20180601Final Approved Tariffs.pdf

LISA NORDSTROM
Lead Counsel
[e-mail]

May 17, 2018

ELECTRONICALLY FILED

Diane Hanian, Secretary
Idaho Public Utilities Commission
472 West Washington Street
P.O. Box 83720
Boise, Idaho 83720-0074

Re: Case No. IPC-E-17-13 – New Schedules for Residential and Small General Service
Customers with On-Site Generation - Tariff Compliance Filing

Dear Ms. Hanian:

Idaho Power Company hereby submits the enclosed compliance filing in the above-
captioned proceeding pursuant to Idaho Public Utilities Commission Order No. 34046. Listed
below are the new tariff sheets, the revised tariff sheets, and the tariff sheets updated to
include the new schedules, all with an effective date of June 1, 2018.

New Tariff Schedules:
Schedule 6 – Sheet Nos. 6-1 through 6-6
Schedule 8 – Sheet Nos. 8-1 through 8-5

Existing Revised Schedules:
Schedule 72 – Sheet Nos. 72-1 through 72-34
Schedule 84 – Sheet No. 84-1

Schedules updated to reference new Schedules 6 and 8:
Schedule Index – Sheet No. iii
Rule C – Sheet No. C-1
Rule G – Sheet No. G-1
Rule H – Sheet Nos. H-1 and H-11
Rule I – Sheet Nos. I-1 and I-2
Schedule 61 – Sheet No. 61-1
Schedule 63 – Sheet Nos. 63-1, 63-2, 63-4
Schedule 66 – Sheet No. 66-3 and 66-4
Schedule 81 – Sheet No. 81-2
Schedule 91 – Sheet No. 91-1
Schedule 98 – Sheet No. 98-1

RECEIVED
2018 May 17 PM 1:55
IDAHO PUBLIC
UTILITIES COMMISSION
Diane Hanian, Secretary
Idaho Public Utilities Commission
May 17, 2018
Page 2

The base rates listed for Schedules 6 and 8 reflect the rates resulting from the
settlement agreement reached in Case No. GNR-U-18-01. If the Commission were to approve
different rates other than the rates resulting from the settlement agreement, the Company will
file revised tariff schedules for both Schedule 6 and 8 after an order is received in Case No.
GNR-U-18-01. Also, the Monthly Charge subsection on page 5 of Schedule 8 was updated to
include Schedule 54 (Fixed Cost Adjustment) and the reference to the Customer’s January
2014 Billing Period was removed from subsection 1(b) on page 3, under Conditions of
Purchase and Sale.

Please note that Schedules 54 (FCA) and 55 (PCA) were not provided in revision form
with this compliance filing. References to new Schedules 6 and 8 will be added to Schedules
54 and 55; however, the revision form of Schedules 54 and 55 will be filed with the compliance
filings for their respective cases, IPC-E-18-02 and IPC-E-18-06, after the Commission has
issued an order in each case.

In compliance with Order No. 34046, Schedule 84 will close to Idaho residential and
small general service customers on June 1, 2018. Idaho Power will move existing residential
and small general service customers from Schedule 84 to Schedule 6 and 8, respectively,
coincident with each customer’s regularly scheduled cycle billing immediately following June 1,
2018.

If you have any questions regarding this filing, please contact Regulatory Analyst Kristy
Patteson at [phone] or [e-mail].

Very truly yours,

Lisa D. Nordstrom

LDN/kkt

Enclosures
Idaho Power Company Fifth Revised Sheet No. iii
Cancels
I.P.U.C. No. 29, Tariff No. 101 Fourth Revised Sheet No. iii
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, ID

SCHEDULE INDEX
SHEET
SCHEDULE TITLE NUMBER

1 Residential Service Standard Plan ..................................................................... 1-1 – 1-2
3 Master-Metered Mobile Home Park Residential Service ..................................... 3-1 – 3-2
4 Residential Service Energy Watch Pilot Plan (Optional) (Suspended) ................ 4-1 – 4-3
5 Residential Service Time-of-Day Pilot Plan (Optional) ........................................ 5-1 – 5-3
6 Residential Service On-Site Generation ............................................................. 6-1 – 6-6
7 Small General Service ........................................................................................ 7-1 – 7-2
8 Small General Service On-Site Generation ........................................................ 8-1 – 8-5
9 Large General Service ........................................................................................ 9-1 – 9-4
15 Dusk to Dawn Customer Lighting .................................................................... 15-1 – 15-2
19 Large Power Service ....................................................................................... 19-1 – 19-7
23 Irrigation Peak Rewards Program (Optional) ................................................. 23-1 – 23-10
24 Agricultural Irrigation Service ........................................................................... 24-1 – 24-6
40 Non-Metered General Service ......................................................................... 40-1 – 40-2
41 Street Lighting Service .................................................................................... 41-1 – 41-8
42 Traffic Control Signal Lighting Service ........................................................................ 42-1
45 Standby Service .............................................................................................. 45-1 – 45-5
46 Alternate Distribution Service .......................................................................... 46-1 – 46-4
54 Fixed Cost Adjustment .................................................................................... 54-1 – 54-2
55 Power Cost Adjustment ................................................................................... 55-1 – 55-3
60 Solar Photovoltaic Service Pilot Program ........................................................ 60-1 – 60-6
61 Payment for Home Wiring Audit .................................................................................. 61-1
62 Green Energy Purchase Program Rider (Optional) ..................................................... 62-1
66 Miscellaneous Charges ................................................................................... 66-1 – 66-4
72 Interconnections to Non-Utility Generation .................................................... 72-1 – 72-34
73 Cogeneration and Small Power Production Schedule – Idaho ....................... 73-1 – 73-10
79 Weatherization Assistance for Qualified Customers ................................................... 79-1
81 Residential Air Conditioner Cycling Program (Optional) ................................... 81-1 – 81-3
82 Flex Peak Program (Optional) ......................................................................... 82-1 – 82-5
84 Customer Energy Production Net Metering Service ......................................... 84-1 – 84-5
86 Cogeneration and Small Power Production Non-Firm Energy ......................... 86-1 – 86-7
87 Intermittent Generation Integration Charges .................................................. 87-1 – 87-15
89 Unit Avoided Energy Cost for Cogeneration and Small Power Production .................. 89-1
91 Energy Efficiency Rider .............................................................................................. 91-1
95 Adjustment for Municipal Franchise Fees ........................................................ 95-1 – 95-2
98 Residential and Small Farm Energy Credit ...................................................... 98-1 – 98-2

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company First Revised Sheet No. C-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. C-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

RULE C
SERVICE AND LIMITATIONS

1. Rates and Tariff. Service supplied by the Company will be in accordance with the Tariff on
file with the state regulatory authority having jurisdiction, and as in effect at the time service is supplied.
All service rates and agreements are subject to the continuing jurisdiction and regulation of such
authority, as provided by law.

When any municipal corporation or other local taxing agency imposes on the Company any
franchise, occupation, sales, license, excise, business, operating, privilege, or use of street tax or
charge based upon meters or Customers, or upon electricity sold or the receipts or income therefrom,
the prorate amount thereof will be billed to all Customers in the area or locality in which such tax or
charge applies and will be separately stated on, and added to, the regular billing.

2. Supplying of Service. Service will be supplied under a given schedule only to Points of
Delivery as are adjacent to facilities of the Company, adequate and suitable as to capacity and voltage for
the service desired and under the schedule applicable thereto. The Company will not be obligated to
construct extensions or install additional service facilities except in accordance with Rule H. In all other
cases, special agreements between the Customer and the Company may be required.

3. Service Application. The Company will normally accept an application for service from the
Customer by telephone, through the Company’s Web site or by other oral communication. The Company
may however, at its discretion, require the Customer to sign an application requesting service

4. Choice of Schedules. The Company's schedules are designed to provide monthly rates
for service supplied to the Customer on an annual basis. The Customer may elect to take service under
any of the schedules applicable to this annual service requirement, and the Company will endeavor to
assist in the selection of the appropriate schedule most favorable to the Customer. Changing of
schedules will occur only when the characteristics of the Customer's usage change such that another
applicable schedule is deemed more favorable to the Customer when applied to the Customer's annual
service requirements. Customers receiving service under Schedules 7, 8, 9, and 19 will be reviewed on a
monthly basis under the provisions established in the Applicability section of each of these schedules.

5. Point of Delivery Service Requirements. A Customer may be served at more than one
Point of Delivery at the same Premises if practicable, unless otherwise specified in a schedule. Service at
each Point of Delivery at the same Premises will be offered under the appropriate schedule. The
Customer's request for service at an additional Point of Delivery will be subject to the applicable line
extension rules of the Company. The Company may refuse to provide service at more than one Point of
Delivery at the same Premises if it is determined by the Company that the additional Point of Delivery
cannot be provided without jeopardizing the safety and reliability of the Company's system or service to
the Customer or to other Customers. Service provided to a Customer at multiple Points of Delivery at the
same Premises will not be interconnected electrically.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Second Revised Sheet No. G-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 First Revised Sheet No. G-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

RULE G
BILLINGS

1. Fractional Periods. When the Customer’s Billing Period is less than 27 days or greater
than 36 days, the Energy Charge for service under Schedules 1, 3, 4, 5, 6, 7, 8, 9, 19, or 24 will be
calculated using actual meter readings. The Energy Charge for service provided under Schedule 40
will be determined using the daily kWh calculated on the basis of load size and number of units served
multiplied by the actual number of days since the account was opened or since the previous billing,
where appropriate. The proration of the applicable Demand Charge, Basic Charge, Facilities Charge,
and Service Charge specified in the appropriate schedule will be calculated by dividing the charge by
30 and multiplying the result by the actual number of days since the account was opened or since the
previous meter reading, where appropriate. However, the prorated Service Charge for Schedules 1, 3,
4, 5, 6, 7, 8, 9, 19, or 24 or the Minimum Charge for Schedule 40, will be no less than the amount
specified in Schedule 66. For Schedule 15, the proration of the applicable Monthly Charge will be
calculated by dividing the charge by 30 and multiplying the result by the actual number of days since
the account was opened or the previous billing, where appropriate; however, in no event will the charge
be less than the Fractional Period Minimum Billings amount specified in Schedule 66.

2. Corrected Billings. Whenever it is determined that a Customer was billed under an
inappropriate schedule, the Customer will be rebilled under the appropriate schedule, except if the
Company selected the schedule on the basis of available information and acted in good faith, the
Company will not be required to rebill or adjust billings. When the customer has been overcharged, the
rebilling period will be no more than the 3-year period as provided by Idaho Code §61-642. When the
customer has been undercharged, the rebilling period shall be limited to six months unless a reasonable
person should have known of the inappropriate billing, in which case the rebilling period may be extended
for a period not to exceed three years.

If the average error for any meter test exceeds ±2 percent, corrected billings will be
prepared. The corrected billings will not exceed 6 months if the time when the malfunction or error began
is unknown. If the time when the malfunction or error began is known and the customer was
overcharged, the corrected billings will be from that time, but will not exceed the 3 year period as provided
by Idaho Code §61-642. If the time when the malfunction or error began is known and the customer was
undercharged, the Company will rebill for a period of six months unless a reasonable person should have
known of the inaccurate billing, in which case the rebilling may be extended for a period not to exceed
three years. If an under-billing occurs, the Company will offer and enter into reasonable payment
arrangements with the Customer. For any over-billings, the Customer will have the choice of a refund or
a credit on future bills.

3. Due Dates. The Company's practices relating to Due Dates are governed by the Utility
Customer Relations Rules (UCRR) of the Idaho Public Utilities Commission, in effect at the time the
event occurred which required application of the UCRR. If the Company's Rules and Regulations on
file with the Idaho Public Utilities Commission contain provisions which conflict with the UCRR, the
provisions of the UCRR supersede those included in the Company's Rules and Regulations.

4. Returned Checks. Checks or payments remitted by Customers in payment of bills are
accepted conditionally. A Returned Check Charge, as specified in Schedule 66, will be assessed the
Customer for handling each check or payment upon which payment has been refused by the bank.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Second Revised Sheet No. H-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 First Revised Sheet No. H-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS

This rule applies to requests for electric service under Schedules 1, 3, 4, 5, 6, 7, 8, 9, 19, 24, 45,
and 46 that require the installation, alteration, relocation, removal, or attachment of Company-owned
distribution facilities. New construction beyond the Point of Delivery for Schedule 9 or Schedule 19 is
subject to the provisions for facilities charges under those schedules. This rule does not apply to
transmission or substation facilities, or to requests for electric service that are of a speculative nature.

1. Definitions

Additional Applicant is a person or entity whose Application requires the Company to provide
new or relocated service from an existing section of distribution facilities with a Vested Interest.

Alteration is any change or proposed change to existing distribution facilities. An alteration may
include Relocation, Upgrade, Conversion, and/or removal.

Applicant is a person or entity whose Application requires the Company to provide new or
relocated service from distribution facilities that are free and clear of any Vested Interest.

Application is a request by an Applicant or Additional Applicant for new electric service from the
Company. The Company, at its discretion, may require the Applicant or Additional Applicant to
sign a written application.

Company Betterment is that portion of the Work Order Cost of a Line Installation and/or
Alteration that provides a benefit to the Company not required by the Applicant or Additional
Applicant. Increases in conductor size and work necessitated by the increase in conductor size
are considered a Company Betterment if the Connected Load added by the Applicant or
Additional Applicant is less than 100 kilowatts. If, however, in the Company’s discretion, it is
determined that the additional Connected Load added by the Applicant or Additional Applicant,
even though less than 100 kilowatts, is (1) located in a remote location, or (2) a part of a
development or project which will add a load greater than 100 kilowatts, the Company will not
consider the work necessitated by the load increase to be a Company Betterment.

Connected Load is the total nameplate kW rating of the electric loads connected for commercial,
industrial, or irrigation service. Connected Load for residences is considered to be 25 kW for
residences with electric space heat and 15 kW for all other residences.

Conversion is a request by a customer to replace overhead facilities with underground facilities.

Cost Quote is a written cost estimate provided by the Company that must be signed and paid by
the Applicant or Additional Applicant prior to the start of construction. Cost Quotes are derived
from Work Order Cost estimates.

Easement is the Company’s legal right to use the real property of another for the purpose of
installing or locating electric facilities.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Tenth Revised Sheet No. H-11
Cancels
I.P.U.C. No. 29, Tariff No. 101 Ninth Revised Sheet No. H-11
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

6. Other Charges (Continued)

j. Underground Service Return Trip Charge. When a residential Customer agrees to
supply the trench, backfill, conduit, and compaction for an underground service, an
Underground Service Return Trip Charge of $95.00 will be assessed each time the
Company’s installation crew is dispatched to the job site at the Customer’s request, but
is unable to complete the cable installation and energize the service.

7. Line Installation and Service Attachment Allowances

The Company will contribute an allowance toward the Terminal Facilities and Line Installation
costs necessary for Line Installations and/or Service Attachments. Allowances are based on
the cost of providing and installing Standard Terminal Facilities for single phase and three
phase services.

a. Allowances for Overhead and Underground Line Installations and Overhead Service
Attachments

Class of Service Maximum Allowance per Service

Residential:
Schedules 1, 3, 4, 5, 6 $2,353.00
Non-residence $ 0.00

Non-residential:
Schedules 7, 8, 9, 24
Single Phase $2,353.00
Three Phase $5,604.00

Large Power Service
Schedule 19 Case-By-Case

b. Allowances for Subdivisions and Multiple Occupancy Projects
Developers of Subdivisions and Multiple Occupancy Projects will receive a $2,353.00
allowance for each single phase transformer installed within a development and a
$5,604.00 allowance for each three phase transformer installed within a development.
Subdividers will be eligible to receive allowances for Line Installations inside residential
and non-residential subdivisions.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Second Revised Sheet No. I-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 First Revised Sheet No. I-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

RULE I
BUDGET PAY PLANS

1. Residential Budget Pay Plan - Schedules 1, 4, 5, and 6. A Budget Pay Plan is available to
Residential Customers desiring to levelize payments for electric service. If a Customer has more than
one electric service on the account, each electric service charge will be levelized individually. A
Customer may sign up for the Budget Pay Plan at any time during the year. In order to be eligible for the
Budget Pay Plan, the Customer’s account must not be in arrears and the customer must have received
service at the same location for a minimum of nine months.

The levelized payment will approximate the average of 12 monthly billings based on either the
historical charges, or an estimate of future charges. The Budget Pay amount for each electric service
on the account will be adjusted to the next higher dollar. Budget Pay amounts will be recalculated at
the 12-month (or 365-day) anniversary of the first bill that was generated after the Customer enrolled in
the Budget Pay Plan. The new monthly payment will be the recalculated Budget Pay amount(s). A
Customer’s Budget Pay amount(s) may decrease, increase, or remain the same.

Customers with a negative balance in their Budget Pay Plan account at the time of recalculation
will have monthly Budget Pay charges equal to the recalculated Budget Pay amount plus one-twelfth of
the negative balance. At the Customer’s request, a negative balance may be paid in full. Customers with
a positive balance in their Budget Pay Plan account at the time of recalculation, or upon termination of the
agreement after all charges for services have been paid, will be refunded at the Customer’s request. If no
request for refund is made, the monthly Budget Pay charges will be equal to the recalculated Budget Pay
amount reduced by one-twelfth of the positive balance. Upon the Customer’s request, a positive balance
for one Budget Pay electric service may be transferred to the balance of another Budget Pay electric
service on the account.

Any estimates furnished by the Company with such Budget Pay Plan should not be construed as
a guarantee that the total actual charges will not exceed the estimates. The Company, because of rate
changes or other requirements, may at any time submit a revised estimate to the Customer and require
that the Customer pay the revised monthly Budget Pay installment as a condition to the continuation of
the Budget Pay Plan for the Customer.

The Budget Pay amount(s) will be billed on the regular service bill each month. Once
established, the Budget Pay Plan will remain in effect from year to year until the Customer notifies the
Company not less than 30 days prior to the desired date of cancellation or unless the Customer fails to
pay the agreed amounts.

2. Small General Service Budget Pay Plan - Schedules 7 and 8. A Budget Pay Plan is
available to Small General Service Customers receiving service on Schedules 7 and 8. If a Customer
has more than one electric service on the account, each electric service charge will be levelized
individually. If a Customer transfers to another schedule (other than Schedules 1, 4, 5, or 6), the Budget
Pay Plan will not be available. A Customer may sign up for the Budget Pay Plan at any time during the
year.

In order to qualify, the Customer must have been receiving service at the same location, under the
same ownership and account number, and with all monthly billings paid on or before the past due date for
at least 12 months prior to applying for the Budget Pay Plan. The Customer must maintain the payment
status as described above or the Customer will be removed from the Budget Pay Plan on the next
monthly billing and all past due balances will become immediately due and payable.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Second Revised Sheet No. I-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 First Revised Sheet No. I-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

RULE I
BUDGET PAY PLANS
(Continued)

2. Small General Service Budget Pay Plan - Schedules 7 and 8 (Continued)

The levelized payment will approximate the average of 12 monthly billings based on historical
charges. Budget Pay amounts will be recalculated at the 12-month (or 365-day) anniversary of the first
bill that was generated after the Customer enrolled in the Budget Pay Plan. The Budget Pay amount for
each electric service on the account will be adjusted to the next higher dollar. The new monthly payment
will be the recalculated Budget Pay amount(s). A Customer’s Budget Pay amount(s) may decrease,
increase, or remain the same.

Customers with a negative balance in their Budget Pay Plan account at the time of recalculation
will have monthly Budget Pay charges equal to the recalculated Budget Pay amount plus one-twelfth of
the negative balance. At the Customer’s request, a negative balance may be paid in full. Customers with
a positive balance in their Budget Pay Plan account at the time of recalculation, or upon termination of the
agreement after all charges for services have been paid, will be refunded at the Customer’s request. If no
request for refund is made, the monthly Budget Pay charges will be equal to the recalculated Budget Pay
amount reduced by one-twelfth of the positive balance. Upon the Customer’s request, a positive balance
for one Budget Pay electric service may be transferred to the balance of another Budget Pay electric
service on the account.

Any estimates furnished by the Company with such Budget Pay Plan should not be construed as
a guarantee that the total actual charges will not exceed the estimates. The Company, because of rate
changes or other requirements, may at any time submit a revised estimate to the Customer and require
that the Customer pay the revised monthly Budget Pay installment as a condition to the continuation of
the Budget Pay Plan for the Customer.

The Budget Pay amount(s) will be billed on the regular service bill each month. Once established,
the Budget Pay Plan will remain in effect from year to year until the Customer notifies the Company not
less than 30 days prior to the desired date of cancellation or unless the Customer fails to pay the agreed
amounts.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 6-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system within
the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are
adjacent to the location where Residential Service, On-Site Generation is desired, and where additional
investment by the Company for new transmission, substation or terminal facilities is not necessary to
supply the desired service. This service is available to Customers intending to operate Small On-Site
Generation Systems to generate electricity to reduce all or part of the monthly energy usage.

APPLICABILITY

Service under this schedule is applicable to Electric Service required for residential service
Customers for general domestic uses, including single phase motors of 7½ horsepower rating or less,
subject to the following conditions:

1. When a portion of a dwelling is used regularly for business, professional or other gainful
purposes, or when service is supplied in whole or in part for business, professional, or other gainful
purposes, the Premises will be classified as non-residential and the appropriate General Service
Schedule will apply. However, if the wiring is so arranged that the service for residential purposes can
be metered separately, this schedule will be applied to such service.

2. Whenever the Customer's equipment does not conform to the Company's specifications
for service under this schedule, service will be supplied under the appropriate General Service Schedule.

3. This schedule is not applicable to standby service, service for resale, or shared service.

4. Customer owns and/or operates a Generation Facility fueled by solar, wind, biomass,
geothermal, hydropower or represents fuel cell technology, with a total nameplate capacity rating of 25
kilowatts (kW) or less, that is connected in parallel with the Idaho Power System.

5. The Generation Facility is interconnected to the Customer’s individual electric system on
the Customer’s side of the Point of Delivery, thus all energy received and delivered by the Company is
through the Company’s existing watt-hour retail meter.

6. Customer meets all requirements applicable to Small On-Site Generation Systems
detailed in the Company’s Schedule 72, Interconnections to Non-Utility Generation.

DEFINITIONS

Designated Meter is the retail meter physically connected to the Small On-Site Generation
System.

Excess Net Energy means the positive difference between the kilowatt-hours (kWh) generated
by a Customer and the kWh supplied by the Company over the applicable Billing Period.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 6-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)

DEFINITIONS (Continued)

Generation Facility means all equipment used to generate electric energy where the resulting
energy is delivered to the Company via a single meter at the Point of Delivery or is consumed by the
Customer.

Interconnection Facilities are all facilities reasonably required by Prudent Electrical Practices and
the applicable electric and safety codes to interconnect and safely deliver energy from the Generation
Facility to the Point of Delivery.

Parallel connection means generating electricity from an on-site generation system that is
connected to and receives voltage from Idaho Power’s system.

Point of Delivery is the retail metering point where the Company's and the Customer’s electrical
facilities are interconnected to allow the Customer to take retail electric service from the Company.

Prudent Electrical Practices are those practices, methods and equipment that are commonly used
in prudent electrical engineering and operations to operate electric equipment lawfully and with safety,
dependability, efficiency and economy.

Schedule 72 is the Company’s service schedule which provides for interconnection to non-utility
generation or its successor schedule(s) as approved by the Commission.

Small On-Site Generation Service is the Company’s service which provides for transfer of electric
energy to the Company under the terms of this Schedule and of Schedule 72 or their successor(s) as
approved by the Commission. This optional service provides for Customers to install Generation
Facilities to interconnect to the Company’s system to offset all or a portion of their electrical usage. This
service is comprised of all customers taking service under Schedule 6 or Schedule 8.

Small On-Site Generation System is a Customer-owned Generation Facility, with a total
nameplate capacity rating of 25 kW or less, interconnected to the Company’s system under the applicable
terms of Schedule 72 and this schedule.

TYPE OF SERVICE

The type of service provided under this schedule is single phase, alternating current at
approximately 120 or 240 volts and 60 cycles, supplied through one meter at one Point of Delivery. Upon
request by the owner of multi-family dwellings, the Company may provide 120/208 volt service for multi-
family dwellings when all equipment is U L approved to operate at 120/208 volts.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 6-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)

WATER HEATING

All electric water heating equipment, including water storage and tankless water heaters (hot
water on demand), shall conform to specifications of the Underwriters' Laboratories, Inc., and the
Company. The installation of the water heating equipment shall conform to all National, State, and
Municipal Codes. No single electric water heating unit shall exceed 6 kW; and where two or more heating
units are used, these units shall be so interlocked that not more than 6 kW can be connected at any one
time.

Where electric water heaters not complying with these specifications are installed, the Customer
will be required to pay the original installation or upgrade costs for any nonstandard facilities needed to
supply the electrical capacity to meet the water heater demand. Water heating equipment must not impair
or interfere with service to any other customer.

RESIDENTIAL SPACE HEATING

All space heating equipment to be served by the Company's system shall be single-phase
equipment approved by Underwriters' Laboratories, Inc., and the equipment and its installation shall
conform to all national, state, and municipal codes and to the following:

Individual resistance-type units for space heating larger than 1,650 watts shall be designed to
operate at 240 or 208 volts, and no single unit shall be larger than 6 kW. Heating units of 2 kW or larger
shall be controlled by approved thermostatic devices. When a group of heating units, with a total capacity
of more than 6 kW, is to be actuated by a single thermostat, the controlling switch shall be so designed
that not more than 6 kW can be switched on or off at any one time. Supplemental resistance-type heaters,
that may be used with a heat exchanger, shall comply with the specifications listed above for such units.

CONDITIONS OF PURCHASE AND SALE

The conditions listed below shall apply to all transactions under this schedule.

1. Balances of generation and usage by the Customer:

a. If electricity supplied by the Company during the Billing Period exceeds the
electricity generated by the Customer and delivered to the Company during the Billing Period, the
Customer shall be billed for the net electricity supplied by the Company at the rates contained
within this schedule, in accordance with normal metering practices.

b. If electricity generated by the Customer and delivered to the Company during the
Billing Period exceeds the electricity supplied by the Company during the Billing Period, the Excess
Net Energy shall be carried forward as a kWh credit to offset energy usage in a subsequent Billing
Period. Excess Net Energy credits are subject to the following provisions:
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 6-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

i. Credits can only be used to offset billed kWh consumption. Customers shall
be billed for all applicable non-energy charges for the Billing Period according to the
applicable standard service schedule.

ii. Credits shall carry forward provided the Customer maintains electric service
at the same Point of Delivery.

iii. Credits are non-transferrable in the event that a Customer relocates and/or
discontinues service at the Point of Delivery associated with the Small On-Site Generation
System. Any unused credits will expire at the time the final bill is prepared.

c. Compensation for the balance of generation and usage by the Customer is subject
to change upon Commission approval.

2. Aggregation of meters for the annual transfer of unused Excess Net Energy credits:

a. If a balance of Excess Net Energy credits exists at a Designated Meter at the end of
the Customer’s December Billing Period the Customer may request to transfer the unused credits
to offset energy consumption at eligible meters. A meter is eligible for aggregation if it meets all of
the following criteria:

i. The account subject to offset is held by the Customer; and

ii. The meter is located on, or contiguous to, the property on which the
Designated Meter is located. For the purposes of this tariff, contiguous property includes
property that is separated from the Premises of the Designated Meter by public or railroad
rights of way; and

iii. The meter is served by the same primary feeder as the Designated Meter at
the time the Customer files the application for the Small On-Site Generation System; and

iv. The electricity recorded by the meter is for the Customer’s requirements; and

v. Credits may only be transferred to meters taking service under Schedule 1,
Schedule 6, Schedule 7, or Schedule 8.

b. Customers may submit requests to transfer Excess Net Energy credits between
January 1 and January 31 of each year. All requests must be received by Idaho Power by midnight,
Mountain Standard Time, on January 31. If a Customer does not request to transfer Excess Net
Energy credits by the January 31 submission deadline Excess Net Energy credits will carry forward
to offset consumption at the Designated Meter until they become eligible for transfer on January 1
of the following year.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 6-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

c. Requests to transfer Excess Net Energy credits must be executed by the Company
no later than March 31. Transfers will be based on the balance of Excess Net Energy credits
available at the time the transfer is made.

d. If multiple meters are eligible for aggregation, Excess Net Energy credits must first
be applied to the Designated Meter, then to eligible meters on the same rate schedule as the
Designated Meter. Remaining Excess Net Energy credits may then be applied to offset
consumption at eligible meters on differing rate schedules in accordance with Section 2a(v) above.

e. A meter aggregation fee of $10.00 will be assessed per aggregated meter per
annual transfer transaction.

3. The Customer shall never deliver or attempt to deliver energy to the Company’s system
when the Company’s system serving the Customer’s Generation Facility is de-energized for any reason.

4. The Company shall not be liable directly or indirectly for permitting or continuing to allow
an attachment of a Small On-Site Generation System to the Company’s system, or for the acts or
omissions of the Customer that cause loss or injury, including death, to any third party.

5. The Customer is responsible for all costs associated with the Generation Facility and
Interconnection Facilities. The Customer is also responsible for all costs associated with any Company
additions, modifications, or upgrades to any Company facilities that the Company determines are
necessary as a result of the installation of the Generation Facility in order to maintain a safe, reliable
electrical system.

6. The Company shall not be obligated to accept, and the Company may require the
Customer to curtail, interrupt or reduce deliveries of Energy if the Company, consistent with Prudent
Electrical Practices, determines that curtailment, interruption, or reduction is necessary because of line
construction or maintenance requirements, emergencies, or other critical operating conditions on its
system.

7. If the Company is required by the Commission to institute curtailment of deliveries of
electricity to its customers, the Company may require the Customer to curtail its consumption of electricity
in the same manner and to the same degree as other Customers on the Company’s standard service
schedules.

8. The Customer shall grant to the Company all access to all Company equipment and
facilities including adequate and continuing access rights to the property of the Customer for the purpose
of installation, operation, maintenance, replacement, or any other service required of said equipment as
well as all necessary access for inspection, switching, and any other operational requirements of the
Customer’s Interconnections Facilities.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 6-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

9. The Customer shall notify the Company immediately if a Small On-Site Generation System
is permanently removed or disabled. Permanent removal or disablement for the purposes of this
Schedule is any removal or disablement of a Small On-Site Generation System lasting longer than six
(6) months. Customers with permanently removed or disabled systems will be removed from service
under this schedule and placed on the appropriate standard service schedule.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on August 31 of each year. The non-
summer season begins on September 1 of each year and ends on May 31 of each year.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set forth
in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy
Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), and Schedule 98 (Residential
and Small Farm Energy Credit).

The following rate structure and charges are subject to change upon Commission approval:

Summer Non-summer

Service Charge, per month $5.00 $5.00

Energy Charge, per kWh
First 800 kWh 8.5318¢ 7.9275¢
801-2000 kWh 10.2590¢ 8.7398¢
All Additional kWh Over 2000 12.1871¢ 9.6792¢

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 8-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERTION

AVAILABILITY

Service under this schedule is available at points on the Company's interconnected system within
the State of Idaho where existing facilities of adequate capacity and desired phase and voltage are
adjacent to the location where Small General Service, On-Site Generation is desired, and where
additional investment by the Company for new transmission, substation or terminal facilities is not
necessary to supply the desired service. This service is available to Customers intending to operate
Small On-Site Generation Systems under this schedule to generate electricity to reduce all or part of their
monthly energy usage.

APPLICABILITY

Service under this schedule is applicable to Electric Service supplied to a Customer at one Point
of Delivery and measured through one meter. This schedule is applicable to Customers whose metered
energy usage is 2,000 kWh, or less, per Billing Period for ten or more Billing Periods during the most
recent 12 consecutive Billing Periods. When the Customer’s Billing Period is less than 27 days or greater
than 36 days, the energy usage will be prorated to 30 days for purposes of determining eligibility under
this schedule. Customers whose metered energy usage exceeds 2,000 kWh per Billing Period on an
actual or prorated basis three times during the most recent 12 consecutive Billing Periods are not eligible
for service under this schedule and will be automatically transferred to the applicable schedule effective
with the next Billing Period. New customers may initially be placed on this schedule based on estimated
usage.

This schedule is also applicable to non-profit or tax supported ball fields, fairgrounds or rodeo
grounds with high demands and intermittent use exceeding 2,000 kWh per month. This schedule is not
applicable to standby service, service for resale, shared service, to individual or multiple family dwellings
first served through one meter after February 9, 1982, or to agricultural irrigation service after October
31, 2004.

Service under this schedule is also subject to the following conditions:

1. Customer owns/and or operates a Generation Facility fueled by solar, wind, biomass,
geothermal, hydropower or represents fuel cell technology, with a total nameplate capacity rating of 25
kilowatts (kW) or less, that is connected in parallel with the Idaho Power System.

2. The Generation Facility is interconnected to the Customer’s individual electric system on
the Customer’s side of the Point of Delivery, thus all energy received and delivered by the Company is
through the Company’s existing watt-hour retail meter.

3. Customer meets all requirements applicable to Small On-Site Generation Systems
detailed in the Company’s Schedule 72, Interconnections to Non-Utility Generation.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 8-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERTION
(Continued)

DEFINITIONS

Designated Meter is the retail meter physically connected to the Small On-Site Generation
System.

Excess Net Energy means the positive difference between the kilowatt-hours (kWh) generated
by a Customer and the kWh supplied by the Company over the applicable Billing Period.

Generation Facility means all equipment used to generate electric energy where the resulting
energy is either delivered to the Company via a single meter at the Point of Delivery or is consumed by the
Customer.

Interconnection Facilities are all facilities reasonably required by Prudent Electrical Practices and
the applicable electric and safety codes to interconnect and safely deliver energy from the Generation
Facility to the Point of Delivery.

Parallel connection means generating electricity from an on-site generation system that is
connected to and receives voltage from Idaho Power’s system.

Point of Delivery is the retail metering point where the Company's and the Customer’s electrical
facilities are interconnected to allow the Customer to take retail electric service from the Company.

Prudent Electrical Practices are those practices, methods, and equipment that are commonly used
in prudent electrical engineering and operations to operate electric equipment lawfully and with safety,
dependability, efficiency and economy.

Schedule 72 is the Company’s service schedule which provides for interconnection to non-utility
generation or its successor schedule(s) as approved by the Commission.

Small On-Site Generation Service is the Company’s service which provides for transfer of electric
energy to the Company under the terms of this Schedule and of Schedule 72 or their successor(s) as
approved by the Commission. This optional service provides for Customers to install Generation
Facilities to interconnect to the Company’s system to offset all or a portion of their electrical usage. This
service is comprised of all customers taking service under Schedule 6 or Schedule 8.

Small On-Site Generation System is a Customer-owned Generation Facility, with a total
nameplate capacity rating of 25 kW or less, interconnected to the Company’s system under the applicable
terms of Schedule 72 and this schedule.

TYPE OF SERVICE

The type of service provided under this schedule is single and/or three-phase alternating current,
at approximately 60 cycles and at the standard service voltage available at the Premises to be served.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 8-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERTION
(Continued)

CONDITIONS OF PURCHASE AND SALE

The conditions listed below shall apply to all transactions under this schedule.

1. Balances of generation and usage by the Customer:

a. If electricity supplied by the Company during the Billing Period exceeds the
electricity generated by the Customer and delivered to the Company during the Billing Period, the
Customer shall be billed for the net electricity supplied by the Company at the rates contained
within this schedule, in accordance with normal metering practices.

b. If electricity generated by the Customer and delivered to the Company during the
Billing Period exceeds the electricity supplied by the Company during the Billing Period, the Excess
Net Energy shall be carried forward as a kWh credit to offset energy usage in a subsequent Billing
Period. Excess Net Energy credits are subject to the following provisions:

i. Credits can only be used to offset billed kWh consumption. Customers shall
be billed for all applicable non-energy charges for the Billing Period according to the
applicable standard service schedule.

ii. Credits shall carry forward provided the Customer maintains electric service
at the same Point of Delivery.

iii. Credits are non-transferrable in the event that a Customer relocates and/or
discontinues service at the Point of Delivery associated with the Small On-Site Generation
System. Any unused credits will expire at the time the final bill is prepared.

c. Compensation for the balance of generation and usage by the Customer is subject
to change upon Commission approval.

2. Aggregation of meters for the annual transfer of unused Excess Net Energy credits:

a. If a balance of Excess Net Energy credits exists at a Designated Meter at the end of
the Customer’s December Billing Period the Customer may request to transfer the unused credits
to offset energy consumption at eligible meters. A meter is eligible for aggregation if it meets all of
the following criteria:

i. The account subject to offset is held by the Customer; and

ii. The meter is located on, or contiguous to, the property on which the
Designated Meter is located. For the purposes of this tariff, contiguous property includes
property that is separated from the Premises of the Designated Meter by public or railroad
rights of way; and

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 8-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERTION
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

iii. The meter is served by the same primary feeder as the Designated Meter at
the time the Customer files the application for the Small On-Site Generation System; and

iv. The electricity recorded by the meter is for the Customer’s requirements; and

v. Credits may only be transferred to meters taking service under Schedule 1,
Schedule 6, Schedule 7, or Schedule 8.

b. Customers may submit requests to transfer Excess Net Energy credits between
January 1 and January 31 of each year. All requests must be received by Idaho Power by midnight,
Mountain Standard Time, on January 31. If a Customer does not request to transfer Excess Net
Energy credits by the January 31 submission deadline Excess Net Energy credits will carry forward
to offset consumption at the Designated Meter until they become eligible for transfer on January 1
of the following year.

c. Requests to transfer Excess Net Energy credits must be executed by the Company
no later than March 31. Transfers will be based on the balance of Excess Net Energy credits
available at the time the transfer is made.

d. If multiple meters are eligible for aggregation, Excess Net Energy credits must first
be applied to the Designated Meter, then to eligible meters on the same rate schedule as the
Designated Meter. Remaining Excess Net Energy credits may then be applied to offset
consumption at eligible meters on differing rate schedules in accordance with Section 2a(v) above.

e. A meter aggregation fee of $10.00 will be assessed per aggregated meter per
annual transfer transaction.

3. The Customer shall never deliver or attempt to deliver energy to the Company’s system
when the Company’s system serving the Customer’s Generation Facility is de-energized for any reason.

4. The Company shall not be liable directly or indirectly for permitting or continuing to allow
an attachment of a Small On-Site Generation System to the Company’s system, or for the acts or
omissions of the Customer that cause loss or injury, including death, to any third party.

5. The Customer is responsible for all costs associated with the Generation Facility and
Interconnection Facilities. The Customer is also responsible for all costs associated with any Company
additions, modifications, or upgrades to any Company facilities that the Company determines are
necessary as a result of the installation of the Generation Facility in order to maintain a safe, reliable
electrical system.

6. The Company shall not be obligated to accept, and the Company may require the
Customer to curtail, interrupt, or reduce deliveries of energy if the Company, consistent with Prudent
Electrical Practices, determines that curtailment, interruption, or reduction is necessary because of line
construction or maintenance requirements, emergencies, or other critical operating conditions on its
system.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 8-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERTION
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

7. If the Company is required by the Commission to institute curtailment of deliveries of
electricity to its customers, the Company may require the Customer to curtail its consumption of electricity
in the same manner and to the same degree as other Customers on the Company’s standard service
schedules.

8. The Customer shall grant to the Company all access to all Company equipment and
facilities including adequate and continuing access rights to the property of the Customer for the purpose
of installation, operation, maintenance, replacement, or any other service required of said equipment as
well as all necessary access for inspection, switching, and any other operational requirements of the
Customer’s Interconnections Facilities.

9. The Customer shall notify the Company immediately if a Small On-Site Generation System
is permanently removed or disabled. Permanent removal or disablement for the purposes of this
Schedule is any removal or disablement of a Small On-Site Generation System lasting longer than six
(6) months. Customers with permanently removed or disabled systems will be removed from service
under this schedule and placed on the appropriate standard service schedule.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on August 31 of each year. The non-
summer season begins on September 1 of each year and ends on May 31 of each year.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set forth
in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy
Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), and Schedule 98 (Residential
and Small Farm Energy Credit).

The following charges are subject to change upon Commission approval:

Summer Non-summer

Service Charge, per month $5.00 $5.00

Energy Charge, per kWh
First 300 kWh 9.7265¢ 9.7265¢
All Additional kWh 11.5843¢ 10.2050¢

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company First Revised Sheet No. 61-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 61-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 61
PAYMENT FOR HOME WIRING
AUDIT

AVAILABILITY

Service under this schedule is available to residential Customers throughout the Company's
service territory within the State of Idaho who are taking service under Schedules 1, 4, 5, or 6.

SERVICES PROVIDED

A $40 payment is provided by the Company to residential Customers who have a home wiring
audit performed by a licensed electrician. To have a home wiring audit performed, a Customer is
responsible for contacting the Company to request the Home Wiring Audit form and then contacting a
licensed electrician to perform the audit. The Customer is also responsible for ensuring the electrician
performs the audit per the instructions of the Home Wiring Audit form. The charge for the audit will be
established by the electrician and will be billed by the electrician directly to the Customer. The Customer
is responsible for paying the electrician the charge for performing the audit.

The $40 payment is provided to the Customer upon receipt by the Company of the appropriate
copy of the completed Home Wiring Audit form. The Customer is responsible for submitting the Home
Wiring Audit form to the Company.

PURPOSE OF PAYMENT

The purpose of the $40 payment is to assist the Customer in identifying any wiring deficiencies
that may be causing power usage problems. The payment is not an indication that the Company has
performed any analysis as to the safety of the Customer's wiring or that the Company concurs with the
findings of the electrician's wiring audit.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company First Revised Sheet No. 63-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 63-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 63
COMMUNITY SOLAR PILOT PROGRAM
(OPTIONAL)

PROGRAM DESCRIPTION

The Community Solar Pilot Program (“Program”) is an optional program that will provide a
limited number of Idaho Power’s Idaho Customers the opportunity to voluntarily subscribe to the
generation output of a 500 kW single-axis tracking community solar array.

AVAILABILITY

The Program is available to Eligible Customers that hold evidence of a Subscription or an
entitlement to the electric generation output of a portion of the community solar array. Participation in
the Program is available on a first-come, first-served basis to all Eligible Customers who complete a
Participant Agreement. Approximately 1,563 Subscriptions will be available. If Idaho Power does not
receive what it deems to be a sufficient number of Subscriptions for the Program, Idaho Power may
terminate the Program and refund the Subscription Fees as set forth under “Refund of Subscription
Fee” in the Participant Agreement.

DEFINITIONS

Eligible Customers. Residential Service (Schedules 1, 5, and 6), Small General Service
(Schedules 7 and 8), Large General Service (Schedule 9), Large Power Service (Schedule 19),
Agricultural Irrigation Service (Schedule 24), Micron Special Contract (Schedule 26), Simplot Special
Contract (Schedule 29), and the Department of Energy Special Contract (Schedule 30) Customers.
Non-metered and lighting accounts may not participate in the Program. Customers must be in Good
Standing with metered electric service accounts with service addresses located in Idaho within Idaho
Power’s service area. Participants must be 18 years of age or older and have full power and authority
to execute the Participation Agreement. Participant must be the customer of record on the Idaho
Power account for the service agreement to which the Subscriptions apply.

Good Standing. At the time of Subscription a Customer is in “Good Standing” if the Customer
does not have a past-due balance of $100 or more that is 60 days or more past due.

Participant. The Customer specified as the Participant in the Participant Agreement is the
Eligible Customer that has received notification of acceptance into the Program, or a successor
Participant designated in accordance with the Participant Agreement.

Participant Agreement. Eligible Customers will be required to sign the Participant Agreement
prior to participating in the Program. Participants will be subject to the terms and conditions of the
Participant Agreement.

Subscription. A “Subscription” is the Participant’s applicable portion of the electricity output
generated by the community solar array developed in connection with the 500 kW project.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company First Revised Sheet No. 63-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 63-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 63
COMMUNITY SOLAR PILOT PROGRAM
(OPTIONAL)
(Continued)

TERM

The Program term will extend 25 years after the date of first production of solar energy on a
non-test basis (Operation Date).

Service on this rate schedule (“Enrollment”) will commence with the first billing cycle following
the later of (i) the approval of the Eligible Customer’s Participant Agreement by the Company, and (ii)
the Operation Date.

SUBSCRIPTION FEE

$562.00 per Subscription.

PAYMENT OF SUBSCRIPTION FEE

Customers have the following payment options:

1. A single upfront payment by check.

2. A single upfront payment made by debit/credit card, mail-in check or money order,
paystation check or money order, or personal on-line bank transfer (“Bill Me”). A Customer who
requests the “Bill Me” option on the Participant Agreement will receive an Idaho Power Company
generated bill, separate from their monthly electric service bill, which must be paid within 30 days. A
convenience fee will be applied to debit/credit card payments.

3. Monthly fee for 2 years (24 months). Residential Service Customers (Schedules 1, 5,
and 6) may choose the monthly fee option and will receive 24 monthly bills, separate from their monthly
electric service bill, which must be paid within 30 days of the monthly invoice date. Payments may be
made by debit/credit card, mail-in check or money order, paystation check or money order, or personal
on-line bank transfer. A convenience fee will be applied to debit/credit card payments. The monthly
Subscription Fee of $26.31 will cover the cost of the Subscription Fee, carrying charges, and an
administration charge of $1.00 per month to reflect the costs of administering this monthly option.
Invoicing of the monthly Subscription Fee will begin with Enrollment.

If the monthly Subscription Fee is not paid within 60 days from the monthly invoice date, the
Customer will be considered in default and the entire Subscription will be transferred to Idaho Power.

PARTICIPATION

To participate in the Program, a Customer must sign and return the Participant Agreement and
elect its method of payment for the Subscription Fee.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company First Revised Sheet No. 63-4
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 63-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 63
COMMUNITY SOLAR PILOT PROGRAM
(OPTIONAL)
(Continued)

SOLAR ENERGY CREDIT (Continued)

Schedule Description
Solar Energy Credit
¢ per kWh
1, 5, and 6 Residential Service 3.0246
7 and 8 Small General Service 3.0209
9S Large General Service 2.9936
9P and 9T Large General Service 2.7352
19 Large Power Service 2.7735
24 Irrigation Service 2.6559
26 Micron Special Contract 2.5167
29 Simplot Special Contract 2.5371
30 DOE Special Contract 2.4915

The Power Cost Adjustment rate set forth in Schedule 55 will be applied to the net of the
Participant’s total energy use measured as the Participant’s monthly billed kWh less their proportional
share of the monthly generation measured in kWh from the array for that month.

The Solar Energy Credit rate is subject to change as the average embedded energy cost
reflected in retail rates changes or as otherwise approved by Commission order.

CANCELLATION

The Participant is not eligible to receive a refund of any portion of the Subscription Fee upon
cancellation of the Subscription. The Participant may elect to transfer the Subscription within 60 days
of the Participant terminating service with Idaho Power. If no transfer is requested within such 60-day
period, the Subscription and all benefits of the Subscription will revert to Idaho Power. The
Subscription transfer terms are discussed below.

SUBSCRIPTION TRANSFER

A Participant may elect to transfer the remaining life of the Participant’s Subscription to a new
service agreement or service location for the same Participant that meets the eligibility requirements.
Such transfers are not subject to additional fees.

Upon termination of a Participant’s service, Participants may transfer the remaining life of their
entire Subscription to another Eligible Customer’s service agreement, including an eligible non-profit,
for a $25 fee. Participants with more than one Subscription may transfer their Subscriptions in whole
subscription increments to one or more Eligible Customers for a $25 fee per transfer. A single
Subscription cannot be split for multiple transfers.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Sixth Revised Sheet No. 66-3
Cancels
I.P.U.C. No. 29, Tariff No. 101 Fifth Revised Sheet No. 66-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 66
MISCELLANEOUS CHARGES
(Continued)
CHARGES (Continued)

RULE F (all times are stated in Mountain Time)

1. Service Establishment Charge $20.00

2. Continuous Service Reversion Charge $10.00

3. Field Visit Charge
Schedules 1, 3, 4, 5, 6, 7, 8, 9 $20.00
Schedules 15, 19, 24, 40, 41, 42 $40.00

4. Service Connection Charge
Schedules 1, 3, 4, 5, 6, 7, 8, 9
Monday through Friday
7:30 am to 6:00 pm $20.00
6:01 pm to 9:00 pm $45.00
9:01 pm to 7:29 am $80.00

Company Holidays and Weekends
7:30 am to 9:00 pm $45.00
9:01 pm to 7:29 am $80.00

Schedules 15, 19, 24, 40, 41, 42
Monday through Friday
7:30 am to 6:00 pm $40.00
6:01 pm to 9:00 pm $65.00
9:01 pm to 7:29 am $100.00

Company Holidays and Weekends
7:30 am to 9:00 pm $65.00
9:01 pm to 7:29 am $100.00

Remote Service Connection
All schedules, all days, all times $13.00

The following is a list of company-recognized holidays and the dates they are observed: New Year’s
Day (January 1), Martin Luther King Jr. Day (third Monday in January), President’s Day (third Monday
in February), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday
in September), Thanksgiving Day (fourth Thursday in November), and Christmas Day (December 25).
When a holiday falls on Saturday the previous Friday will be observed, when a holiday falls on a
Sunday, the following Monday will be observed.

RULE G

1. Returned Check Charge $20.00
2. Late Payment Charge 12 percent per annum, or
one percent per month.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Fourth Revised Sheet No. 66-4
Cancels
I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 66-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 66
MISCELLANEOUS CHARGES
(Continued)

CHARGES (Continued)

RULE G (Continued)

3. Fractional Period Minimum Billings
Schedules 1, 3, 4, 5, 6, 7, and 8 $2.00
Schedules 9 and 19 Secondary Service Level $5.00
Schedules 9 and 19 Primary and Transmission
Service Levels $10.00
Schedule 24 $1.50
Schedule 15 $3.00
Schedule 40 $1.50

RULE M

1. Monthly Facilities Charge Rate

Facilities Installed Facilities Installed
31 Years or Less More Than 31 Years
Schedule 9 1.41% 0.59%
Schedule 15 1.50% 1.50%
Schedule 19 1.41% 0.59%
Schedule 24 1.41% 0.59%
Schedule 32 1.41% 0.59%
Schedule 41 1.21% 1.21%
Schedule 45 1.41% 0.59%
Schedule 46 1.41% 0.59%

The monthly Facilities Charge is determined by multiplying the Monthly Facilities Charge
Rate by the Company’s total investment in distribution facilities installed beyond the
Point of Delivery.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION

AVAILABILITY

Service under this schedule is available throughout the Company's service area within the State
of Idaho to Sellers owning or operating Qualifying Facilities that sign a Uniform Interconnection
Agreement or Generation Facilities that qualify for Schedule 6, Schedule 8, or Schedule 84.
Generation Facilities that qualify for Schedule 6, Schedule 8, or Schedule 84 are not required to sign a
Uniform Interconnection Agreement.

APPLICABILITY

Service under this schedule applies to the construction, operation, maintenance, Upgrade,
Relocation, or removal of transmission and/or distribution lines and equipment necessary to safely
interconnect a Seller's Generation Facility to the Company's system.

DEFINITIONS

Additional Applicant is a person or entity whose request for electrical connection requires the
Company to utilize existing Interconnection Facilities which are subject to a Vested Interest.

Company is the Idaho Power Company.

Connected Load is the combined input rating of the Customer's motors and other energy
consuming devices.

Construction Cost is the cost, as determined by the Company, of Upgrades, Relocation or
construction of Company furnished Interconnection Facilities.

Disconnection Equipment is any device or combination of devices by which the Company can
manually and/or automatically interrupt the flow of energy from the Seller to the Company's system,
including enclosures or other equipment as may be required to ensure that only the Company will have
access to certain of the devices.

First Energy Date is the date when the Seller begins delivering energy to the Company's
system.

Generation Facility means equipment used to produce electric energy at a specific physical
location which meets the requirements to be a Qualifying Facility or that qualifies for Schedule 6,
Schedule 8, or Schedule 84.

Generator Interconnection Process is the Company’s Generation Facility interconnection
application, engineering review and construction process. The intent of the Generator Interconnection
Process is to ensure a safe and reliable generation interconnection in compliance with all applicable
regulatory requirements, good utility practices and national safety standards.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

DEFINITIONS (Continued)

Interconnection Facilities are all facilities which are reasonably required by good utility practices
and the National Electric Safety Code to interconnect and to allow the delivery of energy from the
Seller's Generation Facility to the Company's system, including, but not limited to, Special Facilities,
Disconnection Equipment and Metering Equipment.

Interconnection Point is the point where the Seller’s conductors connect to the facilities owned
by the Company.

Metering Equipment is the Company owned equipment required to measure, record or
telemeter power flows between the Seller's Generation Facility and the Company's system.

Feasibility Review is the Company’s standard engineering review of proposed Net Metering
Systems or Small On-Site Generation Systems. This review is intended to ensure that the Company’s
system is sufficiently equipped to incorporate proposed Net Metering Systems or Small On-Site
Generation Systems in a manner that conforms with good utility practices and the National Electric
Safety Code.

Net Metering Service is the Company’s service which provides for transfer of electric energy to
the Company by means of a net metering arrangement or its successor(s) as approved by the
Commission. This optional service provides for Customers to install Generation Facilities to
interconnect to the Company’s system to offset all or a portion of their electrical usage. This service is
comprised of all customers taking service under Schedule 84.

Net Metering System is a Customer-owned Generation Facility interconnected to the
Company’s system under the terms of Schedule 84.

OATT is the Company’s Federal Energy Regulatory Commission (FERC) approved Open
Access Transmission Tariff.

Protection Equipment is the circuit-interrupting device, protective relaying, and associated
instrument transformers.

PURPA means the Public Utility Regulatory Policies Act of 1978.

Qualifying Facility is a cogeneration facility or a small power production facility which meets the
PURPA criteria for qualification set forth in Subpart B of Part 292, Subchapter K, Chapter I, Title 18, of
the Code of Federal Regulations.

Relocation is a change in the location of existing Company-owned transmission and/or
distribution lines, poles or equipment.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-3
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

DEFINITIONS (Continued)

Seller is a non-utility generator who has contracted or will contract with the Company to
interconnect a Generation Facility to the Company’s system to sell electric energy to the Company, or a
Customer taking service under Schedule 6, Schedule 8, or Schedule 84.

Seller-Furnished Facilities are those portions of the Interconnection Facilities provided by the
Seller.

Small On-Site Generation Service is the Company’s service which provides for transfer of
electric energy to the Company by means of a Small On-Site Generation System as approved by the
Commission. This optional service provides for Customers to install Generation Facilities to
interconnect to the Company’s system to offset all or a portion of their electrical usage. This service is
comprised of all customers taking service under Schedule 6 or Schedule 8.

Small On-Site Generation System is a Customer-owned Generation Facility, with a total
nameplate capacity rating of 25 kW or less, interconnected to the Company’s system under the terms
of Schedule 6 or Schedule 8.

Special Facilities are additions to or alterations of transmission and/or distribution lines and
transformers, including, but not limited to, Upgrades and Relocation, to safely interconnect the Seller's
Generation Facility to the Company's system.

System Verification Form is the form that a Customer must provide to the Company prior to the
connection of Net Metering Service or Small On-Site Generation Service as described in Section 2 of
this schedule.

Transfer Cost is the cost, as determined by the Company, for acceptance by the Company of
Seller-Furnished Facilities.

Upgrades are those improvements to the Company's existing system which are reasonably
required by good practices and the National Electric Safety Code to safely interconnect the Seller’s
Generation Facility. Such improvements include, but are not limited to, additional or larger conductors,
transformers, poles, and related equipment.

Vested Interest is the claim for refund that a Seller or Additional Applicant holds in a specific
portion of Company-owned Interconnection Facilities. The Vested Interest expires 5 years from the
date the Company completes construction of its portion of the Interconnection Facilities unless fully
refunded earlier.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-4
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS

The following provisions apply to all Sellers requesting interconnection to the Company’s
system.

CONSTRUCTION AND OPERATION OF INTERCONNECTION FACILITIES

All Seller-Furnished Interconnection Facilities will be constructed and maintained in a manner to
be in full compliance with all good utility practices, National Electric Safety Code, and all other
applicable federal, state, and local safety and electrical codes and standards at all times.

The Seller shall:

1. Submit proof to the Company that all licenses, permits, inspections, and approvals
necessary for the construction and operation of the Seller's Generation and Interconnection Facilities
under this schedule have been obtained from applicable federal, state, or local authorities.

2. Submit the designs, plans, specifications, and performance data for the Generation
Facility and Seller-Furnished Facilities to the Company for review. The Company’s acceptance shall
not be construed as confirming or endorsing the design, or as a warranty of safety, durability, or
reliability of the Generation Facility or Seller-Furnished Facilities. The Company will retain the right to
inspect this equipment at its discretion.

3. Demonstrate to the Company's satisfaction that the Seller's Generation Facility and
Seller-Furnished Facilities have been completed, and that all features and equipment of the Seller’s
Generation Facility and Seller-Furnished Facilities are capable of operating safely to commence
deliveries of Energy into the Company's system.

4. Provide and maintain adequate protective equipment sufficient to prevent damage to the
Generation Facility, Seller-Furnished Facilities and any other Seller-owned facilities in conformance
with all applicable electrical and safety codes and requirements.

5. Provide and maintain Disconnection Equipment in accordance with all applicable
electrical and safety codes and requirements as described within this Schedule.

6. Provide a 24-hour telephone contact(s). This contact will be used by the Company to
arrange for repairs and inspections or in case of an emergency. The Company will make its best effort
to arrange repairs and inspections during normal business hours and to notify the Seller of such
arrangements in advance. The Company will provide a telephone number to the Seller so that the
Seller can obtain information about Company activity impacting the Seller’s facility.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-5
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

DISCONNECTION EQUIPMENT

Disconnection Equipment is required for all Seller Generation Facilities. The Disconnection
Equipment shall be installed at an electrical location to allow complete isolation of Seller’s Generation
and Interconnection Facilities from the Company’s system. Disconnection Equipment for Net Metering
Systems or Small On-Site Generation Systems will be installed at an electrical location on the Seller’s
side of the Company’s retail metering point to allow complete isolation of the Seller’s Generation and
Interconnection Facilities from the Seller’s other electrical load and service.

The Disconnection Equipment’s operating device shall be:

1. Readily accessible by the Company at all times.

2. Clearly marked “Generation Disconnect Switch” with permanent 3/8 inch or larger letters.

3. Physically installed at a location within 10 feet of the Interconnection Point or exact,
permanent instructions posted at the Interconnection Point indicating the precise location of the
Disconnection Equipment’s operating device.

4. Of a design manually operated and lockable in the open position with a standard
Company padlock.

5. For Net Metering Systems under Schedule 84 or Small On-Site Generation Systems
under Schedules 6 and 8, equipped with a visual disconnect that enables the Company to visually
confirm that the Customer’s and Company’s conductors are physically disconnected. This requires the
ability to visually inspect the actual conductors. Circuit breakers and/or switches do not satisfy this
requirement if the conductors are not visible.

Operation of Disconnection Equipment. If, in the reasonable opinion of the Company, the
Seller's operation or maintenance of the Generation Facility or Interconnection Facilities is unsafe or
may otherwise adversely affect the Company's equipment, personnel, or service to its customers, the
Company may physically disconnect the Seller’s Generation Facility or Interconnection Facilities by
operation of the disconnection device or by any other means the Company deems necessary to
adequately disconnect the Seller’s Generation and Interconnection Facilities from the Company’s
system. At such time as the unsafe condition is remedied or other condition adversely affecting the
Company is resolved to the Company’s satisfaction, the interconnection will be restored.

The Company will disconnect the Seller’s Generation and Interconnection Facilities in
the event of any planned or unplanned maintenance or repair of the Company’s system connected to
the Seller’s Generation and Interconnection Facilities. In the event of unplanned maintenance or
repairs, no prior notice will be provided. In the event of planned repairs, the Company will attempt to
notify the Seller of the time and duration of the planned outage.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-6
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

DISCONNECTION EQUIPMENT (Continued)

The Company will disconnect the Seller’s Generation Facility and Interconnection Facilities in
the event that any terms and conditions of any applicable Company tariff or contract enabling the
interconnection of the Seller’s Generation Facility is deemed by the Company to be in default or
delinquent.

All expenses of disconnection and reconnection incurred by the Company will be billed to the
Seller. Net Metering Customers and Customers with Small On-Site Generation Systems will only be
subject to disconnection and reconnection charges if the expenses are incurred as the result of a
Customer’s Net Metering System or Small On-Site Generation Systems and/or a Customer’s failure to
abide by the provisions of Schedule 72.

In the case of Net Metering Systems or Small On-Site Generation Systems, disconnection of the
service may be necessary. The disconnection may result in interruption of both energy deliveries from
the Seller’s Generation Facility to the Company as well as interruption of energy deliveries from the
Company to the Seller. Disconnection provisions specific to Customers taking service under Schedule
6, Schedule 8, or Schedule 84 are described further in Section 2 of this tariff.

The Company will establish the settings of Protection Equipment to disconnect the Seller’s
Generation Facility and Interconnection Facilities for the protection of the Company’s system and
personnel consistent with good utility practices. If the Seller attempts to modify, adjust or otherwise
interfere with the protection equipment or its settings as established by the Company, such action may
be grounds for the Company's refusal to continue interconnection of the Seller’s Generation and
Interconnection Facilities to the Company’s system.

GENERAL REQUIREMENTS OF INTERCONNECTED PROJECTS

1. The Company will construct, own, operate and maintain all equipment, Upgrades, and
Relocations on the Company’s electrical side of the Interconnection Point.

2. The Company will clearly mark the Metering Equipment and any other Company
equipment associated with the Seller’s Generation Facility and/or Interconnection Facilities designating
the existence of the Seller’s Generation Facility as required by good utility practices.

3. The Seller will be required to submit all specific designs, equipment specifications, and
test results of the Seller-Furnished Facilities to the Company for review. Upon receipt of the design and
equipment specifications, the Company will review the design and equipment specifications for
conformance with applicable electrical and safety codes and standards.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-7
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

OPERATIONS AND MAINTENANCE OBLIGATIONS AND EXPENSES

The Company will operate and maintain Company furnished Interconnection Facilities as well as
any Seller-Furnished Facilities transferred to the Company.

SECTION 2: INTERCONNECTION OF NET METERING OR SMALL ON-SITE GENERATION
FACILITIES

The following section is applicable to all Customers taking Net Metering Service under Schedule
84 and Customers taking Small On-Site Generation Service under Schedule 6 or Schedule 8.

APPLICATION PROCESS

Customers requesting Net Metering Service or Small On-Site Generation Service are required
to complete the following application process prior to interconnection:

1. Customers must submit a completed application form and $100 application fee to the
Company. Applications are available on the Company’s website or will be provided to the Customer
upon request.

2. Upon receipt of a completed application and $100 fee, the Company will provide the
Customer with written or electronic mail notification that the application has been received and all
necessary information has been provided.

3. The Company will perform within seven (7) business days the Feasibility Review based
on project information provided in the application. The Feasibility Review for Net Metering Systems or
Small On-Site Generation Service determines the capability of the Company’s electrical system to
incorporate the proposed Net Metering System or Small On-Site Generation Service and determines if
Upgrades are necessary.

a. If the results of the Feasibility Review indicate satisfactory system capability, the
Company will provide the Customer with an official “Approval to Proceed” notification via written
or electronic mail.

b. If the results of the Feasibility Review indicate that Upgrades are necessary to
accommodate the proposed project, the Company will notify the Customer through written or
electronic mail of such Upgrades. Funding, construction, installation, and maintenance of
required Upgrades will be subject to the Company’s standard Rule H regarding New Service
Attachments and Distribution Line Installations or Alterations.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-8
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 2: INTERCONNECTION OF NET METERING OR SMALL ON-SITE GENERATION
FACILITIES (Continued)

APPLICATION PROCESS (Continued)

4. Following receipt of “Approval to Proceed” the Customer is responsible for completing
the installation of the Net Metering System or Small On-Site Generation System and fulfilling all
applicable federal, state, and local inspection requirements. Upon completion, the Customer must
provide all forms of documentation outlined in Section 1-1 above verifying that all federal, state, and
local requirements have been met. Customers must also provide the Company with a completed
System Verification Form detailing the specifications of all installed components of the completed Net
Metering System or Small On-Site Generation System. System Verification Forms can be found on the
Company’s website or will be provided upon request.

5. Once all required documentation has been submitted and the Company has verified that
all applicable federal, state, and local requirements have been met, the Company will complete, barring
conditions beyond the Company’s control, an on-site inspection within ten (10) business days.
Company on-site inspections will not be performed until the system has passed all applicable federal,
state, and local inspection requirements as described above. The Company on-site inspection includes
the following:

a. Verification that actual installed components correspond to information provided
on the initial application and the System Verification Form
b. Verification that the disconnect is functional and reconnection time complies with
IEEE Standard 1547
c. Verification of the proximity and visibility of the disconnect or a sign indicating the
location of the disconnect
d. Photographic documentation of the installation
e. Posting of appropriate Company signage
f. Documentation of the meter number and system configuration
g. Evaluation of inverters:

i. Systems utilizing verifiable UL 1741 or IEEE 1547 inverters will not be
subject to additional testing
ii. Systems utilizing all inverters other than UL 1741 or IEEE 1547 will be
subject to third-party testing performed at the Customer’s expense

6. Successful completion of the Company on-site inspection constitutes the conclusion of
the application process. The Company must make a reasonable effort to move the Customer to the
appropriate Net Metering Service or Small On-Site Generation Service rate schedule within five (5)
business days. Under no circumstances will the rate change occur more than fifteen (15) business
days from the date of the successfully completed inspection. Upon completion of this process, the
Customer will receive written or electronic mail confirmation that the application process has been
successfully completed.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-9
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-9
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 2: INTERCONNECTION OF NET METERING OR SMALL ON-SITE GENERATION
FACILITIES (Continued)

APPLICATION PROCESS (Continued)

7. In the event that a Net Metering System or a Small On-Site Generation System fails
inspection, the system will be locked and a tag providing Company contact information will be placed
on the device. A Company representative will then follow up via telephone with the Customer regarding
the reason(s) for failure, and assist the Customer in steps needed to bring the system into compliance
with inspection requirements. Once all issues have been addressed and the Customer indicates that
the system has passed all applicable federal, state, and local requirements, Idaho Power will re-inspect
the system.

APPLICATION EXPIRATION

1. Applications that are not completed within one year of the initial Feasibility Review are
considered expired. Customers requesting connection or approval of expired applications are required
to resubmit a completed application form and $100 application fee, and are subject to the full
application process described above.

RECERTIFICATION

1. The Company will perform full recertification inspections of all Net Metering Systems and
Small On-Site Generation Systems once every three years at no charge to the Customer. The
Company will provide the Customer with written notice at least fourteen (14) calendar days prior to
performing a recertification inspection. Recertification inspections will be performed in the same manner
as new Net Metering System and Small On-Site Generation Systems inspections described above.
Customers may choose to verify the results of the Company’s inspection through an independent
inspection performed by a certified third-party at the Customer’s expense. The Company reserves the
right to inspect any Net Metering System and Small On-Site Generation Systems at any time if
conditions are unsafe or may otherwise adversely affect the Company’s equipment, personnel, or
service to its Customers.

SYSTEM EXPANSIONS

1. Any modifications to Net Metering Systems or Small On-Site Generation Systems that
impact the generation capacity of the system or modify the system in any way that may impact the
safety or reliability of the Company’s electrical system are considered system expansions for the
purposes of this tariff.

2. Customers wishing to install system expansions must submit an application form and a
$100 feasibility review and inspection fee, and complete the application process according to the
procedures required for a new installation.

3. Systems that have been expanded in the manner described above without gaining prior
Company approval are considered unauthorized installations subject to the provisions of this schedule
described below.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-10
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-10
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 2: INTERCONNECTION OF NET METERING OR SMALL ON-SITE GENERATION
FACILITIES (Continued)

UNAUTHORIZED INSTALLATIONS AND EXPANSIONS

1. Net Metering Systems and Small On-Site Generation Systems that have been
interconnected to the Company’s system without Company approval are considered unauthorized
installations that jeopardize the reliability of Idaho Power’s system and the safety of its employees.
This includes, but is not limited to, newly installed systems and unapproved expansions of approved
systems. The process described herein provides the Company the ability to offer Net Metering Service
and Small On-Site Generation Systems in an efficient, safe, and reliable manner.

2. Unauthorized installations are subject to immediate Company inspection without notice.

a. If proper disconnection equipment is present, the Company will open and lock
the disconnect. When the system is disconnected, the Company will leave a tag on the system
providing the reason for disconnection and Company contact information. A door hanger or card
will also be left at the front door at the time of disconnection. Within twenty-four (24) hours of the
disconnection, the Customer will be called and written notification will be sent via U.S. Mail.
Upon completion of the full application process the system will be reinstated.

b. If proper disconnection equipment is not present, the Company will evaluate
installed inverters:

i. If the system utilizes UL 1741 or IEEE 1547 inverters, the Company will
contact the Customer either in person or via telephone in addition to written
communication regarding the unauthorized installation. This communication will include
the necessary steps to bring the system into compliance according to the following
procedures:

1. Within fifteen (15) days of notification, the Customer must submit
a completed application and $100 fee.

2. Within thirty (30) days of completion of the Feasibility Review, the
Customer must complete the remainder of the inspection requirements described
above.

3. Customers who do not wish to bring their systems into compliance
with this schedule may choose to disable their systems. Customers choosing to
do so must notify the Company of their decision within thirty (30) days of
receiving the initial Company notification regarding the unauthorized installation.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-11
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-11
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 2: INTERCONNECTION OF NET METERING OR SMALL ON-SITE GENERATION
FACILITIES (Continued)

UNAUTHORIZED INSTALLATIONS AND EXPANSIONS (Continued)

4. Customers that fail to complete the application process within the
allotted timeframe and/or do not disable their systems within thirty (30) days will
be subject to termination of electric service.

ii. If the system utilizes inverters other than UL 1741 or IEEE 1547, or if the
presence of UL 1741 or IEEE 1547 inverters cannot be verified, the Customer will be
subject to immediate termination of service without notice.

3. Customers subject to termination of service under this Schedule are provided two
options for restoration of service. Under both options Customers are responsible for reconnection costs
per the Company’s standard fees contained in Schedule 66.

a. Customers may choose to permanently disconnect Net Metering Systems or
Small On-Site Generation Systems from service. Permanent disconnection must, at a
minimum, include the physical removal of Interconnection Facilities at the associated
Generation Interconnection Point or physical removal of the General Facility itself. Opening a
breaker or switch does not constitute permanent disconnection. Customers choosing to
permanently disconnect their Net Metering System or Small On-Site Generation System must
receive confirmation from a state electrical inspector that the Net Metering System or Small On-
Site Generation System is no longer operational and interconnected to the Company’s system.
The results of this inspection must be provided to the Company prior to restoration of service.

b. Customers can bring the system into compliance with the provisions of this
schedule by completing the full application process described above.

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES

The following section is applicable to all Sellers requesting interconnection of non-utility
generation not taking service under Schedule 6, Schedule 8, or Schedule 84.

SPECIFIC PROJECT REQUIREMENTS

1. Generation Facilities Less than 1 MW Nameplate Rating

The following requirements are for Generation Facilities with nameplate ratings of less than 1
MW.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-12
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-12
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

SPECIFIC PROJECT REQUIREMENTS (Continued)

a. The Company shall procure, install, own and maintain Metering Equipment to
record energy deliveries to the Company. This metering will be separate from any other
metering of the Seller’s load and may be located on either side of the Interconnection Point. All
acquisition, installation, maintenance, inspection and testing costs related to Meter Equipment
installed to measure the Seller’s energy deliveries to the Company shall be borne by the Seller.

b. The Seller is responsible for all costs incurred by the Company for the review,
evaluation and testing of Seller supplied designs and equipment regardless as to the outcome
of the review or test results.

c. The Seller, upon completion of installation and prior to interconnection of the
Generation Facility to the Company’s system, will provide the Company with certification from a
professional engineer licensed in the State of Idaho stating that the Seller’s Generation Facility
and Interconnection Facilities are in compliance with IEEE Standard 1547 and all applicable
electrical and safety codes to enable safe and reliable operation.

d. The Seller will obtain and provide to the Company an annual certification and
testing by a professional engineer licensed in the State of Idaho, certifying the ongoing
compliance with IEEE Standard 1547 and all applicable electrical and safety codes and that the
Seller-Furnished Facilities successfully meet applicable testing requirements and standards. In
the event the Company does not receive and accept the annual certification within thirty (30)
days of the annual anniversary date of the agreement, the project will be disconnected from the
Company’s system until such time as the certification is completed and accepted by the
Company.

e. In addition to the requirements specified in sections a through d, Generation
Facilities that are greater than 100 kW and less than 1 MW total nameplate rating require the
following:

i. If the Company owns the transformer interconnecting the Seller’s
Generation Facility, then the Seller may own and maintain a secondary voltage
disconnection device that can be operated by both the Seller and the Company.

ii. If the Seller owns the transformer interconnecting the Seller’s Generation
Facility, then the Company will own, operate and maintain a primary voltage
disconnection device at the Seller’s expense.

iii. The Company will construct, own, operate and maintain all protective
relays and any associated equipment required to operate the protective relays.

2. Generation Facilities Greater Than 1 MW Nameplate Rating

The Company will own, maintain and operate all Interconnection Facilities and Disconnection
Equipment at the Seller’s expense.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-13
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-13
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

GENERATOR INTERCONNECTION PROCESS

1. Seller shall pay the actual costs of all required interconnection studies. Any difference
between the deposit (if required) and the actual cost of the study shall be paid by or refunded to Seller,
as appropriate. If, during the course of preparing a study, the Company incurs costs in excess of the
deposit amount, the Company may require that the deposit amount be replenished in an amount equal
to the estimated costs for completion of the study. If a deposit amount sufficient to pay for completion
of the study is not maintained, the Company may suspend work on the study.

2. Unless modified by the provisions of this schedule, the FERC-approved Large Generator
Interconnection Procedures and Small Generator Interconnection Procedures posted on the
Company’s website will apply to the Generator Interconnection Process.

3. The deposit amounts for Generation Facilities up to 30 MW are specified in this
schedule. Deposit amounts for Generation Facilities 30 MW and larger are covered by the FERC-
approved Large Generator Interconnection Procedures posted on the Company’s website.

4. Application. The Seller will submit a completed interconnection application in the form
posted on the Company’s website. The application form includes a general description of the
Generation Facility and its location. The application includes payment of an application fee to be
applied against costs the Company incurs to perform the Feasibility Study described below. The
amount of the application fee is $1,000 for a Generation Facility up to 30 MW.

5. Study Agreements. If the Seller desires to proceed beyond the Application stage, the
Seller will be offered a series of study agreements. The individual study agreements establish the time
to perform the study and the deposit the Seller is to provide prior to commencement of the study. The
deposit amount may be waived if a Seller meets the Company’s credit worthiness standards for
unsecured credit specified in Attachment L to the Company’s OATT. The studies consist of:

a. The Feasibility Study: The Feasibility Study includes a general review of project
impact, e.g. exceeding equipment capabilities and violation of electrical performance
requirements. The Feasibility Study Agreement states that no deposit is required, since the
deposit is covered by the application fee.

b. The System Impact Study: The System Impact Study provides a detailed
assessment of the distribution and/or transmission system adequacy to accommodate the
Generation Facility through the evaluation of equipment capabilities and electrical performance
requirements. This step may not be necessary for some projects depending on the size and
location of the project. The System Impact Study Agreement includes a deposit of $2,000 for a
distribution system impact study or a $10,000 deposit for a transmission system impact study.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-14
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-14
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

GENERATOR INTERCONNECTION PROCESS (Continued)

c. The Facility Study: The Facility Study includes the engineering to determine the
design specifications of the project. The Facility Study Agreement includes a deposit of 5% of
the total project costs that were determined in the System Impact Study Report (“SISR”) or the
Feasibility Study Report if a SISR is not required, capped at $30,000.

At the end of each stage of the three-step study process, the Company will provide the Seller
with an increasingly more refined and detailed report that, among other things, will present a list of
required Interconnection Facilities and a non-binding, good faith estimate of Seller’s cost responsibility
for the Interconnection Facilities. If long-lead time equipment items need to be ordered to meet Seller’s
construction schedule, the Company will request advance funding by the Seller to cover these
equipment costs.

6. Generator Interconnection Agreement. The Generator Interconnection Agreement
(“GIA”), will be offered to Seller following completion of the Facility Study. The GIA will utilize the
Uniform Interconnection Agreement template included in this schedule.

COST OF INTERCONNECTION FACILITIES

All Interconnection Facilities provided under this schedule will be valued at the Company's
Construction Cost and/or the Transfer Cost for vesting purposes as well as for operation and
maintenance payment obligations.

PAYMENT FOR INTERCONNECTION FACILITIES

Unless specifically agreed otherwise by written agreement between the Seller and the
Company, the Seller will pay all costs of interconnecting a Generation Facility to the Company's
system. Costs of interconnection include the costs of furnishing and constructing required
Interconnection Facilities, including Upgrades.

Each request for interconnection will go through the Generator Interconnection Process.
Throughout the Generator Interconnection Process, the Company will periodically bill the Seller for
costs incurred or obligated. Failure to pay an invoice within the time specified in the invoice will result
in suspension of work on the interconnection and if the suspension of work extends beyond thirty (30)
calendar days, the Generation Facility will be removed from the interconnection queue. Seller can end
the Generator Interconnection Process at any time. If Seller decides to end the Generator
Interconnection Process prior to completion, the Company will either refund any monies held for
security that have not been spent or obligated, or issue an invoice to Seller for costs incurred prior to
cancellation.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-15
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-15
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

SECURITY FOR PAYMENT OF INTERCONNECTION COSTS

Sellers will provide adequate security for payment of the costs of the Generator Interconnection
Process. Adequate security for Generation Facilities larger than 30 MW can be provided in accordance
with the Large Generator Interconnection Procedures contained in Attachment M to the Company’s
OATT. Adequate security for Generation Facilities up to 30 MW can be provided in one of the following
ways

1. Sellers that meet the Company’s credit worthiness standards for unsecured credit are
not required to provide additional security. The Company’s minimum credit standards for unsecured
credit are described in Attachment L to the OATT.

2. Sellers that do not meet the credit worthiness standards for unsecured credit will be
notified of the reason for the determination and shall be given the option to provide alternative security
acceptable to Idaho Power. In lieu of providing a cash deposit, Seller may establish an escrow
account, provide a letter of credit or provide guarantee of payment by another person or entity which
meets the credit worthiness standards for unsecured credit. Arrangements for alternative security must
be acceptable to Idaho Power.

TRANSFER OF INTERCONNECTION FACILITIES

Transfer of Interconnection Facilities is available only for Generation Facilities with nameplate
ratings greater than 100 kW.

1. Transfer at First Energy Date. If the Seller desires to transfer and the Company desires
to accept any Seller-Furnished Facilities at the First Energy Date, the following will apply:

a. Prior to the beginning of construction, the Seller shall cause the contractor that is
constructing the Seller-Furnished Facilities to provide the Company with a certificate naming the
Company as an additional insured in the amount of not less than $1,000,000 under the
contractor's general liability policy.

b. The Company will provide the Seller's contractor with construction and material
specifications and will have final approval of the design of the Seller-Furnished Facilities.

c. During construction and upon completion, the Company will inspect the Seller-
Furnished Facilities to be transferred to the Company. The cost of such inspection will be borne
by the Seller.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-16
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-16
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

TRANSFER OF INTERCONNECTION FACILITIES (Continued)

d. If the Seller-Furnished Facilities meet the Company's design, material and
construction specifications, are free from defects in materials and workmanship, and the Seller
has provided the Company with acceptable easements, bills of sale and assurance against
labor or materials liens, the Company will accept ownership effective as of the First Energy
Date. In the bill of sale, the Seller will warrant to the Company that the Seller-Furnished
Facilities are free of any liens or encumbrances and will be free from any defects in materials
and workmanship for a period of one year from the First Energy Date.

2. Subsequent Transfer. If, after the First Energy Date, the Seller desires to transfer and
the Company desires to accept any Seller-Furnished Facilities, the following will apply:

a. The Company will inspect the facilities proposed for sale to determine if they
meet the Company's design, material and construction specifications.

b. The Company will determine the Transfer Cost of such facilities. The Transfer
Cost will be equal to the depreciated Construction Cost the Company would have incurred if it
had originally constructed the facilities plus the cost, if any, of bringing the facilities into
compliance with the Company's design, material and construction specifications. Depreciation
of the facilities proposed for transfer will be determined on the same basis as the Company
depreciates its own facilities in accordance with the appropriate FERC account numbers for the
type and size of line or equipment involved. The time period used for the calculation of the
depreciated transfer cost will extend from the First Energy Date until the agreed upon transfer
date. The Transfer Cost will be paid to the Company in cash at the time of transfer. At the
same time, the Company will pay the Seller in cash an amount equal to the depreciated
Construction Cost.

c. As a condition of the Company's acceptance, the Seller will provide the Company
with acceptable easements, bills of sale and acceptable assurance against labor and material
liens. The bill of sale will include a warranty that the transferred facilities are free of all liens and
encumbrances and will be free from any defects in materials and workmanship for a period of
one year from the date of transfer.

d. Effective as of the date of the transfer, the Company will operate and maintain
the transferred facilities.

VESTED INTEREST

A Seller's eligibility for a Vested Interest refund will exist for 5 years after the date the Company
completes construction of its portion of the Interconnection Facilities.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Fourth Revised Sheet No. 72-17
Cancels
I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-17
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

VESTED INTEREST (Continued)

1. The Company will provide a refund payment to each Seller holding a Vested Interest in
Company-owned Interconnection Facilities when an Additional Applicant shares use of those
Interconnection Facilities.

2. The refund payment will be based on the following formula:

Linear Connected Original
Refund = Footage x Load/Peak Generation x Interconnection
Ratio Ratio Cost

a. The Linear Footage Ratio is the length of jointly used Special Facilities divided by
the length of the vested Special Facilities.

b. The Connected Load/Peak Generation Ratio is the Connected Load or Peak
Generation of the Additional Applicant divided by the sum of the Connected Load or Peak
Generation of the Additional Applicant and all other Connected Loads and/or Peak Generation
on the Special Facilities.

c. The Original Interconnection Cost is the sum of the Company's Construction Cost
and any Transfer Costs for the Interconnection Facilities to which the Additional Applicant
intends to connect and share usage.

3. The Additional Applicant will pay the Company the amount of the Vested Interest
refund(s). Additional Applicants making Vested Interest payments are in turn eligible to receive refunds
within the 5 year limit described above.

4. Vested Interest refunds will not exceed 100 percent of the refundable portion of any
party's cash payment to the Company.

5. Vested Interest refund payments may be waived by notifying the Company in writing.

OPERATION AND MAINTENANCE OBLIGATIONS AND EXPENSES

The Company will operate and maintain Company furnished Interconnection Facilities as well as
any Seller-Furnished Facilities transferred to the Company. For all projects not interconnecting as a
Schedule 6, Schedule 8, or Schedule 84 customer, the Seller will pay the Company a monthly
operation and maintenance charge equal to a percentage of the Construction Cost and Transfer Cost
paid by the Seller. The percentage will change annually on the anniversary of the First Energy Date in
accordance with the following tables:

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Fourth Revised Sheet No. 72-18
Cancels
I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 72-18
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

OPERATION AND MAINTENANCE OBLIGATIONS AND EXPENSES (Continued)

TABLE 1: MONTHLY OPERATION AND MAINTENANCE CHARGES FOR 138 kV and 161 kV
Year 1 2 3 4 5 6 7 8 9 10 11 12
O&M Charge 0.26% 0.27% 0.28% 0.29% 0.30% 0.32% 0.33% 0.35% 0.36% 0.38% 0.40% 0.41%
Year 13 14 15 16 17 18 19 20 21 22 23 24
O&M Charge 0.43% 0.45% 0.47% 0.49% 0.52% 0.54% 0.56% 0.59% 0.62% 0.64% 0.67% 0.70%
Year 25 26 27 28 29 30 31 32 33 34 35 36+
O&M Charge 0.73% 0.77% 0.80% 0.84% 0.87% 0.91% 0.96% 1.00% 1.04% 1.09% 1.14% 0.40%

TABLE 2: MONTHLY OPERATING AND MAINTENANCE CHARGES BELOW 138 kV
Year 1 2 3 4 5 6 7 8 9 10 11 12
O&M Charge 0.47% 0.49% 0.52% 0.54% 0.56% 0.59% 0.61% 0.64% 0.67% 0.70% 0.73% 0.77%
Year 13 14 15 16 17 18 19 20 21 22 23 24
O&M Charge 0.80% 0.84% 0.87% 0.91% 0.95% 1.00% 1.04% 1.09% 1.14% 1.19% 1.24% 1.30%
Year 25 26 27 28 29 30 31 32 33 34 35 36+
O&M Charge 1.36% 1.42% 1.48% 1.55% 1.62% 1.69% 1.77% 1.85% 1.93% 2.02% 2.11% 0.70%

The monthly operating and maintenance charges in Table 1 and Table 2 will be applied as a
percentage of the applicable original interconnection investment. These monthly operating and
maintenance charges escalate annually and are equivalent to 35-year levelized rates of 0.40% for
Table 1 and 0.70% for Table 2.

Where a Seller's interconnection will utilize Interconnection Facilities provided under a prior
agreement(s) and the combined term(s) of the prior agreement(s) is less than 35 years, the operation
and maintenance charge related to those existing Interconnection Facilities for the Seller's
interconnection will be computed to include the expired term of the prior agreement(s).

Where a Seller’s interconnection will utilize Interconnection Facilities provided under a prior
agreement(s) and the combined term(s) of the prior agreement(s) is greater than 35 years, the
operation and maintenance charge related to those existing Interconnection Facilities for the Seller’s
interconnection will be computed at the applicable levelized rate designated at 36+ years.

The cost upon which an individual Seller's operation and maintenance charge is based will be
reduced by subsequent Vested Interest refunds. Additional Applicants who are Sellers will pay the
monthly operation and maintenance charge on the amount they paid as an Additional Applicant.

Seller-Furnished Facilities not transferred to the Company will be operated and maintained by
the Seller at the Seller's sole risk and expense.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-19
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-19
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)

This Interconnection Agreement (“Agreement”) is effective as of the ____ day of __________,
20___, between ____________________________, hereinafter called “Seller,” and Idaho Power
Company, hereinafter called “Company.”

RECITALS

A. Seller will own or operate a Generation Facility that qualifies for service under Idaho
Power’s Commission-approved Schedule 72 and any successor schedule.

B. The Generation Facility covered by this Agreement is more particularly described in
Attachment 1.

AGREEMENTS

1. Capitalized terms used herein shall have the same meanings as defined in Schedule 72
or in the body of this Agreement.

2. This Agreement and Schedule 72 provide the rates, charges, terms and conditions
under which the Seller’s Generation Facility will interconnect with, and operate in parallel with, the
Company’s transmission/distribution system. Terms defined in Schedule 72 will have the same defined
meaning in this Agreement. If there is any conflict between the terms of this Agreement and Schedule
72, Schedule 72 shall prevail.

3. This Agreement is not an agreement to purchase Seller’s power. Purchase of Seller’s
power and other services that Seller may require will be covered under separate agreements. Nothing
in this Agreement is intended to affect any other agreement between the Company and Seller.

4. Attached to this Agreement and included by reference are the following:

Attachment 1 – Description and Costs of the Generation Facility, Interconnection
Facilities, and Metering Equipment.

Attachment 2 – One-line Diagram Depicting the Generation Facility, Interconnection
Facilities, Metering Equipment and Upgrades.

Attachment 3 – Milestones For Interconnecting the Generation Facility.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-20
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-20
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

Attachment 4 – Additional Operating Requirements for the Company’s Transmission
System Needed to Support the Seller’s Generation Facility.

Attachment 5 – Reactive Power.

Attachment 6 – Description of Upgrades required to integrate the Generation Facility and
Best Estimate of Upgrade Costs.

5. Effective Date, Term, Termination and Disconnection.

5.1 Term of Agreement. Unless terminated earlier in accordance with the provisions
of this Agreement, this Agreement shall become effective on the date specified above and
remain effective as long as Seller’s Generation Facility is eligible for service under Schedule 72.

5.2 Termination.

5.2.1 Seller may voluntarily terminate this Agreement upon expiration or
termination of an agreement to sell power to the Company.

5.2.2 After a Default, either Party may terminate this Agreement pursuant to
Section 6.5.

5.2.3 Upon termination or expiration of this Agreement, the Seller’s Generation
Facility will be disconnected from the Company’s transmission/distribution system. The
termination or expiration of this Agreement shall not relieve either Party of its liabilities
and obligations, owed or continuing at the time of the termination. The provisions of this
Section shall survive termination or expiration of this Agreement.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-21
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-21
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

5.3 Temporary Disconnection. Temporary disconnection shall continue only for so
long as reasonably necessary under “Good Utility Practice.” Good Utility Practice means any of
the practices, methods and acts engaged in or approved by a significant portion of the electric
industry during the relevant time period, or any of the practices, methods and acts which, in the
exercise of reasonable judgment in light of the facts known at the time the decision was made,
could have been expected to accomplish the desired result at a reasonable cost consistent with
good business practices, reliability, safety and expedition. Good Utility Practice is not intended
to be limited to the optimum practice, method, or act to the exclusion of all others, but rather to
be acceptable practices, methods, or acts generally accepted in the region. Good Utility
Practice includes compliance with WECC or NERC requirements. Payment of lost revenue
resulting from temporary disconnection shall be governed by the power purchase agreement.

5.3.1 Emergency Conditions. "Emergency Condition" means a condition or
situation: (1) that in the judgment of the Party making the claim is imminently likely to
endanger life or property; or (2) that, in the case of the Company, is imminently likely (as
determined in a non-discriminatory manner) to cause a material adverse effect on the
security of, or damage to the Company’s transmission/distribution system, the
Company’s Interconnection Facilities or the equipment of the Company’s customers; or
(3) that, in the case of the Seller, is imminently likely (as determined in a non-
discriminatory manner) to cause a material adverse effect on the reliability and security
of, or damage to, the Generation Facility or the Seller’s Interconnection Facilities. Under
Emergency Conditions, either the Company or the Seller may immediately suspend
interconnection service and temporarily disconnect the Generation Facility. The
Company shall notify the Seller promptly when it becomes aware of an Emergency
Condition that may reasonably be expected to affect the Seller’s operation of the
Generation Facility. The Seller shall notify the Company promptly when it becomes
aware of an Emergency Condition that may reasonably be expected to affect the
Company’s equipment or service to the Company’s customers. To the extent
information is known, the notification shall describe the Emergency Condition, the extent
of the damage or deficiency, the expected effect on the operation of both Parties'
facilities and operations, its anticipated duration, and the necessary corrective action.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-22
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-22
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

5.3.2 Routine Maintenance, Construction, and Repair. The Company may
interrupt interconnection service or curtail the output of the Seller’s Generation Facility
and temporarily disconnect the Generation Facility from the Company’s
transmission/distribution system when necessary for routine maintenance, construction,
and repairs on the Company’s transmission/distribution system. The Company will
make a reasonable attempt to contact the Seller prior to exercising its rights to interrupt
interconnection or curtail deliveries from the Seller’s Facility. Seller understands that in
the case of emergency circumstances, real time operations of the electrical system,
and/or unplanned events, the Company may not be able to provide notice to the Seller
prior to interruption, curtailment or reduction of electrical energy deliveries to the
Company. The Company shall use reasonable efforts to coordinate such reduction or
temporary disconnection with the Seller.

5.3.3 Scheduled Maintenance. On or before January 31 of each calendar year,
Seller shall submit a written proposed maintenance schedule of significant Facility
maintenance for that calendar year and the Company and Seller shall mutually agree as
to the acceptability of the proposed schedule. The Parties determination as to the
acceptability of the Seller’s timetable for scheduled maintenance will take into
consideration Good Utility Practices, Idaho Power system requirements and the Seller’s
preferred schedule. Neither Party shall unreasonably withhold acceptance of the
proposed maintenance schedule.

5.3.4. Maintenance Coordination. The Seller and the Company shall, to the
extent practical, coordinate their respective transmission/distribution system and
Generation Facility maintenance schedules such that they occur simultaneously. Seller
shall provide and maintain adequate protective equipment sufficient to prevent damage
to the Generation Facility and Seller-furnished Interconnection Facilities. In some cases,
some of Seller’s protective relays will provide back-up protection for Idaho Power’s
facilities. In that event, Idaho Power will test such relays annually and Seller will pay the
actual cost of such annual testing.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-23
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-23
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

5.3.5 Forced Outages. During any forced outage, the Company may suspend
interconnection service to effect immediate repairs on the Company’s
transmission/distribution system. The Company shall use reasonable efforts to provide
the Seller with prior notice. If prior notice is not given, the Company shall, upon request,
provide the Seller written documentation after the fact explaining the circumstances of
the disconnection.

5.3.6 Adverse Operating Effects. The Company shall notify the Seller as soon
as practicable if, based on Good Utility Practice, operation of the Seller’s Generation
Facility may cause disruption or deterioration of service to other customers served from
the same electric system, or if operating the Generation Facility could cause damage to
the Company’s transmission/distribution system or other affected systems. Supporting
documentation used to reach the decision to disconnect shall be provided to the Seller
upon request. If, after notice, the Seller fails to remedy the adverse operating effect
within a reasonable time, the Company may disconnect the Generation Facility. The
Company shall provide the Seller with reasonable notice of such disconnection, unless
the provisions of Article 5.3.1 apply.

5.3.7 Modification of the Generation Facility. The Seller must receive written
authorization from the Company before making any change to the Generation Facility
that may have a material impact on the safety or reliability of the Company’s
transmission/distribution system. Such authorization shall not be unreasonably withheld.
Modifications shall be done in accordance with Good Utility Practice. If the Seller makes
such modification without the Company’s prior written authorization, the latter shall have
the right to temporarily disconnect the Generation Facility.

5.3.8 Reconnection. The Parties shall cooperate with each other to restore the
Generation Facility, Interconnection Facilities, and the Company’s
transmission/distribution system to their normal operating state as soon as reasonably
practicable following a temporary disconnection.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-24
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-24
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

5.3.9 Voltage Levels. Seller, in accordance with Good Utility Practices, shall
minimize voltage fluctuations and maintain voltage levels acceptable to Idaho Power.
Idaho Power may, in accordance with Good Utility Practices, upon one hundred eighty
(180) days' notice to the Seller, change its nominal operating voltage level by more than
ten percent (10%) at the Point of Delivery, in which case Seller shall modify, at Idaho
Power's expense, Seller's equipment as necessary to accommodate the modified
nominal operating voltage level.

5.4 Land Rights.

5.4.1 Seller to Provide Access. Seller hereby grants to Idaho Power for the
term of this Agreement all necessary rights-of-way and easements to install, operate,
maintain, replace, and remove Idaho Power's Metering Equipment, Interconnection
Equipment, Disconnection Equipment, Protection Equipment and other Special Facilities
necessary or useful to this Agreement, including adequate and continuing access rights
on property of Seller. Seller warrants that it has procured sufficient easements and
rights-of-way from third parties so as to provide Idaho Power with the access described
above. All documents granting such easements or rights-of-way shall be subject to
Idaho Power's approval and in recordable form.

5.4.2 Use of Public Rights-of-Way. The Parties agree that it is necessary to
avoid the adverse environmental and operating impacts that would occur as a result of
duplicate electric lines being constructed in close proximity. Therefore, subject to Idaho
Power's compliance with Paragraph 5.4.4, Seller agrees that should Seller seek and
receive from any local, state or federal governmental body the right to erect, construct
and maintain Seller-furnished Interconnection Facilities upon, along and over any and all
public roads, streets and highways, then the use by Seller of such public right-of-way
shall be subordinate to any future use by Idaho Power of such public right-of-way for
construction and/or maintenance of electric distribution and transmission facilities and
Idaho Power may claim use of such public right-of-way for such purposes at any time.
Except as required by Paragraph 5.4.4, Idaho Power shall not be required to
compensate Seller for exercising its rights under this Paragraph 5.4.2.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-25
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-25
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

5.4.3 Joint Use of Facilities. Subject to Idaho Power's compliance with
Paragraph 15.4.4, Idaho Power may use and attach its distribution and/or transmission
facilities to Seller's Interconnection Facilities, may reconstruct Seller's Interconnection
Facilities to accommodate Idaho Power's usage or Idaho Power may construct its own
distribution or transmission facilities along, over and above any public right-of-way
acquired from Seller pursuant to Paragraph 5.4.2, attaching Seller's Interconnection
Facilities to such newly constructed facilities. Except as required by Paragraph 5.4.4,
Idaho Power shall not be required to compensate Seller for exercising its rights under
this Paragraph 5.4.3.

5.4.4 Conditions of Use. It is the intention of the Parties that the Seller be left in
substantially the same condition, both financially and electrically, as Seller existed prior
to Idaho Power's exercising its rights under this Paragraph 5.4. Therefore, the Parties
agree that the exercise by Idaho Power of any of the rights enumerated in Paragraphs
5.4.2 and 5.4.3 shall: (1) comply with all applicable laws, codes and Good Utility
Practices, (2) equitably share the costs of installing, owning and operating jointly used
facilities and rights-of-way. If the Parties are unable to agree on the method of
apportioning these costs, the dispute will be submitted to the Commission for resolution
and the decision of the Commission will be binding on the Parties, and (3) shall provide
Seller with an interconnection to Idaho Power's system of equal capacity and durability
as existed prior to Idaho Power exercising its rights under this Paragraph 5.4.

6. Assignment, Liability, Indemnity, Force majeure, Consequential Damages and Default.

6.1 Assignment. This Agreement may be assigned by either Party upon twenty-one
(21) calendar days prior written notice and opportunity to object by the other Party; provided
that:
6.1.1 Either Party may assign this Agreement without the consent of the other
Party to any affiliate of the assigning Party with an equal or greater credit rating and with
the legal authority and operational ability to satisfy the obligations of the assigning Party
under this Agreement.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-26
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-26
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

6.1.2 The Seller shall have the right to contingently assign this Agreement,
without the consent of the Company, for collateral security purposes to aid in providing
financing for the Generation Facility, provided that the Seller will promptly notify the
Company of any such contingent assignment.

6.1.3 Any attempted assignment that violates this article is void and ineffective.
Assignment shall not relieve a Party of its obligations, nor shall a Party's obligations be
enlarged, in whole or in part, by reason thereof. An assignee is responsible for meeting
the same financial, credit, and insurance obligations as the Seller. Where required,
consent to assignment will not be unreasonably withheld, conditioned or delayed.

6.2 Limitation of Liability. Each Party's liability to the other Party for any loss, cost,
claim, injury, liability, or expense, including reasonable attorney's fees, relating to or arising from
any act or omission in its performance of this Agreement, shall be limited to the amount of direct
damage actually incurred. In no event shall either Party be liable to the other Party for any
indirect, special, consequential, or punitive damages, except as authorized by this Agreement.

6.3 Indemnity.

6.3.1 This provision protects each Party from liability incurred to third parties as
a result of carrying out the provisions of this Agreement. Liability under this provision is
exempt from the general limitations on liability found in Article 6.2.

6.3.2 The Parties shall at all times indemnify, defend, and hold the other Party
harmless from, any and all damages, losses, claims, including claims and actions
relating to injury to or death of any person or damage to property, demand, suits,
recoveries, costs and expenses, court costs, attorney fees, and all other obligations by
or to third parties, arising out of or resulting from the other Party's action or failure to
meet its obligations under this Agreement on behalf of the indemnifying Party, except in
cases of gross negligence or intentional wrongdoing by the indemnified Party.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-27
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-27
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

6.3.3 If an indemnified person is entitled to indemnification under this article as
a result of a claim by a third party, and the indemnifying Party fails, after notice and
reasonable opportunity to proceed under this article, to assume the defense of such
claim, such indemnified person may at the expense of the indemnifying Party contest,
settle or consent to the entry of any judgment with respect to, or pay in full, such claim.
Failure to defend is a Material Breach.

6.3.4 If an indemnifying party is obligated to indemnify and hold any
indemnified person harmless under this article, the amount owing to the indemnified
person shall be the amount of such indemnified person's actual loss, net of any
insurance or other recovery.

6.3.5 Promptly after receipt by an indemnified person of any claim or notice of
the commencement of any action or administrative or legal proceeding or investigation
as to which the indemnity provided for in this article may apply, the indemnified person
shall notify the indemnifying party of such fact. Any failure of or delay in such notification
shall be a Material Breach and shall not affect a Party's indemnification obligation unless
such failure or delay is materially prejudicial to the indemnifying party.

6.4 Force Majeure. As used in this Agreement, “Force Majeure” or “an event of
Force Majeure” means any cause beyond the control of the Seller or of the Company which,
despite the exercise of due diligence, such Party is unable to prevent or overcome. Force
Majeure includes, but is not limited to, acts of God, fire, flood, storms, wars, hostilities, civil
strife, strikes and other labor disturbances, earthquakes, fires, lightning, epidemics, sabotage, or
changes in law or regulation occurring after the Operation Date, which, by the exercise of
reasonable foresight such party could not reasonably have been expected to avoid and by the
exercise of due diligence, it shall be unable to overcome. If either Party is rendered wholly or in
part unable to perform its obligations under this Agreement because of an event of Force
Majeure, both Parties shall be excused from whatever performance is affected by the event of
Force Majeure, provided that:

(1) The non-performing Party shall, as soon as is reasonably possible after
the occurrence of the Force Majeure, give the other Party written notice describing the
particulars of the occurrence.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Third Revised Sheet No. 72-28
Cancels
I.P.U.C. No. 29, Tariff No. 101 Second Revised Sheet No. 72-28
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

(2) The suspension of performance shall be of no greater scope and of no
longer duration than is required by the event of Force Majeure.

(3) No obligations of either Party which arose before the occurrence causing
the suspension of performance and which could and should have been fully performed
before such occurrence shall be excused as a result of such occurrence.

6.5 Default and Material Breaches.

6.5.1 Defaults. If either Party fails to perform any of the terms or conditions of
this Agreement (a “Default” or an “Event of Default”), the nondefaulting Party shall cause
notice in writing to be given to the defaulting Party, specifying the manner in which such
default occurred. If the defaulting Party shall fail to cure such Default within the sixty
(60) days after service of such notice, or if the defaulting Party reasonably demonstrates
to the other Party that the Default can be cured within a commercially reasonable time
but not within such sixty (60) day period and then fails to diligently pursue such cure,
then, the nondefaulting Party may, at its option, terminate this Agreement and/or pursue
its legal or equitable remedies.

6.5.2 Material Breaches. The notice and cure provisions in Paragraph 6.6.1 do
not apply to Defaults identified in this Agreement as Material Breaches. Material
Breaches must be cured as expeditiously as possible following occurrence of the
breach.

7. Insurance. During the term of this Agreement, Seller shall secure and continuously carry
the following insurance coverage:

7.1 Comprehensive General Liability Insurance for both bodily injury and property
damage with limits equal to $1,000,000, each occurrence, combined single limit. The deductible
for such insurance shall be consistent with current Insurance Industry Utility practices for similar
property.

7.2 The above insurance coverage shall be placed with an insurance company with
an A.M. Best Company rating of A- or better and shall include:
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Second Revised Sheet No. 72-29
Cancels
I.P.U.C. No. 29, Tariff No. 101 First Revised Sheet No. 72-29
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

(a) An endorsement naming Idaho Power as an additional insured and loss
payee as applicable; and

(b) A provision stating that such policy shall not be canceled or the limits of
liability reduced without sixty (60) days’ prior written notice to Idaho Power.

7.3 Seller to Provide Certificate of Insurance. As required in Paragraph 7 herein and
annually thereafter, Seller shall furnish the Company a certificate of insurance, together with the
endorsements required therein, evidencing the coverage as set forth above.

7.4 Seller to Notify Idaho Power of Loss of Coverage - If the insurance coverage
required by Paragraph 7.1 shall lapse for any reason, Seller will immediately notify Idaho Power
in writing. The notice will advise Idaho Power of the specific reason for the lapse and the steps
Seller is taking to reinstate the coverage. Failure to provide this notice and to expeditiously
reinstate or replace the coverage will constitute grounds for a temporary disconnection under
Section 5.3 and will be a Material Breach.

8. Miscellaneous.

8.1 Governing Law. The validity, interpretation and enforcement of this Agreement
and each of its provisions shall be governed by the laws of the State of Idaho without regard to
its conflicts of law principles.

8.2 Salvage. No later than sixty (60) days after the termination or expiration of this
Agreement, Idaho Power will prepare and forward to Seller an estimate of the remaining value
of those Idaho Power furnished Interconnection Facilities as required under Schedule 72 and/or
described in this Agreement, less the cost of removal and transfer to Idaho Power's nearest
warehouse, if the Interconnection Facilities will be removed. If Seller elects not to obtain
ownership of the Interconnection Facilities but instead wishes that Idaho Power reimburse the
Seller for said Facilities the Seller may invoice Idaho Power for the net salvage value as
estimated by Idaho Power and Idaho Power shall pay such amount to Seller within thirty (30)
days after receipt of the invoice. Seller shall have the right to offset the invoice amount against
any present or future payments due Idaho Power.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Second Revised Sheet No. 72-30
Cancels
I.P.U.C. No. 29, Tariff No. 101 First Revised Sheet No. 72-30
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

9. Notices.

9.1 General. Unless otherwise provided in this Agreement, any written notice,
demand, or request required or authorized in connection with this Agreement ("Notice") shall be
deemed properly given if delivered in person, delivered by recognized national currier service,
or sent by first class mail, postage prepaid, to the person specified below:

If to the Seller:
Seller:
Attention:
Address:
City: State: Zip:
Phone: Fax:

If to the Company:
Company
Attention:
Address:
City: State: Zip:
Phone: Fax:

9.2 Billing and Payment. Billings and payments shall be sent to the addresses set
out below:

Seller:
Attention:
Address:
City: State: Zip:
Phone: Fax:

Company:
Attention:
Address:
City: State: Zip:
Phone: Fax:
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company First Revised Sheet No. 72-31
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 72-31
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

9.3 Designated Operating Representative. The Parties may also designate
operating representatives to conduct the communications which may be necessary or
convenient for the administration of this Agreement. This person will also serve as the point of
contact with respect to operations and maintenance of the Party’s facilities.

Seller’s Operating Representative:
Seller:
Attention:
Address:
City: State: Zip:
Phone: Fax:

Company’s Operating Representative:
Company:
Attention:
Address:
City: State: Zip:
Phone: Fax:

9.5 Changes to the Notice Information. Either Party may change this information by
giving five Business Days written notice prior to the effective date of the change.

10. Signatures.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their
respective duly authorized representatives.

For the Company
Name:
Title:
Date:

For the Seller
Name:
Title:
Date:
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company First Revised Sheet No. 72-32
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 72-32
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

Attachment 1

Description and Costs of the Generation Facility, Interconnection Facilities and Metering
Equipment

In this attachment the Generation Facility and Interconnection Facilities, including Special
Facilities and upgrades, are itemized and identified as being owned by the Seller or the Company. As
provided in Schedule 72, Payment For Interconnection Facilities, the Company will provide a best
estimate itemized cost of its Interconnection Facilities, including Special Facilities, upgrades and
Metering Equipment.

Attachment 2

One-line Diagram Depicting the Small Generation Facility, Interconnection Facilities, Metering
Equipment and Upgrades

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company First Revised Sheet No. 73-33
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 72-33
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

Attachment 3

Milestones

In-Service Date: ___________________

Critical milestones and responsibility as agreed to by the Parties:

Milestone/Date Responsible Party

(1) _______________________________________ ______________________
(2) _______________________________________ ______________________
(3) _______________________________________ ______________________
(4) _______________________________________ ______________________
(5) _______________________________________ ______________________
(6) _______________________________________ ______________________
(7) _______________________________________ ______________________
(8) _______________________________________ ______________________
(9) _______________________________________ ______________________
(10) _______________________________________ ______________________

Agreed to by:

For the Company __________________________ Date______________

For the Seller________________________ Date______________

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 72-34
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

Attachment 4

Additional Operating Requirements for the Company’s Transmission System and Affected
Systems Needed to Support the Seller’s Needs

The Company shall also provide requirements that must be met by the Seller prior to initiating
parallel operation with the Company’s Transmission System.

Attachment 5

Reactive Power Requirements

Idaho Power will determine the reactive power required to be supplied by the Company to the
Seller, based upon information provided by the Seller. The Company will specify the equipment
required on the Company’s system to meet the Facility’s reactive power requirements. These
specifications will include but not be limited to equipment specifications, equipment location, Company-
provided equipment, Seller provided equipment, and all costs associated with the equipment, design
and installation of the Company-provided equipment. The equipment specifications and requirements
will become an integral part of this Agreement. The Company-owned equipment will be maintained by
the Company, with total cost of purchase, installation, operation, and maintenance, including
administrative cost to be reimbursed to the Company by the Seller. Payment of these costs will be in
accordance with Schedule 72 and the total reactive power cost will be included in the calculation of the
Monthly Operation and Maintenance Charges specified in Schedule 72.

Attachment 6

Company’s Description of Upgrades Required to Integrate the Generation Facility and Best
Estimate of Upgrade Costs

As provided in Schedule 72 this Attachment describes Upgrades, including best work upgrades,
and provides an itemized best estimate of the cost of the Upgrades.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Fourth Revised Sheet No. 81-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 81-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 81
RESIDENTIAL AIR CONDITIONER
CYCLING PROGRAM
(OPTIONAL)
(Continued)

AVAILABILITY

Service under this schedule is available on an optional basis to Customers taking service under
Schedules 1, 5, or 6 who have Central Air Conditioning located at their residences and live within the
Program Operation Area. Customers may request to be added to the Program at any time during the
year by providing Notification to the Company.

Service under this schedule may be limited based upon the availability of Program equipment
and/or funding. The Company shall have the right to select and reject Program participants at its sole
discretion based on criteria the Company considers necessary to ensure the effective operation of the
Program. Selection criteria may include, but will not be limited to, energy usage, residential location,
size of home, or other factors. Customers’ Central Air Conditioning equipment must be fully functional
and comply with the National Electric Code (NEC) standards. Customers who are renting or leasing
their home must provide to the Company written proof of the express permission of the owner of the
Central Air Conditioning system prior to acceptance into the program.

TERMS AND CONDITIONS

Upon acceptance into the Program, Customers will be subject to the following terms and
conditions:

1. Each eligible Customer who chooses to take service under this optional schedule is
thereby giving the Company or its representative permission, on reasonable notice, to enter the
Customer’s residence or property to install a Device and, in certain cases, either a mass memory meter
or an end-use meter and to allow Idaho Power or its representative, with prior notice to the Customer,
reasonable access to the Device or other Program-related equipment following its installation.

2. Customers added to the Program during the Air Conditioning Season must be effectively
participating in the Program prior to the 20th day of the month in order to receive an incentive payment
for that month.

3. A Customer may Opt Out of the Program two times during the Air Conditioning Season.

4. A Customer may discontinue participation in the Program without penalty by providing
Notification to the Company.

5. If there is evidence of alteration, tampering, or otherwise interfering with the Company’s
ability to initiate a Cycling Event, the Customer’s participation in the Program will be terminated and the
Customer will be required to reimburse the Company for the cost of replacement or repair of the Device
or other Program equipment and the Company will reverse any amounts credited to the Customer’s
bills during the past twelve months as a result of the Customer’s participation in the Program.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Fourth Revised Sheet No. 84-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 84-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 84
CUSTOMER ENERGY PRODUCTION
NET METERING SERVICE

AVAILABILITY

Service under this schedule is available throughout the Company’s service territory within the
State of Idaho for Customers intending to operate Net Metering Systems to generate electricity to reduce
all or part of their monthly energy usage.

Effective June 1, 2018, Schedule 84 is closed to service for Idaho residential and Idaho small
general service customers.

APPLICABILITY

Service under this schedule is applicable to any Customer that:

1. Does not take service under Schedule 4 or Schedule 5; and

2. Owns and/or operates a Generation Facility fueled by solar, wind, biomass, geothermal,
or hydropower, or represents fuel cell technology; and

3. Maintains its retail electric service account for the loads served at the Point of Delivery
adjacent to the Generation Interconnection Point as active and in good standing; and

4. Meets all requirements applicable to Net Metering Systems detailed in the Company’s
Schedule 72 Interconnections to Non-Utility Generation; and

5. Takes retail electric service under:

a. Schedule 1 or Schedule 7; and

Owns and/or operates a Generation Facility with a total nameplate capacity rating of 25
kilowatts (kW) or smaller that is interconnected to the Customer’s individual electric system on
the Customer’s side of the Point of Delivery, thus all energy received and delivered by the
Company is through the Company’s existing watt-hour retail meter.

b. Schedules other than Schedule 1, Schedule 4, Schedule 5, or Schedule 7; and

Owns and/or operates a Generation Facility with a total nameplate capacity rating of 100
kW or smaller that is interconnected at a Generation Interconnection Point that, at the
Company’s discretion, is located either adjacent to or on the Customer’s side of the Point of
Delivery and is metered through a meter that is separate from the retail load metering at the
Customer’s Point of Delivery. A separate meter from the existing retail load metering at the
Customer’s Point of Delivery is not required if the Customer meets the criteria below. The One
Meter Option is available if:

i. The Generation Facility has a total nameplate capacity rating of 25 kW or
smaller; and

ii. The Generation Facility has a total nameplate capacity rating that is no
more than 2% of the Customer’s Basic Load Capacity (BLC) or comparable average
maximum monthly Billing Demands.
IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Seventh Revised Sheet No. 91-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 Sixth Revised Sheet No. 91-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 91
ENERGY EFFICIENCY RIDER

APPLICABILITY

This schedule is applicable to all retail Customers served under the Company’s schedules and
special contracts. This Energy Efficiency Rider is designed to fund the Company’s expenditures for the
analysis and implementation of energy conservation and demand response programs.

MONTHLY CHARGE

The Monthly Charge is equal to the applicable Energy Efficiency Rider percentage times the
sum of the monthly billed charges for the base rate components.

Schedule Energy Efficiency Rider

Schedule 1 3.75%
Schedule 3 3.75%
Schedule 4 3.75%
Schedule 5 3.75%
Schedule 6 3.75%
Schedule 7 3.75%
Schedule 8 3.75%
Schedule 9 3.75%
Schedule 15 3.75%
Schedule 19 3.75%
Schedule 24 3.75%
Schedule 39 3.75%
Schedule 40 3.75%
Schedule 41 3.75%
Schedule 42 3.75%
Schedule 26 3.75%
Schedule 29 3.75%
Schedule 30 3.75%
Schedule 32 3.75%

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company Fourth Revised Sheet No. 98-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 Third Revised Sheet No. 98-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 98
RESIDENTIAL AND SMALL FARM
ENERGY CREDIT

APPLICABILITY

This schedule is applicable to the Qualifying Electric Energy, as defined below, delivered to
Customers taking service under Schedules 1, 3, 4, 5, 6, 7, 8, 9, 15, or 24.

The Residential and Small Farm Energy Credit (“Credit”) is the result of the Settlement
Agreement between the Company and the Bonneville Power Administration (“BPA”) Contract No.
11PB-12322. The Settlement Agreement provides for the determination of benefits during the period
October 1, 2011, through September 30, 2028. This schedule shall expire when the benefits derived
from the Settlement Agreement have been credited to Customers as provided for under this schedule.

QUALIFYING ELECTRIC ENERGY

RESIDENTIAL

All kilowatt-hours (kWh) of metered energy, delivered during the Billing Period, to
residential Customers taking service under Schedules 1, 3, 4, 5, or 6 and all kWh of metered
residential electric use delivered to Customers taking service under Schedules 7, 8, 9, or 15, as
defined in the BPA Customer Load Eligibility Guidelines for the Residential Exchange Program
Residential Purchase and Sale Agreements, will be considered Residential Qualifying Electric
Energy under this schedule.

SMALL FARM

All kWh of metered energy, delivered during the Billing Period, to eligible small farm
Customers taking service under Schedule 7, 8, or 9, as defined in the BPA Customer Load
Eligibility Guidelines for the Residential Exchange Program Residential Purchase and Sale
Agreements will be considered Small Farm Qualifying Electric Energy under this schedule.

IRRIGATION

All kWh of metered energy, delivered during the Billing Period, to eligible irrigation
Customers taking service under Schedule 24, as defined in the BPA Customer Load Eligibility
Guidelines for the Residential Exchange Program Residential Purchase and Sale Agreements,
limited to either the irrigation Customer’s actual metered energy or 222,000 kWh, whichever is
less, will be considered Irrigation Qualifying Electric Energy under this schedule. Irrigation
Customers will be identified by Tax Identification Number or Social Security Number for
purposes of determining Irrigation Qualifying Electric Energy under this schedule.

IDAHO PUBLIC UTILITIES COMMISSION
Approved Effective
May 21, 2018 June 1, 2018
Per O.N. 34046
Diane M. Hanian Secretary
Idaho Power Company FourthFifth Revised Sheet No. iii
Cancels
I.P.U.C. No. 29, Tariff No. 101 ThirdFourth Revised Sheet No. iii
IDAHO Issued by IDAHO POWER COMPANY
Issued – March 22, 2016 per Order No. 34046Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – April 22, 2016June 1, 2018 1221 West Idaho Street, Boise, ID
Advice No. 16-01

SCHEDULE INDEX
SHEET
SCHEDULE TITLE NUMBER

1 Residential Service Standard Plan ..................................................................... 1-1 – 1-2
3 Master-Metered Mobile Home Park Residential Service ..................................... 3-1 – 3-2
4 Residential Service Energy Watch Pilot Plan (Optional) (Suspended) ................ 4-1 – 4-3
5 Residential Service Time-of-Day Pilot Plan (Optional) ........................................ 5-1 – 5-3
6 Residential Service On-Site Generation ............................................................. 6-1 – 6-6
7 Small General Service ........................................................................................ 7-1 – 7-2
8 Small General Service On-Site Generation ........................................................ 8-1 – 8-5
9 Large General Service ........................................................................................ 9-1 – 9-4
15 Dusk to Dawn Customer Lighting .................................................................... 15-1 – 15-2
19 Large Power Service ....................................................................................... 19-1 – 19-7
23 Irrigation Peak Rewards Program (Optional) ................................................. 23-1 – 23-10
24 Agricultural Irrigation Service ........................................................................... 24-1 – 24-6
40 Non-Metered General Service ......................................................................... 40-1 – 40-2
41 Street Lighting Service .................................................................................... 41-1 – 41-8
42 Traffic Control Signal Lighting Service ........................................................................ 42-1
45 Standby Service .............................................................................................. 45-1 – 45-5
46 Alternate Distribution Service .......................................................................... 46-1 – 46-4
54 Fixed Cost Adjustment .................................................................................... 54-1 – 54-2
55 Power Cost Adjustment ................................................................................... 55-1 – 55-3
60 Solar Photovoltaic Service Pilot Program ........................................................ 60-1 – 60-6
61 Payment for Home Wiring Audit .................................................................................. 61-1
62 Green Energy Purchase Program Rider (Optional) ..................................................... 62-1
66 Miscellaneous Charges ................................................................................... 66-1 – 66-4
72 Interconnections to Non-Utility Generation .................................................. 72-1 – 72-334
73 Cogeneration and Small Power Production Schedule – Idaho ....................... 73-1 – 73-10
79 Weatherization Assistance for Qualified Customers ................................................... 79-1
81 Residential Air Conditioner Cycling Program (Optional) ................................... 81-1 – 81-3
82 Flex Peak Program (Optional) ......................................................................... 82-1 – 82-5
84 Customer Energy Production Net Metering Service ......................................... 84-1 – 84-5
86 Cogeneration and Small Power Production Non-Firm Energy ......................... 86-1 – 86-7
87 Intermittent Generation Integration Charges .................................................. 87-1 – 87-15
89 Unit Avoided Energy Cost for Cogeneration and Small Power Production .................. 89-1
91 Energy Efficiency Rider .............................................................................................. 91-1
95 Adjustment for Municipal Franchise Fees ........................................................ 95-1 – 95-2
98 Residential and Small Farm Energy Credit ...................................................... 98-1 – 98-2

Idaho Power Company First Revised Sheet No. C-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. C-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3050834046 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 1, 2008June 1, 2018 1221 West Idaho Street, Boise, Idaho

RULE C
SERVICE AND LIMITATIONS

1. Rates and Tariff. Service supplied by the Company will be in accordance with the Tariff on
file with the state regulatory authority having jurisdiction, and as in effect at the time service is supplied.
All service rates and agreements are subject to the continuing jurisdiction and regulation of such
authority, as provided by law.

When any municipal corporation or other local taxing agency imposes on the Company any
franchise, occupation, sales, license, excise, business, operating, privilege, or use of street tax or
charge based upon meters or Customers, or upon electricity sold or the receipts or income therefrom,
the prorate amount thereof will be billed to all Customers in the area or locality in which such tax or
charge applies and will be separately stated on, and added to, the regular billing.

2. Supplying of Service. Service will be supplied under a given schedule only to Points of
Delivery as are adjacent to facilities of the Company, adequate and suitable as to capacity and voltage for
the service desired and under the schedule applicable thereto. The Company will not be obligated to
construct extensions or install additional service facilities except in accordance with Rule H. In all other
cases, special agreements between the Customer and the Company may be required.

3. Service Application. The Company will normally accept an application for service from the
Customer by telephone, through the Company’s Web site or by other oral communication. The Company
may however, at its discretion, require the Customer to sign an application requesting service

4. Choice of Schedules. The Company's schedules are designed to provide monthly rates
for service supplied to the Customer on an annual basis. The Customer may elect to take service under
any of the schedules applicable to this annual service requirement, and the Company will endeavor to
assist in the selection of the appropriate schedule most favorable to the Customer. Changing of
schedules will occur only when the characteristics of the Customer's usage change such that another
applicable schedule is deemed more favorable to the Customer when applied to the Customer's annual
service requirements. Customers receiving service under Schedules 7, 8, 9, and 19 will be reviewed on a
monthly basis under the provisions established in the Applicability section of each of these schedules.

5. Point of Delivery Service Requirements. A Customer may be served at more than one
Point of Delivery at the same Premises if practicable, unless otherwise specified in a schedule. Service at
each Point of Delivery at the same Premises will be offered under the appropriate schedule. The
Customer's request for service at an additional Point of Delivery will be subject to the applicable line
extension rules of the Company. The Company may refuse to provide service at more than one Point of
Delivery at the same Premises if it is determined by the Company that the additional Point of Delivery
cannot be provided without jeopardizing the safety and reliability of the Company's system or service to
the Customer or to other Customers. Service provided to a Customer at multiple Points of Delivery at the
same Premises will not be interconnected electrically.

Idaho Power Company FirstSecond Revised Sheet No. G-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 OriginalFirst Revised Sheet No. G-1
IDAHO Issued by IDAHO POWER COMPANY
Issued- August 19, 2009 per Order No. 34046John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – September 19, 2009June 1, 2018 1221 West Idaho Street, Boise, Idaho
Advice No. 09-05

RULE G
BILLINGS

1. Fractional Periods. When the Customer’s Billing Period is less than 27 days or greater
than 36 days, the Energy Charge for service under Schedules 1, 3, 4, 5, 6, 7, 8, 9, 19, or 24 will be
calculated using actual meter readings. The Energy Charge for service provided under Schedule 40
will be determined using the daily kWh calculated on the basis of load size and number of units served
multiplied by the actual number of days since the account was opened or since the previous billing,
where appropriate. The proration of the applicable Demand Charge, Basic Charge, Facilities Charge,
and Service Charge specified in the appropriate schedule will be calculated by dividing the charge by
30 and multiplying the result by the actual number of days since the account was opened or since the
previous meter reading, where appropriate. However, the prorated Service Charge for Schedules 1, 3,
4, 5, 6, 7, 8, 9, 19, or 24 or the Minimum Charge for Schedule 40, will be no less than the amount
specified in Schedule 66. For Schedule 15, the proration of the applicable Monthly Charge will be
calculated by dividing the charge by 30 and multiplying the result by the actual number of days since
the account was opened or the previous billing, where appropriate; however, in no event will the charge
be less than the Fractional Period Minimum Billings amount specified in Schedule 66.

2. Corrected Billings. Whenever it is determined that a Customer was billed under an
inappropriate schedule, the Customer will be rebilled under the appropriate schedule, except if the
Company selected the schedule on the basis of available information and acted in good faith, the
Company will not be required to rebill or adjust billings. When the customer has been overcharged, the
rebilling period will be no more than the 3-year period as provided by Idaho Code §61-642. When the
customer has been undercharged, the rebilling period shall be limited to six months unless a reasonable
person should have known of the inappropriate billing, in which case the rebilling period may be extended
for a period not to exceed three years.

If the average error for any meter test exceeds ±2 percent, corrected billings will be
prepared. The corrected billings will not exceed 6 months if the time when the malfunction or error began
is unknown. If the time when the malfunction or error began is known and the customer was
overcharged, the corrected billings will be from that time, but will not exceed the 3 year period as provided
by Idaho Code §61-642. If the time when the malfunction or error began is known and the customer was
undercharged, the Company will rebill for a period of six months unless a reasonable person should have
known of the inaccurate billing, in which case the rebilling may be extended for a period not to exceed
three years. If an under-billing occurs, the Company will offer and enter into reasonable payment
arrangements with the Customer. For any over-billings, the Customer will have the choice of a refund or
a credit on future bills.

3. Due Dates. The Company's practices relating to Due Dates are governed by the Utility
Customer Relations Rules (UCRR) of the Idaho Public Utilities Commission, in effect at the time the
event occurred which required application of the UCRR. If the Company's Rules and Regulations on
file with the Idaho Public Utilities Commission contain provisions which conflict with the UCRR, the
provisions of the UCRR supersede those included in the Company's Rules and Regulations.

4. Returned Checks. Checks or payments remitted by Customers in payment of bills are
accepted conditionally. A Returned Check Charge, as specified in Schedule 66, will be assessed the
Customer for handling each check or payment upon which payment has been refused by the bank.

Idaho Power Company FirstSecond Revised Sheet No. H-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 OriginalFirst Revised Sheet No. H-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3247334046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 15, 2012June 1, 2018 1221 West Idaho Street, Boise, Idaho

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS

This rule applies to requests for electric service under Schedules 1, 3, 4, 5, 6, 7, 8, 9, 19, 24, 45,
and 46 that require the installation, alteration, relocation, removal, or attachment of Company-owned
distribution facilities. New construction beyond the Point of Delivery for Schedule 9 or Schedule 19 is
subject to the provisions for facilities charges under those schedules. This rule does not apply to
transmission or substation facilities, or to requests for electric service that are of a speculative nature.

1. Definitions

Additional Applicant is a person or entity whose Application requires the Company to provide
new or relocated service from an existing section of distribution facilities with a Vested Interest.

Alteration is any change or proposed change to existing distribution facilities. An alteration may
include Relocation, Upgrade, Conversion, and/or removal.

Applicant is a person or entity whose Application requires the Company to provide new or
relocated service from distribution facilities that are free and clear of any Vested Interest.

Application is a request by an Applicant or Additional Applicant for new electric service from the
Company. The Company, at its discretion, may require the Applicant or Additional Applicant to
sign a written application.

Company Betterment is that portion of the Work Order Cost of a Line Installation and/or
Alteration that provides a benefit to the Company not required by the Applicant or Additional
Applicant. Increases in conductor size and work necessitated by the increase in conductor size
are considered a Company Betterment if the Connected Load added by the Applicant or
Additional Applicant is less than 100 kilowatts. If, however, in the Company’s discretion, it is
determined that the additional Connected Load added by the Applicant or Additional Applicant,
even though less than 100 kilowatts, is (1) located in a remote location, or (2) a part of a
development or project which will add a load greater than 100 kilowatts, the Company will not
consider the work necessitated by the load increase to be a Company Betterment.

Connected Load is the total nameplate kW rating of the electric loads connected for commercial,
industrial, or irrigation service. Connected Load for residences is considered to be 25 kW for
residences with electric space heat and 15 kW for all other residences.

Conversion is a request by a customer to replace overhead facilities with underground facilities.

Cost Quote is a written cost estimate provided by the Company that must be signed and paid by
the Applicant or Additional Applicant prior to the start of construction. Cost Quotes are derived
from Work Order Cost estimates.

Easement is the Company’s legal right to use the real property of another for the purpose of
installing or locating electric facilities.

Idaho Power Company EighthNinth Revised Sheet No. H-11
Cancels
I.P.U.C. No. 29, Tariff No. 101SeventhEighth Revised Sheet No. H-11
IDAHO Issued by IDAHO POWER COMPANY
Issued – December 29, 2015per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 15, 2017June 1, 2018 1221 West Idaho Street, Boise, Idaho
Advice No. 16-09

RULE H
NEW SERVICE ATTACHMENTS
AND DISTRIBUTION LINE
INSTALLATIONS OR
ALTERATIONS
(Continued)

6. Other Charges (Continued)

j. Underground Service Return Trip Charge. When a residential Customer agrees to
supply the trench, backfill, conduit, and compaction for an underground service, an
Underground Service Return Trip Charge of $90.00 will be assessed each time the
Company’s installation crew is dispatched to the job site at the Customer’s request, but
is unable to complete the cable installation and energize the service.

7. Line Installation and Service Attachment Allowances

The Company will contribute an allowance toward the Terminal Facilities and Line Installation
costs necessary for Line Installations and/or Service Attachments. Allowances are based on
the cost of providing and installing Standard Terminal Facilities for single phase and three
phase services.

a. Allowances for Overhead and Underground Line Installations and Overhead Service
Attachments

Class of Service Maximum Allowance per Service

Residential:
Schedules 1, 3, 4, 5, 6 $2,226.00
Non-residence $ 0.00

Non-residential:
Schedules 7, 8, 9, 24
Single Phase $2,226.00
Three Phase $4,977.00

Large Power Service
Schedule 19 Case-By-Case

b. Allowances for Subdivisions and Multiple Occupancy Projects
Developers of Subdivisions and Multiple Occupancy Projects will receive a $2,226.00
allowance for each single phase transformer installed within a development and a
$4,977.00 allowance for each three phase transformer installed within a development.
Subdividers will be eligible to receive allowances for Line Installations inside residential
and non-residential subdivisions.

Idaho Power Company FirstSecond Revised Sheet No. I-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 OriginalFirst Revised Sheet No. I-1
IDAHO Issued by IDAHO POWER COMPANY
Issued – June 4, 2015per Order No. 34046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – July 8, 2015June 1, 2018 1221 West Idaho Street, Boise, Idaho

RULE I
BUDGET PAY PLANS

1. Residential Budget Pay Plan - Schedules 1, 4, and 5, and 6. A Budget Pay Plan is
available to Residential Customers desiring to levelize payments for electric service. If a Customer has
more than one electric service on the account, each electric service charge will be levelized individually.
A Customer may sign up for the Budget Pay Plan at any time during the year. In order to be eligible for
the Budget Pay Plan, the Customer’s account must not be in arrears and the customer must have
received service at the same location for a minimum of nine months.

The levelized payment will approximate the average of 12 monthly billings based on either the
historical charges, or an estimate of future charges. The Budget Pay amount for each electric service
on the account will be adjusted to the next higher dollar. Budget Pay amounts will be recalculated at
the 12-month (or 365-day) anniversary of the first bill that was generated after the Customer enrolled in
the Budget Pay Plan. The new monthly payment will be the recalculated Budget Pay amount(s). A
Customer’s Budget Pay amount(s) may decrease, increase, or remain the same.

Customers with a negative balance in their Budget Pay Plan account at the time of recalculation
will have monthly Budget Pay charges equal to the recalculated Budget Pay amount plus one-twelfth of
the negative balance. At the Customer’s request, a negative balance may be paid in full. Customers with
a positive balance in their Budget Pay Plan account at the time of recalculation, or upon termination of the
agreement after all charges for services have been paid, will be refunded at the Customer’s request. If no
request for refund is made, the monthly Budget Pay charges will be equal to the recalculated Budget Pay
amount reduced by one-twelfth of the positive balance. Upon the Customer’s request, a positive balance
for one Budget Pay electric service may be transferred to the balance of another Budget Pay electric
service on the account.

Any estimates furnished by the Company with such Budget Pay Plan should not be construed as
a guarantee that the total actual charges will not exceed the estimates. The Company, because of rate
changes or other requirements, may at any time submit a revised estimate to the Customer and require
that the Customer pay the revised monthly Budget Pay installment as a condition to the continuation of
the Budget Pay Plan for the Customer.

The Budget Pay amount(s) will be billed on the regular service bill each month. Once
established, the Budget Pay Plan will remain in effect from year to year until the Customer notifies the
Company not less than 30 days prior to the desired date of cancellation or unless the Customer fails to
pay the agreed amounts.

2. Small General Service Budget Pay Plan - Schedules 7 and 8. A Budget Pay Plan is
available to Small General Service Customers receiving service on Schedules 7 and 8. If a Customer
has more than one electric service on the account, each electric service charge will be levelized
individually. If a Customer transfers to another schedule (other than Schedules 1, 4, or 5, or 6), the
Budget Pay Plan will not be available. A Customer may sign up for the Budget Pay Plan at any time
during the year.

In order to qualify, the Customer must have been receiving service at the same location, under the
same ownership and account number, and with all monthly billings paid on or before the past due date for
at least 12 months prior to applying for the Budget Pay Plan. The Customer must maintain the payment
status as described above or the Customer will be removed from the Budget Pay Plan on the next
monthly billing and all past due balances will become immediately due and payable.
Idaho Power Company FirstSecond Revised Sheet No. I-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 OriginalFirst Revised Sheet No. I-2
IDAHO Issued by IDAHO POWER COMPANY
Issued – June 4, 2015per Order No. 34046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – July 8, 2015June 1, 2018 1221 West Idaho Street, Boise, Idaho

RULE I
BUDGET PAY PLANS
(Continued)

2. Small General Service Budget Pay Plan - Schedules 7 and 8 (Continued)

The levelized payment will approximate the average of 12 monthly billings based on historical
charges. Budget Pay amounts will be recalculated at the 12-month (or 365-day) anniversary of the first
bill that was generated after the Customer enrolled in the Budget Pay Plan. The Budget Pay amount for
each electric service on the account will be adjusted to the next higher dollar. The new monthly payment
will be the recalculated Budget Pay amount(s). A Customer’s Budget Pay amount(s) may decrease,
increase, or remain the same.

Customers with a negative balance in their Budget Pay Plan account at the time of recalculation
will have monthly Budget Pay charges equal to the recalculated Budget Pay amount plus one-twelfth of
the negative balance. At the Customer’s request, a negative balance may be paid in full. Customers with
a positive balance in their Budget Pay Plan account at the time of recalculation, or upon termination of the
agreement after all charges for services have been paid, will be refunded at the Customer’s request. If no
request for refund is made, the monthly Budget Pay charges will be equal to the recalculated Budget Pay
amount reduced by one-twelfth of the positive balance. Upon the Customer’s request, a positive balance
for one Budget Pay electric service may be transferred to the balance of another Budget Pay electric
service on the account.

Any estimates furnished by the Company with such Budget Pay Plan should not be construed as
a guarantee that the total actual charges will not exceed the estimates. The Company, because of rate
changes or other requirements, may at any time submit a revised estimate to the Customer and require
that the Customer pay the revised monthly Budget Pay installment as a condition to the continuation of
the Budget Pay Plan for the Customer.

The Budget Pay amount(s) will be billed on the regular service bill each month. Once established,
the Budget Pay Plan will remain in effect from year to year until the Customer notifies the Company not
less than 30 days prior to the desired date of cancellation or unless the Customer fails to pay the agreed
amounts.

Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 6-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 6
RESIDENTIAL SERVICE
ON-SITE GENERATION
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

9. The Customer shall notify the Company immediately if a Small On-Site Generation System
is permanently removed or disabled. Permanent removal or disablement for the purposes of this
Schedule is any removal or disablement of a Small On-Site Generation System lasting longer than six
(6) months. Customers with permanently removed or disabled systems will be removed from service
under this schedule and placed on the appropriate standard service schedule.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on August 31 of each year. The non-
summer season begins on September 1 of each year and ends on May 31 of each year.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set forth
in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy
Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), and Schedule 98 (Residential
and Small Farm Energy Credit).

The following rate structure and charges are subject to change upon Commission approval:

Summer Non-summer

Service Charge, per month $5.00 $5.00

Energy Charge, per kWh
First 800 kWh 8.69015318¢ 8.07467.9275¢
801-2000 kWh 10.44942590¢ 8.90207398¢
All Additional kWh Over 2000 12.41321871¢ 9.858886792¢

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.
Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 8-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERTION
(Continued)

CONDITIONS OF PURCHASE AND SALE

The conditions listed below shall apply to all transactions under this schedule.

1. Balances of generation and usage by the Customer:

a. If electricity supplied by the Company during the Billing Period exceeds the
electricity generated by the Customer and delivered to the Company during the Billing Period, the
Customer shall be billed for the net electricity supplied by the Company at the rates contained
within this schedule, in accordance with normal metering practices.

b. Effective at the beginning of each Customer’s January 2014 Billing Period, iIf
electricity generated by the Customer and delivered to the Company during the Billing Period
exceeds the electricity supplied by the Company during the Billing Period, the Excess Net Energy
shall be carried forward as a kWh credit to offset energy usage in a subsequent Billing Period.
Excess Net Energy credits are subject to the following provisions:

i. Credits can only be used to offset billed kWh consumption. Customers shall
be billed for all applicable non-energy charges for the Billing Period according to the
applicable standard service schedule.

ii. Credits shall carry forward provided the Customer maintains electric service
at the same Point of Delivery.

iii. Credits are non-transferrable in the event that a Customer relocates and/or
discontinues service at the Point of Delivery associated with the Small On-Site Generation
System. Any unused credits will expire at the time the final bill is prepared.

c. Compensation for the balance of generation and usage by the Customer is subject
to change upon Commission approval.

2. Aggregation of meters for the annual transfer of unused Excess Net Energy credits:

a. If a balance of Excess Net Energy credits exists at a Designated Meter at the end of
the Customer’s December Billing Period the Customer may request to transfer the unused credits
to offset energy consumption at eligible meters. A meter is eligible for aggregation if it meets all of
the following criteria:

i. The account subject to offset is held by the Customer; and

ii. The meter is located on, or contiguous to, the property on which the
Designated Meter is located. For the purposes of this tariff, contiguous property includes
property that is separated from the Premises of the Designated Meter by public or railroad
rights of way; and

Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 8-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 8
SMALL GENERAL SERVICE
ON-SITE GENERTION
(Continued)

CONDITIONS OF PURCHASE AND SALE (Continued)

7. If the Company is required by the Commission to institute curtailment of deliveries of
electricity to its customers, the Company may require the Customer to curtail its consumption of electricity
in the same manner and to the same degree as other Customers on the Company’s standard service
schedules.

8. The Customer shall grant to the Company all access to all Company equipment and
facilities including adequate and continuing access rights to the property of the Customer for the purpose
of installation, operation, maintenance, replacement, or any other service required of said equipment as
well as all necessary access for inspection, switching, and any other operational requirements of the
Customer’s Interconnections Facilities.

9. The Customer shall notify the Company immediately if a Small On-Site Generation System
is permanently removed or disabled. Permanent removal or disablement for the purposes of this
Schedule is any removal or disablement of a Small On-Site Generation System lasting longer than six
(6) months. Customers with permanently removed or disabled systems will be removed from service
under this schedule and placed on the appropriate standard service schedule.

SUMMER AND NON-SUMMER SEASONS

The summer season begins on June 1 of each year and ends on August 31 of each year. The non-
summer season begins on September 1 of each year and ends on May 31 of each year.

MONTHLY CHARGE

The Monthly Charge is the sum of the following charges, and may also include charges as set forth
in Schedule 54 (Fixed Cost Adjustment), Schedule 55 (Power Cost Adjustment), Schedule 91 (Energy
Efficiency Rider), Schedule 95 (Adjustment for Municipal Franchise Fees), and Schedule 98 (Residential
and Small Farm Energy Credit).

The following charges are subject to change upon Commission approval:

Summer Non-summer

Service Charge, per month $5.00 $5.00

Energy Charge, per kWh
First 300 kWh 9.90707265¢ 9.90707265¢
All Additional kWh 11.79935843¢ 10.39442050¢

PAYMENT

The monthly bill rendered for service supplied hereunder is payable upon receipt, and becomes
past due 15 days from the date on which rendered.

Idaho Power Company First Revised Sheet No. 61-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 61-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3050834046 John R. GaleTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – March 1, 2008June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 61
PAYMENT FOR HOME WIRING
AUDIT

AVAILABILITY

Service under this schedule is available to residential Customers throughout the Company's
service territory within the State of Idaho who are taking service under Schedules 1, 4, or 5, or 6.

SERVICES PROVIDED

A $40 payment is provided by the Company to residential Customers who have a home wiring
audit performed by a licensed electrician. To have a home wiring audit performed, a Customer is
responsible for contacting the Company to request the Home Wiring Audit form and then contacting a
licensed electrician to perform the audit. The Customer is also responsible for ensuring the electrician
performs the audit per the instructions of the Home Wiring Audit form. The charge for the audit will be
established by the electrician and will be billed by the electrician directly to the Customer. The Customer
is responsible for paying the electrician the charge for performing the audit.

The $40 payment is provided to the Customer upon receipt by the Company of the appropriate
copy of the completed Home Wiring Audit form. The Customer is responsible for submitting the Home
Wiring Audit form to the Company.

PURPOSE OF PAYMENT

The purpose of the $40 payment is to assist the Customer in identifying any wiring deficiencies
that may be causing power usage problems. The payment is not an indication that the Company has
performed any analysis as to the safety of the Customer's wiring or that the Company concurs with the
findings of the electrician's wiring audit.

Idaho Power Company First Revised Sheet No. 63-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 63-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3363834046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 31, 2016June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 63
COMMUNITY SOLAR PILOT PROGRAM
(OPTIONAL)

PROGRAM DESCRIPTION

The Community Solar Pilot Program (“Program”) is an optional program that will provide a
limited number of Idaho Power’s Idaho Customers the opportunity to voluntarily subscribe to the
generation output of a 500 kW single-axis tracking community solar array.

AVAILABILITY

The Program is available to Eligible Customers that hold evidence of a Subscription or an
entitlement to the electric generation output of a portion of the community solar array. Participation in
the Program is available on a first-come, first-served basis to all Eligible Customers who complete a
Participant Agreement. Approximately 1,563 Subscriptions will be available. If Idaho Power does not
receive what it deems to be a sufficient number of Subscriptions for the Program, Idaho Power may
terminate the Program and refund the Subscription Fees as set forth under “Refund of Subscription
Fee” in the Participant Agreement.

DEFINITIONS

Eligible Customers. Residential Service (Schedules 1, and 5, and 6), Small General Service
(Schedules 7 and 8), Large General Service (Schedule 9), Large Power Service (Schedule 19),
Agricultural Irrigation Service (Schedule 24), Micron Special Contract (Schedule 26), Simplot Special
Contract (Schedule 29), and the Department of Energy Special Contract (Schedule 30) Customers.
Non-metered and lighting accounts may not participate in the Program. Customers must be in Good
Standing with metered electric service accounts with service addresses located in Idaho within Idaho
Power’s service area. Participants must be 18 years of age or older and have full power and authority
to execute the Participation Agreement. Participant must be the customer of record on the Idaho
Power account for the service agreement to which the Subscriptions apply.

Good Standing. At the time of Subscription a Customer is in “Good Standing” if the Customer
does not have a past-due balance of $100 or more that is 60 days or more past due.

Participant. The Customer specified as the Participant in the Participant Agreement is the
Eligible Customer that has received notification of acceptance into the Program, or a successor
Participant designated in accordance with the Participant Agreement.

Participant Agreement. Eligible Customers will be required to sign the Participant Agreement
prior to participating in the Program. Participants will be subject to the terms and conditions of the
Participant Agreement.

Subscription. A “Subscription” is the Participant’s applicable portion of the electricity output
generated by the community solar array developed in connection with the 500 kW project.

Idaho Power Company First Revised Sheet No. 63-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 63-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3363834046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 31, 2016June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 63
COMMUNITY SOLAR PILOT PROGRAM
(OPTIONAL)
(Continued)

TERM

The Program term will extend 25 years after the date of first production of solar energy on a
non-test basis (Operation Date).

Service on this rate schedule (“Enrollment”) will commence with the first billing cycle following
the later of (i) the approval of the Eligible Customer’s Participant Agreement by the Company, and (ii)
the Operation Date.

SUBSCRIPTION FEE

$562.00 per Subscription.

PAYMENT OF SUBSCRIPTION FEE

Customers have the following payment options:

1. A single upfront payment by check.

2. A single upfront payment made by debit/credit card, mail-in check or money order,
paystation check or money order, or personal on-line bank transfer (“Bill Me”). A Customer who
requests the “Bill Me” option on the Participant Agreement will receive an Idaho Power Company
generated bill, separate from their monthly electric service bill, which must be paid within 30 days. A
convenience fee will be applied to debit/credit card payments.

3. Monthly fee for 2 years (24 months). Residential Service Customers (Schedules 1, and
5, and 6) may choose the monthly fee option and will receive 24 monthly bills, separate from their
monthly electric service bill, which must be paid within 30 days of the monthly invoice date. Payments
may be made by debit/credit card, mail-in check or money order, paystation check or money order, or
personal on-line bank transfer. A convenience fee will be applied to debit/credit card payments. The
monthly Subscription Fee of $26.31 will cover the cost of the Subscription Fee, carrying charges, and
an administration charge of $1.00 per month to reflect the costs of administering this monthly option.
Invoicing of the monthly Subscription Fee will begin with Enrollment.

If the monthly Subscription Fee is not paid within 60 days from the monthly invoice date, the
Customer will be considered in default and the entire Subscription will be transferred to Idaho Power.

PARTICIPATION

To participate in the Program, a Customer must sign and return the Participant Agreement and
elect its method of payment for the Subscription Fee.

Idaho Power Company First Revised Sheet No. 63-4
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 63-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3363834046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 31, 2016June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 63
COMMUNITY SOLAR PILOT PROGRAM
(OPTIONAL)
(Continued)

SOLAR ENERGY CREDIT (Continued)

Schedule Description
Solar Energy Credit
¢ per kWh
1, and 5,
and 6 Residential Service 3.0246
7 and 8 Small General Service 3.0209
9S Large General Service 2.9936
9P and 9T Large General Service 2.7352
19 Large Power Service 2.7735
24 Irrigation Service 2.6559
26 Micron Special Contract 2.5167
29 Simplot Special Contract 2.5371
30 DOE Special Contract 2.4915

The Power Cost Adjustment rate set forth in Schedule 55 will be applied to the net of the
Participant’s total energy use measured as the Participant’s monthly billed kWh less their proportional
share of the monthly generation measured in kWh from the array for that month.

The Solar Energy Credit rate is subject to change as the average embedded energy cost
reflected in retail rates changes or as otherwise approved by Commission order.

CANCELLATION

The Participant is not eligible to receive a refund of any portion of the Subscription Fee upon
cancellation of the Subscription. The Participant may elect to transfer the Subscription within 60 days
of the Participant terminating service with Idaho Power. If no transfer is requested within such 60-day
period, the Subscription and all benefits of the Subscription will revert to Idaho Power. The
Subscription transfer terms are discussed below.

SUBSCRIPTION TRANSFER

A Participant may elect to transfer the remaining life of the Participant’s Subscription to a new
service agreement or service location for the same Participant that meets the eligibility requirements.
Such transfers are not subject to additional fees.

Upon termination of a Participant’s service, Participants may transfer the remaining life of their
entire Subscription to another Eligible Customer’s service agreement, including an eligible non-profit,
for a $25 fee. Participants with more than one Subscription may transfer their Subscriptions in whole
subscription increments to one or more Eligible Customers for a $25 fee per transfer. A single
Subscription cannot be split for multiple transfers.

Idaho Power Company FifthSixth Revised Sheet No. 66-3
Cancels
I.P.U.C. No. 29, Tariff No. 101 FourthFifth Revised Sheet No. 66-3
IDAHO Issued by IDAHO POWER COMPANY
Issued – June 24, 2015per Order No. 34046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – August 1, 2015June 1, 2018 1221 West Idaho Street, Boise, Idaho
Advice No. 15-07

SCHEDULE 66
MISCELLANEOUS CHARGES
(Continued)
CHARGES (Continued)

RULE F (all times are stated in Mountain Time)

1. Service Establishment Charge $20.00

2. Continuous Service Reversion Charge $10.00

3. Field Visit Charge
Schedules 1, 3, 4, 5, 6, 7, 8, 9 $20.00
Schedules 15, 19, 24, 40, 41, 42 $40.00

4. Service Connection Charge
Schedules 1, 3, 4, 5, 6, 7, 8, 9
Monday through Friday
7:30 am to 6:00 pm $20.00
6:01 pm to 9:00 pm $45.00
9:01 pm to 7:29 am $80.00

Company Holidays and Weekends
7:30 am to 9:00 pm $45.00
9:01 pm to 7:29 am $80.00

Schedules 15, 19, 24, 40, 41, 42
Monday through Friday
7:30 am to 6:00 pm $40.00
6:01 pm to 9:00 pm $65.00
9:01 pm to 7:29 am $100.00

Company Holidays and Weekends
7:30 am to 9:00 pm $65.00
9:01 pm to 7:29 am $100.00

Remote Service Connection
All schedules, all days, all times $13.00

The following is a list of company-recognized holidays and the dates they are observed: New Year’s
Day (January 1), Martin Luther King Jr. Day (third Monday in January), President’s Day (third Monday
in February), Memorial Day (last Monday in May), Independence Day (July 4), Labor Day (first Monday
in September), Thanksgiving Day (fourth Thursday in November), and Christmas Day (December 25).
When a holiday falls on Saturday the previous Friday will be observed, when a holiday falls on a
Sunday, the following Monday will be observed.

RULE G

1. Returned Check Charge $20.00
2. Late Payment Charge 12 percent per annum, or
one percent per month.
Idaho Power Company ThirdFourth Revised Sheet No. 66-4
Cancels
I.P.U.C. No. 29, Tariff No. 101 SecondThird Revised Sheet No. 66-4
IDAHO Issued by IDAHO POWER COMPANY
Issued – August 7, 2015per Order No. 34046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – September 7, 2015June 1, 2018 1221 West Idaho Street, Boise, Idaho
Advice No. 15-09

SCHEDULE 66
MISCELLANEOUS CHARGES
(Continued)

CHARGES (Continued)

RULE G (Continued)

3. Fractional Period Minimum Billings
Schedules 1, 3, 4, 5, 6, and 7, and 8 $2.00
Schedules 9 and 19 Secondary Service Level $5.00
Schedules 9 and 19 Primary and Transmission
Service Levels $10.00
Schedule 24 $1.50
Schedule 15 $3.00
Schedule 40 $1.50

RULE M

1. Monthly Facilities Charge Rate

Facilities Installed Facilities Installed
31 Years or Less More Than 31 Years
Schedule 9 1.41% 0.59%
Schedule 15 1.50% 1.50%
Schedule 19 1.41% 0.59%
Schedule 24 1.41% 0.59%
Schedule 32 1.41% 0.59%
Schedule 41 1.21% 1.21%
Schedule 45 1.41% 0.59%
Schedule 46 1.41% 0.59%

The monthly Facilities Charge is determined by multiplying the Monthly Facilities Charge
Rate by the Company’s total investment in distribution facilities installed beyond the
Point of Delivery.
Idaho Power Company SecondThird Revised Sheet No. 72-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 FirstSecond Revised Sheet No. 72-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION

AVAILABILITY

Service under this schedule is available throughout the Company's service area within the State
of Idaho to Sellers owning or operating Qualifying Facilities that sign a Uniform Interconnection
Agreement or Generation Facilities that qualify for Schedule 6, Schedule 8, or Schedule 84.
Generation Facilities that qualify for Schedule 6, Schedule 8, or Schedule 84 are not required to sign a
Uniform Interconnection Agreement.

APPLICABILITY

Service under this schedule applies to the construction, operation, maintenance, Upgrade,
Relocation, or removal of transmission and/or distribution lines and equipment necessary to safely
interconnect a Seller's Generation Facility to the Company's system.

DEFINITIONS

Additional Applicant is a person or entity whose request for electrical connection requires the
Company to utilize existing Interconnection Facilities which are subject to a Vested Interest.

Company is the Idaho Power Company.

Connected Load is the combined input rating of the Customer's motors and other energy
consuming devices.

Construction Cost is the cost, as determined by the Company, of Upgrades, Relocation or
construction of Company furnished Interconnection Facilities.

Disconnection Equipment is any device or combination of devices by which the Company can
manually and/or automatically interrupt the flow of energy from the Seller to the Company's system,
including enclosures or other equipment as may be required to ensure that only the Company will have
access to certain of the devices.

First Energy Date is the date when the Seller begins delivering energy to the Company's
system.

Generation Facility means equipment used to produce electric energy at a specific physical
location which meets the requirements to be a Qualifying Facility or that qualifies for Schedule 6,
Schedule 8, or Schedule 84.

Generator Interconnection Process is the Company’s Generation Facility interconnection
application, engineering review and construction process. The intent of the Generator Interconnection
Process is to ensure a safe and reliable generation interconnection in compliance with all applicable
regulatory requirements, good utility practices and national safety standards.
Idaho Power Company SecondThird Revised Sheet No. 72-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 FirstSecond Revised Sheet No. 72-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

DEFINITIONS (Continued)

Interconnection Facilities are all facilities which are reasonably required by good utility practices
and the National Electric Safety Code to interconnect and to allow the delivery of energy from the
Seller's Generation Facility to the Company's system, including, but not limited to, Special Facilities,
Disconnection Equipment and Metering Equipment.

Interconnection Point is the point where the Seller’s conductors connect to the facilities owned
by the Company.

Metering Equipment is the Company owned equipment required to measure, record or
telemeter power flows between the Seller's Generation Facility and the Company's system.

Net Metering Feasibility Review is the Company’s standard engineering review of proposed Net
Metering Systems or Small On-Site Generation Systems. This review is intended to ensure that the
Company’s system is sufficiently equipped to incorporate proposed Net Metering Systems or Small On-
Site Generation Systems in a manner that conforms with good utility practices and the National Electric
Safety Code.

Net Metering Service is the Company’s service which provides for transfer of electric energy to
the Company by means of a net metering arrangement or its successor(s) as approved by the
Commission. This optional service provides for Customers to install Generation Facilities to
interconnect to the Company’s system to offset all or a portion of their electrical usage. This service is
comprised of all customers taking service under Schedule 84.

Net Metering System is a Customer-owned Generation Facility interconnected to the
Company’s system under the terms of Schedule 84.

OATT is the Company’s Federal Energy Regulatory Commission (FERC) approved Open
Access Transmission Tariff.

Protection Equipment is the circuit-interrupting device, protective relaying, and associated
instrument transformers.

PURPA means the Public Utility Regulatory Policies Act of 1978.

Qualifying Facility is a cogeneration facility or a small power production facility which meets the
PURPA criteria for qualification set forth in Subpart B of Part 292, Subchapter K, Chapter I, Title 18, of
the Code of Federal Regulations.

Relocation is a change in the location of existing Company-owned transmission and/or
distribution lines, poles or equipment.

Idaho Power Company SecondThird Revised Sheet No. 72-3
Cancels
I.P.U.C. No. 29, Tariff No. 101 FirstSecond Revised Sheet No. 72-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

DEFINITIONS (Continued)

Seller is a non-utility generator who has contracted or will contract with the Company to
interconnect a Generation Facility to the Company’s system to sell electric energy to the Company, or a
Customer taking service under the Company’s net metering tariff,Schedule 6, Schedule 8, or Schedule
84.

Seller-Furnished Facilities are those portions of the Interconnection Facilities provided by the
Seller.

Small On-Site Generation Service is the Company’s service which provides for transfer of
electric energy to the Company by means of a Small On-Site Generation System as approved by the
Commission. This optional service provides for Customers to install Generation Facilities to
interconnect to the Company’s system to offset all or a portion of their electrical usage. This service is
comprised of all customers taking service under Schedule 6 or Schedule 8.

Small On-Site Generation System is a Customer-owned Generation Facility, with a total
nameplate capacity rating of 25 kW or less, interconnected to the Company’s system under the terms
of Schedule 6 or Schedule 8.

Special Facilities are additions to or alterations of transmission and/or distribution lines and
transformers, including, but not limited to, Upgrades and Relocation, to safely interconnect the Seller's
Generation Facility to the Company's system.

System Verification Form is the form that a Customer must provide to the Company prior to the
connection of Net Metering Service or Small On-Site Generation Service as described in Section 2 of
this schedule.

Transfer Cost is the cost, as determined by the Company, for acceptance by the Company of
Seller-Furnished Facilities.

Upgrades are those improvements to the Company's existing system which are reasonably
required by good practices and the National Electric Safety Code to safely interconnect the Seller’s
Generation Facility. Such improvements include, but are not limited to, additional or larger conductors,
transformers, poles, and related equipment.

Vested Interest is the claim for refund that a Seller or Additional Applicant holds in a specific
portion of Company-owned Interconnection Facilities. The Vested Interest expires 5 years from the
date the Company completes construction of its portion of the Interconnection Facilities unless fully
refunded earlier.

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS

The following provisions apply to all Sellers requesting interconnection to the Company’s
system.
Idaho Power Company SecondThird Revised Sheet No. 72-3
Cancels
I.P.U.C. No. 29, Tariff No. 101 FirstSecond Revised Sheet No. 72-3
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

CONSTRUCTION AND OPERATION OF INTERCONNECTION FACILITIES

All Seller-Furnished Interconnection Facilities will be constructed and maintained in a manner to
be in full compliance with all good utility practices, National Electric Safety Code, and all other
applicable federal, state, and local safety and electrical codes and standards at all times.

The Seller shall:

1. Submit proof to the Company that all licenses, permits, inspections, and approvals
necessary for the construction and operation of the Seller's Generation and Interconnection Facilities
under this schedule have been obtained from applicable federal, state, or local authorities.
Idaho Power Company SecondThird Revised Sheet No. 72-4
Cancels
I.P.U.C. No. 29, Tariff No. 101 FirstSecond Revised Sheet No. 72-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

CONSTRUCTION AND OPERATION OF INTERCONNECTION FACILITIES (Continued)
SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS

The following provisions apply to all Sellers requesting interconnection to the Company’s
system.

CONSTRUCTION AND OPERATION OF INTERCONNECTION FACILITIES

All Seller-Furnished Interconnection Facilities will be constructed and maintained in a manner to
be in full compliance with all good utility practices, National Electric Safety Code, and all other
applicable federal, state, and local safety and electrical codes and standards at all times.

The Seller shall:

1. Submit proof to the Company that all licenses, permits, inspections, and approvals
necessary for the construction and operation of the Seller's Generation and Interconnection Facilities
under this schedule have been obtained from applicable federal, state, or local authorities.

2. Submit the designs, plans, specifications, and performance data for the Generation
Facility and Seller-Furnished Facilities to the Company for review. The Company’s acceptance shall
not be construed as confirming or endorsing the design, or as a warranty of safety, durability, or
reliability of the Generation Facility or Seller-Furnished Facilities. The Company will retain the right to
inspect this equipment at its discretion.

3. Demonstrate to the Company's satisfaction that the Seller's Generation Facility and
Seller-Furnished Facilities have been completed, and that all features and equipment of the Seller’s
Generation Facility and Seller-Furnished Facilities are capable of operating safely to commence
deliveries of Energy into the Company's system.

4. Provide and maintain adequate protective equipment sufficient to prevent damage to the
Generation Facility, Seller-Furnished Facilities and any other Seller-owned facilities in conformance
with all applicable electrical and safety codes and requirements.

5. Provide and maintain Disconnection Equipment in accordance with all applicable
electrical and safety codes and requirements as described within this Schedule.

6. Provide a 24-hour telephone contact(s). This contact will be used by the Company to
arrange for repairs and inspections or in case of an emergency. The Company will make its best effort
to arrange repairs and inspections during normal business hours and to notify the Seller of such
arrangements in advance. The Company will provide a telephone number to the Seller so that the
Seller can obtain information about Company activity impacting the Seller’s facility.

DISCONNECTION EQUIPMENT
Idaho Power Company SecondThird Revised Sheet No. 72-4
Cancels
I.P.U.C. No. 29, Tariff No. 101 FirstSecond Revised Sheet No. 72-4
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

Disconnection Equipment is required for all Seller Generation Facilities. The Disconnection
Equipment shall be installed at an electrical location to allow complete isolation of Seller’s Generation
and Interconnection Facilities from the Company’s system. Disconnection Equipment for Net Metering
Systems will be installed at an electrical location on the Seller’s side of the Company’s retail metering
point to allow complete isolation of the Seller’s Generation and Interconnection Facilities from the
Seller’s other electrical load and service.

The Disconnection Equipment’s operating device shall be:

1. Readily accessible by the Company at all times.

2. Clearly marked “Generation Disconnect Switch” with permanent 3/8 inch or larger letters.

3. Physically installed at a location within 10 feet of the Interconnection Point or exact,
permanent instructions posted at the Interconnection Point indicating the precise location of the
Disconnection Equipment’s operating device.
Idaho Power Company SecondThird Revised Sheet No. 72-5
Cancels
I.P.U.C. No. 29, Tariff No. 101 FirstSecond Revised Sheet No. 72-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

DISCONNECTION EQUIPMENT (Continued)
DISCONNECTION EQUIPMENT

Disconnection Equipment is required for all Seller Generation Facilities. The Disconnection
Equipment shall be installed at an electrical location to allow complete isolation of Seller’s Generation
and Interconnection Facilities from the Company’s system. Disconnection Equipment for Net Metering
Systems or Small On-Site Generation Systems will be installed at an electrical location on the Seller’s
side of the Company’s retail metering point to allow complete isolation of the Seller’s Generation and
Interconnection Facilities from the Seller’s other electrical load and service.

The Disconnection Equipment’s operating device shall be:

1. Readily accessible by the Company at all times.

2. Clearly marked “Generation Disconnect Switch” with permanent 3/8 inch or larger letters.

3. Physically installed at a location within 10 feet of the Interconnection Point or exact,
permanent instructions posted at the Interconnection Point indicating the precise location of the
Disconnection Equipment’s operating device.

4. Of a design manually operated and lockable in the open position with a standard
Company padlock.

5. For Net Metering Systems under Schedule 84 or Small On-Site Generation Systems
under Schedules 6 and 8, equipped with a visual disconnect that enables the Company to visually
confirm that the Customer’s and Company’s conductors are physically disconnected. This requires the
ability to visually inspect the actual conductors. Circuit breakers and/or switches do not satisfy this
requirement if the conductors are not visible.

Operation of Disconnection Equipment. If, in the reasonable opinion of the Company, the
Seller's operation or maintenance of the Generation Facility or Interconnection Facilities is unsafe or
may otherwise adversely affect the Company's equipment, personnel, or service to its customers, the
Company may physically disconnect the Seller’s Generation Facility or Interconnection Facilities by
operation of the disconnection device or by any other means the Company deems necessary to
adequately disconnect the Seller’s Generation and Interconnection Facilities from the Company’s
system. At such time as the unsafe condition is remedied or other condition adversely affecting the
Company is resolved to the Company’s satisfaction, the interconnection will be restored.

The Company will disconnect the Seller’s Generation and Interconnection Facilities in the event
of any planned or unplanned maintenance or repair of the Company’s system connected to the Seller’s
Generation and Interconnection Facilities. In the event of unplanned maintenance or repairs, no prior
notice will be provided. In the event of planned repairs, the Company will attempt to notify the Seller of
the time and duration of the planned outage.The Company will disconnect the Seller’s Generation
Facility and Interconnection Facilities in the event that any terms and conditions of any applicable
Idaho Power Company SecondThird Revised Sheet No. 72-5
Cancels
I.P.U.C. No. 29, Tariff No. 101 FirstSecond Revised Sheet No. 72-5
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho
Company tariff or contract enabling the interconnection of the Seller’s Generation Facility is deemed by
the Company to be in default or delinquent.

All expenses of disconnection and reconnection incurred by the Company will be billed to the
Seller. Net Metering Customers will only be subject to disconnection and reconnection charges if the
expenses are incurred as the result of a Customer’s Net Metering System and/or a Customer’s failure
to abide by the provisions of Schedule 72.

In the case of Net Metering Systems, disconnection of the service may be necessary. The
disconnection may result in interruption of both energy deliveries from the Seller’s Generation Facility to
the Company as well as interruption of energy deliveries from the Company to the Seller.
Disconnection provisions specific to Customers taking service under Schedule 84 are described further
in Section 2 of this tariff.

Idaho Power Company SecondThird Revised Sheet No. 72-6
Cancels
I.P.U.C. No. 29, Tariff No. 101 FirstSecond Revised Sheet No. 72-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

DISCONNECTION EQUIPMENT (Continued)

The Company will disconnect the Seller’s Generation Facility and Interconnection Facilities in
the event that any terms and conditions of any applicable Company tariff or contract enabling the
interconnection of the Seller’s Generation Facility is deemed by the Company to be in default or
delinquent.

All expenses of disconnection and reconnection incurred by the Company will be billed to the
Seller. Net Metering Customers and Customers with Small On-Site Generation Systems will only be
subject to disconnection and reconnection charges if the expenses are incurred as the result of a
Customer’s Net Metering System or Small On-Site Generation Systems and/or a Customer’s failure to
abide by the provisions of Schedule 72.

In the case of Net Metering Systems or Small On-Site Generation Systems, disconnection of the
service may be necessary. The disconnection may result in interruption of both energy deliveries from
the Seller’s Generation Facility to the Company as well as interruption of energy deliveries from the
Company to the Seller. Disconnection provisions specific to Customers taking service under Schedule
6, Schedule 8, or Schedule 84 are described further in Section 2 of this tariff.

The Company will establish the settings of Protection Equipment to disconnect the Seller’s
Generation Facility and Interconnection Facilities for the protection of the Company’s system and
personnel consistent with good utility practices. If the Seller attempts to modify, adjust or otherwise
interfere with the protection equipment or its settings as established by the Company, such action may
be grounds for the Company's refusal to continue interconnection of the Seller’s Generation and
Interconnection Facilities to the Company’s system.

GENERAL REQUIREMENTS OF INTERCONNECTED PROJECTS

1. The Company will construct, own, operate and maintain all equipment, Upgrades, and
Relocations on the Company’s electrical side of the Interconnection Point.

2. The Company will clearly mark the Metering Equipment and any other Company
equipment associated with the Seller’s Generation Facility and/or Interconnection Facilities designating
the existence of the Seller’s Generation Facility as required by good utility practices.

3. The Seller will be required to submit all specific designs, equipment specifications, and
test results of the Seller-Furnished Facilities to the Company for review. Upon receipt of the design and
equipment specifications, the Company will review the design and equipment specifications for
conformance with applicable electrical and safety codes and standards.

OPERATIONS AND MAINTENANCE OBLIGATIONS AND EXPENSES

The Company will operate and maintain Company furnished Interconnection Facilities as well as
any Seller-Furnished Facilities transferred to the Company.

Idaho Power Company SecondThird Revised Sheet No. 72-6
Cancels
I.P.U.C. No. 29, Tariff No. 101 FirstSecond Revised Sheet No. 72-6
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho
SECTION 2: INTERCONNECTION OF NET METERING GENERATION FACILITIES

The following section is applicable to all Customers taking Net Metering Service under Schedule
84.

APPLICATION PROCESS

Customers requesting Net Metering Service are required to complete the following application
process prior to interconnection:

1. Customers must submit a completed application form and $100 application fee to the
Company. Applications are available on the Company’s website or will be provided to the Customer
upon request.

Idaho Power Company SecondThird Revised Sheet No. 72-7
Cancels
I.P.U.C. No. 29, Tariff No. 101 FirstSecond Revised Sheet No. 72-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 1: GENERAL INTERCONNECTION REQUIREMENTS (Continued)

OPERATIONS AND MAINTENANCE OBLIGATIONS AND EXPENSES

The Company will operate and maintain Company furnished Interconnection Facilities as well as
any Seller-Furnished Facilities transferred to the Company.

SECTION 2: INTERCONNECTION OF NET METERING OR SMALL ON-SITE GENERATION
FACILITIES

The following section is applicable to all Customers taking Net Metering Service under Schedule
84 and Customers taking Small On-Site Generation Service under Schedule 6 or Schedule 8.

APPLICATION PROCESS

Customers requesting Net Metering Service or Small On-Site Generation Service are required
to complete the following application process prior to interconnection:

1. Customers must submit a completed application form and $100 application fee to the
Company. Applications are available on the Company’s website or will be provided to the Customer
upon request.
SECTION 2: INTERCONNECTION OF NET METERING GENERATION FACILITIES (Continued)

APPLICATION PROCESS (Continued)

2. Upon receipt of a completed application and $100 fee, the Company will provide the
Customer with written or electronic mail notification that the application has been received and all
necessary information has been provided.

3. The Company will perform within seven (7) business days the Net Metering Feasibility
Review based on project information provided in the application. The Net Metering Feasibility Review
for Net Metering Systems or Small On-Site Generation Service determines the capability of the
Company’s electrical system to incorporate the proposed Net Metering System or Small On-Site
Generation Service and determines if Upgrades are necessary.

a. If the results of the Net Metering Feasibility Review indicate satisfactory system
capability, the Company will provide the Customer with an official “Approval to Proceed”
notification via written or electronic mail.

b. If the results of the Net Metering Feasibility Review indicate that Upgrades are
necessary to accommodate the proposed project, the Company will notify the Customer through
written or electronic mail of such Upgrades. Funding, construction, installation, and
maintenance of required Upgrades will be subject to the Company’s standard Rule H regarding
New Service Attachments and Distribution Line Installations or Alterations.

4. Following receipt of “Approval to Proceed” the Customer is responsible for completing
the installation of the Net Metering System and fulfilling all applicable federal, state, and local inspection
Idaho Power Company SecondThird Revised Sheet No. 72-7
Cancels
I.P.U.C. No. 29, Tariff No. 101 FirstSecond Revised Sheet No. 72-7
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho
requirements. Upon completion the Customer must provide all forms of documentation outlined in
Section 1-1 above verifying that all federal, state, and local requirements have been met. Customers
must also provide the Company with a completed System Verification Form detailing the specifications
of all installed components of the completed Net Metering System. System Verification Forms can be
found on the Company’s website or will be provided upon request.

5. Once all required documentation has been submitted and the Company has verified that
all applicable federal, state, and local requirements have been met, the Company will complete an on-
site inspection within ten (10) business days. Company on-site inspections will not be performed until
the system has passed all applicable federal, state, and local inspection requirements as described
above. The Company on-site inspection includes the following:

a. Verification that actual installed components correspond to information provided
on the initial application and the System Verification Form
b. Verification that the disconnect is functional and reconnection time complies with
IEEE Standard 1547
c. Verification of the proximity and visibility of the disconnect or a sign indicating the
location of the disconnect
d. Photographic documentation of the installation
e. Posting of appropriate Company signage
Idaho Power Company SecondThird Revised Sheet No. 72-8
Cancels
I.P.U.C. No. 29, Tariff No. 101 FirstSecond Revised Sheet No. 72-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 2: INTERCONNECTION OF NET METERING OR SMALL ON-SITE GENERATION
FACILITIES (Continued)

APPLICATION PROCESS (Continued)

4. Following receipt of “Approval to Proceed” the Customer is responsible for completing
the installation of the Net Metering System or Small On-Site Generation System and fulfilling all
applicable federal, state, and local inspection requirements. Upon completion, the Customer must
provide all forms of documentation outlined in Section 1-1 above verifying that all federal, state, and
local requirements have been met. Customers must also provide the Company with a completed
System Verification Form detailing the specifications of all installed components of the completed Net
Metering System or Small On-Site Generation System. System Verification Forms can be found on the
Company’s website or will be provided upon request.

5. Once all required documentation has been submitted and the Company has verified that
all applicable federal, state, and local requirements have been met, the Company will complete, barring
conditions beyond the Company’s control, an on-site inspection within ten (10) business days.
Company on-site inspections will not be performed until the system has passed all applicable federal,
state, and local inspection requirements as described above. The Company on-site inspection includes
the following:

a. Verification that actual installed components correspond to information provided
on the initial application and the System Verification Form
b. Verification that the disconnect is functional and reconnection time complies with
IEEE Standard 1547
c. Verification of the proximity and visibility of the disconnect or a sign indicating the
location of the disconnect
d. Photographic documentation of the installation
e. Posting of appropriate Company signage
f. Documentation of the meter number and system configuration
g. Evaluation of inverters:

i. Systems utilizing verifiable UL 1741 or IEEE 1547 inverters will not be
subject to additional testing
ii. Systems utilizing all inverters other than UL 1741 or IEEE 1547 will be
subject to third-party testing performed at the Customer’s expense

6. Successful completion of the Company on-site inspection constitutes the conclusion of
the application process. The Company must make a reasonable effort to move the Customer to the
appropriate Net Metering Service or Small On-Site Generation Service rate schedule within five (5)
business days. Under no circumstances will the rate change occur more than fifteen (15) business
days from the date of the successfully completed inspection. Upon completion of this process, the
Customer will receive written or electronic mail confirmation that the application process has been
successfully completed. 7. In the event that a Net Metering System fails inspection, the
system will be locked and a tag providing Company contact information will be placed on the device. A
Company representative will then follow up via telephone with the Customer regarding the reason(s) for
failure, and assist the Customer in steps needed to bring the system into compliance with inspection
Idaho Power Company SecondThird Revised Sheet No. 72-8
Cancels
I.P.U.C. No. 29, Tariff No. 101 FirstSecond Revised Sheet No. 72-8
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho
requirements. Once all issues have been addressed and the Customer indicates that the system has
passed all applicable federal, state, and local requirements, Idaho Power will re-inspect the system.

APPLICATION EXPIRATION

1. Applications that are not completed within one year of the initial Net Metering Feasibility
Review are considered expired. Customers requesting connection or approval of expired applications
are required to resubmit a completed application form and $100 application fee, and are subject to the
full application process described above.

RECERTIFICATION

1. The Company will perform full recertification inspections of all Net Metering Systems
once every three years at no charge to the Customer. The Company will provide the Customer with
written notice at least fourteen (14) calendar days prior to performing a recertification inspection.
Recertification inspections will be performed in the same manner as new Net Metering System
inspections described above. Customers may choose to verify the results of the Company’s inspection
through an independent inspection performed by a certified third-party at the Customer’s expense. The
Company reserves the right to inspect any Net Metering System at any time if conditions are unsafe or
may otherwise adversely affect the Company’s equipment, personnel, or service to its Customers.

Idaho Power Company SecondThird Revised Sheet No. 72-9
Cancels
I.P.U.C. No. 29, Tariff No. 101 FirstSecond Revised Sheet No. 72-9
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 2: INTERCONNECTION OF NET METERING OR SMALL ON-SITE GENERATION
FACILITIES (Continued)

APPLICATION PROCESS (Continued)

7. In the event that a Net Metering System or a Small On-Site Generation System fails
inspection, the system will be locked and a tag providing Company contact information will be placed
on the device. A Company representative will then follow up via telephone with the Customer regarding
the reason(s) for failure, and assist the Customer in steps needed to bring the system into compliance
with inspection requirements. Once all issues have been addressed and the Customer indicates that
the system has passed all applicable federal, state, and local requirements, Idaho Power will re-inspect
the system.

APPLICATION EXPIRATION

1. Applications that are not completed within one year of the initial Net Metering Feasibility
Review are considered expired. Customers requesting connection or approval of expired applications
are required to resubmit a completed application form and $100 application fee, and are subject to the
full application process described above.

RECERTIFICATION

1. The Company will perform full recertification inspections of all Net Metering Systems and
Small On-Site Generation Systems once every three years at no charge to the Customer. The
Company will provide the Customer with written notice at least fourteen (14) calendar days prior to
performing a recertification inspection. Recertification inspections will be performed in the same manner
as new Net Metering System and Small On-Site Generation Systems inspections described above.
Customers may choose to verify the results of the Company’s inspection through an independent
inspection performed by a certified third-party at the Customer’s expense. The Company reserves the
right to inspect any Net Metering System and Small On-Site Generation Systems at any time if
conditions are unsafe or may otherwise adversely affect the Company’s equipment, personnel, or
service to its Customers.

NET METERING SYSTEM EXPANSIONS

1. Any modifications to Net Metering Systems or Small On-Site Generation Systems that
impact the generation capacity of the system or modify the system in any way that may impact the
safety or reliability of the Company’s electrical system are considered system expansions for the
purposes of this tariff.

2. Customers wishing to install system expansions must submit an application form and a
$100 feasibility review and inspection fee, and complete the application process according to the
procedures required for a new installation.

3. Systems that have been expanded in the manner described above without gaining prior Company approval are
considered unauthorized installations subject to the provisions of this schedule described below.UNAUTHORIZED
INSTALLATIONS AND EXPANSIONS
Idaho Power Company SecondThird Revised Sheet No. 72-9
Cancels
I.P.U.C. No. 29, Tariff No. 101 FirstSecond Revised Sheet No. 72-9
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

1. Net Metering Systems that have been interconnected to the Company’s system without
Company approval are considered unauthorized installations that jeopardize the reliability of Idaho
Power’s system and the safety of its employees. This includes, but is not limited to, newly installed
systems and unapproved expansions of approved systems. The process described herein provides the
Company the ability to offer net metering service in an efficient, safe, and reliable manner.

2. Unauthorized installations are subject to immediate Company inspection without notice.

a. If proper disconnection equipment is present, the Company will open and lock the
disconnect. When the system is disconnected, the Company will leave a tag on the system providing
the reason for disconnection and Company contact information. A door hanger or card will also be left
at the front door at the time of disconnection. Within twenty-four (24) hours of the disconnection, the
Customer will be called and written notification will be sent via U.S. Mail. Upon completion of the full
application process the system will be reinstated.

b. If proper disconnection equipment is not present, the Company will evaluate installed
inverters:

i. If the system utilizes UL 1741 or IEEE 1547 inverters, the Company will contact the
Customer either in person or via telephone in addition to written communication regarding the
unauthorized installation. This communication will include the necessary steps to bring the system into
compliance according to the following procedures:

1. Within fifteen (15) days of notification, the Customer must submit a completed net
metering application and $100 fee.

2. Within thirty (30) days of completion of the Net Metering Feasibility Review, the
Customer must complete the remainder of the inspection requirements described above.
Idaho Power Company SecondThird Revised Sheet No. 72-10
Cancels
I.P.U.C. No. 29, Tariff No. 101FirstSecond Revised Sheet No. 72-10
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 2: INTERCONNECTION OF NET METERING OR SMALL ON-SITE GENERATION
FACILITIES (Continued)

UNAUTHORIZED INSTALLATIONS AND EXPANSIONS

1. Net Metering Systems and Small On-Site Generation Systems that have been
interconnected to the Company’s system without Company approval are considered unauthorized
installations that jeopardize the reliability of Idaho Power’s system and the safety of its employees.
This includes, but is not limited to, newly installed systems and unapproved expansions of approved
systems. The process described herein provides the Company the ability to offer nNet mMetering
sService and Small On-Site Generation Systems in an efficient, safe, and reliable manner.

2. Unauthorized installations are subject to immediate Company inspection without notice.

a. If proper disconnection equipment is present, the Company will open and lock
the disconnect. When the system is disconnected, the Company will leave a tag on the system
providing the reason for disconnection and Company contact information. A door hanger or card
will also be left at the front door at the time of disconnection. Within twenty-four (24) hours of the
disconnection, the Customer will be called and written notification will be sent via U.S. Mail.
Upon completion of the full application process the system will be reinstated.

b. If proper disconnection equipment is not present, the Company will evaluate
installed inverters:

i. If the system utilizes UL 1741 or IEEE 1547 inverters, the Company will
contact the Customer either in person or via telephone in addition to written
communication regarding the unauthorized installation. This communication will include
the necessary steps to bring the system into compliance according to the following
procedures:

1. Within fifteen (15) days of notification, the Customer must submit
a completed net metering an application and $100 fee.

2. Within thirty (30) days of completion of the Net Metering Feasibility
Review, the Customer must complete the remainder of the inspection
requirements described above.
UNAUTHORIZED INSTALLATIONS AND EXPANSIONS (Continued)

3. Customers who do not wish to bring their systems into compliance
with this schedule may choose to disable their systems. Customers choosing to
do so must notify the Company of their decision within thirty (30) days of
receiving the initial Company notification regarding the unauthorized installation.

4. Customers that fail to complete the application process within the
allotted timeframe and/or do not disable their systems within thirty (30) days will
be subject to termination of electric service.

Idaho Power Company SecondThird Revised Sheet No. 72-10
Cancels
I.P.U.C. No. 29, Tariff No. 101FirstSecond Revised Sheet No. 72-10
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho
ii. If the system utilizes inverters other than UL 1741 or IEEE 1547, or if the
presence of UL 1741 or IEEE 1547 inverters cannot be verified, the Customer will be
subject to immediate termination of service without notice.

3. Customers subject to termination of service under this Schedule are provided two
options for restoration of service. Under both options Customers are responsible for reconnection costs
per the Company’s standard fees contained in Schedule 66.

a. Customers may choose to permanently disconnect Net Metering Systems from
service. Permanent disconnection must, at a minimum, include the physical removal of
Interconnection Facilities at the associated Generation Interconnection Point or physical
removal of the General Facility itself. Opening a breaker or switch does not constitute
permanent disconnection. Customers choosing to permanently disconnect their Net Metering
System must receive confirmation from a state electrical inspector that the Net Metering System
is no longer operational and interconnected to the Company’s system. The results of this
inspection must be provided to the Company prior to restoration of service.

b. Customers can bring the system into compliance with the provisions of this
schedule by completing the full application process described above.

SECTION 3: INTERCONNECTION OF NON-NET METERING GENERATION FACILITIES

The following section is applicable to all Sellers requesting interconnection of non-utility
generation not taking service under the Company’s net metering tariff Schedule 84.

SPECIFIC PROJECT REQUIREMENTS

1. Generation Facilities Less than 1 MW Nameplate Rating

The following requirements are for Generation Facilities with nameplate ratings of less than 1
MW.

Idaho Power Company SecondThird Revised Sheet No. 72-11
Cancels
I.P.U.C. No. 29, Tariff No. 101FirstSecond Revised Sheet No. 72-11
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 32: INTERCONNECTION OF NON-NET METERING OR SMALL ON-SITE GENERATION
FACILITIES (Continued)

UNAUTHORIZED INSTALLATIONS AND EXPANSIONS (Continued)

4. Customers that fail to complete the application process within the
allotted timeframe and/or do not disable their systems within thirty (30) days will
be subject to termination of electric service.

ii. If the system utilizes inverters other than UL 1741 or IEEE 1547, or if the
presence of UL 1741 or IEEE 1547 inverters cannot be verified, the Customer will be
subject to immediate termination of service without notice.

3. Customers subject to termination of service under this Schedule are provided two
options for restoration of service. Under both options Customers are responsible for reconnection costs
per the Company’s standard fees contained in Schedule 66.

a. Customers may choose to permanently disconnect Net Metering Systems or
Small On-Site Generation Systems from service. Permanent disconnection must, at a
minimum, include the physical removal of Interconnection Facilities at the associated
Generation Interconnection Point or physical removal of the General Facility itself. Opening a
breaker or switch does not constitute permanent disconnection. Customers choosing to
permanently disconnect their Net Metering System or Small On-Site Generation System must
receive confirmation from a state electrical inspector that the Net Metering System or Small On-
Site Generation System is no longer operational and interconnected to the Company’s system.
The results of this inspection must be provided to the Company prior to restoration of service.

b. Customers can bring the system into compliance with the provisions of this
schedule by completing the full application process described above.

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES

The following section is applicable to all Sellers requesting interconnection of non-utility
generation not taking service under the Company’s net metering tariff Schedule 6, Schedule 8, or
Schedule 84.

SPECIFIC PROJECT REQUIREMENTS

1. Generation Facilities Less than 1 MW Nameplate Rating

The following requirements are for Generation Facilities with nameplate ratings of less than 1
MW.
SPECIFIC PROJECT REQUIREMENTS (Continued)

Idaho Power Company SecondThird Revised Sheet No. 72-11
Cancels
I.P.U.C. No. 29, Tariff No. 101FirstSecond Revised Sheet No. 72-11
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho
a. The Company shall procure, install, own and maintain Metering Equipment to
record energy deliveries to the Company. This metering will be separate from any other
metering of the Seller’s load and may be located on either side of the Interconnection Point. All
acquisition, installation, maintenance, inspection and testing costs related to Meter Equipment
installed to measure the Seller’s energy deliveries to the Company shall be borne by the Seller.

b. The Seller is responsible for all costs incurred by the Company for the review,
evaluation and testing of Seller supplied designs and equipment regardless as to the outcome
of the review or test results.

c. The Seller, upon completion of installation and prior to interconnection of the
Generation Facility to the Company’s system, will provide the Company with certification from a
professional engineer licensed in the State of Idaho stating that the Seller’s Generation Facility
and Interconnection Facilities are in compliance with IEEE Standard 1547 and all applicable
electrical and safety codes to enable safe and reliable operation.

d. The Seller will obtain and provide to the Company an annual certification and
testing by a professional engineer licensed in the State of Idaho, certifying the ongoing
compliance with IEEE Standard 1547 and all applicable electrical and safety codes and that the
Seller-Furnished Facilities successfully meet applicable testing requirements and standards. In
the event the Company does not receive and accept the annual certification within thirty (30)
days of the annual anniversary date of the agreement, the project will be disconnected from the
Company’s system until such time as the certification is completed and accepted by the
Company.

e. In addition to the requirements specified in sections a through d, Generation
Facilities that are greater than 100 kW and less than 1 MW total nameplate rating require the
following:

i. If the Company owns the transformer interconnecting the Seller’s
Generation Facility, then the Seller may own and maintain a secondary voltage
disconnection device that can be operated by both the Seller and the Company.

ii. If the Seller owns the transformer interconnecting the Seller’s Generation
Facility, then the Company will own, operate and maintain a primary voltage
disconnection device at the Seller’s expense.

iii. The Company will construct, own, operate and maintain all protective
relays and any associated equipment required to operate the protective relays.

2. Generation Facilities Greater Than 1 MW Nameplate Rating

The Company will own, maintain and operate all Interconnection Facilities and Disconnection
Equipment at the Seller’s expense.
Idaho Power Company SecondThird Revised Sheet No. 72-12
Cancels
I.P.U.C. No. 29, Tariff No. 101FirstSecond Revised Sheet No. 72-12
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

SPECIFIC PROJECT REQUIREMENTS (Continued)

a. The Company shall procure, install, own and maintain Metering Equipment to
record energy deliveries to the Company. This metering will be separate from any other
metering of the Seller’s load and may be located on either side of the Interconnection Point. All
acquisition, installation, maintenance, inspection and testing costs related to Meter Equipment
installed to measure the Seller’s energy deliveries to the Company shall be borne by the Seller.

b. The Seller is responsible for all costs incurred by the Company for the review,
evaluation and testing of Seller supplied designs and equipment regardless as to the outcome
of the review or test results.

c. The Seller, upon completion of installation and prior to interconnection of the
Generation Facility to the Company’s system, will provide the Company with certification from a
professional engineer licensed in the State of Idaho stating that the Seller’s Generation Facility
and Interconnection Facilities are in compliance with IEEE Standard 1547 and all applicable
electrical and safety codes to enable safe and reliable operation.

d. The Seller will obtain and provide to the Company an annual certification and
testing by a professional engineer licensed in the State of Idaho, certifying the ongoing
compliance with IEEE Standard 1547 and all applicable electrical and safety codes and that the
Seller-Furnished Facilities successfully meet applicable testing requirements and standards. In
the event the Company does not receive and accept the annual certification within thirty (30)
days of the annual anniversary date of the agreement, the project will be disconnected from the
Company’s system until such time as the certification is completed and accepted by the
Company.

e. In addition to the requirements specified in sections a through d, Generation
Facilities that are greater than 100 kW and less than 1 MW total nameplate rating require the
following:

i. If the Company owns the transformer interconnecting the Seller’s
Generation Facility, then the Seller may own and maintain a secondary voltage
disconnection device that can be operated by both the Seller and the Company.

ii. If the Seller owns the transformer interconnecting the Seller’s Generation
Facility, then the Company will own, operate and maintain a primary voltage
disconnection device at the Seller’s expense.

iii. The Company will construct, own, operate and maintain all protective
relays and any associated equipment required to operate the protective relays.

2. Generation Facilities Greater Than 1 MW Nameplate Rating

The Company will own, maintain and operate all Interconnection Facilities and Disconnection
Equipment at the Seller’s expense.
Idaho Power Company SecondThird Revised Sheet No. 72-123
Cancels
I.P.U.C. No. 29, Tariff No. 101FirstSecond Revised Sheet No. 72-123
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF GENERATION FACILITIES OTHER THAN NET METERING
AND SMALL ON-SITE GENERATION FACILITIES (Continued)

GENERATOR INTERCONNECTION PROCESS

1. Seller shall pay the actual costs of all required interconnection studies. Any difference
between the deposit (if required) and the actual cost of the study shall be paid by or refunded to Seller,
as appropriate. If, during the course of preparing a study, the Company incurs costs in excess of the
deposit amount, the Company may require that the deposit amount be replenished in an amount equal
to the estimated costs for completion of the study. If a deposit amount sufficient to pay for completion
of the study is not maintained, the Company may suspend work on the study.

2. Unless modified by the provisions of this schedule, the FERC-approved Large Generator
Interconnection Procedures and Small Generator Interconnection Procedures posted on the
Company’s website will apply to the Generator Interconnection Process.

3. The deposit amounts for Generation Facilities up to 30 MW are specified in this
schedule. Deposit amounts for Generation Facilities 30 MW and larger are covered by the FERC-
approved Large Generator Interconnection Procedures posted on the Company’s website.

4. Application. The Seller will submit a completed interconnection application in the form
posted on the Company’s website. The application form includes a general description of the
Generation Facility and its location. The application includes payment of an application fee to be
applied against costs the Company incurs to perform the Feasibility Study described below. The
amount of the application fee is $1,000 for a Generation Facility up to 30 MW.

5. Study Agreements. If the Seller desires to proceed beyond the Application stage, the
Seller will be offered a series of study agreements. The individual study agreements establish the time
to perform the study and the deposit the Seller is to provide prior to commencement of the study. The
deposit amount may be waived if a Seller meets the Company’s credit worthiness standards for
unsecured credit specified in Attachment L to the Company’s OATT. The studies consist of:

a. The Feasibility Study: The Feasibility Study includes a general review of project
impact, e.g. exceeding equipment capabilities and violation of electrical performance
requirements. The Feasibility Study Agreement states that no deposit is required, since the
deposit is covered by the application fee.

b. The System Impact Study: The System Impact Study provides a detailed
assessment of the distribution and/or transmission system adequacy to accommodate the
Generation Facility through the evaluation of equipment capabilities and electrical performance
requirements. This step may not be necessary for some projects depending on the size and
location of the project. The System Impact Study Agreement includes a deposit of $2,000 for a
distribution system impact study or a $10,000 deposit for a transmission system impact study.

Idaho Power Company SecondThird Revised Sheet No. 72-134
Cancels
I.P.U.C. No. 29, Tariff No. 101FirstSecond Revised Sheet No. 72-134
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

GENERATOR INTERCONNECTION PROCESS (Continued)

c. The Facility Study: The Facility Study includes the engineering to determine the
design specifications of the project. The Facility Study Agreement includes a deposit of 5% of
the total project costs that were determined in the System Impact Study Report (“SISR”) or the
Feasibility Study Report if a SISR is not required, capped at $30,000.

At the end of each stage of the three-step study process, the Company will provide the Seller
with an increasingly more refined and detailed report that, among other things, will present a list of
required Interconnection Facilities and a non-binding, good faith estimate of Seller’s cost responsibility
for the Interconnection Facilities. If long-lead time equipment items need to be ordered to meet Seller’s
construction schedule, the Company will request advance funding by the Seller to cover these
equipment costs.

6. Generator Interconnection Agreement. The Generator Interconnection Agreement
(“GIA”), will be offered to Seller following completion of the Facility Study. The GIA will utilize the
Uniform Interconnection Agreement template included in this schedule.

COST OF INTERCONNECTION FACILITIES

All Interconnection Facilities provided under this schedule will be valued at the Company's
Construction Cost and/or the Transfer Cost for vesting purposes as well as for operation and
maintenance payment obligations.

PAYMENT FOR INTERCONNECTION FACILITIES

Unless specifically agreed otherwise by written agreement between the Seller and the
Company, the Seller will pay all costs of interconnecting a Generation Facility to the Company's
system. Costs of interconnection include the costs of furnishing and constructing required
Interconnection Facilities, including Upgrades.

Each request for interconnection will go through the Generator Interconnection Process.
Throughout the Generator Interconnection Process, the Company will periodically bill the Seller for
costs incurred or obligated. Failure to pay an invoice within the time specified in the invoice will result
in suspension of work on the interconnection and if the suspension of work extends beyond thirty (30)
calendar days, the Generation Facility will be removed from the interconnection queue. Seller can end
the Generator Interconnection Process at any time. If Seller decides to end the Generator
Interconnection Process prior to completion, the Company will either refund any monies held for
security that have not been spent or obligated, or issue an invoice to Seller for costs incurred prior to
cancellation.
Idaho Power Company SecondThird Revised Sheet No. 72-145
Cancels
I.P.U.C. No. 29, Tariff No. 101FirstSecond Revised Sheet No. 72-145
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

SECURITY FOR PAYMENT OF INTERCONNECTION COSTS

Sellers will provide adequate security for payment of the costs of the Generator Interconnection
Process. Adequate security for Generation Facilities larger than 30 MW can be provided in accordance
with the Large Generator Interconnection Procedures contained in Attachment M to the Company’s
OATT. Adequate security for Generation Facilities up to 30 MW can be provided in one of the following
ways

1. Sellers that meet the Company’s credit worthiness standards for unsecured credit are
not required to provide additional security. The Company’s minimum credit standards for unsecured
credit are described in Attachment L to the OATT.

2. Sellers that do not meet the credit worthiness standards for unsecured credit will be
notified of the reason for the determination and shall be given the option to provide alternative security
acceptable to Idaho Power. In lieu of providing a cash deposit, Seller may establish an escrow
account, provide a letter of credit or provide guarantee of payment by another person or entity which
meets the credit worthiness standards for unsecured credit. Arrangements for alternative security must
be acceptable to Idaho Power.

TRANSFER OF INTERCONNECTION FACILITIES

Transfer of Interconnection Facilities is available only for Generation Facilities with nameplate
ratings greater than 100 kW.

1. Transfer at First Energy Date. If the Seller desires to transfer and the Company desires
to accept any Seller-Furnished Facilities at the First Energy Date, the following will apply:

a. Prior to the beginning of construction, the Seller shall cause the contractor that is
constructing the Seller-Furnished Facilities to provide the Company with a certificate naming the
Company as an additional insured in the amount of not less than $1,000,000 under the
contractor's general liability policy.

b. The Company will provide the Seller's contractor with construction and material
specifications and will have final approval of the design of the Seller-Furnished Facilities.

c. During construction and upon completion, the Company will inspect the Seller-
Furnished Facilities to be transferred to the Company. The cost of such inspection will be borne
by the Seller.
Idaho Power Company SecondThird Revised Sheet No. 72-156
Cancels
I.P.U.C. No. 29, Tariff No. 101FirstSecond Revised Sheet No. 72-156
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

TRANSFER OF INTERCONNECTION FACILITIES (Continued)

d. If the Seller-Furnished Facilities meet the Company's design, material and
construction specifications, are free from defects in materials and workmanship, and the Seller
has provided the Company with acceptable easements, bills of sale and assurance against
labor or materials liens, the Company will accept ownership effective as of the First Energy
Date. In the bill of sale, the Seller will warrant to the Company that the Seller-Furnished
Facilities are free of any liens or encumbrances and will be free from any defects in materials
and workmanship for a period of one year from the First Energy Date.

2. Subsequent Transfer. If, after the First Energy Date, the Seller desires to transfer and
the Company desires to accept any Seller-Furnished Facilities, the following will apply:

a. The Company will inspect the facilities proposed for sale to determine if they
meet the Company's design, material and construction specifications.

b. The Company will determine the Transfer Cost of such facilities. The Transfer
Cost will be equal to the depreciated Construction Cost the Company would have incurred if it
had originally constructed the facilities plus the cost, if any, of bringing the facilities into
compliance with the Company's design, material and construction specifications. Depreciation
of the facilities proposed for transfer will be determined on the same basis as the Company
depreciates its own facilities in accordance with the appropriate FERC account numbers for the
type and size of line or equipment involved. The time period used for the calculation of the
depreciated transfer cost will extend from the First Energy Date until the agreed upon transfer
date. The Transfer Cost will be paid to the Company in cash at the time of transfer. At the
same time, the Company will pay the Seller in cash an amount equal to the depreciated
Construction Cost.

c. As a condition of the Company's acceptance, the Seller will provide the Company
with acceptable easements, bills of sale and acceptable assurance against labor and material
liens. The bill of sale will include a warranty that the transferred facilities are free of all liens and
encumbrances and will be free from any defects in materials and workmanship for a period of
one year from the date of transfer.

d. Effective as of the date of the transfer, the Company will operate and maintain
the transferred facilities.

VESTED INTEREST

A Seller's eligibility for a Vested Interest refund will exist for 5 years after the date the Company
completes construction of its portion of the Interconnection Facilities.
Idaho Power Company ThirdFourth Revised Sheet No. 72-167
Cancels
I.P.U.C. No. 29, Tariff No. 101SecondThird Revised Sheet No. 72-167
IDAHO Issued by IDAHO POWER COMPANY
Issued – September 2, 2016per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 3, 2016June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

VESTED INTEREST (Continued)

1. The Company will provide a refund payment to each Seller holding a Vested Interest in
Company-owned Interconnection Facilities when an Additional Applicant shares use of those
Interconnection Facilities.

2. The refund payment will be based on the following formula:

Linear Connected Original
Refund = Footage x Load/Peak Generation x Interconnection
Ratio Ratio Cost

a. The Linear Footage Ratio is the length of jointly used Special Facilities divided by
the length of the vested Special Facilities.

b. The Connected Load/Peak Generation Ratio is the Connected Load or Peak
Generation of the Additional Applicant divided by the sum of the Connected Load or Peak
Generation of the Additional Applicant and all other Connected Loads and/or Peak Generation
on the Special Facilities.

c. The Original Interconnection Cost is the sum of the Company's Construction Cost
and any Transfer Costs for the Interconnection Facilities to which the Additional Applicant
intends to connect and share usage.

3. The Additional Applicant will pay the Company the amount of the Vested Interest
refund(s). Additional Applicants making Vested Interest payments are in turn eligible to receive refunds
within the 5 year limit described above.

4. Vested Interest refunds will not exceed 100 percent of the refundable portion of any
party's cash payment to the Company.

5. Vested Interest refund payments may be waived by notifying the Company in writing.

OPERATION AND MAINTENANCE OBLIGATIONS AND EXPENSES

The Company will operate and maintain Company furnished Interconnection Facilities as well as
any Seller-Furnished Facilities transferred to the Company. For all projects not interconnecting as a
Schedule 6, Schedule 8, or Schedule 84 customer, the Seller will pay the Company a monthly
operation and maintenance charge equal to a percentage of the Construction Cost and Transfer Cost
paid by the Seller. The percentage will change annually on the anniversary of the First Energy Date in
accordance with the following tables:

Idaho Power Company ThirdFourth Revised Sheet No. 72-178
Cancels
I.P.U.C. No. 29, Tariff No. 101SecondThird Revised Sheet No. 72-178
IDAHO Issued by IDAHO POWER COMPANY
Issued – September 2, 2016per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 3, 2016June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

OPERATION AND MAINTENANCE OBLIGATIONS AND EXPENSES (Continued)

TABLE 1: MONTHLY OPERATION AND MAINTENANCE CHARGES FOR 138 kV and 161 kV
Year 1 2 3 4 5 6 7 8 9 10 11 12
O&M Charge 0.26% 0.27% 0.28% 0.29% 0.30% 0.32% 0.33% 0.35% 0.36% 0.38% 0.40% 0.41%
Year 13 14 15 16 17 18 19 20 21 22 23 24
O&M Charge 0.43% 0.45% 0.47% 0.49% 0.52% 0.54% 0.56% 0.59% 0.62% 0.64% 0.67% 0.70%
Year 25 26 27 28 29 30 31 32 33 34 35 36+
O&M Charge 0.73% 0.77% 0.80% 0.84% 0.87% 0.91% 0.96% 1.00% 1.04% 1.09% 1.14% 0.40%

TABLE 2: MONTHLY OPERATING AND MAINTENANCE CHARGES BELOW 138 kV
Year 1 2 3 4 5 6 7 8 9 10 11 12
O&M Charge 0.47% 0.49% 0.52% 0.54% 0.56% 0.59% 0.61% 0.64% 0.67% 0.70% 0.73% 0.77%
Year 13 14 15 16 17 18 19 20 21 22 23 24
O&M Charge 0.80% 0.84% 0.87% 0.91% 0.95% 1.00% 1.04% 1.09% 1.14% 1.19% 1.24% 1.30%
Year 25 26 27 28 29 30 31 32 33 34 35 36+
O&M Charge 1.36% 1.42% 1.48% 1.55% 1.62% 1.69% 1.77% 1.85% 1.93% 2.02% 2.11% 0.70%

The monthly operating and maintenance charges in Table 1 and Table 2 will be applied as a
percentage of the applicable original interconnection investment. These monthly operating and
maintenance charges escalate annually and are equivalent to 35-year levelized rates of 0.40% for
Table 1 and 0.70% for Table 2.

Where a Seller's interconnection will utilize Interconnection Facilities provided under a prior
agreement(s) and the combined term(s) of the prior agreement(s) is less than 35 years, the operation
and maintenance charge related to those existing Interconnection Facilities for the Seller's
interconnection will be computed to include the expired term of the prior agreement(s).

Where a Seller’s interconnection will utilize Interconnection Facilities provided under a prior
agreement(s) and the combined term(s) of the prior agreement(s) is greater than 35 years, the
operation and maintenance charge related to those existing Interconnection Facilities for the Seller’s
interconnection will be computed at the applicable levelized rate designated at 36+ years.

The cost upon which an individual Seller's operation and maintenance charge is based will be
reduced by subsequent Vested Interest refunds. Additional Applicants who are Sellers will pay the
monthly operation and maintenance charge on the amount they paid as an Additional Applicant.

Seller-Furnished Facilities not transferred to the Company will be operated and maintained by
the Seller at the Seller's sole risk and expense.
Idaho Power Company SecondThird Revised Sheet No. 72-189
Cancels
I.P.U.C. No. 29, Tariff No. 101FirstSecond Revised Sheet No. 72-189
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)

This Interconnection Agreement (“Agreement”) is effective as of the ____ day of __________,
20___, between ____________________________, hereinafter called “Seller,” and Idaho Power
Company, hereinafter called “Company.”

RECITALS

A. Seller will own or operate a Generation Facility that qualifies for service under Idaho
Power’s Commission-approved Schedule 72 and any successor schedule.

B. The Generation Facility covered by this Agreement is more particularly described in
Attachment 1.

AGREEMENTS

1. Capitalized terms used herein shall have the same meanings as defined in Schedule 72
or in the body of this Agreement.

2. This Agreement and Schedule 72 provide the rates, charges, terms and conditions
under which the Seller’s Generation Facility will interconnect with, and operate in parallel with, the
Company’s transmission/distribution system. Terms defined in Schedule 72 will have the same defined
meaning in this Agreement. If there is any conflict between the terms of this Agreement and Schedule
72, Schedule 72 shall prevail.

3. This Agreement is not an agreement to purchase Seller’s power. Purchase of Seller’s
power and other services that Seller may require will be covered under separate agreements. Nothing
in this Agreement is intended to affect any other agreement between the Company and Seller.

4. Attached to this Agreement and included by reference are the following:

Attachment 1 – Description and Costs of the Generation Facility, Interconnection
Facilities, and Metering Equipment.

Attachment 2 – One-line Diagram Depicting the Generation Facility, Interconnection
Facilities, Metering Equipment and Upgrades.

Attachment 3 – Milestones For Interconnecting the Generation Facility.

Idaho Power Company SecondThird Revised Sheet No. 72-1920
Cancels
I.P.U.C. No. 29, Tariff No. 101FirstSecond Revised Sheet No. 72-1920
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

Attachment 4 – Additional Operating Requirements for the Company’s Transmission
System Needed to Support the Seller’s Generation Facility.

Attachment 5 – Reactive Power.

Attachment 6 – Description of Upgrades required to integrate the Generation Facility and
Best Estimate of Upgrade Costs.

5. Effective Date, Term, Termination and Disconnection.

5.1 Term of Agreement. Unless terminated earlier in accordance with the provisions
of this Agreement, this Agreement shall become effective on the date specified above and
remain effective as long as Seller’s Generation Facility is eligible for service under Schedule 72.

5.2 Termination.

5.2.1 Seller may voluntarily terminate this Agreement upon expiration or
termination of an agreement to sell power to the Company.

5.2.2 After a Default, either Party may terminate this Agreement pursuant to
Section 6.5.

5.2.3 Upon termination or expiration of this Agreement, the Seller’s Generation
Facility will be disconnected from the Company’s transmission/distribution system. The
termination or expiration of this Agreement shall not relieve either Party of its liabilities
and obligations, owed or continuing at the time of the termination. The provisions of this
Section shall survive termination or expiration of this Agreement.
Idaho Power Company SecondThird Revised Sheet No. 72-201
Cancels
I.P.U.C. No. 29, Tariff No. 101FirstSecond Revised Sheet No. 72-201
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

5.3 Temporary Disconnection. Temporary disconnection shall continue only for so
long as reasonably necessary under “Good Utility Practice.” Good Utility Practice means any of
the practices, methods and acts engaged in or approved by a significant portion of the electric
industry during the relevant time period, or any of the practices, methods and acts which, in the
exercise of reasonable judgment in light of the facts known at the time the decision was made,
could have been expected to accomplish the desired result at a reasonable cost consistent with
good business practices, reliability, safety and expedition. Good Utility Practice is not intended
to be limited to the optimum practice, method, or act to the exclusion of all others, but rather to
be acceptable practices, methods, or acts generally accepted in the region. Good Utility
Practice includes compliance with WECC or NERC requirements. Payment of lost revenue
resulting from temporary disconnection shall be governed by the power purchase agreement.

5.3.1 Emergency Conditions. "Emergency Condition" means a condition or
situation: (1) that in the judgment of the Party making the claim is imminently likely to
endanger life or property; or (2) that, in the case of the Company, is imminently likely (as
determined in a non-discriminatory manner) to cause a material adverse effect on the
security of, or damage to the Company’s transmission/distribution system, the
Company’s Interconnection Facilities or the equipment of the Company’s customers; or
(3) that, in the case of the Seller, is imminently likely (as determined in a non-
discriminatory manner) to cause a material adverse effect on the reliability and security
of, or damage to, the Generation Facility or the Seller’s Interconnection Facilities. Under
Emergency Conditions, either the Company or the Seller may immediately suspend
interconnection service and temporarily disconnect the Generation Facility. The
Company shall notify the Seller promptly when it becomes aware of an Emergency
Condition that may reasonably be expected to affect the Seller’s operation of the
Generation Facility. The Seller shall notify the Company promptly when it becomes
aware of an Emergency Condition that may reasonably be expected to affect the
Company’s equipment or service to the Company’s customers. To the extent
information is known, the notification shall describe the Emergency Condition, the extent
of the damage or deficiency, the expected effect on the operation of both Parties'
facilities and operations, its anticipated duration, and the necessary corrective action.

Idaho Power Company SecondThird Revised Sheet No. 72-212
Cancels
I.P.U.C. No. 29, Tariff No. 101FirstSecond Revised Sheet No. 72-212
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

5.3.2 Routine Maintenance, Construction, and Repair. The Company may
interrupt interconnection service or curtail the output of the Seller’s Generation Facility
and temporarily disconnect the Generation Facility from the Company’s
transmission/distribution system when necessary for routine maintenance, construction,
and repairs on the Company’s transmission/distribution system. The Company will
make a reasonable attempt to contact the Seller prior to exercising its rights to interrupt
interconnection or curtail deliveries from the Seller’s Facility. Seller understands that in
the case of emergency circumstances, real time operations of the electrical system,
and/or unplanned events, the Company may not be able to provide notice to the Seller
prior to interruption, curtailment or reduction of electrical energy deliveries to the
Company. The Company shall use reasonable efforts to coordinate such reduction or
temporary disconnection with the Seller.

5.3.3 Scheduled Maintenance. On or before January 31 of each calendar year,
Seller shall submit a written proposed maintenance schedule of significant Facility
maintenance for that calendar year and the Company and Seller shall mutually agree as
to the acceptability of the proposed schedule. The Parties determination as to the
acceptability of the Seller’s timetable for scheduled maintenance will take into
consideration Good Utility Practices, Idaho Power system requirements and the Seller’s
preferred schedule. Neither Party shall unreasonably withhold acceptance of the
proposed maintenance schedule.

5.3.4. Maintenance Coordination. The Seller and the Company shall, to the
extent practical, coordinate their respective transmission/distribution system and
Generation Facility maintenance schedules such that they occur simultaneously. Seller
shall provide and maintain adequate protective equipment sufficient to prevent damage
to the Generation Facility and Seller-furnished Interconnection Facilities. In some cases,
some of Seller’s protective relays will provide back-up protection for Idaho Power’s
facilities. In that event, Idaho Power will test such relays annually and Seller will pay the
actual cost of such annual testing.
Idaho Power Company SecondThird Revised Sheet No. 72-223
Cancels
I.P.U.C. No. 29, Tariff No. 101FirstSecond Revised Sheet No. 72-223
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

5.3.5 Forced Outages. During any forced outage, the Company may suspend
interconnection service to effect immediate repairs on the Company’s
transmission/distribution system. The Company shall use reasonable efforts to provide
the Seller with prior notice. If prior notice is not given, the Company shall, upon request,
provide the Seller written documentation after the fact explaining the circumstances of
the disconnection.

5.3.6 Adverse Operating Effects. The Company shall notify the Seller as soon
as practicable if, based on Good Utility Practice, operation of the Seller’s Generation
Facility may cause disruption or deterioration of service to other customers served from
the same electric system, or if operating the Generation Facility could cause damage to
the Company’s transmission/distribution system or other affected systems. Supporting
documentation used to reach the decision to disconnect shall be provided to the Seller
upon request. If, after notice, the Seller fails to remedy the adverse operating effect
within a reasonable time, the Company may disconnect the Generation Facility. The
Company shall provide the Seller with reasonable notice of such disconnection, unless
the provisions of Article 5.3.1 apply.

5.3.7 Modification of the Generation Facility. The Seller must receive written
authorization from the Company before making any change to the Generation Facility
that may have a material impact on the safety or reliability of the Company’s
transmission/distribution system. Such authorization shall not be unreasonably withheld.
Modifications shall be done in accordance with Good Utility Practice. If the Seller makes
such modification without the Company’s prior written authorization, the latter shall have
the right to temporarily disconnect the Generation Facility.

5.3.8 Reconnection. The Parties shall cooperate with each other to restore the
Generation Facility, Interconnection Facilities, and the Company’s
transmission/distribution system to their normal operating state as soon as reasonably
practicable following a temporary disconnection.
Idaho Power Company SecondThird Revised Sheet No. 72-234
Cancels
I.P.U.C. No. 29, Tariff No. 101FirstSecond Revised Sheet No. 72-234
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

5.3.9 Voltage Levels. Seller, in accordance with Good Utility Practices, shall
minimize voltage fluctuations and maintain voltage levels acceptable to Idaho Power.
Idaho Power may, in accordance with Good Utility Practices, upon one hundred eighty
(180) days' notice to the Seller, change its nominal operating voltage level by more than
ten percent (10%) at the Point of Delivery, in which case Seller shall modify, at Idaho
Power's expense, Seller's equipment as necessary to accommodate the modified
nominal operating voltage level.

5.4 Land Rights.

5.4.1 Seller to Provide Access. Seller hereby grants to Idaho Power for the
term of this Agreement all necessary rights-of-way and easements to install, operate,
maintain, replace, and remove Idaho Power's Metering Equipment, Interconnection
Equipment, Disconnection Equipment, Protection Equipment and other Special Facilities
necessary or useful to this Agreement, including adequate and continuing access rights
on property of Seller. Seller warrants that it has procured sufficient easements and
rights-of-way from third parties so as to provide Idaho Power with the access described
above. All documents granting such easements or rights-of-way shall be subject to
Idaho Power's approval and in recordable form.

5.4.2 Use of Public Rights-of-Way. The Parties agree that it is necessary to
avoid the adverse environmental and operating impacts that would occur as a result of
duplicate electric lines being constructed in close proximity. Therefore, subject to Idaho
Power's compliance with Paragraph 5.4.4, Seller agrees that should Seller seek and
receive from any local, state or federal governmental body the right to erect, construct
and maintain Seller-furnished Interconnection Facilities upon, along and over any and all
public roads, streets and highways, then the use by Seller of such public right-of-way
shall be subordinate to any future use by Idaho Power of such public right-of-way for
construction and/or maintenance of electric distribution and transmission facilities and
Idaho Power may claim use of such public right-of-way for such purposes at any time.
Except as required by Paragraph 5.4.4, Idaho Power shall not be required to
compensate Seller for exercising its rights under this Paragraph 5.4.2.
Idaho Power Company SecondThird Revised Sheet No. 72-245
Cancels
I.P.U.C. No. 29, Tariff No. 101FirstSecond Revised Sheet No. 72-245
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

5.4.3 Joint Use of Facilities. Subject to Idaho Power's compliance with
Paragraph 15.4.4, Idaho Power may use and attach its distribution and/or transmission
facilities to Seller's Interconnection Facilities, may reconstruct Seller's Interconnection
Facilities to accommodate Idaho Power's usage or Idaho Power may construct its own
distribution or transmission facilities along, over and above any public right-of-way
acquired from Seller pursuant to Paragraph 5.4.2, attaching Seller's Interconnection
Facilities to such newly constructed facilities. Except as required by Paragraph 5.4.4,
Idaho Power shall not be required to compensate Seller for exercising its rights under
this Paragraph 5.4.3.

5.4.4 Conditions of Use. It is the intention of the Parties that the Seller be left in
substantially the same condition, both financially and electrically, as Seller existed prior
to Idaho Power's exercising its rights under this Paragraph 5.4. Therefore, the Parties
agree that the exercise by Idaho Power of any of the rights enumerated in Paragraphs
5.4.2 and 5.4.3 shall: (1) comply with all applicable laws, codes and Good Utility
Practices, (2) equitably share the costs of installing, owning and operating jointly used
facilities and rights-of-way. If the Parties are unable to agree on the method of
apportioning these costs, the dispute will be submitted to the Commission for resolution
and the decision of the Commission will be binding on the Parties, and (3) shall provide
Seller with an interconnection to Idaho Power's system of equal capacity and durability
as existed prior to Idaho Power exercising its rights under this Paragraph 5.4.

6. Assignment, Liability, Indemnity, Force majeure, Consequential Damages and Default.

6.1 Assignment. This Agreement may be assigned by either Party upon twenty-one
(21) calendar days prior written notice and opportunity to object by the other Party; provided
that:
6.1.1 Either Party may assign this Agreement without the consent of the other
Party to any affiliate of the assigning Party with an equal or greater credit rating and with
the legal authority and operational ability to satisfy the obligations of the assigning Party
under this Agreement.

Idaho Power Company SecondThird Revised Sheet No. 72-256
Cancels
I.P.U.C. No. 29, Tariff No. 101FirstSecond Revised Sheet No. 72-256
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

6.1.2 The Seller shall have the right to contingently assign this Agreement,
without the consent of the Company, for collateral security purposes to aid in providing
financing for the Generation Facility, provided that the Seller will promptly notify the
Company of any such contingent assignment.

6.1.3 Any attempted assignment that violates this article is void and ineffective.
Assignment shall not relieve a Party of its obligations, nor shall a Party's obligations be
enlarged, in whole or in part, by reason thereof. An assignee is responsible for meeting
the same financial, credit, and insurance obligations as the Seller. Where required,
consent to assignment will not be unreasonably withheld, conditioned or delayed.

6.2 Limitation of Liability. Each Party's liability to the other Party for any loss, cost,
claim, injury, liability, or expense, including reasonable attorney's fees, relating to or arising from
any act or omission in its performance of this Agreement, shall be limited to the amount of direct
damage actually incurred. In no event shall either Party be liable to the other Party for any
indirect, special, consequential, or punitive damages, except as authorized by this Agreement.

6.3 Indemnity.

6.3.1 This provision protects each Party from liability incurred to third parties as
a result of carrying out the provisions of this Agreement. Liability under this provision is
exempt from the general limitations on liability found in Article 6.2.

6.3.2 The Parties shall at all times indemnify, defend, and hold the other Party
harmless from, any and all damages, losses, claims, including claims and actions
relating to injury to or death of any person or damage to property, demand, suits,
recoveries, costs and expenses, court costs, attorney fees, and all other obligations by
or to third parties, arising out of or resulting from the other Party's action or failure to
meet its obligations under this Agreement on behalf of the indemnifying Party, except in
cases of gross negligence or intentional wrongdoing by the indemnified Party.

Idaho Power Company SecondThird Revised Sheet No. 72-267
Cancels
I.P.U.C. No. 29, Tariff No. 101FirstSecond Revised Sheet No. 72-267
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

6.3.3 If an indemnified person is entitled to indemnification under this article as
a result of a claim by a third party, and the indemnifying Party fails, after notice and
reasonable opportunity to proceed under this article, to assume the defense of such
claim, such indemnified person may at the expense of the indemnifying Party contest,
settle or consent to the entry of any judgment with respect to, or pay in full, such claim.
Failure to defend is a Material Breach.

6.3.4 If an indemnifying party is obligated to indemnify and hold any
indemnified person harmless under this article, the amount owing to the indemnified
person shall be the amount of such indemnified person's actual loss, net of any
insurance or other recovery.

6.3.5 Promptly after receipt by an indemnified person of any claim or notice of
the commencement of any action or administrative or legal proceeding or investigation
as to which the indemnity provided for in this article may apply, the indemnified person
shall notify the indemnifying party of such fact. Any failure of or delay in such notification
shall be a Material Breach and shall not affect a Party's indemnification obligation unless
such failure or delay is materially prejudicial to the indemnifying party.

6.4 Force Majeure. As used in this Agreement, “Force Majeure” or “an event of
Force Majeure” means any cause beyond the control of the Seller or of the Company which,
despite the exercise of due diligence, such Party is unable to prevent or overcome. Force
Majeure includes, but is not limited to, acts of God, fire, flood, storms, wars, hostilities, civil
strife, strikes and other labor disturbances, earthquakes, fires, lightning, epidemics, sabotage, or
changes in law or regulation occurring after the Operation Date, which, by the exercise of
reasonable foresight such party could not reasonably have been expected to avoid and by the
exercise of due diligence, it shall be unable to overcome. If either Party is rendered wholly or in
part unable to perform its obligations under this Agreement because of an event of Force
Majeure, both Parties shall be excused from whatever performance is affected by the event of
Force Majeure, provided that:

(1) The non-performing Party shall, as soon as is reasonably possible after
the occurrence of the Force Majeure, give the other Party written notice describing the
particulars of the occurrence.

Idaho Power Company SecondThird Revised Sheet No. 72-278
Cancels
I.P.U.C. No. 29, Tariff No. 101FirstSecond Revised Sheet No. 72-278
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

(2) The suspension of performance shall be of no greater scope and of no
longer duration than is required by the event of Force Majeure.

(3) No obligations of either Party which arose before the occurrence causing
the suspension of performance and which could and should have been fully performed
before such occurrence shall be excused as a result of such occurrence.

6.5 Default and Material Breaches.

6.5.1 Defaults. If either Party fails to perform any of the terms or conditions of
this Agreement (a “Default” or an “Event of Default”), the nondefaulting Party shall cause
notice in writing to be given to the defaulting Party, specifying the manner in which such
default occurred. If the defaulting Party shall fail to cure such Default within the sixty
(60) days after service of such notice, or if the defaulting Party reasonably demonstrates
to the other Party that the Default can be cured within a commercially reasonable time
but not within such sixty (60) day period and then fails to diligently pursue such cure,
then, the nondefaulting Party may, at its option, terminate this Agreement and/or pursue
its legal or equitable remedies.

6.5.2 Material Breaches. The notice and cure provisions in Paragraph 6.6.1 do
not apply to Defaults identified in this Agreement as Material Breaches. Material
Breaches must be cured as expeditiously as possible following occurrence of the
breach.

7. Insurance. During the term of this Agreement, Seller shall secure and continuously carry
the following insurance coverage:

7.1 Comprehensive General Liability Insurance for both bodily injury and property
damage with limits equal to $1,000,000, each occurrence, combined single limit. The deductible
for such insurance shall be consistent with current Insurance Industry Utility practices for similar
property.

7.2 The above insurance coverage shall be placed with an insurance company with
an A.M. Best Company rating of A- or better and shall include:
Idaho Power Company FirstSecond Revised Sheet No. 72-289
Cancels
I.P.U.C. No. 29, Tariff No. 101OriginalFirst Revised Sheet No. 72-289
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

(a) An endorsement naming Idaho Power as an additional insured and loss
payee as applicable; and

(b) A provision stating that such policy shall not be canceled or the limits of
liability reduced without sixty (60) days’ prior written notice to Idaho Power.

7.3 Seller to Provide Certificate of Insurance. As required in Paragraph 7 herein and
annually thereafter, Seller shall furnish the Company a certificate of insurance, together with the
endorsements required therein, evidencing the coverage as set forth above.

7.4 Seller to Notify Idaho Power of Loss of Coverage - If the insurance coverage
required by Paragraph 7.1 shall lapse for any reason, Seller will immediately notify Idaho Power
in writing. The notice will advise Idaho Power of the specific reason for the lapse and the steps
Seller is taking to reinstate the coverage. Failure to provide this notice and to expeditiously
reinstate or replace the coverage will constitute grounds for a temporary disconnection under
Section 5.3 and will be a Material Breach.

8. Miscellaneous.

8.1 Governing Law. The validity, interpretation and enforcement of this Agreement
and each of its provisions shall be governed by the laws of the State of Idaho without regard to
its conflicts of law principles.

8.2 Salvage. No later than sixty (60) days after the termination or expiration of this
Agreement, Idaho Power will prepare and forward to Seller an estimate of the remaining value
of those Idaho Power furnished Interconnection Facilities as required under Schedule 72 and/or
described in this Agreement, less the cost of removal and transfer to Idaho Power's nearest
warehouse, if the Interconnection Facilities will be removed. If Seller elects not to obtain
ownership of the Interconnection Facilities but instead wishes that Idaho Power reimburse the
Seller for said Facilities the Seller may invoice Idaho Power for the net salvage value as
estimated by Idaho Power and Idaho Power shall pay such amount to Seller within thirty (30)
days after receipt of the invoice. Seller shall have the right to offset the invoice amount against
any present or future payments due Idaho Power.
Idaho Power Company FirstSecond Revised Sheet No. 72-2930
Cancels
I.P.U.C. No. 29, Tariff No. 101OriginalFirst Revised Sheet No. 72-2930
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

9. Notices.

9.1 General. Unless otherwise provided in this Agreement, any written notice,
demand, or request required or authorized in connection with this Agreement ("Notice") shall be
deemed properly given if delivered in person, delivered by recognized national currier service,
or sent by first class mail, postage prepaid, to the person specified below:

If to the Seller:
Seller:
Attention:
Address:
City: State: Zip:
Phone: Fax:

If to the Company:
Company
Attention:
Address:
City: State: Zip:
Phone: Fax:

9.2 Billing and Payment. Billings and payments shall be sent to the addresses set
out below:

Seller:
Attention:
Address:
City: State: Zip:
Phone: Fax:

Company:
Attention:
Address:
City: State: Zip:
Phone: Fax:
Idaho Power Company First Revised Sheet No. 72-31
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 72-301
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

AGREEMENTS (Continued)

9.3 Designated Operating Representative. The Parties may also designate
operating representatives to conduct the communications which may be necessary or
convenient for the administration of this Agreement. This person will also serve as the point of
contact with respect to operations and maintenance of the Party’s facilities.

Seller’s Operating Representative:
Seller:
Attention:
Address:
City: State: Zip:
Phone: Fax:

Company’s Operating Representative:
Company:
Attention:
Address:
City: State: Zip:
Phone: Fax:

9.5 Changes to the Notice Information. Either Party may change this information by
giving five Business Days written notice prior to the effective date of the change.

10. Signatures.
IN WITNESS WHEREOF, the Parties have caused this Agreement to be executed by their
respective duly authorized representatives.

For the Company
Name:
Title:
Date:

For the Seller
Name:
Title:
Date:
Idaho Power Company First Revised Sheet No. 72-32
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 72-312
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

Attachment 1

Description and Costs of the Generation Facility, Interconnection Facilities and Metering
Equipment

In this attachment the Generation Facility and Interconnection Facilities, including Special
Facilities and upgrades, are itemized and identified as being owned by the Seller or the Company. As
provided in Schedule 72, Payment For Interconnection Facilities, the Company will provide a best
estimate itemized cost of its Interconnection Facilities, including Special Facilities, upgrades and
Metering Equipment.

Attachment 2

One-line Diagram Depicting the Small Generation Facility, Interconnection Facilities, Metering
Equipment and Upgrades

Idaho Power Company First Revised Sheet No. 73-33
Cancels
I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 72-323
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

Attachment 3

Milestones

In-Service Date: ___________________

Critical milestones and responsibility as agreed to by the Parties:

Milestone/Date Responsible Party

(1) _______________________________________ ______________________
(2) _______________________________________ ______________________
(3) _______________________________________ ______________________
(4) _______________________________________ ______________________
(5) _______________________________________ ______________________
(6) _______________________________________ ______________________
(7) _______________________________________ ______________________
(8) _______________________________________ ______________________
(9) _______________________________________ ______________________
(10) _______________________________________ ______________________

Agreed to by:

For the Company __________________________ Date______________

For the Seller________________________ Date______________

Idaho Power Company

I.P.U.C. No. 29, Tariff No. 101 Original Sheet No. 72-334
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3284634046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – October 1, 2013June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 72
INTERCONNECTIONS TO
NON-UTILITY GENERATION
(Continued)

SECTION 3: INTERCONNECTION OF NON-GENERATION FACILITIES OTHER THAN NET
METERING AND SMALL ON-SITE GENERATION FACILITIES (Continued)

IDAHO POWER COMPANY
UNIFORM INTERCONNECTION
AGREEMENT
(PURPA)
(Continued)

Attachment 4

Additional Operating Requirements for the Company’s Transmission System and Affected
Systems Needed to Support the Seller’s Needs

The Company shall also provide requirements that must be met by the Seller prior to initiating
parallel operation with the Company’s Transmission System.

Attachment 5

Reactive Power Requirements

Idaho Power will determine the reactive power required to be supplied by the Company to the
Seller, based upon information provided by the Seller. The Company will specify the equipment
required on the Company’s system to meet the Facility’s reactive power requirements. These
specifications will include but not be limited to equipment specifications, equipment location, Company-
provided equipment, Seller provided equipment, and all costs associated with the equipment, design
and installation of the Company-provided equipment. The equipment specifications and requirements
will become an integral part of this Agreement. The Company-owned equipment will be maintained by
the Company, with total cost of purchase, installation, operation, and maintenance, including
administrative cost to be reimbursed to the Company by the Seller. Payment of these costs will be in
accordance with Schedule 72 and the total reactive power cost will be included in the calculation of the
Monthly Operation and Maintenance Charges specified in Schedule 72.

Attachment 6

Company’s Description of Upgrades Required to Integrate the Generation Facility and Best
Estimate of Upgrade Costs

As provided in Schedule 72 this Attachment describes Upgrades, including best work upgrades,
and provides an itemized best estimate of the cost of the Upgrades.

Idaho Power Company ThirdFourth Revised Sheet No. 81-2
Cancels
I.P.U.C. No. 29, Tariff No. 101 SecondThird Revised Sheet No. 81-2
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3292334046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2014June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 81
RESIDENTIAL AIR CONDITIONER
CYCLING PROGRAM
(OPTIONAL)
(Continued)

AVAILABILITY

Service under this schedule is available on an optional basis to Customers taking service under
Schedules 1, or Schedule 5, or 6 who have Central Air Conditioning located at their residences and live
within the Program Operation Area. Customers may request to be added to the Program at any time
during the year by providing Notification to the Company.

Service under this schedule may be limited based upon the availability of Program equipment
and/or funding. The Company shall have the right to select and reject Program participants at its sole
discretion based on criteria the Company considers necessary to ensure the effective operation of the
Program. Selection criteria may include, but will not be limited to, energy usage, residential location,
size of home, or other factors. Customers’ Central Air Conditioning equipment must be fully functional
and comply with the National Electric Code (NEC) standards. Customers who are renting or leasing
their home must provide to the Company written proof of the express permission of the owner of the
Central Air Conditioning system prior to acceptance into the program.

TERMS AND CONDITIONS

Upon acceptance into the Program, Customers will be subject to the following terms and
conditions:

1. Each eligible Customer who chooses to take service under this optional schedule is
thereby giving the Company or its representative permission, on reasonable notice, to enter the
Customer’s residence or property to install a Device and, in certain cases, either a mass memory meter
or an end-use meter and to allow Idaho Power or its representative, with prior notice to the Customer,
reasonable access to the Device or other Program-related equipment following its installation.

2. Customers added to the Program during the Air Conditioning Season must be effectively
participating in the Program prior to the 20th day of the month in order to receive an incentive payment
for that month.

3. A Customer may Opt Out of the Program two times during the Air Conditioning Season.

4. A Customer may discontinue participation in the Program without penalty by providing
Notification to the Company.

5. If there is evidence of alteration, tampering, or otherwise interfering with the Company’s
ability to initiate a Cycling Event, the Customer’s participation in the Program will be terminated and the
Customer will be required to reimburse the Company for the cost of replacement or repair of the Device
or other Program equipment and the Company will reverse any amounts credited to the Customer’s
bills during the past twelve months as a result of the Customer’s participation in the Program.

Idaho Power Company ThirdFourth Revised Sheet No. 84-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 SecondThird Revised Sheet No. 84-1
IDAHO Issued by IDAHO POWER COMPANY
Issued – October 19, 2016per Order No. 34046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – November 22, 2016June 1, 2018 1221 West Idaho Street, Boise, Idaho
Advice No. 16-05

SCHEDULE 84
CUSTOMER ENERGY PRODUCTION
NET METERING SERVICE

AVAILABILITY

Service under this schedule is available throughout the Company’s service territory within the
State of Idaho for Customers intending to operate Net Metering Systems to generate electricity to reduce
all or part of their monthly energy usage.

Effective June 1, 2018, Schedule 84 is closed to service for Idaho residential and Idaho small
general service customers.

APPLICABILITY

Service under this schedule is applicable to any Customer that:

1. Does not take service under Schedule 4 or Schedule 5; and

2. Owns and/or operates a Generation Facility fueled by solar, wind, biomass, geothermal,
or hydropower, or represents fuel cell technology; and

3. Maintains its retail electric service account for the loads served at the Point of Delivery
adjacent to the Generation Interconnection Point as active and in good standing; and

4. Meets all requirements applicable to Net Metering Systems detailed in the Company’s
Schedule 72 Interconnections to Non-Utility Generation; and

5. Takes retail electric service under:

a. Schedule 1 or Schedule 7; and

Owns and/or operates a Generation Facility with a total nameplate capacity rating of 25
kilowatts (kW) or smaller that is interconnected to the Customer’s individual electric system on
the Customer’s side of the Point of Delivery, thus all energy received and delivered by the
Company is through the Company’s existing watt-hour retail meter.

b. Schedules other than Schedule 1, Schedule 4, Schedule 5, or Schedule 7; and

Owns and/or operates a Generation Facility with a total nameplate capacity rating of 100
kW or smaller that is interconnected at a Generation Interconnection Point that, at the
Company’s discretion, is located either adjacent to or on the Customer’s side of the Point of
Delivery and is metered through a meter that is separate from the retail load metering at the
Customer’s Point of Delivery. A separate meter from the existing retail load metering at the
Customer’s Point of Delivery is not required if the Customer meets the criteria below. The One
Meter Option is available if:

i. The Generation Facility has a total nameplate capacity rating of 25 kW or
smaller; and

ii. The Generation Facility has a total nameplate capacity rating that is no
more than 2% of the Customer’s Basic Load Capacity (BLC) or comparable average
maximum monthly Billing Demands.
Idaho Power Company SixthSeventh Revised Sheet No. 91-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 FifthSixth Revised Sheet No. 91-1
IDAHO Issued by IDAHO POWER COMPANY
Issued per Order No. 3373634046 Timothy E. Tatum, Vice President, Regulatory Affairs
Effective – April 1, 2017June 1, 2018 1221 West Idaho Street, Boise, Idaho

SCHEDULE 91
ENERGY EFFICIENCY RIDER

APPLICABILITY

This schedule is applicable to all retail Customers served under the Company’s schedules and
special contracts. This Energy Efficiency Rider is designed to fund the Company’s expenditures for the
analysis and implementation of energy conservation and demand response programs.

MONTHLY CHARGE

The Monthly Charge is equal to the applicable Energy Efficiency Rider percentage times the
sum of the monthly billed charges for the base rate components.

Schedule Energy Efficiency Rider

Schedule 1 3.75%
Schedule 3 3.75%
Schedule 4 3.75%
Schedule 5 3.75%
Schedule 6 3.75%
Schedule 7 3.75%
Schedule 8 3.75%
Schedule 9 3.75%
Schedule 15 3.75%
Schedule 19 3.75%
Schedule 24 3.75%
Schedule 39 3.75%
Schedule 40 3.75%
Schedule 41 3.75%
Schedule 42 3.75%
Schedule 26 3.75%
Schedule 29 3.75%
Schedule 30 3.75%
Schedule 32 3.75%

Idaho Power Company ThirdFourth Revised Sheet No. 98-1
Cancels
I.P.U.C. No. 29, Tariff No. 101 SecondThird Revised Sheet No. 98-1
IDAHO Issued by IDAHO POWER COMPANY
Issued – November 5, 2013per Order No. 34046Gregory W. SaidTimothy E. Tatum, Vice President, Regulatory Affairs
Effective – January 1, 2014June 1, 2018 1221 West Idaho Street, Boise, Idaho
Advice No. 13-06

SCHEDULE 98
RESIDENTIAL AND SMALL FARM
ENERGY CREDIT

APPLICABILITY

This schedule is applicable to the Qualifying Electric Energy, as defined below, delivered to
Customers taking service under Schedules 1, 3, 4, 5, 6, 7, 8, 9, 15, or 24.

The Residential and Small Farm Energy Credit (“Credit”) is the result of the Settlement
Agreement between the Company and the Bonneville Power Administration (“BPA”) Contract No.
11PB-12322. The Settlement Agreement provides for the determination of benefits during the period
October 1, 2011, through September 30, 2028. This schedule shall expire when the benefits derived
from the Settlement Agreement have been credited to Customers as provided for under this schedule.

QUALIFYING ELECTRIC ENERGY

RESIDENTIAL

All kilowatt-hours (kWh) of metered energy, delivered during the Billing Period, to
residential Customers taking service under Schedules 1, 3, 4, or 5, or 6 and all kWh of metered
residential electric use delivered to Customers taking service under Schedules 7, 8, 9, or 15, as
defined in the BPA Customer Load Eligibility Guidelines for the Residential Exchange Program
Residential Purchase and Sale Agreements, will be considered Residential Qualifying Electric
Energy under this schedule.

SMALL FARM

All kWh of metered energy, delivered during the Billing Period, to eligible small farm
Customers taking service under Schedule 7, 8, or 9, as defined in the BPA Customer Load
Eligibility Guidelines for the Residential Exchange Program Residential Purchase and Sale
Agreements will be considered Small Farm Qualifying Electric Energy under this schedule.

IRRIGATION

All kWh of metered energy, delivered during the Billing Period, to eligible irrigation
Customers taking service under Schedule 24, as defined in the BPA Customer Load Eligibility
Guidelines for the Residential Exchange Program Residential Purchase and Sale Agreements,
limited to either the irrigation Customer’s actual metered energy or 222,000 kWh, whichever is
less, will be considered Irrigation Qualifying Electric Energy under this schedule. Irrigation
Customers will be identified by Tax Identification Number or Social Security Number for
purposes of determining Irrigation Qualifying Electric Energy under this schedule.