{"operation":"document","citation":"PHMSA-2017-0045","title":"Alaska Gas Development Corporation – AGDC — Pipeline Special Permit","source_type":"permit","agency":"Pipeline and Hazardous Materials Safety Administration","status":"current","official":true,"published_on":"2019-09-09","effective_on":"2019-09-09","summary":"PHMSA-2017-0045, issued 2019-09-09 for Alaska Gas Development Corporation – AGDC's gas transmission system.","machine_formats":{"json":"https://regulus.evalyn.ai/document/phmsa-special-permit-phmsa-2017-0045.json","markdown":"https://regulus.evalyn.ai/document/phmsa-special-permit-phmsa-2017-0045.md"},"app_url":"https://regulus.evalyn.ai/document/phmsa-special-permit-phmsa-2017-0045","source_url":"https://www.regulations.gov/docket/PHMSA-2017-0045","body":"PHMSA pipeline special permit PHMSA-2017-0045. Operator: Alaska Gas Development Corporation – AGDC. System: Gas Transmission. Issue date: 2019-09-09.\n\n<<<PAGE 1>>>\n\nC\nU.S. Department\nof Transportation\nPipeline and Hazardous\nMaterials Safety\nAdministration\nMr. Frank T. Richards, P.E.\nSenior Vice President, Program Management\nAlaska Gasline Development Corporation\n3201 C Street, Suite 200\nAnchorage, Alaska 99503\nSEP 9 2Q19 1200 New Jersey Avenue, SE\nWashington, D.C. 20590\nDocket No. PHMSA-2017-0045\nDear Mr. Richards:\nOn April 14, 2017, Alaska Gasline Development Corporation (AGDC) requested the Pipeline\nand Hazardous Materials Safety Administration (PHMSA) to issue a special permit to waive\ncompliance from 49 Code of Federal Regulations (CFR) 192.197(a)(4) for the Alaska LNG\nPipeline. The Alaska LNG Pipeline is an 807-mile 42-inch diameter natural gas transmission\npipeline that AGDC has proposed to build extending from the AGDC's proposed Gas Treatment\nPlant (GTP) on the North Slope of Alaska to the Liquefaction Facility on the shore of the Cook\nInlet near Nikiski, Alaska, including an offshore pipeline section crossing the Cook Inlet.\nPHMSA is granting this special permit (enclosed) for the 42-inch diameter Alaska LNG\nPipeline. This special permit provides relief from the Federal Pipeline Safety Regulations for\nthe AGDC special permit segments and requires ADGC to comply with certain conditions and\nlimitations designed to maintain pipeline safety. AGDC is authorized to design, construct, and\noperate the Alaska LNG pipeline with mainline block valve spacing of up to 50 miles in the\nvery sparsely populated region north of Fairbanks borough in Alaska, and up to 30 miles\nspacing south of Fairbanks in Class 1 locations. Section 192.179(a)(4) requires a maximum\nClass 1 location valve spacing of 20-miles.\nPHMSA grants this special permit based on the findings set forth in the \"Special Permit\nAnalysis and Findings\" and the \"Final Environmental Assessment and Finding ofNo\nSignificant Impact\" documents, which can be read in their entirety in Docket No. PHMSA-\n20 17-0045 in the Federal Docket Management System (FDMS) located at\nwww.regulations.gov.\n\n<<<PAGE 2>>>\n\nMy staff would be pleased to discuss this matter or any other regulatory matter with you.\nJohn Gale, Director of Standards and Rulemaking Division may be contacted at\n202-366-0434, on regulatory matters, and Sentho White, Director of Engineering and Research\nDivision, may be contacted at 202-493-2415, on technical matters specific to this special permit\ngrant.\nSincerely,\nA.bL'\nAssociate Administrator for Pipeline Safety\nEnclosure: Special Permit- PHMSA-2017-0045\nSEP-\n9 201t9\nPHMSA-2017-0045-Alaska LNG Pipeline- MLBV Spacing- LOD Page 2 of 2\n\n<<<PAGE 1>>>\n\nU.S. DEPARTMENT OF TRANSPORTATION\nPIPELINE AND HAZARDOUS MATERIALS SAFETY ADMINISTRATION\nSPECIAL PERMIT- Mainline Valve Spacing\nSpecial Permit Information:\nDocket Number:\nRequested By:\nOperator ID#:\nOriginal Date Requested:\nOriginal Issuance Date:\nEffective Date:\nCode Sections:\nPHMSA-2017-0045\nAlaska Gasline Development Corporation\n40015\nApril 14, 2017\nSeptember 9, 2019\nSeptember 9, 2019\n49 CFR 192.179(a)(4)\nGrant of Special Permit:\nBy this order, subject to the terms and conditions set forth below, the United States Department\nof Transportation, Pipeline and Hazardous Materials Safety Administration (PHMSA), Office of\nPipeline Safety (OPS),1 grants this special permit to Alaska Gasline Development Corporation\n(AGDC), owner and operator of the Alaska LNG Pipeline.2 This special permit waives\ncompliance from 49 Code of Federal Regulations (CFR) 192.179(a)(4) for sectionalizing\nmainline valve spacing in Class 1 locations. This special permit requires the use of remote\ncontrolled valves (RCV) or automatic shut-off valves (ASV) for the Alaska LNG Pipeline and\nmandates specific design, construction, operations, and maintenance procedures in accordance\nwith the special permit conditions.\n1 Throughout this special permit, the usage of\"PHMSA\" or \"PHMSA OPS\" means the U.S. Department of\nTransportation's Pipeline and Hazardous Materials Safety Administration, Office of Pipeline Safety.\n2 As used in these draft conditions, the term Alaska LNG Pipeline refers to the approximately 807 miles of 42-inch\nnatural gas transmission pipeline and not to any potential owners, operators or entities associated with the Alaska\nLNG Pipeline. The special permit owner, operator, and applicant/permittee names is Alaska Gasline\nDevelopment Corporation. Please note that this pipeline does not transport liquefied natural gas (LNG). It will\nsupply natural gas to a liquified natural gas (LNG) facility for further transportation as LNG\nPHMSA-2017-0045: Alaska Gasline Development Corporation Alaska LNG Pipeline- Special Permit for Mainline Valve Spacing\nPage 1 of 16\n\n<<<PAGE 2>>>\n\nI. Purpose and Need:\nThe Alaska LNG Pipeline will be approximately 807 miles of 42-inch-diameter steel pipe for\ntransporting natural gas from AGDC's gas treatment plant (GTP) on Alaska's North Slope to the\nliquefaction facility on the eastern shore ofthe Cook Inlet near Nikiski, Alaska. The pipeline\nwill be mostly onshore, with a segment of offshore pipeline crossing the Cook Irdet. The\nonshore portion of the pipeline will be a buried pipeline except for short, above-ground special\ndesign segments, such as aerial water crossings and aboveground fault crossings. The Alaska\nLNG Pipeline's design has a maximum allowable operating pressure (MAOP) of 2,075 pounds\nper square inch gauge (psig).\nAGDC is requesting a waiver of compliance with 49 CFR 192.179(a)(4) for remote, sparsely\npopulated segments along the 42-inch pipeline route. AGDC's special permit request is\nspecifically for the Class 1 location segments.3\nFederal pipeline safety regulations require natural gas transmission pipeline operators to have\nsectionalizing block valves within 10 miles of each point on the pipeline (or no more than 20\nmiles between sectionalizing mainline valves) in a Class 1 location. AGDC' s request allows for\na valve spacing greater than 20 miles in Class 1 locations but requires all ofthe mainline valves\nto be either RCVs or ASVs.\nII. Special Permit Segment:\nState of Alaska\nThe Alaska LNG Pipeline specialpermit segment is defined as: approximately 807 miles of 42-\ninch diameter pipeline originating in the North Slope Borough, traversing the Yukon-Koyukuk\nCensus Area, the Fairbanks North Star Borough, the Denali Borough, the Matanuska-Susitua\nBorough, and the Kenai Peninsula Borough. The specialpermit segment terminates at the\nliquefaction facility on the shore of the Cook Inlet near Nikiski, Alaska.\nThe special permit allows alternative mainline valve placement in Class 1 locations on the 42-\ninch specialpermit segment with the implementation ofthe special permit conditions.\n49 CFR 192.5 defines Class location units and class 1, 2, 3, and 4 locations.\nPHMSA-2017-0045: Alaska Gasline Development Corporation Alaska LNG Pipeline- Special Permit for Mainline Valve Spacing\nPage 2 of 16\n\n<<<PAGE 3>>>\n\nPHMSA hereby grants this special permit for the specialpermit segment based on the findings\nset forth in the \"Final Environmental Assessment and Findings ofNo Sign ficant Impact\"\ndocuments, which both can be read in their entirety in Docket No. PHMSA-2017-0045 in the\nFederal Docket Management System (FDMS) located on the internet at www.regulations.gov.\nIII. Conditions:\nPHMSA grants this special permit to AGDC for alternative mainline valve spacing subject to\nAGDC implementing the following conditions on the specialpermit segment as detailed below:\n1. Applicable Regulations: The specialpermit segment must be designed, constructed,\noperated, and maintained in accordance with 49 CFR Part 192, including but not limited to,\nthose requirements that are stated as pertaining to alternative MAOP (49 CFR 192.112,\n192.328, and 192.620), but with exception of the mainline valve spacing requirement 49 CFR\n192.179(a)(4). In addition to 49 CFR Part 192 conformance, the specialpermit segment\nmust also be designed, constructed, operated and maintained in accordance with the special\npermit conditions.\n2. Maximum Allowable Operating Pressure (MAOP): AGDC must operate the special\npermit segment at or below a maximum allowable operating pressure (MAOP) of 2,075\npounds per square inch gauge (psig). The specialpermit segment may be designed for\noperation up to 80% of specified minimum yield strength, allowing for pressure build-up and\noverpressure protection in accordance with 49 CFR 192.620(e).\nMainline Valve Spacin2, Control. Closure, Operations & Maintenance:\n3. Transmission Line Valves: Sectionalizing block valves along the specialpermit segment\nmust be spaced as shown in Table i4 and as follows for class location segments:5\na) Class 1 locations north of Fairbanks from Mile Post 0.00 to Mile Post 422 must have a\n50-mile maximum sectionalizing block valve spacing between block valves (each point\non the pipeline must be within 25 miles of a sectionalizing block valve).\n\"IfAGDC determines that the sectionalizing block valve spacing or operational controls (RCV or ASV), as shown\nin Table 1 need to be modified, AGDC must submit proposed changes to the conditions and Table ito PHMSA's Western\nRegion Director or PWv1SA Project Designee for review and a \"no objection\" letter must be received prior to the change by\nAGDC.\nTransmission line class locations are defined in 49 CFR 192.5.\nPHMSA-2017-0045: Alaska Gasline Development Corporation Page 3 of 16\nAlaska LNG Pipeline- Special Permit for Mainline Valve Spacing\n\n<<<PAGE 4>>>\n\n4. b) Class 1 locations south of Fairbanks from Mile Post 422 to Mile Post 807 must have a\n30-mile maximum sectionalizing block valve spacing between block valves (each point\non the pipeline must be within 15 miles of a sectionalizing block valve).\nc) Class 2, 3, and 4 locations between Mile Post 0.00 to Mile Post 807 must comply with the\nrequirements of 49 CFR 192.179.6\nd) High consequence areas (as defined in 49 CFR 192.903 and 192.905) located in Class 1\nand 2 locations, must comply with the requirements of 49 CFR 192.179.\nValve Monitoring, Control and Closure: All mainline valves7 within the specialpermit\nsegment must be controlled by a supervisory control and data acquisition (SCADA)\nsystem and must be equipped for remote monitoring and control, or remote monitoring and\nautomatic control, in accordance 49 CFR 192.620(d)(3)(iii), and the below requirements:\na. b. c. d. If any crossover or lateral pipe for gas receipts or deliveries connects to the isolated\nsegment between the upstream and downstream mainline valves, the nearest valve\non the crossover connection(s) or lateral(s) must be isolated, such that, when all\nvalves are closed, there is no flow path for gas to flow to the leak or rupture site\n(except for residual gas already in the shut-off segment);\nAll interconnect and/or meter and regulator stations must be monitored and capable\nof remote operation for isolating from the pipeline such that, when all valves are\nclosed, there is no flow path for gas to flow to the leak or rupture site (except for\nresidual gas already in the shut-off segment);\nMainline valves must be continuously monitored for valve status (open, closed, or\npartial closed/open), upstream pressure, and downstream pressure;\nClosure of the appropriate valves following a pipeline leak or rupture meeting the\ncriteria of Condition 4 must occur as soon as practicable from the time the\n6 Mile Post 0.00 to Mile Post 807 is the starting and ending mile posts ofthe specialpermit segment. Ifthe length\nofthe pipeline length should change due to routing or survey changes, these mile posts must be adjusted based\nupon these changes.\nBoth RCV and ASV are permissible at sectionalizing mainline valves locations. RCV's must be installed at all\npowered and teleconnnunications-equipped locations, that are: compressor, heater and metering locations.\nPHMSA-2017-0045: Alaska Gasline Development Corporation Alaska LNG Pipeline- Special Permit for Mainline Valve Spacing\nPage 4 of 16\n\n<<<PAGE 5>>>\n\npipeline leak or rupture location is confirmed, not to exceed 30 minutes from such\nconfirmation;8\ni. \"Rupture\" means a significant breach of a pipeline that results in a large-\nvolume, uncontrolled release of gas, over a short period oftime as defined\nbelow. For purposes ofthis special permit, AGDC must treat all the\nfollowing as ruptures:\n1. Specialpermit segment pressure drops to 75% of the operating\npressure at the sectionalizing mainline valve based upon maximum\nflow model gradients for the upstream compressor station discharge\nat MOP (2050 psig). In addition, ASV set-points must not be less\nthan that required to actuate the valve before a downstream RCV\nactuates;9\n2. A release of gas observed or reported to the operator by its field\npersonnel, nearby pipeline or utility personnel, the public, local\nresponders, or public authorities, and that may be representative of\nan unintentional and uncontrolled release event defined in\n3. 4. paragraphs (3) or (4) ofthis definition;\nAn unanticipated or unplanned pressure loss of 10 percent or greater,\noccurring within a time interval of 15 minutes or less, unless the\noperator has documented in advance of the pressure loss the need for\na higher pressure-change threshold due to pipeline flow dynamics\nthat cause fluctuations in gas demand that are typically higher than a\npressure loss of 10 percent in a time interval of 15 minutes or less; or\nAn unexplained flow rate change, pressure change, instrumentation\nindication, or equipment function that may be representative of an\nevent defined in paragraph (2) of this definition.\n8 The pipeline valve section location to be closed and isolated (ifthere should be a leak or rupture) must be\nconfirmed by AGDC through Gas Control or other field operations personnel monitoring ofthe appropriate\npipeline pressures, pressure changes, or flow rate changes through a compressor discharge section, meter stations,\nor by location confirmation from responsible persons.\n9AGDC must notify the PHMSA Western Region Director in writing ofthe reasons the pressure drop cannot be met\nand obtain a letter of\"no objection\" from PHMSA prior to implementing any pressure drop below 75% of\nmaximum operating pressure based upon pressure loss through flow gradient.\nPHMSA-2017-0045: Alaska Gasline Development Corporation Page 5 of 16\nAlaska LNG Pipeline- Special Permit for Mainline Valve Spacing\n\n<<<PAGE 6>>>\n\ne. f. Note: Rupture identification occurs when a rupture, as defined in\nthis section, is observed by or reported to pipeline operating\npersonnel or a controller.\nii. Within five (5) minutes ofthe initial notification to AGDC, AGDC must\nevaluate and identify a rupture, as defined above, as being either an actual\nleak event, rupture event or non-rupture event in accordance with operating\nprocedures and 49 CFR 192.615. Once a rupture is verified, closure of the\nappropriate valves must comply with the timing requirements of Condition\n4(d).\nThe Alaska LNG PipelineGas Control Center must monitor the pipeline 24 hours\na day, 7 days a week, and must confirm the existence of a leak or rupture as soon\nas practicable in accordance with Condition 4(d);\nAGDC must maintain remote monitoring and automatic control equipment,\nmainline valves, mainline valve operators, and pressure sensors in accordance\nwith 49 CFR 192.63 1 and 192.745. All remote monitoring and automatic control\nequipment including pressure sensors must have backup power to maintain\ncommunications and control to the AGDC Gas Control Center during power\noutages;\ng. AGDC must conduct a point-to-point verification between SCADA displays and\nthe mainline valve, sensors, and communications equipment in accordance with 49\nCFR 192.63 1(c) and (e);\nh. All valves used to isolate a leak or rupture must be maintained in accordance with\nthis special permit and 49 CFR 192.745;\ni. AGDC must take remedial measures to correct any valve used to isolate a leak or\nrupture that is found to be inoperable or unable to maintain shut-off, as follows:\ni. Repair or replace the valve as soon as practicable, but no later than six (6)\nmonths after the finding;\nii. Designate an alternative valve within seven (7) calendar days of the\nfinding while repairs are being made; and\niii. If valve repair or replacement cannot be met due to circumstances\nbeyond AGDC's control, AGDC must notify the PHMSA Western\nRegion Director or Project Designee in writing of the reasons the\nPHMSA-2017-0045: Alaska Gasline Development Corporation Page 6 of 16\nAlaska LNG Pipeline- Special Permit for Mainline Valve Spacing\n\n<<<PAGE 7>>>\n\nschedule cannot be met and obtain a letter of \"no objection\" from\nPHMSA prior to implementing the schedule change.\n5. Mainline Valve Locations: Mainline valves will be sited per Table 1:\nTable 1: Mainline Valve Locations for Alaska LNG_Pipeline'0\nMLBV # MP A MJ Location Description Valve\nType\nClass\nLocation(s)\nHCA\nYes/No\n1 0.00 GTP Meter Station RCV 1 No\n2 36.74 36.74 Stand-alone MLBV- Potential Station ASV 1 No\n3 75.97 39.23 Compressor Station- Sagwon RCV 1 No\n4 112.04 36.07 Stand-alone MLBV- Potential Station ASV 1 No\n5 148.51 36.47 Compressor Station- Galbriath Lake RCV 1 No\n6 194.09 45.58 Stand-alone MLBV- Potential Station ASV 1 No\n6 194.09 45.58 Stand-alone MLBV- Potential Station ASV 1 No\n7 240.10 46.01 Compressor Station- Coldfoot RCV 1 No\n8 286.05 45.95 Stand-alone MLBV- Potential Station ASV 1 No\n9 332.64 46.59 Compressor Station- Ray River RCV I No\n9A 356.22 23.58 Added for potential \"Hotspot Café\" HCA ASV I No\n10 377.95 21.78 Stand-alone MLBV- Potential Station ASV 1 No\n11 421.56 43.61 Compressor Station- Minto RCV 1 No\n12 444.90 23.34 Stand-alone MLBV ASV 1 No\n13 467.10 22.20 Stand-a1oneMLBV-PotentialStation ASV 1 No\n14 492.96 25.86 Stand-alone MLBV ASV 1 No\n15 517.62 24.66 CompressorStation -Healy RCV 1 No\n16 534.79 17.17 Upstream of Class 3 Location- Nenana Canyon ASV 1 No\n17 538.79 4.00 Downstream of Class 3 Location- Nenana Canyon ASV 1 No\n18 546.50 7.71 Stand-alone MLBV- Potential Station ASV 1 No\n19 572.23 25.73 Stand-alone MLBV ASV 1 No\n20 597.35 25.12 Compressor Station- Honolulu Creek RCV I No\n21 625.83 28.48 Stand-alone MLBV ASV I No\n22 648.16 22.33 Stand-alone MLBV- Potential Station ASV I No\n23 675.24 27.08 Compressor Station- Rabideux Creek RCV I No\n24 703.67 28.43 Stand-alone MLBV- Potential Station ASV I No\n25 725.93 22.26 Stand-alone MLBV- Potential Station ASV I No\n26 749.11 23.18 Heater Station- Theodore River RCV 1 No\n° Sectionalizing mainline valve siting is based upon the latest route revision C2 and may be subject to change with\nfuture route alternatives. The final siting will follow the requirements and limitations ofthe special permit\nconditions.\nPHMSA-2017-0045: Alaska Gasline Development Corporation Alaska LNG Pipeline- Special Permit for Mainline Valve Spacing\nPage 7 of 16\n\n<<<PAGE 8>>>\n\nTable 1: Mainline Valve Locations for Alaska LNG_Pipeline10\nMLBV # MP A MP Location Description Valve\nType\nClass\nLocajons3\nHCA\nYes/No\n27 766.01 16.90 UpstreamofCooklnletcrossing ASV 1 No\n28 793.34 27.33 Downstream of Cook Inlet crossing RCV 1 No\n29 799.85 6.51 Stand-alone MLBV- Potential Class 2 Location RCV 2 No\n30 806.57 6.72 LNG Meter Station RCV 1 No\n6. Emergency Operations:\na) Alaska LNG Pipeline control center operators must continually monitor position and\noperational status of all RCVs affected by a leak/rupture event until positive isolation\nofthe effected segment is confirmed.\nb) AGDC must immediately and directly notify the appropriate public safety access\npoint (9-1-1 emergency call center) or other coordinating agency for the communities\nand jurisdictions in which the pipeline is located when a release is indicated.\nc) AGDC must establish actions required to be taken by a pipeline controller, or the\nappropriate emergency response coordinator, during an emergency in accordance\nwith these special permit conditions and as required in 49 CFR 192.615 and 192.631.\nd) Emergency closure drills simulating shutting down a randomly selected section of\ntransmission line must be performed at least once in a calendar year, but within an\ninterval not to exceed 15 months. AGDC may conduct a table-top emergency closure\ndrill to meet this requirement for no more than two out of each three calendar years.\nThe operator will conduct a site-specific emergency closure drill at a field site at least\nonce every three calendar years.\n7. Emergency Training and Planning: AGDC must develop and implement emergency\nresponse plans and procedures for the specialpermit segment in accordance with 49 CFR\n192.6 15 and the following requirements:\na. Identify the appropriate public safety access point (911 emergency call center), fire,\npolice, and other public officials to be notified;\nAGDC must designate the pipeline controller or the appropriate operator emergency response coordinator in its\noperating procedures and train the pipeline controller or the appropriate operator emergency response\ncoordinator for coordinating with emergency responders.\nPHMSA-2017-0045: Alaska Gasline Development Corporation Page 8 of 16\nAlaska LNG Pipeline- Special Permit for Mainline Valve Spacing\n\n<<<PAGE 9>>>\n\nb. c. Identify responsibility, resources, jurisdictional area, and emergency contact telephone\nnumbers for both local and out-of-area calls of each government organization that may\nrespond to a pipeline emergency; and\nInform emergency officials (911 emergency call centers, fire, police, and other public\nofficials) about the operator's ability to respond to the pipeline emergency and means of\ncommunication.\nd. Emergency response plans must be reviewed, updated and communicated, as required\nin this Condition 7 and 49 CFR 192.615(b) and (c), on a calendar year basis, not to\nexceed 15 months.\nReportin2 and Certification:\n8. Annual Reports: Within twelve (12) months following pipeline start-up'2 and annually13\nthereafter, AGDC must report the following to the PHMSA Western Region Director or\nProject Designee, with copies to the Director, PHMSA Engineering and Research\nDivision, and Director, PHMSA Standards and Rulemaking Division:'4' 15\na) The number of new residences, identified sites, or other structures intended for human\noccupancy and public gathering areas built within a potential impact radius (PIR) of\nthe specialpermit segment, as defined in 49 CFR 192.903;\nb) Any reportable incidents associated with the specialpermit segment that occurred\nduring the previous year;\nc) Any emergency events that cause closure of mainline valves as described in\nCondition 4, including the location (mile post) of valves and closure times;\nd) Any emergency drills performed in accordance with Condition 6(d). Submit a brief\ndescription of the emergency drill and date of the drill; and\n12 Pipeline start-up is defined as an interval during which the pipeline system begins operations, and throughput\n(product flow through the pipeline) is ramped to commercial capacity.\n13 Annual reports must be received by PHMSA by the last day ofthe month of pipeline start-up. For example, the\nannual report for pipeline start-up beginning March 7, 2021, must be received by PHMSA no later than March\n3 1S each year beginning in 2022.\n14 Upon notice to the AGDC, PHMSA may update reporting contacts for Condition 7.\n' AGDC must place a copy of each Alaska LNG Pipeline annual report on the PHMSA docket, PRMSA-20 17-\n0045, at www.regulations.gov.\nPHMSA-2017-0045: Alaska Gasline Development Corporation Alaska LNG Pipeline- Special Permit for Mainline Valve Spacing\nPage 9 of 16\n\n<<<PAGE 10>>>\n\ne) Any company mergers, acquisitions, transfers of assets, or other events affecting the\nregulatory responsibility of the company operating the pipeline to which this special\npermit applies.\n9. Notifications: AGDC must notify the PHMSA UPS Western Region Director or Project\nDesignee, at least 14 days prior to conducting field activities associated with the special\npermit segment to meet Conditions 6(d).\n10. Certification:\na) A senior executive officer of AGDC, vice president or higher, must certify in writing\nthat:\nb) c) i. The specialpermit segment meets the conditions described in this special permit\n(including applicable sections 49 CFR 192.112, 192.328, and 192.620 for\nalternative MAOP) and other applicable sections of 49 CFR Part 192; and\nii. The written manual of O&M procedures required by 49 CFR 192.605 for the\nAlaska LNG Pipeline includes all additional operating and maintenance\nrequirements of this special permit and 49 CFR Part 192;\nThe certification must be sent to PHMSA within three (3) months ofplacing the\nAlaska LNG Pipeline into natural gas service.\nAGDC must send a copy of the certifications required in this condition, with\ncompletion dates, compliance documentation summary, and the required senior\nexecutive signature and date of signature to the PHMSA Associate Administrator for\nPipeline Safety, with copies to the Deputy Associate Administrator for Pipeline\nSafety, PHMSA Field Operations; Deputy Associate Administrator, PHMSA Policy\nand Programs; PHMSA Western Region Director; Director, PHMSA Standards and\nRulemaking Division; Director, PUMSA Engineering and Research Division; and to\nthe Federal Register Docket (PHMSA-2017-0045) at www.regulations.gov.\n11. AGDC may propose changes to these special permit conditions by making a request to\nPHMSA in writing. Any proposed changes to the conditions by AGDC must maintain\nequivalent levels of safety, as determined by PHMSA. PHMSA will determine whether\nsubstantive changes to the conditions require a modification or public notice ofthis special\npermit. PHMSA will provide AGDC with notice of its decision and an opportunity to\nPHMSA-2017-0045: Alaska Gasline Development Corporation Alaska LNG Pipeline- Special Permit for Mainline Valve Spacing\nPage 10 of 16\n\n<<<PAGE 11>>>\n\nrespond to any PHMSA-proposed changes to AGDC's request in accordance with 49 CFR\n190.341. Any submittal timing, review timing, or completion timing in these conditions can\nbe modified by PHMSA upon request by AGDC and with a \"no objection\" letter from\nPHMSA'6 to AGDC.\nIV. Limitations:\nThis special permit is subject to the limitations set forth in 49 CFR 190.34 1 as well as the\nfollowing limitations:\n1) PHMSA has the sole authority to make all determinations on whether AGDC has complied\nwith the specified conditions of this special permit for the Alaska LNG Pipeline. Failure to\ncomply with any condition ofthis special permit may result in revocation ofthe permit.\n2) Any work plans and associated schedules for the Alaska LNG Pipeline supporting this\nspecial permit are automatically incorporated into this special permit and are enforceable in\nthe same manner.\n3) Failure by AGDC to submit the certifications required by Condition 10 (Certification)\nwithin the time frames specified may result in revocation ofthis special permit.\n4) As provided in 49 CFR 190.341, PHMSA may issue an enforcement action for failure to\ncomply with this special permit for the Alaska LNG Pipeline. The terms and conditions\nof any corrective action order, compliance order or other order applicable to a pipeline\nfacility covered by this special permit will take precedence over the terms ofthis special\npermit.\n5) If AGDC sells, merges, transfers, or otherwise disposes of all or part of the assets known as\nthe Alaska LNG Pipeline, AGDC must provide PHMSA with written notice of the change\nwithin 30 days of the consummation date. In the event of such transfer, PHMSA reserves the\nright to revoke, suspend, or modify the special permit ifthe transfer constitutes a material\nchange in conditions or circumstances underlying the permit.\n16 AGDC must submit any proposed changes to the conditions to PHMSA Western Region Director or PHIMSA\nproject designee for review and a letter of \"no objection\" prior to usage.\nPHMSA-2017-0045: Alaska Gasline Development Corporation Alaska LNG Pipeline- Special Permit for Mainline Valve Spacing\nPage 11 of 16\n\n<<<PAGE 12>>>\n\nAUTHORITY: 49 U.S.C. 60118 and 49 CFR 1.97.\nSEP 9 2019\nIssued in Washington, DC on\nAIbJJ\nAssociate Administrator for Pipeline Safety\nFigure 1: Alaska LNG Pipeline Route\nPHMSA-2017-0045: Alaska Gasline Development Corporation Alaska LNG Pipeline- Special Permit for Mainline Valve Spacing\nPage 12 of 16\n\n<<<PAGE 13>>>\n\n0 t L)eaLitofL ea\nup o\nSL -4EM\n/\n- MP\nMP200\n3\n- J\n'1 /uioo\\ /14\\\n.1\nuc /IIW4j7\nLAP5OO\n,/ 1'\n/ /-_\n( 7\nr- ;p\nkDth _&!_) (I\n'z_ /\nA\n(\n3¯ftf¯ m.\nP8OG\nGulf of Alaska\nWkk\nPHMSA-2017-0045: Alaska Gasline Development Corporation Alaska LNG Pipeline- Special Permit for Mainline Valve Spacing\nPage 13 of 16\n\n<<<PAGE 14>>>\n\nTable 2: Mainline Valve Locations for Alaska LNG Pipeline with High Consequence Areas, Bridges, and\nRailroad Locations\nMLBV MP.\nA MP, miles. . .\nLocation Description Valve Class HCA\nType Location(s) Yes/No\n1 0.00 GTP Meter Station RCV 1 No\n2 36.74 36.74 Stand-alone MLBV- Potential Station ASV 1 No\n3 75.97 39.23 Compressor Station- Sagwon RV No\n4 112.04 36.07 Stand-alone MLBV- Potential Station ASV No\n5 148.51 36.47 Compressor Station- Gaibriath Lake RCV 1 No\n6 194.09 45.58 Stand-alone MLBV- Potential Station ASV 1 No\n6 194.09 45.58 Stand-alone MLBV- Potential Station ASV 1 No\n236.08 to 1.25 HCA -Marion Campground- 1.25 miles 1 Yes\n7 240.10 46.01 Compressor Station- Coldfoot RCV 1 No\n8 286.05 45.95 Stand-alone MLBV- Potential Station ASV No\n9 332.64 46.59 Compressor Station- Ray River RCV No\n352.21 to 1.14 HCA-Hotspot Café 1 Yes\n9a 356.22 23.58 Added for potential \"Hotspot Café\" HCA ASV 1 No\n10 377.95 21.73 Stand-alone MLBV- Potential Station ASV 1 No\n11 421.56 43.61 Compressor Station- Minto RCV 1 No\n12 444.90 23.34 Stand-alone MLBV ASV 1 No\n13 467.10 22.20 Stand-alone MLBV- Potential Station ASV 1 No\n14 492.96 25.86 Stand-alone MLBV ASV 1 No\n15 517.62 24.66 COmpressorStation -Healy RCV 1 No\n529.21 to 1.23 HCA-RV Park and Hotel- 1.23 miles 1 Yes\n532.07 Alaska Railroad Crossing No\n532.13 Nenana River Bridge Crossing No\n16 534.79 17.17 Upstream of Class 3 Location- Nenana Canyon ASV 1 No\nHCA- Denali Riverside RV Park, McKinley Chalet\nResort, Denali Rainbow Village and RV, Denali\n535 54 0.45 Princess Wilderness Lodge, Denali Crows Nest 1 Yes\n990 Cabins, Grarid Denali Lodge, and Denali Bluffs Hotel\n-2.20 miles\nHCA- Denali Riverside RV Park, McKinley Chalet\n535 99 Resort, Denali Rainbow Village and RV, Denali\n536 49 0.50 Princess Wilderness Lodge, Denali Crows Nest 3 Yes\nCabins, Grand Denali Lodge, and Denali Bluffs Hotel\n-2.20 miles\nHCA- Denali Riverside RV Park, McKinley Chalet\n536 49 Resort, Denali Rainbow Village and RV, Denali\n537 1.25 Princess Wilderness Lodge, Denali Crows Nest 1 Yes\nCabins, Grand Denali Lodge, and Denali Bluffs Hotel\n-2.20 miles\nPHMSA-2017-0045: Alaska Gasline Development Corporation Alaska LNG Pipeline- Special Permit for Mainline Valve Spacing\nPage 14 of 16\n\n<<<PAGE 15>>>\n\nTable 2: Mainline Valve Locations for Alaska LNG Pipeline with High Consequence Areas, Bridges, and\nRailroad Locations\nMLBV Valve Class HCA\n# MP A MP, miles. .\nLocation Description Type Location(s) Yes/No\n537.79 Lynx Creek Bridge Crossing 1 Yes\n17 538.79 4.00 Downstream of Class 3 Location- Nenana Canyon ASV 1 No\n18 546.50 7.71 Stand-alone MLBV- Potential Station ASV 1 No\n551.34 to 0.93 HCA- Denali Perch Resort- 0.93 miles 1 Yes\n565.77 to 1.46 HCA- DOT/PF Cantwell Station- 1.46 miles 1 Yes\n19 572.23 25.73 Stand-alone MLBV ASV No\n572.79 Alaska Railroad Crossing 1 No\n588.07 Alaska Railroad Crossing 1 No\n20 597.35 25.12 Compressor Station- Honolulu Creek RCV 1 No\n609.02 Alaska Railroad Crossing 1 No\n21 625.83 28.48 Stand-alone MLBV ASV 1 No\n629.75 to 1 60 HCA-Byers Lake Campground (73 units)- 1.60 1 Yes\n631.35 miles\n633.75 to 0.75 HCA- Trappers Creek Pizza Club -0.75 miles 1 Yes\n22 648.16 22.33 Stand-alone MLBV- Potential Station ASV 1 No\n23 675.24 27.08 Compressor Station- Rabideux Creek RCV 1 No\n24 703.67 28.43 Stand-alone MLBV- Potential Station ASV 1 No\n25 725.93 22.26 Stand-alone MLBV- Potential Station ASV 1 No\n26 749.11 23.18 Heater Station- Theodore River RCV 1 No\n27 766.01 16.90 UpstreamofCooklnletcrossing ASV 1 No\n28 793.34 27.33 Downstream of Cook Inlet crossing RCV 1 No\nHCA-Nikiski Middle/High School, Kenai Heliport,\n797 71 0.94 Commercial Buildings, and Industrial Sites- 1.57 1 Yes\n798 65 miles\nHCA-Nikiski Middle/High School, Kenai Heliport,\n798 65 0.63 Commercial Buildings, and Industrial Sites- 1.57 2 Yes\n799 28° miles\n799.28 to 1.99 2 No\n801.27\n29 799.85 6.51 Stand-alone MLBV- Potential Class 2 Location RCV 2 No\n803.39 to HCA- Conoco Phillips Property and Tesoro Kenai\n803.78 0 39 Refinery -2.66 miles I Yes\n803.78 to HCA- Conoco Phillips Property and Tesoro Kenai 2\n806.05 2 27 Refinery -2.66 miles Yes\n806.05 to 0.20 2 No\n806.25\nPHMSA-2017-0045: Alaska Gasline Development Corporation Alaska LNG Pipeline- Special Permit for Mainline Valve Spacing\nPage 15 of 16\n\n<<<PAGE 16>>>\n\nTable 2: Mainline Valve Locations for Alaska LNG Pipeline with High Consequence Areas, Bridges, and\nRailroad Locations\nMLBV I Valve I Class HCA\n# MP\nI A MP, miles\ni Location Description\nI Type Location(s) Yes/No\n30 806.57 6.72 LNG Meter Station RCV 1 No\nPHMSA-2017-0045: Alaska Gasline Development Corporation Alaska LNG Pipeline- Special Permit for Mainline Valve Spacing\nPage 16 of 16\n\n<<<PAGE 1>>>\n\nU.S. DEPARTMENT OF TRANSPORTATION\nPIPELINE AND HAZARDOUS MATERIALS SAFETY ADMINISTRATION\nMainline Block Valve Spacing\nSpecial Permit Analysis and Findings\nSpecial Permit Information:\nDocket Number: PHMSA-2017-0045\nRequested By: Alaska Gasline Development Corporation\nOperator ID#: 40015\nOriginal Date Requested: April 14, 2017\nOriginal Issuance Date: September 9, 2019\nEffective Dates: September 9, 2029\nCode Section(s): 49 CFR 192.179(a)(4)\nPurpose:\nThe Pipeline and Hazardous Materials Safety Administration (PHMSA)1 provides information to\ndescribe the facts of the subject special permit application submitted by the Alaska Gasline\nDevelopment Corporation (AGDC), owner and operator of the Alaska LNG Pipeline,\n2 to discuss any\nrelevant public comments received with respect to the application for a special permit, to present the\nengineering/safety analysis, and to make public the findings regarding whether the requested special\npermit should be granted and if so under what conditions. AGDC requested a special permit for the\nAlaska LNG Pipeline to waive compliance from 49 Code of Federal Regulations (CFR)\n192.179(a)(4) for sectionalizing mainline block valve spacing in Class 1 locations in Alaska.\n1 Throughout this special permit the usage of “PHMSA” or “PHMSA OPS” means the U.S. Department of\nTransportation’s Pipeline and Hazardous Materials Safety Administration Office of Pipeline Safety.\n2 Alaska LNG Pipeline refers to the approximately 807 miles of 42-inch natural gas transmission pipeline and not to any\npotential owners, operators, or entities associated with the Alaska LNG Pipeline. The special permit owner, operator,\nand applicant/permittee is Alaska Gasline Development Corporation. Please note that this pipeline does not transport\nliquefied natural gas (LNG). It will supply natural gas to a LNG facility for further transportation as LNG.\nPHMSA-2017-0045 - - Alaska Gasline Development Corporation Alaska LNG Pipeline – Special Permit Analysis & Findings\nPage 1 of 11\n\n<<<PAGE 2>>>\n\nPipeline System Affected:\nThe Alaska LNG Pipeline will be approximately 807 miles of 42-inch-diameter steel pipe for\ntransporting natural gas from AGDC’s gas treatment plant (GTP) on Alaska’s North Slope to the\nliquefaction facility on the eastern shore of the Cook Inlet near Nikiski, Alaska. The pipeline will be\nmostly onshore, with a segment of offshore pipeline crossing the Cook Inlet. The onshore portion of\nthe pipeline will be a buried pipeline except for short, above-ground special design segments, such\nas aerial water crossings and aboveground fault crossings. The Alaska LNG Pipeline’s design has a\nmaximum allowable operating pressure (MAOP) of 2,075 pounds per square inch gauge (psig).\nAGDC is requesting a waiver of compliance of 49 CFR 192.179(a)(4) for remote, sparsely populated\nsegments along the 42-inch pipeline route. AGDC’s special permit request is specifically for the\nClass 1 location segments.3\nFederal pipeline safety regulations require natural gas transmission pipeline operators to have\nsectionalizing block valves within 10 miles of each point on the pipeline (or no more than 20 miles\nbetween sectionalizing mainline valves) in a Class 1 location. AGDC’s request allows for a valve\nspacing greater than 20 miles in Class 1 locations but requires all mainline block valves to be either\nremote controlled valves (RCVs) or automatic shut-off valves (ASVs).\nSpecial Permit Request:\nAGDC requested increased spacing of sectionalizing mainline block valves along the special permit\nsegment as follows:\nTransmission Line Valves: Sectionalizing block valves along the special permit segment must\nbe spaced as shown in Tables 1 and 24 and as follows for class location segments:\na) Class 1 locations north of Fairbanks from Mile Post 0.00 to Mile Post 422 must have a 50-\nmile maximum sectionalizing block valve spacing between block valves (each point on the\npipeline must be within 25 miles of a sectionalizing block valve).\n3 49 CFR 192.5 defines Class location units and class 1, 2, 3, and 4 locations.\n4 If AGDC determines that the sectionalizing block valve spacing or operational controls (RCV or ASV) as shown in\nTable 1 need to be modified, AGDC must submit proposed changes to the conditions and Table 1 to PHMSA’s Western Region\nDirector or PHMSA Project Designee for review, and a “no objection” letter must be received prior to the change by AGDC.\nPHMSA-2017-0045 - - Alaska Gasline Development Corporation Alaska LNG Pipeline – Special Permit Analysis & Findings\nPage 2 of 11\n\n<<<PAGE 3>>>\n\nb) Class 1 locations south of Fairbanks from Mile Post 422 to Mile Post 807 must have a 30-\nmile maximum sectionalizing block valve spacing between block valves (each point on the\npipeline must be within 15 miles of a sectionalizing block valve).\nc) Class 2, 3, and 4 locations between Mile Post 0.00 to Mile Post 807 must comply with the\nrequirements of 49 CFR 192.179.\nd) High consequence areas (as defined in 49 CFR 192.903 and 192.905) located in Class 1 and\n2 locations, must comply with the requirements of 49 CFR 192.179.\nPHMSA designed a comprehensive set of special permit conditions that AGDC is required to\nimplement in order to operate the 42-inch diameter pipeline with an increased mainline block valve\nspacing. An overview of the special permit condition topics is in the Operational Integrity\nCompliance section of this document. The special permit conditions were based upon pipeline\nsafety considerations for the 49 CFR Part 192 sections that AGDC was seeking relief for an\nalternative mainline block valve spacing.\nThe usage of remote controlled valves (RCVs) and automatic shut-off valves (ACVs) will reduce the\ntime to isolate a pipeline segment should there be a rupture on the pipeline. In remote locations\nwhere it could take over 1 hour to isolate a pipeline segment, the Alaska LNG Pipeline will be able\nto isolate a pipeline segment in less than 35 minutes. The time to isolate a mainline block valve\n(MLBV) along the special permit segment is shown in Table 2 - MLBV Locations with\nApproximate Valve Closure Time and Gas Released.\nSpecial Permit Segment:\nState of Alaska\nThe Alaska LNG Pipeline special permit segment is defined as: approximately 807 miles of 42-inch\ndiameter pipeline originating in the North Slope Borough, traversing the Yukon-Koyukuk Census\nArea, the Fairbanks North Star Borough, the Denali Borough, the Matanuska-Susitna Borough, and\nthe Kenai Peninsula Borough. The special permit segment terminates at the liquefaction facility on\nthe shore of the Cook Inlet near Nikiski, Alaska.\nThe special permit allows alternative mainline valve placement in Class 1 locations on th","truncated":true,"body_characters":131610}