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Notice

Revised Public Utility Filing Requirements for Electric Quarterly Reports

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Start Preamble 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.

Start Further Info

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 Start Printed Page 1877First Street, NE., Washington, DC 20426, (202) 502-8321.

End Further Info End Preamble Start Supplemental Information

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).

I. 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. 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. 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.

II. Discussion

A. 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.”

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.

B. 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 Start Printed Page 1878that would cause a change in these required data elements would require a change in the Contract Commencement 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.

C. 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.

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 < 1 year).

D. Field No. 37—Rate Description

17. The EQR Notice proposed defining Rate Description as a “[t]ext description of rate. May reference FERC tariff, or, if a discounted or negotiated rate, include algorithm.” EEI filed comments in response to the EQR Notice requesting that filers be allowed to enter the tariff location into the Rate Description field in lieu of a detailed description of the rate itself. EEI supported this request by citing the difficulty of putting complex rates into the 150 character field. In Order No. 2001-G, the Commission stated that the EQR fulfills the Commission's statutory obligation under the Federal Power Act (FPA) to have companies' rates on file. We further stated that the Commission relies on the EQR to satisfy the FPA requirement that rates provided in a contract be publicly disclosed and on file. Thus, we concluded that it is imperative that the information reported in EQRs provide an adequate level of detail and transparency.

18. The Commission also stated in Order No. 2001-G that a tariff reference alone, instead of the actual rate description, does not meet the FPA standard. Allowing filers to substitute a tariff reference in place of an actual rate description would force EQR users seeking this information to conduct further research to track down the contents of the tariff on file. This is clearly less transparent than a rate description that actually describes the rate. We also explained that, if the tariff reference is coupled with a descriptive summary of the rate, where the rate is the function of a complex algorithm, the standard is met. Further, we explained that rate information will continue to be available to the public at a level sufficient to explain the bases and methods of calculation with additional detail available upon request to interested persons.

19. On rehearing, EEI argues that, in the case of cost-based rates, the FPA requirement that rates be on file is satisfied by separate on-the-record Commission filings, so it is not necessary to provide a rate description in the EQR to satisfy the FPA. Thus, it argues, a reference to the rate schedule number and page is sufficient for EQR purposes, without any text description of the rate.

Commission Conclusion

20. Prior to the adoption of Order No. 2001, public utilities satisfied the FPA requirement to have their rates on file with the Commission without filing EQRs (which had not yet been established). Thus, EEI is correct that the EQR filings are not the sole means by which this legal requirement can be met. However, section 205(c) provides the Commission with wide discretion on how companies are to file their rates and, in Order No. 2001, the Commission established the EQR as a means to ensure compliance with the FPA, and to provide a mechanism for the public to inspect and review the pertinent terms and conditions of public utilities' contracts and transactions in an electronic format that afforded greater transparency and accessibility to this information.[9]

21. When this issue first was considered in Order No. 2001-G, it centered on the question of whether 150 characters would be sufficient to provide all the information needed to accurately describe a public utility's rates. After consideration of EEI's arguments and the problem of fitting an accurate rate description into 150 characters without sacrificing transparency, we are persuaded to revise the definition for Rate Description to include a provision that relates to a rate that is currently on file with the Commission. The Commission will define Rate Description as “[t]ext 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. Start Printed Page 1879If 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 subsequent lines of data until the rate is adequately described.” With this revision of Rate Description, EQR filers may provide the necessary information without sacrificing transparency.

III. Document Availability

22. In addition to publishing the full text of this document in the Federal Register, the Commission provides all interested persons an opportunity to view and/or print the contents of this document via the Internet through the Commission's Home Page (http://www.ferc.gov) and in the Commission's Public Reference Room during normal business hours (8:30 a.m. to 5 p.m. Eastern time) at 888 First Street, NE., Room 2A, Washington, DC 20426.

23. From the Commission's Home Page on the Internet, this information is available in the eLibrary. The full text of this document is available in the eLibrary both in PDF and Microsoft Word format for viewing, printing, and/or downloading. To access this document in eLibrary, type “RM01-8” in the docket number field. User assistance is available for eLibrary and the Commission's website during the Commission's normal business hours. For assistance contact the Commission's Online Support services at FERCOnlineSupport@ferc.gov or toll-free at (866) 208-3676, or for TTY, contact (202) 502-8659.

The Commission orders:

(A) EEI's request for rehearing or clarification is hereby granted in part, and denied in part, as discussed in the body of this order.

(B) TransAlta's request for clarification is hereby granted, as discussed in the body of this order.

(C) 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.

Start Signature

By the Commission.

Kimberly D. Bose,

Secretary.

End Signature

Attachment

Electric Quarterly Report Data Dictionary Version 1.0 (Issued —)

EQR Data Dictionary

Field No.FieldRequiredValueDefinition
ID Data
1Filer Unique IdentifierFR1(Respondent)—An identifier (i.e., “FR1”) used to designate a record containing Respondent identification information in a comma-delimited (csv) file that is imported into the EQR filing. Only one record with the FR1 identifier may be imported into an EQR for a given quarter.
1Filer Unique IdentifierFS# (where “#” is an integer)(Seller)—An identifier (e.g., “FS1”, “FS2”) used to designate a record containing Seller identification 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.
1Filer Unique IdentifierFA1(Agent)—An identifier (i.e., “FA1”) 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.
2Company NameUnrestricted text (100 characters)(Respondent)—The name of the company taking responsibility for complying with the Commission's regulations related to the EQR.
2Company NameUnrestricted text (100 characters)(Seller)—The name of the company that is 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.
2Company NameUnrestricted text (100 characters)(Agent)—The name of the entity completing the EQR filing. The Agent's Company Name need not be the name of the company under Commission jurisdiction.
3Company DUNS Numberfor Respondent and SellerNine digit numberThe unique nine digit number assigned by Dun and Bradstreet to the company identified in Field Number 2.
4Contact NameUnrestricted text (50 characters)(Respondent)—Name of the person at the Respondent's company taking responsibility for compliance with the Commission's EQR regulations.
4Contact NameUnrestricted text (50 characters)(Seller)—The name of the contact for the 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.
4Contact NameUnrestricted text (50 characters)(Agent)—Name of the contact for the Agent, usually the person who prepares the filing.
5Contact TitleUnrestricted text (50 characters)Title of contact identified in Field Number 4.
6Contact AddressUnrestricted textStreet address for contact identified in Field Number 4.
7Contact CityUnrestricted text (30 characters)City for the contact identified in Field Number 4.
8Contact StateUnrestricted text (2 characters)Two character state or province abbreviations for the contact identified in Field Number 4.
Start Printed Page 1880
9Contact ZipUnrestricted text (10 characters)Zip code for the contact identified in Field Number 4.
10Contact Country NameCA—Canada MX—Mexico US—United States UK—United KingdomCountry (USA, Canada, Mexico, or United Kingdom) for contact address identified in Field Number 4.
11Contact PhoneUnrestricted text (20 characters)Phone number of contact identified in Field Number 4.
12Contact E-MailUnrestricted textE-mail address of contact identified in Field Number 4.
13Filing QuarterYYYYMMA 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
14Contract Unique IDAn integer proceeded by the letter “C” (only used when importing contract data)An identifier beginning with the letter “C” and followed by a number (e.g., “C1”, “C2”) used to designate a record containing contract information in a comma-delimited (csv) file that is imported into the EQR filing. One record for each contract product may be imported into an EQR for a given quarter.
15Seller Company NameUnrestricted text (100 characters)The name of the company that is authorized 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).
16Customer Company NameUnrestricted text (70 characters)The name of the counterparty.
17Customer DUNS NumberNine digit numberThe unique nine digit number assigned by Dun and Bradstreet to the company identified in Field Number 16.
18Contract AffiliateY (Yes) N (No)The customer is an affiliate if it 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.
19FERC Tariff ReferenceUnrestricted text (60 characters)The FERC tariff reference cites the 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.
20Contract Service Agreement IDUnrestricted text (30 characters)Unique identifier given to each service 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.
21Contract Execution DateYYYYMMDDThe date the contract was signed. If the parties signed on different dates, use the most recent date signed.
22Contract Commencement DateYYYYMMDDThe 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.
23Contract Termination DateIf specified in the contractYYYYMMDDThe date that the contract expires.
24Actual Termination DateIf contract terminatedYYYYMMDDThe date the contract actually terminates.
25Extension Provision DescriptionUnrestricted textDescription of terms that provide for the continuation of the contract.
26Class NameSee definitions of each class name below.
26Class NameF—FirmFor 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.
Start Printed Page 1881
26Class NameNF—Non-firmFor 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.
26Class NameUP—Unit Power SaleDesignates a dedicated sale of energy and capacity from one or more than one specified generation unit(s).
26Class NameN/A—Not ApplicableTo be used only when the other available Class Names do not apply.
27Term NameLT—Long Term ST—Short Term N/A—Not ApplicableContracts with durations of one year or greater are long-term. Contracts with shorter durations are short-term.
28Increment NameSee definitions for each increment below.
28Increment NameH—HourlyTerms of the contract (if specifically noted in the contract) set for up to 6 consecutive hours (≤ 6 consecutive hours).
28Increment NameD—DailyTerms of the contract (if specifically noted in the contract) set for more than 6 and up to 60 consecutive hours (> 6 and ≤ 60 consecutive hours).
28Increment NameW—WeeklyTerms of the contract (if specifically noted in the contract) set for over 60 consecutive hours and up to 168 consecutive hours (> 60 and ≤ 168 consecutive hours).
28Increment NameM—MonthlyTerms of the contract (if specifically noted in the contract) set for more than 168 consecutive hours up to, but not including, one year (> 168 consecutive hours and < 1 year).
28Increment NameY—YearlyTerms of the contract (if specifically noted in the contract) set for one year or more (≥ 1 year).
28Increment NameN/A—Not ApplicableTerms of the contract do not specify an increment.
29Increment Peaking NameSee definitions for each increment peaking name below.
29Increment Peaking NameFP—Full PeriodThe product described may be sold during those hours designated as on-peak and off-peak in the NERC region of the point of delivery.
29Increment Peaking NameOP—Off-PeakThe product described may be sold only during those hours designated as off-peak in the NERC region of the point of delivery.
29Increment Peaking NameP—PeakThe product described may be sold only during those hours designated as on-peak in the NERC region of the point of delivery.
29Increment Peaking NameN/A—Not ApplicableTo be used only when the increment peaking name is not specified in the contract.
30Product Type NameSee definitions for each product type below.
30Product Type NameCB—Cost BasedEnergy or capacity sold under a FERC-approved cost-based rate tariff.
30Product Type NameCR—Capacity ReassignmentAn agreement under which a transmission provider sells, assigns or transfers all or portion of its rights to an eligible customer.
30Product Type NameMB—Market BasedEnergy or capacity sold under the seller's FERC-approved market-based rate tariff.
30Product Type NameT—TransmissionThe product is sold under a FERC-approved transmission tariff.
30Product Type NameOtherThe product cannot be characterized by the other product type names.
31Product NameSee Product Name Table, Appendix ADescription of product being offered.
32QuantityIf specified in the contractNumber with up to 4 decimalsQuantity for the contract product identified.
33UnitsIf specified in the contractSee Units Table, Appendix EMeasure stated in the contract for the product sold.
34RateNumber with up to 4 decimalsThe charge for the product per unit as stated in the contract.
35Rate MinimumOne of four rate fields (34, 35, 36, or 37) must be includedNumber with up to 4 decimalsMaximum rate to be charged per the contract, if a range is specified.
36Rate MaximumNumber with up to 4 decimalsMaximum rate to be charged per the contract, if a range is specified.
Start Printed Page 1882
37Rate DescriptionUnrestricted textText 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.
38Rate UnitsIf specified in the contractSee Rate Units Table, Appendix FMeasure stated in the contract for the product sold.
39Point of Receipt Balancing Authority (PORBA)If specified in the contractSee Balancing Authority Table, Appendix BThe registered NERC Balancing Authority (formerly called NERC Control Area) where service begins for a transmission or 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.
40Point of Receipt Specific Location (PORSL)If specified in the contractUnrestricted text (50 characters). If “HUB” is selected for PORCA, see Hub Table, Appendix CThe specific location at which the product is received if designated in the contract. If receipt occurs at a trading hub, a standardized hub name must be used. If more points of receipt are listed in the contract than can fit into 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.
41Point of Delivery Balancing Authority (PODBA)If specified in the contractSee Balancing Authority Table, Appendix BThe registered NERC Balancing Authority (formerly called NERC Control Area) where a jurisdictional product is delivered and/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.
42Point of Delivery Specific Location (PODSL)If specified in the contractUnrestricted text (50 characters). If “HUB” is selected for PODCA, see Hub Table, Appendix CThe specific location at which the product is delivered if designated in the contract. If receipt occurs at a trading hub, a standardized hub name must be used.
43Begin DateIf specified in the contractYYYYMMDDHHMMFirst date for the sale of the product at the rate specified.
44End DateIf specified in the contractYYYYMMDDHHMMLast date for the sale of the product at the rate specified.
45Time ZoneSee Time Zone Table, Appendix DThe time zone in which the sales will be made under the contract.
Transaction Data
46Transaction Unique IDAn integer proceeded by the letter “T” (only used when importing transaction data)An identifier beginning with the letter “T” and followed by a number (e.g., “T1”, “T2”) used to designate a record containing transaction information in a comma-delimited (csv) file that is imported into the EQR filing. One record 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.
47Seller Company NameUnrestricted text (100 Characters)The name of the company that is authorized 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).
48Customer Company NameUnrestricted text (70 Characters)The name of the counterparty.
49Customer DUNS NumberNine digit numberThe unique nine digit number assigned by Dun and Bradstreet to the counterparty to the contract.
Start Printed Page 1883
50FERC Tariff ReferenceUnrestricted text (60 Characters)The FERC tariff reference cites the 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.
51Contract Service Agreement IDUnrestricted text (30 Characters)Unique identifier given to each service 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.
52Transaction Unique IdentifierUnrestricted text (24 Characters)Unique reference number assigned by the seller for each transaction.
53Transaction Begin DateYYYYMMDDHHMM (csv import) MMDDYYYYHHMM (manual entry)First date and time the product is sold during the quarter.
54Transaction End DateYYYYMMDDHHMM (csv import) MMDDYYYYHHMM (manual entry)Last date and time the product is sold during the quarter.
55Time ZoneSee Time Zone Table, Appendix DThe time zone in which the sales will be made under the contract.
56Point of Delivery Balancing Authority (PODBA)See Balancing Authority Table, Appendix BThe registered NERC Balancing Authority (formerly called NERC Control Area) abbreviation used in OASIS applications.
57Point of Delivery Specific Location (PODSL)Unrestricted text (50 characters). If “HUB” is selected for PODBA, see Hub Table, Appendix CThe specific location at which the product is delivered. If receipt occurs at a trading hub, a standardized hub name must be used.
58Class NameSee class name definitions below.
58Class NameF—FirmA sale, service or product that is not interruptible for economic reasons.
58Class NameNF—Non-firmA 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.
58Class NameUP—Unit Power SaleDesignates a dedicated sale of energy and capacity from one or more than one specified generation unit(s).
58Class NameBA—Billing AdjustmentDesignates an incremental material change 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.
58Class NameN/A—Not ApplicableTo be used only when the other available class names do not apply.
59Term NameLT—Long Term ST—Short Term N/A—Not ApplicablePower sales transactions with durations of one year or greater are long-term. Transactions with shorter durations are short-term.
60Increment NameSee increment name definitions below.
60Increment NameH—HourlyTerms of the particular sale set for up to 6 consecutive hours (≤ 6 consecutive hours) Includes LMP based sales in ISO/RTO markets.
60Increment NameD—DailyTerms of the particular sale set for more than 6 and up to 60 consecutive hours (> 6 and ≤ 60 consecutive hours) Includes sales over a peak or off-peak block during a single day.
60Increment NameW—WeeklyTerms of the particular sale set for over 60 consecutive hours and up to 168 consecutive hours (> 60 and ≤ 168 consecutive hours). Includes sales for a full week and sales for peak and off-peak blocks over a particular week.
60Increment NameM—MonthlyTerms of the particular sale set for set for more than 168 consecutive hours up to, but not including, one year (>168 consecutive hours and < 1 year). Includes sales for full month or multi-week sales during a given month.
Start Printed Page 1884
60Increment NameY—YearlyTerms of the particular sale set for one year or more (≥ 1 year). Includes all long-term contracts with defined pricing terms (fixed-price, formula, or index).
60Increment NameDN/A—Not ApplicableTo be used only when other available increment names do not apply.
61Increment Peaking NameSee definitions for increment peaking below
61Increment Peaking NameFP—Full PeriodThe product described was sold during Peak and Off-Peak hours.
61Increment Peaking NameOP—Off-PeakThe product described was sold only during those hours designated as off-peak in the NERC region of the point of delivery.
61Increment Peaking NameP—PeakThe product described was sold only during those hours designated as on-peak in the NERC region of the point of delivery.
61Increment Peaking NameN/A—Not ApplicableTo be used only when the other available increment peaking names do not apply.
62Product NameSee Product Names Table, Appendix ADescription of product being offered.
63Transaction QuantityNumber with up to 4 decimalsThe quantity of the product in this transaction.
64PriceNumber with up to 6 decimalsActual price charged for the product per unit. The price reported cannot be averaged or otherwise aggregated.
65Rate UnitsSee Rate Units Table, Appendix FMeasure appropriate to the price of the product sold.
66Total Transmission ChargeNumber with up to 2 decimalsPayments received for transmission services when explicitly identified.
67Total Transaction ChargeNumber with up to 2 decimalsTransaction Quantity (Field 63) times Price (Field 64) plus Total Transmission Charge (Field 66).

EQR Data Dictionary—Appendix A. Product Names

Product nameContract productTransaction productDefinition
BLACK START SERVICEService 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 POWEREnergy or capacity contractually committed bilaterally for delivery but not actually delivered due to some offsetting or countervailing trade (Transaction only).
CAPACITYA quantity of demand that is charged on a $/KW or $/MW basis.
CUSTOMER CHARGEFixed contractual charges assessed on a per customer basis that could include billing service.
DIRECT ASSIGNMENT FACILITIES CHARGECharges for facilities or portions of facilities that are constructed or used for the sole use/benefit of a particular customer.
EMERGENCY ENERGYContractual provisions to supply energy or capacity to another entity during critical situations.
ENERGYA quantity of electricity that is sold or transmitted over a period of time.
ENERGY IMBALANCEService provided when a difference occurs between the scheduled and the actual delivery of energy to a load obligation.
EXCHANGETransaction 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 CHARGECharge based on the cost or amount of fuel used for generation.
GRANDFATHERED BUNDLEDServices provided for bundled transmission, ancillary services and energy under contracts effective prior to Order No. 888's OATTs.
INTERCONNECTION AGREEMENTContract 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 AGREEMENTAgreement to participate and be subject to rules of a system operator.
MUST RUN AGREEMENTAn agreement that requires a unit to run.
Start Printed Page 1885
NEGOTIATED-RATE TRANSMISSIONTransmission performed under a negotiated rate contract (applies only to merchant transmission companies).
NETWORKTransmission service under contract providing network service.
NETWORK OPERATING AGREEMENTAn 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.
OTHERProduct name not otherwise included.
POINT-TO-POINT AGREEMENTTransmission service under contract between specified Points of Receipt and Delivery.
REACTIVE SUPPLY & VOLTAGE CONTROLProduction or absorption of reactive power to maintain voltage levels on transmission systems (Ancillary Service).
REAL POWER TRANSMISSION LOSSThe loss of energy, resulting from transporting power over a transmission system.
REGULATION & FREQUENCY RESPONSEService 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 SERVICEFirm, 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 & DISPATCHScheduling, 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 RESERVEUnloaded 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 RESERVEService 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 AGREEMENTSAn 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 ENERGYEnergy sold from a plant whereby the buyer provides fuel to a generator (seller) and receives power in return for pre-established fees.
TRANSMISSION OWNERS AGREEMENTThe agreement that establishes the terms and conditions under which a transmission owner transfers operational control over designated transmission facilities.
UPLIFTA make-whole payment by an RTO/ISO to a utility.

EQR Data Dictionary—Appendix B. Balancing Authority

Balancing authorityAbbreviationOutside US *
AESC, LLC—Wheatland CINAEWC
Alabama Electric Cooperative, IncAEC
Alberta Electric System OperatorAESO
Alliant Energy Corporate Services, LLC—EastALTE
Alliant Energy Corporate Services, LLC—WestALTW
Ameren TransmissionAMRN
Ameren Transmission. IllinoisAMIL
Ameren Transmission. MissouriAMMO
American Transmission Systems, IncFE
Aquila Networks—KansasWPEK
Aquila Networks—Missouri Public ServiceMPS
Start Printed Page 1886
Aquila Networks—West Plains DispatchWPEC
Arizona Public Service CompanyAZPS
Associated Electric Cooperative, IncAECI
Avista CorpAVA
Batesville Balancing AuthorityBBA
Big Rivers Electric CorpBREC
Board of Public UtilitiesKACY
Bonneville Power Administration TransmissionBPAT
British Columbia Transmission CorporationBCTC
California Independent System OperatorCISO
Carolina Power & Light Company—CPLWCPLW
Carolina Power and Light Company—EastCPLE
Central and SouthwestCSWS
Central Illinois Light CoCILC
Chelan County PUDCHPD
Cinergy CorporationCIN
City of HomesteadHST
City of Independence P&L DeptINDN
City of TallahasseeTAL
City Water Light & PowerCWLP
Cleco Power LLCCLEC
Columbia Water & LightCWLD
Comision Federal de ElectricidadCFE
Constellation Energy Control and Dispatch—ArkansasPUPP
Constellation Energy Control and Dispatch—City of Benton, ARBUBA
Constellation Energy Control and Dispatch—City of Ruston, LADERS
Constellation Energy Control and Dispatch—Conway, ArkansasCNWY
Constellation Energy Control and Dispatch—Gila RiverGRMA
Constellation Energy Control and Dispatch—HarquehalaHGMA
Constellation Energy Control and Dispatch—North Little Rock, ARDENL
Constellation Energy Control and Dispatch—West Memphis, ArkansasWMUC
Dairyland Power CooperativeDPC
DECA, LLC—Arlington ValleyDEAA
Duke Energy CorporationDUK
East Kentucky Power Cooperative, IncEKPC
El Paso ElectricEPE
Electric Energy, IncEEI
Empire District Electric Co., TheEDE
EntergyEES
ERCOT ISOERCO
Florida Municipal Power PoolFMPP
Florida Power & LightFPL
Florida Power CorporationFPC
Gainesville Regional UtilitiesGVL
Georgia System Operations CorporationGSOC
Georgia Transmission CorporationGTC
Grand River Dam AuthorityGRDA
Grant County PUD No. 2GCPD
Great River EnergyGRE
Great River EnergyGREC
Great River EnergyGREN
Great River EnergyGRES
GridAmericaGA
Hoosier EnergyHE
Hydro-Quebec, TransEnergieHQT
Idaho Power CompanyIPCO
Illinois Power CoIP
Illinois Power CoIPRV
Imperial Irrigation DistrictIID
Indianapolis Power & Light CompanyIPL
ISO New England IncISNE
JEAJEA
Kansas City Power & Light, CoKCPL
Lafayette Utilities SystemLAFA
LG&E Energy Transmission ServicesLGEE
Lincoln Electric SystemLES
Los Angeles Department of Water and PowerLDWP
Louisiana Energy & Power AuthorityLEPA
Louisiana Generating, LLCLAGN
Madison Gas and Electric CompanyMGE
Manitoba Hydro Electric Board, Transmission ServicesMHEB
Michigan Electric Coordinated SystemMECS
Start Printed Page 1887
Michigan Electric Coordinated System—CONSCONS
Michigan Electric Coordinated System—DECODECO
MidAmerican Energy CompanyMEC
Midwest ISOMISO
Minnesota Power, IncMP
Montana-Dakota Utilities CoMDU
Muscatine Power and WaterMPW
Nebraska Public Power DistrictNPPD
Nevada Power CompanyNEVP
New Brunswick Power CorporationNBPC
New Horizons Electric CooperativeNHC1
New York Independent System OperatorNYIS
North American Electric Reliability CouncilTEST
Northern Indiana Public Service CompanyNIPS
Northern States Power CompanyNSP
NorthWestern EnergyNWMT
Ohio Valley Electric CorporationOVEC
Oklahoma Gas and ElectricOKGE
Ontario—Independent Electricity Market OperatorIMO
OPPD CA/TPOPPD
Otter Tail Power CompanyOTP
P.U.D. No. 1 of Douglas CountyDOPD
PacifiCorp-EastPACE
PacifiCorp-WestPACW
PJM InterconnectionPJM
Portland General ElectricPGE
Public Service Company of ColoradoPSCO
Public Service Company of New MexicoPNM
Puget Sound Energy TransmissionPSEI
Reedy Creek Improvement DistrictRC
Sacramento Municipal Utility DistrictSMUD
Salt River ProjectSRP
Santee CooperSC
SaskPower Grid Control CentreSPC
Seattle City LightSCL
Seminole Electric CooperativeSEC
Sierra Pacific Power Co.—TransmissionSPPC
South Carolina Electric & Gas CompanySCEG
South Mississippi Electric Power AssociationSME
South Mississippi Electric Power AssociationSMEE
Southeastern Power Administration—HartwellSEHA
Southeastern Power Administration—RussellSERU
Southeastern Power Administration—ThurmondSETH
Southern Company Services, IncSOCO
Southern Illinois Power CooperativeSIPC
Southern Indiana Gas & Electric CoSIGE
Southern Minnesota Municipal Power AgencySMP
Southwest Power PoolSWPP
Southwestern Power AdministrationSPA
Southwestern Public Service CompanySPS
Sunflower Electric Power CorporationSECI
Tacoma PowerTPWR
Tampa Electric CompanyTEC
Tennessee Valley Authority ESOTVA
Trading HubHUB
TRANSLink Management CompanyTLKN
Tucson Electric Power CompanyTEPC
Turlock Irrigation DistrictTIDC
Upper Peninsula Power CoUPPC
Utilities Commission, City of New Smyrna BeachNSB
Westar Energy—MoPEP CitiesMOWR
Western Area Power Administration—Colorado—MissouriWACM
Western Area Power Administration—Lower ColoradoWALC
Western Area Power Administration—Upper Great Plains EastWAUE
Western Area Power Administration—Upper Great Plains WestWAUW
Western Farmers Electric CooperativeWFEC
Western Resources dba Westar EnergyWR
Wisconsin Energy CorporationWEC
Wisconsin Public Service CorporationWPS
Yadkin, IncYAD
* 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.
Start Printed Page 1888

EQR Data Dictionary—Appendix C. Hub

HUBDefinition
ADHUBThe aggregated Locational Marginal Price (“LMP”) nodes defined by PJM Interconnection, LLC as the AEP/Dayton Hub.
AEPGenHubThe aggregated Locational Marginal Price (“LMP”) nodes defined by PJM Interconnection, LLC as the AEPGenHub.
COBThe 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 HubThe aggregated Elemental Pricing nodes (“Epnodes”) nodes defined by the Midwest Independent Transmission System Operator, Inc., as FE Hub (MISO).
Four CornersThe 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).
MeadThe 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.
NIHUBThe aggregated Locational Marginal Price (“LMP”) nodes defined by PJM Interconnection, LLC as the Northern Illinois Hub.
NOBThe set of delivery points along the Nevada-Oregon border commonly identified as and agreed to by the counterparties to constitute the NOB Hub.
NP15The 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.
NWMTThe 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 HubThe aggregated Locational Marginal Price nodes (“LMP”) defined by PJM Interconnection, LLC as the PJM East Hub.
PJM South HubThe aggregated Locational Marginal Price (“LMP”) nodes defined by PJM Interconnection, LLC as the PJM South Hub.
PJM West HubThe aggregated Locational Marginal Price (“LMP”) nodes defined by PJM Interconnection, LLC as the PJM Western Hub.
Palo VerdeThe 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.
SP15The 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.
ZP26The 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 zoneDefinition
ADAtlantic Daylight.
APAtlantic Prevailing.
ASAtlantic Standard.
CDCentral Daylight.
CPCentral Prevailing.
CSCentral Standard.
EDEastern Daylight.
EPEastern Prevailing.
ESEastern Standard.
MDMountain Daylight.
MPMountain Prevailing.
MSMountain Standard.
NANot Applicable.
PDPacific Daylight.
PPPacific Prevailing.
PSPacific Standard.
UTUniversal Time.

EQR Data Dictionary—Appendix E. Units

UnitsDefinition
KVKilovolt.
KVAKilovolt Amperes.
KVRKilovar.
KWKilowatt.
KWHKilowatt Hour.
KW-DAYKilowatt Day.
KW-MOKilowatt Month.
KW-WKKilowatt Week.
KW-YRKilowatt Year.
MVAR-YRMegavar Year.
MWMegawatt.
MWHMegawatt Hour.
MW-DAYMegawatt Day.
MW-MOMegawatt Month.
MW-WKMegawatt Week.
MW-YRMegawatt Year.
RKVAReactive Kilovolt Amperes.
FLAT RATEFlat Rate.
Start Printed Page 1889

EQR Data Dictionary—Appendix F. Rate Units

Rate unitsDefinition
$/KVdollars per kilovolt.
$/KVAdollars per kilovolt amperes.
$/KVRdollars per kilovar.
$/KWdollars per kilowatt.
$/KWHdollars per kilowatt hour.
$/KW-DAYdollars per kilowatt day.
$/KW-MOdollars per kilowatt month.
$/KW-WKdollars per kilowatt week.
$/KW-YRdollars per kilowatt year.
$/MWdollars per megawatt.
$/MWHdollars per megawatt hour.
$/MW-DAYdollars per megawatt day.
$/MW-MOdollars per megawatt month.
$/MW-WKdollars per megawatt week.
$/MW-YRdollars per megawatt year.
$/MVAR-YRdollars per megavar year.
$/RKVAdollars per reactive kilovar amperes.
CENTScents.
CENTS/KVRcents per kilovolt amperes.
CENTS/KWHcents per kilowatt hour.
FLAT RATErate not specified in any other units.
End Supplemental Information

Footnotes

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).

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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).

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4.  Examples cited in EQR Notice at P 3.

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

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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.

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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).

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8.  EQR Notice at P. 18.

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9.  See, for example, Order No. 2001 at P. 95.

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

BILLING CODE 6717-01-P