me a call if you have any questions.
Leslie
leslie White
802 W Bannock, 12th Floor Boise, ID 83702
Office: 208.336.9793 1 Mobile: [phone]
~~~·~~\j_.§.YU r~}VCl f~i/8 [ 0 p rn_~~lJ..LS~OI11
This electronic or printed document contains information which (a) may be LEGALLY PRIVILEGED, PROPRIETARY IN NATURE. OR OTHERWISE PROTECTED BY LAW
FF~OM DISCLOSURE and (b) is intended only for the use of the Addressee(s) named above. If the reader of this message is not the intend8d recipient. 01 the employee or
agent responsible to deliver it to the intended rec;pient, you are hereby notified that any dissemination. distribution or copymg of this communicat•on is strictly prordbited If you
have rec<'li•1ed this communicc;tion •n error, please immediately notify us by telephone, and return the original message to us at the abovfl amail address. H!ank you.
From: Hackett, Eric [mailto:[e-mail]]
Sent: Wednesday, October 03, 2012 9:24AM
To: Leslie White
Cc: Harris, Joshua; Walker, Donovan; Sloan, Aubrae
Subject: Draft FSR for Swager Farms GI#307
Leslie,
Please see attached .
1
Eric Hackett, P.E., PMP
ENGINEERING LEADER, COST & CONTROLS
Idaho Power I Delivery Projects
1221 W. Idaho St. I Boise, ID I 83702
Work 208-388-5712
Mobile [phone]
Email [e-mail]
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 STRJCTL 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.
2