20210525Exhibit 13.pdf

Exhibit 13

March 9, 2020
Email from Greg Adams and
Attachments
From:Greg Adams
To:Moore, Kyle {Mkt Function}; Bryan Case
Cc:McDermott, Jacob; Woodworth, Thomas
Subject:RE: Fall River"s Proposed PPA for Chester Diversion Hydro Project
Date:Monday, March 09, 2020 2:25:56 PM
Attachments:Fall River Distribution One-Line.pdfChester Interconnection Request.pdfRE_ Q1182_ – Fall River Rural Electric Cooperative, Inc. _ QF System Impact Study Agreement.pdfFully Executed 191108 Q1182 QFSGI SISA.pdf191125 Q1182 LTR Study Provision Delay Notification.pdfQF10-337-001.pdf
Tom, Jacob, and Kyle,
To follow up on my phone call with Tom on Friday, I am responding to the requests for
additional information related to Fall River Rural Electric Cooperative’s Chester DiversionProject, as requested by Kyle. I have reproduced Kyle’s questions in italics below and
provided Fall River’s response beneath each question. We look forward to hearing back fromPacifiCorp and reaching agreement on terms of the proposed PPA for the Chester Project. If
you have any further questions, please contact me.
1. While we understand from your original information provided in September 2019 thatthe Chester Diversion Project is already operating, you also mention that you are
seeking an interconnection to PacifiCorp’s system. Considering these two statementstogether, we assume this means the project is already interconnected to another system
and delivering power. Can you please confirm and elaborate so we may understand thesituation better? Assuming we understand the situation correctly, have you considered
purchasing transmission to deliver the output to PacifiCorp’s system? That would seemto avoid the interconnection study delays you indicate you are experiencing.
Fall River’s Response: As discussed with Tom on the phone on Friday, the Chester
project is currently interconnected to Fall River’s own distribution system, and theoutput of the facility is currently being used to serve Fall River’s own members’ loads.
However, there is a 12.5-kV PacifiCorp line located directly adjacent to the currentinterconnection point on the Fall River line, and therefore Fall River’s engineers have
concluded that interconnecting the facility to the PacifiCorp system would be feasibleand reasonably achievable. During the scoping meeting with PacifiCorp’s
transmission personnel, it appeared that this should be a relatively easy interconnectionwithout any insurmountable obstacles.
With respect to PacifiCorp’s inquiry as to why Fall River proposes to interconnect to
PacifiCorp’s system as opposed to wheeling the power to PacifiCorp’s system from theexisting interconnection point on Fall River’s system, Fall River has considered this
option and believes that the proposal to interconnect to PacifiCorp’s system is the moreefficient and reasonable option from a contractual and engineering standpoint. The
alternative that Fall River has considered is that the parties could attempt to wheel thepower over Fall River’s system to the point of interconnection between the two utilities
in the Rexburg substation. However, there are engineering and contractual obstacles tothis alternative, including: (i) the entire wheeling arrangement would be located within
PacifiCorp’s balancing authority; therefore it is not a standard interchange transactionand it may be difficult for the parties to agree on the proper way to meter and track the
delivery to the Rexburg substation; and (ii) Fall River’s system does not currently
Exhibit 13 Page 1
the Chester facility at all times of the year – In engineering terms, the Chester project’soutput feeds into Fall River’s Daw Substation, and the Daw Substation is connected to
the Rexburg substation (to which PacifiCorp’s system is connected); but while FallRiver does not operate its distribution systems in a looped configuration, meaning the
two feeders from two different substations are electrically connected 24/7/365, thisconnection is occasionally closed and an open point established in another location
during outages or for maintenance. This is depicted on the attached map/one-linediagram of the relevant facilities.
In light of these facts, Fall River has proposed the simpler solution of a direct
interconnection to PacifiCorp’s system.
2. Can you please provide the documentation you’ve exchanged with PacifiCorp’sTransmission Function that relates to your interconnection application and request?
Fall River’s Response: We have attached the following documents:
Fall River’s Interconnection Request, dated October 3, 2019, with check for
$1,000;Fall River and PacifiCorp Transmission held a scoping meeting on October 31,
2019, and it appeared that there should be no major obstacles to achievinginterconnection of the facility; thus, Fall River agreed to waive the Feasibility
Study to expedite the process;Fall River’s email dated November 12, 2019, containing additional project
information, executed System Impact Study Agreement, and $10,000 studydeposit, which PacifiCorp has cashed;
Fully executed System Impact Study Agreement, dated Nov. 22, 2019;Letter from PacifiCorp Transmission dated November 25, 2020, stating that the
study could not be completed on time.
3. Finally, you mention you’ve previously provided PAC the QF self-certification for thisproject. We’re unable to locate in our records and are unable to access on the FERC
eLibrary. Can you please provide us a copy?
Fall River’s Response: The facility has been certified in FERC Docket QF10-337. We have attached the most recently filed recertification form. Please note that Fall
River intends to file a recertification form to include the plans to sell to PacifiCorp andto update some other information, such as the facility’s ownership. If you have any
questions about the facility’s ability to meet the qualification criteria, please let meknow.

Greg Adams
Richardson Adams, PLLC515 N. 27th Street
Boise, Idaho 83702Voice: 208.938.2236
Facsimile: 208.938.7904
Information contained in this electronic message and in any attachments hereto may contain information that is
Exhibit 13 Page 2
confidential, protected by the attorney/client privilege and/or attorney work product doctrine. Inadvertent disclosure
of the contents of this email or its attachments to unintended recipients is not intended to and does not constitute a
waiver of the attorney/client privilege and/or attorney work product doctrine. If you have received this email in
error, please immediately notify the sender of the erroneous receipt and destroy this email and any attachments of
the same either electronic or printed. Thank you.

From: Moore, Kyle {Mkt Function} <[e-mail]> 
Sent: Thursday, March 05, 2020 4:52 PM
To: Bryan Case <[e-mail]>
Cc: Greg Adams <[e-mail]>; McDermott, Jacob
<[e-mail]>; Woodworth, Thomas <[e-mail]>
Subject: RE: Fall River's Proposed PPA for Chester Diversion Hydro Project

Bryan,

We are in receipt of your latest February 19, 2020 correspondence.  As discussed previously,
consistent with the Company’s Idaho Schedule 38 (Part I.B.5), we’re not able to commence
negotiations on the PPA until such time as we can review your available
transmission/interconnection materials to reasonably confirm that the project is able to deliver
power on the date you indicated, which informs your eligibility for the current avoided cost rate. 
We’re happy to continue to evaluate the situation with this project, but we need more information. 
Please see below:

1. While we understand from your original information provided in September 2019 that the
Chester Diversion Project is already operating, you also mention that you are seeking an
interconnection to PacifiCorp’s system.  Considering these two statements together, we
assume this means the project is already interconnected to another system and delivering
power. Can you please confirm and elaborate so we may understand the situation better?
Assuming we understand the situation correctly, have you considered purchasing
transmission to deliver the output to PacifiCorp’s system?  That would seem to avoid the
interconnection study delays you indicate you are experiencing.

2. Can you please provide the documentation you’ve exchanged with PacifiCorp’s Transmission
Function that relates to your interconnection application and request?

3. Finally, you mention you’ve previously provided PAC the QF self-certification for this project. 
We’re unable to locate in our records and are unable to access on the FERC eLibrary.  Can you
please provide us a copy?

Thanks,

Kyle Moore
Rocky Mountain Power
Commercial Services
O 801.220.4467
C 385.210.4209
Exhibit 13 Page 3
From: Greg Adams [mailto:[e-mail]] 
Sent: Wednesday, February 19, 2020 9:34 AM
To: McDermott, Jacob <[e-mail]>; Moore, Kyle {Mkt Function}
<[e-mail]>
Cc: Bryan Case <[e-mail]>
Subject: [INTERNET] Fall River's Proposed PPA for Chester Diversion Hydro Project

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Jacob and Kyle, Please see that attached cover letter and draft PPA that we are sending in
US Mail today. Please contact me with any questions.
Greg Adams
Richardson Adams, PLLC515 N. 27th Street
Boise, Idaho 83702Voice: 208.938.2236
Facsimile: 208.938.7904
Information contained in this electronic message and in any attachments hereto may contain information that is
confidential, protected by the attorney/client privilege and/or attorney work product doctrine. Inadvertent disclosure
of the contents of this email or its attachments to unintended recipients is not intended to and does not constitute a
waiver of the attorney/client privilege and/or attorney work product doctrine. If you have received this email in
error, please immediately notify the sender of the erroneous receipt and destroy this email and any attachments of
the same either electronic or printed. Thank you.

Exhibit 13 Page 4
Exhibit 13 Page 5
SMALL GENERATOR QUALIFIED FACILITY INTERCONNECTION REQUEST
{Application Form)
Transmission Provider: PacifiCorp
Designated Contact Person: Kris Bremer
Address (for U.S. Mail Deliveries): PacifiCorp Transmission
P.O. Box 2757
Portland, OR 97208-2757
Address (for All Other Deliveries): PacifiCorp Transmission
Telephone Number: [phone]
Fax: ------
825 NE Multnomah Ave, Suite 550
Portland, OR 97232
E-Mail Address: [e-mail]
An Interconnection Request is considered complete when it provides all applicable and correct
information required below.
Preamble and Instructions
An Interconnection Customer who requests a Qualified Facility 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 to be evaluated under a 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 deposit of $1,000.
Exhibit 13 Page 6
Interconnection Customer Information
Legal Name of the Interconnection Customer (or, if an individual, individual's name)
Name: Fall River Rural Electric Cooperative, Inc. ________________ _
Contact Person: Dave Peterson '---------------------------
Mailing Address: 1150 N. 3400 E ____________________ _
City: Ashton ________ _ State: Idaho ------Zip: 83420 ___ _
Facility Location (if different from above): Chester Diversion Hydroelectric Project ____ _
Telephone (Day): [phone] __ Telephone (Evening): [phone] ____ _
Fax: [phone] _____ _ E-Mail Address: [e-mail] __
Alternative Contact Information (if different from the Interconnection Customer)
Contact Name: -----------------------------
Title: ---------------------------------
Address: --------------------------------
Telephone (Day): _______ _ Telephone (Evening): _________ _
Fax: ____________ _ E-Mail Address: -------------
Application is for: X_ New Small Generating Qualified Facility
__ Capacity addition to Existing Small Generating Facility
If capacity addition to existing facility, please describe: ---------------
Will the Small Generating Facility be used for any of the following?
To Supply Power to the Interconnection Customer? Yes _x_ No_
To Supply Power to Others? Yes No ~X,__
Exhibit 13 Page 7
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]
Telephone (Day): _______ _ Telephone (Evening): _________ _
Fax: E-Mail Address: --------------------------
Requested Point oflnterconnection: Rocky Mountain Power Pole 31-08-041 #3479000 ___ _
Interconnection Customer's Requested In-Service Date: ---------------
Small Generating Facility Information
Data apply only to the Small Generating Qualified Facility, not the Interconnection Facilities.
Energy Source: _Solar _Wind _X_Hydro Hydro Type (e.g. Run-of-River):Run of the
River -----_Diesel _Natural Gas _Fuel Oil _Other (state type) ______ _
Prime Mover: _Fuel Cell _Recip Engine
_Microturbine
Gas Turb
PV
Type of Generator: _ X_Synchronous Induction
_Steam Turb
~Other
Inverter
Generator Nameplate Rating: (3)x1200 3600kW (Typical) Generator Nameplate kV AR: (3)x581 1743
Expected Interconnection Customer or Customer-Site Load: ___ 300 ___ kW (if none, so state)
Typical Reactive Load (if known): _______ _
Maximum Nameplate Capability Requested: 1840 kW
Exhibit 13 Page 8
List components of the Small Generating Facility equipment package that are currently certified:
Equipment Type
1. ---------2. ---------
3. ---------
4. ---------5. ---------
Certifying Entity
Is the prime mover compatible with the certified protective relay package?
Generator (or solar inverter)
Manufacturer, Model Name & Number: CCJEC SFW -Jl200 -S2/3400
Version Number:
Yes No
------------------------------
Nameplate Output Power Rating in kW: (Summer) _3600 ___ (Winter) _3600 __ _
Nameplate Output Power Rating in kV A: (Summer) _4000 (Winter) _4000 __ _
Individual Generator Power Factor
Rated Power Factor: Leading: ______ Lagging: _.9 ____ _
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): __ NIA ____________ _
List of adjustable set points for the protective equipment or software: ___________ _
Note: A completed Power System Simulator for Engineering (PSS/E) data sheet must be supplied
with the Interconnection Request.
Small Generating Facility Characteristic Data (for inverter-based machines)
Max design fault contribution current: ___ _ Instantaneous or RMS?
Harmonics Characteristics: ------------------------
Start-up requirements:-------------------------
Exhibit 13 Page 9
Small Generating Facility Characteristic Data (for rotating machines)
RPM Frequency: _138.5 RPM_
(*)Neutral Grounding Resistor (If Applicable): ____ _
Synchronous Generators:
Direct Axis Synchronous Reactance, Xd: _.6227 _ P.U.
Direct Axis Transient Reactance, X' ct: .2978 P.U.
Direct Axis Subtransient Reactance, X" ct: .2293 P.U.
Negative Sequence Reactance, X2: _.2379_ P.U.
Zero Sequence Reactance, Xo: _.1062 __ P.U.
KVA Base: _(3) x 1333.3 ____ _
Field Volts: 12500 ---Field Amperes: _61.58 __ _
Induction Generators:
Motoring Power (kW): -------h2t or K (Heating Time Constant): _____ _
Rotor Resistance, Rr: -------
Stator Resistance, Rs: -------
Stator Reactance, Xs: -------Rotor Reactance, Xr:
Magnetizing Reactance, Xm: -------
Short Circuit Reactance, Xd": -------Exciting Current: ______ _
Temperature Rise: -------Frame Size:
Design Letter: ______ _
Reactive Power Required In Vars (No Load): ______ _
Reactive Power Required In Vars (Full Load): _____ _
Total Rotating Inertia, H: Per Unit on kVA Base
Note: Please contact the Transmission Provider prior to submitting the Interconnection Request to
determine if the specified information above is required.
Excitation and Governor System Data for Synchronous Generators Only
Provide appropriate IEEE model block diagram of excitation system, governor system and power system
stabilizer (PSS) in accordance with the regional reliability council criteria. A PSS may be determined to
be required by applicable studies. A copy of the manufacturer's block diagram may not be substituted.
Exhibit 13 Page 10
Interconnection Facilities Information
Will a transformer be used between the generator and the point of interconnection? _Yes _x_No
Will the transformer be provided by the Interconnection Customer? __ Yes _X_No
Transformer Data (If 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 Interconnection Customer-Owned Fuse):
(Attach copy of fuse manufacturer's Minimum Melt and Total Clearing Time-Current Curves)
Manufacturer: _____ Type: ____ Size: ____ Speed: _____ _
Interconnecting Circuit Breaker (if applicable):
Manufacturer: GE Type: _PowerVac __
Load Rating (Amps): _1200_ Interrupting Rating (Amps): _20000_ Trip Speed (Cycles): _5 __
Interconnection Protective Relays (If Applicable):
If Microprocessor-Controlled:
List of Functions and Adjustable Setpoints for the protective equipment or software:
Setpoint Function Minimum Maximum
1. Phase Overcurrent 250A
2. Ground Overcurrent 50A
3. Generator Differential 10% 4 cycles_
4. Reverse Power 2% 10 seconds -
5. Over/Under Voltage 90% 1 second_ 110% 1 second_
6. Over/Under Freguency 59 Hz 1 second_ 61 Hz 1 second -
Exhibit 13 Page 11
If Discrete Components:
(Enclose Copy of any Proposed Time-Overcurrent Coordination Curves)
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Manufacturer: Type: Style/Catalog No.: Proposed Setting:
Current Transformer Data (If Applicable):
(Enclose Copy of Manufacturer's Excitation and Ratio Correction Curves)
Manufacturer: GE-ITI -----------------Type: 780-301 Accuracy Class:_ Proposed Ratio Connection: 300:5
Manufacturer: GE-ITI -----------------Type: 780-101 Accuracy Class:_ Proposed Ratio Connection: 100:5
Potential Transformer Data (If Applicable):
Manufacturer: GE-ITI ------~--~--~--~-Type: PTWS-2-110-123SS Accuracy Class: Proposed Ratio Connection: 100:1
Manufacturer: ------------~--~--~-Type: ______ Accuracy Class: _ Proposed Ratio Connection: __
General Information
Enclose copy of site electrical one-line diagram showing the configuration of all Small Generating
Facility equipment, current and potential circuits, and protection and control schemes. This one-line
diagram must be signed and stamped by a licensed Professional Engineer if the Small Generating
Facility is larger than 50 kW.
Enclose copy of any acceptable site control documentation that indicates the precise physical location of
the proposed Small Generating Facility(~, USGS topographic map or other diagram or
documentation). This is additional to Transmission Provider required Site Control Documentation
reasonably demonstrating:(l) ownership of, a leasehold interest in, or a right to develop a site for the
purpose of constructing the Generating Facility; (2) an option to purchase or acquire a leasehold site for
such purpose; or (3) an exclusivity or other business relationship between Interconnection Customer and
the entity having the right to sell, lease or grant Interconnection Customer the right to possess or occupy
a site for such purpose.
Proposed location of protective interface equipment on property (include address if different from the
Interconnection Customer's address) _2875 E. 930 N. Fremont County Idaho ______ _
Exhibit 13 Page 12
Enclose copy of any site documentation that describes and details the operation of the protection and
control schemes. Is Available Documentation Enclosed? X 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? _X_Yes __ No
Applicant Signature
I hereby certify that, to the best of my knowledge, al the information provided in this Interconnection
Request is true and correct.
Exhibit 13 Page 13
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ONE UHE DIAGRAM a ,.,. •-u°'°'
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Exhibit 13 Page 18
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Exhibit 13 Page 19
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Exhibit 13 Page 20
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Exhibit 13 Page 22
~ (2610C)
•
(RAMS) RUNNCR Bl •DE MODE SWITCH
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CPT -COOROL PO'JER T~ HAA' -HPU ALARM RELAY
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HYDRAULIC PUMP CONTROL PAHEL
LAYOUT/DIMEl'fstOHA.1.
OWG No.: OBP0107-HPCt
Exhibit 13 Page 41
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Exhibit 13 Page 45
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Exhibit 13 Page 46
r
\.>~ Riv>-~-~ FALL RlvER RURAL ELECTRIC COOPERATIVE, INC.
1150 NORTH 3400 EAST 0 ASHTON, ID 83420-5624
[phone]
BANK OF IDA~eck Nbr:
399 N. CAPITAL AVE. IDAHO FALLS, IDAHO 83402
92-367 /1241
148711
RURAL ELECTRIC COOPERATIVE GENERAL AND OPERATING ACCOUNT d Ven or Check Nbr Check Date
10/04/19
Check Amount
$1,000.00
Pay ONE THOUSAND, ZERO DOLLARS AND 00/100 CENTS
To The
Order Of PACIFICORP
825 NE MULTNOMAH
PORTLAND OR 97232
3066 148711
3066 Please Detach and Retain Statement
VOID AFTER 90 DAYS
Check Nbr: F4J..~rlil!Vi.6 RURAL ELECTRIC COOPERATIVE, INC. GENERAL & OPERATING ACCOUNT Check Date:
We herewith hand you our check in settlement of items listed below.
148711
1'*3Si711
10/04/19
Invoice Nbr Description Invoice Date Ref Nbr Amount
ST100419 INTERCONNECTION AGREE F/CHESTER 10/04/19 1,000.00
Exhibit 13 Page 47
From:Dave Peterson
To:Engle, Ty
Cc:_Transmission Contracts; Bryan Case; Greg Adams
Subject:RE: Q1182: – Fall River Rural Electric Cooperative, Inc. / QF System Impact Study Agreement
Date:Tuesday, November 12, 2019 4:20:18 PM
Attachments:image001.png191108 Q1182 QFSGI SISA.pdfPlant one line.pdfQ1182 Tech Data Checklist.xlsx
Dear Mr. Engle:

Attached is the signed agreement, copy of the check for the deposit, the checklist and one line. I will
put the check for the deposit in the mail to you tomorrow.

Thank you,

Dave Peterson
Manager of Engineering
Fall River Electric Cooperative
[phone] Direct Office
[phone] Cell

From: Engle, Ty <[e-mail]>
Sent: Friday, November 8, 2019 12:47 PM
To: Dave Peterson <[e-mail]>
Cc: _Transmission Contracts <[e-mail]>
Subject: Q1182: – Fall River Rural Electric Cooperative, Inc. / QF System Impact Study Agreement

Dear Mr. Peterson:
Attached is a QF System Impact Study Agreement for Fall River Rural Electric Cooperative,Inc. (“Interconnection Customer”).
Please review the attached Technical Data Checklist completed to date for your project. This
document identifies technical data that may still be outstanding and required prior to enteringinto the requested study. Please also provide a requested commercial operations date that was
not listed on the original application.
Interconnection Customer shall sign and email the agreement to PacifiCorp with a depositin the amount of the estimated $10,000 cost to perform the study, no later than fifteen (15)
Business Days (or by December 4, 2019).
PacifiCorp will complete the month, day, and year sections on the first page of the
Exhibit 13 Page 48
agreement.
Sincerely,

Ty Engle
Project Manager
PacifiCorp Generation Interconnection
503.813.6419
825 NE Multnomah St, Suite 1600
Portland, OR 97232

Exhibit 13 Page 49
System Impact Study Agreement
THIS AGREEMENT is made and entered into this 22nd day of November , 20 ~
by and between Fall River Rural Electric Cooperative, Inc (Ql 182), a cooperative corporation
organized and existing under the laws of the State of Idaho, ("Interconnection Customer,") and
PacifiCorp, a Corporation existing under the laws of the State of Oregon, ("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 18, 2019; and
WHEREAS, the Interconnection Customer desires to interconnect the Small Generating Facility
with the Transmission Provider's Transmission System;
WHEREAS, the Interconnection Customer requested that the Transmission Provider forego an
initial 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 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
Exhibit 13 Page 50
Interconnection Customer modifies its designated Point oflnterconnection,
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 nonbinding 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, ifrequired, 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
Business Days after this Agreement is signed by the Parties, or in accordance with the
Exhibit 13 Page 51
Transmission Provider's queuing procedures.
10.0 A deposit of the equivalent of the good faith estimated cost of a distribution system
impact study and the one half the good faith estimated cost of a transmission system
impact study may be required from the Interconnection Customer.
11.0 Any study fees shall be based on the Transmission Provider's actual costs and will be
invoiced to the Interconnection Customer after the study is completed and delivered and
will include a summary of professional time.
12.0 The Interconnection Customer must pay any study costs that exceed the deposit without
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.
13.0 Governing Law, Regulatory Authority, and Rules the validity, interpretation and
enforcement of this Agreement and each of its provisions shall be governed by the laws
of the state ofldaho (where the Point oflnterconnection is located), without regard to its
conflicts of law principles. This Agreement is subject to all Applicable Laws and
Regulations. Each Party expressly reserves the right to seek changes in, appeal, or
otherwise contest any laws, orders, or regulations of a Governmental Authority.
14.0 Amendment
The Parties may amend this Agreement by a written instrument duly executed by both
Parties.
15.0 No Third-Party Beneficiaries
This Agreement is not intended to and does not create rights, remedies, or benefits of any
character whatsoever in favor of any persons, corporations, associations, or entities other
than the Parties, and the obligations herein assumed are solely for the use and benefit of
the Parties, their successors in interest and where permitted, their assigns.
16.0 Waiver
16.1 The failure of a Party to this Agreement to insist, on any occasion, upon strict
performance of any provision of this Agreement will not be considered a waiver
of any obligation, right, or duty of, or imposed upon, such Party.
16.2 Any waiver at any time by either Party of its rights with respect to this Agreement
shall not be deemed a continuing waiver or a waiver with respect to any other
failure to comply with any other obligation, right, duty of this Agreement.
Termination or default of this Agreement for any reason by Interconnection
Customer shall not constitute a waiver of the Interconnection Customer's legal
Exhibit 13 Page 52
16.3
rights to obtain an interconnection from the Transmission Provider. Any waiver of
this Agreement shall, if requested, be provided in writing.
17.0 Multiple Counterparts
This Agreement may be executed in two or more counterparts, each of which is deemed
an original but all constitute one and the same instrument.
18.0 No Partnership
This Agreement shall not be interpreted or construed to create an association, joint
venture, agency relationship, or partnership between the Parties or to impose any
partnership obligation or partnership liability upon either Party. Neither Party shall have
any right, power or authority to enter into any agreement or undertaking for, or act on
behalf of, or to act as or be an agent or representative of, or to otherwise bind, the other
Party.
19.0 Severability
20.0
If any provision or portion of this Agreement shall for any reason be held or adjudged to
be invalid or illegal or unenforceable by any court of competent jurisdiction or other
Governmental Authority, (1) such portion or provision shall be deemed separate and
independent, (2) the Parties shall negotiate in good faith to restore insofar as practicable
the benefits to each Party that were affected by such ruling, and (3) the remainder of this
Agreement shall remain in full force and effect.
Subcontractors
Nothing in this Agreement shall prevent a Party from utilizing the services of any
subcontractor as it deems appropriate to perform its obligations under this Agreement;
provided, however, that each Party shall require its subcontractors to comply with all
applicable terms and conditions of this Agreement in providing such services and each
Party shall remain primarily liable to the other Party for the performance of such
subcontractor.
20.1 The creation of any subcontract relationship shall not relieve the hiring Party of
any of its obligations under this Agreement. The hiring Party shall be fully responsible to
the other Party for the acts or omissions of any subcontractor the hiring Party hires as if
no subcontract had been made; provided, however, that in no event shall the
Transmission Provider be liable for the actions or inactions of the Interconnection
Customer or its subcontractors with respect to obligations of the Interconnection
Customer under this Agreement. Any applicable obligation imposed by this Agreement
Exhibit 13 Page 53
upon the hiring Patty shall be equally binding upon, and shall be construed as having
application to, any subcontractor of such Party.
20.2 The obligations under this article will not be limited in any way by any limitation of
subcontractor's insurance.
21.0 Reservation of Rights
The Transmission Provider shall have the right to make a unilateral filing with FERC to
modify this Agreement with respect to any rates, terms and conditions, charges,
classifications of service, rule or regulation under section 205 or any other applicable
provision of the Federal Power Act and FERC's rules and regulations thereunder, and the
Interconnection Customer shall have the right to make a unilateral filing with FERC to
modify this Agreement under any applicable provision of the Federal Power Act and
FERC's rules and regulations; provided that each Party shall have the right to protest
such filing by the other Party and to participate fully in any proceeding before the FERC
in which such modification may be considered. Nothing in this Agreement shall limit the
rights of the Parties or ofFERC under sections 205 and 206 of the Federal Power Act and
FERC' s rules and regulations, except to the extent that the Parties otherwise agree as
provided herein.
Exhibit 13 Page 54
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.
PacifiCorp lectric Cooperative, Inc
v -AB 2019.11.22 !7.-b-q-,.__--··. 08:57:48 -08'00'
Signed Signed
Kris Bremer
Name (Printed): Name (Printed):
Director, Generation Interconnection
Title: Title:
11/22/19
Date: Date:
Exhibit 13 Page 55
Attachment A to
System Impact Study Agreement
Assumptions Used in Conducting the System Impact Study
As stated in the recitals to this Agreement, the Interconnection Customer requested that the
Transmission Provider forego an initial feasibility study. Accordingly, and notwithstanding what
is otherwise stated in Section 4 of the Agreement, the system impact study shall be based on the
information provided to date by Interconnection Customer, subject to any modifications in
accordance with PacifiCorp's Small Generator Interconnection Procedures, and the following
assumptions:
1) Designation of Point of Interconnection and configuration to be studied.
• Circuit STA13, St Anthony #13, out of St Anthony substation at 12.5 kV (at
approximately 44.0120481090°N, 111.57622449°W)
2) Designation of alternative Points of Interconnection and configuration.
• None
Items 1) and 2) have been provided and/or confirmed by the Interconnection Customer. Other
assumptions (listed below) have been provided and/or confirmed by the Interconnection
Customer and the Transmission Provider.
• Transmission Provider: Currently operational 2.4 MW synchronous hydro generator,
will be a QF
• Interconnection Customer: fAU... P.lVffl.. {(utfAl. t:lEC"f~\.C <bo~AAT\v~ /NC .
Exhibit 13 Page 56
P.O. Box 2757 Portland, OR 97208-2757 825 NE Multnomah St., Suite 550 Portland, Oregon 97232 November 25, 2019
Q1182: Fall River Rural Electric Cooperative, Inc. – Chester Hydro / Notice of Delay of System Impact Study Report Provision Dear Mr. Peterson:

Due to a significant number of Interconnection Requests proposing to interconnect in the same geographical area of PacifiCorp’s electrical system as the Interconnection Request submitted by Fall River Rural Electric Cooperative, Inc. (“Interconnection Customer”), PacifiCorp will be unable to provide the Interconnection Customer’s System Impact Study (“Study”) within the
timelines outlined in PacifiCorp’s Small Generation Interconnection Procedures.
If you have any questions, please contact me at [phone]. Sincerely,

Kristopher Bremer Director, Generation Interconnection
PacifiCorp
Exhibit 13 Page 57
PUBLIC (REDACTED)FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, DC
OMB Control # 1902-0075
Form 556 Certification of Qualifying Facility (QF) Status for a Small Power
Production or Cogeneration Facility
General
Questions about completing this form should be sent to [e-mail]. Information about the Commission's QF
program, answers to frequently asked questions about QF requirements or completing this form, and contact information for
QF program staff are available at the Commission's QF website, www.ferc.gov/QF. The Commission's QF website also
provides links to the Commission's QF regulations (18 C.F.R. § 131.80 and Part 292), as well as other statutes and orders
pertaining to the Commission's QF program.
Who Must File
Any applicant seeking QF status or recertification of QF status for a generating facility with a net power production capacity
(as determined in lines 7a through 7g below) greater than 1000 kW must file a self-certification or an application for
Commission certification of QF status, which includes a properly completed Form 556. Any applicant seeking QF status for a
generating facility with a net power production capacity 1000 kW or less is exempt from the certification requirement, and is
therefore not required to complete or file a Form 556. See 18 C.F.R. § 292.203.
How to Complete the Form 556
This form is intended to be completed by responding to the items in the order they are presented, according to the
instructions given. If you need to back-track, you may need to clear certain responses before you will be allowed to change
other responses made previously in the form. If you experience problems, click on the nearest help button ( ) for
assistance, or contact Commission staff at [e-mail].
Certain lines in this form will be automatically calculated based on responses to previous lines, with the relevant formulas
shown. You must respond to all of the previous lines within a section before the results of an automatically calculated field
will be displayed. If you disagree with the results of any automatic calculation on this form, contact Commission staff at
[e-mail] to discuss the discrepancy before filing.
You must complete all lines in this form unless instructed otherwise. Do not alter this form or save this form in a different
format. Incomplete or altered forms, or forms saved in formats other than PDF, will be rejected.
How to File a Completed Form 556
Applicants are required to file their Form 556 electronically through the Commission's eFiling website (see instructions on
page 2). By filing electronically, you will reduce your filing burden, save paper resources, save postage or courier charges,
help keep Commission expenses to a minimum, and receive a much faster confirmation (via an email containing the docket
number assigned to your facility) that the Commission has received your filing.
If you are simultaneously filing both a waiver request and a Form 556 as part of an application for Commission certification,
see the "Waiver Requests" section on page 3 for more information on how to file.
Paperwork Reduction Act Notice
This form is approved by the Office of Management and Budget (OMB Control No. 1902-0075, expiration 05/31/2013).
Compliance with the information requirements established by the FERC Form No. 556 is required to obtain or maintain status
as a QF. See 18 C.F.R. § 131.80 and Part 292. An agency may not conduct or sponsor, and a person is not required to respond
to, a collection of information unless it displays a currently valid OMB control number. The estimated burden for completing
the FERC Form No. 556, including gathering and reporting information, is as follows: 3 hours for self-certification of a small
power production facility, 8 hours for self-certifications of a cogeneration facility, 6 hours for an application for Commission
certification of a small power production facility, and 50 hours for an application for Commission certification of a
cogeneration facility. Send comments regarding this burden estimate or any aspect of this collection of information,
including suggestions for reducing this burden, to the following: Information Clearance Officer, Office of the Executive
Director (ED-32), Federal Energy Regulatory Commission, 888 First Street N.E., Washington, DC 20426; and Desk Officer for
FERC, Office of Information and Regulatory Affairs, Office of Management and Budget, Washington, DC 20503
([e-mail]). Include the Control No. 1902-0075 in any correspondence.
Expiration 5/31/2013
Exhibit 13 Page 58
FERC Form 556 Page 2 - InstructionsPUBLIC (REDACTED)
Electronic Filing (eFiling)
To electronically file your Form 556, visit the Commission's QF website at www.ferc.gov/QF and click the eFiling link.
If you are eFiling your first document, you will need to register with your name, email address, mailing address, and phone
number. If you are registering on behalf of an employer, then you will also need to provide the employer name, alternate
contact name, alternate contact phone number and and alternate contact email.
Once you are registered, log in to eFiling with your registered email address and the password that you created at
registration. Follow the instructions. When prompted, select one of the following QF-related filing types, as appropriate,
from the Electric or General filing category.
Filing category Filing Type as listed in eFiling Description
Electric
(Fee) Application for Commission Cert. as Cogeneration QF
Use to submit an application for
Commission certification or
Commission recertification of a
cogeneration facility as a QF.
(Fee) Application for Commission Cert. as Small Power QF
Use to submit an application for
Commission certification or
Commission recertification of a
small power production facility as a
QF.
Self-Certification Notice (QF, EG, FC)
Use to submit a notice of self-
certification of your facility
(cogeneration or small power
production) as a QF.
Self-Recertification of Qualifying Facility (QF)
Use to submit a notice of self-
recertification of your facility
(cogeneration or small power
production) as a QF.
Supplemental Information or Request
Use to correct or supplement a
Form 556 that was submitted with
errors or omissions, or for which
Commission staff has requested
additional information. Do not use
this filing type to report new
changes to a facility or its
ownership; rather, use a self-
recertification or Commission
recertification to report such
changes.
General (Fee) Petition for Declaratory Order (not under FPA Part 1)
Use to submit a petition for
declaratory order granting a waiver
of Commission QF regulations
pursuant to 18 C.F.R. §§ 292.204(a)
(3) and/or 292.205(c). A Form 556 is
not required for a petition for
declaratory order unless
Commission recertification is being
requested as part of the petition.
You will be prompted to submit your filing fee, if applicable, during the electronic submission process. Filing fees can be paid
via electronic bank account debit or credit card.
During the eFiling process, you will be prompted to select your file(s) for upload from your computer.
Exhibit 13 Page 59
FERC Form 556 Page 3 - InstructionsPUBLIC (REDACTED)
Filing Fee
No filing fee is required if you are submitting a self-certification or self-recertification of your facility as a QF pursuant to 18
C.F.R. § 292.207(a).
A filing fee is required if you are filing either of the following:
(1) an application for Commission certification or recertification of your facility as a QF pursuant to 18 C.F.R. § 292.207(b), or
(2) a petition for declaratory order granting waiver pursuant to 18 C.F.R. §§ 292.204(a)(3) and/or 292.205(c).
The current fees for applications for Commission certifications and petitions for declaratory order can be found by visiting the
Commission's QF website at www.ferc.gov/QF and clicking the Fee Schedule link.
You will be prompted to submit your filing fee, if applicable, during the electronic filing process described on page 2.
Required Notice to Utilities and State Regulatory Authorities
Pursuant to 18 C.F.R. § 292.207(a)(ii), you must provide a copy of your self-certification or request for Commission certification
to the utilities with which the facility will interconnect and/or transact, as well as to the State regulatory authorities of the
states in which your facility and those utilities reside. Links to information about the regulatory authorities in various states
can be found by visiting the Commission's QF website at www.ferc.gov/QF and clicking the Notice Requirements link.
What to Expect From the Commission After You File
An applicant filing a Form 556 electronically will receive an email message acknowledging receipt of the filing and showing
the docket number assigned to the filing. Such email is typically sent within one business day, but may be delayed pending
confirmation by the Secretary of the Commission of the contents of the filing.
An applicant submitting a self-certification of QF status should expect to receive no documents from the Commission, other
than the electronic acknowledgement of receipt described above. Consistent with its name, a self-certification is a
certification by the applicant itself that the facility meets the relevant requirements for QF status, and does not involve a
determination by the Commission as to the status of the facility. An acknowledgement of receipt of a self-certification, in
particular, does not represent a determination by the Commission with regard to the QF status of the facility. An applicant
self-certifying may, however, receive a rejection, revocation or deficiency letter if its application is found, during periodic
compliance reviews, not to comply with the relevant requirements.
An applicant submitting a request for Commission certification will receive an order either granting or denying certification of
QF status, or a letter requesting additional information or rejecting the application. Pursuant to 18 C.F.R. § 292.207(b)(3), the
Commission must act on an application for Commission certification within 90 days of the later of the filing date of the
application or the filing date of a supplement, amendment or other change to the application.
Waiver Requests
18 C.F.R. § 292.204(a)(3) allows an applicant to request a waiver to modify the method of calculation pursuant to 18 C.F.R. §
292.204(a)(2) to determine if two facilities are considered to be located at the same site, for good cause. 18 C.F.R. § 292.205(c)
allows an applicant to request waiver of the requirements of 18 C.F.R. §§ 292.205(a) and (b) for operating and efficiency upon
a showing that the facility will produce significant energy savings. A request for waiver of these requirements must be
submitted as a petition for declaratory order, with the appropriate filing fee for a petition for declaratory order. Applicants
requesting Commission recertification as part of a request for waiver of one of these requirements should electronically
submit their completed Form 556 along with their petition for declaratory order, rather than filing their Form 556 as a
separate request for Commission recertification. Only the filing fee for the petition for declaratory order must be paid to
cover both the waiver request and the request for recertification if such requests are made simultaneously.
18 C.F.R. § 292.203(d)(2) allows an applicant to request a waiver of the Form 556 filing requirements, for good cause.
Applicants filing a petition for declaratory order requesting a waiver under 18 C.F.R. § 292.203(d)(2) do not need to complete
or submit a Form 556 with their petition.

Exhibit 13 Page 60
FERC Form 556 Page 4 - InstructionsPUBLIC (REDACTED)
Geographic Coordinates
If a street address does not exist for your facility, then line 3c of the Form 556 requires you to report your facility's geographic
coordinates (latitude and longitude). Geographic coordinates may be obtained from several different sources. You can find
links to online services that show latitude and longitude coordinates on online maps by visiting the Commission's QF
webpage at www.ferc.gov/QF and clicking the Geographic Coordinates link. You may also be able to obtain your geographic
coordinates from a GPS device, Google Earth (available free at http://earth.google.com), a property survey, various
engineering or construction drawings, a property deed, or a municipal or county map showing property lines.
Filing Privileged Data or Critical Energy Infrastructure Information in a Form 556
The Commission's regulations provide procedures for applicants to either (1) request that any information submitted with a
Form 556 be given privileged treatment because the information is exempt from the mandatory public disclosure
requirements of the Freedom of Information Act, 5 U.S.C. § 552, and should be withheld from public disclosure; or (2) identify
any documents containing critical energy infrastructure information (CEII) as defined in 18 C.F.R. § 388.113 that should not be
made public.
If you are seeking privileged treatment or CEII status for any data in your Form 556, then you must follow the procedures in 18
C.F.R. § 388.112. See www.ferc.gov/help/filing-guide/file-ceii.asp for more information.
Among other things (see 18 C.F.R. § 388.112 for other requirements), applicants seeking privileged treatment or CEII status for
data submitted in a Form 556 must prepare and file both (1) a complete version of the Form 556 (containing the privileged
and/or CEII data), and (2) a public version of the Form 556 (with the privileged and/or CEII data redacted). Applicants
preparing and filing these different versions of their Form 556 must
. If you are not seeking privileged treatment or CEII status for any of your Form 556 data, then you should not
respond to any of the items on this page.
indicate below the security designation of this version of
their document
Non-Public: Applicant is seeking privileged treatment and/or CEII status for data contained
. This non-public version of the applicant's Form 556 contains all data, including the data that is redacted
in the (separate) public version of the applicant's Form 556.
in the Form 556 lines
indicated below

Public (redacted): Applicant is seeking privileged treatment and/or CEII status for data contained
. This public version of the applicants's Form 556 contains all data except for data from the lines
indicated below, which has been redacted.
in the Form 556 lines
indicated below

Privileged: Indicate below which lines of your form contain data for which you are seeking privileged treatment
The applicant does not seek privileged treatment and has not redacted any portion of
this application.
Critical Energy Infrastructure Information (CEII): Indicate below which lines of your form contain data for which you are
seeking CEII status
None.
The eFiling process described on page 2 will allow you to identify which versions of the electronic documents you submit are
public, privileged and/or CEII. The filenames for such documents should begin with "Public", "Priv", or "CEII", as applicable, to
clearly indicate the security designation of the file. Both versions of the Form 556 should be unaltered PDF copies of the Form
556, as available for download from www.ferc.gov/QF. To redact data from the public copy of the submittal, simply omit the
relevant data from the Form. For numerical fields, leave the redacted fields blank. For text fields, complete as much of the
field as possible, and replace the redacted portions of the field with the word "REDACTED" in brackets. Be sure to identify
above all fields which contain data for which you are seeking non-public status.
The Commission is not responsible for detecting or correcting filer errors, including those errors related to security
designation. If your documents contain sensitive information, make sure they are filed using the proper security designation.
Exhibit 13 Page 61
PUBLIC (REDACTED)FEDERAL ENERGY REGULATORY COMMISSION
WASHINGTON, DC
OMB Control # 1902-0075
Form 556 Certification of Qualifying Facility (QF) Status for a Small Power
Production or Cogeneration Facility
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1a Full name of applicant (legal entity on whose behalf qualifying facility status is sought for this facility)
Fall River Rural Electric Cooperative,Inc.
1b Applicant street address
1150 North 3400 East
1c City
Ashton
1d State/province
ID
1e Postal code
83420
1f Country (if not United States)1g Telephone number
[phone]
1h Has the instant facility ever previously been certified as a QF?Yes No
1i If yes, provide the docket number of the last known QF filing pertaining to this facility: QF10 -337 -000
1j Under which certification process is the applicant making this filing?
Notice of self-certification
(see note below)
Application for Commission certification (requires filing
fee; see "Filing Fee" section on page 3)
Note: a notice of self-certification is a notice by the applicant itself that its facility complies with the requirements for
QF status. A notice of self-certification does not establish a proceeding, and the Commission does not review a
notice of self-certification to verify compliance. See the "What to Expect From the Commission After You File"
section on page 3 for more information.
1k What type(s) of QF status is the applicant seeking for its facility? (check all that apply)
Qualifying small power production facility status Qualifying cogeneration facility status
1l What is the purpose and expected effective date(s) of this filing?
Original certification; facility expected to be installed by and to begin operation on
Change(s) to a previously certified facility to be effective on
(identify type(s) of change(s) below, and describe change(s) in the Miscellaneous section starting on page 19)
Name change and/or other administrative change(s)
Change in ownership
Change(s) affecting plant equipment, fuel use, power production capacity and/or cogeneration thermal output
Supplement or correction to a previous filing submitted on 3/2/10
(describe the supplement or correction in the Miscellaneous section starting on page 19)
1m If any of the following three statements is true, check the box(es) that describe your situation and complete the form
to the extent possible, explaining any special circumstances in the Miscellaneous section starting on page 19.
The instant facility complies with the Commission's QF requirements by virtue of a waiver of certain regulations
previously granted by the Commission in an order dated (specify any other relevant waiver
orders in the Miscellaneous section starting on page 19)
The instant facility would comply with the Commission's QF requirements if a petition for waiver submitted
concurrently with this application is granted
The instant facility complies with the Commission's regulations, but has special circumstances, such as the
employment of unique or innovative technologies not contemplated by the structure of this form, that make
the demonstration of compliance via this form difficult or impossible (describe in Misc. section starting on p. 19)
Expiration 5/31/2013
Exhibit 13 Page 62
FERC Form 556 Page 6 - All FacilitiesPUBLIC (REDACTED)
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2a Name of contact person
Bryan L. Case
2b Telephone number
208-652-7431
2c Which of the following describes the contact person's relationship to the applicant? (check one)
Applicant (self)Employee, owner or partner of applicant authorized to represent the applicant
Employee of a company affiliated with the applicant authorized to represent the applicant on this matter
Lawyer, consultant, or other representative authorized to represent the applicant on this matter
Fall River Rural Electric Cooperative, Inc.
2d Company or organization name (if applicant is an individual, check here and skip to line 2e)
2e Street address (if same as Applicant, check here and skip to line 3a)
2f City 2g State/province
2h Postal code 2i Country (if not United States)
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3a Facility name
Chester Diversion Hydroelectric Project, FERC Project No. 11879
3b Street address (if a street address does not exist for the facility, check here and skip to line 3c)
3c Geographic coordinates: If you indicated that no street address exists for your facility by checking the box in line 3b,
then you must specify the latitude and longitude coordinates of the facility in degrees (to three decimal places). Use
the following formula to convert to decimal degrees from degrees, minutes and seconds: decimal degrees =
degrees + (minutes/60) + (seconds/3600). See the "Geographic Coordinates" section on page 4 for help. If you
provided a street address for your facility in line 3b, then specifying the geographic coordinates below is optional.
Longitude East (+)
West (-)degrees111.583 Latitude North (+)
South (-)degrees44.017
3d City (if unincorporated, check here and enter nearest city)
between Ashton and St. Anthony
3e State/province
Idaho
3f County (or check here for independent city)
Fremont
3g Country (if not United States)
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Identify the electric utilities that are contemplated to transact with the facility.
4a Identify utility interconnecting with the facility
Fall River Rural Electric Cooperative, Inc.
Bonneville Power Administration
4b Identify utilities providing wheeling service or check here if none
Idaho Power Company (power purchase agreement approval pending)
4c Identify utilities purchasing the useful electric power output or check here if none
Fall River Rural Electric Cooperative, Inc.
4d Identify utilities providing supplementary power, backup power, maintenance power, and/or interruptible power
service or check here if none
Exhibit 13 Page 63
FERC Form 556 Page 7 - All FacilitiesPUBLIC (REDACTED)
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5a Direct ownership as of effective date or operation date: Identify all direct owners of the facility holding at least 10
percent equity interest. For each identified owner, also (1) indicate whether that owner is an electric utility, as
defined in section 3(22) of the Federal Power Act (16 U.S.C. 796(22)), or a holding company, as defined in section
1262(8) of the Public Utility Holding Company Act of 2005 (42 U.S.C. 16451(8)), and (2) for owners which are electric
utilities or holding companies, provide the percentage of equity interest in the facility held by that owner. If no
direct owners hold at least 10 percent equity interest in the facility, then provide the required information for the
two direct owners with the largest equity interest in the facility.
Full legal names of direct owners
Electric utility or
holding
company
If Yes,
% equity
interest
1)Fall River Rural Electric Cooperative, Inc.Yes No %100
2)Fremont-Madison Irrigation District Yes No %0
3)Yes No %
4)Yes No %
5)Yes No %
6)Yes No %
7)Yes No %
8)Yes No %
9)Yes No %
10)Yes No %
Check here and continue in the Miscellaneous section starting on page 19 if additional space is needed
5b Upstream (i.e., indirect) ownership as of effective date or operation date: Identify all upstream (i.e., indirect) owners
of the facility that both (1) hold at least 10 percent equity interest in the facility, and (2) are electric utilities, as
defined in section 3(22) of the Federal Power Act (16 U.S.C. 796(22)), or holding companies, as defined in section
1262(8) of the Public Utility Holding Company Act of 2005 (42 U.S.C. 16451(8)). Also provide the percentage of
equity interest in the facility held by such owners. (Note that, because upstream owners may be subsidiaries of one
another, total percent equity interest reported may exceed 100 percent.)
Check here if no such upstream owners exist.
Full legal names of electric utility or holding company upstream owners
% equity
interest
1)%
2)%
3)%
4)%
5)%
6)%
7)%
8)%
9)%
10)%
Check here and continue in the Miscellaneous section starting on page 19 if additional space is needed
5c Identify the facility operator
Fall River Rural Electric Cooperative, Inc.
Exhibit 13 Page 64
FERC Form 556 Page 8 - All FacilitiesPUBLIC (REDACTED)
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6a Describe the primary energy input: (check one main category and, if applicable, one subcategory)
Biomass (specify)
Landfill gas
Manure digester gas
Municipal solid waste
Sewage digester gas
Wood
Other biomass (describe on page 19)
Waste (specify type below in line 6b)
Renewable resources (specify)
Hydro power - river
Hydro power - tidal
Hydro power - wave
Solar - photovoltaic
Solar - thermal
Wind
Other renewable resource
(describe on page 19)
Geothermal
Fossil fuel (specify)
Coal (not waste)
Fuel oil/diesel
Natural gas (not waste)
Other fossil fuel
(describe on page 19)
Other (describe on page 19)
6b If you specified "waste" as the primary energy input in line 6a, indicate the type of waste fuel used: (check one)
Waste fuel listed in 18 C.F.R. § 292.202(b) (specify one of the following)
Anthracite culm produced prior to July 23, 1985
Anthracite refuse that has an average heat content of 6,000 Btu or less per pound and has an average
ash content of 45 percent or more
Bituminous coal refuse that has an average heat content of 9,500 Btu per pound or less and has an
average ash content of 25 percent or more
Top or bottom subbituminous coal produced on Federal lands or on Indian lands that has been
determined to be waste by the United States Department of the Interior's Bureau of Land Management
(BLM) or that is located on non-Federal or non-Indian lands outside of BLM's jurisdiction, provided that
the applicant shows that the latter coal is an extension of that determined by BLM to be waste
Coal refuse produced on Federal lands or on Indian lands that has been determined to be waste by the
BLM or that is located on non- Federal or non-Indian lands outside of BLM's jurisdiction, provided that
applicant shows that the latter is an extension of that determined by BLM to be waste
Lignite produced in association with the production of montan wax and lignite that becomes exposed
as a result of such a mining operation
Gaseous fuels (except natural gas and synthetic gas from coal) (describe on page 19)
Waste natural gas from gas or oil wells

(describe on page 19 how the gas meets the requirements of 18
C.F.R. § 2.400 for waste natural gas; include with your filing any materials necessary to demonstrate
compliance with 18 C.F.R. § 2.400)
Materials that a government agency has certified for disposal by combustion (describe on page 19)
Heat from exothermic reactions (describe on page 19)Residual heat (describe on page 19)
Used rubber tires Plastic materials Refinery off-gas Petroleum coke
Other waste energy input that has little or no commercial value and exists in the absence of the qualifying
facility industry

(describe in the Miscellaneous section starting on page 19; include a discussion of the fuel's
lack of commercial value and existence in the absence of the qualifying facility industry)
6c Provide the average energy input, calculated on a calendar year basis, in terms of Btu/h for the following fossil fuel
energy inputs, and provide the related percentage of the total average annual energy input to the facility (18 C.F.R. §
292.202(j)). For any oil or natural gas fuel, use lower heating value (18 C.F.R. § 292.202(m)).
Fuel
Annual average energy
input for specified fuel
Percentage of total
annual energy input
Natural gas Btu/h %
Oil-based fuels Btu/h %
Coal Btu/h %
Exhibit 13 Page 65
FERC Form 556 Page 9 - All FacilitiesPUBLIC (REDACTED)
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Indicate the maximum gross and maximum net electric power production capacity of the facility at the point(s) of
delivery by completing the worksheet below. Respond to all items. If any of the parasitic loads and/or losses identified in
lines 7b through 7e are negligible, enter zero for those lines.
7a The maximum gross power production capacity at the terminals of the individual generator(s)
under the most favorable anticipated design conditions kW3,600
7b Parasitic station power used at the facility to run equipment which is necessary and integral to
the power production process (boiler feed pumps, fans/blowers, office or maintenance buildings
directly related to the operation of the power generating facility, etc.). If this facility includes non-
power production processes (for instance, power consumed by a cogeneration facility's thermal
host) , do not include any power consumed by the non-power production activities in your
reported parasitic station power.kW 250
7c Electrical losses in interconnection transformers
kW0
7d Electrical losses in AC/DC conversion equipment, if any
kW 0
7e Other interconnection losses in power lines or facilities (other than transformers and AC/DC
conversion equipment) between the terminals of the generator(s) and the point of interconnection
with the utility kW 500
7f Total deductions from gross power production capacity = 7b + 7c + 7d + 7e
kW 750.0
7g Maximum net power production capacity = 7a - 7f
kW2,850.0
7h Description of facility and primary components: Describe the facility and its operation. Identify all boilers, heat
recovery steam generators, prime movers (any mechanical equipment driving an electric generator), electrical
generators, photovoltaic solar equipment, fuel cell equipment and/or other primary power generation equipment
used in the facility. Descriptions of components should include (as applicable) specifications of the nominal
capacities for mechanical output, electrical output, or steam generation of the identified equipment. For each piece
of equipment identified, clearly indicate how many pieces of that type of equipment are included in the plant, and
which components are normally operating or normally in standby mode. Provide a description of how the
components operate as a system. Applicants for cogeneration facilities do not need to describe operations of
systems that are clearly depicted on and easily understandable from a cogeneration facility's attached mass and
heat balance diagram; however, such applicants should provide any necessary description needed to understand
the sequential operation of the facility depicted in their mass and heat balance diagram. If additional space is
needed, continue in the Miscellaneous section starting on page 19.
Three Kaplan S-type turbines with generators rated at 1200 kw. Output will feed
into Fall River's 15 kv system.
Exhibit 13 Page 66
Page 10 - Small Power Production FERC Form 556
If you answered Yes, provide
a brief narrative explanation in the Miscellaneous section starting on page 19 of the construction timeline (in
particular, describe why construction started so long after the facility was certified) and the diligence exercised
toward completion of the facility.
PUBLIC (REDACTED)
Information Required for Small Power Production Facility
If you indicated in line 1k that you are seeking qualifying small power production facility status for your facility, then you
must respond to the items on this page. Otherwise, skip page 10.
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Pursuant to 18 C.F.R. § 292.204(a), the power production capacity of any small power production facility, together
with the power production capacity of any other small power production facilities that use the same energy
resource, are owned by the same person(s) or its affiliates, and are located at the same site, may not exceed 80
megawatts. To demonstrate compliance with this size limitation, or to demonstrate that your facility is exempt
from this size limitation under the Solar, Wind, Waste, and Geothermal Power Production Incentives Act of 1990
(Pub. L. 101-575, 104 Stat. 2834 (1990) as amended by Pub. L. 102-46, 105 Stat. 249 (1991)), respond to lines 8a
through 8e below (as applicable).
8a Identify any facilities with electrical generating equipment located within 1 mile of the electrical generating
equipment of the instant facility, and for which any of the entities identified in lines 5a or 5b, or their affiliates, holds
at least a 5 percent equity interest.
Check here if no such facilities exist.
Facility location
(city or county, state)
Root docket #
(if any)Common owner(s)
Maximum net power
production capacity
1)QF -kW
2)QF -kW
3)QF -kW
Check here andcontinue in the Miscellaneous section starting on page 19 if additional space is needed
8b The Solar, Wind, Waste, and Geothermal Power Production Incentives Act of 1990 (Incentives Act) provides
exemption from the size limitations in 18 C.F.R. § 292.204(a) for certain facilities that were certified prior to 1995.
Are you seeking exemption from the size limitations in 18 C.F.R. § 292.204(a) by virtue of the Incentives Act?
Yes (continue at line 8c below)No (skip lines 8c through 8e)
8c Was the original notice of self-certification or application for Commission certification of the facility filed on or
before December 31, 1994?Yes No
8d Did construction of the facility commence on or before December 31, 1999?Yes No
8e If you answered No in line 8d, indicate whether reasonable diligence was exercised toward the completion of
the facility, taking into account all factors relevant to construction?
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Pursuant to 18 C.F.R. § 292.204(b), qualifying small power production facilities may use fossil fuels, in minimal
amounts, for only the following purposes: ignition; start-up; testing; flame stabilization; control use; alleviation or
prevention of unanticipated equipment outages; and alleviation or prevention of emergencies, directly affecting
the public health, safety, or welfare, which would result from electric power outages. The amount of fossil fuels
used for these purposes may not exceed 25 percent of the total energy input of the facility during the 12-month
period beginning with the date the facility first produces electric energy or any calendar year thereafter.
9a Certification of compliance with 18 C.F.R. § 292.204(b) with respect to uses of fossil fuel:
Applicant certifies that the facility will use fossil fuels exclusively for the purposes listed above.
9b Certification of compliance with 18 C.F.R. § 292.204(b) with respect to amount of fossil fuel used annually:
Applicant certifies that the amount of fossil fuel used at the facility will not, in aggregate, exceed 25
percent of the total energy input of the facility during the 12-month period beginning with the date the
facility first produces electric energy or any calendar year thereafter.
Yes No
Exhibit 13 Page 67
Page 11 - Cogeneration FacilitiesFERC Form 556 PUBLIC (REDACTED)
Information Required for Cogeneration Facility
If you indicated in line 1k that you are seeking qualifying cogeneration facility status for your facility, then you must respond
to the items on pages 11 through 13. Otherwise, skip pages 11 through 13.
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Pursuant to 18 C.F.R. § 292.202(c), a cogeneration facility produces electric energy and forms of useful thermal
energy (such as heat or steam) used for industrial, commercial, heating, or cooling purposes, through the sequential
use of energy. Pursuant to 18 C.F.R. § 292.202(s), "sequential use" of energy means the following: (1) for a topping-
cycle cogeneration facility, the use of reject heat from a power production process in sufficient amounts in a
thermal application or process to conform to the requirements of the operating standard contained in 18 C.F.R. §
292.205(a); or (2) for a bottoming-cycle cogeneration facility, the use of at least some reject heat from a thermal
application or process for power production.
10a What type(s) of cogeneration technology does the facility represent? (check all that apply)
Topping-cycle cogeneration Bottoming-cycle cogeneration
10b To help demonstrate the sequential operation of the cogeneration process, and to support compliance with
other requirements such as the operating and efficiency standards, include with your filing a mass and heat
balance diagram depicting average annual operating conditions. This diagram must include certain items and
meet certain requirements, as described below. You must check next to the description of each requirement
below to certify that you have complied with these requirements.
Check to certify
compliance with
indicated requirement Requirement
Diagram must show orientation within system piping and/or ducts of all prime movers,
heat recovery steam generators, boilers, electric generators, and condensers (as
applicable), as well as any other primary equipment relevant to the cogeneration
process.
Any average annual values required to be reported in lines 10b, 12a, 13a, 13b, 13d, 13f,
14a, 15b, 15d and/or 15f must be computed over the anticipated hours of operation.
Diagram must specify all fuel inputs by fuel type and average annual rate in Btu/h. Fuel
for supplementary firing should be specified separately and clearly labeled. All
specifications of fuel inputs should use lower heating values.
Diagram must specify average gross electric output in kW or MW for each generator.
Diagram must specify average mechanical output (that is, any mechanical energy taken
off of the shaft of the prime movers for purposes not directly related to electric power
generation) in horsepower, if any. Typically, a cogeneration facility has no mechanical
output.
At each point for which working fluid flow conditions are required to be specified (see
below), such flow condition data must include mass flow rate (in lb/h or kg/s),
temperature (in °F, R, °C or K), absolute pressure (in psia or kPa) and enthalpy (in Btu/lb
or kJ/kg). Exception: For systems where the working fluid is liquid only (no vapor at any
point in the cycle) and where the type of liquid and specific heat of that liquid are clearly
indicated on the diagram or in the Miscellaneous section starting on page 19, only mass
flow rate and temperature (not pressure and enthalpy) need be specified. For reference,
specific heat at standard conditions for pure liquid water is approximately 1.002 Btu/
(lb*R) or 4.195 kJ/(kg*K).
Diagram must specify working fluid flow conditions at input to and output from each
steam turbine or other expansion turbine or back-pressure turbine.
Diagram must specify working fluid flow conditions at delivery to and return from each
thermal application.
Diagram must specify working fluid flow conditions at make-up water inputs.
Exhibit 13 Page 68
Page 12 - Cogeneration FacilitiesFERC Form 556 PUBLIC (REDACTED)
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EPAct 2005 cogeneration facilities: The Energy Policy Act of 2005 (EPAct 2005) established a new section 210(n) of
the Public Utility Regulatory Policies Act of 1978 (PURPA), 16 USC 824a-3(n), with additional requirements for any
qualifying cogeneration facility that (1) is seeking to sell electric energy pursuant to section 210 of PURPA and (2)
was either not a cogeneration facility on August 8, 2005, or had not filed a self-certification or application for
Commission certification of QF status on or before February 1, 2006. These requirements were implemented by the
Commission in 18 C.F.R. § 292.205(d). Complete the lines below, carefully following the instructions, to demonstrate
whether these additional requirements apply to your cogeneration facility and, if so, whether your facility complies
with such requirements.
11a Was your facility operating as a qualifying cogeneration facility on or before August 8, 2005?Yes No
11b Was the initial filing seeking certification of your facility (whether a notice of self-certification or an application
for Commission certification) filed on or before February 1, 2006?Yes No
If the answer to either line 11a or 11b is Yes, then continue at line 11c below. Otherwise, if the answers to both lines
11a and 11b are No, skip to line 11e below.
11c With respect to the design and operation of the facility, have any changes been implemented on or after
February 2, 2006 that affect general plant operation, affect use of thermal output, and/or increase net power
production capacity from the plant's capacity on February 1, 2006?
Yes (continue at line 11d below)
No. Your facility is not subject to the requirements of 18 C.F.R. § 292.205(d) at this time. However, it may be
subject to to these requirements in the future if changes are made to the facility. At such time, the applicant
would need to recertify the facility to determine eligibility. Skip lines 11d through 11j.
11d Does the applicant contend that the changes identified in line 11c are not so significant as to make the facility
a "new" cogeneration facility that would be subject to the 18 C.F.R. § 292.205(d) cogeneration requirements?
Yes.

Skip lines 11e through 11j.
Provide in the Miscellaneous section starting on page 19 a description of any relevant changes made to
the facility (including the purpose of the changes) and a discussion of why the facility should not be
considered a "new" cogeneration facility in light of these changes.
No. Applicant stipulates to the fact that it is a "new" cogeneration facility (for purposes of determining the
applicability of the requirements of 18 C.F.R. § 292.205(d)) by virtue of modifications to the facility that were
initiated on or after February 2, 2006. Continue below at line 11e.
11e Will electric energy from the facility be sold pursuant to section 210 of PURPA?
Yes. The facility is an EPAct 2005 cogeneration facility. You must demonstrate compliance with 18 C.F.R. §
292.205(d)(2) by continuing at line 11f below.
No. Applicant certifies that energy will not be sold pursuant to section 210 of PURPA. Applicant also certifies
its understanding that it must recertify its facility in order to determine compliance with the requirements of
18 C.F.R. § 292.205(d) before selling energy pursuant to section 210 of PURPA in the future. Skip lines 11f
through 11j.
11f Is the net power production capacity of your cogeneration facility, as indicated in line 7g above, less than or
equal to 5,000 kW?
Yes, the net power production capacity is less than or equal to 5,000 kW. 18 C.F.R. § 292.205(d)(4) provides a
rebuttable presumption that cogeneration facilities of 5,000 kW and smaller capacity comply with the
requirements for fundamental use of the facility's energy output in 18 C.F.R. § 292.205(d)(2). Applicant
certifies its understanding that, should the power production capacity of the facility increase above 5,000
kW, then the facility must be recertified to (among other things) demonstrate compliance with 18 C.F.R. §
292.205(d)(2). Skip lines 11g through 11j.
No, the net power production capacity is greater than 5,000 kW. Demonstrate compliance with the
requirements for fundamental use of the facility's energy output in 18 C.F.R. § 292.205(d)(2) by continuing on
the next page at line 11g.
Exhibit 13 Page 69
Page 13 - Cogeneration FacilitiesFERC Form 556 PUBLIC (REDACTED)
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Lines 11g through 11k below guide the applicant through the process of demonstrating compliance with the
requirements for "fundamental use" of the facility's energy output. 18 C.F.R. § 292.205(d)(2). Only respond to the
lines on this page if the instructions on the previous page direct you to do so. Otherwise, skip this page.
18 C.F.R. § 292.205(d)(2) requires that the electrical, thermal, chemical and mechanical output of an EPAct 2005
cogeneration facility is used fundamentally for industrial, commercial, residential or institutional purposes and is
not intended fundamentally for sale to an electric utility, taking into account technological, efficiency, economic,
and variable thermal energy requirements, as well as state laws applicable to sales of electric energy from a
qualifying facility to its host facility. If you were directed on the previous page to respond to the items on this page,
then your facility is an EPAct 2005 cogeneration facility that is subject to this "fundamental use" requirement.
The Commission's regulations provide a two-pronged approach to demonstrating compliance with the
requirements for fundamental use of the facility's energy output. First, the Commission has established in 18 C.F.R.
§ 292.205(d)(3) a "fundamental use test" that can be used to demonstrate compliance with 18 C.F.R. § 292.205(d)(2).
Under the fundamental use test, a facility is considered to comply with 18 C.F.R. § 292.205(d)(2) if at least 50 percent
of the facility's total annual energy output (including electrical, thermal, chemical and mechanical energy output) is
used for industrial, commercial, residential or institutional purposes.
Second, an applicant for a facility that does not pass the fundamental use test may provide a narrative explanation
of and support for its contention that the facility nonetheless meets the requirement that the electrical, thermal,
chemical and mechanical output of an EPAct 2005 cogeneration facility is used fundamentally for industrial,
commercial, residential or institutional purposes and is not intended fundamentally for sale to an electric utility,
taking into account technological, efficiency, economic, and variable thermal energy requirements, as well as state
laws applicable to sales of electric energy from a qualifying facility to its host facility.
Complete lines 11g through 11j below to determine compliance with the fundamental use test in 18 C.F.R. §
292.205(d)(3). Complete lines 11g through 11j even if you do not intend to rely upon the fundamental use test to
demonstrate compliance with 18 C.F.R. § 292.205(d)(2).
11g Amount of electrical, thermal, chemical and mechanical energy output (net of internal
generation plant losses and parasitic loads) expected to be used annually for industrial,
commercial, residential or institutional purposes and not sold to an electric utility MWh
11h Total amount of electrical, thermal, chemical and mechanical energy expected to be
sold to an electric utility MWh
11i Percentage of total annual energy output expected to be used for industrial,
commercial, residential or institutional purposes and not sold to a utility
= 100 * 11g /(11g + 11h)% 0
11j Is the response in line 11i greater than or equal to 50 percent?
Yes. Your facility complies with 18 C.F.R. § 292.205(d)(2) by virtue of passing the fundamental use test
provided in 18 C.F.R. § 292.205(d)(3). Applicant certifies its understanding that, if it is to rely upon passing
the fundamental use test as a basis for complying with 18 C.F.R. § 292.205(d)(2), then the facility must
comply with the fundamental use test both in the 12-month period beginning with the date the facility first
produces electric energy, and in all subsequent calendar years.
No. Your facility does not pass the fundamental use test.

Applicants providing a narrative explanation of why their facility should be found to
comply with 18 C.F.R. § 292.205(d)(2) in spite of non-compliance with the fundamental use test may want to
review paragraphs 47 through 61 of Order No. 671 (accessible from the Commission's QF website at
www.ferc.gov/QF), which provide discussion of the facts and circumstances that may support their
explanation. Applicant should also note that the percentage reported above will establish the standard that
that facility must comply with, both for the 12-month period beginning with the date the facility first
produces electric energy, and in all subsequent calendar years. See Order No. 671 at paragraph 51. As such,
the applicant should make sure that it reports appropriate values on lines 11g and 11h above to serve as the
relevant annual standard, taking into account expected variations in production conditions.
Instead, you must provide in the Miscellaneous
section starting on page 19 a narrative explanation of and support for why your facility meets the
requirement that the electrical, thermal, chemical and mechanical output of an EPAct 2005 cogeneration
facility is used fundamentally for industrial, commercial, residential or institutional purposes and is not
intended fundamentally for sale to an electric utility, taking into account technological, efficiency, economic,
and variable thermal energy requirements, as well as state laws applicable to sales of electric energy from a
QF to its host facility.

Exhibit 13 Page 70
Page 14 - Topping-Cycle Cogeneration FacilitiesFERC Form 556 PUBLIC (REDACTED)
Information Required for Topping-Cycle Cogeneration Facility
If you indicated in line 10a that your facility represents topping-cycle cogeneration technology, then you must respond to
the items on pages 14 and 15. Otherwise, skip pages 14 and 15.
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The thermal energy output of a topping-cycle cogeneration facility is the net energy made available to an industrial
or commercial process or used in a heating or cooling application. Pursuant to sections 292.202(c), (d) and (h) of the
Commission's regulations (18 C.F.R. §§ 292.202(c), (d) and (h)), the thermal energy output of a qualifying topping-
cycle cogeneration facility must be useful. In connection with this requirement, describe the thermal output of the
topping-cycle cogeneration facility by responding to lines 12a and 12b below.
12a Identify and describe each thermal host, and specify the annual average rate of thermal output made available
to each host for each use. For hosts with multiple uses of thermal output, provide the data for each use in
separate rows.
Name of entity (thermal host)
taking thermal output
Thermal host's relationship to facility;
Thermal host's use of thermal output
Average annual rate of
thermal output
attributable to use (net of
heat contained in process
return or make-up water)
1)Select thermal host's relationship to facility
Select thermal host's use of thermal output Btu/h
2)Select thermal host's relationship to facility
Select thermal host's use of thermal output Btu/h
3)Select thermal host's relationship to facility
Select thermal host's use of thermal output Btu/h
4)Select thermal host's relationship to facility
Select thermal host's use of thermal output Btu/h
5)Select thermal host's relationship to facility
Select thermal host's use of thermal output Btu/h
6)Select thermal host's relationship to facility
Select thermal host's use of thermal output Btu/h
Check here and continue in the Miscellaneous section starting on page 19 if additional space is needed
12b Demonstration of usefulness of thermal output: At a minimum, provide a brief description of each use of the
thermal output identified above. In some cases, this brief description is sufficient to demonstrate usefulness.
However, if your facility's use of thermal output is not common, and/or if the usefulness of such thermal output is
not reasonably clear, then you must provide additional details as necessary to demonstrate usefulness. Your
application may be rejected and/or additional information may be required if an insufficient showing of usefulness
is made. (Exception: If you have previously received a Commission certification approving a specific use of thermal
output related to the instant facility, then you need only provide a brief description of that use and a reference by
date and docket number to the order certifying your facility with the indicated use. Such exemption may not be
used if any change creates a material deviation from the previously authorized use.) If additional space is needed,
continue in the Miscellaneous section starting on page 19.
Exhibit 13 Page 71
Page 15 - Topping-Cycle Cogeneration FacilitiesFERC Form 556 PUBLIC (REDACTED)
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Applicants for facilities representing topping-cycle technology must demonstrate compliance with the topping-
cycle operating standard and, if applicable, efficiency standard. Section 292.205(a)(1) of the Commission's
regulations (18 C.F.R. § 292.205(a)(1)) establishes the operating standard for topping-cycle cogeneration facilities:
the useful thermal energy output must be no less than 5 percent of the total energy output. Section 292.205(a)(2)
(18 C.F.R. § 292.205(a)(2)) establishes the efficiency standard for topping-cycle cogeneration facilities for which
installation commenced on or after March 13, 1980: the useful power output of the facility plus one-half the useful
thermal energy output must (A) be no less than 42.5 percent of the total energy input of natural gas and oil to the
facility; and (B) if the useful thermal energy output is less than 15 percent of the total energy output of the facility,
be no less than 45 percent of the total energy input of natural gas and oil to the facility. To demonstrate
compliance with the topping-cycle operating and/or efficiency standards, or to demonstrate that your facility is
exempt from the efficiency standard based on the date that installation commenced, respond to lines 13a through
13l below.
If you indicated in line 10a that your facility represents both topping-cycle and bottoming-cycle cogeneration
technology, then respond to lines 13a through 13l below considering only the energy inputs and outputs
attributable to the topping-cycle portion of your facility. Your mass and heat balance diagram must make clear
which mass and energy flow values and system components are for which portion (topping or bottoming) of the
cogeneration system.
13a Indicate the annual average rate of useful thermal energy output made available
to the host(s), net of any heat contained in condensate return or make-up water Btu/h
13b Indicate the annual average rate of net electrical energy output
kW
13c Multiply line 13b by 3,412 to convert from kW to Btu/h
Btu/h0
13d Indicate the annual average rate of mechanical energy output taken directly off
of the shaft of a prime mover for purposes not directly related to power production
(this value is usually zero)hp
13e Multiply line 13d by 2,544 to convert from hp to Btu/h
Btu/h0
13f Indicate the annual average rate of energy input from natural gas and oil
Btu/h
13g Topping-cycle operating value = 100 * 13a / (13a + 13c + 13e)
%0
13h Topping-cycle efficiency value = 100 * (0.5*13a + 13c + 13e) / 13f
%0
13i Compliance with operating standard: Is the operating value shown in line 13g greater than or equal to 5%?
Yes (complies with operating standard)No (does not comply with operating standard)
13j Did installation of the facility in its current form commence on or after March 13, 1980?
Yes. Your facility is subject to the efficiency requirements of 18 C.F.R. § 292.205(a)(2). Demonstrate
compliance with the efficiency requirement by responding to line 13k or 13l, as applicable, below.
No. Your facility is exempt from the efficiency standard. Skip lines 13k and 13l.
13k Compliance with efficiency standard (for low operating value): If the operating value shown in line 13g is less
than 15%, then indicate below whether the efficiency value shown in line 13h greater than or equal to 45%:
Yes (complies with efficiency standard)No (does not comply with efficiency standard)
13l Compliance with efficiency standard (for high operating value): If the operating value shown in line 13g is
greater than or equal to 15%, then indicate below whether the efficiency value shown in line 13h is greater than or
equal to 42.5%:
Yes (complies with efficiency standard)No (does not comply with efficiency standard)
Exhibit 13 Page 72
Page 16 - Bottoming-Cycle Cogeneration FacilitiesFERC Form 556 PUBLIC (REDACTED)
Information Required for Bottoming-Cycle Cogeneration Facility
If you indicated in line 10a that your facility represents bottoming-cycle cogeneration technology, then you must respond
to the items on pages 16 and 17. Otherwise, skip pages 16 and 17.
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The thermal energy output of a bottoming-cycle cogeneration facility is the energy related to the process(es) from
which at least some of the reject heat is then used for power production. Pursuant to sections 292.202(c) and (e) of
the Commission's regulations (18 C.F.R. § 292.202(c) and (e)) , the thermal energy output of a qualifying bottoming-
cycle cogeneration facility must be useful. In connection with this requirement, describe the process(es) from which
at least some of the reject heat is used for power production by responding to lines 14a and 14b below.
14a Identify and describe each thermal host and each bottoming-cycle cogeneration process engaged in by each
host. For hosts with multiple bottoming-cycle cogeneration processes, provide the data for each process in
separate rows.
Name of entity (thermal host)
performing the process from
which at least some of the
reject heat is used for power
production
Thermal host's relationship to facility;
Thermal host's process type
Has the energy input to
the thermal host been
augmented for purposes
of increasing power
production capacity?

(if Yes, describe on p. 19)
1)Select thermal host's relationship to facility
Select thermal host's process type
Yes No
2)Select thermal host's relationship to facility
Select thermal host's process type
Yes No
3)Select thermal host's relationship to facility
Select thermal host's process type
Yes No
Check here and continue in the Miscellaneous section starting on page 19 if additional space is needed
14b Demonstration of usefulness of thermal output: At a minimum, provide a brief description of each process
identified above. In some cases, this brief description is sufficient to demonstrate usefulness. However, if your
facility's process is not common, and/or if the usefulness of such thermal output is not reasonably clear, then you
must provide additional details as necessary to demonstrate usefulness. Your application may be rejected and/or
additional information may be required if an insufficient showing of usefulness is made. (Exception: If you have
previously received a Commission certification approving a specific bottoming-cycle process related to the instant
facility, then you need only provide a brief description of that process and a reference by date and docket number
to the order certifying your facility with the indicated process. Such exemption may not be used if any material
changes to the process have been made.) If additional space is needed, continue in the Miscellaneous section
starting on page 19.
Exhibit 13 Page 73
Page 17 - Bottoming-Cycle Cogeneration FacilitiesFERC Form 556 PUBLIC (REDACTED)
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Applicants for facilities representing bottoming-cycle technology and for which installation commenced on or after
March 13, 1990 must demonstrate compliance with the bottoming-cycle efficiency standards. Section 292.205(b) of
the Commission's regulations (18 C.F.R. § 292.205(b)) establishes the efficiency standard for bottoming-cycle
cogeneration facilities: the useful power output of the facility must be no less than 45 percent of the energy input
of natural gas and oil for supplementary firing. To demonstrate compliance with the bottoming-cycle efficiency
standard (if applicable), or to demonstrate that your facility is exempt from this standard based on the date that
installation of the facility began, respond to lines 15a through 15h below.
If you indicated in line 10a that your facility represents both topping-cycle and bottoming-cycle cogeneration
technology, then respond to lines 15a through 15h below considering only the energy inputs and outputs
attributable to the bottoming-cycle portion of your facility. Your mass and heat balance diagram must make clear
which mass and energy flow values and system components are for which portion of the cogeneration system
(topping or bottoming).
15a Did installation of the facility in its current form commence on or after March 13, 1980?
Yes. Your facility is subject to the efficiency requirement of 18 C.F.R. § 292.205(b). Demonstrate compliance
with the efficiency requirement by responding to lines 15b through 15h below.
No. Your facility is exempt from the efficiency standard. Skip the rest of page 17.
15b Indicate the annual average rate of net electrical energy output
kW
15c Multiply line 15b by 3,412 to convert from kW to Btu/h
Btu/h0
15d Indicate the annual average rate of mechanical energy output taken directly off
of the shaft of a prime mover for purposes not directly related to power production
(this value is usually zero)hp
15e Multiply line 15d by 2,544 to convert from hp to Btu/h
Btu/h0
15f Indicate the annual average rate of supplementary energy input from natural gas
or oil Btu/h
15g Bottoming-cycle efficiency value = 100 * (15c + 15e) / 15f
%0
15h Compliance with efficiency standard: Indicate below whether the efficiency value shown in line 15g is greater
than or equal to 45%:
Yes (complies with efficiency standard)No (does not comply with efficiency standard)
Exhibit 13 Page 74
FERC Form 556 Page 18 - All FacilitiesPUBLIC (REDACTED)
Certificate of Completeness, Accuracy and Authority
Applicant must certify compliance with and understanding of filing requirements by checking next to each item below and
signing at the bottom of this section. Forms with incomplete Certificates of Completeness, Accuracy and Authority will be
rejected by the Secretary of the Commission.
Signer identified below certifies the following: (check all items and applicable subitems)
He or she has read the filing, including any information contained in any attached documents, such as cogeneration
mass and heat balance diagrams, and any information contained in the Miscellaneous section starting on page 19, and
knows its contents.
He or she has provided all of the required information for certification, and the provided information is true as stated,
to the best of his or her knowledge and belief.
He or she possess full power and authority to sign the filing; as required by Rule 2005(a)(3) of the Commission's Rules of
Practice and Procedure (18 C.F.R. § 385.2005(a)(3)), he or she is one of the following: (check one)
The person on whose behalf the filing is made
An officer of the corporation, trust, association, or other organized group on behalf of which the filing is made
An officer, agent, or employe of the governmental authority, agency, or instrumentality on behalf of which the
filing is made
A representative qualified to practice before the Commission under Rule 2101 of the Commission's Rules of
Practice and Procedure (18 C.F.R. § 385.2101) and who possesses authority to sign
He or she has reviewed all automatic calculations and agrees with their results, unless otherwise noted in the
Miscellaneous section starting on page 19.
He or she has provided a copy of this Form 556 and all attachments to the utilities with which the facility will
interconnect and transact (see lines 4a through 4d), as well as to the regulatory authorities of the states in which the
facility and those utilities reside. See the Required Notice to Public Utilities and State Regulatory Authorities section on
page 3 for more information.
Provide your signature, address and signature date below. Rule 2005(c) of the Commission's Rules of Practice and
Procedure (18 C.F.R. § 385.2005(c)) provides that persons filing their documents electronically may use typed characters
representing his or her name to sign the filed documents. A person filing this document electronically should sign (by
typing his or her name) in the space provided below.
Your Signature
Gregory M. Adams
Your address
515 N. 27th Street, Boise, Idaho
83702
Date
10/21/2010
Audit Notes
Commission Staff Use Only:
Exhibit 13 Page 75
FERC Form 556 Page 19 - All Facilities
Miscellaneous
Use this space to provide any information for which there was not sufficient space in the previous sections of the form to
provide. For each such item of information clearly identify the line number that the information belongs to. You may also use
this space to provide any additional information you believe is relevant to the certification of your facility.
Your response below is not limited to one page. Additional page(s) will automatically be inserted into this form if the
length of your response exceeds the space on this page. Use as many pages as you require.
PUBLIC (REDACTED)
1l. The applicant, Fall River Rural Electric Cooperative, submits this self
recertification form to supplement the information filed in the initial self
certification form on March 2, 2010. The changes since the initial filing are that the
facility will interconnect with Fall River Rural Electric Cooperative's distribution
system, and will wheel the output over its system and the system of Bonneville Power
Administrative to the Goshen Substation in Idaho for delivery and sale to Idaho Power
Company. The previous filing described the facility to interconnect and sell its output
to PacifiCorp, dba Rocky Mountain Power

5a. Fall River Rural Electric Cooperative is currently the full owner of the facility.
After capital expenses are paid, Fremont Madison Irrigation District will become a fifty
percent owner, entitled to fifty percent of the profits from the Chester Diversion
Project.
Exhibit 13 Page 76