Notices. Correction
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/register/2007/05/08/07-2304A research copy — for the controlling text, always check the official state or federal source. Not legal advice.
BILLING CODE 3710-08-M DEPARTMENT OF DEFENSE Department of the Army, Corps of Engineers Reissuance of Nationwide Permits; Notice AGENCY: Army Corps of Engineers, DoD. ACTION: Correction. SUMMARY: This document contains corrections to the final notice of issuance of Nationwide Permits
(NWPs)which was published in the ** Federal Register ** on Monday, March 12, 2007 (72 FR 11092—11198). ADDRESSES: U.S. Army Corps of Engineers, Attn: CECW-CO, 441 G Street NW., Washington, DC 20314-1000. FOR FURTHER INFORMATION CONTACT: Mr. David Olson at 202-761-4922 or by e-mail at *david.b.olson@usace.army.mil* or access the U.S. Army Corps of Engineers Regulatory Home Page at *http://www.usace.army.mil/inet/functions/cw/cecwo/reg/.* On page 11172, third column, in the first sentence of the fourth full paragraph (the preamble discussion of the definition of “discharge”), delete the text following the word “clarify” and replace it with the following: “That this term is used in the NWPs to refer to a discharge of dredged or fill material.” Delete the second sentence of this paragraph. On page 11185, first column, in Note 2 of NWP 24, replace the reference to 33 CFR 322.3(a)(2) with 33 CFR 322.4(b). On page 11194, third column, in the last sentence of paragraph
(a)of general condition 27 insert the phrase “until either” between the word “activity” and the colon. In the first sentence of subparagraph (a)(1) of general condition 27, replace the word “Until” with the phrase “He or she is”. In the first sentence of subparagraph (a)(2) of general condition 27, delete the word “If” and replace the number 45 with the words “Forty-five”. On page 11196, second column, in the definition of “discharge”, insert a period after the word “material” and delete the rest of the sentence. Dated: May 3, 2007. Mark F. Sudol, Acting Chief, Operations, Directorate of Civil Works. [FR Doc. E7-8782 Filed 5-7-07; 8:45 am] BILLING CODE 3710-92-P DEPARTMENT OF EDUCATION National Assessment Governing Board; Meeting AGENCY: Department of Education, National Assessment Governing Board. ACTION: Notice; correction. SUMMARY: The National Assessment Governing Board published a document in the **Federal Register** of May 2, 2007, announcing the schedule and proposed agenda of a forthcoming meeting of the National Assessment Governing Board. The meeting agenda has been revised. FOR FURTHER INFORMATION CONTACT: Munira Mwalimu at
(202)357-6906. Correction In the **Federal Register** of May 2, 2007, in FR DOCID: fr02my07-43, Volume 72, Number 84, page 24282, delete the sentence “Assessment Development Committee: Open Session12 p.m. to 3 p.m.” and delete the sentence on page 24282 that reads “On May 17, the Assessment Development Committee will meet in open session from 12 p.m. to 3 p.m.” This meeting of the Assessment Development Committee is cancelled. On page 24282, delete the paragraph that reads “On May 18, the full Board will meet in closed session from 12:15 p.m. to 1:45 p.m. The Board will receive a briefing provided by the National Center for Education Statistics on the NAEP 2006 U.S. History and Civics Report Cards. The Governing Board will be provided with embargoed data that cannot be discussed in an open meeting prior to their official release. The meeting must therefore be conducted in closed session as disclosure of data would significantly impede implementation of The Nation's Report Card initial release activities, as protected by exemption 9(B) of section 552b(c) of Title 5 U.S.C.” Replace this paragraph with the following sentence, “On May 18, the full Board will meet in open session from 12:15 p.m. to 1:45 p.m. to receive a briefing provided by the National Center for Education Statistics on the NAEP 2006 U.S. History and Civics Report Cards.” This session of the Board meeting is now open to the public. *Electronic Access to This Document:* You may view this document, as well as all other documents of this Department published in the **Federal Register** , in text or Adobe Portable Document Format
(PDF)on the Internet at the following site: *http://www.ed.gov/news/fedregister/index.html.* To use PDF you must have Adobe Acrobat Reader, which is available free at this site. If you have questions about using PDF, call the U.S. Government Printing Office (GPO), toll free at 1-888-293-6498; or in the Washington, DC, area at
(202)512-1530. Note: The official version of this document is the document published in the **Federal Register** . Free Internet access to the official edition of the **Federal Register** and the Code of Federal Regulations is available on GPO Access at: *http://www.gpoaccess.gov/nara/index.html.* Dated: May 3, 2007. Charles E. Smith, Executive Director, U.S. Department of Education, National Assessment Governing Board. [FR Doc. E7-8800 Filed 5-7-07; 8:45 am] BILLING CODE 4000-01-P DEPARTMENT OF ENERGY Office of Hearings and Appeals; Proposed Implementation of Special Refund Procedures AGENCY: Office of Hearings and Appeals, Department of Energy. ACTION: Notice of Proposed Implementation of Special Refund Procedures. SUMMARY: The Office of Hearings and Appeals
(OHA)of the Department of Energy
(DOE)announces the proposed procedures for the disbursement of $1,592,901, plus accrued interest, in motor gasoline overcharges obtained by the DOE pursuant to remedial orders issued to Powerine Oil Company, Case No. TEF-0006, and Storey Oil Company, Inc., Case No. TEF-0009. The OHA has tentatively determined that the funds will be distributed in accordance with the provisions of 10 CFR Part 205, Subpart V. DATES: Comments must be filed in duplicate within 30 days of publication of this notice in the **Federal Register** . ADDRESSES: Comments should be addressed to the Office of Hearings and Appeals, Department of Energy, 1000 Independence Ave., SW., Washington, DC 20585-1615. All comments should display a reference to Case Nos. TEF-0006 or TEF-0009. FOR FURTHER INFORMATION CONTACT: Richard A. Cronin, Jr., Assistant Director, Office of Hearings and Appeals, 1000 Independence Ave., SW., Washington, DC 20585-1615,
(202)287-1589, *richard.cronin@hq.doe.gov.* SUPPLEMENTARY INFORMATION: In accordance with 10 CFR 205.282(b), notice is hereby given of the issuance of the Proposed Decision and Order set out below. The Proposed Decision sets forth the procedures that the DOE has tentatively formulated to distribute to eligible claimants $1,592,901, plus accrued interest, obtained by the DOE pursuant to Remedial Orders issued to Powerine Oil Company (Powerine) and Storey Oil Company, Inc. (Storey). The Remedial Orders issued to Powerine and Storey adjudicated allegations concerning violations of the federal petroleum price regulations involving the sale of motor gasoline during the price control period, August 13, 1973 through January 27, 1981. The OHA has proposes to distribute the Remedial Order funds in a refund proceeding described in the Proposed Decision and Order to provide restitution for those parties injured by Powerine or Storey's alleged violations of pricing regulations for motor gasoline. Purchasers of motor gasoline from Powerine or Storey will have the opportunity to submit refund applications. Refunds will be granted to applicants who satisfactorily demonstrate that they were injured by the pricing violations and who document the volume of motor gasoline they purchased from one of the firms during the price control period. Any member of the public may submit written comments regarding the proposed refund procedures. Commenting parties are requested to forward two copies of their submission, within 30 days of the publication of this notice in the **Federal Register** , to the address set forth at the beginning of this notice. Comments so received will be made available for public inspection between the hours of 1 p.m. and 5 p.m., Monday through Friday, except Federal Holidays, in Room 7132 ( the public reference room), 950 L'Enfant Plaza, Washington, DC. Fred L. Brown, Acting Director, Office of Hearings and Appeals. Proposed Decision and Order Department of Energy Implementation of Special Refund Procedures Names of Firms: Powerine Oil Company, Storey Oil Company, Inc. Dates of Filing: June 23, 2005. June 23, 2005. Case Numbers: TEF-0006. TEF-0009. The Office of General Counsel
(OGC)of the Department of Energy
(DOE)filed a Petition requesting that the Office of Hearings and Appeals
(OHA)formulate and implement Subpart V special refund proceedings. Under the procedural regulations of the DOE, special refund proceedings may be implemented to refund monies to persons injured by violations of the DOE petroleum price regulations, provided DOE is unable to readily identify such persons or to ascertain the amount of any refund. 10 CFR 205.280. We have considered OGC's request to formulate refund procedures for the disbursement of monies remitted by Powerine Oil Company (Powerine) and Storey Oil Company (Storey) pursuant to Remedial Orders DOE has issued regarding them and have determined that such procedures are appropriate. Under the terms of the Remedial Orders, Powerine's bankruptcy trustee has remitted a total of $1,546,302 to the DOE to remedy motor gasoline retailer-reseller pricing violations which occurred during the price control period, August 13, 1973 through January 27, 1981. Storey has remitted a total of $46,599 to remedy similar violations. These funds are being held in an escrow account established with the United States Treasury pending a determination of their proper distribution. This Decision sets forth OHA's proposed plan to distribute those funds. The specific application requirements we propose appear in Section III of this Decision. I. Background Powerine was a privately held corporation which operated a refinery located in Santa Fe Springs, California during the price control period. During this period, Storey, operating in Colorado, was a reseller of refined petroleum products. Economic Regulatory Administration audits of Powerine and Storey revealed possible violations of the Mandatory Petroleum Price Regulations
(MPPR)in their sales of motor gasoline. Subsequently, OHA issued Remedial Orders in each case directing Powerine and Storey to remit to the DOE $7,956,934 and $64,639, respectively, in restitution for overcharges by each firm in sales to their customers during the period of price controls. 1 1 See Powerine Oil Company, 21 DOE ¶ 83,008 (1991); Storey Oil Company, Inc., 16 DOE ¶ 83,007 (1987). II. Jurisdiction and Authority The general guidelines that govern OHA's ability to formulate and implement a plan to distribute refunds are set forth at 10 CFR part 205, subpart V. These procedures apply in situations where the DOE cannot readily identify the persons who were injured as a result of actual or alleged violations of the regulations or ascertain the amount of the refund each person should receive. For a more detailed discussion of Subpart V and the authority of the OHA to fashion procedures to distribute refunds, see Office of Enforcement, 9 DOE ¶ 82,508
(1981)and Office of Enforcement, 8 DOE ¶ 82,597 (1981). III. Refund Procedures A. Allocation of Consent Order Funds Both firms' violations of the MPPR involved sales of a refined petroleum product—motor gasoline. Consequently, all of the funds that have been remitted by Powerine and Storey will be allocated for restitution to those parties injured by the firms' alleged violations of the pricing regulations for motor gasoline. B. Refined Petroleum Product Refund Procedures 1. Application Requirements In cases where the ERA is unable to identify parties injured by the alleged overcharges or the specific amounts to which they may be entitled, we normally implement a two-stage refund procedure. In the first stage, those who bought refined petroleum products from the consenting firms may apply for refunds, which are typically calculated on a pro-rata or volumetric basis. In order to calculate the volumetric refund amount, the OHA divides the amount of money available for direct restitution by the number of gallons sold by the firm during the price control period. In the present case, however, we lack much of the information that we normally use to provide direct restitution to injured customers of the consenting firms. In particular, we have been unable to obtain any information on the volumes of motor gasoline products sold by the firms during the price control period. Nor do we have any information concerning the customers of these firms. Based on the present state of the record in these cases, it would be difficult to implement a volumetric refund process. Nevertheless, we will accept any refund claims submitted by persons who purchased motor gasoline from Powerine or Storey during the settlement periods discussed above. We will work with those claimants to develop additional information that would enable us to determine who should receive refunds and in what amounts. 2 2 Applications for Refund will be accepted only for motor gasoline pricing violations. To apply for a refund from the Powerine or Storey Remedial Order funds, a claimant should submit an Application for Refund containing the following information:
(1)Identifying information including the claimant's name, current business address, business address during the refund period, social security number or taxpayer identification number, a statement indicating whether the claimant is an individual, corporation, partnership, sole proprietorship, or other business entity, the name, title, and telephone number of a person to contact for additional information, and the name and address of the person who should receive any refund check; 3 3 An applicant must submit the social security number or employer identification number of the person or legal entity that is seeking the refund. This information will be used in processing refund applications, and is requested pursuant to our authority under the Petroleum Overcharge Distribution and Restitution Act of 1986 and the regulations codified at 10 CFR Part 205, Subpart V. The information may be shared with other Federal agencies for statistical, auditing or archiving purposes, and with law enforcement agencies when they are investigating a potential violation of civil or criminal law.
(2)A monthly motor gasoline gallonage purchase schedule covering the price control order period. The applicant should specify the source of this gallonage information. In calculating its purchase volumes, an applicant should use actual records from the refund period, if available. If these records are not available, the applicant may submit estimates of its motor gasoline purchases, but the estimation method must be reasonable and must be explained;
(3)A statement whether the applicant or a related firm has filed, or has authorized any individual to file on its behalf, any other application in that refund proceeding. If so, an explanation of the circumstances of the other filing or authorization must be submitted;
(4)If the applicant is or was in any way affiliated with Powerine or Storey, it must explain this affiliation, including the time period in which it was affiliated; 4 4 As in other refund proceedings involving alleged refined product violations, the DOE will presume that affiliates of a Remedial Order firm were not injured by the firm's overcharges. See, e.g., Marathon Petroleum Co./EMRO Propane Co., 15 DOE ¶ 85,288 (1987). This is because the Remedial Order firm presumably would not have sold petroleum products to an affiliate if such a sale would have placed the purchaser at a competitive disadvantage. See Marathon Petroleum Co./Pilot Oil Corp., 16 DOE ¶ 85,611 (1987), amended claim denied, 17 DOE ¶ 85,291 (1988), reconsideration denied, 20 DOE ¶ 85,236 (1990). Furthermore, if an affiliate of the Remedial Order firm were granted a refund, the remedial order firm would be indirectly compensated from a Remedial Order fund remitted to settle its own alleged violations.
(5)The statement listed below signed by the individual applicant or a responsible official of the firm filing the refund application: I swear (or affirm) that the information contained in this application and its attachments is true to the best of my knowledge and belief. I understand that anyone who is convicted of providing false information to the federal government may be subject to a fine, a jail sentence, or both, pursuant to 18 U.S.C. 1001. I understand that the information contained in this application is subject to public disclosure. I have enclosed a duplicate of this entire application which will made available at OHA. All applications should be either typed or printed and clearly labeled with the name and case number of the relevant firm (Powerine Oil Company, Case No. TEF-0006 or Storey Oil Company, Inc., Case No. TEF-0009). Each applicant must submit an original and one copy of the application. If the applicant believes that any of the information in its application is confidential and does not wish for that information to be publicly disclosed, it must submit an original application, clearly designated “confidential,” containing the confidential information, and two copies of the application with the confidential information deleted. All refund applications should be sent to the address below: Office of Hearings and Appeals, Department of Energy, 1000 Independence Ave., SW., Washington, DC 20585-0107. We will adopt the standard OHA procedures relating to refund applications filed on behalf of applicants by “representatives,” including refund filing services, consulting firms, accountants, and attorneys. See, e.g., Starks Shell Service, 23 DOE ¶ 85,017 (1993); Texaco Inc., 20 DOE ¶ 85,147
(1990)(Texaco); Shell Oil Co., 18 DOE ¶ 85,492 (1989). We will also require strict compliance with the filing requirements as specified in 10 C.F.R. § 205.283, particularly the requirement that applications and the accompanying certification statement be signed by the applicant. The OHA reiterates its policy to scrutinize applications filed by filing services closely. Applications submitted by a filing service should contain all of the information indicated above. Finally, the OHA reserves the authority to require additional information from an applicant before granting any refund in these proceedings. 2. Allocation Claims We may receive claims based upon Powerine's or Storey's failure to furnish motor gasoline that they were obliged to supply under the DOE allocation regulations that became effective in January 1974. See 10 CFR Part 211. Any such application will be evaluated with reference to the standards set forth in Texaco (and cases cited therein). See Texaco, 20 DOE at 88,321. 3. Impact of the Petroleum Overcharge Distribution and Restitution Act of 1986 (PODRA) Amendments on Powerine and Storey Refined Product Refund Claims The Interior and Related Agencies Appropriations Act for FY 1999 amended certain provisions of the Petroleum Overcharge and Distribution and Restitution Act of 1986 (PODRA). These amendments extinguished rights that refund applicants had under PODRA to refunds for overcharges on the purchases of refined petroleum products. They also identified and appropriated a substantial portion of the funds being held by the DOE to pay refund claims (including the funds paid by Powerine and Storey). Congress specified that these funds were to be used to fund other DOE programs. As a result, the petroleum overcharge escrow accounts in the refined product area contain substantially less money than before. In fact they may not contain sufficient funds to pay in full all pending and future refund claims (including those in litigation) if they should all be found to be meritorious. See Enron Corp./Shelia S. Brown, 27 DOE ¶ 85,036 at 88,244
(2000)(Brown). Congress directed OHA to “assure the amount remaining in escrow to satisfy refined petroleum product claims for direct restitution is allocated equitably among all claimants.” Omnibus Consolidated and Emergency Supplemental Appropriation Act, 1999, Pub. L. No. 105-277 § 337, 112 Stat 2681, 2681-295
(1998)(language added to PODRA); Brown, 27 DOE at 88,244. In view of this Congressional directive and the limited amount of funds available, it may become necessary to prorate the funds available for the meritorious claimants in the Powerine and Storey refund proceedings. *It is therefore ordered that:* The payments remitted to the Department of Energy by Powerine Oil Company and Storey Oil Company, Inc., pursuant to remedial orders signed on August 30, 1991 and June 24, 1987 respectively, will be distributed in accordance with the forgoing Decision. [FR Doc. E7-8771 Filed 5-7-07; 8:45 am] BILLING CODE 6450-01-P DEPARTMENT OF ENERGY Office of Energy Efficiency and Renewable Energy Energy Efficiency Building Technology Application Centers AGENCY: Office of Energy Efficiency and Renewable Energy, Department of Energy. ACTION: Program notice. SUMMARY: The National Energy Technology Laboratory, on behalf of the Office of Energy Efficiency and Renewable Energy's Building Technologies Program, intends to issue a Funding Opportunity Announcement
(FOA)to select and fund Energy-Efficient Building Technology Application Centers. This FOA is expected to be issued on or about May 15, 2007. The goal of this funding opportunity is to establish geographically and climatically diverse Energy-Efficient Building Technology Application Centers. This goal supports the EERE Strategic Plan to increase the energy efficiency of the Nation's buildings and the Building Technology Program's Technology Validation and Market Introduction activity goal of accelerating the widespread market adoption of energy-efficient building technologies and practices. It also encourages demonstration and commercial application of advanced energy methods and technologies through education and outreach to building and industry professionals, and other individuals and organizations with an interest in efficient energy use. FOR FURTHER INFORMATION CONTACT: James Rannels, U.S. Department of Energy, Office of Energy Efficiency and Renewable Energy, Program Office EE-2J, 1000 Independence Avenue, SW., Washington, DC 20585-0121,
(202)586-8070, E-mail: *James.Rannels@ee.doe.gov.* C. Edward Christy, National Energy Technology Laboratory, 3610 Collins Ferry Road, M/S E-02, Morgantown, WV 26507,
(304)285-4604, E-mail: *Eddie.Christy@netl.doe.gov.* Dated: May 2, 2007. C. Edward Christy, Director, Building and Industrial Technologies Division. [FR Doc. E7-8788 Filed 5-7-07; 8:45 am] BILLING CODE 6450-01-P DEPARTMENT OF ENERGY Federal Energy Regulatory Commission [Docket No. IC07-555-000; FERC-555] Commission Information Collection Activities, Proposed Collection; Comment Request; Extension May 1, 2007. AGENCY: Federal Energy Regulatory Commission, DOE. ACTION: Notice. SUMMARY: In compliance with the requirements of section 3506(c)(2)(a) of the Paperwork Reduction Act of 1995 (Pub. L. No. 104-13), the Federal Energy Regulatory Commission (Commission) is soliciting public comment on the specific aspects of the information collection described below. DATES: Comments on the collection of information are due July 13, 2007. ADDRESSES: For more information on the records retention requirements, the public can view the Commission's regulations on the Commission's Web site ( *http://www.ferc.gov/legal/maj-ord-reg.asp* ) or contacting the Federal Energy Regulatory Commission, Attn: Michael Miller, Office of the Executive Director, ED-34, 888 First Street NE., Washington, DC 20426. Comments may be filed either in paper format or electronically. Those parties filing electronically do not need to make a paper filing. For paper filing, the original and 14 copies of such comments should be submitted to the Secretary of the Commission, Federal Energy Regulatory Commission, 888 First Street, NE., Washington, DC 20426 and refer to Docket No. IC07-555-000. Documents filed electronically via the Internet must be prepared in WordPerfect, MS Word, Portable Document Format, or ASCII format. To file the document, access the Commission's Web site at *http://www.ferc.gov* and click on “Make an E-filing”, and then follow the instructions for each screen. First time users will have to establish a user name and password. The Commission will send an automatic acknowledgement to the sender's e-mail address upon receipt of comments. All comments may be viewed, printed or downloaded remotely via the Internet through FERC's homepage using the eLibrary link. For user assistance, contact *FERCOlineSupport@ferc.gov* or toll-free at
(866)208-3676. or for TTY, contact
(202)502-8659. FOR FURTHER INFORMATION CONTACT: Michael Miller may be reached by telephone at
(202)502-8415, by fax at (202)273-0873, and by e-mail at *michael.miller@ferc.gov.* SUPPLEMENTARY INFORMATION: The information collected under the requirements of FERC-555 “Records Retention Requirements” (OMB No. 1902-0098) is used by the Commission to carry out its responsibilities in implementing the statutory provisions of sections 301, 304 and 309 of the Federal Power Act
(FPA)(16 U.S.C. 825, 825c and 825h), sections 8, 10 and 16 of the Natural Gas Act
(NGA)(15 U.S.C. 717-717w), and section 20 of the Interstate Commerce Act (ICA, 49 U.S.C. 20). The regulations for preservation of records establish retention periods, necessary guidelines and requirements to sustain retention of applicable records for the regulated public utilities, natural gas and oil pipeline companies subject to the Commission's jurisdiction. These records will be used by the regulated companies as the basis for their required rate filings and reports for the Commission. In addition, the records will be used by the Commission's audit staff during compliance reviews, by enforcement staff during investigations and for special analyses as deemed necessary by the Commission. The records retained by jurisdictional companies as directed by the Commission are the result of a mandatory requirement. On January 8, 1999 the Commission issued AI99-2-000, an Accounting Issuance providing guidance on records storage media. Specifically, FERC gave each jurisdictional company the flexibility to select its own storage media. The storage media selected must have a life expectancy equal to the applicable record period unless the quality of the data transferred from one media to another with no loss of data would exceed the record period. On January 27, 2000, FERC issued a final rule amending its records retention regulations for public utilities and licensees, and natural gas and oil pipeline companies. These changes included revising the general instructions, and shortening various records retention periods. The final rule's objective was to reduce or eliminate burdensome and unnecessary regulatory requirements. It has been more than seven years since the issuance of the final rule and the accounting guidance, and jurisdictional companies have experienced more than sufficient time to implement these provisions. In responding to this notice, the Commission seeks information on whether jurisdictional companies have obtained substantial reductions in the recordkeeping burden for maintaining their records under the revised retention periods and the use of alternative storage media. Further, the Commission is interested in learning if and what savings were achieved by jurisdictional companies by freeing up storage space formerly used for retaining records. The Commission implements these filing requirements in the Code of Federal Regulations
(CFR)under 18 CFR parts 125, 225, and 356. *Action:* The Commission is requesting a three-year extension of the current expiration date, with no changes to the existing collection of data. *Burden Statement:* Public reporting burden for this collection is estimated as: Number of respondents annually Number of responses per respondent Average burden hours per response Total annual burden hours
(3)(1)x(2)x(3) 515 1 2,402 1,237,030 Estimated cost burden to respondents is $141,045. (1,237,030 hours/2080 hours per year times $122,137 per year average per employee = $ 72,638,045). The cost per respondent is $ 141,045). The reporting burden includes the total time, effort, or financial resources expended to generate, maintain, retain, disclose, or provide the information including:
(1)Reviewing instructions;
(2)developing, acquiring, installing, and utilizing technology and systems for the purposes of collecting, validating, verifying, processing, maintaining, disclosing and providing information;
(3)adjusting the existing ways to comply with any previously applicable instructions and requirements;
(4)training personnel to respond to a collection of information;
(5)searching data sources;
(6)completing and reviewing the collection of information; and
(7)transmitting, or otherwise disclosing the information. The estimate of cost for respondents is based upon salaries for professional and clerical support, as well as direct and indirect overhead costs. Direct costs include all costs directly attributable to providing this information, such as administrative costs and the cost for information technology. Indirect or overhead costs are costs incurred by an organization in support of its mission. These costs apply to activities, which benefit the whole organization rather than any one particular function or activity. Comments are invited on:
(1)Whether the proposed collection of information is necessary for the proper performance of the functions of the Commission, including whether the information will have practical utility;
(2)the accuracy of the agency's estimate of the burden of the proposed collection of information, including the validity of the methodology and assumptions used;
(3)ways to enhance the quality, utility and clarity of the information to be collected; and
(4)ways to minimize the burden of the collection of information on those who are to respond, including the use of appropriate automated, electronic, mechanical, or other technological collection techniques or other forms of information technology *e.g.* permitting electronic submission of responses. Kimberly D. Bose, Secretary. [FR Doc. E7-8701 Filed 5-7-07; 8:45 am] BILLING CODE 6717-01-P DEPARTMENT OF ENERGY Federal Energy Regulatory Commission [Project No. 11291-023] Star Mill, Inc.; Notice of Termination of License by Implied Surrender May 1, 2007. Take notice that the following hydroelectric proceeding has been initiated by the Commission: a. *Proceeding Type:* Termination of License by Implied Surrender. b. *Project No:* 11291-023. c. *Date Initiated:* October 18, 2006. d. *Licensee:* Star Mill, Inc. e. *Name of Project:* Star Milling and Electric Minor Water Power Project (Star Milling). f. *Location:* On Fawn River in LaGrange County, near the town of Howe, Indiana. g. *Proceeding Initiated Pursuant to:* 18 CFR 6.4. h. *FERC Contact:* Diane M. Murray, Telephone:
(202)502-8838 and e-mail: *diane.murray@ferc.gov* . i. *Deadline for filing comments and or motions:* June 1, 2007. *All documents (original and eight copies) should be filed with:* Secretary, Federal Energy Regulatory Commission, 888 First Street, NE., Washington, DC 20426. Please include the project number (P-11291-023) on any comments. j. *Description of Proceeding:* Because of the licensee's failure to live up to the obligations of its license, the Commission considers this inaction an implied surrender of the license. By letter dated October 18, 2006, the Commission gave the licensee notice of its intent to accept the surrender of the license for the Star Milling Project. k. *Locations of the Letter:* A copy of the letter is available for inspection and reproduction at the Commission's Public Reference Room, located at 888 First Street, NE., Room 2A, Washington, DC 20426, or by calling
(202)502-8371. This filing may also be viewed on the Commission's Web site at *http://www.ferc.gov* using the “eLibrary” link. Enter the docket number excluding the last three digits in the docket number field to access the document. You may also register online at *http://www.ferc.gov/docs-filing/esubscription.asp* to be notified via e-mail of new filings and issuances related to this or other pending projects. For assistance, call toll-free 1-866-208-3676 or e-mail *FERCOnlineSupport@ferc.gov* . For TTY, call
(202)502-8659. l. Individuals desiring to be included on the Commission's mailing list should so indicate by writing to the Secretary of the Commission. m. Comments, Protests, or Motions to Intervene—Anyone may submit comments, a protest, or a motion to intervene in accordance with the requirements of Rules of Practice and Procedure, 18 CFR 385.210, .211, .214. In determining the appropriate action to take, the Commission will consider all protests or other comments filed, but only those who file a motion to intervene in accordance with the Commission's Rules may become a party to the proceeding. Any comments, protests, or motions to intervene must be received on or before the specified comment date for the particular proceeding. n. Any filings must bear in all capital letters the title “COMMENTS”, “RECOMMENDATIONS FOR TERMS AND CONDITIONS”, “PROTESTS”, or “MOTIONS TO INTERVENE”, as applicable, and the Project Number of the particular proceeding to which the filing refers. o. Agency Comments—Federal, state, and local agencies are invited to file comments on the described proceeding. If an agency does not file comments within the time specified for filing comments, it will be presumed to have no comments. p. Comments, protests, and interventions may be filed electronically via the Internet in lieu of paper. See, 18 CFR 385.2001(a)(1)(iii) and the instructions on the Commission's Web site at *http://www.ferc.gov* under the “e-Filing” link. Kimberly D. Bose, Secretary. [FR Doc. E7-8702 Filed 5-7-07; 8:45 am] BILLING CODE 6717-01-P DEPARTMENT OF ENERGY Federal Energy Regulatory Commission Combined Notice of Filings # 1 May 1, 2007. Take notice that the Commission received the following electric rate filings: *Docket Numbers:* ER01-537-002; ER01-538-001. *Applicants:* Westmoreland Partners (ROVA I); Westmoreland Partners (ROVA II). *Description:* Triennial Updated Market Power Analysis of Westmoreland Partners et al. *Filed Date:* 4/30/2007. *Accession Number:* 20070430-5204. *Comment Date:* 5 p.m. Eastern Time on Monday, May 21, 2007. *Docket Numbers:* ER04-374-006; ER05-717-006; ER05-721-006; ER99-2341-008; ER06-230-003; ER06-1334-003; ER07-277-001. *Applicants:* Judith Gap Energy LLC; Spring Canyon Energy LLC; Invenergy TN LLC; Hardee Power Partners Limited; Wolverine Creek Energy LLC; Spindle Hill Energy LLC; Invenergy Cannon Falls LLC. *Description:* Spring Canyon Energy LLC, Judith Gap Energy LLC, and Invenergy TN LLC submit a notice of change in status under its market-based rate authority. *Filed Date:* 4/27/2007. *Accession Number:* 20070501-0288. *Comment Date:* 5 p.m. Eastern Time on Friday, May 18, 2007. *Docket Numbers:* ER06-1355-002. *Applicants:* Evergreen Wind Power, LLC. *Description:* Evergreen Wind Power LLC submit a change in status with respect to the characteristics upon which the Commission previously relied when granting its market-based rate authority and submit an errata on 4/27/07. *Filed Date:* 04/25/2007; 04/27/2007. *Accession Number:* 20070427-0037; 20070427-5017. *Comment Date:* 5 p.m. Eastern Time on Wednesday, May 16, 2007. *Docket Numbers:* ER07-485-001. *Applicants:* Southern Company Services, Inc. *Description:* Southern Company Services, Inc agent for Alabama Power Company et al submits materials in response to Commission's 3/28/07 letter order. *Filed Date:* 4/27/2007. *Accession Number:* 20070430-0182. *Comment Date:* 5 p.m. Eastern Time on Friday, May 18, 2007. *Docket Numbers:* ER07-579-002. *Applicants:* Midwest Independent Transmission System Operator, Inc. *Description:* Midwest Independent Transmission System Operator Inc submits executed amended and restated generator interconnection agreement with Michigan Electric Transmission Company, LLC et al. *Filed Date:* 4/26/2007. *Accession Number:* 20070427-0044. *Comment Date:* 5 p.m. Eastern Time on Thursday, May 17, 2007. *Docket Numbers:* ER07-591-001. *Applicants:* Exel Power Sources, LLC. *Description:* Exel Power Sources, LLC submits its Petition for acceptance of Initial Tariff, Waivers and Blanket Authority and request for acceptance of FERC Electric Tariff, Original Volume 1 etc. *Filed Date:* 4/10/2007. *Accession Number:* 20070412-0087. *Comment Date:* 5 p.m. Eastern Time on Thursday, May 10, 2007. *Docket Numbers:* ER07-705-001. *Applicants:* GSG, LLC. *Description:* GSG, LLC submits an amendment to its application for Order Accepting Market-Based Rate Tariff, Granting Authorizations and Blanket Authority, and Waiving Certain Requirements. *Filed Date:* 4/27/2007. *Accession Number:* 20070427-5021. *Comment Date:* 5 p.m. Eastern Time on Friday, May 18, 2007. *Docket Numbers:* ER07-785-000. *Applicants:* American Electric Power Service Corporation. *Description:* American Electric Power Service Corporation agent for AEP Operating Companies submits a first revision to the Interconnection and Local Delivery Service agreement 1425 with Village of Plymouth. *Filed Date:* 4/25/2007. *Accession Number:* 20070426-0170. *Comment Date:* 5 p.m. Eastern Time on Wednesday, May 16, 2007. *Docket Numbers:* ER07-792-000. *Applicants:* New York Independent System Operator, Inc. *Description:* New York Independent System Operator Inc submits proposed amendments to its Market Administration and Control Area Services Tariff and its Open Access Transmission Tariff etc. *Filed Date:* 4/25/2007. *Accession Number:* 20070427-0034. *Comment Date:* 5 p.m. Eastern Time on Wednesday, May 16, 2007. *Docket Numbers:* ER07-793-000. *Applicants:* Perryville Energy Partners, L.L.C. *Description:* Perryville Energy Partners, LLC informs FERC that it will not file revisions to the Pro Form Open Access Transmission Tariff addressed in the Commission's Order 890 etc. *Filed Date:* 4/25/2007. *Accession Number:* 20070427-0038. *Comment Date:* 5 p.m. Eastern Time on Wednesday, May 16, 2007. *Docket Numbers:* ER07-794-000. *Applicants:* Attala Transmission, LLC. *Description:* Attala Transmission LLC informs FERC they will not file the revisions to the pro forma Open Access Transmission Tariff addressed in FERC's Order 890 etc. *Filed Date:* 4/25/2007. *Accession Number:* 20070427-0035. *Comment Date:* 5 p.m. Eastern Time on Wednesday, May 16, 2007. *Docket Numbers:* ER07-795-000. *Applicants:* California Independent System Operator Corporation. *Description:* California Independent System Operator Corporation submits informational filing intended to provide notice re the revised transmission Access Changes effective 1/1/07. *Filed Date:* 4/26/2007. *Accession Number:* 20070427-0033. *Comment Date:* 5 p.m. Eastern Time on Thursday, May 17, 2007. *Docket Numbers:* ER07-796-000. *Applicants:* New England Participating Transmission Owners. *Description:* New England Participating Transmission Owners submits proposed revisions to the revenue requirement formulas for transmission services set forth in the Attachment F, Annual Transmission Revenue Requirements etc. *Filed Date:* 4/26/2007. *Accession Number:* 20070427-0036. *Comment Date:* 5 p.m. Eastern Time on Thursday, May 17, 2007. *Docket Numbers:* ER07-797-000. *Applicants:* American Electric Power Service Corporation. *Description:* American Electric Power Service Corp on behalf of AEP Operating Companies submits the first revision to the Interconnection and Local Delivery Service Agreement with the Village of Wharton. *Filed Date:* 4/26/2007. *Accession Number:* 20070430-0157. *Comment Date:* 5 p.m. Eastern Time on Thursday, May 17, 2007. *Docket Numbers:* ER07-798-000. *Applicants:* American Electric Power Service Corporation. *Description:* American Electric Power Service Corp on behalf of AEP Operating Companies submits the first revision to the Interconnection and Local Delivery Service Agreement with the City of Clyde. *Filed Date:* 4/26/2007. *Accession Number:* 20070430-0158. *Comment Date:* 5 p.m. Eastern Time on Thursday, May 17, 2007. *Docket Numbers:* ER07-799-000. *Applicants:* Norwalk Power LLC. *Description:* Norwalk Power LLC submits unexecuted cost-of-service agreement with NRG Power Marketing Inc and ISO New England Inc. *Filed Date:* 4/26/2007. *Accession Number:* 20070430-0188. *Comment Date:* 5 p.m. Eastern Time on Thursday, May 17, 2007. *Docket Numbers:* ER07-800-000. *Applicants:* American Electric Power Service Corp. *Description:* American Electric Power Service Corporation, as designated agent for AEP Operating Companies submits a first revision to the Interconnection & Local Delivery Service Agreement 1419 with Village of Cary. *Filed Date:* 4/26/2007. *Accession Number:* 20070430-0160. *Comment Date:* 5 p.m. Eastern Time on Thursday, May 17, 2007. *Docket Numbers:* ER07-801-000. *Applicants:* Wisconsin Electric Power Company. *Description:* Letter to Remove Umbrella Agreements by Wisconsin Electric Power Company under ER07-801. *Filed Date:* 4/18/2007. *Accession Number:* 20070418-5020. *Comment Date:* 5 p.m. Eastern Time on Wednesday, May 9, 2007. *Docket Numbers:* ER07-802-000. *Applicants:* MEP Clarksdale Power, LLC. *Description:* MEP Clarksdale Power, LLC submits a notice of cancellation of its FERC Electric Tariffs. *Filed Date:* 4/27/2007. *Accession Number:* 20070430-0159. *Comment Date:* 5 p.m. Eastern Time on Friday, May 18, 2007. *Docket Numbers:* ER07-803-000. *Applicants:* Consolidated Edison Co. of New York, Inc. *Description:* Consolidated Edison Company of New York, Inc submits the Revised and Restated Interconnection Agreement with the Power Authority of the State of New York, dated 5/1/07. *Filed Date:* 4/27/2007. *Accession Number:* 20070430-0196. *Comment Date:* 5 p.m. Eastern Time on Tuesday, May 8, 2007. *Docket Numbers:* ER07-804-000. *Applicants:* Xcel Energy Operating Companies. *Description:* Xcel Energy Services, Inc submits the Master Transmission to Load Interconnection Agreement between Northern States Power Co and Great River. *Filed Date:* 4/27/2007. *Accession Number:* 20070430-0185. *Comment Date:* 5 p.m. Eastern Time on Friday, May 18, 2007. *Docket Numbers:* ER07-813-000. *Applicants:* Midwest Independent Transmission System Operator, Inc. *Description:* Midwest Independent Transmission System Operator Inc submits its proposed revisions to Sheet 207 of the Midwest ISO's Open Access Transmission and Energy Markets Tariff. *Filed Date:* 4/23/2007. *Accession Number:* 20070425-0161. *Comment Date:* 5 p.m. Eastern Time on Monday, May 14, 2007. Take notice that the Commission received the following electric securities filings: *Docket Numbers:* ES07-33-000. *Applicants:* Entergy Mississippi, Inc. *Description:* Form 523—Application of Entergy Mississippi, Inc. for Authorization to issue and sell preferred stock and long-term debt securities during the two-year period ending 6/30/99. *Filed Date:* 04/30/2007. *Accession Number:* 20070430-5037. *Comment Date:* 5 p.m. Eastern Time on Monday, May 21, 2007. *Docket Numbers:* ES07-34-000. *Applicants:* System Energy Resources, Inc. *Description:* Form 523—Application of System Energy Resources, Inc. for authorization to issue and sell long-term securities during two-year period ending June 30, 2009. *Filed Date:* 4/30/2007. *Accession Number:* 20070430-5039. *Comment Date:* 5 p.m. Eastern Time on Monday, May 21, 2007. *Docket Numbers:* ES07-35-000. *Applicants:* Entergy Gulf States Louisiana, L.L.C. *Description:* Application by Entergy Gulf States Louisiana, L.L.C. for Authorization to Issue Securities in ES07-35. *Filed Date:* 4/30/2007. *Accession Number:* 20070430-5116. *Comment Date:* 5 p.m. Eastern Time on Monday, May 21, 2007. *Docket Numbers:* ES07-36-000. *Applicants:* Entergy Texas, Inc. *Description:* Application by Entergy Texas, Inc. for Authorization to Issue Securities in ES07-36. *Filed Date:* 4/30/2007. *Accession Number:* 20070430-5120. *Comment Date:* 5 p.m. Eastern Time on Monday, May 21, 2007. Take notice that the Commission received the following public utility holding company filings: *Docket Numbers:* PH0711-000. *Applicants:* General Electric Company; General Electric Capital Services, Inc.; General Electric Capital Corporation; General Electric Credit Corporation of Tennessee; EFS Cogen Holdings I LLC; East Coast Power, LLC; East Coast Power Linden Holdings, LLC; East Coast Power Linden, Inc.; East Coast Power Linden GP, LLC; Linden VFT Holding, LLC; GE Structured Finance Inc.; GPSF Securities, Inc.; GESF Birchwood-GP LLC; Aircraft Services Corporation; EFS-SSCC Holdings, Inc.; Fox Energy OP, L.P.; GE Capital CALGEN; GE Energy Holdings, Inc; SFG-J Inc.; Lake Benton Power Associates LLC; Lake Benton Holdings LLC; SFG-M Inc.; Storm Lake II Power Associates LLC; Storm Lake II Holdings LLC; Source Gas Holdings LLC; Southern Star Central Corp. *Description:* FERC Form 65 A Exemption Notification of General Electric Energy Financial Services. *Filed Date:* 4/27/2007. *Accession Number:* 20070427-5053. *Comment Date:* 5 p.m. Eastern Time on Friday, May 18, 2007. Any person desiring to intervene or to protest in any of the above proceedings must file in accordance with Rules 211 and 214 of the Commission's Rules of Practice and Procedure (18 CFR 385.211 and 385.214) on or before 5 p.m. Eastern time on the specified comment date. It is not necessary to separately intervene again in a subdocket related to a compliance filing if you have previously intervened in the same docket. Protests will be considered by the Commission in determining the appropriate action to be taken, but will not serve to make protestants parties to the proceeding. Anyone filing a motion to intervene or protest must serve a copy of that document on the Applicant. In reference to filings initiating a new proceeding, interventions or protests submitted on or before the comment deadline need not be served on persons other than the Applicant. The Commission encourages electronic submission of protests and interventions in lieu of paper, using the FERC Online links at *http://www.ferc.gov.* To facilitate electronic service, persons with Internet access who will eFile a document and/or be listed as a contact for an intervenor must create and validate an eRegistration account using the eRegistration link. Select the eFiling link to log on and submit the intervention or protests. Persons unable to file electronically should submit an original and 14 copies of the intervention or protest to the Federal Energy Regulatory Commission, 888 First St., NE., Washington, DC 20426. The filings in the above proceedings are accessible in the Commission's eLibrary system by clicking on the appropriate link in the above list. They are also available for review in the Commission's Public Reference Room in Washington, DC. There is an eSubscription link on the Web site that enables subscribers to receive e-mail notification when a document is added to a subscribed dockets(s). For assistance with any FERC Online service, please e-mail *FERCOnlineSupport@ferc.gov.* or call
(866)208-3676 (toll free). For TTY, call
(202)502-8659. Kimberly D. Bose, Secretary. [FR Doc. E7-8731 Filed 5-7-07; 8:45 am] BILLING CODE 6717-01-P DEPARTMENT OF ENERGY Federal Energy Regulatory Commission [Project No. 516-445] South Carolina Electric & Gas Company; Notice of Application for Amendment of License and Soliciting Comments, Motions To Intervene, and Protests May 1, 2007. Take notice that the following hydroelectric application has been filed with the Commission and is available for public inspection: a. *Application Type:* Amendment of License to Transfer Interests in Project Lands. b. *Project No:* 516-445. c. *Date Filed:* April 16, 2007. d. *Applicant:* South Carolina Electric & Gas Company. e. *Name of Project:* Saluda Hydroelectric Project. f. *Location:* The project is located on the Saluda and Congaree Rivers, in Lexington, Newberry, Richland, and Saluda Counties, South Carolina. The project does not occupy any Federal or tribal lands. g. *Filed Pursuant to:* Federal Power Act, 16 U.S.C. 791a-825r. h. *Applicant Contact:* Mr. J. Hagood Hamilton, Senior Counsel, SCANA Corporation, Columbia, SC 29218, Telephone
(803)217-8938, e-mail *hhamilton@scana.com* . i. *FERC Contact:* Christopher Yeakel, Telephone
(202)502-8132, and e-mail: *christopher.yeakel@ferc.gov* . j. *Deadline for filing comments, motions to intervene, and protest:* June 1, 2007. *All documents (original and eight copies) should be filed with:* Secretary, Federal Energy Regulatory Commission, 888 First Street, NE., Washington, DC 20426. The Commission's Rules of Practice and Procedure require all interveners filing documents with the Commission to serve a copy of that document on each person whose name appears on the official service list for the project. Further, if an intervener files comments or documents with the Commission relating to the merits of an issue that may affect the responsibilities of a particular resource agency, they must also serve a copy of the document on that resource agency. A copy of any motion to intervene must also be served upon each representative of the Applicant specified in the particular application. k. *Description of Request:* The licensee proposes to transfer fee simple interest in a 36 acre tract of land located within the project boundary along the western bank of the Saluda River in Newberry County, South Carolina, southwest of the intersection of routes 34 and 121 at the Deadfall Crossroads. In exchange for the interest in the 36 acre tract, the licensee will receive fee title to a tract of land 150 feet wide and approximately 1.25 miles long, running adjacent to the western bank of the Saluda River, to which the licensee currently only has flowage rights. l. *Locations of the Application:* A copy of the application is available for inspection and reproduction at the Commission's Public Reference Room, located at 888 First Street, NE., Room 2A, Washington, DC 20426, or by calling
(202)502-8371. This filing may also be viewed on the Commission's Web site at *http://www.ferc.gov* using the “eLibrary” link. Enter the docket number excluding the last three digits in the docket number field to access the document. You may also register online at *http://www.ferc.gov/docs-filing/esubscription.asp* to be notified via e-mail of new filings and issuances related to this or other pending projects. For assistance, call 1-866-208-3676 or e-mail *FERCOnlineSupport@ferc.gov* , for TTY, call
(202)502-8659. A copy is also available for inspection and reproduction at the address in item
(h)above. m. Individuals desiring to be included on the Commission's mailing list should so indicate by writing to the Secretary of the Commission. n. *Comments, Protests, or Motions to Intervene:* Anyone may submit comments, a protest, or a motion to intervene in accordance with the requirements of Rules of Practice and Procedure, 18 CFR 385.210, .211, .214. In determining the appropriate action to take, the Commission will consider all protests or other comments filed, but only those who file a motion to intervene in accordance with the Commission's Rules may become a party to the proceeding. Any comments, protests, or motions to intervene must be received on or before the specified comment date for the particular application. o. Any filings must bear in all capital letters the title “COMMENTS”, “PROTEST”, or “MOTION TO INTERVENE”, as applicable, and the Project Number of the particular application to which the filing refers (P-516-445). p. *Agency Comments:* Federal, state, and local agencies are invited to file comments on the described application. A copy of the application may be obtained by agencies directly from the Applicant. If an agency does not file comments within the time specified for filing comments, it will be presumed to have no comments. One copy of an agency's comments must also be sent to the Applicant's representatives. q. Comments, protests and interventions may be filed electronically via the Internet in lieu of paper. See 18 CFR 385.2001(a)(1)(iii) and the instructions on the Commission's Web site at *http://www.ferc.gov* under the “e-Filing” link. Kimberly D. Bose, Secretary. [FR Doc. E7-8699 Filed 5-7-07; 8:45 am] BILLING CODE 6717-01-P DEPARTMENT OF ENERGY Federal Energy Regulatory Commission [Docket No. CP07-8-000] Guardian Pipeline, L.L.C; Notice of the Change in Location of the Public Comment Meetings for the Guardian Expansion and Extension Project Draft Environmental Impact Statement May 1, 2007. On April 13, 2007, the staff of the Federal Energy Regulatory Commission (FERC or Commission) issued a draft Environmental Impact Statement
(EIS)for the Guardian Expansion and Extension Project, proposed by Guardian Pipeline, L.L.C. Issuance of the draft EIS began a 45-day public comment period which will end on May 29, 2007. In addition to accepting written comments on the draft EIS, the Commission staff will be hosting public comment meetings in the project area to accept oral comments as listed in the following table. Public meeting date and time Location Tuesday, May 15, 2007 at 7 p.m.
(CST)Olympia Resort and Conference Center, 1350 Royale Mile Road, Oconomowoc, WI 53066, Phone:
(262)369-4999. Wednesday, May 16, 2007 at 7 p.m.
(CST)Bauer Ramada Plaza Hotel, 1 North Main St., Fond du Lac, WI 54935, Phone:
(920)923-3000. Thursday, May 17, 2007 at 7 p.m.
(CST)Regency Suites and Conference Center Downtown Green Bay, 333 Main St., Green Bay, WI 54301, Phone:
(920)432-4555. Comment Procedure Instructions for submitting written comments are included in the draft EIS and the Notice of Availability that were issued on April 13, 2007. These documents can be found on the FERC Internet Web site as discussed below. Oral comments presented at the public comment meetings will be given the same consideration as written comments received by mail before the close of the public comment period on May 29, 2007. As with previous public meetings on the Guardian Expansion and Extension Project, attendees will be asked to provide their name and address so that any project-related environmental information issued by the Commission may be mailed to all attendees. Additionally, those wishing to provide oral comments will be asked to put their name on a Speakers List. Depending on the number of individuals wishing to provide oral comments, speakers may be asked to limit their presentations to 5 minutes in order that all speakers may be accommodated. Transcripts of the public comment meetings will be prepared and placed into the FERC's public record. Additional information about the project is available from the Commission's Office of External Affairs, at 1-866-208-FERC or on the FERC Internet Web site ( *http://www.ferc.gov* ) using the eLibrary link. Click on the eLibrary link, click on “General Search” and enter the docket number excluding the last three digits in the Docket Number field. Be sure you have selected an appropriate date range. For assistance, please contact FERC Online Support at *FERCOnlineSupport@ferc.gov* or toll free at 1-866-208-3676, or for TTY, contact
(202)502-8659. The eLibrary link on the FERC Internet Web site also provides access to the texts of formal documents issued by the Commission, such as orders, notices, and rulemakings. Kimberly D. Bose, Secretary. [FR Doc. E7-8703 Filed 5-7-07; 8:45 am] BILLING CODE 6717-01-P DEPARTMENT OF ENERGY Federal Energy Regulatory Commission [Docket No. RM01-8-006] Revised Public Utility Filing Requirements for Electric Quarterly Reports April 23, 2007. AGENCY: Federal Energy Regulatory Commission. ACTION: Notice Seeking Comments on Proposed Electric Quarterly Report
(EQR)Data Dictionary. SUMMARY: In this notice, the Federal Energy Regulatory Commission (Commission) proposes to adopt an EQR Data Dictionary to define the terms and values used in filing EQR data, and invites comments on this proposal. DATES: Comments on the proposal are due June 7, 2007. ADDRESSES: You may submit comments on the proposal, identified by Docket No. RM01-8-006, by one of the following methods: • *Agency Web Site: http://www.ferc.gov* . Follow the instructions for submitting comments via the eFiling link found in the Comment Procedures Section of the preamble. • *Mail:* Commenters unable to file comments electronically must mail or hand deliver an original and 14 copies of their comments to the Federal Energy Regulatory Commission, Secretary of the Commission, 888 First Street, NE., Washington, DC 20426. Please refer to the Comment Procedures Section of the preamble for additional information on how to file paper comments. 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 First Street, NE., Washington, DC 20426,
(202)502-8321. SUPPLEMENTARY INFORMATION: 1. The Commission is proposing to adopt an Electric Quarterly Report
(EQR)Data Dictionary that will define the terms and values used in filing EQR data. 1 In this notice, the Commission attaches a draft EQR Data Dictionary and invites comment on whether this document should be adopted or modified. 1 We are also proposing to change three field names to reflect terminology adopted by the North American Electric Reliability Corporation
(NERC)in 2005. We are not proposing any other changes to field names. All other proposed changes are to the definitions of terms and values used for EQR filings. Background 2. On April 25, 2002, the Commission issued Order No. 2001, a final rule establishing revised public utility filing requirements. 2 This rule revised the Commission's filing requirements to require companies subject to the Commission's regulation under section 205 of the Federal Power Act (public utilities) 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. 2 *Revised Public Utility Filing Requirements,* Order No. 2001, 67 FR 31043, FERC Stats. & Regs. ¶ 31,127, *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). 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. For example, in a pair of orders issued on May 31 and October 21, 2002, the Commission provided guidance describing how EQR filers were to complete several data fields in the EQR software. 3 3 *Revised Public Utility Filing Requirements* , 99 FERC ¶ 61,238 (2002); *Revised Public Utility Filing Requirements* , 67 FR 65973 (Oct. 29, 2002), FERC Stats. & Regs. ¶ 35,045 (Oct. 21, 2005). 4. Likewise, on December 23, 2003, the Commission issued Order No. 2001-E, to resolve some recurring issues faced by EQR filers, to help filers better understand the requirements of Order No. 2001, and to improve the quality and consistency of EQR data. 4 To this end, the Commission:
(1)Ordered standard formats to be used for certain location fields;
(2)established an EQR Refiling Policy; and
(3)streamlined and defined allowable data entries in certain data fields. The Commission instructed Staff to issue filing guidance to address these changes. 5 This guidance was posted on the EQR page of the Commission's website on March 25, 2004. 6 Commission Staff posted additional guidance on the Internet at the *http://www.ferc.gov* Web site, and several EQR Users Group meetings have been held to address the questions of EQR filers. 4 Revised Public Utility Filing Requirements, Order No. 2001-E, 105 FERC ¶ 61,352 (2003). 5 *Id.* at P 8. 6 Posted at *http://www.ferc.fed.us/docs-filing/eqr/com-order.asp* . 5. After Order No. 2001-E, the Commission recognized that rapid change in the electric industry may require flexibility in adding or changing the entries allowed in restricted fields in the EQR. NERC, for example, frequently adds and deletes balancing authorities (previously “control areas”) from its Transmission System Information Network rolls. In an order issued on March 25, 2004, the Commission directed Staff to alert EQR users of any future changes to allowable entries for restricted fields by e-mail, and to post these changes on the EQR page of the Commission's Web site. 7 7 *Revised Public Utility Filing Requirements* , 106 FERC ¶ 61,281 (2004). 6. Since 2004, the Commission has performed outreach to the industry to determine which current EQR definitions are sufficient and understandable and which should be revised. As relevant here, on November 8, 2006, the Commission issued a public notice announcing that Staff was convening a meeting of the EQR Users Group to discuss a Staff draft EQR Data Dictionary. 8 In preparation for that meeting, Staff compiled existing definitions contained in previous orders and Commission issuances. 9 In addition, Staff suggested revisions and refinements to these definitions based on more than four years of experience reviewing EQR filings, responding to questions from EQR filers, and discussions with the EQR Users Group. Many of the revisions and refinements were intended to codify Staff guidance provided over the years to clarify companies' EQR filing obligations. Staff made its draft EQR Data Dictionary available to interested persons before the meeting. 10 8 *Revised Public Utility Filing Requirements for Electric Quarterly Reports* , Notice of Electric Quarterly Reports User's Group Meeting, Nov. 8, 2006. 9 *See* Staff Draft of the EQR Data Dictionary, posted on the EQR Users Group and Workshops page on FERC.gov at *http://www.ferc.gov/docs-filing/eqr/groups-workshops.asp* . 10 *Revised Public Utility Filing Requirements for Electric Quarterly Reports* , Notice of Electric Quarterly Reports User's Group Meeting, 71 FR 69111 (Nov. 29, 2006). 7. Almost 200 people registered to attend the November 29, 2006, meeting (either in person or via teleconference) and many who attended participated in the discussion of the issues. Participants were invited to file comments on the Staff draft EQR Data Dictionary by January 12, 2007. Occidental Power Services, Inc., Southern California Edison Company, and Edison Electric Institute
(EEI)filed written comments. Discussion 8. To improve the quality of EQR filings, the Commission has determined that it would be appropriate to issue formal definitions for those fields that are currently undefined. A common, documented basis for the definition of the terms and values in the EQR will provide the Commission with more reliable and understandable information related to the contracts and transactions reported. Further, a common EQR language will create greater regulatory certainty for companies responsible for filing the EQR. 9. The proposed EQR Data Dictionary compiles all the terms used in the EQR, as they have evolved since the issuance of Order No. 2001, into an organized reference for filers and public use. Specifically, the proposed EQR Data Dictionary (Attachment A) provides the terms and values used to file the EQR. It includes terms that were not previously defined except through Staff guidance. In general, the definitions and descriptions are consistent with those provided since the issuance of Order No. 2001. The underlying structure of the EQR will remain unchanged. 10. The text of this notice and Attachment B point out the instances where the proposed definitions vary from those used in prior Commission orders. Attachment B is provided on an informational basis only, to aid commenters in identifying revisions. Comments should only be addressed to the proposed EQR Data Dictionary in Attachment A. 11. The proposed EQR Data Dictionary revises the definitions provided in previous Commission orders for the following terms: • *ID Data:* Company Name—Respondent (Field Number 2); Company Name—Seller (Field Number 2); Company Name—Agent (Field Number 2); Company DUNS Number—Respondent (Field Number 3); Company DUNS Number—Seller (Field Number 3); Company DUNS Number—Agent (Field Number 3); Contact Country Name (Field Number 10); and Filing Quarter (Field Number 13). • *Contract Data:* Seller Company Name (Field Number 15); Customer Company Name (Field Number 16); Customer DUNS Number (Field Number 17); Contract Affiliate (Field Number 18); FERC Tariff Reference (Field Number 19); Contract Service Agreement ID (Field Number 20); Contract Execution Date (Field Number 21); Contract Commencement Date (Field Number 22); Contract Termination Date (Field Number 23); Extension Provision Description (Field Number 25); Term Name (Field Number 27); Product Name (Field Number 31); Quantity (Field Number 32); Units (Field Number 33); Rate (Field Number 34); Rate Units (Field Number 38); Point of Receipt Balancing Authority (Field Number 39); Point of Receipt Specific Location (Field Number 40); Point of Delivery Balancing Authority (Field Number 41); Point of Delivery Specific Location (Field Number 42); Begin Date (Field Number 43); and End Date (Field Number 44). • *Transaction Data:* Seller Company Name (Field Number 47); Customer Company Name (Field Number 48); Customer DUNS Number (Field Number 49); FERC Tariff Reference (Field Number 50); Contract Service Agreement ID (Field Number 51); Transaction Begin Date (Field Number 53); Transaction End Date (Field Number 54); Point of Delivery Balancing Authority (Field Number 56); Point of Delivery Specific Location (Field Number 57); Term Name (Field Number 59); Product Name (Field Number 62); Transaction Quantity (Field Number 62); Price (Field Number 64); Rate Units (Field Number 65); Total Transmission Charge (Field Number 66); and Total Transaction Charge (Field Number 67). 12. The proposed EQR Data Dictionary also adds definitions for terms not previously defined by Commission order, including: • *ID Data:* Filer Unique Identifier (Field Number 1). • *Contract Data:* Contract Unique ID (Field Number 14); Class Name (Field Number 26); Increment Name (Field Number 28); Increment Peaking Name (Field Number 29); Product Type Name (Field Number 30); and Time Zone (Field Number 45). • *Transaction Data:* Transaction Unique ID (Field Number 46); Time Zone (Field Number 55); Class Name (Field Number 58); Increment Name (Field Number 60); and Increment Peaking Name (Field Number 61). 13. The proposed EQR Data Dictionary makes the following key revisions to the existing EQR definitions: • The definitions of the identifiers used at the beginning of each record in the comma-delimited import files (Field Numbers 1, 14 and 60) have been expanded to clarify their function. • The definitions of the ID Data fields have been expanded to link each of the fields to the appropriate filer identified in Field Numbers 1 and 2. • The definition of “FERC Tariff Reference” reported in the Contract Data (Field Number 19) and Transaction Data (Field Number 50) permits references other than the filing company's own FERC tariff where sales occur under Commission-approved, cost-based rate schedules for certain power pools. • The definition of “Contract Service Agreement ID” reported in the Contract Data (Field Number 20) and in the Transaction Data (Field Number 51) allows an “internal identification system” as opposed to a “numbering” system to allow for the inclusion of non-numeric characters in the identifiers. • The definitions of “Class Name, F-Firm” and “Class Name, NF-Non-Firm” reported in the Contract Data (Field Number 26) and the Transaction Data (Field Number 58) provide two definitions, to differentiate between firm transmission service and firm power sales. 11 11 These definitions are intended to be consistent with NERC and the pro forma Open Access Transmission Tariff
(OATT)definitions and Commission precedent. *See* , *e.g.* , *Preventing Undue Discrimination and Preference in Transmission Service* , Order No. 890, 72 FR 12266 (Mar. 15, 2007), FERC Stats. & Regs. ¶ 31,241 at P 1452-55, P 1539 and P 1688-92 (Feb. 16, 2007) (Order No. 890). However, as explained below, *infra* P 21, these definitions only govern the manner in which these items are reported in the EQR. • The definitions of the allowable entries for “Term Name” reported in the Contract Data (Field Number 27) and in the Transaction Data (Field Number 59) are being expanded. While EQR filers have indicated a preference that the definitions for power sales and transmission be differentiated, the Commission is striving to create consistency for uses of “long term” and “short term,” across its programs. 12 Therefore, we propose to define “Term Name” in the same way for both power and transmission sales. 12 *See Market-Based Rates for Wholesale Sales of Electric Energy, Capacity and Ancillary Services by Public Utilities* , notice of proposed rulemaking, 71 FR 33102 (Jun. 7, 2006), FERC Stats. & Regs. ¶ 32,602 at P 137 (May 19, 2006). Also, the Commission is aware of inconsistencies in these definitions with the FERC Form 1 and is in the process of reviewing comments in *Assessments of Information Requirements for FERC Financial Forms* , notice of inquiry, 72 FR 8316 (Feb. 15, 2007). • The definitions of “Increment Peaking Name, OP-Off-Peak” and “Increment Peaking Name, P-Peak” reported in the Contract Data (Field Number 29) and the Transaction Data (Field Number 61) specify that the “relevant NERC region” was the “NERC region of the point of delivery.” • The definition of “Increment Peaking Name, N/A-Not Applicable” in the Contract Data (Field Number 29) indicates that “N/A” is an acceptable entry if the contract does not specify the increment peaking period for the sale. The definition of “Increment Peaking Name, N/A-Not Applicable” in the Transaction Data (Field Number 61) indicates that “N/A” is an acceptable entry only when other available increment peaking names do not apply. “N/A” will not be acceptable for products such as “Energy,” “Booked Out Power,” “Capacity,” or “Ancillary Services.” • The definitions of “Product Type Name, CB-Cost-Based” and “Product Type Name, MB-Market-Based” reported in the Contract Data (Field Number 30) specify “energy or capacity sold” under the seller's FERC-approved tariffs. This change allows filers to differentiate these product types from “Product Type Name, T-Transmission,” which applies to cost-based or market-based transmission-related services. • The definition of “Product Type Name, S-Service” in the Contract Data (Field Number 30) has been deleted to remove ambiguity regarding the types of products that must be reported. • The name and definition of “Point of Receipt Control Area” reported in the Contract Data (Field Number 39) has been revised to “Point of Receipt Balancing Authority” in response to changes in terminology implemented by NERC beginning April 1, 2005. • The name and definition of “Point of Delivery Control Area” reported in the Contract Data (Field Number 41) and in the Transaction Data (Field Number 56) has been revised to “Point of Delivery Balancing Authority” in response to changes in terminology implemented by NERC beginning April 1, 2005. • The continued requirement to fill certain Contract Data fields—Contract Termination Date (Field Number 23); Quantity (Field Number 32); Units (Field Number 33); Rate Units (Field Number 38); Point of Receipt Balancing Authority (PORBA) (Field Number 39); Point of Receipt Specific Location (PORSL) (Field Number 40); Point of Delivery Balancing Authority (PODBA) (Field Number 41); Point of Delivery Specific Location (PODSL) (Field Number 42); Begin Date (Field Number 43) and End Date (Field Number 44)—has been clarified to be contract-specific. The EQR may still be filed if these fields are left empty, but the public utility has the obligation to complete the fields if the relevant terms are included in the contract. 13 13 As pointed out above, *supra* note 1, to be consistent with NERC terminology, the proposed Data Dictionary uses the field name “PORBA” (previously “PORCA” and “PODBA” (previously “PODCA”). • The “Product Name” (Attachment A, Appendix A) in the Contract Data (Field Number 31), “Capacity Reassignment,” has been added to address a new EQR reporting requirement required by Order No. 890. 14 14 *See* Order No. 890, FERC Stats. & Regs. ¶ 31,241 at note 499. • The “Product Names” (Attachment A, Appendix A) in the Contract Data (Field Number 31), “Regulation & Frequency Response,” “Spinning Reserve,” and “Supplemental Reserve” have been modified to address changes in the OATT in Order No. 890. • The “Product Name” (Attachment A, Appendix A) in the Contract Data (Field Number 31), “Exchange Agreement,” has been revised to “Exchange” and incorporated into the allowable product names in the Transaction Data (Field Number 62). This change will make it easier to identify sales under exchange agreements and adjust for their effects when reviewing product prices. • The “Product Name” (Attachment A, Appendix A) in the Contract Data (Field Number 31 and Field Number 62), “Transmission Owners Agreement,” has been revised to expand the definition beyond agreements with ISOs. 14. Two fields merit specific discussion. The Increment Name fields (Field Number 28 of the Contract Data and Field Number 60 of the Transaction Data) are intended to provide insight into the duration of the agreement under which a sale is being made. To compare sales in the EQR appropriately, we must be able to understand the duration of the underlying transaction that resulted in each sale. On a single day in a given market, prices for power under terms set at the beginning of a month may differ from hourly prices determined through an RTO or ISO in its real time market. The Increment Name fields provide a basis to understand price differentiation among otherwise similarly situated sales. 15. The proposed EQR Data Dictionary includes definitions of Increment Names that offer more clarity and allow the fields to be automatically calculated. These definitions lay out specific time periods for each of the restricted values. 16. Deals covering peak periods or off-peak periods (as identified in the Increment Peaking Name fields) are commonly characterized as daily, rather than as hourly transactions, even though they last less than 24 hours. 15 For this reason, the proposed EQR Data Dictionary defines “D-Daily” transactions as those under deals that last over six and up to and including thirty-six hours to ensure that both peak and off-peak blocks for a single day are included. 15 These deals would be reported in Field Number 29 of Contract Data and in Field Number 61 of Transaction Data. 17. Hourly deals, such as sales to ISOs, are characterized with terms shorter than the daily deals. Under the proposed EQR Data Dictionary deals of up to, and including, six hours would be reported as “H-Hourly.” 18. Transactions that cover blocks of hours over the course of a week (commonly identified in the industry by such terms as “5x16” or “2x24”) are characterized as weekly transactions. 16 Sales under deals of over 36 and up to and including 168 hours (seven days) are defined in the proposed EQR Data Dictionary as “W-Weekly” deals. Deals over a week (168 hours) and up to and including one month would be reported as “M-Monthly.” Deals of a year or more (including sales where precise terms are set in a long-term contract) will be reported as “Y-Yearly.” We also propose a new “S-Seasonal” value to be used to characterize power sales that are made for longer than one month but less than a year, such as sales for the duration of a peak season. 16 “5x16” (5 days × 16 hours) refers to a peak hour weekly deal and “2 × 24” (2 days x 24 hours) refers to a weekend deal. 19. In the Contracts tab, the Increment Name field (Field Number 28) has descriptive value for those contracts that lay out the specific terms (price, quantity, and period) of the arrangement. Contracts that do not contain these specific terms should be described using “N/A.” 20. Also, in Order No. 890, the Commission addressed the issue of what constitutes a sufficient level of firmness to be eligible for designation as a network resource. 17 We invite comments on whether the definitions of Class Names, “Firm” and “Non-Firm” (Field Numbers 26 and 58), need revision. 17 *See* Order No. 890, FERC Stats. & Regs. ¶ 31,241 at P 1452-55. 21. Subject to our review of any comments filed in response to this notice, the Commission plans to adopt the EQR Data Dictionary shown in Attachment A to this notice. We expect that these definitions would take effect the first day of the first new quarter after issuance of a Final Order. We caution that the definitions we are proposing in the EQR Data Dictionary are only intended to govern the manner in which these items are reported in the EQR and are not intended to be precedent in other contexts. Comment Procedures 22. The Commission invites interested persons to submit comments on the matters and issues proposed in this notice, including any related matters or alternative proposals that commenters may wish to discuss. Comments are due June 7, 2007. Comments must refer to Docket No. RM01-8-006, and must include the commenter's name, the organization they represent, if applicable, and their address. Comments may be filed either in electronic or paper format. 23. Comments may be filed electronically via the eFiling link on the Commission's Web site at *http://www.ferc.gov.* The Commission accepts most standard word processing formats and commenters may attach additional files with supporting information in certain other file formats. Commenters filing electronically do not need to make a paper filing. Commenters that are not able to file comments electronically must send an original and 14 copies of their comments to: Federal Energy Regulatory Commission, Secretary of the Commission, 888 First Street NE., Washington, DC 20426. 24. All comments will be placed in the Commission's public files and may be viewed, printed, or downloaded remotely as described in the Document Availability section below. Commenters on this proposal are not required to serve copies of their comments on other commenters. Document Availability 25. 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. 26. 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 the docket number excluding the last three digits of this document in the docket number field. User assistance is available for eLibrary and the Commission's website during our normal business hours. For assistance contact FERC Online Support at *FERCOnlineSupport@ferc.gov* or toll-free at
(866)208-3676, or for TTY, contact
(202)502-8659. By direction of the Commission. Kimberly D. Bose, Secretary. Note: The following attachments
(A)and
(B)will not appear in the Code of Federal Regulation. Attachment A Electric Quarterly Report Data Dictionary Version 1.0 (issued —) EQR Data Dictionary [ID Data] Field No. Field Required Value Definition 1 Filer Unique Identifier ✓ FR1 (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. 1 Filer Unique Identifier ✓ FS# (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. 1 Filer Unique Identifier ✓ FA1 (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. 2 Company Name ✓ Unrestricted text (70 characters) (Respondent)—The name of the company taking responsibility for complying with the Commission's regulations related to the EQR. 2 Company Name ✓ Unrestricted text (70 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. 2 Company Name ✓ Unrestricted text (70 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. 3 Company DUNS Number For Respondent and Seller Nine digit number The unique nine digit number assigned by Dun and Bradstreet to the company identified in Field Number 2. 4 Contact Name ✓ Unrestricted text (50 characters) (Respondent)—Name of the person at the Respondent's company taking responsibility for compliance with the Commission's EQR regulations. 4 Contact Name ✓ Unrestricted 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. 4 Contact Name ✓ Unrestricted text (50 characters) (Agent)—Name of the contact for the Agent, usually the person who prepares the filing. 5 Contact Title ✓ Unrestricted text (50 characters) Title of contact identified in Field Number 4. 6 Contact Address ✓ Unrestricted text Street address for contact identified in Field Number 4. 7 Contact City ✓ Unrestricted text (30 characters) City for the contact identified in Field Number 4. 8 Contact State ✓ Unrestricted text (2 characters) Two character state or province abbreviations for the contact identified in Field Number 4. 9 Contact Zip ✓ Unrestricted text (10 characters) Zip code for the contact identified in Field Number 4. 10 Contact Country Name ✓ CA-Canada, MX-Mexico, US-United States, UK-United Kingdom Country (USA, Canada, Mexico, or United Kingdom) for contact address identified in Field Number 4. 11 Contact Phone ✓ Unrestricted text (20 characters) Phone number of contact identified in Field Number 4. 12 Contact E-Mail ✓ Unrestricted text E-mail address of contact identified in Field Number 4. 13 Filing Quarter ✓ 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). 14 Contract Unique ID ✓ An 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. 15 Seller Company Name ✓ Unrestricted text (70 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). 16 Customer Company Name ✓ Unrestricted text (70 characters) The name of the counterparty to the contract. 17 Customer DUNS Number ✓ Nine digit number The unique nine digit number assigned by Dun and Bradstreet to the company identified in Field Number 16. 18 Contract Affiliate ✓ Y
(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. 19 FERC Tariff Reference ✓ Unrestricted 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 or power sales 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 Agreement ID ✓ Unrestricted 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. 21 Contract Execution Date ✓ YYYYMMDD The date the contract was signed. If the parties signed on different dates, or there are contract amendments, use the most recent date signed. 22 Contract Commencement Date ✓ YYYYMMDD The date the contract was effective. If it is not specified in the contract, the first date of service under the contract. 23 Contract Termination Date If specified in the contract YYYYMMDD The date that the contract expires. 24 Actual Termination Date If contract terminated YYYYMMDD The date the contract actually terminates. 25 Extension Provision Description ✓ Unrestricted text Description of terms that provide for the continuation of the contract. 26 Class Name ✓ See definitions of each class name below. 26 Class Name ✓ F—Firm For transmission sales, service or product that always has priority over non-firm service. For power sales, service or product that is not interruptible for economic reasons. 26 Class Name ✓ NF—Non-firm For transmission sales, 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. An energy 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. 26 Class Name ✓ UP—Unit Power Sale Designates a dedicated sale of energy and capacity from one or more than one generation unit(s). 26 Class Name ✓ N/A—Not Applicable To be used only when the other available Class Names do not apply. 27 Term Name ✓ LT—Long Term, ST—Short Term, N/A—Not Applicable Contracts with durations of one year or greater are long-term. Contracts with shorter durations are short-term. 28 Increment Name ✓ See definitions for each increment below. 28 Increment Name ✓ H—Hourly Terms of the contract (if specifically noted in the contract) set for up to 6 consecutive hours (= 6 consecutive hours). 28 Increment Name ✓ D—Daily Terms of the contract (if specifically noted in the contract) set for more than 6 and up to 36 consecutive hours (≤6 and = 36 consecutive hours). 28 Increment Name ✓ W—Weekly Terms of the contract (if specifically noted in the contract) set for over 36 consecutive hours and up to 168 consecutive hours (≤36 and = 168 consecutive hours). 28 Increment Name ✓ M—Monthly Terms of the contract (if specifically noted in the contract) set for more than 168 consecutive hours up to one month (>168 consecutive hours and ≤ 1 month). 28 Increment Name ✓ Y—Yearly Terms of the contract (if specifically noted in the contract) set for one year or more (≥1 year). 28 Increment Name ✓ S—Seasonal Terms of the contract (if specifically noted in the contract) set for greater than one month and less than 365 consecutive days (> 1 month and < 1 year). 28 Increment Name ✓ N/A—Not Applicable Terms of the contract do not specify an increment. 29 Increment Peaking Name ✓ See definitions for each increment peaking name below. 29 Increment Peaking Name ✓ FP—Full Period The product described may be sold during all hours under the contract. 29 Increment Peaking Name ✓ OP—Off-Peak The product described may be sold only during those hours designated as off-peak in the NERC region of the point of delivery. 29 Increment Peaking Name ✓ P—Peak The product described may be sold only during those hours designated as on-peak in the NERC region of the point of delivery. 29 Increment Peaking Name ✓ N/A—Not Applicable To be used only when the increment peaking name is not specified in the contract. 30 Product Type Name ✓ See definitions for each product type below. 30 Product Type Name ✓ CB—Cost Based Energy or capacity sold under a FERC-approved cost-based rate tariff. 30 Product Type Name ✓ MB—Market Based Energy sold under the seller's FERC-approved market-based rate tariff. 30 Product Type Name ✓ T—Transmission The product is sold under a FERC-approved transmission tariff. 30 Product Type Name ✓ Other The product cannot be characterized by the other product type names. 31 Product Name ✓ See Product Name Table, Appendix A. Description of product being offered. 32 Quantity If specified in the contract Number with up to 4 decimals Quantity for the contract product identified. 33 Units If specified in the contract See Units Table, Appendix E Measure stated in the contract for the product sold. 34 Rate One of four rate fields (34, 35, 36, or 37) must be included Number with up to 4 decimals The charge for the product per unit as stated in the contract. 35 Rate Minimum One of four rate fields (34, 35, 36, or 37) must be included Number with up to 4 decimals Minimum rate to be charged per the contract, if a range is specified. 36 Rate Maximum One of four rate fields (34, 35, 36, or 37) must be included Number with up to 4 decimals Maximum rate to be charged per the contract, if a range is specified. 37 Rate Description One of four rate fields (34, 35, 36, or 37) must be included Unrestricted text Text description of rate. May reference FERC tariff, or, if a discounted or negotiated rate, include algorithm. 38 Rate Units If specified in the contract See Rate Units Table, Appendix F Measure stated in the contract for the product sold. 39 Point of Receipt Balancing Authority (PORBA) If specified in the contract See Balancing Authority Table, Appendix B The registered NERC Balancing Authority (formerly called NERC Control Area) abbreviation used in OASIS applications or “Hub” if point of receipt is at a restricted trading hub. 40 Point of Receipt Specific Location (PORSL) If specified in the contract Unrestricted text (50 characters). If “HUB” is selected for PORCA, see Hub Table, Appendix C The 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. 41 Point of Delivery Balancing Authority(PODBA) If specified in the contract See Balancing Authority Table, Appendix B The registered NERC Balancing Authority (formerly called NERC Control Area) abbreviation used in OASIS applications or “Hub” if point of receipt is at a restricted trading hub. 42 Point of Delivery Specific Location (PODSL) If specified in the contract Unrestricted text (50 characters). If “HUB” is selected for PODCA, see Hub Table, Appendix C The 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. 43 Begin Date If specified in the contract YYYYMMDDHHMM First date for the sale of the product at the rate specified. 44 End Date If specified in the contract YYYYMMDDHHMM Last date for the sale of the product at the rate specified. 45 Time Zone ✓ See Time Zone Table, Appendix D The time zone in which the sales will be made under the contract. EQR Data Dictionary [Transaction Data] Field No. Field Required Value Definition 46 Transaction Unique ID ✓ An 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. 47 Seller Company Name ✓ Unrestricted text (70 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). 48 Customer Company Name ✓ Unrestricted text (70 Characters) The name of the counterparty to the contract. 49 Customer DUNS Number ✓ Nine digit number The unique nine digit number assigned by Dun and Bradstreet to the counterparty to the contract. 50 FERC Tariff Reference ✓ Unrestricted 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 or power sales 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 Agreement ID ✓ Unrestricted 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. 52 Transaction Unique Identifier ✓ Unrestricted text (24 Characters) Unique reference number assigned by the seller for each transaction. 53 Transaction Begin Date ✓ YYYYMMDDHHMM (csv import) First date and time the product is sold during the quarter at the specified price. MMDDYYYYHHMM (manual entry) 54 Transaction End Date ✓ YYYYMMDDHHMM (csv import) Last date and time the product is sold during the quarter at the specified price. MMDDYYYYHHMM (manual entry) 55 Time Zone ✓ See Time Zone Table, Appendix D The time zone in which the sales will be made under the contract. 56 Point of Delivery Balancing Authority (PODBA) ✓ See Balancing Authority Table, Appendix B The registered NERC Balancing Authority (formerly called NERC Control Area) abbreviation used in OASIS applications. 57 Point of Delivery Specific Location (PODSL) ✓ Unrestricted text (50 characters). If “HUB” is selected for PODBA, see Hub Table, Appendix C The specific location at which the product is delivered. If receipt occurs at a trading hub, a standardized hub name must be used. 58 Class Name ✓ See class name definitions below. 58 Class Name ✓ F—Firm For transmission sales, service or product that always has priority over non-firm service. For power sales, service or product that is not interruptible for economic reasons. 58 Class Name ✓ NF—Non-firm For transmission sales, 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 transmission service. An energy 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 ✓ UP—Unit Power Sale Designates a dedicated sale of energy and capacity from one or more than one generation unit(s). 58 Class Name ✓ BA—Billing Adjustment Incremental positive or negative material change to previous EQR totals. 58 Class Name ✓ N/A—Not Applicable To be used only when the other available class names do not apply. 59 Term Name ✓ LT—Long Term, ST—Short Term, N/A—Not Applicable Power sales transactions with durations of one year or greater are long-term. Transactions with shorter durations are short-term. 60 Increment Name ✓ See increment name definitions below. 60 Increment Name ✓ H—Hourly Terms of the particular sale set for up to 6 consecutive hours (≤ 6 consecutive hours) Includes LMP based sales in ISO/RTO markets. 60 Increment Name ✓ D—Daily Terms of the particular sale set for more than 6 and up to 36 consecutive hours (> 6 and ≤ 36 consecutive hours) Includes sales over a peak or off-peak block during a single day. 60 Increment Name ✓ W—Weekly Terms of the particular sale set for over 36 consecutive hours and up to 168 consecutive hours (> 36 and ≤ 168 consecutive hours). Includes sales for a full week and sales for peak and off-peak blocks over a particular week. 60 Increment Name ✓ M—Monthly Terms of the particular sale set for more than 168 consecutive hours up to one month (> 168 consecutive hours and ≤ 1 month). Includes sales for full month or multi-week sales during a given month. 60 Increment Name ✓ S—Seasonal Terms of the specific sales set for greater than one month and less than 365 consecutive days (> 1 month and < 1 year). 60 Increment Name ✓ Y—Yearly Terms 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). 60 Increment Name ✓ N/A—Not Applicable To be used only when other available increment names do not apply. 61 Increment Peaking Name ✓ See definitions for increment peaking below 61 Increment Peaking Name ✓ FP—Full Period The product described may be sold during all hours under the contract. 61 Increment Peaking Name ✓ OP—Off-Peak The product described may be sold only during those hours designated as off-peak in the NERC region of the point of delivery. 61 Increment Peaking Name ✓ P—Peak The product described may be sold only during those hours designated as on-peak in the NERC region of the point of delivery. 61 Increment Peaking Name ✓ N/A—Not Applicable To be used only when the other available increment peaking names do not apply. 62 Product Name ✓ See Product Names Table, Appendix A Description of product being offered. 63 Transaction Quantity ✓ Number with up to 4 decimals The quantity of the product in this transaction. 64 Price ✓ Number with up to 6 decimals Price charged for the product per unit. 65 Rate Units ✓ See Rate Units Table, Appendix F Measure appropriate to the price of the product sold. 66 Total Transmission Charge ✓ Number with up to 2 decimals Payments received for transmission services when explicitly identified. 67 Total Transaction Charge ✓ Number with up to 2 decimals Transaction Quantity (Field 63) times Price (Field 64) plus Total Transmission Charge (Field 66). EQR Data Dictionary [Appendix A. Product Names] Product name Contract product Transaction product Definition BLACK START SERVICE ✓ ✓ 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 ✓ Energy or capacity contractually committed bilaterally for delivery but not actually delivered due to some offsetting or countervailing trade (Transaction only). CAPACITY ✓ ✓ A quantity of demand that is charged on a $/KW or $/MW basis. CAPACITY REASSIGNMENT ✓ An agreement under which a transmission customer sells, assigns or transfers all or portion of its rights to an eligible customer. CUSTOMER CHARGE ✓ ✓ Fixed contractual charges assessed on a per customer basis that could include billing service. DIRECT ASSIGNMENT FACILITIES CHARGE ✓ Charges for facilities or portions of facilities that are constructed or used for the sole use/benefit of a particular customer. EMERGENCY ENERGY ✓ Contractual provisions to supply energy or capacity to another entity during critical situations. ENERGY ✓ ✓ A quantity of electricity that is sold or transmitted over a period of time. ENERGY IMBALANCE ✓ ✓ Service provided when a difference occurs between the scheduled and the actual delivery of energy to a load obligation. EXCHANGE ✓ ✓ (Previously “Exchange Agreement”). Transaction whereby the receiver accepts delivery of energy for a supplier's account and returns energy later at times, rates, and in amounts as mutually agreed. FUEL CHARGE ✓ ✓ Charge based on the cost or amount of fuel used for generation. GRANDFATHERED BUNDLED ✓ ✓ Services provided for bundled transmission, ancillary services and energy under contracts effective prior to Order No. 888's OATTs. INTERCONNECTION AGREEMENT ✓ 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 ✓ Agreement to participate and be subject to rules of a system operator. MUST RUN AGREEMENT ✓ An agreement that requires a unit to run. NEGOTIATED-RATE TRANSMISSION ✓ ✓ Transmission performed under a negotiated rate contract (applies only to merchant transmission companies). NETWORK ✓ Transmission service under contract providing network service. NETWORK OPERATING AGREEMENT ✓ 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 ✓ ✓ Product name not otherwise included. POINT-TO-POINT AGREEMENT ✓ Transmission service under contract between specified Points of Receipt and Delivery. REACTIVE SUPPLY & VOLTAGE CONTROL ✓ ✓ Production or absorption of reactive power to maintain voltage levels on transmission systems (Ancillary Service). REAL POWER TRANSMISSION LOSS ✓ ✓> The loss of energy, resulting from transporting power over a transmission system. REGULATION & FREQUENCY RESPONSE ✓ ✓ 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 ✓ ✓ 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 ✓ ✓ 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 ✓ ✓ 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 ✓ ✓ 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 ✓ ✓ 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 ✓ ✓ 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 ✓ The agreement that establishes the terms and conditions under which a transmission owner transfers operational control over designated transmission facilities. UPLIFT ✓ ✓ A make-whole payment by an RTO/ISO to a utility. EQR Data Dictionary [Appendix B. Balancing Authority] Balancing authority Abbreviation AESC, LLC—Wheatland CIN AEWC Alabama Electric Cooperative, Inc. AEC Alberta Electric System Operator AESO 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 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 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 Constellation Energy Control and Dispatch—Arkansas PUPP Constellation Energy Control and Dispatch—City of Benton, AR BUBA Constellation Energy Control and Dispatch—City of Ruston, LA DERS 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 Rock, AK DENL Constellation Energy Control and Dispatch—West Memphis, Arkansas WMUC 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 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 MHEB, Transmission Services MHEB Michigan Electric Coordinated System MECS 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 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 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 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 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. AEP
(into)The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into the AEP balancing authority. 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 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). Comed
(into)The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into the Commonwealth Edison balancing authority. 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. 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. 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. Attachment B Explanation and Comparison of Revisions to Prior Commission Orders Contained in the Proposed EQR Data Dictionary Definitions ID DATA Respondent Data Field Number 1: Filer Unique Identifier Current Definition: None Proposed Definition: FR (Filing 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. Field Number 2: Company Name Current Definition: Name of company (for consistency sake, it must be represented the same as it is listed in the DUNS Report). Proposed Definition: The name of the company taking responsibility for complying with the Commission's regulations related to the EQR. Field Number 3: Company Duns Number Current Definition: DUNS number for company unique identification. Proposed Definition: The unique nine digit number assigned by Dun and Bradstreet to the company identified in Field Number 2. Field Number 4: Contact Name Current Definition: Name of contact(s) for the filing. Proposed Definition: Name of the person at the Respondent's company taking responsibility for compliance with the Commission's EQR regulations. Field Number 5: Contact Title Current Definition: Title of contact. Proposed Definition: Title of contact identified in Field Number 4. Field Number 6: Contact Address Current Definition: Street address for contact. Proposed Definition: Street address for contact identified in Field Number 4. Field Number 7: Contact City Current Definition: Contact city. Proposed Definition: Contact city for the contact identified in Field Number 4. Field Number 8: Contact State Current Definition: Two character state or province abbreviation. Proposed Definition: Two character state or province abbreviations for the contact identified in Field Number 4. Field Number 9: Contact Zip Current Definition: Contact zip code. Proposed Definition: Zip code for the contact identified in Field Number 4. Field Number 10: Contact Country Name Current Definition: Country (USA, Canada, Mexico, or United Kingdom) for contact address for the company identified in Field Number 2. Proposed Definition: Contact address for the contact identified in Field Number 4. Field Number 11: Contact Phone Current Definition: Phone number of contact. Proposed Definition: Phone number of contact identified in Field Number 4. Field Number 12: Contact Email Current Definition: E-mail address of contact. Proposed Definition: E-mail address of contact identified in Field Number 4. Field Number 13: Filing Quarter Current Definition: The period for which the Electric Quarterly Report is being submitted. Proposed Definition: 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) Seller Data Field Number 1: Filer Unique Identifier Current Definition: None Proposed Definition: FS (Filing 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. Field Number 2: Company Name Current Definition: Name of company (for consistency sake, it must be represented the same as it is listed in the DUNS Report). Proposed Definition: 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. Field Number 3: Company Duns Number Current Definition: DUNS number for company unique identification. Proposed Definition: The unique nine digit number assigned by Dun and Bradstreet to the company identified in Field 2. Field Number 4: Contact Name Current Definition: Name of contact(s) for the filing. Proposed Definition: 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 Company Name of the Respondent. Field Number 5: Contact Title Current Definition: Title of contact. Proposed Definition: Title of contact identified in Field Number 4. Field Number 6: Contact Address Current Definition: Street address for contact. Proposed Definition: Street address for contact identified in Field Number 4. Field Number 7: Contact City Current Definition: Contact city. Proposed Definition: Contact city for the contact identified in Field Number 4. Field Number 8: Contact State Current Definition: Two character state or province abbreviation. Proposed Definition: Two character state or province abbreviations for the contact identified in Field Number 4. Field Number 9: Contact Zip Current Definition: Contact zip code. Proposed Definition: Zip code for the contact identified in Field Number 4. Field Number 10: Contact Country Name Current Definition: Country (USA, Canada, Mexico or United Kingdom) for contact address. Proposed Definition: Country (USA, Canada, Mexico, or United Kingdom) for contact address identified in Field Number 4. Field Number 11: Contact Phone Current Definition: Phone number of contact. Proposed Definition: Phone number of contact identified in Field Number 4. Field Number 12: Contact Email Current Definition: E-mail address of contact. Proposed Definition: E-mail address of contact identified in Field Number 4. Field Number 13: Filing Quarter Current Definition: The period for which the Electric Quarterly Report is being submitted. Proposed Definition: 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) Agent Data Field Number 1: Filer Unique Identifier Current Definition: None Proposed Definition: FA (Filing 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. Field Number 2: Company Name Current Definition: Name of company (for consistency sake, it must be represented the same as it is listed in the DUNS Report). Proposed Definition: The name of the entity completing the EQR filing. The Agent's Company Name need not be the name of a company under Commission jurisdiction. Field Number 3: Company Duns Number Current Definition: DUNS number for company unique identification. Proposed Definition: The unique nine digit number assigned by Dun and Bradstreet to the company identified in Field 2. Field Number 4: Contact Name Current Definition: Name of contact(s) for the filing. Proposed Definition: Name of the contact for the Agent, usually the person who prepares the filing. Field Number 5: Contact Title Current Definition: Title of contact. Proposed Definition: Title of contact identified in Field Number 4. Field Number 6: Contact Address Current Definition: Street address for contact. Proposed Definition: Street address for contact identified in Field Number 4. Field Number 7: Contact City Current Definition: Contact city. Proposed Definition: City for the contact identified in Field Number 4. Field Number 8: Contact State Current Definition: Two character state or province abbreviation. Proposed Definition: Two character state or province abbreviations for the contact identified in Field Number 4. Field Number 9: Contact Zip Current Definition: Contact zip code. Proposed Definition: Zip code for the contact identified in Field Number 4. Field Number 10: Contact Country Name Current Definition: Country (USA, Canada, Mexico or United Kingdom) for contact address. Proposed Definition: Country (USA, Canada, Mexico, or United Kingdom) for contact address identified in Field Number 4. Field Number 11: Contact Phone Current Definition: Phone number of contact. Proposed Definition: Phone number of contact identified in Field Number 4. Field Number 12: Contact Email Current Definition: E-mail address of contact. Proposed Definition: E-mail address of contact identified in Field Number 4. Field Number 13: Filing Quarter Current Definition: The period for which the Electric Quarterly Report is being submitted. Proposed Definition: 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: Field Number 14: Contract Unique ID Current Definition: None. Proposed Definition: 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. Field Number 15: Seller Company Name Current Definition: Name of company (For consistency sake, it must be represented the same as it is listed in the DUNS Report.) Proposed Definition: 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). Field Number 16: Customer Company Name Current Definition: Name of company (For consistency sake, it must be represented the same as it is listed in the DUNS Report.) Proposed Definition: The name of the counterparty to the contract. Field Number 17: Customer DUNS Number Current Definition: DUNS Number for Company Unique Identification. Proposed Definition: The unique nine digit number assigned by Dun and Bradstreet to the company identified in Field Number 16. Field Number 18: Contract Affiliate Current Definition: This is a flag to determine if the customer is an affiliate. Set to Yes if the customer is an affiliate of the provider. Proposed Definition: The customer is an affiliate if it controls, is controlled by or is under common control with the seller, and includes a division that operates as a functional unit. 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. Field Number 19: FERC Tariff Reference Current Definition: Valid Entries: FERC's designation, e.g., “FERC Electric Tariff, Second Revised Volume No. 5, Schedule 2;” or “FERC Electric Rate Schedule No. 126.” Proposed Definition: The FERC tariff reference cites the document that specifies the terms and conditions under which a Seller is authorized to make transmission sales or power sales 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. Field Number 20: Contract Service Agreement ID Current Definition: Unique (company) name given to each service agreement. It may be the number assigned by FERC for those service agreements that have been filed and approved by the Commission, or it can be an internal numbering system. Proposed Definition: 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. Field Number 21: Contract Execution Date Current Definition: The date the contract was signed. If the parties signed on different dates, or there are different contract amendments, the latest date signed. Proposed Definition: The date the contract was signed. If the parties signed on different dates, or there are contract amendments, use the most recent date signed. Field Number 22: Contract Commencement Date Current Definition: The first date the contract was effective—frequently the first date of service under a contract. Proposed Definition: The date the contract was effective. If it is not specified in the contract, the first date of service under the contract. Field Number 23: Contract Termination Date Current Definition: The date specified (if any) in the contract that the contract will expire of its own terms. Proposed Definition: The date that the contract expires. Field Number 24: Actual Termination Date Current Definition: The date the contract actually terminates. Proposed Definition: No Change. Field Number 25: Extension Provision Description Current Definition: Description of extension provision. This field would contain Text—for example “Automatically renewed until canceled.” Proposed Definition: Description of terms that provide for the continuation of the contract. Field Number 26: Class Name Current Definition: Name of class. Valid entries are F—Firm, NF—Non-Firm, UP—Unit Power Sale, BA—Billing Adjustment, and N/A—Not Applicable. Proposed Definition: • F—Firm: For transmission sales, service or product that always has priority over non-firm service. For power sales, service or product that is not interruptible for economic reasons. • NF—Non-Firm: For transmission sales, 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. An energy 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. • UP—Unit Power Sale: Designates a dedicated sale of energy and capacity from one or more than one generation unit(s). • N/A—Not Applicable: To be used only when the other available Class Names do not apply. Field Number 27: Term Name Current Definition: Name for term. LT = Long-Term (≥ one year), ST = Short-Term (< one year). Proposed Definition: Contracts with durations of one year or greater are long-term. Contracts with shorter durations are short-term. Field Number 28: Increment Name Current Definition: None. Proposed Definition: • H—Hourly: Terms of the contract (if specifically noted in the contract) set for up to 6 consecutive hours (≤ 6 consecutive hours). • D—Daily: Terms of the contract (if specifically noted in the contract) set for more than 6 and up to 36 consecutive hours (> 6 and ≤ 36 consecutive hours). • W-Weekly: Terms of the contract (if specifically noted in the contract) set for over 36 consecutive hours and up to 168 consecutive hours (> 36 and ≤ 168 consecutive hours). • M—Monthly: Terms of the contract (if specifically noted in the contract) set for more than 168 consecutive hours up to one month (> 168 consecutive hours and ≤ 1 month). • S—Seasonal: Terms of the contract (if specifically noted in the contract) set for greater than one month and less than 365 consecutive days (> 1 month and < 1 year). • Y—Yearly: Terms of the contract (if specifically noted in the contract) set for one year or more (≤ 1 year). • N/A—Not Applicable: Terms of the contract do not specify an increment. Field Number 29: Increment Peaking Name Current Definition: Name for increment peaking. For product, services, or transaction[s] that are identified as P = On Peak, OP = Off-Peak, FP = Full Period, N/A = Not Applicable, Undefined. Proposed Definition: • FP—Full Period: The product described may be sold during all hours under the contract. • OP—Off-Peak: The product described may be sold only during those hours designated as off-peak in the NERC region of the point of delivery. • P—Peak: The product described may be sold only during those hours designated as on-peak in the NERC region of the point of delivery. • N/A—Not Applicable: To be used only when the increment peaking name is not specified in the contract. Field Number 30: Product Type Name Current Definition: A product is something being bought and sold, a type of service or standard agreement. The “product type name” includes: T = Electric Transmission, MB = Market Based Power, CB = Cost Based Power, S = Services—Other. Proposed Definition: • CB—Cost-Based: Energy or capacity sold under a FERC-approved cost-based rate tariff. • MB—Market-Based: Energy sold under the seller's FERC-approved market-based rate tariff. • T—Transmission: The product is sold under a FERC-approved transmission tariff. • Other: The product cannot be characterized by the other product type names. Field Number 31: Product Name Current Definition: A product is something being bought and sold, a type of service or standard agreement. Proposed Definition: Description of the product being offered. (Refer to Attachment A-Appendix A for an acceptable list of product names for this field). Field Number 32: Quantity Current Definition: Product quantity for the contract item identified. Proposed Definition: Quantity for the contract product identified. Field Number 33: Units Current Definition: The unit of measurement for the quantity and rates represented. Examples include KW, MW, and MWH. Proposed Definition: Measure stated in the contract for the product sold (Refer to Attachment A-Appendix E for an acceptable list of units for this field). Field Number 34: Rate Current Definition: Rate charged for this product per unit. Used when a single rate is designated for a product. Proposed Definition: The charge for the product per unit as stated in the contract. Field Number 35: Rate Minimum Current Definition: Minimum rate to be charged per the contract, if a range is specified. Proposed Definition: No Change. Field Number 36: Rate Maximum Current Definition: Maximum rate to be charged per the contract, if a range is specified. Proposed Definition: No Change. Field Number 37: Rate Description Current Definition: Text description of rate. May reference FERC tariff, or, if a discounted or negotiated rate, include algorithm. Proposed Definition: No Change. Field Number 38: Rate Units Current Definition: The unit of measurement for the quantity and rates represented. Examples include KW, MW, and MWH. Proposed Definition: Measure stated in the contract for the product sold. (Refer to Attachment A-Appendix F for an acceptable list of rate units for this field). Field Number 39: Point of Receipt Balancing Authority (PORBA) Current Definition: The registered control area abbreviation used in OASIS applications. Proposed Definition: The registered NERC Balancing Authority (formerly called NERC Control Area) abbreviation used in OASIS applications or “Hub” if point of receipt is at a restricted trading hub. Field Number 40: Point of Receipt Specific Location (PORSL) Current Definition: The specific location for the point of receipt
(POR)as spelled out in the contract. Examples include a named sub-station or generation plant. Proposed Definition: The 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. (Refer to Attachment A-Appendix C for an acceptable list of locations for this field). Field Number 41: Point of Delivery Balancing Authority (PODBA) Current Definition: The registered control area abbreviation used in OASIS applications. Proposed Definition: The registered NERC Balancing Authority (formerly called NERC Control Area) abbreviation used in OASIS applications or “Hub” if point of receipt is at a restricted trading hub. Field Number 42: Point of Delivery Specific Location (PODSL) Current Definition: The specific location for the point of delivery
(POD)as spelled out in the contract. Examples include a named sub-station or generation plant. Proposed Definition: The 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. (Refer to Attachment A-Appendix C for an acceptable list of hubs for this field). Field Number 43: Begin Date Current Definition: Beginning date [of] for the product specified (this should be specified here as explicitly as it is specified in the contract, i.e., yyyy+mo+dd+hh+mm+ss+tz). TZ = time zone. Proposed Definition: First date for the sale of the product at the rate specified. Field Number 44: End Date Current Definition: Ending date for the product specified (this should be specified here as explicitly as it is specified in the contract, i.e., yyyy+mo+dd+hh+mm+ss+tz). TZ = time zone. Proposed Definition: Last date for the sale of the product at the rate specified. Field Number 45: Time Zone. Current Definition: None. Proposed Definition: The time zone in which the sales will be made under the contract. (Refer to Attachment A-Appendix D for an acceptable list of time zones for this field). TRANSACTION DATA Field Number 46: Transaction Unique ID Current Definition: None. Proposed Definition: 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. Field Number 47: Seller Company Name Current Definition: Name of company (For consistency sake, it must be represented the same as it is listed in the DUNS Report.) Proposed Definition: 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). Field Number 48: Customer Company Name Current Definition: Name of company. (For consistency sake, it must be represented the same as it is listed in the DUNS Report.) Proposed Definition: The name of the counterparty to the contract. Field Number 49: Customer DUNS Number Current Definition: DUNS Number for Company Unique Identification. Proposed Definition: The unique nine digit number assigned by Dun and Bradstreet to the counterparty to the contract. Field Number 50: FERC Tariff Reference Current Definition: Valid Entries: FERC's designation, e.g., “FERC Electric Tariff, Second Revised Volume No. 5, Schedule 2;” or “FERC Electric Rate Schedule No. 126.” Proposed Definition: The FERC tariff reference cites the document that specifies the terms and conditions under which a Seller is authorized to make transmission sales or power sales 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. Field Number 51: Contract Service Agreement ID Current Definition: Unique (company) name given to each service agreement. It may be the number assigned by FERC for those service agreements that have been filed and approved by the Commission, or it can be an internal numbering system. Proposed Definition: 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. Field Number 52: Transaction Unique Identifier Current Definition: Unique reference number assigned by the seller for each transaction. Proposed Definition: No Change. Field Number 53: Transaction Begin Date Current Definition: Transaction begin date must be prior to the end of the reporting quarter. Date must contain hours, minutes, seconds, and time zone (MM.DD.YYYY.HH.MM.SS.TZ). Where minutes and seconds are not provided, default to zeros. Proposed Definition: First date and time the product is sold during the quarter at the specified price. Field Number 54: Transaction End Date Current Definition: Transaction end date and time must be after the beginning of the reporting quarter. Date must contain hours, minutes, seconds, and time zone (MM.DD.YYYY.HH.MM.SS.TZ). Where minutes and seconds are not provided, default to zeros. Proposed Definition: Last date and time the product is sold during the quarter at the specified price. Field Number 55: Time Zone. Current Definition: None. Proposed Definition: The time zone in which the sales will be made under the contract. (Refer to Attachment A-Appendix D for an acceptable list of time zones for this field). Field Number 56: Point of Delivery Balancing Authority (PODBA) Current Definition: The registered control area abbreviation used in OASIS applications. Proposed Definition: The registered NERC Balancing Authority (formerly called NERC Control Area) abbreviation used in OASIS applications or “Hub” if point of receipt is at a restricted trading hub. Field Number 57: Point of Delivery Specific Location (PODSL) Current Definition: The specific location for the point of delivery
(POD)as spelled out in the contract. Examples include sub-station or generation plant. Proposed Definition: The specific location at which the product is delivered. If receipt occurs at a trading hub, a standardized hub name must be used. (Refer to Attachment A-Appendix C for an acceptable list of hubs for this field). Field Number 58: Class Name Current Definition: Name of class. Valid entries are F-Firm, NF-Non-Firm, UP-Unit Power Sale, BA-Billing Adjustment, and N/A-Not Applicable. Proposed Definition: • F-Firm: For transmission sales, service or product that always has priority over non-firm service. For power sales, service or product that is not interruptible for economic reasons. • NF-Non-Firm: For transmission sales, 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 transmission service. An energy 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. • UP-Unit Power Sale: Designates a dedicated sale of energy and capacity from one or more than one generation unit(s). • BA-Billing Adjustment: Incremental positive or negative material change to previous EQR totals. • N/A-Not Applicable: To be used only when the other available class names do not apply. Field Number 59: Term Name Current Definition: Name for term. LT = Long-Term (> one year), ST = Short-Term (≤ one year). Proposed Definition: Power sales transactions with durations one year or greater are long-term. Transactions with shorter durations are short-term. Field Number 60: Increment Name Current Definition: Name of increment which would be one of the following: H = Hourly, D = Daily, W = Weekly, M = Monthly, Y = Yearly (or annually) or {registered}. (New items may be included in this list provided they are registered with FERC prior to their inclusion in the filing.) Proposed Definition: • H-Hourly: Terms of the particular sale set for up to 6 consecutive hours (≤ 6 consecutive hours) Includes LMP based sales in ISO/RTO markets. • D-Daily: Terms of the particular sale set for more than 6 and up to 36 consecutive hours (> 6 and ≤ 36 consecutive hours) Includes sales over a peak or off-peak block during a single day. • W-Weekly: Terms of the particular sale set for over 36 consecutive hours and up to 168 consecutive hours (> 36 and ≤ 168 consecutive hours). Includes sales for a full week and sales for peak and off-peak blocks over a particular week. • M-Monthly: Terms of the particular sale set for set for more than 168 consecutive hours up to one month (> 168 consecutive hours and ≤ 1 month). Includes sales for full month or multi-week sales during a given month. • S-Seasonal: Terms of the specific sales set for greater than one month and less than 365 consecutive days (> 1 month and < 1 year). • Y-Yearly: Terms 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 indexed). • N/A-Not Applicable: To be used only when other available increment names do not apply. Field Number 61: Increment Peaking Name Current Definition: Name for increment peaking. For product, services, or transaction[s] that are identified as P = On Peak, OP = Off-Peak, FP = Full Period, N/A = Not Applicable, Undefined. Proposed Definition: • FP—Full Period: The product described may be sold during all hours under the contract. • OP—Off-Peak: The product described may be sold only during those hours designated as off-peak in the NERC region of the point of delivery. • P—Peak: The product described may be sold only during those hours designated as on-peak in the NERC region of the point of delivery. • N/A—Not Applicable: To be used only when other available increment peaking names do not apply. Field Number 62: Product Name Current Definition: A product is something being bought and sold, a type of service or standard agreement. Proposed Definition: Description of product being offered. (Refer to Attachment A-Appendix A for an acceptable list of product names for this field). Field Number 63: Transaction Quantity Current Definition: The quantity of the product in this transaction. This could be a whole number or it could include decimals. Proposed Definition: The quantity of the product in this transaction. Field Number 64: Price Current Definition: Rate charged for this item per unit. Used with contract data when a single rate is designated for a product. Used with transaction data to designate the transaction period's weighted average actual rate. Proposed Definition: Price charged for the product per unit. Field Number 65: Rate Units Current Definition: The unit of measurement for the quantity and rates represented. Examples include KW, MW, and MWH. Proposed Definition: Measure appropriate to the price of the product sold. (Refer to Attachment A-Appendix F for an acceptable list of rate units for this field). Field Number 66: Total Transmission Charge Current Definition: State N/A if transmission is not provided by the selling entity, else this represents the total transmission charge associated with the identified power sale transaction. Proposed Definition: Payments received for transmission services when explicitly identified. Field Number 67: Total Transaction Charge Current Definition: Total revenue for transaction, including for the commodity and all other services related to the commodity sale under the terms of the contract, including bundled ancillary and transmission services provided by the respondent or others. This is in dollars and cents. Proposed Definition: Transaction Quantity (Field 63) times Price (Field 64) plus Total Transmission Charge (Field 66). PRODUCT NAME APPENDIX BLACK START SERVICE Current Definition: 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) Proposed Definition: No Change. BOOKED OUT POWER Energy or capacity contractually committed bilaterally for delivery but not actually delivered due to some offsetting or countervailing trade (Transaction only). Proposed Definition: No Change. CAPACITY A quantity of demand that is charged on a $/KW or $/MW basis. Proposed Definition: No Change. CAPACITY REASSIGNMENT Current Definition: None. Proposed Definition: An agreement under which a transmission customer sells, assigns or transfers all or portion of its rights to an eligible customer. CUSTOMER CHARGE Current Definition: Fixed contractual charges assessed on a per customer basis that could include billing service. Proposed Definition: No Change. DIRECT ASSIGNMENT FACILITIES CHARGE Charges for facilities or portions of facilities that are constructed or used for the sole use/benefit of a particular customer. Proposed Definition: No Change. EMERGENCY ENERGY Contractual provisions to supply energy or capacity to another entity during critical situations. Proposed Definition: No Change. ENERGY A quantity of electricity that is sold or transmitted over a period of time. Proposed Definition: No Change. ENERGY IMBALANCE Service provided when a difference occurs between the scheduled and the actual delivery of energy to a load obligation. Proposed Definition: No Change. EXCHANGE (Previously “Exchange Agreement”.) Transaction whereby the receiver accepts delivery of energy for a supplier's account and returns energy later at times, rates, and in amounts as mutually agreed. Proposed Definition: The product name is being changed from “Exchange Agreement” to “Exchange.” However, the underlying definition is not proposed to be changed. FUEL CHARGE Current Definition: Charge based on the cost or amount of fuel used for generation. Proposed Definition: No Change. GRANDFATHERED BUNDLED Services provided for bundled transmission, ancillary services and energy under contracts effective prior to Order No. 888's OATTs. Proposed Definition: No Change. INTERCONNECTION AGREEMENT 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. Proposed Definition: No Change. MEMBERSHIP AGREEMENT Agreement to participate and be subject to rules of a system operator. Proposed Definition: No Change. MUST RUN AGREEMENT An agreement that requires a unit to run. Proposed Definition: No Change. NEGOTIATED-RATE TRANSMISSION Transmission performed under a negotiated rate contract (applies only to merchant transmission companies). Proposed Definition: No Change. NETWORK Transmission service under contract providing network service. Proposed Definition: No Change. NETWORK OPERATING AGREEMENT 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. Proposed Definition: No Change. OTHER Product name not otherwise included. Proposed Definition: No Change. POINT-TO-POINT AGREEMENT Transmission service under contract between specified Points of Receipt and Delivery. Proposed Definition: No Change. REACTIVE SUPPLY & VOLTAGE CONTROL Production or absorption of reactive power to maintain voltage levels on transmission systems (Ancillary Service). Proposed Definition: No Change. REAL POWER TRANSMISSION LOSS The loss of energy, resulting from transporting power over a transmission system. Proposed Definition: No Change. REGULATION & FREQUENCY RESPONSE 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 as necessary to follow the moment-by-moment changes in load (Ancillary Service). Proposed Definition: 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 Current Definition: 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.) Proposed Definition: No Change. SCHEDULE SYSTEM CONTROL & DISPATCH 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). Proposed Definition: No Change. SPINNING RESERVE Unloaded synchronized generating capacity that is immediately responsive to system frequency and that is capable of being loaded in a short time period (Ancillary Service). Proposed Definition: 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 Current Definition: Service needed to serve load in the event of a system contingency, available with greater delay than SPINNING RESERVE (Ancillary Service). Proposed Definition: 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 Current Definition: 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. Proposed Definition: No Change. TOLLING ENERGY Current Definition: None. Proposed Definition: 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 Current Definition: The agreement that establishes the terms and conditions under which a transmission owner transfers to an ISO operational control over designated transmission facilities. Proposed Definition: The agreement that establishes the terms and conditions under which a transmission owner transfers operational control over designated transmission facilities. UPLIFT Current Definition: None. Proposed Definition: A make-whole payment by an RTO/ISO to the EQR filer. Balancing Authority Appendix: Ameren Native Load—No Change Alabama Electric Cooperative, Inc.—No Change Associated Electric Cooperative, Inc.—No Change Alberta Electric System Operator—No Change AESC, LLC—Wheatland CIN-Revised NERC Definition—AEWC, Allegheny Energy Supply Company, LLC—Wheatland CIN, ECAR Alliant Energy—CA—ALTE-Revised NERC Definition—ALTE, Alliant Energy Corporate Services, Inc.—East, MRO Alliant Energy—CA—ALTW—Revised NERC Definition—ALTW, Alliant Energy Corporate Services, Inc.—West, MRO Ameren Transmission—Revised NERC Definition—AMRN, Ameren Transmission (legal name Ameren Services Company), SERC Avista Corp.—Revised NERC Definition—AVA, Avista Corp., WSCC Arizona Public Service Company—Revised NERC Definition—AZPS, Arizona Public Service Company, WSCC CECD, LLC—Batesville—No Change British Columbia Transmission Corporation—No Change Bonneville Power Administration Transmission—Revised NERC Definition—BPAT, Bonneville Power Administration Transmission, WSCC Big Rivers Electric Corp.—Revised NERC Definition—BREC, Big Rivers Electric Corp., SERC Comision Federal de Electricidad—Revised NERC Definition—CFE, Comision Federal de Electricidad, WSCC Chelan County PUD—Revised NERC Definition—CHPD, Chelan County PUD, WSCC Central Illinois Light Co—Revised NERC Definition—CILC, Central Illinois Light Co, SERC Cinergy Corporation—No Change California Independent System Operator—Revised NERC Definition—CISO, California Independent System Operator (CAISO), WSCC Cleco Power LLC—No Change CECD, LLC—No Change Michigan Electric Coordinated System—Consumers—No Change Carolina Power & Light Company—CPLE—Revised NERC Definition—CPLE, Carolina Power & Light Company—East, SERC Carolina Power & Light Company—CPLW—Revised NERC Definition—CPLW, Carolina Power & Light Company—West, SERC Central and Southwest—No Change Columbia Water & Light—Revised NERC Definition—CWLD, Central and Southwest, SERC City Water Light & Power—Revised NERC Definition—CWLP, City Water Light & Power, RFC DECA, LLC—Arlington Valley—Revised NERC Definition—DEAA, CECD, LLC—Arlington Valley, WSCC Michigan Electric Coordinated System—Detroit Edison—No Change DECA, LLC—North Little Rock—Revised NERC Definition—DENL, ECD, LLC—North Little Rock, SERC CECD, LLC—City of Ruston, LA—No Change P.U.D. No. 1 of Douglas County—Revised NERC Definition—DOPD, P.U.D. No. 1 of Douglas County, WSCC Dairyland Power Cooperative—Revised NERC Definition—DPC, Dairyland Power Cooperative, MRO Duke Energy Corporation—Revised NERC Definition—DUK, Duke Power Company LLC (Transmission), SERC Empire District Electric Co., The—No Change Electric Energy, Inc.—No Change Entergy—No Change East Kentucky Power Cooperative, Inc.—Revised NERC Definition—EKPC, East Kentucky Power Cooperative, Inc., SERC El Paso Electric—Revised NERC Definition—EPE, El Paso Electric, WSCC ERCOT ISO—No Change American Transmission Systems, Inc.—No Change Florida Municipal Power Pool—No Change Florida Power Corporation—No Change Florida Power & Light—No Change GridAmerica—No Change Grant County PUD No.2—Revised NERC Definition—GCPD, Grant County PUD No.2, WSCC Grand River Dam Authority—No Change Great River Energy—Revised NERC Definition—GRE, Great River Energy, MRO Great River Energy—No Change Great River Energy—No Change Great River Energy—No Change CECD, LLC—Gila River—No Change Georgia System Operations Corporation—No Change Georgia Transmission Corporation—No Change Gainesville Regional Utilities—No Change Hoosier Energy—No Change CECD, LLC—Harquahalla—No Change Hydro—Quebec, TransEnergie—No Change City of Homestead—No Change Imperial Irrigation District—Revised NERC Definition—IID, Imperial Irrigation District, WSCC City of Independence P&L Dept.—No Change Illinois Power Co.—Revised NERC Definition—IP, Illinois Power Co., SERC Idaho Power Company—Revised NERC Definition—IPCO, Idaho Power Company, WSCC Indianapolis Power & Light Company—No Change Illinois Power Co.—No Change ISO New England Inc.—No Change JEA—No Change Board of Public Utilities—No Change Kansas City Power & Light, Co—No Change Lafayette Utilities System—No Change Louisiana Generating, LLC—No Change Los Angeles Department of Water and Power—Revised NERC Definition—LDWP, Los Angeles Department of Water and Power, WSCC Louisiana Energy & Power Authority—No Change Lincoln Electric System—No Change LG&E Energy Transmission Services—Revised NERC Definition—LGEE, E.ON U.S. Services Inc., RFC Montana—Dakota Utilities Co.—No Change MidAmerican Energy Company—No Change Michigan Electric Coordinated System—Revised NERC Definition—MECS, Michigan Electric Coordinated System, RFC Madison Gas and Electric Company—Revised NERC Definition—MGE, Madison Gas and Electric Company, MRO MHEB, Transmission Services—No Change Midwest ISO—No Change Westar Energy/Missouri Joint Municipal Electric Utility Commission—No Change Minnesota Power, Inc.—No Change Aquila Networks—MPS-Revised NERC Definition—MPS, Aquila Networks—Missouri Public Service, SPP Muscatine Power and Water—No Change New Brunswick Power Corporation—No Change Nevada Power Company—Revised NERC Definition—NEVP, Nevada Power Company, WSCC New Horizons Electric Cooperative—No Change Northern Indiana Public Service Company—Revised NERC Definition—NIPS, Northern Indiana Public Service Company, RFC Nebraska Public Power District—No Change Utilities Commission, City of New Smyrna Beach—No Change Northern States Power Company—Revised NERC Definition—NSP, Northern States Power Company, MRO NorthWestern Energy—No Change New York Independent System Operator—No Change Oklahoma Gas and Electric—No Change Ontario—Independent Electricity System Operator—No Change OPPD CA/TP—No Change Otter Tail Power Company—Revised NERC Definition—OTP, Otter Tail Power Company, MRO Ohio Valley Electric Corporation—Revised NERC Definition—OVEC, Ohio Valley Electric Corporation, RFC PacifiCorp—East—Revised NERC Definition—PACE, PacifiCorp—East, WSCC PacifiCorp—West—Revised NERC Definition—PACE, PacifiCorp—West, WSCC Portland General Electric—Revised NERC Definition—PGE, Portland General Electric, WSCC PJM Interconnection—Revised NERC Definition—PJM, PJM Interconnection, RFC Public Service Company of New Mexico—Revised NERC Definition—PNM, Public Service Company of New Mexico, WSCC Public Service Company of Colorado—Revised NERC Definition—PSCO, Public Service Company of Colorado CA&TP, WSCC Puget Sound Energy Transmission—Revised NERC Definition—PSEI, Puget Sound Energy Transmission, WSCC CECD, LLC—Arkansas—No Change Reedy Creek Improvement District—No Change Santee Cooper—No Change South Carolina Electric & Gas Company—No Change Seattle City Light—Revised NERC Definition—SCL, Seattle City Light, WSCC Seminole Electric Cooperative—No Change Sunflower Electric Power Corporation—No Change Southeastern Power Administration—Revised NERC Definition—SEHA, Southeastern Power Administration—Hartwell, SERC Southeastern Power Administration—Revised NERC Definition—SERU, Southeastern Power Administration—Russell, SERC Southeastern Power Administration—Revised NERC Definition—SETH, Southeastern Power Administration—Thermond, SERC Southern Indiana Gas & Electric Co.—Revised NERC Definition—SIGE, Southern Indiana Gas & Electric Co., RFC Southern Illinois Power Cooperative—Revised NERC Definition—SIPC, Southern Illinois Power Cooperative, SERC South Mississippi Electric Power Association—No Change South Mississippi Electric Power Association—No Change Southern Minnesota Municipal Power Agency—No Change Sacramento Municipal Utility District—Revised NERC Definition—SMUD, Sacramento Municipal Utility District, WSCC Southern Company Services, Inc.—No Change Southwestern Power Administration—No Change SaskPower Grid Control Centre—No Change Sierra Pacific Power Co.—Transmission—Revised NERC Definition—SPPC, Sierra Pacific Power Co.—Transmission, WSCC Southwestern Public Service Company—No Change Salt River Project—Revised NERC Definition—SRP, Salt River Project, WSCC Southwest Power Pool—No Change City of Tallahassee—No Change Tampa Electric Company—No Change Tucson Electric Power Company—Revised NERC Definition—TEPC, Tucson Electric Power Company, WSCC North American Electric Reliability Council—No Change Turlock Irrigation District—No Change TRANSLink Management Company—No Change Tacoma Power—Revised NERC Definition—TPWR, Tacoma Power, WSCC Tennessee Valley Authority ESO—No Change Upper Peninsula Power Co.—No Change Western Area Power Administration—CM—Revised NERC Definition—WACM, Western Area Power Administration—Colorado-Missouri, WSCC Western Area Power Administration—DSW—Revised NERC Definition—WALC, Western Area Power Administration—Lower Colorado, WSCC Western Area Power Administration—UGPR—Revised NERC Definition—WAUE, Western Area Power Administration—Upper Great Plains East, MAPP Western Area Power Administration—UGPR—Revised NERC Definition—WAUW, Western Area Power Administration—Upper Great Plains West, WSCC Wisconsin Energy Corporation—Revised NERC Definition—WEC, Wisconsin Energy Corporation, RFC Western Farmers Electric Cooperative—No Change CECD, LLC—No Change Aquila Networks—West Plains Dispatch—No Change Aquila Networks—WPK—Revised NERC Definition—WPEK, Aquila Networks—Kansas, SPP Wisconsin Public Service Corporation—Revised NERC Definition—WPS, Wisconsin Public Service Corporation, MRO Westar Energy, Inc.—No Change Yadkin, Inc.—No Change HUB APPENDIX ADHUB Current Definition: None Proposed Definition: The aggregated Locational Marginal Price (“LMP”) nodes defined by PJM Interconnection, LLC as the AEP/Dayton Hub. AEP
(into)Current Definition: None Proposed Definition: The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into the AEP balancing authority. AEPGenHub Current Definition: None Proposed Definition: The aggregated Locational Marginal Price (“LMP”) nodes defined by PJM Interconnection, LLC as the AEPGenHub. COB Current Definition: None Proposed Definition: The set of delivery points along the California-Oregon commonly identified as and agreed to by the counterparties to constitute the COB Hub. Cinergy
(into)Current Definition: None Proposed Definition: 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)Current Definition: None Proposed Definition: The aggregated Elemental Pricing nodes (“Epnodes”) defined by the Midwest Independent Transmission System Operator, Inc., as Cinergy Hub (MISO). Comed
(into)Current Definition: None Proposed Definition: The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into the Commonwealth Edison balancing authority. Entergy
(into)Current Definition: None Proposed Definition: The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into the Entergy balancing authority. FE Hub Current Definition: None Proposed Definition: The aggregated Elemental Pricing nodes (“Epnodes”) defined by the Midwest Independent Transmission System Operator, Inc., as FE Hub (MISO). Four Corners Current Definition: None Proposed Definition: The set of delivery points at the Four Corners power plants commonly identified as and agreed to by the counterparties to constitute the Four Corners Hub. Illinois Hub
(MISO)Current Definition: None Proposed Definition: The aggregated Elemental Pricing nodes (“Epnodes”) defined by the Midwest Independent Transmission System Operator, Inc., as Illinois Hub (MISO). Mead Current Definition: None Proposed Definition: 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)Current Definition: None Proposed Definition: The aggregated Elemental Pricing nodes (“Epnodes”) defined by the Midwest Independent Transmission System Operator, Inc., as Michigan Hub (MISO). Mid-Columbia (Mid-C) Current Definition: None Proposed Definition: 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)Current Definition: None Proposed Definition: The aggregated Elemental Pricing nodes (“Epnodes”) defined by the Midwest Independent Transmission System Operator, Inc., as Minnesota Hub (MISO). NEPOOL (Mass Hub) Current Definition: None Proposed Definition: The aggregated Locational Marginal Price nodes (“LMP”) defined by ISO New England Inc., as Mass Hub. NIHUB Current Definition: None Proposed Definition: The aggregated Locational Marginal Price nodes (“LMP”) defined by PJM Interconnection, LLC as the Northern Illinois Hub. NOB Current Definition: None Proposed Definition: 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 Current Definition: None Proposed Definition: 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 Current Definition: None Proposed Definition: 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 Current Definition: None Proposed Definition: The aggregated Locational Marginal Price nodes (“LMP”) defined by PJM Interconnection, LLC as the PJM East Hub. PJM South Hub Current Definition: None Proposed Definition: The aggregated Locational Marginal Price nodes (“LMP”) defined by PJM Interconnection, LLC as the PJM South Hub. PJM West Hub Current Definition: None Proposed Definition: The aggregated Locational Marginal Price nodes (“LMP”) defined by PJM Interconnection, LLC as the PJM Western Hub. Palo Verde Current Definition: None Proposed Definition: The switch yard at the Palo Verde nuclear power station west of Phoenix in Arizona. SOCO
(into)Current Definition: None Proposed Definition: The set of delivery points commonly identified as and agreed to by the counterparties to constitute delivery into the Southern Company balancing authority. SP15 Current Definition: None Proposed Definition: 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)Current Definition: None Proposed Definition: 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 Current Definition: None Proposed Definition: 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. TIME ZONE APPENDIX AD—Never previously defined—Atlantic Daylight AP—Never previously defined—Atlantic Prevailing AS—Never previously defined—Atlantic Standard CD—Never previously defined—Central Daylight CP—Never previously defined—Central Prevailing CS—Never previously defined—Central Standard ED—Never previously defined—Eastern Daylight EP—Never previously defined—Eastern Prevailing ES—Never previously defined—Eastern Standard MD—Never previously defined—Mountain Daylight MP—Never previously defined—Mountain Prevailing MS—Never previously defined—Mountain Standard NA—Never previously defined—Not Applicable PD—Never previously defined—Pacific Daylight PP—Never previously defined—Pacific Prevailing PS—Never previously defined—Pacific Standard UT—Never previously defined—Universal Time UNITS APPENDIX KV—Never previously defined—kilovolt KVA—Never previously defined—kilovolt amperes KVR—Never previously defined—kilovar KW—Never previously defined—kilowatt KWH—Never previously defined—kilowatt hour KW—DAY—Never previously defined—kilowatt day KW—MO—Never previously defined—kilowatt month KW—WK—Never previously defined—kilowatt week KW—YR—Never previously defined—kilowatt year MVAR—YR—Never previously defined—megavar year MW—Never previously defined—megawatt MWH—Never previously defined—megawatt hour MW—DAY—Never previously defined—megawatt day MW—MO—Never previously defined—megawatt month MW—WK—Never previously defined—megawatt week MW—YR—Never previously defined—megawatt year RKVA—Never previously defined—reactive kilovolt amperes FLAT RATE—Never previously defined—flat rate RATE UNITS APPENDIX $/KV—Never previously defined—dollars per kilovolt $/KVA—Never previously defined—dollars per kilovolt amperes $/KVR—Never previously defined—dollars per kilovar $/KW—Never previously defined—dollars per kilowatt $/KWH—Never previously defined—dollars per kilowatt hour $/KW—DAY—Never previously defined—dollars per kilowatt day $/KW—MO—Never previously defined—dollars per kilowatt month $/KW—WK—Never previously defined—dollars per kilowatt week $/KW—YR—Never previously defined—dollars per kilowatt year $/MW—Never previously defined—dollars per megawatt $/MWH—Never previously defined—dollars per megawatt hour $/MW—DAY—Never previously defined—dollars per megawatt day $/MW—MO—Never previously defined—dollars per megawatt month $/MW—WK—Never previously defined—dollars per megawatt week $/MW—YR—Never previously defined—dollars per megawatt year $/MVAR—YR—Never previously defined—dollars per megavar year $/RKVA—Never previously defined—dollars per reactive kilovar amperes CENTS—Never previously defined—cents CENTS/KVR—Never previously defined—cents per kilovolt amperes CENTS/KWH—Never previously defined—cents per kilowatt hour FLAT RATE—Never previously defined—rate not specified by any other units [FR Doc. E7-8640 Filed 5-7-07; 8:45 am] BILLING CODE 6717-01-P ENVIRONMENTAL PROTECTION AGENCY [FRL-8309-5] Issuance of Final NPDES General Permit for Groundwater Remediation Discharge Facilities in Idaho (Permit No. ID-G91-0000) AGENCY: Environmental Protection Agency (EPA). ACTION: Notice of availability of final NPDES general permit. SUMMARY: The Director, Office of Water and Watersheds, EPA Region 10, is publishing notice of availability of a general National Pollutant Discharge Elimination System (NPDES) permit for groundwater remediation discharge facilities in Idaho, pursuant to the provisions of the Clean Water Act, 33 U.S.C. 1251 *et seq.* The general permit authorizes the discharge of treated groundwater from new and existing facilities to surface waters of the United States within the State of Idaho. Existing dischargers must apply for coverage within 90 days of the effective date of the permit by submitting a Notice of Intent
(NOI)in accordance with the instructions in the permit. New dischargers whose operations commence after the effective date of the general permit must submit a NOI at least 30 days prior to the commencement of the discharge. A fact sheet has also been prepared which sets forth the principle factual, legal, policy, and scientific information considered in the development of the general permit. The general permit contains a variety of technology-based and water quality-based effluent limitations for 55 pollutants of concern commonly found in contaminated groundwater, along with administrative and monitoring requirements, as well as other standard conditions, prohibitions, and management practices. Effluent limits are applied at end-of-pipe with no mixing zone. However, mixing zones are available on an individual basis at the discretion of the Idaho Department of Environmental Quality
(IDEQ)for pollutants with water quality-based effluent limits. Mixing zones will be granted through an individual State certification that will be attached to EPA's authorization to discharge letter. DATES: *Effective Date:* The general NPDES permit shall become effective on July 1, 2007. *Public Comment:* Pursuant to section 402 of the Clean Water Act, EPA proposed the draft general permit and solicited comments in the **Federal Register** at 71 FR 34131-34132 (June 13, 2006). Notice of the draft permit was also published in the Idaho Statesman and the Coeur d'Alene Press. The 60 day comment period on the draft permit expired on August 14, 2006. In addition, copies of the draft permit were sent to known groundwater remediation facilities discharging to surface water in Idaho. Changes have been made from the draft permit to the final permit in response to comments received from facility representatives, government agencies, and trade groups. All comments, along with EPA's responses, are summarized in the Response to Comment document. The general permit, fact sheet, and Response to Comment document may be obtained by contacting Robert Rau; USEPA Region 10; 1200 6th Ave, OWW-130; Seattle, Washington 98101; or via e-mail at *rau.rob@epa.gov* . These documents may also be downloaded from the Region 10 Web site at *http://www.epa.gov/r10earth/waterpermits.htm* (click on general permits). Other Legal Requirements State Water Quality Standards and State Certification Pursuant to Section 401 of the Clean Water Act, IDEQ has certified that the conditions of the general permit comply with State Water Quality Standards (IDAPA 58.01.02), including the State's antidegradation policy. Endangered Species Act EPA has determined that issuance of the groundwater remediation discharge general permit will have no affect any threatened or endangered species, designated critical habitat, or essential fish habitat. Executive Order 12866 EPA has determined that this general permit is not a “significant regulatory action” under the terms of Executive Order 12866 and is therefore not subject to Office of Management and Budget
(OMB)review. Paperwork Reduction Act The information collection requirements of this general permit were previously approved by the OMB under the provisions of the Paperwork Reduction Act, 44 U.S.C. 3501 *et seq.* , and assigned OMB control numbers 2040-0086 (NPDES permit application) and 2040-0004 (discharge monitoring reports). Regulatory Flexibility Act The Regulatory Flexibility Act (RFA), 5 U.S.C. 601 *et seq.* , requires that EPA prepare a regulatory flexibility analysis for rules subject to the requirements of 5 U.S.C. 553(b) that have a significant impact on a substantial number of small entities. However, general NPDES permits are not “rules” subject to the requirements of 5 U.S.C. 553(b), and is therefore not subject to the RFA. Unfunded Mandates Reform Act Section 201 of the Unfunded Mandates Reform Act (UMRA), Public Law 104-4, generally requires federal agencies to assess the effects of their “regulatory actions” (defined to be the same as “rules” subject to the RFA) on tribal, State, and local governments and the private sector. However, the general permit issued today is not a “rule” subject to the RFA, and is therefore not subject to the UMRA. Appeal of Permit Any interested person may appeal the general permit in the Federal Court of Appeals in accordance with section 509(b)(1) of the Clean Water Act. This appeal must be filed within 120 days of the permit effective date. Persons affected by the permit may not challenge the conditions of the permit in further EPA proceedings (see 40 CFR 124.19). Instead, they may either challenge the permit in court or apply for an individual NPDES permit. Signed this 27th day of April, 2007. Michael F. Gearheard, Director, Office of Water and Watersheds. [FR Doc. E7-8664 Filed 5-7-07; 8:45 am] BILLING CODE 6560-50-P EQUAL EMPLOYMENT OPPORTUNITY COMMISSION Notice of Sunshine Act Meeting Agency Holding the Meeting: Equal Employment Opportunity Commission. Date and Time: Wednesday, May 16, 2007, 9:30 a.m. Eastern Time. Place: Clarence M. Mitchell, Jr. Conference Room on the Ninth Floor of the EEOC Office Building, 1801 “L” Street, NW., Washington, DC 20507. Status: The meeting will be open to the public. Matters to be Considered: Open Session 1. Announcement of Notation Votes, 2. Employment Testing and Screening—Invited Panelists, and 3. Full-Service Publication Storage and Distribution Center Contract. Note: In accordance with the Sunshine Act, the meeting will be open to public observation of the Commission's deliberations and voting. (In addition to publishing notices on EEOC Commission meetings in the **Federal Register** , the Commission also provides a recorded announcement a full week in advance on future Commission sessions.) Please telephone
(202)663-7100 (voice) and
(202)663-4074
(TTY)at any time for information on these meetings. The EEOC provides sign language interpretation at Commission meetings for the hearing impaired. Requests for other reasonable accommodations may be made by using the voice and TTY numbers listed above: Contact Person for More Information: Stephen Llewellyn, Acting Executive Officer on
(202)663-4070. This Notice Issued May 4, 2007. Stephen Llewellyn, Acting Executive Officer, Executive Secretariat. [FR Doc. 07-2304 Filed 5-4-07; 3:15 pm]
Connectionstraces to 18
Traces to 18 documents
CFR
- Activities requiring permits.§ 322.3
- Activities not requiring permits.§ 322.4
- Evaluation of petition by the Office of Hearings and Appeals.§ 205.282
- Purpose and scope.§ 205.280
- Applications for refund.§ 205.283
- Termination by implied surrender.§ 6.4
- Method of notice; dates established in notice (Rule 210).§ 385.210
- Filings and Other Submissions.§ 385.2001
- Protests other than under Rule 208 (Rule 211).§ 385.211
- Form and style of rate schedules, tariffs and service agreements.§ 35.10
U.S. Code
public-private-law
register
9 references not yet in our index
- 10 CFR 205
- 10 CFR 211
- Pub. L. 105-277
- Pub. L. 104-13
- 15 USC 717-717w
- 49 USC 20
- 16 USC 791a-825r
- Pub. L. 104-4
- 40 CFR 124.19
Citation graph
cites case law
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Cite10 CFR 205
Cite10 CFR 211
Pub. L.Pub. L. 105-277
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