20180518PacifCor Tariff filing OATT Schedules 3_3A_5_6.pdf

Troutman Sanders LLP
401 9th Street, N. W., Suite 1000
Washington, D.C. 20004-2134
troutman.com
Amie V. Colby
[e-mail]
May 18, 2018
VIA E-TARIFF
The Honorable Kimberly D. Bose
Secretary
Federal Energy Regulatory Commission
888 First Street, NE
Washington, DC 20426
Re: PacifiCorp, Docket Nos. ER17-219-___, EL17-27-___
eTariff Compliance Filing for Schedules 3, 3A, 5, and 6
Dear Secretary Bose:
Pursuant to Part 35 of the Federal Energy Regulatory Commission’s (the “Commission”)
Rules of Practice and Procedure,1 and in compliance with the Commission’s order in PacifiCorp,
163 FERC ¶ 61,035 (2018) (“April 2018 Order”), PacifiCorp hereby submits this transmittal letter
and revised tariff sheets for its Open Access Transmission Tariff (“OATT”) Schedules 3, 3A, 5,
and 6. In an order issued on February 2, 2017, the Commission accepted, subject to refund,
PacifiCorp’s proposed revisions to Schedules 3, 3A, 5, and 6, and established hearing and
settlement judge procedures for these Schedules.2
Following settlement judge procedures, the parties to this proceeding reached a
settlement, which was approved by the Commission in the April 2018 Order. However, the April
2018 Order required PacifiCorp to submit a compliance filing to file revised tariff records for
Schedules 3, 3A, 5 and 6.3 PacifiCorp respectfully requests that the Commission accept this
filing as compliant with the April 2018 Order, effective January 1, 2018.
PacifiCorp also notes that the settlement contemplated that the filing of Attachments U
and V, which contain the revised criteria for self-supply of services under Schedules 5 and 6,
would occur on a later date to be agreed to by the settlement parties.4 In accordance with
Section 3.1 of the settlement, the parties have agreed to an effective date of July 1, 2018 for the
1 18 C.F.R. Part 35 (2018).
2 PacifiCorp, 158 FERC ¶ 61,121 (2017) (“February 2017 Order”).
3 April 2018 Order at P 8.
4 PacifiCorp, ER17-219-002, Offer of Settlement, at Section 3.1 (filed Jan. 31, 2018).
The Honorable Kimberly D. Bose
May 18, 2018
Page 2
filing of Attachments U and V, and PacifiCorp is thus simultaneously making a separate filing
with those tariff records and requesting a July 1, 2018 effective date.5
I. BACKGROUND
On October 28, 2016, PacifiCorp filed proposed updates to five OATT Schedules:
Schedule 3, Regulation and Frequency Response Service; Schedule 3A, Generator Regulation
and Frequency Response Service; Schedule 5, Operating Reserve – Spinning Reserve Service;
and Schedule 6, Operating Reserve – Supplemental Reserve Service (together the “Regulation
and Operating Reserve Schedules”); and Schedule 11, Unauthorized Use of Transmission
Service—to which only minor clarifying revisions were proposed (“Initial Filing”).6 The then
effective rates in these schedules were the product of a 2011 “black box” settlement that had
become effective in March 2013 (the “2013 Schedules”).7 PacifiCorp explained that the purpose
of the revisions to the Regulation and Operating Reserve Schedules were to: (1) permit
PacifiCorp to better allocate the costs and benefits of providing reserve service among customer
groups; (2) ensure reliable operation of the PacifiCorp transmission system; and (3) make
certain that PacifiCorp recovered the costs of providing regulation reserve and operating
reserve services. In addition, the proposed revisions for Regulation reserve provided for
differentiated rates to reflect the variability in costs associated with variable energy resources
(“VERs”), resources that are not VERs (“Non-VERs”), and load.
In response to protests and certain errors noted by Utah Municipal Power Agency and
Deseret Generation & Transmission Co-operative, Inc. (“Deseret”), on December 14, 2016,
PacifiCorp filed a response (“Answer”), which also amended PacifiCorp’s complaint.8 In
particular, in its Answer, PacifiCorp removed third-party shares of units at the Hunter power
plant from the facilities that are likely to provide ancillary services, and corrected the amount of
Deseret’s peak load subject to Schedule 3 charges.9 These changes would reduce the rates
from those PacifiCorp first proposed in its Initial Filing, and in an effort to be responsive to these
changes, PacifiCorp proposed in its Answer to file updated ancillary service schedules in a
5 PacifiCorp notes that the effective date for the interim tariff records for Schedules 3, 3A, 5, and 6
is February 1, 2018. PacifiCorp understands that the tariff records with a later-in-time effective date (i.e.,
February 1, 2018) will appear as effective in the eTariff viewer rather than the tariff records filed herewith
with the effective date of January 1, 2018. Because PacifiCorp is making conforming changes to
Schedules 3, 3A, 5, and 6 to show the agreed-to 2017 rates under those schedules, as approved by the
Commission, PacifiCorp is also refiling those tariff records with the concurrent filing of Attachments U and
V and requesting an effective date of July 1, 2018 to bring forward the correct tariff record as the
currently-effective tariff record.
6 PacifiCorp, Docket No. ER17-219-000, Transmittal Letter at 1 (filed Oct. 28, 2016) (“PacifiCorp
Transmittal Letter”).
7 Id.; February 2017 Order at P 2.
8 February 2017 Order at P 38 (finding that PacifiCorp’s December 14, 2016 Answer to be an
amendment to its October 28, 2016 filing).
9 Id.
The Honorable Kimberly D. Bose
May 18, 2018
Page 3

future compliance filing.10 PacifiCorp made that compliance filing on March 3, 2017,11 which the
Commission accepted on June 7, 2017.12
Following the issuance of the Commission’s February 2017 Order, all parties to this
proceeding engaged in settlement discussions before Judge Glazer. The settlement
discussions ultimately resulted in an uncontested settlement, which PacifiCorp filed with the
Commission on January 31, 2018.13 The Commission accepted the parties’ uncontested offer
of settlement in its April 2018 Order.
II. DESCRIPTION OF FILING
In compliance with the Commission April 2018 Order,14 PacifiCorp is submitting revised
tariff sheets for Schedules 3, 3A, 5, and 6 that reflect the rates and self-supply of ancillary
services concepts agreed to by all parties to this proceeding in the uncontested offer of
settlement approved by the Commission.
III. ADDITIONAL INFORMATION
A. Requested Effective Date
Consistent with the April 2018 Order, PacifiCorp respectfully requests an effective date
of January 1, 2018 for the Schedules 3, 3A, 5, and 6 rates.15 PacifiCorp respectfully requests
waiver of the Commission’s prior notice requirements in order to permit this requested effective
date. The Commission has authority to waive the sixty day notice requirement upon a showing
of “good cause.”16

10 Id.; see also PacifiCorp Answer at 54.
11 PacifiCorp, Docket No. ER17-219-001, Ancillary Services Compliance Filing (filed March 3, 2017)
(“1st Compliance Filing”).
12 PacifiCorp, Docket No. ER17-219-001, Delegated Letter Order (June 7, 2017) (accepting 1st
Compliance Filing).
13 PacifiCorp, ER17-219-002, Offer of Settlement (filed Jan. 31, 2018).
14 April 2018 Order at P 8.
15 April 2018 Order at P 3 where the Commission notes, “The Settlement essentially establishes two
sets of black-box rates for ancillary services, over two periods. For Schedules 3 and 3A, the first set of
rates is effective from July 13, 2017 through December 31, 2017, and the second set, beginning January
1, 2018. For Schedules 5 and 6, the first set of rates is effective February 13, 2017, and the second,
beginning January 1, 2018.”
16 See Central Hudson Gas & Electric Corp., 60 FERC ¶ 61,106 at 61,338, order on reh’g, 61 FERC
¶ 61,089 (1992).
The Honorable Kimberly D. Bose
May 18, 2018
Page 4

Good cause exists to waive the prior notice requirements because all parties have
agreed that the rates shall become effective as of that date, and the Commission has already
approved January 1, 2018 as the effective date in its April 2018 Order.
B. Documents Included with this Filing
PacifiCorp is submitting an eTariff XML filing package that consists of the following
materials:
 This Transmittal Letter;
 Revised tariff records, as approved by the Commission in the April 2018 Order, for filing
in eTariff;
 Redline Comparisons of Schedules 3, 3A, 5, and 6; and
 Clean versions of the revised Tariff records, for filing in eLibrary.
IV. CONCLUSION
PacifiCorp respectfully requests that the Commission accept the tariff records contained
herein for filing and permit an effective date of January 1, 2018 for OATT Schedules 3, 3A, 5,
and 6.
Respectfully Submitted,

/s/ Amie V. Colby
Amie V. Colby

Attorney for PacifiCorp

CERTIFICATE OF SERVICE
I hereby certify that on this, the 18th day of May, 2018, I have caused a copy of the
foregoing document to be served via electronic mail on the official service list compiled by the
Office of the Secretary for the above-referenced proceedings.
/s/ Jessica Zahnow
Jessica Zahnow
Senior Compliance Specialist for PacifiCorp
May 18, 2018
Portland, OR
SCHEDULE 3
Regulation and Frequency Response Service
Regulation and Frequency Response Service is necessary to
provide for the continuous balancing of resources (generation and
interchange) with load and for maintaining scheduled Interconnection
frequency at sixty cycles per second (60 Hz). Regulation and
Frequency Response Service is accomplished by committing on-line
generation whose output is raised or lowered (predominantly through
the use of automatic generating control equipment) and by other
non-generation resources capable of providing this service as
necessary to follow the moment-by-moment changes in load. The
obligation to maintain this balance between resources and load lies
with the Transmission Provider (or the BA that performs this function
for the Transmission Provider).
The Transmission Provider must offer this service when the
Transmission Service is used to serve load within its BAA. The
Transmission Customer must purchase this service from the
Transmission Provider, self-supply the service, or make alternative
comparable arrangements to satisfy its Regulation and Frequency
Response Service obligation as further described in applicable
PacifiCorp business practices. The Transmission Provider will take
into account the speed and accuracy of regulation resources in its
determination of Regulation and Frequency Response reserve
requirements, including as it reviews whether a self-supplying
Transmission Customer has made alternative comparable arrangements.
Upon request by the self-supplying Transmission Customer, the
Transmission Provider will share with the Transmission Customer its
reasoning and any related data used to make the determination of
whether the Transmission Customer has made alternative comparable
arrangements.
For purposes of serving load under this schedule, the amount
of and charges for Regulation and Frequency Response Service are
differentiated by load, Variable Energy Resources (VERs), and
resources that are not VERs (Non-VERs). The Transmission Customer
shall pay a total Regulation and Frequency Response Service charge
under this tariff equal to the sum of the charges applicable to the
customer’s load, VERs, and Non-VERs, as set forth below. To the
extent the BA performs this service for the Transmission Provider,
charges to the Transmission Customer are to reflect only a
pass-through of the costs charged to the Transmission Provider by
that BA.
Charge for Regulation and Frequency Response Service:
The load charges below apply to all load served by Network
Integration Transmission Service or by Point-To-Point Transmission
Service. Firm imports do not reduce the load obligation.
The rates below are applied to the Transmission Customer’s
Monthly Network Load for Network Integration Transmission Service
or to the load served by Point-To-Point Transmission Service.
Load
Effective Rates from
July 13, 2017 through
December 31, 2017
Effective Rates
beginning January 1,
2018
1.Yearly Rate $2.25 per kW-Year $2.124 per kW-Year
2.Monthly Rate $0.188 per kW-Month $0.177 per kW-Month
The charges below apply to all generators serving Network Load and
are differentiated by the type of resources (VERs or Non-VERs)
serving that load. The applicable differentiated rate below is
applied to customers by charging the monthly rate times the nameplate
capacity of the generator.
Each year by December 1, the Transmission Customer shall provide to
the Transmission Provider, attestation of the nameplate capacity of
VERs and Non-VERs owned or controlled by the Transmission Customer
and located within the BAA.
VERs - Uncommitted Scheduling
Effective Rates from
July 13, 2017 through
December 31, 2017
Effective Rates
beginning January 1,
2018
1.Yearly Rate $6.984 per kW-Year $6.593 per kW-Year
2.Monthly Rate $0.582 per kW-Month $0.549 per kW-Month
VERs - Committed Scheduling
To qualify for this committed scheduling rate for a month, during
every hour of that month (except as specified below), a VER customer
must utilize and submit into BSAP by 57 minutes prior to the operating
hour (T-57), consistent with PacifiCorp’s EIM Business Practice,
hour-ahead base schedules consistent with PacifiCorp’s VER forecast
vendor’s forecast available as of no more than 72 minutes prior to
the operating hour (T-72) without modification or manual override of
the hour-ahead forecast, fifteen-minute schedule, and five-minute
schedule. In any calendar month for up to two operating hour
intervals, a VER customer may utilize and submit into BSAP by T-57,
hour-ahead schedules consistent with PacifiCorp’s VER forecast
vendor’s forecast available as of up to 90 minutes prior to the
operating hour (T-90), without modification or manual override of the
hour-ahead forecast, fifteen-minute schedule, and five-minute
schedule, and still be eligible for this rate. Use and submission
into BSAP of hour-ahead schedules older than PacifiCorp’s VER
forecast vendor’s forecast at T-90 in any hour during a calendar month
will make a VER customer ineligible for this rate in that month.
Effective Rates from
July 13, 2017 through
December 31, 2017
Effective Rates
beginning January 1,
2018
1.Yearly Rate $5.965 per kW-Year $5.631 per kW-Year
2.Monthly Rate $0.497 per kW-Month $0.469 per kW-Month
Non-VERs
Effective Rates from
July 13, 2017 through
December 31, 2017
Effective Rates
beginning January 1,
2018
1.Yearly Rate $1.90 per kW-Year $1.794 per kW-Year
2.Monthly Rate $0.158 per kW-Month $0.150 per kW-Month
Self-Supply:
A Network Customer may choose to self-supply its Regulation and
Frequency Response Service obligation consistent with the
requirements herein and PacifiCorp’s business practices and
consistent with the settlement in Docket Nos. ER17-219 and EL17-27.
The total charge for failure to self-supply shall not exceed
the Monthly Rate pursuant to this Schedule 3 times the highest amount
in megawatts not covered under self-supply.
SCHEDULE 3
Regulation and Frequency Response Service
Regulation and Frequency Response Service is necessary to
provide for the continuous balancing of resources (generation and
interchange) with load and for maintaining scheduled
Interconnection frequency at sixty cycles per second (60 Hz).
Regulation and Frequency Response Service is accomplished by
committing on-line generation whose output is raised or lowered
(predominantly through the use of automatic generating control
equipment) and by other non-generation resources capable of
providing this service as necessary to follow the
moment-by-moment changes in load. The obligation to maintain
this balance between resources and load lies with the
Transmission Provider (or the BA that performs this function for
the Transmission Provider).
The Transmission Provider must offer this service when the
Transmission Service is used to serve load within its BAA. The
Transmission Customer must purchase this service from the
Transmission Provider, self-supply the service, or make
alternative comparable arrangements to satisfy its Regulation and
Frequency Response Service obligation as further described in
applicable PacifiCorp business practices. The Transmission
Provider will take into account the speed and accuracy of
regulation resources in its determination of Regulation and
Frequency Response reserve requirements, including as it reviews
whether a self-supplying Transmission Customer has made
alternative comparable arrangements. Upon request by the
self-supplying Transmission Customer, the Transmission Provider
will share with the Transmission Customer its reasoning and any
related data used to make the determination of whether the
Transmission Customer has made alternative comparable
arrangements.
For purposes of serving load under this schedule, the amount
of and charges for Regulation and Frequency Response Service are
differentiated by load, Variable Energy Resources (VERs), and
resources that are not VERs (Non-VERs). The Transmission
Customer shall pay a total Regulation and Frequency Response
Service charge under this tariff equal to the sum of the charges
applicable to the customer’s load, VERs, and Non-VERs, as set
forth below. To the extent the BA performs this service for the
Transmission Provider, charges to the Transmission Customer are
to reflect only a pass-through of the costs charged to the
Transmission Provider by that BA.
Charge for Regulation and Frequency Response Service:
The load charges below apply to all load served by Network
Integration Transmission Service or by Point-To-Point
Transmission Service. Firm imports do not reduce the load
obligation.
The rates below are applied to the Transmission Customer’s
Monthly Network Load for Network Integration Transmission Service
or to the load served by Point-To-Point Transmission Service.
Load
1.Yearly Rate $2.124 per kW-Year
2.Monthly Rate $0.177 per kW-Month
Effective Rates
from July 13, 2017
through December
31, 2017
Effective Rates
beginning January 1,
2018
1. Yearly Rate $2.25 per kW-Year $2.124 per kW-Year
2. Monthly Rate $0.188 per kW-Month $0.177 per kW-Month
The charges below apply to all generators serving Network Load
and are differentiated by the type of resources (VERs or
Non-VERs) serving that load. The applicable differentiated rate
below is applied to customers by charging the monthly rate times
the nameplate capacity of the generator.
Each year by December 1, the Transmission Customer shall provide
to the Transmission Provider, attestation of the nameplate
capacity of VERs and Non-VERs owned or controlled by the
Transmission Customer and located within the BAA.
VERs - Uncommitted Scheduling
1.Yearly Rate $6.593 per kW-Year
2.Monthly Rate $0.549 per kW-Month
Effective Rates
from July 13, 2017
through December
31, 2017
Effective Rates
beginning January 1,
2018
1. Yearly Rate $6.984 per kW-Year $6.593 per kW-Year
2. Monthly Rate $0.582 per kW-Month $0.549 per kW-Month
VERs - Committed Scheduling
To qualify for this committed scheduling rate for a month,
during every hour of that month (except as specified below), a
VER customer must utilize and submit into BSAP by 57 minutes
prior to the operating hour (T-57), consistent with PacifiCorp’s
EIM Business Practice, hour-ahead base schedules consistent with
PacifiCorp’s VER forecast vendor’s forecast available as of no
more than 72 minutes prior to the operating hour (T-72) without
modification or manual override of the hour-ahead forecast,
fifteen-minute schedule, and five-minute schedule. In any
calendar month for up to two operating hour intervals, a VER
customer may utilize and submit into BSAP by T-57, hour-ahead
schedules consistent with PacifiCorp’s VER forecast vendor’s
forecast available as of up to 90 minutes prior to the operating
hour (T-90), without modification or manual override of the
hour-ahead forecast, fifteen-minute schedule, and five-minute
schedule, and still be eligible for this rate. Use and
submission into BSAP of hour-ahead schedules older than
PacifiCorp’s VER forecast vendor’s forecast at T-90 in any hour
during a calendar month will make a VER customer ineligible for
this rate in that month.
1.Yearly Rate $5.631 per kW-Year
2.Monthly Rate $0.469 per kW-Month
Effective Rates
from July 13, 2017
through December
31, 2017
Effective Rates
beginning January 1,
2018
1. Yearly Rate $5.965 per kW-Year $5.631 per kW-Year
2. Monthly Rate $0.497 per kW-Month $0.469 per kW-Month
Non-VERs
1.Yearly Rate $1.794 per kW-Year
2.Monthly Rate $0.150 per kW-Month
Effective Rates
from July 13, 2017
through December
31, 2017
Effective Rates
beginning January 1,
2018
1. Yearly Rate $1.90 per kW-Year $1.794 per kW-Year
2. Monthly Rate $0.158 per kW-Month $0.150 per kW-Month
Self-Supply:
A Network Customer may choose to self-supply its Regulation
and Frequency Response Service obligation consistent with the
requirements herein and PacifiCorp’s business practices.and
consistent with the settlement in Docket Nos. ER17-219 and
EL17-27.
The total charge for failure to self-supply shall not exceed
the Monthly Rate pursuant to this Schedule 3A times the highest
amount in megawatts not covered under self-supply.
SCHEDULE 3A
Generator Regulation and Frequency Response Service
Generator Regulation and Frequency Response Service is
necessary to provide for the continuous balancing of resources
(generation and interchange) with load and for maintaining scheduled
Interconnection frequency at sixty cycles per second (60 Hz).
Generator Regulation and Frequency Response Service is accomplished
by committing on-line generation whose output is raised or lowered
(predominantly through the use of automatic generating control
equipment) as necessary to follow the moment-by-moment changes for
a generator located within the BAA. The obligation to maintain this
balance between resources and the generator’s schedule lies with the
Transmission Provider (or the BAA that performs this function for
the Transmission Provider).
The Transmission Provider must offer this service when
transmission service is provided for a generator physically or
electrically located in the Transmission Provider’s BAA. Generator
Regulation and Frequency Response Service applies to the extent that
a Transmission Customer is not already subject to Regulation and
Frequency Response Service provided under Schedule 3. When
applicable, the Transmission Customer must purchase Generator
Regulation and Frequency Response Service from the Transmission
Provider, self-supply the service, or make alternative comparable
arrangements, as further described in applicable PacifiCorp business
practices which may include self-supplying regulation reserve
capacity from generation or non-generation resources or through
dynamically scheduling its generation to another BAA. The
Transmission Provider will take into account the speed and accuracy
of regulation resources in its determination of Generator Regulation
and Frequency Response reserve requirements, including as it reviews
whether a self-supplying Transmission Customer has made alternative
comparable arrangements. Upon request by the self-supplying
Transmission Customer, the Transmission Provider will share with the
Transmission Customer its reasoning and any related data used to make
the determination of whether the Transmission Customer has made
alternative comparable arrangements.
For purposes of exports or Third-Party Sales, the amount of and
charges for Generator Regulation and Frequency Response Service are
differentiated by the type of exporting resource (Variable Energy
Resources (VERs) or resources that are not VERs (Non-VERs)) and are
set forth below. To the extent a BA performs this service for the
Transmission Provider, charges to the Transmission Customer are to
reflect only a pass-through of the costs charged to the Transmission
Provider by that BA. The Transmission Provider may not charge a
Transmission Customer for regulation reserves under both Schedule
3 and Schedule 3A for the same transaction.
Charge for Generator Regulation and Frequency Response Service:
The charges below apply to generation that originates in the
PacifiCorp BAA and terminates in another BAA or for any resource not
designated as a Network Resource. The applicable differentiated rate
below is applied to customers by charging the monthly rate times the
nameplate capacity of the generator.
Each year by December 1, the Transmission Customer shall provide
to the Transmission Provider, attestation of the nameplate capacity
of VERs and Non-VERs owned or controlled by the Transmission Customer
and located within the BAA.
VERs - Uncommitted Scheduling
Effective Rates from
July 13, 2017 through
December 31, 2017
Effective Rates
beginning January 1,
2018
1.Yearly Rate $6.984 per kW-Year $6.593 per kW-Year
2.Monthly Rate $0.582 per kW-Month $0.549 per kW-Month
VERs - Committed Scheduling
To qualify for this committed scheduling rate for a month, during
every hour of that month (except as specified below), a VER customer
must utilize and submit into BSAP by 57 minutes prior to the operating
hour (T-57), consistent with PacifiCorp’s EIM Business Practice,
hour-ahead base schedules consistent with PacifiCorp’s VER forecast
vendor’s forecast available as of no more than 72 minutes prior to
the operating hour (T-72) without modification or manual override of
the hour-ahead forecast, fifteen-minute schedule, and five-minute
schedule. In any calendar month for up to two operating hour
intervals, a VER customer may utilize and submit into BSAP by T-57,
hour-ahead schedules consistent with PacifiCorp’s VER forecast
vendor’s forecast available as of up to 90 minutes prior to the
operating hour (T-90), without modification or manual override of the
hour-ahead forecast, fifteen-minute schedule, and five-minute
schedule, and still be eligible for this rate. Use and submission
into BSAP of hour-ahead schedules older than PacifiCorp’s VER
forecast vendor’s forecast at T-90 in any hour during a calendar month
will make a VER customer ineligible for this rate in that month.
Effective Rates from
July 13, 2017 through
December 31, 2017
Effective Rates
beginning January 1,
2018
1.Yearly Rate $5.965 per kW-Year $5.631 per kW-Year
2.Monthly Rate $0.497 per kW-Month $0.469 per kW-Month
Non-VERs
Effective Rates from
July 13, 2017 through
December 31, 2017
Effective Rates
beginning January 1,
2018
1.Yearly Rate $1.90 per kW-Year $1.794 per kW-Year
2.Monthly Rate $0.158 per kW-Month $0.150 per kW-Month
Self-Supply:
A Network Transmission Customer may choose to self-supply its
Generator Regulation and Frequency Response Service obligation
consistent with the requirements herein and PacifiCorp’s business
practices and consistent with the settlement in Docket Nos. ER17-219
and EL17-27.
The total charge for failure to self-supply shall not exceed
the Monthly Rate pursuant to this Schedule 3A times the highest amount
in megawatts not covered under self-supply.
SCHEDULE 3A
Generator Regulation and Frequency Response Service
Generator Regulation and Frequency Response Service is
necessary to provide for the continuous balancing of resources
(generation and interchange) with load and for maintaining
scheduled Interconnection frequency at sixty cycles per second
(60 Hz). Generator Regulation and Frequency Response Service is
accomplished by committing on-line generation whose output is
raised or lowered (predominantly through the use of automatic
generating control equipment) as necessary to follow the
moment-by-moment changes for a generator located within the BAA.
The obligation to maintain this balance between resources and the
generator’s schedule lies with the Transmission Provider (or the
BAA that performs this function for the Transmission Provider).
The Transmission Provider must offer this service when
transmission service is provided for a generator physically or
electrically located in the Transmission Provider’s BAA.
Generator Regulation and Frequency Response Service applies to
the extent that a Transmission Customer is not already subject to
Regulation and Frequency Response Service provided under Schedule
3. When applicable, the Transmission Customer must purchase
Generator Regulation and Frequency Response Service from the
Transmission Provider, self-supply the service, or make
alternative comparable arrangements, as further described in
applicable PacifiCorp business practices which may include
self-supplying regulation reserve capacity from generation or
non-generation resources or through dynamically scheduling its
generation to another BAA. The Transmission Provider will take
into account the speed and accuracy of regulation resources in
its determination of Generator Regulation and Frequency Response
reserve requirements, including as it reviews whether a
self-supplying Transmission Customer has made alternative
comparable arrangements. Upon request by the self-supplying
Transmission Customer, the Transmission Provider will share with
the Transmission Customer its reasoning and any related data used
to make the determination of whether the Transmission Customer
has made alternative comparable arrangements.
For purposes of exports or Third-Party Sales, the amount of
and charges for Generator Regulation and Frequency Response
Service are differentiated by the type of exporting resource
(Variable Energy Resources (VERs) or resources that are not VERs
(Non-VERs)) and are set forth below. To the extent a BA performs
this service for the Transmission Provider, charges to the
Transmission Customer are to reflect only a pass-through of the
costs charged to the Transmission Provider by that BA. The
Transmission Provider may not charge a Transmission Customer for
regulation reserves under both Schedule 3 and Schedule 3A for the
same transaction.
Charge for Generator Regulation and Frequency Response
Service:
The charges below apply to generation that originates in the
PacifiCorp BAA and terminates in another BAA or for any resource
not designated as a Network Resource. The applicable
differentiated rate below is applied to customers by charging the
monthly rate times the nameplate capacity of the generator.
Each year by December 1, the Transmission Customer shall
provide to the Transmission Provider, attestation of the
nameplate capacity of VERs and Non-VERs owned or controlled by
the Transmission Customer and located within the BAA.
VERs - Uncommitted Scheduling
1.Yearly Rate $6.593 per kW-Year
2.Monthly Rate $0.549 per kW-Month
Effective Rates
from July 13, 2017
through December
31, 2017
Effective Rates
beginning January 1,
2018
1. Yearly Rate $6.984 per kW-Year $6.593 per kW-Year
2. Monthly Rate $0.582 per kW-Month $0.549 per kW-Month
VERs - Committed Scheduling
To qualify for this committed scheduling rate for a month,
during every hour of that month (except as specified below), a
VER customer must utilize and submit into BSAP by 57 minutes
prior to the operating hour (T-57), consistent with PacifiCorp’s
EIM Business Practice, hour-ahead base schedules consistent with
PacifiCorp’s VER forecast vendor’s forecast available as of no
more than 72 minutes prior to the operating hour (T-72) without
modification or manual override of the hour-ahead forecast,
fifteen-minute schedule, and five-minute schedule. In any
calendar month for up to two operating hour intervals, a VER
customer may utilize and submit into BSAP by T-57, hour-ahead
schedules consistent with PacifiCorp’s VER forecast vendor’s
forecast available as of up to 90 minutes prior to the operating
hour (T-90), without modification or manual override of the
hour-ahead forecast, fifteen-minute schedule, and five-minute
schedule, and still be eligible for this rate. Use and
submission into BSAP of hour-ahead schedules older than
PacifiCorp’s VER forecast vendor’s forecast at T-90 in any hour
during a calendar month will make a VER customer ineligible for
this rate in that month.
1.Yearly Rate $5.631 per kW-Year
2.Monthly Rate $0.469 per kW-Month
Effective Rates
from July 13, 2017
through December
31, 2017
Effective Rates
beginning January 1,
2018
1. Yearly Rate $5.965 per kW-Year $5.631 per kW-Year
2. Monthly Rate $0.497 per kW-Month $0.469 per kW-Month
Non-VERs
1.Yearly Rate $1.794 per kW-Year
2.Monthly Rate $0.150 per kW-Month
Effective Rates
from July 13, 2017
through December
31, 2017
Effective Rates
beginning January 1,
2018
1. Yearly Rate $1.90 per kW-Year $1.794 per kW-Year
2. Monthly Rate $0.158 per kW-Month $0.150 per kW-Month
Self-Supply:
A Network Transmission Customer may choose to self-supply
its Generator Regulation and Frequency Response Service
obligation consistent with the requirements herein and
PacifiCorp’s business practices. and consistent with the
settlement in Docket Nos. ER17-219 and EL17-27.
The total charge for failure to self-supply shall not exceed
the Monthly Rate pursuant to this Schedule 3A times the highest
amount in megawatts not covered under self-supply.
SCHEDULE 5
Operating Reserve - Spinning Reserve Service
Spinning Reserve Service is needed to serve load in the BAA and
to support other transmission usage sourced from generation in the
BAA including exports and sales. Spinning Reserve Service may be
provided by generating units that are on-line and loaded at less than
maximum output and by non-generation resources capable of providing
this service. The Transmission Provider must offer this service
when the transmission service is used to serve load within its BAA
and to support other transmission usage sourced from generation in
the BAA including exports and sales. The Transmission Customer must
purchase this service from the Transmission Provider, self-supply
the service, or make alternative comparable arrangements to satisfy
its Spinning Reserve Service obligation. The amount of and charges
for Spinning Reserve Service are set forth below. To the extent the
BA performs this service for the Transmission Provider, charges to
the Transmission Customer are to reflect only a pass-through of the
costs charged to the Transmission Provider by that BA.
Charges for Spinning Reserve Service:
Under the current NERC Regional Reliability Standard BAL-002-WECC,
the Transmission Provider is required to maintain a minimum amount
of contingency reserve equal to the sum of three percent of hourly
integrated load plus three percent of hourly integrated generation
with at least half as spinning. Consistent with the Transmission
Provider operating in accordance with this reliability standard, the
charges for Schedule 5 below apply one and one-half percent to load
and one and one-half percent to generation.
For load, the rates below are charged to a Network Customer’s hourly
integrated load (including losses).
For generation, the rates below are applied to customers by charging
actual hourly generation delivered to the Transmission Provider at
the Point of Receipt.
The rate shall be an Hourly Rate of:
Effective rates
February 13, 2017
through December 31,
2017
Effective rates
beginning January 1,
2018
Schedule 5 (Spinning
Reserves)
$0.16 per MWh $0.151 per MWh
Self-Supply:
A Transmission Customer may choose to self-supply all or a portion
of its reserve obligation.
The total reserve obligation for a Transmission Customer who
self-supplies is determined by the currently-effective version of
the NERC Regional Reliability Standard BAL-002-WECC. The
requirement is currently equal to the sum of one and one-half percent
of hourly integrated load plus one and one-half percent of hourly
integrated generation. For a Transmission Customer choosing to
self-supply a portion of its reserve obligation, the billing
determinants for supplemental purchases of Schedule 5 reserve
service shall be determined by: (1) identifying the difference
between the amount self-supplied during each hour each month and the
Transmission Customer’s full requirement, as determined by NERC
Regional Reliability Standard BAL-002-WECC; (2) charging the
Transmission Customer the Hourly Rate multiplied by the amount of
megawatts identified in (1) where the Transmission Customer failed
to supply its full requirement for each hour, if any failure occurred.
The Transmission Customer shall schedule that portion which it will
self-supply and/or supply from third parties pursuant to procedures
set forth in the business practices of the Transmission Provider.
During any period that a Transmission Customer has scheduled
self-supply and/or supply from third parties but fails to provide
the full amount scheduled due to partial or full forced outage of
the generation source or a transmission curtailment or interruption,
the Transmission Customer shall purchase the shortfall at the Hourly
Rate, as described in the proceeding section.
Spinning Reserve Service to be Provided:
The Transmission Provider, using its generators controlled by
automatic generation control, will provide the capacity required to
provide Spinning Reserve Service for a Transmission Customer. Upon
an outage of a generation resource for which Spinning Reserve Service
has been purchased from the Transmission Provider, the Transmission
Provider will provide replacement capacity commencing immediately
upon such outage until the earlier of (1) the restoration of such
resource to service by the Transmission Customer or (2) the end of
ten (10) full minutes after the occurrence of such outage.
To the extent that the Transmission Provider determines that a
Transmission Customer’s specific Spinning Reserve Requirements are
not being fully met through the purchase of Spinning Reserve Service
as provided above, the Transmission Provider reserves the right (upon
filing with the Commission) to require such Transmission Customer
to purchase a greater amount of Spinning Reserve Service.
SCHEDULE 5
Operating Reserve - Spinning Reserve Service
Spinning Reserve Service is needed to serve load in the BAA
and to support other transmission usage sourced from generation
in the BAA including exports and sales. Spinning Reserve Service
may be provided by generating units that are on-line and loaded
at less than maximum output and by non-generation resources
capable of providing this service. The Transmission Provider
must offer this service when the transmission service is used to
serve load within its BAA and to support other transmission usage
sourced from generation in the BAA including exports and sales.
The Transmission Customer must purchase this service from the
Transmission Provider, self-supply the service, or make
alternative comparable arrangements to satisfy its Spinning
Reserve Service obligation. The amount of and charges for
Spinning Reserve Service are set forth below. To the extent the
BA performs this service for the Transmission Provider, charges
to the Transmission Customer are to reflect only a pass-through
of the costs charged to the Transmission Provider by that BA.
Charges for Spinning Reserve Service:
Under the current NERC Regional Reliability Standard
BAL-002-WECC, the Transmission Provider is required to maintain a
minimum amount of contingency reserve equal to the sum of three
percent of hourly integrated load plus three percent of hourly
integrated generation with at least half as spinning. Consistent
with the Transmission Provider operating in accordance with this
reliability standard, the charges for Schedule 5 below apply one
and one-half percent to load and one and one-half percent to
generation.
For load, the rates below are charged to a Network Customer’s
hourly integrated load (including losses).
For generation, the rates below are applied to customers by
charging actual hourly generation delivered to the Transmission
Provider at the Point of Receipt.
The rate shall be an Hourly Rate of:
Effective rates
February 13, 2017
through December
31, 2017
Effective rates
beginning January 1,
2018
Schedule 5
(Spinning Reserves)
$0.16 per MWh $0.151 per MWh
Self-Supply:
A Transmission Customer may choose to self-supply all or a
portion of its reserve obligation.
The total reserve obligation for a Transmission Customer who
self-supplies is determined by the currently-effective version of
the NERC Regional Reliability Standard BAL-002-WECC. The
requirement is currently equal to the sum of one and one-half
percent of hourly integrated load plus one and one-half percent
of hourly integrated generation. For a Transmission Customer
choosing to self-supply a portion of its reserve obligation, the
billing determinants for supplemental purchases of Schedule 5
reserve service shall be determined by: (1) identifying the
difference between the amount self-supplied during each hour each
month and the Transmission Customer’s full requirement, as
determined by NERC Regional Reliability Standard BAL-002-WECC;
(2) charging the Transmission Customer the Hourly Rate multiplied
by the amount of megawatts identified in (1) where the
Transmission Customer failed to supply its full requirement for
each hour, if any failure occurred.
The Transmission Customer shall schedule that portion which it
will self-supply and/or supply from third parties pursuant to
procedures set forth in the business practices of the
Transmission Provider. During any period that a Transmission
Customer has scheduled self-supply and/or supply from third
parties but fails to provide the full amount scheduled due to
partial or full forced outage of the generation source or a
transmission curtailment or interruption, the Transmission
Customer shall purchase the shortfall at the Hourly Rate, as
described in the proceeding section.
Spinning Reserve Service to be Provided:
The Transmission Provider, using its generators controlled by
automatic generation control, will provide the capacity required
to provide Spinning Reserve Service for a Transmission Customer.
Upon an outage of a generation resource for which Spinning
Reserve Service has been purchased from the Transmission
Provider, the Transmission Provider will provide replacement
capacity commencing immediately upon such outage until the
earlier of (1) the restoration of such resource to service by the
Transmission Customer or (2) the end of ten (10) full minutes
after the occurrence of such outage.
To the extent that the Transmission Provider determines that a
Transmission Customer’s specific Spinning Reserve Requirements
are not being fully met through the purchase of Spinning Reserve
Service as provided above, the Transmission Provider reserves the
right (upon filing with the Commission) to require such
Transmission Customer to purchase a greater amount of Spinning
Reserve Service.
SCHEDULE 6
Operating Reserve - Supplemental Reserve Service
Supplemental Reserve Service is needed to serve load in the BAA
and to support other transmission usage sourced from generation in
the BAA including exports and sales; however, it is not available
immediately to serve load but rather within a short period of time.
Supplemental Reserve Service may be provided by generating units that
are on-line but unloaded, by quick-start generation or by
interruptible load or other non-generation resources capable of
providing this service. The Transmission Provider must offer this
service when the transmission service is used to serve load within
its BAA and to support other transmission usage sourced from
generation in the BAA including exports and sales. The Transmission
Customer must purchase this service from the Transmission Provider,
self-supply the service, or make alternative comparable arrangements
to satisfy its Supplemental Reserve Service obligation. The amount
of and charges for Supplemental Reserve Service are set forth below.
To the extent the BA performs this service for the Transmission
Provider; charges to the Transmission Customer are to reflect only
a pass-through of the costs charged to the Transmission Provider by
that BA.
Charges for Supplemental Reserve Service:
Under the current NERC Regional Reliability Standard BAL-002-WECC,
the Transmission Provider is required to maintain a minimum amount
of contingency reserve equal to the sum of three percent of hourly
integrated load plus three percent of hourly integrated generation
with at least half as spinning. Consistent with the Transmission
Provider operating in accordance with this reliability standard, the
charges for Schedule 6 below apply one and one-half percent to load
and one and one-half percent to generation.
For load, the rates below are charged to a Network Customer’s hourly
integrated load (including losses).
For generation, the rates below are applied to customers by charging
actual hourly generation delivered to the Transmission Provider at
the Point of Receipt.
The rate shall be an Hourly Rate of:
Effective Rates from
February 13, 2017
through December 31,
Effective Rates
beginning January 1,
2018
2017
Schedule 6
(Supplemental
Reserves)
$0.16 per MWh $0.151 per MWh
Self-Supply:
A Transmission Customer may choose to self-supply all or a portion
of its reserve obligation.
The total reserve obligation for a Transmission Customer who
self-supplies is determined by the currently-effective version of
the NERC Regional Reliability Standard BAL-002-WECC. The
requirement is currently equal to the sum of one and one-half percent
of hourly integrated load plus one and one-half percent of hourly
integrated generation. For a Transmission Customer choosing to
self-supply a portion of its reserve obligation, the billing
determinants for supplemental purchases of Schedule 6 reserve
service shall be determined by: (1) identifying the difference
between the amount self-supplied during each hour of each month and
the Transmission Customer’s full requirement, as determined by NERC
Regional Reliability Standard BAL-002-WECC; (2) charging the
Transmission Customer the Hourly Rate multiplied by the amount of
megawatts identified in (1) where the Transmission Customer failed
to supply its full requirement for each hour, if any failure occurred.
The Transmission Customer shall schedule that portion which it will
self-supply and/or supply from third parties pursuant to procedures
set forth in the Business Practices of the Transmission Provider.
During any period that a Transmission Customer has scheduled
self-supply and/or supply from third parties but fails to provide
the full amount scheduled due to partial or full forced outage of
the generation source or a transmission curtailment or interruption,
the Transmission Customer shall purchase the shortfall at the hourly
rate.
Supplemental Reserve Service to be Provided:
The Transmission Provider, using its generators controlled by
automatic generation control, will provide the capacity required to
provide Supplemental Reserve Service for a Transmission Customer.
Upon an outage of a generation resource for which Supplemental
Reserve Service has been purchased from the Transmission Provider,
the Transmission Provider will provide replacement capacity
commencing at the end of ten (10) full minutes after such outage until
the earlier of (1) the restoration of such resource to service by
the Transmission Customer or (2) the end of the first full hour
immediately following such outage.
To the extent that the Transmission Provider determines that a
Transmission Customer’s specific Supplemental Reserve Requirements
are not being fully met through the purchase of Supplemental Reserve
Service as provided above, the Transmission Provider reserves the
right (upon filing with the Commission) to require such Transmission
Customer to purchase a greater amount of Supplemental Reserve
Service.
SCHEDULE 6
Operating Reserve - Supplemental Reserve Service
Supplemental Reserve Service is needed to serve load in the
BAA and to support other transmission usage sourced from
generation in the BAA including exports and sales; however, it is
not available immediately to serve load but rather within a short
period of time. Supplemental Reserve Service may be provided by
generating units that are on-line but unloaded, by quick-start
generation or by interruptible load or other non-generation
resources capable of providing this service. The Transmission
Provider must offer this service when the transmission service is
used to serve load within its BAA and to support other
transmission usage sourced from generation in the BAA including
exports and sales. The Transmission Customer must purchase this
service from the Transmission Provider, self-supply the service,
or make alternative comparable arrangements to satisfy its
Supplemental Reserve Service obligation. The amount of and
charges for Supplemental Reserve Service are set forth below. To
the extent the BA performs this service for the Transmission
Provider; charges to the Transmission Customer are to reflect
only a pass-through of the costs charged to the Transmission
Provider by that BA.
Charges for Supplemental Reserve Service:
Under the current NERC Regional Reliability Standard
BAL-002-WECC, the Transmission Provider is required to maintain a
minimum amount of contingency reserve equal to the sum of three
percent of hourly integrated load plus three percent of hourly
integrated generation with at least half as spinning. Consistent
with the Transmission Provider operating in accordance with this
reliability standard, the charges for Schedule 6 below apply one
and one-half percent to load and one and one-half percent to
generation.
For load, the rates below are charged to a Network Customer’s
hourly integrated load (including losses).
For generation, the rates below are applied to customers by
charging actual hourly generation delivered to the Transmission
Provider at the Point of Receipt.
The rate shall be an Hourly Rate of:
Effective Rates Effective Rates
from February 13,
2017 through
December 31, 2017
beginning January 1,
2018
Schedule 6
(Supplemental
Reserves)
$0.16 per MWh $0.151 per MWh
Self-Supply:
A Transmission Customer may choose to self-supply all or a
portion of its reserve obligation.
The total reserve obligation for a Transmission Customer who
self-supplies is determined by the currently-effective version of
the NERC Regional Reliability Standard BAL-002-WECC. The
requirement is currently equal to the sum of one and one-half
percent of hourly integrated load plus one and one-half percent
of hourly integrated generation. For a Transmission Customer
choosing to self-supply a portion of its reserve obligation, the
billing determinants for supplemental purchases of Schedule 6
reserve service shall be determined by: (1) identifying the
difference between the amount self-supplied during each hour of
each month and the Transmission Customer’s full requirement, as
determined by NERC Regional Reliability Standard BAL-002-WECC;
(2) charging the Transmission Customer the Hourly Rate multiplied
by the amount of megawatts identified in (1) where the
Transmission Customer failed to supply its full requirement for
each hour, if any failure occurred.
The Transmission Customer shall schedule that portion which it
will self-supply and/or supply from third parties pursuant to
procedures set forth in the Business Practices of the
Transmission Provider. During any period that a Transmission
Customer has scheduled self-supply and/or supply from third
parties but fails to provide the full amount scheduled due to
partial or full forced outage of the generation source or a
transmission curtailment or interruption, the Transmission
Customer shall purchase the shortfall at the hourly rate.
Supplemental Reserve Service to be Provided:
The Transmission Provider, using its generators controlled by
automatic generation control, will provide the capacity required
to provide Supplemental Reserve Service for a Transmission
Customer. Upon an outage of a generation resource for which
Supplemental Reserve Service has been purchased from the
Transmission Provider, the Transmission Provider will provide
replacement capacity commencing at the end of ten (10) full
minutes after such outage until the earlier of (1) the
restoration of such resource to service by the Transmission
Customer or (2) the end of the first full hour immediately
following such outage.
To the extent that the Transmission Provider determines that a
Transmission Customer’s specific Supplemental Reserve
Requirements are not being fully met through the purchase of
Supplemental Reserve Service as provided above, the Transmission
Provider reserves the right (upon filing with the Commission) to
require such Transmission Customer to purchase a greater amount
of Supplemental Reserve Service.