WESTERN ELECTRICITY COORDINATING COUNCIL
DATA COLLECTION MANUAL
January 17, 2013
W E S T E R N
E L E C T R I C I T Y
C O O R D I N A T I N G
C O U N C I L
•
W W W . W E C C . B I Z
155 NORTH 400 WEST • SUITE 200 • SALT LAKE CITY • UTAH • 84103 -1114 • PH 801.582.0353 • FX 801.582.3918
WECC Data Collection Manual
This page intentionally left blank.
January 17, 2013
ii
WECC Data Collection Manual
Table of Contents
Introduction and Overview............................................................................................... 1
Attachment A:
Excel Workbook ................................................................................... 5
Attachment B:
Existing and Planned Generation Reporting Instructions ................... 11
Reporting Instructions for Existing Generation and Generation
Additions Data .................................................................................... 13
Existing Generation and Generation Additions Data: Facility
Record Format ................................................................................... 15
Correlation of NERC Class Codes and WECC Class Codes ............. 22
Attachment C:
Peak Demands, Energy Loads, Resource Outages, and Actual
Transfers Instructions ......................................................................... 25
Input Guide for Peak Demand Loads, DSM, Outages, and
Transfers Data .................................................................................... 27
Data Types and Codes ....................................................................... 28
Actual Peak Demand Loads, DSM, Outages, and Transfers
Data Code Definitions......................................................................... 31
60-Minute Peak Demand MW ............................................................ 31
Estimated Peak Demand Loads, DSM, Outages, and Transfers
Data Code Definitions......................................................................... 33
Actual and Estimated Peak Demand Loads and Transfers
Coding Data Record Format ............................................................... 35
Energy Loads Instructions .................................................................. 37
Actual and Estimated Energy Loads Coding Data Record
Format ................................................................................................ 38
Attachment D:
Reliability and Supply Assessments ................................................... 41
Actual Generation ............................................................................... 43
Transfer Path Capabilities .................................................................. 43
Load Temperature Sensitivity Data .................................................... 44
Regulating Reserves .......................................................................... 44
Energy Efficiency ................................................................................ 44
January 17, 2013
iii
WECC Data Collection Manual
Attachment E:
Miscellaneous Data ............................................................................ 47
Hourly Demand .................................................................................. 49
Hourly Wind Production ...................................................................... 49
Hourly Solar Production...................................................................... 50
Projected Transmission Line Additions............................................... 51
Projected Transformer Additions ........................................................ 55
Transmission Line Circuit Miles .......................................................... 57
Remote Resources ............................................................................. 57
Demand-Side Management (DSM) Programs .................................... 58
Appendix A:
Glossary for WECC Data Collection Manual ...................................... 59
Appendix B:
WECC Balancing Authorities and Abbreviations ................................ 67
WECC Balancing Authorities .............................................................. 69
State Abbreviations ............................................................................ 70
Appendix C:
List of Balancing Authorities and Load-Serving Entities by
Power Areas ....................................................................................... 71
Canada Power Area ........................................................................... 73
Basin Power Area ............................................................................... 76
Rocky Mountain Power Area .............................................................. 78
Desert Southwest Power Area ........................................................... 80
Northern California Power Area .......................................................... 82
Southern California Power Area ......................................................... 84
Mexico Power Area ............................................................................ 85
Appendix D:
WECC Criteria for Uniform Reporting of Generator Ratings ............... 87
Appendix E:
Exhibit B – Collection and Review of Loads and Resources Data ...... 91
January 17, 2013
iv
WECC Data Collection Manual
Introduction and Overview
Purpose
The Western Electricity Coordinating Council (WECC) Data Collection Manual (Manual)
provides instructions for reporting various loads and resources (L&R) information that
the WECC requests from all Balancing Authorities (BA) in the Western Interconnection.
The information is used for a variety of analytic activities and reporting purposes.
Portions of the WECC L&R information are used by the North American Electric
Reliability Corporation (NERC) in its reliability assessment reports.1 The information is
also the basis for the resource adequacy evaluation contained in WECC’s Power
Supply Assessment (PSA).2
Portions of the information are reported by NERC to the U.S. Department of Energy’s
(DOE) Energy Information Administration (EIA) in satisfaction of its Form EIA-411 filing
requirements.3 Annual and seasonal filings are submitted to NERC under NERC’s
Standards and Guides compliance templates, according to NERC Rules and Procedure
Section 800.4
Data Submission Due Date
The data must be submitted to WECC by the first Friday of March.
Important Note to Member and Balancing Authority Representatives:
Information Reporting Responsibility
Planning Coordinating Committee (PCC) representatives are responsible for reporting
L&R information for their organizations.5
PCC Representatives of Balancing Authorities
The PCC representatives of the organizations that operate the BAs in the Western
Interconnection are responsible for reporting the requested information. The L&R
information is for the entire BA area (both member and nonmember entity information)
and is to include the BA’s information as well as the information for all non-BA entities
within the BA’s area. The non-BA entity information includes planning information such
as generation additions, load forecasts of LSEs, and scheduled maintenance outages.
The PCC or Member representatives of the non-BA entities are responsible for reporting
1
NERC Assessments
2
WECC Power Supply Assessments
3
http://www.eia.doe.gov/cneaf/electricity/page/eia411/eia411.html
4
http://www.nerc.com/fileUploads/File/Rules_of_Procedure/NERC_Rules_of_Procedure_EFFECTIVE_2
0111117_without_appendices.pdf
5
PCC Charter
January 17, 2013
1
WECC Data Collection Manual
their organizations’ information to the BA and for developing appropriate data collection
procedures to ensure that all requested information is provided to the appropriate nonBA entities and that there is no duplication or double reporting of the information. It is
important to note that, in developing its actual and forecast demand values, each LSE
shall count peak demand and energy load only one time on an aggregated and
dispersed basis. The demand, net energy for load, and controllable Demand-Side
Management (DSM) supplied for this WECC Data Collection request shall be consistent
with the demand, net energy for load, and controllable DSM supplied in response to the
eleven annual Power Flow Base Case data requests.
PCC or Member Representatives of Non-Balancing Authority Entities
The PCC or Member representatives of non-BA entities are responsible for responding
to BA requests for planning information such as generation additions, load forecasts,
and scheduled maintenance outages.
PCC or Member representatives may designate reporting contacts within their
organizations. The designated reporting contacts will be asked to provide the requested
information to the WECC staff by the established due date and to answer questions that
may arise concerning that information. However, the PCC or Member representatives
are ultimately responsible for the quality and timeliness of the data reported for their
organizations.
Information Requirements and Manual Overview
This Manual consists of five attachments and associated appendices. Attachment A
consists of an explanation of pages and terms found in the Excel workbook used to
collect data requested in Attachments B and C. Attachment B contains instructions for
reporting existing and planned generation capacity. Attachment C is the instruction for
reporting peak demands, energy loads, resource outages, and actual year transfers.
Attachment D contains the reporting instruction for Power Supply Assessment data and
Attachment E contains the instructions for several miscellaneous requests.
Long-Term Reliability Assessment (LTRA) and Season Assessment Information
Requirements
The LTRA data is primarily gathered through the WECC data request and the season
assessment information request. The LTRA incorporates the transfers between
subregions that are derived during the development of the PSA. Additional information
and/or narrative questions for the LTRA and the Seasonal Assessments will be
requested from the BAs after WECC receives these instructions from NERC.
Data Confidentiality
Exhibit B of the WECC Reliability Information Sharing Policy addresses confidentiality
procedures for L&R data. Exhibit B is presented in Appendix E of this Manual.
All data, except as specified in Exhibit B, will be considered non-confidential. Exhibit B,
Section C.1 states: "The following information will be treated as confidential under the
“WECC Reliability Information Sharing Policy, Section D – Protecting Confidential,
January 17, 2013
2
WECC Data Collection Manual
Privileged, and Proprietary Information”6 (approved by the Board on December 2005):
first three years of future data on projected peak demand, energy load, and scheduled
outages. These data will remain confidential for three years from the date of
designation, after which the data will become non-confidential. Future year peak
demands, future year energy load, and future year scheduled outages data beyond
three years will not be deemed confidential."
Data Submission
The completed Excel workbook should be sent via email to dick@wecc.biz on or before
the Data Submission Due Date. Since BAs are responsible for reporting data from nonBA entities within their respective areas, BAs should establish earlier dates for collecting
coordinated future year data from the non-BA entities. The LRS procedures specify that
the LRS chair will contact the PCC representatives of reporting entities that have not
submitted their data by the Data Submission Due Date. The LRS and PCC chairs will
also contact the PCC representatives of reporting entities that have provided data that
are incomplete or are inconsistent with these reporting instructions.
List of NERC Registered Load-Serving Entities within the WECC Region
It is requested that BAs review and update the List of NERC registered Load-Serving
Entities that are located within their BA footprint (see Appendix C).
Comments on this Manual
Questions on data reporting, or suggestions for improving the Data Collection Manual,
should be directed to WECC staff, Dick Simons or Layne Brown, at (801) 582-0353.
6
WECC Information Sharing Policy
January 17, 2013
3
WECC Data Collection Manual
This page intentionally left blank.
January 17, 2013
4
WECC Data Collection Manual
Attachment A: Excel Workbook
January 17, 2013
5
WECC Data Collection Manual
Attachment A
This page intentionally left blank.
January 17, 2013
6
WECC Data Collection Manual
Attachment A
Excel Workbook
An Excel workbook is used for the L&R data reporting. The workbook contains L&R
data that must be updated and, as needed, have projections added. There are also
several reports and charts that show results related to the data submitted through the
workbook, along with some data checking. The workbook is rather large and will work
best if automatic calculation is turned off.
Workbook Structure
The following table is a summary of the worksheets in the workbook.
Worksheet
Main
Status
Description
Used to hold pertinent information about the represented area.
Explains data requirements and provides feedback regarding the status of
the input data.
gen_exist
Data input sheet for existing generation information.
gen_add
Data input sheet for generation additions information.
peak_data
energy_data
growth
load_diff
Data input sheet for the “peak” data, including peak loads, outages, and
actual transfers.
Data input sheet for energy load information
A data checking form for load growth.
A data checking form for month-to-month load differences.
load_chart
A series of charts representing the reported loads and load forecasts.
load_comp
Comparison sheet of previous and current energy load data.
LoadOut
Actual
Generation
Comparison sheet of previous and current peak demands data.
Data input sheet for actual generation from Wind, Solar, Hydro, and
Biomass resources.
Paths
Data input sheet for transmission paths between modeling areas.
Tsens
Data input sheet for temperature sensitivity information.
Regulating
Reserves
Data input sheet for regulating reserves information.
Energy
Efficiency
Data input sheet for energy efficiency information.
Hourly Demand
Data input sheet for hourly demand for actual year.
Hourly Wind
Data input sheet for actual hourly wind generation information. (Multiple
sheets if required)
Hourly Solar
Data input sheet for actual hourly solar generation information. (Multiple
sheets if required)
January 17, 2013
7
WECC Data Collection Manual
Worksheet
Attachment A
Description
Projected
Transmission
Data input sheet for projected transmission additions.
Projected
Transformer
Data input sheet for projected transformer additions.
Transmission
Miles
Data input sheet for existing transmission line circuit miles.
Remote
Resources
DSM Programs
DVal
Data input sheet for ownership percentages of generation resources
located outside of generation owners BA.
Voluntary data input sheet for DSM programs.
Data validation checks used in conjunction with the Status sheet of the
workbook.
There are a few other worksheets in the workbook. These are hidden
intentionally and should not be modified or disturbed. These are for WECC
staff only.
Data Reporting
The data input sheets ({gen_exist}, {gen_add}, {peak_data}, and {energy_data}) must
be updated and checked as part of the L&R data submittal process. The descriptions of
the data input sheets are presented below (see Attachments B and C for detailed
instructions). There should not be any blank rows in the final versions of the data input
sheets. When adding, copying, or deleting rows, it is recommended that row-level
editing be used (i.e., click on the row heading(s) to select). Also, data that needs to be
deleted should be deleted, not lined through. Lined through data are not excluded when
a spreadsheet sums numerical values.
The existing generation {gen_exist} worksheet is a detailed list of the generating units in
the BA area with in-service dates up to the end of the actual year. Check the data
provided in the data request spreadsheet for accuracy and update as necessary,
including updating actual retirement dates. If there are older existing units missing from
the list, or new units that need to be added, insert a new row and provide the
information requested.
The generation additions {gen_add} worksheet is a detailed list of the generating units
in a BA’s area that represent anticipated increases or decreases in generating capacity
during future years. This includes retirements, up-rates and derates to existing plants,
and new generation construction. Update the provided list per the instructions and add
rows as necessary to provide information for new additions and other changes.
The {peak_data} worksheet is a listing of BA loads, outages, actual transfers, and other
miscellaneous data.
The {energy_data} worksheet contains the actual and projected energy load data for the
BA.
January 17, 2013
8
WECC Data Collection Manual
Attachment A
Data Checking
One of the goals of this workbook is to improve the accuracy of the data submittals. This
should help to meet the NERC deadlines for forwarding the WECC information. The
following data checks should be used to validate the data and locate data
inconsistencies.
1. Load Growth – the {growth} worksheet lists the annual changes in peak demands
and energy loads (% Growth rows) and highlights in yellow year-to-year load growth
changes that exceed ± 1% (% Difference rows). An explanation is required for each
of the highlighted ‘% Difference’ load growths. The purpose of this data check is to
identify the causes of unusual patterns in BA load forecasts that may be the result of
the addition or deletion of major loads (e.g., startup or shutdown of a large industrial
facility). Explanations regarding load changes from the prior actual year load to the
current actual year load and from the current actual year load to the first future year
forecast load should include references to the actual weather conditions experienced
during the prior actual year and the current actual year. The charts in the
{load_chart} worksheet can also be helpful for locating inconsistent and/or erroneous
data.
2. Load Differences – the peak demand and energy load pattern is expected to repeat
each year, with some growth from year to year. The differences in the monthly loads
from year to year are presented in the {load_diff} worksheet. Charts in the
{load_chart} worksheet show the patterns from year to year. A chart is also provided
that presents a comparison of the actual peak demands and energy loads to the
Hourly Demand data.
Calculation
The calculation mode should be set to manual to avoid long calculation delays each
time data is entered. The workbook may require several minutes to calculate.
With the calculation mode set to manual, the formulas are not calculated and cell results
are not automatically updated. Pressing function key F9 will initiate a manual calculation
of the entire workbook. Once the calculation is completed, the word ‘Ready’ will be
displayed at the left of the status bar. The calculation progress display is generally not
indicative of the actual progress. Typing or clicking with the mouse will often interrupt
the calculation process, so it is important to be patient. If the word ‘calculate’ is
displayed on the status bar, then a change has been made to the workbook that may or
may not be reflected in the results.
It is recommended that users enter as much data as possible before initiating the
calculation process. Note that if the Automatic Calculation option is enabled, the
workbook is also calculated each time that it is saved.
Data Submission
After updating and checking the data, the workbook should be sent via email to
dick@wecc.biz. The LRS procedures specify that the LRS chair will contact the PCC
January 17, 2013
9
WECC Data Collection Manual
Attachment A
representatives of reporting entities that have not submitted their data in accordance
with the Data Submission Due Date. The LRS chair may also contact the PCC
representatives of reporting entities that have provided data that are incomplete or are
not consistent with these reporting instructions.
Data Errors and need for Clarification
WECC staff will contact a BA should the data checking process reveal a potential error
or the need for clarification, detailed explanation, or both in the L&R data submitted in
the BA’s workbook. If the data checking process reveals the need for the BA to provide
comments regarding the L&R workbook data (e.g., certain changes in growth rates
exceed pre-defined ranges), WECC staff will contact the affected BA. WECC staff will
not make significant data changes without notifying the BA affected by the change.
January 17, 2013
10
WECC Data Collection Manual
Attachment B:
Existing and Planned Generation Reporting
Instructions
January 17, 2013
11
WECC Data Collection Manual
This page intentionally left blank.
January 17, 2013
12
WECC Data Collection Manual
Attachment B
Reporting Instructions for Existing Generation and Generation
Additions Data
Data Reporting Process
Existing generation and generation additions worksheets are described in Attachment A
of this Manual. The data are updated by changing the information presented in the
worksheets for the BA. The changes should make the information current as of
December 31 of the actual year and, for BAs in the U.S., should be consistent with the
data reported to the DOE in Form EIA-860.
The existing generation {gen_exist} worksheet is a detailed list of all generating units in
the BA area with in-service dates up to the end of the actual year. Check the data
provided for accuracy and update as necessary, including updating actual retirement
dates. If there are units missing from the list, or new units need to be added, insert a
new row and provide the information requested. For units that were retired during the
actual year, report zero (0) capacity in the summer and winter capacity columns, update
the Retirement Date to reflect the actual retirement date, and update the Status Code to
RE. If a unit was rerated during the actual year, report the new total capacity in the
summer and winter columns. Units with a NERC class code of Existing-Inoperable (EI)
are to be reported with a summer and winter capacity of zero (0).
Units with a Status Code of OS are reported with a summer and winter capacity of zero
(0). A cold standby unit should be reported as SB, with a summer and winter capacity
that reflects the expected available capacity of the unit.
Data for each unit that came into service during the actual year are to be added, with a
Status Code of OP and a Commission date, to the {gen_exist} sheet and removed from
the {gen_add} sheet. Likewise, data for each unit that was retired during the actual year
are to be updated on the {gen_exist} sheet, with a Status Code of RE and a Retirement
date, and removed from the {gen_add} sheet.
The generation additions {gen_add} worksheet is a detailed list of the generating units
in a BA’s area that represent anticipated increases or decreases in generating capacity
during future years. This includes retirements and up-rates or derates to existing plants
and new generation construction. Update the provided list and add rows as necessary
to provide information for new additions and other changes. Planned retirements should
be reported as negative values in the summer and winter capacity column (equal to the
capacity reported on the {gen_exist} sheet), with the anticipated retirement date
reported in the Retirement Date column. Planned up-rates and derates should be
reported as the incremental change (a positive or negative value) that, when added to
the existing capacity reported on {gen_exist}, nets to the future planned capacity. The
anticipated rerate date should be reported in the Commission Date column.
Units that were reported on {gen_add} last year but are not being reported this year
should remain on the {gen_add} sheet (for one year only) with the NERC Class Code
blank, and a WECC Class Code of 5. This process allows WECC staff to track the
progress of planned units.
January 17, 2013
13
WECC Data Collection Manual
Attachment B
Comments should be included in the comment fields as appropriate. For example: for
each inoperable unit state that the unit is in deactivated shutdown, on cold standby, etc.
For units that were retired or derated during the actual year, or are planned to be retired
or derated, indicate the reason for the retirement or derate (e.g., due to EPA
regulations) in the comments field.
The combustion turbine portions and steam portions of combined cycle units should be
reported separately. The rating of each should be equal to the rating that applies when
the units are operated in a combined cycle configuration. Therefore, the sum of the
ratings of each component should equal the rated output of the combined cycle unit. (An
existing steam or combustion turbine unit that is planned to be converted to a combined
cycle unit should not be reported as a combined cycle unit.)
Since the master database will be manually updated based on submitted worksheet
revisions, highlight, in green, all worksheet cells (not rows) where changes are made.
Updated worksheets should be submitted via email to dick@wecc.biz on or before the
Data Submission Due Date.
January 17, 2013
14
WECC Data Collection Manual
Attachment B
Existing Generation and Generation Additions Data:
Facility Record Format
Field Name
Explanation
EIA Plant
Code
EIA Plant Code
EIA Unit Code
EIA Unit Code
Zone
For BAs with resources in multiple modeling areas, enter the zone where the
resource is located. The affected BAs and the zone names are identified below.
For all other BAs, enter the same code as entered in the BA column.
Modeling Area/Zone Table
BA →
AZPS
WALC
WACM
PACE
CISO
IPCO
Modeling Area ↓
Zones
Zones
Zones
Zones
Zones
Zones
IID
AZID
Arizona
AZAZ
WAAZ
New Mexico
AZNM
WANM
Colorado
WACO
Wyoming
WAWY
PAWY
Idaho
PAID
Utah
PAUT
PG&E_Bay
CIPB
PG&E_Vly
CIPV
SCE
CISC
SDGE
CISD
Treas Vly
IPTV
Magic Vly
IPMV
Far East
IPFE
Field Name
Explanation
BA
Balancing Authority code (see Appendix B).
Org
Name/acronym of Load Serving Entity where the unit is located (see Appendix
C for list of LSE names).
Unit Name
Power Plant Unit Name (Unit Name plus Unit Number should create a unique
identifier for the unit.)
January 17, 2013
15
WECC Data Collection Manual
Attachment B
Field Name
Explanation
Unit Number
Unit Number (Do not leave blank)
Unit Type
The following options are included in the workbook:
ST ....... Steam Turbine, including nuclear, geothermal and solar steam (does
not include combined cycle)
GT ....... Combustion (Gas) Turbine - Simple Cycle (includes jet engine design)
IC ........ Internal Combustion Engine (diesel, piston, reciprocating)
CA ....... Combined Cycle Steam Part
CT ....... Combined Cycle Combustion Turbine Part (type of coal or solid must
be reported as energy source for integrated coal gasification)
CS ....... Combined Cycle Single Shaft (combustion turbine and steam turbine
share a single generator)
CC ....... Combined Cycle Total Unit (use only for future generation)
CD ....... Combined Cycle Duct Firing
HY ....... Hydraulic Turbine (includes turbines associated with delivery of water
by pipeline)
HY-R ... Hydraulic Turbine that qualified as a renewable resource under
applicable state or province definition
PS ....... Hydraulic Turbine – Reversible (pumped storage)
BT ....... Turbines Used in a Binary Cycle (such as used for geothermal
applications)
PV-T .... Solar Photovoltaic with Tracking
PV-NT . Solar Photovoltaic without Tracking
SP-S.... Solar Thermal with Storage
SP-NS . Solar Thermal without Storage
WT ...... Wind Turbine, Onshore
CE ....... Compressed Air Energy Storage
FC ....... Fuel Cell
OT ....... Other
OS ....... Other Storage
NA ....... Undetermined/Unknown
Note: The following resources should be reported as Other (OT) with the
associated abbreviation listed in the comments field.
- Energy Storage, Battery (BA),
- Energy Storage, Concentrated Solar Power (CP),
- Energy Storage, Flywheel (FW),
- Hydrokinetic, Axel Flow Turbine (HA),
- Hydrokinetic, Wave Body (HB),
- Hydrokinetic, Other (HK),
- Wind Turbine, Offshore (WS)
Nameplate
The initial capacity of a piece of electrical equipment as stated on the attached
nameplate. Actual capability can vary from the nameplate rating due to age,
wear, maintenance, or ambient conditions. Data to be entered in MW, rounded
to the tenth of a MW.
January 17, 2013
16
WECC Data Collection Manual
Attachment B
Field Name
Explanation
Summer Cap
The expected capability available to the grid, of a generating unit during the
peak of the summer season. Do not include station service capacity and do not
reduce to reflect planned outages (e.g., scheduled maintenance). Data to be
entered in MW, rounded to the tenth of a MW.
Winter Cap
The expected capability available to the grid, of a generating unit during the
peak of the winter season. Do not include station service capacity and do not
reduce to reflect planned outages (e.g., scheduled maintenance). Data to be
entered in MW, rounded to the tenth of a MW.
Cogen
Equipment used to produce electric energy and forms of useful thermal energy,
such as heat or steam, used for industrial, commercial, heating, or cooling
purposes, through sequential use of energy. Enter “True” if unit is a
cogeneration unit.
Cogen
Summer Cap
This is the must run (capacity needed for on-site process) net capacity of the
cogeneration unit available to the system during the summer season. Do not
include generator output committed to serve self-generation requirements. Data
to be entered in MW.
Cogen Winter
Cap
This is the must run (capacity needed for on-site process) net capacity of the
cogeneration unit available to the system during the winter season. Do not
include generator output committed to serve self-generation requirements. Data
to be entered in MW.
For conventional technology generation, refer to WECC Criteria for Uniform Reporting
of Generator Ratings (Appendix D) for rating instructions.
Field Name
Explanation
The following options are included in the workbook:
Primary Fuel
BIT .......Anthracite Coal and Bituminous Coal
SUB .....Subbituminous Coal
LIG .......Lignite Coal
WC ......Waste/Other Coal. Including anthracite culm, bituminous gob, fine
coal, lignite waste, waste coal
SC .......Coal Synfuel. Coal-based solid fuel that has been processed by a coal
synfuel plant; and coal-based fuels such as briquettes, pellets, or
extrusions, which are formed from fresh or recycled coal and binding
materials
PC .......Petroleum Coke
DFO .....Distillate Fuel Oil. Including Diesel, No. 1, No. 2, and No. 4 Fuel Oils
SG .......Synthetic Gas, other than coal-derived
SGC .....Synthetic Gas, derived from coal
JF ........Jet Fuel
KER .....Kerosene
RFO .....Residual Fuel Oil. Including No. 5, No. 6 Fuel Oils, and Bunker C Fuel
Oil
WO ......Waste/Other Oil. Including Crude Oil, Liquid Butane, Liquid Propane,
Oil Waste, Re-Refined Motor Oil, Sludge Oil, Tar Oil, or other
January 17, 2013
17
WECC Data Collection Manual
Attachment B
Field Name
Explanation
Primary Fuel
The following options are included in the workbook:
petroleum-based liquid waste
NG .......Natural Gas
PG .......Gaseous Propane
BFG .....Blast Furnace Gas
OG .......Other Gas (coke oven, refinery etc.)
NUC .....Nuclear including Uranium, Plutonium, Thorium
GEO.....Geothermal Steam
WAT.....Water at a conventional hydroelectric turbine- base ratings on median
hydro conditions
AB ........Agriculture Crop Byproducts/Straw/Energy Crops
BLQ .....Black Liquor
LFG......Landfill Gas
MSW ....Municipal Solid Waste
OBL .....Other Biomass Liquids
OBS .....Other Biomass Solids
OBG.....Other Biomass Gas (includes digester gas, methane, and other
biomass gases)
PUR .....Purchased Steam
SLW .....Sludge Waste
TDF......Tire-derived Fuels
WDL.....Wood Waste Liquids excluding Black Liquor (includes red liquor,
sludge wood, spent sulfite liquor, and other wood-based liquids)
WDS ....Wood/Wood Waste Solids. Including paper pellets, railroad ties, utility
poles, wood chips, bark, and wood waste solids
SUN .....Solar
WND ....Wind
OTH .....Other (Describe in Comments)
WH ......Waste heat not directly attributed to an energy source. WH should only
be reported where the energy source for the waste heat is
undetermined
Secondary
Fuel
Use one of the options listed above under primary fuel. Fuel used for start-up
should not be reported as an alternate fuel.
If a unit can burn two or more fuel types, report the type most likely to be burned as the
primary fuel. Report the next fuel type most likely to be burned, based on expected
annual energy predominance, as the secondary fuel.
Field Name
Explanation
Status Code
The following options are available for reporting the Status Code:
Existing Generation Only
OP .......Operating or short-term outage
SB ........Cold standby, 3-6 mo. to reactivate
OS .......Out of service
RE .......Retired (report a summer and winter capacity of zero (0) and indicate
January 17, 2013
18
WECC Data Collection Manual
Field Name
Attachment B
Explanation
reason for retirement in the comments field)
Status Code
Generation Additions/Repowers Only
P ..........Planned for installation but not under active construction
L ..........Regulatory approval pending but not under active construction (started
site preparation)
T ..........Regulatory approval received but not under active construction
U ..........Under active construction, less than or equal to 50% complete (based
on construction time to first electric date)
V ..........Under active construction, more than 50% complete (based on
construction time to first electric date)
TS ........Construction complete, but not yet in commercial operation (including
low power testing of nuclear units)
A ..........Generator capability increased (rerated or relicensed)
D ..........Generator capability decreased (rerated or relicensed) (indicate
reason in comments field)
M .........Generator to be put in deactivated shutdown status
RA .......Previously retired or deactivated generator planned for reactivation
RT ........Existing generator scheduled for retirement (indicate reason in
comments field)
FC ........Existing generator planned for conversion to another fuel or energy
source
IP .........Indefinitely postponed (WECC Class Code 5)
CO .......Change of ownership (including change of shares of jointly-owned
units)
State
State Code (see Appendix B).
County
County where generation is located.
NERC
Class Code
When determining categorization of supply resources, refer to the criteria
listed within each supply category. Determine a supply resource's
applicability to a category by assessing the criteria in each supply
category in order of certainty (use logical progression). For example, first
assess whether the resource falls into the Existing-Certain category. If the
resource does not meet that criteria, assess the criteria of Existing-Other.
If not, assess the criteria of Existing-Inoperable. If not, assess the criteria
of Future-Planned. If not assess the criteria of Future-Other. If not, assess
the criteria of Conceptual. Furthermore, a resource will qualify within a
supply category if any one of the listed criteria is true for that resource.
[Note: information in brackets and bold were added by WECC Staff.]
EXISTING RESOURCES
Enter the class code that best reflects the current status of existing
generation.
EC – Existing-Certain – This category contains generation resources
available to operate and deliver power within or into the region during peak
demand in the assessment. Resources included in this category may be
reported as a portion of the full capability of the resource, plant, or unit. This
January 17, 2013
19
WECC Data Collection Manual
Field Name
Attachment B
Explanation
category includes, but is not limited to the following:
 Contracted (or firm) or other similar resource confirmed to serve
load during peak demand in the assessment.
 Where organized markets exist, designated market resource that is
eligible to bid into a market or has been designated as a firm
network resource.
 Network Resource, as the term is used for FERC pro forma or other
regulatory approved tariffs.
 Energy-only resources confirmed able to serve load during peak
demand and will not be curtailed [recalled]. ["Energy-only"
applies only to generators that have chosen ER
Interconnection Service under FERC Order No. 2003. Do not
include unless this service specifically applies.]
 Capacity resources that cannot be sold elsewhere.
 Other resources not included in the above categories that have
been confirmed able to serve load and not to be curtailed [recalled]
during peak demand.
NERC
Class Code
EO – Existing-Other – [WECC staff does not believe that the ExistingOther class code applies to resources in the Western Interconnection.
Contact WECC staff before classifying a resource as Existing-Other] This
category contains generation resources that may be available to operate and
deliver power within or into the region during peak demand in the assessment,
but may be curtailed or interrupted at any time for various reasons. This
category also includes portions of intermittent generation not included in
Existing-Certain. This category includes, but is not limited to the following:
 A resource with non-firm or other similar transmission arrangements.
 Energy-only resources confirmed able to serve load during peak
demand and may be curtailed [recalled] for any reason. ["Energyonly" applies only to generators that have chosen ER
Interconnection Service under FERC Order No. 2003. Do not
include unless this service specifically applies.]
 Mothballed generation (that may be returned to service for the
period of the assessment).
 Portion of generation resources constrained for other reasons.
EI – Existing-Inoperable – This category contains generation resources that
are out-of-service and cannot be brought back into service to serve load during
peak demand. However, this category can include inoperable resources that
could return to service at some point in the future. This value may vary for
future seasons and can be reported as zero (0). This includes ALL existing
generation within a Region or subregion not included in Existing-Certain or
Existing-Other, but is not limited to, the following:
 Mothballed generation (that cannot be returned to service for the
period of the assessment).
 Other existing but out-of-service generation (that cannot be returned
to service for the period of the assessment).
 This category does not include behind-the-meter generation or nonconnected emergency generators.
January 17, 2013
20
WECC Data Collection Manual
Field Name
Attachment B
Explanation
FUTURE RESOURCES
Enter the class code that best reflects the current status of generation
additions.
This category includes generation resources the reporting entity has a
reasonable expectation of coming on-line during the period of the assessment.
As such, to qualify in either of the Future categories, the resource must have
achieved one or more of these milestones:
 Construction has started.
 Application has been submitted to begin a regulatory process (e.g.
Site Permit, Construction Permit, Environmental Permit).
 Regulatory approval has been received to be in the rate base.
 Approved power purchase agreement.
 Approved and/or designated as a resource by a market operator.
One of these criteria must be met before categorizing a supply resource as
Future-Planned or Future-Other.
NERC
Class Code
FP – Future-Planned – Generation resources anticipated to be available to
operate and deliver power within or into the region during peak demand in the
assessment. This category includes, but is not limited to, the following:
 Contracted (or firm) or other similar resource.
 Where organized markets exist, designated market resource that is
eligible to bid into a market or has been designated as a firm
network resource.
 Network Resource, as that term is used for FERC pro forma or other
regulatory approved tariffs.
 Energy-only resources confirmed able to serve load during the
period of analysis in the assessment and will not be curtailed
[recalled].
 Where applicable, included in an integrated resource plan under a
regulatory environment that mandates resource adequacy
requirements and the obligation to serve.
FO – Future-Other – [WECC staff does not believe that the Future-Other
class code applies to resources in the Western Interconnect. Contact
WECC staff before classifying a resource as Future-Other] This category
includes generation resources that do not qualify as Future-Planned and are not
included in the Conceptual category. This category includes, but is not limited
to, generation resources during the peak that may:
 Be curtailed [recalled] or interrupted at any time for any reason.
 Energy-only resources that may be able to serve load during the
period of analysis in the assessment.
C – Conceptual – This category includes generation resources that are not in a
prior listed category, but have been identified and/or announced on a resource
planning basis through one or more of the following sources:
 Corporate announcement.
 Entered into or is in the early stages of an approval process.
 Is in a generator interconnection (or other) queue for study.
 “Place-holder” generation for use in modeling.
January 17, 2013
21
WECC Data Collection Manual
Field Name
Attachment B
Explanation
0 – Existing Generation – All generation existing as of December 31 of the
actual year should be identified in Class 0.
Enter the class code that best reflects the current status of generation
additions or retirements.
1 – Class 1 – Generation additions that were reported to be under active
construction as of December 31 of the actual year and are projected to be inservice within the period ending five years from the end of the actual year. Also
include any facility or unit that has a firm date for retirement within the
assessment period as a result of regulatory requirements or corporate
decisions.
WECC
Class Code
2 – Class 2 – Generation additions that were reported to have 1) received
regulatory approval, or are undergoing regulatory review, 2) with a signed
interconnection agreement, and 3) with an expected on-line date within the
period ending seven years from the end of the actual year. This class includes
resources that were expected to be in service as early as Class 1 resources but
do not meet the test of being under construction. Also include any facility or unit
that is estimated by the reporting entity to be retired within the assessment
period.
3 – Class 3 – Generation additions/retirements that were reported which have
met the NERC criteria for Future-Planned or Future-Other Resources but,
because of expected on-line requirements, do not qualify as Class 1 or 2
Resources.
4 – Class 4 – Generation additions/retirements that were reported which have
met the NERC criteria for Conceptual Resources.
5 – Class 5 – Generation additions that were reported last year but are no
longer expected to enter service, retire, etc., within the assessment period.
Correlation of NERC Class Codes and WECC Class Codes
NERC Class
Codes
EC
EO*
WECC Class
Codes
0
1
2
3
2
3
4
4
4
5
FP
FO*
C
EI
-
January 17, 2013
22
WECC Data Collection Manual
Attachment B
* WECC staff does not believe that the Existing-Other or Future-Other class codes apply
to resources in the Western Interconnection. Contact WECC staff before classifying a
resource as Existing-Other or Future-Other.
Field Name
Field Content
Explanation
Existing
generation only
Month and Year the unit entered service.
Planned
generation only
Month and Year unit is expected to be in service.
Conceptual
generation only
Month and Year unit is conceptually expected to be in
service.
Retirement
Date
Existing
generation only
Month and Year the unit was, or is expected to be retired.
Latitude
Generation
Latitude
Latitude location of generating unit. Use XX.XXXX/ –
XX.XXXX convention. This should be the actual location of
the unit, not the center of the County as is allowed when
supplying this data to EPA for the eGRID report.
Longitude
Generation
Longitude
TSS Bus
Bus Number
Wind/Solar
Zone
Wind/Solar Zone
TEPPC
Profile
Wind/Solar
Profile Location
Comments
Comments
Commission
Date
Longitude location of generating unit. Use XXX.XXXX/ –
XXX.XXXX convention. This should be the actual location of
the unit, not the center of the County as is allowed when
supplying this data to EPA for the eGRID report.
Bus number associated with generation location. The Bus
number should be the same number submitted for TSS base
cases.
For Wind or Solar Generation, indicate the zone where the
generation is located or, for new construction, will be
located. See the Modeling Area/Zone Table, page 15, for
zone names.
For Wind or Solar Generation, indicate the TEPPC Profile
where the generation is located or, for new construction, will
be located. If the wind facility is not located in or near a
TEPPC Profile, do not enter a code in this cell. See TEPPC
Renewable Energy Cases7 for Profile names.
Comments are used for purposes such as providing
explanations for OT unit type codes and fuel type codes,
giving unit ownership information, explaining plant operating
status, and documenting status of new generation, etc. Also
use the comment field to report the reason for derating or
retirement of generating units.
7
Document is available on the WECC website at:
http://www.wecc.biz/committees/StandingCommittees/PCC/LRS/Shared%20Documents/Wind%20Profiles
/Renewable%20Energy%20Generation%20Paper.pdf
January 17, 2013
23
WECC Data Collection Manual
Attachment B
This page intentionally left blank
January 17, 2013
24
WECC Data Collection Manual
Attachment C:
Peak Demands, Energy Loads, Resource Outages,
and Actual Transfers Instructions
January 17, 2013
25
WECC Data Collection Manual
This page intentionally left blank
January 17, 2013
26
WECC Data Collection Manual
Attachment C
Input Guide for Peak Demand Loads, DSM, Outages, and Transfers
Data
Introduction
Peak demand L&R information is collected to provide a data base that may be used to
prepare power supply evaluations for the WECC subregions’ report to NERC and for
other sub-areas, including the zones used in the PROMOD model that are represented
in the LTRA and PSA. To accomplish this, the following data are required:
1. Loads – Both firm and non-firm, include transmission losses and Standby Demand
but not station use, self-serve load (behind the fence), or pumped storage pumping,
are to be reported separately.
2. Demand-Side Management (DSM) – DSM program information.
3. Unavailable capability – Total maintenance and outage data broken down between
hydro and non-hydro are to be reported.
4. Transfer data – The actual year’s imports and exports that cross Power Area
borders are to be reported.
A discussion about each of these required data types is presented in the next section of
this manual. This discussion section is followed by a section that presents detailed
information about the required data codes and data formats that must be used when
populating the data responses.
Monthly peak demand L&R information is needed for the actual year through the
eleventh (11) future year plus January, February, and March of the twelfth (12) future
year.
The LSE shall count its customer demand once and only once, on an aggregated and
dispersed basis, in developing its actual and forecast customer demand values. The
demand, net energy for load, and controllable DSM supplied for this WECC Data
Collection request shall be consistent with the demand, net energy for load, and
controllable DSM supplied in response to the eleven annual Power Flow Base Case
data requests. BAs are to aggregate the LSEs’ demand forecast data, or provide a
coincident BA forecast, for all LSEs within their BA area.
January 17, 2013
27
WECC Data Collection Manual
Attachment C
Data Types and Codes
LOAD DATA (Codes 1 and 2)
Peak demand load data are reported as firm and non-firm loads under data codes 1 and
2, respectively.

Firm peak demand load data are reported as Code 1. It includes transmission
losses and Standby Demand but does not include station use, self-serve load
(behind the fence), or pumped storage pumping served at time of monthly BA
peak demand during the actual year. For future years one through eleven, firm
peak demand load data are to include transmission losses and the amount of
Standby Demand, but does not include station use, self-serve load (behind the
fence), or pumped storage pumping that is expected to be served at time of
monthly BA peak demand.

For actual year, non-firm peak demand load data are reported as Code 2. It
includes the amount of non-firm Dispatchable DSM (DDSM) demand that was
served at the time of the monthly BA peak. For future year’s one through eleven,
non-firm peak demand load data are the amount of DDSM that is expected to be
served at the time of monthly BA peak demand. DDSM programs include: 1)
Interruptible Demand (also known as contractual interruptible demand); 2) Direct
Control Load Management; 3) Critical Peak Pricing with Control; and 4) Load as
a Capacity Resource. These programs are described in detail below.8
o Interruptible demand is defined as demand that the end-use customer has
made available to the LSE, via contract or agreement, for curtailment.
Interruptible/Contractually Interruptible peak demands are designated by
an 'I' in column C (DSM Code) of the data record and is the amount of
customer demand that can be interrupted at the time of the monthly BA
peak. In some instances, the demand reduction may be affected by action
of the System Operator (remote tripping), after notice to the customer, in
accordance with contractual provisions.
o Direct Control Load Management (DCLM) is DSM that is under the direct
control of the system operator. DCLM may control the electric supply to
individual appliances or equipment on customer premises. DCLM as
defined here does not include Interruptible Demand. DCLM loads are
designated by an ‘L’ in column C (DSM Code) and are the amount of
customer demand that can be interrupted at the time of the BAs monthly
peak.
8
Customer demand that can be curtailed in accordance with a contractual agreement (interruptible peak
demand) is generally separately metered so actual year monthly interruptible peak demand data are
usually available. However, Direct Control Load Management peak demand is generally not separately
metered so estimated data may be required. The “Critical Peak Pricing with Control” DDSM program or
the “Load as a Capacity Resource” program also may, or may not, be separately metered so estimated
data may be required.
January 17, 2013
28
WECC Data Collection Manual
Attachment C
o Critical Peak-Pricing with Control is DSM that combines direct remote
control with a pre-specified high price for use during designated critical
peak periods. Critical Peak-Pricing is designated by a ‘P’ in column C
(DSM Code) and is the amount of customer demand that can be
interrupted at the time of the monthly BA peak.
Note: Critical Peak Pricing is a sub-set of DCLM. DSM associated
with these programs should be counted only once as either DCLM or
Critical Peak-Pricing, not as both.
o Load as a Capacity Resource are demand-side resources that acts as a
capacity resource that can be committed for pre-specified load reductions
under certain conditions. Load as a Capacity Resource is designated by
an ‘R’ in column C (DSM Code) and is the amount of customer demand
that can be interrupted at the time of the monthly BA peak.

For the actual year, the monthly sum of the firm peak demand (Code 1) and
served DDSM peak demand (Code 2) must equal the total monthly metered peak
demand. For future years, the monthly sums must equal the total monthly
forecast peak demands.
The peak demand load forecasts should include the effects of such factors as
economic, demographic, weather effects , and customer trends; conservation,
improvements in the efficiency of electrical energy use, and other changes in the end
uses of electricity. The peak demand load forecast for each month should have a
50% probability of not being exceeded (expected peak demand). This load
forecast is commonly referred to as the 1-in-2 monthly peak load forecast.
Individual systems should maintain documentation regarding the assumptions,
methodologies, and the manner in which forecast uncertainties are addressed in their
forecasts. This information would be helpful in understanding forecast discontinuities
and deviations from actual-year peak demands.
UNAVAILABLE CAPABILITY DATA (Codes 14-16)
Actual year unavailable utility generating capability is reported under five data codes –
14 (Scheduled Maintenance – non-hydro), 14H (Scheduled Maintenance – hydro), 15
(Inoperable Capacity – non-hydro), 15H (Inoperable Capability – hydro) and 16 (Forced
Outages). Future years 1-11 unavailable utility generating capability is reported under
four data codes – 14 (Scheduled Maintenance – non-hydro), 14H (Scheduled
Maintenance – hydro), 15 (Inoperable Capability – non-hydro) and 15H (Inoperable
Capability – hydro). Code 16 (Forced Outages) is not reported for future years.
ACTUAL YEAR TRANSFER DATA (Code 50)
The actual year transfer data is limited to buy/sell transactions that cross Power Area
borders, and transfers from remote renewable resources. (See Appendix C for Power
January 17, 2013
29
WECC Data Collection Manual
Attachment C
Areas) Do not include transfers from thermal and large hydro9 remote resources.
Transfers include: transfers, sales, purchases, imports, and exports, firm capacity
transfers, contractual firm transfers, firm system transfers, full responsibility purchases,
and full responsibility sales, and are those transfers that occur during the 60-minute
time of the peak demand for the month specified. Imports and exports are reported
separately and as positive numbers.
9
Thermal remote resources include Colstrip, Intermountain, Four Corners, Jim Bridger, Navajo, Palo
Verde, San Onofre, Springerville, and Hayden. Large hydro remote resource is Hoover.
January 17, 2013
30
WECC Data Collection Manual
Attachment C
Actual Peak Demand Loads, DSM, Outages, and Transfers Data
Code Definitions
60-Minute Peak Demand MW
(Actual Year - Report Monthly Data)
DATA DESCRIPTION .......................
DATA CODE
Loads - Firm (excluding station use) ............................................................................... 1
Loads - Non-firm (DDSM programs, served) ................................................................... 2
Scheduled Maintenance ................................................................................................ 14
Scheduled Maintenance Hydro ................................................................................... 14H
Inoperable Capability..................................................................................................... 15
Inoperable Capability Hydro ........................................................................................ 15H
Forced Outages ............................................................................................................ 16
Transfers ....................................................................................................................... 50
Report buy/sell transactions that cross power area borders, and transfers from
remote renewable resources separately and as positive numbers. Imports are
coded as “I” and exports are coded as “E” in column I.
Demand-Side Programs contributing to Ancillary Service
Demand-side resources displace generation deployed as operating reserves
and/or regulation; penalties are assessed for non-performance.
Non-Spin Reserves .................................................................................................. 80
Enter the amount of demand-side resources that can displace generation
deployed as operating reserves (that are not connected to the system but
capable of serving demand within a specified time). Penalties are assessed for
non-performance.
Spinning Reserves ................................................................................................... 81
Enter the amount of demand-side resources that can displace generation
deployed as operating reserves (that are synchronized and ready to provide
solutions for energy supply and demand imbalance within the first few minutes of
an electric grid event). Penalties are assessed for non-performance.
Regulation ................................................................................................................ 82
Enter the amount of demand-side resources that are responsive to Automatic
Generation Control to provide normal regulating margin. (These programs are
not common.)
January 17, 2013
31
WECC Data Collection Manual
Attachment C
Emergency Energy-Voluntary .................................................................................. 83
Enter the amount of demand-side resources that can be curtailed voluntarily
when offered the opportunity to do so for compensation. Non-performance is not
penalized.
January 17, 2013
32
WECC Data Collection Manual
Attachment C
Estimated Peak Demand Loads, DSM, Outages, and Transfers Data
Code Definitions
(Future Years one through eleven - Report Monthly Data, and January, February, and
March of twelfth Future Year)
DATA DESCRIPTION
DATA CODE
Loads - Firm (excluding station use) ............................................................................... 1
Loads - Non-firm (DDSM programs, served) ................................................................... 2
Scheduled Maintenance Non-Hydro.............................................................................. 14
Scheduled Maintenance Hydro ................................................................................... 14H
Inoperable Capability Non-Hydro .................................................................................. 15
Inoperable Capability Hydro ........................................................................................ 15H
Load Forecasting Information
New Energy Efficiency (Impacts).............................................................................. 70
Permanent changes to electricity usage at peak conditions, through use of more
efficient end-use devices or more effective operation of existing devices.
Generally these measures result in reduced consumption across most hours of a
month, rather than event-driven targeted load reductions affecting only a few
hours. Only effects of new programs on estimated loads should be reported.
[WECC understands this to mean the monthly reduction in the submitted
peak demand forecast resulting from all ratepayer-funded energy efficiency
programs implemented over the forecast period. Only include the impact of
future energy efficiency programs reflected within the submitted forecast.]
Standby Demand...................................................................................................... 73
Demand that is normally served by behind the meter generation, that has a
contract with a LSE, to provide power if the generator becomes unavailable.
Standby Demand power is intended to be used infrequently by any one
customer.
Demand-Side Programs contributing to Ancillary Service
Demand-side resource displaces generation deployed as operating reserves
and/or regulation; penalties are assessed for nonperformance.
Non-Spin Reserves .................................................................................................. 80
Enter the amount of demand-side resources that can displace generation
deployed as operating reserves (that are not connected to the system but
capable of serving demand within a specified time). Penalties are assessed for
non-performance.
January 17, 2013
33
WECC Data Collection Manual
Attachment C
Spinning Reserves ................................................................................................... 81
Enter the amount of demand-side resources that can displace generation
deployed as operating reserves (that are synchronized and ready to provide
solutions for energy supply and demand imbalance within the first few minutes of
an electric grid event). Penalties are assessed for non-performance.
Regulation ................................................................................................................ 82
Enter the amount of demand-side resources that are responsive to Automatic
Generation Control to provide normal regulating margin. (These programs are
not common.)
Emergency Energy-Voluntary .................................................................................. 83
Enter the amount of demand-side resources that can be curtailed voluntarily
when offered the opportunity to do so for compensation. Nonperformance is not
penalized.
Confidence of Future Other Resources (requested by NERC)
Future Other Confidence Factor ............................................................................... 84
A value, from zero (0) to 100, used to represent the confidence of Future-Other
resources coming on-line by the reported date (example: 0 = 0%; 33 = 33%; 100
= 100%). Report a MW weighted value for every month that resources are
expected on-line. If no confidence factor is reported a value of zero (0) will be
entered for the applicable month/year.
Confidence of Conceptual Resources (requested by NERC)
Conceptual Confidence Factor ................................................................................. 85
Confidence of Conceptual Resources coming on-line using reasonable judgment.
A value, from zero (0) to 100, used to represent the confidence of Conceptual
resources coming on-line by the reported date (example: 0 = 0%; 33 = 33%; 100
= 100%). Report a MW weighted value for every month that resources are
expected on-line. If no confidence factor is reported a value of zero (0) will be
entered for the applicable month/year.
January 17, 2013
34
WECC Data Collection Manual
Attachment C
Actual and Estimated Peak Demand Loads and Transfers
Coding Data Record Format
(Actual Year and Estimated Future Years one through eleven, and January, February,
and March of twelfth Future Year)
COLUMN
HEADING
B
Year
DESCRIPTION
Year
For data Code 2 (Non-firm peak demand)
I - Interruptible
L - Load Management
P - Critical Peak-Pricing with Control
R - Load as a Capacity Resource
C
DSM Code
D
Code
Data Code - Identifies type of data (see previous tables for actual
and future year codes)
Zone
For BAs with demand in multiple modeling areas, enter the zone
where the demand is located. The affected BAs and the zone names
are identified below. For all other BAs, enter the same code as
entered in the BA column.
E
Modeling Area/Zone Table
BA →
AZPS
WALC
WACM
PACE
CISO
IPCO
Modeling Area ↓
Zones
Zones
Zones
Zones
Zones
Zones
IID
AZID
Arizona
AZAZ
WAAZ
New Mexico
AZNM
WANM
Colorado
WACO
Wyoming
WAWY
PAWY
Idaho
PAID
Utah
PAUT
PG&E_Bay
CIPB
PG&E_Vly
CIPV
SCE
CISC
SDGE
CISD
Treas Vly
IPTV
Magic Vly
IPMV
Far East
IPFE
January 17, 2013
35
WECC Data Collection Manual
Attachment C
F
BA
WECC BA Organization Codes (See Appendix B)
G
NA
NA
H
NA
NA
I
I/E
Transfer Export/Import Code:
E - Export
I - Import
J–U
Jan-Dec
V
Comment
January 17, 2013
Monthly Values
Comment
36
WECC Data Collection Manual
Attachment C
Energy Loads Instructions
Energy load data are reported as firm and non-firm loads under data Codes 1 and 2
respectively in column D of worksheet {energy_data}. The energy load data are to be
reported on the same basis as the peak demand load data (e.g., net of station use, selfserve load (behind the fence), or pumped storage pumping and including transmission
line losses).
The monthly actual energy loads and monthly forecast loads for the first through
eleventh future year and January, February, and March of the twelfth future year are
reported in columns J through U.
All energy load numbers are to be reported in gigawatt-hours (GWh).
January 17, 2013
37
WECC Data Collection Manual
Attachment C
Actual and Estimated Energy Loads
Coding Data Record Format
(Actual Year and Future Years one through eleven, and January, February, and March
of the twelfth Future Year)
COLUMN
HEADING
DESCRIPTION
B
Year
C
NA
D
Code
Data Code - Identifies type of data :
1 - Firm Energy
2 - Non-Firm Energy
Zone
For BAs with load in multiple modeling areas, enter the
zone where the load is located. The affected BAs and the
zone names are identified below. For all other BAs, enter
the same code that is entered in the BA column.
E
Year
NA
Modeling Area/Zone Table
BA →
AZPS
WALC
WACM
PACE
CISO
IPCO
Modeling Area ↓
Zones
Zones
Zones
Zones
Zones
Zones
IID
AZID
Arizona
AZAZ
WAAZ
New Mexico
AZNM
WANM
Colorado
WACO
Wyoming
WAWY
PAWY
Idaho
PAID
Utah
PAUT
PG&E_Bay
CIPB
PG&E_Vly
CIPV
SCE
CISC
SDGE
CISD
Treas Vly
IPTV
Magic Vly
IPMV
Far East
IPFE
F
BA
WECC BA Organization Codes (See Appendix B)
G
NA
NA
H
NA
NA
I
NA
NA
January 17, 2013
38
WECC Data Collection Manual
J–U
Jan-Dec
V
Comment
January 17, 2013
Attachment C
Monthly Values
Comment
39
WECC Data Collection Manual
Attachment C
This page intentionally left blank.
January 17, 2013
40
WECC Data Collection Manual
Attachment D:
Reliability and Supply Assessments
January 17, 2013
41
WECC Data Collection Manual
This page intentionally left blank
January 17, 2013
42
WECC Data Collection Manual
Attachment D
Actual Generation
On the {Actual Generation} worksheet, report the actual energy generated within the BA
(all output from resources listed on the {gen_exist} sheet), in MWs, during the peak hour
of the summer and winter seasons from wind, solar, hydro, and biomass resources.
Transfer Path Capabilities
Verify and update the {Paths} worksheet with the appropriate transfer capabilities
between modeling areas. Note that there are two sets of transfer data for each path
(inbound and outbound). The data reflects the values that were used in PROMOD for
the current NERC LTRA and WECC PSA. The list of transmission lines in the {Paths}
worksheet identifies the cut planes between modeling areas. Planned
upgrades/changes should be reported in both the {Paths} and {Projected Transmission}
worksheets.
Detailed Column Descriptions for updating the {Paths} worksheet
Column
J
K
Heading
Transfer Capability Summer - Max
OTC - Summer
L
Transfer Capability Summer - High Load
M
Transfer Capability Winter - Max
OTC - Winter
N
O
Transfer Capability Winter - High Load
P
Q
Loss %
Wheel $/MWh
Data Description
The aggregate maximum transfer capability from the modeling
area in column B to the modeling area in column C for summer.
The aggregate Operating Transfer Capability (OTC) from the
modeling area in column B to the modeling in column C for
summer.
The aggregate "High Load" transfer capability from the modeling
area in column B to the modeling area in column C for summer.
These limits are used in PROMOD to calculate transfers for the
NERC LTRA and the WECC PSA.
The aggregate maximum transfer capability from the modeling
area in column B to the modeling area in column C for winter.
The aggregate OTC from the modeling area in column B to the
modeling area in column C for winter.
The aggregate "High Load" transfer capability from the modeling
area in column B to the modeling area in column C for winter.
These limits are used in PROMOD to calculate transfers for the
NERC LTRA and the WECC PSA.
The transmission loss percent on the path.
The cost for wheeling on the path. These charges are used in
PROMOD to calculate transfers for the NERC LTRA and the
WECC PSA.
Term
Maximum Transfer
capability
Definition
Maximum Transfer Capabilities are the rated-path capabilities
associated with ratings found in the WECC Path Rating Catalog.
If the path is not rated, please provide the best estimate.
OTC
Nominal Operating Transfer Capabilities are the transfer limits
used in day-to-day operations based on seasonal thermal and/or
stability limits.
The capacity that may reasonably be expected to apply under
simultaneous high seasonal transmission loading conditions.
These limits are used in PROMOD to calculate transfers for the
"High Load" Transfer
capability
January 17, 2013
43
WECC Data Collection Manual
Attachment D
NERC LTRA and the WECC PSA.
Load Temperature Sensitivity Data
The load temperature sensitivity data requested provides a basis for modeling extreme
weather conditions in the Western Interconnection for the NERC LTRA and the WECC
PSA. In providing the requested data, BAs with non-BA operator entities are asked to
make best efforts to factor those loads into their response. Provide a best estimate
where the requested data are not available due to special load forecasting
methodologies. Detailed instructions are included on the {Tsens} sheet of the workbook.
Regulating Reserves
Regulating Reserves — the amount of spinning reserves responsive to automatic
generation control that are sufficient to provide normal regulating margin, or reserves to
balance variations in output from variable resources (such as wind) — are an element of
the building block reserve margin used in the annual NERC LTRA and WECC PSA. On
the {Regulating Reserve} sheet, each BA should report the amount of regulating
reserves expected to be available during the summer and winter seasons. The BA can
report the reserves as either a MW amount or as a percentage of load.
Energy Efficiency
(VOLUNTARY)
In addition to its use by WECC, the Transmission Expansion Planning Policy Committee
(TEPPC) study program specifies that the “reference case be guided by existing utility
integrated resource plans (IRPs), and other utility-level information, with appropriate
review from state regulators,” and, specifically, that the load forecast be “consistent with
utility and state assumptions on energy efficiency, DSM, and demand response.”
Specifically, TEPPC relies on the LRS data collection process for securing necessary
data to be used in developing the reference case load forecast:
1. The reference case load forecast should reflect the expected energy and peak
demand savings achieved through (a) ratepayer-funded energy efficiency and
demand response programs, and (b) standards resulting from existing state and
federal laws and regulatory decisions in place as of March 1 of each year.
2. In the case of ratepayer-funded energy efficiency and demand response
programs, expected energy and peak demand savings should be based on the
level of savings specified in energy efficiency resource standards, integrated
resource plans, and DSM program plans. Programs should be assumed to
continue at the annual savings levels in the last year covered by the existing
policies or plans. In the absence of any specific policy or resource plan, savings
should be assumed to continue at current levels.
January 17, 2013
44
WECC Data Collection Manual
Attachment D
3. In the case of federal and state appliance efficiency standards, the reference
case load forecast should reflect the savings that are realized in the future as a
result of standards that are already in place, as well as expected savings from
standards that are scheduled to take effect over the TEPPC study period.
TEPPC will use the data collected on energy efficiency to create a set of adjusted load
forecasts, developed by deducting from the balancing authorities’ load forecasts some
amount of incremental energy and peak demand savings. Collecting program-specific
data as defined below will also help to track program performance and to quantify the
level of energy efficiency, DSM, and demand response modeled.
On the {Energy Efficiency} worksheet, report the monthly reduction in the submitted
load forecast (GWh) from all ratepayer-funded energy efficiency programs implemented
over the forecast period. Only include the impact of future energy efficiency programs
captured within the submitted forecast.
Report the future energy efficiency program savings for each of the following end-use
types:

Lighting savings is designated by an 'L' in column B (EE Code) of the data record
and is the amount of monthly energy savings resulting from all future energy
efficiency programs that are captured within the submitted load forecast and that
primarily target lighting measures.

Heating, ventilation, and air-conditioning (HVAC) is designated by an 'H' in
column B (EE Code) of the data record and is the amount of monthly energy
savings resulting from all future energy efficiency programs that are captured
within the submitted load forecast and that primarily target HVAC measures.

Other savings is designated by an 'O' in column B (EE Code) of the data record
and is the amount of monthly energy savings resulting from all future energy
efficiency programs that are captured within the submitted load forecast and that
primarily target measures affecting end-uses other than lighting or HVAC.

Report the total monthly energy savings from all future energy efficiency
programs, across all end use categories, using a code ‘T’ in column B. This total
should be equal to the sum of values reported for the three aforementioned enduse categories (codes L, H, and O). If energy efficiency program savings by enduse category are not available, report only the total (code ‘T’).
January 17, 2013
45
WECC Data Collection Manual
Attachment D
This page intentionally left blank.
January 17, 2013
46
WECC Data Collection Manual
Attachment E:
Miscellaneous Data
January 17, 2013
47
WECC Data Collection Manual
This page intentionally left blank
January 17, 2013
48
WECC Data Collection Manual
Attachment E
Hourly Demand
In the worksheet named {Hourly Demand}, column A corresponds to the hour from the
actual year and column B correspond to BA’s hourly data. The use of the hourly format
removes the need to adjust for daylight-saving time (contact WECC staff if there are
questions regarding adjustments for daylight-saving time). Report, in column B, the
actual hourly demand (in MWs) corresponding to each hour in column A. Additional
instructions are included on the {Hourly Demand} sheet. The Hourly Demand data
should be consistent with the data reported to FERC in Form 714.
The following BAs, whose areas contain several modeling zones, should report the
Hourly Demand data by the following zones:
Balancing Authority
PACE
CISO
IPCO
Zone
BA Total Load
PACE
Wyoming, PACE Utility
PAWY
Idaho, PACE Utility
PAID
Utah, PACE Utility
PAUT
California, PG&E_Bay
CIPB
California, PG&E_Vly
CIPV
California, SCE
CISC
California, SDGE
CISD
Idaho, Treasure Valley
IPTV
Idaho, Magic Valley
IPMV
Idaho, Far East
IPFE
Hourly Wind Production
BAs that report a wind resource on the {gen_exist} are to reports the nameplate
capacity, available capacity and actual generation for each hour of the year on the
{Hourly Wind Profile} sheet as requested below. One sheet should be used for each
Wind Profile and additional sheets may be added to the workbook as needed to record
profile-specific data. Wind generation that does not fit into any Wind Profile should be
reported on a separate sheet, leaving the Wind Profile (F1) cell blank.
Column
Row
A
B
1
Field Name
Definition
Hour of the year
Hour of year reported
Time Zone
Time zone where generation is
located
January 17, 2013
49
Instructions
Report the time zone for where
generation is located.
WECC Data Collection Manual
Column
Row
B
1
D
F
Field Name
Definition
Instructions
Total nameplate capacity of the
wind location
Report the sum of nameplate
capacity of all generation
installed at the wind location.
Report in MWs. Indicate when
new generation is installed by
increasing the capacity from that
hour forward.
Available Capacity
The total nameplate capacity
less any capacity unavailable
due to forced or planned
outages.
Report the sum of all nameplate
capacity less capacity
unavailable due to forced or
planned outages only. Do not
reduce available capacity for
control measures, e.g., blade
feathering. Report in MWs.
Modeling Area
Modeling Area where generation
is located
Report the Modeling Area where
the generation is located (use
dropdown).
Actual Hourly
Generation
Actual hourly generation in
MWs.
Report the actual energy
generation for the wind location.
Report in MWs.
Regional location of generation
Report the Profile name for the
location of the generation. If the
wind facility is not located in or
near a TEPPC Wind Profile,
leave this cell blank. (See TEPPC
Renewable Energy Cases10 for
Profile names)
Nameplate
C
D
Attachment E
1
TEPPC Wind Profile
Hourly Solar Production
BAs that report a solar resource on the {gen_exist} are to report the nameplate capacity,
available capacity and actual generation for each hour of the year on the {Hourly Solar
Profile} sheet as requested below. One sheet should be used for each Solar Profile and
additional sheets may be added to the workbook as needed to record profile-specific
data. Solar generation that does not fit into any Solar Profile should be reported on a
separate sheet, leaving the Solar Profile (F1) cell blank.
Column Row
Field Name
Definition
A
Hour of the year
Hour of year reported
Time Zone
Time zone where generation is
located
B
1
10
Instructions
Report the time zone for where
generation is located.
Document is available on the WECC website at:
http://www.wecc.biz/committees/StandingCommittees/PCC/LRS/Shared%20Documents/Wind%20Profiles
/Renewable%20Energy%20Generation%20Paper.pdf
January 17, 2013
50
WECC Data Collection Manual
Column Row
B
C
D
1
D
F
1
Field Name
Attachment E
Definition
Instructions
Nameplate
Total nameplate capacity of the
solar location
Report the sum of nameplate
capacity of all generation installed
at the solar location. Report in
MWs. Indicate when new
generation is installed by
increasing the capacity from that
hour forward.
Available Capacity
The total nameplate capacity less
any capacity unavailable due to
forced or planned outages.
Report the sum of all nameplate
capacity less capacity unavailable
due to forced or planned outages
only.
Modeling Area
Report the Modeling Area where
Modeling Area where generation is
generation is located (use
located
dropdown).
Actual Hourly Generation Actual hourly generation in MWs.
Report the actual energy
generation for the solar location.
Report in MWs.
TEPPC Solar Profile
Report the Profile name for the
location of the generation. If the
solar facility is not located in or
near a TEPPC Solar Profile, leave
this cell blank. (See TEPPC
Renewable Energy Cases11 for
Profile names)
Regional location of generation
Projected Transmission Line Additions
The {Projected Transmission} sheet should be verified and updated by each BA for all
transmission line additions at 100 kV and above projected for the eleven-year period
beginning with the current year.
Each entry should have the same attributes over the entire reported-line addition. For
example, a reported line of 200-299 kV should be the same voltage for the entirety of
the specified line mileage. If line attributes change over a single project, this should be
reported by two separate entries.
Note that in most cases separate entries must be made for each three-phase circuit of a
multi-circuit line. An exception to this rule occurs when the projected in-service date of
one or more of the circuits is beyond the assessment period. Note, also, that
retirements and operating voltage changes to multi-circuit lines are to be reported on a
circuit-by-circuit basis and not on a multi-line basis.
Data entries for Conductor Material Type, Bundling Arrangement, Circuits Per Structure
Present, Circuits Per Structure Ultimate, Pole/Tower Material, and Comments are
optional. Leave the Project Identification Number column blank.
Data Validation drop-downs have been provided in the {Projected Transmission} sheet.
11
Document is available on the WECC website at:
http://www.wecc.biz/committees/StandingCommittees/PCC/LRS/Shared%20Documents/Wind%20Profiles
/Renewable%20Energy%20Generation%20Paper.pdf
January 17, 2013
51
WECC Data Collection Manual
Column
B
Field Name
Zone
Attachment E
Definition
Instruction
Zone where transmission is
located.
For BAs with transmission in multiple
modeling areas, enter the Zone where the
transmission is located. The affected BAs
and the zone names are identified below.
For all other BAs, enter the same code as
entered in the BA column.
Modeling Area/Zone Table
BA →
AZPS
WALC
WACM
PACE
CISO
IPCO
Modeling Area ↓
Zones
Zones
Zones
Zones
Zones
Zones
IID
AZID
Arizona
AZAZ
WAAZ
New Mexico
AZNM
WANM
Colorado
WACO
Wyoming
WAWY
PAWY
Idaho
PAID
Utah
PAUT
PG&E_Bay
CIPB
PG&E_Vly
CIPV
SCE
CISC
SDGE
CISD
Treas Vly
IPTV
Magic Vly
IPMV
Far East
IPFE
C
BA
WECC BA Organization Codes
Report the BA where transmission is
located. (See Appendix B for BA codes)
D
Project Identification
Number
N/A
Leave Blank
January 17, 2013
52
WECC Data Collection Manual
Attachment E
Under Construction
-Construction of the line has
begun
Planned (any of the following)
-Permits have been
approved to proceed
-Design is complete
-Needed in order to meet a
regulatory requirement
E
F
Transmission Status
(Choose One)
Type
Conceptual (any of the
following)
-A line projected in a
transmission plan
-A line that is required to
meet a NERC TPL
Standard or power flow
model and cannot be
categorized as "Under
Construction" or “Planned”
-Projected transmission
lines that are not “Under
Construction” or “Planned”
Planned Retirement
-Any lines that will be taken
out of service during the
assessment period.
Planned Upgrade
-Projects that involve
upgrades to existing
transmission lines.
New Line
Upgrade
Retirement
Cancellation
Choose one of the predefined
transmission categories.
Enter negative line length, in column R, for
Planned Retirement entries.
If a Planned Upgrade does not involve a
voltage change, enter zero line length, in
column R.
If a Planned Upgrade involves a voltage
change, provide two entries – one with
negative circuit miles in column R and the
existing operating voltage in column U.
The other entry is to have positive circuit
miles in column R and the new operating
voltage in column U.
Choose one of the predefined type
categories.
Reliability
G
Primary Driver (choose
one)
Generation Integration (Choose
one from below)
-Variable/Renewable
Integration
-Nuclear Integration
-Fossil-Fire Integration
-Hydro Integration
Choose one of the predefined drivers for
each line addition. While it is understood
that one line could serve multiple functions
(e.g., reliability and economics), please
specify the primary consideration/driver for
this addition.
Economics or Congestion
Other
Reliability
H
Secondary Driver
(if applicable)
Generation Integration (Choose
one from below)
-Variable/Renewable
Integration
-Nuclear Integration
-Fossil-Fire Integration
-Hydro Integration
Choose one of the predefined drivers for
each line addition. While it is understood
that one line could serve multiple functions
(e.g., reliability and economics), please
specify the primary consideration/driver for
this addition (if applicable).
Economics or Congestion
Other
I
Tie Line?
January 17, 2013
A tie line connects two or more
systems.
53
Please specify (Yes/No) whether this
addition is a tie line across two or more
systems.
WECC Data Collection Manual
Attachment E
Please specify (Yes/No) whether this
addition is classified as a Merchant Line.
J
Merchant Line
K
Project Name
Reporting entity defined project
name.
Enter the project name associated with
this addition.
L
Terminal From Location
Beginning terminal point.
Enter the name of the beginning terminal
point of the line.
M
Terminal To Location
Ending terminal point.
Enter the name of the ending terminal
point of the line.
N
Company Name
The name of the company that
owns the transmission line.
Enter the company name.
O
EIA Company Code
Identify each organization by the sixcharacter code assigned by EIA.
P
Type of Entity
Identify the type of organization that best
represents the line owner including the
following types of utilities – Investorowned (I), Municipality (M), Cooperative
(C), State-owned (S), Federally-owned
(F), or other (O).
Q
Percent Ownership
If the transmission line will be jointlyowned, enter the percentages owned by
each individual respondent.
R
Line Length in Circuit
Miles
For lines fully contained within a BA area,
enter miles between beginning and ending
terminal points of the line. If line crosses
into multiple BA areas, include only that
portion located in your BA. Please enter
Circuit Line Miles and not linear miles.
S
Line Type
Select physical location of the line
conductor – overhead (OH), underground
(UG), or submarine (SM).
T
Voltage Type
Select voltage as alternating current (AC)
or direct current (DC).
U
Voltage Operating
Select the voltage at which the line is
normally operated in kilovolts (kV).
V
Voltage Design
Enter the voltage at which the line was
designed to operate in kilovolts (kV).
W
Conductor Size
Enter the size of the line conductor in
thousands of circular mils (MCM).
X
Conductor Material
Type
Data entry is optional
Select the line conductor material type –
aluminum, ACCR, ACSR, copper, or
other.
Y
Bundling Arrangement
Data entry is optional
Select the bundling arrangement/
configuration of the line conductors –
single, double, triple, quadruple, or other
(1, 2, 3, 4, OT).
Z
Circuits Per Structure
Present
Data entry is optional
Select the initial number of three-phase
circuits on the structures of the line.
AA
Circuits Per Structure
Ultimate
Data entry is optional
Select the ultimate number of three-phase
circuits that the structures of the line are
designed to accommodate.
Data entry is optional
Identify the predominant pole/tower
material for the line – wood, concrete,
steel, combination, composite material, or
other (W, C, S, B, P, O).
AB
Pole/Tower Material
January 17, 2013
54
WECC Data Collection Manual
Attachment E
Also include the type of structure – single
pole, H-frame structure, tower,
underground, or other (P, H, T, U, O).
AC
Pole/Tower Structure
Type
AD
Capacity Rating (MVA)
Enter the normal load-carrying capacity of
the line in millions of voltamperes
(megavoltampheres - MVA).
AE
Original In-Service
Month (MM)
Select the original month the line was to
be energized under the control of the
system operator.
AF
Original In-Service Year
(YYYY)
Select the original year the line was to be
energized under the control of the system
operator.
AG
Expected In-Service
Month (MM)
Select the projected month the line will be
energized under the control of the system
operator.
AH
Expected In-Service
Year (YYYY)
Select the projected year the line will be
energized under the control of the system
operator.
AI
Line Delayed?
Identify if this line has been delayed
beyond one seasonal peak.
AJ
Cause of Delay
If Column AI is "Yes," describe the
cause(s) of the delay.
AK
Comments
Enter any necessary comments.
Data entry is optional
Projected Transformer Additions
The {Projected Transformer} sheet should be completed by each BA for all transformer
additions at 100 kV Low-Side and above projected for the eleven-year period beginning
with the current year. Replacement transformers should be reported and noted in the
Description/Status field.
Column
B
Field Name
Zone
Definition
Instructions
Zone where transformer is
located.
For BAs with transmission in multiple
modeling areas, enter the Zone where the
transmission is located. The affected BAs
and the zone names are identified below.
For all other BAs, enter the same code as
entered in the BA column.
Modeling Area/Zone Table
BA →
AZPS
WALC
WACM
PACE
CISO
IPCO
Modeling Area ↓
Zones
Zones
Zones
Zones
Zones
Zones
IID
AZID
Arizona
AZAZ
WAAZ
New Mexico
AZNM
WANM
Colorado
WACO
Wyoming
WAWY
January 17, 2013
55
PAWY
WECC Data Collection Manual
Attachment E
Idaho
PAID
Utah
PAUT
PG&E_Bay
CIPB
PG&E_Vly
CIPV
SCE
CISC
SDGE
CISD
Treas Vly
IPTV
Magic Vly
IPMV
Far East
IPFE
BA
D
Transformer Project
Name
Enter the name of the project.
E
High-Side Voltage (kV)
Enter the High-Side Voltage.
F
Low-Side Voltage (kV)
Enter the Low-Side Voltage.
G
Expected In-Service
Date (MM-YYY)
Enter the projected date the transformer
will be energized under the control of the
system operator.
H
Description/Status
Provide a brief description/status on the
projected transformer addition.
January 17, 2013
WECC BA Organization Codes
Report the BA where transformer is
located. (See Appendix B for BA codes)
C
56
WECC Data Collection Manual
Attachment E
Transmission Line Circuit Miles
Only the total existing transmission circuit miles need to be reported on the
{Transmission Line Circuit Miles} sheet. The resulting values should be the net existing
circuit miles for each category.
Column
Field Name
A
Balancing Authority
B-H
AC Voltage (kV)
Categories
I
Total AC
Definition
Instructions
Report only Existing (commercially inservice and in control of the operator) AC
transmission lines as of the end of the
Actual Year in WHOLE number circuit
miles for the specified voltages.
Sum of existing AC
transmission line miles.
Report only Existing (commercially inservice and in control of the operator) DC
transmission lines as of the end of the
Actual Year in WHOLE number circuit
miles for the specified voltages.
J-M
DC Voltage (kV)
Categories
N
Total DC
Sum of existing DC
transmission line miles.
O
AC & DC Total
Sum of existing AC & DC
transmission line miles.
Remote Resources
NERC requires the reporting of data for remote resources in the annual LTRA. Remote
resources are defined as a resource that is physically located in one BA area but is
owned by an entity, or entities, located in another BA’s geographic footprint. Each BA
should report all remote resources located in its area that are reported on the
{gen_exist} or {gen_add} sheets. The following data is required to respond to the NERC
request.
Column
Field Name
Definition
Instructions
A
Year
Year of ownership change
If ownership of a remote resource
changes, or if allocations among owners
change, report the year the change
becomes effective. Otherwise, this field
should be blank.
B
Unit Name
Power Plant Unit Name
Report unit name. This name must be the
same as the name reported on the
{gen_exist} or {gen_add} sheet.
BA Code
Report the Balancing Authority code for
where the resource is located. This code
must be the same as the code reported
on the {gen_exist} or {gen_add} sheet
(see Appendix B for code names).
Nameplate Rating
Report the nameplate rating of the unit.
This nameplate rating must be the same
as the rating reported on the {gen_exist}
or {gen_add} sheet. Report in MWs.
C
D
Area
Nameplate
January 17, 2013
57
WECC Data Collection Manual
Column
E
F-I
Field Name
Attachment E
Definition
Instructions
Controlling Owner
Percent
In cell E5, report the name of the owner
that controls the remote unit. In cells E7
and below, enter the percent ownership,
rounded to the nearest whole number, of
the controlling owner.
Joint Owner Percent
In cell F5-I5, report the names of the joint
owners of the remote unit. In cells F7, G7,
H7, I7, etc. (additional columns can be
added as needed) and below, enter the
percent ownership, rounded to the
nearest whole number, of the joint
owners.
Demand-Side Management (DSM) Programs
(VOLUNTARY)
The {DSM Programs} sheet may be completed by all BAs that report non-firm load for
the ten-year period. The total amount enrolled of each DSM program or tariff should be
entered as a separate row in the sheet. These DSM programs will be designated by the
same four non-firm load types — Interruptible Demand (I), Direct Control Load
Management (L), Critical Peak Pricing with Control (P), and Load as a Capacity
Resource (R) — with the associated program name or tariff listed in the
Program/Tariff/Comment field (Column Q). If the disaggregated DSM programs are
unknown, enter the total aggregate non-firm load with appropriate corresponding DSM
Code designation and make a notation of this in the Program/Tariff/Comment field
(Column Q).
NOTE: The amount reported in this section should be equal to or greater than the
amount reported as interruptible demand in Code 2.
Column
Field Name
Definition
A
Year
Year reported
Instructions
B
DSM Code
Demand-Side Management
Code
Identify the Demand-Side Management
category:
I - Interruptible
L- Load Management
P - Critical Peak-Pricing with Control
R - Load as a Capacity Resource
C
Code
Data Code
Enter a 2 for non-firm demand.
D
BA
Balancing Authority
WECC Balancing Authorities
Organization Code (See Appendix B)
Jan-Dec
Monthly data values associated with each
Demand-Side Management program.
This amount is the total enrolled in the
specific program and not the amount that
is expected to be served.
E-P
Month
Q
Program/Tariff/Comment
January 17, 2013
Enter the specific Demand-Side
Management program name/tariff.
58
WECC Data Collection Manual
Appendix A: Glossary for WECC Data Collection Manual
January 17, 2013
59
WECC Data Collection Manual
This page intentionally left blank
January 17, 2013
60
WECC Data Collection Manual
Appendix A
Glossary for WECC Data Collection Manual
Term
Definition
ACTIVE
CONSTRUCTION
Active construction includes personnel consistently onsite,
payroll met, building materials delivery ongoing, turbine or other
major items on order, etc.
ACTUAL YEAR
The calendar year just completed for which actual results are
reported.
BIOMASS
Any organic material not derived from conventional fossil fuels.
Examples are animal waste, agricultural or forest by-products,
and municipal refuse.
CAPABILITY
The maximum load that a generator, turbine, transmission
circuit, apparatus, stations, or system can supply under
specified conditions for a given time interval, without exceeding
approved limits of temperature and stress.
Inoperable
The coincident sum of capabilities (net generation) that could
not be operated for reasons such as lack of fuel availability,
legal restrictions, lack of manpower, etc., at the time of the peak
demand for the month specified. Inoperable capability does not
include scheduled maintenance or forced outages.
CAPACITY
Synonymous with capability.
CAPACITY WITH
FULL RESERVE
The highest (in availability) form of capacity transaction. The
system is obligated to deliver power and energy at a specified
degree of reliability. The selling system must purchase power or
take other appropriate actions before curtailing the transactions.
CAPACITY
WITHOUT
RESERVE
A transaction in which the capacity is supplied when available
from the aggregate of generating units of the seller. The seller
does not have to deliver power and energy whenever certain
system conditions exist that would impose undue hardship on
the seller.
CONSERVATION
Implementation of measures that decrease energy consumption
of targeted end uses resulting in beneficial load shape changes,
often by encouraging the use of more efficient appliances and
equipment.
January 17, 2013
61
WECC Data Collection Manual
Appendix A
Term
Definition
DEMAND
The rate at which electric energy is delivered to or by a system
or part of a system, generally expressed in kilowatts or
megawatts, at a given instant or averaged over any designated
interval of time.
The rate at which energy is being used by the customer.
Coincident
Two or more demands that occur in the same demand interval.
Firm
That portion of the Demand that a power supplier is obligated to
provide except when system reliability is threatened or during
emergency conditions.
The maximum 60-minutes coincident load for the month
specified. It includes transmission system losses and standby
demand, and excludes station service, load management, and
interruptible loads.
Non-coincident
The sum of individual systems’ Peak Demands, regardless of
when they occur. Non-coincident Peak Demand will always be
greater than or equal to the Coincident Peak Demand.
Maximum (Peak)
The highest hourly integrated Net Energy for Load within a
Balancing Authority Area occurring within a given period (e.g.,
day, month, season, or year).
The highest instantaneous demand within the Balancing
Authority Area.
Standby
Standby Demand is demand that may be served, in accordance
with contractual arrangements, to provide power and energy to
a customer (often to a cogenerating industrial customer) as a
second source or backup for outage of the customer’s
generation. Standby power is intended to be used infrequently
by any given customer. Probability considerations should be
applied to determine the amount of standby demand included in
firm load.
DEMAND-SIDE
MANAGEMENT
(DSM)
The term for all activities or programs undertaken by an electric
system or its customers to influence the amount and timing of
electricity use. Included in DSM are the planning,
implementation, and monitoring of utility activities that are
designed to influence consumer use of electricity in ways that
will produce desired changes in a utility’s load shape, such as,
direct load control, interruptible load, and conservation.
January 17, 2013
62
WECC Data Collection Manual
Term
Appendix A
Definition
Direct Control
Load
Management
(DCLM)
Demand-side management that is under the direct control of the
system operator. DCLM may control the electric supply to
individual appliances or equipment on customer premises.
DCLM as defined here does not include Interruptible Demand.
Critical PeakPricing with
Control
Demand-side management that combines direct remote control
with a pre-specified high price for use during designated critical
peak periods, triggered by system contingencies or high
wholesale market prices. (This does not to include Critical Peak
Pricing that does not have direct control but only has economic
penalties if not followed.)
Load as a
Capacity
Resource
Demand-side resources that act as a capacity resource to
commit to pre-specified load reductions for certain system
conditions. (Similar to Interruptible demand, but is compensated
differently.)
ENERGY
Electric energy usually measured in gigawatt-hours.
FUEL CELL
A device in which a chemical process is used to convert a fuel
directly into electricity.
FULL
RESPONSIBILITY
PURCHASE
A Full Responsibility capacity purchase results when the seller
is contractually obligated to deliver power and energy to the
purchaser with the same degree of reliability as provided to the
seller’s own native load (customers).
FULL
RESPONSIBILITY
SALE
A Full Responsibility capacity sale results when the seller is
contractually obligated to deliver power and energy to the
purchaser with the same degree of reliability as provided to the
seller’s own native load (customers).
GENERATION
The act or process of producing electric energy from other
forms of energy; also the amount of energy so produced.
Gross Generation
The total amount of electric energy produced by a generating
station or stations, measured at the generator terminals.
Hydro
A term used to identify a type of electric generating station,
capacity, or capability, or output in which the source of energy
for the prime mover is falling water.
Net Generation
Gross generation less station use.
January 17, 2013
63
WECC Data Collection Manual
Term
Appendix A
Definition
Pumped Storage
Plant
A power plant utilizing an arrangement whereby electric energy
is generated for peak load use by utilizing water pumped into a
storage reservoir usually during off-peak periods. A pumped
storage plant may also be used to provide reserve generating
capacity.
Station Use
Energy used in a generating plant as necessary in the
production of electricity. It includes all energy consumed for
plant light, power, and auxiliaries regardless of whether such
energy is produced at the plant or comes from another source.
Thermal
A term used to identify a type of electric generating station,
capacity, or capability, or output in which the source of energy
for the prime mover is heat.
Cogeneration
Equipment used to produce electric energy and forms of useful
thermal energy, such as heat or steam, used for industrial,
commercial, heating, or cooling purposes, through sequential
use of energy. Combined Cycle generation is not considered
cogeneration.
LOAD
An end-use device or customer that receives power from the
electric system.
Firm Load
Electric power load (including standby demand) intended to be
served at all times during the period covered by a commitment,
even under adverse conditions.
Interruptible
Demand (Load)
Demand that the end-use customer makes available to its
Load- Serving Entity via contract or agreement for curtailment.
MARGIN
Reserve
NET ENERGY
January 17, 2013
The differences between capacity and peak demand. Margin is
usually expressed in megawatts.
The difference between capacity and firm peak demand divided
by firm peak demand expressed as a percentage. The reserve
margin (RM) equals the capacity margin (CM) divided by one
minus the capacity margin or RM = CM / (1 - CM).
The electric energy requirements of a system. It is defined as
system net generation plus energy received from others less
energy delivered to others. It includes system losses but
excludes energy required for “pumping up” pumped storage
plants.
64
WECC Data Collection Manual
Appendix A
Term
Definition
OUTAGE
The period during that a generating unit, transmission line, or
other facility is out-of-service.
Forced
The removal from service availability of a generating unit,
transmission line, or other facility for emergency reasons.
The condition in which the equipment is unavailable due to
unanticipated failure.
Scheduled
The shutdown of a generating unit, transmission line, or other
facility, for inspection or maintenance, in accordance with an
advance schedule.
PREVIOUS YEAR
The calendar year immediately preceding the reporting year.
RESERVE
Synonymous with Margin.
SUMMER SEASON
The summer season begins on June 1 and runs through
September 30.
SYSTEM
The physically connected generation, transmission, distribution
and other facilities operated as an integral unit under one
control, management, or operating supervision, often referred to
as “electric system,” “electric power system” or “power system.”
TRANSFER
The transfer of electrical energy across a point or points of
interconnection during a stated period. For purposes of this
request transfers include: transfers, sales, purchases, imports,
exports, firm capacity transfers, contractual firm transfers, firm
system transfers, full responsibility purchases, and full
responsibility sales.
WINTER SEASON
The winter season begins on December 1 and runs through the
end of February of the following year. It is convenient to
describe the winter season by means of two years.
January 17, 2013
65
WECC Data Collection Manual
Appendix A
This page intentionally left blank
January 17, 2013
66
WECC Data Collection Manual
Appendix B: WECC Balancing Authorities and Abbreviations
January 17, 2013
67
WECC Data Collection Manual
This page intentionally left blank
January 17, 2013
68
WECC Data Collection Manual
Appendix B
WECC Balancing Authorities
Balancing Authority
Canada Power Area
Organization Code
Alberta Electric System Operator .......................................................AESO
British Columbia Transmission Company ...........................................BCHA
Northwest Power Area
Avista Corp. .......................................................................................... AVA
Bonneville Power Administration – Transmission ............................... BPAT
Chelan County Public Utility District .................................................. CHPD
Douglas County Public Utility District ................................................. DOPD
Glacier Wind Agency ........................................................................... GWA
Grant County Public Utility District ..................................................... GCPD
NaturEner Wind Watch, LLC .............................................................. WWA
NorthWestern Energy ....................................................................... NWMT
PacifiCorp – West .............................................................................. PACW
Portland General Electric Company ..................................................... PGE
Puget Sound Energy ........................................................................... PSEI
Seattle Department of Lighting ..............................................................SCL
Tacoma Power .................................................................................. TPWR
Western Area Power Administration, Upper Great Plains – West .... WAUW
Basin Power Area
Idaho Power Company ........................................................................ IPCO
PacifiCorp – East ................................................................................ PACE
Sierra Pacific Power Company ........................................................... SPPC
Rocky Mountain Power Area
Public Service Company of Colorado ................................................ PSCO
Western Area Power Administration, Colorado-Missouri Region...... WACM
Arizona-New Mexico-Southern Nevada Power Area
Arizona Public Service Company ....................................................... AZPS
DECA, LLC – Arlington Valley ............................................................ DEAA
El Paso Electric Company .................................................................... EPE
Gila River ........................................................................................... GRMA
Griffith Energy...................................................................................... GRIF
Harquahala ....................................................................................... HGMA
Imperial Irrigation District ......................................................................... IID
Nevada Power Company .................................................................... NEVP
Public Service Company of New Mexico ..............................................PNM
Salt River Project .................................................................................. SRP
Tucson Electric Power Company........................................................ TEPC
Western Area Power Administration, Lower Colorado Region .......... WALC
Northern California Power Area
California Independent System Operator ............................................ CISO
Balancing Authority of Northern California ..........................................BANC
January 17, 2013
69
WECC Data Collection Manual
Appendix B
Turlock Irrigation District ...................................................................... TIDC
Southern California Power Area
California Independent System Operator ............................................ CISO
Los Angeles Department of Water and Power................................... LDWP
Mexico Power Area
Comisión Federal de Electricidad ......................................................... CFE
Appendix C presents a detailed list of Load-Serving Entities within each of the above
BAs.
State Abbreviations
ABBREVIATION
STATE (PROVINCE)
AB ......................................................... Alberta
AZ ........................................................ Arizona
BC .......................................... British Columbia
CA ..................................................... California
CO ......................................................Colorado
ID ........................................................... Idaho
KS ........................................................ Kansas
MT ...................................................... Montana
NE ..................................................... Nebraska
ND ............................................... North Dakota
NM ................................................ New Mexico
NV ........................................................ Nevada
OK .................................................... Oklahoma
OR ........................................................ Oregon
SD .............................................. South Dakota
TX .......................................................... Texas
UT .............................................................Utah
WA ................................................ Washington
WY .................................................... Wyoming
January 17, 2013
70
WECC Data Collection Manual
Appendix C: List of Balancing Authorities and Load-Serving Entities
by Power Areas
January 17, 2013
71
WECC Data Collection Manual
This page intentionally left blank
January 17, 2013
72
WECC Data Collection Manual
Appendix C
List of Balancing Authorities and Load-Serving Entities by Power
Area
(Member and Nonmember)
Canada Power Area
Power Area
LSE
BA
Alberta Electric System Operator ............................................................................ AESO
ATCO Electric Ltd. ................................................................ ATCO
Calgary AB, City of .........................................................................
Edmonton Power - AB ............................................................. EDP
Lethbridge AB, City of .....................................................................
Medicine Hat AB, City of ......................................................... CMH
Red Deer AB, City of ......................................................................
TransAlta Utilities Corporation - AB ...................................... TAUC
British Columbia Hydro and Power Authority - Canada .................... BCHA ............ BCHA
West Kootenay Power Ltd. ........................................................ ILA
Northwest Power Area
Power Area
LSE
BA
Avista Corp. ........................................................................................ AVA ............... AVA
Bonneville Power Administration ......................................................... BPA ............. BPAT
Federal loads Bureau of Indian Affairs - Wapato, WA ...........................................
Bureau of Indian Affairs - Flathead, MT ..........................................
Bureau of Mines - OR .....................................................................
DOE - Richland Operations - WA ...................................................
Fairchild Air Force Base - WA ........................................................
USBR - Pacific Northwest Region......................................... USPN
U. S. Army Corps of Engineers (North Pacific) ..................... USCE
U. S. Navy ......................................................................................
Municipal Systems Albion ID, City of .............................................................................
Ashland OR, City of ........................................................................
Bandon OR, City of.........................................................................
Blaine City Light - WA.....................................................................
Bonners Ferry ID, City of ........................................................... BF
Burley Municipal Distribution System - ID .......................................
Canby OR, City of ..........................................................................
Cascade Locks OR, City of.............................................................
Centralia WA, City of ................................................................. CC
Cheney WA, City of ........................................................................
Chewelah WA, City of .....................................................................
Consolidated Irrigation District #19 - WA ........................................
Coulee Dam WA, City of .................................................................
January 17, 2013
73
WECC Data Collection Manual
Appendix C
Declo ID, City of .............................................................................
Drain OR, City of ............................................................................
Eatonville Power & Light Company - WA ........................................
Ellensburg WA, City of ....................................................................
Eugene Water and Electric Board - OR ................................EWEB
Energy Northwest ...........................................................................
Fircrest WA, Town of ......................................................................
Forest Grove OR, City of ................................................................
Heyburn ID, City of .........................................................................
McCleary Light & Power - WA ........................................................
McMinnville OR, City of ..................................................................
Milton WA, Town of ........................................................................
Milton-Freewater Light & Power - OR .............................................
Minidoka ID, City of ........................................................................
Monmouth OR, City of ....................................................................
Plummer ID, City of ........................................................................
Port Angeles WA, City of ................................................................
Richland WA, City of.......................................................................
Rupert ID, City of ............................................................................
Soda Springs ID, City of .................................................................
Springfield Utility Board - OR ..........................................................
Steilacoom WA, Town of ................................................................
Sumas WA, City of .........................................................................
Troy MT, City of ..............................................................................
Vera Irrigation District No. 15 - WA .................................................
Public Utility Districts Benton County PUD - WA ..............................................................
Central Lincoln PUD - OR...............................................................
Clallam County PUD - WA ..............................................................
Clark County PUD - WA ........................................................CLPD
Clatskanie PUD - OR......................................................................
Columbia River PUD - OR ..............................................................
Cowlitz County PUD - WA .................................................... COPD
Emerald PUD - OR .........................................................................
Ferry County PUD - WA .................................................................
Franklin County PUD - WA .............................................................
Grays Harbor County PUD - WA .......................................... GHPD
Kittitas County PUD - WA ...............................................................
Klickitat County PUD - WA .............................................................
Lewis County PUD - WA.................................................................
Mason County PUD No. 1 - WA......................................................
Mason County PUD No. 3 - WA......................................................
Northern Wasco County PUD - OR ................................................
Pacific County PUD No. 2 - WA......................................................
Pend Oreille County PUD - WA ............................................ POPD
Skamania County PUD - WA ..........................................................
Snohomish County PUD - WA .............................................. SNPD
Tillamook PUD - OR .......................................................................
Wahkiakum County PUD - WA .......................................................
Whatcom County PUD - WA...........................................................
Cooperatives -
January 17, 2013
74
WECC Data Collection Manual
Appendix C
Alder Mutual Light Company - WA..................................................
Benton Rural Electric Association - WA .................. PNGC member
Big Bend Electric Cooperative, Inc. - WA........................................
Blachly-Lane Cnty. Coop Elec. Assn. - OR ............. PNGC member
Central Electric Cooperative, Inc. - OR ................... PNGC member
Clearwater Power Company - ID ............................ PNGC member
Columbia Basin Electric Cooperative, Inc. - OR..............................
Columbia Power Cooperative Association - OR..............................
Columbia Rural Electric Association, Inc. - WA...............................
Consumers Power, Inc. - OR .................................. PNGC member
Coos-Curry Electric Coop, Inc. - OR ....................... PNGC member
Douglas Electric Coop, Inc. - OR ............................ PNGC member
East End Mutual Electric Company, Ltd. - Rupert, ID .....................
Elmhurst Mutual Power & Light Company - WA..............................
Fall River Rural Electric Coop, Inc. - ID .................. PNGC member
Farmers Electric Company - Rupert, ID ..........................................
Flathead Electric Cooperative, Inc. - MT .........................................
Glacier Electric Cooperative - MT ...................................................
Harney Electric Cooperative, Inc. - OR ...........................................
Hood River Electric Cooperative - OR ............................................
Idaho County Light & Power Coop. Assn., Inc. - ID.........................
Inland Power & Light Company - WA .............................................
Kootenai Electric Cooperative, Inc. - ID ..........................................
Lakeview Light & Power Company - WA ........................................
Lane Electric Cooperative, Inc. - OR ...................... PNGC Member
Lincoln Electric Cooperative, Inc. - MT ...........................................
Lincoln Electric Cooperative, Inc. - WA ................... PNGC member
Lost River Electric Cooperative, Inc. - ID ................ PNGC member
Lower Valley Power & Light, Inc. - WY ................... PNGC member
Midstate Electric Cooperative, Inc. - OR .........................................
Missoula Electric Cooperative, Inc. - MT.........................................
Modern Electric Water Company - WA ...........................................
Nespelem Valley Electric Cooperative - WA ...................................
Northern Lights, Inc. - ID ........................................ PNGC Member
Ohop Mutual Power & Light Company - WA ...................................
Orcas Power & Light Company - WA..............................................
Oregon Trail Cooperative, Inc. - OR ....................... PNGC Member
Parkland Light & Water Company - WA ..........................................
Peninsula Light Company, Inc. - WA ..............................................
Raft River Rural Electric Coop, Inc. - ID.................. PNGC member
Ravalli County Electric Cooperative, Inc. - MT ................................
Riverside Electric Company - Rupert, ID ........................................
Rural Electric Company - Rupert, ID...............................................
Salem Electric - OR ........................................................................
Salmon River Electric Cooperative, Inc. - ID ...................................
South Side Electric Lines, Inc. - Declo, ID ......................................
Surprise Valley Electrification Corp. - OR/CA .................................
Tanner Electric - WA ......................................................................
Umatilla Electric Cooperative Assn. - OR ............... PNGC member
Unity Light & Power Company - Burley, ID .....................................
Vigilante Electric Cooperative, Inc. - MT .........................................
January 17, 2013
75
WECC Data Collection Manual
Appendix C
Wasco Electric Cooperative, Inc. - OR............................................
Wells Rural Electric Cooperative, Inc. - NV .....................................
West Oregon Electric Cooperative, Inc. - OR..................................
Chelan County Public Utility District - WA ........................................ CHPD ............ CHPD
Cashmere WA, City of ....................................................................
Colockum Transmission Company .................................................
Douglas County Public Utility District - WA....................................... DOPD ............ DOPD
Okanogan PUD - WA .....................................................................
Okanogan County Electric Cooperative - WA .................................
Glacier Wind Agency - MT ......................................................................... .............. GWA
Grant County Public Utility District - WA........................................... GCPD ............ GCPD
NaturEner Wind Watch - MT ...................................................................... ............. WWA
NorthWestern Energy - MT ............................................................. NWMT ........... NWMT
Central Montana Electric Power Cooperative .................................
Big Horn County Electric Cooperative ............................................
Mission Valley Power .....................................................................
Yellowstone National Park ..............................................................
PacifiCorp - West ................................................................................ PAC ........... PACW
Portland General Electric Company - OR ............................................PGE ...............PGE
Puget Sound Energy - WA .................................................................. PSE .............. PSEI
Seattle Department of Light (Seattle City Light) - WA .......................... SCL ............... SCL
Tacoma Power - WA ........................................................................TPWR ............ TPWR
Ruston Electric Utility - WA .............................................................
Western Area Power Administration – Great Plains - West ........................ ...........WAUW
Basin Power Area
Power Area
LSE
BA
Idaho Power Company - ID ............................................................... IPCO ............. IPCO
Weiser ID, City of ...........................................................................
PacifiCorp - East ................................................................................. PAC ............ PACE
Brigham City UT, City of ......................................... UAMP member
Deaver WY, Town of ......................................................................
Defense Depot Ogden - UT ............................................................
Deseret Generation & Transmission Co-operative ...................DGT
Bridger Valley Electric Association, Inc. - WY ....................DGT
Colorado City AZ, City of ..................................................DGT
Dixie-Escalante REA - UT..................................................DGT
Flowell Electric Association - UT ........................................DGT
Garkane Electric Association - UT/AZ ................................DGT
Hilldale UT, City of ............................................................DGT
Kanab UT, City of ..............................................................DGT
Moon Lake Electric Association - UT .................................DGT
January 17, 2013
76
WECC Data Collection Manual
Appendix C
Mt. Wheeler Power Association - NV .................................DGT
Helper UT, City of ...........................................................................
Helper UT, Annex ...........................................................................
Hill Air Force Base - UT ..................................................................
Montana Dakota Utilities Company - WY ........................................
Price UT, City of ..................................................... UAMP member
Tooele Army Depot - UT .................................................................
University of Utah - UT ...................................................................
Utah Associated Municipal Power Systems - UT .................. UAMP
Beaver UT, City of .......................................................... UAMP
Blanding UT, City of ........................................................ UAMP
Bountiful UT, City of ........................................................ UAMP
Central Utah Water Conservancy District ........................ UAMP
Enterprise UT, City of ..................................................... UAMP
Ephraim UT, City of ........................................................ UAMP
Fairview UT, City of ........................................................ UAMP
Fillmore UT, City of ......................................................... UAMP
Fredonia AZ, Town of ..................................................... UAMP
Heber Light & Power - UT ............................................... UAMP
Holden UT, Town of ........................................................ UAMP
Hurricane UT, City of ...................................................... UAMP
Hyrum UT, City of ........................................................... UAMP
Idaho Falls ID, City of ..................................................... UAMP
Kanosh UT, City of.......................................................... UAMP
Kaysville UT, City of ........................................................ UAMP
Lehi UT, City of ............................................................... UAMP
Logan UT, City of ............................................................ UAMP
Meadow UT, City of ........................................................ UAMP
Monroe UT, City of.......................................................... UAMP
Morgan UT, City of.......................................................... UAMP
Mount Pleasant UT, City of ............................................. UAMP
Murray City Corporation - UT .......................................... UAMP
Oak City - UT .................................................................. UAMP
Paragona UT, Town of .................................................... UAMP
Parowan UT, City of ........................................................ UAMP
Payson UT, City of .......................................................... UAMP
Saint George UT, City of ................................................. UAMP
Santa Clara UT, City of ................................................... UAMP
Spring City - UT .............................................................. UAMP
Springville UT, City of ..................................................... UAMP
Strawberry Water Users Assoc. - UT .............................. UAMP
Utah State University ...................................................... UAMP
Washington UT, City of ................................................... UAMP
Weber Basin Water Conservancy District - UT ............... UAMP
Utah Municipal Power Agency .............................................. UMPA
Levan UT, Town of ......................................................... UMPA
Manti UT, City of ............................................................. UMPA
Nephi UT, City of ............................................................ UMPA
Provo UT, City of ............................................................ UMPA
Salem UT, City of............................................................ UMPA
Spanish Fork UT, City of ................................................. UMPA
January 17, 2013
77
WECC Data Collection Manual
Appendix C
Western Area Power Administration - Salt Lake .................. WAUC
CUP - Bonneville Unit .................................................... WAUC
CUP - Jensen Unit ......................................................... WAUC
USBR - Upper Colorado Region .................................... WAUC
Uintah Water Conservancy Dist. .................................... WAUC
Sierra Pacific Power Company - NV.................................................... SPP ............ SPPC
Rocky Mountain Power Area
Power Area
LSE
BA
Public Service Company of Colorado .................................................. PSC ............ PSCO
Aquila Networks-WPC ............................................................ WPE
Arkansas River Power Authority ........................................... ARPA
Granada CO, City of - (non-ARPA member) ................... ARPA
Holly CO, City of ............................................................. ARPA
La Junta CO, City of ....................................................... ARPA
Las Animas CO, City of .................................................. ARPA
Lamar CO, City of ........................................................... ARPA
Raton NM, City of ........................................................... ARPA
Springfield CO, City of .................................................... ARPA
Trinidad CO, City of ........................................................ ARPA
Burlington CO, City of .....................................................................
Center CO, City of ..........................................................................
DOE - Rocky Flats ..........................................................................
Grand Valley Rural Power Lines - Grand Junction CO ...................
Holy Cross Electric Association - Glenwood Springs CO ................
Intermountain Rural Electric Assn. - Sedalia CO ............................
Municipal Energy Agency of Nebraska ................................. MEAN
Aspen CO, City of ........................................................... MEAN
Glenwood Springs CO, City of ........................................ MEAN
Yampa Valley Electric Assn. - Steamboat Springs CO ...................
Western Area Power Administration - Colorado-Missouri Region ............... ........... WACM
Basin Electric Power Cooperative - west .............................. BEPC
Rushmore Electric Power Cooperative ........................... BEPC
Tri-County Electric Association, Inc. ............................... BEPC
Black Hills Power and Light Company ................................... BHPL
Upton, City of ................................................................... BHPL
South Dakota State Cement Plant ................................... BHPL
South Dakota School of Mines & Technology .................. BHPL
Cody WY, City of ................................................... WMPA member
Colorado River Pumps (7) ..............................................................
Colorado Springs Utilities ........................................................CSU
Air Force Academy ............................................................CSU
Norad.................................................................................CSU
Peterson Air Force Base ....................................................CSU
Denver Water Board .......................................................................
Forest Service ................................................................................
Fort Laramie WY, City of ....................................... WMPA member
January 17, 2013
78
WECC Data Collection Manual
Appendix C
Goshen Irrigation District ................................................................
Guernsey WY, City of ............................................ WMPA member
Highland-Hanover Irrigation District ................................................
Lingle WY, City of .................................................. WMPA member
Lusk WY, City of .................................................... WMPA member
Midvale Irrigation District ................................................................
Municipal Energy Agency of Nebraska ................................. MEAN
Aspen CO, City of ........................................................... MEAN
Basin WY, Town of ......................................................... MEAN
Bayard NE, City of .......................................................... MEAN
Bridgeport NE, City of ..................................................... MEAN
Delta CO, City of ............................................................. MEAN
Fleming CO, City of ........................................................ MEAN
Fort Morgan CO, City of - (RMGC member).................... MEAN
Fountain CO, City of ....................................................... MEAN
Gering NE, City of ........................................................... MEAN
Gillette WY, City of.......................................................... MEAN
Gunnison CO, City of ...................................................... MEAN
Haxtun CO, City of .......................................................... MEAN
Holyoke CO, City of - (RMGC member) .......................... MEAN
Kimball NE, City of .......................................................... MEAN
Lyman NE, City of ........................................................... MEAN
Lyons CO, City of............................................................ MEAN
Mitchell NE, City of ......................................................... MEAN
Morrill NE, City of ............................................................ MEAN
Oak Creek CO, City of .................................................... MEAN
Sidney NE, City of........................................................... MEAN
Torrington WY, City of .................................................... MEAN
Yuma CO, City of ............................................................ MEAN
National Park Service .....................................................................
Owl Creek Irrigation District ............................................................
Pine Bluffs WY, City of .......................................... WMPA member
Powell WY, City of ................................................. WMPA member
Pueblo Army Depot, CO .................................................................
Tri-State Generation and Transmission Association, Inc. ......TSGT
Big Horn Rural Electric Co. - Basin WY ...........................TSGT
Carbon Power & Light - Saratoga WY..............................TSGT
Chimney Rock Public Power District - West - Bayard NE.TSGT
Delta-Montrose Rural Power Lines - Delta CO.................TSGT
Empire Electric Association - Cortez CO..........................TSGT
Garland Light & Power - Powell WY ................................TSGT
Gunnison County Electric Assn. - Crested Butte CO........TSGT
Highline Electric Association - West - Holyoke CO...........TSGT
Hot Springs County REA - Thermopolis WY ....................TSGT
K. C. Electric Association - Hugo CO ...............................TSGT
La Plata Electric Association - Durango CO .....................TSGT
Morgan County Rural Electric Assn. - Fort Morgan CO ....TSGT
Mountain Parks Electric - Granby CO ..............................TSGT
Mountain View Electric Association - Limon CO ..............TSGT
Niobrara Electric Association, Inc. - Lusk WY ..................TSGT
Poudre Valley Rural Electric Assn. - Fort Collins CO .......TSGT
January 17, 2013
79
WECC Data Collection Manual
Appendix C
Riverton Valley Electric Association - Riverton WY ..........TSGT
Roosevelt Public Power District - Mitchell NE ..................TSGT
Rural Electric Company - Pine Bluffs CO .........................TSGT
San Isabel Electric Service, Inc. - Pueblo CO ..................TSGT
San Luis Valley Rural Electric Coop - Monte Vista CO ....TSGT
San Miguel Power Association - Nucla CO ......................TSGT
Sangre De Cristo Electric Assn. - Buena Vista CO ..........TSGT
Sheridan-Johnson Rural Electric Assn. - Sheridan WY ....TSGT
Southeast Colorado Power Association - La Junta CO ....TSGT
United Power, Inc. - Brighton CO .....................................TSGT
Wheatbelt Public Power District - West - Sidney NE ........TSGT
Wheatland Rural Electric Association - Wheatland WY....TSGT
White River Electric Association - Meeker CO .................TSGT
Wyrulec Company - Lingle WY ........................................TSGT
Y-W Electric Association - Akron CO ...............................TSGT
Frederick CO, City of .................. (non-TSGT member) ...TSGT
Northern CO Water Cons. Dist.... (non-TSGT member) ...TSGT
Wray CO, City of ......................... (non-TSGT member) ...TSGT
Upper Bluff Irrigation District ...........................................................
USBR - Animas - La Plata ..............................................................
USBR - Dolores Project ..................................................................
USBR - Paradox .............................................................................
Warren Air Force Base - WY ................................. RMGC member
Wheatland WY, City of .......................................... WMPA member
Willwood Light & Power - WY ................................ RMGC member
Silt Water Conservancy District ........................................... WAUC
Uintah Water Conservancy District ...................................... WAUC
Desert Southwest Power Area
Power Area
LSE
BA
Arizona Public Service Company ........................................................ APS ............. AZPS
Aguila Irrigation District ...................................................................
Ajo Improvement Company ............................................................
Ak-Chin Indian Community .............................................................
Buckeye Water Conservancy District ......................... APA member
Citizens Utilities Company ...................................................... CUC
Colorado River Agency...................................................................
Electrical District No. 1 - Pinal, AZ ..................................................
Electrical District No. 3 - Pinal, AZ ............................. APA member
Electrical District No. 6 - Pinal, AZ ............................. APA member
Electrical District No. 7 - Maricopa, AZ ...................... APA member
Electrical District No. 8 - Maricopa, AZ ...........................................
Gila Bend Air Force Base ...............................................................
Harquahala P.D. .............................................................................
Luke Air Force Base .......................................................................
Maricopa MWCD No. 1 .............................................. APA member
Marine Corps Air Station ................................................................
McMullen Valley W.C.&D................................................................
January 17, 2013
80
WECC Data Collection Manual
Appendix C
Mojave County ...............................................................................
Roosevelt Irrigation District ........................................ APA member
Tohono O'odham Utility Authority ......................................... TOUA
Tonopah Irrigation District...............................................................
Wickenburg Electrical Department..................................................
Yuma Irrigation District - residential ................................................
Yuma Proving Grounds - DOD .......................................................
DECA, LLC – Arlington Valley .................................................................... ............ DEAA
El Paso Electric Company ................................................................... EPE ............... EPE
Rio Grande Electric Cooperative, Inc. .............................................
Holloman AFB ................................................................................
Gila River Maricopa Arizona....................................................................... ........... GRMA
Griffith Energy ............................................................................................ .............. GRIF
Harquahala Generator Maricopa Arizona ................................................... ........... HGMA
Imperial Irrigation District ...................................................................... IID ..................IID
Nevada Power Company ................................................................. NEVP ............ NEVP
City of Boulder City - NV ..........................................................CBC
DOE/NTS .......................................................................................
Fort Mojave Indian Tribe - AZ .........................................................
Lincoln County Power District #1 ....................................................
Littlefield Electric Coop. - AZ ..........................................................
Needles CA, City of ........................................................................
Nellis Air Force Base ......................................................................
Overton Power District #5 ...............................................................
State of Nevada (Colorado River Commission) ................... CRCN
Valley Electric Association ..............................................................
Public Service Company of New Mexico ............................................ PNM .............. PNM
Gallup NM, City of ..........................................................................
Kirtland AFB ...................................................................................
Los Alamos County - NM ......................................................... LAC
DOE - Albuquerque ........................................................... LAC
Navopache Electric Cooperative, Inc. .............................................
Navajo Agricultural Products Industry ............................... NAPI
Texas-New Mexico Power Company ....................................... TNP
Tri-State Generation and Transmission Association, Inc. ......TSGT
Central New Mexico Electric Cooperative, Inc. ................TSGT
Columbus Electric Cooperative, Inc. ................................TSGT
Continental Divide Electric Cooperative, Inc. ...................TSGT
Jemez Mountains Electric Cooperative, Inc. ....................TSGT
Kit Carson Electric Cooperative, Inc. ...............................TSGT
Mora-San Miguel Electric Cooperative, Inc. .....................TSGT
Northern Rio Arriba Electric Cooperative, Inc. ..................TSGT
Otero Electric Cooperative, Inc. .......................................TSGT
Sierra Electric Cooperative, Inc........................................TSGT
Socorro Electric Cooperative, Inc. ....................................TSGT
Southwestern Electric Cooperative, Inc. ..........................TSGT
Springer Electric Cooperative Inc.....................................TSGT
January 17, 2013
81
WECC Data Collection Manual
Appendix C
Truth or Consequences NM, City of (non-TSGT member)TSGT
Salt River Project ................................................................................ SRP ............... SRP
Arizona Power Authority .......................................................... APA
Chandler Heights Citrus IP .................................. APA member
Electrical District No. 5 - Maricopa, AZ................. APA member
Electrical District No. 6 - Pinal, AZ ....................... APA member
Ocotillo Water Conservation District .................... APA member
Queen Creek Irrigation District ............................. APA member
Roosevelt Irrigation District .................................. APA member
Roosevelt Water Conservation District................. APA member
Central Arizona Water Conservation District ...................................
Electrical District No. 4 - Pinal, AZ ..................................................
Electrical District No. 5 - Pinal, AZ ..................................................
San Tan Irrigation District ...............................................................
Tucson Electric Power Company ........................................................ TEP ............. TEPC
Cortaro Marana Irrigation District ............................... APA member
Navajo Tribal Utility Authority................................................ NTUA
Western Area Power Administration - Lower Colorado Region .................. ............ WALC
Arizona Electric Power Cooperative .......(AZPPA member) .. AEPC
Anza Electric Cooperative................. ............................. AEPC
Arizona Power Pooling Association .. ........................... AZPPA
Avra Valley ....................................... .......................................
Duncan Valley Cooperative .............. ............................. AEPC
Electrical District No. 2 - Pinal, AZ .... ..............AZPPA member
Graham County Electric Cooperative ............................. AEPC
Mesa AZ, City of ............................... ..............AZPPA member
Mohave Electric Cooperative ............ .......................................
Safford AZ, City of ............................ ............................. AEPC
San Carlos Irrigation Project (SCIP) . ..............AZPPA member
Silverbell ........................................... .......................................
Sulphur Springs Valley Cooperative . .......................................
Thatcher AZ, City of .......................... ............................. AEPC
Tohono O'odham Utility Authority ..... ............................. TOUA
Trico Electric Cooperative ................. ............................. AEPC
Farmington NM, City of ................................................... FARM
Aztec NM, City of ............................................................ FARM
Page AZ, City of .............................................................................
Wellton-Mohawk Irrigation District ..................................................
USBR - Protective Regulatory Pumps ............................................
USBR - Yuma Desalting Plant ........................................................
USBR - Yuma Project .....................................................................
Yuma Irrigation District ...................................................................
Northern California Power Area
Power Area
LSE
BA
California Independent System Operator ................................................... ............. CISO
Department of Water Resources/California ......................... CDWR
January 17, 2013
82
WECC Data Collection Manual
Appendix C
Northern California Power Agency........................................ NCPA
Alameda CA, City of ....................................................... NCPA
Biggs CA, City of ............................................................ NCPA
Gridley CA, City of .......................................................... NCPA
Healdsburg CA, City of ................................................... NCPA
Lodi CA, City of ............................................................... NCPA
Lompoc CA, City of ......................................................... NCPA
Oakland, Port of .............................................................. NCPA
Palo Alto CA, City of ....................................................... NCPA
Plumas-Sierra Rural Electric Cooperative ....................... NCPA
Ukiah CA, City of ............................................................ NCPA
Pacific Gas & Electric Company ........................................... PG&E
Calaveras Public Power Agency ..................................... PG&E
East Bay Municipal Utility District .................................... PG&E
Lassen County Municipal Utility District .......................... PG&E
Merced Irrigation District ................................................. PG&E
Nevada Irrigation District................................................. PG&E
Oakdale Irrigation District................................................ PG&E
Oroville-Wyandotte Irrigation District ............................... PG&E
Placer County Water Agency .......................................... PG&E
San Francisco, City and County of - loads only............... PG&E
Shelter Cove Improvement District ................................. PG&E
Solano Irrigation District .................................................. PG&E
South San Joaquin Irrigation District ............................... PG&E
Trinity County Public Utility District ................................. PG&E
Tuolumne County Public Power Agency ......................... PG&E
Yuba County Water Agency............................................ PG&E
Santa Clara CA, City of - NCPA, CCPA & MSR member .......SNCL
San Francisco, City and County of - resources only ............. CCSF
Transmission Agency of Northern California ......................... TANC
WASN loads wheeled by PG&E
Ames Research Center (NASA)................................................
Arvin-Edison Water District (IP) ................................................
Avenal, City of ..........................................................................
Banta-Carbona Irrigation District (IP) ........................................
Bay Area Rapid Transit .............................................................
Beale Air Force Base ................................................................
Broadview Water District...........................................................
Byron-Bethany Irrigation District (IP) .........................................
Camp Parks (Provisional) .........................................................
Cawela Water District ...............................................................
Coleman National Fish Hatchery ..............................................
Defense District Depot (Sharpe Facility) (DLA) .........................
Defense District Depot (Tracy Facility) (DLA)............................
Delano/Lindsay/Terra (IP) .........................................................
Deuel Vocation Institution .........................................................
DOE - Lawrence Berkeley Lab..................................................
DOE - Site 300 .........................................................................
DOE - Stanford Linear Accelerator Center ................................
Glenn-Colusa Irrigation District (IP) ..........................................
Inter. Comm. Ag. - Dixon ..........................................................
January 17, 2013
83
WECC Data Collection Manual
Appendix C
James Irrigation District ............................................................
Kern-Tulare River Water District ...............................................
Lassen Municipal Utility District.................................................
Lower Tule Water District..........................................................
Mare Island Naval Shipyard ......................................................
Naval Air Station - Lemoore ......................................................
Naval Air Station - Moffett Field ................................................
Naval Comm. Station - Stockton ...............................................
Naval Radio Station - Dixon ......................................................
Naval Weapons Station - Concord ............................................
Northern California Youth Center ..............................................
Oakland Naval Supply Center ...................................................
Onizuka Air Force Base ............................................................
Parks Reserve Forces Training Area - Dublin (DLA) .................
Patterson Water District (IP) .....................................................
Provident Irrigation District (IP) .................................................
Reclamation Dist. 2035 (Main) (IP) ...........................................
Reclamation Dist. 2035 (Booster) (IP).......................................
Santa Clara Valley Water District ..............................................
San Luis Water District .............................................................
Sierra Conservation ..................................................................
Sonoma County WA .................................................................
Travis Air Force Base ...............................................................
Travis Wherry Housing .............................................................
University of California - Davis ..................................................
Vacaville Medical Facility ..........................................................
Westlands Water District (IP) ....................................................
W. Stanislaus Irrigation District (IP) ..........................................
West Side Irrigation District .......................................................
Balancing Authority of Northern California - CCPA member ....................... ............ BANC
Folsom State Prison .......................................................................
McClellan Air Force Base ...............................................................
Modesto Irrigation District - CCPA & MSR member ..................MID
Redding CA, City of - NCPA, CCPA & MSR member RDNG/WASN
Roseville CA, City of .................................................. NCPA/WASN
Sacramento Municipal Utility District .....................................SMUD
Western Area Power Administration - Sierra Nevada RegionWASN
California State Parks - Folsom ..................................... WASN
CSUS - Nimbus ............................................................. WASN
DOE - Lawrence Livermore National Lab....................... WASN
Shasta Lake, City of....................................................... WASN
Turlock Irrigation District – NCPA member ........................................... TID .............. TIDC
Southern California Power Area
Power Area
LSE
BA
California Independent System Operator ................................................... ............. CISO
Department of Water Resources/California ......................... CDWR
Metropolitan Water District/Southern California ..................... MWD
January 17, 2013
84
WECC Data Collection Manual
Appendix C
Pasadena CA, City of ............................................................PASA
San Diego Gas & Electric Company ..................................... SDGE
Southern California Edison Company ...................................... SCE
Edwards Air Force Base .................................................... SCE
March Air Force Base ........................................................ SCE
SCE Blythe District ............................................................ SCE
Anaheim CA, City of .......................................................ANHM
Azusa CA, City of............................................................. AZSA
Banning CA, City of ........................................................ BNNG
Colton CA, City of ............................................................ CLTN
Riverside CA, City of ....................................................... RVSD
Vernon CA, City of .......................................................... VERN
Los Angeles Department of Water & Power ..................................... LDWP ............ LDWP
Burbank CA, City of .............................................................. BURB
Glendale CA, City of ............................................................. GLEN
Mexico Power Area
Power Area
LSE
BA
Comisión Federal de Electricidad - northern Baja only ........................ CFE ............... CFE
January 17, 2013
85
WECC Data Collection Manual
Appendix C
This page intentionally left blank
January 17, 2013
86
WECC Data Collection Manual
Appendix D: WECC Criteria for Uniform Reporting of Generator
Ratings
January 17, 2013
87
WECC Data Collection Manual
This page intentionally left blank
January 17, 2013
88
WECC Data Collection Manual
Appendix D
WECC Criteria for Uniform Reporting of Generator Ratings
A. STEAM TURBO-GENERATOR CAPABILITY
(No regulating or emergency loading limits included)
1. Conditions
a. All essential equipment available for service.
2. Ratings (report on summer, winter, or monthly basis) –
Those net kW ratings for individual generating units that the owner is willing to
use for regular day-to-day operation. An owner may include units that are not
operated on a day-to-day basis but that are maintained in operable condition.
Ratings would be based on the capability expected by the operator at the time of
the monthly or seasonal peak load. Such ratings will be based on condensing
water temperatures and ambient temperatures that influence capability at the
time of peak load (use a, b, or c below as it applies to a system's use of the unit).
a. Unit for a 4-hour period.
b. Unit for a 10-hour period.
c. Unit for a 24-hour period.
For a common header plant, use a, b, or c above on a plant basis.
B. GAS TURBO-GENERATOR CAPABILITY
(No regulating or emergency loading limits included)
1. Conditions
a. All essential equipment available for service.
2. Ratings (report on summer, winter, or monthly basis) –
Those net kW ratings for individual generating units that the owner is willing to
use for regular day-to-day operation. An owner may include units that are not
operated on a day-to-day basis but that are maintained in operable condition.
Ratings would be based on the capability expected by the operator at the time of
the monthly or seasonal peak load. Such ratings will be based on ambient
temperatures that influence capability at the time of peak load (use a, b, c or d
below as it applies to a system's use of the unit).
a. Unit for a 1-hour period.
b. Unit for a 4-hour period.
c. Unit for a 10-hour period.
d. Unit for a 24-hour period.
January 17, 2013
89
WECC Data Collection Manual
Appendix D
C. HYDRO TURBO-GENERATOR CAPABILITY
(No regulating or emergency loading limits included)
1. Conditions (Median and Adverse Water)
a. All essential equipment available for service.
b. Water conditions based upon minimum head during that period of the month
or season when system peak is maximum.
c. For multiple-unit hydro plants, each unit is assigned a rating by apportioning
the combined capabilities among the units.
2. Ratings (report on summer, winter, or monthly basis) –
Those net kW ratings for the individual generating plant that the owner is willing
to use for regular day-to-day operation.
a. Plant for a 1-hour period.
b. Plant for a 4-hour period (or longer period if the system's daily peak period is
longer than 4 hours).
Prepared and Submitted by the
Operating Studies Work Group
Approved by the Technical Operations
Subcommittee, February 15, 1974
Approved by the Operations Committee
March 14, 1974
Submitted to the Executive Committee
March 21, 1974
Adopted by the Executive Committee
June 20, 1974
January 17, 2013
90
WECC Data Collection Manual
Appendix E: Exhibit B – Collection and Review of
Loads and Resources Data
Effective Date: December 7, 2007
91
WECC Data Collection Manual
This page intentionally left blank
Effective Date: December 7, 2007
92
WECC Data Collection Manual
Appendix E
Exhibit B – Collection and Review of Loads and Resources Data
A. Overview and Background.
The WECC Loads and Resources Subcommittee (LRS) oversees the WECC loads
and resources data collection and power supply assessment for the resource
adequacy in WECC. The LRS is the primary WECC forum that addresses the loads
and resources activities at NERC. The LRS is also the primary WECC entity
disseminating information to all parties within the Western Interconnection as it
relates to load and resources. Data collected by the LRS may also be incorporated
into the Transmission Expansion Planning Policy Committee Database for regional
and subregional studies.
LRS responsibilities also include:
 developing and recommending resource adequacy guidelines and targets
to the Planning Coordination Committee for the power supply assessment;
 developing approaches that will promote compilation of loads and
resources data that are clear, comprehensive, and accurate;
 developing meaningful processes for assessing resource adequacy
(capacity and energy) and reporting the results of such assessments;
 preparing and presenting reports of the data received from WECC entities,
including aggregations of confidential data that are suitable for release to
the public; and
 other duties as directed by the Planning Coordination Committee.
B. Identification of Exhibit B Data Collected by the LRS.
In accordance with the WECC Reliability Information Sharing Policy, the WECC
balancing authorities, load-serving entities, or other stakeholders are requested to
provide to WECC staff and/or the LRS and update as necessary the data in the
general categories listed below, which are referred to elsewhere in this document as
“Exhibit B Data.” Section F of this document describes the process for identifying
more specifically the data to be submitted from these categories:
 existing generation and transmission data;
 actual year resources data;
 generation additions data;
 future year peak demands, future resources, future scheduled outages,
future transfers, and planning reserves data;
 future year demand reduction impacts;
 future year energy load data;
 future year transmission data;
 actual year peak demands, outages, and transfers data;
Effective Date: December 7, 2007
93
WECC Data Collection Manual



Appendix E
actual year demand reduction data;
actual year energy load data; and
other data collected in support of the annual Power Supply Assessment
process.
C. Access to Loads and Resources Data by the LRS Members and WECC Staff.
1. Confidentiality. The following information will be treated as confidential under
the “WECC Reliability Information Sharing Policy, Section D – Protecting
Confidential, Privileged, and Proprietary Information” (approved by the Board on
December 1, 2005): first three years of future data on projected peak demand,
energy load, and scheduled outages. These data will remain confidential for
three years from the date of designation, after which the data will become nonconfidential. Future year peak demands, future year energy load, and future year
scheduled outages data beyond three years will not be deemed confidential.
2. Access to Data by LRS Members and WECC Staff. The LRS chair will
designate LRS members who are authorized to be active participants in LRS
data or adequacy analysis task forces. These designated LRS members and
WECC staff may obtain and review:

all Exhibit B Data;

other data obtained from supplemental data requests for use in the annual
power supply assessment process and other assessments required by
NERC; and

results of the annual power supply assessment.
LRS members designated by the LRS chair to be given access to confidential
Exhibit B Data must not be involved in trading or marketing activities and must be
transmission function or shared employees (as defined by Standards of Conduct
filings submitted to FERC by jurisdictional utilities in the U.S. or Standards of
Conduct filings submitted to provincial authorities for Canadian utilities). Class 5
WECC members and members based outside the U.S. that are not subject to
Standard of Conduct and are not involved in marketing or trading activities may
be given access by the LRS chair.
Members designated by the LRS chair as having access to Exhibit B Data will be
re-designated annually and these members will be listed on the website. Further,
these members will report any change in their status under applicable Standards
of Conduct filings.
Data to be treated as confidential in accordance with Section C.1 of this
document will be used only for the purpose of assessing reliability and adequacy.
For the first three years following designation, confidential Exhibit B Data may be
accessed only after a WECC confidentiality agreement has become effective
pursuant to Section D.2.2.3 of the WECC Reliability Information Sharing Policy. A
person or entity that is denied access to Exhibit B Data covered by Section C.1
Effective Date: December 7, 2007
94
WECC Data Collection Manual
Appendix E
may appeal this decision to the WECC Board of Directors as specified in the
WECC Reliability Information Sharing Policy and the WECC Bylaws.
3. Release of Aggregated Versions of Confidential Data. For Exhibit B Data that
is to be treated as confidential in accordance with Section C.1, the LRS is
obligated to develop aggregated totals for the first three years of the forecast
period that will allow the data to be released to the public without identification of
individual member data and end user values.
D. Disagreements. Any disagreements about any Exhibit B Data requests or members
having access to confidential data as designated by the LRS chair will be resolved
through WECC review processes specified in the WECC Reliability Information
Sharing Policy.
E. Critical Energy Infrastructure Information. None of the Exhibit B Data will be
treated as Critical Energy Infrastructure Information unless specifically identified
otherwise in an Exhibit to the WECC Reliability Information Sharing Policy.
F. Specific Data. Exhibit B Data will be identified more specifically in the “WECC
Reporting Process for the Collection of Loads and Resources Data” that is adopted
annually by the LRS. In addition, any supplemental data requests containing data
subject to Section C.1 to support the annual Power Supply Assessment prepared
and issued by the WECC staff will be considered Exhibit B Data following review and
approval of such data requests by the LRS.
Effective Date: December 7, 2007
95
WECC Data Collection Manual
Appendix E
This page intentionally left blank.
January 17, 2013
96