Final Approved Tariffs.pdf

IDAHO—>i *SI POWER
An idacorp company
DONOVAN E.WALKER
Lead Counsel
[e-mail]
Januarys,2015
ELECTRONICALLY FILED
Jean D.Jewell,Secretary
Idaho Public Utilities Commission
472 West Washington Street
P.O.Box 83720
Boise,Idaho 83720-0074
Re:IPC-E-14-24 -Compliance Filing,Revised Tariff Schedule 73
Dear Ms.Jewell:
Idaho Power Company hereby submits the enclosed compliance filing in the
above-captioned proceeding pursuant to Commission Order No.33197 which includes
its revised Tariff Schedule 73 with an effective date of January 1,2015.
If you have any questions regarding this filing,please contact Mike Youngblood at
388-2882 or [e-mail].
Very truly'Vours,
lovan E.Walker
DEW/kkt
Enclosures
cc:RA File
Legal File
P.O.Box 70 (83707)
1221 W.Idaho St.
Boise,ID 83702
RECEIVED
2015 January 6 PM 4:27
IDAHO PUBLIC
UTILITIES COMMISSION
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 73-1

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33197 Gregory W. Said, Vice President, Regulatory Affairs
Effective – January 1, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE - IDAHO

AVAILABILITY

In all electric territory served by the Company in the State of Idaho.

APPLICABILITY

To Qualifying Facilities that intend to sell their output to the Company by either (i)
interconnecting to the Company’s electrical system at an interconnection point within the State of Idaho,
or (ii) delivering the output to the Company at a point of delivery (“POD”) on the Company’s electrical
system within the State of Idaho.

A Customer selling the output of any Qualifying Facility (including both Qualifying Facilities with
a maximum generating capability equal to or less than the Eligibility Cap and Qualifying Facilities with a
maximum generating capability greater than the Eligibility Cap) will be required to enter into a written
Energy Sales Agreement (“ESA”) with the Company in accordance with the contracting procedures set
forth in this tariff. Any such ESA is subject to the approval of the Idaho Public Utilities Commission
(“Commission”).

DEFINITIONS

Customer as used herein means any individual, partnership, corporation, association,
governmental agency, political subdivision, municipality, or other entity that owns an existing or
proposed Qualifying Facility.

Cogeneration Facility means equipment used to produce 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.

Daily Shape Adjustment means an adjustment to rates based on a difference between Heavy
Load rates and Light Load rates of $7.28 per MWh as established in Commission Order No. 30415.

Eligibility Cap means for all Qualifying Facilities except wind and solar Qualifying Facilities, 10
average megawatts in any given month. For wind and solar Qualifying Facilities, “Eligibility Cap”
means 100 kilowatts (“kW”) nameplate capacity.

Facility means the electric generation facility owned by the Customer that is located on the
Customer’s side of the POD, and all facilities ancillary and appurtenant thereto, including
interconnection equipment.

Heavy Load Hours means the daily hours from hour ending 0700 – 2200 Mountain Time, (16
hours) excluding all hours on Sundays, New Years Day, Memorial Day, Independence Day, Labor Day,
Thanksgiving Day, and Christmas Day.

Light Load Hours means the daily hours from hour ending 2300 – 0600 Mountain Time, (8
hours) plus all hours on Sundays, New Years Day, Memorial Day, Independence Day, Labor Day,
Thanksgiving Day, and Christmas Day.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jan. 8, 2015 Jan. 1, 2015
Per O.N. 33197
Jean D. Jewell Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 73-2

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33197 Gregory W. Said, Vice President, Regulatory Affairs
Effective – January 1, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE - IDAHO
(Continued)
DEFINITIONS (continued)

Integration Charges means the Commission-approved integration charge applicable to any
intermittent generation resource, including but not limited to, wind and solar generation.

Generator Interconnection Agreement (“GIA”). The interconnection agreement that specifies
terms, conditions, and requirements of interconnecting to the Company electrical system, which will
include, but not be limited to, all requirements as specified by Schedule 72. If the Facility is not
interconnecting directly to the Company electrical system, the Facility will not have a GIA with the
Company but instead will have a similar agreement with the utility the Facility is directly interconnecting
to.

Point of Delivery (POD) is the location specified in the GIA (or Transmission Agreement) where
the Company’s and the Seller’s (or third-party transmission provider’s) electrical facilities are
interconnected and the energy from the Qualifying Facility is delivered to the Company electrical
system.

Qualifying Facility shall mean a Cogeneration Facility or a Small Power Production Facility that
is a “Qualifying Facility” as that term is defined in the Federal Energy Regulatory Commission’s
regulations, 18 C.F.R. § 292.101(b)(1) (2010), as may be amended or superseded.

Seasonal Factors means a seasonal weighting of 0.735 for the months of March, April, and
May, 1.20 for the months of July, August, November, and December and 1.00 for the months of
January, February, June, September, and October.

Small Power Production Facility means the equipment used to produce output including electric
energy solely by the use of biomass, waste, solar power, wind, water, or any other renewable resource.

Transmission Agreement. If the Facility is not directly interconnected to the Company electrical
system, the Facility must obtain firm transmission rights from the appropriate utility(s) to deliver the
Facility’s maximum capacity to an agreed to POD on the Company electrical system for the full term of
the ESA. This agreement(s) shall have minimum terms equal to the lesser of (a) the term of the ESA
being requested by the Qualifying Facility in Section 1.a.xiv., or (b) the minimum term required by the
third-party transmission entity to ensure firm roll over transmission rights, and (c) any other applicable
terms and conditions to ensure the Facility shall have firm transmission rights for the full term of the
ESA.

RATE OPTIONS

The Company is required to pay the following rates, at the election of the Qualifying Facility, for
the purchase of output from Facilities for which this tariff applies and that is delivered and accepted by
the Company in accordance with the ESA. These rates are adjusted periodically and are on file with
the Commission.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jan. 8, 2015 Jan. 1, 2015
Per O.N. 33197
Jean D. Jewell Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 73-3

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33197 Gregory W. Said, Vice President, Regulatory Affairs
Effective – January 1, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE - IDAHO
(Continued)

RATES OPTIONS (Continued)

1. Levelized Fueled Rates. These rates shall apply to Qualifying Facility projects at or
below the Eligibility Cap when the Customer chooses to supply output including energy and capacity
under Levelized Avoided Cost Rates for Fueled Facilities. The rates shall apply to Facilities fueled with
fossil fuels and shall depend upon the on-line operation date and term of the agreement and shall be
fixed for the term. The adjustable component rate shall be changed periodically subject to Commission
orders. Both the fixed and adjustable rate components are subject to Seasonal Factors, a Daily Shape
Adjustment, and Integration Charges.

2. Non-Levelized Fueled Rates. These rates shall apply to Qualifying Facility projects at or
below the Eligibility Cap when the Customer chooses to supply output including energy and capacity
under Non-Levelized Avoided Cost Rates for Fueled Facilities. The rates shall apply to Facilities fueled
with fossil fuels and shall depend upon the on-line operation date and term of the agreement. The fixed
component rate shall be fixed for the term of the agreement. The adjustable component rate shall be
changed periodically subject to Commission orders. Both the fixed and adjustable rate components are
subject to Seasonal Factors, a Daily Shape Adjustment, and Integration Charges.

3. Levelized Non-Fueled Rates. These rates shall apply to Qualifying Facility projects at or
below the Eligibility Cap when the Customer chooses to supply output including energy and capacity
under Levelized Avoided Cost Rates for Non-Fueled Facilities. These rates shall apply to Facilities that
do not use fossil fuels as their primary fuel. The rates shall depend upon the on-line operation date and
term of the agreement and shall be fixed for the term. The rate components are subject to Seasonal
Factors, a Daily Shape Adjustment, and Integration Charges.

4. Non-Levelized Non-Fueled Rates. These rates shall apply to Qualifying Facility projects
at or below the Eligibility Cap when the Customer chooses to supply output including energy and
capacity under a contract based on Non-Levelized Avoided Cost Rates for Non-Fueled Facilities.
These rates shall apply to Facilities that do not use fossil fuels as their primary fuel, and shall be fixed
for the term. The rates are subject to a Seasonal Factor, a Daily Shape Adjustment, and Integration
Charges.

5. Rates Determined at the Time of Delivery. Please see the Company’s tariff Schedule
86.

6. Integrated Resource Plan (“IRP”) Based Rate. The IRP Based Rate is required for all
Qualifying Facilities that do not meet the Eligibility Cap and shall be calculated based on the
Incremental Cost IRP Methodology tailored to the individual characteristics of the proposed Qualifying
Facility.

CONTRACTING PROCEDURES

The Company agrees to adhere to the following contract procedures for the purchase of output
from Customers who own Qualifying Facilities for which this tariff applies and that is delivered to the
Company’s system. These contracting procedures are adjusted periodically and are on file with the
Commission.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jan. 8, 2015 Jan. 1, 2015
Per O.N. 33197
Jean D. Jewell Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 73-4

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33197 Gregory W. Said, Vice President, Regulatory Affairs
Effective – January 1, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE - IDAHO
(Continued)

CONTRACTING PROCEDURES (Continued)

1. Procedures

a. To obtain an indicative pricing proposal for a proposed Qualifying Facility, the
Customer shall provide the Company a completed Qualifying Facility Energy Sales Agreement
Application utilizing the Application template included in this Schedule. The information required
within the application is general information as listed below.

i. Qualifying Facility owner name, organizational structure and chart, contact
information, and project name;

ii. Generation and other related technology applicable to the Qualifying
Facility;

iii. Maximum design capacity, station service requirements, and the net
amount of power, all in kW, to be delivered to the Company’s electric system by the
Qualifying Facility;

iv. Schedule of estimated Qualifying Facility electric output, in an 8,760-hour
electronic spreadsheet format;

v. Ability, if any, of Qualifying Facility to respond to dispatch orders from the
Company;

vi. Map of Qualifying Facility location, electrical interconnection point, and
POD (identified by nearest landmark and GPS coordinates);

vii. Anticipated commencement date for delivery of electric output;

viii. List of acquired and outstanding Qualifying Facility permits, including a
description of the status and timeline for acquisition of any outstanding permits;

ix. Demonstration of ability to obtain Qualifying Facility status;

x. Fuel type(s) and source(s);

xi. Plans to obtain, or actual fuel and transportation agreements, if
applicable;

xii. Where Qualifying Facility is or will be interconnected to an electrical
system besides the Company’s, plans to obtain, or actual electricity transmission
agreements with the interconnected system;

xiii. Interconnection agreement status; and
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jan. 8, 2015 Jan. 1, 2015
Per O.N. 33197
Jean D. Jewell Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 73-5

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33197 Gregory W. Said, Vice President, Regulatory Affairs
Effective – January 1, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE - IDAHO
(Continued)

CONTRACTING PROCEDURES (Continued)

1. Procedures (Continued)

xiv. Proposed contracting term and requested Rate Option for the sale of
electric output to the Company.

b. Where the Company determines that the Customer has not provided sufficient
information as required by Section 1.a., the Company shall, within 10 business days, notify the
Customer in writing of any deficiencies.

c. Following satisfactory receipt of all information required in Section 1.a., the
Company shall, within 20 business days, provide the Customer with an indicative pricing
proposal containing terms and conditions tailored to the individual characteristics of the
proposed Qualifying Facility; provided, however, that for Qualifying Facilities eligible for
Published Rates pursuant to the Commission’s eligibility requirements, the Company will
provide such indicative pricing proposal within 10 business days.

d. The indicative pricing proposal provided to the Customer pursuant to Section 1.c.
will not be final or binding on either party. Prices and other terms and conditions will become
final and binding on the parties under only two conditions:

i. The prices and other terms contained in an ESA shall become final and
binding upon full execution of such ESA by both parties and approval by the
Commission, or

ii. The applicable prices that would apply at the time a complaint is filed by a
Qualifying Facility with the Commission shall be final and binding upon approval of such
prices by the Commission and a final non-appealable determination by the Commission
that:

(a) a “legally enforceable obligation” has arisen and, but for the
conduct of the Company, there would be a contract, and
(b) the Qualifying Facility can deliver its electrical output within 365
days of such determination.

e. If the Customer desires to proceed with contracting its Qualifying Facility with the
Company after reviewing the indicative pricing proposal, it shall request in writing that the
Company prepare a draft ESA to serve as the basis for negotiations between the parties. In
connection with such request, the Customer shall provide the Company with any additional
Qualifying Facility information that the Company reasonably determines necessary for the
preparation of a draft ESA, which shall include:

i. Updated information of the categories described in Section 1.a.

ii. Evidence of site control for the entire contracting term
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jan. 8, 2015 Jan. 1, 2015
Per O.N. 33197
Jean D. Jewell Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 73-6

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33197 Gregory W. Said, Vice President, Regulatory Affairs
Effective – January 1, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE - IDAHO
(Continued)

CONTRACTING PROCEDURES (Continued)

1. Procedures (Continued)

iii. Anticipated timelines for completion of key Qualifying Facility milestones,
to include:

(a) Licenses, permits, and other necessary approvals;
(b) Funding;
(c) Qualifying Facility engineering and drawings;
(d) Significant equipment purchases;
(e) Construction agreement(s);
(f) Interconnection agreement(s); and
(g) Signing of third-party Transmission Agreements, where
applicable.

iv. Additional information as explained in the Company’s indicative pricing
proposal.

f. If the Company determines that the Customer has not provided sufficient
information as required by Section 1.e., the Company shall, within 10 business days, notify the
Customer in writing of any deficiency.

g. Following satisfactory receipt of all information required in Section 1.e., the
Company shall, within 15 business days, provide the Customer with a draft ESA containing a
comprehensive set of proposed terms and conditions. The draft shall serve as the basis for
subsequent negotiations between the parties and, unless clearly indicated, shall not be
construed as a binding proposal by the Company.

h. Within 90 calendar days after its receipt of the draft ESA from the Company
pursuant to Section 1.g., the Customer shall review the draft ESA and shall (a) notify the
Company in writing that it accepts the terms and conditions of the draft ESA and is ready to
execute an ESA with same or similar terms and conditions as the draft ESA or (b) prepare an
initial set of written comments and proposals based on the draft and provide them to the
Company. The Company shall not be obligated to commence negotiations with a Customer or
draft a final ESA unless or until the Company has timely received an initial set of written
comments and proposals from the Customer, or notice from the Customer that it has no such
comments or proposals, in accordance with this Section 1.h.

i. After Customer has met the provisions of Section 1.h. above, Customer shall
contact the Company to schedule ESA negotiations at such times and places as are mutually
agreeable to the parties.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jan. 8, 2015 Jan. 1, 2015
Per O.N. 33197
Jean D. Jewell Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 73-7

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33197 Gregory W. Said, Vice President, Regulatory Affairs
Effective – January 1, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE – IDAHO
(Continued)

CONTRACTING PROCEDURES (Continued)

1. Procedures (Continued)

j. In connection with any ESA negotiations between the Company and the
Customer, the Company:

i. Shall not unreasonably delay negotiations and shall respond in good faith
to any additions, deletions, or modifications to the draft ESA that are proposed by the
Customer;

ii. May request to visit the site of the proposed Qualifying Facility;

iii. Shall update its pricing proposals at appropriate intervals to
accommodate any changes to the Company’s avoided cost calculations, the proposed
Qualifying Facility or proposed terms of the draft ESA;

iv. Shall include any revised contracting terms, standards, or requirements
that have occurred since the initial draft ESA was provided;

v. May request any additional information from the Customer necessary to
finalize the terms of the ESA and to satisfy the Company’s due diligence with respect to
the Qualifying Facility.

k. When both parties are in full agreement as to all terms and conditions of the draft
ESA, including the price paid for delivered energy, and the Customer provides evidence that
any applicable Transmission Agreements have been executed and/or execution is imminent, the
Company shall prepare and forward to the Customer, within 10 business days, a final,
executable version of the ESA.

l. The Customer shall, within 10 business days, execute and return the final ESA to
the Company.

m. Where the Customer timely executes and returns the final ESA to the Company
in accordance with Section 1.l. above, the Company will, within 10 business days of its receipt
of the ESA executed by the Customer, execute such ESA. The Company will then submit the
executed ESA to the Commission for its review.

n. Failure of the Customer to meet any timelines set forth in this section relieves the
Company of any obligation under this tariff until such time as the Customer resubmits its
Qualifying Facility and the procedures begin anew. If the Customer does not execute the final
ESA per Section 1.l, such final ESA shall be deemed withdrawn and the Company shall have
no further obligation to the Customer under this tariff unless or until such time the Customer
resubmits the Qualifying Facility to the Company in accordance with this Schedule.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jan. 8, 2015 Jan. 1, 2015
Per O.N. 33197
Jean D. Jewell Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 73-8

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33197 Gregory W. Said, Vice President, Regulatory Affairs
Effective – January 1, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE – IDAHO
(Continued)

CONTRACTING PROCEDURES (Continued)

2. Interconnection, Transmission Agreements, and Designated Network Resource

a. The Company’s obligation to purchase Qualifying Facility electrical output from
the Customer will be conditioned on the consummation of a GIA in accordance with the
Company’s Schedule 72. Where the Qualifying Facility will not be physically located within the
Company’s electrical system, the Customer will need to consummate a similar GIA with the
third-party electrical system.

b. Where the Qualifying Facility will be interconnected to a third-party electrical
system and is requesting either Published Rates, or rates based on firm delivery of its electrical
output, the Company’s obligation to purchase such electrical output will be conditioned on the
Customer obtaining a firm Transmission Agreement or agreements to deliver all electrical output
to the agreed upon POD.

c. The Company’s obligation to purchase Qualifying Facility electrical output from
the Customer will be conditioned on the Facility being classified as a Company Designated
Network Resource.

3. Qualifying Facility Energy Sales Agreement Application

(FORM STARTS ON NEXT PAGE)
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jan. 8, 2015 Jan. 1, 2015
Per O.N. 33197
Jean D. Jewell Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 73-9

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33197 Gregory W. Said, Vice President, Regulatory Affairs
Effective – January 1, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE – IDAHO
(Continued)

QUALIFYING FACILITY ENERGY SALES AGREEMENT APPLICATION

Idaho Power Qualifying Facility (QF) contact information:

Mailing Address: Attn: Energy Contracts, P O Box 70 Boise, ID 83702
Physical Address: 1221 W. Idaho Street, Boise, ID 83703
Telephone number: 208-388-6070
E-Mail Address: [e-mail]

Preamble and Instructions

All generation facilities that qualify pursuant to Idaho Power Company Schedule 73 for a QF Energy
Sales Agreement and wish to sell energy from their facility to Idaho Power must complete the following
information and submit this Application by hand delivery, mail or E-mail to Idaho Power.

Upon receipt of a complete Application, Idaho Power shall process this request for a QF Energy Sales
Agreement pursuant to Idaho Power Company Schedule 73.

Qualifying Facility Information

Proposed Project
Name of Facility:
Resource Type: (i.e. wind, solar, hydro, etc):
Facility Location: GPS Coordinates:
Nearest City or landmark:
County and State:
Map of Facility, including proposed interconnection point.
Anticipated commencement date of energy deliveries to Idaho Power:
Facility Nameplate Capacity Rating (kW):
Facility Maximum Output Capacity (kW):
Station Service Requirements (kW):
Facility Net Delivery to Idaho Power (kW):
Facility interconnection status:
Proposed Contracting Term (cannot exceed 20 years):
Requested Rate Option (details provided in Schedule 73):
Does the Facility have the ability to respond to dispatch
orders from Idaho Power Company (Yes or No):

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jan. 8, 2015 Jan. 1, 2015
Per O.N. 33197
Jean D. Jewell Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 73-10

IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 33197 Gregory W. Said, Vice President, Regulatory Affairs
Effective – January 1, 2015 1221 West Idaho Street, Boise, Idaho

SCHEDULE 73
COGENERATION AND SMALL POWER PRODUCTION SCHEDULE – IDAHO
(Continued)

QUALIFYING FACILITY ENERGY SALES AGREEMENT APPLICATION
(Continued)

Please include the following attachments:

 Hourly estimated energy deliveries (kW) to Idaho Power for every hour of a one year period.

 List of acquired and outstanding Qualifying Facility permits, including a description of the status
and timeline for acquisition of any outstanding permits.
 At the minimum a FERC issued QF certificate/self-certification is required and/or
evidence that Facility will be able to obtain a Qualifying Facility certificate.

 If the Facility will require fuel be transported to the Facility (i.e. natural gas pipelines, railroad
transportation, etc), evidence of ability to obtain sufficient transportation rights to operate the
Facility at the stated Maximum Output Amount.

 If the Facility will not be interconnecting directly to the Idaho Power electrical system, evidence
that the Facility will be able to interconnect to another utility’s electrical system and evidence
that the Facility will be able to obtain firm transmission rights over all required transmission
providers to deliver the Facility’s energy to Idaho Power.

Owner Information
Owner / Company Name:
Contact Person:
Address:
City: State: Zip:
Telephone:
E-mail:

Applicant Signature

I hereby certify that, to the best of my knowledge, all information provided in this Qualifying
Facility Energy Sales Agreement application is true and correct.

__________________________________________________________________
Signature

__________________________________________________________________
Print Name

________________________________________
Date
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
Jan. 8, 2015 Jan. 1, 2015
Per O.N. 33197
Jean D. Jewell Secretary