Revised Public Utility Filing Requirements for Electric Quarterly Reports,

[Federal Register: January 10, 2008 (Volume 73, Number 7)]

[Notices]

[Page 1876-1889]

From the Federal Register Online via GPO Access [wais.access.gpo.gov]

[DOCID:fr10ja08-50]

DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

[Docket No. RM01-8-007]

Revised Public Utility Filing Requirements for Electric Quarterly Reports

December 21, 2007. AGENCY: Federal Energy Regulatory Commission, Department of Energy.

ACTION: Order No. 2001-H; Order on Rehearing and Clarification.

SUMMARY: In this order, the Federal Energy Regulatory Commission (Commission) grants in part, and denies in part, rehearing and clarifies the information to be reported in the Electric Quarterly Report's (EQR'S) fields for Contract Execution Date (Field No. 21), Contract Commencement Date (Field No. 22) and Rate Description (Field No. 37). In addition, the order corrects an error relating to Increment Name (Field Nos. 28 and 60).

DATES: This order becomes effective upon issuance. The revised definitions adopted in this order shall be applied to EQR filings beginning with the Q1 2008 EQR (due on April 30, 2008) and in subsequent EQR filings due thereafter.

FOR FURTHER INFORMATION CONTACT:

Michelle Veloso (Technical Information), Office of Enforcement, Federal Energy Regulatory Commission, 888 First Street, NE., Washington, DC 20426, (202) 502-8363.

Gary D. Cohen (Legal Information), Office of the General Counsel, Federal Energy Regulatory Commission, 888

[[Page 1877]]

First Street, NE., Washington, DC 20426, (202) 502-8321.

SUPPLEMENTARY INFORMATION:

Before Commissioners: Joseph T. Kelliher, Chairman; Suedeen G. Kelly, Marc Spitzer, Philip D. Moeller, and Jon Wellinghoff.

1. On October 24, 2007, Edison Electric Institute (EEI) filed a request for rehearing or clarification in response to the Commission's order adopting an Electric Quarterly Report (EQR) Data Dictionary.\1\ Order No. 2001-G collected in one document the definitions of certain terms and values used in filing EQR data (previously provided in Commission orders and in guidance materials posted at the Commission's website) and issued formal definitions for fields that were previously undefined.\2\ In this order, the Commission grants in part, and denies in part, rehearing and clarifies the information to be reported in Contract Execution Date (Field No. 21), Contract Commencement Date (Field No. 22) and Rate Description (Field No. 37). In addition, we correct an error that we made in Order No. 2001-G relating to Increment Name (Field Nos. 28 and 60).

\1\ Revised Public Utility Filing Requirements for Electric Quarterly Reports, Order No. 2001-G, 120 FERC ] 61,270 (Sep. 24, 2007), 72 FR 56735 (Oct. 4, 2007).

\2\ Id.

  1. Background

    2. On April 25, 2002, the Commission issued Order No. 2001, a Final Rule establishing revised public utility filing requirements.\3\ This rule revised the Commission's filing requirements to require companies subject to the Commission's regulations under section 205 of the Federal Power Act to file quarterly reports that: (1) Provide data identifying the utility on whose behalf the report is being filed (ID Data); (2) summarize pertinent data about the utility's currently effective contracts (Contract Data); and (3) summarize data about wholesale power sales the utility made during the reporting period (Transaction Data). The requirement to file EQRs replaced the requirement to file quarterly transaction reports summarizing a utility's market-based rate transactions and sales agreements that conformed to the utility's tariff.

    \3\ Revised Public Utility Filing Requirements for, Order No. 2001, 67 FR 31043, FERC Stats. & Regs. ] 31,127 (2002), reh'g denied, Order No. 2001-A, 100 FERC ] 61,074, reconsideration and clarification denied, Order No. 2001-B, 100 FERC ] 61,342, order directing filings, Order No. 2001-C, 101 FERC ] 61,314 (2002), order directing filings, Order No. 2001-D, 102 FERC ( 61,334, order refining filing requirements, Order No. 2001-E, 105 FERC ] 61,352 (2003), clarification order, Order No. 2001-F, 106 FERC ] 61,060 (2004).

    3. In Order No. 2001, the Commission also adopted a new section in its regulations, 18 CFR 35.10b, which requires that the EQRs are to be prepared in conformance with the Commission's software and guidance posted and available from the Commission website. This obviates the need to revise section 35.10b to implement revisions to the software and guidance. Since the issuance of Order No. 2001, as need has arisen, the Commission has issued orders to resolve questions raised by EQR users and has directed Staff to issue additional guidance.\4\

    \4\ Examples cited in EQR Notice at P 3.

    4. On September 24, 2007, the Commission issued Order No. 2001-G, providing a data dictionary to clarify the information to be reported in EQR data. EEI filed a request for rehearing or clarification requesting clarification of a few specific items. In addition, on December 4, 2007, TransAlta filed comments alerting the Commission to a filing problem it was experiencing relating to Increment Name (Field Nos. 28 and 60). The discussion below addresses EEI's rehearing request and TransAlta's comments.

  2. Discussion

    1. Field No. 21--Contract Execution Date

      5. The EQR Notice \5\ proposed only a slight change to the Order No. 2001 definition for Contract Execution Date: ``The date the contract was signed. If the parties signed on different dates, or there are contract amendments, use the most recent date signed.''

      \5\ Notice Seeking Comments on Proposed Electric Quarterly Report Data Dictionary, FERC Stats. & Regs. ] 35,050 (2007), 72 FR 26091 (May 8, 2007).

      6. In response to the EQR Notice, Reliant and EEI suggested that the Contract Execution Date should not change because of a minor amendment to the contract. Both commenters noted that, frequently, contract amendments are minor changes, such as changes in an address or in payment terms, that do not affect the key operational parameters of the agreement.

      7. Based on these comments, the Commission found in Order No. 2001- G that the usefulness of the data may be increased with a single execution date for each contract across all periods. However, the order explained that, if there are material amendments to the contract, then the Contract Execution Date must be changed.

      8. In EEI's request for rehearing, it argues that the Commission's instruction that the Contract Execution Date must be changed when there are material amendments to the contract is confusing and burdensome. It suggests that the original execution date should be reported for the duration of the contract and argues that changes in the contract will be reflected in the descriptions of revised contract provisions, such as in the Rate (Field No. 34), Begin Date (Field No. 43) and End Date fields (Field No. 44). Commission Conclusion

      9. In Order No. 2001-G, the Commission agreed with EEI and Reliant that it need not change the Contract Execution Date each time there is a minor revision to the contract and, accordingly, modified the instructions on what information should be reported in this field. The Commission reduced the burden and confusion by clarifying that minor, non-material changes may be omitted for the purpose of identifying the Contract Execution Date. EEI argues that the Contract Execution Date should not be revised, even in instances where there has been a material amendment to the contract.

      10. The Commission recognizes the benefits of classifying a contractual relationship based on when it originated and will revise the definition of Contract Execution Date as EEI suggests to require companies to report the original date the contract was executed, without regard to any subsequent revisions to the contract. For the purposes of the EQR Data Dictionary, the definition will read: ``The date the contract was signed. If the parties signed on different dates, use the most recent date signed.'' However, this change will not be incorporated at the cost of obscuring information that would alert EQR users that key terms in the contract have been revised. Thus, the Commission will revise the definition of Contract Commencement Date as described below.

    2. Field No. 22--Contract Commencement Date

      11. In order to alert EQR users that a contract has been revised, the Commission will revise the definition of Contract Commencement Date to refer to the date that service commenced under the current terms and conditions of the contract. The Commission will further clarify that the terms deemed relevant for determining or changing the Contract Commencement Date are those that are reported in the Contract Data section of the EQR.\6\ Any amendment

      [[Page 1878]]

      that would cause a change in these required data elements would require a change in the Contract Commencement Date.

      \6\ In developing the EQR, the Commission identified a number of key terms associated with the products and services offered under any given jurisdictional contract. These terms include: Class Name, Term Name, Increment Name, Increment Peaking Name, Increment Peaking Name, Product Type Name, Product Name, Rate (actual, maximum, minimum or description), and Time Zone. The Commission requires that Class Name, Term Name, Increment Name, Increment Peaking Name, Product Type Name, Product Name, and Time Zone be reported in the EQR for every product offered under every jurisdictional contract. Additionally, the Commission requires a definition of the rate for every product either as a Rate, a Rate Minimum, a Rate Maximum or a Rate Description. Finally, the Commission requires that companies report, when specified in the contract for a given product, Quantity, Units, Rate Units, Point of Receipt Control Area, Point of Receipt Specific Location, Point of Delivery Control Area, Point of Delivery Specific Location, Begin Date, and End Date.

      12. The Commission recognizes EEI's concern regarding potential inconsistency between the EQR and eTariff in identifying an original execution date. However, there is a very real public interest in identifying when key terms of the contract were determined. As market conditions change over time, it is imperative to be able to sort the deals that occurred years ago from those that were confirmed more recently. To better understand the market conditions at the time a contract was put in place, it is necessary to document the date that key terms were established.

      13. The Commission will define Contract Commencement Date as ``The date the terms of the contract reported in the EQR were effective. If the terms reported in the Contract Data section of the EQR became effective or if service under those terms began on multiple dates (i.e.: due to an amendment), the date to be reported as the Commencement Date is the date when service began pursuant to the most recent amendment to the terms reported in the Contract Data section of the EQR.'' In this way, the Commission and the public will continue to be able to determine when the contract terms reported in the EQR were determined.

    3. Field Nos. 28 and 60--Increment Name

      14. In the EQR Notice,\7\ the Commission proposed to revise Field Nos. 28 and 60 to, among other matters, create an Increment Name covering ``Seasonal'' sales to characterize power sales made for longer than one month, but less than a year.\8\ This proposal was opposed in comments filed by EEI, Reliant and Occidental. In Order No. 2001-G, the Commission agreed with the commenters that the term ``S--Seasonal'' should not be included in the options available for the Increment Name fields. However, in the issued Order No. 2001-G, when the term ``Seasonal'' was dropped from the Data Dictionary, the interval to be included in ``Monthly'' should have been adjusted in the attached Data Dictionary, so there would be no gap between ``Monthly'' and ``Annual.'' Unfortunately, this correction was inadvertently omitted.

      \7\ Revised Public Utility Filing Requirements for Electric Quarterly Reports, 72 Fed. Reg. 26091 (May 8, 2007), FERC Stats. & Regs. ] 35,050 (2007) (EQR Notice).

      \8\ EQR Notice at P. 18.

      15. On December 4, 2007, TransAlta filed comments alerting the Commission to this problem. Commission Conclusion

      16. We will take this opportunity to correct the inadvertent error in Order No. 2001-G involving Increment Name, so that filers can accurately report their sales covering a period of more than 168 consecutive hours up to one year as M-Monthly (>168 consecutive hours and (Seller)--An identifier (e.g., ``FS1'', Identifier.

      (where ``'' is an

      containing Seller identification integer).

      information in a comma-delimited (csv) file that is imported into the EQR filing. One record for each seller company may be imported into an EQR for a given quarter. 1.......... Filer Unique [check].......... FA1.............. (Agent)--An identifier (i.e., ``FA1'') Identifier.

      used to designate a record containing Agent identification information in a comma-delimited (csv) file that is imported into the EQR filing. Only one record with the FA1 identifier may be imported into an EQR for a given quarter. 2.......... Company Name..... [check].......... Unrestricted text (Respondent)--The name of the company (100 characters). taking responsibility for complying with the Commission's regulations related to the EQR. 2.......... Company Name..... [check].......... Unrestricted text (Seller)--The name of the company that is (100 characters). authorized to make sales as indicated in the company's FERC tariff(s). This name may be the same as the Company Name of the Respondent. 2.......... Company Name..... [check].......... Unrestricted text (Agent)--The name of the entity completing (100 characters). the EQR filing. The Agent's Company Name need not be the name of the company under Commission jurisdiction. 3.......... Company DUNS for Respondent Nine digit number The unique nine digit number assigned by Number.

      and Seller.

      Dun and Bradstreet to the company identified in Field Number 2. 4.......... Contact Name..... [check].......... Unrestricted text (Respondent)--Name of the person at the (50 characters). Respondent's company taking responsibility for compliance with the Commission's EQR regulations. 4.......... Contact Name..... [check].......... Unrestricted text (Seller)--The name of the contact for the (50 characters). company authorized to make sales as indicated in the company's FERC tariff(s). This name may be the same as the Contact Name of the Respondent. 4.......... Contact Name..... [check].......... Unrestricted text (Agent)--Name of the contact for the (50 characters). Agent, usually the person who prepares the filing. 5.......... Contact Title.... [check].......... Unrestricted text Title of contact identified in Field (50 characters). Number 4. 6.......... Contact Address.. [check].......... Unrestricted text Street address for contact identified in Field Number 4. 7.......... Contact City..... [check].......... Unrestricted text City for the contact identified in Field (30 characters). Number 4. 8.......... Contact State.... [check].......... Unrestricted text Two character state or province (2 characters). abbreviations for the contact identified in Field Number 4.

      [[Page 1880]]

      9.......... Contact Zip...... [check].......... Unrestricted text Zip code for the contact identified in (10 characters). Field Number 4. 10......... Contact Country [check].......... CA--Canada....... Country (USA, Canada, Mexico, or United Name.

      MX--Mexico....... Kingdom) for contact address identified US--United States in Field Number 4. UK--United Kingdom. 11......... Contact Phone.... [check].......... Unrestricted text Phone number of contact identified in (20 characters). Field Number 4. 12......... Contact E-Mail... [check].......... Unrestricted text E-mail address of contact identified in Field Number 4. 13......... Filing Quarter... [check].......... YYYYMM........... A six digit reference number used by the EQR software to indicate the quarter and year of the filing for the purpose of importing data from csv files. The first 4 numbers represent the year (e.g., 2007). The last 2 numbers represent the last month of the quarter (e.g., 03 = 1st quarter; 06 = 2nd quarter, 09 = 3rd quarter, 12 = 4th quarter).

      Contract Data

      14......... Contract Unique [check].......... An integer

      An identifier beginning with the letter ID.

      proceeded by the ``C'' and followed by a number (e.g., letter ``C'' ``C1'', ``C2'') used to designate a (only used when record containing contract information in importing

      a comma-delimited (csv) file that is contract data) imported into the EQR filing. One record for each contract product may be imported into an EQR for a given quarter. 15......... Seller Company [check].......... Unrestricted text The name of the company that is authorized Name.

      (100 characters). to make sales as indicated in the company's FERC tariff(s). This name must match the name provided as a Seller's ``Company Name'' in Field Number 2 of the ID Data (Seller Data). 16......... Customer Company [check].......... Unrestricted text The name of the counterparty. Name.

      (70 characters). 17......... Customer DUNS [check].......... Nine digit number The unique nine digit number assigned by Number.

      Dun and Bradstreet to the company identified in Field Number 16. 18......... Contract

      [check].......... Y (Yes).......... The customer is an affiliate if it Affiliate.

      N (No)........... controls, is controlled by or is under common control with the seller. This includes a division that operates as a functional unit. A customer of a seller who is an Exempt Wholesale Generator may be defined as an affiliate under the Public Utility Holding Company Act and the FPA. 19......... FERC Tariff

      [check].......... Unrestricted text The FERC tariff reference cites the Reference.

      (60 characters). document that specifies the terms and conditions under which a Seller is authorized to make transmission sales, power sales or sales of related jurisdictional services at cost-based rates or at market-based rates. If the sales are market-based, the tariff that is specified in the FERC order granting the Seller Market Based Rate Authority must be listed. 20......... Contract Service [check].......... Unrestricted text Unique identifier given to each service Agreement ID.

      (30 characters). agreement that can be used by the filing company to produce the agreement, if requested. The identifier may be the number assigned by FERC for those service agreements that have been filed with and accepted by the Commission, or it may be generated as part of an internal identification system. 21......... Contract

      [check].......... YYYYMMDD......... The date the contract was signed. If the Execution Date.

      parties signed on different dates, use the most recent date signed. 22......... Contract

      [check].......... YYYYMMDD......... The date the terms of the contract Commencement

      reported in the EQR were effective. If Date.

      the terms reported in the Contract Data section of the EQR became effective or if service under those terms began on multiple dates (i.e.: due to an amendment), the date to be reported as the Commencement Date is the date when service began pursuant to the most recent amendment to the terms reported in the Contract Data section of the EQR. 23......... Contract

      If specified in YYYYMMDD......... The date that the contract expires. Termination Date. the contract. 24......... Actual

      If contract

      YYYYMMDD......... The date the contract actually terminates. Termination Date. terminated. 25......... Extension

      [check].......... Unrestricted text Description of terms that provide for the Provision

      continuation of the contract. Description. 26......... Class Name....... [check].......... ................. See definitions of each class name below. 26......... Class Name....... [check].......... F--Firm.......... For transmission sales, a service or product that always has priority over non- firm service. For power sales, a service or product that is not interruptible for economic reasons.

      [[Page 1881]]

      26......... Class Name....... [check].......... NF--Non-firm..... For transmission sales, a service that is reserved and/or scheduled on an as- available basis and is subject to curtailment or interruption at a lesser priority compared to Firm service. For an energy sale, a service or product for which delivery or receipt of the energy may be interrupted for any reason or no reason, without liability on the part of either the buyer or seller. 26......... Class Name....... [check].......... UP--Unit Power Designates a dedicated sale of energy and Sale.

      capacity from one or more than one specified generation unit(s). 26......... Class Name....... [check].......... N/A--Not

      To be used only when the other available Applicable.

      Class Names do not apply. 27......... Term Name........ [check].......... LT--Long Term.... Contracts with durations of one year or ST--Short Term... greater are long-term. Contracts with N/A--Not

      shorter durations are short-term. Applicable. 28......... Increment Name... [check].......... ................. See definitions for each increment below. 28......... Increment Name... [check].......... H--Hourly........ Terms of the contract (if specifically noted in the contract) set for up to 6 consecutive hours (6 and 60 and 168 consecutive hours and = 1 year). 28......... Increment Name... [check].......... N/A--Not

      Terms of the contract do not specify an Applicable.

      increment. 29......... Increment Peaking [check].......... ................. See definitions for each increment peaking Name.

      name below. 29......... Increment Peaking [check].......... FP--Full Period.. The product described may be sold during Name.

      those hours designated as on-peak and off- peak in the NERC region of the point of delivery. 29......... Increment Peaking [check].......... OP--Off-Peak..... The product described may be sold only Name.

      during those hours designated as off-peak in the NERC region of the point of delivery. 29......... Increment Peaking [check].......... P--Peak.......... The product described may be sold only Name.

      during those hours designated as on-peak in the NERC region of the point of delivery. 29......... Increment Peaking [check].......... N/A--Not

      To be used only when the increment peaking Name.

      Applicable.

      name is not specified in the contract. 30......... Product Type Name [check].......... ................. See definitions for each product type below. 30......... Product Type Name [check].......... CB--Cost Based... Energy or capacity sold under a FERC- approved cost-based rate tariff. 30......... Product Type Name [check].......... CR--Capacity An agreement under which a transmission Reassignment. provider sells, assigns or transfers all or portion of its rights to an eligible customer. 30......... Product Type Name [check].......... MB--Market Based. Energy or capacity sold under the seller's FERC-approved market-based rate tariff. 30......... Product Type Name [check].......... T--Transmission.. The product is sold under a FERC-approved transmission tariff. 30......... Product Type Name [check].......... Other............ The product cannot be characterized by the other product type names. 31......... Product Name..... [check].......... See Product Name Description of product being offered. Table, Appendix A. 32......... Quantity......... If specified in Number with up to Quantity for the contract product the contract. 4 decimals.

      identified. 33......... Units............ If specified in See Units Table, Measure stated in the contract for the the contract. Appendix E.

      product sold. 34......... Rate............. ................. Number with up to The charge for the product per unit as 4 decimals.

      stated in the contract. 35......... Rate Minimum..... One of four rate Number with up to Maximum rate to be charged per the fields (34, 35, 4 decimals.

      contract, if a range is specified. 36, or 37) must be included. 36......... Rate Maximum..... ................. Number with up to Maximum rate to be charged per the 4 decimals.

      contract, if a range is specified.

      [[Page 1882]]

      37......... Rate Description.

      Unrestricted text Text description of rate. If the rate is currently available on the FERC Web site, a citation of the FERC Accession Number and the relevant FERC tariff including page number or section may be included instead of providing the entire rate algorithm. If the rate is not available on the FERC Web site, include the rate algorithm, if rate is calculated. If the algorithm would exceed the 150 character field limit, it may be provided in a descriptive summary (including bases and methods of calculations) with a detailed citation of the relevant FERC tariff including page number and section. If more than 150 characters are required, the contract product may be repeated in a subsequent line of data until the rate is adequately described. 38......... Rate Units....... If specified in See Rate Units Measure stated in the contract for the the contract. Table, Appendix product sold. F. 39......... Point of Receipt If specified in See Balancing The registered NERC Balancing Authority Balancing

      the contract. Authority Table, (formerly called NERC Control Area) where Authority

      Appendix B.

      service begins for a transmission or (PORBA).

      transmission-related jurisdictional sale. The Balancing Authority will be identified with the abbreviation used in OASIS applications. If receipt occurs at a trading hub specified in the EQR software, the term ``Hub'' should be used. 40......... Point of Receipt If specified in Unrestricted text The specific location at which the product Specific

      the contract. (50 characters). is received if designated in the Location (PORSL).

      If ``HUB'' is contract. If receipt occurs at a trading selected for hub, a standardized hub name must be PORCA, see Hub used. If more points of receipt are Table, Appendix listed in the contract than can fit into C.

      the 50 character space, a description of the collection of points may be used. `Various,' alone, is unacceptable unless the contract itself uses that terminology. 41......... Point of Delivery If specified in See Balancing The registered NERC Balancing Authority Balancing

      the contract. Authority Table, (formerly called NERC Control Area) where Authority

      Appendix B.

      a jurisdictional product is delivered and/ (PODBA).

      or service ends for a transmission or transmission-related jurisdictional sale. The Balancing Authority will be identified with the abbreviation used in OASIS applications. If delivery occurs at the interconnection of two control areas, the control area that the product is entering should be used. If delivery occurs at a trading hub specified in the EQR software, the term ``Hub'' should be used. 42......... Point of Delivery If specified in Unrestricted text The specific location at which the product Specific

      the contract. (50 characters). is delivered if designated in the Location (PODSL).

      If ``HUB'' is contract. If receipt occurs at a trading selected for hub, a standardized hub name must be PODCA, see Hub used. Table, Appendix C. 43......... Begin Date....... If specified in YYYYMMDDHHMM..... First date for the sale of the product at the contract.

      the rate specified. 44......... End Date......... If specified in YYYYMMDDHHMM..... Last date for the sale of the product at the contract.

      the rate specified. 45......... Time Zone........ [check].......... See Time Zone The time zone in which the sales will be Table, Appendix made under the contract. D.

      Transaction Data

      46......... Transaction

      [check].......... An integer

      An identifier beginning with the letter Unique ID.

      proceeded by the ``T'' and followed by a number (e.g., letter ``T'' ``T1'', ``T2'') used to designate a (only used when record containing transaction information importing

      in a comma-delimited (csv) file that is transaction

      imported into the EQR filing. One record data).

      for each transaction record may be imported into an EQR for a given quarter. A new transaction record must be used every time a price changes in a sale. 47......... Seller Company [check].......... Unrestricted text The name of the company that is authorized Name.

      (100 Characters). to make sales as indicated in the company's FERC tariff(s). This name must match the name provided as a Seller's ``Company Name'' in Field 2 of the ID Data (Seller Data). 48......... Customer Company [check].......... Unrestricted text The name of the counterparty. Name.

      (70 Characters). 49......... Customer DUNS [check].......... Nine digit number The unique nine digit number assigned by Number.

      Dun and Bradstreet to the counterparty to the contract.

      [[Page 1883]]

      50......... FERC Tariff

      [check].......... Unrestricted text The FERC tariff reference cites the Reference.

      (60 Characters). document that specifies the terms and conditions under which a Seller is authorized to make transmission sales, power sales or sales of related jurisdictional services at cost-based rates or at market-based rates. If the sales are market-based, the tariff that is specified in the FERC order granting the Seller Market Based Rate Authority must be listed. 51......... Contract Service [check].......... Unrestricted text Unique identifier given to each service Agreement ID.

      (30 Characters). agreement that can be used by the filing company to produce the agreement, if requested. The identifier may be the number assigned by FERC for those service agreements that have been filed and approved by the Commission, or it may be generated as part of an internal identification system. 52......... Transaction

      [check].......... Unrestricted text Unique reference number assigned by the Unique

      (24 Characters). seller for each transaction. Identifier. 53......... Transaction Begin [check].......... YYYYMMDDHHMM (csv First date and time the product is sold Date.

      import).

      during the quarter. MMDDYYYYHHMM (manual entry). 54......... Transaction End [check].......... YYYYMMDDHHMM (csv Last date and time the product is sold Date.

      import).

      during the quarter. MMDDYYYYHHMM (manual entry). 55......... Time Zone........ [check].......... See Time Zone The time zone in which the sales will be Table, Appendix made under the contract. D. 56......... Point of Delivery [check].......... See Balancing The registered NERC Balancing Authority Balancing

      Authority Table, (formerly called NERC Control Area) Authority

      Appendix B.

      abbreviation used in OASIS applications. (PODBA). 57......... Point of Delivery [check].......... Unrestricted text The specific location at which the product Specific

      (50 characters). is delivered. If receipt occurs at a Location (PODSL).

      If ``HUB'' is trading hub, a standardized hub name must selected for be used. PODBA, see Hub Table, Appendix C. 58......... Class Name....... [check].......... ................. See class name definitions below. 58......... Class Name....... [check].......... F--Firm.......... A sale, service or product that is not interruptible for economic reasons. 58......... Class Name....... [check].......... NF--Non-firm..... A sale for which delivery or receipt of the energy may be interrupted for any reason or no reason, without liability on the part of either the buyer or seller. 58......... Class Name....... [check].......... UP--Unit Power Designates a dedicated sale of energy and Sale.

      capacity from one or more than one specified generation unit(s). 58......... Class Name....... [check].......... BA--Billing

      Designates an incremental material change Adjustment.

      to one or more transactions due to a change in settlement results. ``BA'' may be used in a refiling after the next quarter's filing is due to reflect the receipt of new information. It may not be used to correct an inaccurate filing. 58......... Class Name....... [check].......... N/A--Not

      To be used only when the other available Applicable.

      class names do not apply. 59......... Term Name........ [check].......... LT--Long Term.... Power sales transactions with durations of ST--Short Term... one year or greater are long-term. N/A--Not

      Transactions with shorter durations are Applicable.

      short-term. 60......... Increment Name... [check].......... ................. See increment name definitions below. 60......... Increment Name... [check].......... H--Hourly........ Terms of the particular sale set for up to 6 consecutive hours ( 6 and 60 and 168 consecutive hours and = 1 year). Includes all long-term contracts with defined pricing terms (fixed-price, formula, or index). 60......... Increment Name... [check].......... DN/A--Not

      To be used only when other available Applicable.

      increment names do not apply. 61......... Increment Peaking [check].......... See definitions Name.

      for increment peaking below. 61......... Increment Peaking [check].......... FP--Full Period.. The product described was sold during Peak Name.

      and Off-Peak hours. 61......... Increment Peaking [check].......... OP--Off-Peak..... The product described was sold only during Name.

      those hours designated as off-peak in the NERC region of the point of delivery. 61......... Increment Peaking [check].......... P--Peak.......... The product described was sold only during Name.

      those hours designated as on-peak in the NERC region of the point of delivery. 61......... Increment Peaking [check].......... N/A--Not

      To be used only when the other available Name.

      Applicable.

      increment peaking names do not apply. 62......... Product Name..... [check].......... See Product Names Description of product being offered. Table, Appendix A. 63......... Transaction

      [check].......... Number with up to The quantity of the product in this Quantity.

      4 decimals.

      transaction. 64......... Price............ [check].......... Number with up to Actual price charged for the product per 6 decimals.

      unit. The price reported cannot be averaged or otherwise aggregated. 65......... Rate Units....... [check].......... See Rate Units Measure appropriate to the price of the Table, Appendix product sold. F. 66......... Total

      [check].......... Number with up to Payments received for transmission Transmission

      2 decimals.

      services when explicitly identified. Charge. 67......... Total Transaction [check].......... Number with up to Transaction Quantity (Field 63) times Charge.

      2 decimals.

      Price (Field 64) plus Total Transmission Charge (Field 66).

      EQR Data Dictionary--Appendix A. Product Names

      Contract Transaction Product name

      product

      product

      Definition

      BLACK START SERVICE..................

      [check]

      [check] Service available after a system-wide blackout where a generator participates in system restoration activities without the availability of an outside electric supply (Ancillary Service). BOOKED OUT POWER..................... ...............

      [check] Energy or capacity contractually committed bilaterally for delivery but not actually delivered due to some offsetting or countervailing trade (Transaction only). CAPACITY.............................

      [check]

      [check] A quantity of demand that is charged on a $/KW or $/MW basis. CUSTOMER CHARGE......................

      [check]

      [check] Fixed contractual charges assessed on a per customer basis that could include billing service. DIRECT ASSIGNMENT FACILITIES CHARGE..

      [check] ............... Charges for facilities or portions of facilities that are constructed or used for the sole use/benefit of a particular customer. EMERGENCY ENERGY.....................

      [check] ............... Contractual provisions to supply energy or capacity to another entity during critical situations. ENERGY...............................

      [check]

      [check] A quantity of electricity that is sold or transmitted over a period of time. ENERGY IMBALANCE.....................

      [check]

      [check] Service provided when a difference occurs between the scheduled and the actual delivery of energy to a load obligation. EXCHANGE.............................

      [check]

      [check] Transaction whereby the receiver accepts delivery of energy for a supplier's account and returns energy at times, rates, and in amounts as mutually agreed if the receiver is not an RTO/ISO. FUEL CHARGE..........................

      [check]

      [check] Charge based on the cost or amount of fuel used for generation. GRANDFATHERED BUNDLED................

      [check]

      [check] Services provided for bundled transmission, ancillary services and energy under contracts effective prior to Order No. 888's OATTs. INTERCONNECTION AGREEMENT............

      [check] ............... Contract that provides the terms and conditions for a generator, distribution system owner, transmission owner, transmission provider, or transmission system to physically connect to a transmission system or distribution system. MEMBERSHIP AGREEMENT.................

      [check] ............... Agreement to participate and be subject to rules of a system operator. MUST RUN AGREEMENT...................

      [check] ............... An agreement that requires a unit to run.

      [[Page 1885]]

      NEGOTIATED-RATE TRANSMISSION.........

      [check]

      [check] Transmission performed under a negotiated rate contract (applies only to merchant transmission companies). NETWORK..............................

      [check] ............... Transmission service under contract providing network service. NETWORK OPERATING AGREEMENT..........

      [check] ............... An executed agreement that contains the terms and conditions under which a network customer operates its facilities and the technical and operational matters associated with the implementation of network integration transmission service. OTHER................................

      [check]

      [check] Product name not otherwise included. POINT-TO-POINT AGREEMENT.............

      [check] ............... Transmission service under contract between specified Points of Receipt and Delivery. REACTIVE SUPPLY & VOLTAGE CONTROL....

      [check]

      [check] Production or absorption of reactive power to maintain voltage levels on transmission systems (Ancillary Service). REAL POWER TRANSMISSION LOSS.........

      [check]

      [check] The loss of energy, resulting from transporting power over a transmission system. REGULATION & FREQUENCY RESPONSE......

      [check]

      [check] Service providing for continuous balancing of resources (generation and interchange) with load, and for maintaining scheduled interconnection frequency by committing on-line generation where output is raised or lowered and by other non-generation resources capable of providing this service as necessary to follow the moment-by-moment changes in load (Ancillary Service). REQUIREMENTS SERVICE.................

      [check]

      [check] Firm, load-following power supply necessary to serve a specified share of customer's aggregate load during the term of the agreement. Requirements service may include some or all of the energy, capacity and ancillary service products. (If the components of the requirements service are priced separately, they should be reported separately in the transactions tab.) SCHEDULE SYSTEM CONTROL & DISPATCH...

      [check]

      [check] Scheduling, confirming and implementing an interchange schedule with other Balancing Authorities, including intermediary Balancing Authorities providing transmission service, and ensuring operational security during the interchange transaction (Ancillary Service). SPINNING RESERVE.....................

      [check]

      [check] Unloaded synchronized generating capacity that is immediately responsive to system frequency and that is capable of being loaded in a short time period or non-generation resources capable of providing this service (Ancillary Service). SUPPLEMENTAL RESERVE.................

      [check]

      [check] Service needed to serve load in the event of a system contingency, available with greater delay than SPINNING RESERVE. This service may be provided by generating units that are on-line but unloaded, by quick-start generation, or by interruptible load or other non-generation resources capable of providing this service (Ancillary Service). SYSTEM OPERATING AGREEMENTS..........

      [check] ............... An executed agreement that contains the terms and conditions under which a system or network customer shall operate its facilities and the technical and operational matters associated with the implementation of network. TOLLING ENERGY.......................

      [check]

      [check] Energy sold from a plant whereby the buyer provides fuel to a generator (seller) and receives power in return for pre-established fees. TRANSMISSION OWNERS AGREEMENT........

      [check] ............... The agreement that establishes the terms and conditions under which a transmission owner transfers operational control over designated transmission facilities. UPLIFT...............................

      [check]

      [check] A make-whole payment by an RTO/ISO to a utility.

      EQR Data Dictionary--Appendix B. Balancing Authority

      Balancing authority

      Abbreviation

      Outside US *

      AESC, LLC--Wheatland CIN................................... AEWC

      ............... Alabama Electric Cooperative, Inc.......................... AEC

      ............... Alberta Electric System Operator........................... AESO

      [check] Alliant Energy Corporate Services, LLC--East............... ALTE

      ............... Alliant Energy Corporate Services, LLC--West............... ALTW

      ............... Ameren Transmission........................................ AMRN

      ............... Ameren Transmission. Illinois.............................. AMIL

      ............... Ameren Transmission. Missouri.............................. AMMO

      ............... American Transmission Systems, Inc......................... FE

      ............... Aquila Networks--Kansas.................................... WPEK

      ............... Aquila Networks--Missouri Public Service................... MPS

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

      [[Page 1886]]

      Aquila Networks--West Plains Dispatch...................... WPEC

      ............... Arizona Public Service Company............................. AZPS

      ............... Associated Electric Cooperative, Inc....................... AECI

      ............... Avista Corp................................................ AVA

      ............... Batesville Balancing Authority............................. BBA

      ............... Big Rivers Electric Corp................................... BREC

      ............... Board of Public Utilities.................................. KACY

      ............... Bonneville Power Administration Transmission............... BPAT

      ............... British Columbia Transmission Corporation.................. BCTC

      [check] California Independent System Operator..................... CISO

      ............... Carolina Power & Light Company--CPLW....................... CPLW

      ............... Carolina Power and Light Company--East..................... CPLE

      ............... Central and Southwest...................................... CSWS

      ............... Central Illinois Light Co.................................. CILC

      ............... Chelan County PUD.......................................... CHPD

      ............... Cinergy Corporation........................................ CIN

      ............... City of Homestead.......................................... HST

      ............... City of Independence P&L Dept.............................. INDN

      ............... City of Tallahassee........................................ TAL

      ............... City Water Light & Power................................... CWLP

      ............... Cleco Power LLC............................................ CLEC

      ............... Columbia Water & Light..................................... CWLD

      ............... Comision Federal de Electricidad........................... CFE

      [check] Constellation Energy Control and Dispatch--Arkansas........ PUPP

      ............... Constellation Energy Control and Dispatch--City of Benton, BUBA

      ............... AR. Constellation Energy Control and Dispatch--City of Ruston, DERS

      ............... LA. Constellation Energy Control and Dispatch--Conway, Arkansas CNWY

      ............... Constellation Energy Control and Dispatch--Gila River...... GRMA

      ............... Constellation Energy Control and Dispatch--Harquehala...... HGMA

      ............... Constellation Energy Control and Dispatch--North Little DENL

      ............... Rock, AR. Constellation Energy Control and Dispatch--West Memphis, WMUC

      ............... Arkansas. Dairyland Power Cooperative................................ DPC

      ............... DECA, LLC--Arlington Valley................................ DEAA

      ............... Duke Energy Corporation.................................... DUK

      ............... East Kentucky Power Cooperative, Inc....................... EKPC

      ............... El Paso Electric........................................... EPE

      ............... Electric Energy, Inc....................................... EEI

      ............... Empire District Electric Co., The.......................... EDE

      ............... Entergy.................................................... EES

      ............... ERCOT ISO.................................................. ERCO

      ............... Florida Municipal Power Pool............................... FMPP

      ............... Florida Power & Light...................................... FPL

      ............... Florida Power Corporation.................................. FPC

      ............... Gainesville Regional Utilities............................. GVL

      ............... Georgia System Operations Corporation...................... GSOC

      ............... Georgia Transmission Corporation........................... GTC

      ............... Grand River Dam Authority.................................. GRDA

      ............... Grant County PUD No. 2..................................... GCPD

      ............... Great River Energy......................................... GRE

      ............... Great River Energy......................................... GREC

      ............... Great River Energy......................................... GREN

      ............... Great River Energy......................................... GRES

      ............... GridAmerica................................................ GA

      ............... Hoosier Energy............................................. HE

      ............... Hydro-Quebec, TransEnergie................................. HQT

      [check] Idaho Power Company........................................ IPCO

      ............... Illinois Power Co.......................................... IP

      ............... Illinois Power Co.......................................... IPRV

      ............... Imperial Irrigation District............................... IID

      ............... Indianapolis Power & Light Company......................... IPL

      ............... ISO New England Inc........................................ ISNE

      ............... JEA........................................................ JEA

      ............... Kansas City Power & Light, Co.............................. KCPL

      ............... Lafayette Utilities System................................. LAFA

      ............... LG&E Energy Transmission Services.......................... LGEE

      ............... Lincoln Electric System.................................... LES

      ............... Los Angeles Department of Water and Power.................. LDWP

      ............... Louisiana Energy & Power Authority......................... LEPA

      ............... Louisiana Generating, LLC.................................. LAGN

      ............... Madison Gas and Electric Company........................... MGE

      ............... Manitoba Hydro Electric Board, Transmission Services....... MHEB

      [check] Michigan Electric Coordinated System....................... MECS

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

      [[Page 1887]]

      Michigan Electric Coordinated System--CONS................. CONS

      ............... Michigan Electric Coordinated System--DECO................. DECO

      ............... MidAmerican Energy Company................................. MEC

      ............... Midwest ISO................................................ MISO

      ............... Minnesota Power, Inc....................................... MP

      ............... Montana-Dakota Utilities Co................................ MDU

      ............... Muscatine Power and Water.................................. MPW

      ............... Nebraska Public Power District............................. NPPD

      ............... Nevada Power Company....................................... NEVP

      ............... New Brunswick Power Corporation............................ NBPC

      [check] New Horizons Electric Cooperative.......................... NHC1

      ............... New York Independent System Operator....................... NYIS

      ............... North American Electric Reliability Council................ TEST

      ............... Northern Indiana Public Service Company.................... NIPS

      ............... Northern States Power Company.............................. NSP

      ............... NorthWestern Energy........................................ NWMT

      ............... Ohio Valley Electric Corporation........................... OVEC

      ............... Oklahoma Gas and Electric.................................. OKGE

      ............... Ontario--Independent Electricity Market Operator........... IMO

      [check] OPPD CA/TP................................................. OPPD

      ............... Otter Tail Power Company................................... OTP

      ............... P.U.D. No. 1 of Douglas County............................. DOPD

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

      ............... PacifiCorp-West............................................ PACW

      ............... PJM Interconnection........................................ PJM

      ............... Portland General Electric.................................. PGE

      ............... Public Service Company of Colorado......................... PSCO

      ............... Public Service Company of New Mexico....................... PNM

      ............... Puget Sound Energy Transmission............................ PSEI

      ............... Reedy Creek Improvement District........................... RC

      ............... Sacramento Municipal Utility District...................... SMUD

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

      ............... Santee Cooper.............................................. SC

      ............... SaskPower Grid Control Centre.............................. SPC

      [check] Seattle City Light......................................... SCL

      ............... Seminole Electric Cooperative.............................. SEC

      ............... Sierra Pacific Power Co.--Transmission..................... SPPC

      ............... South Carolina Electric & Gas Company...................... SCEG

      ............... South Mississippi Electric Power Association............... SME

      ............... South Mississippi Electric Power Association............... SMEE

      ............... Southeastern Power Administration--Hartwell................ SEHA

      ............... Southeastern Power Administration--Russell................. SERU

      ............... Southeastern Power Administration--Thurmond................ SETH

      ............... Southern Company Services, Inc............................. SOCO

      ............... Southern Illinois Power Cooperative........................ SIPC

      ............... Southern Indiana Gas & Electric Co......................... SIGE

      ............... Southern Minnesota Municipal Power Agency.................. SMP

      ............... Southwest Power Pool....................................... SWPP

      ............... Southwestern Power Administration.......................... SPA

      ............... Southwestern Public Service Company........................ SPS

      ............... Sunflower Electric Power Corporation....................... SECI

      ............... Tacoma Power............................................... TPWR

      ............... Tampa Electric Company..................................... TEC

      ............... Tennessee Valley Authority ESO............................. TVA

      ............... Trading Hub................................................ HUB

      ............... TRANSLink Management Company............................... TLKN

      ............... Tucson Electric Power Company.............................. TEPC

      ............... Turlock Irrigation District................................ TIDC

      ............... Upper Peninsula Power Co................................... UPPC

      ............... Utilities Commission, City of New Smyrna Beach............. NSB

      ............... Westar Energy--MoPEP Cities................................ MOWR

      ............... Western Area Power Administration--Colorado--Missouri...... WACM

      ............... Western Area Power Administration--Lower Colorado.......... WALC

      ............... Western Area Power Administration--Upper Great Plains East. WAUE

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

      ............... Western Farmers Electric Cooperative....................... WFEC

      ............... Western Resources dba Westar Energy........................ WR

      ............... Wisconsin Energy Corporation............................... WEC

      ............... Wisconsin Public Service Corporation....................... WPS

      ............... Yadkin, Inc................................................ YAD

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

      * Balancing authorities outside the United States may only be used in the Contract Data section to identify specified receipt/delivery points in jurisdictional transmission contracts.

      [[Page 1888]]

      EQR Data Dictionary--Appendix C. Hub

      HUB

      Definition

      ADHUB......................... The aggregated Locational Marginal Price (``LMP'') nodes defined by PJM Interconnection, LLC as the AEP/Dayton Hub. AEPGenHub..................... The aggregated Locational Marginal Price (``LMP'') nodes defined by PJM Interconnection, LLC as the AEPGenHub. COB........................... The set of delivery points along the California-Oregon border commonly identified as and agreed to by the counterparties to constitute the COB Hub. Cinergy (into)................ The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into the Cinergy balancing authority. Cinergy Hub (MISO)............ The aggregated Elemental Pricing nodes (``Epnodes'') nodes defined by the Midwest Independent Transmission System Operator, Inc., as Cinergy Hub (MISO). Entergy (into)................ The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into the Entergy balancing authority. FE Hub........................ The aggregated Elemental Pricing nodes (``Epnodes'') nodes defined by the Midwest Independent Transmission System Operator, Inc., as FE Hub (MISO). Four Corners.................. The set of delivery points at the Four Corners power plant commonly identified as and agreed to by the counterparties to constitute the Four Corners Hub. Illinois Hub (MISO)........... The aggregated Elemental Pricing nodes (``Epnodes'') nodes defined by the Midwest Independent Transmission System Operator, Inc., as Illinois Hub (MISO). Mead.......................... The set of delivery points at or near Hoover Dam commonly identified as and agreed to by the counterparties to constitute the Mead Hub. Michigan Hub (MISO)........... The aggregated Elemental Pricing nodes (``Epnodes'') nodes defined by the Midwest Independent Transmission System Operator, Inc., as Michigan Hub (MISO). Mid-Columbia (Mid-C).......... The set of delivery points along the Columbia River commonly identified as and agreed to by the counterparties to constitute the Mid-Columbia Hub. Minnesota Hub (MISO).......... The aggregated Elemental Pricing nodes (``Epnodes'') nodes defined by the Midwest Independent Transmission System Operator, Inc., as Minnesota Hub (MISO). NEPOOL (Mass Hub)............. The aggregated Locational Marginal Price (``LMP'') nodes defined by ISO New England Inc., as Mass Hub. NIHUB......................... The aggregated Locational Marginal Price (``LMP'') nodes defined by PJM Interconnection, LLC as the Northern Illinois Hub. NOB........................... The set of delivery points along the Nevada-Oregon border commonly identified as and agreed to by the counterparties to constitute the NOB Hub. NP15.......................... The set of delivery points north of Path 15 on the California transmission grid commonly identified as and agreed to by the counterparties to constitute the NP15 Hub. NWMT.......................... The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into the Northwestern Energy Montana balancing authority. PJM East Hub.................. The aggregated Locational Marginal Price nodes (``LMP'') defined by PJM Interconnection, LLC as the PJM East Hub. PJM South Hub................. The aggregated Locational Marginal Price (``LMP'') nodes defined by PJM Interconnection, LLC as the PJM South Hub. PJM West Hub.................. The aggregated Locational Marginal Price (``LMP'') nodes defined by PJM Interconnection, LLC as the PJM Western Hub. Palo Verde.................... The switch yard at the Palo Verde nuclear power station west of Phoenix in Arizona. Palo Verde Hub includes the Hassayampa switchyard 2 miles south of Palo Verde. SOCO (into)................... The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into the Southern Company balancing authority. SP15.......................... The set of delivery points south of Path 15 on the California transmission grid commonly identified as and agreed to by the counterparties to constitute the SP15 Hub. TVA (into).................... The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into the Tennessee Valley Authority balancing authority. ZP26.......................... The set of delivery points associated with Path 26 on the California transmission grid commonly identified as and agreed to by the counterparties to constitute the ZP26 Hub.

      EQR Data Dictionary--Appendix D. Time Zone

      Time zone

      Definition

      AD................................ Atlantic Daylight. AP................................ Atlantic Prevailing. AS................................ Atlantic Standard. CD................................ Central Daylight. CP................................ Central Prevailing. CS................................ Central Standard. ED................................ Eastern Daylight. EP................................ Eastern Prevailing. ES................................ Eastern Standard. MD................................ Mountain Daylight. MP................................ Mountain Prevailing. MS................................ Mountain Standard. NA............................... Not Applicable. PD................................ Pacific Daylight. PP................................ Pacific Prevailing. PS................................ Pacific Standard. UT................................ Universal Time.

      EQR Data Dictionary--Appendix E. Units

      Units

      Definition

      KV............................... Kilovolt. KVA.............................. Kilovolt Amperes. KVR.............................. Kilovar. KW............................... Kilowatt. KWH.............................. Kilowatt Hour. KW-DAY........................... Kilowatt Day. KW-MO............................ Kilowatt Month. KW-WK............................ Kilowatt Week. KW-YR............................ Kilowatt Year. MVAR-YR.......................... Megavar Year. MW............................... Megawatt. MWH.............................. Megawatt Hour. MW-DAY........................... Megawatt Day. MW-MO............................ Megawatt Month. MW-WK............................ Megawatt Week. MW-YR............................ Megawatt Year. RKVA............................. Reactive Kilovolt Amperes. FLAT RATE........................ Flat Rate.

      [[Page 1889]]

      EQR Data Dictionary--Appendix F. Rate Units

      Rate units

      Definition

      $/KV.................................. dollars per kilovolt. $/KVA................................. dollars per kilovolt amperes. $/KVR................................. dollars per kilovar. $/KW.................................. dollars per kilowatt. $/KWH................................. dollars per kilowatt hour. $/KW-DAY.............................. dollars per kilowatt day. $/KW-MO............................... dollars per kilowatt month. $/KW-WK............................... dollars per kilowatt week. $/KW-YR............................... dollars per kilowatt year. $/MW.................................. dollars per megawatt. $/MWH................................. dollars per megawatt hour. $/MW-DAY.............................. dollars per megawatt day. $/MW-MO............................... dollars per megawatt month. $/MW-WK............................... dollars per megawatt week. $/MW-YR............................... dollars per megawatt year. $/MVAR-YR............................. dollars per megavar year. $/RKVA................................ dollars per reactive kilovar amperes. CENTS................................. cents. CENTS/KVR............................. cents per kilovolt amperes. CENTS/KWH............................. cents per kilowatt hour. FLAT RATE............................. rate not specified in any other units.

      [FR Doc. E8-184 Filed 1-9-08; 8:45 am]

      BILLING CODE 6717-01-P

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