Point Thomson Project - DOG
Point Thomson ProjectUSPT-WP-YBDES-060001, Rev 3POINT THOMSON DESIGN BASIS FORPERMITTING – EXPORT PIPELINESeptember, 2011Table of Contents1.INTRODUCTION . 71.1Purpose . 72.GENERAL DESIGN AND CRITERIA.102.1Liquid Hydrocarbon Properties and Characteristics .102.2Extent of Subject Facilities .112.3Design Life .132.4Regulations, Standards and Codes .133.PHYSICAL FEATURES/CIVIL .153.1Topography/Oceanography .153.2Climate/Meteorology .163.3Geotechnical .163.4Hydrology .203.5Seismicity .213.6Export Pipeline Routing .223.7Road Crossings .233.8High Consequence Area Evaluation and Selection .254.STRUCTURAL .264.1Vertical Support Members .264.2Design Loads .274.3Foundation Design .274.4Stream Crossings .294.4.1 Scour .304.4.2 Freshwater Ice .314.4.3 Bank Migration .334.4.4 Pipe Elevation .334.5Storm Surges and Sea Ice Run-up .335.MECHANICAL .345.1Steady State Hydraulics .345.2Surge Analysis.355.3Pipe Wall Thickness Considerations .365.3.1 Design Factor .365.3.2 Corrosion Allowance .365.3.3 Accidental Bullet Impact.365.4Export Pipeline Design Loading Categories .365.4.1 Internal Design Pressure .375.4.2 Surge Pressure .375.4.3 Hydrostatic Testing .375.4.4 Dead and Live Loads .385.4.5 Snow and Ice Loads .38Page 2 of 57
Point Thomson ProjectUSPT-WP-YBDES-060001, Rev 3POINT THOMSON DESIGN BASIS FORPERMITTING – EXPORT PIPELINESeptember, 20115.4.6 Wind Load .385.4.7 Temperature Differential .385.4.8 Earthquake Loads.385.4.9 Loss of Support.385.4.10 Wind Induced Vibration .395.5Pipe Stress Criteria .395.5.1 Allowable Stresses .395.5.2 Load Combinations .405.6Configuration .425.7Facilities .435.8Material Selection .445.9Guides, Slides, and Anchors.455.10 Wind Induced Vibration Prevention and Mitigation .456.WELDING .476.1Welding Criteria .477.HYDROSTATIC TESTING .488.CLEANING AND DRYING.499.INTEGRATED CONTROL AND SAFETY SYSTEM (ICSS) .509.1General Description of ICSS .509.1.1 Process Control System (PCS) .509.1.2 Safety Instrumented System (SIS) .509.1.3 Fire Detection System (FDS) .509.1.4 Third Party Equipment .509.2Communication System .519.3Leak Detection System .519.4Fire Detection and Suppression System .519.5Gas Detection System .5210. OPERATIONS.5310.1 Flow Control .5310.2 Pipeline Isolation .5310.3 Pressure Monitoring and Relief .5310.4 Start-up.5410.5 Flow Constraints .5410.6 Normal Operations .5410.7 Planned and Unplanned Shutdown of Liquid Hydrocarbon Line .5410.8 Maintenance .5410.9 Dismantle, Remove, and Restore .5510.10 Surveillance .5511. CORROSION CONTROL AND MONITORING .5611.1 Corrosion Control Measures .5611.1.1 Internal Corrosion .56Page 3 of 57
Point Thomson ProjectUSPT-WP-YBDES-060001, Rev 3POINT THOMSON DESIGN BASIS FORPERMITTING – EXPORT PIPELINESeptember, 201111.1.2 External Corrosion .5611.2 In-Line Inspection .5612. RISK ASSESSMENTS .57TablesTable 2.1Table 2.2Table 3.1Table 4.1Point Thomson Liquid Hydrocarbon Composition . 10Point Thompson Liquid Hydrocarbon Properties and Characteristics . 11Spectral Response Accelerations . 22Steel Shapes and Grades Typically Meeting Charpy V-Notch (CVN) TestingCriteria at Rated Temperatures (1) . 26Table 4.2 Typical Adfreeze Stresses for VSM. 28Table 4.3 Data for Export Pipeline Streams with Drainage Areas Greater than 10 SquareMiles . 30Table 4.4: VSM Scour Locations and Estimated Maximum Scour Depth. 30Table 4.5 Ice Parameter Summary . 32Table 5.1 Pipe Design Parameters for Hydraulic Analysis . 34Table 5.2 Pipe Pressure Drop and Outlet Temperature . 34Table 5.3 Peak Potential Surge Pressure . 36Table 5.4 Export Pipeline Stress Criteria . 40Table 5.5 Export Pipeline Load Combinations . 41FiguresFigure 1.1Figure 2.1Figure 3.1Figure 3.2Figure 3.3Figure 3.4Figure 5.1Figure 5.2Figure 5.3Export Pipeline Routing Map. 9Point Thomson Export Pipeline Schematic Diagram . 12Comparison of Moisture (Ice) Contents . 17Comparison of Ground Temperatures. 18Measured Ground Temperatures for Undisturbed Tundra, Deadhorse, Alaska(Osterkamp 2003) . 19Typical Road Crossing Elevation and Section . 24Z-Offset Configuration. 42PI-Configuration . 42Vertical Loop . 43Attachment 1: Log of ChangesPage 4 of 57
Point Thomson ProjectUSPT-WP-YBDES-060001, Rev 3POINT THOMSON DESIGN BASIS FORPERMITTING – EXPORT PIPELINELIST OF ACRONYM S AND ABBREVIATIONSAISCAmerican Institute of Steel ConstructionAPIAmerican Petroleum InstituteAPSCAlyeska Pipeline Service CompanyASCEAmerican Society of Civil EngineersASMEAmerican Society of Mechanical EngineersBPTABSOPBP Transportation AlaskaBadami Sales Oil PipelineCCRCentralized Control RoomCFRCode of Federal RegulationsCPCFPCentral PadCentral Facilities PadCPFCentral Production FacilityCVNCharpy V-NotchDR&REMPCoDismantle, Remove, and RestoreExxonMobil Pipeline CompanyESDEmergency Shut DownFFBEFahrenheitFusion-Bonded EpoxyFDSFire Detection SystemgGravitational AccelerationHAZOPHazardous OperationsHCAHigh Consequence AreasIBCInternational Building CodeICSSIntegrated Control and Safety SystemMOPMSLMaximum Operating PressureMean Sea LevelMTRMaterial Test ReportOIMSOperations Integrity Management SystemPCSPGAProcess Control SystemPeak Ground AccelerationPLCProgrammable Logic ControllerPTEPPoint Thomson Export PipelinePTUPoint Thomson UnitPage 5 of 57September, 2011
Point Thomson ProjectUSPT-WP-YBDES-060001, Rev 3POINT THOMSON DESIGN BASIS FORPERMITTING – EXPORT PIPELINESDVShut Down ValveSISSafety Instrumented SystemSMYSSpecified Minimum Yield StressTAPSTrans Alaska Pipeline SystemTVATuned Vibration AbsorbersUHMWPEUltra-High Molecular Weight PolyethyleneVSMVertical Support Member(s)WIVZPAWind Induced VibrationZero Period AccelerationPage 6 of 57September, 2011
Point Thomson ProjectUSPT-WP-YBDES-060001, Rev 31.INTRODUCTION1.1PurposePOINT THOMSON DESIGN BASIS FORPERMITTING – EXPORT PIPELINESeptember, 2011The purpose of this document is to provide design basis for Point Thomson Export Pipeline(PTEP) supporting the Pipeline Right-of-Way Lease Application.1.2BackgroundThe Point Thomson field, a high-pressure gas liquid hydrocarbon reservoir discovered in 1977,is located approximately 60 miles east of the Prudhoe Bay field. The Point Thomson field isbeing developed as a gas cycling project. A single production well will be drilled from a CentralPad (CP). Additional wells may be drilled from two remote onshore well pads located along thecoastline. All wells will extend to a vertical depth of approximately 13,000 feet and will useextended reach drilling to reach outlying targets.Produced gas, water, and liquid hydrocarbons, will be gathered from the wells to the CentralProcessing facility (CPF), where the liquid hydrocarbons will be separated from the productionstream, stabilized to meet sales quality specifications and shipped via the PTEP and existingdownstream pipeline systems to the Trans Alaska Pipeline System (TAPS) Pump Station No. 1(PS-01). The gas will be compressed and re-injected into the Point Thomson reservoir at theinjection well pad located immediately adjacent to the CP.Point Thomson CPF will be staffed with full-time operations and support personnel for routineoperations and maintenance activities. Transportation of personnel and light equipment to andfrom the site will be via commercial and charter aircraft. Sea ice roads may be constructed foraccess by road during the winter but will only be built when their construction is justified byspecial activities (e.g., rig mobilization and demobilization and construction).1.3Subject FacilitiesThe facilities to which this design basis pertains (i.e., the subject facilities) consist of the PTEPcommencing at the proposed Point Thomson CP and terminating at a point of connection to the12-inch nominal diameter Badami Sales Oil Pipeline (BSOP) near the Badami Central FacilitiesPad (CFP). The route is approximately 22 miles long and is illustrated in Figure 1.1. Thepipeline facilities begin upstream of the inlet valves to the launcher barrel at the CP and end atthe isolation valve adjacent to the tie-in to the BSOP. The PTEP will be insulated and installedaboveground on vertical support members (VSM) for its entire length.The minimum design clearance between the surface of the tundra, streams and lakes andlowest point of any element being support by VSM (e.g., pipe insulation, pipeline attachmentssuch as tuned vibration absorbers, electrical/communication cables, etc.) for the PTEP is sevenfeet. This criterion does not apply to the actual VSM where the bottom of the lowest structuralelements will be less than seven feet from the surface of tundra, streams and lakes.Page 7 of 57
Point Thomson ProjectUSPT-WP-YBDES-060001, Rev 3POINT THOMSON DESIGN BASIS FORPERMITTING – EXPORT PIPELINESeptember, 2011This design basis sets out the criteria and standards to which the subject facilities will bedesigned. The purpose of this document is to establish a design baseline to which supportingdesign information will be compared to verify that design requirements are met.Page 8 of 57
Point Thomson ProjectUSPT-WP-YBDES-060001, Rev. 3POINT THOMSON DESIGN BASIS FOR PERMITTING – EXPORT PIPELINEFigure 1.1Export Pipeline Routing MapPage 9 of 57September, 2011
Point Thomson ProjectUSPT-WP-YBDES-060001, Rev. 3POINT THOMSON DESIGN BASIS FORPERMITTING – EXPORT PIPELINE2.GENERAL DESIGN AND CRITERIA2.1Liquid Hydrocarbon Properties and CharacteristicsSeptember, 2011The composition of the Point Thomson liquid hydrocarbon is summarized in Table 2.1.Table 2.1Point Thomson Liquid Hydrocarbon CompositionComponentMole FractionsNitrogen, N20Carbon Dioxide, CO20.0007Methane, C10.0021Ethane, C20.0022Propane, C30.0054I-Butane, iC40.0032N-Butane, nC40.0087I-Pentane, iC50.0077N-Pentane, nC50.0108C60.0575N-Heptane, C70.0728Octane, C80.1001Nonane, C90.0832Dodecane, C120.3436Heptadecane, C170.2003C270.0817C420.0126C650.0031C86 0Water, H2O0.0043TOTAL1.00The physical properties and characteristics of the Point Thomson liquid hydrocarbon aresummarized in Table 2.2.Page 10 of 57
Point Thomson ProjectUSPT-WP-YBDES-060001, Rev. 3Table 2.2POINT THOMSON DESIGN BASIS FORPERMITTING – EXPORT PIPELINEPoint Thompson Liquid Hydrocarbon Properties and CharacteristicsVALUE @ STDCONDITIONS(0 PSIG & 60 F)VALUE @ DESIGNOPERATINGCONDITIONS1(1000 PSIG AND 143 F)MW170.4176.0Enthalpy (BTU/lb)–966.9–903Cp (BTU/lbmole- F)73.3983.3952.4651.40.084690.0789Viscosity (cP)5.0461.94Specific Gravity0.841PHYSICAL PROPERTY3Density (lb/ft )Thermal Conductivity (BTU/hr-ft- F)API Gravity1September, 201137MOP conditions are 2035 psi and 200 FPoint Thomson liquid hydrocarbon has similar components as the fluids currently beingtransported through the Badami pipeline system, the Endicott pipeline system, and TAPS. Theliquid hydrocarbon is therefore chemically compatible with the pipe material and has similarchemical and physical properties as the fluids being transported through the existing pipelinesystems. Point Thomson liquid hydrocarbon will contain little or no sulfurous (i.e., sour)substances.A provision in the TAPS Connection Agreement (3-06-03 revision) is that a party seeking to shippetroleum on the TAPS should provide to Alyeska Pipeline Service Company (APSC) sufficientdata, petroleum sampling results, and other information to enable APSC to fully evaluate thesuitability and compatibility of the petroleum stream proposed for delivery through TAPS.PTEP Operations will ensure that the Point Thomson liquid hydrocarbon delivered throughBadami pipeline system, and thence via Endicott pipeline system and TAPS will meet the BPTransportation Alaska (BPTA) connection agreement requirements for sampling result, deliverypressure, and delivery temperature.2.2Extent of Subject FacilitiesThe subject facilities design process will involve two major contractors; Michael Baker Jr., Inc.(MBJ) and WorleyParsons (WP). MBJ will design the cross-country pipelines, associatedcomponents and support structures. WP will be responsible for the integrated control and safetysystems (ICSS), on-pad facilities including launcher, custody transfer meter, surveillance meter,meter prover and corrosion control and monitoring. MBJ and WP will coordinate withExxonMobil Pipeline Company (EMPCo) to address operational needs.Page 11 of 57
Point Thomson ProjectUSPT-WP-YBDES-060001, Rev. 3POINT THOMSON DESIGN BASIS FORPERMITTING – EXPORT PIPELINESeptember, 2011The subject facilities will commence at a defined point (e.g., butt weld or flange connection),located downstream from the Point Thomson shipping pumps flow control and pressure relieffacilities. The launcher barrel, its associated valves and piping; the inlet block valve on theexport line, located on the Point Thomson CP; fiscal metering at the CPF; and leak detectionmetering at Badami are considered part of the subject facilities.The subject facilities will terminate at a defined point (e.g., butt weld or flange connection) at the tiein of the PTEP to the existing BSOP. The tie-in to the BSOP will be made through a piggable wye,which will be installed in the existing pipeline. Standalone PTEP supports and the portion of sharedsupports (i.e., supporting the PTEP and non-regulated infield gathering lines) that directly supportthe PTEP are considered to be part of the subject facilities. The subject facilities are illustratedschematically in Figure 2.1.Figure 2.1Point Thomson Export Pipeline Schematic DiagramPage 12 of 57
Point Thomson ProjectUSPT-WP-YBDES-060001, Rev. 3POINT THOMSON DESIGN BASIS FORPERMITTING – EXPORT PIPELINESeptember, 2011Leak detection meters, instrumentation, and associated signal processing systems will beinstalled at Point Thomson CP and at Badami. In addition, a leak detection programmable logiccontroller (PLC) will be installed at each end of the PTEP utilizing independent pressure signalsand proprietary EMPCo software. Vertical loops will be employed as isolation devices at rivercrossings where applicable. The vertical loops, leak detection meters, and associatedinstrumentation are considered part of the subject facilities. Leak detection will be computed andmonitored at the Point Thomson Centralized Control Room (CCR).2.3Design LifeThe minimum design life of the PTEP will be 30 years and will be incorporated into applicabledesign criteria for the pipeline. Time-sensitive parameters (e.g., VSM creep rate) are selectedbased on a 30-year design life.2.4Regulations, Standards and CodesThe subject facilities will be designed in accordance with, but not limited to, the followingregulations, standards and codes. Code of Federal Regulations Title 49, “Transportation,” Part 195, “Transportation ofHazardous Liquids by Pipeline,” October 1, 2008.Alaska Administrative Code (AAC) 18 AAC 75, Oil and Hazardous Substances PollutionControlAmerican Institute of Steel Construction (AISC-303-05), “Code of Standard Practice forSteel Buildings and Bridges.”AISC, Manual of Steel Construction, 13th EditionAmerican Welding Society (AWS) D1.1/D1.1M:2006, Structural Welding Code—SteelAPI 5L, Specification for Line Pipe, 2004API 6D, Pipeline Valves, Edition 22, 2002API 1104, Welding Pipelines and Related Facilities, 2005API 1130, Computational Pipeline Monitoring for Liquid Pipelines, 2002API RP 1102 Steel Pipelines Crossing Railroads and Highways, 7th EditionASCE 7-05, Minimum Design Loads for Buildings and Other Structures, 2005ASME B31.4, “Pipeline Transportation Systems for Liquid Hydrocarbons and OtherLiquids,” 2006.ASME B16.5-2003, Pipe Flanges and Flanged Fittings: NPS 1/2 through 24ASTM International A572/A572M-07, Standard Specification for High-Strength Low-AlloyColumbium-Vanadium Structural SteelFederal Highway Administration (FHA). 2001. Evaluating Scour At Bridges. HydraulicEngineering Circular No. 18. Publication No. FHWA NHI 01-001. Fourth Edition. U.S.Department of Transportation. May 2001International Building Code, 2006Page 13 of 57
Point Thomson ProjectUSPT-WP-YBDES-060001, Rev. 3 POINT THOMSON DESIGN BASIS FORPERMITTING – EXPORT PIPELINE2008 National Electrical Code (NEC)NFPA 30, Flammable and Combustible Liquids Code, 2008 editionAlaska Safety Handbook, 2010North Slope Environmental Field Handbook (NSEFH), February 2005Page 14 of 57September, 2011
Point Thomson ProjectUSPT-WP-YBDES-060001, Rev. 3POINT THOMSON DESIGN BASIS FORPERMITTING – EXPORT PIPELINE3.PHYSICAL FEATURES/CIVIL3.1Topography/OceanographySeptember, 2011The project area is located on the Arctic Coastal Plain situated between the Beaufort Sea andthe Brooks Mountain Range. The PTEP traverses the coastal zone of the Ancient Canning RiverAlluvial Fan, a broad, relatively flat, treeless area. The coastal zone is located within 2 to 3 milesof the coastline and at elevations of up to 25 to 30 feet above mean sea level (MSL). A poorlydefined terrace face marks the transition from the coastal zone to the relatively higher, betterdrained inland zone. Surface drainage in the coastal zone is characterized as channel flow,which consists of a network of shallow lakes and streams while surface drainage in the inlandzone is generally not confined to defined channels and is characterized as sheet flow.The PTEP route is located in the coastal zone and passes close to numerous shallow lakes andcrosses several defined stream channels. Between lakes and streams, drainage is poor due toimpermeable underlying permafrost. Runoff and water from summer thaw of the near surfacesoils accumulates above the permafrost table resulting in slow run-off into small streams and inthe swampy character of much of the tundra during the summer.Wind-oriented thaw lakes dominate the landscape in the coastal zone. The thaw-lake basinsoriginate in areas of restricted drainage where shallow ponding results in a warmer surfacetemperature that causes the underlying ground ice to thaw resulting in subsidence. Most of theponds and lakes are relatively shallow. The thaw lakes go through a cycle of development,expansion, drainage, and revegetation.Topography along the PTEP route is relatively flat with the landform between drainagesdominated by patterned ground. Sharp topographic breaks and features are uncommonalthough low ridges exist at lake and stream edges and adjacent to ice wedges. Small (e.g.,typically less than one foot) seasonal variation in local tundra elevation due to freezing andthawing of the active layer is common. Other than a few remaining gravel exploration pads builtand used in the 1970s, the Point Thomson area is essentially undeveloped.The principal marine environment in the Point Thomson area is a relatively shallow marinelagoon that is situated south of a barrier island complex with water depths typically between 7and 12 feet. Sea level variation due to tide action during the open water season is less than onefoot.The barrier island complex parallels the coast and extends approximately 18 miles fromChallenge Island on the west to Flaxman Island on the east. Documents prepared for the LibertyDevelopment Project indicate that the barrier island complex partially protects much of thelagoon in the Point Thomson area from exposure to storm waves generated in the Beaufort Seaduring the open-water periods. Based on this information, it is expected that storm surges in thePoint Thomson area will be generally less than 3 feet. During extreme storms, surges mayreach up to 7 feet above MSL.Page 15 of 57
Point Thomson ProjectUSPT-WP-YBDES-060001, Rev. 33.2POINT THOMSON DESIGN BASIS FORPERMITTING – EXPORT PIPELINESeptember, 2011Climate/MeteorologyBased on Prudhoe Bay temperature normals by month between 1971 and 2000, the meanannual ambient temperature is approximately 10.7 F. Ambient temperature ranges from ahighest daily average of 53.9 F to a lowest daily average of 35.8 F. The record maximumtemperature is 83 F (June 21, 1991) and the record minimum temperature is 62 F (January1989). The area annually experiences approximately 9,291 degree days F freezing andapproximately 960 degree days F thawing.Winds are generally from the northeast (N70 E at Prudhoe Bay to N79 E at Barter Island), butwind shifts to the west or northwest is common throughout the summer. Strong westerly andsouthwesterly winds periodically occur during storms. Wind data was collected at PointThomson and Flaxman Island during the summers of 1997 and 1999 (URS 2000) and isgenerally consistent with the wind speed and direction recorded at Deadhorse during the sameperiods. Wind speed varies from a low of 11.4 mph to a high of 12.9 mph. Maximuminstantaneous recorded wind speeds vary from 38 mph in early summer to 81 mph in winter.Prudhoe Bay mean annual precipitation is approximately 4 inches per year with total annualsnow accumulation estimated to be ap
stream, stabilized to meet sales quality specifications and shipped via the PTEP and existing downstream pipeline systems to the Trans Alaska Pipeline System (TAPS) Pump Station No. 1 (PS-01). The gas will be compressed and re-injected into the Point Thomson reservoir at the injection well pad located immediately adjacent to the CP.
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