Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004
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Dee, ember 20, 2004
Honorable Magalie R. Salas Secretary Federal Energy Regulatory Commission 888 First Street, N.E. Washington, D.C. 20426
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Re: California Independent System Operator Corporation. Docket No. ER01-313-004 Pacific Gas and Electric Company Docket No. ER01-424-004
Dear Secretary Salas:
Enclosed please find an original and 7 copies of the Prepared Direct Testimony and Exhibits of A. Dearie Lyon on behalf of the California Independent System Operator Corporation. Two additional copies of this filing are enclosed to be stamped with the date and lime of filing and returned to our messenger. If there arc any questions concerning this filing, please contact the undersigned.
Respectfully submitted,
Ronald E. Minsk
Counsel for the California Independent System Operator Corporation
co: The Honorable Bobbie I, McCarmey Service List
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" ORIGINAL - - •
Summary of Testimony of A. ~ L y o n ~O on Behalf of the Catifomla Indepen(IQ(~Sl~, tern ,~
Operator Corporation ~7/: ,~>. , 9 . ~/r,b 0 ,. 0
A. Deane Lyon is manager of Operations Support at the C a l i ~ Independent
System Operator Corporation ("ISO"). His testimony addresses the manner and extent
to which behind-the-meter generation was included in the ISO's transmission and
operations planning studies between 2001 and 2003. His testimony also identif'ms the
relevant factors the iSO considers when modeling behind-the-meter generators in its
transmission and operations planning studies and how behind-the-meter load netted
against unmodeled generation impo~s control area services costs on the ISO.
Mr. Lyon's testimony initially defines behind4he-meter generation as situations in
which a Load's electrical consumption cannot be distinguished from a Generating Unit's
simultaneous production of electricity, because since both are measured with only one
meter. Mr. Lyon's testimony the presents the list of generators that the ISO modeled
between 2001 and 2003 which was prepared for the initial refund calculation in this
proceeding, and states that the ISO has not prepared a similar list for generators
modeled in 2004, No such list was prepared because the basis for calculating the Grid
Management charge has changed sufficiently. It is now allocated on a basis that does
not depend on the identification of the Generating Units that the ISO models, and the
ISO, therefore, does not maintain a list of the included Generating Units.
Mr. Lyon's testimony explains that the ISO adopts the powerfiow modeling of
generators from the Participating TOs and that the process for modeling generators is
the same, regardless whether the generator is "behind the meter" or not. He then
explains that for most Planning and Operations study cases, the Participating TOs - not
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the ISO - decide which generators to model when they provide their powerflow models
to the WECC and the ISO, and the ISO merely adopts that modeling representation.
Mr. Lyon's testimony summarizes the services provided by the ISO, the costs of
which were intended to be recovered by the control area services component of the
former GMC, and explains that there are certain services provided by the ISO from
which all loads and generation derive benefits, including behind-the-meter load. The
testimony also reiterates that there was not in 2001, and there currently is, no
exemption in WECC that permits excluding "load behind the meter" from a Control
Area's Load Responsibility. Mr. Lyon indicates that the ISO directly incurs costs for
behind-the-meter load in connection with all Control Area Services that are directed
toward ensuring that load continues to be served and that behind-the-meter load also
benef'ds, although less directly, from such activities as transmission planning,
maintenance, and outage coordination that ensure the existence of a robust
transmission network that can protect load in the case of the failure of behind-the-mater
generation. Mr. Lyon states that in order to meet its Control Area Operator reliability
obligations to the WECC, the ISO has the operational responsibility, operations
engineering and grid planning obligations to: 1) study and determine the impact to the
transmission system of such behind-the-meter loads and generators, 2) ensure that
local transmission facilities and substation equipment are designed and built such that
the interconnection of these loads and generators do not negatively impact that system,
and, 3) where necessary, modify local transmission facilities and substation equipment
to meet WECC planning and operating criteda for the Control Area in order to reliably
accommodate the new behind-the-meter loads and generators.
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UNITED STATES OF AMERICA BEFORE THE
FEDERAL ENERGY REGULATORY COMMISSION
California Independent System Operator Corporation
Pacific Gas and Electric Company
) ) ) ) )
Docket Nos. ER01-313-000 ER01-313-001
Docket Nos. ER01-424-000 ER01-424-001
PREPARED DIRECT TESTIMONY OF A. DEANE LYON
ON BEHALF OF THE CALIFORNIA INDEPENDENT SYSTEM
OPERATOR CORPORATION
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PLEASE STATE YOUR NAME, TITLE AND BUSINESS ADDRE88.
My name is A. Deane Lyon. ! am Director of Operations Support and Training
('OSAT") for the California Independent System Operator ('lSO'). My business
address is 151 Blue Ravine Road, Folsom, CA 95630.
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HAVE YOU PREVIOUSLY PROVIDED TESTIMONY IN A REGULATORY
PROCEEDING?
Yes I have. I provided testimony for the hearing that preceded the Initial
Decision in this docket. The Commission's Order establishing this proceeding
requests elaboration of the discussion of Control Area Services in my previous
testimony. I also provided testimony in Docket No. EL99-93-000, Turlock
Irrigab'on District v. California Independent System Operator Corporab'on,
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A.
WHAT IS YOUR EDUCATIONAL BACKGROUND?
I am cert~sd by the California Apprenticeship Council as a System Operator.
Through May 19, 2004, I was a certified System Operator by the Western
Electricity Coordinating Council ('VVECC') and the North American Electric
Reliability Council ("NERC"). I attended Ohlone Junior College, Fremont,
California in 1976, taking business law, business administration and electronics
courses. Since being employed first with Pacific Gas and Electric Company
('PG&E') from December 1976 through September 1997 and from October 1997
with the California ISO, I have completed several system operations, supervisory
and management courses.
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PLEASE DESCRIBE YOUR WORK EXPERIENCE PRIOR TO THE
WORK YOU ARE DOING TODAY.
I began my professional career with PG&E in 1976 as a System Operator.
Through the course of my PG&E career, I worked as a System Operator at both
the distribution and transmission switching center levels, and supervised or
managed distribution and transmission switching canters, regional transmission
departments and a regional operator training program. I was an instructor at the
PG&E System Operator Training Center and Power System simulator. The last
seven years of my career with PG&E were spent in its Energy Control Center as
a Transmission Dispatcher, Interchange Scheduler, Generation Dispatcher and
Senior Operations Supervisor, in that order. As Senior Operations Supervisor, or
Shift Supervisor, I was responsible for the safe and reliable operation of the
PG&E Control Area grid which, prior to its incorporation into the ISO Control
Area, spanned from Bakersfield in the south to the California-Oregon border in
the north, and from the California coast to the California-Nevada border in the
east.
I joined the California ISO in October 1997 as a Shift Manager, assuming
the same responsibilities as I had at PG&E, but with a considerably larger
Control Area that includes most of the state of California, and with the added
market component. I moved from Grid Operations to the Operations Support and
Training department in late 1999 as an Operations Trainer. I became manager
of Operations Support in June 2000, and I became the Director, Operations
Support and Training in August 2001.
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WHAT ARE YOUR CURRENT RESPONSIBILITIES AT THE ISO?
I am currently Director of the Operations Support and Training Department at the
ISO. Personnel that report directly to me include managers for the following
groups: Operations Support, Operations Training, Operations Applications
Support and Operations Coordination. The primary role of OSAT is to provide
support to all departments within the Operations Division, including the
development of training programs, and support and development of tools for
operations. OSAT coordinates the Operations Division position on matters
affecting Operations and coordinates responses by Operations respondents to
market participant and legal inquiries. OSAT provides training and support to all
groups within the Operations Division, to other departments within the ISO, and
to Market Participants, to ensure and enhance system reliability as well as to
facilitate and expand workably competitive markets.
As the Director of OSAT, I am responsible for overseeing preparation and
administration of training across all operations groups, other groups in the ISO,
and Market Participants; providing support for ISO efforts to interface with and
incorporate markets and deregulation from an operations perspective as they
develop inside and outside the ISO; updating, creating and maintaining all ISO
Operating Procedures; implementing emergency response programs and
procedures within the ISO and in coordination with state and federal agencies;
providing presentation development and support for the Operations organization;
reviewing ISO Tariff changes, legislation, and regional and national operating
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organization polices from an operations feasibility point-of-view; and for providing
budget development and support for the Operations Division.
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AS YOU TESTIFY, WILL YOU BE USING ANY SPECIALIZED TERMS?
Yes, I will usa capitalized terms as defined in the Master Definitions Supplement,
Appendix A of the ISO Tariff.
6 Q, WHAT IS THE PURPOSE OF YOUR TESTIMONY?
7 A. The purpose of my testimony is to provide information in response to issues
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identified by the Commission in its November 16, 2004, Order initiating this
proceeding. Those issues are the following:
. The manner and extent to which behind-the-meter generation was included during the time period at issue in the ISO's transmission and operations planning studies, including a listing of generators that ware explicitly modeled in these studies. Additionally, the Commission also asked for the same information for 2004.
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. All relevant factors the ISO has considered when modeling behind-the-meter generators in its transmission and operations planning studies, including: (1) WECC requirements for modeling; (2) the generator size and location on the transmission and/or distribt¢don system; (3) load associated with that generation; (4) voltage, stability, and short-circuit concerns; and (5) the impact of the generator on the transmission system.
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. How and to what extent behind-the-meter load netted against unmodeled generation imposes CAS costs, as delineated by ISO witness Lyon, on the ISO.
24 4. What regulatory controls (if any) are necessary for the ISO to report which 25 generation and associated load it does not model.
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Q.
A.
DO YOU UNDERSTAND THE TERM "BEHIND-THE-METER
GENERATION" AS IT IS USED BY THE COMMISSION IN ITS ORDER
OF NOVEMBER 18, 2004?
Yes. The term "behind-the-meter" generally refers to situations in which a
Load's electrical consumption cannot be distinguished from a Generating Unit's
simultaneous production of electricity, because both are measured with only one
meter. This is the manner in which I used the term in my previous testimony and
the manner in which I understand the Commission to have used it in the
November 16 Order. This definition of behind-the-meter holds true no matter
what type of entity is generating power behind the meter, including municipal
utility generators, QFs, and any other entity that might be generating power.
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Q. IN THE NOVEMBER 16 ORDER, THE COMMISSION INDICATED THAT
IT WANTED INFORMATION ABOUT THE MANNER AND EXTENT TO
WHICH BEHIND-THE-METER GENERATION WAS INCLUDED DURING
THE TIME PERIOD AT ISSUE IN THE ISO'S TRANSMISSION AND
OPERATIONS PLANNING STUDIES, INCLUDING A USTING OF
GENERATORS THAT WERE EXPLICITLY MODELED IN THESE
STUDIES. PLEASE IDENTIFY THE GENERATORS THAT THE ISO
MODELED AS PART OF ITS TRANSMISSION AND OPERATIONS
PLANNING STUDIES BETWEEN JANUARY I , 2001 AND DECEMBER
31, 2003.
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A. Exhibit ISO-37 is a list of the generators that the ISO modeled as part of its
transmission and operations planning studies between January 1, 2001 and
December 31, 2003. This list was previously prepared in order to comply with
the Commission's January 23, 2004 rehearing order in this proceeding, and was
used to identify the generators with unmodeled behind-the-meter load, so that
the ISO could undertake the calculations necessary for the compliance filing of
the ISO in this proceeding, which was filed on November 15, 2004 and rendered
moot by the Commission's Order issued the following day. The list was not
included as part of the submission to the Commission. I did not prepare that
filing.
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Q.
A.
THE COMMISSION ALSO ASKED FOR INFORMATION REGARDING
THE GENERATORS THAT THE ISO MODELED AS PART OF ITS
TRANSMISSION AND OPERATIONS PLANNING STUDIES SINCE
JANUARY 1, 2004. DO YOU HAVE SUCH INFORMATION AT THIS
TIME?
No. As I will discuss later in my testimony, the ISO adopts powerflow models
from the Partic/pating Transmission Owners (Participating TO's), who identify the
Generating Units to be included. It is not necessary for the ISO to maintain a list
of the included Generating Units. The list of generators for the compliance filing
was prepared specifically for that purpose. Because the Grid Management
charge is now allocated on a basis that does not depend on the identification of
the Generating Units that the ISO models, the ISO does not have a list for 2004.
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Q. IN ADDITION TO ASKING ABOUT THE MANNER IN WHICH ISO
INCLUDES THE MODELING OF BEHIND-THE-METER GENERATION IN
THE ISO'S TRANSMISSION AND OPERATIONS PLANNING STUDIES,
THE COMMISSION INQUIRED ABOUT RELEVANT FACTORS THE ISO
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A.
HAS CONSIDERED WHEN MODELING BEHIND-THE-METER
GENERATORS IN ITS TRANSMISSION AND OPERATIONS PLANNING
STUDIES. PLEASE EXPLAIN THE ROLE OF GENERATION
MODELING, INCLUDING BEHIND-THE-METER GENERATION, IN THE
ISO'S TRANSMISSION AND OPERATIONS PLANNING.
In order to discharge all of its WECC functions, the ISO models such generation
not only for Grid Planning, but also, along with the other generation in the Control
Area, for operational engineering and other operations responsibilities. For
example, the ISO and its Participating TO must include all behind-the-meter
generation and associated load in operating and planning studies when:
The behind-the-meter generation may deliver excess Energy to the grid in the wholesale market arena, either on a regular and routine basis, or intermittently at various times throughout the year.
The behind-the-mater load served by the behind-the-meter generation would remain connected and continue to draw power from the transmission grid in the event the behind-the-meter generation tripped or was curtailed (i.e., for facilities that have a standby service agreement with the UDC).
The behind-the-meter generation is of such size, nature, and character and connected at a critical point within the transmission system such that the generation could have a pronounced and significant effect on the transient or dynamic performance of the transmission system including, but not limited to:
2g ~ transient stability,
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voltage collapse, local area power quality, fault current contribution, coordination of protective devices.
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A.
PLEASE EXPLAIN THE ISO'S PROCESS FOR MODELING A
GENERATOR IN ITS TRANSMISSION AND OPERATIONS AND
PLANNING STUDY CASES.
The ISO adopts the power flow modeling of generators from the Participating
TOs. For existing units, the generator models are embedded in power flow
cases the ISO routinely receives from Participating TOs or the WECC through
various Planning and Operating study forums. For proposed and newly
constructed units, the ISO receives power flow model "change files" from the
Participating TO where the unit will be connecting. These incremental modeling
changes are then applied to the ISO's current resident Planning and Operating
study cases, where appropriate.
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A.
DOES THE MODEUNG PROCESS VARY FROM GENERATOR TO
GENERATOR? FOR A BEHIND-THEJ~ETER GENERATOR AS
OPPOSED TO ONE THAT IS NOT BEHIND-THE~METER, FOR
EXAMPLE? IF SO, PLEASE OESCRIBE THE REASON THAT, AND
THE MANNER IN WHICH, THE PROCESS MIGHT VARY BETWEEN
GENERATORS.
For most Planning and Operations study cases, the process for modeling
generators is the same, regardless whether the generator is behind-the-meter or
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not. In some specialized uses of the power flow model (Energy Management
System's (EMS) and the Market Model power flow), the ISO changes the
detailed, gross representation of behind-the-meter generation and load to an
equivalent ('netted') model.
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A.
HOW DOES THE ISO DECIDE WHICH GENERATORS TO MODEL AND
WHICH GENERATORS NOT TO MODEL?
For most Planning and Operations study cases, the Participating TOs - not the
ISO - decide which generators to model when they provide their powerflow
models to the WECC and the ISO; the ISO adopts and preserves that modeling
representation. The ISO only changes generator models in the previously
described specialized circumstances, when the nature of the associated
information system (EMS telemetry, or the appropriate granularity for Market
Scheduling) necessitates changing it.
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A.
PLEASE EXPLAIN WHAT YOU UNDERSTAND TO BE THE MEANING
OF 'NETTING LOAD,' AS USED BY THE COMMISSION IN THE
NOVEMBER 16 ORDER.
In the context provided by the Commission's November 16 Order in this
proceeding, I understand the term to mean the metered value at the point of
delivery, which generally is the netted value of the behind-the-meter load and
generation. For example if a behind-the-rneter generator is producing 20 MW
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and the behind-the-meter load in that same location is consuming 10 MW, the
metered value at the point of delivery would be 10 MW
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A.
PLEASE SUMMARIZE THE SERVICES PROVIDED BY THE ISO, THE
COSTS OF WHICH WERE INTENDED TO BE RECOVERED BY THE
CONTROL AREA SERVICES COMPONENT OF THE FORMER GMC.
The ISO is charged with ensuring the safe, reliable operation of the Control Area,
including the dispatch of bulk power supplies in accordance with NERC and
WECC (formerly WSCC) standards It is therefore the ISO's responsibility,
subject to monetary penalty, to ensure that it provides system balancing and to
arrange for adequate Operating Reserves for ALL Loads within the ISO Control
Area, which include those Loads sewed by on-site Generation interconnected
and synchronized to the ISO Controlled Grid and capable of drawing Energy in
the event of an on-site Outage of Generation The physics of a transmission grid
require that a system operator must constantly monitor, in real time. what is
happening to the entire transmission grid to maintain the reliability and safety of
the system. While the actual Energy used to balance Generation and Load is not
itself an element of CAS, the monitoring efforts by the ISO to ensure the safe and
reliable operation of the ISO Control Area, and the administrative costs of
dispatching of the Energy to balance Generation and Load are a part of the CAS
component.
The ISO, as Control Area operator, performs numerous administrative
functions beyond the moment-to-moment monitoring and operation of the ISO
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Controlled Grid and real-time delivery of Energy requirements. A non-
comprehensive listing of these functions includes:
• Determination of mat-time resource adequacy • Dispatching of resources in order to balance Load and resources in
real time • Procurement and maintenance of the required amount of Operating
Reserve • Coordination of Western Interconnection reliability with WECC
reliability coordinators • Integration and coordination with other control areas • Interchange scheduling • Existing Transmission Contracts scheduling and administration • Development, maintenance and monitoring of the EMS and associated
telemetry • Day-ahead/Hour-ahead intertie scheduling • Reconciliation of schedules post real-time • NERC, WECC, and ISO Tariff required reporting • Coordination of transmission and generation outages • Development, monitoring and enforcement of transmission
maintenance standards • Management and oversight of generation interconnection • Performance of seasonal, annual and special analyses of transmission
system performance and ratings • Performance of transmission planning to ensure overall system
reliability, performance of reserve requirement studies, load forecasting and long term transmission resource adequacy
• Coordination of participation in regional organizations, such as WECC, NERC, and NAES8
• Determination of Long Term Generation adequacy • Determination of Reliability Must Run requirements
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A.
DOES THE ISO PROVIDE THESE SERVICES FOR ALL LOAD,
INCLUDING BEHIND-THE-METER LOAD? FOR EXAMPLE, DOES THE
ISO UNDERTAKE TRANSMISSION PLANNING ACTIVITIES TO
SUPPORT BEHIND-THE-METER LOAD?
There are certain services provided by the ISO from which all loads and
generation derive benefits. As I allude to above, and elaborate upon here. the
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ISO, as a Control Area Operator, is obligated by WECC criteria and NERC policy
to provide its proportionate share of frequency control to the Western
Interconnection, to control and manage voltage within the ISO Control Area and
to balance resources with load, including maintaining a required amount of
operating reserve, such that the ISO Control Area is not a burden to the other
Control Areas and non-Control Area entities that comprise the Western
Interconnection. The ISO Grid Planning process incorporates transmission
assessments performed by Participating Transmission Owners to develop
transmission expansion plans for the ISO Controlled Grid. These studies include
transmission adequacy analyses during generation outage conditions that require
the transmission system to serve load that can no longer be served by local
generation because the local generation is unavailable.
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A.
ARE BEHIND-THE-METER LOADS A PART OF THE ISO'S LOAD
RESPONSIBILITY FOR THE ISO CONTROL AREA?
Yes, when the behind-the-meter load served by the behind-the-meter generation
remains connected and continues to draw power from the transmission grid in
the event the behind-the-meter generation trips, that is, disconnects from the
grid. The ISO therefore needs to have reserves available to serve the load if the
behind-the-meter generation trips. There was not in 2001 and there currently is
no exemption in WECC that permits excluding load behind the meter from a
Control Area's Load Responsibility. As was discussed during the previous
hearing on this docket, there has been some discussion regarding revisions of
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the WECC requirements to exclude behind-the-meter retail load with standby
service from a Control Area's Responsibility, but that has not occurred and
certainly does not affect the period at issue in this proceeding.
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A.
IN RESPONSE TO THE COMMISSION'S INQUIRY, CAN YOU IDENTIFY
THE AREAS IN WHICH THE ISO INCURS COSTS TO MEET ITS
RESPONSIBILITIES WITH RESPECT TO BEHIND-THE-METER LOAO
(I.E., BEHINO-THE-METER LOAD NETTED AGAINST UNMODELED
GENERATION)?
The (SO acknowledged in 2001 GMC that it hoped in later filings to allocate the
Grid Management Charge with a greater degree of granularity, and indeed has
done so. From my perspective as a former System Operator, the Control Area
Services category in the 2001 GMC filing is not easily amenable to further
specific subdivisions. The most important factor is that the WECC does not
distinguish between load behind-the-meter and any other load. Therefore the
ISO directly incurs costs for behind-the-meter load in connection with all Control
Area Services that are directed toward ensuring that load continues to be sewed.
These costs would include the maintenance of voltage control; frequency control;
and Operations Engineering and Planning functions to determine the impact of
the behind-the-meter load or generator when connected to and disconnected
from the gdd, To the extent the behind-the-meter load has not self-provided or
made appropriate arrangements (for example though an adequate standby
service arrangement) for the required amount of operating reserve, the ISO must
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be prepared to maintain continuity of service to such load, and, therefore, must
procure the required amount of operating reserve. Behind-the-meter load also
beneFds, although less directly, from such activities as transmission planning,
maintenance, and outage coordination that ensure the existence of a robust
transmission network that can protect load in the case of the failure of behind-
the-meter generation.
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A.
WHY MUST THE ISO PROVIDE SUCH SERVICES FOR BEHIND-THE-
METER LOAD? WHY IS IT ESSENTIAL THAT THE ISO HAVE
COMPREHENSIVE INFORMATION ABOUT BEHIND-THE-METER
LOAD IN ORDER TO MANAGE THE GRID?
Simply stated, in order to meet its Control Area Operator reliability obligations to
the WECC. The ISO has the operational responsibility, operations engineering
and grid planning obligations to: 1) study and determine the impact to the
transmission system of such behind-the-meter loads and generators, 2) ensure
that local transmission facilities and substation equipment are designed and built
such that the interconnection of these loads and generators does not negatively
impact that system, e.g., that this new equipment does not exceed existing
substation circuit breaker fault duties and that protective relays are properly
coordinated, 3) where necessary, modify local transmission facilities and
substation equipment to meet WECC planning and operating criteda for the
Control Area in order to reliably accommodate the new behind-the-meter loads
and generators.
Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004
Exh. ISO-54 Page 15 of 15
1
2
3
4
5
6
7
8
9
10
11
12
13
14
15
16
17
Q.
A.
DOES THE ISO NEED INFORMATION THAT IT DOES NOT HAVE, IN
ORDER TO REPORT WHICH GENERATORS ANO WHAT
ASSOCIATED LOAO THE ISO DOES NOT MODEL?
It is my understanding that this fact finding proceeding by the Commission relates
to the Commissions' orders in Opinion No. 463-A. Specifically it refers to the
liability of behind-the-meter generation for the Control Area Services component
of the then Grid Management Charge. Because the ISO no longer estimates
behind-the-meter load for the purposes of assessing Control Area Services (or its
current equivalent) and that the relevant entities remaining within the Control
Area now comply with the ISO's requirements, regulatory controls through which
the Commission directs parties to provide information to the ISO so that it may
accurately charge behind-the-meter load are not required.
As to whether or not there is additional information that the Commission
might assist the ISO in obtaining, the answer is yes there is. However, I am
unsure whether, given the earlier part of my answer and the restricted nature of
this proceeding, this is the place to seek such assistance.
Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004
EXHIBIT IS0-55
Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004
Callfomia ISO Docket NOS. ER01-313-004 et al.
SCE 28008 AGUAMNSA ,SCE 25653 ALAMO SC ISCE 24001 ALAMTI G SCE 24002 ALAMT2 G
'SCE 24003 ALAMT3 G 'SCE 24004 ALAMT4 G ,SCE 24005 ALAMT5 G ISCE 24161 ALAMT6 G SCE 24162 ALAMT7 G 5CE 24714 ALTA IG
'SCE 24715 ALTA 2G ,SCE 24719 ALTA30ST ;SCE 24718 ALTA31GT ~,CE 24734 ALTA32GT 5CE 24721 ALTA40ST
'SCE 24720 ALTA41GT ,SCE 24735 ALTA42GT ,SCE 25635 ALTW1ND SCE 25203 ANAHEIMG
24009 APPGENIG 24010 APPGEN2G
rsc E :SCE SCE SCE SCE
24012 APPGEN3G 24457 %RBW1ND 24011 ARCO 1G
SCE 24012 ARCO 2G SCE 24013 ARCO 3G SCE 24014 ARCO 4G SCE 24163 ARCO 5G SCE 24164 ARCO 6G SCE 24314 B CRK 4 SCE 24314 8 CRK4 SCE 24315 B CRK8 ,SCE 24315 B CRK 8 ;SCE 24306 B CRKI-1 ;SCE 24306 B CRKI-1 SCE 24307 B CRKI-2
'SCE 24307 8 CRKI-2 ,SCE 24308 B CRK2-1 ,SCE 24308 B CRK2-1 ~CE 24309 B CRK2-2 SCE 24309 B CRK2-2
!SCE 24310 B CRK2-3 ~CE 24310 B CRK2-3 SCE 24311 B CRK3-1 SCE 24311 B CRK3-1 5CE 24312 3 CRK3-2 SCE 24312 8 CRK3-2 SCE 24313 B CRK3-3 ' 5CE 28282 BIGCRK1
13.8 1 30 139 I 0
181 I 158 181 2 158 181 3 300 18; 4 606.45 201 5 460 2C 6 460 16' 7 0
13.8 1 60 13.8 2 80 13.8! 30 80 13.9 31 50 13,8 32 50 t3.8 40 80 13.8 41 50 13.8 42 50 115 1 0
13.8 I "so :=3.8 1 50 13.8 2 50 13.8 3 10
66 1 0 13.8 1 400 13.8 I 4OO 13.8 1 400 13.8 1 400 13.8 I 400 13.8 1 400
12 41 50 t2 42 40
13.8 81 25 13.8 82 35 7.2 1 15 7.2 2 15
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13.8 1 30 13.8 2 30 13.8 3 30 13.8 4 37 13.8 5 25
33 PO 0
Exh. ISO-55 Page 2 of 18
Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004
California ISO Docket Nos. ER01-313-004 eta/.
SCE 24703 BLM E7G 13.8 7 20 SCE 24704 BLM E8G 13.8 8 20 SCE 24705 BLM WgG 13.8 g 20 SCE 24708 E3ORAX I 13.8 I 47 SCE 24456 BOREL 66 1 0 SCE 2802~ BRDWAYB3 13.8 C1 0 SCE 2440a BREEZE 66 1 0 SCE 28506 BREEZE1 12 1 0 SCE 28507 BREEZE2 12 1 0 SCE 24018 BRIGEN 13.8 1 0 SCE 2470~ BSPHYD26 2.2 26 12 SCE 2471(] BSPHYD34 2.2 34 14 SCE 25634 B U C ~ D 115 1 0 SCE 28280 ~,BAZON 34.5 1 0 SCE 24711 3ALGENIG 13.8 1 30 SCE 24712 3ALGEN2G 13.8 2 25 SCE 24713 ~ALGEN3G 13.8 3 25 SCE 25633 ~APWtND 115 1 0 SCE 24020 CARBOGEN 13.8 1 34 SCE 28007 CENTURY 12.47 1 7.25 SCE 28007 CENTURY 12.47 2 7.25 SCE 28007 CENTURY 12.47 3 7.25 SCE 28007 CENTURY 12,47 4 7.25 SCE 2419g CHEVMA]N 86 1 76 SCE 24028 ~IMGEN 13.8 1 30 ;CE 24027 3OLDGEN 13.8 1 0 ;CE 28022 3PC-COLT 12 1 0
SCE 28022 3PC-COLT 12 2 0 ;CE 24726 3SA DIAB 4.16 1 15 ;CE 24030 :~ELGEN 13.8 1 45
SCE 28006 3REWSG12 12.47 1 8 SCE 28006 D R ~ G 1 2 12.47 2 6 SCE 28009 DREWSG34 12.47 3 6 SCE 28009 3~REVVSG34 12.47 4 6 SCE 24460 IDUTCHWND 66 1 0 SCE 25641 IDVLCYN1G 13.8 1 80 SCE 25649 IDVLCYN2G 13.8 2 80 SCE 25603 'DVLCYN3G 13.8 3 0 SCE 25604 IDVLCYN4G 13.8 4 0 SCE 24045 ELSEG1 G 18 I 0 SCE 24046 ELSEG2 G 18 2 0 SCE 24047 ELSEG3 G 18 3 310 SCE 24048 'ELSEG4 G 18 4 310 SCE 24458 =,NCANWND 66 1 0 SCE 24055 ETIWANDA 66 MW 23 SCE 24055 ETIWANDA 66 QF 30 SCE 24459 FLOW1ND 66 1 0 SCE 24831 GARNET 34.5 QF 2 SCE 24831 GARNET 34.5 UN 0
Exh. ISO-55 Page 3 of 18
Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004
California 1SO Docket Nos. ER01-313-004 et aL
SCE 28028 IGLNARMCI SCE 28029 3LNARMC2 SCE 28030 IGLNARMC3 SCE 28031 ~LNARMC4 SCE 24436 3OLDTOWN SCE 24057 30LETA SCE 24057 3OLETA SCE 24057 3OLETA SCE 24060 IGROWGEN SCE 24062 ~L4JRBOR G SCE 24062 r'IARBOR G SCE 25510 ~IARBORG3 SCE 28003 -(IOEDCT1 SCE 28002 IHIDEDCT2 SCE 28001 ~tlDEDCT3 SCE 28000 HIOEDST1 SCE 24063 HILLGEN SCE 24064 HINSON SCE 24727 rdOLGATE SCE 24727 HOLGATE ;CE 24068 ~UNT1 G
SCE 24067 r"IUNT2 G ;CE 24167 HUNT3 G
SCE 24184 HUNT4 G SCE 24189 ~UNT5 G SCE 24070 ICEGEN 5CE 28180 rNDIGOG1 SCE 28190 INDIGOG2 SCE 28191 INDIGOG3 SCE 24071 rNLAND SCE 25417 LRONMTP1 SCE 25417 IRONMTP1 SCE 25417 rRONMTP1 SCE SCE SCE SCE
25417 IRONMTP1 25418 IRONMTP2 25418 rRONMTP2 25418 IRONMTP2
SCE 25418 ;RONMTP2 SCE 25418 rRONMTP2 SCE 24437 <ERNRVR SCE 28284 ~(JERNRVU1 SCE 28285 K3ERN U2 SCE 24732 ~¢JERRGEN SCE 24733 KERRMGEE SCE 24237 ~ACSD SCE 24237 L.ACSD SCE 24237 J~,CS D SCE 24237 LACSD
28008 LAKEGEN SCE
13.8 C1 0 13.8 C2 0 13.8 C3 0 13.8 C4 0
66 1 0 66EX 0 66 GV 0 66 QF 0
13.8 1 0 13.8 I 80 13.8 2 10 4.1( 3 14
15 1 175 15 1 175 15 1 175 20 1 0
13.8 1 45 86 1 0
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12.5 1 0 13.6 1 55
12 1 10 12 2 10 12 3 10 12 4 5.5
13.8 1 0
Exh. ISO-55 Page 4 of 18
Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004
California ISO Docket Nos. ER01-313-004 et al.
SCE 24078 LBEACHIG 13.8 1 60 SCE 24170 LBEACH2G 13.8 2 50 SCE 24171 LBEACH3G 13.8 3 50 SCE 24172 LBEACH4G 13.8 4 50 SCE 24173 LBEACHSG 13.8 5 50 SCE 24174 LBEACH6G 13.8 6 50 SCE 2407g LBEACH7G 13.8 7 50 SCE 24080 LBEACH8G 13.8 8 70 SCE 24081 LBEACHgG 13.8 9 50 SCE 24737 rUZ8 G 13.8 8 80 SCE 24738 LUZ9 G 13.8 9 80 SCE 24317 ~AMOTH1G 13.8 1 80 SCE 24318 MAMOTH2G 13.8 2 80 SCE 24089 MANDLYIG 13.8 1 200 SCE 24090 ~IANDLY2G 13.8 2 200 SCE 24740 ~4C GEN 13.8 1 105 SCE 24464 ~IDWtND 68 1 0 SCE 24094 ~OBGEN 13.8 1 45 SCE 24742 MOGEN G 13.8 1 57 SCE 24095 MOHAVICC 22 1 880 SCE 24096 VlOHAV2CC 22 2 680 SCE 24465 ~ORW1ND 66 1 0 SCE 24050 MTNVIST1 15.5 1 0 SCE 24051 ~ITNVIST2 15.5 2 0 SCE 24052 ~ITNV1ST3 18 3 300 SCE 24053 ~4TNVIST4 18 4 300 SCE 24054 VITNVIST5 18 5 125 SCE 24744 NAVYII4G 13.8 4 25 SCE 24745 NAVYII5G 13.8 5 25 SCE 24746 INAVYII6G 13.8 6 25 ;CE 24462 NORTHWND 66 1 0
5CE 24491 OAK'WIND 68 1 0 SCE 24211 OLINDA 66 1 0 SCE 24102 OMAR IG 13.8 1 70 SCE 24103 OMAR 2G 13.8 2 70 SCE 24104 OMAR 3G 13.8 3 70 SCE 24105 OMAR 4G 13.8 4 70 5CE 24107 ORMOND1G 28 1 700 SCE 24108 ORMOND2G 26 2 700 SCE 24747 OXBOW G1 13.8 1 53 5CE 24110 OXGEN 13.8 1 34 SCE 24422 :~ALM DALE 66 1 0 SCE 25640 PANAERO 115 1 0 SCE 28286 PANDOL1G 13.8 1 25 SCE 28287 mANDOL2G 13.8 2 25 SCE 28005 PASADNA1 13.8 I 0 SCE 28006 PASADNA2 13.8 1 0 5CE 28005 PICO_THM 13.8 1 0 SCE 24118 PITCHGEN 13.8 I 30
Exh ISO-55 Page 5 of 18
]nofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004
California ISO Docket Nos. ER01-313-004 et al.
SCE 2415~ ULTRAGEN SCE 2418C VALLEYSC SCE 25645 VENWlND SCE 24152 VESTAL SCE 24152 VESTAL SCE 24902 VSTA SCE 24157 WALNUT SCE 25651 WARNE1 SCE 25652 WARNE2 SCE 28061 WHITEWTR SCE 24155 WtLLAMET SCE 2802C WINTEC6 SCE 2818C WINI'EC8 SCE 2482E W1NTEC9 SCE 28191 W1NTECX1 SCE 2819~ W1NTECX2 SCE 24483 ZONDW1ND SCE 28504 ZONDWND1 SCE 28505 ZONDWND2 PG&E 3316C DOW CHEM PG&E 3316(; DOW CHEM PG&E 33145 CROWNZ PG&E 3586~ OLS-AGNE PG&E 3586(: OLS-AGNE PG&E 33463 CARDINAL PG&E 34608 AGRICO
34608] ~GRICO PG&E PG&E 31726 ELKCREEK PG&E 3431E ONEILPMP PG&E 3431E ONEILPMP PG&E 34318 ONEILPMP PG&E 34315 ONEILPMP PG&E 3431E ONEILPMP PG&E 32001 WOLFSKIL PG&E 35663 ~CEFGT4 PG&E 35662 LECEFGT3 PG&E 35661 LECEFGT2 PG&E 3,566C LECEFGT1 PG&E 32175 CREEDGT1 PG&E 32174 GOOSEHGT PG&E 32173 .AMBGT1 PG&E 38357 WOODMID2 PG&E 3317E RIVERVG1 PG&E 34773 FELLOWSG PG&E 34779 FELLOWSG PG&E 3220-'3 FREC PG&E 3 2 ~ STATIN-L PG&E 31874 SPI-BURN PG&E 35851 GLRYCGS2
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Exh. 150-55 Page 7 of 18
Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004
California ISO Dodxet Nos. ER01-313-004 et aL
PG&E 34773 FELLOWSG PG&E 35079 SUNRSE3S PG&E 33807 GV~:TRCY2 PG&E PG&E PG&E PG&E PG&E PG&E PG&E PG&E PG&E PG&E PG&E PG&E PG&E PG&E PG&E PG&E PG&E PG&E
33805 GWFTRCY1 32150 DG_VADIX 32172 H I G ~ D S 32513 WISE2 36207 KCTYPKER 32662 GRNLFPKR 37958 RDGCT4 34608 AGRICO 34301 CHOWCOGN 31621 NEO RBLF 36209 s i n ENRG 35034 MIDSUN ÷ 36226 DUKMOSS6 36225 DUKMOSS5 38224 DUKMOSS4 38223 DUKMOSS3 36222 DUKMOSS2 36221 DUKMOSSI
PG&E PG&E PG&E PG&E
33110 DEC CTG3 33109 DEC CTG2 33108 DEC CTG1 33107 DEC STG1
PG&E PG&E PG&E
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9.11 1 SMUD OWN 0.9 13.8 1 SMUD OWN 22 13.8 1 SMUD OWN 22.6
Exh. ISO-55 Page 8 of 18
PG&E 38119 %LMDACT2
Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004
.o,
California ISO Docket Nos. ER01-313-004 et 81.
=G&E 32903 OAKLND 3 13.8 3 SMUD OV~I 0 PG&E 32902 OAKLND 2 13.81 2 SMUD OVM~I 42.7 PG&E 32901 OAKLND 1 13.8 1 SMUD OWN 42.7 PG&E 31430 SMUDGEO1 13.8' 1 SMUD OWN 33 PG&E 32922 CHEVGEN2 13.8' 1 54 PG&E 32921 CHEVGEN1 13.8' 1 54 PG&E 36940 SPI1 601 1 10.47 PG&E 32512 W1SE1 2.31 1 0 PG&E 32900 CRCKTCOG 181 1 240 PC-&E 33134 GYM = #4 13.81 1 18.58 PC-&E 33141 SHELL 1 12.471 1 20 PG&E 33143 SHELL 3 12.471 3 40 PG&E 33142 SHELL 2 12.471 2 40 PG&E 38029 PALTOLND 601 1 1.02 PG&E 36205 ClC COGN 12.47] 1 28 PG&E 36200 SARGCN G 13.81 1 33.73 PG&E 36201 SALNR GN 13.81 1 32.15 PG&E 33804 BELLTA T 13.e 1 0 PG&E 31400 SANTAFE 13.8 1 32.1 PG&E 31402 BEAR CAN 13.8 1 9.8 PG&E 31402 BEAR CAN 13.8 2 9.8 PG&E 31404 WEST FOR 13.8 1 12.1 PG&E 31764 MALCHA 13.8 1 12.54 PG&E 31798 BRNYFRST 13.2 1 26.56 PG&E 31800 SMPSN-AN 12.47 1 42 PG&E 33132 GWF#2 13.8 1 12.33 PG&E 32910 UNOCAL 12 1 15.7 PG&E 32910 UNOCAL 12 2 15.7 PG&E 32910 UNOCAL 12 3 15.7 PG&E 35850 GLRYCGG1 13.8 1 82 PG&E 34050 CHSTN. 13.8 1' 10.02 PG&E 33816 IENERGY 12 1 14.5 PG&E 33818 COGNTNL 12 I I 35 PG&E 34054 MDSTO CN 13.8 1 = 4.45 PG&E 34056 STNSLSRP 13.8 1' 16.27 PG&E 33806 THE.OV. t3.8 1' 19.65 PG&E 33808 8,1COGEN 13.8 1' 45.24 PG&E 33814 CPC STCN 12,47 1 49 PG&E 33810 SP CMPNY 13.8 1' 37.7 PG&E 35004 SUNSETG1 13.8 11 75 PG&E 31902 HAT CRK1 6.e 11 8 I PG&E 31904 HAT CRK2 6.e 1 ~ 8.51 PG&E 31818 PIT 1 U1 11 11 30l PG&E 31818 PiT 1 U1 11 2 t 11.25 PG&E 31802 PiT 3 11.5 11 23 PG&E 31802 =IT3 11.5 21 18 I PG&E 31802 ' IT3 11.5 31 23 I PG&E 31766 )IT4 13.8 11 47 PG&E 31766 PIT4 13.8 21 32
I
Exh. ISO-55 Page 9 of 18
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~ m i a ISO Docket Nos. ER01-313-.004 et aL
PG&E 3485~ W1SHON PG&E 34343 ~ERCK1G1 PG&E 34344 KERCK1G2 PG&E 34345 KERCK1G3 PG&E KERCKHOF PG&E
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Exh ISO-55 Page 12 of 18
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C, alifom L~ ISO Docket Nos. ER01-313-004 et al.
;)G&E 38120 LODI25CT PC-&E 31900 GRIZZLYG PG&E 38860 CSCGNRA1 ~G&E 36859 CSCGNRA2 ~G&E 38114 STIG CC ~G&E 31435 GEO.ENGY PG&E 31435 GEO.ENGY PG&E 36906 W1N.-AMED F'G&E 36906 W1N-AMED PG&E 31846 COVE RD PG&E 31848 COVE..RD PG&E 31848 COVE ,,,RD ~G&E 31846 COVE=RD PG&E 31162 LOW GAP PG&E 31164 BLUFORD PC-&E 31166 KEKAWAK PG&E 3143( INDIAN V PG&E 31168 V~r~A BAKR PG&E 31554 GROUSCRK PG&E 31583 LEV~STON PG&E 31855 OLSEN PC-,&E 31590 CEDR CRK PG&E 31858 BAILEY+2 PG&E 31858 BNLEY+2 PG&E 31858 BAILEY+2 PG&E 31862 DEADWOOD PG&E 31475 KANAKA PG&E 31868 HATLOST+ PG&E 31868 HATLOST+ PG&E 31868 HATLOST+ PG&E 31870 FORK.BUTT ;'G&IE 31870 FORKBUTr PG&E 32488 HAYPRES+ PG&E 32488 HAYPRES+ IaG&E 31591 COWCREEK PG&E 33901 PHOENIX I=G&E 32375 BONNIE N ~G&E 33505 MURPHYS I:)G&E 31705 CLARK RD PG&E 31705 CLARK RD PG&E 33505 MURPHYS PG&E 31587 BEAR CRK PG&E 31872 CLOVER PG&E 34838 FRtANTDM PG&E 35020 RIOBRAVO PC-&E 31874 SPI-BURN I:~-&E 31876 BIG VLLY PG&E 31880 SPI-HAYF PG&E 31884 :'AC.ENGY PG&E 32490 GRNLEAFI PG&E 32492 GRNLEAF2 PG&E 32494 CUBA CTY
13.8 1 10 8.9 1 15.81
13.8 1 19.5 13.8 2 19.5 13.8 1 48,16 9.11 1 8.92 9.11 2 8.93
60 I I 6O 2 2
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Exh. ISO-55 Page 14 of 18
Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004
California tSO Docket No~. ER01-313-004 et af.
PG&E 32154 WADHAM PG&E 31888 OROENGY PG&E 31890 PO POWER PG&E 31890 PO POWER PG&E 36908 JELD-WEN PG&E 31892 PE.WWOOD PG&E 36910 HONEYLAK PG&E 36910 HONEYLAK PG&E 31894 COLLINS PG&E 31896 SPI-QUCY PG&E 31896 SPI-QUCY PG&E 32156 WOODLAND PG&E 32498 SPILINCF PG&E 32500 ULTR RCK PG&E 33826 MARTELL PG&E 33830 'GENMILL PG&E 31446 SONMA LF PG&E 33151 FOSTER W PG&E 33151 IFOSTER W PG&E 33151 FOSTER W PG&E 33466 tUNTED CO PG&E 33488 SRI INTL PG&E 32738 OLS PG&E 33160 DOW CHEM PG&E 33133 GWF #3 PG&E 33145 CROWNZ. PG&E 32920 UNION CH PG&E 33139 STAUFER PG&E 33131 ,GWF #1 F)G&E 33135 GWF ~G&E 35860 'OLS-AGNE ~G&E 36856 CSC CCA ~G&E 35863 CATALYST PG&E 34332 JRWCOGEN PG&E 34334 BIO PWR PG&E 33483 CARDINAL PG&E 36418 ST MARIA PG&E 34840 ULTR.I:~N~ PG&E 34842 KINGSBUR
SANGERCO JG&E 34646 PG&E 34848 IDINUBA E PG&E 34650 GWF-PWR. PG&E 34653 'DERRICK PG&E 34653 DERRICK PG&E 34654 COLNGAGN PC-&E 35024 ,DEXEL + JG&E 35026 KERNFRNT IG&E 34733 IDOUBLE C
PG&E 34723 dlSIERRA PG&E 34727 BADGERCK PG&E 35025 IOILDALE PG&E 35032 3HV-CYMR
9.11 1 22.84 9.11 I 8.5 9.11 1 9.11 2
60 I I 12 1 10.5 60 I 60 2
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12 1 4.65 9,11 1 22.12 9.11 1 11 9,11 1 2.5 9.11 I 4
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12 I 26 13.8 I 19.77 13.8 I 19.0: 13.8 1 40 9.11 1 20.37 4.16 I 1.95 9.11 I 12.74 13.8 I 18.94 9.11 1 9.86 13.8 1 23.75
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Exh. ISO-55 Page 15 of 18
Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004
California ISO Docket Nos. ER01-313-004 et aL
PG&E 34783 TEXCO_NM PG&E 3478~ TEX MCKT PG&E 3503~ MT POSO PG&E 34757 UNIVRSTY PG&E 3503~ CHALKCLF PG&E 3504C KERNRDGE PG&E 350441TX MIDST PG&E 3804~ SHL-KERN PG&E 3504~ FRITOLAY PG&E 3505(: SLR-TANN PG&E 35052 CHEV.USA PG&E 350581PSE-LVOK PG&E 350~ PSEMCKIT PG&E 350~ DISCOVRY PG&E 35064, NAVY 35R PG&E 35064 NAVY 35R PG&E 33136' CCCSD PG&E 35066 PSE-BEAR PG&E 32165: USW1NDPW PG&E 32168 USWINDPW PG&E 30570 USWP-RLF PG&E 30575 WND MSTR PG&E 33175 ALTAMONT PG&E 33175 ALTAMONT PG&E 33838 USWP=#3 PG&E 33840 FLOWD3-6 PG&E 33171 NE&HOWO PG&E 30655 ADCC PG&E 35312 SEAWESTF PG&E 35314 WALKER+ PG&E 35316 ZOND SYS PG&E 35208 USWI:LFRK PG&E 35318 FLOWDPTR PG&E 33576 USWP-PAT PG&'E 33576 USWP-PAT PG&E 33576 USWP-PAT PG&E 33576 USWP-PAT PG&E 33579 FAYETTE PG&E 33578 FAYETTE PG&E 33578 FAYETI'E PG&E 33578 FAYETI'E PG&E 34342 INT.TURB PG&E 37549 FOLSOMI PG&E 37550 FOL$OM2 PG&E 37551 FOLSOM3 PG&E 37553 J.F.CARR PG&E 37553 J.F.CARR PG&E 37645 NIMBUS12 PG&E 37645 N(MBUS12 PG&E 37561 MELONE1 PC-&E 37562 MELONE2 PG&E 37575 SHASTA1
9.11 1 5.38 9.11 1 2.7 13.8 t 50
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12 1 ,4.25 6.g 1 14.95
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Exh. IS0-55 Page 16 of 18
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California ISO Docket Nos. ER01-313-004 et al.
PG&E 34539 GWF GT1 13.8 1 49 PG&E 34541 GV~ GT2 13.8 1 49 PG&E 34186 DG PAN1 13.8 1 49 PG&E 32963 GROYPKR1 13.8 1 48.7 PG&E 32964 GROYPKR2 13.8 2 48.7 PG&E 32965 GROYPKR3 13.8 3 48.7 PG&E 31154 HUMBOLDT 13.2 1 15 PG&E 31154 HUMBOLDT 13.2 2 15 PG&E 31400 SANTAFE 13.8 2 32.1 PG&E 38556 WALNUT1 13.8 1 0 PG&E 38558 WALN UT2 13.8 1 0 F~3;&E 30464 EXXON,. BH 12.47 1 52 PG&E 35009 SUNSETG2 13.8 2 75 PG&E 35010 SUNSETG3 13.8 3 75 PG&E 35035 ULTRAOGL 13.8 1 34.47 PG&E 35078 ELKHIL3G 18 1 SMUD OWN 225.5 PG&E 35077 ELKHIL2G 18 1 SMUD OWN 166.8 PG&E 35076 ELKHIL1G 18 1 SMUD OWN 166.8 PG&E 36202 BAF COG1 13.8 1 38 PG&E 36203 BAF COG2 13.8 1 75 ~G&E PTSB 1 PG&E PTSB 2 PG&E PTSB 3 PG&E PTSB 4 PG&E FMC CT PG&E 33687 SCE 24120 SCE 24149 PG&E 33918 PG&E 31451
STKTN 60 1 Smurflt Stone Container Corp, Jeffenmn Smunlr Coqx~ Berry Petroleum Placenta, Berr~ Petroleum I SPI-Standard ~on-tine), Siena Pacific Indu=dnes WE~S Shasta Energy (on-line). Wheelabrator Enviro~me
Exh. IS0-55 Page 18 of 18
Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004
UNITED STATES OF AMERICA BEFORE THE
FEDERAL ENERGY REGULATORY COMMISSION
California Independent System Operator Corporation
Pacific Gas and Electric Company
Docket No. E R01-313-004
Docket No. ER01-424-004
DECLARATION OF WITNESS
I, Deane Lyon, declare under penalty of perjury that the statements contained in
the Prepared Direct Testimony on behalf of the California Independent System
Operator Corporation in this proceeding are true and correct to the best of my
knowledge, information, and belief.
Executed on this 17th day of December, 2004.
Deane Lyon
Jnofflclal FERC-Generated PDF of 20041221-0327 Received by FERC OSEC 12/20/2004 in Docket#: ER01-313-004
CERTI~CATE OF SERVICE
I hereby certify that I have this day served a copy of this document upon all parties limed on the
official service list compiled by the Secretary in the above-captioned proceedings, in accordance with the
requirements of Rule 2010 of the Commission's Rules of Practice and Procedure (18 C.F.R. § 385.2010).
Dated this 20 ~h day of December in the year 2004 at Folsom in the State of California.
Stephen A.S. Morrison