William M. Dudley
Assistant General Counsel
1800 Larimer Street, Suite 1100
Denver, CO 80202
Phone: 303.294.2842
Fax: 303.294-2852
Email: [email protected]
October 30, 2014
Kimberly D. Bose
Secretary
Federal Energy Regulatory Commission
888 First Street, N.E.
Washington, D.C. 20426
Re:
Public Service Company of Colorado
Xcel Energy Operating Companies Joint Open Access Transmission Tariff – Second
Revised Volume No. 1
Proposed Tariff Revisions
Docket No. ER15-____-000
Dear Ms. Bose:
Pursuant to Section 205 of the Federal Power Act (“FPA”), 16 U.S.C. § 824d (2012), and
Section 35.13 of the Federal Energy Regulatory Commission’s (“Commission” or “FERC”)
regulations, 18 C.F.R. § 35.13 (2014), Xcel Energy Services Inc. (“XES”), 1 on behalf of Public
Service Company of Colorado (“PSCo”) hereby submits proposed tariff sheets to the Xcel
Energy Operating Companies Joint Open Access Transmission Tariff (“Xcel Energy OATT”).
The proposed tariff sheets reflect changes to the Xcel Energy OATT designed to facilitate
the joint dispatch of the generating resources of PSCo, Platte River Power Authority (“PRPA”),
and Black Hills Colorado Electric Utility Company, LP (“BHCE”) (collectively, the “Parties”). 2
The Parties have entered into a Joint Dispatch Agreement (“JDA”), to be filed in conjunction
with the instant tariff revisions, that is intended to provide the Parties with a centralized,
coordinated, intra-hour dispatch system for their generation resources with the overall goal of
achieving more efficient and lower cost generation to serve the combined participating native
load requirements within the PSCo Balancing Authority Area (“PSCo BAA”). In this filing,
1
XES is the service company subsidiary of Xcel Energy Inc., the holding company parent of PSCo and the
other Xcel Energy Operating Companies, namely, Northern States Power Company, a Minnesota corporation,
Northern States Power Company, a Wisconsin corporation, and Southwestern Public Service Company. As such,
XES makes filings with, and appears in proceedings before, the Commission on behalf of the Xcel Energy Operating
Companies.
2
Consistent with the requirements of Order No. 714, FERC Stats. & Regs. ¶ 31,276 at P 63 (2008), PSCo is
the designated e-Tariff filing entity for the Xcel Energy OATT and will include in its tariff database the rate
schedule representing the JDA being submitted with this filing. BHCE will be seeking Commission approval of
changes corresponding to those PSCo is submitting in the instant filing. PRPA, while a non-jurisdictional entity,
will also make conforming revisions to its transmission arrangements to provide for Joint Dispatch Transmission
Service.
Honorable Kimberly D. Bose
October 30, 2014
Page 2 of 8
PSCo proposes revisions to the Xcel Energy OATT to provide the Parties with non-firm
transmission service to be used to deliver the energy dispatched under the JDA at no additional
cost.
As further discussed herein, the new service proposed in the attached revisions will not
have an adverse impact on other transmission users, will not be unduly discriminatory, and will
facilitate the Parties’ efforts to achieve dispatch cost savings from their committed resources.
Thus, PSCo respectfully requests that the Commission approve the attached provisions with an
effective date of January 1, 2015.
I.
Introduction
PSCo is a direct subsidiary of Xcel Energy, a holding company that primarily engages in
the production, transmission and distribution of electricity and the distribution of natural gas
through its four utility subsidiaries: PSCo, SPS and Northern States Power Company, a
Minnesota corporation and Northern States Power Company, a Wisconsin corporation. PSCo
generates, transmits and distributes electric power and energy throughout portions of the State of
Colorado. PSCo provides electric service to approximately 1.3 million wholesale and retail
customers in Colorado. The Company's greatest concentration of retail customers is in the
Denver metropolitan area.
PSCo is located at the eastern edge of the Western Interconnection and is a member of
the Western Electricity Coordinating Council ("WECC"). Since there is no regional
transmission organization ("RTO") serving Colorado, PSCo is the Transmission Provider for the
PSCo transmission system. PSCo provides Network Integration Transmission Service (“NITS”)
and Point-to-Point Transmission Services and derives rates for such services pursuant to
Attachment O-PSCo of the Xcel Energy OATT, on file with the Commission pursuant to Order
Nos. 888 and 890.
PSCo has collaborated with the other Parties to establish the JDA in order to realize cost
savings through a centralized system of energy dispatch within the PSCo BAA. The overarching
goal of joint dispatch is to achieve efficiencies through the collaborative use of the Parties’
generation resources. The purpose of the instant filing is to establish tariff provisions that
provide corresponding non-firm transmission service to the Parties for the delivery of energy
under the JDA.
Honorable Kimberly D. Bose
October 30, 2014
Page 3 of 8
II.
Communications
PSCo requests that all correspondence, communications, and service related to this filing
be directed to the following individuals:
Terri K. Eaton
Director, Federal Regulatory/Compliance
Xcel Energy Services Inc.
1800 Larimer Street
Denver, CO 80202
Tel: (303) 571-7112
Email: [email protected]
Floyd L. Norton IV
Arjun P. Ramadevanahalli
Morgan, Lewis & Bockius LLP
1111 Pennsylvania Ave., N.W.
Washington, DC 20004
Tel: (202) 739-5620/5913
Email: [email protected]
[email protected]
Robert Staton
Control Center Manager
Xcel Energy Services Inc.
18201 West 10th Ave.
Golden, CO 80401
Tel: (303) 273-4797
Email: [email protected]
William M. Dudley
Assistant General Counsel
Xcel Energy Services Inc.
1800 Larimer Street, 11th Floor
Denver, CO 80202
Tel: (303) 294-2842
Email: [email protected]
Daniel Ahrens
Standards of Conduct / Fed. Reg. Manager
Xcel Energy Services Inc.
1800 Larimer Street, 14th Floor
Denver, CO 80202
Tel: (303) 571-6428
Email: [email protected]
Peter Colussy
Manager, Market Operations
Xcel Energy Services Inc.
1800 Larimer, Suite 10
Denver, CO 80202
Tel: (303) 808-2607
Email: [email protected]
III.
Description of Proposed Revisions
A.
Background
The Parties developed the JDA in order to achieve efficiencies through the collaborative
use of generation resources within the PSCo BAA. The JDA will facilitate the real-time
optimization of generation dispatch decisions between the Parties and allocate the lowest cost
generation available in real-time to serve native load requirements. The joint economic dispatch
of the pooled generation resources will occur intra-hour and will utilize Available Transfer
Capability (“ATC”) that is otherwise unused after the scheduling hour is closed. As discussed
below in section B.3, the ATC will be monitored at designated interconnection points between
the Parties so that intra-hour schedules by other transmission users will have priority over Joint
Dispatch Transmission Service. Overall, the JDA will result in an organized and cost-effective
Honorable Kimberly D. Bose
October 30, 2014
Page 4 of 8
means for the Parties to meet their own native load requirements within the PSCo BAA. The
proposed revisions submitted with this filing will add a new section to the Xcel Energy OATT
titled “Joint Dispatch Transmission Service” that will provide for delivery by PSCo of energy
provided under the JDA.
B.
Schedule 15, Joint Dispatch Transmission Service
1.
Terms and Service Description
Joint Dispatch Transmission Service is a non-firm transmission product provided only on
an “as-available” basis for the sole purpose of facilitating energy transfers under the JDA. The
conditions that an entity must meet in order to take Joint Dispatch Transmission Service are as
follows:

Be a load serving entity within the PSCo BAA;

Execute the JDA with each participating transmission provider;

Offer generating resources that meet the dispatch criteria into the JDA pool;

Secure an agreement with the JDA Customer’s host transmission provider to provide
corresponding non-firm, zero rate transmission service for use by other Parties to the
JDA. 3
The Joint Dispatch Transmission Service is not limited solely to PSCo, PRPA, and
BHCE. Other similarly situated entities may become Parties to the JDA and take Joint Dispatch
Transmission Service if those entities meet the conditions for service, outlined above. If those
conditions are met, a prospective JDA Customer need only submit an application to obtain the
Joint Dispatch Transmission Service. Due to the non-firm nature of Joint Dispatch Transmission
Service, prospective JDA Customers will not need to arrange for transmission studies prior to
taking Joint Dispatch Transmission Service.
2.
Rates and Charges
PSCo proposes to offer Joint Dispatch Transmission Service at a zero rate to eligible
customers, and no additional transmission charges will be assessed for the receipt or delivery of
energy dispatched pursuant to the JDA. The zero rate term is consistent with the nature of this
transmission service as the Joint Dispatch Transmission Service will only utilize non-firm ATC
within the operating hour that is otherwise unused—capability that is not being compensated
currently. As discussed by Ms. Eaton, every Joint Dispatch Transmission Service Customer will
still be required to maintain adequate firm network and point-to-point service for its wholesale
and retail native load, and each Party will continue to pay third parties for point-to-point
service. 4 In this manner, Joint Dispatch Transmission Service is structured as a zonal or license3
See Exh. No. PSC-3 at Section 42.
4
See Eaton Testimony, Exh. No. PSC-1 at 11.
Honorable Kimberly D. Bose
October 30, 2014
Page 5 of 8
plate service, in which a customer will not be responsible for additional charges beyond those it
is already bearing for transmission facilities located within its zone.
Charges for power losses will continue to be the responsibility of the Joint Dispatch
Transmission Service Customer, and these charges will be paid at pancaked rates. In other
words, energy transactions delivered across two different systems will be assessed losses by both
of those systems. 5 Additionally, Joint Dispatch Transmission Service Customers will continue
to be responsible for charges for ancillary services provided by PSCo as a Balancing Authority. 6
Imbalance charges for Joint Dispatch Transmission Service Customers will not apply. Because
PSCo will serve as the scheduling and dispatch authority under the JDA, and will thus be
responsible for balancing the combined load and participating resources of all the Parties.
3.
Restrictions on Joint Dispatch Transmission Service
As discussed above, Joint Dispatch Transmission Service will be limited solely to the
receipt and delivery of energy dispatched under the JDA within the PSCo BAA to serve the
wholesale and/or retail load of any Party. Joint Dispatch Transmission Service will not be
available for off-system sales of capacity or energy or for providing direct or indirect
transmission service to a third party. Joint Dispatch Transmission Service Customers must
continue to ensure that point-to-point transmission service has been obtained, as needed, to
import purchases from outside the PSCo BAA or export off-system sales, in accordance with
FERC regulations. 7 In addition, the transfer of energy will be limited to ATC at designated
interconnection points under the JDA. PSCo will limit transfers under Joint Dispatch
Transmission Service by determining every five minutes the unused ATC that remains on the
system after all other procurement and scheduling deadlines have passed. Although scheduledriven ATC updates may occur every quarter-hour, the five-minute update ensures that any intrahour schedule changes, such as those prompted by outages, are captured and that only the
leftover ATC be made available for Joint Dispatch Transmission Service. 8 This also ensures that
scheduled transmission receives priority over Joint Dispatch Transmission Service for JDA
transactions, causing adjustments to the joint economic dispatch to ensure ATC will not be
exceeded.
C.
The New Joint Dispatch Transmission Service Is in the Public Interest
Joint Dispatch Transmission Service facilitates the efficient and cost-effective use of
pooled generating resources under the JDA, with multiple benefits to the Parties and their
wholesale and retail customers, and is therefore in the public interest. Under the design of the
5
Eaton Testimony, Exh. No. PSC-1 at 13.
6
Customers will be responsible for services under the following schedules in the Xcel Energy OATT:
Scheduling, System Control and Dispatch, Reactive Supply and Voltage Control, Reserve Sharing, Operating
Reserve – Spinning, and Operating Reserve – Supplemental. See Eaton Testimony, Exh. No. PSC-1 at Page 13.
7
Exh. No. PSC-3 at Section 42.3. Off-system deliveries of Joint Dispatch Energy will be accomplished by
redirecting point-to-point reservations. See Eaton Testimony, Exh. No. PSC-1 at 11.
8
Eaton Testimony, Exh. No. PSC-1 at 9.
Honorable Kimberly D. Bose
October 30, 2014
Page 6 of 8
JDA, the Parties will be able to access a broader pool of resources to serve their own native load
requirements. As a result, the Parties will have the ability to purchase energy at a rate that is less
than what it would cost the Party to produce a corresponding amount of energy. These cost
savings will ultimately be passed on to wholesale and/or retail customers within the PSCo BAA. 9
D.
The New Joint Dispatch Service Will Not Adversely Impact Other Transmission
Users and Is Not Unduly Discriminatory
Energy transfers made under the Joint Dispatch Transmission Service will facilitate a
more efficient use of transmission capacity, but will not adversely impact other transmission
users. As described above, the Parties will provide transmission access based on residual ATC
after the close of the last scheduling deadline during each intra-hour period. 10 Thus, pooled
energy under the JDA will be capped based on the maximum residual ATC on the system.
Moreover, Joint Dispatch Transmission Service will have the lowest curtailment priority, and
will not displace other transmission service.
The Joint Dispatch Transmission Service is not unduly discriminatory to nonparticipating transmission customers because it provides an alternative mechanism to manage the
difference between scheduled and actual load, which is currently managed through Energy
Imbalance services under Schedule 4 of the Xcel Energy OATT. PSCo as the BAA provides
energy imbalance services without purchasing transmission service to do so. PSCo balances the
system after taking into account the resources provided by each customer. Under joint economic
dispatch facilitated by the JDA and Joint Dispatch Transmission Service, PSCo will have
dispatch authority over participating resources of the parties, drawing from the committed
resources of each party as determined prior to the start of the hour. Participating generation
resources of the Parties will be dispatched by PSCo in economic order to achieve balance.
In this manner, the JDA framework is analogous to an energy imbalance market or other
energy market, albeit on a small scale. The Commission has approved the use of zonal
transmission rates based on the host transmission owner’s cost and has eliminated intra-market
pancaked transmission rates in a number of instances. 11 In a recent example, the Commission
approved the California Independent System Operator Corporation’s (“CAISO”) proposed tariff
revisions to implement an Energy Imbalance Market (“EIM”), in which neighboring BAAs may
participate in CAISO’s real-time market for imbalance energy. 12 To facilitate the transfer of
EIM energy between participating BAAs, CAISO proposed that it would not assess charges on
transmission capacity made available to the real-time market through the EIM. 13 The
9
Eaton Testimony, Exh. No. PSC-1 at 7.
10
Eaton Testimony, Exh. No. PSC-1 at 9.
11
See, e.g., PJM Interconnection, L.L.C., Opinion No. 494, 119 FERC ¶ 61,063 (2007), order on reh’g and
compliance filing, Opinion No. 494-A, 122 FERC ¶ 61,082, order denying reh’g, 124 FERC ¶ 61,033 (2008); ITC
Holdings Corp., 143 FERC ¶ 61,257 at P 124 (2013) (“[T]he Commission has . . . accepted reconfigurations of
license plate pricing zones that deviate from historical configurations.”).
12
Cal. Indep. Sys. Operator Corp., 147 FERC ¶ 61,231 (2014).
13
Id. at P 125 n. 172.
Honorable Kimberly D. Bose
October 30, 2014
Page 7 of 8
Commission approved CAISO’s proposal to eliminate intra-market pancaked transmission rates,
noting that doing so could promote more efficiency, provide customers in the EIM and in CAISO
with access to additional energy supplies, and result in downward pressure on market prices. 14
Although the Commission’s approval of CAISO’s elimination of pancaked transmission rates
occurred in the RTO context, the example is relevant here, as both the EIM and the JDA aim to
promote efficiency by employing a zonal transmission scheme to provide access to additional
energy supplies.
Joint Dispatch Transmission Service facilitates these economic energy deliveries at zero
cost in recognition that the Service will only utilize ATC that is currently being unused.
Additionally, this zero cost transmission service will maximize cost savings for customers of the
participating Parties in a not unduly discriminatory manner. Participation in the JDA is
voluntary and non-exclusive, and those transmission customers that do not participate in the JDA
will continue to be provided balancing service under Schedule 4 of the Xcel Energy OATT.
Moreover, the implementation of zero cost transmission for Joint Dispatch Transmission Service
is limited to providing economic energy transfers pursuant to the JDA.
E.
The Proposed Tariff Revisions Do Not Significantly Alter PSCo’s OATT
Lastly, the proposed tariff provisions do not depart from the Commission’s previous
determination that PSCo’s OATT conforms with, or is superior to, the pro forma OATT. 15 First,
the proposed tariff provisions serve only to provide a new type of service for Parties to the JDA.
Moreover, as discussed above, Joint Dispatch Transmission Service is not exclusive, and any
load-serving entity in the PSCo BAA that is willing to sign the JDA, has the ability to contribute
generating resources to the JDA pool, and whose transmission provider agrees to the terms
comparable to those proposed in this filing would also be able to participate in the JDA.
IV.
Proposed Effective Date and Request for Waivers
PSCo requests that the Commission approve the requested effective date of January 1,
2015. PSCo also respectfully requests waiver of any other requirements of the Commission’s
rules and regulations, as well as any authorizations as may be necessary or required, to permit the
proposed tariff sheets to be accepted by the Commission and made effective in the manner
proposed herein. Because no charge will be assessed for Joint Dispatch Transmission Service,
cost support under Section 35.13 of the Commission’s regulations is not necessary.
14
Id. at P 156.
15
See Letter Order Accepting Xcel Energy’s Baseline OATT, Docket No. ER10-2070 (Sept. 24, 2010).
Honorable Kimberly D. Bose
October 30, 2014
Page 8 of 8
V.
Contents of Filing
Pursuant to 18 C.F.R. § 35, this filing consists of the following documents:

This transmittal letter;

Attachment 1: Testimony of Terri K. Eaton, Director, Federal Regulatory
Administration, Xcel Energy Services Inc. (Exhibit No. PSC-1);

Attachment 2: Redlined version of the proposed tariff changes (Exhibit No.
PSC-2); and

Attachment 3: Clean version of the tariff changes (Exhibit No. PSC-3).
To the extent necessary, PSCo respectfully requests waiver of any of the other applicable
requirements of 18 C.F.R. § 35.13. The proposed tariff revisions do not involve a rate increase
within the meaning of section 35.13(a)(2)(iii) of the Commission’s regulations and do not
otherwise modify any existing terms or conditions of the Xcel Energy OATT.
VI.
Service and Posting
An electronic copy or notice of this filing will be served on all customers of PSCo taking
transmission or ancillary services under the Xcel Energy OATT and on the Public Utilities
Commission of Colorado. In advance of this filing, on October 1, 2014, PSCo provided a
complete copy of this filing in draft form, including the transmittal letter, testimony, and tariff
sheets, to its transmission Customers for their review.
A copy of this filing is also available at the Open Access Transmission Tariff filings
pages of the Xcel Energy Inc. website (www.xcelenergy.com).
VII.
Conclusion
For the reasons stated herein, PSCo respectfully requests that the Commission accept the
proposed tariff sheets to be effective on January 1, 2015. PSCo sincerely appreciates the
Commission’s prompt attention to this matter. Please direct any questions regarding this filing to
the undersigned.
Sincerely,
/s/ William M. Dudley
William M. Dudley
Assistant General Counsel
EXHIBIT 1
Exhibit PSC-1
Page 1 of 13
UNITED STATES OF AMERICA
BEFORE THE
FEDERAL ENERGY REGULATORY COMMISSION
Public Service Company of Colorado
)
Docket No. ER15-___-000
PREPARED TESTIMONY
OF
TERRI K. EATON
XCEL ENERGY SERVICES INC.
ON BEHALF OF
PUBLIC SERVICE COMPANY OF COLORADO
October 30, 2014
Exhibit PSC-1
Page 2 of 13
1
I
INTRODUCTION AND EXPERIENCE
2
Q.
PLEASE STATE YOUR NAME AND BUSINESS ADDRESS.
3
A.
My name is Terri K Eaton. My office address is 1800 Larimer Street, 14th Floor, Denver,
4
Colorado, 80202.
5
Q.
BY WHOM ARE YOU EMPLOYED AND IN WHAT CAPACITY?
6
A.
I am employed by Xcel Energy Services Inc. (“XES”). I am the Director, Federal
7
Regulatory Administration.
8
Q.
ON WHOSE BEHALF ARE YOU TESTIFYING IN THIS PROCEEDING?
9
A.
I am testifying on behalf of Public Service Company of Colorado (“PSCo” or the
10
“Company”), a wholly owned subsidiary of Xcel Energy Inc. (“Xcel Energy”). PSCo is
11
an integrated electric and natural gas utility operating in Colorado, including in the
12
Denver metropolitan area, and is one of four utility operating company subsidiaries of
13
Xcel Energy.
14
Q.
PLEASE EXPLAIN YOUR DUTIES AND RESPONSIBILITIES.
15
A.
My department is responsible for regulatory filings, regulatory activity, and compliance
16
monitoring activities involving the Federal Energy Regulatory Commission (“FERC” or
17
“Commission”) for the four Xcel Energy utility operating companies, including PSCo.
18
The FERC compliance monitoring responsibilities include PSCo compliance with North
19
American Electric Reliability Corporation (“NERC”) and the Western Electricity
20
Coordinating Council (“WECC”) mandatory electric reliability standards.
Exhibit PSC-1
Page 3 of 13
1
Q.
2
3
WHAT IS YOUR EDUCATION AND YOUR EXPERIENCE IN THE ELECTRIC
UTILITY BUSINESS?
A.
In 1981, I received my B.S. degree from the University of Texas. In 1985, I received my
4
J.D. from the University of Texas School of Law. From 2000 to 2002, I worked as a staff
5
attorney for the Public Utility Commission of Texas (“PUCT”). In that role, I was
6
responsible for representing PUCT staff in rate case, transmission line, stranded cost, and
7
various other proceedings.
8
Manager of Governmental Affairs, representing the company’s interests as a competitive
9
retail electric provider before the PUCT, the Texas legislature, and the Electric Reliability
10
Council of Texas (“ERCOT”). I joined XES in 2005 as a Manager of Market Operations,
11
representing the interests of PSCo’s affiliate Southwestern Public Service Company
12
(“SPS”) in the efforts by Southwest Power Pool, Inc. (“SPP”) to create its Energy
13
Imbalance Service market. In 2006, I transferred into XES’s FERC regulatory group
14
where I managed electric market policy issues. In 2007, I assumed a newly created
15
position focused on monitoring and oversight of mandatory reliability standards
16
compliance efforts of the Xcel Energy Operating Companies. In 2009, I assumed my
17
current position.
18
Q.
19
20
In 2002, I joined Green Mountain Energy Company as
HAVE YOU PREVIOUSLY SUBMITTED TESTIMONY BEFORE ANY
REGULATORY COMMISSION?
A.
Yes, I have previously submitted pre-filed testimony before this Commission in Docket
21
No. ER12-1589 and ER14-1969. Additionally, I have submitted affidavits to the
22
Commission on various matters, including affidavits in support of tariff change filings in
23
Docket Nos. ER12-435-000, ER12-436-000, and ER12-455-000.
Exhibit PSC-1
Page 4 of 13
1
II
PURPOSE AND SUMMARY
2
Q.
WHAT IS THE PURPOSE OF YOUR TESTIMONY?
3
A.
The purpose of my testimony is to provide a brief description of Xcel Energy, XES and
4
PSCo, and to provide an overview of PSCo’s request for approval of revisions to its Open
5
Access Transmission Tariff (“Xcel Energy OATT”) to facilitate transactions under the
6
Joint Dispatch Agreement (“JDA”).
7
approval of the JDA, an agreement that will provide for the economic dispatch of
8
participating generation within the PSCo Balancing Authority Area (“BAA”), and the
9
other FERC jurisdictional party to the JDA is filing revisions to its Open Access
10
Concurrent with this filing, PSCo is filing for
Transmission Tariff corresponding to PSCo’s changes in this filing.
11
Q.
PLEASE SUMMARIZE THE PROPOSED TARIFF CHANGES.
12
A.
The proposed revisions to the Xcel Energy OATT include:

13
A new section titled Joint Dispatch Transmission Service that provides non-firm
14
transmission service at a rate discounted to zero applicable only to load serving
15
entities that have participating generation that they can contribute to the joint
16
dispatch pool in the PSCo Balancing area and are signatories to a Joint Dispatch
17
Agreement;
18

A new Schedule 15, Joint Dispatch Transmission Service; and,
19

A Service Agreement for Joint Dispatch Transmission Service.
20
21
Q.
ARE THERE EXCEPTIONS TO THE REQUIREMENT THAT GENERATION
BE LOCATED INSIDE THE BAA?
Exhibit PSC-1
Page 5 of 13
1
A.
Yes. Generation could be located outside the PSCo Balancing area but pseudo-tied into
2
the PSCo balancing area. A pseudo-tie essentially involves electrically sinking the
3
output of a generator in one balancing area into another sink balancing area.
4
Q.
5
6
HAVE YOU INCLUDED ATTACHMENTS TO YOUR TESTIMONY SHOWING
THE CHANGES TO THE OATT?
A.
7
Yes. The attached Exhibit No. PSC-2 is a redlined version of the proposed tariff changes,
while Exhibit No. PSC-3 is a clean version of the tariff changes.
8
III
CORPORATE OVERVIEW
9
Q.
PLEASE PROVIDE A BRIEF DESCRIPTION OF XCEL ENERGY.
10
A.
Xcel Energy is a holding company that primarily engages in the production, transmission
11
and distribution of electricity and the distribution of natural gas through its four utility
12
subsidiaries: PSCo, SPS and Northern States Power Company, a Minnesota corporation
13
(“NSPM”) and Northern States Power Company, a Wisconsin corporation (“NSPW”)
14
(NSPM and NSPW jointly the “NSP Companies”). PSCo, NSPM and NSPW are each
15
combination electric and natural gas utilities. SPS is an electric-only utility. Collectively
16
Xcel Energy’s utility operating company subsidiaries serve 3.4 million electric and 1.9
17
million natural gas customers in Colorado, Michigan, Minnesota, New Mexico, North
18
Dakota, South Dakota, Texas and Wisconsin.
19
transmission facilities in Kansas and Oklahoma. I note that the changes to the Xcel
20
Energy OATT proposed in this filing do not affect the rates or terms of service on the
21
NSP Companies or SPS transmission systems.
22
Q.
PLEASE DESCRIBE XES.
In addition, SPS owns and operates
Exhibit PSC-1
Page 6 of 13
1
A.
XES is a service company that provides a variety of management and administrative
2
services to Xcel Energy’s four utility operating companies, including PSCo. Some of the
3
services provided by XES include executive management, human resources, accounting,
4
audit, legal, claims, regulatory and compliance, fuel and energy management,
5
engineering and customer services. As a service company, XES files an annual Form 60
6
service company report with the Commission each year detailing the revenues from its
7
charges to the individual utility operating companies.
8
Q.
PLEASE PROVIDE A BRIEF DESCRIPTION OF PSCO.
9
A.
PSCo generates, transmits and distributes electric power and energy throughout portions
10
of the State of Colorado. PSCo provides electric service to approximately 1.3 million
11
wholesale and retail customers in Colorado. The Company’s greatest concentration of
12
retail customers is in the Denver metropolitan area.
13
PSCo is located at the eastern edge of the Western Interconnection and is a
14
member of the Western Electricity Coordinating Council (“WECC”). Since there is no
15
regional transmission organization (“RTO”) serving Colorado, PSCo is the Transmission
16
Provider for the PSCo transmission system.
17
Transmission Service (“NITS”) and Point-to-Point Transmission Services and derives
18
rates for such services pursuant to Attachment O-PSCo of the Xcel Energy OATT, on file
19
with the Commission pursuant to Order Nos. 888 and 890.
PSCo provides Network Integration
20
IV
JDA BACKGROUND
21
Q.
WHAT IS THE PURPOSE OF THE INSTANT FILING?
22
A.
The instant filing reflects changes to the Xcel Energy OATT designed to facilitate joint
23
dispatch of the resources of PSCo, Platte River Power Authority (“PRPA”) and Black
Exhibit PSC-1
Page 7 of 13
1
Hills Colorado Electric Utility Company, LP (“BHCE”) (collectively referred to as “the
2
Parties”) under the JDA. More specifically, the proposed tariff changes provide that non-
3
firm transmission service used to deliver energy dispatched under the JDA will be
4
provided at no cost, other than payment of losses, to parties to the JDA.
5
Q.
WHAT IS THE PURPOSE OF THE JDA?
6
A.
The Parties to the JDA intend to capture efficiencies and cost savings through joint
7
dispatch of their committed resources to serve the native load obligation of the parties to
8
the JDA within the PSCo BAA.
9
Q.
HOW WILL THE JDA CAPTURE EFFICIENCIES?
10
A.
As discussed in more detail in the companion filing, the parties to the JDA have agreed
11
to allow PSCo to dispatch the committed and participating resources of all the parties in
12
real-time in a manner that maintains reliability while minimizing overall production costs
13
and respecting transmission constraints and unit operating characteristics.
14
Q.
WHERE IS THE LOAD THAT WILL BE SERVED BY THE JDA LOCATED?
15
A.
Under the JDA, the load that can be served under the agreement is limited to that which is
16
located within the PSCo BAA.
17
V
POLICY
18
Q.
WHY
19
20
SHOULD
THE
TARIFF
REVISION
BE
APPROVED
BY
THE
COMMISSION, AND IS THE JDA IN THE PUBLIC INTEREST?
A.
The JDA will enable optimal dispatch of the combined participating resources of all the
21
participating parties, resulting in increased dispatch efficiency. The tariff revisions are in
22
the public interest because, among other things, the dispatch efficiency facilitated by the
Exhibit PSC-1
Page 8 of 13
1
JDA and tariff revisions will be reflected through reduced fuel costs for the customers of
2
all participating parties, including PSCo’s retail and wholesale customers.
3
The JDA and tariff revisions provide an alternative mechanism to effectively
4
manage the difference between scheduled and actual load, which is currently managed
5
through Energy Imbalance services under Schedule 4 of the PSCo OATT. PSCo, as the
6
BAA, provides energy imbalance services without purchasing transmission service to do
7
so. PSCo balances the system after taking into account the committed resources from
8
each customer that were determined prior to the start of the hour. Under joint economic
9
dispatch facilitated by the JDA and Joint Dispatch Transmission Service, participating
10
generation resources will be dispatched in the most economic order to achieve this
11
balance.
12
VI
OATT REVISIONS
13
Q.
WHAT REVISIONS ARE BEING MADE TO PSCO’S OATT?
14
A.
PSCo is revising its OATT in order to offer Joint Dispatch Transmission Service. Joint
15
Dispatch Service is service that can only be used to receive and deliver energy dispatched
16
under the JDA to the Parties’ wholesale and retail native load customers.
17
Q.
18
19
ARE THE TARIFF PROVISIONS PROVIDING FOR THE NEW SERVICE
OPTION EXCLUSIVE OR UNDULY DISCRIMINATORY?
A.
No. The tariff provisions are not limited to the initial Parties of the JDA. Any load-
20
serving entity in the PSCo BAA that is willing to sign the JDA, has the ability to
21
contribute generating resources to the JDA pool, and whose host transmission provider
22
agrees to provide joint dispatch service at rates and terms comparable to those proposed
23
in this filing would also be able to participate in the JDA.
Exhibit PSC-1
Page 9 of 13
1
Q.
2
3
ARE THE PROPOSED CHANGES CONSISTENT WITH, OR SUPERIOR TO,
THE COMMISSION’S PRO FORMA OATT?
A.
Yes. The new tariff provisions provide for a new type of service for Parties to the JDA
4
that is essentially a license plate rate available to those entities that have committed to
5
joint dispatch of their participating resources to serve load located in the PSCo BAA.
6
These new provisions do not depart from the Commission’s prior determination that
7
PSCo’s OATT conforms with, or is superior to, the pro forma OATT. In addition to
8
being non-discriminatory, the new service will not have an adverse impact on other
9
transmission users.
10
Q.
11
12
PLEASE EXPLAIN HOW THE JOINT DISPATCH TRANSMISSION SERVICE
WILL NOT ADVERSELY IMPACT OTHER TRANSMISSION USERS.
A.
Joint Dispatch Transmission Service is only available if there is posted non-firm
13
Available Transmission Capacity (“ATC”) after all other procurement and scheduling
14
deadlines have passed. PSCo will limit transfers under Joint Dispatch Transmission
15
Service to the amount of unused ATC that remains on the system after such procurement
16
and scheduling deadlines have passed. Although schedule-driven ATC updates may
17
occur every quarter-hour, PSCo will update ATC limits for Joint Dispatch Transmission
18
Service every five minutes. By conducting these updates every five minutes, PSCo will
19
ensure that any immediate intra-hour schedule changes, such as those prompted by
20
outages, are captured and only the leftover ATC be made available for Joint Dispatch
21
Transmission Service. In this way, energy transfers are limited by ATC availability on
22
the system, and participating generation units will be adjusted to limit volumetric
23
transfers between Parties based on unused ATC that remains after the close of
Exhibit PSC-1
Page 10 of 13
1
transmission schedules. Thus, Joint Dispatch Transmission Service will only use ATC
2
that would otherwise go unused. Additionally, Joint Dispatch Transmission Service will
3
have the lowest priority, and any party seeking transmission service will be in a queue
4
position higher than Joint Dispatch Transmission Service.
5
Each Party’s transmission service provider will be required to post ATC that
6
PSCo will collect and use to determine appropriate transfer capabilities.
Based on
7
historic data, PSCo estimates the transfer capabilities needed to execute the JDA should
8
not exceed 300 MW between parties. Typically, transfers are expected to be less than
9
150 MW.
10
Q.
IS PSCO THE ONLY PARTY PROPOSING TO REVISE ITS OATT?
11
A.
No. BHCE will be seeking FERC approval of revisions to its OATT that mirror the
12
changes PSCo is proposing here. Further, while PRPA is a non-jurisdictional entity, it
13
has committed to revising its tariff to conform to the revisions proposed by PSCo here.
14
VII
DESCRIPTION OF THE SERVICE
15
Q.
WHAT TYPE OF TRANSMISSION SERVICES WILL BE PROVIDED UNDER
16
17
THE NEW TARIFF PROVISIONS?
A.
Joint Dispatch Transmission Service is a non-firm, “as-available” transmission service
18
provided at zero cost that is made available for the sole purpose of facilitating energy
19
transfers pursuant to the JDA.
20
Q.
WOULD A JDA BE FEASIBLE WITH TRANSMISSION CHARGES?
21
A.
No. Xcel Energy and BHCE explored a joint dispatch arrangement a few years ago, but
22
shelved the idea primarily because the economic benefits would be severely diminished if
23
both PSCo and BHCE secured point-to-point transmission service to facilitate dynamic
Exhibit PSC-1
Page 11 of 13
1
transfers or if BHCE became a network customer under the PSCo OATT.
2
proposal too, transmission charges would likely eliminate the benefits that the Parties
3
expect to achieve through the JDA.
4
Q.
In this
CAN JOINT DISPATCH TRANSMISSION SERVICE BE USED BY A PARTY
5
FOR TRANSACTIONS OTHER THAN TO SERVE NATIVE LOAD WITH JDA
6
ENERGY?
7
A.
No. Joint Dispatch Transmission Service will not be available for off-system sales of
8
capacity or energy or for providing direct or indirect transmission service to a third party
9
and is limited to the use described above. The Service cannot be used as a substitute for
10
point-to-point or network service. For off-system purchases and sales, Joint Dispatch
11
Transmission Service Customers must ensure point-to-point transmission service has
12
been obtained, as needed, to import purchases from outside the PSCo BAA, or to export
13
off-system sales, in accordance with FERC regulations.
14
Transmission Service customer will continue to be required to maintain adequate firm
15
network and point-to-point service for its wholesale and retail native load and its
16
contractual commitments.
Thus, each Joint Dispatch
17
Q.
DOES THE JDA ITSELF PROVIDE FOR TRANSMISSION SERVICE?
18
A.
No transmission services are provided under the JDA.
19
Q.
WHO CAN TAKE JOINT DISPATCH TRANSMISSION SERVICE?
20
A.
Joint Dispatch Transmission Service will be limited to entities that have signed the JDA,
21
offer resources into the JDA pool and serve load within the PSCo BAA.
22
VIII. TRANSMISSION CHARGES
23
Q.
WHAT IS THE CHARGE FOR JOINT DISPATCH TRANSMISSION SERVICE?
Exhibit PSC-1
Page 12 of 13
1
A.
PSCo is proposing that Joint Dispatch Transmission Service be priced at $0 per MWh,
2
meaning that the Joint Dispatch Transmission Service Customers will not pay any
3
charges for receipt and delivery of energy dispatched under the JDA.
4
Dispatch Transmission Service Customer will have to maintain adequate firm network
5
and firm point-to-point service to serve its wholesale and retail native load; no additional
6
transmission service charge will be imposed for energy deliveries under the JDA. The
7
proposed $0 rate is consistent with the nature of this transmission service because the
8
Joint Dispatch Transmission Service will only utilize non-firm ATC within the operating
9
hour that is otherwise unused—capability that is not being compensated currently. In
10
essence Joint Dispatch Transmission Service is a zonal or license plate service since each
11
party to the JDA will be required to maintain network and point-to-point service to serve
12
its load. Each Party will continue to pay point-to-point charges for sales to third parties.
Each Joint
13
Q.
IS THERE PRECEDENT FOR THIS TYPE OF LICENSE PLATE SERVICE?
14
A.
Yes. In Docket No. ER14-1386 the Commission conditionally approved a proposal by
15
California Independent System Operator (“CAISO”) to facilitate and Energy Imbalance
16
Market outside of the CAISO footprint. PacifiCorp is one of the first participants and
17
filed revisions to its OATT in Docket No. ER14-1578 to allow it to participate in the
18
EIM. In that case, FERC conditionally accepted PacifiCorp’s OATT revisions, but
19
specifically rejected the proposal to require participating resources in the EIM in
20
PacifiCorp’s Balancing Authority Area to pay for additional transmission service to
21
participate above what they would regularly pay as transmission customers on PaciCorp’s
22
OATT.
Exhibit PSC-1
Page 13 of 13
1
Q.
2
3
HOW WILL ANCILLARY SERVICES BE CHARGED UNDER THESE
PROPOSED TARIFF PROVISIONS?
A.
As provided in the proposed tariff language, all Joint Dispatch Transmission Service
4
Customers will be responsible for losses, paid at pancaked rates. So, for example, if
5
energy is delivered from PRPA to BHCE, which necessarily involves a delivery across
6
PSCo’s system, BHCE will be assessed losses by both PRPA and PSCo.
7
Q.
WILL JOINT DISPATCH CUSTOMERS BE RESPONSIBLE FOR ANY OTHER
8
ANCILLARY SERVICE CHARGES?
9
Joint Dispatch Transmission Service Customers will be responsible for services provided
10
by PSCo as a Balancing Authority under the following schedules in the Xcel Energy
11
OATT including Scheduling, System Control and Dispatch, Reactive Supply and Voltage
12
Control, Reserve Sharing, Operating Reserve – Spinning, and Operating Reserve --
13
Supplemental.
14
Notably, however, while Joint Dispatch Transmission Service Customers would
15
otherwise be responsible for imbalance charges under Schedule 4 of the Xcel Energy
16
OATT. This is because, by definition, PSCo will be responsible for balancing the load
17
and resources of all parties to the JDA. More detail about the services offered under the
18
JDA and the charges associated with those services is found in the companion JDA filing.
19
IX
CONCLUSION
20
Q.
DOES THIS CONCLUDE YOUR PREPARED PRE-FILED TESTIMONY?
21
A.
Yes.
EXHIBIT 2
TABLE OF CONTENTS
I.
COMMON SERVICE PROVISIONS
1
Definitions
1.1
Affiliate
1.2
Ancillary Services
1.3
Annual Transmission Costs
1.4
Application
1.5
Commission
1.6
Completed Application
1.7
Control Area
1.8
Curtailment
1.9
Delivering Party
1.10 Designated Agent
1.11 Direct Assignment Facilities
1.12 Eligible Customer
1.13 Facilities Study
1.14 Firm Point-To-Point Transmission Service
1.15 Good Utility Practice
1.16 Interruption
1.17 Load Ratio Share
1.18 Load Shedding
1.19 Long-Term Firm Point-To-Point Transmission Service
1.20 Native Load Customers
1.21 NERC TLR Procedures
1.22 Network Customer
1.23 Network Integration Transmission Service
1.24 Network Load
1.25 Network Operating Agreement
1.26 Network Operating Committee
1.27 Network Resource
1.28 Network Upgrades
1.29 Non-Firm Point-To-Point Transmission Service
1.30 Non-Firm Sale
1.31 Non-Variable Energy Resource
1.32 Open Access Same-Time Information System (OASIS)
1.33 Part I
1.34 Part II
1.35 Part III
1.35A Part IV
1.36 Parties
1.37 Point(s) of Delivery
1.38 Point(s) of Receipt
1.39 Point-To-Point Transmission Service
1.40 Power Purchaser
1.41 Pre-Confirmed Application
1.42 Receiving Party
1.43 Regional Transmission Group (RTG)
1.44 Reserved Capacity
2
3
4
5
6
7
8
9
10
11
12
1.45 Service Agreement
1.46 Service Commencement Date
1.47 Short-Term Firm Point-To-Point Transmission Service
1.48 System Condition
1.49 System Impact Study
1.50 Third-Party Sale
1.51 Transmission Customer
1.52 Transmission Provider
1.53 Transmission Provider's Monthly Transmission System Peak
1.54 Transmission Service
1.55 Transmission System
1.56 Variable Energy Resource
Initial Allocation and Renewal Procedures
2.1
Initial Allocation of Available Transfer Capability
2.2
Reservation Priority For Existing Firm Service Customers
Ancillary Services
3.1
Scheduling, System Control and Dispatch Service
3.2
Reactive Supply and Voltage Control from Generation or Other Sources
Service
3.3
Regulation and Frequency Response Service
3.4
Energy Imbalance Service
3.5
Operating Reserve - Spinning Reserve Service
3.6
Operating Reserve - Supplemental Reserve Service
3.7
Flex Reserve Service
3.8
Generator Imbalance Service
Open Access Same-Time Information System (OASIS)
4.1
Terms and Conditions
4.2
NAESB WEQ Business Practice Standards
Local Furnishing Bonds
5.1
Transmission Providers That Own Facilities Financed by Local Furnishing
Bonds
5.2
Alternative Procedures for Requesting Transmission Service
Reciprocity
Billing and Payment
7.1
Billing Procedure
7.2
Interest on Unpaid Balances
7.3
Customer Default
Accounting for the Transmission Provider's Use of the Tariff
8.1
Transmission Revenues
8.2
Study Costs and Revenues
Regulatory Filings
Force Majeure and Indemnification
10.1 Force Majeure
10.2 Indemnification
Creditworthiness
Dispute Resolution Procedures
12.1 Internal Dispute Resolution Procedures
12.2 Mediation Procedures
12.3 External Arbitration Procedures
12.4 Arbitration Decisions
12.5 Costs
12.6
II.
Rights Under The Federal Power Act
POINT-TO-POINT TRANSMISSION SERVICE
Preamble
13
Nature of Firm Point-To-Point Transmission Service
13.1 Term
13.2 Reservation Priority
13.3 Use of Firm Transmission Service by the Transmission Provider
13.4 Service Agreements
13.5 Transmission Customer Obligations for Facility Additions or Redispatch
Costs
13.6 Curtailment of Firm Transmission Service
13.7 Classification of Firm Transmission Service
13.8.1 Scheduling of Firm Point-To-Point Transmission Service on the PSCo
System
13.8.2 Scheduling of Firm Point-To-Point Transmission Service on the NSP and
SPS Systems
14
Nature of Non-Firm Point-To-Point Transmission Service
14.1 Term
14.2 Reservation Priority
14.3 Use of Non-Firm Point-To-Point Transmission Service by the
Transmission Provider
14.4 Service Agreements
14.5 Classification of Non-Firm Point-To-Point Transmission Service
14.6.1 Scheduling of Non-Firm Point-To-Point Transmission Service on the
PSCo System
14.6.2 Scheduling of Non-Firm Point-To-Point Transmission Service on the NSP
and SPS Systems
14.7 Curtailment or Interruption of Service
15
Service Availability
15.1 General Conditions
15.2 Determination of Available Transfer Capability
15.3 Initiating Service in the Absence of an Executed Service Agreement
15.4 Obligation to Provide Transmission Service that Requires Expansion or
Modification of the Transmission System, Redispatch or Conditional
Curtailment
15.5 Deferral of Service
15.6 Other Transmission Service Schedules
15.7 Real Power Losses
16
Transmission Customer Responsibilities
16.1 Conditions Required of Transmission Customers
16.2 Transmission Customer Responsibility for Third-Party Arrangements
17
Procedures for Arranging Firm Point-To-Point Transmission Service
17.1 Application
17.2 Completed Application
17.3 Deposit
17.4 Notice of Deficient Application
17.5 Response to a Completed Application
17.6 Execution of Service Agreement
17.7 Extensions for Commencement of Service
18
Procedures for Arranging Non-Firm Point-To-Point Transmission Service
19
20
21
22
23
24
25
26
27
III.
18.1 Application
18.2 Completed Application
18.3.1 Reservation of Non-Firm Point-To-Point Transmission Service on the
PSCo System
18.3.2 Reservation of Non-Firm Point-To-Point Transmission Service on the
NSP and SPS Systems
18.4 Determination of Available Transfer Capability
Additional Study Procedures For Firm Point-To-Point Transmission Service
Requests
19.1 Notice of Need for System Impact Study
19.2 System Impact Study Agreement and Cost Reimbursement
19.3 System Impact Study Procedures
19.4.1 Facilities Study Procedures
19.4.2 Clustered Transmission Service Requests
19.5 Facilities Study Modifications
19.6 Due Diligence in Completing New Facilities
19.7 Partial Interim Service
19.8 Expedited Procedures for New Facilities
19.9 Penalties For Failure to Meet Study Deadlines
Procedures if The Transmission Provider is Unable to Complete New
Transmission Facilities for Firm Point-To-Point Transmission Service
20.1 Delays in Construction of New Facilities
20.2 Alternatives to the Original Facility Additions
20.3 Refund Obligation for Unfinished Facility Additions
Provisions Relating to Transmission Construction and Services on the
Systems of Other Utilities
21.1 Responsibility for Third-Party System Additions
21.2 Coordination of Third-Party System Additions
Changes in Service Specifications
22.1 Modifications On a Non-Firm Basis
22.2 Modification On a Firm Basis
Sale or Assignment of Transmission Service
23.1 Procedures for Assignment or Transfer of Service
23.2 Limitations on Assignment or Transfer of Service
23.3 Information on Assignment or Transfer of Service
Metering and Power Factor Correction at Receipt and Delivery Points(s)
24.1 Transmission Customer Obligations
24.2 Transmission Provider Access to Metering Data
24.3 Power Factor
Compensation for Transmission Service
Stranded Cost Recovery
Compensation for New Facilities and Redispatch Costs
NETWORK INTEGRATION TRANSMISSION SERVICE
Preamble
28
Nature of Network Integration Transmission Service
28.1 Scope of Service
28.2 Transmission Provider Responsibilities
28.3 Network Integration Transmission Service
28.4 Secondary Service
28.5 Real Power Losses
29
30
31
32
33
34
28.6 Restrictions on Use of Service
Initiating Service
29.1 Condition Precedent for Receiving Service
29.2 Application Procedures:
29.3 Technical Arrangements to be Completed Prior to Commencement of
Service
29.4 Network Customer Facilities
29.5 Filing of Service Agreement
Network Resources
30.1 Designation of Network Resources
30.2 Designation of New Network Resources
30.3 Termination of Network Resources
30.4 Operation of Network Resources
30.5 Network Customer Redispatch Obligation
30.6 Transmission Arrangements for Network Resources Not
Physically Interconnected With The Transmission Provider
30.7 Limitation on Designation of Network Resources
30.8 Use of Interface Capacity by the Network Customer
30.9 Network Customer Owned Transmission Facilities
Designation of Network Load
31.1 Network Load
31.2 New Network Loads Connected With the Transmission Provider
31.3 Network Load Not Physically Interconnected with the Transmission
Provider
31.4 New Interconnection Points
31.5 Changes in Service Requests
31.6 Annual Load and Resource Information Updates
Additional Study Procedures For Network Integration Transmission Service
Requests
32.1 Notice of Need for System Impact Study
32.2 System Impact Study Agreement and Cost Reimbursement
32.3 System Impact Study Procedures
32.4.1 Facilities Study Procedures
32.4.2 Clustered Transmission Service Requests
32.5 Penalties For Failure to Meet Study Deadlines
Load Shedding and Curtailments
33.1.1 Procedures on the PSCo System
33.1.2 Procedures on the NSP and SPS Systems
33.2 Transmission Constraints
33.3 Cost Responsibility for Relieving Transmission Constraints
33.4 Curtailments of Scheduled Deliveries
33.5 Allocation of Curtailments
33.6 Load Shedding
33.7 System Reliability
Rates and Charges
34.1.1 Monthly Demand Charge on the SPS Transmission System
34.1.2 Monthly Demand Charge on the PSCo Transmission System
34.2 Determination of Network Customer's Monthly Network Load
34.3 Determination of Network Customer’s Average Network Load on
the SPS System
34.4
35
Determination of Transmission Provider's Monthly Transmission System
Load on the SPS Transmission System
34.5 Reserved For Future Use
34.6 Determination of Transmission Provider’s Average Transmission System
Load on the SPS Transmission System
34.7 Redispatch Charge
34.8 Stranded Cost Recovery
34.9 SPS Meter Charge
Operating Arrangements
35.1 Operation under The Network Operating Agreement
35.2 Network Operating Agreement
35.3 Network Operating Committee
IV.
BALANCING AUTHORITY ANCILLARY SERVICES
Preamble
36
Definitions
36.1 Ancillary Service Customer (ASC)
36.2 Ancillary Service Load
36.3 Balancing Authority Area (BAA)
36.4 Balancing Authority (BA) Operator
36.5 Balancing Authority (BA) Services
36.6 Internal Transmission Owner (ITO
36.7 Load Serving Entity (LSE)
36.8 Reserved Capacity
36.9 RMRG
36.10 WECC
37
Nature of Balancing Authority Services
37.1 Requirement to Provide and Obtain BA Services
37.2 Source and Acquisition of BA Services
37.3 Sufficiency of Balancing Authority Services
37.4 Real Power Losses
37.5 Service Agreements
37.6 No Transmission Service Provided
38
Authority and Obligations
38.1 BA Operator Authority
38.2 ASC Obligations
39
Metering
39.1 ASC Obligations
39.2 Metering Data
39.3 Testing
39.4 Meter Failure
39.5 Billing Adjustments
39.6 Examination of Records
39.7 BA Operator Access to Metering Data
40
Billing
V.
JOINT DISPATCH TRANSMISSION SERVICE (Applicable to Public Service
Company of Colorado only)
Preamble
41
Definitions
41.1 Joint Dispatch Arrangement
41.2
41.3
41.4
42
43
Joint Dispatch Agreement
Joint Dispatch Transmission Service
Service Agreement for Joint Dispatch Transmission Service (“Service
Agreement”)
41.5 Joint Dispatch Transmission Service Customer
Nature of Joint Dispatch Transmission Service
42.1 Limited Transmission Provider Responsibilities
42.2 Real Power Losses
42.3 Restrictions on Use of Service
42.4 Imbalance Service
Initiating Service
43.1 Condition Precedent for Receiving Service
43.2 Application Procedures
43.3 Joint Dispatch Transmission Customer Facilities
43.4 Filing of Service Agreement
SCHEDULE 1 SCHEDULE 2 SCHEDULE 3 SCHEDULE 3A -
Scheduling, System Control and Dispatch Service
Reactive Supply and Voltage Control from Generation Sources Service
Regulation and Frequency Response Service
Regulation and Frequency Response Service for Point-To-Point
Transmission Service for the PSCo Balancing Authority Area
SCHEDULE 4 Energy Imbalance Service
SCHEDULE 4A Reserve Sharing Energy Charges
SCHEDULE 4B Reserve Sharing Energy Charges
SCHEDULE 5 Operating Reserve - Spinning Reserve Service
SCHEDULE 6 Operating Reserve - Supplemental Reserve Service
SCHEDULE 6A Flex Reserve Service
SCHEDULE 7 Long-Term Firm and Short-Term Firm Point-To-Point Transmission
Service
SCHEDULE 8 Non-Firm Point-To-Point Transmission Service
SCHEDULE 9 Generator Imbalance Service
SCHEDULE 10 Tax Adjustment Rider for Service by Southwestern Public Service
Company
SCHEDULE 11 Reserved For Future Use
SCHEDULE 12 Midwest Independent Transmission System Operator, Inc. Charges
SCHEDULE 13 Network Integration Transmission Service on the PSCo Transmission
System
SCHEDULE 13A Network Integration Transmission Service across the Lamar Tie Line
SCHEDULE 14 Point-to-Point Transmission Losses on the PSCo Transmission
System
SCHEDULE 15 Joint Dispatch Transmission Service
ATTACHMENT A-1 - Form of Service Agreement For Short-Term Firm Point-To-Point
Transmission Service
ATTACHMENT A-2 - Form of Service Agreement For Long-Term Firm Point-To-Point
Transmission Service
ATTACHMENT A-3 - Form of Service Agreement For The Resale, Reassignment Or Transfer
Of Point-To-Point Transmission Service
ATTACHMENT B - Form of Service Agreement For Non-Firm Point-To-Point Transmission
Service
ATTACHMENT C - Methodology To Assess Available Transfer Capability
ATTACHMENT D ATTACHMENT E ATTACHMENT F -
Methodology for Completing a System Impact Study
Index of Point-To-Point Transmission Service Customers
Form of Service Agreement For Network Integration Transmission
Service
ATTACHMENT G - Form of Network Operating Agreement
ATTACHMENT H - Annual Transmission Revenue Requirement For Network Integration
Transmission Service
ATTACHMENT I Index of Network Integration Transmission Service Customers
ATTACHMENT J - Procedures for Addressing Parallel Flows
ATTACHMENT K - Form of System Impact Study Agreement
ATTACHMENT L - Form of Facilities Study Agreement
ATTACHMENT M - Methodology for Allocating Transmission Revenues Among Utility
Operating Companies
ATTACHMENT N - Standard Large Generator Interconnection Procedures (LGIP) Applicable to Generating Facilities that exceed 20 MWs
ATTACHMENT O - Public Service Company of Colorado Formulaic Rates
ATTACHMENT O – SPS - Southwestern Public Service Company Formulaic Rates
ATTACHMENT P - Standard Small Generator Interconnection Procedures (SGIP) Applicable to Generating Facilities less than 20 MWs
ATTACHMENT Q - Creditworthiness Procedures
ATTACHMENT R – PSCo - Transmission Planning Process
ATTACHMENT S - Reserved For Future Use
ATTACHMENT T - Form of Service Agreement For Balancing Authority Ancillary Services
Applicable to the Public Service Company of Colorado (PSCo) System
ATTACHMENT U - Form of Service Agreement For Transmission to Load Interconnection
Service
ATTACHMENT V - Form of Service Agreement For Joint Dispatch Transmission Service
ATTACHMENT AA – Service Agreements For Point-To-Point Transmission Service
ATTACHMENT BB – Service Agreements For Network Transmission Service
ATTACHMENT CC – Service Agreements For Generation Interconnection Service
ATTACHMENT DD – Service Agreements For Balancing Authority Ancillary Services
ATTACHMENT EE - Reserved For Future Use
ATTACHMENT FF – Service Agreements For Transmission to Load Interconnection Service
Additional Volumes of
Xcel Energy Operating Companies
Transmission Service Tariffs
Volume No.
Contents
Joint Open Access Transmission Tariff
Original Volume 2
Reserved for Future Use
FERC Electric Transmission Tariff
Original Volume 3
Northern States Power Company transmission rate
schedules
Original Volume 4
Northern States Power Company (Wisconsin) transmission
rate schedules
Original Volume 5
Public Service Company of Colorado transmission rate
schedules
Original Volume 6
Southwestern Public Service Company) transmission rate
schedules
Original Volume 7
WestConnect Point-to-Point Regional Transmission Service
Experiment Tariff
Note: The noted tariff volumes contain transmission-related rate schedules filed by the
Transmission Services function of the Xcel Energy Operating Companies.
Rate schedules related to electric supply services may be found in the Electric Services Tariffs
separately maintained by the Xcel Energy Markets function.
V.
JOINT DISPATCH TRANSMISSION SERVICE (Applicable to Public Service
Company of Colorado only)
Preamble
Service under Part V shall be applicable only to load serving entities in the PSCo
Balancing Authority Area that are signatories to a Joint Dispatch Agreement (JDA) under
which: (1) participating generating resources of the parties are dispatched as a pool on
a least-cost basis respecting transmission limitations; (2) the Joint Dispatch
Transmission Service Customers’ respective transmission service providers have
provided within their OATT a transmission service schedule for energy dispatched
pursuant to the JDA at a rate equal to zero dollars on a non-firm, as-available basis with
the lowest curtailment priority, pursuant to the provisions of this Part V of the Tariff.
41
Definitions
In addition to the Definitions and Terms set forth in the Common Service Provisions
found in Part 1 of this Tariff, the following definitions shall apply to this Part V, the Joint
Dispatch Services set forth in Schedule 15 and Attachment V of this Tariff.
42
41.1
Joint Dispatch Arrangement: An operating arrangement whereby participating
generation resources owned, operated or controlled by load serving entities
within the PSCo Balancing Authority Area are dispatched as a pool on a leastcost basis respecting transmission limitations in order to economically optimize
dispatch on an aggregate real-time basis among all participants in the Joint
Dispatch Arrangement.
41.2
Joint Dispatch Agreement: An agreement detailing the rights and obligations
of participants in a Joint Dispatch Arrangement.
41.3
Joint Dispatch Transmission Service: Non-firm transmission service across
transmission facilities of the Transmission Provider that is used to transmit
energy dispatched pursuant to a Joint Dispatch Agreement and that is subject to
the provisions of this Part V of the Tariff. Joint Dispatch Transmission Service
will be made available from posted ATC after procurement and scheduling
deadlines have passed for the current operating hour, as specified in the
Transmission Provider’s Business Practices posted on OASIS.
41.4
Service Agreement for Joint Dispatch Transmission Service (“Service
Agreement”): An agreement between the Transmission Provider and a Joint
Dispatch Transmission Service Customer for Joint Dispatch Transmission
Service.
41.5
Joint Dispatch Transmission Service Customer: Any entity (or its Designated
Agent) that: (i) executes a Service Agreement; or (ii) requests in writing that the
Transmission Provider file with the Commission a proposed unexecuted Service
Agreement.
Nature of Joint Dispatch Transmission Service
Joint Dispatch Transmission Service is an optional service available to any load serving
entity in the PSCo Balancing Authority Area that: (1) has entered into a Joint Dispatch
Agreement; and (2) makes Joint Dispatch Transmission Service on its transmission
system, if any, available to PSCo and all other parties to the Joint Dispatch Agreement
at the same rate, terms, and conditions as set out in this Part V of the Tariff and related
schedules and attachments. As further detailed herein, Joint Dispatch Transmission
Service may only be used to deliver energy dispatched under a Joint Dispatch
Agreement to the entity’s wholesale and retail native load customers. Joint Dispatch
Transmission Service is provided only on a non-firm, as available basis and has the
lowest curtailment priority.
42.1
Limited Transmission Provider Responsibilities. The Transmission Provider
shall have the obligation to operate its Transmission System in accordance with
Good Utility Practice. For purposes of Joint Dispatch Transmission Service, the
Transmission Provider shall have no obligation to plan, construct, or maintain its
Transmission System for the benefit of any Joint Dispatch Transmission Service
Customer.
42.2
Real Power Losses. Real Power Losses are associated with all transmission
service. The Joint Dispatch Transmission Service Customer shall be responsible
for all losses associated with Joint Dispatch Transmission Service, which
responsibility shall be manifested as the difference between the amount of
energy dispatched on behalf of the Joint Dispatch Transmission Service
Customer and the amount of energy actually delivered to such customer based
on the following loss factors.
PRPA
Seller
Buyer
PRPA
PSCo
BHCE
PRPA
PRPA+PSCo
PSCo
BHCE
PSCo
PSCo+BHCE
BHCE
PSCo
Where:
PRPA= Loss Factor set forth in PRPA’s OATT Section 15.7 (where PRPA’s Loss
Factor 1.7% as of January 1, 2015)
PSCo=Loss Factor set forth in PSCo OATT Section 15.7 (where PSCo’s Loss
Factor is 2.56% as of January 1, 2015)
BHCE= Loss Factor set forth in BHCE OATT Section 15.7 (BHCE’s Loss Factor
is 1.94% as of January 1, 2015)
42.3
Restrictions on Use of Service. The Joint Dispatch Transmission Service
Customer shall not use Joint Dispatch Transmission Service for (i) off-system
sales of capacity or energy or (ii) direct or indirect provision of transmission
service by the Joint Dispatch Transmission Service Customer to any third party.
Joint Dispatch Transmission Service may be used only for receipt or delivery of
energy dispatched within the PSCo Balancing Authority Area on a non-firm basis
to serve wholesale or retail native load of any participant in a Joint Dispatch
Agreement.
42.4
43
Imbalance Service. The purpose of the Joint Dispatch Arrangement is to
balance loads and resources of the parties by optimizing dispatch of the parties’
resources. As a result, the Transmission Provider shall not assess energy
imbalance charges under Ancillary Service Schedule 4 or 9 to any Joint Dispatch
Transmission Service Customer.
Initiating Service
43.1
Condition Precedent for Receiving Service. Subject to the terms and
conditions of this Part V of the Tariff, and related schedules and attachments, the
Transmission Provider will provide Joint Dispatch Transmission Service to any
eligible customer, provided that (i) the eligible customer has wholesale or retail
native load in the Transmission Provider’s Balancing Authority Area; (ii) the
eligible customer has entered into a Joint Dispatch Agreement; (iii) the eligible
customer’s transmission provider has a transmission service tariff offering Joint
Dispatch Transmission Service on the same terms and conditions as offered
under this Part V of the Tariff, and related schedules and attachments; and (iv)
the eligible customer executes a Service Agreement pursuant to Attachment V
for service under this Part V of the Tariff or requests in writing that the
Transmission Provider file a proposed unexecuted Service Agreement with the
Commission.
43.2
Application Procedures. An Eligible Customer requesting service under Part V
of this Tariff must submit an application containing the information specified
below. No deposit or credit evaluation is necessary to obtain Joint Dispatch
Transmission Service. Further, no transmission studies shall be required to
obtain Joint Dispatch Transmission Service because such service is provided
only on a non-firm, as available basis. Applications should be submitted to the
Transmission Provider via e-mail to the person(s) listed on OASIS. Application
contents:
(i)
(ii)
(iii)
(iv)
(v)
(vi)
(vii)
The identity, address, telephone number and facsimile number of the
party requesting service;
A statement that the party requesting service is, or will be upon
commencement of service, an Eligible Customer under the tariff;
A statement that the party requesting service has, or will have upon
commencement of service, wholesale or retail native load in the PSCo
Balancing Authority Area;
A statement that the party requesting service has, or will have upon
commencement of service, entered into a Joint Dispatch Agreement with
PSCo;
A statement that the party requesting service has, or will have upon
commencement of service, a tariff offering Joint Dispatch Transmission
Service at the same rates, terms, and conditions as this Part V of the
Tariff and associated schedules and attachments;
Service Commencement Date and the term of the requested Joint
Dispatch Transmission Service.
A statement signed by an authorized officer from or agent of the Joint
Dispatch Transmission Service Customer attesting that Joint Dispatch
(viii)
Transmission Service will be used only for receipt or delivery of energy
dispatched under a Joint Dispatch Agreement for the benefit of that
customer’s wholesale and retail native load customers.
Service is conditioned on the Transmission Provider being in receipt of an
executed Joint Dispatch Agreement.
Unless the Parties agree to a different timeframe, the Transmission Provider
must acknowledge the request within ten (15) days of receipt. The
acknowledgement must include a date by which a response, including a Service
Agreement, will be sent to the Eligible Customer. If an application fails to meet
the requirements of this section, the Transmission Provider shall notify the
Eligible Customer requesting service within fifteen (15) days of receipt and
specify the reasons for such failure. Wherever reasonably possible, the
Transmission Provider will attempt to remedy deficiencies in the Application
through informal communications with the Eligible Customer. If efforts are
unsuccessful, the Transmission Provider shall return the Application, without
prejudice to the Eligible Customer filing a new or revised Application that fully
complies with the requirements of this section.
43.3
Joint Dispatch Transmission Customer Facilities: The Joint Dispatch
Transmission Service Customer’s transmission provider will retain its existing
obligations to plan, construct, operate and maintain its transmission system using
standard utility practices.
43.4
Filing of Service Agreement. The Transmission Provider will file Service
Agreements with the Commission in compliance with applicable Commission
regulations, if any.
Schedule 15
Joint Dispatch Transmission Service
This is an optional service provided by PSCo, subject to the terms and conditions of Part
V of this Tariff. For Joint Dispatch Transmission Service Customers meeting the
conditions set forth in Part V of this Tariff, no charge shall be assessed for receipt or
delivery of energy dispatched pursuant to a Joint Dispatch Agreement with PSCo
provided the customer makes Joint Dispatch Transmission Service available to PSCo at
the same rates, terms, and conditions as set forth in Part V of this Tariff, this Schedule
15, and any other related schedules or attachments to this Tariff. Joint Dispatch
Transmission Service is provided in real-time on a non-firm, as available basis having
the lowest curtailment priority.
1) Monthly delivery: the rate or $0.00/kW-month of Reserved Capacity.
2) Weekly delivery: the rate $0.00/kW-week of Reserved Capacity.
3) Daily delivery: the rate $0.00/kW-day of Reserved Capacity.
4) Hourly delivery: On-Peak Hours: the on-peak rate $0.00/MWh of Reserved Capacity.
Off-Peak Hours: the off-peak rate $0.00/MWh of Reserved Capacity.
ATTACHMENT V
Form of Service Agreement For Joint Dispatch Transmission Service Applicable to the
Public Service Company of Colorado (PSCo) System
1.0
This
Joint
Dispatch
Transmission
Service
Agreement,
dated
as
of
__________________________,
is
entered
into,
by and between __________________________ (“Transmission Provider”),
and __________________________ ("Joint Dispatch Transmission Customer"),
all of whom may be referred to individually as “Party” or jointly as “Parties”.
2.0
The Joint Dispatch Transmission Customer has been determined by the Transmission
Provider to have a signed a Joint Dispatch Agreement.
3.0
Service under this agreement shall commence on the later of (1) the requested service
commencement date, or (2) such other date as it is permitted to become effective by the
Commission. Service under this agreement shall terminate on such date as mutually
agreed upon by the parties.
4.0
Any notice or request made to or by either Party regarding this Service Agreement shall
be made to the representative of the other Party as indicated below.
Transmission Provider:
_____________________________________
_____________________________________
_____________________________________
Transmission Customer:
_____________________________________
_____________________________________
_____________________________________
5.0
The Tariff is incorporated herein and made a part hereof.
IN WITNESS WHEREOF, the Parties have caused this Service Agreement to be executed by
their respective authorized officials.
Transmission Provider:
By:
___________________ ___________________ ___________________
Name
Title
Date
Transmission Customer:
By:
___________________ ___________________ ___________________
Name
Title
Date
EXHIBIT 3
Xcel Energy Operating Companies
FERC Electric Tariff, Second Revised Volume No. 1
TABLE OF CONTENTS Version: 0.4.0 Effective: 1/1/2015
TABLE OF CONTENTS
I.
COMMON SERVICE PROVISIONS
1
Definitions
1.1
Affiliate
1.2
Ancillary Services
1.3
Annual Transmission Costs
1.4
Application
1.5
Commission
1.6
Completed Application
1.7
Control Area
1.8
Curtailment
1.9
Delivering Party
1.10 Designated Agent
1.11 Direct Assignment Facilities
1.12 Eligible Customer
1.13 Facilities Study
1.14 Firm Point-To-Point Transmission Service
1.15 Good Utility Practice
1.16 Interruption
1.17 Load Ratio Share
1.18 Load Shedding
1.19 Long-Term Firm Point-To-Point Transmission Service
1.20 Native Load Customers
1.21 NERC TLR Procedures
1.22 Network Customer
1.23 Network Integration Transmission Service
1.24 Network Load
1.25 Network Operating Agreement
1.26 Network Operating Committee
1.27 Network Resource
1.28 Network Upgrades
1.29 Non-Firm Point-To-Point Transmission Service
1.30 Non-Firm Sale
1.31 Non-Variable Energy Resource
1.32 Open Access Same-Time Information System (OASIS)
1.33 Part I
1.34 Part II
1.35 Part III
1.35A Part IV
1.36 Parties
1.37 Point(s) of Delivery
1.38 Point(s) of Receipt
1.39 Point-To-Point Transmission Service
1.40 Power Purchaser
1.41 Pre-Confirmed Application
1.42 Receiving Party
1.43 Regional Transmission Group (RTG)
1.44 Reserved Capacity
Page No. 1
Xcel Energy Operating Companies
FERC Electric Tariff, Second Revised Volume No. 1
2
3
4
5
6
7
8
9
10
11
12
Page No. 2
1.45 Service Agreement
1.46 Service Commencement Date
1.47 Short-Term Firm Point-To-Point Transmission Service
1.48 System Condition
1.49 System Impact Study
1.50 Third-Party Sale
1.51 Transmission Customer
1.52 Transmission Provider
1.53 Transmission Provider's Monthly Transmission System Peak
1.54 Transmission Service
1.55 Transmission System
1.56 Variable Energy Resource
Initial Allocation and Renewal Procedures
2.1
Initial Allocation of Available Transfer Capability
2.2
Reservation Priority For Existing Firm Service Customers
Ancillary Services
3.1
Scheduling, System Control and Dispatch Service
3.2
Reactive Supply and Voltage Control from Generation or Other Sources
Service
3.3
Regulation and Frequency Response Service
3.4
Energy Imbalance Service
3.5
Operating Reserve - Spinning Reserve Service
3.6
Operating Reserve - Supplemental Reserve Service
3.7
Flex Reserve Service
3.8
Generator Imbalance Service
Open Access Same-Time Information System (OASIS)
4.1
Terms and Conditions
4.2
NAESB WEQ Business Practice Standards
Local Furnishing Bonds
5.1
Transmission Providers That Own Facilities Financed by Local Furnishing
Bonds
5.2
Alternative Procedures for Requesting Transmission Service
Reciprocity
Billing and Payment
7.1
Billing Procedure
7.2
Interest on Unpaid Balances
7.3
Customer Default
Accounting for the Transmission Provider's Use of the Tariff
8.1
Transmission Revenues
8.2
Study Costs and Revenues
Regulatory Filings
Force Majeure and Indemnification
10.1 Force Majeure
10.2 Indemnification
Creditworthiness
Dispute Resolution Procedures
12.1 Internal Dispute Resolution Procedures
12.2 Mediation Procedures
12.3 External Arbitration Procedures
12.4 Arbitration Decisions
12.5 Costs
Xcel Energy Operating Companies
FERC Electric Tariff, Second Revised Volume No. 1
12.6
II.
Page No. 3
Rights Under The Federal Power Act
POINT-TO-POINT TRANSMISSION SERVICE
Preamble
13
Nature of Firm Point-To-Point Transmission Service
13.1 Term
13.2 Reservation Priority
13.3 Use of Firm Transmission Service by the Transmission Provider
13.4 Service Agreements
13.5 Transmission Customer Obligations for Facility Additions or Redispatch
Costs
13.6 Curtailment of Firm Transmission Service
13.7 Classification of Firm Transmission Service
13.8.1 Scheduling of Firm Point-To-Point Transmission Service on the PSCo
System
13.8.2 Scheduling of Firm Point-To-Point Transmission Service on the NSP and
SPS Systems
14
Nature of Non-Firm Point-To-Point Transmission Service
14.1 Term
14.2 Reservation Priority
14.3 Use of Non-Firm Point-To-Point Transmission Service by the
Transmission Provider
14.4 Service Agreements
14.5 Classification of Non-Firm Point-To-Point Transmission Service
14.6.1 Scheduling of Non-Firm Point-To-Point Transmission Service on the
PSCo System
14.6.2 Scheduling of Non-Firm Point-To-Point Transmission Service on the NSP
and SPS Systems
14.7 Curtailment or Interruption of Service
15
Service Availability
15.1 General Conditions
15.2 Determination of Available Transfer Capability
15.3 Initiating Service in the Absence of an Executed Service Agreement
15.4 Obligation to Provide Transmission Service that Requires Expansion or
Modification of the Transmission System, Redispatch or Conditional
Curtailment
15.5 Deferral of Service
15.6 Other Transmission Service Schedules
15.7 Real Power Losses
16
Transmission Customer Responsibilities
16.1 Conditions Required of Transmission Customers
16.2 Transmission Customer Responsibility for Third-Party Arrangements
17
Procedures for Arranging Firm Point-To-Point Transmission Service
17.1 Application
17.2 Completed Application
17.3 Deposit
17.4 Notice of Deficient Application
17.5 Response to a Completed Application
17.6 Execution of Service Agreement
17.7 Extensions for Commencement of Service
18
Procedures for Arranging Non-Firm Point-To-Point Transmission Service
Xcel Energy Operating Companies
FERC Electric Tariff, Second Revised Volume No. 1
19
20
21
22
23
24
25
26
27
III.
Page No. 4
18.1 Application
18.2 Completed Application
18.3.1 Reservation of Non-Firm Point-To-Point Transmission Service on the
PSCo System
18.3.2 Reservation of Non-Firm Point-To-Point Transmission Service on the
NSP and SPS Systems
18.4 Determination of Available Transfer Capability
Additional Study Procedures For Firm Point-To-Point Transmission Service
Requests
19.1 Notice of Need for System Impact Study
19.2 System Impact Study Agreement and Cost Reimbursement
19.3 System Impact Study Procedures
19.4.1 Facilities Study Procedures
19.4.2 Clustered Transmission Service Requests
19.5 Facilities Study Modifications
19.6 Due Diligence in Completing New Facilities
19.7 Partial Interim Service
19.8 Expedited Procedures for New Facilities
19.9 Penalties For Failure to Meet Study Deadlines
Procedures if The Transmission Provider is Unable to Complete New
Transmission Facilities for Firm Point-To-Point Transmission Service
20.1 Delays in Construction of New Facilities
20.2 Alternatives to the Original Facility Additions
20.3 Refund Obligation for Unfinished Facility Additions
Provisions Relating to Transmission Construction and Services on the
Systems of Other Utilities
21.1 Responsibility for Third-Party System Additions
21.2 Coordination of Third-Party System Additions
Changes in Service Specifications
22.1 Modifications On a Non-Firm Basis
22.2 Modification On a Firm Basis
Sale or Assignment of Transmission Service
23.1 Procedures for Assignment or Transfer of Service
23.2 Limitations on Assignment or Transfer of Service
23.3 Information on Assignment or Transfer of Service
Metering and Power Factor Correction at Receipt and Delivery Points(s)
24.1 Transmission Customer Obligations
24.2 Transmission Provider Access to Metering Data
24.3 Power Factor
Compensation for Transmission Service
Stranded Cost Recovery
Compensation for New Facilities and Redispatch Costs
NETWORK INTEGRATION TRANSMISSION SERVICE
Preamble
28
Nature of Network Integration Transmission Service
28.1 Scope of Service
28.2 Transmission Provider Responsibilities
28.3 Network Integration Transmission Service
28.4 Secondary Service
28.5 Real Power Losses
Xcel Energy Operating Companies
FERC Electric Tariff, Second Revised Volume No. 1
29
30
31
32
33
34
Page No. 5
28.6 Restrictions on Use of Service
Initiating Service
29.1 Condition Precedent for Receiving Service
29.2 Application Procedures:
29.3 Technical Arrangements to be Completed Prior to Commencement of
Service
29.4 Network Customer Facilities
29.5 Filing of Service Agreement
Network Resources
30.1 Designation of Network Resources
30.2 Designation of New Network Resources
30.3 Termination of Network Resources
30.4 Operation of Network Resources
30.5 Network Customer Redispatch Obligation
30.6 Transmission Arrangements for Network Resources Not
Physically Interconnected With The Transmission Provider
30.7 Limitation on Designation of Network Resources
30.8 Use of Interface Capacity by the Network Customer
30.9 Network Customer Owned Transmission Facilities
Designation of Network Load
31.1 Network Load
31.2 New Network Loads Connected With the Transmission Provider
31.3 Network Load Not Physically Interconnected with the Transmission
Provider
31.4 New Interconnection Points
31.5 Changes in Service Requests
31.6 Annual Load and Resource Information Updates
Additional Study Procedures For Network Integration Transmission Service
Requests
32.1 Notice of Need for System Impact Study
32.2 System Impact Study Agreement and Cost Reimbursement
32.3 System Impact Study Procedures
32.4.1 Facilities Study Procedures
32.4.2 Clustered Transmission Service Requests
32.5 Penalties For Failure to Meet Study Deadlines
Load Shedding and Curtailments
33.1.1 Procedures on the PSCo System
33.1.2 Procedures on the NSP and SPS Systems
33.2 Transmission Constraints
33.3 Cost Responsibility for Relieving Transmission Constraints
33.4 Curtailments of Scheduled Deliveries
33.5 Allocation of Curtailments
33.6 Load Shedding
33.7 System Reliability
Rates and Charges
34.1.1 Monthly Demand Charge on the SPS Transmission System
34.1.2 Monthly Demand Charge on the PSCo Transmission System
34.2 Determination of Network Customer's Monthly Network Load
34.3 Determination of Network Customer’s Average Network Load on
the SPS System
Xcel Energy Operating Companies
FERC Electric Tariff, Second Revised Volume No. 1
Page No. 6
34.4
35
Determination of Transmission Provider's Monthly Transmission System
Load on the SPS Transmission System
34.5 Reserved For Future Use
34.6 Determination of Transmission Provider’s Average Transmission System
Load on the SPS Transmission System
34.7 Redispatch Charge
34.8 Stranded Cost Recovery
34.9 SPS Meter Charge
Operating Arrangements
35.1 Operation under The Network Operating Agreement
35.2 Network Operating Agreement
35.3 Network Operating Committee
IV.
BALANCING AUTHORITY ANCILLARY SERVICES
Preamble
36
Definitions
36.1 Ancillary Service Customer (ASC)
36.2 Ancillary Service Load
36.3 Balancing Authority Area (BAA)
36.4 Balancing Authority (BA) Operator
36.5 Balancing Authority (BA) Services
36.6 Internal Transmission Owner (ITO
36.7 Load Serving Entity (LSE)
36.8 Reserved Capacity
36.9 RMRG
36.10 WECC
37
Nature of Balancing Authority Services
37.1 Requirement to Provide and Obtain BA Services
37.2 Source and Acquisition of BA Services
37.3 Sufficiency of Balancing Authority Services
37.4 Real Power Losses
37.5 Service Agreements
37.6 No Transmission Service Provided
38
Authority and Obligations
38.1 BA Operator Authority
38.2 ASC Obligations
39
Metering
39.1 ASC Obligations
39.2 Metering Data
39.3 Testing
39.4 Meter Failure
39.5 Billing Adjustments
39.6 Examination of Records
39.7 BA Operator Access to Metering Data
40
Billing
V.
JOINT DISPATCH TRANSMISSION SERVICE (Applicable to Public Service
Company of Colorado only)
Preamble
41
Definitions
41.1 Joint Dispatch Arrangement
Xcel Energy Operating Companies
FERC Electric Tariff, Second Revised Volume No. 1
Page No. 7
41.2
41.3
41.4
42
43
Joint Dispatch Agreement
Joint Dispatch Transmission Service
Service Agreement for Joint Dispatch Transmission Service (“Service
Agreement”)
41.5 Joint Dispatch Transmission Service Customer
Nature of Joint Dispatch Transmission Service
42.1 Limited Transmission Provider Responsibilities
42.2 Real Power Losses
42.3 Restrictions on Use of Service
42.4 Imbalance Service
Initiating Service
43.1 Condition Precedent for Receiving Service
43.2 Application Procedures
43.3 Joint Dispatch Transmission Customer Facilities
43.4 Filing of Service Agreement
SCHEDULE 1 SCHEDULE 2 SCHEDULE 3 SCHEDULE 3A -
Scheduling, System Control and Dispatch Service
Reactive Supply and Voltage Control from Generation Sources Service
Regulation and Frequency Response Service
Regulation and Frequency Response Service for Point-To-Point
Transmission Service for the PSCo Balancing Authority Area
SCHEDULE 4 Energy Imbalance Service
SCHEDULE 4A Reserve Sharing Energy Charges
SCHEDULE 4B Reserve Sharing Energy Charges
SCHEDULE 5 Operating Reserve - Spinning Reserve Service
SCHEDULE 6 Operating Reserve - Supplemental Reserve Service
SCHEDULE 6A Flex Reserve Service
SCHEDULE 7 Long-Term Firm and Short-Term Firm Point-To-Point Transmission
Service
SCHEDULE 8 Non-Firm Point-To-Point Transmission Service
SCHEDULE 9 Generator Imbalance Service
SCHEDULE 10 Tax Adjustment Rider for Service by Southwestern Public Service
Company
SCHEDULE 11 Reserved For Future Use
SCHEDULE 12 Midwest Independent Transmission System Operator, Inc. Charges
SCHEDULE 13 Network Integration Transmission Service on the PSCo Transmission
System
SCHEDULE 13A Network Integration Transmission Service across the Lamar Tie Line
SCHEDULE 14 Point-to-Point Transmission Losses on the PSCo Transmission
System
SCHEDULE 15 Joint Dispatch Transmission Service
ATTACHMENT A-1 - Form of Service Agreement For Short-Term Firm Point-To-Point
Transmission Service
ATTACHMENT A-2 - Form of Service Agreement For Long-Term Firm Point-To-Point
Transmission Service
ATTACHMENT A-3 - Form of Service Agreement For The Resale, Reassignment Or Transfer
Of Point-To-Point Transmission Service
ATTACHMENT B - Form of Service Agreement For Non-Firm Point-To-Point Transmission
Service
ATTACHMENT C - Methodology To Assess Available Transfer Capability
Xcel Energy Operating Companies
FERC Electric Tariff, Second Revised Volume No. 1
ATTACHMENT D ATTACHMENT E ATTACHMENT F -
Page No. 8
Methodology for Completing a System Impact Study
Index of Point-To-Point Transmission Service Customers
Form of Service Agreement For Network Integration Transmission
Service
ATTACHMENT G - Form of Network Operating Agreement
ATTACHMENT H - Annual Transmission Revenue Requirement For Network Integration
Transmission Service
ATTACHMENT I Index of Network Integration Transmission Service Customers
ATTACHMENT J - Procedures for Addressing Parallel Flows
ATTACHMENT K - Form of System Impact Study Agreement
ATTACHMENT L - Form of Facilities Study Agreement
ATTACHMENT M - Methodology for Allocating Transmission Revenues Among Utility
Operating Companies
ATTACHMENT N - Standard Large Generator Interconnection Procedures (LGIP) Applicable to Generating Facilities that exceed 20 MWs
ATTACHMENT O - Public Service Company of Colorado Formulaic Rates
ATTACHMENT O – SPS - Southwestern Public Service Company Formulaic Rates
ATTACHMENT P - Standard Small Generator Interconnection Procedures (SGIP) Applicable to Generating Facilities less than 20 MWs
ATTACHMENT Q - Creditworthiness Procedures
ATTACHMENT R – PSCo - Transmission Planning Process
ATTACHMENT S - Reserved For Future Use
ATTACHMENT T - Form of Service Agreement For Balancing Authority Ancillary Services
Applicable to the Public Service Company of Colorado (PSCo) System
ATTACHMENT U - Form of Service Agreement For Transmission to Load Interconnection
Service
ATTACHMENT V - Form of Service Agreement For Joint Dispatch Transmission Service
ATTACHMENT AA – Service Agreements For Point-To-Point Transmission Service
ATTACHMENT BB – Service Agreements For Network Transmission Service
ATTACHMENT CC – Service Agreements For Generation Interconnection Service
ATTACHMENT DD – Service Agreements For Balancing Authority Ancillary Services
ATTACHMENT EE - Reserved For Future Use
ATTACHMENT FF – Service Agreements For Transmission to Load Interconnection Service
Xcel Energy Operating Companies
FERC Electric Tariff, Second Revised Volume No. 1
Page No. 9
Additional Volumes of
Xcel Energy Operating Companies
Transmission Service Tariffs
Volume No.
Contents
Joint Open Access Transmission Tariff
Original Volume 2
Reserved for Future Use
FERC Electric Transmission Tariff
Original Volume 3
Northern States Power Company transmission rate
schedules
Original Volume 4
Northern States Power Company (Wisconsin) transmission
rate schedules
Original Volume 5
Public Service Company of Colorado transmission rate
schedules
Original Volume 6
Southwestern Public Service Company) transmission rate
schedules
Original Volume 7
WestConnect Point-to-Point Regional Transmission Service
Experiment Tariff
Note: The noted tariff volumes contain transmission-related rate schedules filed by the
Transmission Services function of the Xcel Energy Operating Companies.
Rate schedules related to electric supply services may be found in the Electric Services Tariffs
separately maintained by the Xcel Energy Markets function.
Xcel Energy Operating Companies
FERC Electric Tariff, Second Revised Volume No. 1
Page No. 10
Part V Joint Dispatch Trans Svc Version: 0.0.0 Effective: 1/1/2015
V.
JOINT DISPATCH TRANSMISSION SERVICE (Applicable to Public Service
Company of Colorado only)
Preamble
Service under Part V shall be applicable only to load serving entities in the PSCo
Balancing Authority Area that are signatories to a Joint Dispatch Agreement (JDA) under
which: (1) participating generating resources of the parties are dispatched as a pool on
a least-cost basis respecting transmission limitations; (2) the Joint Dispatch
Transmission Service Customers’ respective transmission service providers have
provided within their OATT a transmission service schedule for energy dispatched
pursuant to the JDA at a rate equal to zero dollars on a non-firm, as-available basis with
the lowest curtailment priority, pursuant to the provisions of this Part V of the Tariff.
Xcel Energy Operating Companies
FERC Electric Tariff, Second Revised Volume No. 1
Page No. 11
41 Definitions Version: 0.0.0 Effective: 1/1/2015
41
Definitions
In addition to the Definitions and Terms set forth in the Common Service Provisions
found in Part 1 of this Tariff, the following definitions shall apply to this Part V, the Joint
Dispatch Services set forth in Schedule 15 and Attachment V of this Tariff.
41.1
Joint Dispatch Arrangement: An operating arrangement whereby participating
generation resources owned, operated or controlled by load serving entities
within the PSCo Balancing Authority Area are dispatched as a pool on a leastcost basis respecting transmission limitations in order to economically optimize
dispatch on an aggregate real-time basis among all participants in the Joint
Dispatch Arrangement.
41.2
Joint Dispatch Agreement: An agreement detailing the rights and obligations
of participants in a Joint Dispatch Arrangement.
41.3
Joint Dispatch Transmission Service: Non-firm transmission service across
transmission facilities of the Transmission Provider that is used to transmit
energy dispatched pursuant to a Joint Dispatch Agreement and that is subject to
the provisions of this Part V of the Tariff. Joint Dispatch Transmission Service
will be made available from posted ATC after procurement and scheduling
deadlines have passed for the current operating hour, as specified in the
Transmission Provider’s Business Practices posted on OASIS.
41.4
Service Agreement for Joint Dispatch Transmission Service (“Service
Agreement”): An agreement between the Transmission Provider and a Joint
Dispatch Transmission Service Customer for Joint Dispatch Transmission
Service.
41.5
Joint Dispatch Transmission Service Customer: Any entity (or its Designated
Agent) that: (i) executes a Service Agreement; or (ii) requests in writing that the
Transmission Provider file with the Commission a proposed unexecuted Service
Agreement.
Xcel Energy Operating Companies
FERC Electric Tariff, Second Revised Volume No. 1
Page No. 12
42 Nat of Joint Dispatch Trans Svc Version: 0.0.0 Effective: 1/1/2015
42
Nature of Joint Dispatch Transmission Service
Joint Dispatch Transmission Service is an optional service available to any load serving
entity in the PSCo Balancing Authority Area that: (1) has entered into a Joint Dispatch
Agreement; and (2) makes Joint Dispatch Transmission Service on its transmission
system, if any, available to PSCo and all other parties to the Joint Dispatch Agreement
at the same rate, terms, and conditions as set out in this Part V of the Tariff and related
schedules and attachments. As further detailed herein, Joint Dispatch Transmission
Service may only be used to deliver energy dispatched under a Joint Dispatch
Agreement to the entity’s wholesale and retail native load customers. Joint Dispatch
Transmission Service is provided only on a non-firm, as available basis and has the
lowest curtailment priority.
42.1
Limited Transmission Provider Responsibilities. The Transmission Provider
shall have the obligation to operate its Transmission System in accordance with
Good Utility Practice. For purposes of Joint Dispatch Transmission Service, the
Transmission Provider shall have no obligation to plan, construct, or maintain its
Transmission System for the benefit of any Joint Dispatch Transmission Service
Customer.
42.2
Real Power Losses. Real Power Losses are associated with all transmission
service. The Joint Dispatch Transmission Service Customer shall be responsible
for all losses associated with Joint Dispatch Transmission Service, which
responsibility shall be manifested as the difference between the amount of
energy dispatched on behalf of the Joint Dispatch Transmission Service
Customer and the amount of energy actually delivered to such customer based
on the following loss factors.
PRPA
Seller
Buyer
PRPA
PSCo
BHCE
PRPA
PRPA+PSCo
PSCo
BHCE
PSCo
PSCo+BHCE
BHCE
PSCo
Where:
PRPA= Loss Factor set forth in PRPA’s OATT Section 15.7 (where PRPA’s Loss
Factor 1.7% as of January 1, 2015)
PSCo=Loss Factor set forth in PSCo OATT Section 15.7 (where PSCo’s Loss
Factor is 2.56% as of January 1, 2015)
BHCE= Loss Factor set forth in BHCE OATT Section 15.7 (BHCE’s Loss Factor
is 1.94% as of January 1, 2015)
42.3
Restrictions on Use of Service. The Joint Dispatch Transmission Service
Customer shall not use Joint Dispatch Transmission Service for (i) off-system
sales of capacity or energy or (ii) direct or indirect provision of transmission
service by the Joint Dispatch Transmission Service Customer to any third party.
Xcel Energy Operating Companies
FERC Electric Tariff, Second Revised Volume No. 1
Page No. 13
Joint Dispatch Transmission Service may be used only for receipt or delivery of
energy dispatched within the PSCo Balancing Authority Area on a non-firm basis
to serve wholesale or retail native load of any participant in a Joint Dispatch
Agreement.
42.4
Imbalance Service. The purpose of the Joint Dispatch Arrangement is to
balance loads and resources of the parties by optimizing dispatch of the parties’
resources. As a result, the Transmission Provider shall not assess energy
imbalance charges under Ancillary Service Schedule 4 or 9 to any Joint Dispatch
Transmission Service Customer.
Xcel Energy Operating Companies
FERC Electric Tariff, Second Revised Volume No. 1
Page No. 14
43 Initiating Svc Version: 0.0.0 Effective: 1/1/2015
43
Initiating Service
43.1
Condition Precedent for Receiving Service. Subject to the terms and
conditions of this Part V of the Tariff, and related schedules and attachments, the
Transmission Provider will provide Joint Dispatch Transmission Service to any
eligible customer, provided that (i) the eligible customer has wholesale or retail
native load in the Transmission Provider’s Balancing Authority Area; (ii) the
eligible customer has entered into a Joint Dispatch Agreement; (iii) the eligible
customer’s transmission provider has a transmission service tariff offering Joint
Dispatch Transmission Service on the same terms and conditions as offered
under this Part V of the Tariff, and related schedules and attachments; and (iv)
the eligible customer executes a Service Agreement pursuant to Attachment V
for service under this Part V of the Tariff or requests in writing that the
Transmission Provider file a proposed unexecuted Service Agreement with the
Commission.
43.2
Application Procedures. An Eligible Customer requesting service under Part V
of this Tariff must submit an application containing the information specified
below. No deposit or credit evaluation is necessary to obtain Joint Dispatch
Transmission Service. Further, no transmission studies shall be required to
obtain Joint Dispatch Transmission Service because such service is provided
only on a non-firm, as available basis. Applications should be submitted to the
Transmission Provider via e-mail to the person(s) listed on OASIS. Application
contents:
(i)
(ii)
(iii)
(iv)
(v)
(vi)
(vii)
(viii)
The identity, address, telephone number and facsimile number of the
party requesting service;
A statement that the party requesting service is, or will be upon
commencement of service, an Eligible Customer under the tariff;
A statement that the party requesting service has, or will have upon
commencement of service, wholesale or retail native load in the PSCo
Balancing Authority Area;
A statement that the party requesting service has, or will have upon
commencement of service, entered into a Joint Dispatch Agreement with
PSCo;
A statement that the party requesting service has, or will have upon
commencement of service, a tariff offering Joint Dispatch Transmission
Service at the same rates, terms, and conditions as this Part V of the
Tariff and associated schedules and attachments;
Service Commencement Date and the term of the requested Joint
Dispatch Transmission Service.
A statement signed by an authorized officer from or agent of the Joint
Dispatch Transmission Service Customer attesting that Joint Dispatch
Transmission Service will be used only for receipt or delivery of energy
dispatched under a Joint Dispatch Agreement for the benefit of that
customer’s wholesale and retail native load customers.
Service is conditioned on the Transmission Provider being in receipt of an
executed Joint Dispatch Agreement.
Xcel Energy Operating Companies
FERC Electric Tariff, Second Revised Volume No. 1
Page No. 15
Unless the Parties agree to a different timeframe, the Transmission Provider
must acknowledge the request within ten (15) days of receipt.
The
acknowledgement must include a date by which a response, including a Service
Agreement, will be sent to the Eligible Customer. If an application fails to meet
the requirements of this section, the Transmission Provider shall notify the
Eligible Customer requesting service within fifteen (15) days of receipt and
specify the reasons for such failure. Wherever reasonably possible, the
Transmission Provider will attempt to remedy deficiencies in the Application
through informal communications with the Eligible Customer. If efforts are
unsuccessful, the Transmission Provider shall return the Application, without
prejudice to the Eligible Customer filing a new or revised Application that fully
complies with the requirements of this section.
43.3
Joint Dispatch Transmission Customer Facilities: The Joint Dispatch
Transmission Service Customer’s transmission provider will retain its existing
obligations to plan, construct, operate and maintain its transmission system using
standard utility practices.
43.4
Filing of Service Agreement. The Transmission Provider will file Service
Agreements with the Commission in compliance with applicable Commission
regulations, if any.
Xcel Energy Operating Companies
FERC Electric Tariff, Second Revised Volume No. 1
Page No. 16
15 Joint Dispatch Trans Svc Version: 0.0.0 Effective: 1/1/2015
Schedule 15
Joint Dispatch Transmission Service
This is an optional service provided by PSCo, subject to the terms and conditions of Part
V of this Tariff. For Joint Dispatch Transmission Service Customers meeting the
conditions set forth in Part V of this Tariff, no charge shall be assessed for receipt or
delivery of energy dispatched pursuant to a Joint Dispatch Agreement with PSCo
provided the customer makes Joint Dispatch Transmission Service available to PSCo at
the same rates, terms, and conditions as set forth in Part V of this Tariff, this Schedule
15, and any other related schedules or attachments to this Tariff. Joint Dispatch
Transmission Service is provided in real-time on a non-firm, as available basis having
the lowest curtailment priority.
1) Monthly delivery: the rate or $0.00/kW-month of Reserved Capacity.
2) Weekly delivery: the rate $0.00/kW-week of Reserved Capacity.
3) Daily delivery: the rate $0.00/kW-day of Reserved Capacity.
4) Hourly delivery: On-Peak Hours: the on-peak rate $0.00/MWh of Reserved Capacity.
Off-Peak Hours: the off-peak rate $0.00/MWh of Reserved Capacity.
Xcel Energy Operating Companies
FERC Electric Tariff, Second Revised Volume No. 1
Page No. 17
V Form of Svc Agrmt for Joint Dispatch Trans Svc Version: 0.0.0 Effective: 1/1/2015
ATTACHMENT V
Form of Service Agreement For Joint Dispatch Transmission Service Applicable to the
Public Service Company of Colorado (PSCo) System
1.0
This
Joint
Dispatch
Transmission
Service
Agreement,
dated
as
of
__________________________,
is
entered
into,
by and between __________________________ (“Transmission Provider”),
and __________________________ ("Joint Dispatch Transmission Customer"),
all of whom may be referred to individually as “Party” or jointly as “Parties”.
2.0
The Joint Dispatch Transmission Customer has been determined by the Transmission
Provider to have a signed a Joint Dispatch Agreement.
3.0
Service under this agreement shall commence on the later of (1) the requested service
commencement date, or (2) such other date as it is permitted to become effective by the
Commission. Service under this agreement shall terminate on such date as mutually
agreed upon by the parties.
4.0
Any notice or request made to or by either Party regarding this Service Agreement shall
be made to the representative of the other Party as indicated below.
Transmission Provider:
_____________________________________
_____________________________________
_____________________________________
Transmission Customer:
_____________________________________
_____________________________________
_____________________________________
5.0
The Tariff is incorporated herein and made a part hereof.
Xcel Energy Operating Companies
FERC Electric Tariff, Second Revised Volume No. 1
Page No. 18
IN WITNESS WHEREOF, the Parties have caused this Service Agreement to be executed by
their respective authorized officials.
Transmission Provider:
By:
___________________ ___________________ ___________________
Name
Title
Date
Transmission Customer:
By:
___________________ ___________________ ___________________
Name
Title
Date

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