February 9, 2007
Mr. Raymond Palmieri
Vice President and Director, Compliance
ReliabilityFirst Corporation
220 Market Ave South
Suite 501
Canton, OH 44702
Dear Mr. Palmieri,
PJM, in its role as a registered Balancing Authority, Planning Authority, Reliability Coordinator, Transmission
Operator and Transmission Planner, is responsible to submit data to NERC, RFC and SERC under Modeling
Standards MOD-017 through MOD-021. Attachment 1 lists the requirements contained in these standards.
The data provided by PJM under these standards includes the load for all PJM member companies that serve load
including distribution companies, power marketers and retail energy suppliers. PJM understands that these entities
will not be required to report duplicate information to RFC under these standards. Attached is a list of PJM Member
companies registered with ReliabilityFirst as Load Serving Entities, Transmission Planners, Planning Authorities and
Resource Planners whose requirements are covered by the PJM data submittal.
Please contact me at (610)666-4597 or Mark Kuras at (610)666-8924 if you have any questions.
Sincerely,
Alicia E. Daugherty
Manager, NERC and Regional Coordination
Cc:
401019
Gary Campbell, RFC
Paul Kure, RFC
Jim Uhrin, RFC
Tom Bowe, PJM
Mark Kuras, PJM
Susan McGill, PJM
Page 1 of 4
Attachment 1 – Requirements of MOD-017 through MOD-021
MOD-017-0
Aggregated Actual and Forecast Demands and Net Energy for Load
R1. The Load-Serving Entity, Planning Authority and Resource Planner shall each provide the following information
annually on an aggregated Regional, subregional, Power Pool, individual system, or Load-Serving Entity basis to
NERC, the Regional Reliability Organizations, and any other entities specified by the documentation in Standard
MOD-016-0_R1.
R1.1. Integrated hourly demands in megawatts (MW) for the prior year.
R1.2. Monthly and annual peak hour actual demands in MW and Net Energy for Load in gigawatthours
(GWh) for the prior year.
R1.3. Monthly peak hour forecast demands in MW and Net Energy for Load in GWh for the next two years.
R1.4. Annual Peak hour forecast demands (summer and winter) in MW and annual Net Energy for load in
GWh for at least five years and up to ten years into the future, as requested.
MOD-018-0
Reports of Actual and Forecast Demand Data
R1. The Load-Serving Entity, Planning Authority, Transmission Planner and Resource Planner’s report of actual and
forecast demand data (reported on either an aggregated or dispersed basis) shall:
R1.1. Indicate whether the demand data of nonmember entities within an area or Regional Reliability
Organization are included, and
R1.2. Address assumptions, methods, and the manner in which uncertainties are treated in the forecasts of
aggregated peak demands and Net Energy for Load.
R1.3. Items (MOD-018-0_R1.1) and (MOD-018-0_R1.2) shall be addressed as described in the reporting
procedures developed for Standard MOD-016-0_R1.
R2. The Load-Serving Entity, Planning Authority, Transmission Planner and Resource Planner shall each report data
associated with Reliability Standard MOD-018-0_R1 to NERC, the Regional Reliability Organization, Load-Serving
Entity, Planning Authority, and Resource Planner on request (within 30 calendar days).
MOD-019-0
Forecasts of Interruptible Demands and DCLM Data
R1. The Load-Serving Entity, Planning Authority, Transmission Planner, and Resource Planner shall each provide
annually its forecasts of interruptible demands and Direct Control Load Management (DCLM) data for at least five
years and up to ten years into the future, as requested, for summer and winter peak system conditions to NERC, the
Regional Reliability Organizations, and other entities (Load-Serving Entities, Planning Authorities, and Resource
Planners) as specified by the documentation in Reliability Standard MOD-016-0_R1.
MOD-020-0
Providing Interruptible Demands and DCLM Data
R1. The Load-Serving Entity, Transmission Planner, and Resource Planner shall each make known its amount of
interruptible demands and Direct Control Load Management (DCLM) to Transmission Operators, Balancing
Authorities, and Reliability Coordinators on request within 30 calendar days.
MOD-021-0
Accounting Methodology for Effects of Controllable DSM in Forecasts
R1. The Load-Serving Entity Transmission Planner and Resource Planner’s forecasts shall each clearly document
how the Demand and energy effects of DSM programs (such as conservation, time-of-use rates, interruptible
Demands, and Direct Control Load Management) are addressed.
R2. The Load-Serving Entity, Transmission Planner and Resource Planner shall each include information detailing
how Demand-Side Management measures are addressed in the forecasts of its Peak Demand and annual Net
Energy for Load in the data reporting procedures of Standard MOD-016-0_R1.
R3. The Load-Serving Entity, Transmission Planner and Resource Planner shall each make documentation on the
treatment of its DSM programs available to NERC on request (within 30 calendar days).
401019
Page 2 of 4
Attachment 2 – PJM Member Companies Registered as LSE/PA/RP/TP
Member Name
AEP Agent for Appalachian Power Company, Columbus Southern
Power Company, Indiana Michigan Power, Kentucky Power, Kingsport
Power, Ohio Power, Wheeling Power
Allegheny Electric Cooperative, Inc.
Allegheny Power
American Municipal Power-Ohio, Inc.
American PowerNet Management, L.P.
Atlantic City Electric Company
Baltimore Gas and Electric Company
Blue Ridge Power Agency, Inc.
Blue Star Energy Services, Inc.
BOC Energy Services, Inc.
Borough of Chambersburg
Borough of Ephrata
BP Energy Company
Buckeye Power, Inc.
City of Dowagiac
CMS Energy Resource Management Company
Commonwealth Edison Company
ConEdison Energy, Inc.
Consolidated Edison Solutions, Inc.
Constellation Energy Commodities Group, Inc.
Constellation NewEnergy, Inc.
Consumers Energy Company
Dayton Power & Light Company
Delmarva Power & Light Company
Detroit Edison Company
Direct Energy Services, LLC
Dominion Retail, Inc.
DTE Energy Trading, Inc.
Duquesne Light Company
Duquesne Light Energy, LLC
Eagle Energy Partners I, L.P.
Easton Utilities Commission
Energy Cooperative Association of Pennsylvania
Exelon Energy Company
FirstEnergy Solutions Corp.
Hoosier Energy REC, Inc.
Illinois Municipal Electric Agency
Indiana Municipal Power Agency
Jack Rich, Inc. d/b/a Anthracite Power & Light Company
Jersey Central Power & Light Company
MidAmerican Energy Company
Northern Indiana Public Service Company
401019
Registered Function(s)
LSE
PA
RP
TP
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Page 3 of 4
Member Name
Ohms Energy Company
Old Dominion Electric Cooperative
PECO Energy Company
Pepco Energy Services, Inc.
Potomac Electric Power Company
PPL Electric Utilities Corporation d/b/a PPL Utilities
PPL EnergyPlus, LLC
PSEG Energy Resources and Trade, LLC
Public Service Electric and Gas Company
Reliant Energy Electric Solutions, LLC
Rockland Electric Company (Registered with RFC as Orange &
Rockland Utilities)
Select Energy, Inc.
Sempra Energy Solutions
South Jersey Energy Company
Southern Maryland Electric Cooperative, Inc.
Strategic Energy, LLC
UGI Energy Services, Inc.
UGI Utilities, Inc.
Vineland Municipal Electric Utility (Registered with RFC as City of
Vineland, New Jersey)
Wabash Valley Power Association, Inc.
Wisconsin Electric Power Company
Wolverine Power Supply Cooperative, Inc.
WPS Energy Services, Inc.
401019
Registered Function(s)
LSE
PA
RP
TP
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
X
Page 4 of 4