# TEXAS GAS TRANSMISSION, LLC — Corrective Action Order **Citation:** CPF 32026003CAO **Type / status:** enforcement / current **Agency:** Pipeline and Hazardous Materials Safety Administration **Effective:** Not stated **Published:** 2026-01-18 OPEN corrective action order. ## Document text Corrective Action Order involving TEXAS GAS TRANSMISSION, LLC. The dataset does not identify a cited regulation for this case. The case was opened on 2026-01-18 and is reported as open. Open the official case record for notices, responses, orders, and the latest status. Official case documents: 32026003CAO_Corrective Action Order (AMENDED)_02062026_(26-362613).pdf: https://primis.phmsa.dot.gov/enforcement-documents/32026003CAO/32026003CAO_Corrective%20Action%20Order%20(AMENDED)_02062026_(26-362613).pdf 32026003CAO_Corrective Action Order (AMENDED)_02062026_(26-362613)_text.pdf: https://primis.phmsa.dot.gov/enforcement-documents/32026003CAO/32026003CAO_Corrective%20Action%20Order%20(AMENDED)_02062026_(26-362613)_text.pdf 32026003CAO_Corrective Action Order (AMENDED)_02232026_(26-362613).pdf: https://primis.phmsa.dot.gov/enforcement-documents/32026003CAO/32026003CAO_Corrective%20Action%20Order%20(AMENDED)_02232026_(26-362613).pdf 32026003CAO_Corrective Action Order (AMENDED)_02232026_(26-362613)_text.pdf: https://primis.phmsa.dot.gov/enforcement-documents/32026003CAO/32026003CAO_Corrective%20Action%20Order%20(AMENDED)_02232026_(26-362613)_text.pdf 32026003CAO_Corrective Action Order_01182026_(26-362613).pdf: https://primis.phmsa.dot.gov/enforcement-documents/32026003CAO/32026003CAO_Corrective%20Action%20Order_01182026_(26-362613).pdf 32026003CAO_Corrective Action Order_01182026_(26-362613)_text.pdf: https://primis.phmsa.dot.gov/enforcement-documents/32026003CAO/32026003CAO_Corrective%20Action%20Order_01182026_(26-362613)_text.pdf 32026003CAO_Corrective Action Order (AMENDED)_02062026_(26-362613)_text.pdf U.S. Department of Transportation Pipeline and Hazardous Materials Safety Administration 1200 New Jersey Avenue, SE Washington, DC 20590 February 6, 2026 VIA ELECTRONIC MAIL TO: Scott.Hallam@bwpipelines.com Scott Hallam President and CEO Texas Gas Transmission, LLC 9 Greenway Plaza, Suite 2800 Houston, Texas 77046 Re: CPF No. 3-2026-003-CAO Dear Mr. Shindle, Enclosed please find an Amended Corrective Action Order (“ACAO” or “Order”) issued by the Pipeline and Hazardous Materials Safety Administration (PHMSA), Office of Pipeline Safety (OPS). The ACAO requires Texas Gas Transmission, LLC, to take certain corrective actions with respect to the pipeline failure that occurred on January 17, 2026, on the 20-inch diameter SHC 20- 1 pipeline near DeBerry, Texas. Service of the ACAO by electronic mail is effective upon the date of transmission and acknowledgment of receipt as provided under 49 CFR § 190.5. The terms and conditions of this Order are effective upon completion of service. Sincerely, Linda Daugherty Acting Associate Administrator for Pipeline Safety Enclosure: ACAO cc: Mr. David Barrett, Acting Director, Central Region, Office of Pipeline Safety, PHMSA Brad Shindle, VP Asset Performance, TGT, Brad.Shindle@bwpipelines.com Tina Baker, Manager, Compliance Services, TGT, Tina.Baker@bwpipelines.com CONFIRMATION OF RECEIPT REQUESTED U.S. DEPARTMENT OF TRANSPORTATION PIPELINE AND HAZARDOUS MATERIALS SAFETY ADMINISTRATION OFFICE OF PIPELINE SAFETY WASHINGTON, D.C. 20590 ____________________________________ ) In the Matter of ) ) Texas Gas Transmission, LLC, ) CPF No. 3-2026-003-CAO ) Respondent. ) ) ____________________________________) AMENDED CORRECTIVE ACTION ORDER Purpose and Background The Pipeline and Hazardous Materials Safety Administration (PHMSA), Office of Pipeline Safety (OPS), is issuing this Amended Corrective Action Order (“ACAO” or “Order”)1 pursuant to the authority provided in 49 U.S.C. § 60112. The ACAO requires Texas Gas Transmission, LLC (TGT),2 to take certain necessary corrective actions to protect the public, property, and the environment from the potential hazards associated with the continued operation of the SHC 20-1 Carthage to Sharon Compressor station pipeline. The SHC 20-1 is a 20-inch gas transmission line that originates in Carthage, Texas, and runs northeast towards the Sharon Compressor station. The line passes through portions of Panala County, Texas; Caddo Parish, Louisiana; Bossier Parrish, Louisiana; Webster Parish, Louisiana; Claiborne Parish, Louisiana; and Lincoln Parish, Louisiana. At approximately 3:04 p.m. CST on January 17, 2026, TGT’s control room personnel received SCADA alarms for a possible incident and notified field personnel. TGT subsequently confirmed that a failure occurred, resulting in the ejection of a portion of the 20-inch diameter pipe onto the pipeline right-of-way. There were no reported injuries, fatalities, or evacuations, and there was no ignition of the escaping gas. Pursuant to 49 U.S.C. § 60117, PHMSA has initiated an investigation of the failure. The preliminary findings of PHMSA’s ongoing investigation are as follows: 1 To the extent this ACAO is modified from the original CAO issued to Respondent under CPF No. 3-2026-003- CAO on January 18, 2026, this ACAO supersedes and replaces the original CAO. To the extent this ACAO is unmodified from the original CAO, this ACAO retains the full force and effect of the original CAO. All deadlines noted in the order which refer to the date “this Order is issued” or “receipt of this Order” refer to the issuance of the original CAO on January 18, 2026. 2 Texas Gas Transmission pipeline system consists of approximately 6,000 miles of natural gas transmission pipelines transporting gas from the Louisiana Gulf coast up through Arkansas, Mississippi, Tennessee, and Kentucky, to supply gas to Illinois, Indiana, and Ohio. Preliminary Findings January 17, 2026 Incident • At approximately 3:04 p.m. CST on January 17, 2025, TGT’s control room personnel received SCADA alarms for a possible incident and notified field personnel. • At 4:12 p.m. CST, field personnel confirmed that a rupture occurred on the SHC 20-1 20- inch pipeline. At 4:20 p.m., the failure location was isolated by closing Valves SHC-7 and SHC-8. At 4:50 pm, the line segment was completely blown down to zero pressure. • The failure occurred at mile post (MP) 88+3571 on TGT’s SHC 20-1 Carthage to Red River pipeline segment in Panala County, Texas. • TGT notified the National Response Center (NRC) of the failure on January 17, 2026, at approximately 4:29 pm CST (NRC Incident Report #1452961). • PHMSA launched an investigation, with investigators arriving on January 18, 2026. • The pipe at the failure location is 20-inch diameter pipe, 0.281-inch wall thickness constructed in 1949 with API 5L X46 direct current electric resistance welded (DC- ERW) longitudinal seam manufactured by Youngstown. DC-ERW pipe of this vintage is known to present certain integrity risks. • On the Carthage to Red River pipeline segment, TGT reports that there is approximately 42,572 feet of DC-ERW pipe. On the Red River to Sharon Compressor station pipe segment, TGT reports that there is approximately 26,209 feet of DC-ERW pipe. • In 2024, 2017, 2010, and 2004, TGT ran inline inspection (ILI) tools through the pipeline at the location of the failure, including magnetic flux leakage (MFL), deformation, and inertial mapping tools. • The maximum allowable operating pressure (MAOP) of the pipe at the failure site is 931 pounds per square inch gauge (psig). The operating pressure at the time of the failure was approximately 785 psig as measured at the Carthage #3 Mark West, which is approximately 2.5 miles upstream of the failure location. Amended Determination of Necessity for Corrective Action Order and Right to Hearing Section 60112 of title 49, United States Code, authorizes PHMSA to determine that a pipeline facility is or would be hazardous to life, property, or the environment and if there is a likelihood of serious harm, to expeditiously order the operator of the facility to take necessary corrective action, including suspended or restricted use of the facility, physical inspection, testing, repair, replacement, or other appropriate action. An order issued expeditiously must provide an opportunity for a hearing as soon as practicable after the order is issued. In deciding whether to issue an order, PHMSA must consider the following, if relevant: (1) the characteristics of the pipe and other equipment used in the pipeline facility, including the age, manufacture, physical properties, and method of manufacturing, constructing, or assembling the equipment; (2) the nature of the material the pipeline facility transports, the corrosive and deteriorative qualities of the material, the sequence in which the material is transported, and the pressure required for transporting the material; (3) the aspects of the area in which the pipeline facility is located, including climatic and geologic conditions and soil characteristics; (4) the proximity of the area in which the facility is located to environmentally sensitive areas; (5) the population density and population and growth patterns of the area in which the pipeline facility is located; (6) any recommendation of the National Transportation Safety Board made under another law; and (7) any other factors PHMSA may consider as appropriate. After evaluating the foregoing preliminary findings of fact, and having considered the characteristics of the pipeline, the nature of the failure; the hazardous nature of the material transported; the existing and potential additional impacts to property, the environment, and wildlife; it is hereby determined that continued operation of the Affected Segment of the TGT SHC 20-1 pipeline, as defined below, without corrective measures is or would be hazardous to life, property, or the environment, and that failure to issue this Order expeditiously would result in the likelihood of serious harm. Accordingly, this Order mandating immediate corrective action is issued expeditiously without prior notice and opportunity for a hearing. The terms and conditions of this Order are effective upon completion of service. Within 10 days of receipt of this Order, Respondent may request a hearing, to be held as soon as practicable, by notifying the Associate Administrator for Pipeline Safety in writing, with a copy to the Director, PHMSA, OPS Central Region. If a hearing is requested, it will be held in accordance with 49 CFR § 190.211. After receiving and analyzing additional data in the course of this investigation, PHMSA may identify other corrective measures that need to be taken. Respondent will be notified of any additional measures required and, if appropriate, PHMSA will consider a further amended order. To the extent consistent with safety, Respondent will be afforded notice and an opportunity for a hearing prior to the imposition of any additional corrective measures. Definitions Affected Segment – The “Affected Segment” means the 20-inch diameter SHC 20-1 20” pipeline from the start of the mainline at the Carthage facility (M.P. 96 + 2140 ft.) to the Sharon Compressor Station (MP 0.000). Isolated Segment – The “Isolated Segment” means the 20-inch diameter SHC 20-1 20” pipeline between mainline valves SHC-7 and SHC-8. Director – The “Director” means the Director, PHMSA, OPS Central Region. 1. Restart Plan. Prior to resuming operation of the Isolated Segment, TGT must develop and submit a written Restart Plan to the Director for prior approval. a. The Restart Plan must include a Repair Plan for the Director’s approval. b. The Director may approve the Restart Plan incrementally, including the Repair Plan, without approving the entire plan. c. Once approved by the Director, the Restart Plan will be incorporated by reference into this Order. d. The Restart Plan must provide for adequate patrolling and sufficient surveillance of the Isolated Segment during the restart process to ensure that no leaks are present when operation of the line resumes. e. The Restart Plan must specify a day-light restart and include advance communications with local emergency response officials. 2. Operating Pressure Restriction. TGT must reduce and maintain a twenty percent (20%) pressure reduction in the actual operating pressure along the entire length of the Affected Segment, such that the operating pressure along the Affected Segment will not exceed eighty percent (80%) of the actual operating pressure in effect immediately prior to the failure on January 17, 2026. a. This pressure restriction must remain in effect until written approval to increase the pressure or return the pipeline to its pre-failure operating pressure is obtained from the Director. b. Within 10 days of issuance of the Order, TGT must provide the Director the actual operating pressures of each compressor station and each main line pressure regulating station on the Affected Segment at the time of failure and the reduced pressure restriction set-points at these same locations. c. This pressure restriction requires any relevant remote or local alarm limits, software programming set-points or control points, and mechanical over-pressure devices to be adjusted accordingly. d. When determining the pressure restriction set-points, TGT must take into account any in-line inspection (ILI) features or anomalies present in the Affected Segment to provide for continued safe operation while further corrective actions are completed. e. TGT must review the pressure restriction monthly by analyzing the operating pressure data. TGT must take into account any ILI features or anomalies present in the Affected Segment and immediately reduce the operating pressure to maintain the safe operations of the Affected Segment, if warranted by the monthly review. TGT must submit the results of the monthly review to the Director. The results must include, at a minimum, the current discharge set-points (including any additional pressure reductions), and any pressure exceedance at discharge set-points. f. TGT may request approval from the Director to increase the operating pressure on individual segments on the Affected Pipeline based on an engineering analysis or other justification that the segment does not pose a safety risk. 3. Mechanical and Metallurgical Testing. Within 45 days of receipt of this Order, TGT must complete mechanical and metallurgical testing and failure analysis of the failed pipe, including an analysis of soil samples and any foreign materials. Complete the testing and analysis as follows: a. Document the chain-of-custody when handling and transporting the failed pipe section and other evidence from the failure site. b. Within 10 days of receipt of this Order, develop and submit the testing protocol and the proposed testing laboratory to the Director for prior approval. c. Prior to beginning the mechanical and metallurgical testing, provide the Director with the scheduled date, time, and location of the testing to allow for an OPS representative to witness the testing. d. Ensure the testing laboratory distributes all reports (whether draft or final) in their entirety to the Director at the same time they are made available to TGT. 4. Root Cause Failure Analysis. Within 90 days following receipt of this Order, TGT must complete a root cause failure analysis (RCFA) and submit a final report of this RCFA to the Director. The RCFA must be supplemented/facilitated by an independent third-party acceptable to the Director and must document the decision making process and all factors contributing to the failure. The final report must include findings, and any lessons learned and whether the findings and any lessons learned are applicable to other locations within TGT’s pipeline system. The independent third-party must distribute all RCFA reports (whether draft or final) in their entirety to the Director at the same time they are made available to TGT provide all versions of the RCFA 5. Remedial Work Plan (RWP). a. Within 120 days following receipt of this Order, TGT must submit a Remedial Work Plan (RWP) to the Director for approval. b. The Director may approve the RWP incrementally without approving the entire RWP. c. Once approved by the Director, the RWP will be incorporated by reference into this Order. d. The RWP must specify the tests, inspections, assessments, evaluations, and remedial measures TGT will use to verify the integrity of the Affected Segment. It must address all known or suspected factors and causes of the January 17, 2026 failure. TGT must consider both the risk of another failure and the consequence of another failure to develop a prioritized schedule for RWP related work along the Affected Segment. e. The RWP must include a procedure or process to: i. Identify pipe in the Affected Segment with characteristics similar to the contributing factors identified for the January 17, 2026 failure. ii. Gather all data necessary to review the failure history (in service and pressure test failures) of the Affected Segment and to prepare a written report containing all the available information such as the locations, dates, and causes of leaks and failures. iii. Integrate the results of the metallurgical testing, RCFA, and other corrective actions required by this Order with all relevant pre-existing operational and assessment data for the Affected Segment. Pre-existing operational data includes, but is not limited to, construction, operations, maintenance, testing, repairs, prior metallurgical analyses, and any third party consultation information. Pre-existing assessment data includes, but is not limited to, ILI tool runs, hydrostatic pressure testing, direct assessments, close interval surveys, and DCVG/ACVG surveys. iv. Determine if conditions similar to those contributing to the failure on January 17, 2026, are likely to exist elsewhere on the Affected Segment. v. Conduct additional field tests, inspections, assessments, and/or evaluations to determine whether, and to what extent, the conditions associated with the failure on January 17, 2026, and other failures from the failure history (see [(e)(ii)] above) or any other integrity threats are present elsewhere on the Affected Segment. At a minimum, this process must consider all failure causes and specify the use of one or more of the following: 1) ILI tools that are technically appropriate for assessing the pipeline system based on the cause of failure on January 17, 2026, and that can reliably detect and identify anomalies, 2) Hydrostatic pressure testing, 3) Close-interval surveys, 4) Cathodic protection surveys, to include interference surveys in coordination with other utilities (e.g. underground utilities, overhead power lines, etc.) in the area, 5) Coating surveys, 6) Stress corrosion cracking surveys, 7) Selective seam corrosion surveys; and, 8) Other tests, inspections, assessments, and evaluations appropriate for the failure causes. Note: TGT may use the results of previous tests, inspections, assessments, and evaluations if approved by the Director, provided the results of the tests, inspections, assessments, and evaluations are analyzed with regard to the factors known or suspected to have caused the January 17, 2026 failure. vi. Describe the inspection and repair criteria TGT will use to prioritize, excavate, evaluate, and repair anomalies, imperfections, and other identified integrity threats. Include a description of how any defects will be graded and a schedule for repairs or replacement. vii. Describe the methods TGT will use to repair, replace, or take other corrective measures to remediate the conditions associated with the pipeline failure on January 17, 2026, and to address other known integrity threats along the Affected Segment. The repair, replacement, or other corrective measures must meet the criteria specified in [1(d)(vi)] above. viii. Implement continuing long-term periodic testing and integrity verification measures to ensure the ongoing safe operation of the Affected Segment considering the results of the analyses, inspections, evaluations, and corrective measures undertaken pursuant to the Order. f. Include a proposed schedule for completion of the RWP. g. TGT must revise the RWP as necessary to incorporate new information obtained during the failure investigation and remedial activities, to incorporate the results of actions undertaken pursuant to this Order, and/or to incorporate modifications required by the Director. i. Submit any plan revisions to the Director for prior approval. ii. The Director may approve plan revisions incrementally. iii. Any and all revisions to the RWP after it has been approved and incorporated by reference into this Order will be fully described and documented in the CAO Documentation Report (CDR). h. Implement the RWP as it is approved by the Director, including any revisions to the plan. 6. CAO Documentation Report (CDR). TGT must create and revise, as necessary, a CAO Documentation Report (CDR). When TGT has concluded all the items in this Order it will submit the final CDR in its entirety to the Director. This will allow the Director to complete a thorough review of all actions taken by TGT with regards to this Order prior to approving the closure of this Order. The intent is for the CDR to summarize all activities and documentation associated with this Order in one document. a. The Director may approve the CDR incrementally without approving the entire CDR. b. Once approved by the Director, the CDR will be incorporated by reference into this Order. c. The CDR must include but not be limited to: i. Table of Contents; ii. Summary of the pipeline failure of January 17, 2026, and the response activities; iii. Summary of pipe data/properties and all prior assessments of the Affected Segment; iv. Summary of all tests, inspections, assessments, evaluations, and analysis required by the Order; v. Summary of the Mechanical and Metallurgical Testing as required by the Order; vi. Summary of the RCFA with all root causes as required by the Order; vii. Documentation of all actions taken by TGT to implement the RWP, the results of those actions, and the inspection and repair criteria used; viii. Documentation of any revisions to the RWP including those necessary to incorporate the results of actions undertaken pursuant to this Order and whenever necessary to incorporate new information obtained during the failure investigation and remedial activities; ix. Lessons learned while completing this Order; x. A path forward describing specific actions TGT will take on its entire pipeline system as a result of the lessons learned from work on this Order; and xi. Appendices (if required). Other Requirements: 7. Approvals. With respect to each submission under this Order that requires the approval of the Director, the Director may: (a) approve, in whole or part, the submission; (b) approve the submission on specified conditions; (c) modify the submission to cure any deficiencies; (d) disapprove in whole or in part, the submission, directing that Respondent modify the submission, or (e) any combination of the above. In the event of approval, approval upon conditions, or modification by the Director, Respondent shall proceed to take all action required by the submission as approved or modified by the Director. If the Director disapproves all or any portion of the submission, Respondent must correct all deficiencies within the time specified by the Director and resubmit it for approval. 8. Extensions of Time. The Director may grant an extension of time for compliance with any of the terms of this Order upon a written request timely submitted demonstrating good cause for an extension. 9. Reporting. Submit quarterly reports to the Director that: (1) include all available data and results of the testing and evaluations required by this Order; and (2) describe the progress of the repairs or other remedial actions being undertaken. The first quarterly report is due on April 30, 2026, covering the period through March 31, 2026. The Director may change the interval for the submission of these reports. 10. Documentation of the Costs. It is requested that Respondent maintain documentation of the costs associated with implementation of this CAO. Include in each monthly report submitted, the to-date total costs associated with: (1) preparation and revision of procedures, studies, and analyses; (2) physical changes to pipeline infrastructure, including repairs, replacements, and other modifications; and (3) environmental remediation, if applicable. Be advised that all material submitted in response to this enforcement action is subject to being made publicly available. If you believe that any portion of your responsive material qualifies for confidential treatment under 5 U.S.C. § 552(b), along with the complete original document you must provide a second copy of the document with the portions you believe qualify for confidential treatment redacted and an explanation of why you believe the redacted information qualifies for confidential treatment under 5 U.S.C. § 552(b). In your correspondence on this matter, please refer to “CPF No. 3-2026-003-CAO” and for each document you submit, please provide a copy in electronic format whenever possible. The actions required by this Order are in addition to and do not waive any requirements that apply to Respondent’s pipeline system under 49 CFR Parts 190 through 199, under any other order issued to Respondent under authority of 49 U.S.C. Chapter 601, or under any other provision of Federal or State law. Respondent may appeal any decision of the Director to the Associate Administrator for Pipeline Safety. Decisions of the Associate Administrator shall be final. Failure to comply with this Order may result in the assessment of civil penalties and in referral to the Attorney General for appropriate relief in United States District Court pursuant to 49 U.S.C. § 60120. The terms and conditions of this Order are effective upon service in accordance with 49 CFR § 190.5. _____________________________ __________________________ Linda Daugherty Date Issued Acting Associate Administrator for Pipeline Safety 32026003CAO_Corrective Action Order_01182026_(26-362613)_text.pdf U.S. Department of Transportation Pipeline and Hazardous Materials Safety Administration 1200 New Jersey Avenue, SE Washington, DC 20590 January 18, 2026 VIA ELECTRONIC MAIL TO: Scott.Hallam@bwpipelines.com Scott Hallam President and CEO Texas Gas Transmission, LLC 9 Greenway Plaza, Suite 2800 Houston, Texas 77046 Re: CPF No. 3-2026-003-CAO Dear Mr. Shindle, Enclosed please find a Corrective Action Order (“CAO” or “Order”) issued by the Pipeline and Hazardous Materials Safety Administration (PHMSA), Office of Pipeline Safety (OPS). The CAO requires Texas Gas Transmission, LLC, to take certain corrective actions with respect to the pipeline failure that occurred on January 17, 2026, on the 20-inch diameter SHC 20-1 pipeline near DeBerry, Texas. Service of the CAO by electronic mail is effective upon the date of transmission and acknowledgment of receipt as provided under 49 CFR § 190.5. The terms and conditions of this Order are effective upon completion of service. Sincerely, Linda Daugherty Acting Associate Administrator for Pipeline Safety Enclosure: CAO cc: Mr. David Barrett, Acting Director, Central Region, OPS, PHMSA Brad Shindle, VP Asset Performance, TGT, Brad.Shindle@bwpipelines.com Tina Baker, Manager, Compliance Services, TGT, Tina.Baker@bwpipelines.com CONFIRMATION OF RECEIPT REQUESTED U.S. DEPARTMENT OF TRANSPORTATION PIPELINE AND HAZARDOUS MATERIALS SAFETY ADMINISTRATION OFFICE OF PIPELINE SAFETY WASHINGTON, D.C. 20590 ____________________________________ ) In the Matter of ) ) Texas Gas Transmission, LLC, ) CPF No. 3-2026-003-CAO ) Respondent. ) ) ____________________________________) CORRECTIVE ACTION ORDER Purpose and Background The Pipeline and Hazardous Materials Safety Administration (PHMSA), Office of Pipeline Safety (OPS), is issuing this Corrective Action Order (“CAO” or “Order”) pursuant to the authority provided in 49 U.S.C. § 60112. The CAO requires Texas Gas Transmission, LLC (TGT),1 to take certain necessary corrective actions to protect the public, property, and the environment from the potential hazards associated with the continued operation of the SHC 20-1 Carthage to Sharon Compressor station pipeline. The SHC 20-1 is a 20-inch gas transmission line that originates in Carthage, Texas, and runs northeast towards the Sharon Compressor station. The line passes through portions of Panala County, Texas; Caddo Parish, Louisiana; Bossier Parrish, Louisiana; Webster Parish, Louisiana; Claiborne Parish, Louisiana; and Lincoln Parish, Louisiana. At approximately 3:04 p.m. CST on January 17, 2026, TGT’s control room personnel received SCADA alarms for a possible incident and notified field personnel. TGT subsequently confirmed that a failure occurred, resulting in the ejection of a portion of the 20-inch diameter pipe onto the pipeline right-of-way. There were no reported injuries, fatalities, or evacuations, and there was no ignition of the escaping gas. Pursuant to 49 U.S.C. § 60117, PHMSA has initiated an investigation of the failure. The preliminary findings of PHMSA’s ongoing investigation are as follows: 1 Texas Gas Transmission pipeline system consists of approximately 6,000 miles of natural gas transmission pipelines transporting gas from the Louisiana Gulf coast up through Arkansas, Mississippi, Tennessee, and Kentucky, to supply gas to Illinois, Indiana, and Ohio. Preliminary Findings January 17, 2026 Incident • At approximately 3:04 p.m. CST on January 17, 2025, TGT’s control room personnel received SCADA alarms for a possible incident and notified field personnel. • At 4:12 p.m. CST, field personnel confirmed that a rupture occurred on the SHC 20-1 20- inch pipeline. At 4:20 p.m., the failure location was isolated by closing Valves SHC-7 and SHC-8. At 4:50 pm, the line segment was completely blown down to zero pressure. • The failure occurred at mile post (MP) 88+3571 on TGT’s SHC 20-1 Carthage to Red River pipeline segment in Panala County, Texas. • TGT notified the National Response Center (NRC) of the failure on January 17, 2026, at approximately 4:29 pm CST (NRC Incident Report #1452961). • PHMSA launched an investigation, with investigators arriving on January 18, 2026. • The pipe at the failure location is 20-inch diameter pipe, 0.281-inch wall thickness constructed in 1949 with API 5L X46 low frequency electric resistance welded (LF- ERW) longitudinal seam manufactured by Youngstown. LF-ERW pipe of this vintage is known to present certain integrity risks. • On the Carthage to Red River pipeline segment, TGT reports that there is approximately 42,572 feet of LF-ERW pipe. On the Red River to Sharon Compressor station pipe segment, TGT reports that there is approximately 26,209 feet of LF-ERW pipe. • In 2024, 2017, 2010, and 2004, TGT ran inline inspection (ILI) tools through the pipeline at the location of the failure, including magnetic flux leakage (MFL), deformation, and inertial mapping tools. • The maximum allowable operating pressure (MAOP) of the pipe at the failure site is 931 pounds per square inch gauge (psig). The operating pressure at the time of the failure was approximately 785 psig as measured at the Carthage #3 Mark West, which is approximately 2.5 miles upstream of the failure location. Determination of Necessity for Corrective Action Order and Right to Hearing Section 60112 of title 49, United States Code, authorizes PHMSA to determine that a pipeline facility is or would be hazardous to life, property, or the environment and if there is a likelihood of serious harm, to expeditiously order the operator of the facility to take necessary corrective action, including suspended or restricted use of the facility, physical inspection, testing, repair, replacement, or other appropriate action. An order issued expeditiously must provide an opportunity for a hearing as soon as practicable after the order is issued. In deciding whether to issue an order, PHMSA must consider the following, if relevant: (1) the characteristics of the pipe and other equipment used in the pipeline facility, including the age, manufacture, physical properties, and method of manufacturing, constructing, or assembling the equipment; (2) the nature of the material the pipeline facility transports, the corrosive and deteriorative qualities of the material, the sequence in which the material is transported, and the pressure required for transporting the material; (3) the aspects of the area in which the pipeline facility is located, including climatic and geologic conditions and soil characteristics; (4) the proximity of the area in which the facility is located to environmentally sensitive areas; (5) the population density and population and growth patterns of the area in which the pipeline facility is located; (6) any recommendation of the National Transportation Safety Board made under another law; and (7) any other factors PHMSA may consider as appropriate. After evaluating the foregoing preliminary findings of fact, and having considered the characteristics of the pipeline, the nature of the failure; the hazardous nature of the material transported; the existing and potential additional impacts to property, the environment, and wildlife; it is hereby determined that continued operation of the Affected Segment of the TGT SHC 20-1 pipeline, as defined below, without corrective measures is or would be hazardous to life, property, or the environment, and that failure to issue this Order expeditiously would result in the likelihood of serious harm. Accordingly, this Order mandating immediate corrective action is issued expeditiously without prior notice and opportunity for a hearing. The terms and conditions of this Order are effective upon completion of service. Within 10 days of receipt of this Order, Respondent may request a hearing, to be held as soon as practicable, by notifying the Associate Administrator for Pipeline Safety in writing, with a copy to the Director, PHMSA, OPS Central Region. If a hearing is requested, it will be held in accordance with 49 CFR § 190.211. After receiving and analyzing additional data in the course of this investigation, PHMSA may identify other corrective measures that need to be taken. Respondent will be notified of any additional measures required and, if appropriate, PHMSA will consider a further amended order. To the extent consistent with safety, Respondent will be afforded notice and an opportunity for a hearing prior to the imposition of any additional corrective measures. Definitions Affected Segment – The “Affected Segment” means the 20-inch diameter SHC 20-1 20” pipeline from the start of the mainline at the Carthage facility (M.P. 96 + 2140 ft.) to the Sharon Compressor Station (MP 0.000). Isolated Segment – The “Isolated Segment” means the 20-inch diameter SHC 20-1 20” pipeline between mainline valves SHC-7 and SHC-8. Director – The “Director” means the Director, PHMSA, OPS Central Region. 1. Restart Plan. Prior to resuming operation of the Isolated Segment, TGT must develop and submit a written Restart Plan to the Director for prior approval. a. The Restart Plan must include a Repair Plan for the Director’s approval. b. The Director may approve the Restart Plan incrementally, including the Repair Plan, without approving the entire plan. c. Once approved by the Director, the Restart Plan will be incorporated by reference into this Order. d. The Restart Plan must provide for adequate patrolling and sufficient surveillance of the Isolated Segment during the restart process to ensure that no leaks are present when operation of the line resumes. e. The Restart Plan must specify a day-light restart and include advance communications with local emergency response officials. 2. Operating Pressure Restriction. TGT must reduce and maintain a twenty percent (20%) pressure reduction in the actual operating pressure along the entire length of the Affected Segment, such that the operating pressure along the Affected Segment will not exceed eighty percent (80%) of the actual operating pressure in effect immediately prior to the failure on January 17, 2026. a. This pressure restriction must remain in effect until written approval to increase the pressure or return the pipeline to its pre-failure operating pressure is obtained from the Director. b. Within 10 days of issuance of the Order, TGT must provide the Director the actual operating pressures of each compressor station and each main line pressure regulating station on the Affected Segment at the time of failure and the reduced pressure restriction set-points at these same locations. c. This pressure restriction requires any relevant remote or local alarm limits, software programming set-points or control points, and mechanical over-pressure devices to be adjusted accordingly. d. When determining the pressure restriction set-points, TGT must take into account any in-line inspection (ILI) features or anomalies present in the Affected Segment to provide for continued safe operation while further corrective actions are completed. e. TGT must review the pressure restriction monthly by analyzing the operating pressure data. TGT must take into account any ILI features or anomalies present in the Affected Segment and immediately reduce the operating pressure to maintain the safe operations of the Affected Segment, if warranted by the monthly review. TGT must submit the results of the monthly review to the Director. The results must include, at a minimum, the current discharge set-points (including any additional pressure reductions), and any pressure exceedance at discharge set-points. f. TGT may request approval from the Director to increase the operating pressure on individual segments on the Affected Pipeline based on an engineering analysis or other justification that the segment does not pose a safety risk. 3. Mechanical and Metallurgical Testing. Within 45 days of receipt of this Order, TGT must complete mechanical and metallurgical testing and failure analysis of the failed pipe, including an analysis of soil samples and any foreign materials. Complete the testing and analysis as follows: a. Document the chain-of-custody when handling and transporting the failed pipe section and other evidence from the failure site. b. Within 10 days of receipt of this Order, develop and submit the testing protocol and the proposed testing laboratory to the Director for prior approval. c. Prior to beginning the mechanical and metallurgical testing, provide the Director with the scheduled date, time, and location of the testing to allow for an OPS representative to witness the testing. d. Ensure the testing laboratory distributes all reports (whether draft or final) in their entirety to the Director at the same time they are made available to TGT. 4. Root Cause Failure Analysis. Within 90 days following receipt of this Order, TGT must complete a root cause failure analysis (RCFA) and submit a final report of this RCFA to the Director. The RCFA must be supplemented/facilitated by an independent third-party acceptable to the Director and must document the decision making process and all factors contributing to the failure. The final report must include findings, and any lessons learned and whether the findings and any lessons learned are applicable to other locations within TGT’s pipeline system. The independent third-party must distribute all RCFA reports (whether draft or final) in their entirety to the Director at the same time they are made available to TGT provide all versions of the RCFA 5. Remedial Work Plan (RWP). a. Within 120 days following receipt of this Order, TGT must submit a Remedial Work Plan (RWP) to the Director for approval. b. The Director may approve the RWP incrementally without approving the entire RWP. c. Once approved by the Director, the RWP will be incorporated by reference into this Order. d. The RWP must specify the tests, inspections, assessments, evaluations, and remedial measures Texas will use to verify the integrity of the Affected Segment. It must address all known or suspected factors and causes of the January 17, 2026 failure. TGT must consider both the risk of another failure and the consequence of another failure to develop a prioritized schedule for RWP related work along the Affected Segment. e. The RWP must include a procedure or process to: i. Identify pipe in the Affected Segment with characteristics similar to the contributing factors identified for the January 17, 2026 failure. ii. Gather all data necessary to review the failure history (in service and pressure test failures) of the Affected Segment and to prepare a written report containing all the available information such as the locations, dates, and causes of leaks and failures. iii. Integrate the results of the metallurgical testing, RCFA, and other corrective actions required by this Order with all relevant pre-existing operational and assessment data for the Affected Segment. Pre-existing operational data includes, but is not limited to, construction, operations, maintenance, testing, repairs, prior metallurgical analyses, and any third party consultation information. Pre-existing assessment data includes, but is not limited to, ILI tool runs, hydrostatic pressure testing, direct assessments, close interval surveys, and DCVG/ACVG surveys. iv. Determine if conditions similar to those contributing to the failure on January 17, 2026, are likely to exist elsewhere on the Affected Segment. v. Conduct additional field tests, inspections, assessments, and/or evaluations to determine whether, and to what extent, the conditions associated with the failure on January 17, 2026, and other failures from the failure history (see [(e)(ii)] above) or any other integrity threats are present elsewhere on the Affected Segment. At a minimum, this process must consider all failure causes and specify the use of one or more of the following: 1) ILI tools that are technically appropriate for assessing the pipeline system based on the cause of failure on January 17, 2026, and that can reliably detect and identify anomalies, 2) Hydrostatic pressure testing, 3) Close-interval surveys, 4) Cathodic protection surveys, to include interference surveys in coordination with other utilities (e.g. underground utilities, overhead power lines, etc.) in the area, 5) Coating surveys, 6) Stress corrosion cracking surveys, 7) Selective seam corrosion surveys; and, 8) Other tests, inspections, assessments, and evaluations appropriate for the failure causes. Note: TGT may use the results of previous tests, inspections, assessments, and evaluations if approved by the Director, provided the results of the tests, inspections, assessments, and evaluations are analyzed with regard to the factors known or suspected to have caused the January 17, 2026 failure. vi. Describe the inspection and repair criteria TGT will use to prioritize, excavate, evaluate, and repair anomalies, imperfections, and other identified integrity threats. Include a description of how any defects will be graded and a schedule for repairs or replacement. vii. Describe the methods TGT will use to repair, replace, or take other corrective measures to remediate the conditions associated with the pipeline failure on January 17, 2026, and to address other known integrity threats along the Affected Segment. The repair, replacement, or other corrective measures must meet the criteria specified in [1(d)(vi)] above. viii. Implement continuing long-term periodic testing and integrity verification measures to ensure the ongoing safe operation of the Affected Segment considering the results of the analyses, inspections, evaluations, and corrective measures undertaken pursuant to the Order. f. Include a proposed schedule for completion of the RWP. g. TGT must revise the RWP as necessary to incorporate new information obtained during the failure investigation and remedial activities, to incorporate the results of actions undertaken pursuant to this Order, and/or to incorporate modifications required by the Director. i. Submit any plan revisions to the Director for prior approval. ii. The Director may approve plan revisions incrementally. iii. Any and all revisions to the RWP after it has been approved and incorporated by reference into this Order will be fully described and documented in the CAO Documentation Report (CDR). h. Implement the RWP as it is approved by the Director, including any revisions to the plan. 6. CAO Documentation Report (CDR). TGT must create and revise, as necessary, a CAO Documentation Report (CDR). When TGT has concluded all the items in this Order it will submit the final CDR in its entirety to the Director. This will allow the Director to complete a thorough review of all actions taken by TGT with regards to this Order prior to approving the closure of this Order. The intent is for the CDR to summarize all activities and documentation associated with this Order in one document. a. The Director may approve the CDR incrementally without approving the entire CDR. b. Once approved by the Director, the CDR will be incorporated by reference into this Order. c. The CDR must include but not be limited to: i. Table of Contents; ii. Summary of the pipeline failure of January 17, 2026, and the response activities; iii. Summary of pipe data/properties and all prior assessments of the Affected Segment; iv. Summary of all tests, inspections, assessments, evaluations, and analysis required by the Order; v. Summary of the Mechanical and Metallurgical Testing as required by the Order; vi. Summary of the RCFA with all root causes as required by the Order; vii. Documentation of all actions taken by TGT to implement the RWP, the results of those actions, and the inspection and repair criteria used; viii. Documentation of any revisions to the RWP including those necessary to incorporate the results of actions undertaken pursuant to this Order and whenever necessary to incorporate new information obtained during the failure investigation and remedial activities; ix. Lessons learned while completing this Order; x. A path forward describing specific actions TGT will take on its entire pipeline system as a result of the lessons learned from work on this Order; and xi. Appendices (if required). Other Requirements: 7. Approvals. With respect to each submission under this Order that requires the approval of the Director, the Director may: (a) approve, in whole or part, the submission; (b) approve the submission on specified conditions; (c) modify the submission to cure any deficiencies; (d) disapprove in whole or in part, the submission, directing that Respondent modify the submission, or (e) any combination of the above. In the event of approval, approval upon conditions, or modification by the Director, Respondent shall proceed to take all action required by the submission as approved or modified by the Director. If the Director disapproves all or any portion of the submission, Respondent must correct all deficiencies within the time specified by the Director and resubmit it for approval. 8. Extensions of Time. The Director may grant an extension of time for compliance with any of the terms of this Order upon a written request timely submitted demonstrating good cause for an extension. 9. Reporting. Submit quarterly reports to the Director that: (1) include all available data and results of the testing and evaluations required by this Order; and (2) describe the progress of the repairs or other remedial actions being undertaken. The first quarterly report is due on April 30, 2026, covering the period through March 31, 2026. The Director may change the interval for the submission of these reports. 10. Documentation of the Costs. It is requested that Respondent maintain documentation of the costs associated with implementation of this CAO. Include in each monthly report submitted, the to-date total costs associated with: (1) preparation and revision of procedures, studies, and analyses; (2) physical changes to pipeline infrastructure, including repairs, replacements, and other modifications; and (3) environmental remediation, if applicable. Be advised that all material submitted in response to this enforcement action is subject to being made publicly available. If you believe that any portion of your responsive material qualifies for confidential treatment under 5 U.S.C. § 552(b), along with the complete original document you must provide a second copy of the document with the portions you believe qualify for confidential treatment redacted and an explanation of why you believe the redacted information qualifies for confidential treatment under 5 U.S.C. § 552(b). In your correspondence on this matter, please refer to “CPF No. 3-2026-003-CAO” and for each document you submit, please provide a copy in electronic format whenever possible. The actions required by this Order are in addition to and do not waive any requirements that apply to Respondent’s pipeline system under 49 CFR Parts 190 through 199, under any other order issued to Respondent under authority of 49 U.S.C. Chapter 601, or under any other provision of federal or state law. Respondent may appeal any decision of the Director to the Associate Administrator for Pipeline Safety. Decisions of the Associate Administrator shall be final. Failure to comply with this Order may result in the assessment of civil penalties and in referral to the Attorney General for appropriate relief in United States District Court pursuant to 49 U.S.C. § 60120. The terms and conditions of this Order are effective upon service in accordance with 49 CFR § 190.5. January 18, 2026 _____________________________ __________________________ Linda Daugherty Date Issued Acting Associate Administrator for Pipeline Safety 32026003CAO_Corrective Action Order (AMENDED)_02232026_(26-362613)_text.pdf U.S. Department of Transportation Pipeline and Hazardous Materials Safety Administration 1200 New Jersey Avenue, SE Washington, DC 20590 February 23, 2026 VIA ELECTRONIC MAIL TO: Scott.Hallam@bwpipelines.com Scott Hallam President and CEO Texas Gas Transmission, LLC 9 Greenway Plaza, Suite 2800 Houston, Texas 77046 Re: CPF No. 3-2026-003-CAO Dear Mr. Shindle, Enclosed please find a Corrected Amended Corrective Action Order (Corrected ACAO) issued by the Pipeline and Hazardous Materials Safety Administration (PHMSA), Office of Pipeline Safety (OPS). The Corrected ACAO corrects two typographical errors in paragraphs 5.e.v. and 5.e.vii. of the list of corrective actions in the Amended Corrective Action Order that was issued on February 6, 2026, regarding the pipeline failure that occurred on January 17, 2026, on the 20-inch diameter SHC 20-1 pipeline near DeBerry, Texas. Service of the Corrected ACAO by electronic mail is effective upon the date of transmission and acknowledgment of receipt as provided under 49 CFR § 190.5. Sincerely, Linda Daugherty Acting Associate Administrator for Pipeline Safety Enclosure: Corrected ACAO cc: Mr. David Barrett, Acting Director, Central Region, Office of Pipeline Safety, PHMSA Brad Shindle, VP Asset Performance, TGT, Brad.Shindle@bwpipelines.com Tina Baker, Manager, Compliance Services, TGT, Tina.Baker@bwpipelines.com CONFIRMATION OF RECEIPT REQUESTED U.S. DEPARTMENT OF TRANSPORTATION PIPELINE AND HAZARDOUS MATERIALS SAFETY ADMINISTRATION OFFICE OF PIPELINE SAFETY WASHINGTON, D.C. 20590 ____________________________________ ) In the Matter of ) ) Texas Gas Transmission, LLC, ) CPF No. 3-2026-003-CAO ) Respondent. ) ) ____________________________________) AMENDED CORRECTIVE ACTION ORDER Purpose and Background The Pipeline and Hazardous Materials Safety Administration (PHMSA), Office of Pipeline Safety (OPS), is issuing this Amended Corrective Action Order (“ACAO” or “Order”)1 pursuant to the authority provided in 49 U.S.C. § 60112. The ACAO requires Texas Gas Transmission, LLC (TGT),2 to take certain necessary corrective actions to protect the public, property, and the environment from the potential hazards associated with the continued operation of the SHC 20-1 Carthage to Sharon Compressor station pipeline. The SHC 20-1 is a 20-inch gas transmission line that originates in Carthage, Texas, and runs northeast towards the Sharon Compressor station. The line passes through portions of Panala County, Texas; Caddo Parish, Louisiana; Bossier Parrish, Louisiana; Webster Parish, Louisiana; Claiborne Parish, Louisiana; and Lincoln Parish, Louisiana. At approximately 3:04 p.m. CST on January 17, 2026, TGT’s control room personnel received SCADA alarms for a possible incident and notified field personnel. TGT subsequently confirmed that a failure occurred, resulting in the ejection of a portion of the 20-inch diameter pipe onto the pipeline right-of-way. There were no reported injuries, fatalities, or evacuations, and there was no ignition of the escaping gas. 1 To the extent this ACAO is modified from the original CAO issued to Respondent under CPF No. 3-2026-003- CAO on January 18, 2026, this ACAO supersedes and replaces the original CAO. To the extent this ACAO is unmodified from the original CAO, this ACAO retains the full force and effect of the original CAO. All deadlines noted in the order which refer to the date “this Order is issued” or “receipt of this Order” refer to the issuance of the original CAO on January 18, 2026. 2 Texas Gas Transmission pipeline system consists of approximately 6,000 miles of natural gas transmission pipelines transporting gas from the Louisiana Gulf coast up through Arkansas, Mississippi, Tennessee, and Kentucky, to supply gas to Illinois, Indiana, and Ohio. 2 Pursuant to 49 U.S.C. § 60117, PHMSA has initiated an investigation of the failure. The preliminary findings of PHMSA’s ongoing investigation are as follows: Preliminary Findings January 17, 2026 Incident • At approximately 3:04 p.m. CST on January 17, 2025, TGT’s control room personnel received SCADA alarms for a possible incident and notified field personnel. • At 4:12 p.m. CST, field personnel confirmed that a rupture occurred on the SHC 20-1 20- inch pipeline. At 4:20 p.m., the failure location was isolated by closing Valves SHC-7 and SHC-8. At 4:50 pm, the line segment was completely blown down to zero pressure. • The failure occurred at mile post (MP) 88+3571 on TGT’s SHC 20-1 Carthage to Red River pipeline segment in Panala County, Texas. • TGT notified the National Response Center (NRC) of the failure on January 17, 2026, at approximately 4:29 pm CST (NRC Incident Report #1452961). • PHMSA launched an investigation, with investigators arriving on January 18, 2026. • The pipe at the failure location is 20-inch diameter pipe, 0.281-inch wall thickness constructed in 1949 with API 5L X46 direct current electric resistance welded (DC- ERW) longitudinal seam manufactured by Youngstown. DC-ERW pipe of this vintage is known to present certain integrity risks. • On the Carthage to Red River pipeline segment, TGT reports that there is approximately 42,572 feet of DC-ERW pipe. On the Red River to Sharon Compressor station pipe segment, TGT reports that there is approximately 26,209 feet of DC-ERW pipe. • In 2024, 2017, 2010, and 2004, TGT ran inline inspection (ILI) tools through the pipeline at the location of the failure, including magnetic flux leakage (MFL), deformation, and inertial mapping tools. • The maximum allowable operating pressure (MAOP) of the pipe at the failure site is 931 pounds per square inch gauge (psig). The operating pressure at the time of the failure was approximately 785 psig as measured at the Carthage #3 Mark West, which is approximately 2.5 miles upstream of the failure location. Amended Determination of Necessity for Corrective Action Order and Right to Hearing 3 Section 60112 of title 49, United States Code, authorizes PHMSA to determine that a pipeline facility is or would be hazardous to life, property, or the environment and if there is a likelihood of serious harm, to expeditiously order the operator of the facility to take necessary corrective action, including suspended or restricted use of the facility, physical inspection, testing, repair, replacement, or other appropriate action. An order issued expeditiously must provide an opportunity for a hearing as soon as practicable after the order is issued. In deciding whether to issue an order, PHMSA must consider the following, if relevant: (1) the characteristics of the pipe and other equipment used in the pipeline facility, including the age, manufacture, physical properties, and method of manufacturing, constructing, or assembling the equipment; (2) the nature of the material the pipeline facility transports, the corrosive and deteriorative qualities of the material, the sequence in which the material is transported, and the pressure required for transporting the material; (3) the aspects of the area in which the pipeline facility is located, including climatic and geologic conditions and soil characteristics; (4) the proximity of the area in which the facility is located to environmentally sensitive areas; (5) the population density and population and growth patterns of the area in which the pipeline facility is located; (6) any recommendation of the National Transportation Safety Board made under another law; and (7) any other factors PHMSA may consider as appropriate. After evaluating the foregoing preliminary findings of fact, and having considered the characteristics of the pipeline, the nature of the failure; the hazardous nature of the material transported; the existing and potential additional impacts to property, the environment, and wildlife; it is hereby determined that continued operation of the Affected Segment of the TGT SHC 20-1 pipeline, as defined below, without corrective measures is or would be hazardous to life, property, or the environment, and that failure to issue this Order expeditiously would result in the likelihood of serious harm. Accordingly, this Order mandating immediate corrective action is issued expeditiously without prior notice and opportunity for a hearing. The terms and conditions of this Order are effective upon completion of service. Within 10 days of receipt of this Order, Respondent may request a hearing, to be held as soon as practicable, by notifying the Associate Administrator for Pipeline Safety in writing, with a copy to the Director, PHMSA, OPS Central Region. If a hearing is requested, it will be held in accordance with 49 CFR § 190.211. After receiving and analyzing additional data in the course of this investigation, PHMSA may identify other corrective measures that need to be taken. Respondent will be notified of any additional measures required and, if appropriate, PHMSA will consider a further amended order. To the extent consistent with safety, Respondent will be afforded notice and an opportunity for a hearing prior to the imposition of any additional corrective measures. Definitions 4 Affected Segment – The “Affected Segment” means the 20-inch diameter SHC 20-1 20” pipeline from the start of the mainline at the Carthage facility (M.P. 96 + 2140 ft.) to the Sharon Compressor Station (MP 0.000). Isolated Segment – The “Isolated Segment” means the 20-inch diameter SHC 20-1 20” pipeline between mainline valves SHC-7 and SHC-8. Director – The “Director” means the Director, PHMSA, OPS Central Region. 1. Restart Plan. Prior to resuming operation of the Isolated Segment, TGT must develop and submit a written Restart Plan to the Director for prior approval. a. The Restart Plan must include a Repair Plan for the Director’s approval. b. The Director may approve the Restart Plan incrementally, including the Repair Plan, without approving the entire plan. c. Once approved by the Director, the Restart Plan will be incorporated by reference into this Order. d. The Restart Plan must provide for adequate patrolling and sufficient surveillance of the Isolated Segment during the restart process to ensure that no leaks are present when operation of the line resumes. e. The Restart Plan must specify a day-light restart and include advance communications with local emergency response officials. 2. Operating Pressure Restriction. TGT must reduce and maintain a twenty percent (20%) pressure reduction in the actual operating pressure along the entire length of the Affected Segment, such that the operating pressure along the Affected Segment will not exceed eighty percent (80%) of the actual operating pressure in effect immediately prior to the failure on January 17, 2026. a. This pressure restriction must remain in effect until written approval to increase the pressure or return the pipeline to its pre-failure operating pressure is obtained from the Director. b. Within 10 days of issuance of the Order, TGT must provide the Director the actual operating pressures of each compressor station and each main line pressure regulating station on the Affected Segment at the time of failure and the reduced pressure restriction set-points at these same locations. c. This pressure restriction requires any relevant remote or local alarm limits, software programming set-points or control points, and mechanical over-pressure devices to be adjusted accordingly. d. When determining the pressure restriction set-points, TGT must take into account any in-line inspection (ILI) features or anomalies present in the Affected Segment to provide for continued safe operation while further corrective actions are completed. e. TGT must review the pressure restriction monthly by analyzing the operating pressure data. TGT must take into account any ILI features or anomalies present in the Affected Segment and immediately reduce the operating pressure to maintain the safe operations of the Affected Segment, if warranted by the monthly review. TGT must submit the results of the monthly review to the Director. The results must include, at a 5 minimum, the current discharge set-points (including any additional pressure reductions), and any pressure exceedance at discharge set-points. f. TGT may request approval from the Director to increase the operating pressure on individual segments on the Affected Pipeline based on an engineering analysis or other justification that the segment does not pose a safety risk. 3. Mechanical and Metallurgical Testing. Within 45 days of receipt of this Order, TGT must complete mechanical and metallurgical testing and failure analysis of the failed pipe, including an analysis of soil samples and any foreign materials. Complete the testing and analysis as follows: a. Document the chain-of-custody when handling and transporting the failed pipe section and other evidence from the failure site. b. Within 10 days of receipt of this Order, develop and submit the testing protocol and the proposed testing laboratory to the Director for prior approval. c. Prior to beginning the mechanical and metallurgical testing, provide the Director with the scheduled date, time, and location of the testing to allow for an OPS representative to witness the testing. d. Ensure the testing laboratory distributes all reports (whether draft or final) in their entirety to the Director at the same time they are made available to TGT. 4. Root Cause Failure Analysis. Within 90 days following receipt of this Order, TGT must complete a root cause failure analysis (RCFA) and submit a final report of this RCFA to the Director. The RCFA must be supplemented/facilitated by an independent third-party acceptable to the Director and must document the decision making process and all factors contributing to the failure. The final report must include findings, and any lessons learned and whether the findings and any lessons learned are applicable to other locations within TGT’s pipeline system. The independent third-party must distribute all RCFA reports (whether draft or final) in their entirety to the Director at the same time they are made available to TGT provide all versions of the RCFA 5. Remedial Work Plan (RWP). a. Within 120 days following receipt of this Order, TGT must submit a Remedial Work Plan (RWP) to the Director for approval. b. The Director may approve the RWP incrementally without approving the entire RWP. c. Once approved by the Director, the RWP will be incorporated by reference into this Order. d. The RWP must specify the tests, inspections, assessments, evaluations, and remedial measures TGT will use to verify the integrity of the Affected Segment. It must address all known or suspected factors and causes of the January 17, 2026 failure. TGT must consider both the risk of another failure and the consequence of another failure to develop a prioritized schedule for RWP related work along the Affected Segment. e. The RWP must include a procedure or process to: 6 i. Identify pipe in the Affected Segment with characteristics similar to the contributing factors identified for the January 17, 2026 failure. ii. Gather all data necessary to review the failure history (in service and pressure test failures) of the Affected Segment and to prepare a written report containing all the available information such as the locations, dates, and causes of leaks and failures. iii. Integrate the results of the metallurgical testing, RCFA, and other corrective actions required by this Order with all relevant pre-existing operational and assessment data for the Affected Segment. Pre-existing operational data includes, but is not limited to, construction, operations, maintenance, testing, repairs, prior metallurgical analyses, and any third party consultation information. Pre-existing assessment data includes, but is not limited to, ILI tool runs, hydrostatic pressure testing, direct assessments, close interval surveys, and DCVG/ACVG surveys. iv. Determine if conditions similar to those contributing to the failure on January 17, 2026, are likely to exist elsewhere on the Affected Segment. v. Conduct additional field tests, inspections, assessments, and/or evaluations to determine whether, and to what extent, the conditions associated with the failure on January 17, 2026, and other failures from the failure history (see (e)(ii) above) or any other integrity threats are present elsewhere on the Affected Segment. At a minimum, this process must consider all failure causes and specify the use of one or more of the following: 1) ILI tools that are technically appropriate for assessing the pipeline system based on the cause of failure on January 17, 2026, and that can reliably detect and identify anomalies, 2) Hydrostatic pressure testing, 3) Close-interval surveys, 4) Cathodic protection surveys, to include interference surveys in coordination with other utilities (e.g. underground utilities, overhead power lines, etc.) in the area, 5) Coating surveys, 6) Stress corrosion cracking surveys, 7) Selective seam corrosion surveys; and, 8) Other tests, inspections, assessments, and evaluations appropriate for the failure causes. Note: TGT may use the results of previous tests, inspections, assessments, and evaluations if approved by the Director, provided the results of the tests, inspections, assessments, and evaluations are analyzed with regard to the factors known or suspected to have caused the January 17, 2026 failure. vi. Describe the inspection and repair criteria TGT will use to prioritize, excavate, evaluate, and repair anomalies, imperfections, and other identified integrity threats. Include a description of how any defects will be graded and a schedule for repairs or replacement. 7 vii. Describe the methods TGT will use to repair, replace, or take other corrective measures to remediate the conditions associated with the pipeline failure on January 17, 2026, and to address other known integrity threats along the Affected Segment. The repair, replacement, or other corrective measures must meet the criteria specified in (e)(vi) above. viii. Implement continuing long-term periodic testing and integrity verification measures to ensure the ongoing safe operation of the Affected Segment considering the results of the analyses, inspections, evaluations, and corrective measures undertaken pursuant to the Order. f. Include a proposed schedule for completion of the RWP. g. TGT must revise the RWP as necessary to incorporate new information obtained during the failure investigation and remedial activities, to incorporate the results of actions undertaken pursuant to this Order, and/or to incorporate modifications required by the Director. i. Submit any plan revisions to the Director for prior approval. ii. The Director may approve plan revisions incrementally. iii. Any and all revisions to the RWP after it has been approved and incorporated by reference into this Order will be fully described and documented in the CAO Documentation Report (CDR). h. Implement the RWP as it is approved by the Director, including any revisions to the plan. 6. CAO Documentation Report (CDR). TGT must create and revise, as necessary, a CAO Documentation Report (CDR). When TGT has concluded all the items in this Order it will submit the final CDR in its entirety to the Director. This will allow the Director to complete a thorough review of all actions taken by TGT with regards to this Order prior to approving the closure of this Order. The intent is for the CDR to summarize all activities and documentation associated with this Order in one document. a. The Director may approve the CDR incrementally without approving the entire CDR. b. Once approved by the Director, the CDR will be incorporated by reference into this Order. c. The CDR must include but not be limited to: i. Table of Contents; ii. Summary of the pipeline failure of January 17, 2026, and the response activities; iii. Summary of pipe data/properties and all prior assessments of the Affected Segment; iv. Summary of all tests, inspections, assessments, evaluations, and analysis required by the Order; v. Summary of the Mechanical and Metallurgical Testing as required by the Order; vi. Summary of the RCFA with all root causes as required by the Order; vii. Documentation of all actions taken by TGT to implement the RWP, the results of those actions, and the inspection and repair criteria used; 8 viii. Documentation of any revisions to the RWP including those necessary to incorporate the results of actions undertaken pursuant to this Order and whenever necessary to incorporate new information obtained during the failure investigation and remedial activities; ix. Lessons learned while completing this Order; x. A path forward describing specific actions TGT will take on its entire pipeline system as a result of the lessons learned from work on this Order; and xi. Appendices (if required). Other Requirements: 7. Approvals. With respect to each submission under this Order that requires the approval of the Director, the Director may: (a) approve, in whole or part, the submission; (b) approve the submission on specified conditions; (c) modify the submission to cure any deficiencies; (d) disapprove in whole or in part, the submission, directing that Respondent modify the submission, or (e) any combination of the above. In the event of approval, approval upon conditions, or modification by the Director, Respondent shall proceed to take all action required by the submission as approved or modified by the Director. If the Director disapproves all or any portion of the submission, Respondent must correct all deficiencies within the time specified by the Director and resubmit it for approval. 8. Extensions of Time. The Director may grant an extension of time for compliance with any of the terms of this Order upon a written request timely submitted demonstrating good cause for an extension. 9. Reporting. Submit quarterly reports to the Director that: (1) include all available data and results of the testing and evaluations required by this Order; and (2) describe the progress of the repairs or other remedial actions being undertaken. The first quarterly report is due on April 30, 2026, covering the period through March 31, 2026. The Director may change the interval for the submission of these reports. 10. Documentation of the Costs. It is requested that Respondent maintain documentation of the costs associated with implementation of this CAO. Include in each monthly report submitted, the to-date total costs associated with: (1) preparation and revision of procedures, studies, and analyses; (2) physical changes to pipeline infrastructure, including repairs, replacements, and other modifications; and (3) environmental remediation, if applicable. Be advised that all material submitted in response to this enforcement action is subject to being made publicly available. If you believe that any portion of your responsive material qualifies for confidential treatment under 5 U.S.C. § 552(b), along with the complete original document you must provide a second copy of the document with the portions you believe qualify for confidential treatment redacted and an explanation of why you believe the redacted information qualifies for confidential treatment under 5 U.S.C. § 552(b). In your correspondence on this matter, please refer to “CPF No. 3-2026-003-CAO” and for each document you submit, please provide a copy in electronic format whenever possible. The actions required by this Order are in addition to and do not waive any requirements that apply 9 to Respondent’s pipeline system under 49 CFR Parts 190 through 199, under any other order issued to Respondent under authority of 49 U.S.C. Chapter 601, or under any other provision of Federal or State law. Respondent may appeal any decision of the Director to the Associate Administrator for Pipeline Safety. Decisions of the Associate Administrator shall be final. Failure to comply with this Order may result in the assessment of civil penalties and in referral to the Attorney General for appropriate relief in United States District Court pursuant to 49 U.S.C. § 60120. The terms and conditions of this Order are effective upon service in accordance with 49 CFR § 190.5. _____________________________ __________________________ Linda Daugherty Date Issued Acting Associate Administrator for Pipeline Safety ## Provenance - Official: Yes - Source: - Source ID: `phmsa-enforcement` - SHA-256: `3224e6ce244dc15bad902dc0d9748cedd80faaf6e39552f48d7d9c7e94510e5f` - Retrieved: 2026-08-20T04:44:44.458Z - Exported: 2026-08-23T23:09:57.717Z - Document slug: `phmsa-enforcement-32026003cao` ### Source metadata ```json { "cpf": "32026003CAO", "operator": "TEXAS GAS TRANSMISSION, LLC", "region": "Central", "pipelineType": "INTERSTATE GAS TRANSMISSION", "caseStatus": "OPEN", "citedSections": [], "dataAsOf": "08/04/2026 12PM", "caseDataAsOf": "2026-08-04", "attachmentCount": 6, "attachments": [ { "name": "32026003CAO_Corrective Action Order (AMENDED)_02062026_(26-362613).pdf", "url": "https://primis.phmsa.dot.gov/enforcement-documents/32026003CAO/32026003CAO_Corrective%20Action%20Order%20(AMENDED)_02062026_(26-362613).pdf", "bytes": 316782, "category": "agency_document" }, { "name": "32026003CAO_Corrective Action Order (AMENDED)_02062026_(26-362613)_text.pdf", "url": "https://primis.phmsa.dot.gov/enforcement-documents/32026003CAO/32026003CAO_Corrective%20Action%20Order%20(AMENDED)_02062026_(26-362613)_text.pdf", "bytes": 291979, "category": "agency_document" }, { "name": "32026003CAO_Corrective Action Order (AMENDED)_02232026_(26-362613).pdf", "url": "https://primis.phmsa.dot.gov/enforcement-documents/32026003CAO/32026003CAO_Corrective%20Action%20Order%20(AMENDED)_02232026_(26-362613).pdf", "bytes": 290453, "category": "agency_document" }, { "name": "32026003CAO_Corrective Action Order (AMENDED)_02232026_(26-362613)_text.pdf", "url": "https://primis.phmsa.dot.gov/enforcement-documents/32026003CAO/32026003CAO_Corrective%20Action%20Order%20(AMENDED)_02232026_(26-362613)_text.pdf", "bytes": 288245, "category": "agency_document" }, { "name": "32026003CAO_Corrective Action Order_01182026_(26-362613).pdf", "url": "https://primis.phmsa.dot.gov/enforcement-documents/32026003CAO/32026003CAO_Corrective%20Action%20Order_01182026_(26-362613).pdf", "bytes": 270390, "category": "agency_document" }, { "name": "32026003CAO_Corrective Action Order_01182026_(26-362613)_text.pdf", "url": "https://primis.phmsa.dot.gov/enforcement-documents/32026003CAO/32026003CAO_Corrective%20Action%20Order_01182026_(26-362613)_text.pdf", "bytes": 295470, "category": "agency_document" } ], "extractedAgencyDocumentCount": 3, "attachmentPolicy": "Official attachment links are retained. Agency-issued documents may also include a verified local PDF and page-level text representation.", "jurisdiction": "US", "operatorName": "TEXAS GAS TRANSMISSION, LLC" } ```