{"operation":"document","citation":"CPF 12024040NOA","title":"EQT PRODUCTION — Notice of Amendment","source_type":"enforcement","agency":"Pipeline and Hazardous Materials Safety Administration","status":"historical","official":true,"published_on":"2024-11-12","effective_on":null,"summary":"CLOSED notice of amendment citing 192.605(b)(1).","machine_formats":{"json":"https://regulus.evalyn.ai/document/phmsa-enforcement-12024040noa.json","markdown":"https://regulus.evalyn.ai/document/phmsa-enforcement-12024040noa.md"},"app_url":"https://regulus.evalyn.ai/document/phmsa-enforcement-12024040noa","source_url":"https://primis.phmsa.dot.gov/enforcement-data/case/12024040NOA","body":"Notice of Amendment involving EQT PRODUCTION. PHMSA's enforcement data identifies the cited regulation as 192.605(b)(1). The case was opened on 2024-11-12 and is reported as closed as of 2025-05-13. Open the official case record for notices, responses, orders, and the latest status.\n\nOfficial case documents:\n\n12024040NOA_Closure Letter_05132025_(23-276594).pdf: https://primis.phmsa.dot.gov/enforcement-documents/12024040NOA/12024040NOA_Closure%20Letter_05132025_(23-276594).pdf\n\n12024040NOA_Closure Letter_05132025_(23-276594)_text.pdf: https://primis.phmsa.dot.gov/enforcement-documents/12024040NOA/12024040NOA_Closure%20Letter_05132025_(23-276594)_text.pdf\n\n12024040NOA_Notice of Amendment_11122024_(23-276594).pdf: https://primis.phmsa.dot.gov/enforcement-documents/12024040NOA/12024040NOA_Notice%20of%20Amendment_11122024_(23-276594).pdf\n\n12024040NOA_Notice of Amendment_11122024_(23-276594)_text.pdf: https://primis.phmsa.dot.gov/enforcement-documents/12024040NOA/12024040NOA_Notice%20of%20Amendment_11122024_(23-276594)_text.pdf\n\n12024040NOA_Operator Response to Notice and Request Time Extension_12032024_(23-276594).pdf: https://primis.phmsa.dot.gov/enforcement-documents/12024040NOA/12024040NOA_Operator%20Response%20to%20Notice%20and%20Request%20Time%20Extension_12032024_(23-276594).pdf\n\n12024040NOA_Notice of Amendment_11122024_(23-276594)_text.pdf\n\nNOTICE OF AMENDMENT\nOVERNIGHT EXPRESS DELIVERY\nNovember 12, 2024\nMr. Justin Trettel\nSenior Vice President\nEQT Production Company\n2200 Energy Drive\nCanonsburg, Pennsylvania 15317\nCPF 1-2024-040-NOA\nDear Mr. Trettel:\nFrom October 31, 2022 through March 27, 2023, representatives of the Pipeline and Hazardous\nMaterials Safety Administration (PHMSA) pursuant to Chapter 601 of 49 United States Code\n(U.S.C.), inspected EQT Production Company’s (EQT))1 procedures for compliance with\nPHMSA’s gas pipeline integrity regulations2 in Canonsburg, Pennsylvania.\nAs a result of the inspection, PHMSA has identified apparent inadequacies found within EQTs’\nplans or procedures. The items inspected and the inadequacies are described below:\n1. 49 C.F.R. § 192.605 Procedural manual for operations, maintenance, and\nemergencies.\n(a) . . . .\n(b) Maintenance and normal operations. The manual required by\n1 At the time of the inspection, the operator of the pipeline facilities being inspected for compliance with Part 192\nwas Equitrans Midstream Corporation (PHMSA Operator Identification No. (OPID) 31604). However, Equitrans\nMidstream Corporation and its pipeline facilities that were the subject of the inspection have since been acquired by\nEQT Corporation (see, e.g., https://ir.eqt.com/investor-relations/news/news-release-details/2024/EQT-Completes-\nAcquisition-of-Equitrans-Midstream/default.aspx), and the pipeline facilities are presently operated by EQT\nCorporation’s subsidiary, EQT Production Company (PHMSA OPID 39491).\n2 See, e.g., the requirements established in PHMSA final rule titled “Pipeline Safety: Safety of Gas Transmission\nPipelines: MAOP Reconfirmation, Expansion of Assessment Requirements, and Other Related Amendments” (84\nFed. Reg. 52,180 (Oct 1, 2019)) as codified in 49 C.F.R. Part 192. Docket No. PHMSA–2011–0023.\n\n\n\nparagraph (a) of this section must include procedures for the\nfollowing, if applicable, to provide safety during maintenance and\noperations.\n(1) Operating, maintaining, and repairing the pipeline in\naccordance with each of the requirements of this subpart and subpart\nM of this part.\nEQT’s written procedures for operating and maintaining its pipeline in accordance with\nrequirements of Subpart L of 49 CFR Part 192 were inadequate to assure safe operation of a\npipeline facility. Specifically, EQT failed to present adequate procedures for verification of\nmaterial properties and attributes when traceable, verifiable, and complete (TVC) records are\nmissing during maximum allowable operating pressure (MAOP) reconfirmation efforts in\naccordance with the requirements of § 192.607(c).3\n3 § 192.607 Verification of Pipeline Material Properties and Attributes: Onshore steel transmission pipelines.\n(a) Applicability. Wherever required by this part, operators of onshore steel transmission pipelines must document\nand verify material properties and attributes in accordance with this section.\n(b) Documentation of material properties and attributes. Records established under this section documenting\nphysical pipeline characteristics and attributes, including diameter, wall thickness, seam type, and grade (e.g., yield\nstrength, ultimate tensile strength, or pressure rating for valves and flanges, etc.), must be maintained for the life of\nthe pipeline and be traceable, verifiable, and complete. Charpy v-notch toughness values established under this\nsection needed to meet the requirements of the ECA method at § 192.624(c)(3) or the fracture mechanics\nrequirements at § 192.712 must be maintained for the life of the pipeline.\n(c) Verification of material properties and attributes. If an operator does not have traceable, verifiable, and complete\nrecords required by paragraph (b) of this section, the operator must develop and implement procedures for\nconducting nondestructive or destructive tests, examinations, and assessments in order to verify the material\nproperties of aboveground line pipe and components, and of buried line pipe and components when excavations\noccur at the following opportunities: Anomaly direct examinations, in situ evaluations, repairs, remediations,\nmaintenance, and excavations that are associated with replacements or relocations of pipeline segments that are\nremoved from service. The procedures must also provide for the following:\n(1) For nondestructive tests, at each test location, material properties for minimum yield strength and ultimate tensile\nstrength must be determined at a minimum of 5 places in at least 2 circumferential quadrants of the pipe for a\nminimum total of 10 test readings at each pipe cylinder location.\n(2) For destructive tests, at each test location, a set of material properties tests for minimum yield strength and\nultimate tensile strength must be conducted on each test pipe cylinder removed from each location, in accordance\nwith API Specification 5L.\n(3) Tests, examinations, and assessments must be appropriate for verifying the necessary material properties and\nattributes.\n(4) If toughness properties are not documented, the procedures must include accepted industry methods for verifying\npipe material toughness.\n(5) Verification of material properties and attributes for non-line pipe components must comply with paragraph (f)\nof this section.\n(d) Special requirements for nondestructive Methods. Procedures developed in accordance with paragraph (c) of\nthis section for verification of material properties and attributes using nondestructive methods must:\n(1) Use methods, tools, procedures, and techniques that have been validated by a subject matter expert based on\ncomparison with destructive test results on material of comparable grade and vintage;\n(2) Conservatively account for measurement inaccuracy and uncertainty using reliable engineering tests and\nanalyses; and\n(3) Use test equipment that has been properly calibrated for comparable test materials prior to usage.\n(e) Sampling multiple segments of pipe. To verify material properties and attributes for a population of multiple,\ncomparable segments of pipe without traceable, verifiable, and complete records, an operator may use a sampling\nprogram in accordance with the following requirements:\n\n\n\nDuring the inspection, PHMSA reviewed EQT’s Operations and Maintenance Manual Revision\n15, Effective 10/17/22 (O&M Manual), and EQT’s procedures titled Establishing Maximum\nAllowable Operating Pressure, Revision 2, Effective 10/3/2022 (MAOP-1); MAOP\nReconfirmation, Revision 2, Effective 10/5/2022 (MAOP-2); TVC Recordkeeping, Revision 2,\n(1) The operator must define separate populations of similar segments of pipe for each combination of the following\nmaterial properties and attributes: Nominal wall thicknesses, grade, manufacturing process, pipe manufacturing\ndates, and construction dates. If the dates between the manufacture or construction of the pipeline segments exceeds\n2 years, those segments cannot be considered as the same vintage for the purpose of defining a population under this\nsection. The total population mileage is the cumulative mileage of pipeline segments in the population. The pipeline\nsegments need not be continuous.\n(2) For each population defined according to paragraph (e)(1) of this section, the operator must determine material\nproperties at all excavations that expose the pipe associated with anomaly direct examinations, in situ evaluations,\nrepairs, remediations, or maintenance, except for pipeline segments exposed during excavation activities pursuant to\n§ 192.614, until completion of the lesser of the following:\n(i) One excavation per mile rounded up to the nearest whole number; or\n(ii) 150 excavations if the population is more than 150 miles.\n(3) Prior tests conducted for a single excavation according to the requirements of paragraph (c) of this section may\nbe counted as one sample under the sampling requirements of this paragraph (e).\n(4) If the test results identify line pipe with properties that are not consistent with available information or existing\nexpectations or assumed properties used for operations and maintenance in the past, the operator must establish an\nexpanded sampling program. The expanded sampling program must use valid statistical bases designed to achieve at\nleast a 95% confidence level that material properties used in the operation and maintenance of the pipeline are valid.\nThe approach must address how the sampling plan will be expanded to address findings that reveal material\nproperties that are not consistent with all available information or existing expectations or assumed material\nproperties used for pipeline operations and maintenance in the past. Operators must notify PHMSA in advance of\nusing an expanded sampling approach in accordance with § 192.18.\n(5) An operator may use an alternative statistical sampling approach that differs from the requirements specified in\nparagraph (e)(2) of this section. The alternative sampling program must use valid statistical bases designed to\nachieve at least a 95% confidence level that material properties used in the operation and maintenance of the\npipeline are valid. The approach must address how the sampling plan will be expanded to address findings that\nreveal material properties that are not consistent with all available information or existing expectations or assumed\nmaterial properties used for pipeline operations and maintenance in the past. Operators must notify PHMSA in\nadvance of using an alternative sampling approach in accordance with § 192.18.\n(f) Components. For mainline pipeline components other than line pipe, an operator must develop and implement\nprocedures in accordance with paragraph (c) of this section for establishing and documenting the ANSI rating or\npressure rating (in accordance with ASME/ANSI B16.5 (incorporated by reference, see § 192.7)),\n(1) Operators are not required to test for the chemical and mechanical properties of components in compressor\nstations, meter stations, regulator stations, separators, river crossing headers, mainline valve assemblies, valve\noperator piping, or cross-connections with isolation valves from the mainline pipeline.\n(2) Verification of material properties is required for non-line pipe components, including valves, flanges, fittings,\nfabricated assemblies, and other pressure retaining components and appurtenances that are:\n(i) Larger than 2 inches in nominal outside diameter,\n(ii) Material grades of 42,000 psi (Grade X-42) or greater, or\n(iii) Appurtenances of any size that are directly installed on the pipeline and cannot be isolated from mainline\npipeline pressures.\n(3) Procedures for establishing material properties of non-line pipe components must be based on the documented\nmanufacturing specification for the components. If specifications are not known, usage of manufacturer's stamped,\nmarked, or tagged material pressure ratings and material type may be used to establish pressure rating. Operators\nmust document the method used to determine the pressure rating and the findings of that determination.\n(g) Uprating. The material properties determined from the destructive or nondestructive tests required by this\nsection cannot be used to raise the grade or specification of the material, unless the original grade or specification is\nunknown and MAOP is based on an assumed yield strength of 24,000 psi in accordance with § 192.107(b)(2).\n\n\n\nEffective 10/5/2022 (MAOP-3); Verification of Pipeline Material Properties and Attributes,\nRevision 1, Effective 10/7/2022 (MAOP-4). PHMSA identified the following inadequacies in\nEQTs procedures:\n• EQT’s O&M Manual did not incorporate references to applicable procedures addressing\n§ 192.607 (MAOP-1, MAOP-2, MAOP-3 and MAOP-4) presented during the inspection,\nincluding operator qualification requirements for personnel conducting material\nverifications as required by § 192.8014. The conduct of material verifications is a\ncovered task under Part 192;\n• Section 5 of procedure MAOP-4 failed to include adequate procedures for verification of\nmaterial properties and attributes when TVC records are missing during MAOP\nreconfirmation efforts. For example, EQT’s procedures did not address processes for\nattaining or establishing such records, including for how affected pipeline segments\nwould be identified or scheduled for consideration opportunistically, or the dissemination\nof applicable requirements to relevant involved parties (e.g., communications between\nthe EQT’s Pipeline Integrity Group and field personnel conducting activities required\nunder § 192.607);\n• Section 5.2 of procedure MAOP-4 (Line Pipe Item 4) lacked adequate information\naddressing material verification via new non-destructive examination (NDE) technology\nreadily available for attaining in-situ toughness properties, including any specifications or\nscope of work;\n• Section 5.2 of procedure MAOP-4 (Line Pipe Item 4) also lacked adequate information\naddressing material verification of NDE technology readily available for attaining in-situ\nyield strength and ultimate tensile strength (UTS), including any specifications or scope\nof work; and,\n• Section 6 of procedure MAOP-3 (Initial Procedure) and Appendix A – Acceptable\nCompletion Matrix (Appendix A) address the requirement of MAOP reconfirmation and\nevaluation of TVC status when applicable. Appendix A serves as a guideline in\ndetermining the minimum amount and type of documentation required to support MAOP\nreconfirmation. During the inspection, numerous MAOP records were reviewed and the\nTVC records status was determined via utilization of Appendix A. However in several\ninstances, it was discussed that material properties information (e.g., material grade) was\ncaptured from identical notes within field survey books and transposed across several\nproject records, including alignment sheets. This process inflated the number of material\ngrade reference records, and thus, prematurely considered the records as TVC without\nseparate documentation (e.g. material test reports) per the requirements governing TVC\nrecords.5\n4 § 192.801 Scope.\n(a) This subpart prescribes the minimum requirements for operator qualification of individuals performing covered\ntasks on a pipeline facility.\n(b) For the purpose of this subpart, a covered task is an activity, identified by the operator, that:\n(1) Is performed on a pipeline facility;\n(2) Is an operations or maintenance task;\n(3) Is performed as a requirement of this part; and\n(4) Affects the operation or integrity of the pipeline.\n5 See 85 Fed. Reg. 52,180.\n\n\n\nTherefore, EQT’s written procedures required by § 192.605(b)(1) were inadequate. Equitrans\nmust amend its written procedures to address the deficiencies noted above pertaining to the\nrequirements of § 192.607.\n2. § 192.605 Procedural manual for operations, maintenance, and emergencies.\n(a) …\n(b) Maintenance and normal operations. The manual required by\nparagraph (a) of this section must include procedures for the following,\nif applicable, to provide safety during maintenance and operations.\n(1) Operating, maintaining, and repairing the pipeline in\naccordance with each of the requirements of this subpart and subpart\nM of this part.\nEquitrans’ written procedures for operating and maintaining its pipeline in accordance with\nrequirements of Subpart M of 49 CFR Part 192 were inadequate to assure safe operation of a\npipeline facility. Specifically, EQT’s O&M Manual and its Integrity Management Plan\nCompliance (10/15/22) (IMP Compliance) procedure fail to adequately address the requirements\nof § 192.710.6\n6 As in effect during the 2022-2023 PHMSA inspection: § 192.710 Transmission lines: Assessments outside of high\nconsequence areas.\n(a) Applicability: This section applies to onshore steel transmission pipeline segments with a maximum allowable\noperating pressure of greater than or equal to 30% of the specified minimum yield strength and are located in:\n(1) A Class 3 or Class 4 location; or\n(2) A moderate consequence area as defined in § 192.3, if the pipeline segment can accommodate inspection by\nmeans of an instrumented inline inspection tool (i.e., “smart pig”).\n(3) This section does not apply to a pipeline segment located in a high consequence area as defined in § 192.903.\n(b) General —\n(1) Initial assessment. An operator must perform initial assessments in accordance with this section based on a risk-\nbased prioritization schedule and complete initial assessment for all applicable pipeline segments no later than July\n3, 2034, or as soon as practicable but not to exceed 10 years after the pipeline segment first meets the conditions of §\n192.710(a) (e.g., due to a change in class location or the area becomes a moderate consequence area), whichever is\nlater.\n(2) Periodic reassessment. An operator must perform periodic reassessments at least once every 10 years, with\nintervals not to exceed 126 months, or a shorter reassessment interval based upon the type of anomaly, operational,\nmaterial, and environmental conditions found on the pipeline segment, or as necessary to ensure public safety.\n(3) Prior assessment. An operator may use a prior assessment conducted before July 1, 2020 as an initial assessment\nfor the pipeline segment, if the assessment met the subpart O requirements of part 192 for in-line inspection at the\ntime of the assessment. If an operator uses this prior assessment as its initial assessment, the operator must reassess\nthe pipeline segment according to the reassessment interval specified in paragraph (b)(2) of this section calculated\nfrom the date of the prior assessment.\n(4) MAOP verification. An integrity assessment conducted in accordance with the requirements of § 192.624(c) for\nestablishing MAOP may be used as an initial assessment or reassessment under this section.\n(c) Assessment method. The initial assessments and the reassessments required by paragraph (b) of this section\nmust be capable of identifying anomalies and defects associated with each of the threats to which the pipeline\nsegment is susceptible and must be performed using one or more of the following methods:\n(1) Internal inspection. Internal inspection tool or tools capable of detecting those threats to which the pipeline is\nsusceptible, such as corrosion, deformation and mechanical damage (e.g., dents, gouges and grooves), material\ncracking and crack-like defects (e.g., stress corrosion cracking, selective seam weld corrosion, environmentally\nassisted cracking, and girth weld cracks), hard spots with cracking, and any other threats to which the covered\nsegment is susceptible. When performing an assessment using an in-line inspection tool, an operator must comply\n\n\n\nDuring the inspection, PHMSA reviewed EQT’s O&M Manual and IMP Compliance\nprocedures. PHMSA identified the following inadequacies:\n• EQT’s O&M Manual failed to incorporate references to applicable § 192.710\nrequirements residing within EQT’s IMP Compliance procedure;\n• EQT’s IMP Compliance procedure failed to adequately address how moderate\nconsequence areas (MCAs) are initially and subsequently identified to support a\nproper initial and periodic assessment schedule under § 192.710(b). The assessment\nschedule produced during the inspection and utilized by EQT also requires\nmanagement of change via a revision date to differentiate original MCA baseline\nsegments as compared to newly added MCA segments;\nwith § 192.493;\n(2) Pressure test. Pressure test conducted in accordance with subpart J of this part. The use of subpart J pressure\ntesting is appropriate for threats such as internal corrosion, external corrosion, and other environmentally assisted\ncorrosion mechanisms; manufacturing and related defect threats, including defective pipe and pipe seams; and stress\ncorrosion cracking, selective seam weld corrosion, dents and other forms of mechanical damage;\n(3) Spike hydrostatic pressure test. A spike hydrostatic pressure test conducted in accordance with § 192.506. A\nspike hydrostatic pressure test is appropriate for time-dependent threats such as stress corrosion cracking; selective\nseam weld corrosion; manufacturing and related defects, including defective pipe and pipe seams; and other forms\nof defect or damage involving cracks or crack-like defects;\n(4) Direct examination. Excavation and in situ direct examination by means of visual examination, direct\nmeasurement, and recorded non-destructive examination results and data needed to assess all applicable threats.\nBased upon the threat assessed, examples of appropriate non-destructive examination methods include ultrasonic\ntesting (UT), phased array ultrasonic testing (PAUT), Inverse Wave Field Extrapolation (IWEX), radiography, and\nmagnetic particle inspection (MPI);\n(5) Guided Wave Ultrasonic Testing. Guided Wave Ultrasonic Testing (GWUT) as described in Appendix F;\n(6) Direct assessment. Direct assessment to address threats of external corrosion, internal corrosion, and stress\ncorrosion cracking. The use of use of direct assessment to address threats of external corrosion, internal corrosion,\nand stress corrosion cracking is allowed only if appropriate for the threat and pipeline segment being assessed. Use\nof direct assessment for threats other than the threat for which the direct assessment method is suitable is not\nallowed. An operator must conduct the direct assessment in accordance with the requirements listed in § 192.923\nand with the applicable requirements specified in §§ 192.925, 192.927 and 192.929; or\n(7) Other technology. Other technology that an operator demonstrates can provide an equivalent understanding of\nthe condition of the line pipe for each of the threats to which the pipeline is susceptible. An operator must notify\nPHMSA in advance of using the other technology in accordance with § 192.18.\n(d) Data analysis. An operator must analyze and account for the data obtained from an assessment performed under\nparagraph (c) of this section to determine if a condition could adversely affect the safe operation of the pipeline\nusing personnel qualified by knowledge, training, and experience. In addition, when analyzing inline inspection\ndata, an operator must account for uncertainties in reported results (e.g., tool tolerance, detection threshold,\nprobability of detection, probability of identification, sizing accuracy, conservative anomaly interaction criteria,\nlocation accuracy, anomaly findings, and unity chart plots or equivalent for determining uncertainties and verifying\nactual tool performance) in identifying and characterizing anomalies.\n(e) Discovery of condition. Discovery of a condition occurs when an operator has adequate information about a\ncondition to determine that the condition presents a potential threat to the integrity of the pipeline. An operator must\npromptly, but no later than 180 days after conducting an integrity assessment, obtain sufficient information about a\ncondition to make that determination, unless the operator demonstrates that 180 days is impracticable.\n(f) Remediation. An operator must comply with the requirements in §§ 192.485, 192.711, and 192.713, where\napplicable, if a condition that could adversely affect the safe operation of a pipeline is discovered.\n(g) Analysis of information. An operator must analyze and account for all available relevant information about a\npipeline in complying with the requirements in paragraphs (a) through (f) of this section.\n\n\n\n• EQT’s IMP Compliance procedure (Section 14.10, Assessments Outside of High\nConsequence Area (§ 192.710)) lacks a process which exemplifies the application of\na formal risk-based prioritization schedule as prescribed by § 192.710(b)(1) for\nsegments outside of high consequence areas (HCAs) other than elective assessments,\nand an Interstate Natural Gas Association of America initiative that is based upon\npopulation density within respective potential impact radius (PIR);\n• EQT’s IMP Compliance procedure (Section 14.10.2) addresses § 192.710\nrequirements governing periodic reassessment intervals every 10 years, not to exceed\n126-months. However, the procedures governing analysis of whether shorter\nintervals are necessary based upon previous assessment results as prescribed in\n§ 192.710(b)(2) is inadequate. For example, the reference to Section 5.6 depicts\nshorter intervals for integrity management segments based on predicted failure\npressures per ASME B31G. However, the procedure is unclear if the same process is\nto be utilized for pipeline segments addressed by the requirements of § 192.710;\n• EQT’s IMP Compliance procedures were inadequate with regard to identification of\nsegments that will be covered under those procedures as compared to any remaining\nsegments, and also does not address tool selection or other methods of assessment as\naddressed by § 192.710(c)(1). During the inspection, EQT indicated its IMP\nCompliance procedure is followed for segments addressed by § 192.710. However, a\nreview of documents, including tool selection for pipeline segment H-125, which is\ngoverned by the requirements of § 192.710, indicates the IMP Compliance procedure\nwas not applied to that segment.\nTherefore, EQT’s procedures required by § 192.605(b)(1) were inadequate to address the\nrequirements of § 192.710. EQT must amend its written procedures to address the deficiencies\nnoted above.\n3. § 192.605 Procedural manual for operations, maintenance, and emergencies.\n(a) …\n(b) Maintenance and normal operations. The manual required by\nparagraph (a) of this section must include procedures for the following,\nif applicable, to provide safety during maintenance and operations.\n(1) Operating, maintaining, and repairing the pipeline in\naccordance with each of the requirements of this subpart and subpart\nM of this part.\nEQT’s written procedures for operating and maintaining its pipeline in accordance with\nrequirements of Subpart L of 49 CFR Part 192 were inadequate to assure safe operation of a\npipeline facility. Specifically, Equitrans’ procedures addressing § 192.613 were inadequate.\nSection 192.613(a) states, in part, that “[e]ach operator shall have a procedure for continuing\nsurveillance of its facilities…” The requirement for continuing surveillance applies to the entire\npipeline facility, including non-covered pipeline segments not subject to the requirements of\nSubpart O of Part 192 (addressing gas transmission pipeline integrity management (IMP)). The\n\n\n\nprocedures required by § 192.605(e)7, which includes surveillance, must also be included within\nthe manual of written procedures for conducting operations and maintenance activities.\nDuring the inspection, PHMSA reviewed EQT’s O&M Manual Section 6.1 (Continuing\nSurveillance). However, Section 6.1 appeared to be solely applicable to covered segments within\nEQT’s IMP via reference specifically explaining that issues such as “[l]eakage history, corrosion,\nand substantial changes in cathodic protection requirements are reviewed as part of the Integrity\nManagement Program. The Integrity Management Program addresses the appropriate actions for\neach of these potential issues”.\nDuring the inspection, PHMSA also noted a lack of specific procedures within the O&M Manual,\nor specific references to other documents for the continuing surveillance of its pipeline facilities,\naddressing determination of and appropriate actions addressing changes in class location, failures,\nleakage history, corrosion, substantial changes in cathodic protection requirements, and other\nunusual operating and maintenance conditions. The O&M Manual also does not address relevant\napplicable roles, responsibilities or timeframes to manage MCAs or class locations once changes\nto population density or other unusual operations and maintenance conditions are identified or\noccur.\nTherefore, EQT’s procedures required by § 192.605(b)(1) were inadequate to address the\nrequirements of § 192.613 and subpart L of Part 192. EQT must amend its written procedures to\naddress the deficiencies noted above.\n4. § 192.605 Procedural manual for operations, maintenance, and emergencies.\n(a) …\n(b) Maintenance and normal operations. The manual required by\nparagraph (a) of this section must include procedures for the following,\nif applicable, to provide safety during maintenance and operations.\n(1) Operating, maintaining, and repairing the pipeline in\naccordance with each of the requirements of this subpart and subpart\nM of this part.\nEQT’s written procedures for operating and maintaining its pipeline in accordance with\nrequirements of Subpart L of 49 CFR Part 192 were inadequate to assure safe operation of a\npipeline facility. Specifically, EQT’s procedures for complying with § 192.611(d)8 were\ninadequate.\n7 § 192.605 Procedural manual for operations, maintenance, and emergencies.\n(a) . . .\n(e) Surveillance, emergency response, and accident investigation. The procedures required by §§ 192.613(a),\n192.615, and 192.617 must be included in the manual required by paragraph (a) of this section.\n8 §192.611 Change in class location: Confirmation or revision of maximum allowable operating pressure.\n(a) …\n(d) Confirmation or revision of the maximum allowable operating pressure that is required as a result of a study\nunder §192.609 must be completed within 24 months of the change in class location. Pressure reduction under\nparagraph (a) (1) or (2) of this section within the 24-month period does not preclude establishing a maximum\nallowable operating pressure under paragraph (a)(3) of this section at a later date.\n\n\n\nDuring the inspection, PHMSA reviewed EQT’s O&M Manual, Section 7.1, addressing class\nlocation determination in accordance with § 192.611. The following inadequacies were identified:\n• EQT’s procedures did not address process(es) for instances where current MAOP may\nnot be in accordance with requirements for an existing Class location;\n• EQT’s procedures did not address the process for actions from identification to resolution\nthat shall be taken in order to satisfy the specified 24-month timeline requirement of §\n192.611(d); and,\n• EQT’s procedures did not address roles, responsibilities or applicable timeframes to\nmanage class location changes once changes to population density, PIR, and/or identified\nsites that are identified or occur.\nTherefore, EQT’s procedures required by § 192.605(b)(1) were inadequate in addressing the\nrequirements of§ 192.611. EQT must amend its written procedures to address the deficiencies\nnoted above.\nResponse to this Notice\nThis Notice is provided pursuant to 49 U.S.C. § 60108(a) and 49 C.F.R. § 190.206. Enclosed as\npart of this Notice is a document entitled Response Options for Pipeline Operators in Enforcement\nProceedings.\nPlease refer to this document and note the response options. Be advised that all material you\nsubmit in response to this enforcement action is subject to being made publicly available. If you\nbelieve that any portion of your responsive material qualifies for confidential treatment under 5\nU.S.C. § 552(b), along with the complete original document you must provide a second copy of\nthe document with the portions you believe qualify for confidential treatment redacted and an\nexplanation of why you believe the redacted information qualifies for confidential treatment under\n5 U.S.C. § 552(b).\nFollowing the receipt of this Notice, you have 30 days to submit written comments, revised\nprocedures, or a request for a hearing under § 190.211. If you do not respond within 30 days of\nreceipt of this Notice, this constitutes a waiver of your right to contest the allegations in this Notice\nand authorizes the Associate Administrator for Pipeline Safety to find facts as alleged in this Notice\nwithout further notice to you and to issue an Order Directing Amendment. If your plans or\nprocedures are found inadequate as alleged in this Notice, you may be ordered to amend your plans\nor procedures to correct the inadequacies (49 C.F.R. § 190.206). If you are not contesting this\nNotice, we propose that you submit your amended procedures to my office within 30 days of\nreceipt of this Notice. This period may be extended by written request for good cause. Once the\ninadequacies identified herein have been addressed in your amended procedures, this enforcement\naction will be closed.\nIt is requested (not mandated) that EQT maintain documentation of the safety improvement costs\nassociated with fulfilling this Notice of Amendment (preparation/revision of plans, procedures)\nand submit the total to Robert Burrough, Director, Eastern Region, Pipeline and Hazardous\nMaterials Safety Administration. In correspondence concerning this matter, please refer to CPF 1-\n\n\n\n2024-040-NOA and, for each document you submit, please provide a copy in electronic format\nwhenever possible.\nSincerely,\nRobert Burrough\nDirector, Eastern Region\nPipeline and Hazardous Materials Safety Administration\nEnclosure: Response Options for Pipeline Operators in Enforcement Proceedings\n\n12024040NOA_Closure Letter_05132025_(23-276594)_text.pdf\n\nVIA ELECTRONIC MAIL TO: justin.trettel@eqt.com\nMay 13, 2025\nMr. Justin Trettel\nSenior Vice President\nEQT Production Company\n2200 Energy Drive\nCanonsburg, Pennsylvania 15317\nCPF 1-2024-040-NOA\nDear Mr. Trettel:\nOn October 31, 2022, through March 27, 2023, representatives of the Pipeline and Hazardous\nMaterials Safety Administration (PHMSA) pursuant to Chapter 601 of 49 United States Code\n(U.S.C.) conducted an inspection of EQT Production Company (EQT) procedures in Canonsburg,\nPA. As a result of the inspection, EQT was issued a Notice of Amendment on November 12, 2024,\nto amend certain aspects of its procedures.\nOn December 3, 2024, EQT requested an extension until January 31, 2025, which PHMSA\ngranted. EQT timely submitted its amended procedures on January 31, 2025. My staff reviewed\nthe amended procedures, and it appears that the inadequacies outlined in this Notice of Amendment\nhave been corrected.\nThis letter is to inform you no further action is necessary and this case is now closed. Thank you\nfor your cooperation.\nSincerely,\nRobert Burrough\nDirector, Eastern Region\nPipeline and Hazardous Materials Safety Administration","truncated":false,"body_characters":35469}