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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

1 5 5 N O R T H 4 0 0 W E S T • S U I T E 2 0 0 • S A L T L A K E C I T Y • U T A H • 8 4 1 0 3 - 1 1 1 4 • P H 8 0 1 . 5 8 2 . 0 3 5 3 • F X 8 0 1 . 5 8 2 . 3 9 1 8

WECC Data Collection Manual

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Table of ContentsIntroduction 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

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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

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Introduction and OverviewPurpose

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 DateThe 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 AuthoritiesThe 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 their organizations’ information to the BA and for developing appropriate data collection

1 NERC Assessments2 WECC Power Supply Assessments3 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_20111117_without_appendices.pdf 5 PCC Charter

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http://www.wecc.biz/library/Documentation%20Categorization%20Files/Charters/PCC/PCC%20Charter.pdf

http://www.nerc.com/fileUploads/File/Rules_of_Procedure/NERC_Rules_of_Procedure_EFFECTIVE_20111117_without_appendices.pdf

http://www.nerc.com/fileUploads/File/Rules_of_Procedure/NERC_Rules_of_Procedure_EFFECTIVE_20111117_without_appendices.pdf

http://www.eia.doe.gov/cneaf/electricity/page/eia411/eia411.html

http://www.wecc.biz/library/default.aspx?RootFolder=%2Flibrary%2FWECC%20Documents%2FPublications%2FPower%20Supply%20Assessments&FolderCTID=0x012000278A29140A43884799CB122F821DFD01&View=%7B8D18396E-7F8B-4472-AB30-18D2A9576FF0%7D

http://www.nerc.com/page.php?cid=4%7C61


procedures to ensure that all requested information is provided to the appropriate non-BA 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 EntitiesThe 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 OverviewThis 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 RequirementsThe 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 ConfidentialityExhibit 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,

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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 SubmissionThe completed Excel workbook should be sent via email to [email protected] on or before the Data Submission Due Date. Since BAs are responsible for reporting data from non-BA 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 RegionIt 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 ManualQuestions 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

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http://www.wecc.biz/library/WECC%20Documents/Business%20and%20Governance%20Documents/Policies/Reliability%20Information%20Sharing%20Policy.pdf



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Attachment A: Excel Workbook

WECC Data Collection Manual Attachment A


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Excel WorkbookAn 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 DescriptionMain Used to hold pertinent information about the represented area.

Status 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 Data input sheet for the “peak” data, including peak loads, outages, and actual transfers.

energy_data Data input sheet for energy load information

growth A data checking form for load growth.

load_diff 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 Comparison sheet of previous and current peak demands data.

Actual Generation

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)

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Worksheet DescriptionProjected

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

Data input sheet for ownership percentages of generation resources located outside of generation owners BA.

DSM Programs Voluntary data input sheet for DSM programs.

DVal 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.

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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 [email protected]. The LRS procedures specify that the LRS chair will contact the PCC

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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.

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Attachment B:Existing and Planned Generation Reporting

Instructions

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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.

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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 [email protected] on or before the Data Submission Due Date.

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Existing Generation and Generation Additions Data: Facility Record Format

Field Name ExplanationEIA Plant Code EIA Plant Code

EIA Unit Code EIA Unit Code

ZoneFor 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 ExplanationBA 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.)

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Field Name ExplanationUnit 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 PartCT........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 FiringHY........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 definitionPS........Hydraulic Turbine – Reversible (pumped storage)BT........Turbines Used in a Binary Cycle (such as used for geothermal

applications)PV-T....Solar Photovoltaic with TrackingPV-NT..Solar Photovoltaic without TrackingSP-S....Solar Thermal with StorageSP-NS..Solar Thermal without StorageWT.......Wind Turbine, OnshoreCE........Compressed Air Energy Storage FC........Fuel CellOT........OtherOS.......Other StorageNA........Undetermined/UnknownNote: 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.

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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 ExplanationPrimary Fuel The following options are included in the workbook:

BIT.......Anthracite Coal and Bituminous CoalSUB.....Subbituminous CoalLIG.......Lignite CoalWC.......Waste/Other Coal. Including anthracite culm, bituminous gob, fine

coal, lignite waste, waste coalSC........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 CokeDFO.....Distillate Fuel Oil. Including Diesel, No. 1, No. 2, and No. 4 Fuel OilsSG.......Synthetic Gas, other than coal-derivedSGC.....Synthetic Gas, derived from coalJF.........Jet FuelKER.....KeroseneRFO.....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

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Primary FuelThe following options are included in the workbook:

petroleum-based liquid wasteNG.......Natural GasPG.......Gaseous PropaneBFG.....Blast Furnace GasOG.......Other Gas (coke oven, refinery etc.)NUC.....Nuclear including Uranium, Plutonium, ThoriumGEO.....Geothermal SteamWAT.....Water at a conventional hydroelectric turbine- base ratings on median

hydro conditionsAB........Agriculture Crop Byproducts/Straw/Energy CropsBLQ.....Black LiquorLFG......Landfill GasMSW....Municipal Solid WasteOBL.....Other Biomass LiquidsOBS.....Other Biomass SolidsOBG.....Other Biomass Gas (includes digester gas, methane, and other

biomass gases)PUR.....Purchased SteamSLW.....Sludge WasteTDF......Tire-derived FuelsWDL.....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 solidsSUN.....SolarWND....WindOTH.....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 ExplanationStatus Code The following options are available for reporting the Status Code:

Existing Generation OnlyOP.......Operating or short-term outageSB........Cold standby, 3-6 mo. to reactivateOS.......Out of serviceRE........Retired (report a summer and winter capacity of zero (0) and indicate

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Status Code

reason for retirement in the comments field)

Generation Additions/Repowers Only P..........Planned for installation but not under active constructionL...........Regulatory approval pending but not under active construction (started

site preparation)T..........Regulatory approval received but not under active constructionU..........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 statusRA........Previously retired or deactivated generator planned for reactivationRT........Existing generator scheduled for retirement (indicate reason in

comments field)FC........Existing generator planned for conversion to another fuel or energy

sourceIP.........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

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NERCClass Code

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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

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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 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.

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EO – Existing-Other – [WECC staff does not believe that the Existing-Other 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. ["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.]

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 non-connected emergency generators.

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.

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

January 17, 2013 23


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.

January 17, 2013 24


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.

WECC Class Code

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 in-service 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.

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 CodesNERC Class

CodesWECC Class

CodesEC

0EO*FP 1

2

January 17, 2013 25


3

FO*234

C 4EI 4- 5

* 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

Commission Date

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

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.

TSS Bus Bus NumberBus number associated with generation location. The Bus number should be the same number submitted for TSS base cases.

Wind/Solar Zone Wind/Solar Zone

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.

TEPPC Profile

Wind/Solar Profile Location

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.

7 Document is available on the WECC website at: http://www.wecc.biz/committees/StandingCommittees/PCC/LRS/Shared%20Documents/Wind

January 17, 2013 26

http://www.wecc.biz/committees/StandingCommittees/PCC/LRS/Shared%20Documents/Wind%20Profiles/Renewable%20Energy%20Generation%20Paper.pdf



Field Name Field Content Explanation

Comments Comments

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.

%20Profiles/Renewable%20Energy%20Generation%20Paper.pdf

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Attachment C: Peak Demands, Energy Loads, Resource Outages,

and Actual Transfers Instructions

WECC Data Collection Manual Attachment C

Input Guide for Peak Demand Loads, DSM, Outages, and Transfers Data

IntroductionPeak 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 31


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 32


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 33


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 34


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 35


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 36


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 37


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 38


Actual and Estimated Peak Demand Loads and TransfersCoding Data Record Format

(Actual Year and Estimated Future Years one through eleven, and January, February, and March of twelfth Future Year)

COLUMN HEADING DESCRIPTION

B Year Year

C DSM Code

For data Code 2 (Non-firm peak demand)I - InterruptibleL - Load ManagementP - Critical Peak-Pricing with ControlR - Load as a Capacity Resource

D Code Data Code - Identifies type of data (see previous tables for actual and future year codes)

E 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.




IID AZID

Arizona AZAZ WAAZ


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 39


F BA WECC BA Organization Codes (See Appendix B)

G NA NA

H NA NA

I I/ETransfer Export/Import Code:

E - Export I - Import

J – U Jan-Dec Monthly Values

V Comment Comment

January 17, 2013 40


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, self-serve 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 41


Actual and Estimated Energy LoadsCoding Data Record Format

(Actual Year and Future Years one through eleven, and January, February, and March of the twelfth Future Year)

COLUMN HEADING DESCRIPTIONB Year Year

C NA NA

D CodeData Code - Identifies type of data :

1 - Firm Energy2 - Non-Firm Energy

E 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.




IID AZID

Arizona AZAZ WAAZ


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 42


J – U Jan-Dec Monthly Values

V Comment Comment

January 17, 2013 43



January 17, 2013 44


Attachment D:Reliability and Supply Assessments

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} worksheetColumn Heading Data Description

J Transfer Capability - Summer - Max

The aggregate maximum transfer capability from the modeling area in column B to the modeling area in column C for summer.

K OTC - Summer The aggregate Operating Transfer Capability (OTC) from the modeling area in column B to the modeling in column C for summer.

L Transfer Capability - Summer - High Load

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.

M Transfer Capability - Winter - Max

The aggregate maximum transfer capability from the modeling area in column B to the modeling area in column C for winter.

N OTC - Winter The aggregate OTC from the modeling area in column B to the modeling area in column C for winter.

O Transfer Capability - Winter - High Load

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.

P Loss % The transmission loss percent on the path.Q Wheel $/MWh 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 DefinitionMaximum Transfer capability

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.

"High Load" Transfer The capacity that may reasonably be expected to apply under

January 17, 2013 47


capability simultaneous high seasonal transmission loading conditions. These limits are used in PROMOD to calculate transfers for the 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 48


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 end-use categories (codes L, H, and O). If energy efficiency program savings by end-use category are not available, report only the total (code ‘T’).

January 17, 2013 49



January 17, 2013 50


Attachment E:Miscellaneous Data

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 IPCOZone

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 Field Name Definition InstructionsA Hour of the year Hour of year reported

B 1 Time Zone Time zone where generation is located

Report the time zone for where generation is located.

January 17, 2013 53


Column Row Field Name Definition Instructions

B Nameplate 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.

C 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.

D 1 Modeling Area Modeling Area where generation is located

Report the Modeling Area where the generation is located (use dropdown).

D Actual Hourly Generation

Actual hourly generation in MWs.

Report the actual energy generation for the wind location. Report in MWs.

F 1 TEPPC Wind Profile 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)

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 InstructionsA Hour of the year Hour of year reported

B 1 Time Zone Time zone where generation is located

Report the time zone for where generation is located.

10 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 54




Column Row Field Name Definition Instructions

B 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.

C Available CapacityThe 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.

D 1 Modeling Area Modeling Area where generation is located

Report the Modeling Area where generation is located (use dropdown).

D Actual Hourly Generation Actual hourly generation in MWs.

Report the actual energy generation for the solar location. Report in MWs.

F 1 TEPPC Solar Profile Regional location of generation

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)

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 55




Column Field Name Definition Instruction

B Zone 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.




IID AZID

Arizona AZAZ WAAZ


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 56


E Transmission Status (Choose One)

Under Construction -Construction of the line has

begunPlanned (any of the following) -Permits have been

approved to proceed -Design is complete -Needed in order to meet a

regulatory requirementConceptual (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.

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.

F Type

New LineUpgradeRetirementCancellation

Choose one of the predefined type categories.

G Primary Driver (choose one)

ReliabilityGeneration Integration (Choose one from below) -Variable/Renewable Integration -Nuclear Integration -Fossil-Fire Integration -Hydro IntegrationEconomics or CongestionOther

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.

January 17, 2013 57


H Secondary Driver(if applicable)

ReliabilityGeneration Integration (Choose one from below) -Variable/Renewable Integration -Nuclear Integration -Fossil-Fire Integration -Hydro IntegrationEconomics or CongestionOther

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).

I Tie Line? A tie line connects two or more systems.

Please specify (Yes/No) whether this addition is a tie line across two or more systems.

J Merchant Line Please specify (Yes/No) whether this addition is classified as a 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 six-character 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 – Investor-owned (I), Municipality (M), Cooperative (C), State-owned (S), Federally-owned (F), or other (O).

Q Percent OwnershipIf the transmission line will be jointly-owned, 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 TypeSelect 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).

January 17, 2013 58


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.

AB Pole/Tower Material 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).

AC Pole/Tower Structure Type Data entry is optional

Also include the type of structure – single pole, H-frame structure, tower, underground, or other (P, H, T, U, O).

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.

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.

January 17, 2013 59


Column Field Name Definition Instructions

B Zone 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.




IID AZID

Arizona AZAZ WAAZ


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 transformer is located. (See Appendix B for BA codes)

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 60


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 Definition InstructionsA Balancing Authority

B-H AC Voltage (kV) Categories

Report only Existing (commercially in-service 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.

I Total AC Sum of existing AC transmission line miles.

J-M DC Voltage (kV) Categories

Report only Existing (commercially in-service 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.

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.


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 NameReport unit name. This name must be the same as the name reported on the {gen_exist} or {gen_add} sheet.

C Area 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).

January 17, 2013 61



D Nameplate 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.

E 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.

F-I 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 InstructionsA Year Year reported

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)

E-P Month Jan-Dec Monthly data values associated with each

January 17, 2013 62


Column Field Name Definition InstructionsDemand-Side Management program. This amount is the total enrolled in the specific program and not the amount that is expected to be served.

Q Program/Tariff/Comment

Enter the specific Demand-Side Management program name/tariff.

January 17, 2013 63


Appendix A: Glossary for WECC Data Collection Manual

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 66


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 67


Term 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 Peak-Pricing 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 68


Term 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 The differences between capacity and peak demand. Margin is usually expressed in megawatts.

Reserve 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).

NET ENERGY 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.

January 17, 2013 69


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 70



January 17, 2013 71


Appendix B: WECC Balancing Authorities and Abbreviations

January 17, 2013 72

WECC Data Collection Manual Appendix B

WECC Balancing Authorities Balancing Authority

Canada Power Area Organization CodeAlberta Electric System Operator........................................................AESOBritish Columbia Transmission Company...........................................BCHA

Northwest Power AreaAvista Corp............................................................................................AVABonneville Power Administration – Transmission................................BPATChelan County Public Utility District...................................................CHPDDouglas County Public Utility District.................................................DOPDGlacier Wind Agency............................................................................GWAGrant County Public Utility District......................................................GCPDNaturEner Wind Watch, LLC...............................................................WWANorthWestern Energy........................................................................NWMTPacifiCorp – West..............................................................................PACWPortland General Electric Company......................................................PGEPuget Sound Energy............................................................................PSEISeattle Department of Lighting..............................................................SCLTacoma Power...................................................................................TPWRWestern Area Power Administration, Upper Great Plains – West.....WAUW

Basin Power AreaIdaho Power Company.........................................................................IPCOPacifiCorp – East................................................................................PACESierra Pacific Power Company...........................................................SPPC

Rocky Mountain Power AreaPublic Service Company of Colorado.................................................PSCOWestern Area Power Administration, Colorado-Missouri Region......WACM

Arizona-New Mexico-Southern Nevada Power AreaArizona Public Service Company........................................................AZPSDECA, LLC – Arlington Valley.............................................................DEAAEl Paso Electric Company.....................................................................EPEGila River...........................................................................................GRMAGriffith Energy......................................................................................GRIFHarquahala .......................................................................................HGMAImperial Irrigation District..........................................................................IIDNevada Power Company....................................................................NEVPPublic Service Company of New Mexico..............................................PNMSalt River Project...................................................................................SRP

January 17, 2013 74

WECC Data Collection Manual Appendix B

Tucson Electric Power Company........................................................TEPCWestern Area Power Administration, Lower Colorado Region...........WALC

Northern California Power AreaCalifornia Independent System Operator.............................................CISOBalancing Authority of Northern California..........................................BANCTurlock Irrigation District.......................................................................TIDC

Southern California Power AreaCalifornia Independent System Operator............................................CISO Los Angeles Department of Water and Power...................................LDWP

Mexico Power AreaComisión 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 ..........................................................AlbertaAZ .........................................................ArizonaBC ...........................................British ColumbiaCA ......................................................CaliforniaCO ......................................................ColoradoID ............................................................IdahoKS .........................................................KansasMT .......................................................MontanaNE .....................................................NebraskaND ...............................................North DakotaNM .................................................New MexicoNV ........................................................NevadaOK ....................................................OklahomaOR ........................................................OregonSD ...............................................South DakotaTX ...........................................................TexasUT .............................................................UtahWA .................................................WashingtonWY .....................................................Wyoming

January 17, 2013 75


Appendix C: List of Balancing Authorities and Load-Serving Entitiesby Power Areas

WECC Data Collection Manual Appendix C

List of Balancing Authorities and Load-Serving Entities by Power Area

(Member and Nonmember)

Canada Power AreaPower Area LSE BAAlberta 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.............BCHAWest Kootenay Power Ltd...........................................................ILA

Northwest Power AreaPower Area LSE BAAvista Corp............................................................................................AVA................AVA

Bonneville Power Administration...........................................................BPA..............BPATFederal 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.......................................................................

January 17, 2013 78


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...................................................................

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 -

January 17, 2013 79


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 -

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

January 17, 2013 80


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....................................

January 17, 2013 81


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..........................................

Wasco Electric Cooperative, Inc. - OR.............................................

Wells Rural Electric Cooperative, Inc. - NV......................................

West Oregon Electric Cooperative, Inc. - OR...................................

Chelan County Public Utility District - WA..........................................CHPD.............CHPDCashmere WA, City of......................................................................

Colockum Transmission Company...................................................

Douglas County Public Utility District - WA........................................DOPD.............DOPDOkanogan 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............NWMTCentral 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............TPWRRuston Electric Utility - WA...............................................................

Western Area Power Administration – Great Plains - West....................................WAUW

Basin Power AreaPower Area LSE BAIdaho Power Company - ID.................................................................IPCO..............IPCO

Weiser ID, City of..............................................................................

PacifiCorp - East...................................................................................PAC.............PACE

January 17, 2013 82


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

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

January 17, 2013 83


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

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

January 17, 2013 84


Rocky Mountain Power AreaPower Area LSE BAPublic 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............................WACMBasin 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

January 17, 2013 85


Norad..................................................................................CSU

Peterson Air Force Base.....................................................CSU

Denver Water Board.........................................................................

Forest Service..................................................................................

Fort Laramie WY, City of.........................................WMPA member

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.......................................................................

January 17, 2013 86


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

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

January 17, 2013 87


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 AreaPower Area LSE BAArizona 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 88


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................EPERio 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.............NEVPCity 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...............PNMGallup 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

January 17, 2013 89


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

Truth or Consequences NM, City of (non-TSGT member)TSGT

Salt River Project..................................................................................SRP................SRPArizona 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....................................



San Tan Irrigation District.................................................................

Tucson Electric Power Company..........................................................TEP.............TEPCCortaro Marana Irrigation District................................APA member

Navajo Tribal Utility Authority..................................................NTUA

Western Area Power Administration - Lower Colorado Region................................WALCArizona 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

January 17, 2013 90


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 AreaPower Area LSE BACalifornia Independent System Operator...................................................................CISO

Department of Water Resources/California...........................CDWR

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

January 17, 2013 91


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............................................................................

January 17, 2013 92


DOE - Stanford Linear Accelerator Center.................................

Glenn-Colusa Irrigation District (IP)............................................

Inter. Comm. Ag. - Dixon............................................................

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.....................................BANCFolsom State Prison.........................................................................

McClellan Air Force Base.................................................................

January 17, 2013 93


Modesto Irrigation District - CCPA & MSR member.................MID

Redding CA, City of - NCPA, CCPA & MSR memberRDNG/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 AreaPower Area LSE BACalifornia Independent System Operator...................................................................CISO

Department of Water Resources/California...........................CDWR

Metropolitan Water District/Southern California......................MWD

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.............LDWPBurbank CA, City of................................................................BURB

Glendale CA, City of...............................................................GLEN

Mexico Power AreaPower Area LSE BAComisión Federal de Electricidad - northern Baja only.........................CFE................CFE

January 17, 2013 94


January 17, 2013 95



January 17, 2013 96


Appendix D: WECC Criteria for Uniform Reporting of Generator Ratings

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


1. Conditions



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 99

WECC Data Collection Manual Appendix D

C. HYDRO TURBO-GENERATOR CAPABILITY


1. Conditions (Median and Adverse Water)


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.


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 100


Appendix E: Exhibit B – Collection and Review ofLoads and Resources Data

Effective Date: December 7, 2007 101

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; 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 non-confidential. 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 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.




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