Contract Reporting Requirements of Intrastate Natural Gas Companies, 29404-29420 [2010-12614]

Download as PDF 29404 Federal Register / Vol. 75, No. 101 / Wednesday, May 26, 2010 / Rules and Regulations and its practical application during the original 30-day comment period. Therefore, the FAA will re-open the comment period for 30 days. ALPA has not formally submitted to the public docket its specific questions about the policy’s practical application and, as mentioned, few commenters provided input in this regard during the open comment period. To receive appropriate consideration, therefore, the FAA requests specific information regarding these concerns be provided during the next 30 days of the re-opened comment period. Re-Opening of Comment Period In accordance with Sec. 11.47(c) of title 14, Code of Federal Regulations, the FAA has reviewed ALPA’s comment for extension of the comment period to Docket FAA–2009–0773. Since the comment period has already closed, the FAA will re-open it for a period of 30 days. The petitioner has shown a substantive interest in the policy and has provided good cause to grant reopening of the comment period. The FAA has determined that re-opening the comment period is consistent with the public interest and that good cause exists for taking this action. Accordingly, the comment period is re-opened until June 25, 2010. Issued in Washington, DC, on May 20, 2010. Frederick E. Tilton, Federal Air Surgeon. [FR Doc. 2010–12576 Filed 5–25–10; 8:45 am] BILLING CODE P DEPARTMENT OF ENERGY Federal Energy Regulatory Commission 18 CFR Part 284 [Docket No. RM09–2–000; Order No. 735] Contract Reporting Requirements of Intrastate Natural Gas Companies May 20, 2010. AGENCY: Federal Energy Regulatory Commission. ACTION: Final rule. SUMMARY: In this Final Rule, the Commission revises the contract reporting requirements for those natural gas pipelines that fall under the Commission’s jurisdiction pursuant to section 311 of the Natural Gas Policy Act or section 1(c) of the Natural Gas Act. The Final Rule revises § 284.126(b) and replaces Form No. 549—Intrastate Pipeline Annual Transportation Report with the new Form No. 549D— Quarterly Transportation and Storage Report for Intrastate Natural Gas and Hinshaw Pipelines. The Final Rule makes changes so as to increase the reporting frequency from annual to quarterly, include certain additional types of information and cover storage transactions as well as transportation transactions, establish a procedure for the Form No. 549D reports to be filed in a uniform electronic format and posted on the Commission’s Web site, and hold that those reports must be public and may not be filed with information redacted as privileged. The Commission is also modifying its policy concerning periodic reviews of the rates charged by section 311 and Hinshaw pipelines to extend the cycle for such reviews from 3 years to 5 years. DATES: Effective Date: This rule will become effective April 1, 2011. FOR FURTHER INFORMATION CONTACT: Vince Mareino (Legal Information), Office of the General Counsel, Federal Energy Regulatory Commission, 888 First Street, NE., Washington, DC 20426, (202) 502–6167, Vince.Mareino@ferc.gov. James Sarikas (Technical Information), Office of Energy Markets Regulation, Federal Energy Regulatory Commission, 888 First Street, NE., Washington, DC 20426, (202) 502– 6831, James.Sarikas@ferc.gov. Thomas Russo (Technical Information), Office of Enforcement, Federal Energy Regulatory Commission, 888 First Street, NE., Washington, DC 20426, (202) 502–8792, Thomas.Russo@ferc.gov. SUPPLEMENTARY INFORMATION: Before Commissioners: Jon Wellinghoff, Chairman; Marc Spitzer, Philip D. Moeller, and John R. Norris. Order No. 735 Final Rule Issued May 20, 2010. Paragraph Nos. emcdonald on DSK2BSOYB1PROD with RULES I. Introduction and Summary .................................................................................................................................................................. II. Background ........................................................................................................................................................................................... III. Statutory Authority for the Rule ........................................................................................................................................................ IV. Need for the Rule ............................................................................................................................................................................... V. Details of Pipeline Posting Requirements .......................................................................................................................................... A. Overview and Summary of Requirements .................................................................................................................................. B. Definition of Reportable Service .................................................................................................................................................. C. Reporting Frequency .................................................................................................................................................................... D. Identification of Receipt and Delivery Points and Shippers ..................................................................................................... E. Requests for Exemptions and Safe Harbor .................................................................................................................................. F. Public Status of Reports ............................................................................................................................................................... G. Data Format and Technical Protocols ......................................................................................................................................... VI. Periodic Rate Review ......................................................................................................................................................................... VII. Effective Date of the Final Rule and Compliance Deadlines .......................................................................................................... VIII. Information Collection Statement ................................................................................................................................................... IX. Environmental Analysis ..................................................................................................................................................................... X. Regulatory Flexibility Act ................................................................................................................................................................... XI. Document Availability ....................................................................................................................................................................... XII. Effective Date and Congressional Notification ................................................................................................................................ I. Introduction and Summary gas pipelines 1 providing interstate 1. In this Final Rule, the Commission revises the contract reporting requirements for (1) intrastate natural 1 Pursuant to section 2(16) of the NGPA, 15 U.S.C. 3301(16), the term ‘‘intrastate pipeline’’ may refer to all entities engaged in natural gas transportation under section 311 of the NGPA or section 1(c) of the NGA. For consistency, this Final Rule will also VerDate Mar<15>2010 17:49 May 25, 2010 Jkt 220001 PO 00000 Frm 00002 Fmt 4700 Sfmt 4700 transportation service pursuant to section 311 of the Natural Gas Policy use the terms ‘‘transportation,’’ ‘‘pipeline,’’ and ‘‘shippers’’ to refer inclusively to storage activity (except where noted). E:\FR\FM\26MYR1.SGM 26MYR1 1 2 15 22 41 41 43 49 54 62 68 80 89 97 103 109 110 112 115 Federal Register / Vol. 75, No. 101 / Wednesday, May 26, 2010 / Rules and Regulations Act of 1978 (NGPA) 2 and (2) Hinshaw pipelines providing interstate service subject to the Commission’s Natural Gas Act (NGA) section 1(c) jurisdiction pursuant to blanket certificates issued under § 284.224 of the Commission’s regulations.3 The revised reporting requirements are intended to increase market transparency, without imposing unduly burdensome requirements on the pipelines. Specifically, the Final Rule revises § 284.126(b) and replaces Form No. 549—Intrastate Pipeline Annual Transportation Report with the new Form No. 549D, so as to (1) increase the reporting frequency from annual to quarterly, (2) include certain additional types of information and cover storage transactions as well as transportation transactions,4 (3) establish a procedure for Form No. 549D to be filed in a uniform electronic format and posted on the Commission’s Web site, and (4) hold that those reports must be public and may not be filed with information redacted as privileged. The Commission is also modifying its policy concerning periodic reviews of the rates charged by section 311 and Hinshaw pipelines to extend the cycle for such reviews from 3 years to 5 years. II. Background A. Current Reporting Requirements 2. NGPA section 311 authorizes the Commission to allow intrastate pipelines to transport natural gas ‘‘on behalf of’’ interstate pipelines or local distribution companies served by interstate pipelines ‘‘under such terms and conditions as the Commission may prescribe.’’ 5 NGPA section 601(a)(2) exempts transportation service authorized under NGPA section 311 from the Commission’s NGA jurisdiction. Congress adopted these provisions in order to eliminate the regulatory barriers between the intrastate and interstate markets and to promote the entry of intrastate pipelines into the interstate market. Such entry eliminates the need for duplication of 2 15 U.S.C. 3372. 1(c) of the NGA exempts from the Commission’s NGA jurisdiction those pipelines which transport gas in interstate commerce if (1) they receive natural gas at or within the boundary of a state, (2) all the gas is consumed within that state and (3) the pipeline is regulated by a state Commission. This exemption is referred to as the Hinshaw exemption after the Congressman who introduced the bill amending the NGA to include section 1(c). See ANR Pipeline Co. v. Federal Energy Regulatory Comm’n, 71 F.3d 897, 898 (1995) (briefly summarizing the history of the Hinshaw exemption). 4 This Final Rule does not eliminate or revise § 284.126(c) and the corresponding Form No. 537, which require a semi-annual storage report. 5 15 U.S.C. 3371(c). emcdonald on DSK2BSOYB1PROD with RULES 3 Section VerDate Mar<15>2010 15:14 May 25, 2010 Jkt 220001 facilities between interstate and intrastate pipelines.6 Shortly after the adoption of the NGPA, the Commission authorized Hinshaw pipelines to apply for NGA section 7 certificates, authorizing them to transport natural gas in interstate commerce in the same manner as intrastate pipelines may do under NGPA section 311.7 3. Subpart C of the Commission’s Part 284 open access regulations (18 CFR § 284.121–126) implements the provisions of NGPA section 311 concerning transportation by intrastate pipelines. Those regulations require that intrastate pipelines performing interstate service under NGPA section 311 must do so on an open access basis.8 However, consistent with the NGPA’s goal of encouraging intrastate pipelines to provide interstate service, the Commission has not imposed on intrastate pipelines all of the Part 284 requirements imposed on interstate pipelines.9 For example, when the Commission first adopted the Part 284 open access regulations in Order No. 436, the Commission exempted intrastate pipelines from the requirement that they offer open access service on a firm basis.10 The Commission found that requiring intrastate pipelines to offer firm service to out-of-state shippers could discourage them from providing any interstate service, because such a requirement could progressively turn the intrastate pipeline into an interstate pipeline against its will and against the will of the responsible state authorities. Similarly, Order No. 636–B exempted intrastate pipelines from the requirements of Order No. 636.11 Those requirements included capacity release, electronic bulletin boards (now Internet 6 EPGT Texas Pipeline, 99 FERC ¶ 61,295 at 62,252–3 (2002). 7 Certain Transportation, Sales, and Assignments by Pipeline Companies not Subject to Commission Jurisdiction Under Section 1(c) of the Natural Gas Act, Order No. 63, FERC Stats. & Regs. ¶ 30,118, at 30,824–25 (1980). 8 See 18 CFR §§ 284.7(b), 284.9(b) and 284.122. 9 Associated Gas Distributors v. FERC, 824 F.2d 981, 1002–1003 (D.C. Cir. 1987) (AGD); Mustang Energy Corp. v. Federal Energy Regulatory Comm’n, 859 F.2d 1447, 1457 (10th Cir. 1988), cert. denied, 490 U.S. 1019 (1988); see also EPGT Texas Pipeline, 99 FERC ¶ 61,295 (2002). 10 Regulation of Natural Gas Pipelines After Partial Wellhead Decontrol, Order No. 436, FERC Stats. & Regs. ¶ 30,665, at 31,502 (1985). 11 Pipeline Service Obligations, and Revisions to Regulations Governing Self-Implementing Transportation Under Part 284 of the Commission’s Regulations; Regulation of Natural Gas Pipelines After Partial Wellhead Decontrol, Order No. 636–B, 61 FERC ¶ 61,272, at 61,992 n.26 (1992), order on reh’g, 62 FERC ¶ 61,007 (1993), aff’d in part and remanded in part sub nom. United Distribution Cos. v. FERC, 88 F.3d 1105 (D.C. Cir. 1996), order on remand, Order No. 636–C, 78 FERC ¶ 61,186 (1997). PO 00000 Frm 00003 Fmt 4700 Sfmt 4700 29405 Web sites), and flexible receipt and delivery points. 4. Section 284.224 of the regulations provides for the issuance of blanket certificates to Hinshaw pipelines to provide open access transportation service ‘‘to the same extent that, and in the same manner’’ as intrastate pipelines are authorized to perform such service by Subpart C. 5. The Commission currently has less stringent transactional reporting requirements for NGPA section 311 intrastate pipelines and Hinshaw pipelines, than for interstate pipelines. In Order No. 637,12 the Commission revised the reporting requirements for interstate pipelines in order to provide more transparent pricing information and to permit more effective monitoring for the exercise of market power and undue discrimination. As adopted by Order No. 637, § 284.13(b) requires interstate pipelines to post on their Internet Web sites basic information on each transportation and storage transaction with individual shippers, including revisions to a contract, no later than the first nomination under a transaction. This information includes: • The name of the shipper. • The contract number (for firm service). • The rate charged. • The maximum rate. • The duration (for firm service). • The receipt and delivery points and zones covered. • The quantity of natural gas covered. • Any special terms or details, such as any deviations from the tariff. • Whether any affiliate relationship exists. 6. Section 284.13(c) of the Commission’s regulations also requires interstate pipelines to file with the Commission on the first business day of each calendar quarter an index of its firm transportation and storage customers and to publish the same information on their Web sites. The information required to be included in the Index of Customers does not include the rates paid by the customers. Section 284.13(e) requires interstate pipelines to file semi-annual reports of their storage injection and withdrawal activities, including the identities of the 12 Regulation of Short-Term Natural Gas Transportation Services and Regulation of Interstate Natural Gas Transportation Services, Order No. 637, FERC Stats. & Regs. ¶ 31,091, clarified, Order No. 637–A, FERC Stats. & Regs. ¶ 31,099, reh’g denied, Order No. 637–B, 92 FERC ¶ 61,062 (2000), aff’d in part and remanded in part sub nom. Interstate Natural Gas Ass’n of America v. FERC, 285 F.3d 18 (D.C. Cir. 2002), order on remand, 101 FERC ¶ 61,127 (2002), order on reh’g, 106 FERC ¶ 61,088 (2004), aff’d sub nom. American Gas Ass’n v. FERC, 428 F.3d 255 (D.C. Cir. 2005). E:\FR\FM\26MYR1.SGM 26MYR1 29406 Federal Register / Vol. 75, No. 101 / Wednesday, May 26, 2010 / Rules and Regulations emcdonald on DSK2BSOYB1PROD with RULES customers, the volumes injected into and withdrawn from storage for each customer and the unit charge and total revenues received. Order No. 637 did not modify the reporting requirements for NGPA section 311 intrastate pipelines and Hinshaw pipelines provided in § 284.126(b) and (c) of the Commission’s regulations. 7. Section 284.126(b) of the Commission’s regulations requires intrastate pipelines to file with the Commission annual reports of their transportation transactions, but not their storage transactions. Those Form No. 549 reports must include the following information: • The name of the shipper receiving transportation service. • The type of service performed (i.e. firm or interruptible). • The total volumes transported for the shipper, including for firm service a separate statement of reservation and usage quantities. • Total revenues received for the shipper, including for firm service a separate statement of reservation and usage revenues. 8. Unlike the interstate pipelines’ reporting requirement (§ 284.13(b)), the current version of § 284.126(b) does not require intrastate pipelines to include in these Form No. 549 reports the rate charged under each contract, the duration of the contract, the receipt and delivery points and zones or segments covered by each contract, whether the contract includes any special terms and conditions, and whether there is an affiliate relationship between the pipeline and the shipper. 9. Section 284.126(c) requires Section 311 intrastate pipelines and Hinshaw pipelines to file Form No. 537, a semiannual report of their storage activity, within 30 days of the end of each complete storage and injection season. This requirement is substantially the same as the § 284.13(e) requirement that interstate pipelines file such semiannual reports of their storage activity. B. The NOPR 10. In November 2008, the Commission issued a Notice of Inquiry (NOI), requesting comments on whether the Commission should impose additional reporting requirements on NGPA section 311 intrastate pipelines and on Hinshaw pipelines.13 The NOI stated that, in a contemporaneous order, the Commission was denying a request by interstate storage provider with market based rates 14 for waiver of the requirements that interstate pipelines post the rates charged in firm and interruptible transactions no later than first nomination for service. In that order, the Commission held that the fact some interstate storage companies have been authorized to charge market-based rates does not justify exempting them from the requirements in section 284.13(b) that they post the rates charged in each storage transaction. The SGRM order held that the existing posting requirements for interstate pipelines are necessary to provide shippers with the price transparency they need to make informed decisions, and the ability to monitor transactions for undue discrimination and preference.15 The Commission also found that the requested exemption would be contrary to NGA section 4(c)’s requirement that ‘‘every natural gas company * * * keep open * * * for public inspection * * * all rates.’’ 16 11. However, in recognition of interstate storage providers’ concern about the competitive effects of the disparate reporting requirements for interstate pipelines and section 311 intrastate pipelines, the NOI stated that the Commission was interested in exploring (1) whether the disparate reporting requirements for interstate and intrastate pipelines have an adverse competitive effect on the interstate pipelines and (2) if so, whether the Commission should modify the posting requirements for Section 311 intrastate pipelines and Hinshaw pipelines in order to make them more comparable to the § 284.13(b) posting requirements for interstate pipelines. Accordingly, the Commission sought comments to assist it in evaluating whether changes in the Commission’s posting requirements should be considered in order to remove any competitive disadvantage for interstate pipelines, as compared to intrastate pipelines providing interstate transportation and storage services under Section 311 of the NGPA and to Hinshaw pipelines providing such service pursuant to a § 284.224 blanket certificate. 12. Based upon a review of the comments received in response to the NOI, the Commission issued a Notice of Proposed Rulemaking (NOPR),17 proposing to revise its transactional reporting requirements for intrastate and Hinshaw pipelines in order to increase market transparency, without imposing unduly burdensome requirements on 15 SGRM, 13 Contract Reporting Requirement of Intrastate Natural Gas Companies, FERC Stats. & Regs. ¶ 35,559 (2008). 14 SG Resources Mississippi, L.L.C. (SGRM). VerDate Mar<15>2010 15:14 May 25, 2010 Jkt 220001 125 FERC ¶ 61,191 (2008). U.S.C. 717c(c). 17 Contract Reporting Requirements of Intrastate Natural Gas Companies, FERC Stats. & Regs. ¶ 32,644 (2009) (NOPR). those pipelines. The Commission proposed to increase the availability and usefulness of the transactional information reported by intrastate and Hinshaw pipelines by requiring that (1) the existing annual § 284.126(b) transactional reports be filed on a quarterly basis, (2) the quarterly reports include certain additional types of information and cover storage transactions as well as transportation transactions, (3) the quarterly reports be filed in a uniform electronic format and posted on the Commission’s Web site, and (4) the reports must be public and may not be filed with information redacted as privileged. 13. The Commission invited all interested parties to comment on all aspects of the NOPR. The Commission also elaborated on the proposed uniform electronic format in a separate Notice Requesting Comments On Proposed Standardized Electronic Information Collection (Information Notice).18 14. Comments on the NOPR and Information Notice were due on November 4, 2009. Sixteen parties filed comments. A list of Commenters and Abbreviations is included as an appendix to this order. Most commenters were Section 311 or Hinshaw pipelines or their associations, but interstate pipelines, exploration & production companies, and an association of municipal consumers also filed comments. We discuss the comments below in the context of reviewing, amending, and promulgating each aspect of this Final Rule. III. Statutory Authority for the Rule 15. In this section, we address contentions by some commenters that the Commission lacks authority under NGPA section 311 to require intrastate pipelines to file more detailed transactional reports. While some commenters contest specific aspects of our proposal as it affects Hinshaw pipelines, no commenter questions the Commission’s general authority under NGA sections 4 and 10 to require Hinshaw pipelines to file more detailed transactional reports. A. NOPR 16. In the NOPR, the Commission stated that NGPA section 311(c) authorizes the Commission to prescribe the ‘‘terms and conditions’’ under which intrastate pipelines perform interstate service. The NOPR concluded that its proposal to require intrastate pipelines to file and make public the proposed 16 15 PO 00000 Frm 00004 Fmt 4700 Sfmt 4700 18 Contract Reporting Requirements of Intrastate Natural Gas Companies, FERC Stats. & Regs. ¶ 35,051 (2009) (Information Notice). E:\FR\FM\26MYR1.SGM 26MYR1 Federal Register / Vol. 75, No. 101 / Wednesday, May 26, 2010 / Rules and Regulations transactional reports so that shippers and others can monitor NGPA section 311 transactions for undue discrimination is well within the Commission’s broad conditioning authority under § 311(c). B. Comments 17. TPA claims that the Commission lacks statutory authority to enact the proposed regulations, arguing that ‘‘Congressional intent [was] that transactions under NGPA Section 311 are to be subjected to minimal regulation.’’ 19 Enogex, along with TPA, adds that the proposed reporting requirements are ‘‘in direct contravention of Section 311 of the NGPA and the legislative intent,’’ because compliance would be ‘‘unduly burdensome,’’ and because disclosure would harm the pipelines’ business position.20 18. Other commenters, citing the legislative history of the NGPA, argue that the proposed regulations are lawful. Clayton Williams states that ‘‘to the extent the intrastate pipeline is involved in an authorized’’ interstate transaction, the Commission has jurisdiction to review that transaction.21 Similarly, Texas Alliance argues that claims of undue burden are too conclusory, and that the NGPA’s jurisdiction is actually based on whether a given activity of a Section 311 pipeline is interstate or intrastate.22 Clayton Williams argues that it is the purpose of Section 311 to ‘‘help integrate gas markets,’’ and that ‘‘reasonable rules have always been part of the 311 world.’’ 23 Further, Apache argues for even more frequent and detailed reporting, stating, ‘‘the Commission has jurisdiction and discretion to require * * * [intrastate] pipelines to report the same information during the same time frame about natural gas transactions that the interstate pipelines are required to report.’’ 24 Apache reasons ‘‘that interstate pipelines and Section 311 and Hinshaw pipelines are held to the same prohibition on undue discrimination,’’ 25 so the transparency regulations necessary to ensure compliance should be the same as well. C. Commission Determination 19. The Commission’s statutory authority to impose reporting requirements on Section 311 pipelines derives from NGPA section 311(c), which states, ‘‘any authorization granted under this section shall be under such terms and conditions as the Commission may prescribe.’’ 26 This blanket authority is well-established as the ground for the previous reporting requirements for Form No. 549. As the Commission reasoned in the rulemaking establishing a previous version of this reporting requirement, ‘‘section 311 tasks the Commission with the responsibility to ensure rates and charges are fair and equitable. For the Commission to carry out this responsibility, it is important for rates charged to be reported.’’ 27 None of the commenters in this docket challenge the legality of the previous reporting requirements. The new reporting requirements are not so different in scope or burden as to generate serious questions about the Commission’s long-established statutory authority to require transactional reporting. 20. TPA’s characterization that the NGPA limits the Commission to ‘‘minimal regulation,’’ 28 is misleading and unsupported. While Congress sought to encourage intrastate pipelines to participate in the interstate transportation market by enabling them to do so without bearing the burden of full Commission regulation under the NGA,29 this does not mean that Commission regulation under NGPA section 311 was to be minimal. In Associated Gas Distributors v. FERC,30 the court affirmed the Commission’s use of its NGPA section 311(c) conditioning authority to impose conditions necessary to assure that section 311 intrastate pipelines do not engage in undue discrimination. The court also stated ‘‘that the Commission has been correct in its belief that under § 311 it should assert the traditional regulatory approach in areas where it is needed to protect the public from market dominance by natural gas companies.’’ 31 Requiring intrastate 26 15 U.S.C. 3371(c). to Uniform System of Accounts, Forms, Statements, and Reporting Requirements for Natural Gas Companies, Order No. 581, 60 FR 53019, 53050–51, FERC Stats. & Regs. ¶ 31,026 (1995), order on reh’g, Order No. 581–A, FERC Stats. & Regs. ¶ 31,032 (1996) (Order No. 581). 28 TPA at 2. 29 Mustang Energy Corp. v. Federal Energy Regulatory Comm’n, 859 F.2d 1447, 1457 (10th Cir. 1988), cert. denied, 490 U.S. 1019 (1988); see also EPGT Texas Pipeline, 99 FERC ¶ 61,295 (2002). 30 824 F.2d 981, 1002–1003 (D.C. Cir. 1987) (AGD). 31 Id. at 1018 (citation omitted). 27 Revisions 19 TPA at 2. See also id. at 12, 13, 16. at 6. Enogex and several other commenters also raise this concern as a policy argument instead of an argument on statutory authority; these policy arguments are addressed in the subsequent section on the Need for the Rule. 21 Clayton Williams at 4 (quoting H.R. Rep. No. 543, 95th Cong. 1st Sess. 45 (1977)). 22 Texas Alliance at 8. 23 Clayton Williams at 3–4. 24 Apache at 3. 25 Apache at 6. emcdonald on DSK2BSOYB1PROD with RULES 20 Enogex VerDate Mar<15>2010 15:14 May 25, 2010 Jkt 220001 PO 00000 Frm 00005 Fmt 4700 Sfmt 4700 29407 pipelines to file quarterly transactional reports to permit the Commission, shippers, and others to monitor for undue discrimination is fully within the scope of this conditioning authority. 21. While the Commission will consider the burden question in more detail below, commenters have provided no persuasive evidence that the Final Rule is somehow so burdensome as to be beyond Commission’s jurisdiction. As compared to the requirements for interstate pipelines, the Final Rule is limited in the scope of the reports, the burden of publishing a report, and the frequency of the reports. As discussed below, the Commission held itself to these limitations so that the § 284.126(b) requirements should remain lighter than the § 284.13(b) interstate requirements and so that the value of the increased flow of information exceeds the increased burden of reporting. Any further lightening would risk undermining the Final Rule’s ability to increase transparency and improve the functioning of the transportation market. IV. Need for the Rule A. NOPR 22. Upon review of the comments received in response to the NOI, the Commission held that its primary goal in revising the transactional reporting requirements for intrastate and Hinshaw pipelines would be to increase market transparency.32 As the Commission reasoned, ‘‘[t]ransactional information provides price transparency so shippers can make informed purchasing decisions, and also permits both shippers and the Commission to monitor actual transactions for evidence of possible abuse of market power or undue discrimination.’’ 33 The Commission found that certain types of additional information should be published in order to enable shippers, other market participants, and the Commission ‘‘to determine the extent to which particular transactions are comparable to one another,’’ 34 a prerequisite for determining the rights of similarly situated shippers and for detecting undue discrimination. 23. The Commission stated in the NOPR that it ‘‘believes that the revised reporting requirements * * * avoid[ ] unduly burdensome requirements that might discourage * * * participating in the interstate market.’’ 35 In proposing 32 NOPR at 1, 16. at 16. 34 NOPR at 19. 35 NOPR at 17. 33 NOPR E:\FR\FM\26MYR1.SGM 26MYR1 29408 Federal Register / Vol. 75, No. 101 / Wednesday, May 26, 2010 / Rules and Regulations the frequency, content, and format of the reports, the Commission sought the best balance of minimizing the reporting burden and maximizing the competitive effects on the markets. For example, the Commission proposed to host reporting data on its own Web site, and encouraged intrastate pipelines to comment on the preferred file format, in order to help the Commission lessen the information technology burden for pipelines.36 emcdonald on DSK2BSOYB1PROD with RULES B. Comments 24. Several intrastate pipelines argue that the Commission failed to identify sufficiently compelling reasons for revising the reporting requirements. These commenters argue that further transparency is unnecessary, or that the proposal would have little practical benefit.37 Enogex, for example, argues that ‘‘[i]n view of the minimal amount of concern expressed by interstate pipelines * * * the Commission should have terminated this proceeding.’’ 38 AOG suggests that the Commission should, if not abandon the proposal, at least ‘‘more narrowly tailor[ it] to address a perceived problem [regarding] * * * transparency.’’ 39 TPA claims that further transparency in the section 311 and Hinshaw transportation and storage markets is not needed because the United States’ natural gas commodity sales hubs are the most pricetransparent in the world.40 TPA further complains that commenters have yet to ‘‘cite[ ] any specific examples of adverse market impacts’’ from the status quo, and ‘‘no entity has asked the Commission to expand the Section 311 reporting requirements to increase transparency,’’ and is therefore ‘‘not reasoned decision making.’’ 41 25. Several pipelines argue that the new regulations place them at a competitive disadvantage compared to pipelines that only operate under the NGA or under state jurisdiction, or compared to shippers. Similarly, several pipelines complain that the current proposal could be too burdensome,42 potentially causing some pipelines to abandon the Section 311 or Hinshaw markets.43 26. Enogex and Enstor contend that the proposed reporting requirements would harm NGPA section 311 storage providers with market-based rates. Enogex argues that letting competitors 36 NOPR at 28–29. OneOK at 3, TPA at 3. 38 Enogex at 5. 39 AOG at 1. 40 TPA at 11. 41 TPA at 2, 4, 10. 42 E.g., AGA at 7; AOG at 7; Jefferson at 2, 6. 43 E.g., Enogex at 8; TPA at 14. 37 E.g., VerDate Mar<15>2010 15:14 May 25, 2010 Jkt 220001 see its rate information would limit its own ability to ‘‘capture rates’’, calling it ‘‘tantamount to rescinding market-based rate authority.’’ 44 Enogex asserts the Commission should at least exempt storage services provided at marketbased rates. Enogex argues that sufficient public information already exists on storage services, and that the Commission has stated when it authorizes market-based rates that such providers lack market power, thus reducing the need for regulatory scrutiny.45 Enstor is also concerned that the proposed reporting requirements, particularly the requirement to report quarterly revenues received from each storage customer, would allow customers ‘‘to recreate the storage positions’’ that resulted in another customer receiving favorable rates.46 Shippers, Enstor argues, should not have more information about the pipeline than the pipeline has about its shippers. 27. Atmos goes further, warning ‘‘of potential collusion or other anticompetitive behaviors that can be facilitated by untimely public disclosure of transaction-specific information.’’ 47 28. Other commenters, however, applaud the NOPR, arguing that the information sought in the reports would help enable the market to function more efficiently. Cities, Clayton Williams, and Texas Alliance ask the Commission to expand reporting requirements in order to provide greater transparency, especially in the Texas market.48 Cities and others contend that this ‘‘lack of competition in the intrastate pipeline market in Texas’’ could be ameliorated by ‘‘making information and records available both to the public and to shippers.’’ 49 For example, Clayton Williams provides a detailed narrative suggesting that it could have pursued allegations that a pipeline has been engaging in unlawful business practices, if only it had more publicly available information to support its allegation.50 29. These commenters further argue that lack of transparency harms the 44 Enogex at 8. at 11–12. 46 Enstor at 7. 47 Atmos at 5 (citing Transparency Provisions of Section 23 of the Natural Gas Act, Order No. 704, FERC Stats. & Regs. ¶ 31,260 at P. 88 (2007); order on reh’g, Transparency Provisions of Section 23 of the Natural Gas Act, Order No. 704–A, FERC Stats. & Regs. ¶ 31,275 (2008); order on reh’g, Transparency Provisions of Section 23 of the Natural Gas Act, Order No. 704–B, 125 FERC ¶ 61,302 (2008)). 48 Cities at 3; Clayton Williams at 1; Texas Alliance at 8. 49 Cities at 2, 4. 50 Clayton Williams at 5–15. 45 Enogex PO 00000 Frm 00006 Fmt 4700 Sfmt 4700 integrity of national price indices,51 and that the Commission’s proposed new regulations will help state-level transparency, and thus state-level markets, as well.52 Apache also responds to TPA’s argument that interstate pipelines have not sought out the proposed regulation: ‘‘It can be expected that most interstate pipelines would hope to levelize the playing field by eliminating regulation for all pipelines, rather than increasing regulation for all.’’ 53 However, Apache urges, new regulations are warranted based on the expected usefulness of improved access to market information. 30. These commenters also argue that publicly available data is vital to eliminate unfair advantages.54 For example, Apache argues that intrastate and interstate pipelines both face the same economic environment and therefore should report the same information.55 Constellation argues that existing regulations harm the market by leaving shippers without enough information to ‘‘make fully informed purchasing decisions.’’ 56 Texas Alliance and Clayton Williams, likewise, argue that transparency helps limit the abuse of the monopoly power that some pipelines have over upstream shippers.57 31. Commenters also dismiss the notion that the current proposal could be too burdensome.58 Apache argues, ‘‘[a] Section 311 pipeline is not going to forego the opportunity to earn money merely because it must comply with a transactional posting requirement.’’ 59 As Texas Alliance phrases it, the reason why the rulemaking ‘‘is so strongly opposed by the Texas intrastate pipelines and their association [is that i]t threatens to let sunshine in where they prefer the dark.’’ 60 C. Commission Determination 32. In this Final Rule, the Commission is adopting the proposed quarterly transactional reporting requirements for section 311 and Hinshaw pipelines, with several clarifications discussed in subsequent sections of this rule. The Commission finds that these transactional reporting requirements appropriately balance the need for increased transparency of intrastate and Hinshaw pipeline transactions, while 51 Texas Alliance at 4. at 4; Texas Alliance at 6. 53 Apache at 8. 54 E.g., Yates at 6. 55 Apache at 7–8. 56 Constellation at 4. 57 Texas Alliance at 9–10; Clayton Williams at 12. 58 E.g., Yates at 7. 59 Apache at 8. 60 Texas Alliance at 3. 52 Cities E:\FR\FM\26MYR1.SGM 26MYR1 emcdonald on DSK2BSOYB1PROD with RULES Federal Register / Vol. 75, No. 101 / Wednesday, May 26, 2010 / Rules and Regulations avoiding unduly burdensome requirements that might discourage such pipelines from participating in the interstate market. 33. Transactional information provides price transparency so shippers can make informed purchasing decisions, and also permits both shippers and the Commission to monitor actual transactions for evidence of possible abuse of market power or undue discrimination. The existing reporting requirements in § 284.126 are inadequate for this purpose. For example, the annual reports of transportation transactions required by existing § 284.126(b) do not include (1) the rates charged by the pipeline under each contract, (2) the receipt and delivery points and zones or segments covered by each contract, (3) the quantity of natural gas the shipper is entitled to transport, store, or deliver, (4) the duration of the contract, or (5) whether there is an affiliate relationship between the pipeline and the shipper. Similarly, the semi-annual storage reports required by existing § 284.126(c) do not include the rates charged by the storage provider in each contract, the duration of each contract, or whether there is an affiliate relationship between the storage provider and its customer. 34. However, all this information is necessary to allow the Commission, shippers, and others to determine the extent to which particular transactions are comparable to one another for purposes of monitoring for undue discrimination. For example, contracts for service on different parts of a pipeline system or with different durations may not be comparable to one another. In addition, the requirement that affiliate relationships between the pipeline and its shippers be reported will allow the Commission and interested parties to monitor whether the pipeline is favoring its affiliates. The additional information required to be reported by the Final Rule is also necessary to allow shippers to make informed decisions about their capacity purchases. Shippers need to know the price paid for capacity over a particular path to enable them to decide, for instance, how much to offer for the specific capacity they seek. 35. The Commission also finds that the lack of transparency ultimately harms not only shippers, but the pipelines themselves, whose individual actions to protect market advantage work collectively to make intrastate transportation less attractive. Without transparency and trust, efficient freemarket allocation of resources is not possible. As the specific example VerDate Mar<15>2010 15:14 May 25, 2010 Jkt 220001 reported by Clayton Williams shows, the current market’s lack of transparency fosters, at the very least, an atmosphere of mistrust. While TPA may plausibly assert that natural gas commodity sales hubs are the most price-transparent commodity markets in the world, the same cannot be said of the market for intrastate transportation. It is the Commission’s obligation to ensure transparency at all stages of the natural gas market over which it has jurisdiction, because inefficiencies and unfair treatment in one stage of the market can lead to harm elsewhere in the market. Accordingly, we find that there is a need for revised regulations that improve market transparency. 36. Exempting storage services provided at market-based rates is also unwarranted. A Commission finding that a service provider lacks market power should not be read to mean that its shippers are at no risk of undue discrimination or other unlawful practices. Furthermore, it is still in the public interest to disseminate market information concerning the transactions of market-based storage services. As the Commission reasoned in a previous rulemaking, ‘‘[i]t is even more critical for the Commission to review pricing when the Commission is relying on competition to regulate rates, rather than scrutinizing the underlying cost of service. Thus, we will not exempt intrastate storage companies charging market-based rates from the requirement to file * * * reports.’’ 61 Posting rates charged in previous market-based transactions leads to greater transparency and competition. As the Commission found, in Order No. 637–A, with respect to alleged competitive harm to individual firms: While disclosure of the transactional information may cause some commercial disadvantage to individual entities, it will benefit the market as a whole, by improving efficiency and competition. Buyers of services need good information in order to make good choices among competing capacity offerings. Without the provision of such information, competition suffers.62 61 Revisions to Uniform System of Accounts, Forms, Statements, and Reporting Requirements for Natural Gas Companies, Order No. 581, 60 FR 53019, 53051, FERC Stats. & Regs. ¶ 31,026 (1995), order on reh’g, Order No. 581–A, FERC Stats. & Regs. ¶ 31,032 (1996) (Order No. 581). 62 Order No. 637–A, at 31,614–615. Enstor is concerned that the requirement to include the revenues received from each interruptible storage customer during a quarter will cause competitive damage, alleging that such information will allow customers to recreate the storage positions that resulted in another customer receiving favorable rates. However, the existing semi-annual storage reports required by § 284.126(c) already require the reporting of revenues received from each customer. Increasing the frequency of such revenue reports PO 00000 Frm 00007 Fmt 4700 Sfmt 4700 29409 37. Further, we are convinced the burdens to respondents will be small relative to the gains that the new regulations will bring to the market. The burden test goes to the heart of our regulatory authority: One purpose of the NGPA was to induce intrastate pipelines to participate in the interstate market by ensuring that it would not be unduly burdensome to do so.63 As discussed in more detail below, we are minimizing the burden of these new transactional reporting requirements in several ways. For example, we are not imposing a daily posting requirement, such as we have required of interstate pipelines. Therefore, the transactional reports required by the Final Rule will not require section 311 and Hinshaw pipelines to maintain internet Web sites. We are also clarifying several of the specific proposed reporting requirements as requested by commenters in a manner that should reduce the burden of compliance. Finally, while the reports must be filed in a standardized electronic format, the Commission will develop an electronic form in a PDF format that can be downloaded from the FERC Web site and saved to a user’s computer desktop. In addition, the Commission will develop an XML Schema that can be used by Respondents who wish to file an XML file. 38. In addition, since the establishment of the first intrastate pipeline reporting requirements, electronic communications have reduced the cost of reporting transactional information. Given these advances in data management, collecting and compiling information for the proposed quarterly reports should be no more burdensome at present than it was to manage the lesser amount of information required when the Commission first established transactional reporting for intrastate pipelines. 39. We consider the question of undue burden not only in isolation, but in the context of a pipeline’s entire jurisdictional business, and relative to the benefits to the market.64 The new from semi-annually to quarterly would not appear to significantly affect this concern. 63 Associated Gas Distributors v. FERC, 824 F.2d 981, 1001–1003 (D.C. Cir. 1987). 64 See, e.g., Transparency Provisions of Section 23 of the Natural Gas Act, Order No. 704–A, FERC Stats. & Regs. ¶ 31,275 at P 17 (2008) (‘‘While we acknowledge that removing purchases from volumes that must be reported on Form No. 552 would somewhat reduce the reporting burden on certain market participants, we continue to believe that the substantial benefits of having such data publicly available outweigh this burden.’’), order on reh’g, Order No. 704–B, 125 FERC ¶ 61,302 (2008). E:\FR\FM\26MYR1.SGM Continued 26MYR1 29410 Federal Register / Vol. 75, No. 101 / Wednesday, May 26, 2010 / Rules and Regulations requirements aim to empower shippers ‘‘to determine the extent to which particular transactions are comparable to one another.’’ 65 In this way, the Commission gives shippers increased ability to protect themselves from undue discrimination, and thus be less dependent on Commission investigations to protect their rights. The new reporting requirements also provide information that may assist state and local regulatory bodies, without interfering in their autonomy of action. 40. In response to the pipelines that suggest that they have an overriding confidentiality interest, or that even raise the specter that increased transparency may cause unlawful behavior, we disagree. The Commission’s decades of experience in enforcement have confirmed the wisdom of what jurists have long held in the related realm of financial disclosure: ‘‘confidentiality interest is not absolute, however, and can be overcome by a sufficiently weighty government purpose. * * * ‘Sunlight is said to be the best of disinfectants; electric light the most efficient policeman.’ ’’ 66 V. Details of Pipeline Posting Requirements emcdonald on DSK2BSOYB1PROD with RULES A. Overview and Summary of Requirements 41. The Final Rule, in accordance with the NOPR, requires Form No. 549D transactional reports under § 284.126(b) to be filed on a quarterly basis, to include certain additional types of information and cover storage as well as transportation, and to be filed in a uniform electronic format and posted on the Commission’s Web site without redaction. 42. In addition, the Final Rule clarifies or amends the NOPR on several points elaborated below. We clarify that pipelines are to file their Form No. 549D transactional reports on a contract-bycontract basis for each shipper, rather See also Pipeline Posting Requirements under Section 23 of the Natural Gas Act, Order No. 720, 73 FR 73494, FERC Stats. & Regs. 31,283, at P 56 (2008) (‘‘We also believe that the goals of this Final Rule outweigh the burdens to be placed upon noninterstate and interstate pipelines.’’); order on reh’g, Order No. 720–A, FERC Stats. & Regs. ¶ 35,302, at P 116 (2010) (‘‘The Commission understands commenters’ arguments that posting new points on a rolling basis would be burdensome for major noninterstate pipelines, but believes that these burdens are overstated and substantially outweighed by the transparency benefit of timely posting of newly eligible points.’’). 65 NOPR at 19. 66 Statharos v. New York City Taxi & Limousine Comm’n, 198 F.3d 317, 323 (2d Cir. N.Y. 1999) (citing Louis Brandeis, Other People’s Money and How the Bankers Use It 62 (1914)). VerDate Mar<15>2010 15:14 May 25, 2010 Jkt 220001 than on a transaction-by-transaction basis. We adopt a common identification requirement for shippers. For receipt and delivery points, however, pipelines need only use an industry common code where one is already in use, and may report wells and other gathering systems in the aggregate. We clarify that pipelines should continue to only report on their jurisdictional activities. Finally, we provide several clarifications regarding the data format and technical protocols, with the result being a flexible framework similar to the ‘‘simple spreadsheet’’ concept proposed by some commenters. B. Definition of Reportable Service 1. NOPR 43. The version of § 284.126(b)(1) proposed in the NOPR calls for a quarterly report that contains information on ‘‘each transportation and storage service provided.’’ Neither the proposed regulations nor the preamble to the NOPR directly defined the word ‘‘service.’’ In the preamble, in the context of rejecting daily posting, the Commission rejected the option of ‘‘daily postings of information about individual transactions.’’ 67 However, the preamble also states that pipelines should report ‘‘additional information concerning each transaction.’’ 68 2. Comments 44. Some commenters express concern that the NOPR’s phrasing is unclear as to whether pipelines are to make their reports on a contract-bycontract basis or a transaction-bytransaction basis.69 They point out that a shipper may schedule numerous transactions during a quarter under a single contract. For example, a shipper may have a single interruptible contract, but may schedule separate transactions at different rates using different receipt and delivery points on a daily basis. AGA, for example, ‘‘urges the Commission to clarify that Hinshaw pipelines are required to report their ‘contracts’ on a quarterly basis in a manner similar to what they currently report [rather than r]equiring information to be reported separately for each individual ‘transaction.’ ’’ 70 Other commenters are concerned that the Commission intends to require separate reports for each transaction. TPA, for example, complains that under ‘‘the onerous approach * * * proposed in the NOPR,’’ a pipeline with ‘‘multiple daily transactions under single contracts could [be] * * * reporting thousands of individual transportation transactions.’’ 71 45. Apache and Jefferson take the opportunity to propose alternative approaches to the question of what should be reported. Apache argues that ‘‘[f]ull transparency regarding all natural gas transactions on a real-time basis, comparable to the reporting requirements of interstate pipelines, is the only comprehensive way to protect natural gas consumers to ensure the integrity of the market.’’ 72 Nevertheless, Apache clarifies that it supports the NOPR as ‘‘a helpful improvement over the status quo.’’ 73 Jefferson argues that the level of detail proposed in the NOPR for the reports is too burdensome and too far beyond what is required to address the actual disparities between interstate and intrastate reporting.74 Accordingly, Jefferson proposes limiting the report to 22 fields.75 3. Commission Determination 46. We clarify that pipelines are to report the required transactional information in Form No. 549D on a contract-by-contract basis for each shipper, rather than on a transaction-bytransaction basis. In general, a pipeline will be required to make a separate data entry for each of a shipper’s contracts under a given rate schedule. The pipeline should aggregate all nominations and shipments under each contract for the quarter. In other words, while the reports will contain information on each transaction, that information will be aggregated by contract for each shipper for each type of service provided. 47. If the pipeline charges a shipper multiple prices for different transactions or shipments under a single contract and service, the pipeline would still file a single report for that contract, with the following information. The pipeline would report the volume-weighted average rate charged under that contract for the quarter. The pipeline would also include a list of all the various rates charged during the quarter in the appropriate comment field for that contract. The pipeline would not be required to state the volumes associated with each rate or the dates each rate was charged. Similarly, the pipeline would list the receipt and delivery points used during each quarter for each contract, but is not required to separately report 71 TPA 67 NOPR at 25. 68 NOPR at 20. 69 E.g., Jefferson at 11. 70 AGA at 2; see also AGA at 9–10. PO 00000 Frm 00008 Fmt 4700 Sfmt 4700 at 4–5. at 3. 73 Apache at 3. 74 Jefferson at 16. 75 Jefferson at 15–16. 72 Apache E:\FR\FM\26MYR1.SGM 26MYR1 Federal Register / Vol. 75, No. 101 / Wednesday, May 26, 2010 / Rules and Regulations the rates charged and volumes received and delivered at each point. 48. We decline the opportunity to radically alter the type of information reported, as suggested by Apache and Jefferson. Based on the comments in this docket, the Commission believes that refinements to the NOPR are more certain to ensure a fair balance of the additional transparency benefits that would accrue to the market versus the administrative costs of compliance. C. Reporting Frequency 1. NOPR 49. In the NOPR, the Commission found that increasing the frequency of the § 284.126(b) transactional reports from annual to quarterly would provide market participants and the Commission with more timely and more useful information concerning the transactions entered into by intrastate pipelines. The Commission stated that it sought to balance the benefits of increased transactional transparency against the need to avoid creating undue burden for the responding pipelines. The Commission highlighted that ‘‘one primary difference will remain between the reporting requirements for interstate pipelines and the Section 311 and Hinshaw pipelines: Interstate Pipelines will post transactional information daily on their Web sites, while Section 311 and Hinshaw pipelines will submit this information in a quarterly report to the Commission.’’ 76 The Commission noted alternative proposals from commenters, but found that a quarterly filing requirement would strike the appropriate balance. emcdonald on DSK2BSOYB1PROD with RULES 2. Comments 50. Most commenters support quarterly reporting. Even some parties who urge the Commission to cancel the rulemaking docket nevertheless state that they could accept limited quarterly reporting.77 Some shippers, while generally supportive of the NOPR, state that they would prefer daily reporting is the best way to ensure transparency and competitive markets.78 The pipelines, however, consider the possibility of daily reporting to be ‘‘very costly, particularly if daily posting on a Web site was required,’’ 79 due ‘‘to the [sheer] volume of reporting’’ of each day’s transactions.80 76 NOPR at P 23. at 6; Atmos at 5. 78 Apache at 2–3; Constellation at 4; Yates at 5–6. 79 Duke at 5. 80 TPA at 20. 77 TPA VerDate Mar<15>2010 15:14 May 25, 2010 Jkt 220001 3. Commission Determination 51. The Final Rule adopts the NOPR’s proposal to require quarterly reporting by section 311 and Hinshaw pipelines. The Commission continues to find that a quarterly reporting requirement strikes the appropriate balance of increasing transparency without imposing undue burdens on section 311 and Hinshaw pipelines. One purpose of the NGPA was to induce intrastate pipelines to participate in the interstate market by ensuring that it would not be unduly burdensome to do so.81 This participation by intrastate pipelines eliminates the need for duplication of facilities between interstate and intrastate pipelines.82 Thus, as the court has stated, ‘‘Congress intended that intrastate pipelines should be able to compete in the transportation market without bearing the burden of full regulation by FERC under the Natural Gas Act.’’ 83 52. In the NOPR, the Commission stated that a daily reporting requirement would require all intrastate and Hinshaw pipelines to maintain their own Web sites for this purpose, and such daily postings of information about individual transactions would be significantly more burdensome than a quarterly reporting requirement. As described above, several pipeline commenters have reaffirmed that a daily posting requirement would be very costly. In addition, Constellation, while stating that daily posting would provide more transparency, agrees that at this time such a requirement appears unduly burdensome.84 53. Only two commenters request that the Commission require daily reporting. They contend that real-time reporting of individual transaction data would allow more immediate monitoring of whether the pipeline is engaging in undue discrimination and provide more useful price transparency. The Commission recognizes that daily posting could enable shippers and others to observe potentially discriminatory actions more quickly. However, the quarterly reports will provide similar information, enabling shippers and others to file complaints if they believe such information suggests a pattern of discrimination by the pipeline. Given the interest in avoiding placing undue burdens on section 311 and Hinshaw 81 AGD, 82 EPGT 824 F.2d at 1001–1003. Texas Pipeline, L.P., 99 FERC ¶ 61,295 at 62,252. 83 Mustang Energy Corp. v. Federal Energy Regulatory Comm’n, 859 F.2d 1447, 1457 (10th Cir. 1988), cert. denied, 490 U.S. 1019 (1988); see also EPGT Texas Pipeline, 99 FERC ¶ 61,295 (2002). 84 Constellation at 4. PO 00000 Frm 00009 Fmt 4700 Sfmt 4700 29411 pipelines, the Commission finds that the quarterly reporting requirement, together with our other changes to the reporting requirements including the requirement that all reports be public, appropriately balances the need for more transparency with the interest in encouraging section 311 and Hinshaw pipelines to participate in the interstate pipeline grid. D. Identification of Receipt and Delivery Points and Shippers 1. NOPR 54. The NOPR proposed requiring intrastate pipelines to report several new elements of information, among them the primary receipt and delivery points covered by the contract. The NOPR proposed that the reports include the ‘‘industry common code’’ for each receipt and delivery point in order to minimize any ambiguity as to what receipt and delivery points are being reported and to ensure that all reporting pipelines identify such points in a consistent manner.85 Similarly, the NOPR proposed that, when reporting the identity of a given shipper, respondents should include not only the full legal name, but also an ‘‘identification number’’ for each shipper.86 55. However, the NOPR stated that, while the Commission was aware of some shipper identification standards and receipt and delivery point codes that are used in the natural gas industry (for example, Dun & Bradstreet, Inc.’s D–U–N–S identification numbers for shippers), the Commission was reluctant to choose any particular standard without input as to that standard’s cost-effectiveness and usefulness. Accordingly, the Commission sought comment on two related questions: (1) What sort of shipper identification numbers and receipt and delivery point common industry codes are currently used or readily available to section 311 and Hinshaw pipelines?; and (2) Which shipper identification standard or standards and receipt and delivery point codes, if any, should be used?87 2. Comments 56. Some commenters argue that using industry common codes to report receipt and delivery points would be highly burdensome, due to the cost of obtaining common code identifiers from a third-party registry. According to Jefferson, the annual charge for licensing common location codes is 85 NOPR at P 33. at P 33. 87 NOPR at P 34. 86 NOPR E:\FR\FM\26MYR1.SGM 26MYR1 29412 Federal Register / Vol. 75, No. 101 / Wednesday, May 26, 2010 / Rules and Regulations emcdonald on DSK2BSOYB1PROD with RULES $1,670 for 1–20 points, $3,506 for 21– 100 points, and $5,428 for 100+ points.88 Enogex protests that it ‘‘does not have ‘primary’ and ‘secondary’ points on its system, but rather uses standard receipt and delivery points. As a result, Enogex does not have * * * common codes,’’ and urges that the Commission reject this element as ‘‘base[d] * * * on the business practices of interstate pipelines.’’ 89 TPA voices similar concerns. Jefferson and ONEOK suggest letting respondents use their own meter codes instead. AGA suggests, as a compromise, that pipelines that do not already use common codes should be allowed ‘‘to use an interstate pipeline’s Data Reference Number (DRN) for points of interconnection with an interstate pipeline and use [their own] proprietary code where a DRN has not already been assigned.’’ 90 57. AOG and Cranberry, whose pipelines perform gathering functions, state that they do not keep organized records of who has contract rights to which receipt or delivery points.91 AOG proposes that, instead of differentiating among receipt points that are gas wells, they ‘‘would simply identify all receipt points as ‘AOG system.’ ’’ 92 Cranberry proposes that the Commission waive the requirement to report receipt and delivery points where, as with their system, all shippers have access to all or numerous points, and no common industry codes exist.93 58. The proposal to require use of standardized shipper identification numbers also raised some concerns. Jefferson estimated that ‘‘it will cost approximately $24,000 annually to utilize a third-party service to verify a unique shipper identification number such as a D–U–N–S® number,’’ and suggests removing this requirement.94 TPA likewise argues that intrastate providers would have no use for D–U–N–S numbers other than filing the proposed reports. TPA proposes having the public reports only ‘‘contain coded references to individual shippers and points, with the key to the code available to the Commission’’ for investigation but otherwise kept confidential; in the alternative TPA suggests that the exact legal name of the shipper should be sufficient.95 Most pipelines, however, did not object to standardized shipper identification, and 88 Jefferson at 9. at 12. 90 AGA at 2. 91 AOG at 6; Cranberry at 5. 92 AOG at 10. 93 Cranberry at 6. 94 Jefferson at 9. 95 TPA at 22. 89 Enogex VerDate Mar<15>2010 15:14 May 25, 2010 ‘‘AGA supports the use of the D–U–N–S® Number as a common company identifier.’’ 96 3. Commission Determination 59. We acknowledge the concern of some pipelines that requiring all pipelines to use industry common codes for receipt and delivery points could prove to be expensive, and we have adjusted § 284.126(b)(1)(iv) of the final regulations accordingly. Where respondents already use Industry Common Codes in their existing business practices (such as wherever an intrastate system interconnects with an NGA interstate system), they must use those codes in their reports. However, where respondents do not use Industry Common Codes, they should report using the same point identification system that they use for scheduling with shippers. In addition, respondents who do not use Industry Common Codes must publish a list of all the jurisdictional receipt and delivery point codes they use for scheduling, along with the county and state of each point, and the name of the jurisdictional pipeline (if any) that interconnects at each point. This list should be filed as a separate narrative alongside the respondent’s initial report; if the list should change at any time, the respondent should include a narrative alongside its next quarterly report updating the list. 60. The Commission also acknowledges the particular challenges in reporting receipt points for systems that perform a gathering function. Accordingly, for gas received from dedicated wells or gathering lines, respondents may instead note as the receipt point the common point where the gathered gas is considered to enter the pipeline’s transmission system. Respondents who use this method in their reports must develop their list of jurisdictional receipt and delivery points accordingly. 61. In contrast with receipt and delivery points, however, standardized shipper identification is not unduly burdensome in comparison to the benefit to the Commission and market participants of being certain of the true identity of a pipeline’s shippers. As of the date that the Commission approves this Final Rule, we observe that it is possible to both create a D–U–N–S number 97 and search for any company’s D–U–N–S number 98 for free. Further, 96 AGA at 2. 97 Available at https://smallbusiness.dnb.com/ establish-your-business/12334338-1.html. 98 Available at https://smallbusiness.dnb.com/ ePlatform/servlet/DUNSAdvancedCompanySearch? storeId=10001&catalogId=70001. Jkt 220001 PO 00000 Frm 00010 Fmt 4700 Sfmt 4700 since standardized shipper identification numbers, by their nature, do not change with time, respondents will not need to spend time verifying each number every quarter. Accordingly, the time and expense spent on verifying the identity of one’s shippers should be reasonable. E. Requests for Exemptions and Safe Harbor 1. NOPR 62. In the NOI, the Commission sought comment on whether any of the proposed reporting requirements should exempt certain classes of respondents, based on the type of service provided or on the respondent’s size. Having considered the comments received, the Commission did not provide for any exemptions in the NOPR. The Commission reasoned that so long as reports were hosted on the FERC Web site and no more frequent than quarterly, they would not be unduly burdensome to prepare and file.99 2. Comments 63. AOG asks the Commission to exempt companies with de minimis jurisdictional activity. In particular, AOG suggests a cut-off ‘‘somewhere between 2.2 and 50 million MMBtu,’’ 100 or for entities with under 500 employees. ONEOK similarly argues that it should be excluded, but does not proffer a cut-off point. 64. In addition to the above exemption requests, AGA suggests two clarifications as a means of minimizing the burden for all respondents. First, AGA asks the Commission to ‘‘clearly state that Hinshaw pipelines are required to report only those contracts authorized by their limited jurisdictional certificates and are not required to report on retail or intrastate activities that are not regulated by the Commission.’’ 101 Second, ‘‘AGA also recommends that the Commission explicitly state as part of the Final Rule in this proceeding that it will not prosecute, penalize or otherwise impose remedies on parties for inadvertent errors in reporting.’’ 102 3. Commission Determination 65. The Commission rejects the requests for exemptions based on size or type of activity. As the Commission reasoned in the NOPR, since the reports and data are to be hosted on the FERC Web site and filed no more frequently than quarterly, they should not be 99 See, e.g., NOPR at P 14, 24. at 8. 101 AGA at 1; see also AGA at 8–9. 102 AGA at 3; see also AGA at 15–16. 100 AOG E:\FR\FM\26MYR1.SGM 26MYR1 Federal Register / Vol. 75, No. 101 / Wednesday, May 26, 2010 / Rules and Regulations unduly burdensome to prepare and file. The Commission has not exempted any section 311 or Hinshaw pipelines from filing the existing reports required by § 284.126, using current Form No. 549. With the clarifications made to the technical protocols discussed below, the Commission is confident that, after the transition to the new reporting format, it will not be significantly more burdensome for pipelines to prepare and file each Form No. 549D report required by this rule, than it has been to file the existing Form No. 549 Intrastate Pipeline Annual Transportation report. In addition, if a pipeline has de minimis jurisdictional activity, it follows that it should have relatively few transactions to report, thereby minimizing its burden of completing the necessary report. 66. We grant AGA’s requested clarification that Hinshaw pipelines are required to report only those contracts authorized by their limited jurisdictional certificates and are not required to report on retail or intrastate activities that are not regulated by the Commission. Similarly section 311 pipelines are only required to report contracts for NGPA section 311 interstate service, and not contracts for non-jurisdictional intrastate service. 67. In response to the AGA’s second request, the Commission states that because Form No. 549D is a new information collection, we will focus any enforcement efforts on instances of intentional submission of false, incomplete, or misleading information to the Commission, of failure to report in the first instance, or of failure to exercise due diligence in compiling and reporting data.103 F. Public Status of Reports emcdonald on DSK2BSOYB1PROD with RULES 1. NOPR 68. The NOPR proposed to require that the reports filed pursuant to revised § 284.126(c) be posted without any information redacted as privileged. The Commission stated that currently, when a report is filed subject to a request for privileged treatment, any person desiring to see the report must file a formal request, pursuant to the Freedom of Information Act (FOIA) and § 385.1112 of the Commission’s Rules of Practice and Procedure,104 that the Commission make the report public. 103 The Commission adopted a similar guideline in Transparency Provisions of Section 23 of the Natural Gas Act, Order No. 704, 73 FR 1014 (Jan. 4, 2008), FERC Stats. and Regs. ¶ 31,260 at P 114 (2007), order on reh’g, Order No. 704–A, 73 FR 55726 (Sept. 26, 2008), FERC Stats. & Regs. ¶ 31,275 (2008), order on reh’g, Order No. 704–B, 125 FERC ¶ 61,302 (2008). 104 18 CFR 385.1112. VerDate Mar<15>2010 17:49 May 25, 2010 Jkt 220001 Due to the expense and delay caused by this additional step, in practice these requests have been infrequent. The Commission stated that allowing pricing information to be confidential undermines the Commission’s goals of preventing undue discrimination and promoting price transparency, while a prohibition on the confidential treatment of § 284.126(b) reports would further all of these policy goals. The Commission noted concerns about the commercial sensitivity of the information to be reported, but found, based on the comments filed, that ‘‘a quarterly reporting requirement should allay any concerns regarding the commercial sensitivity of contract data.’’ 105 69. In addition to the policy considerations, the Commission found that its governing statutes support public treatment of data reported both by Hinshaw pipelines and by NGPA Section 311 pipelines. Accordingly, the NOPR proposed that the standardized reporting form include a statement that the report will be public. 2. Comments 70. TPA and some individual pipelines argue that the Commission must retain the traditional confidentiality process in Rule 1112 and § 388.112 of the Commission’s regulations.106 TPA argues that a policy of public disclosure would violate both Commission precedent and § 388.112, which call for case-by-case review of requests to release information.107 ONEOK and TPA argue that complying with the proposed regulations could violate the confidentiality provisions of existing contracts.108 Enstor and ONEOK suggest that many marketoriented shippers and large industrial end-users would seek to avoid Section 311 transactions in order to protect their trading positions.109 71. Enstor particularly urges the Commission to amend the proposed § 284.126(b)(1)(viii) requirement to report ‘‘Total revenues received for the shipper.’’ Enstor argues that, when applied to ‘‘interruptible storage services (such as parking and lending),’’ this requirement would compel reporting of information ‘‘that is not currently disclosed by interstate natural gas companies.’’ 110 Especially if unredacted, reporting individual shipper revenues ‘‘even on a quarterly 105 NOPR at P 31. Enogex at 8. 107 TPA at 18. 108 TPA at 5, 16–17; ONEOK at 5. 109 Enstor at 9; ONEOK at 5. 110 Enstor at 6. 106 E.g., PO 00000 Frm 00011 Fmt 4700 Sfmt 4700 29413 basis’’ would do ‘‘catastrophic’’ damage to a pipeline’s ‘‘business model, as well as to market liquidity.’’ 111 72. However Apache, Cities, Clayton Williams, Texas Alliance, and Yates expressly support public reporting, in order for the reports to serve the purported goal of benefitting market participants.112 Clayton Williams cites the specific example of Texas’s ‘‘grossly inadequate’’ 113 state-level data, which it claims is responsible for rampant discriminatory behavior in Texas markets. 3. Commission Determination 73. As we clarified in the preceding section, the revised reporting requirements adopted by this rule apply only to contracts for interstate service which are subject to our jurisdiction under the NGA in the case of Hinshaw pipelines or NGPA section 311 in the case of intrastate pipelines. While we regulate the interstate services of Hinshaw pipelines in a more lighthanded manner than we regulate interstate pipelines, nevertheless the courts have made clear that such regulation of Hinshaw pipelines must comply with the basic requirements of the NGA, including sections 4 and 5 of the NGA.114 In SGRM, the Commission pointed out that NGA section 4(c) requires that ‘‘under such rules and regulations as the Commission may prescribe, every natural gas company shall * * * keep open for public inspection * * * all rates * * * together with all contracts which in any manner affect or relate to such rates.’’ The Commission concluded that: Although the NGA gives the Commission some discretion with respect to how to provide for the disclosure of rate schedules and contracts, clearly the public disclosure of rate schedules and related contracts, in some manner, is required.115 74. Accordingly, our requirement that the quarterly reports of Hinshaw pipelines concerning their jurisdictional contracts be posted without any information redacted is simply carrying out NGA section 4(c)’s requirement for public disclosure of rate and contract information ‘‘under such regulations and regulations as the Commission may prescribe.’’ Furthermore, NGA section 23(a)(1) directs the Commission ‘‘to 111 Enstor at 7. Apache at 10–11. 113 Clayton Williams at 1. 114 Consumers Energy Co. v. FERC, 226 F.3d 777 (6th Cir. 2000), holding that the Commission must comply with the requirements of NGA section 5 in order to require a Hinshaw pipeline to modify its rates for interstate service. 115 SGRM, 125 FERC ¶ 61,191 at P 23, quoting Order No. 637–A, at 31,614. 112 E.g., E:\FR\FM\26MYR1.SGM 26MYR1 29414 Federal Register / Vol. 75, No. 101 / Wednesday, May 26, 2010 / Rules and Regulations emcdonald on DSK2BSOYB1PROD with RULES facilitate price transparency in markets for the sale or transportation of physical natural gas in interstate commerce.’’ 116 75. While the NGPA does not contain an express public disclosure provision similar to NGA section 4(c), Section 311(c) of the NGPA authorizes the Commission to prescribe the ‘‘terms and conditions’’ under which intrastate pipelines perform interstate service. Requiring NGPA section 311 pipelines to publicly disclose transactional information for the purpose of allowing shippers and others to monitor NGPA Section 311 transactions for undue discrimination is well within the Commission’s broad conditioning authority under Section 311(c).117 76. We reject TPA’s argument that the Commission procedural rules in §§ 385.1112 and 388.112 require the Commission to allow pipelines to request confidential or privileged treatment of their transactional reports. The existence of those procedural rules does not prevent the Commission from establishing, in this rulemaking proceeding after notice and comment, a category of document, i.e., the Form 549D reports required by this rule, which must be made public in order for the Commission to carry out its statutory responsibilities under the NGA and the NGPA. Such automatic disclosure requirements already apply to various other reports filed with the Commission, including for example the FERC Form Nos. 2, 2–A, and 3–Q financial reports required by §§ 260.1, 260.2, and 260.300.118 77. As a matter of policy, we find that Hinshaw and section 311 pipelines must file their Form No. 549D reports as public in order to achieve the Final Rule’s purpose of improving transparency, monitoring discrimination, and fostering efficient markets. The Commission recognizes the concern of some pipelines that disclosure of commercially sensitive information will enable a shipper to know what the pipeline is charging other shippers and thus prevent the pipeline from being able to negotiate the best price for the services it offers. In 116 15 U.S.C. 717t–2(a)(1). See Energy Policy Act of 2005, Public Law 109–58, § 316 (‘‘Natural Gas Market Transparency Rules’’), 119 Stat. 594 (2005). 117 See, e.g., AGD, 824 F.2d at 1015–1018 (DC Cir. 1987) (affirming the Commission’s use of Section 311(c) to require intrastate pipelines to permit their interstate sales customers to convert to transportation-only service). 118 See Quarterly Financial Reporting and Revisions to the Annual Reports, Order No. 646, FERC Stats. & Regs. ¶ 31,158, Appendix B at 48 (‘‘This report is also considered to be a nonconfidential public use form.’’), order on reh’g, Order No. 646–A, FERC Stats. & Regs. ¶ 31,163 (2004); accord Instructions for Filing FERC Forms 2, 2–A, and 3–Q at I. VerDate Mar<15>2010 15:14 May 25, 2010 Jkt 220001 Order No. 637–A, the Commission exercised its discretion concerning the manner of public disclosure to delay interstate pipelines’ posting of transactional information until the first nomination of service under the contract, rather than requiring posting upon execution of the contract. The Commission stated that this would temper any potential disadvantages from the public disclosure requirement, because the first nomination could be significantly after the contract was executed. In light of our more lighthanded regulation of Hinshaw and section 311 pipelines and our desire to minimize undue burdens on such pipelines, we are permitting a longer delay between contract execution and disclosure by only requiring such reports to be filed quarterly. This should temper any potential adverse effects from disclosure. 78. However, public disclosure of all information in the quarterly reports is necessary to permit all market participants to monitor the market and detect undue discrimination. The Commission also expects and hopes that market participants will use the information from these reports in order to educate themselves about market conditions. Regardless of any adverse effect on individual entities, public disclosure will improve the market as a whole by improving efficiency and competition. 79. Finally, while ONEOK and TPA assert that the disclosure requirement could violate the confidentiality provisions of pipelines’ existing contracts, most jurisdictional contracts include provisions that the contract is subject to all rules adopted by the Commission. Moreover, the Commission has previously held that such confidentiality provisions violate Commission policy. For example, in Bay Gas Storage Co.,119 the Commission required a section 311 pipeline to remove from its Statement of Operating Conditions a provision that the terms of any storage or transportation service agreement must be kept confidential with certain exceptions, holding that the provision was ‘‘contrary to the Commission’s favoring public disclosure of the provisions of service contracts under NGPA section 311.’’ If any Hinshaw or section 311 pipeline believes that it is subject to a binding contractual obligation to keep confidential any information required to be disclosed by this rule, it must file that contract with the Commission so 119 110 PO 00000 FERC ¶ 61,154 at P 17 (2005). Frm 00012 Fmt 4700 Sfmt 4700 that it can be modified to remove any such provision. G. Data Format and Technical Protocols 1. NOPR and Information Notice 80. The NOPR proposed that Commission Staff develop a mandatory, standardized electronic format for the Form No. 549D reports. The goals are to facilitate data submission, to provide the public timely and easy access to the information, and to avoid the costs of requiring intrastate pipelines to maintain a NAESB-compliant Web site. 81. The Commission introduced its proposed format in the Information Notice. The Information Notice provided a table showing proposed Form No. 549D data elements to be collected each quarter from each respondent. It also included an example of data entries reported by a sample pipeline for one shipper, a Proposed Form No. 549D Data Dictionary and Reporting Units, and draft Instructions for Reporting Data. The Commission also asked for comments on the technological issue of whether the proposed standardized format should be developed using XML or an ASP.NET Web-based form. 2. Comments 82. The discussion of information technology in the NOPR and Information Notice garnered widespread concern from pipelines. The chief concern of pipelines is that they may have to engage in extensive training or outsourcing in order to understand and comply with the Commission’s directive.120 AGA reports that ‘‘one company has estimated the cost of developing an in-house solution for XML Schema reporting to be approximately $30,000.’’ 121 Jefferson reported its own estimate of $130,000 ‘‘to develop a quarterly report similar to the proposed Form No. 549D in the XML Schema format.’’ 122 Jefferson also stated, however, that it could not support ASP.NET unless the Commission could first guarantee that the format would not ‘‘require[] a filer to manually enter data,’’ or otherwise make the data submission and correction process laborious.123 83. In order to reduce this compliance burden, AGA along with Duke recommend that the Commission support not only the XML and ASP.NET approaches, but also ‘‘a simple spreadsheet with the data in tabular form that the intrastate and Hinshaw 120 E.g., Jefferson at 9–11. at 7. 122 Jefferson at 14. 123 Jefferson at 10. 121 AGA E:\FR\FM\26MYR1.SGM 26MYR1 Federal Register / Vol. 75, No. 101 / Wednesday, May 26, 2010 / Rules and Regulations pipelines could complete and file with the Commission using the eFiling portal.’’ 124 TPA urges the Commission to not adopt a form at all, but rather allow pipelines to continue to file reports similar in format and content to what they file now.125 In the alternative, TPA recommends making both XML and ASP.NET available.126 84. AGA also ‘‘recommends that the Commission develop a Frequently Asked Questions Web page or other Web-based Query System to assist intrastate and Hinshaw pipelines in complying with the new standardized electronic information filing requirements.’’ 127 AGA, TPA, and Jefferson have several questions in this vein regarding specific elements and definitions from the Information Notice.128 85. Cities, along with Constellation, praise the Commission’s decision ‘‘to shoulder the burden of Web site maintenance and standards compliance.’’ 129 Yates, while generally supporting the Commission’s proposal, argues that it would not be unduly burdensome to require pipelines to maintain their own Web sites on which they regularly publish transactional data.130 3. Commission Determination 86. The Commission will use XML to collect and process the data required by the Form No. 549D report and present it in a timely manner on its Web site. The Commission recognizes that some respondents may prefer not to use XML. Other respondents have experience with the format or for efficiency purposes would use XML. Therefore, the Commission will allow respondents at the beginning of each quarter to select the method 131 of filing most appropriate to their circumstances as described below: a. Fillable-PDF Form No. 549D For respondents who prefer not to use XML, the Commission will develop an electronic form in a PDF format that can be downloaded from the FERC Web site and saved to a user’s computer desktop. The form can be viewed and updated using Adobe Acrobat Reader version 9 124 AGA at 14; see also Duke at 2–3, 7–9. at 16. 126 TPA at 20; see also ONEOK at 5. 127 AGA at 3; see also AGA at 15. 128 AGA at Appendix A; TPA at 20–25; Jefferson at 11–13. 129 Cities at 4; see also Constellation at 4. 130 Yates at 7. 131 Respondents must choose only one methodology in a given quarter to file their quarterly report. They do not have to notify Commission staff of their selection. emcdonald on DSK2BSOYB1PROD with RULES 125 TPA VerDate Mar<15>2010 17:49 May 25, 2010 Jkt 220001 or higher. The fillable-PDF form will look like a standard document, so that a clerk or any other employee(s) will be able collaborate on filling it out, saving it, and submitting the fillable-PDF electronically to the Commission.132 The data will be verified and validated before it will be officially accepted by the Commission. Each respondent’s filing would be publicly available in eLibrary within 1 day after filing. The public would also be able to download the entire Form No. 549D database for the quarter from the FERC Web site a few days after the filing deadline. Respondents would be able to correct any errors in their initial filings by filing a revised fillable PDF Form No. 549D with the Commission.133 29415 up a form549D e-mail box (form549d@ferc.gov) where respondents can send questions. Commission staff will also provide online filing guidance and technical advice to respondents who request it, in line with the Commission’s current guidelines for contact between Staff and regulated entities. 88. Finally, to the extent possible, the General Instructions for Form No. 549D developed by the Commission Staff will conform with the instructions for eTariff filing, so that pipelines shall use the same names to refer to the same objects and concepts in both their Statements of Operating Conditions and their quarterly reports. In this manner, the Commission hopes to address all of the above-noted concerns with regard to information technology for the Form No. 549D. b. File an XML file that validates against an XML Schema for Form No. 549D This method of filing is for those respondents who have some experience with XML, or have a relatively large number of shippers and contracts to report on each quarter. The Commission would develop an XML Schema for Form No. 549D and make it available for download on the FERC Web site. Respondents would have to test and successfully validate their XML filing against the XML Schema for Form No. 549D prior to submitting it electronically to the Commission. Once the XML file is submitted, the Commission will examine it to ensure that it is formatted properly and validates against FERC’s XML Schema for Form No. 549D before it is officially accepted by the Commission. Each respondent’s filing would be publicly available in eLibrary within 1 day after filing. The public would also be able to download the entire Form No. 549D database for the quarter from the FERC Web site a few days after the filing deadline. Respondents would be able to correct any errors in their initial filings by resubmitting another XML file. 87. An updated data dictionary, paper copy of the Fillable PDF Form No. 549D, an example of the filled out Form No. 549D, and Instructions are attached as an appendix to this order. At a date closer to the deadline for filing the first Form No. 549D, the Commission will issue a notice for a Workshop in which Commission Staff will explain the overall filing process, including the fillable-PDF Form No. 549D, data dictionary, XML Schema and will answer any technical questions. Commission Staff are also directed to set A. Current Policy 89. Section 311 of the NGPA provides that the rates of intrastate pipelines performing transportation service under the NGPA shall be fair and equitable. Section 284.123 of the Commission’s regulations implements this requirement for section 311 pipelines, and § 284.224(e)(i) provides that provides that Hinshaw pipelines performing interstate service will be subject to the same rate requirements that apply to intrastate pipelines under § 284.123. As a general matter, the Commission’s review of the rates of both section 311 and Hinshaw pipelines is more light-handed than its review of the rates of interstate pipelines. For example, when intrastate and Hinshaw pipelines file a request for a rate change, the Commission does not impose the five-month suspension typically imposed on interstate pipeline rate increases, and it uses advisory, nonevidentiary proceedings to resolve the issues, rather than setting the case for an evidentiary hearing before an Administrative Law Judge, as it does for interstate pipeline rate cases.134 90. However, as part of this overall, more light-handed regulation of intrastate and Hinshaw pipelines, the Commission has established a policy of reviewing the rates of both types of pipelines every three years in order to ensure that the rates affecting interstate services remain fair and equitable.135 The Commission has stated that the triennial rate review of section 311 132 See Appendix for a paper copy of the Form No. 549D and an example of a completed copy. 133 The Form No. 549D database accessible on the FERC Web site would only show the latest filing of each Respondent. 134 Gulf Terra Texas Pipeline, L.P., 109 FERC ¶ 61,350, at P 9 (2004) (Gulf Terra). 135 See, e.g., id. at P 10 (citing Arkansas Western Gas Company, 56 FERC ¶ 61,407 (1991), reh’g denied, 58 FERC ¶ 61099 (1992)). PO 00000 Frm 00013 Fmt 4700 Sfmt 4700 VI. Periodic Rate Review E:\FR\FM\26MYR1.SGM 26MYR1 29416 Federal Register / Vol. 75, No. 101 / Wednesday, May 26, 2010 / Rules and Regulations intrastate and Hinshaw pipelines enables the Commission to determine whether their rates have become unfair and unreasonable because the cost of service data upon which they are based have become stale. 91. The primary difference in the Commission’s regulation of section 311 and Hinshaw pipelines is the procedural vehicle through which the three-year rate review of those pipelines’ rates is performed. This difference arises from the difference in the statutes under which we regulate the two types of pipelines. For the reasons discussed in full in Green Canyon Pipe Line Co.,136 the Commission has broad conditioning authority under NGPA section 311(c), which it has consistently exercised to require intrastate pipelines to file new petitions for rate approval every three years. However, the United States Court of Appeals for the District of Columbia Circuit has held that the Commission cannot require interstate pipelines subject to its NGA jurisdiction to make new rate filings under NGA section 4.137 Consistent with that finding, the Commission in Consumers Energy Co.138 only required Hinshaw pipelines performing interstate service under a § 284.224 certificate to submit a triennial informational filing in the form specified in § 154.313 of the Commission’s regulations for minor rate changes. 92. While the triennial rate review requirement is not part of the Commission’s regulations, the Commission has consistently imposed that requirement as a condition of its approval of each rate filing by a section 311 or Hinshaw pipeline. The Commission has done this, whether the pipeline has chosen to elect a statebased rate pursuant to § 284.123(b)(1) or has proposed a rate for a Commissionapproved rate pursuant to § 284.123(b)(2).139 B. Comments 93. While the NOPR did not directly raise the issue of whether the Commission should modify its triennial rate review policy, Duke points out in its comments that Order No. 636 removed the requirement that interstate pipelines file new rate cases every three years. It contends that, in order to treat emcdonald on DSK2BSOYB1PROD with RULES 136 98 FERC ¶ 61,041 at 61,122–3 (2002). Service Commission of New York v. FERC, 866 F.2d 487 (D.C. Cir. 1989). 138 94 FERC ¶ 61,287 (2001). See also Gulf Terra at P 12. 139 See Centana Intrastate Pipeline Co., 75 FERC ¶ 61,253 (1996) (Order on Rehearing) (imposing triennial rate review on a § 284.123(b)(1) filing); Green Canyon Pipe Line Company, L.P., 98 FERC ¶ 61,041 (2002) (Order on Rehearing) (imposing triennial rate review on a § 284.123(b)(2) filing). 137 Public VerDate Mar<15>2010 15:14 May 25, 2010 Jkt 220001 section 311 pipelines and Hinshaw pipelines similarly: ‘‘the Commission should either reimpose a periodic rate filing requirement on interstate pipelines or eliminate the triennial filing requirement currently imposed on intrastate and Hinshaw pipelines.’’ 140 94. Other commenters argue that the triennial rate review requirement renders any additional information collection partly or wholly unnecessary. TPA predicts that the proposed reports ‘‘would not likely yield significant transparency benefits,’’ because Section 311 pipelines already must file Statements of Operating Conditions with maximum rates and submit cost of service filings to the Commission and to state officials.141 Enogex argues that the triennial rate review offers the Commission and other interested parties sufficient opportunity to review the rates and contracts of Section 311 pipelines. Enogex further argues that most interstate pipelines are not subject to rate reviews that are as detailed or frequent, and that Section 311 pipelines would be unduly burdened if further reporting were required.142 C. Commission Determination 95. As noted above, the Commission generally requires triennial rate reviews of section 311 intrastate and Hinshaw pipelines to ensure that the Commission has current information and rates have not become stale. Since these pipelines are not subject to the same reporting requirements, nor the same level of rate review, as interstate pipelines, the Commission can not eliminate periodic rate review without abrogating its duty to continually assure fair and equitable rates. 96. However, the Commission is sensitive to concerns that the improved reporting requirements could prove too burdensome, when considered in aggregation with other burdens such as triennial rate review. In recent years, the Commission has found it only occasionally necessary to impose rate reductions during these periodic reviews. It is our expectation that the improved reporting requirements will instill further market discipline, thus helping to continue this favorable trend. It thus appears that requiring all section 311 and Hinshaw pipelines to make filings for a review of their rates every three years imposes an unnecessary burden on both the pipelines and the Commission, as compared to the public benefits obtained by such rate review. Accordingly, the Commission has decided to modify its triennial rate review policy in order to decrease the frequency of review from three to five years. Therefore, the Commission intends in future orders approving rates filed by section 311 and Hinshaw pipelines to include a condition requiring a review of those rates five years from the date the approved rates took effect. Any pipelines subject to a requirement to file a triennial rate review after the issuance of this Final Rule may file a request for an extension of time consistent with the revised policy announced here. VII. Effective Date of the Final Rule and Compliance Deadlines A. Comments 97. Several commenters expressed concern over the speed with which the Commission would adopt and implement the proposed reporting requirements. Three suggestions raised by Jefferson and others were to hold conferences or otherwise delay the issuance of the Final Rule, delay the effective date of the Final Rule, and establish a safe harbor period. 98. First, Jefferson and others seek to delay the issuance of the Final Rule. Jefferson argues that the proposed format ‘‘[r]equires additional guidance in the form of industry conferences and workshops prior to the Commission’s issuance of a Final Rule to avoid conflicts in interpretation of each proposed data element, develop a consensus regarding proposed technical reporting formats, and to give intrastate and Hinshaw pipelines an opportunity to present information that would more accurately represent the burden of reporting.’’ 143 TPA, while also requesting a conference, urges the Commission to postpone any activity in this docket until after the Commission has completed the implementation and appeals process for the rulemaking in Order No. 720, which also concerns intrastate pipeline reporting, and assesses the impact of that rule before considering any further regulations.144 99. Second, Jefferson requests ‘‘an implementation period of at least 18 months from the issuance of a final rule * * * regardless of the technical format ultimately selected.’’ 145 AGA also requests a delayed effective date, without specifying a length.146 100. Third, Jefferson requests a one year safe-harbor period, during which 143 Jefferson 144 TPA 140 Duke at 7. at 3. 142 Enogex at 10–11. 3. 141 TPA PO 00000 Frm 00014 Fmt 4700 at 7. at 6, 15; see also Atmos at 7; ONEOK at 145 Jefferson 146 AGA Sfmt 4700 E:\FR\FM\26MYR1.SGM at 8. at 16. 26MYR1 Federal Register / Vol. 75, No. 101 / Wednesday, May 26, 2010 / Rules and Regulations pipelines will not be penalized for inadvertent reporting errors.147 B. Commission Determination 101. The Final Rule will become effective on April 1, 2011. Pursuant to the regulations, the Form No. 549D quarterly report for the period January 1, 2011 through March 31, 2011 must be eFiled on or before May 1, 2011. Based on the comments from all shippers, we believe that this allows a sufficient period before implementation of the revised reporting requirement to allow reporting pipelines to familiarize themselves with the new reporting format and update their internal processes, if necessary. As noted above, Commission Staff plans to hold a technical workshop on a date to be announced in the near future for the purpose of assisting reporting pipelines in this transition. 102. We will not institute a safeharbor period. However, as stated above in this order, because this is a new information collection, the Commission will focus any enforcement efforts on instances of intentional submission of false, incomplete, or misleading Number of respondents Data collection Form No. 549D ................................................................................ Using an hourly rate of $150 to estimate the costs for filing and other administrative processes, the Commission estimated the total cost for all respondents to be $262,500. emcdonald on DSK2BSOYB1PROD with RULES B. Comments 104. Many pipelines strongly disagreed with the Commission’s burden estimate. Most prominently, commenters urge the Commission to consider the initial implementation burden. Atmos states that it spent five months on the first annual report required by Order No. 704.149 AGA estimates that the development of an XML Schema alone would cost $30,000 per respondent, for an initial total burden of $3.75 million.150 Enogex estimates the ‘‘major information systems upgrades to allow Enogex to track, report, and maintain the level of detailed data necessary * * * [at] $3 to $4 million.’’151 105. Commenters also disagreed with the estimated ongoing annual burden. AGA estimated annual reporting would take over 12 hours per respondent to complete, which for 125 respondents would be an annual burden of $900,000.152 TPA also believes that annual burdens will be significantly higher, especially if the Commission chooses a format that requires manual data entry.153 ‘‘[D]ue to the large number of small-volume, interruptible 311 transactions * * * the burden of additional reporting might outweigh the benefits of participating,’’ TPA warns.154 147 Jefferson at 8. e.g., Order No. 704 at P 114. 149 Atmos at 3. 150 AGA at 7. 151 Enogex at 7. 152 AGA at 7. 153 TPA at 15. 154 TPA at 24. 148 See, VerDate Mar<15>2010 15:14 May 25, 2010 Jkt 220001 Jefferson estimates 24 hours per quarter per respondent, with thousands of dollars in fees to third party information technology vendors.155 In addition, Jefferson and others provide separate estimates of the cost of using industry common codes for shippers and receipt and delivery points, as detailed above in this order.156 C. Revised Statement 106. The Office of Management and Budget (OMB) regulations require that OMB approve certain reporting, record keeping, and public disclosure requirements (collections of information) imposed by an agency.157 The Commission has submitted notification of these proposed information collection requirements to OMB for its review and approval under section 3507(d) of the Paperwork Reduction Act of 1995.158 107. The requirement for intrastate pipelines to post additional information regarding their transactions would impose an initial burden on pipelines as they organize their corporate data to be compatible with the data elements selected by the Commission for Form No. 549D. Certain pipelines have asserted in comments that the costs could include the reconfiguring of information collection systems. However, given that this information is used in their business, the Commission still believes that the burden that would be imposed by this proposed requirement is largely for the collection 155 Jefferson at 14. Jefferson at 9. 157 5 CFR 1320.11. 158 44 U.S.C. 3507(d). 159 See 5 CFR 1320.3(b)(2) (‘‘The time, effort, and financial resources necessary to comply with a collection of information that would be incurred by persons in the normal course of their activities (e.g., 156 E.g., PO 00000 Frm 00015 Fmt 4700 Sfmt 4700 information to the Commission, of failure to report in the first instance, or of failure to exercise due diligence in compiling and reporting data.148 VIII. Information Collection Statement A. Original Statement 103. In the NOPR, in accordance with the requirements of the Office of Management and Budget (OMB), the Commission estimated that on an annual basis the burden to comply with the rule as proposed would be as follows: Number of responses 125 29417 Hours per response 4 Total hours 3.5 1,750 of this information.159 As stated above in this Final Rule, intrastate pipelines can choose to submit their quarterly Form No. 549D using a Commissionprovided Fillable PDF form.160 In this instance, intrastate pipelines would not be required to incur costs to learn XML or develop an XML Schema. Even if an intrastate pipeline chose to file an XML file, it would not incur costs to develop an XML Schema. The Schema would be developed by the Commission and provided to pipelines in order to validate their submission before eFiling it to the Commission. While the Commission erred in not including this burden in its original estimate, we nevertheless find that the burden estimates provided by commenters are far too high. These estimates were based on assumptions that the Commission would require a far more intensive volume of reports—transaction-bytransaction reports instead of contractby-contract reports—and that the Commission would require the more technologically challenging XML data format without developing a ‘‘simple spreadsheet’’ form to guide respondents. 108. OMB regulations require OMB to approve certain information collection requirements imposed by agency rule. The Commission submitted notification of this rule to OMB. The Commission has developed a cost estimate of the initial implementation burden and revised the estimate of the ongoing annual burden concomitant with the decision allow multiple versions of the in compiling and maintaining business records) will be excluded from the ‘‘burden’’ if the agency demonstrates that the reporting, recordkeeping, or disclosure activities needed to comply are usual and customary.’’). 160 Respondents would have to download the free version of Acrobat Reader version 9 to use the fillable PDF. E:\FR\FM\26MYR1.SGM 26MYR1 29418 Federal Register / Vol. 75, No. 101 / Wednesday, May 26, 2010 / Rules and Regulations report. The analysis began with an examination of a representative sample of over one-third of the companies currently filing a Form No. 537, the semi-annual storage report, or Form No. 549, the annual transportation report. Studying the level and type of services performed for their shippers made it possible to split the industry between those that would logically file using the PDF form because of the relatively small number of shippers and services, and those that would incur the addition upfront effort associated with developing tools for filing the report using the Commission’s XML schema. This analysis estimates that the 70 percent of Respondents that average less than five shippers transacting in a given quarter would file using the PDF form. The other 30 percent would incur addition development costs associated with the XML-based report to offset the larger ongoing burden cost associated with reporting more shippers, services, and contracts. Cost estimates were developed for the initial burden and the on-going burden for each of the permissible file methods, using prevailing Houston labor costs and the most efficient hourly split of manpower by legal, accounting, regulatory and IT departments. The initial burden was split between effort involved in the initial review and planning procedures to ensure compliance with the rulemaking and the effort required to develop and implement the new procedures. The PDF startup effort would require an average 68 personhours or $4,354 per Respondent. The XML startup effort would require an additional 128 person-hours, primarily associated with the increased IT development and testing requirements, for an estimated initial burden of $11,287 per Respondent. The start-up burden estimates for complying with this Final Rule are as follows: INITIAL PUBLIC REPORTING BURDEN Average start-up burden per respondent Number of respondents Data collection filing method Total industry hours Total industry costs Using PDF Form .............................................................................. Using XML Schema ......................................................................... 87 38 $4,354 11,287 5,916 7,448 $378,798 428,906 Total .......................................................................................... 125 ............................ 13,364 807,704 To estimate ongoing burden, the Commission analyzed two sets of costs: The per-report cost for the effort by the legal accounting, IT and regulatory departments related to changes in the mix of shippers and services, and the per-contract costs related to the effort populate the report with the information associated with each shipper by service type and by contract. For the first set of costs, this analysis estimates the PDF form to require 11 person-hours at an estimated cost of $596 per report, and the XML Schema 10 man-hours at an estimated cost of $556 per report. For the per-contract set of costs, this analysis estimates the PDF form to require $663 per report and the XML Schema $543 per report, for the average Respondent. ONGOING PUBLIC REPORTING BURDEN Average annual ongoing burden per respondent Number of respondents Data collection filing method Total industry hours per year Total industry costs per year 87 38 $2,650 2,171 4,294 1,520 $230,550 82,498 Total .......................................................................................... emcdonald on DSK2BSOYB1PROD with RULES Using PDF Form .............................................................................. Using XML Schema ......................................................................... 125 ............................ 5,814 313,048 Title: Form No. 549D. Action: Proposed Information Posting and Information Filing. OMB Control No: xxxx-xxxx. Respondents: Business or other for profit. Frequency of Responses: Quarterly posting requirements. Necessity of the Information: The quarterly filing of additional information by intrastate pipelines is necessary to provide information regarding the price and availability of natural gas transportation services to market participants, state commissions, the Commission, and the public. The filing would contribute to market transparency by empowering market participants to determine the extent to which particular transactions are VerDate Mar<15>2010 15:14 May 25, 2010 Jkt 220001 comparable to one another; and it would allow the monitoring of potentially manipulative or unduly discriminatory activity. Interested persons may obtain information on the reporting requirements by contacting the following: Federal Energy Regulatory Commission, 888 First Street, NE., Washington, DC 20426. [Attention: Data Clearance, Phone: (202) 502–8415, fax: (202) 273–0873] e-mail: DataClearance@ferc.gov or by contacting: Office of Management and Budget, Office of Information and Regulatory Affairs, Washington, DC 20503, [Attention: Desk Officer for the Federal Energy Regulatory PO 00000 Frm 00016 Fmt 4700 Sfmt 4700 Commission, phone: (202) 395–7345, fax: (202) 395–7285]. IX. Environmental Analysis 109. The Commission is required to prepare an Environmental Assessment or an Environmental Impact Statement for any action that may have a significant adverse effect on the human environment.161 The Commission has categorically excluded certain actions from these requirements as not having a significant effect on the human environment.162 The actions taken here fall within categorical exclusions in the 161 Order No. 486, Regulations Implementing the National Environmental Policy Act of 1969, 52 FR 47897 (Dec. 17, 1987), FERC Stats. & Regs., Regulations Preambles 1986–1990 ¶ 30,783 (1987). 162 18 CFR 380.4. E:\FR\FM\26MYR1.SGM 26MYR1 Federal Register / Vol. 75, No. 101 / Wednesday, May 26, 2010 / Rules and Regulations Commission’s regulations for rules that are corrective, clarifying or procedural, for information gathering, analysis, and dissemination, and for sales, exchange, and transportation of natural gas that requires no construction of facilities.163 Therefore an environmental review is unnecessary and has not been prepared in this rulemaking. X. Regulatory Flexibility Act 110. The Regulatory Flexibility Act of 1980 (RFA) 164 generally requires a description and analysis of final rules that will have significant economic impact on a substantial number of small entities. The Commission is not required to make such analysis if proposed regulations would not have such an effect. 111. Most of the natural gas companies regulated by the Commission do not fall within the RFA’s definition of a small entity.165 Approximately 125 natural gas companies are potential respondents subject to the requirements adopted by this rule. For the year 2008 (the most recent year for which information is available), 4 companies had annual revenues of less than $7 million. This represents 3.2 percent of the total universe of potential respondents or only a very few entities that may have a significant burden imposed on them. In addition, by providing entities with an option of how they file the information, the Commission has provided alternatives, thereby lessening the economic impact for smaller entities while still accomplishing the regulatory objective of increasing market transparency. In view of these considerations, the Commission certifies that this Final Rule’s amendments to the regulations will not have a significant impact on a substantial number of small entities. emcdonald on DSK2BSOYB1PROD with RULES XI. Document Availability 112. In addition to publishing the full text of this document, except for the Appendix, in the Federal Register, the Commission provides all interested persons an opportunity to view and/or print the contents of this document, including the Appendix, via the Internet 163 See 18 CFR 380.4(a)(2)(ii), 380.4(a)(5) and 380.4(a)(27). 164 5 U.S.C. 601–612. 165 See 5 U.S.C. 601(3), citing section 3 of the Small Business Act, 15 U.S.C. 623. Section 3 of the SBA defines a ‘‘small business concern’’ as a business which is independently owned and operated and which is not dominant in its field of operation. The Small Business Size Standards component of the North American Industry Classification System defines a small natural gas pipeline company as one that transports natural gas and whose annual receipts (total income plus cost of goods sold) did not exceed $7 million for the previous year. VerDate Mar<15>2010 15:14 May 25, 2010 Jkt 220001 through FERC’s Home Page (https:// www.ferc.gov) and in FERC’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. 113. From FERC’s Home Page on the Internet, this information is available on eLibrary. The full text of this document, including the Appendix, is available on eLibrary 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. 114. User assistance is available for eLibrary and the FERC’s Web site during normal business hours from FERC Online Support at 202–502–6652 (toll free at 1–866–208–3676) or email at ferconlinesupport@ferc.gov, or the Public Reference Room at (202) 502– 8371, TTY (202) 502–8659. E-mail the Public Reference Room at public.referenceroom@ferc.gov. XII. Effective Date and Congressional Notification 115. These regulations are effective April 1, 2011. The quarterly report for transactions occurring during the period January 1, 2011 through March 31, 2011 must be filed on or before May 1, 2011. The Commission has determined that this rule is not a ‘‘major rule’’ as defined in section 351 of the Small Business Regulatory Enforcement Fairness Act of 1996. List of Subjects in 18 CFR Part 284 Continental shelf, Natural gas, Reporting and recordkeeping requirements. By the Commission. Nathaniel J. Davis, Sr., Deputy Secretary. In consideration of the foregoing, the Commission amends Part 284, Chapter I, Title 18, Code of Federal Regulations, as follows. ■ PART 284—CERTAIN SALES AND TRANSPORTATION OF NATURAL GAS UNDER THE NATURAL GAS POLICY ACT OF 1978 AND RELATED AUTHORITIES 1. The authority citation for Part 284 continues to read as follows: ■ Authority: 15 U.S.C. 717–717w, 3301– 3432; 42 U.S.C. 7101–7352; 43 U.S.C. 1331– 1356 2. In § 284.126, paragraph (b) is revised to read as follows: ■ § 284.126 Reporting requirements. * * PO 00000 * Frm 00017 * Fmt 4700 * Sfmt 4700 29419 (b) Form No. 549D, Quarterly Transportation and Storage Report of Intrastate Natural Gas and Hinshaw Pipelines. (1) Each intrastate pipeline must use Form No. 549D to file a quarterly report with the Commission and the appropriate state regulatory agency that contains, for each transportation and storage service provided during the preceding calendar quarter under § 284.122, the following information on each transaction, aggregated by contract: (i) The full legal name, and identification number, of the shipper receiving the service, including whether there is an affiliate relationship between the pipeline and the shipper; (ii) The type of service performed (i.e., firm or interruptible transportation, storage, or other service); (iii) The rate charged under each contract, specifying the rate schedule/ name of service and docket where the rates were approved. The report should separately state each rate component set forth in the contract (i.e., reservation, usage, and any other charges); (iv) The primary receipt and delivery points covered by the contract, identified by the list of points that the pipeline has published with the Commission, which shall include the industry common code for each point where one has already been established; (v) The quantity of natural gas the shipper is entitled to transport, store, or deliver under each contract; (vi) The duration of the contract, specifying the beginning and ending month and year of the current agreement; (vii) Total volumes transported, stored, injected or withdrawn for the shipper; and (viii) Total revenues received for the shipper. The report should separately state revenues received under each rate component; (2) The quarterly Form No. 549D report for the period January 1 through March 31 must be filed on or before May 1. The quarterly report for the period April 1 through June 30 must be filed on or before August 1. The quarterly report for the period July 1 through September 30 must be filed on or before November 1. The quarterly report for the period October 1 through December 31 must be filed on or before February 1. (3) Each Form No. 549D report must be filed as prescribed in § 385.2011 of this chapter as indicated in the General Instructions and Data Dictionary set out in the quarterly reporting form. Each report must be prepared and filed in conformance with the Commission’s software or XML Schema, eTariff filing structure, and reporting guidance, so as E:\FR\FM\26MYR1.SGM 26MYR1 29420 Federal Register / Vol. 75, No. 101 / Wednesday, May 26, 2010 / Rules and Regulations to be posted and available for downloading from the FERC Web site (https://www.ferc.gov). One copy of the report must be retained by the respondent in its files. (4) Intrastate pipelines filing Form No. 549D are no longer required to file Form No. 549—Intrastate Pipeline Annual Transportation Report after their March 31, 2011 filing. * * * * * [FR Doc. 2010–12614 Filed 5–25–10; 8:45 am] BILLING CODE 6717–01–P DEPARTMENT OF HOMELAND SECURITY Coast Guard W12–140, 1200 New Jersey Avenue, SE., Washington, DC 20590, between 9 a.m. and 5 p.m., Monday through Friday, except Federal holidays. You may also find this docket on the Internet by going to https://www.regulations.gov, inserting USCG–2007–27022 in the ‘‘Keyword’’ box, and then clicking ‘‘Search.’’ FOR FURTHER INFORMATION CONTACT: If you have questions on this rule, call or e-mail Commander Patrick Clark, CG–5222, U.S. Coast Guard; telephone 202–372–1410, e-mail Patrick.W.Clark@uscg.mil. If you have questions on viewing the docket, call Renee V. Wright, Program Manager, Docket Operations, telephone 202–366– 9826. SUPPLEMENTARY INFORMATION: 33 CFR Part 127 Table of Contents for Preamble [Docket No. USCG–2007–27022] I. Abbreviations II. Regulatory History III. Background A. Basis and Purpose of the Final Rule B. Discussion of FERC Regulations With Regard to LNG IV. Discussion of Comments and Changes A. General Comments B. Comments on the Letter of Intent C. Comments on Waterway Safety, and the Waterway Suitability Assessment D. Comments on Frequency of Shipments E. Comments on Evaluating the Density and Character of Marine Traffic F. Comments on the Letter of Recommendation G. Comments on Timely Issuance of the Letter of Recommendation H. Comments on the Differences Between LNG and LHG I. Other Changes V. Regulatory Analyses A. Regulatory Planning and Review B. Small Entities C. Assistance for Small Entities D. Collection of Information E. Federalism F. Unfunded Mandates Reform Act G. Taking of Private Property H. Civil Justice Reform I. Protection of Children J. Indian Tribal Governments K. Energy Effects L. Technical Standards M. Environment RIN 1625–AB13 Revision of LNG and LHG Waterfront Facility General Requirements Coast Guard, DHS. Final rule. AGENCY: emcdonald on DSK2BSOYB1PROD with RULES ACTION: SUMMARY: In this final rule, the Coast Guard revises the requirements for waterfront facilities handling liquefied natural gas (LNG) and liquefied hazardous gas (LHG). The revisions bring the regulations up to date with industry practices and Coast Guard policy implemented due to increased emphasis on security since the events of September 11, 2001. These revisions harmonize the Coast Guard’s regulations for LNG with those established by the Federal Energy Regulatory Commission (FERC), the agency with exclusive authority to approve or deny an application for the siting, construction, expansion, or operation of an LNG facility located onshore or within State waters. This rulemaking does not affect LNG deepwater ports. DATES: This final rule is effective June 25, 2010. To the extent this rulemaking affects the collection of information in 33 CFR 127.007, we will not enforce the revised collection requirements until the collection is approved by the Office of Management and Budget (OMB). When OMB approves, we will publish notification in the Federal Register. ADDRESSES: Comments and material received from the public, as well as documents mentioned in this preamble as being available in the docket, are part of docket USCG–2007–27022 and are available for inspection or copying at the Docket Management Facility (M–30), U.S. Department of Transportation, West Building Ground Floor, Room VerDate Mar<15>2010 15:14 May 25, 2010 Jkt 220001 I. Abbreviations CFR Code of Federal Regulations COTP Captain of the Port DHS Department of Homeland Security FERC Federal Energy Regulatory Commission FR Federal Register LHG Liquefied hazardous gas LNG Liquefied natural gas LOI Letter of Intent LOR Letter of Recommendation NEPA National Environmental Policy Act of 1969 NTTAA National Technology Transfer and Advancement Act NPRM Notice of proposed rulemaking PO 00000 Frm 00018 Fmt 4700 Sfmt 4700 NVIC Navigation and Vessel Inspection Circular OMB Office of Management and Budget U.S.C. United States Code WSA Waterway Suitability Assessment II. Regulatory History On April 28, 2009, we published in the Federal Register a notice of proposed rulemaking entitled ‘‘Revision of LNG and LHG Waterfront Facility General Requirements’’ (74 FR 19159). We received four letters commenting on the proposed rule, containing a total of 38 comments. No public meeting was requested and none was held. III. Background A. Basis and Purpose of the Final Rule Over the last decade, the worldwide production and transportation of liquefied natural gas (LNG) has increased substantially. Currently, the United States consumes about 25 percent of the world’s annual natural gas production. Over the next 20 years, U.S. natural gas consumption is projected to increase. Should domestic gas production not meet this demand, increased marine LNG imports may be needed to help resolve this likely shortfall. Currently, there are nine waterfront LNG facilities in the United States: eight are import facilities, and one is an export facility. To meet rising demand, the energy industry has submitted dozens of proposals to build LNG import facilities along our coasts, and an unspecified number of proposals are in the early planning stages. We have not seen, and do not expect, a similar increase in the production and transportation of liquefied hazardous gas (LHG). Although LNG and LHG facilities and the cargoes they handle are different in nature, we believe the vessels that transport these cargoes pose similar risks to the waterway environment and the area surrounding the marine transfer area of the facility when transfer operations are underway. Safety and security of our ports and waterways have become paramount concerns since the events of September 11, 2001. Currently, the owner or operator intending to construct, modify, or reactivate an LNG or LHG facility must submit a Letter of Intent (LOI) to the Coast Guard. Information obtained in the LOI enables the Coast Guard to provide specific input, in a Letter of Recommendation (LOR), to an agency having jurisdiction for siting, construction, and operation. The LOR serves as the Coast Guard’s recommendation to the jurisdictional agency as to the suitability of the waterway for LNG or LHG marine traffic on the waterway associated with the E:\FR\FM\26MYR1.SGM 26MYR1

Agencies

[Federal Register Volume 75, Number 101 (Wednesday, May 26, 2010)]
[Rules and Regulations]
[Pages 29404-29420]
From the Federal Register Online via the Government Printing Office [www.gpo.gov]
[FR Doc No: 2010-12614]


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DEPARTMENT OF ENERGY

Federal Energy Regulatory Commission

18 CFR Part 284

[Docket No. RM09-2-000; Order No. 735]


Contract Reporting Requirements of Intrastate Natural Gas 
Companies

May 20, 2010.
AGENCY: Federal Energy Regulatory Commission.

ACTION: Final rule.

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SUMMARY: In this Final Rule, the Commission revises the contract 
reporting requirements for those natural gas pipelines that fall under 
the Commission's jurisdiction pursuant to section 311 of the Natural 
Gas Policy Act or section 1(c) of the Natural Gas Act. The Final Rule 
revises Sec.  284.126(b) and replaces Form No. 549--Intrastate Pipeline 
Annual Transportation Report with the new Form No. 549D--Quarterly 
Transportation and Storage Report for Intrastate Natural Gas and 
Hinshaw Pipelines. The Final Rule makes changes so as to increase the 
reporting frequency from annual to quarterly, include certain 
additional types of information and cover storage transactions as well 
as transportation transactions, establish a procedure for the Form No. 
549D reports to be filed in a uniform electronic format and posted on 
the Commission's Web site, and hold that those reports must be public 
and may not be filed with information redacted as privileged. The 
Commission is also modifying its policy concerning periodic reviews of 
the rates charged by section 311 and Hinshaw pipelines to extend the 
cycle for such reviews from 3 years to 5 years.

DATES: Effective Date: This rule will become effective April 1, 2011.

FOR FURTHER INFORMATION CONTACT:

Vince Mareino (Legal Information), Office of the General Counsel, 
Federal Energy Regulatory Commission, 888 First Street, NE., 
Washington, DC 20426, (202) 502-6167, Vince.Mareino@ferc.gov.
James Sarikas (Technical Information), Office of Energy Markets 
Regulation, Federal Energy Regulatory Commission, 888 First Street, 
NE., Washington, DC 20426, (202) 502-6831, James.Sarikas@ferc.gov.
Thomas Russo (Technical Information), Office of Enforcement, Federal 
Energy Regulatory Commission, 888 First Street, NE., Washington, DC 
20426, (202) 502-8792, Thomas.Russo@ferc.gov.

SUPPLEMENTARY INFORMATION: 
    Before Commissioners: Jon Wellinghoff, Chairman; Marc Spitzer, 
Philip D. Moeller, and John R. Norris.

Order No. 735

Final Rule

Issued May 20, 2010.

 
                                                               Paragraph
                                                                 Nos.
 
I. Introduction and Summary.................................           1
II. Background..............................................           2
III. Statutory Authority for the Rule.......................          15
IV. Need for the Rule.......................................          22
V. Details of Pipeline Posting Requirements.................          41
    A. Overview and Summary of Requirements.................          41
    B. Definition of Reportable Service.....................          43
    C. Reporting Frequency..................................          49
    D. Identification of Receipt and Delivery Points and              54
     Shippers...............................................
    E. Requests for Exemptions and Safe Harbor..............          62
    F. Public Status of Reports.............................          68
    G. Data Format and Technical Protocols..................          80
VI. Periodic Rate Review....................................          89
VII. Effective Date of the Final Rule and Compliance                  97
 Deadlines..................................................
VIII. Information Collection Statement......................         103
IX. Environmental Analysis..................................         109
X. Regulatory Flexibility Act...............................         110
XI. Document Availability...................................         112
XII. Effective Date and Congressional Notification..........         115
 

I. Introduction and Summary

    1. In this Final Rule, the Commission revises the contract 
reporting requirements for (1) intrastate natural gas pipelines \1\ 
providing interstate transportation service pursuant to section 311 of 
the Natural Gas Policy

[[Page 29405]]

Act of 1978 (NGPA) \2\ and (2) Hinshaw pipelines providing interstate 
service subject to the Commission's Natural Gas Act (NGA) section 1(c) 
jurisdiction pursuant to blanket certificates issued under Sec.  
284.224 of the Commission's regulations.\3\ The revised reporting 
requirements are intended to increase market transparency, without 
imposing unduly burdensome requirements on the pipelines. Specifically, 
the Final Rule revises Sec.  284.126(b) and replaces Form No. 549--
Intrastate Pipeline Annual Transportation Report with the new Form No. 
549D, so as to (1) increase the reporting frequency from annual to 
quarterly, (2) include certain additional types of information and 
cover storage transactions as well as transportation transactions,\4\ 
(3) establish a procedure for Form No. 549D to be filed in a uniform 
electronic format and posted on the Commission's Web site, and (4) hold 
that those reports must be public and may not be filed with information 
redacted as privileged. The Commission is also modifying its policy 
concerning periodic reviews of the rates charged by section 311 and 
Hinshaw pipelines to extend the cycle for such reviews from 3 years to 
5 years.
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    \1\ Pursuant to section 2(16) of the NGPA, 15 U.S.C. 3301(16), 
the term ``intrastate pipeline'' may refer to all entities engaged 
in natural gas transportation under section 311 of the NGPA or 
section 1(c) of the NGA. For consistency, this Final Rule will also 
use the terms ``transportation,'' ``pipeline,'' and ``shippers'' to 
refer inclusively to storage activity (except where noted).
    \2\ 15 U.S.C. 3372.
    \3\ Section 1(c) of the NGA exempts from the Commission's NGA 
jurisdiction those pipelines which transport gas in interstate 
commerce if (1) they receive natural gas at or within the boundary 
of a state, (2) all the gas is consumed within that state and (3) 
the pipeline is regulated by a state Commission. This exemption is 
referred to as the Hinshaw exemption after the Congressman who 
introduced the bill amending the NGA to include section 1(c). See 
ANR Pipeline Co. v. Federal Energy Regulatory Comm'n, 71 F.3d 897, 
898 (1995) (briefly summarizing the history of the Hinshaw 
exemption).
    \4\ This Final Rule does not eliminate or revise Sec.  
284.126(c) and the corresponding Form No. 537, which require a semi-
annual storage report.
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II. Background

A. Current Reporting Requirements

    2. NGPA section 311 authorizes the Commission to allow intrastate 
pipelines to transport natural gas ``on behalf of'' interstate 
pipelines or local distribution companies served by interstate 
pipelines ``under such terms and conditions as the Commission may 
prescribe.'' \5\ NGPA section 601(a)(2) exempts transportation service 
authorized under NGPA section 311 from the Commission's NGA 
jurisdiction. Congress adopted these provisions in order to eliminate 
the regulatory barriers between the intrastate and interstate markets 
and to promote the entry of intrastate pipelines into the interstate 
market. Such entry eliminates the need for duplication of facilities 
between interstate and intrastate pipelines.\6\ Shortly after the 
adoption of the NGPA, the Commission authorized Hinshaw pipelines to 
apply for NGA section 7 certificates, authorizing them to transport 
natural gas in interstate commerce in the same manner as intrastate 
pipelines may do under NGPA section 311.\7\
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    \5\ 15 U.S.C. 3371(c).
    \6\ EPGT Texas Pipeline, 99 FERC ] 61,295 at 62,252-3 (2002).
    \7\ Certain Transportation, Sales, and Assignments by Pipeline 
Companies not Subject to Commission Jurisdiction Under Section 1(c) 
of the Natural Gas Act, Order No. 63, FERC Stats. & Regs. ] 30,118, 
at 30,824-25 (1980).
---------------------------------------------------------------------------

    3. Subpart C of the Commission's Part 284 open access regulations 
(18 CFR Sec.  284.121-126) implements the provisions of NGPA section 
311 concerning transportation by intrastate pipelines. Those 
regulations require that intrastate pipelines performing interstate 
service under NGPA section 311 must do so on an open access basis.\8\ 
However, consistent with the NGPA's goal of encouraging intrastate 
pipelines to provide interstate service, the Commission has not imposed 
on intrastate pipelines all of the Part 284 requirements imposed on 
interstate pipelines.\9\ For example, when the Commission first adopted 
the Part 284 open access regulations in Order No. 436, the Commission 
exempted intrastate pipelines from the requirement that they offer open 
access service on a firm basis.\10\ The Commission found that requiring 
intrastate pipelines to offer firm service to out-of-state shippers 
could discourage them from providing any interstate service, because 
such a requirement could progressively turn the intrastate pipeline 
into an interstate pipeline against its will and against the will of 
the responsible state authorities. Similarly, Order No. 636-B exempted 
intrastate pipelines from the requirements of Order No. 636.\11\ Those 
requirements included capacity release, electronic bulletin boards (now 
Internet Web sites), and flexible receipt and delivery points.
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    \8\ See 18 CFR Sec. Sec.  284.7(b), 284.9(b) and 284.122.
    \9\ Associated Gas Distributors v. FERC, 824 F.2d 981, 1002-1003 
(D.C. Cir. 1987) (AGD); Mustang Energy Corp. v. Federal Energy 
Regulatory Comm'n, 859 F.2d 1447, 1457 (10th Cir. 1988), cert. 
denied, 490 U.S. 1019 (1988); see also EPGT Texas Pipeline, 99 FERC 
] 61,295 (2002).
    \10\ Regulation of Natural Gas Pipelines After Partial Wellhead 
Decontrol, Order No. 436, FERC Stats. & Regs. ] 30,665, at 31,502 
(1985).
    \11\ Pipeline Service Obligations, and Revisions to Regulations 
Governing Self-Implementing Transportation Under Part 284 of the 
Commission's Regulations; Regulation of Natural Gas Pipelines After 
Partial Wellhead Decontrol, Order No. 636-B, 61 FERC ] 61,272, at 
61,992 n.26 (1992), order on reh'g, 62 FERC ] 61,007 (1993), aff'd 
in part and remanded in part sub nom. United Distribution Cos. v. 
FERC, 88 F.3d 1105 (D.C. Cir. 1996), order on remand, Order No. 636-
C, 78 FERC ] 61,186 (1997).
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    4. Section 284.224 of the regulations provides for the issuance of 
blanket certificates to Hinshaw pipelines to provide open access 
transportation service ``to the same extent that, and in the same 
manner'' as intrastate pipelines are authorized to perform such service 
by Subpart C.
    5. The Commission currently has less stringent transactional 
reporting requirements for NGPA section 311 intrastate pipelines and 
Hinshaw pipelines, than for interstate pipelines. In Order No. 637,\12\ 
the Commission revised the reporting requirements for interstate 
pipelines in order to provide more transparent pricing information and 
to permit more effective monitoring for the exercise of market power 
and undue discrimination. As adopted by Order No. 637, Sec.  284.13(b) 
requires interstate pipelines to post on their Internet Web sites basic 
information on each transportation and storage transaction with 
individual shippers, including revisions to a contract, no later than 
the first nomination under a transaction. This information includes:
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    \12\ Regulation of Short-Term Natural Gas Transportation 
Services and Regulation of Interstate Natural Gas Transportation 
Services, Order No. 637, FERC Stats. & Regs. ] 31,091, clarified, 
Order No. 637-A, FERC Stats. & Regs. ] 31,099, reh'g denied, Order 
No. 637-B, 92 FERC ] 61,062 (2000), aff'd in part and remanded in 
part sub nom. Interstate Natural Gas Ass'n of America v. FERC, 285 
F.3d 18 (D.C. Cir. 2002), order on remand, 101 FERC ] 61,127 (2002), 
order on reh'g, 106 FERC ] 61,088 (2004), aff'd sub nom. American 
Gas Ass'n v. FERC, 428 F.3d 255 (D.C. Cir. 2005).
---------------------------------------------------------------------------

     The name of the shipper.
     The contract number (for firm service).
     The rate charged.
     The maximum rate.
     The duration (for firm service).
     The receipt and delivery points and zones covered.
     The quantity of natural gas covered.
     Any special terms or details, such as any deviations from 
the tariff.
     Whether any affiliate relationship exists.
    6. Section 284.13(c) of the Commission's regulations also requires 
interstate pipelines to file with the Commission on the first business 
day of each calendar quarter an index of its firm transportation and 
storage customers and to publish the same information on their Web 
sites. The information required to be included in the Index of 
Customers does not include the rates paid by the customers. Section 
284.13(e) requires interstate pipelines to file semi-annual reports of 
their storage injection and withdrawal activities, including the 
identities of the

[[Page 29406]]

customers, the volumes injected into and withdrawn from storage for 
each customer and the unit charge and total revenues received. Order 
No. 637 did not modify the reporting requirements for NGPA section 311 
intrastate pipelines and Hinshaw pipelines provided in Sec.  284.126(b) 
and (c) of the Commission's regulations.
    7. Section 284.126(b) of the Commission's regulations requires 
intrastate pipelines to file with the Commission annual reports of 
their transportation transactions, but not their storage transactions. 
Those Form No. 549 reports must include the following information:
     The name of the shipper receiving transportation service.
     The type of service performed (i.e. firm or 
interruptible).
     The total volumes transported for the shipper, including 
for firm service a separate statement of reservation and usage 
quantities.
     Total revenues received for the shipper, including for 
firm service a separate statement of reservation and usage revenues.
    8. Unlike the interstate pipelines' reporting requirement (Sec.  
284.13(b)), the current version of Sec.  284.126(b) does not require 
intrastate pipelines to include in these Form No. 549 reports the rate 
charged under each contract, the duration of the contract, the receipt 
and delivery points and zones or segments covered by each contract, 
whether the contract includes any special terms and conditions, and 
whether there is an affiliate relationship between the pipeline and the 
shipper.
    9. Section 284.126(c) requires Section 311 intrastate pipelines and 
Hinshaw pipelines to file Form No. 537, a semi-annual report of their 
storage activity, within 30 days of the end of each complete storage 
and injection season. This requirement is substantially the same as the 
Sec.  284.13(e) requirement that interstate pipelines file such semi-
annual reports of their storage activity.

B. The NOPR

    10. In November 2008, the Commission issued a Notice of Inquiry 
(NOI), requesting comments on whether the Commission should impose 
additional reporting requirements on NGPA section 311 intrastate 
pipelines and on Hinshaw pipelines.\13\ The NOI stated that, in a 
contemporaneous order, the Commission was denying a request by 
interstate storage provider with market based rates \14\ for waiver of 
the requirements that interstate pipelines post the rates charged in 
firm and interruptible transactions no later than first nomination for 
service. In that order, the Commission held that the fact some 
interstate storage companies have been authorized to charge market-
based rates does not justify exempting them from the requirements in 
section 284.13(b) that they post the rates charged in each storage 
transaction. The SGRM order held that the existing posting requirements 
for interstate pipelines are necessary to provide shippers with the 
price transparency they need to make informed decisions, and the 
ability to monitor transactions for undue discrimination and 
preference.\15\ The Commission also found that the requested exemption 
would be contrary to NGA section 4(c)'s requirement that ``every 
natural gas company * * * keep open * * * for public inspection * * * 
all rates.'' \16\
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    \13\ Contract Reporting Requirement of Intrastate Natural Gas 
Companies, FERC Stats. & Regs. ] 35,559 (2008).
    \14\ SG Resources Mississippi, L.L.C. (SGRM).
    \15\ SGRM, 125 FERC ] 61,191 (2008).
    \16\ 15 U.S.C. 717c(c).
---------------------------------------------------------------------------

    11. However, in recognition of interstate storage providers' 
concern about the competitive effects of the disparate reporting 
requirements for interstate pipelines and section 311 intrastate 
pipelines, the NOI stated that the Commission was interested in 
exploring (1) whether the disparate reporting requirements for 
interstate and intrastate pipelines have an adverse competitive effect 
on the interstate pipelines and (2) if so, whether the Commission 
should modify the posting requirements for Section 311 intrastate 
pipelines and Hinshaw pipelines in order to make them more comparable 
to the Sec.  284.13(b) posting requirements for interstate pipelines. 
Accordingly, the Commission sought comments to assist it in evaluating 
whether changes in the Commission's posting requirements should be 
considered in order to remove any competitive disadvantage for 
interstate pipelines, as compared to intrastate pipelines providing 
interstate transportation and storage services under Section 311 of the 
NGPA and to Hinshaw pipelines providing such service pursuant to a 
Sec.  284.224 blanket certificate.
    12. Based upon a review of the comments received in response to the 
NOI, the Commission issued a Notice of Proposed Rulemaking (NOPR),\17\ 
proposing to revise its transactional reporting requirements for 
intrastate and Hinshaw pipelines in order to increase market 
transparency, without imposing unduly burdensome requirements on those 
pipelines. The Commission proposed to increase the availability and 
usefulness of the transactional information reported by intrastate and 
Hinshaw pipelines by requiring that (1) the existing annual Sec.  
284.126(b) transactional reports be filed on a quarterly basis, (2) the 
quarterly reports include certain additional types of information and 
cover storage transactions as well as transportation transactions, (3) 
the quarterly reports be filed in a uniform electronic format and 
posted on the Commission's Web site, and (4) the reports must be public 
and may not be filed with information redacted as privileged.
---------------------------------------------------------------------------

    \17\ Contract Reporting Requirements of Intrastate Natural Gas 
Companies, FERC Stats. & Regs. ] 32,644 (2009) (NOPR).
---------------------------------------------------------------------------

    13. The Commission invited all interested parties to comment on all 
aspects of the NOPR. The Commission also elaborated on the proposed 
uniform electronic format in a separate Notice Requesting Comments On 
Proposed Standardized Electronic Information Collection (Information 
Notice).\18\
---------------------------------------------------------------------------

    \18\ Contract Reporting Requirements of Intrastate Natural Gas 
Companies, FERC Stats. & Regs. ] 35,051 (2009) (Information Notice).
---------------------------------------------------------------------------

    14. Comments on the NOPR and Information Notice were due on 
November 4, 2009. Sixteen parties filed comments. A list of Commenters 
and Abbreviations is included as an appendix to this order. Most 
commenters were Section 311 or Hinshaw pipelines or their associations, 
but interstate pipelines, exploration & production companies, and an 
association of municipal consumers also filed comments. We discuss the 
comments below in the context of reviewing, amending, and promulgating 
each aspect of this Final Rule.

III. Statutory Authority for the Rule

    15. In this section, we address contentions by some commenters that 
the Commission lacks authority under NGPA section 311 to require 
intrastate pipelines to file more detailed transactional reports. While 
some commenters contest specific aspects of our proposal as it affects 
Hinshaw pipelines, no commenter questions the Commission's general 
authority under NGA sections 4 and 10 to require Hinshaw pipelines to 
file more detailed transactional reports.

A. NOPR

    16. In the NOPR, the Commission stated that NGPA section 311(c) 
authorizes the Commission to prescribe the ``terms and conditions'' 
under which intrastate pipelines perform interstate service. The NOPR 
concluded that its proposal to require intrastate pipelines to file and 
make public the proposed

[[Page 29407]]

transactional reports so that shippers and others can monitor NGPA 
section 311 transactions for undue discrimination is well within the 
Commission's broad conditioning authority under Sec.  311(c).

B. Comments

    17. TPA claims that the Commission lacks statutory authority to 
enact the proposed regulations, arguing that ``Congressional intent 
[was] that transactions under NGPA Section 311 are to be subjected to 
minimal regulation.'' \19\ Enogex, along with TPA, adds that the 
proposed reporting requirements are ``in direct contravention of 
Section 311 of the NGPA and the legislative intent,'' because 
compliance would be ``unduly burdensome,'' and because disclosure would 
harm the pipelines' business position.\20\
---------------------------------------------------------------------------

    \19\ TPA at 2. See also id. at 12, 13, 16.
    \20\ Enogex at 6. Enogex and several other commenters also raise 
this concern as a policy argument instead of an argument on 
statutory authority; these policy arguments are addressed in the 
subsequent section on the Need for the Rule.
---------------------------------------------------------------------------

    18. Other commenters, citing the legislative history of the NGPA, 
argue that the proposed regulations are lawful. Clayton Williams states 
that ``to the extent the intrastate pipeline is involved in an 
authorized'' interstate transaction, the Commission has jurisdiction to 
review that transaction.\21\ Similarly, Texas Alliance argues that 
claims of undue burden are too conclusory, and that the NGPA's 
jurisdiction is actually based on whether a given activity of a Section 
311 pipeline is interstate or intrastate.\22\ Clayton Williams argues 
that it is the purpose of Section 311 to ``help integrate gas 
markets,'' and that ``reasonable rules have always been part of the 311 
world.'' \23\ Further, Apache argues for even more frequent and 
detailed reporting, stating, ``the Commission has jurisdiction and 
discretion to require * * * [intrastate] pipelines to report the same 
information during the same time frame about natural gas transactions 
that the interstate pipelines are required to report.'' \24\ Apache 
reasons ``that interstate pipelines and Section 311 and Hinshaw 
pipelines are held to the same prohibition on undue discrimination,'' 
\25\ so the transparency regulations necessary to ensure compliance 
should be the same as well.
---------------------------------------------------------------------------

    \21\ Clayton Williams at 4 (quoting H.R. Rep. No. 543, 95th 
Cong. 1st Sess. 45 (1977)).
    \22\ Texas Alliance at 8.
    \23\ Clayton Williams at 3-4.
    \24\ Apache at 3.
    \25\ Apache at 6.
---------------------------------------------------------------------------

C. Commission Determination

    19. The Commission's statutory authority to impose reporting 
requirements on Section 311 pipelines derives from NGPA section 311(c), 
which states, ``any authorization granted under this section shall be 
under such terms and conditions as the Commission may prescribe.'' \26\ 
This blanket authority is well-established as the ground for the 
previous reporting requirements for Form No. 549. As the Commission 
reasoned in the rulemaking establishing a previous version of this 
reporting requirement, ``section 311 tasks the Commission with the 
responsibility to ensure rates and charges are fair and equitable. For 
the Commission to carry out this responsibility, it is important for 
rates charged to be reported.'' \27\ None of the commenters in this 
docket challenge the legality of the previous reporting requirements. 
The new reporting requirements are not so different in scope or burden 
as to generate serious questions about the Commission's long-
established statutory authority to require transactional reporting.
---------------------------------------------------------------------------

    \26\ 15 U.S.C. 3371(c).
    \27\ Revisions to Uniform System of Accounts, Forms, Statements, 
and Reporting Requirements for Natural Gas Companies, Order No. 581, 
60 FR 53019, 53050-51, FERC Stats. & Regs. ] 31,026 (1995), order on 
reh'g, Order No. 581-A, FERC Stats. & Regs. ] 31,032 (1996) (Order 
No. 581).
---------------------------------------------------------------------------

    20. TPA's characterization that the NGPA limits the Commission to 
``minimal regulation,'' \28\ is misleading and unsupported. While 
Congress sought to encourage intrastate pipelines to participate in the 
interstate transportation market by enabling them to do so without 
bearing the burden of full Commission regulation under the NGA,\29\ 
this does not mean that Commission regulation under NGPA section 311 
was to be minimal. In Associated Gas Distributors v. FERC,\30\ the 
court affirmed the Commission's use of its NGPA section 311(c) 
conditioning authority to impose conditions necessary to assure that 
section 311 intrastate pipelines do not engage in undue discrimination. 
The court also stated ``that the Commission has been correct in its 
belief that under Sec.  311 it should assert the traditional regulatory 
approach in areas where it is needed to protect the public from market 
dominance by natural gas companies.'' \31\ Requiring intrastate 
pipelines to file quarterly transactional reports to permit the 
Commission, shippers, and others to monitor for undue discrimination is 
fully within the scope of this conditioning authority.
---------------------------------------------------------------------------

    \28\ TPA at 2.
    \29\ Mustang Energy Corp. v. Federal Energy Regulatory Comm'n, 
859 F.2d 1447, 1457 (10th Cir. 1988), cert. denied, 490 U.S. 1019 
(1988); see also EPGT Texas Pipeline, 99 FERC ] 61,295 (2002).
    \30\ 824 F.2d 981, 1002-1003 (D.C. Cir. 1987) (AGD).
    \31\ Id. at 1018 (citation omitted).
---------------------------------------------------------------------------

    21. While the Commission will consider the burden question in more 
detail below, commenters have provided no persuasive evidence that the 
Final Rule is somehow so burdensome as to be beyond Commission's 
jurisdiction. As compared to the requirements for interstate pipelines, 
the Final Rule is limited in the scope of the reports, the burden of 
publishing a report, and the frequency of the reports. As discussed 
below, the Commission held itself to these limitations so that the 
Sec.  284.126(b) requirements should remain lighter than the Sec.  
284.13(b) interstate requirements and so that the value of the 
increased flow of information exceeds the increased burden of 
reporting. Any further lightening would risk undermining the Final 
Rule's ability to increase transparency and improve the functioning of 
the transportation market.

IV. Need for the Rule

A. NOPR

    22. Upon review of the comments received in response to the NOI, 
the Commission held that its primary goal in revising the transactional 
reporting requirements for intrastate and Hinshaw pipelines would be to 
increase market transparency.\32\ As the Commission reasoned, 
``[t]ransactional information provides price transparency so shippers 
can make informed purchasing decisions, and also permits both shippers 
and the Commission to monitor actual transactions for evidence of 
possible abuse of market power or undue discrimination.'' \33\ The 
Commission found that certain types of additional information should be 
published in order to enable shippers, other market participants, and 
the Commission ``to determine the extent to which particular 
transactions are comparable to one another,'' \34\ a prerequisite for 
determining the rights of similarly situated shippers and for detecting 
undue discrimination.
---------------------------------------------------------------------------

    \32\ NOPR at 1, 16.
    \33\ NOPR at 16.
    \34\ NOPR at 19.
---------------------------------------------------------------------------

    23. The Commission stated in the NOPR that it ``believes that the 
revised reporting requirements * * * avoid[ ] unduly burdensome 
requirements that might discourage * * * participating in the 
interstate market.'' \35\ In proposing

[[Page 29408]]

the frequency, content, and format of the reports, the Commission 
sought the best balance of minimizing the reporting burden and 
maximizing the competitive effects on the markets. For example, the 
Commission proposed to host reporting data on its own Web site, and 
encouraged intrastate pipelines to comment on the preferred file 
format, in order to help the Commission lessen the information 
technology burden for pipelines.\36\
---------------------------------------------------------------------------

    \35\ NOPR at 17.
    \36\ NOPR at 28-29.
---------------------------------------------------------------------------

B. Comments

    24. Several intrastate pipelines argue that the Commission failed 
to identify sufficiently compelling reasons for revising the reporting 
requirements. These commenters argue that further transparency is 
unnecessary, or that the proposal would have little practical 
benefit.\37\ Enogex, for example, argues that ``[i]n view of the 
minimal amount of concern expressed by interstate pipelines * * * the 
Commission should have terminated this proceeding.'' \38\ AOG suggests 
that the Commission should, if not abandon the proposal, at least 
``more narrowly tailor[ it] to address a perceived problem [regarding] 
* * * transparency.'' \39\ TPA claims that further transparency in the 
section 311 and Hinshaw transportation and storage markets is not 
needed because the United States' natural gas commodity sales hubs are 
the most price-transparent in the world.\40\ TPA further complains that 
commenters have yet to ``cite[ ] any specific examples of adverse 
market impacts'' from the status quo, and ``no entity has asked the 
Commission to expand the Section 311 reporting requirements to increase 
transparency,'' and is therefore ``not reasoned decision making.'' \41\
---------------------------------------------------------------------------

    \37\ E.g., OneOK at 3, TPA at 3.
    \38\ Enogex at 5.
    \39\ AOG at 1.
    \40\ TPA at 11.
    \41\ TPA at 2, 4, 10.
---------------------------------------------------------------------------

    25. Several pipelines argue that the new regulations place them at 
a competitive disadvantage compared to pipelines that only operate 
under the NGA or under state jurisdiction, or compared to shippers. 
Similarly, several pipelines complain that the current proposal could 
be too burdensome,\42\ potentially causing some pipelines to abandon 
the Section 311 or Hinshaw markets.\43\
---------------------------------------------------------------------------

    \42\ E.g., AGA at 7; AOG at 7; Jefferson at 2, 6.
    \43\ E.g., Enogex at 8; TPA at 14.
---------------------------------------------------------------------------

    26. Enogex and Enstor contend that the proposed reporting 
requirements would harm NGPA section 311 storage providers with market-
based rates. Enogex argues that letting competitors see its rate 
information would limit its own ability to ``capture rates'', calling 
it ``tantamount to rescinding market-based rate authority.'' \44\ 
Enogex asserts the Commission should at least exempt storage services 
provided at market-based rates.
---------------------------------------------------------------------------

    \44\ Enogex at 8.
---------------------------------------------------------------------------

    Enogex argues that sufficient public information already exists on 
storage services, and that the Commission has stated when it authorizes 
market-based rates that such providers lack market power, thus reducing 
the need for regulatory scrutiny.\45\ Enstor is also concerned that the 
proposed reporting requirements, particularly the requirement to report 
quarterly revenues received from each storage customer, would allow 
customers ``to recreate the storage positions'' that resulted in 
another customer receiving favorable rates.\46\ Shippers, Enstor 
argues, should not have more information about the pipeline than the 
pipeline has about its shippers.
---------------------------------------------------------------------------

    \45\ Enogex at 11-12.
    \46\ Enstor at 7.
---------------------------------------------------------------------------

    27. Atmos goes further, warning ``of potential collusion or other 
anticompetitive behaviors that can be facilitated by untimely public 
disclosure of transaction-specific information.'' \47\
---------------------------------------------------------------------------

    \47\ Atmos at 5 (citing Transparency Provisions of Section 23 of 
the Natural Gas Act, Order No. 704, FERC Stats. & Regs. ] 31,260 at 
P. 88 (2007); order on reh'g, Transparency Provisions of Section 23 
of the Natural Gas Act, Order No. 704-A, FERC Stats. & Regs. ] 
31,275 (2008); order on reh'g, Transparency Provisions of Section 23 
of the Natural Gas Act, Order No. 704-B, 125 FERC ] 61,302 (2008)).
---------------------------------------------------------------------------

    28. Other commenters, however, applaud the NOPR, arguing that the 
information sought in the reports would help enable the market to 
function more efficiently. Cities, Clayton Williams, and Texas Alliance 
ask the Commission to expand reporting requirements in order to provide 
greater transparency, especially in the Texas market.\48\ Cities and 
others contend that this ``lack of competition in the intrastate 
pipeline market in Texas'' could be ameliorated by ``making information 
and records available both to the public and to shippers.'' \49\ For 
example, Clayton Williams provides a detailed narrative suggesting that 
it could have pursued allegations that a pipeline has been engaging in 
unlawful business practices, if only it had more publicly available 
information to support its allegation.\50\
---------------------------------------------------------------------------

    \48\ Cities at 3; Clayton Williams at 1; Texas Alliance at 8.
    \49\ Cities at 2, 4.
    \50\ Clayton Williams at 5-15.
---------------------------------------------------------------------------

    29. These commenters further argue that lack of transparency harms 
the integrity of national price indices,\51\ and that the Commission's 
proposed new regulations will help state-level transparency, and thus 
state-level markets, as well.\52\ Apache also responds to TPA's 
argument that interstate pipelines have not sought out the proposed 
regulation: ``It can be expected that most interstate pipelines would 
hope to levelize the playing field by eliminating regulation for all 
pipelines, rather than increasing regulation for all.'' \53\ However, 
Apache urges, new regulations are warranted based on the expected 
usefulness of improved access to market information.
---------------------------------------------------------------------------

    \51\ Texas Alliance at 4.
    \52\ Cities at 4; Texas Alliance at 6.
    \53\ Apache at 8.
---------------------------------------------------------------------------

    30. These commenters also argue that publicly available data is 
vital to eliminate unfair advantages.\54\ For example, Apache argues 
that intrastate and interstate pipelines both face the same economic 
environment and therefore should report the same information.\55\ 
Constellation argues that existing regulations harm the market by 
leaving shippers without enough information to ``make fully informed 
purchasing decisions.'' \56\ Texas Alliance and Clayton Williams, 
likewise, argue that transparency helps limit the abuse of the monopoly 
power that some pipelines have over upstream shippers.\57\
---------------------------------------------------------------------------

    \54\ E.g., Yates at 6.
    \55\ Apache at 7-8.
    \56\ Constellation at 4.
    \57\ Texas Alliance at 9-10; Clayton Williams at 12.
---------------------------------------------------------------------------

    31. Commenters also dismiss the notion that the current proposal 
could be too burdensome.\58\ Apache argues, ``[a] Section 311 pipeline 
is not going to forego the opportunity to earn money merely because it 
must comply with a transactional posting requirement.'' \59\ As Texas 
Alliance phrases it, the reason why the rulemaking ``is so strongly 
opposed by the Texas intrastate pipelines and their association [is 
that i]t threatens to let sunshine in where they prefer the dark.'' 
\60\
---------------------------------------------------------------------------

    \58\ E.g., Yates at 7.
    \59\ Apache at 8.
    \60\ Texas Alliance at 3.
---------------------------------------------------------------------------

C. Commission Determination

    32. In this Final Rule, the Commission is adopting the proposed 
quarterly transactional reporting requirements for section 311 and 
Hinshaw pipelines, with several clarifications discussed in subsequent 
sections of this rule. The Commission finds that these transactional 
reporting requirements appropriately balance the need for increased 
transparency of intrastate and Hinshaw pipeline transactions, while

[[Page 29409]]

avoiding unduly burdensome requirements that might discourage such 
pipelines from participating in the interstate market.
    33. Transactional information provides price transparency so 
shippers can make informed purchasing decisions, and also permits both 
shippers and the Commission to monitor actual transactions for evidence 
of possible abuse of market power or undue discrimination. The existing 
reporting requirements in Sec.  284.126 are inadequate for this 
purpose. For example, the annual reports of transportation transactions 
required by existing Sec.  284.126(b) do not include (1) the rates 
charged by the pipeline under each contract, (2) the receipt and 
delivery points and zones or segments covered by each contract, (3) the 
quantity of natural gas the shipper is entitled to transport, store, or 
deliver, (4) the duration of the contract, or (5) whether there is an 
affiliate relationship between the pipeline and the shipper. Similarly, 
the semi-annual storage reports required by existing Sec.  284.126(c) 
do not include the rates charged by the storage provider in each 
contract, the duration of each contract, or whether there is an 
affiliate relationship between the storage provider and its customer.
    34. However, all this information is necessary to allow the 
Commission, shippers, and others to determine the extent to which 
particular transactions are comparable to one another for purposes of 
monitoring for undue discrimination. For example, contracts for service 
on different parts of a pipeline system or with different durations may 
not be comparable to one another. In addition, the requirement that 
affiliate relationships between the pipeline and its shippers be 
reported will allow the Commission and interested parties to monitor 
whether the pipeline is favoring its affiliates. The additional 
information required to be reported by the Final Rule is also necessary 
to allow shippers to make informed decisions about their capacity 
purchases. Shippers need to know the price paid for capacity over a 
particular path to enable them to decide, for instance, how much to 
offer for the specific capacity they seek.
    35. The Commission also finds that the lack of transparency 
ultimately harms not only shippers, but the pipelines themselves, whose 
individual actions to protect market advantage work collectively to 
make intrastate transportation less attractive. Without transparency 
and trust, efficient free-market allocation of resources is not 
possible. As the specific example reported by Clayton Williams shows, 
the current market's lack of transparency fosters, at the very least, 
an atmosphere of mistrust. While TPA may plausibly assert that natural 
gas commodity sales hubs are the most price-transparent commodity 
markets in the world, the same cannot be said of the market for 
intrastate transportation. It is the Commission's obligation to ensure 
transparency at all stages of the natural gas market over which it has 
jurisdiction, because inefficiencies and unfair treatment in one stage 
of the market can lead to harm elsewhere in the market. Accordingly, we 
find that there is a need for revised regulations that improve market 
transparency.
    36. Exempting storage services provided at market-based rates is 
also unwarranted. A Commission finding that a service provider lacks 
market power should not be read to mean that its shippers are at no 
risk of undue discrimination or other unlawful practices. Furthermore, 
it is still in the public interest to disseminate market information 
concerning the transactions of market-based storage services. As the 
Commission reasoned in a previous rulemaking, ``[i]t is even more 
critical for the Commission to review pricing when the Commission is 
relying on competition to regulate rates, rather than scrutinizing the 
underlying cost of service. Thus, we will not exempt intrastate storage 
companies charging market-based rates from the requirement to file * * 
* reports.'' \61\ Posting rates charged in previous market-based 
transactions leads to greater transparency and competition. As the 
Commission found, in Order No. 637-A, with respect to alleged 
competitive harm to individual firms:
---------------------------------------------------------------------------

    \61\ Revisions to Uniform System of Accounts, Forms, Statements, 
and Reporting Requirements for Natural Gas Companies, Order No. 581, 
60 FR 53019, 53051, FERC Stats. & Regs. ] 31,026 (1995), order on 
reh'g, Order No. 581-A, FERC Stats. & Regs. ] 31,032 (1996) (Order 
No. 581).

    While disclosure of the transactional information may cause some 
commercial disadvantage to individual entities, it will benefit the 
market as a whole, by improving efficiency and competition. Buyers 
of services need good information in order to make good choices 
among competing capacity offerings. Without the provision of such 
---------------------------------------------------------------------------
information, competition suffers.\62\

    \62\ Order No. 637-A, at 31,614-615. Enstor is concerned that 
the requirement to include the revenues received from each 
interruptible storage customer during a quarter will cause 
competitive damage, alleging that such information will allow 
customers to recreate the storage positions that resulted in another 
customer receiving favorable rates. However, the existing semi-
annual storage reports required by Sec.  284.126(c) already require 
the reporting of revenues received from each customer. Increasing 
the frequency of such revenue reports from semi-annually to 
quarterly would not appear to significantly affect this concern.
---------------------------------------------------------------------------

    37. Further, we are convinced the burdens to respondents will be 
small relative to the gains that the new regulations will bring to the 
market. The burden test goes to the heart of our regulatory authority: 
One purpose of the NGPA was to induce intrastate pipelines to 
participate in the interstate market by ensuring that it would not be 
unduly burdensome to do so.\63\ As discussed in more detail below, we 
are minimizing the burden of these new transactional reporting 
requirements in several ways. For example, we are not imposing a daily 
posting requirement, such as we have required of interstate pipelines. 
Therefore, the transactional reports required by the Final Rule will 
not require section 311 and Hinshaw pipelines to maintain internet Web 
sites. We are also clarifying several of the specific proposed 
reporting requirements as requested by commenters in a manner that 
should reduce the burden of compliance. Finally, while the reports must 
be filed in a standardized electronic format, the Commission will 
develop an electronic form in a PDF format that can be downloaded from 
the FERC Web site and saved to a user's computer desktop. In addition, 
the Commission will develop an XML Schema that can be used by 
Respondents who wish to file an XML file.
---------------------------------------------------------------------------

    \63\ Associated Gas Distributors v. FERC, 824 F.2d 981, 1001-
1003 (D.C. Cir. 1987).
---------------------------------------------------------------------------

    38. In addition, since the establishment of the first intrastate 
pipeline reporting requirements, electronic communications have reduced 
the cost of reporting transactional information. Given these advances 
in data management, collecting and compiling information for the 
proposed quarterly reports should be no more burdensome at present than 
it was to manage the lesser amount of information required when the 
Commission first established transactional reporting for intrastate 
pipelines.
    39. We consider the question of undue burden not only in isolation, 
but in the context of a pipeline's entire jurisdictional business, and 
relative to the benefits to the market.\64\ The new

[[Page 29410]]

requirements aim to empower shippers ``to determine the extent to which 
particular transactions are comparable to one another.'' \65\ In this 
way, the Commission gives shippers increased ability to protect 
themselves from undue discrimination, and thus be less dependent on 
Commission investigations to protect their rights. The new reporting 
requirements also provide information that may assist state and local 
regulatory bodies, without interfering in their autonomy of action.
---------------------------------------------------------------------------

    \64\ See, e.g., Transparency Provisions of Section 23 of the 
Natural Gas Act, Order No. 704-A, FERC Stats. & Regs. ] 31,275 at P 
17 (2008) (``While we acknowledge that removing purchases from 
volumes that must be reported on Form No. 552 would somewhat reduce 
the reporting burden on certain market participants, we continue to 
believe that the substantial benefits of having such data publicly 
available outweigh this burden.''), order on reh'g, Order No. 704-B, 
125 FERC ] 61,302 (2008). See also Pipeline Posting Requirements 
under Section 23 of the Natural Gas Act, Order No. 720, 73 FR 73494, 
FERC Stats. & Regs. 31,283, at P 56 (2008) (``We also believe that 
the goals of this Final Rule outweigh the burdens to be placed upon 
non-interstate and interstate pipelines.''); order on reh'g, Order 
No. 720-A, FERC Stats. & Regs. ] 35,302, at P 116 (2010) (``The 
Commission understands commenters' arguments that posting new points 
on a rolling basis would be burdensome for major non-interstate 
pipelines, but believes that these burdens are overstated and 
substantially outweighed by the transparency benefit of timely 
posting of newly eligible points.'').
    \65\ NOPR at 19.
---------------------------------------------------------------------------

    40. In response to the pipelines that suggest that they have an 
overriding confidentiality interest, or that even raise the specter 
that increased transparency may cause unlawful behavior, we disagree. 
The Commission's decades of experience in enforcement have confirmed 
the wisdom of what jurists have long held in the related realm of 
financial disclosure: ``confidentiality interest is not absolute, 
however, and can be overcome by a sufficiently weighty government 
purpose. * * * `Sunlight is said to be the best of disinfectants; 
electric light the most efficient policeman.' '' \66\
---------------------------------------------------------------------------

    \66\ Statharos v. New York City Taxi & Limousine Comm'n, 198 
F.3d 317, 323 (2d Cir. N.Y. 1999) (citing Louis Brandeis, Other 
People's Money and How the Bankers Use It 62 (1914)).
---------------------------------------------------------------------------

V. Details of Pipeline Posting Requirements

A. Overview and Summary of Requirements

    41. The Final Rule, in accordance with the NOPR, requires Form No. 
549D transactional reports under Sec.  284.126(b) to be filed on a 
quarterly basis, to include certain additional types of information and 
cover storage as well as transportation, and to be filed in a uniform 
electronic format and posted on the Commission's Web site without 
redaction.
    42. In addition, the Final Rule clarifies or amends the NOPR on 
several points elaborated below. We clarify that pipelines are to file 
their Form No. 549D transactional reports on a contract-by-contract 
basis for each shipper, rather than on a transaction-by-transaction 
basis. We adopt a common identification requirement for shippers. For 
receipt and delivery points, however, pipelines need only use an 
industry common code where one is already in use, and may report wells 
and other gathering systems in the aggregate. We clarify that pipelines 
should continue to only report on their jurisdictional activities. 
Finally, we provide several clarifications regarding the data format 
and technical protocols, with the result being a flexible framework 
similar to the ``simple spreadsheet'' concept proposed by some 
commenters.

B. Definition of Reportable Service

1. NOPR
    43. The version of Sec.  284.126(b)(1) proposed in the NOPR calls 
for a quarterly report that contains information on ``each 
transportation and storage service provided.'' Neither the proposed 
regulations nor the preamble to the NOPR directly defined the word 
``service.'' In the preamble, in the context of rejecting daily 
posting, the Commission rejected the option of ``daily postings of 
information about individual transactions.'' \67\ However, the preamble 
also states that pipelines should report ``additional information 
concerning each transaction.'' \68\
---------------------------------------------------------------------------

    \67\ NOPR at 25.
    \68\ NOPR at 20.
---------------------------------------------------------------------------

2. Comments
    44. Some commenters express concern that the NOPR's phrasing is 
unclear as to whether pipelines are to make their reports on a 
contract-by-contract basis or a transaction-by-transaction basis.\69\ 
They point out that a shipper may schedule numerous transactions during 
a quarter under a single contract. For example, a shipper may have a 
single interruptible contract, but may schedule separate transactions 
at different rates using different receipt and delivery points on a 
daily basis. AGA, for example, ``urges the Commission to clarify that 
Hinshaw pipelines are required to report their `contracts' on a 
quarterly basis in a manner similar to what they currently report 
[rather than r]equiring information to be reported separately for each 
individual `transaction.' '' \70\ Other commenters are concerned that 
the Commission intends to require separate reports for each 
transaction. TPA, for example, complains that under ``the onerous 
approach * * * proposed in the NOPR,'' a pipeline with ``multiple daily 
transactions under single contracts could [be] * * * reporting 
thousands of individual transportation transactions.'' \71\
---------------------------------------------------------------------------

    \69\ E.g., Jefferson at 11.
    \70\ AGA at 2; see also AGA at 9-10.
    \71\ TPA at 4-5.
---------------------------------------------------------------------------

    45. Apache and Jefferson take the opportunity to propose 
alternative approaches to the question of what should be reported. 
Apache argues that ``[f]ull transparency regarding all natural gas 
transactions on a real-time basis, comparable to the reporting 
requirements of interstate pipelines, is the only comprehensive way to 
protect natural gas consumers to ensure the integrity of the market.'' 
\72\ Nevertheless, Apache clarifies that it supports the NOPR as ``a 
helpful improvement over the status quo.'' \73\ Jefferson argues that 
the level of detail proposed in the NOPR for the reports is too 
burdensome and too far beyond what is required to address the actual 
disparities between interstate and intrastate reporting.\74\ 
Accordingly, Jefferson proposes limiting the report to 22 fields.\75\
---------------------------------------------------------------------------

    \72\ Apache at 3.
    \73\ Apache at 3.
    \74\ Jefferson at 16.
    \75\ Jefferson at 15-16.
---------------------------------------------------------------------------

3. Commission Determination
    46. We clarify that pipelines are to report the required 
transactional information in Form No. 549D on a contract-by-contract 
basis for each shipper, rather than on a transaction-by-transaction 
basis. In general, a pipeline will be required to make a separate data 
entry for each of a shipper's contracts under a given rate schedule. 
The pipeline should aggregate all nominations and shipments under each 
contract for the quarter. In other words, while the reports will 
contain information on each transaction, that information will be 
aggregated by contract for each shipper for each type of service 
provided.
    47. If the pipeline charges a shipper multiple prices for different 
transactions or shipments under a single contract and service, the 
pipeline would still file a single report for that contract, with the 
following information. The pipeline would report the volume-weighted 
average rate charged under that contract for the quarter. The pipeline 
would also include a list of all the various rates charged during the 
quarter in the appropriate comment field for that contract. The 
pipeline would not be required to state the volumes associated with 
each rate or the dates each rate was charged. Similarly, the pipeline 
would list the receipt and delivery points used during each quarter for 
each contract, but is not required to separately report

[[Page 29411]]

the rates charged and volumes received and delivered at each point.
    48. We decline the opportunity to radically alter the type of 
information reported, as suggested by Apache and Jefferson. Based on 
the comments in this docket, the Commission believes that refinements 
to the NOPR are more certain to ensure a fair balance of the additional 
transparency benefits that would accrue to the market versus the 
administrative costs of compliance.

C. Reporting Frequency

1. NOPR
    49. In the NOPR, the Commission found that increasing the frequency 
of the Sec.  284.126(b) transactional reports from annual to quarterly 
would provide market participants and the Commission with more timely 
and more useful information concerning the transactions entered into by 
intrastate pipelines. The Commission stated that it sought to balance 
the benefits of increased transactional transparency against the need 
to avoid creating undue burden for the responding pipelines. The 
Commission highlighted that ``one primary difference will remain 
between the reporting requirements for interstate pipelines and the 
Section 311 and Hinshaw pipelines: Interstate Pipelines will post 
transactional information daily on their Web sites, while Section 311 
and Hinshaw pipelines will submit this information in a quarterly 
report to the Commission.'' \76\ The Commission noted alternative 
proposals from commenters, but found that a quarterly filing 
requirement would strike the appropriate balance.
---------------------------------------------------------------------------

    \76\ NOPR at P 23.
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2. Comments
    50. Most commenters support quarterly reporting. Even some parties 
who urge the Commission to cancel the rulemaking docket nevertheless 
state that they could accept limited quarterly reporting.\77\ Some 
shippers, while generally supportive of the NOPR, state that they would 
prefer daily reporting is the best way to ensure transparency and 
competitive markets.\78\ The pipelines, however, consider the 
possibility of daily reporting to be ``very costly, particularly if 
daily posting on a Web site was required,'' \79\ due ``to the [sheer] 
volume of reporting'' of each day's transactions.\80\
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    \77\ TPA at 6; Atmos at 5.
    \78\ Apache at 2-3; Constellation at 4; Yates at 5-6.
    \79\ Duke at 5.
    \80\ TPA at 20.
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3. Commission Determination
    51. The Final Rule adopts the NOPR's proposal to require quarterly 
reporting by section 311 and Hinshaw pipelines. The Commission 
continues to find that a quarterly reporting requirement strikes the 
appropriate balance of increasing transparency without imposing undue 
burdens on section 311 and Hinshaw pipelines. One purpose of the NGPA 
was to induce intrastate pipelines to participate in the interstate 
market by ensuring that it would not be unduly burdensome to do so.\81\ 
This participation by intrastate pipelines eliminates the need for 
duplication of facilities between interstate and intrastate 
pipelines.\82\ Thus, as the court has stated, ``Congress intended that 
intrastate pipelines should be able to compete in the transportation 
market without bearing the burden of full regulation by FERC under the 
Natural Gas Act.'' \83\
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    \81\ AGD, 824 F.2d at 1001-1003.
    \82\ EPGT Texas Pipeline, L.P., 99 FERC ] 61,295 at 62,252.
    \83\ Mustang Energy Corp. v. Federal Energy Regulatory Comm'n, 
859 F.2d 1447, 1457 (10th Cir. 1988), cert. denied, 490 U.S. 1019 
(1988); see also EPGT Texas Pipeline, 99 FERC ] 61,295 (2002).
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    52. In the NOPR, the Commission stated that a daily reporting 
requirement would require all intrastate and Hinshaw pipelines to 
maintain their own Web sites for this purpose, and such daily postings 
of information about individual transactions would be significantly 
more burdensome than a quarterly reporting requirement. As described 
above, several pipeline commenters have reaffirmed that a daily posting 
requirement would be very costly. In addition, Constellation, while 
stating that daily posting would provide more transparency, agrees that 
at this time such a requirement appears unduly burdensome.\84\
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    \84\ Constellation at 4.
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    53. Only two commenters request that the Commission require daily 
reporting. They contend that real-time reporting of individual 
transaction data would allow more immediate monitoring of whether the 
pipeline is engaging in undue discrimination and provide more useful 
price transparency. The Commission recognizes that daily posting could 
enable shippers and others to observe potentially discriminatory 
actions more quickly. However, the quarterly reports will provide 
similar information, enabling shippers and others to file complaints if 
they believe such information suggests a pattern of discrimination by 
the pipeline. Given the interest in avoiding placing undue burdens on 
section 311 and Hinshaw pipelines, the Commission finds that the 
quarterly reporting requirement, together with our other changes to the 
reporting requirements including the requirement that all reports be 
public, appropriately balances the need for more transparency with the 
interest in encouraging section 311 and Hinshaw pipelines to 
participate in the interstate pipeline grid.

D. Identification of Receipt and Delivery Points and Shippers

1. NOPR
    54. The NOPR proposed requiring intrastate pipelines to report 
several new elements of information, among them the primary receipt and 
delivery points covered by the contract. The NOPR proposed that the 
reports include the ``industry common code'' for each receipt and 
delivery point in order to minimize any ambiguity as to what receipt 
and delivery points are being reported and to ensure that all reporting 
pipelines identify such points in a consistent manner.\85\ Similarly, 
the NOPR proposed that, when reporting the identity of a given shipper, 
respondents should include not only the full legal name, but also an 
``identification number'' for each shipper.\86\
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    \85\ NOPR at P 33.
    \86\ NOPR at P 33.
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    55. However, the NOPR stated that, while the Commission was aware 
of some shipper identification standards and receipt and delivery point 
codes that are used in the natural gas industry (for example, Dun & 
Bradstreet, Inc.'s D-U-N-S identification numbers for shippers), the 
Commission was reluctant to choose any particular standard without 
input as to that standard's cost-effectiveness and usefulness. 
Accordingly, the Commission sought comment on two related questions: 
(1) What sort of shipper identification numbers and receipt and 
delivery point common industry codes are currently used or readily 
available to section 311 and Hinshaw pipelines?; and (2) Which shipper 
identification standard or standards and receipt and delivery point 
codes, if any, should be used?\87\
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    \87\ NOPR at P 34.
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2. Comments
    56. Some commenters argue that using industry common codes to 
report receipt and delivery points would be highly burdensome, due to 
the cost of obtaining common code identifiers from a third-party 
registry. According to Jefferson, the annual charge for licensing 
common location codes is

[[Page 29412]]

$1,670 for 1-20 points, $3,506 for 21-100 points, and $5,428 for 100+ 
points.\88\ Enogex protests that it ``does not have `primary' and 
`secondary' points on its system, but rather uses standard receipt and 
delivery points. As a result, Enogex does not have * * * common 
codes,'' and urges that the Commission reject this element as ``base[d] 
* * * on the business practices of interstate pipelines.'' \89\ TPA 
voices similar concerns. Jefferson and ONEOK suggest letting 
respondents use their own meter codes instead. AGA suggests, as a 
compromise, that pipelines that do not already use common codes should 
be allowed ``to use an interstate pipeline's Data Reference Number 
(DRN) for points of interconnection with an interstate pipeline and use 
[their own] proprietary code where a DRN has not already been 
assigned.'' \90\
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