Load and Resource Data Collection Manual

Transcription

1 Load and Resource Data Collection Manual Effective Date: March 3, 2015 Version: Bayport Drive, Suite 600 Tampa, Florida (813) Phone (813) Fax Classification: Public

2 Page 2 of 38 The original signatures are maintained on file. TITLE NAME DATE Version Author Denise Lam 01/26/2015 Document Review Authority Resource Working Group (RWG) Load Forecast Working Group (LFWG) 01/26/2015 Document Owner/Approval Authority Planning Committee (PC) 03/03/2015 Document Subject Matter Expert: Planning Engineer Original Author: Scott Beecher Effective Date: 03/03/2015 Responsible Department: Planning Review Cycle: Every 3 Years Last Date Reviewed: 03/03/2015 Next Planned Review Date: 01/01/2018 Retention Period: 7 Years File Name: frccmspl040_loadandresource Document ID #:

3 Table of Contents Page 3 of 38 Page 1.0 Purpose Terms and Definitions Background Applicability Responsibilities Procedure References Attachments Review and Modification History Disclaimer Attachment A: List of Owning Entities / Operating Entities Attachment B: Unit Type Codes Attachment C: Ownership Codes Attachment D: Fuel Type Codes Attachment E: Fuel Transportation Method Codes Attachment F: Unit Status / Construction Status Codes... 38

4 1.0 Purpose Page 4 of 38 This document outlines the data collected annually in the Load and Resource Database (LRDB). 2.0 Terms and Definitions In addition to those terms defined below, the capitalized terms used in this procedure are defined in the North American Electric Reliability Corporation (NERC) Glossary of Terms Load and Resource Database (LRDB): The Load and Resource Database is used by the FRCC to collect historical and forecasted planning information from Utilities within the FRCC Region and the State of Florida Regional Load & Resource Plan (L&RP): The L&RP is the main work product generated from the data collected from the LRDB and is published annually in July. 3.0 Background The Florida Reliability Coordinating Council (FRCC) Load and Resource Database (LRDB) is an online database used by the FRCC to collect historical and forecasted planning information from utilities within the FRCC Region and the State of Florida. Data provided by the utilities is reflective of data contained in each FRCC Regional Entity s annual Ten Year Site Plan (TYSP). Florida Statute (Title: XIII Chapter 186 Section 801 Ten Year Site Plans) requires each electric utility within the State of Florida to submit to the Florida Public Service Commission (FPSC) a TYSP that estimates its power-generating needs and the general location of proposed power plant sites. The statute also states TYSP shall be reviewed and submitted not less frequently than every 2 years. The FRCC has developed the as a guide for Regional Entities and to assist in collecting data. This manual is posted on the LRDB website as well as on the FRCC website. Access to the database is restricted to designated personnel representing a reporting Entity. The LRDB is opened annually in early February to allow utilities to input their TYSP data in the appropriate forms within the database. The database is closed in mid-march and the data put through a series of checks and validations to ensure that information was entered in the proper forms and is as accurate as possible. Data contained in the LRDB is used to generate various assessments and reports that are required by state and governmental agencies, such as the Florida Public Service Commission (FPSC), North American Electric Reliability Corporation (NERC), Federal Energy Regulatory Commission (FERC), and the Department of Energy s (DOE) Energy Information Administration (EIA). The main work product that is generated using information from the LRDB is the Regional Load & Resource Plan (L&RP). The L&RP is an annual FRCC publication required for regulatory filings to the Florida Public Service Commission (FPSC). Data collected from FRCC entities is aggregated (i.e., loads, resources, energy, fuels, etc.) and used to assemble the L&RP. The FRCC resource adequacy criterion is assessed to ensure that the regional planning criterion of a 15% Reserve Margin is satisfied for the future 10-year period for peninsular Florida. FRCC reserve margin calculations include merchant plant capacity that is under firm contract to Load-Serving

5 Page 5 of 38 Entities (LSEs). The FRCC assesses the upcoming ten-year summer and winter peak hours on an annual basis to ensure that the regional reserve margin requirement of 15% is satisfied. Since the summer of 2004, the three Investor Owned Utilities (Florida Power & Light Company, Duke Energy Florida, and Tampa Electric Company) are currently maintaining a 20% minimum reserve margin planning criterion, consistent with a voluntary stipulation agreed to by the FPSC, while all other utilities typically employ a 15% minimum reserve margin planning criterion. Annual reports that are compiled (in part or whole) from data extracted from the LRDB are the EIA-411 Survey, the FRCC Reliability Assessment to the FPSC, and FRCC submissions to NERC including the Summer Reliability Assessments, the Winter Reliability Assessment, the Long-Term Reliability Assessment, and the Probabilistic Assessment. As new standards are developed, data extracted from the LRDB may be used to compile other reports to fulfill new requirements. 4.0 Applicability FRCC Planning Authority (PA) FRCC Load-Serving Entity (LSE) FRCC Resource Planner (RP) FRCC Transmission Planner (TP) 5.0 Responsibilities Resource Working Group (RWG) The RWG is responsible for the periodic review of this document. Load Forecast Working Group (LFWG) The LFWG is responsible for the periodic review of this document. Planning Committee (PC) The PC is responsible for the final approval of this document. 6.0 Procedure FRCC Form 1.0 Existing Generating Facilities All data entered in this Form is as of December 31 st of the year ended just prior to the current reporting year. The data in this form is populated with data from prior years, please update as needed Owning Entity The entity entering in the data for the unit is assumed to be the owning entity. If this assumption is incorrect, please contact FRCC.

6 Page 6 of 38 See Attachment A for acronyms Operating Entity List the name of the entity that operates the unit. See Attachment A for acronyms Plant Name List the power plant name Unit Number List the number, or number and code for the unit Location List the county where the plant is located. If the plant is located outside of the Florida, also list the state abbreviation where the plant is located Unit Type List the unit type using the corresponding code. See Attachment B for code explanation Ownership List the ownership of the unit using the corresponding code. See Attachment C for code explanation Primary Fuel Type List the primary fuel type using the corresponding code. See Attachment D for code explanation Primary Fuel Transportation Method List the principal method of transporting the primary fuel to the plant site using the corresponding code. See Attachment E for code explanation Alternate Fuel Type If applicable, list the alternate fuel type using the corresponding code. See Attachment D for code explanation Alternate Fuel Transportation Method If applicable, list the principal method of transporting the alternate fuel to the plant site using the corresponding code. See Attachment E for code explanation Alternate Fuel Storage (Days Burn)

7 Page 7 of 38 List the number of days the generator can run under peak summer conditions using the available on-site alternate fuel, based on one of the following parameters for each unit: Capacity Factor Base Load Unit: 50% Intermediate Load Unit: 20% Peaking Load Unit: 5% Load Flow Model Identification Input the model bus number and model unit number for the unit. This may be obtained from the reporting company s transmission planning department, or the FRCC. Also enter the EIA plant and operator generator code Commercial In-Service Date List the commercial in-service month (MM) and year (YYYY) Gross Capability (MW) List the summer and winter gross capabilities of the unit. Report owned portion of a jointly owned unit if the reporting company is not the Primary Owner/Operator of the unit. Consult with the Primary Owner/Operator in determining this amount Net Capability (MW) List the summer and winter net capabilities of the unit. Report owned portion of a jointly owned unit if the reporting company is not the Primary Owner/Operator of the unit. Consult with the Primary Owner/Operator in determining this amount Status List the existing unit status, using the corresponding code. See Attachment F for code explanation Notes Enter any clarifications about the unit. FRCC Form 1.0a Planned Changes to Existing Generation All data on this form is for additions and changes to existing generation that are to occur after December 31 st of the year just ended prior to the reporting year. To apply changes to a unit, click Add Future Change in the menu bar and select the unit. Only units that have been entered in Form 1.0 will appear in the list of units Owning Entity The owning entity is populated from Form 1.0 and cannot be changed in section 1.0a. If a change is needed, please contact FRCC Operating Entity

8 Page 8 of 38 The operating entity is populated from Form 1.0 and cannot be changed in section 1.0a. If a change is needed it can be done in Form Plant Name The plant name is populated from Form 1.0 and should remain the same Unit Number The unit number is populated from Form 1.0 and should remain the same Location The location is populated from Form 1.0 and cannot be changed in section 1.0a and should remain the same Unit Type If there will be a change in the unit type, select the new unit type using the corresponding code. If there is no change to be made, this field will remain the same. See Attachment B for code explanation Ownership The ownership is populated from Form 1.0 and cannot be changed in section 1.0a. If a change is needed it can be done in Form 1.0. See Attachment C for code explanation Primary Fuel Type If there will be a change in the primary fuel type, select the new fuel type using the corresponding code. If there is no change to be made, this field will remain the same. See Attachment D for code explanation Primary Fuel Transportation Method If there will be a change in the primary fuel transportation method, select the new transportation method using the corresponding code. If there is no change to be made, this field will remain the same. See Attachment E for code explanation Alternate Fuel Type If there will be a change in the alternate fuel type, select the new alternate fuel type using the corresponding code. If there is no change to be made this field will remain the same. See Attachment D for code explanation Alternate Fuel Transportation Method If there will be a change in the alternate fuel transportation method select the new alternate fuel method, using the corresponding code. If there is no change to be made this field will remain the same. See Attachment E for code explanation.

9 Page 9 of Alternate Fuel Storage (Days Burn) Only if a change is needed, list the number of days the generator can run under peak summer conditions using the available on-site alternate fuel, based on one of the following parameters for each unit: Capacity Factor Base Load Unit: 50% Intermediate Load Unit: 20% Peaking Load Unit 5% Load Flow Model Identification Verify that the information listed is correct. Please contact FRCC if changes are needed Type of Change List the type of change that is taking place (e.g., D for decrease in capacity). See Attachment F for code explanation Unit Status List the new status that the unit will have after the effective change date. See Attachment F for code explanation Effective Change Date List the date that this change will take place (e.g., if the unit is to retire this would be the retirement date) Gross Capability Change (MW) List any changes to the summer and winter gross capabilities of the unit. To show a decrease in the gross capabilities use negative number (e.g., -200 is a decrease of 200 MW). Report the owned portion of a jointly owned unit. Consult with the Primary Owner/Operator in determining this amount Net Capability Changes (MW) List any changes to the summer and winter net capabilities of the unit. To show a decrease in the gross capabilities use negative number (e.g., -200 is a decrease of 200 MW). Report owned portion of a jointly owned unit. Consult with the Primary Owner/Operator in determining this amount Notes Enter any clarifications about the unit. FRCC Form 1.1 Planned and Prospective Generating Facility Additions and Changes All data on this form is for additions and changes that are to occur after December 31 st of the year just ended prior to the reporting year.

10 Page 10 of Owning Entity The entity entering in the data for the unit is assumed to be the owning entity. If this assumption is incorrect, please contact FRCC. See Attachment A for acronyms Operating Entity List the name of the entity that operates the unit. See Attachment A for acronyms Plant Name List the power plant name Unit Number List the number, or number and code for the unit Location List the county where the plant is located. If the plant is located outside of the Florida, also list the state abbreviation where the plant is located Unit Type List the unit type using the corresponding code. See Attachment B for code explanation Ownership See Attachment C for code explanation Primary Fuel Type List the primary fuel type using the corresponding code. See Attachment D for code explanation Primary Fuel Transportation Method List the principal method of transporting the primary fuel to the plant site using the corresponding code. See Attachment E for code explanation Alternate Fuel Type List the alternate fuel type, if applicable, using one of the corresponding code. See Attachment D for code explanation Alternate Fuel Transportation Method List the principal method, if applicable, of transporting the alternate fuel to the plant site, using the corresponding code. See Attachment E for code explanation.

11 Page 11 of Alternate Fuel Storage (Days Burn) List the number of days the generator can run under peak summer conditions using the available on-site alternate fuel, based on one of the following parameters for each unit: Capacity Factor Base Load Unit: 50% Intermediate Load Unit: 20% Peaking Load Unit: 5% Load Flow Model Identification Input the model bus number and model unit number for the unit. This may be obtained from the reporting company s transmission planning department, or the FRCC. Also enter the EIA plant and operator generator code Commercial In-Service Date List the commercial in-service month (MM) and year (YYYY) of the new unit Construction Start Date List the construction start month (MM) and year (YYYY) Gross Capability (MW) List the summer and winter gross capabilities of the unit Net Capability (MW) List the summer and winter net capabilities of the unit Construction Status List the unit status using the corresponding code. See Attachment D for code explanation Notes Enter any clarifications about the unit. FRCC Form 1.1a Planned and Prospective Generation Changes and Additions (Print View Only) This Form is a view only Form that combines Forms 1.0a and 1.1 to show changes to existing generation and new generation plants to come in the future. The user can utilize this Form to verify their information on changes to their generation. The Form is also used to generate Forms in the Regional Load & Resource Plan. FRCC Form 2.0 Jointly-Owned Generator (JOU) Units This Form lists the all the owning entities and owning percentage of all jointly owned generator units. This should only be completed by the primary owning entity.

12 Page 12 of Power Plant Name List the name of the existing power plant. If this is a new plant, list the name in the second field labeled New Plant Unit Number List the number, or number and code for the unit Total Gross Capability (MW) List the total summer and winter gross capabilities of the unit. Do not enter just the reporting company's ownership share Total Net Capability (MW) List the total summer and winter net capabilities of the unit. Do not enter just the reporting company's ownership share Commercial In-Service Date List the commercial in-service month (MM) and year (YYYY) Entity Names List the names (acronyms) of all of the owners of the unit. See Attachment A for acronyms % Ownership List the percent ownership for each of the owners of the unit. FRCC Form 3.0 Existing Non-Utility, QF, and Self-Service Generation Facilities All data entered in this schedule is as of December 31 st of the year ended just prior to the current reporting year Owning Entity The entity entering in the data for the unit is assumed to be the owning entity (or the purchasing company of a co-generator or other Non-Utility Generator (NUG)). If this assumption is incorrect, please contact FRCC. See Attachment A for acronyms Operating Entity List the name of the entity that operates the unit. If the reporting company is a utility, and is purchasing from a co-generator or other NUG, enter the co-generator or NUG s name here. See Attachment A for acronyms Facility Name List the name of the NUG facility.

13 Page 13 of Unit Number List the number, or number and code for the unit Location List the county where the plant is located. If the plant is located outside of the Florida, also list the state abbreviation where the plant is located Unit Type List the unit type, using the corresponding code. See Attachment B for code explanation Primary Fuel Type List the primary fuel type, using the corresponding code. See Attachment D for code explanation Alternate Fuel Type List the alternate fuel type, if applicable, using one of the codes in the fuel code list for primary fuel type See Attachment D for code explanation Potential Export to Grid at Time of Seasonal Peak (MW) Firm (MW): For each NUG, list the firm potential summer and winter seasonal capacities to be delivered to the purchasing utility at the time of the utility's seasonal peak in MW. Uncommitted (MW): For each NUG, list the uncommitted potential summer and winter seasonal capacities that could be delivered to the purchasing utility at the time of the utility's seasonal peak in MW Commercial In-Service Date List the commercial in-service month (MM) and year (YYYY) Retirement Date List the retirement month (MM) and year (YYYY). Leave this field blank if the retirement date is not known Gross Capability (MW) List the summer and winter gross capabilities of the unit Net Capability (MW) List the summer and winter net capabilities of the unit Unit Status

14 Page 14 of 38 List the existing unit status, using one of the corresponding codes. See Attachment F for code explanation Contract Status List the contract status, using one of the following codes: C Under contract for the delivery of firm energy and/or capacity to the reporting utility NC No firm contract for the delivery of firm energy and/or capacity to the reporting utility Ownership List the ownership type, using the corresponding code. See Attachment C for code explanation. FRCC Form 3.1 Planned and Prospective Non-Utility, QF, and Self-Service Generation Facilities This Form is for additions and changes that are to occur after December 31 st of the year just ended prior to the reporting year Owning Entity The entity entering in the unit data is assumed to be the owning entity (or the purchasing company of a co-generator or other Non-Utility Generator (NUG)). If this assumption is incorrect, please contact FRCC. See Attachment A for acronyms Operating Entity List the name of the entity that operates the unit. If the reporting company is a utility, and is purchasing from a co-generator or other NUG, enter the co-generator or NUG s name. See Attachment A for acronyms Facility Name List the name of the NUG facility Unit Number List the number, or number and code for the unit Location List the county where the plant is located. If the plant is located outside of the Florida, also list the state abbreviation where the plant is located Unit Type List the unit type, using the corresponding code. See Attachment B for code explanation.

15 Page 15 of Primary Fuel Type List the primary fuel type, using the corresponding code. See Attachment D for code explanation Alternate Fuel Type List the alternate fuel type, if applicable, using one of the codes in the fuel code list for primary fuel type. See Attachment D for code explanation Potential Export to Grid at Time of Seasonal Peak (MW) Firm (MW): For each NUG, list the firm potential summer and winter seasonal capacities to be delivered to the purchasing utility at the time of the utility's seasonal peak in MW. Uncommitted (MW): For each NUG, list the uncommitted potential summer and winter seasonal capacities that could be delivered to the purchasing utility at the time of the utility's seasonal peak in MW Effective Change Date List the date the change will be going into effect (MM) and year (YYYY) (i.e., this can be a commercial in-service date, retirement date, etc.) Gross Capability (MW) List the summer and winter gross capabilities of the unit. If this is a change to an existing unit, enter the planned change in capacity (e.g., a capacity decrease of five megawatts would be listed as -5MW) Net Capability (MW) List the summer and winter net capabilities of the unit. If this is a change to an existing unit, enter the planned change in capacity (e.g., a capacity decrease of five megawatts would be listed as -5MW) Unit Status List the 'proposed' unit status, using the corresponding code. See Attachment F for code explanation Contract Status List the contract status, using one of the following codes: C Contract in place CC Contract change NC No contract R Retirement (of physical unit)

16 Page 16 of Ownership List the ownership type using the corresponding code. See Attachment C for code explanation. FRCC Form 4 (Parts 1 and 2) History and Forecast of Energy Consumption and Number of Customers by Customer Class The column numbers referred to in this section are the columns numbers in the Form not the column numbers in the view/print mode. Use whole number integer values in this Form (i.e., no decimals) Year Part 1: Time period is ten years of historical data. Part 2: Time period is ten years of forecast data Population In Column 2, list the population that is served or will be served in the reporting company s control area Rural and Residential (GWh) In Column 3, list the total energy sales to rural and residential customers, then in Column 4, list the average annual number of rural and residential customers. The average annual energy usage per rural and residential customer will be calculated for the output Form Commercial (GWh) In Column 5, list the total energy sales to commercial customers, then in Column 6, list the average annual number of commercial customers. The average annual energy usage per commercial customer will be calculated for the output Form Industrial (GWh) In Column 7, list total energy sales to industrial customers, then in Column 8, list the average annual number of industrial customers. The average annual energy usage per industrial customer will be calculated for the output Form Street and Highway Lighting (GWh) In Column 9.1, list the total energy sold for street and highway lighting Other Sales (GWh) In Column 10, list the total energy sales to governmental accounts such as military bases, sport fields, etc. where such sales are made pursuant to a special rate schedule Wholesale Purchases for Resale (GWh) In Column 11, list total wholesale energy purchases made under a Partial or Full Requirements tariff Wholesale Sales for Resale (GWh)

17 Page 17 of 38 In Column 12, list total wholesale energy sales to wholesale customers for resale made under a Partial or Full Requirements tariff Utility Use and Losses (GWh) This is the balance of the Net Energy for Load (NEL) account. Unbilled sales should be included in this column Net Energy for Load (GWh) The Net Energy for Load is a calculated field. This number should match the Net Energy for Load that appears on FRCC Forms 7.0, 8.0, and 9.1. FRCC Forms 5.0 and 6.0 History and Forecast of Summer/Winter Peak Demand (MW) Form 5.0 is for the entry of summer data and Form 6.0 is for the entry of winter data. Use whole number integer values in this Form (i.e., no decimals) Year Data for the specified years and seasons is to be entered, starting with two historical years of data Net Firm Peak Demand (MW) Enter the seasonal Net Firm Peak Demand. This is a 60-minute net integrated peak value Interruptible Load (MW) This is the energy reduction due to the controllable interruptible load for each year was used in the historical years, or will be made available for use in forecasted years Residential Load Management (MW) This is the energy reduction due to controllable Residential load management for each year that was used in historical years, or will be made available for use in forecasted years Commercial/Industrial Load Management (MW) This is the energy reduction due to controllable Commercial/Industrial load management for each year that has been used in the historical years, or will be available made for use in the forecasted years QF Load Served By QF Generation (MW) The QF load served by the qualifying facility (QF) generators in the reporting company s control area at the time of the peak Cumulative Residential & Commercial/Industrial Conservation Since 1980 (MW) Enter the cumulative load reduction at the time of the peak due to residential conservation programs and commercial/industrial conservation programs for the two historical years. Use a starting year of 1980 to calculate the accumulation.

18 Page 18 of Incremental Residential & Commercial/Industrial Conservation (MW) Enter the incremental load reduction at the time of the peak due to residential conservation programs for the year and the incremental load reduction at the time of the peak due to commercial/industrial conservation programs. FRCC Forms 5.1, 5.2 and 6.1, 6.2 Forms for Partial or Full Requirements Reporting If the reporting entity generates its own system requirements and does not purchase or sell Partial or Full Requirement wholesale power, do not fill out these Forms. Form 5.x is for the entry of summer data and Forms 6.x is for the entry of winter data. If the reporting entity supplies wholesale power (Partial or Full Requirement power) to other entities, fill out FRCC Forms 5.1 and 6.1. If the reporting entity purchases wholesale power (Partial or Full Requirement power) from other entities, fill out FRCC Forms 5.2 and 6.2. Partial requirement and full requirement sales or purchases should be listed on the forms by the abbreviated entity name, not by individual delivery point. Use whole number integer values in this Form (i.e., no decimals) Year Data for the specified years and seasons is to be entered, starting with two historical years of data Net Firm Demand (MW) This is the entities firm demand forecast. This column is pulled from the Net Firm Peak Demand column on FRCC Forms 5.0 and Net Firm Retail Peak Demand (MW) Column (2) - Summation of Columns 4 through Full Or Partial Requirement Wholesale Delivery (MW) Columns 4 through 15 should be filled to indicate the wholesale Partial or Full Requirement sales (Forms 5.1 & 6.1)/purchases (Forms 5.2 & 6.2) to/from other entities which are included in the official forecast. For aggregation purposes, only purchases from/sales to FRCC Members (Entities) who enter data into the LRDB are required; all other non-reporting entities are NOT to be broken out, i.e., only report sales to/purchases from entities that are listed in the dropdown box. See Attachment A for acronyms. FRCC Form 7.0 History and Forecast of Annual Net Energy for Load (GWh) Use whole number integer values in this Form (i.e., no decimals).

19 Page 19 of Year Data for the specified years is to be entered, starting with two historical years of data Net Energy For Load (GWh) Enter the calendar year s Net Energy for Load for the reporting company s control area. For the historical years, this should be the Net Energy for Load the company actually served for the calendar year. This data will automatically appear in the second column of FRCC Forms 7.1 and Interruptible Load (GWh) This is the energy reduction due to the controllable interruptible load for each year was used in the historical years, or will be made available for use in forecasted years Residential Load Management (GWh) This is the energy reduction due to controllable Residential load management for each year that was used in historical years, or will be made available for use in forecasted years Commercial/Industrial Load Management (GWh) This is the energy reduction due to controllable Commercial/Industrial load management for each year that has been used in the historical years, or will be available made for use in the forecasted years QF Load Served By QF Generation (GWh) The qualifying facility (QF) load served by qualifying facility generators in the reporting company s control area for the calendar year. For the historical years, enter actual data only Cumulative Residential & Commercial/Industrial Conservation Since 1980 (GWh) Enter the cumulative energy reduction at the time of the peak due to residential conservation programs and commercial/industrial conservation programs for the two historical years. Use a starting year of 1980 to calculate the accumulation Incremental Residential & Comm./Industrial Conservation (GWh) Enter the incremental energy reduction for the calendar year due to residential and commercial/industrial conservation programs. For the historical years, enter the conservation actually achieved. FRCC Form 7.1 and 7.2 Annual Net Energy for Load and its Components Supplying/Purchasing Entity If the reporting entity generates its own system requirements and does not purchase or sell Partial or Full Requirement wholesale power, do not fill out these Forms. If the reporting entity supplies wholesale power (Partial or Full Requirement power) to other entities, fill out FRCC Form 7.1.

20 Page 20 of 38 If the reporting entity purchases wholesale power (Partial or Full Requirement power) from other entities, fill out FRCC Form 7.2. Partial requirement and full requirement sales or purchases should be listed on the forms by the abbreviated entity name, not by individual delivery point. Use whole number integer values in this Form (i.e., no decimals) Year Data for the specified years is to be entered, starting with two historical years of data Net Energy For Load Energy (GWh) For the historical years, this is the Net Energy for Load actually served for the calendar year. This data is taken from FRCC Form 7.0, and automatically appears in the second column of FRCC Form 7.1 and Full Or Partial Requirement Wholesale Delivery (GWh) Columns 4 through 15 should be filled to indicate the wholesale Partial or Full Requirement sales (Form 7.1)/purchases (Form 7.2) to/from other entities which are included in the official forecast. For aggregation purposes, only purchases from/sales to FRCC Members (Entities) who enter data into the LRDB are required; all other non-reporting entities are NOT to be broken out, i.e., only report sales to/purchases from entities that are listed in the dropdown box. See Attachment A for acronyms. FRCC Form 8.0 Part 1 Previous Year Peak Demand (MW) and Net Energy for Load (GWh) by Month Use whole number integer values in this Form (i.e., no decimals) Actual Total Peak Hour Demand (MW) This is the maximum integrated clock hour sum of the demands of all customers that a system serves, plus the losses incidental to that service. It is automatically calculated on this Form according to the following formula: Total Peak Hour Demand = Actual Peak Hour Demand + Load Management + Interruptible + QF Load Served by QF Generation at Peak Interruptible Implemented At Peak (MW) Show the amount of interrupted load that was activated during the peak Residential Load Management Implemented at Peak (MW) Show the amount of residential interruptible load that was activated during the peak Comm./Ind. Load Management Implemented at Peak (MW) Show the amount of commercial and or industrial interruptible load that was activated during the peak.

21 Page 21 of QF Load Actually Served By QF Gen At Peak (MW) Show the QF load served by QF generation during the peak period Actual Peak Hour Demand (MW) Show the firm peak hour demand that was actually experienced Day Of Peak (DD) Enter the day the peak occurred for each month Time Of Peak (Hour Ending) Enter the Hour Ending (H.E.) that the peak occurred on the peak day for each month. As an example, if the peak occurred between 2:00 p.m. (1400) and 3:00 p.m. (1500), the hour ending time would be Actual Net Energy For Load (GWh) Show the Net Energy for Load experienced for each month. FRCC Form 8.0 Part 2 and 3 Reporting Year (Part 2) and Next Year (Part 3) Peak Demand (MW) and Net Energy for Load (GWh) by Month Use whole number integer values in this Form (i.e., no decimals) Total Peak Hour Demand (MW) This is the maximum integrated clock hour sum of the demands of all customers that a system serves, plus the losses incidental to that service. Total Peak Hour Demand = Firm Peak Hour Demand + Load Management + Interruptible + QF Load Served by QF Gen at Peak Load Management (MW) Show the total amount of controllable residential and commercial/industrial load management available during the peak Interruptible (MW) Show the amount of interruptible load available during the peak QF Load Served By QF Generation At Peak (MW) Show the QF load expected to be served by QF generation during the peak period Firm Peak Hour Demand (MW) Show the firm peak hour demand. Firm Peak Hour Demand = Total Peak Hour Demand - Load Management - Interruptible - QF Load Served Load Served by QF Gen at Peak Net Energy For Load (GWh) Show the net energy for load forecast for each month.

22 Page 22 of 38 FRCC Form 8.1 Previous Year Actual and Two Year Forecast of Peak Demand (MW) and Net Energy for Load (GWh) by Month Served to Wholesale Purchasers To be completed only by those utilities that are suppliers to wholesale purchasers. To add a purchasing entity, click on Add Purchaser on the yellow menu bar. Add as many purchasing entities as necessary. For aggregation purposes, only sales to FRCC Members (Entities) who enter data into the LRDB are required; all other non-reporting entities are NOT to be broken out, i.e., only report sales to entities that are listed in the dropdown box. Use whole number integer values in this Form (i.e., no decimals). See Attachment A for acronyms Actual (Previous Year): Peak Hour Demand (MW) This is the actual monthly 60-minute net integrated demand of purchaser component of the system peak demand for previous year actual. Use whole number integer values. Actual Wholesale Energy Sales (GWh) This is the monthly wholesale energy sale component of the system to serve this purchaser for the previous year actual. Use whole number integer values Forecast (Reporting Year): Forecast (Next Year): Peak Hour Demand (MW) 5Monthly 60-minute net integrated demand of this purchaser component of the system firm peak demand for the current year forecast. Use whole number integer values. Wholesale Energy Sales (GWh) Monthly wholesale energy sale forecast component of the system to serve this purchaser for the current next year. Use whole number integer values. Peak Hour Demand (MW) Monthly 60-minute net integrated demand of this purchaser component of the system firm peak demand for next year s forecast. Use whole number integer values. Wholesale Energy Sales (GWh) Monthly wholesale energy sale forecast component of the system to serve this purchaser for next year forecast. Use whole number integer values.

23 Page 23 of 38 FRCC Form 9.0 Fuel Requirements Use whole number integer values in this Form (i.e., no decimals) Nuclear List the BTU's, in trillion BTU, consumed or expected to be produced for electrical generation for the one historical and ten forecast calendar years Coal List the tons of coal in thousands consumed or expected to be consumed by generating facilities during the one historical and ten forecast calendar years for the reporting entity Residual List the barrels of residual oil, in thousands, consumed or expected to be consumed by generating facilities, by generator type, during the one historical and ten forecast calendar years for the reporting entity. Include diesel generator consumption with CTs Distillate List the barrels of distillate oil, in thousands, consumed or expected to be consumed by generating facilities, by generator type, during the one historical and ten forecast calendar years for the reporting entity. Include diesel generator consumption with CTs Natural Gas List the amount of natural gas, in 1000 MCF, consumed or expected to be consumed by generating facilities, by generator type, during the one historical and ten forecast calendar years for the reporting entity Other Specify the type and amount of any other fuel consumed or expected to be consumed by generating facilities during the one historical and ten forecast calendar years. Indicate the type(s) of fuel(s) in the text box, along with the desired Unit of Measure (e.g., BTU, Tons, BBL, MCF, etc.). FRCC Form 9.1 Energy Sources (GWh) Use whole number integer values in this Form (i.e., no decimals) Annual Net Firm Inter-Region Interchange Enter the entity's net calendar year firm inter-region interchange from outside the FRCC Region. This number will be negative if the utility is a net exporter Nuclear Through Hydro Enter the total calendar year net energy produced, by unit and fuel type. Include diesel units in CT Other

24 Page 24 of 38 Identify and enter the total calendar year net energy produced by other sources. FRCC Form 9.2 Energy Sources (%) (Print View Only) This Form is view only and needs no additional information. The Form is used in the Fuels section of the Regional Load & Resource Plan, and is based upon data entered into Form 9.1. FRCC Form 10.0 and 10.1 Forecast of Capacity, Demand, and Reserve Margin at Time of Summer Peak (Form 10.0) and Winter Peak (Form 10.1) These Forms are view only and need no additional information. Form 10.0 pertains to summer and Form 10.1 pertains to winter. These two Forms are included in the composition of Form 10. The Regional Form 10 is the aggregate of all reporting members of the FRCC region and can be found in the Generating Facilities section of the Regional Load & Resource Plan Column 2 - Installed Capacity (MW) Installed capacity begins with seasonal summation of all generation listed in Form 1.0 which has a status of OP (status codes of SB or OS are not included in the aggregation), and seasonally adjusted by entries in Forms 1.0a and 1.1. See Attachment F for definitions of the status codes mentioned above. Seasonal Adjustments Summer: For any generation additions to impact summer capacities, they must have an effective date less than or equal to June 1 st. Any subtractions that have an effective change date less than or equal to August 31 st will be taken into account for the entire summer. Winter: For any generation additions to impact winter capacities, they must have an effective date less than or equal to January 1 st. Any subtractions that have an effective change date less than or equal to March 1 st will be taken into account for the entire winter Column 3 - Net Contracted Firm Interchange (MW) This capacity comes from imports (purchases) from outside the FRCC Region into the entity s area, as listed on Forms 11.0 and 11.1, and contracts (Form 12.0). Carefully address the appropriate fields involving firm contracts in Form. These fields are designed to eliminate the potential for double counting resources that may have already been listed in the NUG section (Forms 3.0 and 3.1) and/or in the Regional imports (Forms 11.0 and 11.1) Column 4 - Projected Net Firm to Grid from NUG (MW) Capacities are the summation of NUGs (Forms 3.0 and 3.1) Column 5 - Total Available Capacity (MW) This capacity is the summation of Columns 2, 3, and Column 6 - Total Peak Demand (MW)

25 Page 25 of 38 The Total Peak Demand is the summation of Net Firm Demand plus Load Management (LM) plus Interruptible Loads (INT). For Form 10.0, these components of Total Peak Demand are listed on Form 5.0. For Form 10.1, these components of Total Peak Demand are listed on Form 6.0. Total Peak Demand = Net Firm Demand + LM + INT Column 7 - Reserve Margin w/o Exercising LM/INT (MW) This is the difference between Total Available Capacity and Total Peak Demand. Col 7 = Col 5 - Col Column 8 - Reserve Margin w/o Exercising LM/INT (%) This is the Reserve Margin (MW) expressed as a percentage of Total Available Capacity (based on Total Peak Demand). Col 8 = Col 7 / Col Column 9 - Firm Peak Demand (MW) The Firm Peak Demand is the Total Peak Demand minus Load Management (LM) minus Interruptible Loads (INT). For Form 10.0, this is the Summer Net Firm Peak Demand as listed on Form 5.0. For Form 10.1, this is the Winter Net Firm Peak Demand as listed on Form 6.0. Firm Peak Demand = (Total Peak Demand) LM - INT Column 10 - Reserve Margin with Exercising LM/INT (MW) This is the difference between Total Available Capacity and Firm Peak Demand. Col 10 = Col 5 Col Column 11 - Reserve Margin with Exercising LM/INT (%) This is the Reserve Margin (MW) expressed as a percentage of Total Available Capacity (based on Firm Peak Demand). Col 11 = Col 10 / Col 9 Note: Reserve Margin should be equal to or greater than 20% for all IOUs, and equal to or greater than 15% for all others. TAL carries 17%. FRCC Form 11 Parts 1 & 2 Contracted Firm Summer (Part 1)/Winter (Part 2) Imports and Exports from/to Outside the FRCC Region at Time of Peak Use whole number integer values in this Form (i.e., no decimals) Suppliers (Imports) (MW) List the total firm capacity import to the reporting utility from outside the FRCC Region at the time of summer peak. Enter the acronym of each Supplier in the blanks at the top of the column, using capital letters. See Attachment A for acronyms.

26 Page 26 of Purchasers (Exports) (MW) List the total firm capacity export from the reporting utility to outside the FRCC Region at the time of summer peak. Enter the acronym of each Purchaser in the blanks at the top of the column, using capital letters. See Attachment A for acronyms Total Imports (MW) This is the total firm capacity imported to the reporting utility from outside the FRCC Region. This field is calculated using the information the user enters in the supplier fields Total Exports (MW) The total firm capacity exported from the reporting utility to outside the FRCC Region. This field is calculated using the information the user enters in the purchasers fields Net Interchange (MW) This is a calculated field that uses the following formula: Net Interchange = Total Imports - Total Exports FRCC Form 12 Summary of Firm Capacity and Energy Contracts Purchasing Entity List the acronym of the purchasing entity. This is the entity that will be purchasing the firm power. See Attachment A for acronyms Selling Entity List the acronym of the selling entity. This is the entity that will be selling the firm power. See Attachment A for acronyms Net Capability (MW) List the total net capability (capacity) to be purchased or sold at time of seasonal peak. If the amount of capacity of the contract changes from year to year, then the user entering this information will have to create a separate contract for each year where there is a variation (use the "Add Contract" function on the yellow menu bar to create a separate contract for). To ensure that there is no double counting of the capacity from year to year the user must verify that the dates do not overlap with one another. Then, note this in the Description block Contract Term List the month, day, and year in which the scheduled interchange is to commence and end. For the purpose of this Form, scheduled interchange is defined as the purchase or sale of firm capacity and energy pursuant to a FERC approved schedule or contract, including unit power purchases and sales. A beginning and an ending date must be entered or the data will not be accepted.

27 Page 27 of Fuel Type List the primary and alternate fuel types, using the corresponding codes. See Attachment D for code explanation Description Identify the type of scheduled interchange involved. Identify whether the load from each contract is included as part of the Firm Peak Demand listed on the FRCC Forms 5.0, 6.0, and 7.0. Provide any additional information deemed necessary to describe how each contract should be included in the entity's Reserve Margin calculation. The description listed will be published in the L&RP If this is a sale for your company, how are you including in your firm peak demand: This information will be used to determine how each contract is included in the Firm Peak Demand. If any additional information is needed to clarify how this contract should be included in the summer and winter Reserve Margin calculation, use as much space as necessary in the Description section of this Form If this is a purchase for your company, how much of it are you including in your total available resources? This information will be used to determine how each contract is included in the Total Available Capacity. If any additional information is needed to clarify how this contract should be included in the summer and winter Reserve Margin calculation, use as much space as necessary in the Description section of this Form. It is essential that this information is provided to ensure proper accounting for this capacity on FRCC Forms 10.0 and Is this contract included on your import or export form? Again, this eliminates double counting on FRCC Forms 10.0 and Use the Description section to elaborate, if necessary Did you include this contract as a unit on FRCC Forms 3.0 or 3.1? If this contract has been included as a unit on FRCC Forms 3.0 or 3.1 providing "Firm Potential Export to Grid at Time of Peak", this box must be checked so the capacity is not double counted in the Reserve Margin calculations on FRCC Forms 10.0 and FRCC Form 13 Summary and Specifications of Proposed Transmission Lines This Form is for all transmission line additions at 100kV and above projected for the ten-year period Primary / Secondary Line Ownership If the transmission line will be jointly-owned, enter company name for each owner. Otherwise, enter name of your Company and leave secondary field blank Primary / Secondary Line Ownership (%) If the transmission line will be jointly-owned, enter the percentages owned by each individual respondent. Otherwise, enter 100% for primary ownership and leave secondary percentage blank.

28 Page 28 of Originating Terminal Enter the name of the beginning terminal point of the line Terminating Terminal Enter the name of the ending terminal point of the line Line Length Ckt Miles Enter miles between originating and terminating terminal points of the line, regardless of the number of conductors or circuits carried Nominal Operating Voltage Enter the voltage at which the line is normally operated in kilovolts (kv) Nominal Design Voltage Enter the voltage at which the line was designed to operate in kilovolts (kv) Capacity Enter the normal load-carrying capacity of the line in millions of volt-amperes (MVA) Sited Under Specify if the line will be sited under the Power Plant Siting Act, Transmission Line Siting Act, or NA if not applicable Primary Driver(s) Choose one of the predefined drivers for each line addition. While it is understood that one line could serve multiple functions (i.e. reliability and economics), please specify the principal consideration/driver for this addition. Reliability Generation Integration (Choose one from below) - Variable/Renewable Integration - Nuclear Integration - Fossil-Fire Integration - Hydro Integration Economics or Congestion Other Status Apply a level of certainty for each line addition based on the following criteria: Under Construction - Construction of the line has begun Planned (any of the following) - Permits have been approved to proceed - Design is complete - Needed in order to meet a regulatory requirement Conceptual (any of the following)