Summaries of the agenda items for the Federal Energy Regulatory Commission’s monthly open meeting to be held on September 10, 2026, pursuant to the sunshine notice released on September 3, 2026.
Electric
E-1 – North American Electric Reliability Corporation (Docket No. RD26-9-000). On July 16, 2026, the North American Electric Reliability Corporation (NERC) filed a petition for approval of proposed Reliability Standard CIP-014-4. In the petition, NERC stated that the proposed physical security standard would identify and protect transmission stations, transmission substations, and their associated primary control centers that could result in instability, uncontrolled separation, or cascading within an interconnection if rendered inoperable or damaged due to a physical attack. To address inconsistent practices identified in an April 2023 evaluation report, NERC noted that CIP-014-4 would align the risk assessment cycle, requiring transmission owners to identify applicable facilities existing or planned to be in service within a 36-month timeframe. NERC stated that the revisions include a new provision mandating the identification of proximate existing Bulk Electric System transmission stations and substations within 1,500 feet or 457 meters measured from substation fence line to substation fence line to evaluate the impact of a physical attack on adjacent equipment. The standard would require a documented risk assessment methodology, specifying the performance of both steady-state and dynamic simulations using at least one system peak load case and one system off-peak load case. NERC requested a 24-month implementation plan to allow adequate time for transmission owners and operators to determine applicability, perform risk assessments, and procure unaffiliated third parties for verification. Agenda item E-1 may be an order regarding the petition for approval of Reliability Standard CIP-014-4.
E-2 – ISO New England Inc. (Docket No. EL26-45-000). On March 10, 2026, the Commission issued an order establishing a show cause proceeding against ISO New England Inc. (ISO-NE), pursuant to section 206 of the Federal Power Act (FPA). In the show cause order, the Commission stated that the ISO-NE Transmission, Markets and Services Tariff (Tariff) may be unjust and unreasonable due to a lack of provisions enabling the correction of improper or erroneous payments or charges. The Commission directed ISO-NE to either prove why the Tariff remains just and reasonable without a mechanism to adjust erroneous Capacity Performance Payment charges prior to final settlement and refund erroneously received payments, or explain how it will revise the rules to remedy the identified concerns. On May 8, 2026, ISO-NE submitted an answer, proposing two narrow changes to the ISO New England Billing Policy to add a mechanism to accept and allocate improper payments back to the Capacity Load Obligation cost allocator and to expand the Requested Billing Adjustment process by removing language that limits corrections solely to ISO-NE errors. ISO-NE stated that the market settlement rules must retain the prohibition on correcting errors that impact unit commitment or real-time dispatch, noting the inability to determine counterfactual operations or fund hypothetical settlements to reverse charges like the $68,000 Capacity Performance Payment at issue in a prior waiver proceeding. On June 8, 2026, Massachusetts Municipal Wholesale Electric Company, Connecticut Municipal Electric Energy Cooperative, and Vermont Public Power Supply Authority filed comments, expressing support for revisions allowing the acceptance and distribution of erroneously received funds but reserving comment on specific language due to concerns regarding the level of discretion ISO-NE might retain in allocating the refunds. Agenda item E-2 may be an order regarding the proposed Tariff provisions.
E-3 – Tri-State Generation and Transmission Association, Inc. (Docket No. ER20-681-016). On March 19, 2026, Tri-State Generation and Transmission Association, Inc. (Tri-State) filed a notice of change in status, reflecting its impending participation in the Southwest Power Pool, Inc. (SPP) expansion into the Western Interconnection (SPP RTO West) effectuated on April 1, 2026. Tri-State submitted a horizontal market power analysis to ensure ongoing authorization for market-based rate (MBR) sales, given SPP RTO West's operation as a new balancing authority area within a single, expanded market. Tri-State stated that it passed the indicative pivotal supplier screen for the December 1, 2021 through November 30, 2022 study period, noting that its 2,079 MW of uncommitted capacity is less than the 55,508 MW of net uncommitted supply in the expanded SPP market, which continued to support the rebuttable presumption that it lacks market power in energy and ancillary services. Tri-State requested an effective date of April 1, 2026 for limited revisions to its MBR tariff to authorize transactions in the integrated marketplace. On April 15, 2026, Tri-State submitted a supplement, stating that the SPP RTO West expansion went live on April 1, 2026, which superseded a prior change in status filing for the Western Area Power Administration - Colorado-Missouri balancing authority area and rendered the associated rates no longer subject to refund. Agenda item E-3 may be an order regarding the notice of change in status.
E-4 – Grays Harbor Energy LLC, Hardee Power Partners Limited, Invenergy Cannon Falls LLC, Invenergy Nelson LLC, Invenergy Nelson Expansion LLC, Lackawanna Energy Center LLC, Spindle Hill Energy LLC and Gray Wolf Power, LLC (Docket No. EC26-76-000). On March 24, 2026, Grays Harbor Energy LLC, Hardee Power Partners Limited, Invenergy Cannon Falls LLC, Invenergy Nelson LLC, Invenergy Nelson Expansion LLC, Lackawanna Energy Center LLC, Spindle Hill Energy LLC, and Gray Wolf Power, LLC (collectively, the Applicants) submitted a joint application, pursuant to section 203(a)(1) of the FPA. In the filing, the Applicants requested authorization for the disposition of jurisdictional facilities resulting from a proposed transaction whereby Gray Wolf Power, LLC will acquire 50 percent of the interests in Invenergy AMPCI Thermal Power LLC from InfraBridge North America Thermal Power Acquisition LLC. On May 26, 2026, the Independent Market Monitor for PJM (IMM) submitted comments, noting that the transaction would increase the generation owned by ArcLight Capital Partners, LLC to 11,822 MW in PJM Interconnection, L.L.C. (PJM) and proposing behavioral commitments to prevent the removal of existing capacity to serve data center loads and to mitigate the exercise of market power in the Chesapeake submarket. On June 10, 2026, the Applicants filed an answer, stating that the IMM improperly relied on pivotal supplier tests instead of the codified delivered price test and that PJM market rules already prohibit the hypothesized conduct regarding resources on both sides of a constraint. On June 22, 2026, the IMM submitted an answer, stating that the transaction is inextricably intertwined with related acquisitions involving SoftBank Group Corp. and DigitalBridge Group, Inc. and that the failure to address the cumulative increase in market power withholds material information. On July 7, 2026, the Applicants filed a reply, stating that the transactions are legally distinct and only one is conditioned on another, noting that the cumulative market power concerns are misplaced as the combined effect was analyzed conservatively in a separate proceeding. Agenda item E-4 may be an order regarding the FPA section 203 application.
E-5 – Bluestone Farm Solar, LLC (Docket No. ER20-1385-004), ENGIE 2020 ProjectCo-NH1 LLC (Docket No. ER22-210-002), ENGIE Energy Marketing NA, Inc. (Docket No. ER17-1370-010), ENGIE Portfolio Management, LLC (Docket No. ER16-581-011), ENGIE Power & Gas LLC (Docket No. ER21-2204-004), ENGIE Resources LLC (Docket No. ER16-2271-010), ENGIE Solidago Solar LLC (Docket No. ER22-1929-002), Genbright LLC (Docket No. ER21-1254-004), Hawtree Creek Farm Solar, LLC (Docket No. ER21-1498-003), MATEP LLC (Docket No. ER10-3194-009), MATEP Limited Partnership (Docket No. ER10-3195-010), Sunnybrook Farm Solar, LLC (Docket No. ER22-1927-002), Powells Creek Farm Solar, LLC (Docket No. ER22-1945-001), Salt City Solar LLC (Docket No. ER22-1928-001), Whitehorn Solar LLC (Docket No. ER20-1853-003). On June 29, 2023, Bluestone Farm Solar, LLC, ENGIE 2020 ProjectCo-NH1 LLC, ENGIE Energy Marketing NA, Inc., ENGIE Portfolio Management, LLC, ENGIE Power & Gas LLC, ENGIE Resources LLC, ENGIE Solidago Solar LLC, Genbright LLC, Hawtree Creek Farm Solar, LLC, MATEP LLC, MATEP Limited Partnership, Sunnybrook Farm Solar, LLC, Powells Creek Farm Solar, LLC, Salt City Solar LLC, and Whitehorn Solar LLC (collectively, ENGIE Northeast MBR Sellers) filed a triennial market power update for the Northeast region, pursuant to section 205 of the FPA. In the triennial, ENGIE Northeast MBR Sellers stated that they continue to satisfy the requirements for MBR authorization in all relevant markets, relying upon Commission-approved market monitoring and mitigation to address potential horizontal market power and confirming a lack of vertical market power. On August 28, 2023, the IMM for PJM submitted comments, noting that the current rules for market power mitigation are insufficient to support MBR authorizations and proposing a separate proceeding pursuant to section 206 of the FPA to investigate whether existing mitigation remains just and reasonable. On September 15, 2023, PJM filed an answer, stating that the energy market results were competitive in the first six months of 2023 and that individual compliance proceedings are not the appropriate forum for generic market reforms. On May 4, 2026, the Commission issued a letter requesting additional information regarding the updated market power analysis. On June 4, 2026, ENGIE Northeast MBR Sellers submitted a response. On June 26, 2026, the Commission issued a second deficiency letter. On July 1, 2026, ENGIE Northeast MBR Sellers submitted a response. Agenda item E-5 may be an order regarding the triennial.
E-6 – TransAlta Energy Marketing (U.S.) Inc. (Docket No. ER23-276-000). On October 28, 2022, TransAlta Energy Marketing (U.S.) Inc. (TransAlta) filed a notice and justification for spot sales above the Western Electricity Coordinating Council (WECC) soft cap. In the filing, TransAlta furnished justification for three spot transactions executed on September 1 and September 6, 2022 to sell electricity for physical delivery in the WECC energy market at prices exceeding the $1,000/MWh soft price cap. To account for the lack of completed transactions at the Mead hub on September 6 for delivery on September 7, TransAlta noted index liquidity using a combination of the September 2 day-ahead Mead peak index of $1,166.65/MWh and the Palo Verde peak index. TransAlta stated that the prices are also justified under the opportunity cost framework, noting that the alternative sales option included selling into the California Independent System Operator Corporation market, where the maximum import bid price was raised to $2,000/MWh during the extreme heat event. TransAlta stated that the Mobile-Sierra doctrine should excuse it from its cost justification obligations. On November 18, 2022, Southern California Edison Company and Pacific Gas and Electric Company filed a joint protest, stating that the index liquidity demonstration improperly averaged data over a 90-day period rather than focusing on the specific transaction dates and requesting refunds for costs exceeding the $1,000/MWh cap. Also on November 18, 2022, the California Public Utilities Commission submitted a protest, stating that TransAlta failed to provide concrete evidence of an alternative sale option under the opportunity cost framework and seeking the consolidation of all justification filings arising out of the September 2022 heat wave into a single proceeding. Agenda item E-6 may be an order regarding the justification for spot sales above the WECC soft cap.
E-7 – Mercuria Energy America, LLC (Docket No. ER23-450-000). On November 16, 2022, Mercuria Energy America, LLC (Mercuria) filed a notice and justification for a spot market index sale above the WECC soft cap. In the filing, Mercuria provided justification for one spot market index sale executed on June 16, 2021, for June 17, 2021, that settled above the $1,000/MWh soft price cap. The transaction settled at a total price of $1,440/MWh, reflecting Mercuria's sale of 100 MW (1,600 MWh) of next-day peak power for Palo Verde delivery to TransAlta Corporation at the Intercontinental Exchange (ICE) Palo Verde Physical Peak index plus $20/MWh. Mercuria noted that the Mobile-Sierra doctrine governs the transaction and requires a presumption that the rate is just and reasonable, as the sale was executed pursuant to a freely negotiated wholesale energy contract under an MBR tariff. Mercuria stated that the transaction satisfies the index-based framework, noting a total price that was lower than the weighted average price of $1,550/MWh and within the high-low range of $777/MWh to $1,983/MWh used for the ICE weighted average. Mercuria requested that the Commission accept the submission out-of-time, stating that the process of gathering relevant information began only after the Commission initiated discussions regarding the June 2021 spot sale. Agenda item E-7 may be an order regarding the justification for a spot market index sale above the WECC soft cap.
E-8 – Calpine Energy Services, L.P. (Docket No. ER23-316-000). On October 31, 2022, Calpine Energy Services, L.P. (Calpine) filed a notice and justification for spot sales above the WECC soft cap. In the filing, Calpine submitted justification for a spot transaction executed on September 6, 2022 to sell electricity for physical delivery in the WECC energy market at a fixed price exceeding the $1,000/MWh soft price cap. Calpine relied on the day-ahead peak price index for Mead, which settled at $1,400/MWh, to justify the transaction involving firm power delivery on September 7, 2022. On November 18, 2022, Southern California Edison Company filed a protest, stating that the index liquidity demonstration improperly referenced an approximate 120-day period rather than the Commission's 90-day review period, that liquidity must be evaluated at the specific time of the transaction, and requesting refunds for costs exceeding the $1,000/MWh cap. On November 21, 2022, the California Public Utilities Commission submitted a protest, stating that Calpine improperly relied on the Platts Megawatt Daily index when the Intercontinental Exchange recorded no transactions at Mead for that date, that the Mobile-Sierra doctrine does not exempt sellers from soft cap justification, and seeking the consolidation of all September 2022 soft cap proceedings. On November 28, 2022, Calpine filed an answer, stating that the Platts Megawatt Daily index reflects transactions for the same delivery location, day, and hours, and clarifying that the average daily volume traded during the 90-day review period from June 8, 2022 to September 5, 2022 was 2,566 MWh, which satisfies the 2,000 MWh liquidity threshold. Agenda item E-8 may be an order regarding the justification for spot sales above the WECC soft cap.
E-9 – Southwest Power Pool, Inc. (Docket No. ER26-1861-001). On March 18, 2026, SPP filed an unexecuted Generator Interconnection Agreement (GIA) among SPP, Silver Queen Wind Farm, LLC (Silver Queen), and Western Area Power Administration-Upper Great Plains Region, pursuant to section 205 of the FPA. SPP submitted the agreement unexecuted following a dispute by Silver Queen regarding the inclusion of nearly $25 million in network upgrades to a point of interconnection owned by Evergy Kansas Central, Inc. (Evergy). On April 8, 2026, Silver Queen filed a protest, stating that the allocation of the Evergy network upgrades based on a Midcontinent Independent System Operator, Inc. (MISO) affected system restudy violates the "but for" cost causation standard, as the 180 MW wind facility did not cause the pre-existing constraint. On April 22, 2026, SPP submitted an answer, contending that the disputed upgrades were appropriately assigned to Silver Queen pursuant to the Joint Operating Agreement between SPP and MISO, which authorizes MISO to identify and require upgrades for limiting elements on tie lines interconnecting the two transmission systems. On May 15, 2026, the Commission issued an order accepting the unexecuted GIA. On June 12, 2026, Silver Queen filed a request for rehearing, stating that the Commission failed to engage in reasoned decision-making in the May 15 order by dismissing arguments that the upgrades should have been included in SPP's Integrated Transmission Planning process and that MISO lacked authority to unilaterally assign the costs. Agenda item E-9 may be an order on the rehearing request.
E-10 – Invenergy Nelson LLC (Docket Nos. ER19-266-004, ER19-266-005), Invenergy Nelson Expansion LLC (Docket Nos. ER24-2166-003, ER24-2166-004), Lackawanna Energy Center LLC (Docket Nos. ER18-2370-006, ER18-2370-007). On March 2, 2026, Invenergy Nelson LLC (Nelson), Invenergy Nelson Expansion LLC (Nelson Expansion), and Lackawanna Energy Center LLC (Lackawanna) submitted an informational filing, regarding a proposed transaction pursuant to section 203 of the FPA where SoftBank Group Corp. will indirectly acquire a controlling interest in DigitalBridge Group, Inc. and DigitalBridge Operating Company, LLC. Nelson, Nelson Expansion, and Lackawanna stated that the underlying costs associated with providing reactive supply and voltage control from generation sources to PJM will not change following the indirect upstream ownership transfer of the facilities. To reflect the unchanged costs, Nelson, Nelson Expansion, and Lackawanna noted that no revisions to their respective reactive rate schedules are necessary for the 628 MW Nelson facility, the 397.8 MW Nelson Expansion facility, and the 1,499 MW Lackawanna facility. On March 26, 2026, Nelson, Nelson Expansion, and Lackawanna submitted a second informational filing, stating that a separate proposed transaction pursuant to section 203 of the FPA involves Grey Wolf Power, LLC acquiring 50 percent of the interests in Invenergy AMPCI Thermal Power LLC from InfraBridge North America Thermal Power Acquisition LLC. Nelson, Nelson Expansion, and Lackawanna affirmed that the underlying costs of providing reactive service to PJM will remain unchanged following this second indirect upstream change in control, preserving the existing revenue requirements for the 586 MW Nelson facility, the 314 MW Nelson Expansion facility, and the 1,362 MW Lackawanna facility. Agenda item E-10 may be an order regarding the informational filings.
Hydro
H-1 – FFP Project 101, LLC (Docket No. P-14861-003). On February 23, 2026, Columbia Riverkeeper filed a request for rehearing and motion for stay, alongside a corresponding request and motion submitted by the Confederated Tribes and Bands of the Yakama Nation (Yakama Nation), pursuant to section 313(a) of the FPA, with respect to the order issued by the Commission on January 22, 2026 granting an original license to FFP Project 101, LLC (FFP) for the Goldendale Energy Pumped Storage Hydroelectric Project. In the requests, Columbia Riverkeeper and Yakama Nation stated that the Commission irreversibly committed to the project footprint before completing mandatory obligations under the National Historic Preservation Act and the National Environmental Policy Act. Columbia Riverkeeper and Yakama Nation asserted that the Commission unlawfully relied on a Programmatic Agreement to defer the resolution of irreversible harms to a future Historic Properties Management Plan (HPMP). Yakama Nation further stated that the Commission failed to satisfy its non-delegable duty of government-to-government consultation, noting the improper implementation of ex parte rules to exclude sensitive cultural resource information from the environmental review. On March 10, 2026, FFP filed an answer, stating that Yakama Nation lacks standing to seek a stay as a non-party to the proceeding and that Columbia Riverkeeper failed to demonstrate imminent irreparable injury, noting that ground-disturbing activities remain conditioned on future Commission approval of the HPMP. Agenda item H-1 may be an order on the requests for rehearing and motions for stay.
H-2 – Northern States Power Company - Wisconsin (Docket No. P-2639-028). On November 30, 2021, Northern States Power Company - Wisconsin (NSPW) filed a final license application, pursuant to the FPA, requesting a new license to continue to operate and maintain the Cornell Hydroelectric Project on the Chippewa River in Wisconsin. NSPW proposed no changes to the current project facilities and stated that it would continue to operate the project in a peaking mode. On June 15, 2022, the National Park Service submitted comments, stating a public need for vehicular small craft tailwater access in the 30-acre section of river between the Cornell Dam and the rock rapids. On March 8, 2023, NSPW filed reply comments, stating that the proposed project operation is not the cause of the lack of access. On September 10, 2024, the Commission issued an Environmental Assessment (EA), finding that the issuance of a new license with additional staff-recommended environmental measures would not constitute a major federal action significantly affecting the quality of the human environment. On October 31, 2025, NSPW submitted a letter, providing the final water quality certification issued by the Wisconsin Department of Natural Resources pursuant to Section 401(a)(1) of the Clean Water Act following the withdrawal of a request for a contested case hearing. Agenda item H-2 may be an order on the final license application.
Certificates
C-1 – Gulf South Pipeline Company, LLC (Docket No. CP25-547-000), Texas Gas Transmission, LLC (Docket No. CP25-549-000). On September 12, 2025, Gulf South Pipeline Company, LLC (Gulf South) and Texas Gas Transmission, LLC (Texas Gas) filed an abbreviated application for a Certificate of Public Convenience and Necessity (CPCN) and abandonment authorization, pursuant to sections 7(b), 7(c), and 7(e) of the Natural Gas Act (NGA). In the abbreviated application, Gulf South and Texas Gas requested authorization to abandon by sale and acquire the 98-mile Greenville Lateral and Isola Compressor Station, construct 110.9 miles of new pipeline including the 102.9-mile, 36-inch-diameter Kosciusko Junction Pipeline and the 8.1-mile, 36-inch-diameter Columbia Gulf Lateral, and construct two new compressor stations and four new meter stations in Mississippi. Gulf South and Texas Gas stated that the Kosciusko Junction Pipeline Project will create 1.175 billion cubic feet per day of firm transportation capacity to support industrial and power generation customers by transporting new natural gas supplies to expanding delivery markets in the Southeast. On October 14, 2025, Southern Company Services, Inc. submitted a motion to intervene and comments, urging the Commission to grant the authorization. On October 16, 2025, Sierra Club filed a motion to intervene and comments opposing the proposed project. Following the Commission's issuance of environmental information requests, Gulf South and Texas Gas submitted multiple responses to provide additional project details. On April 1, 2026, the Commission issued a Draft Environmental Impact Statement (EIS). On July 24, 2026, the Commission issued a Final EIS, finding that environmental effects would be less than significant for all resources, except for climate change effects that are not characterized as significant or insignificant, with the implementation of proposed avoidance, minimization, and mitigation measures alongside recommended environmental conditions. Agenda item C-1 may be an order on the abbreviated CPCN application and abandonment authorization.
C-2 – Venture Global Gator Express, LLC (Docket No. CP26-104-000). On February 25, 2026, Venture Global Gator Express, LLC (Gator Express) filed a prior notice request for blanket certificate authorization, pursuant to the NGA, for authorization to increase the certificated capacity of its Gator Express Pipeline by 627,000 Dth/d to a total capacity of 4,567,000 Dth/d without the construction or modification of any facilities. In the request, Gator Express stated that actual pipeline operating flow and pressure conditions perform with less frictional loss than originally assumed, enabling the pipeline to support the increased flow of feed gas to the Plaquemines LNG Terminal. On March 25, 2026, the Commission issued an EA, finding that the increased capacity would not result in ground disturbance or changes in operational air or noise emissions. In the ensuing weeks and months, the Commission issued multiple data requests; Gator Express submitted respective responses to provide supplemental information. On May 4, 2026, Healthy Gulf and Louisiana Bucket Brigade filed a protest and motion to intervene, stating that the Commission should process the request as a separate application under section 7 of the NGA in order to address questions regarding improper segmentation with the Plaquemines LNG terminal uprates and expansion. Healthy Gulf and Louisiana Bucket Brigade noted that the 16 percent capacity increase and higher maximum allowable operating pressure may pose unexamined safety risks and potential increases in fugitive emissions. Agenda item C-2 may be an order on the prior notice request.
C-3 – Texas Gas Transmission, LLC (Docket No. CP26-16-000). On October 31, 2025, Texas Gas Transmission, LLC (Texas Gas) filed an abbreviated application for a CPCN, pursuant to sections 7(c) and 7(e) of the NGA, requesting authorization to install one new compressor unit and auxiliary appurtenant facilities at the existing Crosby-Harrison Compressor Station. Texas Gas stated that the project will create 170,000 Dth/d of new firm pipeline transportation capacity, which is fully subscribed by Duke Energy Ohio, Inc. On December 4, 2025, Duke Energy Ohio, Inc. filed a motion to intervene and comments, stating support for the Carnation Project. In the ensuing weeks and months, the Commission issued multiple data requests; Texas Gas submitted respective responses to provide supplemental information. On May 11, 2026, the Commission issued an EA, finding that approval of the proposed project would not constitute a major federal action significantly affecting the quality of the human environment. On June 25, 2026, Texas Gas submitted a response to the EA, requesting that the recommended environmental condition requiring a visual screening plan at the location of the regulators not be included in any authorization. Agenda item C-3 may be an order on the abbreviated CPCN application.
C-4 – UGI Auburn, LLC and UGI Auburn Gathering, LLC (Docket Nos. CP26-9-000, CP26-9-001). On October 10, 2025, UGI Auburn, LLC (UGI Auburn) and UGI Auburn Gathering, LLC (UGI Auburn Gathering) filed a joint abbreviated application for a CPCN, blanket certificates, a limited jurisdiction certificate, and a request for waivers, pursuant to section 7(c) of the NGA, seeking authorization for UGI Auburn to lease 281,970 Dth/d of capacity on a portion of UGI Auburn Gathering's non-jurisdictional system, operating a new interstate natural gas pipeline utilizing an existing 45-mile pipeline in Susquehanna, Wyoming, and Luzerne Counties, Pennsylvania. UGI Auburn and UGI Auburn Gathering stated that the leased capacity will be utilized to receive gas from Tennessee Gas Pipeline Company and deliver gas to Transcontinental Gas Pipe Line Company on an open-access basis. On October 29, 2025, the Commission issued an EA, determining a categorical exclusion regarding environmental impacts. On November 12, 2025, New Jersey Natural Gas Company submitted a motion to intervene and comments in support, stating that the project will enhance the ability to reliably meet retail customer needs by providing additional supply options in the Appalachian shale gas producing areas. On November 13, 2025, BKV Operating, LLC (BKV) filed a motion to intervene and protest, stating that the proposed lease unduly discriminates against existing gathering customers. On May 18, 2026, UGI Auburn and UGI Auburn Gathering filed an amendment to the joint abbreviated application in order to increase the leased capacity to 311,970 Dth/d to accommodate a precedent agreement with BKV, adding a primary receipt point at the existing Energy Transfer LP interconnection, and requesting a revised in-service date of July 1, 2027. On May 21, 2026, BKV submitted a withdrawal of its opposition to the application, noting that a settlement resolved the protested issues. Agenda item C-4 may be an order regarding the joint abbreviated CPCN application, blanket certificates, a limited jurisdiction certificate, and a request for waivers.
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