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Home My WebLink About100-026o>r r • THE STATE Department of Environmental 011-1LASKL'1 GOVERNOR SEAN PARNELL RECEIVED FEB 0 7 2014 February 4, 2014 A0GCC Certified Mail, Return Receipt Requested Article No.: 7012 2210 0002 1216 2391 Wayne Svejnoha BLM — Division of Resources 222 W 7th Ave, #13 Anchorage, Alaska 99513 Conservation Division of Spill Prevention and Response Contaminated Sites Program File: 320.38.010 SCANNED 0 2 2014 Re: Potentiall Responsible Party Notice Letter and Information Request NPRA Legacy Wells - General Hazard ID: 26125 Ledger Code: 14339387 Dear Mr. Svejnoha: 610 University Ave. Fairbanks, Alaska 99709-3643 Main: 907.451.2181 Fax: 907.451.5105 This letter is to advise you that the Alaska Department of Environmental Conservation (ADEC) has identified the 136 legacy wells within the National Petroleum Reserve in Alaska (NPRA) as potential contaminated sites. Some of these wells require extensive cleanup of oil and other hazardous substances released to the environment. Since you are identified as a current or past owner and/or operator of these sites, please be advised you may be financially responsible or liable for the investigation and /or cleanup of any hazardous substance contamination that might be present. Alaska Statute 46.03.822 establishes who is liable for contamination. Records available to the ADEC indicate that you meet one or more of the following criteria: » owned or controlled the hazardous substance at the time of its release; » own(ed) or operate(d) the property or facility from which the release occurred; » owned or operated property at which the hazardous substance came to be located; and » arranged for transport, disposal or treatment of hazardous substances that were released. Site History From 1944 through 1982 the US Government drilled 136 wells to explore for oil and gas resources in the NPRA. It is our understanding that other federal agencies and some private companies may have operated or managed these sites in the past. We have also been informed that 23 of these well have been conveyed to public and private entities. The ADEC currently lists 14 of the 136 legacy wells on our database of contaminated sites. The Bureau of Land Management (BLM) is identified as the responsible party for the following sites. Wayne Svejnoha 0 2 February 4, 2014 • BLM Cape Halkett Drill Site (File # 300.38.108) • BLM East Simpson #2 (File # 300.38.109) • BLM East Teshekpuk Drill Site (File # 300.38.110) The U.S. Army Corps of Engineers, under the Formerly Used Defense Sites program, is working with ADEC under the Defense States Memorandum of Agreement on cleanup actions at the 11 Umiat test well sites. BLM is identified as the landowner in our records, and as such is identified as a potentially responsible party in addition to the Department of Defense: C Umiat Test Wells 1-11 (File # 335.38.001) The information contained in these files is part of the public record. Our databases are accessible on the Internet at: http://dec.alaska.gov/spar/csp/db_search.httn Additional Actions Needed ADEC sent a letter on July 11, 2013, identifying an additional 15 legacy well sites with confirmed releases (enclosed). As stated in the letter, ADEC recommends that BLM develop a plan to address known, suspected, and unknown releases at the legacy well sites, in coordination with the appropriate regulatory agencies. We expected a response to this letter before now. Please respond to this letter within 30 days. After we receive and review your response we will determine what additional actions will be taken regarding each site with known or suspected contamination. In addition, with your response, please complete and return the enclosed questionnaire requesting more information about past operators. In accordance with Alaska Statute Title 46, ADEC is authorized to provide regulatory oversight for any contamination response efforts initiated by the responsible party. However, if response actions by the responsible party are not satisfactory to ADEC, we may then assume the lead role in the investigation and cleanup efforts. In the event that State response actions are necessary, the responsible parties may be held financially liable for any response actions taken by the State. Alaska Statutes 46.04.010 and 46.08.070 establish cost recovery procedures for certain costs, including oversight activities, incurred by the State in responding to pollution incidents. If you are determined to be a responsible or liable party, ADEC may bill you at a later date for our expenditures associated with this pollution incident. Expenses for which we may seek reimbursement include: Staff time associated with general or technical assistance; work plan review; project oversight; general project management; legal services; interest; travel; equipment and supplies; and any contracting costs. Pursuant to Alaska Statute 46.08.075, the State may also file liens against all property owned by a person who is responsible or liable for State expenditures. Please respond in writing within thirty (30) days from the date of this letter addressing your intended actions with respect to this pollution incident. If you believe someone else is responsible for this pollution incident (e.g., a past owner or operation of the site) or if you have any questions concerning this matter, please contact Mr. Fred Vreeman at (907) 451-2181. The attached "ADEC Information Request" describes the minimum information expected in your response. Additional information may needed to evaluate the risks and responses required at each legacy well site. Sincerely, Fred Vreeman Environmental Program Manager G:\SPAR\CS\Contaminated Site Files (38)\320 National Petro Reserve Area\320.38.010 NPRA Legacy Wells General\2-2-2014 Letter\PRP Letter All Wells.docx Wayne Sveinoha Enclosure: 0 3 • ADEC Information Request Concerning Contaminated Sites BLM Legacy Wells Dispute letter date July 11, 2013 February 4, 2014 cc: Bud Cribley, Director, Bureau of Land Management Steven Cohn, Deputy Director, Bureau of Land Management Jolie Pollet, Branch Chief, Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer, Bureau of Land Management Larry Hartig, Commissioner, Alaska Department of Environmental Conservation Lynn Kent, Deputy Commissioner, Alaska Department of Environmental Conservation Kristen Ryan, Director, Alaska Department of Environmental Conservation Lori Aldrich, Program Manager, Alaska Department of Environmental Conservation Steve Bainbridge, Program Manager, Alaska Department of Environmental Conservation Jennifer Roberts, Program Manager, Alaska Department of Environmental Conservation ADEC Response Fund Administration GASPAR\CS\Contarr nmted Site Files (38)\320 National Petro Reserve Area\320.38.010 NPRA Legacy Wells General\2-2-2014 Letter\PRP Letter All Wells.docx 0 0 ADEC INFORMATION REQUEST Concerning a contaminated site(s) Re: Legacy Well Sites in and near the National Petroleum Reserve, Alaska (NPRA) Please precede each answer with the number of the question to which it corresponds. Please direct any questions concerning this information request to Fred Vreeman, Contaminated Sites Program, 610 University Avenue, Fairbanks, AK 99709; Phone: 907-451-2181. Thank you for your cooperation. 1. Provide name and company affiliation of the person answering the questionnaire. 2. Provide copies of all studies, reports, and supporting information (including preaquisition assessments and work done on behalf of other parties) which you have knowledge of which address past and/or present environmental conditions at the site. Identify the name, title, address, and phone number of the party(s) who are responsible for preparing the studies or information. Information which has been previously submitted to ADEC need not be submitted again (unless specifically requested in a subsequent communication) if you can provide the name of the office (and name and title of the DEC officer if known) to whom the report was previously provided. 3. Provide a description of any ongoing or planned investigations or cleanup work at the site. Identify the names, titles and phone numbers of the individuals responsible for preparing the studies or information. 4. Provide a description of known releases at the site (date of occurrence, quantity released, type of substance released, etc.) and a description of corrective measures that were taken. Provide information on any suspected releases which may have or are occurring. 5. Describe the nature of past and present operations at the site. In particular, any actions that may have caused the release or threat of release at the site. Describe the physical characteristics of the site including major structures, water wells, fuel or waste storage systems, drainage or septic systems, etc. 6. Provide a list of any permits issued by the Department which relate to activities at the site and a list of RCRA identification numbers (U.S. EPA identification numbers) which may be held. 7. Identify persons to whom you leased all or a portion of the property and describe the nature of their operations. 8. Identify the person(s) who used the site for disposal of substances deposited there, if any. 9. Provide copies of manifests for any hazardous waste and/or petroleum contaminated materials taken to or from the site. 10. Provide a list of persons and their phone numbers and addresses of persons who have knowledge about the use of hazardous substances at the site. 11. Provide information regarding the existence of insurance coverage for damages resulting from releases of hazardous substances and copies of all such insurance policies, both currently in effect and in effect during the periods of activity in question. 12. Describe the acts or omissions of any person, other than your employees, agents, or those persons with whom you had a contractual relationship, that may have caused the release or threat of release of hazardous substances at the site. a. In addition, describe all precautions that you took against foreseeable acts or omissions of any such third parties. 13. Describe the care you exercised with respect to the hazardous substances found at the site. 14. Describe the physical characteristics of the site including structures, wells, drainage systems, etc. THE STATE July 11, 2013 'ALASKA GOVERNOR SEAN PARNELL Wayne Svejnoha Supervisory Minerals & Energy Specialist 222 W 7th Avenue, #13 Anchorage, Alaska 99513 Re: BLM Legacy Wells Dispute Dear Mr. Svejnoha: Department of Environmental Conservation Division of Spill Prevention and Response Contaminated Sites Program 610 University Ave. Fairbanks, Alaska 99709-3643 Main: 907.451.2181 Fax: 907.451.2155 The Alaska Department of Environmental Conservation (ADEC) — Contaminated Sites has reviewed the National Petroleum Reserve in Alaska: 2013 Legacy Wells Summary Report dated February 2013, containing updated information on the status of the 136 Legacy Wells located in the National Petroleum Reserve — Alaska (NPR -A), and the draft National Petroleum Reserve in Alaslm. 2013 Legacy Weiss Strategic Plan dated May 2013. ADEC has also reviewed the response by the Alaska Oil and Gas Conservation Commission (AOGC). We concur with the response by ACIGC and have no further comment regarding the priorities. We do have comments about the investigation and cleanup plans presented in the report. With this letter we arc outlining regulatory requirements related to the environmental work that is proposed and required as part of these cleanups. ADEC is concerned that the 2013 Legacy Wells Strategic Plan prepared by the BLM does not include either assessment of the contingency for assessment of known, likely, or unknown but possible contaminant releases. In addition, BLM plans for surface cleanup of these wells should be made clear in the plan. At least one of these legacy wells has extensive PCB contamination and has resulted in a multi-year cleanup totaling tens of millions of dollars. At others, solid waste disposal practices have resulted in releases to the environment with estimated cleanup costs in the hundreds of millions. Known releases documented in the records we reviewed include crude oil, gasses, refined oil and fuel, drilling fluids that include various organics, metals, and other chemicals, and unknown contaminants from drums and other containers observed to be damaged and abandoned at the various well sites. There are 13 legacy well sites with known releases currently on the DEC contaminated sites list. Many of these are in the process of being addressed, cleaned up, and closed. From our Waited records review there are 15 additional legacy well sites with confirmed releases. These should be prioritized for initial records reviews and then added to the BLM contaminated sites list under our cooperative agreement. Suspected releases include fuel releases from operations, storage, and fuel spills at the sites, impacts to various surface water bodies from spilled fluids during drilling and breaches of containment at reserve and flare pits, continued surface runoff from drilling fluids uncontained at several sites, and down -hole substances that were ejected from the holes over time or during blowouts or drilling operations. 1 Wayne Sve noha ? July 11, 2013 Y The.BLN-1 plan to address these known, suspected, and unknown releases at legacy well sites is notably absent from the documents presented to date. The three primary regulatory agencies that need to be involved in the plan are ADEC — Contaminated Sites, Alaska Oil & Gas Conservation Commission, and ADEC — EH/Solid Waste. Other agencies will need to be consulted. as well. Below we provide recommendations for a coordinated plan using the Uniform Federal Policy for Quality Assurance Project Plans (UFP-QAPP) that will involve all of the regulatory agencies in one coordinated manner. This will allow BLM to address these sites in a consistent and coordinated project which fulfills all of the regulatory requirements so that the sites do not need to be re -visited in the fu=e xvhen they are closed after this project. Attached are our comments on each specific well. The acronyms used on the list include terms that are typically used in a CERCLA type investigation however they are also suitable for investigations conducted under the State of Alaska cleanup rules. These include the following; Historical Records Review (HRR) 'chis is recommended for almost all of the well sites. Much of the information required for these reviews is already contained in various reports and appendices or in BLM files. The Historical Records Review should document the type of releases that might have occurred from drilling operations as well as historical use of the site, and should capture all available information on the drilling fluids used and any product produced or released. Preliminary Assessment (PA) This is recommended for almost all of the well sites. A Preliminary Assessment is a limited scope investigation that provides an assessment of information about a site and its surrounding area to distinguish between sites that pose little or no threat to human health or the environment and sites that require further investigation. The PA is a CERCLA defined document and typically does not require sampling. Site Inspection (SI) If the PA recommends further investigation, then an SI is necessary. The SI is a CERCLA defined document, and it is analogous to an initial report of contamination under state cleanup rules. On some legacy well drillings sites it is evident now that an Sl is required just from a review of the reports. An SI investigation typically includes the collection of samples to determine what contaminants are present at the site and whether they are being released into the environment. An approved site specific workplan is required under both CERCL-A and 18 AAC 75 prior to SI sampling. The SI typically is not intended to develop a full site characterization, but is limited to determining the presence or absence of a release. If contamination is found after completion of the HRR, PA, and SI then a RI/FS under CERCLA, or a Site Characte-rizatiowlteportandcleanup-Alas,under-l-fi-AAC7iis`required. -- ----- - -- — --------- - DEC recommends that BLM incorporate into the strategic pian the processes outlined in this letter. A team of agencies composed of AOGC, DEC -CS, EPA as required, and DEC -EH should address regulatory and technical requirements for these well closures. By cooperating and working together with the regulatory agencies BLM will save time and expense, and regulatory uncertainties will be avoided. The strategic plan should reference a project to prepare a generic workplan. DEC suggests that BLM utilize the generic UFP-QAPP workplan format for the required environmental work. If properly prepared, the workplan could encompass most of the investigations and cleanups required at these sites over multiple years. At other multi -site projects we have found this to be an effective way to reduce uncertainties and risk in these types of investigations. A very small site specific FSP could then be developed as BLM approaches each drilling site. Regulatory decisions made during workplan development would provide more certainty in the planning process for cleanups. G:\SPAR\CS\federal F2cilitie3\Ci%ih2n 1-cdcrrt Agr=ics\DOl\B[.nl\1'roiens\lxgAey Wells\7 11 13 Luter to KIN on lxbxy wells.doex Wayne Svejnoha 3 0 July 11, 2013 Please review the attached list of specific sites. If you have any questions, please do not hesitate to call me at 907-451-2181 or by email at fred.vreeman@alaska.gov. I look forward to working with you as the Federal Government fulfills its requirement to clean up these well drilling sites in Alaska. Sincerely, y' Fred Vreeman Environmental Program Manager Enclosure: SPAR Response with Legacy Wells cc: Bud Cribley, State Director, Bureau of Land Management Steven Cohn, Deputy State Director for Resources, Bureau of Land Management Jolie Pollet, Branch Chief, Bureau of Land Management Robert Brumbaugh, Geologist, Bureau of Land Management Michael McCrum, Environmental Engineer, Bureau of Land Management Cathy Foerster, Commissioner, Alaska Oil and Gas Conservation Commission Larry Hartig, Commissioner, Alaska Department of Environmental Conservation Kristen Ryan, Director, ADEC Division of Spill Prevention and Response Steve Bainbridge, Program Manager, ADEC Contaminated Sites Program Jennifer Roberts, Program Manager, ADEC Contaminated Sites Program GASI'AR\CS\Fedcrrl Fo61ibLy\Gvi6n Falctul AgcnnCs\DOI\BI.N1\Proitcts\lA'6.1' q W03\7 11 1314tur to Aim\I on Ug2cy Wclls.doex Well Name operator I RP I Land Simpson Core Test #5 1! Na 1 BLM Simpson Core Test #6 US Na I BLM Simpson Core Test #7 us Na 1 Bl. M Sin son Core Test 98 US Navy 113LM Si son Core Test #9 U5 Na I BLM Sinwson Core Test #1f) U.S Navy! BLM Core Test #11 AOGCC Subsurlaca I BLM Core Test #12 FUSNa a I BLM Core Test #16 a 18LM Core Test #17 US Na 1 BLM Core Test 018 US Na I BLM Core Test #19 US Na 1 BLM t Core Test #20 US Navy 1 BLM i Gore Test #21 2S Na 1 BLM I Core Test #22 US Na 111•LM I Core Test dnlf fluids left in hole i BLM Core Test �#2vy I BLhA n CareTest #25 US Na Y I BLM K Core #1 US Navy i BLM 1 -t- *1 SPAR Response with Legacy Wells Lisl.xlsx 2013 Risk Ity CSP Status I Fito tllHazid Rolea5e7 Nnne None IYOMWil Low RNooe ane Nona Unused, Unused. I None Unused, i None Uncased, None None None None (None Unknown Unknown Page 1 of 14 •I AOGCC Subsurlaca AOGCC Surface SPAR W arkgroup Notes Status Status Need HRR, PA, S1 no data no data Need HRR. PA. SI no data no data Need PA ind drill fluid assessnsenl & workplan drillin 11uids left in hole no data Need PA ind drill fluid assessment & work an drilling fluids left in hole no data Need PA incl drill Ifusd assessment & work Ian dnlf fluids left in hole no data Need PA nc drill fluid assessmcnf &work Ian dnllxs fluids left rn hale no data well skc-lch provided by Need PA ind drill fluid BLM not consistent with assessment & work Ian AOGCC or BLM data no data Need PA ind drill fluid assessment & work Ian dnflin fluids left in hole no data Need PA and 51 ind 13611 fluid assessment. workplan rid sampling stressed debfis, partially as blowout and fire rove elated site areas Need PA incl drill fluid assessment & workplan dn lling fluids left in hole no data geed PA ind drill fluid assessment & wOTk Ian drij I ing fluids teff in hole no data Need PA incl dfifl nutd assessment & work Ian drillin fluids left m holo no data Need PA incl drill fluid assessment & work Ian drillin ituids left in hole no data Need HRR. PA, SI no data no data Need PA incl drill fluid assessment & work Ian drillin fluids felt in hole ria data Need PA incl dnll fluid assessment & work larx drillin fluids left in hole no data Need PA incl drill fluid assessment & work Ian drillin fluids Teff in hole no data Need PA ind dnll fluid drflfing fluids and ball assessment & work len peen hammer left in hole no data overshot, drill collar, rock revegelated —131 Need HRR, PA bit, and N -reds left in hole can't find it Review Report as PA. No evidence of sheen, stressed veg, or drilling Not abandoned, waste on surface. Veg ----_— , ,raw,, plunaed to surface site not cleared •I SPAR Response with Legacy Wells LisLxlsx Page 2 of 14 is • vi nce o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator I RP I Land Mgr Priority CSP Status file #IHazid Release? SPAR Workgroup Notes Status Status plugging operations inadequate and Wellhead tell as Umiat 43 US Navy I BLM I FUDS None pending dos 335.38.00113092 Yes. see file 'Plugged by BLM in 2004 incomplete historic site? plugging operations inadequate and Wellhead left as Umiat #4 US Navy I BLM / FUDS None pending dos 335.38.001!3079 Yes, see file Plugged by BLM in 2004 incomplete historic site? plugging operations inadequate and Wellhead left as Umial 98 US NaMy I BLM I FUDS None pendinq dos 335.38.001/3D81 'Yes, see_ _file Plugged BLM in 2004 incomplete historic sile? plugging operations inadequate and Wellhead left as Umiat #1'0 US Navyj BLM_I FUDS None pendingdos 335.38.00113082 Yes, see fila Plu ed by BLM in 2004 incomplete historic site? Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 7868'. Drilling Cleanup. Photos - evidence mud and diesel to Awuna #1 USGS I BLM Medium None None Yes of erosion into lake surface. > 100 _Pylons Need HRR, PA, SI with sampling. Drilling mud Wood , metal, assessment. Surface Plugged to 2039'. Diesel plastic debris. Fast Simpson #1 USGS I BLM Low None None Yes Cleanup. to surface. >10D Pylons Need HRR, PA, SI with Wood and metal Drilling mud assessment debris. Pylons - Photos straw areas of no Plugged to 2047'. Diesel Tankage for lk ' #1 USGS / 8LM Low None None Yes ve elation. to surface. flammable fluids Need HRR. PA, SI wdh sampling. Drilling mud assessment. Surface Plugged to 1400'. Drilling Wood and metal Koluktak #1 USGS I BLM Low None None LYes Cleanup. mud & diesel to surface debris Pylons Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 1894'. Diesel Wood and metal Ku am 91 USGS I BLM Low None None Unknown Cleanup. to surface debris. Pylons Need HRR, PA, Sl with sampling_ Drilling mud assessment_ Surface Plugged to 4464'. Drilling Wood & metal Kuyanak #1 USGS I BLM Low None None Yes Clean mud & diesel to surface debris. Pylons Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Photos show Plugged to 1840'. Diesel Plastic and metal Lisburne 41 USGS I BLM Low None None Yes stained soil to surface debris. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Plugged to 8192'. Drilling Wood and metal North Iii ok $1 USGS I BLM Low None INone Yes Cleanup. mud & diesel to surface debris - Page 2 of 14 is • Well Name Peard South Meade #1 1 RP 1 Land 1BLM BLM #1 4USGS ! BLM SPAR Response with Legacy Wells Usl.xlsx ;013 Risk &W CSP Status File XlHazkl T Page 3 of 14 AOGCC Subsurface AOGCC Surface WAR Workgroup Notes Status r Status � deed HERR, PA SI with iampling. Dining mud rssessment- Surface ;leanup. Site photos show areas of stressed iegetalion. No issues Plugged to 2232'. Diesel Wood and metal soled in USGS re ort. to surface debris. Pylons Need HRR, PA, SI with sampling_ Drilling mud assessment Surface Plugged to 2026'. Diesel Wood and metal Cleanup. to surface debris. P Ions Add to She list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Od reported bubbling to the surface within reserve pit in 1982. Oily residue and sheen observed adjacent to east side of reserve pil, down hole material at the Plugged to 1875. Diesel Wood and metal surface to surface debris. P ons Add to Site list. Need HRR, PA, S) with sampl'uig. Drilling mud assessment - Surface Cleanup. Reserve pit berm had breaches anowirrg water to exit. Oil - stained sediment was observed above the Plugged to 1478'. Diesel Wood and metal waterline of the I. to surface debris. Site photos may show hydrocarbon sheen on Plugged to 2600'. Drilling Wood and metal water in well cellar mud & diesel to surface debris. Pylons Add to Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Berms have been breached an allow water to flow out of reserve piUllare pit. Rising bubbles of ail observed in Hare pit 1484. Photos Show Plugged to 1825'. Diesel Metal debris. ra.. v-1 v.nnnralinn to Surface ... 0 •I SPAR Response with Legacy Wells Lisl.xlsx Page 4 of 114 0 0 vi encs o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator 1 RP f Land Mgr Priority CSP Status File #fHazld Release? SPAR Workgroup Motes Status Status Need HRR, PA, Sl wrlh sampling. Drilling mud assessment Surface Cleanup. Breaches in bemi allow water to flow into and out of reserve pit, sheen on Plugged to 2700' Diesel Wood and metal West Dease #1 USGS l BLM Low Nona None Yes surface water in well cellar to surface debns. Pylons Add to Site list. Need HRR,. PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Water flows into the pits through breaches on the eastern berm and out of the pits through breaches on the northern and western berms. Downhole material Plugged to 228'9'. Drilling Wood and metal South Harrison Bay #1 USGS f BLAB Low None None es Present at surface mud & diesel to surface debris. Add to Site list. Need HRR, PA, SI with sampliing. Drilling mud assessment. Surface Cleanup. Stressed vegetation noted and apparent in site pholos. Plugged to 2443'. Drilling West Fish Creek #1 USGS 1 BLM Low None None Yes Drilling mud around well mud & diesel to surface Pylons Need HRR, PA, SI with sampling. Drilling mud assessment, Surface Cleanup. High TPH Plugged to 1977'_ Drilling wellhead sticking concentrations underneath mud under plugs. Diesel up. Wood debris. Fast Simpson #2 USGS 1 BLM I Low _ Active 300.38.10912691 Yes, see file the rig inundation to surface Pylons South Barrow 94 US NavyiNorth Slope Bono None None None Unknown Need Surface Status completed gas well - no data South Barrow #5 USAF - BLM Unknown None None None. Unknown Need Surface Status completed gas well no data South Barrow #& US Na /Norlh Sto Burg None None None Unknown Need HRR, PA, St no data no data South Barrow #9 US NavyfNarih Slop2 Boro None None None Unknown Need HRR, PA, Sl no data no data _ South Barrow #10 US Navyfflorlh Sto Bora None None None Unknown Need Surface Status com ted gas well no data South Barrow It12 US Na /North Slope Baro None None None Unknown Need HRR, PA. Sl no data no data BLM well skMh not consistent with AOGCC South Barrow #14 US NavyMorth Sloe Boro None None one Unknown Nsed HRR. PA, St data no data Need PA ind drill fluid well left filled with drilling South Barrow #16 US NavyiNotih Slope Bora None None None Unknown assessment & workplan mud and diesel no data Need PA incl drill !turd tubing in well. no perfs, Soulh Barrow 017 US Na /North Sloe 13ora None None None jUnknown assessment & work fan I unknown fluid, I no data Page 4 of 114 0 0 SPAR Response with Legacy Wells Lisl.xisx Page 5 of 14 •I E CYfuu .v v AOGCC Subsurface A Surlaco TEHILM T013 Risk CSP Stilus File #IHaaid Historic Rekeasa7 SFAR YUnrkgroup Nates 5latus at US $1<ntus Well Name flperatar f RP f Land Mgriority Unknown Need Surface Status corn feted as well no data 5aulh Barrow #18 US Na INorlh Slo a Bora None None None Unknown Need HRR, PA, St no data no data Walak a #1 USGS! Unknown None None None rsg 890`. Multiple cement plugs of unknown volume. Shallowest None None Unknown _ Need HRR, PA, SI SOD' no dada Gubik #1 US Na d Ur#cnown Low Add to Site list. Need HRR. PA. SI with sampling. csg Q SOD' Well blowout Drilling mud assessment. from zone al 1SOT during Surface Cleanup. Photos plugging operations show disturbed/ slashed Plugging never completed after blowout. no data Gub* #2 US Na ! Unknown Low None Nora es areas two downhole Dement plugs of unknown depth Mone None Unknown Need MR. PA. Sl and volume no data Grandstand #1 US Navy 1 Unknown None Add to Site list. Need HRR. PA, SI with sampling. Dnliing mud assessment. Surface Cleanup Sediment from the reserve pit was excavated and spread over the pad to drill a 2nd well at this location, Upon completion of the 2nd well. the sediment was pushed back into ft reserve pit.. Area does not appear to be revegetaling. perhaps from the presence property plugged but no of drilling mud at the data on abandonment None None Yes surface status no data W 7 Foran #1 " USGS I Unknown Low on Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Slressed vegetation, photos show plugged, but not open csg; metal & Active 306.3$.108f2689 Yes. see file site underwater abandoned at surface corwsele debris under 5' of water, Cape Halken #1 " US Na (Unknown Low None Unknown !Need HRR, PA. SI es to 27' open C_s Min a Veloei #1 U5 Na f t3LM one None csg @ 31" 280' of drill pipe, drill collar, and Core Unknown Need HRR. PA, SL barrel left rn hole. rove etaled Ournalik Core #i US Na / BLM None -No obsery None !None Page 5 of 14 •I E SPAR Response with Legacy Wells Lisi.xlsx Page 6 of 14 • • WI F3nCe Q BLM 2013 Risk Historic AOGCC Subsurface ADGCC Surface Well Name Operator t RP I Land Mgr Priority CSP Status File #IHazid Release? SPAR Workgroup Notes Status Status Need HRR, PA, Workplan for St with Sampling. Drilling Mud Assessment. Surface Cleanup. Photos show debris, stressed No csg. 15' of drift pipe Oumalik Caro #2 US Navy 1 ULM Low None None yes ve elation and rock hit left in hole. no data Need HRR, PA, Workplan for Si with Sampling open csg & other Drillip) Mud Assessment. piping sticking out Surface Cleanup_ Reports of ground; wood, of debris, drilling muds on melat, conciele Oumalik Core 011 US Navy 1 BLM Low None None Yes surface (__q to 9', debris open csg sticking out of ground; wood & metal 0umalik Core #12 US Navy I BLM Low None None No Need HRR, PA, SI no data —__—debris _„ debris buried by landslide. Need HRR, PA, St, Well not no dala on Sentinel Hill #1 US Navy 1 BLM Low None None Unknown ap panent in site Rholos Csq to 3t1'. underwater status Need IQR, PA, SI. No evidence of sheen, open crag slightly stressed veg, or drilling above ground waste on surface. Veg 37' of csg, drilling fluids level; wood and S imp son Core Test #1 US Navy 1 BLM Low None None No appears healthy lett in hole metal debris Need HRR, PA, St. No evidence of sheen, stressed veg, or drilling waste on surface_ Veg 76'01 Csg, drilling fluids Simpson Core Test #2 US Navy I BLM Low None None No appears healthy left in hate no data Need HRR, PA, Sl. No evidence of sheen, stressed veg, or drilling waste an surface. Veg 61' of csg, drilling fluids Sim sun Core Test #3 US Navy I BLM Low None None No appears healthy left in hole no data Need HRR, PA, St. No evidence of sheen, stressed veg, ordrilling waste on surface. Veg --60' of crag, drilling fluids Sim eson Core Test #4 US Nayy t BLM Low Norse None No apecars healthy left in hole no data Need HRR, PA, St. No evidence of sheen, stressed veg, or drilling waste on surface. Veg csg cemented @25% open csg sticking Songsoncore Test #13 US Na 1 BLM Low None None No appears health dritin fluids IeR in hole_ out of round Need HRR, PA, SI. Vegetated, no evidence of crag cemented @2D'; open csg sticking Simpson Core Test #14 US Navy ! BLM Low None None No release. drillin fluids left in hole out of ground Page 6 of 14 • • SPAR Response with Legacy Wells Lisl.xlsx ism son Core Fest #26 t=vrdence or Medium AOGCC Subsur(aen ADGGC Surface 13LM 2013 Risk CSP Status File WHazid Historic Retease7 SPAR Wwkgroup Notes Status Status Well Name operator r RP 1 Land Mgr Priority Unko Need HRR, PA. SL US Na ! $LM open casing None Nave Vegetated. no ev4dence of cog set shallow; drilling slicking nut of Low No release- fluids left in hole round Simpson Core Teri #14a US Na !BLM Low None None & weilhead slick Need HRR. PA, SI crude nil left in hole open casing Need HIR, PA, Workplan Vegetated, no e+wdence of csg cemented 12181; slicking out of openregd ng No release. drillingfluid left in hole round Simoson Care Tesl #15 US Na !BLM Low None None d wooden Oellar, Need HRR, PP, SL Sate a9 r�110'. dolling fluids wood 8 metal ism son Core Fest #26 US Na ! BLM Medium None None res Sim sen Core Test 027 US Na J 13LM IJone None None Unko Sim son Gore Test #28 US Na ! $LM Low None Nave Yes clmnnnn Core Tesl #29 US Navy! BLM Low Norte No No Simpson Core Test 030 US Na 1 !BLM Core Test #30a JUS,Navy 1 BLM Low `None Prone n Gore Test #31 JUS Navy/ BLM None Page 7o(14 photos appear to show oil at surface, from a natural csg Q 350'. Completed in oil seep, seep, also drilling mud in oil well Open perfs. At 1welhead sticking sacks on the tundra one lime capable of up_ metal debris PI u ed b BLM in 2004. unassisled flow. and rustingbarrels 'Need HRR, PA, St. Site photos appear to show Oil csg cemented at surface, from a natural @i02;dnllutg fluids nn oily ground; csg seep- Plugged by BLM in including diesel and & weilhead slick vin 20014 crude nil left in hole out of ground Need HIR, PA, Workplan for Sl with Sampling- openregd ng ❑rilling Mud Assessment . out grouunnd in Surface Cleanup. Site d wooden Oellar, photos appear to show a p le of drilling mud about a9 r�110'. dolling fluids wood 8 metal 160 feel tram the welt tell in hole debris. Solid waste Need HRR, PA, Sl_ No evidence of sheen, stressed veg, or dri" waste on surface. Veg csg cemented at 1S2'; open csg. Wood a ears healthy dnknq fluids lett in hole and metal debris Need HRR, PA, SI. frilling mud at surface. but well is also in the middle of a large in oil seep; Open oil seep and surrounded by cog sticking up; pooled oil. Plugged by BLNI csg cemented A150'; wood & metal ser Holes in 20514- drillin fluids left in hole detail on oily ground; tog Need HRR. PA, Sl. Well is wellhead slick in the middle of a large oil seep and surrounded by csg cemented at 100% out of ground. pooled oil. Plugged by 131. dulling mud left in hole. wellhead leaking see noses in 2004 gas blowout at 423' gas Need HRR, PA, St. Leaky valve replaced in 2001, little evidence of contamination following valva on city ground; reg replacement- Plugged by csg cemented at 100'; & wellhead stick see notes BLM in 20174 iddifing fluids, left in hole out o1 round SPAR Response with Legacy Wells List.xlsx Page 8 of 14 • • yr enco o BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator f RP f Land Mgr Priority CSP Status File glHasid Release? SPAR Workgroup Notes Status Status Need HRR PA, Workplan csg Cemente=d al for Sl with Sampling. 1028', cement plugs a1 Drilling Mud Assessment. 6387' and 5520'. Fish in Surface Cleanup. Drilling hole, drilling fluids Iefs in No data. Open Simpson Test Welt #1 ak US Navy1 BLM Low None INone yes muds near wellhead hale casing Need HRR, PA, Workplan for Sl with Sampling. Dolling Mud Assessment. Surface Cleanup Also Wellhead sticking evidence of a natural seep- above ground, Tar sheens in the summer ST from 2552 to 3018. wood, melel, and months. BLM is concerned csg @2915. Slotted liner concrete debris. Fish Creek #1 US Navy I BLM Medium None None Yes about exposure to wildlife to TO. Completed oil well Rusting barrels Need HRR, PA, Workplan for SI with Sampling. rasing cemented at 48; Drilling Mud Assessment. gas 0mv and explosion Surface Cleanup. Small gas while drilling at 863'; hole leak in wellhead flange, will Filled with fresh water to Wolf Creek 91 US Navy f BLM Low None Nano No flow if the valve iso en 330' No data. csg cemented a[ 53';hole left tilted with fresh water, Wolf Creek 02 US Navy 1 BLM Low Noire Nona No Need HRR. PA. Sl. fish in hole csg cemented at 107'; No data bridge plugs from 1447 to 1735 and from 554 to Wolf Creek #3 US Nayy I BLM Low None None No Meed HRR, PA, SI. 661, No data Add to Site list. Need HRR, PA, SI with sampling. csg slicking out of Drilling mud assessment ground with wood Surface Cleanup. Sheen on plug on top; solid surface water in well cellar, csg cemented at 30'; drill waste; wood hundreds of drums indicate pipe, drilling mud and debris; about 200 Skull Cliff Core iesl #1 US NaMy I BLM High None None Yes polential for cornlamrna[ion diesel left in hole nisling barrels Need HRR, PA, SI. Two open csg, wood drums are floating on a building; pylons; pond near the well. csg cemented at 1000', wood & metal Kaolak 01 US Navy 1 BLM t ow None jNone lNo Potential for hurried landfill. fdriltingluidsieftin hole debris Page 8 of 14 • • SPAR Response with Legacy Wells Lisl.xlsx 181-11119013 Risk Well Name Operator f RP ! land Mgr Priorlty CSP Status File 1NHazid #1 1 U Navy 19LM #1 JUS Navy/ umatik Ill US Na I BLM Low None None as[ Oumalik #i US Na !BLM Low None None #1 N East Topagoruk #1 USN l BLM Kniteblade #1 US Navy l BLM Page 9 of 14 Subsurface `AOGCC Surface SPAR Workgroup Notes Status Add to Site list. Need HRR, PA, SI with sampling. open flange Q Drilling mud assessment. Surface Cleanup. Drilling Gas well. Open ports. ground level. Mud pile overgrown with Drilling fluids and Metal & wood v , etallon and lichen tubulars lett in hole debris Need HRR, PA, SI. No evidence of sheen, stressed veg, or drilling csg cemented at 502'; open casing slicking out of waste on surface. Veg plug at 3470 to 3511'; ground. Wood appears heall drilling nuids left in hole debris. Open casing below Add to Site list. Need HRR, ground level. PA, SI with sampling- Revegetated. Drilling mud assessment. Numerous metal Surface Cleanup. Debris csg partially cemented at I support structures and drilling muds. Stressed 2762'. Plug at 2543% slicking up. vegetation Dridin mud left in hole Concrete debris, plate welded to pipe: l' of pipe rsg cemented at 1100'. sticking up - Need HRR. PA. SI. Drig fluids left in hole Wooden debris. Add to Site list. Need HRR, PA, SI with sampling. Driving mud assessment. open csg broken Surface Cleanup. Downhole material present csg cemented at 6073'. off and sticking up: at surface, area mostly original hole drilled to wood, metal, revegetated. Diesel still 7154'& junk len; concrete and other occupies the ground sidetrack hole left wilh debris. rusting dreulatioir lines. drillina fluids barrel Add to Site list. Need HRR, PA, SI with sampling. Dolling mud assessment. Surface Cleanup. Pile of tsg 10 1100'; pkig al open casing drilling muds is next to the 1049% drilling mud below sticking up. Wood, teller. No offical reserve pit plug: unknown fluids in metal, and glass noted o en hole debris. open casing Need HRR, PA, SI. BLM sticking up. Wood, stales that there was no metal, and glass debris at this site in 2012. csg cemented at 420% debris - •I 0 SPAR Response with Legacy Welts Lisl.xlsx Paye 10 of 14 0 0 w once a BLM 2013 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator I RP f Land Mgr Priority CSP Status File #IHazid Release? SPAR Workgroup Notes Status v F Status open casing sticking up. Wood, metal, & concrete debris rusting Need NRR, PA, SI. Reports barrels. One indicate solid waste csg cemented to 45';fish marked flammable Knileblade #2 US Navy I BLM Low None None No drums in hole hazard. open casing slicking up; metal & Krideblade #2a US Navy 1 BLM Low None None No Need HRR, PA, SI. csq cemented at 38% concrete debris Need HRR, PA, SI including learning assessment. Site partially No wellhead. submerged intermittently csg cemented at 80; Metal. Solid waste North Simpson Test Wel 4 US N2n I BLM Low None None No during the summer dri0ing fluids left in hole ? No dala crude wellhead. Need HRR, PA, St. Surface csg cemented at 685'; Wood and metal Umiat 01 US Navy J BLM I FUDS Medium Cleanup co 335.38.00113090 Yes, see file Cleanup drillinq fluids left in bole debris No wellhead. Gravel pad partially csg cemented a1486; revegelaled wood Need HRR, PA, SI. Surface cement plug from 440 to debris and pipe Umiat #i t US Na I BLM I FURS Low pending dos 335.38.00113083 Yes, see file Clea 490'; sticking u csg cemented at 7206'; vVefNwad- Gravel various plugs from 8250' pad revegetaled 7 South Sirnpson 01 US Navy I BLM Low None None Yes Need HRR, PA, SI. to surface No data Add to Site list. Need HRR, PA, SI with sampling. Drilling mud assessment. Surface Cleanup. Large quantifies of ferrous oxide, zinc oxide, zinc carbonate, and barium sulfate were added to drilling muds. Stains apparent in photos. BLM field camp an site. Walls between the reserve and Pare pits have eroded. Wellhead and Water flows into surface gravel pad. ? No Wook #1 USGS I BLM Low lNone Name Yes water during break22L no data data Paye 10 of 14 0 0 SPAR Response with Legacy Wells Lrsl.xlsx BLM 2x13 Risk Well Name 10porator I RP I Land Mgr Priority CSP Status I File #IHazid Arca- Barrow Cure #1 US Na l til.M Avak 01 US Navy I BLM Barrow Bi R' #1 US Na I BLM Barrow Cafe Rig Test 91 US Na I BLM #2 I US Navy I BLM #1JUS N,a I BLM H' h NOr1e None Test Well #1 US Test Well #2 US Barrow Test Wetl #31115 Na IN©r1h Slo c Bora IAedium None None Unknown Page 11 of 14 Subsurface -FAOGCC Surface SPAR IWorkgfoup Notes Status _ ___ araiu5 Need HRR, PA, SI. Surface Cleanup, Photo CIMG0218 csg cemented at 53` shows area of disturbed tubing hung to 708': hole open casing vegetation that should be heft filled with drilling mud slicking up; wood & investi algid durin Sf and diesel metal debris open casing Need HRR. PA, St. Surface csg cemeoled at BIF. sticking up; wood & Cleanu-. lu set at 1348' metal debris Not abandoned, site not cleared, Need HRR, PA, SI. Surface open easing 7? No Cleanup no data data Not abandoned, site not eteared, Need HRR. PA, SI. 'Surface open casing 77 No Cteanu no data data Need HRR, PA, St with sampling. trilling mud assessment. Surface Cleanup. Drilling Muds on Not abandoned, site -slowly revegelatmg site not igred, More information on drilling open casing 7? No mud specifics rs being researched no data data Need 1lRR, PA, SI wdh sampling. Drilling mud wellhead leaking assessment. Surface cemented Csg to gas!? Wood & Cleanup- Cellar does not 1270;slotted liner to metal debris. Area retain water 1956': tbg to 1939 affected 50'x50' Need HRR, PA. SI. Drilling Csg cemented at mud assessment. Surface 441'.hole Iell willed with open pipe; metal & Cleanup- On mads stem water concmie debris Need HRR, PA, Sl. Drilling Csg cemented al 2260'; mud assessment- Surface periorated liner to TD. wood, metal & Cleariu . fln road s stem lin Completed well. Conerete debris Need HRR, PA, SI with sampling and workplan. Drilling mud assessment. Surface Cleanup. Drilling +csg cemented at 10461: open c5g slinking mud at surface. Sheen on hole left filled with drilling up; wood & metal surface wafer in well cell larQuids and wafer. de" 0 SPAR Response with Legacy Wells Lisl.xlsx Well Flame Operator I RP I Land Mgr BLM 201$ Risk Priority CSP Status File #ltiazid yr once oF— Historic Release? SPAR Workgroup Notes AOGCC Subsurface Salus g AOGCC Surface Status no data. Likely revegetaled. Removed from our list of wells of concern in < 50', no csg, no API#, October, 2012 Oumalik Foundation Tess A US Navy I BLM None-uncased hc None None lUnknown Need HRR, PA. not in AOGCC database Monlht Meeting no data. Likely revegetated. Removed from our fist of wells of concern in < 50', no csg, no API#, October, 2012 Cumalik Foundalion Test b US Navy I BLM None-uncased hC None jNane Unknown Need HRR. PA, not in AOGCC database Monthly Meeting no data. Likely revegetated. Removed From our irsl of wells of Concern In < 50', no csg. no API#, October, 2012 Oumalik Foundation Test A US Navy I BLM None-uncased hc None lNone Unknown Need HRR. PA, not m AOGCC database Monthly Meeting no data. Likely revegetated. Removed from our list of wells of concern in < 50', no c5g. no APF#. Odubut. 2012 Oumalik Foundation Test A US Navy I BLM None-uncased ht Nune lNone Unknown Need HRR, PA, nal in AOGCC database Monthiv Meetin no data. Likely revegetaled. Removed from our Ilst of wells of con cam in < 501, no csg, no APi#. October, 2012 Oumatik Foundation Test 0 US NavyI BLM None-uncased hc None None Unknown Need HRR. PA, not in AOGCC database Moral Meeting no data. Likely revegetaled. Removed from our list of wells of concern in < 50', no csg. no API#, October, 2012 Ournalik Foundation Test 4US Navy I BLM None4xwased h_j None None Unknown I Need HRR. PA, not in AOGCC database Month Meetin Page 12 of 14 0 Page 13 of 14 SPAR Response with Legacy Wells LrsLxisx Well Name BLM 2013 Risk Operator f RP I Land Mgr Priority Historic CSP Status Fife #IHazld Rslease7 AOGCC subsurface Status �__ - -_-�� . A013CC Surface Status no dala. Likely SPAR 1Norkgroup Nates revegelaled. Removed from our list of wells of concern in < 50'. no csg, no AP IN, October, 2012 Oumalik Foundation Test US Na!q BLM None -encased h None None Unknown Need HRR. PA. not w AOGCC database MonthlyMeetin no data. Likely revegelated. Removed from our list of wells of concern in < 501. no csg, no API#, October, 2012 Oumalik Foundalion rest U5 Na I BLM None -encased h None None Unknown Need HRR, PA, not in AOGCC database Monihl lAeeli no data. Likely revegetaled. Removed from aur fist of wells of concern in 0urn alik Foundation Test US Na 18 LM None -encased fi None None ilnknown Need HRR. PA, < 50', no csg. no API#, not in AOGCC database October, 2012 Month! Meetin no data. Likely revegetated. Removed from our list of wells of concern In < 50', no csg, no API#, October, 2012 Oumalik Foundat'Gon Test US Na I BLM None encased h Nome None Unknown Need HRR, PA, not m AOGCC database Month! Meeting property abandoned per then -applicable South Banow #7 US NEILM 2LI None None Unknown Need HRR. PA, ro erl lu ed re s no data to support proper Um -Qt 02 US N Noire Pendin Clo 335.30.001/3078 Yes, see file Plu d to surface abandonment no data to support proper Uncal #5 Ummt #9 Urrval A66 Umial #T Atiaaru Point#1 U5 US US Na I BL M US Na I BLM USGS/BLM None Pendin Hi h -PCB cleanu Active None Pendia None tPendi Mane Clo 3L5 313.00113079 335.38.00113093 Cao 335.3$.00113080 Clo 335 38 001I3091 None Yes, see file Yes, see file Yes, see file Yes. see lite No Plu ed E4 surface property plugged and abandoned pfupedy plugged and abandoned property plugged and abandoned Need HRR. PA,Plugged by properly plugged and BLM in 2009. abandoned abandonment suriaoe site rcmediated surface site remediated suriacx V le remediated surface site re medialed Page 13 of 14 SPAR Response with Legacy Wells LrsLxlsx Page 14 of 14 0 vrcTon`ce o BLM 2813 Risk Historic AOGCC Subsurface AOGCC Surface Well Name Operator i RP 1 Land Mgr Priority CSP Status File #fFlaxid Releases SPAR Workgroup Notes Status Status Add to Site list. Need HRR, PA. SI with workplan and sampling. Chilling mud assessment. Surface Cleanup. Two large breaches on the south side of the berm allow water out of the reserve pit. Plugged properly plugged and surface site Drew Point #1 USGS 1 BLM None None None Yes by BLM in 2410. abandoned remedialed On Site list Need HRR, PA, 51 with workplan and sampling. [frilling mud assessment. Surface Cleanup. In 1976 the reserve pit berm failed and dolling muds/cutlings were released onlo the Poe of Teshekpuk Lake. Plugged by BLM in 2008. Solid waste from camp aril drilling operations buried on northern portion of pad. Erosion has exposed solid properly plugged and surface site East Teshek uk #1 US Navy 1 BLM None Active - waits 3Q0.38.11012652 Ycs, see file waste. abandoned remediated Threatened by erosion. properly plugged and surface site J. W. Dalton $P USGS f BLM None None None No Plu ed b BLM in 20fl5. abandoned rernediated properly plugged and surface site South Barrow #8 USAF 1 BLM None None None Unknown Need HRR, PA, abandoned remediated properly plugged and surface sile South Bartow 911 US Na INorih Slope Bono None None None Unknown Need HRR, PA, abandoned remedialed properly plugged and surface site South Barrow 013 US Na lNerlh Slope Boro None None None Unknown Need HHR, PA, abandoned remedialed properly plugged and surface site South Barrow #15 US Na !North Sloe Boro None None None Unknown Need HRR, PA, abandoned remediated properly plugged and surface site South Barrow #19 US Na 1Nrarlh Sloe Baro None Nana None Unknown Need HRR. PA, abandoned remediated Properly plugged and surface site South Barrow 1x20 US Na Worth Slope Bora None None None Unknown Need HRR, PA, abandoned remedialed Need HRR, PA, dolling mud assessment, containment assessment, possible releases. Breaches allow wafer to flow into and aul of property plugged and surface site Watakpa #2 USGSI BLM None None lNone lyes I reserve and flare pits. labandoned irernediated Page 14 of 14 0 Colombie, Jody J (DOA) From: Wallace, Chris D (DOA) Sent: Monday, December 03, 2012 9:49 AM To: Ballantine, Tab A (LAW) Cc: Foerster, Catherine P (DOA); Colombie,Jody J (DOA) Subject: Legacy Wells North Slope Borough South Barrow#4 (PTD 1000260) and #7 (PTD 1000300 and PTD 1870750) Attachments: Letter to Cathy Foerster 11-29-12.pdf; Certified mail for Cathy Foerster AK Oil Gas Conservation Commission 11-30-12.pdf Tab, Please find attached correspondence from North Slope Borough following our enquiry for South Barrow#4 and South Barrow#7 legacy wells status. South Barrow#4 Please review NSB response and provide legal opinion on if this is a NSB or Federal problem. NSB indicates it to be a Federal Legacy. South Barrow#7 (PTD 1000300) and NSB-07DP (PTD 1870750) same surface location. There is a ground clearance granted by AOGCC in October 20, 1988 which states "the commission determines the location meets requirements of 20 AAC 25.170 and hereby approves final location clearance for NSB SB#7 well location." There is documentation from AOGCC (August 31, 2000) recommending the marker post be removed and abandonment be removing the marker post, cutting off casing 3 ft below grade and welding on a marker plate. That would be to current AOGCC regulations 20 AAC 25.170. If NSB abandoned this well to AOGCC specifications of 1988, can we now require them to comply with 2012 regulations? Would NSB similarly be able to claim this to be a Federal legacy? Thanks and Regards, Chris Wallace Sr. Petroleum Engineer SCANNED APR 2 2 2Df4 Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1250(phone) (907) 276-7542 (fax) chris.wallace@alaska.gov Original Message From: Foerster, Catherine P (DOA) Sent: Friday, November 30, 2012 9:24 AM To: Colombie,Jody 1 (DOA); Wallace, Chris D(DOA) Subject: FW: certified Letter to Cathy Foerster 11-29-12 Jody, 1 They sent this directly to me; so you .._.ver got a copy. Chris, Let me know where we need to go from here. Thanks. Cathy Original Message From: Reanne V. Heath [mailto:Reanne.Heath@north-slope.org] Sent: Friday, November 30, 2012 8:52 AM To: Foerster, Catherine P (DOA) Cc: Tom Nicolos Subject: FW: certified Letter to Cathy Foerster 11-29-12 Good Morning, Tom Nicolos asked that I forward this email on to you. The original is forthcoming in the mail. Have a good day. Sincerely, Reanne Tupaaq Heath Senior Office Specialist North Slope Borough Public Works Airports& Landfills Ext. 814 Original Message From: Marissa Crooks Sent: Friday, November 30, 2012 8:38 AM To: Tom Nicolos Cc: Reanne V. Heath Subject: certified Letter to Cathy Foerster 11-29-12 Good Morning, Here's your copy. Thank you 2 North Slope Borough Department of Public Works Central Office T t k P.O. Box 350 Barrow, Alaska 99723 r Phone: 907-852-0489 �:4 Fax 907-852-2300 440-►aale4;I AA Z'W1 Charlie Sakeagak, Director November 29, 2012 Ms. Cathy P. Foerster Chair, Commissioner Alaska Oil & Gas Conservation Commission 333 West Seventh Avenue DECEIVED Anchorage, AK 99501-3572 DEC 0 3 201Z RE: Well Com letio rm 10-407 and Daily Records Permit: 100-026, S. Barrow 21D AOGCO Permit: 100-030, S. Barrow #7 Dear Ms. Foerster: Please find attached information and documentation that I hope addresses your questions and concerns. South Barrow Test Well#4, Permit#100-026 For South Barrow #4, the attached AOGCC Inter Department Memo dated August 31, 2000 reads "There is no data on any type of P&A. From our records it appears the well was drilled in 1950 by the US Navy, production as apparently curtailed in 1968" The memo (attached) went on to describe AOGCC recommendations made in the demo and abandonment of the remaining well #4 well house, and equipment in place. In evaluation, South Barrow#4 with production from this well apparently ending in 1968 was not a well under control of the North Slope Borough during the period 1950 through 1968. The Barrow Gas Fields Transfer Act of 1984 was the instrument that gave a transfer in interests from the Federal Government to the North Slope Borough, extinguished federal obligations, and gave right, title and interest to the"subsurface estate held by the United States" The enactment approved by Congress in July 1984, became effective at midnight on September 30,1984, and specified boundaries by name and longitude/latitude in which right of way and subsurface rights for sand and gravel were included. South Barrow #4 went out of production in 1968,pre-dating the Barrow Gas Fields Transfer Act by 16 years. The 1984 Act reads the Borough is responsible for plug and abandonment if"the Borough abandons any Federal test well" and "shall be subject to all applicable federal rules and regulations in effect at time of abandonment" The Borough Dept of Public Works response to AOGCC may be accordingly, as well #7 was abandoned by the Government prior to conveyance to the Borough, that the Government should be responsible for the costs to be incurred for the plug and abandonment, and in meeting AOGCC requirements for this legacy well, as requested of the Borough in 2012. South Barrow # 7 Permit#100-030 According to records for South Barrow #7, the well was plugged and abandoned by the Borough in 1988. The AOGCC memorandum of August 31, 2000 reads the well was cemented by Halliburton and "probably a good cement job" although apparently there are some final details that need occur such as digging the well out 3' below grade, casings cut off, and welded cover be put in place. The AOGCC memo of October 16, 2012 reads the well completion report 10-407 has not been received for this well. There apparently has been some confusion internally at AOGCC on the designation of this well. The same AOGCC Memo describes South Barrow #7 to have a permit designation of 100-030. It was in 1992 the AOGCC allowed a permit to deepen the well. When the AOGCC assigned a new permit designation of#187-075 they then re-named the well NSB-07DP. There are then two permit numbers and descriptors for one well location. (Copies of correspondence enclosed) Research of hard copy well files in Barrow; show that apparently the AOGCC does not have this information in their electronic database. In the hardcopy files it was found on October 20, 1988 the AOGCC gave final location clearance for the well, and the well service report from the Borough describing the abandonment of South Barrow#7 was found (Form 10-407) these records then demonstrate compliance and are attached herein. Not in November 1992 the AOGCC made other changes to the database giving well #7 a new API number. I have included some backup information that I hopes clarify or address any concerns you may have. Sincerely, Tom D. Nicolos North Slope Borough Airports, Landfills, &Natural Gas Manager cc: Charlie Sakeagak, Director, Public Works Morris Lemen Jr., Deputy Director, Public Works • • • Or r 0,44 \� %mss THE STATE Alaska Oil and Gas °f Conservation Commission 1# _ =- ALASI�;A ltt- _:- :- = l GOVERNOR SEAN PARNELL , 333 West Seventh Avenue -11*ALAg81'P. r. \ Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 PUBLIC Pithrws N38 October 16, 2012 i Kent M. Grinage Manager, Fuel and Natural Gas Facilities Deparuiiem of Public Works North Slope Borough P.O. Box 350 Barrow, Alaska 99723 Subject: Well Completion Form 10-407 and daily records Permit: 100-026, S. Barrow#4 Permit: 100-030, S. Barrow#7 Dear Mr. Grinage: A routine database check reveals the files regarding the above referenced wells are incomplete. Specifically, well completion reports (10-407) and daily well operations reports have not been received with regard to those wells. The well completion reports and daily well operations reports are required to be produced within 30 days after abandonment of the wells. 20 AAC 25.070 (3)and(4). Please provide the required information no later than November 30. 2012. Should you have any questions relating to this matter, please contact Sr. Petroleum Engineer Chris Wallace on 907- 7931250, email chris.wallacealaska.gov. Sincerely, c � L Cathy P/oerster Chair, Commissioner cc: Each well file lir Note to file 7 January, 2003 Re: S. Barrow#7 50-023-20001-00 100-030 North Slope Borough Operator S. Barrow#7 DPN 50-023-20001-90 187-075 North Slope Borough Operator Problem: The 407's submitted indicate different surface locations. I called George Finlayson, N.S. Borough Gas Operations, (907-367-3228) about this. He had no specific location available (i.e. metes, bounds, sec, Twps, Rng)for these wells, but suggested that the surface location for the original hole and the redrill deepen,was about one-quarter mile south of the S. Barrow#8 well. That would suggest the the surface location for these two wells is that of the original well, i.e. 2040 FNL, 610 FEL, Sec 14, T22N. R18W U.M. RBDMS, Geoframe, and mainframe databases reflect this information. Ho and Okiand • f I • (a Cel // /CD MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Dan Seamount, (jt , DATE: August 31, 2000 Commissioner; THRU: Blair Wondzell, SUBJECT: Barrow Gas Field P. I. Supervisor i(rq/oa South Barrow Field FROM: John H Spaulding 4<3..1.e4 toCANNEV OCT 2 8 2005 Petroleum inspector August 31, 2000: I traveled to the Barrow Gas Field to review their records for "proper" Plug and Abandonment procedures on the following wells. South Barrow Test well #4 PTD 100-026 : There is no data on any type of P&A. From our records it appears that the well was drilled in 1950 by the U.S. Navy, production was apparently curtailed in 1968. The well still has a cover/wellhouse over it, there is still wellhead attached. As the accompanying pictures denote the area around the well head is covered in water. I was unable to find anyplace that would show there was a reserve pit, it is quite possible that the reserve pit was removed. I suggest that before writing this well off as P&A'd, that the US Navy be contacted in an effort to find out where cement in the well bore might be. I recommend that this well have the well house removed, the well head removed, the casing blinded off and at a minimum a mound of gravel or dirt placed around the well to keep the water from impacting the casing as well as mitigating a safety hazard. South Barro\hJ 7 NSB-07DP, PTD 187-075: According to Halliburton's job log and billing statement this well was P&A'd 3-29- 88, the AOGCC records show the well was removed from production status,and P&A'd on 11/17/88.The well has dry hole marker that appears to be placed in the cement after the well head was removed—no welded cover. From the pump reports it appears that cement was circulated down the production tubing with returns being taken thru the annulus. Once cement was observed at surface the annulus valve was shut in, squeeze pressure was obtained', and a volume was placed behind pipe or into the formation. Considering the depth of these wells (shallow) this is probably a good cement job, therefore a pretty good P&A. I recommend that the well be dug out 3' below original grade, dasings cut off and a welded cover be placed on the casing stub. As these wells are close to town this would mitigate a safety concern of mine with the winter snow machine traffic. goo IA XVI CO:ZI 9007./ST/an • • South Barrow# 12, PTD 100-035 and South Barrow# 18, PTD 100-046- These wells were P&A'd at about the same time as well number 7, same contractor and the same procedure was used. Contractor billings were used to obtain this information as well. No.Sundries were applied for or issued for these 3 wells. As noted in the pictures the casing on well# 12 is tore up some, and it appears that the dry hole marker has been placed in the cement at the top of the casing. There is no evidence of a reserve pit in the area. Well 18 as shown in the pictures, has the same type of surface abandonment, with the exception of the reserve pit area. The reserve pit area has been broached and some of the gravel has been removed. I recommend that these three wells be cut off 3" below original grade the casing stubs blinded with a welded cap and a mound of gravel placed over the casing. Facilities While in Barrow I visited the facilities that are currently in use. These will be replaced in the near future. The new facilities are on location but have not been commissioned as yet I was particularly interested in the current and future LACT metering systems. When at peak usage this meter handles about 6mmcf daily, a relatively small amount. I am not familiar with the current Rockwell "Electro Corrector„ system that is in use, this is a charted turbine meter. This meter is "checked"on a monthly basis and is compared to the Barrow Utilities Sales meter. This meter is calibrated on an annual basis. In the new facilities there are 3 separate runs, one for each field with a'Daniels" computerized orifice plate meter. These will feed into a 4" line that contains the "Daniels" LACT meter. The new facilities are quite a step up from where they are today. SUMMARY (by Blair Wondzeq): 1. South Barrow wells 7,12, and 18 appear to be properly plugged but should be cut off at least 3' below original ground level and a marker plate installed. 2. South Barrow well#4 does not appear to be properly plugged; the well house should be removed, downhole plugs installed and casings cut off at least 3' below original ground level and marker plate installed. 3. The AOGCC should make an annual inspection that would coincide with the calibration of the gas meters. Attachment: Pictures , Cu,- St Savok coo n XVI CO:Z.1 900Z/9T/60 11 ' ,;�� :) �! �� ;� � WALTER J.NICKEL,GOVERNOR � ! ( + + H ( �• �f. 111 1 C �� I t � .) 111 1 ALASKA OIL AND GAS !r 3001 PORCUPINE DRIVE CONSERVATION COMMISSION / ANCHORAGE,ALASKA 99501-3192 PHONE: (907)279-1433 f TELECOPY:(907)276-7542 November 5, 1992 Jerry Wilt Director, Industrial Development North Slope Borough Box 1120 Barrow, Alaska 99723 Dear Mr. Wilt: Regarding our phone discussion on November 3, the AOGCC will be reassigning API numbers on a well operated by the North Slope Borough in the Barrow Gas Field. In order to remove duplicate records from our databases, we will change the number for the following well: Well Name Permit # Old API Number New API Number S Barrow NSB-7DPN 87-75 50-023-20001 50-023-20001-90 We will not announce these changes to the public until the first week of December to give you the opportunity to make the necessary changes. Give me a call if you would like to discuss this matter further or if you have any questions. Sincerely, (, Jack Hartz Petroleum Reservoir Engineer Telecopy No. (907) 276-7542 October 20, 1988 Erik Opstad North Slope Borough 3201 "C" Street, Suite 602 Anchorage, AK 99503 Re: Final Location Clearance, North Slope Borough, South Barrow Well #7 Dear Mr Opstad: On August 16, 1988 the North Slope Borough (NSB) South Barrow (SB) #7 well location was inspected by our representative. A meeting was held with you and Gary Hammon in the Commission offices on September 22, 1988 to discuss additional work to be done on the location. By letter dated October 11 , 1988 you provided the Commission with photographs which showed all additional work to be completed. The Commission determines the location meets requirements of 20 AAC 25.170, and hereby approves final location clearance for the NSB SB #7 well location. Sincerely, . ,r Lonnie C Smith Commissioner jo/A.RAD.78 • • 51,OPE .6O NORTH SLOPE BOROUGH � �p Yprom ..a 'DEPARTMENT OF INDUSTRIAL DEVELOPMENT 11#� f,:•,/* •'•�•°°'^ �te BARROW GAS FIELD DEVELOPMENT "" rriA 3201 C Street, Suite 602 Anchorage, Alaska 99503 Phone: 907-561-8820 • - ` /Inin/hmiled UdU TO: Mr. C. V. Chatterton DATE: October 17 , 1988 Alaska Oil & Gas Conservation Commission TRANS.#: 8810171-NSB 3001 Porcupine Drive Anchorage, Alaska 99501 REFERENCE: SB #7 Completion Report & Wireline Log The following technical data is being submitted herewith. Please acknowledge receipt by signing and returning a copy of this transmittal to the North Slope Borough, attention Mr. Erik A. Opstad. ENCLOSED INFORMATION SUMMARY Submittal SB #7 Bluelines: 1 Dual Induction Log X Sepia: 1 Dual Induction Log X Completion Form 10-407 X Report: da44 ia3/Cts t Received By: A.O.G.C.C. / Date • opPE 110 NORTH SLOPE BOROUGH DEPARTMENT OF INDUSTRIAL DEVELOPMENT O � W1,lir �w BARROW GAS FIELD DEVELOPMENT Z M.r1..MParr '$` 1 3201 C Street, Suite 602 Anchorage, Alaska 99503 Phone: 907-561-8820 ^'"l. "N'-1(!) Mr. C. V. Chatterton October 17, 1988 Commissioner N. '` )) � Alaska Oil & Gas4, ,p nneA hil10-t Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 Re: Well Completion or Recompletion Report & Log SB #7 Dear Commissioner Chatterton: Over the past year we have been reorganizing and improving the well records system for the Barrow Gas Fields as part of an overall effort to correct the many weaknesses which have developed over the years. During this process it has come to our attention that a Completion Report may never have been filed for the redrill work conducted on SB #7 in 1987 . To correct this apparent discrepancy, enclosed please find a Well Completion or Recompletion Report & Log (Form 10-407 ) for SB #7 with appropriate attachments. As you know, SB #7 has now been plugged and abandoned, but we still regret this oversight and hope that it has not caused any inconvenience. Please let either Gary Hammon or myself know if you have any additional questions concerning this submittal . Respectfully yours, 46,-/Ze"------- Erik A. Opstad Geological Consultant North Slope Borough cc: Well Records � >o STATE OF ALASKA --- ALASKF. .,IL AND GAS CONSERVATION f_.rMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1.Status of Well AA Classification of Service Well OIL 0 GAS SUSPENDED/ „` ABANDONED SERVICE 0 • 2. Name of Operator /l�.L, 7.Permit Number North Slope Borough 87-75 3.Address 8.API Number 3201 C Street, Suite 602, Anchorage, Alaska 99503 50-023-20001 4. Location of well at surface 9.Unit or Lease Name 2042' FNL & 222' FWL, Sec. 14, T22N, R18W U.M. Alaska South Barrow At Top Producing Interval 10.Well Number As Above South Barrow #7 (SB #7) At Total Depth 11.Field and Pool As Above South Barrow 5. Elevation in feet (indicate KB,DF,etc.) 6. Lease Designation and Serial No. KB = 28.10 N/A _ 12. Date Spudded 13. Date T.D.Reached 14. Date Comp.,Susp.or Aband. 15.Water Depth,if offshore 16. No.of Completions 06/04/87 06/07/87 Susp. 06/11/87 N/A feet MSL One (1) 17.Total Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey 20.Depth where SSSV set 21.Thickness of Permafrost 2412 MD 2412 MD YES 0 NO No SSSV feet MD Est. 900' 22.Type Electric or Other Logs Run Dresser Atlas (DLL/GR) & (MLL/CR) 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT.PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" 65# - ace 158' 18-5/8" 110 sxs Perm_ - 10-3/4" 51# J-55 libiace 998' 14" ' 500 sxs Perm. - 7" 29# N-80 Surface 2238' 9-518" _700 sxs Perm. - 5-1/2" 20# J-55 2205' 2403' 8-1/2" - - 24.Perforations open to Production (MD+TVD of Top and Bottom and 25. _ TUBING RECORD interval,size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" 2395' None 8 Jts 5-1/2" 20# VFJ Slotted Liner - 10 Row 20 Slots/ft. , .060" 2244 - 2403' MD. 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/1----- N/A 27. PRODUCTION TEST , Date First Production Method of Operation (Flowing,gas lift,etc.) Well Susp. after 1st test. Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL ` CHOKE SIZE GAS-OIL RATIO 06/09/87 24 TEST PERIOD ♦ None 220 150 10/64 N/A Flow Tubing Casing Pressure CALCULATED011.-138L GAS-MCF WATER-88L OIL GRAVITY-API (corr) Press. N/A 520 24-HOUR RATE ♦ - - - N/A 28. CORE DATA Brief description of lithology,porosity,fractures,apparent dips and presence of oil,gas or water.Submit core chips. Originally, SB #7 was completed only in the Upper Barrow and this redrill was intended to slight deepen the well to expose approximately 33' of potentially productive Lower Barrow Sandstone. Operational problems prevented the collection of ditch samples, but subsequent wireline logs showed the Lower Barrow to be lithologically equivalent to that observed in SB #6 and SB #8 which are offset to the northwest and north. Calculated water saturations suggested that water had encroached into the Lower Barrow, and the production test on completion confirmed the wireline data. Form:0-407 Submit in duplicate r 29. 30. GEOLO( IC MARK ,1 i-ORMATION TESTS NAME Include interval tested,pressure data,all fluids recovered and gravity, MEAS.DEPTH TRUE VERT.DEPTH GOR,and time of each phase. Top Lower Barrow 2347 2347 Base Barrow Sand 239 ) 2390 31. LIST OF ATTACHMENTS Dresser Atlas openhole wireline (DLL/MLL/GR/SP/CAL) 32. I hereby certify that the fc regoin true and correct to the best of my knowledge Signed � Title Proj. Geologist Date Oct 17, 1988 INSTRUCTIONS General: This form is Designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. • Item 1: Classification ,)f Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a ;eparate form for each additional interval to be separately produced, showing the data pertinent to such i]terval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached sup)lemental records for this well should show the details of any multiple stage cement- ing and the location of :he cementing tool. Item 27: Method of C peration: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, ;,hut-in, Other-explain. Item 28: If no cores taken, indicate "none". -,11,01% BOROUGH $SUPE 1(; cS! OF INDUSTRIAL DEVELOPMENT " .. N:. S FIELD DEVELOPMENT eot, Suite 602 Anchorage, Alaska 99503 Phone: 907-561-8820 SR 'N Mr. Lonnie C. Smith October 11 , 1988 Commissioner �T� ; „ MS1 i Alaska Oil & Gas -M5 c az, ++r�+lk�ruled •011 I i.`.� 1 Conservation Commission ��u�.� �(�,.� ' '�T ilEC 3001 Porcupine Drive Anchorage, Alaska 99501 � ,, _,,, �,� i0-/9 88 ' Re: Photographs of Various Barrow Gas Fields P & A Well Locations Dear Mr. Smith: During our September meeting you indicated that it would be helpful if we provided the AOGCC with photographs of the final site work around the Barrow Gas Fields wells which were plugged and abandoned this spring. Enclosed are four (4 ) photographs of each location (SB #5, #7 , #12 and #18) taken immediately following our recently completed grading of the sites. In our opinion these locations now meet AOGCC guidelines concerning restoration of abandoned well locations in actively producing fields, and we respectively request your final approval of this work. Please let either Gary Hammon or myself know if you have any additional questions concerning the condition of the sites, or any other issues related to this matter. Respectfully yours, 400775,? -7 Erik A. Opstad Geological Consultant North Slope Borough r' , ( {,; .) cc: Well Records 1 r I • -Ari - . w ✓ ..!' r11 t.. ag . - :"'"► a 10 7 „DI", 7 .....,...... T irtiti, -1 0. ........ . __ . _ ..... •..... 1 . . ..... .. _ _ ... ... • li✓_ i ... C_ _ MEMORANDUM State of Alaska ALASKA OIL AND GAS CONSERVATION COPM4ISSION TO: Lonnie C. Smith DATE: September 2 , 1988 Commissioner FILE NO: D.ADA.017 TELEPHONE NO: THRU: Michael T. Minder AK4/. SUBJECT. Location Clearance Sr. Petroleum Engineer NSB South Barrow No. 7 Barrow Gas Field Sec. 14, T22N, R18W, U.M. FROM: Doug Amo CIET Petroleum Inspector Tuesday, August 16, 1988: I traveled this date from Anchorage to Barrow to conduct the final location clearance inspection on North Slope Borough South Barrow Gas Well No. 7. As the attached photo- graph's and AOGCC Surface Abandonment Report indicate this location is in good condition. The gravel pad is clean and contoured. There is a rough area around the marker post but I was assured by Gary Hammon NSB Rep. , that this area of the pad would be smoothed and compacted when the barrel around the marker post is filled in. I therefore, recommend that the commission grant this location final clearance status. In summary, I conducted the final location clearance inspection on North Slope Borough South Barrow Gas Field Well No. 7. I found the location to be in an overall good condition with the exception of the rough area around the marker post. I recommend that the commis- sion grant this location final clearance status. Attachment September 22, 1988 Final approval pending. NSB to remove barrel around marker post, fill and grade around marker and grade rough section of pad. Pictures showing completed work to be sent to AOGCC. Y - n0 nnln/Oa.,Rrnc aor-h Sl.org $os eu61 y Seuevet V Av&w et As P1 et pnT l'."4•••0410 .. 4 • •\•„ • aKi . . \ 1411r4 \ POT . . . ? 101, , .:. � .�.�.: . . .�w . . . . . MAIMrefSgr \. ~ . — . » . Itfi¥6,f ' 'tiinserc eirf . . . . yv \ . S_11,4EACE ABANi)L 1iN1' REFORI 20 AAC 25, AR'1'ICLE 2 FILE INFORMATION: Operator ; '. �. g . Date Downhole P & AA-1/ , Address .320/ 4 ' , `Y,,c�i;l_, e, A* ,?,:.7:7:2, Surface Location of Well Permit No. 2o40 Ft. 16 ,5 3, to Ft. 7W $. OF A1� (-ore. API No. 50- oz-7 - L..pCJo/ 1 • Sec. /¢ , T ZZ ,c/ ; R /� ;�, • a M. Unit or Lease Name u7�y-/ /3f;'I2/�'_v Well No. 1z' —7 .: Field & Pool ,r_77e> 2 AJ 674 FIELD 20 AAC 25.120: WELL ABANDONMENT MARKER: Dia. Steel Post (4"Min.) AL" Length (10' Min.) /Z./ Height Above Final Grade Level (4' tin.) /0/ Top of Marker Pipe Closed with: Cement Plug Screw Cap Welds 4....--- Set: —Set: On Well Head , On Cutoff Casing t,� In Concrete Plug Distance Below Final Grade Level 2.. Ft. . ,:., '' in. Lr Side Outlets: All Valves ,and Nipples Removed N/ j All Openings Closed if: , With Blinds , With Cement 1.-."'', Other �M INFORMATION BEAD`A'ELDED I)IKECTFL'i TO MRKER POST: rimr- (List Where Different from File Information) Operator /A/, 5, 25. Unit or Lease Name 6,74.4-7-- 4/1,( uJ 14A T.;. Well Number 051 7 , Surface Location of Well: 2o40 Ft. f S V, :,/O Ft. , .Ai -V,: Sec /4 , T Z21 ^1 , Il /8 1/J, M • 20 AAC 25. 170: LOCATION CLEAN-UP , .b m'` 2,,,,-. PITS: Filled In , Liners Removed or Buried , Debris Removedr SURFACE OF PAD AND/OR LOCATION: Rough , Smooth , Contoured , Flat Compacted , Other • CLEAN UP OF PAD AND/OR LOCATION: Clean 1/, Pipe Scrap , Iron Scrap , Wood , Mud , Cement , ' Paper , Other illir SURROUNDING AREA: Wooded , Brush , Tundra L/ , Crass , Dirt , Gravel , r" - Sand , Other CONDITION SURROUNDING AREA: Clean _ 1✓ Trash from Site , Trees and/or Brush from Clearing Site , Other ACCESS ROAD: Dirt , Gravel (.., , Ice , Other CONDITION ACCi 'S ROAD ANI) SURROUNDING: ' L-__ Clean Rough , Smooth , Trash from Operations , Trees and/or Brush from. Clearing Road , Spoil from Clearing Road , l__ Other REMAINING TO BE DONE: c /f!K 1,-.`"/c_.c.. 5 5 67 4== ,'.'rWA r;j i,':./`;i"_i /f/Mir =/.:' [0.77- O [" RECON LEND• APPROVAL OF ABANDONMENT: Yes i✓; No Final Inspection r •, rs (;'j .', ) DATE '�//�/ INSPECTED BY ; [nt F,!34/ 05/26/81 wirelpipppippogripplimpoilipmeimwrilmigPF-_, 4 ., ti • • • 0 szs *47 11/4 n � ► -MEMORANuuM Stat t of Alaska ALASKA OIL AND GAS CONSERVATION COMMISSION TO: Lonnie C Smith f` DATE: June 22, 1988 Commissioner FILENO: D.ADA.116 TELEPHONE NO: THRU: Michael T Minder SUBJECT. Location Clearance Sr Petroleum Engineer NSB SBU 5 & 7 South Barrow Gas Field FROM: Doug Amos \ Petroleum Inspector Tuesday, June 14, 1988 : I traveled this date from Anchorage to Barrow to conduct the location clearance inspection for the abandonment of the North Slope Borough South Barrow Gas Field wells 5 & 7 . I was unable to conduct a complete inspection on these two locations because of the snow cover. I was able to inspect and photograph the well abandonment marker post. Both marker posts were in compliance with the applicable AOGCC regulations. As the attached photographs show, there is considerable snow-covered debris on these locations. I was assured by Gary Hammon, NSB representative, that the locations would be cleaned up as soon as the weather permitted, and that he would contact our office to schedule another inspection. I filled out AOGCC location clearance inspection forms . These two forms , along with the photographs of the marker posts, are attached. In summary, I conducted a partial location clearance inspection on the North Slope Borough South Barrow Gas Field wells 5 & 7 . I was unable to conduct a complete inspection because of the snow cover on the locations . Attachments 02-001A(Rev.8/85) ,. $. RFACE AUANUC':?II•: :T REI'i)Rf l'.-y 7 Frn�,"ES 20 AAC 25, ;.RTICi ; 2 T c,- lc:' i'ILE INFORMATION: Operator I400-71-4 t...e,p6 Q(�5,., ate Downhole & A 4..../ BAddress - w I "C-II S- C.1r1 re,gP `4.id J Surface Location of Well permit No. SIC f4 20447' Ft. FS+, k,I( Ft. F Int*,OF. Nl£ corz,o.F API No. 50- 4.1av t,I6 ;_.:. ,.Sec. )4. , T 22 .&_, RJ , •JLM. Unit or Lease Name 5ni�tT1-4 Arz2-019 Well N o. -"1ZA. Field & Pool `',,pU7'"�i r AR, ..ac.,J cf615 TICL-D 20 AAC 25. 120: WEL1, ABANDONMENT MARKER: Dia. Steel Post (4"Min.) ¢11 , Length (10' Min.) Height Above Final Grade Level (4 ' lin.) (.,./ Top of Marker Pipe Closed with: Cement Plug Screw Cap Welds Set: On Well Head , On Cutoff Casing , In Concrete Plug V-- Distance Below Final Grade Level Z.' Ft. © i in. Side Outlets: All Valves and Nipples Removed -- All Openings Closed , With Blinds �,, With Cement 1„...--r-Other #,` : INFORMATION BEADWELDRI) DIRFCCFL'i TO 1 ARKER POST: Fir (List Where Different from File Information) Operator a:r44 SLOPE eni2'QU.61H Unit or Lease Name �0,,4.1-1..i 'R 412.1e-0 (n.) Well Number '� , Surface Location of Well: 2040 Ft. F S 04,, 6010 Ft. , F W fe. Sec 1 L}. , T 2.7- 14 , R, (g .Vi , U ''t 20 AAC 25. 170: LOCATION CLEAN-UP �t tiR of r.w PITS: ;.. Filled In , Liners Removed or Buried , Debris Removed KID Pr SURFACE OF PAD AND/OR LOCATION: Rough , Smooth , Contoured , Flat , Compacted , 2. Other ' CLEAN UP OF PAD AND/OR LOCATION: �. Clean , Pipe Scrap , Iron Scrap Wood , Mud , Cement , Paper , Other " SURROUNDING AREA: Wooded , Brush , Tundra (/Grass , Dirt , Gravel , r" Sand , Other r CONDITION SURROUNDING AREA: Clean , Trash from Site , Trees and/or Brush from Clearing Site - , Other ACCESS ROAD: - I Dirt , Gravel (///':-Ice , Other f' CONDITION ACCESS ROAD AND SURROUNDING: Clean Rough Smooth r/', Trash from Operations k Trees and/or Brush from Clearing Road , Spoil from Clearing Road , Other REMAINING TO BE DONE: R 1AAC`1'S b F5(2-i 6 fj Her4 5tab c.J 15 ,o_1.1 e O RECOMMEND, APPROVAL OF ABANDONMENT: Yes , No ✓ Final Inspection INSPECTED BY E( DATE 6,/ )4/gp, 05/26/81 / f r"-• u-rk 1,Al2.Fz.o14 1\10. I 1111.101,- 411p.- ,• • • — • . . • .. • • - , , . opPE NORTH SLOPE BOROUGH DEPARTMENT OF INDUSTRIAL DEVELOPMENT Q • BARROW GAS FIELD DEVELOPMENT "'"°°' -,/4- 3201 C Street, Suite 602 Anchorage, Alaska 99503 Phone: 907-561-8820 �_ .. Mr. C. V. Chatterton March 10, 1988 Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 REFERENCE: P & A Sundry Application for South Barrow Field Well #7 and East , 1 �� Barrow Field Well #12. Dear Mr. Chatterton: Enclosed are applications by the North Slope Borough to plug and abandon two wells within the South Barrow Gas Fields Pool Rules Area. This work marks the first step in the North Slope Borough's effort to improve operational efficiency in the Barrow Gas Fields, and to eliminate conditions which could potentially pose safety problems in the future. Briefly, well #7 was originally drilled by the Navy during the initial phase of South Barrow Gas Field development. The well was a marginal producer from the on-set of initial production and now produces water at rates which exceed the handling capacity of the well and surface facility design. Well #12 is a marginal producer originally drilled by the Navy as an exploratory step-out. This well contributes little to village gas supplies and the wellhead, along with other surface facilities, are in poor condition. The well requires ever increasing maintenance and could pose safety problems in the near future. Faced with the cited conditions we feel that abandonment of these two wells is a rational and prudent course of action. y STATE OF ALASKA — ALAS' OIL AND GAS CONSERVATION COM1, JSION -'c'`) .. APPLICATION FOR SUNDRY APPROVALS '1. Type of Request: Abandon II Suspend ❑ Operation Shutdown ❑ Re-enter suspended well ❑ Alter casing ❑ Time extension ❑ Change approved program ❑ Plugging ❑ Stimulate ❑ Pull tubing O Amend order ❑ Perforate O Other CI 2. Name of Operator 5. Datum elevation (DF or KB) North Slope Borough KB = 36' feet 3. Address 6. Unit or Property name 3201 "C" Street, Suite 602, Anchorage, Alaska 99503 South Barrow 4. Location of well at surface Umiate Meridian Alaska 7. Well number 2040' FNL & 610' FEL, Sec. 14, T22N, R18W 7 At top of productive interval 8. Permit number As Above Unknown At effective depth 9. API number As Above 50— 023-20001-00 At total depth 10. Pool As Above East Barrow Field 11. Present well condition summary Q Total depth: measured 2351' feet Plugs (measured) N/A �n'd I��,5 a true vertical 2351' feet �)1 , f "0V-.. Effective depth: measured 2349' feet Junk (measured) None L----'o�S true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface 146' 16" ± 100 sxs. 158' 158' Intermediate 986' 10-3/4" ± 600 sxs. 998' 998' • Production 2227' 7" ± 210 sxs. 2238' 2238' Liner 159' 52" None 2403' 2403' Perforation depth: measured 1„ 5 . , 20#/ft, slotted liner from 2205' - 2403 slotted 244' - 2403' MD BKB true vertical V:',.'.•�}' As Above Tubing (size, grade and measured depth) 2-3/8", 4.7#/ft. , N-80 @ 2395' MD BKB r.. „(:..:"''' Packers and SSSV (type and measured depth) None , 12.Attachments Description summary of proposal Detailed operations program BOP sketch 114---- 13. 1Y13. Estimated date for commencing operation On or about March 16, 1988 14. If proposal was verbally approved Name of approver %, Date approved 15. I hereby cer /' ->�� is true and correct to the best of my knowled e // � Signed i+' i 2-�� Title j G � � /77 Date 3 l0",, 7 Commission Use Only Conditions of approval Notify commission so representative may witness Approval No.8 _ //_3 Plug integrity 0 BOP Test )1-(fLocationclearance (0 Approved Copy Returned „... (..-,0. ...,./a by order of L4.Approved by Commissioner the commission Date-/ e, Form 10-403 Rev 12-1-85 Submit in triplicate . 51,0PE BO NORTH SLOPE BOROUGH DEPARTMENT OF INDUSTRIAL DEVELOPMENT 0 ""• �. "� BARROW GAS FIELD DEVELOPMENT "'"°°' 3201 C Street, Suite 602 Anchorage, Alaska 99503 Phone: 907-561-8820 =_ SOUTH BARROW WELL #7 PROPOSAL SUMMARY >_ r AND OPERATIONS PROGRAM ��- ,0' March 10, 1988 Proposal Summary Well #7 was originally drilled by the Navy during the initial development of the South Barrow Gas Field. As a result, the available data on this well has been obtained from incomplete daily drilling reports, miscellaneous correspondence, and contractor reports. The information contained in this application has been complied by the Barrow Gas Field Drilling and Geoscience staff and represents the best available information. Well #7 produces water at rates which exceed the water handling capacity of the well and surface facility design. Since this well can no longer contribute to village gas deliverability, we feel that abandonment is called for. General Operations Summary To abandon well #7 we intend to employ a quick and simple procedure as follows: 1. R.U. Halliburton, circulate permafrost cement 1,4 down the 2-7/8" Tbg and up the 2-7/8" x 7" annulus to completely fill the entire hole volume to surface with cement. 2. Close annulus and bullhead 50 sxs. of cement into the formation, R.D. Halliburton & WOC. 3. Observe wellhead pressure, remove wellhead, cut off below ground level and install " Dryhole" marker as per A. O . G . C. C. regulations. We expect operations to commence on or about March 16, 1988 to be completed in less than 24 hours. A.O.G. C.C. Page 2 of 2 P & A #7/#12 03/10/88 General Operations Plan To accomplish the abandonment work, we will employ the following plan for both well #7 and well #12 : 1. Circulate permafrost cement down 2-7/8" Tbg and up the 2-7/8" x 7" annulus to completely fill the entire hole volume with cement. 2 . Close annulus and bullhead 50 sxs. of cement into the formation, WOC, observe wellhead pressure. 3 . Remove wellhead and install "Dryhole" marker as per A.O.G.C.C. regulations. We expect to commence operations immediately on your approval, so your prompt consideration of this application would be appreciated. Thank you. ;.t. Sincerely, Er' A. Opstad Consulting Geologist cc: BGF Ops. . . , . • , 2- VENTED T.H.Fiu ROOF OF WELL HCA-ME 2. PRESSURE REDUCTION • STATION 0 0 . ii 0 0 . I/2.'VENTED OUTSIDE 0 0 Imo 0 ,../..-77"... . Of WELL 14 CX)7 . . 0 lb ale '16 ifi t / . .. IbIN,' ,.''''•..... , ',NAL 4W.. -qt 0 til i la 0 ° 0 .. 41) 1611 r , 1 i I/2' VENTED OUTSIDE .4 0 II Of WEL,UiOUSE milk CP my 1%26.,..... ir7f4 ; 11-Wifilk ..., -6,. li\l's iti.6...1 %or 414 , II! r git.. f0.1 400414. 3 Noor 40111%...00" 4010nv to, ,o, ID kID ... , • CO (%-.1„. dp, 0 0 Mragh 6 0 , 0 10 friN,.... 0 i iiiih' • I., ..- , e,,,,. . i .0 i, eakwir . , L. _, 0 ‘'`lig,. ' .%''''''Y .4. ii ite f V fite4, -' VIC i tliir° . 0 0 t 4kt. - V‘" • 0 l',' ' 0 . • "iu'''' ' 1i ( 4 0 - (5 0 . . ,..., • , , . . . i SOUTH BARROW WELL N2 .7 '3 . ISOMETRIC WELLHEAD SCHEMATIC • . r . NORTH SLOPE BOIROUGH +�1OPE Bo DEPT. OF PUBLIC WORKS - CIP ' UV "" ��, A Barrow Gas Development �� `" � +� 3201 "C" Street, Suite 600 ' s VA 3201 6 ,!‘,4, . -;-.'_ '.° Anchorage, Alaska 99503 i/ -z. Phone: 907-561-8820 1J 1,'`V ""cogJvwled luny 2'1411 TO: Mr. C. V. Chatterton DATE: December 21, 1987 Alaska Oil & Gas Conservation Commission TRANS. ,: 87122101-NSB 3001 Porcupine Drive Anchorage, Alaska 99501 REFERENCE: NSB #1, #2 , #3, #4 , and SB #7 Geologic Data The following technical data is being submitted herewith. Please acknowledge receipt by signing and returning a copy of this letter to this office, attention Mr. Erik A. Opstad. /V58 # 7(Dresse,- Ede 3o41)-- 6 3 ,.5"8'8 - n -Opal/ - a/s3 02ile� ENCLOSED INFO TION SUMMARY AtsQ / ,Orrssor .263'0#p3,6 g.7- D - opo-`r - g6am,2,fiz Ms * / &On) -#-03uc86- 0 -- caused` / 3/0.44< ,35--- Submittal /-. NSB #1 NSB #2 NSB #3 NSB #4 NSB #7 /1/53 # I/ �sek ECS 3a03)>#-D,35.s— p - a ,3o/ A/5. # akwid ,IWD #-C3L5ya -D - e�5 - , ye Wireline LIS X Alit/p) X X N'X Verification .X X X }X `,X MWD LIS Tapes X X �_X N, Verification X X ). MWD Log Sepia _ X Diplog Sepia X - X . CCL SepiaX Well History7;------:: G X () :4P- _Eilt12, 011. 0 � • - . A.O.G.C.C. /Ai �i& 2s.18 :4° oReceived By:olCOnRiSS►Oi/VS& #c2 & )#0v58,z - 0 -CaCse of - /�o rages 8/ -5 8 #dZ p 3,5g3 --b -- 0 y -- 83(7-,Z33 J Al to Ns a#3(Bakerd.)#D 3,5E44--O -cased- /06- .24(.2.5- 4/5 5 74'0.5"SSB 3 CA-es�S'ey q r O D - Ode 8 - 020 93--.21477.-y etx„golv NORTH SLOPE BOROUGHc, •PE Bp DEPT. OF PUBLIC WORKS - CIP `S' ' 4?0-. 6 Barrow Gas Development y ,M,,, ,�, M� 3201 "C" Street, Suite 600 Anchorage, Alaska 99503 we4.1(V- 1.1;5 -- - Phone: 907-561-8820 C4V- 111°I,Poratedltilli 2�� TO: Mr. C. V. Chatterton DATE: December 2 , 1987 Alaska Oil & Gas Conservation Commission TRANS.#: 87120201-NSB 3001 Porcupine Drive Anchorage, Alaska 99501 REFERENCE: South Barrow Well #7 Recompletion Report The following technical data is being submitted herewith. Please acknowledge receipt by signing and returning a copy of this letter to this office, attention Mr. Erik A. Opstad. ENCLOSED INFORMATION SUMMARY 1) Completion Report (3 copies) 2) Wireline Logs (2RA4Diir p ,r7X L. 1987 Received By: C,il !"'_ Gasrl�. om!�C lcsir C A.O.G.C.C. / Date Anc!1ssravp it 4o G S Re- c E -c,/ co R. c... er 14 ("S G-'cf-Y tv3 c 3 NJ I Ns I3rv. 1 Q (--Z) BNc G,K , 1, - , .s O 0 iJ ifARm Oa_(7 X 0 GE.J_.5.-- O. L.t-. (hTc e.� S�'� S �J n O C N 6 I, a, 5- C7 (Z CO 0- c. O. G. R . /, a, s CD Q tR4, P. ) UTP\-a6 Q Q CD . G N Nr'NS:a( 6 R I; a s' N4 c, 11/4). '(,l e v.), G Q S.r^.o X X 0 . Rof lJa, s' x x X S" Q ra_i )c x L c c,//,- god CP 0._ Pe- ,--? 0 1-- o r, /r /i/as/)9 7. 1 # 1 &t,s 1& 84 7 -cc/DI 4 oZ 44Ls !U.a L .4- y Si,iw " V 3 ,4ets /a LAG 6 5eee,;, bets / BL 4-. .Se r I a-- 7 ha.-s .2 gL i ,SeAIa. • ^` STATE OF ALASKA 4... . • . ALAS;., JIL AND GAS CONSERVATION' .,.,Iv1MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1.Status of Well - Classification of Service Well OIL 0 GAS ii SUSPENDED 0 ABANDONED 0 SERVICE 0 ' 2. Name of Operator 7.Permit Number North Slope Borough 87-75 3.Address 8.API Number . 3201 "C" Street, Suite 600, Anchorage, Alaska 50-023-2-9024 2°6°1 4. Location of well at surface 9.Unit or Lease Name 2042' FNL & 222' FWL, Sec. 14, T22N, R18W U.M. Alaska South Barrow At Top Producing Interval 10.Well Number As Above SB #7 At Total Depth 11. Field and Pool As Above South Barrow Gas Field 5. Elevation in feet (indicate KB,DF,etc.) 6. Lease Designation and Serial No. 24,10' .@ Bradenhead Flange N/A 12.,Date Spudded 13. Date T.D.Reached 14. Date Comp.,Susp.or Aband. 15.Water Depth,if offshore 16. No.of Completions 106-04-87 06-07-87 Comp. 06-11-87 N/A feet MSL One 17.fgtal Depth (MD+TVD) 18.Plug Back Depth(MD+TVD) 19. Directional Survey 20.Depth where SSSV set 21.Thickness of Permafrost 2412' ' MD 2412' MD YES ❑ NO 3 Not .used >ovx 11x'x Not determined 22.Type Electric or Other Logs Run •(DLL/MLL/GR) &, COLLAR LOG; measured from rig KB @ 36.0' elevation. 23: CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT.PER FT. GRADE TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 16" ':.• .' 65# - Surface 158' _ 18-5/8" 110 sxs --- 10-3/'4" .-.510 ' J-55 Surface 998' 14" 500 sxs --- _ 7" 29# N-80 Surface 2238' 9-5/8" 700 sxs --- 51" 20# J-55 2205' 2403' 24.Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval,size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 2-3/8" 7395' MD None 8 Jts 52" 20# VFJ Slotted Liner @ 10 Row with 20 Slots/Ft. , .060 Slots, run ing 26. ACID, FRACTURE,CEMENT SQUEEZE,ETC. from 2244' - 2403 w _bk,i DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED 27. tl. wuS t'9''r<= PRODUCTION TEST Date First Production Vii^-'"'' Method o+tperation (Flowing,gas lift,etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE 'GAS-OIL RATIO 07-05-87 15 Hours TEST PERIOD ♦ None 805 None 6/64 NIA Flow Tubing Casing Pressure CALCULATEDOIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (torr) Press. 230 N/A 24-HOUR RATE mr — — — — 28. CORE DATA Brief description of lithology,porosity,fractures,apparent dips and presence of oil,gas or water.Submit core chips. No core taken! Wireline logs indicate that the well reached TD below the base of the Lower Barrow Sandstone. The Lower Barrow sands had higher than expected water saturations. This observation when coupled with recent pressure profiles is suggesting that water influx may becoming a factor in the South Field. Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE VX 29. • 30. GEOLOGIC MARKEHJ ' ., uRMATION TESTS NAME Include interval tested,pressure data,all fluids recovered and gravity, MEAS.DEPTH TRUE VERT. DEPTH GOR,and time of each phase. Upper Barrow 2264 2264 None Lower Barrow 2347 2347 Base Barrow 2380 2380 ..f. frC q i mel p.' �`•els ' P's f*L491/1 :1".• gef .•• � %2 ERI A. OPSTAD ti 31. LIST OF ATTACHMENTS �4 %•• AA-188 Wireline Logs , � g0,eee_.•�.•t�•�<A�' 32. I hereby certify that the foregoing is true and correct to the best of my knowledge �'�r0O1+P Signer/J�/ Title Date /We, INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". LJLS : 7 f ni IL 6 SE Q STEVE COWPER, GOVERNOR ,...E ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 TELEPHONE(907) 279-1433 TELECOPY NO: (907) 276-7542 July 27 , 1987 Mr. Ron Chapman North Slope Borough 3201 "C" Street Anchorage , Alaska 99503 Dear Mr. Chapman: Attached for your files are approved applications for permits to drill North Slope Borough Wells #1 , 2, 3, 4 and 4,111 You will note that the approval date for these Permit to Drill Forms is subsequent to the actual drilling of the wells. The delay in processing these permits results from "honest differ- ences of opinion" which culminated in a June 22, 1987 agreement between the Borough and the Commission. We look forward to a continuing mutually beneficial relationship. Sincere , (...? _ / / V. Chatt-r .n Chairman Enclosures dlf: 6.NSB STATE OF ALASKA . - ALASKA L AND GAS CONSERVATION C IMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill 0 Redrill 0 lb. Type of well. Exploratory 0 Stratigraphic Test 0 Development Oil 0 Re-Entry 0 Deepen Xi Service 0 Developement Gas ZJ Single Zone 0 Multiple Zone 0 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool NORTH SLOPE BOROUGH 36 KB feet SOUTH BARROW 3. Address 6. Property Designation 3201 C STREET ANCHORAGE, AK. 99503 NSB FEE 4. Location of well at surface 7. Unit or property Name 11. Type Bond(gee 20 AAC 25.025) 2042 FNL & 222 FWL SECTION 14,T22N, R18W UH SOUTH BARROW At top of productive interval ABOVE 8. Well number Number At total depth ABOVE 9. Approximate spud date Amount 200,000 6/1/87 12. Distance to nearest 13. Distance to nearest well 14. Number of acres In property 15. Proposed depth(MD and TVD) property line 5,502 feet 1,800 feet 21,120 2,500 feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) Kickoff depth feet Maximum hole angle a Maximum surface 1,000 Psig At total depth(TVD) 1,050 pslg 18. Casing program Setting Depth size Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (Include stage data) 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 2,351 feet Plugs (measured) true vertical feet Effective depth: measured 2,351 feet Junk (measured) true vertical ' feet Casing Length Size Cemented Measured depth True Vertical depth Structural 134 16 100 Sx 158 Conductor Surface 974 10-3/4 600 Sx 998 Intermediate Production 2214 7 210 Sx 2238 Liner 149 51 Slotted Liner 2200 - 2349 Perforation depth: measured OPEN HOLE true vertical 20. Attachments Filing fee CX Property plat IX BOP Sketch ® Diverter Sketch 0 Drilling program X] Drilling fluid program 129 Time vs depth plot 0 Refraction analysis 0 Seabed report 0 20 AAC 25.050 requirements 0 21. I hereby certify that the foregoing istru -nd correct to the best of my knowledge Signed / .....2-0. /�/ Lite ?..e,Litiroi., Date 7 Commission Use Only PermitNt'.75 I A•I nurn2.5o01trs_2c, Approoat data See cover letter 50— 2p0t / for other requirements Conditions of approval Samples required 0 Yes T9,No Mud log required ❑ Yes No Hydrogen sulfide measures 0 Yes 0 No Directional survey required 0 Yes 0 No Required working sure for BOP- iI ; • 3M; 0 5M; ❑ 10M; 0 15M Other: "-- by order of Approved by --.-/ // /I Commissioner the commission Dat007 EPSON LAGOON • ' E I I • • ' l • SOUTH {ARROW EAST AREA FIELD _ D M,ror LMo --,_ / SD vwvpw COD r ! PROVED RESERVES DECEMBER R 1-11.5.ICY 6 SOUTH !•BROW FIELD wror (-4 / I PROBABLE RESERVES DECEMBER 19){-].!BCE PROVED RESERVES ~' 1 DECEMBER 197E-14p CF IIIITwII •lIA I --_- '/ _,...- I".- I _ ` COs rMll CONTACT yoH SEISMIC CLOSURE. POTENTIAL • ADDITIONAL GAS RESOURCES -,yr POTENTIAL RESERVES / < • B, ___`op »»i» Inn• 7 ICF M9660. , 3',,,a• ,fr ID•_= IJ ] r _ N "'WM,. ad 01111 :3294....7' 3294...05II;:0lI DADRA=•lE• / ' .,.. /J., Orr I *wn 41 `, \, _ 1\ 1 �oM1 p g! d n x 121:42:14 stIlk Ts �� . \ eE s. ' \ \ f1 ..3. , r�ry OIff W�[D �[ONI s•. 1 S \ \ 1 I I I r�SEE Il SS= -70SD� . 1\�1 / �� ` I• �°hr's) „.4:•6 M1`5° , „.. b. \�\ a;�/ Toro °piii, , .=1s°' ° / / a I\• VS ``_-' IA ' { S SEISMIC CLOSURE, POTENTIAL» EM'Mr -_' -=\I, / ' S S� O• IO QQ .9_, ADDITIONAL GAS RESOURCES —� Ili .....--- .5/00 71SD Kr' ----...-4//� 1y ^\ ti X l ` POTENTIAL RESERVES 1) {CF \ I hi, ...4111111.1111.111111k1171.50.1' .71SD u '� 4700' I L.—�/ Ru I\ 1 NMI =7Oa."' �o.jjp0 -7700. / ' s ' \ u` =75 0I 1 ..--'-•7700' --.7„...____I___--4........ ` ' v M1 \•••-----1------..'' •100%t / � D I ° I -----./ ...„...--.7730 — ---...' j0° u 1Y \ •7100'I \ 1Y N. SEISMIC CLOSURE,POTENiuL • I �- ADDITION•L 6A3 RESOURCES \ / �•/ \� I -�I �� _ POTENTIAL RESERVES • BCF \ _2100.---"" � •=� l_ _ �� I / r u .l N N N nE. / IA ,. I. ONT Xa 4,1110 TO I , �_ -7310'\ ...,,r464/266/6.06 22,4 " RI r IT Tl II a H Tl TT . :r3 i I i / I Ifil - STRUCTURE MAP i LEGEND APPROXIMATE TOP BARROW S I N n ,. :. a PROVED AND T. +. 1 BARROW AREA I I Pin.POIl HrI•I lFfflvE3•{I[ 5511191$ 1 O NATIONAL PETROLEUM RESERVE IN I u•%E F 41:4,17.1 TEMPI 1 GLUT AND ASSOCIATES R Irv.' (iv I7 L✓ R /4 W A+GE Nr — ) U/ J / / .%,I) ✓L-'..., ,J 1 % !) ! . I . ' -58 i i t Aill---jea I: . iiii ! , , 1 . 1 i ; , , _ra_.15,-) .A3.5-. : .: , ' ' 1 : , . i 6t -� t4 -t .d i i 1 I � ,�■r,_-� f a tE i • 4 , I 1 rt....), >L I_ 1 ' i i 1 5 � v�? , =� 1 � � jii 1 ' i I IT-1-7 ! 11.!? � , i I 1 ! i i , i I . . mill 1 i 1 iiiiiai I i I i ' 1IliNtilMIL I III i 1 11111 111111 11i1i1 IA • ORt ! i I I 1 i v I Ui'!IIIUIIIHIIHH 111111 ' i11 I : I • l /, -roc --r . MINIM 1 ■■■■■■■■RV1■ , t ./..rill ill i i MINIIIIIIIIIIIMI11■■■ 1111■ ' Ik.t ■ I _. ■■E ' i ' i ■11■■■ I iniiiiiiIIiiiiiI i I i I i I 11111111l l t..F . i /Pt' !, I ` 1 ' ` ^ ' +wiiIU■■■■■ /i' V ■ W iLLJ ! _ iliii illg/,M .,, , . X o ®�11�■■■■■1�" - d o s 111 MINN1 11N 1 � ■ ■ I i i 1111■■ 1 1 OI N 'I 0 II I 1 1 4 ... __. i I I I i 11111111111111 ' i 1111111111111111x 11 11ni■■W1 xa -AIME 1 Milll i I I I I , I • 1II .. :ft ) e).4)c — IIi i 1 •• •E 1 , ; , , 1 .2 , , 47 /, - • .1 n1 1 , 1 , , , ! , , 1 , . ,- 1 . , . . , , , ! ; A ---7--: , ._ I i t1 ± 11 , • /30� MEMORANDUM :VW TO: Kenny Wolcott, Manager of Barrow Gas FieldsOA FROM: Ron Chapman, Petroleum Engineer Public Works Department DATE: May 22, 1987 SUBJECT: Remedial Operations - Barrow Gas Fields Potential quick capacity reduction in the East Field has nessita- ted two operations on existing wells. No. 14, a 1 MMCFPD producer is the lowest producing well in the East Field. To offset its potential demise it is envisioned that No. 7 will be deepened and No. 19' be converted to high volume production. The intended sequence after drilling No. 1 through 4 is to deepen No. 7 and then rework No. 19. Each of these operations are discussed below. No. 7 was drilled into the Upper Barrow Sand only. Deepening of the well be less than 50' would expose the potentially highly pro- ductive Lower Barrow Sand. The planned sequence is as follows: 1. Kill well with 77 CaCl . Observe 2 hours before proceeding. 2. PU joint so first collar is at 7" , set clamp, strip over THF. NU flange, screw in tbg hanger w/BPV. Land and set lock downs. NU double rams and hydril with mud cross. 3. POOH,LD 2-7/8". 4. RU Dresser. Cut 5" 20# liner 5' below hanger. 5. RIH w/spear and stop to set grapples 2-3 from TOL. Jar loose and POOH. 6. RIH w/jars and spear. Latch liner and POOH. 7. Inspect liner and replace if indicated. Kenny Wolcott Remedial Operations/BGF Page 2 8. TIH to bottom of 7 Circ & Cond. drlg fluid - 7% CaCl . w/HEC only: VIS = 45. filter all fluids prior to pumping. 9. Drill to 10 ' below base of Lower Harrow. Drlg times will be plotted - approx 50 ' total . TD will be called on rig. 10. POOH. PU liner hanger & liner. 11 . TIH. Set hanger. 12. POOH. LD DP. 13. RIH w/2-3/8" tbg to near bottom. 14. Space out. Install BPV & land. Displace hole to 77 CaCl wino NEC. 15. ND BOPs, NU tree. 16. Rock in , flow until clear and release rig. 17. Clean up. 18. Reset wellhouse piping, power ad turn to production. Do not exceed 300 mcf/d for first two weeks increasing rates at maximum of 100 mcf/d per week thereafter. In regards to No. 19, you have my memo of April 22, 1987 speaking of the reason for working on the well to anticipate the loss of No. 14. Further, in response to your question of what happens "if it doesn 't work" ,, the well can be replumbed via a Hercable snubbing unit prior to major demand times. Below is the detailed procedure. Ron Chapman - ' ' �iA'w^�r+�•.i'�;erlrs�. '��• 1 "'lr•s . OIOIT!) Hyl. I `e�..; ' __... •-- ti ' irfr '4 •. 44 C 14i1,33%.,,, / *tr • E144 ..,:..iii. .%* P142 • '� SOUTH BARROW 7 ~ .E 142♦ « 1' WELL B << • r •E141 ;� 1 N 6,314,929 f (,./ E 666,220 i �\/ ( iDIGITIZED 3 «\ i 3 i w 7 SOUTH BARROW :1 I �' _ -� ) WELL 6 / N 6,313,657 / . P149 E 663,139 y 1_J .0 C DIGITIZED (\� , ) �.) a. • ��E\a6w PI51 / `J ��,\� \ .. • ,n7:4-1, 5 / _ k_ 154 `. C(� •``��_. • / j \-. . `� -i' ,\ E148 sic. SOUTH BARROW �� ) Al ." \ WELL 7 I1. -..�. \ i.) . �..", C, , .. ) N 6,312,993 \ ,,., '•" _\DIGITIZED C _ \ . ��" R115 /71: • S• ^c � y __._ -- 1, I \ . ---.. , �/a I o c ) \• �` `\.• .. of tai Al • '„, _ h > �, , .f o r'1 /4, 1 Se • SOUTH BARROW- - \ :. ��r /7 22 Al �E jh WELL II ;';_, 139'1 N 6,311,567 - 6' E 664,031 T • 17 AJ 1 f v/f11 \ DIGITIZED l` ;, �, / 1 •.. `1� \ cle.e/�en /,'!j . 1 • P-el , 7` Sh' we_,C • BAR SCALE - \ \ A) �(, .. 400 0 400 800 12O0feet • ., t , This mop located within T22N, RIBN!and RI7W;U.•M. 1- \ //14c/ L /' L ) LAKE �,� I I •�~ �r 4p . � / , + ` DRY J I4 3 / : . !, 2 24 Y , / , .<.,1f (.rcLA u.iSi PGR Nnvl WcZL PTS C many LIov',, 5-7,1), Fc.-e,-gi., Ice & Well N�. S--'� �.. r-,,.,` _'IJ5 7 Tis APPROVE DATEND RE^.ARXS (1)Fee `j 7 ',-s7 1. Is the pe^rit fee at-,acbed 7-2-'-a7 �2. Is we11 to be located in a de:fned °�•f .V' I,r a br c., plt,,,.,5 (2) Inc Pool •F..(ro.•-��5 8/�•!P� p.•4•'c h�.,r� (2 for 3) 3. Is well located proper distance iron property line - ii , 4. Is well located proper distance from other wells ., e. 5. Is s tient tmdericated acreage available in this pool 6. Is well to be deviated and is we_lbare plat included a s,i,t 4.1, 7. Is operator the only affected parry 2g7 .�1/,y,( 7-2V-8.-r fifteen-day Can permit be approved before fte n-day wait 7 (8 - (3) Admin ?-?4-7''f, 9. Does operator have a band in farce ( tau li 10. Is a conservation order needed 4k -v:<< h. ...,.r+,,. <c`ri•- rb,,('i h,,,i y ct 7 a 11. Is adiamnstrative approval needed �1 - 0 a 13) 12. Is the lease=liber appropriate 13. Does the well have a unique name and rna,+b zi.. -_0.44 N s p-7 (4) Cas �dq�il/ 20- (- (14 us 14. Is conductor swing provided _ 6.Y,s•E,1 P-.,,..,f f4 rl.-..-/, 15. Will surface casing protect fresh water zones N/a 16. Is enough cent used to circulate on conductor and surface 17. Will cut tie in surface and intermediate or production sayings _ 0 t:8 18. Will cement cover all known productive horizons - D.9.4-4.4 41../,- m 19. Will all casing give adequate safety in collapse, tension and burst.. ,y/A 20. Is this well to be kicked off from an eacsting wellbore - At.. cn$ 21. Is old wellbore abandonment procedure ineltvieri on 10-403 -AeJ,o m M 22. Is adequate wellbore separation proposed /' (5) BOPS 1'7`✓.i4!7-2o-87 rz (23 tcru 28) 23. Is a diverter system required �C 24. Is the drilling fluid program sciatic and list of equipment adequate- i/ I,;,... • 25. Are necessary diagrams and descriptions of asfeseeraik BOPE attached. _ 26. Does BOPS have snff;c+enc pressure rating - Test to goon psig .. ,OL - 27. Does the choke manifold comply w/API RP-53 (May 84) _ 1028. Is the presence of 82S gas probable - Far acploratory and Serati.gz�hic wells: (6) Qffglt 6 29. Are data presented on potential overpressure zones? 30. Are seismic analysis data presented on sballoa gas zones 31. If an offshore loc., are survey results of seabed conditions presented--- -- . (6) Add: 1q'7'4/7.z,87 32. Additional requirements - ,4. eeo� Additional Remarks: ,51-6»-.:4!,.4 P4_t Qo.r ,. • c,t,,,' iTCW�: I1R INLTIAL CEO. UNIT ON/OFF I,c41,t.. .f (h-/a.6 .,..,I - 0_4. ,,r,,, '.,c 5-. •e', WVA4 MIM RAD= I POOL. CLASS STATUS AREA NO. SHORE a aSfi-wwti...0 u-vecld ,I,-,(g7- 7,4.(5-00 .1)F V I- -4 F9d - 0,,U 01/28/87 ** REEL HEADER ** N3 t -fi / 1 G.EEL N/ P : OPe y CATS ORIGIN =SYS �/ /' 3_5-kW. SERVICE NAME : FITLIS -; EEL CONTINUATION NUiM3ER. 21 P -> r,.:f r c1.4,' PR4 VIOUS R=FL NL`.Y P f COM;1ENTS : DRESSER ATLAS L _S CUSTOMER TAPE --- CREATEC 3Y SE_ PP. CO'A r LENGTH : 172 SYTES * * TAPE HEADER ** TAPE NAME : CATE ORIGIN : FSYS SERVICE NAME : 'MAIN G TAPE CONTINUATION; NUM1'.ER : 01 PREVIOUS TAPE NAF : COMMENTS : L`ENGT- : 172 FYTES ** FILE HEADER r' 1 ** "FILE NAM_ : MAIN D .C51 ( j SERVICE NAME : I f 2i lo-0 VERSION "- : 1 DATE: 05 /11 / 20 MAX RECUR,' LrFN PTH : 1C2, ',YTES FILE TYPE: LC PREVIOUS F LE M vE : ** INFJRN.ATICN RECCRLS ** VMEM CONTENTS _NITS3 DO CtiNGPTH :LOP.- ?ORO-J-' tt WN ' NS-' NO. 7- C�n�•Cpl� t FM . ._.STvim-" SARRU'nGAS FIa �aS \1&t:00 5 COU:' : NOR" SLOPE STAT . ALASKA LCC ** FORMAT ** ENTRY BLOCKS TYPE T-NTRY .:ESCPIPTION 4 1 .DEPTHS DECREASE 6'. 0 FRN+VE SPACING v . 1IN FRAME SPACING UNITS 11 1n UAX:MUM FRAMES /REC - 0 T -+Rv:N.1TOR -0 .. 5 0 L':VEL SPACING DATUM .SPEC: TCATInN yLnf.KS CURVE REP l, .V ,2PPR NAME CODE SIZE SA 'PLE UNITS .Jav _ C'0 : ' SAO. L -. UNIT : S h i L 1 S [ 1 m J Tk • ... -, 1 z , , 2 T:K . 4 1 /<\ \_: k , : 1 F / e' ILL . : 4 l 2,vy 4 1 ," P R3 - SS 4 1 2 wP 2 -* CR T -* :\TPY TL124 : TYPE :&TPY _, _. :R: 2T:Cx 4 1 :EPTH3 :ECPE4S 67 . 1' ":P=mt.- SRC:\, 9 . 1 :N RR-v- 3:aC NC UNITS 11 1E k.XIMJM FR4MESIRECORO 2 TERMINATOR -2. 500 LEVEL SPaCING DATJM SPECI.IC TION .LEEKS CURVE REcR CURVE Rf77 wage CCs. OI: E S:0 PL. = UNITS wane 0CC : ::: S PL: UN:TS CAL 6k 4 1 I . £S 63 4 1 vV Is ") 4 1 4 5z fR 4 1 ©V ID ! E 4 1 4 T:12 *� 1 SEG. CP 65 4 1 4PI SR \j 4 1 xV TTEN 69 4 1 L27 3P5 63 4 1 ;/ NN ;'ILL 63 4 1 Cee' Ps f? 4 1 'r t, kD 6s 4 1 C"-IMP/ ** 04T4 ** SEPT¥ 2409. CE0 FT 734 . 264( m C=L 3. 132 ES 1 £3 . §£2 IS 357 .464 EE 2-2 . 976 ID 147 .043 TEMP 60. 094 CR 65. 4,63 SA 1 . 464 TTEN 939. 305 S= C ] . CCC RMLL 10000 . 000 2S ] . 763 RD 24. 144 SEPT¥ 2400 .000 RT 731 . 5215 M CAL 3. 172 ES 123 .932 I3 357 . 4!= ED .74C . -,7- ID 147. 043 TEtR c: . :'- :R 64 . 727 EP 1 . 4t4 ITEN 1Q1D. 497 SPD 41 . 746 RMLL 12022 . 000 RS 1 ; . 76« RD 24 . 144 SFPTH 2300. CCn FT 701 .5415 M :AL 3.132 ES 147 . 03£ :S 514 . 123 e: 1@3 . 2 §4 ID 166,6\£ TEMP 60. 127 SR 53 . 602 SP -2 . 173 TTeN 1712 . 124 SPD 39, 446 RMLL 12002. 00E P5 1C. ;=: RO 17.296 : EPTH 2220. 200 FT 67[. 5613 M CAL 3 . 263 ES -0. 126 IS 5 . 235 EE 1 . C4, ID 4.440 TEP 5;. 5C3 C7 ` 75 S� -10 . 331 TTEN 1628 .760 SPO 40 .135 P'LL 10000. 000 R: 2 . 133 R3 5 . 502 DEPTH 2137, 500 9T 651 . 5112 M • TTEN ' 167T.2i2 SPU 3, ,9at r1LL IauLW. UL. ,a ) R: 0. 163 STARTING DEPTH = 2409. 000 FT 73A . 2646 M ENDING' DEPTH = 2137 . 500 FT 651 . 5112 M ** PILE TRAILER * * FILE NAME : MAIN C . JO1 SERVICE NAVE : VS SICN » : 1 DATE : 95/11 / m;XIM:M LENGTH : 1024 FILE TYPE: LC NEXT FILE •* FILE HEADER t 2 ** FILE NAME : REPT C . 302 SERVICE N41E : VERSION ¢ : I care : E5 /11Z2E MAX REOOPD LENGTH : 102A FYTES @IL5 TYPE : LC ;REV:OL: PILE NAME : . ** INFORMATION RECORDS ** NNEM CONTENTS UNITS CN : NORTH SLOPE BOROUGH «N : NSE NO.7 EN : SOUTH 5A RON GAS PIE COUN : NORTH SLOPE STAT : ALASKA LCC : 150.00 ** FORMAT ** ENTRY ELOCKS TYPE ENTRY DESCRIPTION 4 1 DEPTHS DECREASE 60. 3 FRAME SPACING 9 . ; IN FRAME SPACING UNITS 11 1a MAXIMUM FRAMESZRECCRD 0 TERMINATOR -0 . 500 LEVEL SPACING DATUM SPECIEICATICN ?LOCKS CURVE REPR CURVE REPR NAME CODE SIZE SAMPLE LITS NAME 000E 500E 0A P L3 UNIT; CAL 6R 4 1 IN ES 6e 1 MV I3 6E 4 1 A EC 63 4 1 MV :0 6£ 4 1 4 TEMP 63 - ] GR 68 4 1 API So 4 1 MV TTEN 6a 4 1 LEE SoC . _ 4 ] E/mN RMLL 66 4 1 OHMM PS !S = 1 OHMM RD 6R 4 1 CMMi 4 . SNIP¥ ELCCKS TYPE $KTRY :ESCRIPTIUN & ' 1 CEPTHS OEC FA SE a 6C. : Fk4NE S(INC 9 . 1IN FRAME SPACING ,NIT: 11 i . vakl*u® FPAMES/P: COR: C TERMINATOR -0. 500 LEVEL SPACING DATUM SPECIFICATION !LOCKS CURVE REP; CLAVE REP NAME COOP SIZE :AMPLE LITS \NE CODE SIZE SAGA:: GRIT: -- - ---- ---- ---- CAL 6a a 1 :n 3: sa Q 1 wv IS 6a 4 1 . 3_ f: ; 1 2v ID 63 Q 1 ; T\Mo Ef 4 1 SES[ GR 675 4 1 __: SP ±a & 1 yv ITEN 6a 4 1 LaF )r: of ; 1 EZx% PILL 6a 4 1 C-t1 ;s 6U & 1 cE7y ;s 6E 4 1 Thum ** :;T4 -* :E;TH 235P .C:G FT 715. 720E M CAL 3. 122 ES 142 . 361 : : 512 . 443 :D 475 . 12¥ IS 165.421 TEMP 59 . EcA G\ 4 . .lC7 EP -2 , :25 :TSN 1655.630 595 2.200 RMLL ] 20(2 .2:C 2S 15. £ 72 @3 16.355 DEPTH 2323.000 FT 701 . 0415 R CAL 3 . 132 53 133. 552 IS 773.403 :D l6; , Gz3 IS 246. 070 TF¥P 63.310 G; 64 . 921 5R -.t . L12 TTEN 1713 .466 SPO 73 . 924 RMLL 12000. 3CC Rs x . 532 kc 11 .C19 DEPTH 2200. 000 FT 670. 9612 M CAL 3 . 264 ES -1 . 222 IS 45. 302 FZ 1 . 6:5 ID 321 . 467 TEMP 59.412 GR ; 2 .961 s. -21 . ;3: TTEN 1571 . 232 SPO 33. 997 RMLL 1000:. \:: Rs 0. 120 PO 0. 100 DEPTH 2150. 5CC PT 653. 4736 M CAL . 264 ES -1 . 220 IS 45, 3CE 3E 1 . 625 Io 321 . 467 TEMP 59. 294 GR 92 .9!1 SP -31 ,G7p TTEN 1671 . 232 SPD 73. 997 RMLL 10000 . 02E RS 0 . 139 RD 0. 130 STARTING OEPTH = 2353 .003 FT 713. 7200 M ENDING DEPTH = 2153, 522 FT 655 .4756 ' ** FILE TRAILER ** PILE NAME : PEPT 2 . 302 SERVICE NAME : VERSION # : 1 SATE : 55/11 / FILE TYPE tC ) . NEXT FILE NAME : ** TARE TRAILER ** TAPE NAME : SERVICE %AME : REPT 0 DATE : S¥IGIN CF :AT&: FSYS TAPE CONTINUATION r : 2] NEXT TAPE NAME : COMMENTS : *- REEL TRAILER � • REEL NAME : SERVICE NAME : AITLIC :ATE : ORIGIN OF SATA : PSYS REEL CONTINUATION # : 01 NEXT PEEL NAME : COMMENTS : DRl :x ATLAS LIS CUSTOMER TACE --- CREATED EY SOS PROGRAM , REEL HEADER - 1 IAAF HEADER - 1 3ILE hEADER - 2 INFORMATION - 2 FORMAT - 4 DATA - 55 TABLE DUMP - 2 FILE TRAILER - 2 TAPE TRAILER - 1 REEL TRAILER - 1 TOTAL RECORDS : 71 w\ jj � 9 THE STATE Alaska Oil and Gas Of _�,; Conservation Commission ALAS A , GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 ALAS Main: 907.279.1433 Fax: 907.276.7542 October 16, 2012 Kent M. Grinage Manager, Fuel and Natural Gas Facilities Department of Public Works SCANNED PR Z North Slope Borough P.O. Box 350 Barrow, Alaska 99723 Subject: Well Completion Form 0 -407 and daily records Permit: 100 -026, S. Barrow #4 Permit: 11 -130, S. Barrow #7 Dear Mr. Grinage: A routine database check reveals the files regarding the above referenced wells are incomplete. Specifically, well completion reports (10 -407) and daily well operations reports have not been received with regard to those wells. The well completion reports and daily well operations reports are required to be produced within 30 days after abandonment of the wells. 20 AAC 25.070 (3) and (4). Please provide the required information no later than November 30, 2012. Should you have any questions relating to this matter, please contact Sr. Petroleum Engineer Chris Wallace on 907- 7931250, email chris.wallace@alaska. Sincerely, / : 7 7 .36,k2 1 (...._ Cathy P 9 oerster Chair, Commissioner cc: Each well file ~ I: !à\ lJ Œ m}f8ij\ L~\ ~ æ ffi\ ,. ! TONY KNOWLES, GOVERNOR AI.ASIiA. OIL A5D GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE. ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 April 14, 2000 Mr. George Finlayson North Slope Borough P.B. Box 709 Barrow, AK 99723 Subject: Plug and Abandonment Well Completion Form 10-407 Permit: 100-026, S. Barrow #4 Permit: 100-030, S. Barrow #7 Permit: 100-035, S. Barrow #12 Permit: 100-046, S. Barrow #18 Dear Mr. Finlayson: While doing a computer database check of well status, our well files are incomplete. In checking well status, production reports and the well file, the listed wells completion reports (10-407) and daily well operations, have not been received by the Commission to date. We noticed that correspondence referring to site clearance final approval by the Commission was sent to the operator in 1988 for well S. Barrow # 12. These materials are required within thirty days after the abandonment of the well under our current regulations 20 AAC 25.070(3). This statement has been in our regulations since 1986. Please provide the completion report and daily well operations for the four wells as soon as reasonable, May 30, 2000? ;p~ Robert N. Christenson, P.E. Chairman Cc: Each well file moo lDff ALASKA OIL AND GAS CONSERVATION COMMISSION PETROLEUM WELL RECORD - Commission use only - 04/05/2000 +----------------------------------------------------------------------+ -~;~~~--I---~~~~---I------~~~--------@--~;~~~--I~~~:I--~~;~~-- 100-026-0 023-10012-00 S BARROW 04 020 FEE-NSB +----------------------------------------- ------ -------------------------+ -~~~;-I-----------~:~;;~~~------------I=~~~I----~~~~~-------I~~~;;I~~~~~~ 131300 NORTH SLOPE BOROUGH 890 ARCTIC SLOPE ON +--------------------------------------------------------------------------+ FLDPOL FIELD AND POOL I MULTIPLE POOLS -=~~~-I------------~~~---------------- ~~~~~~I~~~~~~I~~~~~~I~~~~~~I~~~~~~ 764500 SOUTH BARROW, SOUTH BARROW 000000 000000 000000 000000 000000 +--------------------------------------------------------------------------+ UNIT UNIT I ELEVATIONS I DEPTHS INUM -=~~~I--------------~~~-------------- =~~~I~~~:I=~~~I~~~: -~~--I-~- =~~ 00000 KB 43 00 2538 2538 0 +--------------------------------------------------------------------------+ SURFACE LOCATION I BOTTOM HOLE LOCATION ~~~:I~=~I~~~:I~=~I~~=I:~~I-~~~I~~~ ~~~:I~=~I~~~:I~=~I~~=I:~~I-~~I~~~ 0550 N 0800 W 14 22N 018W U 0550 N 0800 W 14 22N 018W U +--------------------------------------------------------------------------+ LATITUDE I LONGITUDE I FOOTAGE DRILLED IPERMFI SSSV ~~~I~=~I-~~=- ~~~I~=~I-~~=- =~~~I~~~:-I=~~~I~~~:-I=~~~I~~~:- :~==~ -~~~:~- 71 15 51.00 156 37 50.00 1950 2538 +--------------------------------------------------------------------------+ INITIAL I FINAL I CURRENT I REQUIREMENTS IFRM SALES =~~~~I~:~:~~ =~~~~I~:~:~~ =~~~~I~:~:~~ ~~~~I-~~-I-~~~-I~:~~~ :~: ~==:=~~ DEV 1-GAS DEV 1-GAS 76001 +--------------------------------------------------------------------------+ _~~~;~~~~_\--~~;~~~--I-~~~~~~~--\-=~~~:~:=I=~;~~:~~~~I~;~~~~~:~l_~~~~~~_ 03/09/1950 05/09/1950 06/11/1999 01693 +--------------------------------------------------------------------------+ If"V'-ð ~~ DD~ ~~w ~ , /YY\~ Vrol< ~ ~(}ib ALASKA INDIVIDUAL WELL PRODUCTION AS OF 04/05/2000 WELL-NAME: S BARROW 04 API: 023-10012-00 LEASE: FEE-NSB OPERATOR: NORTH SLOPE BOROUGH FIELD/POOL: SOUTH BARROW, SOUTH BARROW SALES CD - 76 ACCT GRP - 001 FINAL STATUS: DEV 1-GAS CURRENT STATUS: ** GAS PRODUCTION ** 1950 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH FLOWING FLOWING FLOWING FLOWING DAYS 30 31 30 30 OIL WTR GAS 8,490 10,000 11,300 12,850 1950 TOTALS OIL WATER GAS 42,640 CUM OIL CUM WATER CUM GAS 42,640 1951 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING , DAYS 30 28 31 30 31 30 31 31 30 31 30 31 OIL WTR GAS 14,000 13,700 13,618 11,500 10,250 9,016 8,000 8,500 9,006 10,000 12,000 15,760 1951 TOTALS OIL WATER GAS 135,350 CUM OIL CUM WATER CUM GAS 177,990 1952 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING DAYS 31 29 31 30 31 30 31 31 30 31 30 31 OIL WTR GAS 15,000 13,000 12,086 12,000 11,500 11,298 8,000 9,000 10,337 10,800 11,500 12,024 1952 TOTALS OIL WATER GAS 136,545 CUM OIL CUM WATER CUM GAS 314,535 1953 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING FLOWING SHUT-IN SHUT-IN SHUT-IN DAYS 31 28 31 30 31 30 31 31 15 OIL WTR GAS 9,500 9,000 8,566 10,500 9,800 9,303 9,000 7,000 2',000 1953 TOTALS OIL WATER GAS 74,669 CUM OIL CUM WATER CUM GAS 389,204 1954 JAN FEB MAR APR MAY JUN JUL AUG ~EP OCT NOV DEC , METH SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN SHUT-IN FLOWING FLOWING FLOWING FLOWING DAYS 15 12 14 31 OIL WTR GAS 6,661 5,000 6,000 9,468 1954 TOTALS OIL WATER GAS 27,129 CUM OIL CUM WATER CUM GAS 416,333 1955 JAN FEB MAR APR MAY JUN JUL AUG SEP OCT NOV DEC METH FLOWING FLOWING FLOWING FLOWING FLOWING DAYS 31 28 31 30 31 OIL WTR GAS 12,500 11,400 10,377 10,000 9,000 1955 TOTALS OIL WATER GAS 53,277 CUM OIL CUM WATER CUM GAS 469,610 :# :# ~ . " . ~ '. MANAGEMENT SERVICE ~:.'fII 2501 CEDAR SPRINGS ROAD, DALLAS, TEXAS 75201 Date: 9/17/79 OPERATOR: United States Geological Survey LEASE NAME AND WELL NUMBER: S. Barrow No. 7 FIELD: S. Barrow LOCATION: 2040' S. and 610' N. of NE Corner of Section Meridian. STATE: Alaska 4/1/68 Theoretical of 1500 MCFPD. TD: 2351' PBTD: CAS ING DEPTH WT./FT. GRADE THREAD SIZE HOLE CEMENT 16" 158' 65 Unknown Unknown 18-5/8" 100 sx 10-3/4" 998' 51 N-80 " 15" 600 sx 7" 2238' 29 N-80 " .9-5/8" 210 sx '7 ./ . .~ ~L f'" '"' , r~.. 'ill!! MANAGEMENT SERVICE CD .~' ~ 2501 CEDAR SPRINGS ROAD DALLAS, TEXAS 75201 9/17/79 LOGS INTERVAL SERVICE CO. REMARKS Induction Micro10g Cement Bond Log Sonic Log 999'-2350' 999'-2318' Unknown 999'-2350' Sch1umberger Sch1umberger Sch1umberger Sch1umberger 2 runs PERFORATIONS INTERVAL 5~n slotted liner 2230' -2349' 10 rows on 6"'centers (20 slots!f¿) FORMATION TOPS Basal Unconformity Upper'é!-nd Lower Barrow Sand CASING AND CEMENTING DETAIL: Surface casing ~ Ran 158' of 16", 65D/ft. casing and cemented to surface with 100 sacks ca1sea1 cement. Intermediate casing - Ran 998' of 10-3/4" SID/ft., N-80casing and cemented to surface with 600'sacks of Class "G" cement. Production casing - Ran 2238' of 7" 29IJ/ft., N-80 casing and cemented with 150 sacks at shoe and 60 sacks through D.V. collar at 1134' preceeded by 33 BBLS. diesel. CeJnent bond log and pressure test indicated bad bonding and squeeze jobs were p~rformed on 7" casing. . . Squeeze No.>1: perforated one shot @ .. . MANAGEMENT SERVICE CO. 2501 CEDAR SPRINGS ROAD DALLAS, TEXAS 75201 Date: 9/17/79 cement and 97 sacks Class "G" cement. Squeeze No.2: perforated one shot @ 2160' and squeezed 120 sacks Class "G" cement. Liner _ Ran 5~", 20#/ft., J-55 , security flush threaded, slotted liner from 2200'-2349' with slots at 2230'-2349'. Not cemented. TUBING DETAIL: Ran 2-7/8" tubing Most of the data contained herein was obtained from incomplete daily drilling reports and miscellaneous. ... correspondence. rèport prepared after complètion of this well was ",' '.-~.~ . _ _', "'f',' .,',' .'- .;-~,: -/ /.; pressure reduction station throùgha common Therefore, production from Well No. '7 cannot . . _ ", _.: - ._ d;'.·'·--..,\<-····-,,·;··.·~..·_, ,:-, ,-:>. . ".. . . 2· VENTED THRU ROOF 0# WEL1.HOlY' ~ PAGE 4 OF ~ \ -. 1/2" VENTED OUTSIDE Of WELLHOUSE .' DR.J.B. ENG, R. S. SOUTH BARROW WELL Nt .7 ISOMETRIC WELLHEAD SCHEMATIC , .. ~ ' . Ie- GRUY MANAGEMENT SERVICE CO. 2501 CEDAR SPRINGS ROAD' DALLAS, TEXAS 75201 WELLHEAD NO. 7 EQUIPMENT: 1. 10", 2K psi x 10-3/4" slipweld Shaffer casing head with two 2" LPoutl~ts. 2. 10", 2K psi x 6" flanged Shaffer tubing head with two 2" LP outlets. 3. 2", ANSI 1500, SE, Rockwell plug valve. 4. 5. 6. 2" NPT tee. 7. 2" bull plug. 8. 2" NPT union. 16. ~"gate valve. 17. 2", ANSI 900, SE, Rockwell plug valve. 18. ~"NPT ell. . . .. R=SE~~\:·C)I.P. ==r~GII>JEERII'~G .l\I~~D GEC)I.J()GI(:; S'IUDY I .. of the SOUTH BARROW GAS FIELD NAVAL PETROLEUM RESERVE NO.4 ALASKA H. J. GRUY AND ASSOC!ATt~S. INC. PETROLEur.1 CONSULTANTS u", ,._"~,-"-"c"__",,,,~,,,,_,,---_, _., '~.'" . ~~....:...,."- "n' .__"_ "",-~"'"""""_'-' _.:~., ~".";":....""""",-..-:,->. -,.-~,."-<,>~.<,'"'' . . H. J: GRUY AND ASSOCIATES, INC. PETROLEUM CONSULTANTS SOUT~WEST TOWER HOUSTON, TEXAS 77002 o"êtober 7, 1976 Husky Oil NPR Operations, Inc. Suite 600 3201 "C" Street Anchorage, Alaska 99503 Gentlemen: it We have made a reservoir engineering study of the South Bar- row Gas field in Naval Petroleum Reserve No.4, Alaska. This study was done to estimate the remaining recoverable gas reserve and to predict the future delivery capacity and the ~emand requirements. This work inc~uded a complete study of the geology of the field, a review of the seismic data, detailed quantitative analyses of the electric logs, a study of the pressure-production performance, a deliverability study, a demand and production forecast, and an estimate òf ultimate recovery and remaining gas reserve. The pertinent basic and work data, includ- ing individ"ll:al well performance, have been summarized and are pre- sented in this report. . Based on this study, we estimate the ultimate gas recovery to be 25. 2 billion cubic feet and the remaining gas reserve, as of July 1, 1976, to be 16. 1 billion cubic feet. This gas reserve and the estimated delivery capacity will meet estimated demand requirements through 1986. We recommend additional drilling to add to the producing ca- pacity to maintain an adequate margin of safety during periods of peak demand and to define the limits of the reservoir. The development dril- ling to date has proved about one third of tlie total ~stimated productive area of the field. . The data upon which this study is based were obtained from the files of Husky Oil NPR Operations, Inc. in Anchorage. In addition, an inspection trip was made to South Barrow Gas field to observe field operations and to discuss the operating problems with field personnel. . H.J. GRUY AND ASSOCIATES, INC. Page 2 Husky Oil NPR Operations, Inc. October 7, 1976 . We appreciate the opportunity to perform this study and if there are questions, please advise. f, GRD:JDH;RRR:jg:kh:dd ... (" ~. Yours very truly, -¡j {l. ~a-9~/4. H. J. Gruy and Associates, Inc. ¡ i ¡ ! ¡ I. I < i r . . H..J. GRUY AND ASSOCIATES, INC. t ~RESE~VOIR ENGINEERING AND GEOLOGIC STUDY of the SOUTH BARROW GAS FIELD NAVAL PET ROLEUM RESERVE NO. 4 ALASKA e e- H.J. GRUY AND ASSPCIATES, INC. T ABLE OF CONTENTS Page No. . SUMMARY CONCLUSIONS RECOMMENDATIONS DISCUSSION History and Development Geology Reservoir Drive Mechanism and Determination of Gas i, Initially in Place Prediction of Demand Well Spacing and Future Drilling Reservoir Pressure Data Reservoir Temperature Core Analysis Log Knalysis Gas Analysis Individual Well Performance Field and Well Operations 1 2 3 4 4-6 r 6-7 8 8-9 9- 10 10- 11 11 11- 12 13 13-15 15- 16 LIST OF TABLES Table No. Summary of Basic Reservoir Parameters Gas Deliverability Study - Current Wells Gas Deliverability Study - Current Plus Six Wells Estimated Remaining Recoverable Reserve by Well Summary of Well Completion and Well Status Data Geologic Data Sheet Pressure and Production Data Reservoir Temperature Data Summary of Core Analysis Data Computer Analysis of Electric Logs on Well No. 9 Summary of Gas Analyses Historical Production Data 1 2 3 4 5 6 7 8 9 10 11 12 LIST OF FIGURES Figure No. Bottom Hole Pressure Over Z vs. Cumulative Gas Production Average Flowing Casing. Pressure vs. Cumulative Gas Production 1 2 ~~'7c;~.:'¡.._.".~.,.,,,,,.<,.!.)·.~·.-~'":..-, "'":'.~'-' "'-'__~"~";.'P'-':_~ _.~."C"'f_~,~_".,._~~.J, - ~.".,.-~.p.--,<--~,'. .~.~;':" ~-- "'~""'''''::>''''''~';~~''. "'o,:"'_~*;";-:~'~';~;'¡;'~~"""~!_'_;'_ .. ~,.-~:,~~1I'!:r,,_'''r'''''''''''-;~''';;'+~'~O''>="__C''''''~''~C-<''~y;¡:r__"._,....,:¡_~J~""":~~_,:"~..:~¥ . . H.J. GRUY AND AS$OCIATES, INç:. T ABLE OF CONTENTS (Continued) LIST OF FIGURES (Continued) Estimated Individual Well Deliverabilities "Z" Factor vs. Pressure (PSIA) Estimate of Sandface Drawdown Without Hydrate Formation vs. Shut In Reservoir Pressure History of P~rformance and Basis for Estimate of Future Demand Deliverability and Demand vs. Time Performance History - South Barrow Gas Well No. 2 Performance History - South Barrow Gas Well No.4 Performance History - South Barrow Gas Well No. 5 Performance History - South Barrow Gas Well No. 6 Performance History - South Barrow Gas Well No. 7 Performance History - South Barrow Gas Well No. 8 . . Performanc'e History - South Barrow Gas Well No. 9 Performance History - South Barrow Gas Well No. 10 Performance History - South Barrow Gas Well No. 11 LIST OF MAPS I,..ocation Map Oil and Gas Fields of the Arctic North Slope Gas Transmission System, South Barrow Field Top of Basal Unconformity Sand Net Hydrocarbon, Basal Unconformity Sand Top of Upper Barrow Sand Net Hydrocarbon, Upper and Lower Barrow Sands Isopach, Top Basal Unconformity Sand to Top Upper Barrow Sand LIST OF CROSS-SECTIONS Structure - Stratigraphic, Well Nos. 2 through 11 Structure - Stratigraphic, Well Nos. 9, 6 and 7 Stratigraphic, Well Nos. 2 through 11 LIST OF APPENDICES Pc' Pr' T c' and. T r Calculations Recovery Factor Calculations Water Influx Calculations /'- "d~ _.. Figure No. . 3 4 5 6 7 8 9 10 11 12 13 14 15 16 Map No. 1 2 3 4 5 6 7 8 Cross-section A-A' B-B' C-C' Appendix 'A B C J . . H.J. GRUY AND ASSOCIATES, INC. SUMMAR Y This study consists of a detailed geologic and engineering analy~ sis of the South Barrow Gas field, Naval Petroleum Reserve No.4, Alaska. In this study, all of the available basic data were examined and the pertinent basic data, as well as interpretative data, are presented in this report. Material balanceca1culations and analysis of the pressure- production performance indicate an original gas in place of ,approximately 32 billion cubic fe.et. This volume is confirmed by the geologic interpre- tation which incorporates fault limit~ on the south and east sides of the field determined from seismic data. This interpretation shows a pro- " ductive area of about 3500 acres and a total net gas sand volume of about 108,000 acre feet. A detailed analysis of the electric logs indicated an average porosity of 16 percent and an average initial water saturation of 52 per- cent. 'Dhese values and the reservoir volume determined from the net gas sand isopach maps result in a volumetr~èally determined gas initially in place, which is in substantial agreement with the 32 billion cubic feet determined by performance. r Future demand was estimated by extrapolating historîcal trends. Deliverability studies werè made using the 32 billion cubic feet of gas initially in place with and without additional drilling to determine the estimated remaining recoverable gas reserve and the point at which the delivery capacity from the field could no longer meet the estimated demand. A summary of the basic reservoir parameters developed in this study is presented in Table 1. Summëíries of the deliverability studies with and without additional drilling are presented in Tables 2 and 3. The estimated remaining recoverable gas reserve by well for both deliverability studies is presented in Table 4. Page 1 ~ ~ I! _ !II! ~~""'~~'_~"~ ;_,['"""_''''-~',:""~''r':'.'"''!-tI'~~~-""!"~~,~-q:,::~',,,,,,,,, ~\!o;:~~;"';"-'~':'"""":"''''P'''''''''·""?=,..__ t,_..._.:;,.4....._"7".'=;'<" ~__, ._...,._~_..,':'i.~~,;~,.,_.,To':",~~"'?_',."'i""__/~"",,~,,,_r_, _~_,"~'"'''''.o:.,.!...''' ""'~ J~..,..,...lII!.'-" . . H.J. GRUY AND ASSOCIATES, INC. CONCLUSIONS 1. The South Barrow Gas field has not been defined by develop- ment drilling to date. The estimated total productive area is approxi- mately 3500 acres, whereas development has been confined to about 1100 acres. 2.. The original gas in phice is estimated to have been 32 bil- lion cubic feet. 3. The remaining recoverable gas reserve, as of Juiy I, 1976, is estima"ted to be 16. I billion cubic feet. 4. The average annual demand for gas from the South Barro"", . Gas field is increasing at a rate of 5.0 percent per year. The maximum peak demand for gas from the field is increasing at an average annual rate of ? 5 percent. .. , . 5. The South Barrow Gas field should be able to supply the present rate of demand increase without additional drilling through 19.86. Additional drilling will maintain excess capacity to provide an adequate margin of safety during 'periods of peak demand and will enable the field to meet the estimated demand until the winter of 1987. 6. The primary ,reservoir producing mechanism in the South Barrow Gas field is pressure depletion. Water influx from the aquifer has been occurring.at relatively low rates and is expected to continue. Although one or more low wells may eventually water out; the water influx is not expected to be a significant factor in operations or recovery efficiency. 7. The surface pressure buildup surveys taken with conven- tional pre,ssure gauges are not of sufficient accuracy or sensitivity for meaningful analysis. 8. Deciining reservoir pressure with the depletion of the gas reserve will cause increased water production. This increased water production will appear in all wells because the water vapor car.rying capacity of the gas increases as the pressure declines. Page 2 i' ".,'^~~"'~~.. ........,-""","""',"'.,,,""',- ~ . . H.J. GRUY AND ASSOCIATES, INC. . . RECOMMENDATIONS 1. It is recommended that additional vyells be drilled to define the fiel.d limits and to maintain the current safe level of exces s capacity. Two specific recommended well locations are shown as Locations A and B on Maps 4, 5, 6 and 7, which are structure and net gas sand maps for both the Basal Cretaceous and Barrow Gas Sands. These locations are as follows: A - 2600 feet from north. line and 960 feet from west line I. of Section 23, Township 23 North, Range 18 West. (3000 feet south of Well No. 13) B - 1200 feetfromnorth line and 1200 feet from east line of Section 22, Township 23 North, Range 18 West. ; 2. It is recommended that bottom hole pres sure buildup sur- .. veys be run in all of the wells using Hewlett Packard or other instru- ments of equivalent accuracy and sensitivity. It is important t.o main- tain accurate individual well production records prior to these buildup surveys. 3. It is reconunended that ~ore frequent well tests be taken or. that individual meters be installed on each well to more accurately allocate' production to individual wells. 4. It is recommended that Well No. 13 and at least one other well be full hole cored through the productive interval and into the Argil- lite. Special handling and analyzing procedures should be used to insure accurate porosity determinations which reflect the true shale contènt. 5. It is recommended that casing be set through the pay inter- val and perforated on Well No. 13 to eval~ate this completion method. 6. It is recommended that consideration be given to' shutting in Well No. 5 for use as an observation well for taking annual bottom hole pressure measurements. 7. It is recommended that consideration be given to deepening either Well No.7 or Well No.8. 8. It is recommended that Well No. 11 be acidized if a bottom hole pressure buildup survey indicates·wellbore damage. Page 3 ~ ~ ~ .~~.~. ~..."..,.J.'.=_.'_"":"'''':''': ~_~., -.;~7A!""·'_ ,,"'-- ~_._,. . "',_. ,:~ L ~". ..". "'- ...~-.""_. -"."'7.'" '. _ . -._. ":',""'._ ~ ~.""__."""",,, '_ ." _,._,.___~,__..T.'",,,,,,.'..~'\k~.~ """: . . H.J. GRUY AND ASSOCIATES, INC. DISCUSSION Historv and Development r The South Barrow Gas field is located approximately four miles south of the village of Barrow, Alaska. The field was discovered April· 15, 1949, by the drilling of South Barrow Test Well No.2 to a total depth of 2505 feet. This well was drilled into the Pre-Mesozoic .Argillite and completed in the ga"s-bearing Basal Cretaceous and Jurassic Sands over- lying the Argillite zone. South Barrow Test Well No. 2 was located on the arctic tundra on the north flank of a geophysical high in Section 14, Township 22 North, Range 18 West. Well No. 2 produced 53,500 MCF during the winter of 1949-50 for camp fuel, caught on fire in April, 1950, was killed and replaced by South Barrow Test Well No.4 in May 0:( 1950. Both Well Nos. 2 and 4 produced sufficient water to cause operating prob- lems. South BarrowGas Well No.5 was completed in June, 1955, to re- place w.eh No.2 and to supplement Well No.4 in supplying an increas- ing demand for gas at Barrow Camp and Ba.r'row Village. Subsequently, Well Nos. 6 through 11 were drilled and completed between April, 1964, and March, 1974, to supply increasing domestic demands and to reduce individual production rates from existing wells. No dry holes have been drilled in the field. The dri.lling to date has not encountered agas -water contact or other limits, such as faults or pinchouts. Gas production from the South Barrow Gas field totals 9,099,548 MCF, as ó£ July 1, 1976. A summary of the original completion and performance of all nine wells in the South Barrow Gas field is presented in Table 5, and the production histories for each well and for the field are presented in Table 12. Geology The South Barrow Gas field is located in th.e northern portion of the Arctic North Slope within the geologic province known as the Arctic' Coastal Plain outlined on Map 1. Map 2 shows the relation of the South Barrow Gas field to the presently disc-overed oil and gas fields on the North Slope. Map 3 shows the location of the South Barrow Gas field and the gathering system in relation to Barrow Village and the Naval Arctic Research Laboratory. Locally, the field is situated on the west flank of the Barrow Arch which is a well defined circular uplift consisting of a complex Pre-Mesozoic basement corè. Seismic and gravity data indicat~ this core extends to within 1200 feet of the surface, is approxi- mately five miles in diameter, and '~s bounded by peripheral faults down- Pag7 4 . H.J. GRUY AND ASSOCIATES, INC. . thrown toward the center. Maps 4 and 6 illustrate the structural inter- pretation of the field~ based on subsurface, seismic, and reservoir per- formance data, at the top of the Cretaceous Basal Unconformity Sand and the Jurassic Upper Barrow Sand, respectively. The trap is an elongated northeast-southwest trending closure on the upthrown side of a fault depicted by seismic as forming the ~astern boundary of the field. The structure appear s to be about 3 -1/2 miles long by 1-1/2 miles wide and covets approximately 3500 acres. Seismic da.ta was reviewed in the office of Tetra Tech, Inc., Houston,' Texas. 'Tohis data was included in a report to the Navy dated February 14, 1975, entitled "Future Drilling Prospects on Barrow High, NPR-4, Alaska" by R. R. Simonson. r The stratigraphic sedimentary section of the field consists of about 2500 feet of predominately shales and sands. The first 100 to 150 feet are Quaternary age beds followed by 2000 to 2200 feet of Lower Cretaceous beds and 100 to 200 feet of Jurassic beds which overlie un- conformably Pre-Mesozoic Argillite. Detailed correlations between wells indicate an angul~r unconformity is present between the Lower Cretaceous and the Jurassic. This unconfor~ty appears to cut out some of the upper portion of the Jurassic (J-l p.nd J~2 zones) in all the wells except Well Nos. 7,8, and 11, as shown on the electric log Cross-secti0I?-s A-AI, B-BI and C-CI. Seismic data indicate the Jurrassic thickens both eastward and westward away from the field. Subsurface data confirm the eastwarçl thickening as illustrated by the stratigraphic Cross-section C-CI, and the isopach map from the top of the Basal Unconformity Sa.nd to the top of the Upper Ba.rrow.Sand, Map 8. The current producing zones in the South Barrow Gas field include the Cretaceous Basal Unconformity Sand (BK), and the Upper and Lower Barrow Sand (UB and LB). Table 6 lists geologic data de- termined by electric log analyses which include the top and base of po- rosityand net gas pay for the Basal Unconformity Sand and the combined Upper and Lower Barrow Sand penetrated by each well. For wells not penetrating the en~ire Lower Barrow Sand, the estiP-1.ated total net gas at that location is shown in a separate column. Thecon"lpletion technique has been to open hole complete all of these zones as a common reservoir. The structure and' stratigraphic electric log cross-sections of the field wells show these zones along Vi(ith the potential productive' Cretaceous Sands behind pipe and the Pre-Mesozoic Argillite which underlie.s the Lower Barrow Sand. The Basal Unconformity Sand zone is present in all the wells and is easily identified on the electric logs. It. has about four to six feet Page 5 ~~.!1~:~;,:"%?:š.r.f\~:l~~~~::'~<:"'-::7"'·'--"-_ ~-,-"; ,,,:.": ':-:-':9;'ti:'~:~::"?!~" ,-'\·"':r;~,.~·:~~t~~~~~:~'~·~~~~~~~'ltftj~~0~!.~'-,·"ê:.",,,,,,_:,,~:,/... ·"·'·-~~,~!~.~.}~Þ.ié)~~4":-'-''':-_ _"''=;0._,~.'''',,:~~~::~r1,~-~-'i''' :;;;::-.J >--p;..'~ , . . H.J. GRUY AND ASSOCIATES, INC. of net gas pay, except in Well Nos. 8 and 9 which appear silty with low permeability. From the core and sample descriptions, this zone is a conglomerate that includes sands, gravels and shales. Map 4 shows the structure of this zone at the topaf the porosity,'and Map 5 is thenet gas sand isopach map. The estimated productive area covers about 2500 acres. The Upper and Lower Barrow Sand zones are considered as a common reservoir. Both zones have been penetrated and produced in all the wells except 7 and 8, assuming the correlations are correct as shown on the cross-sections. The net gas pay presently open for pro- duction r~nges from 11 feet in Well No.7 to 44 feet in Well No.9. The entire Lower Barrow Sand has been penetrated only in Well Nos. 2, 4, 5, and 11. The poor performance of Well Nos. 7 and 8 is believ,ed due to the wells not being drilled deep enough to encounter the Lower "Barrow Sand which has better developed porosity and permeability than the Upper Barrow, Sand. Well No. 11 may have formation damage which limits its productivity.. Map 6 is a structure map on top of th~ Upper Barrow Sand porosity, and Map 7 is a net gas sand isopach map showing the estimated total pay for both zones including the additional gas sand expected at locations not penetrating the entire Lower Barrow Sand zone. The esti- mated productive area covers approximately 3500 acres. The potential productive zones in the South Barrow, Gas field include several thin Lower Cretaceous Sands with good gas shows en- cQuntereçl between depths of 1900 and 2250 feet in various wells. The K-I Sand shown on the electric log cross-sections is the upper member of this series. By electric log correlations, the sands are thin, rela- tively tight and erratic indicating the reservoirs may be small. These zones have not been produced to date. The Prß-Mesozoic Argillite test- ed gas in Well Nos. 2 and 4 and could have a commercial gas accumula- tion updip. Well No. 13 should be a good location to test the Argillite. Reservoir Drive Mechanism and Determination of Gas Initially in Place Using data given in Table 7, a plot of bottom hole pres sure over compressibility factor (BHP! Z) versus cumulative production was made and is presented in Figure 1. An analysis of the BHP! Z versus cumulative curve shows that during the early years of low withdrawals the bottom hole pressure was supported to some extent by water influx. The slope of the curve for later years at inçreased withdrawals indicates a gas initially in place of about 32 billion cubic feet. Page 6 . . '-'" H:J. GRUYAND ASSOCIATES, INC. Several material balance calculations were made on the com- puter in an attempt to determine both the gas initially in place and the magnitude of the water influx. The program used solves the material balance equation as a straight line assuming unsteady state water influx. A satisfactory solution was not obtained and it was concluded that the data were not of sufficient accuracy to give meaningful results. Hand material balance calculations were then made using the estimated 32 billion cubic feet of.gas initially in place. These resulted in calculations of water influx as follows: i. Cumulati ve Bottom Hole Cumulati ve Production Pressure Water Influx Date MCF PSIA Barrels 4/20/49 0 1102 0 -3/21/64 1,894,000 .1075 1,995,000 3/24/73 6,588,000 930 2,349,000 7/15/76 "9,121,000 857 2,795,000 Based on the total calculated water influx, about 1,049,000 MCF has been displaced by water to July 15,1976, or about 11. 5 percent of the total production to dá.te. This would flood out approximately 8. 7 percent of the reser;voir and this volume could easily fit below the lowest known gas in Well No.5. The .geology from available well control with south and east limits from seismic data and an assumed gas-water contact 25 feet below the lowest known gas shows.a total productive at:ea of about 3500 acres and a net _ gas sa~d volume of 108,000 acre feet. U sing the reservoir parameters developed in this study and this sand volume results in a calculated gas initially in place of 32 billion cubic feet. Based on the agreement between the volumetric and material balance calculations, we estimate the original gas in place to have been appr"Oximately 32 billion cubic feet. The ultimate recoverable gas reserve to an assumed constant line pressure of 235 psia is estimated to be 25.2 billion cubic feet. De- ducting the cumulative production to July I, .1976, of 9. I billion cubic feet, the remaining recoverable gas reserve is estimated to be 16. 1 billion cubic feet. Page 7 . . H....J. GRUY AND ASSOCIATES, INC. . Prediction of Demand Demand for South Barrow Gas field gas has increased every year since 1956. This is illustrated. by Figure ~ which shows the field. Production Rate or Demand versus Time. It is likely that the decrease in demand during 1953 and 1954 was due to restriction of production of Well No. 4 because of water production. Since completion of Well No. 5 in 1955, there has always been sufficient well capacity available to meet the demand. Since 1964, actual monthly production data has been plotted and the. demand rate variation of approximately two to one of winter over s~mmer can be seen. Thß rate of increase of average maximum ;:rates and average annual rates are nearly parallel and the average annual rate has increased for the past seven years at-five per- cent per year. Another trend which must be considered for projection of performance into the future is the rate of increa.se of the ma.;ximum short term demand rate. Deliverability must be available to meet the maximum peak rate of demand during the coldest month. The data which a.~e available are maximum monthly average rates, and it was found that the' rate of inc~ease of maximuin monthly demand was 5.5 percent per year. In this study, these trends have been projected to estimate future demand. r The gas deliverability of a well or a group of wells can usually be calculated from the performance of .each well or from the composite performance of the field. However. in the South Barrow Gas field de- liverability study the average demand. maximum demand. and hydrate problems had to be considered as follows: I 1. Average annual and maximum peak demands were estimat- ed by projection of past trends as shown on Figure 6. z. An allowable was assigned to each well in the field to pro- duce the anticipated demand and each annual rate was checked against the total fie1çi deliverability to insure tha.t the composite deliverability of all wells exceeded the estimated Inaximum peak demand without im- posing producing rates which would cause hydrate form.ation in the res- ervoiror opposite the permafrost. Well Spacing and Future Drilling Initial reservoir pressures measured in each well drilled in the South Barrow Gas field since completion of South Barrow Gas Well No.5 have indicated lower reservoir pressures than were observed in Well Nos. Z and 4. This indicates each new well penetrated an area of Page 8 .'-' . . H.J. GRUY AND ASSOCIATES, INC. reservoir that had been drained to some extent by previous production and that all wells are in a common reservoir. ~ith the exception of Well Nos. 2, 4, and 5, each new well has been drilled at a distance from existing wells of 1950 feet or more. The radius of an area of 320 acres is 2106 feet. It appears that each of the earlier wells was drain- ing at least 320 acres. The present spacing of the developed portion of the field is approximately 160 acres per well. . The past development practice appears to have been to acquire . maximum additional producing capacity whiie minimizing the risk of a dry hole. No p'roducing limit to the field has been proved with this practice, and it now appears that the fièld is substantially larger. It (I. should be possible and practical to complete delineation of the r.eservoir with subsequent wells spaced'on approximately 320 acres. The total productive 'area of the South Barrow Gas field is es- timated tq be about 3500 acres with a pres~nt1y developed area of ap- proximatElly 1120 acres. There appears to be at least one productive location ~in the. southwest portion of Section 12 which may define the northeast limit of the reservoir. The southwest extent of the reservoir is unknown and :p1.ay provide sufficient area for at least five 320 acre r locations providing reservoir sand characteristics, such as average thickness, porosity, and water saturation, are consistent with the pres- ently developed area of the field. Reservoir Pressure Data The original bottom hole pres sure of the South Barrow Gas field is estimated to be 1102 psia at a datum of -2250 feet. This is based on a surface shut in pressure measured a few days after Well No.2 was completed. The available pressure data are presented in Table 7. These are predominately shut in surface pressures converted to a reservoir datum of -2250 feet by a static gas gradient with the assumption that no liquid is present in the bottom of the hole. Some measured bottom hole pressures from drill stem tests are available from individual wells. The first reliable ·meas·ured drill stem test pressure was ob- tained from Well No.4 in April, 1950, and is 1081 psia corrected to -2250 feet. This measured pressure, when compared with the calculated pressure from Well No.2, suggests that the production of 53,500 MCF of gas from Well No.2 had interfered with a sufficient area of re servoir to be observed in Well No.4. The observation from the pressure data that the reservoir is connected and continuous over the developed area can be seen from the original pressure~ in each new well as they were Page 9 . . H.J. GRUY AND ASSOCIATES, INC. completed. Well Nos. 8 and 9 indicated origina.l pressure greater than the apparent field average but within a few months fell into line with the other wells in the field. The surface pressure data from the South Barrow Gas Held are believed accurate enough foruse in estimating reserves. The operators have dead weight tested the pressure gauges carefully. Corrections for the specific environment of each pressure gauge have been observed, re- corded and applied to each gauge reading. An effort app~ars to have been made to void each well bore of liquid before a shut in buildup was obtained. Even with this care, the gaugß pressures are not accurate or sensitive en,pugh for reliable buildup analyses. The three pressure surveys shown on Table 7 dated 10/15/70, 7/15/75 and 7/15/76 are the only pressures that involve more than one well at a, time and are considered to be the most representative data available. All surface shut in pressure points since 1964 have been shut :in for 48 }fours or more. The shut in buildup on Well No.5 in 1966 was .. for 52 hours, the four well surveys run in 197.d averaged 98 hours of shut in time, and the -two surveys in 1975 and 1976 were for 72 hours of shut in time. During the multiwell surveys, only one well was shut in at a time with the remainder of the wells producing the rate demanded by consumption. The multiwell ~urveys may present pressures lower than stabilized reservoir pressure due to continued production of offsetting wells. Use of ob served pres sures lower than actual stabilized re'servoir pressure in a material balance would indicate less gas originally in place than "actually existed. Table 7 lists nineteen pressure data points which were con- sidered valid él.nd used in this study. A straight line through these data, illustrated by Figure 1, was used in the engineeríng analysis of the South Barrow Gas field. Reservoir Temperature The bottom hole temperature of the South Barrow Gas field is estimated to be 630 F. This is the a.rithmetic average of the temperature data from Table 8. Table 8 lists 11 measured bottom hole temperatures. The. highest recorded temperature is 730 F and was measured in two drill stem tests taken in Well No.9. These high temperatures may have been caused by the warm mud necessary to prevent mud fr.eezing while no circulation was occurring during the test. The lowest recorded tem- perature is 520 F from a temperature survey taken in Well No.2. Ex- Page 10 .-;. ,. _"~"::-~o,,: , _.; _, .~"êc~',·""'~.'~~.\.·, ,,' ,. --/« ~. .~ ~. ~,'_7_ "..,....J(~,.-,~\..,...I.)i ,.-">.,.I._,..~""""'.~..""+'1''J'_'.';_~''::'''''''~:=-''~''';:'_~~~'(,j!"...!~:""'~,t!lð,_...,:tt~ ~~..~,,__ ~ "::'J,;.,..::~~_~"'fOo"'_~'"- _.........-..._-.."..'..¡..~,."i;.. ,..,:~. 0""" . . H.J. GRUY AND ASSOCIATES, INC. cept for temperatures taken from the elect:r:ic log headings on Well Nos. 10 and II, this type of data was not considered for Table 8 because on the remaining electric logs it was not recorded whether the temperatures were measured or estimated. Core Analvsis Table 9 summarizes the available conventional core analysis data and indicates an arithmetic average porosity of 17. 3. percent from 111 samples and an average permeability of 26.0 md from 91 samples. Well records indicate that conventional cores have been cut in the productiveïnterval of the South Barrow Jurassic Gas Sand in four wells. These wells are South Barrow Gas Well Nos. 2, 4, 6, and 9.. Apparently 184 feet of core were cut in Well No. 2 withexcellent-'recov- ery but only 21 samples were analyzedfor porosity and 16 samples were analyzed for p ern1.e ability. In Well No.4, 130 feet of core were cut and only 17 samples were analyzed for porosity and 2 samples were analyzed for permeability. Twenty feet of 'core wère cut in Well No.6 but no core àrialysis was available. The complete Juras sic Gas Sand interval which was penetrated in Well No. 9 was cored with 100 percent recovery. A core analysis of each foot of 73 feet of sand was analyzed for porosity, permeability and fluid saturations and this data comprises the bulk of the- available core analysis data from the South Barrow Gas field. The 4. 19 percent residual oil saturation reported on this core analysis may have been caused by the seven percent diesel oil emulsion mud used in the coring operations. Log Analysis Using all of the log analyses, the estimated weighted average porosityis 16 percent, and the water saturation is S2 percent as presented in Table 1. The well logs from South Barrow Well Nos. 9 and 11 were processed by computer using a neutron-density "shaly sand" method. The computer analysis shows interstitial clay throughout the reservoir sand in the wells studied. This is consistent with descriptions of cores and cuttings that have been reported. Permeability is adversely affected by the presence of clay. This is evident iri the core analysis from South Barrow Well No.9, where most samples having a porosity of 14 percent or Ies s exhibit less than one millidarcy pe;meability. Page'Il . H.J..GRUY AND ASSOCIATES, INC. . TABLE 1 SUMMARY OF BASIC RESERVOIR PARAMETERS SOUTH BARROW GAS FIELD NAVAL PETROLEUM RESERVE NO.4 ALASKA General Formation Names 4t Formation Ages Lithology Reservoir Properties I Basal Unconformity Sand Barrow Gas Sands Basal Cretaceous Juras sic Sand # Average Porosity (Log Analysis) Average Connate Water Saturation (Log" Analysis) Average Permeability To Gas Datum Original Reservoir Pressure ReservoiÍ" Temperature Original Reservoir Gas Gravity (Air = 1. 0) Gas Compressibility Factor Original Gas In Place , Productive Area and Sand Volumes Productive Area Proved By Development Estimated Productive Area Average Productive Sand Thickness Total Estimated'Productive Sand Volume Gas Initially In Place and Estimated Reserves Original Gas In Place (Performance) Estimated Ultimate Recovery Cumulative Production To 7/1/76 Estimated Gas Res erve as of 7/1/76 16 52 5 -2250 1102 63 0.564 0.839 298.2 1100 3500 30.9 108,000 32.0 25.2 9. 1 16. 1 0/0 0/0 md Feet PSIA of Mcf / AF Acres Acres Feet AF BCF BCF BCF BCF Table 1 - NC H.J. GRUY AND ASSOCIATES TABLE Z GAS DELIVERABILITY STUDY CURRENT WELLS SOUTH BARROW GAS FIELD NAVAL PETROLEUM RESERVE NO.4 ALASKA PWOUU\;JIOh "MI;F -.-___'..1 .-.----- . 8HAK£ INI;HEMEM. Yt.AH I;UfI TUrAL CUll foIP --------- . I, NU. UF wELLS AYG. Pf.HIOU CAPCn A~G. 1111f1. PSlA. --.-.. Ll"'f. P~f.SS. PSlA. --.-.- HAR e . o. O. O. U. ". o. U. o. O. O. II. O. O. O. O. U. U. U. O. II. U. O. II. O. O. O. o. O. O. O. O. II. U. 1/. II. O. u. u. u. u. u. U. O. 391/.31 l$i9.1I 1¿,lIö.5ó 171I1.U 0/193.10 i!lIlIu.UI 3111b.92 31119.38 191.1I HI. 1111 ~i!71.ðö 56u.311 IIqUII.II~ lou7.~ lbOb.O~ öi!I.14 lIöU.23 91I1I.30 101~q.ö lUö1J.31:1 114b5.C!7 1¿lu9.0~ Il1.U.11 Ul91.ö7 137910.7-1 lo!30.7J 1~öll.92 lqlll~.99 IS09¿.IIJ l!:Iill.5b 151.1S7.39 1!:1515./) 15blö.il 1~11:19.ilY l~öSu.IO 159.11.111 1~9ö~.7u 1000".b~ 101de.1I1 10ù~.IIS Ihlll~.11 11>09';).',) 110114.110 390.31 U9.411 j9.09 9UI.31 1.11I2.U 949.111 111111.91 9'1'i.H 512.1I lUSi.1I ~qo.u¿ 111111.50 501l.9 1107.09 S.,II.OII liOIl.b9 IIUII.1I9 lC!74.l1 1:I0b.lò! ji!~.00 1:151.91 lê9S.b9 bll.Ob 11 1111. III 911.lIq 9Sl.lIb 350.19 b45.lb 211:1.U~ 4ul.!:I' 1~9.b3 19¡.ol Iv¿.1Y lYJ.1J1:I I$u.öl 1~2.511 b3.lIl 1$'.Yl ¿J.ld q.9ö to.Y '110. '11 Y.u~ 390.3b7 439.095 1I)9.U95 1I2.27fi! 1I1Ii! .270! 411b.'1U 411/1.910 SU.bu ~12.bU 5110.u17 5110.01/ 5/111.467 5/18.1I1 5911.bvU SYII.bUU IIUII.u9U ò08.0'lU IIbb.ll5 IIbll.ll5 11511.1177 1I~1.91i! b3.11b b2l.Ub4 5Òb.75b 4'1öòll.IIII 1.134.010 3Su.lb9 lYS.ul1 21ò.U4S löS.5l5 159.110 UII.Ob IOl.711) 'il.1/7t> IIU.IIUb 71.7711 03.lIl~ ¿.I~1 ¿3.v,?0 ¿1.Y~b o!U.'I1I1 1'1.'111 1 'I. "S!> I 7 J 7 7 1 I 7 1 7 I 1 7 1 7 7 1 , 7 1 7 ., 7 7 7 I II o ¡¡ II 4 3 J S 3 J 1 I I I I I lll.1I4~ is.böll 21.1.lIöll lJ.1I7ii! li.II¡¡9 ll.IILII 20.571 19.~19 U.l.lbl 11.11010 Ib.J~b IS.30l III.i¡¡b 13.11111 Il.Ul 11.U95 10.ulll 9.0511 Ö.Oi!\I I.ulll o.OIHI ~.IY9 ¡¡.3b9 3.b2b ò!.911" l.4!:11 l.IIU l.bll5 1.423 l.lU l.u~2 .'IU'I .1'1~ .7vlI .b¿~ .55!:1 .911 .II~II .¡¡Sj .qlS .S"¡¡ ..51) .~!:Iö 759. 7411. 152. 7111. 1ulI. b1l9. ò1. 0511. 11112. b25. 11011. 591. S7S. 55¡¡. 535. 515. 49b. '1111. qSl. q31. 1.109. H7. Jbb. Jq7. HII. 31~. J1/3. 293. ¿t'5. ¿7'1. US. o!lItI. ¿bS. ¿IIi!. iS9. iSb. ¿')q. ¿5$. i52. ¿~ I. l51. ¿~(. ¿l4q. 2J5. 23S. o!35. 235. iJS, 235. 235. 235. i3!;. i!J~. i!3S. ¿3~. 2j~. i3~. i!3~. l3S. i3S. .US. ¿S!;. ¿3~. i!J5. i3~. 23S. 2j5. 23'). iS5. l35. ¿J5. ¿35. ¿3S. ¿H. .US. ¿.sS. .H5. i35. i3~. 23':1. l35. ¿SS. ¿3'>. 2J5. i!3S. ¿$5. I 1 2 2 3 3 II S 5 II Ò 7 7 15 II '* C 10 10 11 11 Ii! 12 U 1J 1 1'1 15 15 III 11> 17 11 Ib III 19 1 Y iv 20 II ¿I U 1-4 ØJ c:r .- (Ð N I 'I I ,~ ;:~ ;~ 1 " " [ .,~ f I 'fi f ! ! - - ..... .... -. IiiIíIìIL ---, IriiiIìR. .-. .. - H.J. GRUY AND ASSOCIATES, INC. TABLE 3 GAS DELIVERABIUTY STUDY CURRENT PLUS SIX NEW WELLS SOUTH BARROW GAS FIELD NAVAL PETROLEUM RESERVE NO.4 ALASKA . .. nA~ LINE AliI>. AvG. "'0. f'ROIJUCT10N I1I'1I.:F " P~tSS. IIIHP. PENIOD U~ ----~~.-----.._--.-----------.._--. tt"A¡(l I'SlA. "SIA. CAPCn wELLS INCR~"'E",T YEAH &;UI1 TUTAL. I.Ul1 HI' ì ------- ----.--.- .---.--. .---.---- -...... 1 23>. I~tI. 2b,b1b 7 IIlb.1011 41b.10 4111.10 U. 1 ¿JS. 711!!. ¿5.b511 7 1I1b.l0u tU2.20 I:IJè.20 o. è lJ5. 7H. ¿1I.705 1 IIlb.l0u IIlb.l0 Illlll,30 0. 2 235. 717. i!b.070 II SUII.1I37 YU.SII 1751.1.711 II. J 23S. 702. 211,1131> 1:1 50b.lI37 5010.1111 22101.17 O. 3 2.3S. ð6ð. 2.3.b2i! 1:1 SOb.4)7 1012.1:17 21117.111 O. II iUS. bll). 22.430 II 5011.4]1 50b.1I1I .32711,115 I), II iUS. b55. ¿1.2óO 1:1 5Ub.II.51 1012.61 Htlo.llq 0, 5 ¿3S, b.3b. 21.tloO 'I 5~ò.71,) 5'1ò.71 IIJ77.2b O. > 23S. olli. 20.lIj') 'I S9b.715 11'd.5> "9711.1111 O. 10 013>, 5'19. 1q.o.,j 9 5qb.71S S",0.77 5S/II.bl u. b ¿3.,. 5t:!0. 11.IIIJ 'I 5Yb.770; I1'1J.55 blb7.S'I II. 7 2.3.,. SIIZ. Ib.Jllt:! Y 5'io.17" S"'II.71 b1bll.Jo II. 7 2.35. 511.3.' 15.IOb q S'~b.115 11'd.S5 73111.111 O. Ij 23S. Sèll. 1i.t:!")'I 9 S'lb.7JS SYb.I, 19S7.91 O. II 2.3S. 5UII. 12.blll 9 S911.775 11'1j.55 ·IISSII.1I9 O. 9 23S. <I!lS. 11.117Z 'I 5"b.77S S"'b.71 'I1S1.1.I11 O. 9 ¿.3!:i. 4b.3. 11.111 11) btll.lli! lë!tl3.69 96,S!j.S7 O. 111 2.3'.:1. 114U. '1.151 111 bt:!7. He! bb7.11 10S2>.0" I). lU ¿.3S. 1117. b.1I1I1 10 bö1.11¿· 131".U 11l12.8U II. 11 23". 3911. 7. 1/;.... lu ot:!I.112 bel7.1I lIC1'1'1.YI O. II 23':1. 309. . b.f4U.... II 711/j.b'lb I¡U5.1I1 l¿b41:1.bl O. 12 ¿~5. j1l4. S."o¿ Ie! 1J'I.bO¿ 1.39.bO U]lIò.¿1 u~ I¿ ¿jS. j¿l. iI.Z¿1I 1¿ bllll.t:!5è 13tH!. liS 1110H.Ob O. i Ii 23'). jUl. j.q¿O 1¿ 5bb.1311 50b.l.3 1459Y.¿1I O. ~ 1J i!.3 ") . 2H I. ¿.SoY 11 1I]I.TJn '"'.tll 15030.9,S U. I ~q ¿~5. no. I.I~I IU .31'1.'131 .)1'1."'1 1535U.tl7 U. I" ¿15. ¿bel. 1.512 III 2"7.20.3 'J" 7.t II 155'1!!.1I7 O. i IS ¿j';). ¿b". l.l'" ,S 100.ltll luu.1Y l"oYtI.211 O. . I 15 235. ¿ot. 1.lu" j nll,~II" leI'I."U 157t1/.ul U. Ib ¿,S5. 25ð. .iI/;1 :\ III.IIIU ItI.ClI 15I1b':>.1I1I U. I It. ¿ 35. ¿'Jo. · II 11 j 70.021 14/.Ò's I'JY.35.'I0 Ú. 17 ~].,. ¿S4. · 7 III .¿ liS. III I ..S.15 1"'dl.u5 O. 1 7 ¿'s'J. t5,S. .IH I c!1.I.3bll 09.'J~ IbOIl'J.&¡1 u. III ¿~'J. ¿5¿. · IIJ j I ¿,S.2H ¿3.¿,S 10O¿II.t>" II. 1-4 11:1 ¿'s'J. 25¿. .blu I ¿¿.I.,,, "5.j'l 1005tJ.bIJ O. PI ll 235. ¿51. .0.311 I ¿ I .12Ø ¿ 1.13 IbO/I,IIj O. ,0" 1'1 ¿j':>. ¿':>u. · b" ' I ¿u.l"l "I.c!'¡ Ibll'l¿.Ol< II. .- 2') C!j5. ¿&¡I. · "1'1 I 1'#.lU IY.U 1"111 . ~ I) II. ~ 21) .. 3';). ¿"I. · ',.,S I It.-.jjl ~'.':>I) 1012'1.1>11 u. I VJ I .. .. -- e . I I I I I I I I I I I . . H.J. GRUY AND ASSOCIATES, INC. TABLE 4 ESTIMATED REMAINING RECOVERABLE GAS RESERVE BY WELL (AS OF JULY I, 1976.) SOUTH BARROW GAS FIELD NAVAL PETROLEUM RESERVE NO.4 ALASKA REMAINING RECOVERABLE GAS RESERVE I- Current Plus , Current Wells Six New Wells Well No. MMCF MMCF 5 1068.7 788.8 6 i 3746.6 2771. 7 .. .7 1301. 2 948.8 8 1169.5 897.7 . . 9 3733.6 2482.6 10 3775.2 2518.9 11 1320. 1 973. 1 13 1938.4 14 1486.8 15 673.7 16 312.6 17 227.9 18 108. 9 16114.9 16129.9 Tahle 4 .r--"" .:~..":<...,,...~-,AÞ...f;; ,._., "_':_~~'_~;~"":~:,,",, ':'!;;_'~'-';''7c''~~7.;/-.I.'g..-.-,-",}~",~~~.:r~';'~!f':;;,",,~~~~;~~~_....~~ L. $Pi - - - - -. -. -. -- -- _. .... H.J. GRUY AND ASSOCIATES, INC. .. :0. TABLE 5 SUMMARY OF WELL COMPLETION AND W.ELL STATUS DATA SOOTH ßARROW GAS FIELD NAVAL PETROLEUM RESERVE NO. 4 - ALASKA INITIAL PERFORMANCE DATA Theoretical Maximum Original Casing Tubing Shut In Absolute Flowing' Initial Datum Total Setting Setting Surface Open Flow Surface Production Well Elevation (KB) Completion Depth Depth Depth Type Status Pressure Potential Pre~sure Rate ~ Feet Date Feet Feet Feet Completion Sept. . 1976 PSIG MCF/D PSIG MCF/D 6400 1 35.0 4/15/49 2505 ZZ60 Z468 Open Hole T. A. 1020 640 6000 4 43,0 5/09/50 2538 ZZ75 2463 Open Hole P. &t A, 1000 Z75 1805 5 38,3 6/17/55 2458 Z320 Z446 .Open Hole Producing 1000 IZ300 960 1460 6 39.7 3/24/64 2363 ZZ76 235Z Open I;ole Producing 980 8200 805 3840 7 36,0 41.01/68 2351 ZZ38 Z339 Open Hole Producing 950 1500 650 1000 8 31. 2 5/01/69 2363 2261 ZH8 Open Hole Producing 980 1250 680 619 9 29.0 4/15/70 2450 2384 2442 Open Hole Producing 920 7800 .515 5118 10 38.0 3/24/73 2349 2250 2342 Open Hole Producing 880 8200 510 5070 . \I 34.0 3/06/74 2350. 2185 2142 Open Hole Producing 830 1600 480 815 ~ III Ci' ...-\ ('þ U"I ,.1 - - ~ ...... -. -- ,.. - .. H. J. GRUY AND ASSOCIATES/INC. TABLE 6 GEOLOGIC DATA 'SHEET SOUTH BARROW GAS FIELD NAVAL PETROLEUM RESERVE NO. 4 ALASKA ,. .. " BASAL UNCONFORMITY SAND UPPER AND LOWER BARROW SAND Estimated e Datum Net Pay Total Well Elevation (KB) Top Porosity Base Porosity Net Pay Top Porosity Base Porosity Penetrated Net Pay No. Feet Feet Fëet F'eet Feet Feet Feet Feet 2 35 2326(-2291) 2330(~2295) ·4 2339(-2304) 2440(-2405) 35 35 4 43 2350(- 2307) 2353(~2310) 0 2361(-2318) 2463(-2420) 32 32 5 38 No Logs . 6 40 2280(~2240) 2285(-2245) 5 2317(-2277) Not Reached 34 41 TD 2363(-2323) 7 36 2240( - 2204) 2246(-2210) 5 2321 (-2285) Not Reached 11 31 TD 2351(~2315) 8 31 2261(-2230) 2264(- 2233) 2 2330(-2299) Not Reached 16 36 TD 2363(-2332) 9 29 2373(-2344) 2380(-2351) 0 2394(-2365) Not Reached 44 50 . TD 2450(-2421) 10 38 2257(-2219) 2262(- 2224) 5 2286(-2248) Not Reached 27 35 TD 2349(-2311) 11 34 '2190(-2156) 2196(-2162) 6 2252(-2218) 2306(~2272) 34 34 ~ !.I cr .- (þ 0" I 1 í ~ 'J 1 " ¡ 1 .¡ 1 1 '1 j ¡ ,~ ~ , i J '" or: :it \ H.J. GRUY AND ASSOCIATES, INC. , Well No. Date 2 4 6 6 5 7 8 8 9 ,9 5,6,7, & 8 5 10 10 11 11 7 5,6,7,8,9,10, & 11 5,6,7,8,9, 10, & 11 4/20/49 4/ ? /50 3/21/64 3/21/64 6/17/66 4/12/68 5/03/69 6/28/69 4/09/70 4/15/70 10/15/70 6/18/71 3/22/73 3/24/73 .3/01/74 3/06/74 12/09/74 7/15/75 7/15/76 ~ ¡ ..... TABLE 7 PRESSURE AND PRODUC'rION DATA SOUTH ,BARROW GAS FIELD NAVAL PETROLEUM RESERVE NO.4 .. ALASKA Average Surface Shut In Pressure PSIA 1035 1010 982 965 995 970 935 911 920 895 845 831 837 . 808 Shut In Bottom Hole Pressures Measured At Depth PSIA 1090 1040 , 1055 932 897 Shut In Bottom Hole . Pressures Corrected To -2250' PSI A 1102.2 1081. 0 1075.3 1041. 0 1044.7 1026,3 1058,6 1031. 8 1050.5 993.8 . 967.2 977.7 932.0 950.6 899.0 896.4 881. 7 886.6 856,6 ...... ... ... Compres sibility Factor Z .839 .842 ,841 .845 .842 .849 .845 .848 ,847 .852 .855 .853 .859 ,856 ,864. .864 .866 .865 .869 Notes: (a) Typical surface shut in build-ups are for 72 hours. (b) Measured bottom hole pressures are from drill stem tests: (c) Bottom hole pressures calculated from surface data assume no liquid in wellbores. ~ II 0" - CD ooJ - 1M Bottom Hole Pressure Over Z PSI A 1313.7 1283.8 1278.6 1232.0 1240,7 1208.8 1252.8 1216.8 1240.3 1166,4 1B1.2 1146. 2 1085.0 1110.6 1040.2 1037.2 1018.1 1025.0 985.8 - .. _. - Cumulative Gas Production To Date Of Test MCF . ",. t o 53,500 1,894,231 1,894,231 2,690,359 3,562,329 4,116,999 4,216,405 4,668,992 4,681, 112 4,950,288 5,405,496 6,582,793 6,587,823 7,241,.172 7,256,300 7,798,872 8,291,900 9, 121,433 . I . . I H.J. GRUY AND ASSOCIATES,INC. I TABLE 8 RESERVOIR TEMPERATURE DATA SOUTH BARROW GAS FIELD I NAVAL PETROLEUM RESERVE NO. 4 ALASKA I Well Temp. Depth Source Date No. of Feet Of Data I 2/23/74 11 60 2300 Logs " I 3/01/74 11 68 2172 DST #2 1/17/73 10 60 2288 Logs . I 3/22/73 10 52 2349 DST #2 , I ~ 4/09/70 9 73 ,2424 DST #2 I 4/04/70 9 73 2125 DST # 1 4/11/70 7 52 2300 Temp. Survey I 12/04/50 2 60 2465 Temp. Survey I 1/21/51 2 68 2468 Temp~ Survey 2/28/50 2 62 2450 Temp. Survey f . 2/17/50 2 62 2450 Temp. Survey ! Avg. 63 of . Tahle 8 --- ---.......... H.J. GRUY AND AssOCIATES/INC. TABLE 9 SUMMARY OF CORE ANALYSIS DATA' SOUTH BARROW GAS FIELD ;1 NAVAL PETROLEUM ~ESERVE NO. 4 ALASKA- " " Porosity Permeability. Cored Interval ø K Fluid Saturation Barrow J~ras sic No. Arith. No. Ari tho . Well Gas Sand Only Samples Average Samples Average Hydrocarbon Water No. .F eet Analyzed 0/0 Analyzed Md 0/0 P. V. 0/0 P. V. - " 2 2286-2470 21 17.71 16 36.30 4 2340-2470 17 10.70 2 14.00 5 . No Record 6 2343-2363 No Analysis Available 7 No Record 8 No Record . 9 2379.5-2450.5 73 18.78 73 24. 10 4. 19* 59.80 10 No 'Record 11 No Record ~ lI 111 17.34 91 26.09 4.19 59.80 0" - Cl> -.J:) * Well No. 9 cored with seven percent diesel oil in mud. iJî ¡.1 ~~'Í! "J ~~. ~' ~i , ~ , M ,¡ tJ .; I , ~ III cr - '(1) !~ Ù - - - ...... iIIIiIIiII; ... ~ ~ - - - H.J. GRUY AND ASSOCIATES, I:'-Jc. '. TABLE 10, COMPUTER ANALYSIS OF ELECTRIC LOGS WELL NO. 9 SOUTH BARROW GAS FIELD NAVAL PETROLEUM RESERVE NO. 4 ALASKA .. .. DENSITY (~ ,;' $w CEPTH CALIpER GR SP DÈLTA T PHI NPL RT APP. RXO APP. pcr CLA., RHO MAT PHI.ÊFF PHI SEC DELTA SO -.----- ------- -..----- -.--.- ----.-- ------- ..------ ------ ----..--- -------- -----.- -----.- -..---. ------- 237".0 9.00 5Ò.í.l0 .00 2'''75 8".00 15.00 17.5· .0 30.55. 2.833 11.75 54.2 .00 2.70 '2.577.0 9.00 50.0U .00 2."50 92.50 15.50 16.0 .0 29.91 2.785 11.60 53.8 .óo 4.86 2.579.0 8.80 40.00 .OU 2."80 86.00 12.00 17.5 .0 30.55 2.545. 10.30 57.9 .00 .00 2381.0 8.90 47.UO .00 2.420 90.00 15.00 16.5 .0 31.92 2.663 9.77 59.8 .00 .95 23005.0 9.00 50.00 .00 2.520 87.50 13.50 15.0 .0 34.29 2.849 .00 100.0 .00 .00 23/35.0 8.ao 45.uO .00 2.425 91.50 14.50 15.5 .0 33.46 2.615 13.64 51.4 .00 .00 2.587.0 a.80 4J.1I0 .00 2."95 87.50 13.50 17.0 .0 31.22 2.741 .00 100.0 .00 .00 2389.5 8.ao 3':1.00 .00 2.390 94.00 13.50 17.5 .0 25.25 2.590 15.76 49.1' .00 .00 2393.0 8.80 45.00 .00 2.500 87.50 13.00 17.5 .0 30.55 2.714 .00 100.0 .00 .00 2397.5 8.70 40.00 .00 2.370 93.00 14.00 21.0 .0 23.72 2.621 11.26 56.4 .00 1.39 2401.0 8.70 40.00 .ou 2.345 97.00 14.50 21.0 .0 21.29 2.646 13.25 53.5 .00 2.24 2411.3.5 f1.80 60.00 .00 2.520 85.00 14.00 22.0 .0 25.73 2.944 13.16 48.Q .00 3.84 240b.0 8.HO 40.0U .ou 2.,550 98.00 13.50 23.0 .0 18.06 2.641 18.18 43.6 .00 .56 2407.5 8.80 32.ÙO .00 2.420 83.00 13.50 23.0 .0 15.56 2.689 14.26 53.5 .00 .00 240B.S 8.80 3B.OO .00 2..340 93.00 12.50 23.0 .0 12.13 2.643 le.79 4&.3 .00 .00 2409.5 B.80 41.00 .00 2.400 90.50 13.00 22.0 .0 24.98 2.584 15.15 45.6 .00 .14 2411.5 8.80 54.00 .ou 2.j50 94.00 14.50 19.0 .0 22.19 2.6,.1 18.18 45.5 .00 .81 2414.5 B.80 52.UO .OU 2.550 83.00 17.00 16.0 .0 32.&1 3.811 23.57 '37.4 .00 6.92 241b.5 tJ.tJO 54.00 .00 2.500 89.00 16.20 17.5 .0 30.55 3.105 1&.63 45.0 .00 6.57 2417.5 8.80 53.úO .00 2.550 84.00 15.00 17.5 .0 30.55 3.408 19.91 40.5 .00 3.44 2'119.0 8.80 40.00 .00 2.,590 93.00 13.50 27.0 .0 22.07 2.628 10.61 52.8 .00 5.75 2421.0 8.80 . 43.00 .00 2.420 90.00 13.70 21.5 .0 21.16 2.661. 10.42 53.2 .00 6.83 ,424.5 '6.00 :51.00 .00 2.j2a 91.50 13.00 23.0 .0 10.60 2.664 18.46 48.1 .00 .00 242d.0 bolO 32.00 .00 2.420. 85.50 12.00 25.0 .0 15.56 2.633 13.94 52.2 .00 .00 2430.5 8.50 32.00 .00 2.300 91.50 12.70 26.0 .0 5.77 2.686 19.65 4&.1· .00 .00 24.303.0 1:1.50 33.00 .00 2.,500 93.00 12.00 25.0 .0 2.e8 2.679 19.80 48.7 .00 .00 2435.0 8.50 32.0~ .00 2.300 95.00 12.00 25.0 .0 2.ee 2.679 19.AO 48.7 .00 .00 243b.5 8.50 32.00 .00 2.j30 101.00 13.00 30.0 .0 12.40 2.666 14.77 48.2 .00 1.96 ~HALE-COK~ECTLD SU~M^RY OF THE INTERVI\L 2372.0 TO 2437.0 tiEr PA Y = 42.00 FEET' POROSITy = 15.1 PERCF=:NT, WATt:k SATURATION = 50.2 PERCENT .' e e - o - I . H..J.·GRUY AND ASSOCIATES, INC. .. I TABLE 11 SUMMARY OF GAS ANALYSES SOUTH BARROW GAS FIELD NAVAL PETROLEUM RESERVE NO.4 ALASKA I I COMPOSITE OF SIX SAMPLES OBTAINED BEFORE JUNE, 1969 I I Mol Specí~ic Critical Critical Molecular .'" Component Percent Gravity Pressure T emperatur e Weight Methaneo( 97.96 0.555 673. 1 343.5 16.042 Ethane 0.95. 1.046 708.3 550..0 30.068 Propanes 0.15 1.547 617.4 666.0 44.094 :Butanes 0.02 2.069 539.9 750.3 "58. 120 Pentanes + 0.00 Nitrogen O. ·80 0.967 492.0 227.0 28.016 Argo~ ' T Helium 0._02 0.278 33.2 9.5 4.003 ""Carbon Dioxide 0.10 1. 519 1073.0 548.0 44.010 100.00 Weighted Averages. 0.564 Ó 72.2 345. 1 16.347 ·1 I I I ,COMPOSITE OF EIGHT SAMPLES OBTAINED AUGUST 6, 1976 I .. Mol Specific Critical Critical Molecular Component pèrcent Gravity Pressure Temperature Weight . Methane . 99.67 0.555 673.1 343.5 16.042 , . Ethane 0.30 1. 046 708.3 550.0 30.068 Propanes T .Butanes 0.00 Pentane s' + 0.00 Nitrogen :0.01 0.967 492.0 227.0 28.016 Argon 0.00 Helium 0.00 Carbon Dioxide 0.02 1. 519 1073.0 548.0 44.010 100.00 Weighted Averages 0.557 673.3 344.1 16.090 ~ ( Table 11 ~jWl~~~~''m;cf!."1'fé:''~~~'Y'-èi''~':''~~Ff'<~.::;,;,!>'io~~~~~~~~~~~'j;~':;:;::~~~~$"~~~~,~;,~"t"~:~¡·~~,;~\~.,:,c;;r!'"""-,,,,,:..,,,,,·-""'..'f''''.~~ NC H.J. GRUY AND ASSOCIATES, . . .0 " )() .......... "- . ~ . ~. " ?-. "- . ~ I'.. 8 f'- ¡ . '" FIGURE 1 t- " BOTTOM HOLE PRESSURE OVER Z " VS. t- "- CUMULATIVE GAS PRODUCTION t- o r'-.. SOUTH BARROW FIELD - Ì'-... NAVAL PETROLEUM RESERVE NO.4, ALASKA - ¡""- SEPTEMBER, 1976 "" HOUSTON, TEXAS H. J. GRUY & ASSOCIATES.INC. f-- "- ,,{~ "- Ì'-.. ,·1 ',~. " :<.),~::t{ r" ~ 1""- . "" I'.. )0 I'. Ì'. Ì"- ."'- )0 "-~ ì'-... Ì'- "'- I I I I I Ì'.. I " ~ . ¿ . . '" '" .. ,¿ U .. .. .. "^ .. u .. h C"m"lo,i". 38 36 34 32 30 28 26 24 BCF 20 22 Production Gal 14 12 20 6 10 4 8 4(. .., Q,. , N .. · > o · .. : ~ ... · õ x e ~ Õ co ~ .... O'Q c:: 11 CÞ ..- - ... - - - - - NO H. J. GRUY ÁND ASSOCIATES, . . 00 '. , ~ ,., . ~ " ~ FIGURE 2 r- ........ , AVERAGE FLOWING CASING PRESSURE VS. r- -....... ~ CUMULATIVE GAS PRODUCTION ~ o 00 '!, G 1"'-" )0 ~ SOUTH BARROW FIELD ~ 0 . i'... NAVAL PETROLEUM RESE~VE NO.4, ALASKA - ¡"""- SEPTEMBER, 1976 H. J. GRUY &' ASSOCIATES,INC. - "'- HOUSTON, TEXAS -....... ',- i\ ,',' .;;.,/ ;t~'~:"':?~~T'~!{f,:;:Y~~~ ~:i~G~!T:f.:-~~:~~?!\l~ )~r¿4·:r!\>Vt;J~,! ,"::.{ ) "'- ~ -....... I'-.... l'- ......... ...... '0 "'- ......... ...... ."'-. 1'-...... Es imo ed ulti ot. 0 '" .... . " ...... " .... " , " "- , , . . 0 .n .. .. .. -. .n .. - . .. h 40 38 36 34 32 30 28 26 20 22 24 Production - 8 C F Gos 16 ,. CumulQtive 14 12 10 6 4 2 14 o 12 10 c( 01) CI. I ! :> .. .. ~ . CI. '" C ~ go c ïi ~6 "- . CII ~ . ,. c( 4 2 I-r1 .... O'Q ¡: 11 () N , )-; ~~ c ~' ;,. '1' _~L ~ \I"~ ;~ , k j> ','I ~;~ Ii,! t,~, ~.{ <- ,. I I I I I a I I (. I I I I I I I I . u .z , CI) LJ ~ U o (I) -CI) -< o .z '< >- :;:) 0:: (!) .., :r: . . .... . ~ 0 I I J I I ~ I I .~ ... " j i , Ii': ",'" O· ~ ~ I ;>' \- ... I .;ft' / V .. I v'" ¥ ,- ~ I I ~ " / -:-'- O· I V / ~ + I ;.; ~ v ~.. .. ~/ 0' I I ;. V + 0 ...... ! ./ .// ./ ... , ./ ./, ./ L "L ./ ./ ./ // L L ./ Æ /V '/ / V' ð L ~ / / /,:v LL ~ L , ./ ~~ yZ' ~ / ~ / V v 0 / I .. - ~ ,- V ~ /v./ / / ,1 ./ .// ./ I ./ /./ ./ ./ ! -± / "L.. / .ó / v . I /L L tL: #' / L L t2'" IL i , ! I ¡ ~ /~- / ~ I ! ¡ I , : . I~ / Pc - She". '" W.Uhevd PT..... I 1 I Pw-. iFto.¡", W.fJ'-ad ".--. I I I ! I I I , I ! , , I J J i I i , fIGURE 3 ESTIMATED INDIVIDUAL WEll Dfl1VERAB1l1T I ES .. SOUTH BARROW FI ElD NA VA l PETROLEUM RESERVE NO.4, ALASKA SEPTEMBER, 1976 H. 1 GRUY &. AS50C1ATE5. tNC. HOUSTON, TEXAS '-L-L -L I i ! ; 1G. 1. x ~·o ":,.v - OJI1 -.....01100 1.aGO 10.000 100,000 -Go. lot., MCFPD Figure 3 ~- 1!!!!¡-~··,·~",·~"~"""",-.""r.."-~,_""",,,,,,,,,,,,.,-,~,'~;iê~.-<,,'~'''''''''-~~-~'''''''TII!" I .. ,... "",,,,-.-, ." , ....._.a.:'"'"l>:.~...."....~... 'M"", n H. J. GRUY AND ASSOCIATES, INC. u, O Pressure-PSIA '.■■■■■■■■■■■■■■■■ NOON■■ ■�■■■■_■■■■■■■■■■■■■■NNn� NOON ■■■■■■■■■■►�■■� ilii■■■■■ ■■■■■■■O■■■■■■■■■■1 -----.-■■■■■■■i ;'N■■■■ NOON■■■■■i■'■■■■■ ■■■■■■■■■r ■■i ,■■■■■i■■■■■■■■N ■�.�■■■i■■ ■■■■■N■. ..NOON■ ■■■■■■■■■■■■■■■■■■was■■■■ ■■■ ■e■. ■N ■■I ■ ■■■■■ONu■■ ■■■i■■� ,iii:. ■■� ■■� _ ■■■■■■■■■■ ■■■■■■N�■� ■■■■■■■■■■■■■ NOON■■i ,■■■■■■■■■■i■ii■ MEN ■■■.■■�■NN■■N■■■■■■■■■■■i .■■■■■■■■■■■■■■■i ■ ■■■■■■■■■o■o■�i■■�i■■■■■■■■i ■■■■■■s■■■■■■n■■■■■ ■.■.. N.■ ■■■■■■■i■■■■■■■■■ FIGURE 4 ■■■■■N■■■■■■■■■■■i■■■■■i■■■ ■N■■■■■FACTOR ■■■■■■■■■■■■■.■C■■■I ■■■■■■■ ■ ■ ■■■■a■■ BARROW i■■s ■■■i■■■■■■■i■i■.i■ ■■■ ■■■BARROW ■N■■■■■■■■■■■■ ■ ■■a■ ■■■ .. . ...s.■ �s ■ ;■■....■ �■ii■■■i■■ ■ ■■SEPTEMBER, 1976 'HOUSTON, TEXAS H. J. GRUY & ASSOCIATES,INC. ■i■ ■ ■ ■e ■ LEININIM Pressure-PSIA d .ig .. :1 , , .. '~ ... .. ~ ~f ~ '{ ~ I ~ ~ ~ ~ ~ II ò: ~" ~,; ~. ~ ~ , .~ I I - -, - -- -j - - - - - - .. .'. " H.J. GRUY AND ASSOCIÁTES/INC. ~ , .. " '" ,""" '-.. S., ~ '. I' .......... Ga. Gra.;.. = 0.564(Air =\1 , .......... ....-T.mp.= 63- F .......... "' ........... \ ..... ........... .......... .......... - - - '"'" ---- V ---- . /" ---- V / ---- ./ ","" / FIGURE 5 ...- ",'"'" - ./ ESTlMA T E OF SANDFACE DRAWDOWN / WITHOUT HYDRATE FORMATION - ...-' .---- VS, SHUT IN RESERVOIR PRESSURE - ./ SOUTH BARROW FIELD - v ."" NAVAL PETROLEUM RESERVE NO.4, ALASKA ./ i-- / SEPTEMBER, 1976 . / H, J. GRUY & ASSOCIATES, INC. r-- /' HOUSTON, TEXAS /' '.; +",.\,\ .,,>ij \::-1Q~. .\ I- '\ ,/ I I I I I I I I I I . 1400 1200 1000 . c( ~ 100 . ~ .. . ~ ... .. õ ~ 600 .. .. "" 400 200 .... (Q ¡:: '1 () U1 00 400 SOD 700 100 900" 1000 200 300 600 100 Permissible Sondfac. Drawpown Without Hvdrat. Formation -PSIA '~~ " ,,'.........,,"'..,..... ~~--~ '1'i'<!1'~'!1r~/~;,'!¡"~"i¡t",.'~..· ";r'"'''' "U; J 1, '.M:l1 ·W!', T. '---:"".'~ ·..~4_p_ tI ." ,. H.J. GRUY AND ASSOCIATES, INC . . 9 I 7 6 S .. . J ¡ 0 9 8 7 "" r.'., I ... 'H L.. b ; ~ .'... ........ (C"",. . ..11. 1101. ,i. ow ..11 5 '., ............. ---- . /'-..... ....J Colculo .d toto f¡eld .I.veto 111"- f Cut", .11, I \.7 ........... ......... ...... ! ..."'....." I- ~~ -- '. l--- - E _""ot.d ..1 Ruol d mond -- .J- ..- --- -~ :ç ~-- --- --- --- .- \. \ .- - .-- ,- - "' ~ - --ç: 1'\\ -£ ,,,,,al.d o..rog onnua d.",on ~ \ FIGURE 7 "'" DElIVERABIUTY AND DEMAND VS. I'.. TIME \ '\.. J \ "- SOUTH BARROW FIELD \ "' NAVAL PETROlEUM RESERVE NO.4, ALASKA SEPTEMlfR, 197b H. J GRUY & ASSOCIATES,INC, 2 HOUSTON, TEXAS 1\ \. ~~9'¡ 1995 I I ..-.. --'f--- 1976 1977 1978 1979 1980 1981 1982 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1996 1997 1998 1999 2000 2001 2002 2003 .---..-- 10,000,000 ~ c · I ~ u :I · · :: ~ ! ~ 100,000 9 8 I 6 ~ 4 10,000 \000,00' ~ .... I)Q f;: Ii ('þ ~ i ~ " \ H.J. GRUY AND ASSOCIATES/INC. Irj .... OQ r: ,0; () 00 100,000 9 · 7 · ) 2 ! > ... '1 10,000 9 e 7 A 6 , I · . " 2- 1.000 · 7 6 , · f-.-- ) 2 - ~ Ii :x: ~ - ~ ~ .., Õ a ~ .. .. ~ .. ~ " .;¡ ; ~ ~ . ,~::I _ J~~~.3 - - 1~~!iiI cJ~~- ":9}"!. j¥~rL~5!_L~_6.Q. - - I --t- -'-- I I I -¡-9JI96AI'1~ 19b4i965 . --~- ----- j------- 191>.~ E~I>.~_ - - -- - - "'- fiGURE a PERfORMANCE HISTORY SO\JTH BARROW GAS WE'Ll NO. 2 SOUTH BARROW GAS SAND SOUTH a-ARROW FIELD NAVAL PE TROlEUM RE SERVE NO 4,ALASKA SEPlEMIEt, 1976 HOUSTON, Tf.A~ H J GRUY & ASSOCIATES_ 'NC I - Ij ¡ 1 I d . - -- -. -- ¡ -- , 1972 ~ 1~73 Ll~~4_1!~?~_l!'?!~_ T r ï~~1I~6~~ 119!ö 1971 - .. e . . . . . - - - ... - - -- H.J. GRO'f ÅND ASSOCIATES I 'I NC e . i 7 6 .. . ". ! t ~ r~ . 9 VI . j 'If '^ : .. . 7' ~ .J: 6 : .:. ." . ." 5: oil . -" .. 5 ~t8 .. · \J ã z . n _ . i. z~ ~ .. e ~ .. I . 7 6 FIGURE 9 5 PERFORMANCE HISTORV SOUTH BARROW GAS WEll NO. .. . SOUTH BARROW GAS SAND I SOUTH BARROW FIELD .- - NAVAL PETROLEUM RESERVE NO.4, ALASKA - I _ ~'J~~~C:~~"~~~5 H J GRUV & ASSOCIATES. INC. -. -- -.- ...-f----t---'- +-___ .----r--.' "'''- _ b." ij" '!i! .N~""¡ '"iõ'Æ ,.,. i"Tjij¡¡" ]W TiiO ¡,,, i'!¡ ¡ ~ J"¡ ¡¡¡, "!'!'" ¡",hi! :ili~ ,,¡¡¡ ij,! J!¡¡¡¡fl.~;o" ~'!!! _"" Jill: 100,000 10.000 1,001 ~ E · . > . ..., .~ · u ::f · " ~ .... OQ s:: '1 (1) -.0 \ \ ~f ¡-. -j. ¡ ~, fl' :\~, hr " ì. ¥ - - - - - - - - - - - - - NC H.J. GRUY AND ASSOCIATES e . 100,000 o " ;;; .. 000 00 · 7 6 .. · J 2 ^ IA It-. ~ J\/ VI rv ~ r r \rI , I (\ II IJ : ~ ¡'I 1 6 I ,rv' Vl If 5 I -, · I · · ~ .. · 2 -_ N. " § .:: ~. .f o - I · ; I . 1 <I FIGURE 10 5 PERFORMANCE HISTORY SOUTH. BARRÖW GAS Well NO. S · SOUTH BARROW GAS SAND , J SOUTH BARROW FIELD ~ NAVAL PETROLEUM RESERVE NO.4, ALAsKA ¡ ~EJ~~~~~'J~I:5 H J GRUY & ASSOCIATES,INC. i -- --J I I ,~ :¡.-.b-~.~ "" ~"- "" ~,,' "j, ¡o¡, "" "" "" J'" .;oj! ,,,. ,... ,.., '''' Jill. "i!:c>'~ ~!,. "" .".~, ,.... :...[ ~ ' 100,000 . '0.00' Ii! ~ I > E ..., .~ . V . :I! Õ " \ I,;j ..... (Q ~ ~ CD I- o - ..... -. .... ... ... -·-~--"---"".";i ð H.J. GRUY AND ASSOCIATES NC. 100,000 -;- - r------o - '---'- -- - r-- -,.- IOQOO( , -f- - ~ - - - - - f-- - f-- . -f- - ~ - - - - - f-- - f- 7 -f- - ---I - - - - - - - - - - - -- -¡ - - - - - . - - - t---I - ~ - - - - , 4 "\ - r-:- ~ - - - ~- - - tJ¡- - f-- ~ - - - r--- - t-- J .J\ f-- - - - - -- - t-- fJ1 \ JIY .. - - - - - I-- - - 2 \ r I I I / \ ~ j - f---- - - - r-- - - e \J V V 1/ V U V\ (VI ~ (~ h ,1 v v \( V \/ \ - - - - - - 1<\000 - - - - - I-- 10,000 , \/' IT - -.¡ - I- - I-- a V - ---I - I- - '-- 7 - t---I - I- - I-- - ---I - - - r--- 5 '-- - - - r--- i . . I- - - - r--- 0': I- - ---I - l- .., ~ - '--- - t---I - f----:- ... ".. '-- - ~ ...,..1- r 2 I- ---l - - i ¡¡: l- f---- - - . ~OOO - - I- -t---I 1,000 . 9 - I---- -I-----< a '" - I- f---4 7 - I- L-J . l- I-- FIGURE 11 s I- - PERFORMANCE HISTORY SOUTH BARROW GAS WEll NO.6 . - - - -.. "- SOUTH BARROW GAS SAND 3 SOUTH BARROW FIELD .--- NAVAL PETROLEUM RESERVE NO.4, ALASKA 2 1 -. ~~~:~o'::\¡r:, " , Go" · A"O'~'". 'N' IT f--- 1-' - --- ~~k;,:.. "" j ~~::6!ö.'iiT .." I", i!IL}'iIc,'" i"'I'''' ',;¡, ...... I OQ L.!~~~T i97i~lm î973- ¡: oo~ ;9681ï969~L97Ö= 100 ""I 1990 1991 (1) --_.L_L...__,::",- ..... ..... ,., I , ;',J j î j ,.¡ - - - - - - - - - - - - . H.J. GRUY AND ASSOCIATES, INC. ¡ W ~ 100,000 · tJ . e 100,000 0.000 J r~ DO. u I" J ,000 JOO . "- II _ '~ 1 \ . ~ « N I N AMI 7 E' \ 5 .. ~ ~ I I I A" V I . II : \1 I ." "I . j & . D ~ J I I ¡.......r 1 Il-J..l '-...j . J · FIGURE 12 I +-...- PERFORMANCE HISTORY SOUTH BARROW GAS WEll NO 7 I SOUTH BARROW GAS SAND I SOUTH BARROW FIELD -- NAVAL PE TROlEUM RE SE RVE NO.4, ALASKA ~~~~~J~~ii~7:5 H J aM & A SSOCIATES,INC ----- '- -- - ~ -¡J69 I97Õ ï971 í97_~_ I~_~lJ~7'-,ii!.[_T976__19~7 _1918- !~!~-I~!£J!!!.._ T9i2 -f9ã3 ï98419~I~~ !?~T_ii'¡f.lli~-~í9iq:]99I: 1992 ~~~ ~!4 Î995X 6 5- · 10,000 · · 1,000 100 « ~f H ~.... ~r; . s . C) Þr ~. OCI r:: ~ CD .- N -' - - - .. .. -, - - . . I " rtN"6. ,. Hi, J. Gìpfu'Ý ~N'D) j(SS'OCI!A""Ë:S~ . . r 000 ~ .." . - Õ'" Do. U .. . i £ .' 000 100 , , I I ; I I j II .. I ~ I , ! kA , I I \ W 9 · 1\ IA 7 \ b \ 5 ^ \r \ I · I~ U \, I I p ) - , ÏI __ : J..J W'- ..... > FIGURE 13 I PERFORMANCE HISTORY SOUTH BARROW GAS WEll NO, B I '- SOUTH BARROW GAS SAN D I SOUTH BARROW FielD I -- NAVAL PETROLEUM RESERVE NO, 4, ALASKA Ii.., SEPTEM.ER, 197. H J GRUY & ASSOCIATES INC I_-t-- ---·t t------ -- - --."" .---_. -- . HOUSTON, nus , . I "" "" "ij,,,.-J,, " '"" ...".~h"~'''~·Jlli: ,," iiK ". , ....-:>: .¡", ".. ".. WOO >¡,,¡- "" J'." ".. c",-,",,' J 100,000 9 . b-J"" r~¡ 6 10,000 . !~ " . > . ..., .~ . u .. '" ii " 1,0' It1 .... (Q ~ 11 '(þ >- l.ù i~'i I t' ;.,:. .;,. ':~ . !. ¡ ~ ·"°1 ",.'11 '. , till - III - fIi!I!!I ~ f!"""!"I!"c .........". ~ NC H. J. GRUY AND ASSOCIATES e . 1OQOOO '0,000 i ~ .." . - -:'", 0.. u ~ i . ¡¡: '.000 9 . 7 6 , ... . " I '\ r ~ r'1 f l ~ h I V V \ \J \/ \ , 9 L . 7 6 5 . I ! - . , . 1 I ..... - -- V- 7 6 FIGURE 14 5 PERfORMANCE HISTORV SOUTH BARROW GAS WEll NO. 9 . SOUTH BARROW GAS SAND SOUTH BARROW FIELD NAVAL PE TROLEUM RE SE RVE NO, 4, ALASKA ¡ Sf PIE !/oIER, 1976 H J. GRUY & ASSOCIATES,INC. I HOU~ION, tEU ~ !:t:Li,,: . -- ------ --,---- I 'to" ",d." -1~t~7 8 ~~lo i.9i~1~: I I -i97;¡- ïm ï97ó 198(:h988_ ~-_. --..._-- i:9Ü~ !99~ )i.9d~~~~ Ici9Ò'lm I 1973 1989 1990 1991 1-...-.- ____ ----. ------ 100,000 10,000 1.000 '0' i.. .:. ë: · . · . "'- .~ · v .. ~ S " "Zj .... OQ ~ ÞOO (þ - ~ ~ ~ ~ '~ ~ !~! "I ~ D ~_:_. J\J ., ~-( ~ , ì 100 .'1 t1 a '10 ... pIIIIII!t .... ...... .......... ~ - .......,. - NC, H.J. GRUY AND ASSOCIATES 100.000 9 8 100,0OO " 0' .. 4 . ì 111\ J 1 'ì . .' lqooo t . 1 . - F! - ... DL V . C - i ¡¡: - - 1,000 - - - - FIGURE 15 PERFORMANCE HISTORY SOUTH BARROW GAS WELL NO. 10 SOUTH BARROW GAS SAND SOUTH BARROW FIELD NAVAL PETROLEUM RESERVE NO.4, ALASKA ~EPTEM'E., 191. H J GRUY & ASSOCIATES,INC. HOU~rON, rfXA.~ . '"'"'" 10,000 · 8 1 6, 5 · I- ',000 · 8 " · 5 4 2 J &£ : Ii ., E ..., o~ , V ~~ " :]fóO.L, J ¡¡,; 1!:o'!.1i"¡:¡1''':LifiTŒ,.Ü"ifi¡,. n..,¡,OOO 100 -t-r-rJ ---t---t--- ï9j4D.~ffîJì9i7-1197BI!97~~b-B_~11f~ 19B3 'lj:~IT~B~¡'i98btciF --+--- ¡ h973 '(j' I%j .... OQ ~ 11 (þ - \J\ - - - - - - - - NO H.J. GRUY AND ASSOCIATES . . IOO.ÐOO 10.000 f ~ J~ . I Ii: .000 00 . 8 1 , . I , I - . I 1 I ~ I , . , I i , '- ./ , F IOURE '16 PERFORMANCE HISTORV SOUTH 8ARROWGAS WEll NO, II -- ---'-- -- --- -- -- SOUTH BARROW GAS SAND SOUTH BARROW FIELD NAVAL. PETROLEUM RESERVE NO 4, ALASKA -- -- SEPTeMBER, 1976 H J GRUY & ASSOCIATES,INC. HOVSTON, lEU S --- -' ~ L-~ i97T im ¡.,.l~,."J"'I"'" '... To., To..~ '''' ".. ii..d ii.' iiiC ~. L,'''. ~'i" '"i.", 'i",," .'Ù' 12001 ---Ii L~~~ 197b 1999 2000 2002 -- .:::- 1..--_ ___--:.-.. 100.000 .fo.OOO 1,00 '1 .~ CJ IT1 .... 00 s:: "1 (b ..... 0' D q '1 .- ~ ... ... - - - I ,,~"I"'C'''IC" I,.·' ..."..._..., .~ .r· ·"...'.f.0"lsrAl f.'Jpt'A'A' .........'........ , ..... .....,.......,\, ~"~) ....... .,.......\ " I ....~ , ..,....... I I~'-v/ ',.,' ( "'....fI..,.... '--1-, ., I '.j \ , , , FIELD BARROW . . N D ();) ALASKA LOCATION MAP . SCALE IN MILES 100 0 100 200 300 AOO ~OO I!!! 5 - - 5 . SEPTEMBER,1976 H J GRUY & ASSOCIATES, INC HOUSTON, TEXAS ' . ". , \n » » ~ z ~\~ , \ I L. I i / I / , ~ ..... .. \1% .. ,).!o- ........./ ~ d7 ~ ØJ >tj .... '>1 ., i'~ ¡ ; ~ ~ ~ IÎ d I I \ a:: '11' '1j N ..~ """'" ...... .. .. - - . . ".. Itt'- th" 10'.- In· ISO" ,..- TO· . "~. , ~¡p C"'~ /C TI" '" OCEA . NPR-4 BOUNDARy..., ............ leO" 14:r r,eeo- I OIL AND GAS FielDS OF THE ARCTIC NORTH SLOPE . aJ> Oil FIelD €iD GAS FielD SCALE IN MILES --- NPR-4 BOUNDARY 30 o 30 60 90 . 60 SEPTEMBER, 1976 HOUSTON, TEXAS H. J. GRUY & ASSOCIATES, INC. I . . I "' ..... I N V\ 0 'Z. I tp. ..... ~ '1> ~ I +' 0 i-(, 0 'Z. +ù. .o~ (, , \) -- 35 . 3 2 .' 7 . 9 11 .' ~ ~ t' ~ ~~ 13 0- CO ,. 17 -t6 15 .10 I. 13 ~ " 18 . ~ ~ t" ð!: ~ 011 z. 19 20 21 2. 19 " P 25 30 29 2. 25 30 'GAS TRANSMISSION SYSTEM SOUTH BARROW FIELD NAVAL PETROLEUM RESERVE NO. 4, ALASKA . :SCAlE IN MilES 1 ·-tEGEND- . .location . -Go. Will If . -AbonÒ"gned Go. W.11 ·-Go,-.i...I¡". ll". 1 o H. J. GRUY & ASSOCIATES, INC. SEPTEMBER, 1976 HOUSTON, TEXAS .---- ~4::;,~~:>.:c{..~,..~~~¥ __,_~r~~.i:Þ!"'~ ~ M _ "^'" ~ U bS' J! 2 3 Map 3 TOP OF BASAL UNCONFORMITY SAND SOUTH 181~f{ f{OW 1f'~~1b.1OJ 'NAVAL PETROLEUM RESERVE NO.4, ALASKA c. I. = 50' SCALE . . T 23 N T 22 N 4 '3 2 9 ~ 10 11 s(f ~~ .023/"300' , ~ 16 21 28 33 o' ~~~~~g~R'T~9:ZS H. 1 GRUY & ASSOCIATES. INC. 34 3000' , 13 ~;: CO,.... -- 0::0:: 24 25 3000' 6000' Map 4 W-·~.q,.."....",M~~ - . . I T 23 N I T 22 N I ~ 3 2 1 I I ~ I- 10 I I i I ~ -3: 3: 16 G)-r-- -- I --a: a:: 013 1/ } / I 21 22 2~ I I I I 28 U D 25 '33 34 ·NET HYDROCARBON 'BASAL UNCONFORMITY SAND .SOllTIHI BARROW f'BELD ;NAVAL PETROLEUM RESERVE NO.4, ALASKA Co!.: S· SCAlf 3~0' _ 0'._ .. 3000' 6000' ~~~~rJ~~'T~¡~S H. 1 GRUY & ASSOCIATES. INC. Map 5 .J'-' !!·~'~'~;"',i'j-~,"1;I1!f_1l ~ACC'ØiI.llll-'J. I . . I T 23 N I T 22 N [ 4 :3 2 [ [ 9 . 10 [: , . ~~ 16 13 CO,... -- 0:0: -21 '28 24 25 TOP OF UPPER BARROW SAND SOUTIHI ISARIROW IF'~~ILID >NAVAl·PETROlEUMRESERVE NO.4, ALASKA CI.=50' SCALE 30:>0'· _0' _ 3000' 6000' ~~0~rJ~~'T~9Iks H. J. GRUY S. ASSOCIATES.' INC. '33 "34 -- , - Map 6 I I I I I I I I I I I I I I I I i I I ".. I "" ~ . . T 23 N T 22 N 4 3 2 9.t a: a:: 10 16 13 ~3: COr-- -- ~1 24 28 25 33 NET HYDROCARBON UPPER AND LOWER BARROW SAND ~OUTIHJ ~~RROW roltlbD . NAVAL PETROLEUM RESERVE NO.4, ALASKA c.!. = 10' SCALE 3ogQ' 0' _ _""".. 3000' ~~OO' ~~0~rJ~~'Tk9¡~S H. 1 GRUY & ASSOCIATES, INC, 34 Map 7 ~' I . . t T 23 N T 22 N 4 3 2 9 ~ ISOPACH MAP I #. ~~ 16 tOr-- -- a:: a:: r 21 28 33 3.4 -:rop BASAL UNCONFORMITY SAND TO "TOP UPPER BARROW SAND ";SOUTH ~A~l~OW IF"~~IL.D '':NAVA1. PETROLEUM RESERVE NO.4, ALASKA c.1. = 10' SCALE 'opo'. _ M:PT.fM6ER, 1976 :HOUSTON, TEXAS . 0' 3000' I,,~OO' H. 1 GRUY & ASSOCIATES. INC. Map 8 ~- ~~~"'.....- \ () "1 o u). U) I U, (1) (') ...... ...... o .:J ,tó . I tó I 1 \ ~,~ BASAl UNCONFOR/(dT:V SAN ~'" UPPER BARROW SANQ (UB) ,.,-. LOWER BARROW . '. , SAND (LB) ,... 8 -2000' - - - - - - - - - - - - .. ~ TD 2450' US NAVY SOUTH BAR ROW NO. 9 '* TD 2351' US NAVY SOUTH BAR ROW NO.7 8' ~ TD 2363' US NAVY SOUTH BAR ROW NQ, 6 .. K' . I . . . ~ .. ! o -- 8 o K-2 -2000' K-3 -+-+ J_~.. K-2 K-3 K-, J - 2 K·' J - 3 UB -+ *,10 14 8' STRUCTURE-STRATIGRAPHIC CROSS SECTION SOUTH BARROW FIELD NAVAL PETROLEUM RESERVE NO, 4, ALASKA DATUM -2000' HOVSlON, TEXAS H, J. GRUY & ASSOCIATES, I NC. t¡," . . H.J. GRUY AND ASSOCIATES, INC. APPENDIX A PC' Pr' Tc' and Tr Calculations The pseudo critical properties used to obtain the compressibi- lity factors presented in Figure 4 are based on the specific gravity of the well strea.mof 0.564. Using this specific gravity and Figures 4 and 5 of the NGSMA Gas Data Book, 19.57, results in~ pseudo critical pres- sure of 673 psia and a pseudo critical temperature of 3540 Rankine. The Pseudo reduced pressures (P ) and temperatures (T ) are determined r r by dividing"the observed reservoir pressures and temperatures by these pseudo critical properties. Using these pseudo reduced pressures and temperatures, the compressibility factors presented in Figure 4 are read from the standard compressibility factor chart by Standing and'Katz. Although the compressibility factors based on the specific grav- ity of th,~ gas are different from those ba~ed on the pseudo critical properties of the gas, either set of compr.essibility factors ca.n be used without changing the results or conclusions of the reservoir engineeriD:g study. The reason for this is that although the magnitude of the com- pressibility factors are slightly different, the slopes of the two com- pressibility.curves are the same over the pressure range studied. ~.. I . . t H.J. GRUY AND ASSOCIATES, INC. r- APPENDIX B Recovery Factor Calculations The recovery factor calculated for the South Barrow Gas field is based on a deliverability study. Individual wellhead deliverability curves were plotted on log-log paper for each well to obtain the following deliverability equation: Q = C (Pc - Pw) 1'1 #. where I Q = Producing rate, MCF /Day C = Performance coefficient or intercept on log-log plot 1'1 = Reciprocal of the mathematical slope of the de- liverability curve Pc = Shut in wellhead pres sure P w = Flowing wellhead pressure # In the deliver ability computer program the line pressure or flowing wellhead pressure is specified ~nd the well abandonment rate is sp~cified. Thus, as the reservoir pressure declines, individual wells are shut ·in when they are unable to produce above the abandonment rate. The ultimate recovery and recovery factor is determined when the last well (the well with the highest deliverability) is unable to produce into the line and is shut in. The deliverability study, using a 235 psia line pressure, re- sulted in a reservoir abandonment pres sure of about 265 psia. This gave a recovery factor of 78.8 percent of gas initially in place and an ultimate recovery of 2~. 2 billion cubic feet. , ...,~'-~ I . . I H. J. GRUY AND ASSOCIATES, INC. I APPENDIX C f Water Influx Calculations [ The material balance equation used for the water influx calcu.- lations include rock and water compressibilities as set out below: I G = Gp Bg - We(5.615) (Bg - Bgi) + Bgi.(Pi - P) (SwCw + Cf) l-S w [ It Where ~ I G = Gas initially in place, MMCF Gp = Cumulative gas production, MMCF We = Water influx, millio.n barrels Bgi = Initial volume factqr, cubic' feet/SCF Bg = Volume factor, cubic feet/SCF Pi = Initial reservoir pressure, psia P = Current reservoir pressure, psia Sw = Conp.ate water, fraction Cw = Compressibility of water, vol/vol/psi Cf = Compressibility of formation, volt volt psi ~ . f. I " ¡ 'An example calculation for the last pressure point is as follows: Given G = 32.000 billion cubic fe~t Gp = 9.121 billion cubic feet Pi = 1102 psia P = 857 Zi = ,.839 (From Figure 4) Z =. 870 (Fr01n Figure 4) Bgi = .011218 cubic feet/SCF (Calculated) Bg =.014958 cubic feet/SCF (Calculated) Sw =. 52 Cw = 3.4 x 10-6 vol/vollpsi Cf = 4.0 x 10- 6 volt volt ~si _.j .J :~ j ;j j .;J , 1 .j '.~ j ;j ,~ <'5 I I ¡¡¡ ~ I ~ ~.~~,;'.::-..-g:,::},~;.:::::':1:-:1I . . H.J. GRUY AND ASSOCIATES, INC. APPENDIX C Water Influx Calculations (Continued) 1. To calculate water influx: ,. We = 2.795203 million barrels of water influx. 2. To calculate the gas displaced by the water influx: GDisp. = 2795203 bbls. x 5.615 = 1,049,275,628 SCF t .014958- # 3. With a 24 percent residual gas saturation, each acre foot flooded out would displace approximately 11 L 8 MCF as calculated below: 1546 (857)(.16) (1 - .52 - .24) (.87)(523) . . ..... = Ill. 8 MCF!~F.· ~. ... Therefore: 1,049,276 MCF = 9385 Acre Feet flooded out Ill. 8 MCFjAF Thus, with 108,000 acre feet in the reservoir, approximately 8. 7 percent would have been flooded out. . . A JI tf ¢- ~ ~ * TD 2505' TD 2450' TD 2363' TD 2349' TD 2350' TD 23~ US NAVY US NAVY US NAVY US NAVY -U S NAVY US Nt c SOUTH BARROW NO. 2 SOUTH BARROW NO.9 -SOUTH BARROW NO, 6 SOUTH BARROW NO. 10 SOUTH BAR ROW NO. 11 SOUTH BA R R C It-I 1700- - ~ 1800 - j I » ~ ~ ~ . 2000- RUN 3 -2000' } ~ '2100 - ( ~ - > .2200 - 1t-2 1(-3 ... => o ... u C þo ... .. U .. ~ K-I ~ BASAL UNCONFORMITY ~ SAND IlK)') ! 2300 1 - ...... - u ;;; ... C .. => .., UPPER BARROW SAND ; .:: ____ (UB) i -=-=- 'O....':f~ 'ON' j ~ _ b(~ i -RUNS~_ T -- - - . ? I;-r -3 u Õ S! ~ ... .. ..!!=..- ARGILLIte f]l ift1~'(~ hf~ r r!11 . ~Õ::~::J ~~-==-B \ t~~ ( =-~~~ ? ~.,-=-~ ) 'I' F-= :~' ~ t;:. .-:. ..:..~ 'If I-,¿<:-,~-- E- ~=1.(> .. , - ~ ' .~. ._,:-) ~. -_.~. ;~J . - . .~~ .. . - - - - --- ~ -L, !.. - - ---~ ---~ ! èí +=-., .:: ..' ". ~I-~~+~' f~ : I ~ ;. , 1 ~ ~ . I, . ¡ :: I ~ ; : , _~ ___ _ _ .--- : : \~; -4\' _.:~~- _.:! ",' ~: < J . );: . . '~I: ¡ ;; ~ , ;; . .~~: J ., j' I __~~_ __._._;- ! --~ g -;-- ~ ~ ,L--- '.. g :~, o . ). ¡ I ; t;! 1\ : ~d_' ! ; 1 i' U.: " :--- [ . ; ¡ -~~.~r- --x--. . .--.... ~ ! -~[--.--~ : : ! : /~/~ !. /. I' . , ~ ' _~_I-.._--5"~" 1 )~---i . -- ---:::::r~- It-I Z' - ~ ' -' ~r- - -- ~~ -""K-1-4'"~-: ¡ . ': ". ¡ Š ~ / II I .,,; ! ...:, \ . . / ~), I· ,¡: : : ! i -":',' ...~ 7-, < g i _ _ - § 1;-' ,"---: ,;./ . ~ //. 7-;¿ --'K-2-~'-- ' 1t-2 ~\ ...-// : ' i r -4\',a;-- ._ -- It-I ~j~T +}-~/ ,/~---. --K:¡--~-~--~ 1t-3 : ~ t·~! MI--,.t- . ~ t - ~ 1t-7 t.~ .. ¡ ~ ¡ /1 1. : ~--'--_-.:..- 11.[ v,1. '~. _, r-:-: ~~u: 1t-3 '.l·..... ~ J \ \ . ¡... ¡: ;= - -: ,~=. _n_ , .. _ ~ .j. + I ¡:. i - _.. glt"'~': - _ t-· ¡ J. e I!J ~/I?, ~þ. ~-r~t~!~ . i j. Jrt' t '.. I, A ~;:<l"..: /~ ;-...:z:-:::'i J-3 tit ~ t /.~~~ -,'- _+.L-- i f~ f ., ~ :.~'_~~'_ .:_~._~~:-._-~IUB~ It-' .11~t J ~~ ¡ ; i&S ~ ~·~-i UB ¡ : .- »~.~: :~==~~~ I LB f 'J; '* , _- 2 L ! l BI .... . B~ ·;_.A~! W.,' ' - ---.--' u~.I'·=- ______ _ ~ ~ ~~--~ USB .-41". ~ ~ _____ __ ~.../" ARGILLITE (ESTIMATED) lB . <~11 / / o o . ': ~ -? , ~ , 1 i . :-------+.....".-- +........ ; i , t , , , '~ : , · ,. , . , - - t , : , ; .... , --t o' ,. ! , : , I ; -- · ! t ¡ ¡. _ ~ f I !. ~ ¡ - ~-t-"--.). -..- · . · . ) . ':0> - . ~ ----<: >~-- -- .- ~1 - -- -'- " - I' . - . . ..; i I - ---t/.. ."~ ! - >--1. . . . . _1' '. ! ¡ 1.(<-=---.; _. "'[ NIt-.' . \ . t . . - . ¡ :!: i i . ..~ ¡ _~- . r-'-: : :- 'I~~~.~--·;· . ~ ~.-=- ~ :. :: ~'.', ¡ . "-_ -r-~ . -....-~ ,---Ç~i-'':-=-~~ . I __ ._\.2 t-c ~.' , I - -..... r---.. .. i_....-..s·¡~ . , .,.,- 1_;-~--:2.·F:~-"': ~ ---------- -..-J .' . · . Ë= ;-~= t ~.: -~n ~ 5-:-::::-~. --~-+~. - b~~ '.~. I~ '" +£' -E , 'c~ <!~ ±~~.-t-"l--- :f ~::9. ~ ; :+ -r=r: - - '::f=,'- ¡ j -'-.--+-. -+--¿. ~~~~j. ~ ~~ ~i - ~ .: :=-?l ~ ur-~~' - -Jr.-,j~~~-~~ L .:~Lt +-\--- -. ~BK~ ~ §1· C' :_~_= ~ I .... :t.=~,:=- ~~--=+. '~t UB~._.· ~_=~ s,:'-J ~. --' - ~~,- t ~~. ~ .....~"" LBSS'§~~ ~ ~ _ ¡)t 1:.< .................~ l. }~. - ." "'.:..-). ¡ J ¡.......:.. II..}- " .....:.......:. í ' . "....... ~, . t ¡:{{-"Í '¿' '-." : .: k Tll _. . -!.t: r..r ~~ -' >i ,. ~i "'- ~ '" : ---, ------=. I . ! i ~ ! t..:.··.¡; - I ; Ii: l.: ¡ ,~ i ~ , ~'IC.~ '"1 J-2 · :/ 't=> , ~> : . 1t"1 t -' - ¡ - J ~ c:::: j i , - - ·1- I ..;- - ( I Ii . 'C: I :.. :~. - t - ¡ g \ >~--, I I I · (' I I '-; I ~ :,I.'j' '! I "~>' :. . . ~,..., :C~.I .-...;: : ~ I 1t-2 I).;..: '. I 1l: : :~'- i " :"¡ I', ~I 1t;3 d='":N ; S I o : ¡ ; ! , i.......... i I : ,- :: ¡. .............¡ ;,[i:';;I· I ~ ~: ì ~; J- - - ¡ . «' I ! K-' . .. ~ ¡..¿ ;l:. ;. :. ~j. ~:..' ~. L.. ..~, . ........--.\ ....) ! ; ~ ': ~ f~1 ; ;' ; ¡ ¡~ ! r:-B . : I ! .,' I I ~ ! ~T~ ~ I'· I ' I J-3 i - '. ~. ¡~: :.' : ¡ .~.;.. J-¡-¡: ua ,\ ;~, ,~- .-' ¡' 7 J.í"" I",·~::~·· J-2 LB r-..'. . " ~ -~(F J~3;·~ ~.~ ~ & - I It-t ~ I ~ g Ie K-2 !i 1t-3 f¡ !I Ii , I õ I o I I I I t ¡ '- : ~ i g ! š UB 1& - ~ '"\...-.--.. ......--.-.. . * TD 2363' US NAVY SOUTH BARROW NO.8 -, ,-15 . _ I > -- --¡ 0 . .-::;:'. : ': 13 i c.. j I I J ..-. - .---~ -'I I .. --~ ~ K-3 rtH-:i:.::: .. . - ..-,. ,. .' --. . t_ .. "..... . . .... I . - g ~ 11 A' I. 4 . 'fI, 25 A ~. / T* IOq~ll./ ~2000' .3 o . A' 12 13 24 ~ ~ ~ -"'" ~ ~ ---- ---...- ARGILLITE (ESTIMATED) STRUCTURE-ST~ATIGRAPHIC CROSS SECTION SOUTH BARROW FIELD NAVAL PETROLEUM RESERVE NO.4, ALASKA DATUM: -2000' HOUSTON,TEXAS H. J. GRUY & ASSOCIATES, I NC. :23 ,.. . ..... ~ Cross, section A- A' . . TABLE 12í HISTORICAL PROPU~I~~ !!)ATA SOUTH BARROW G~J1~D NAVAL PETROLEUM Ri¡j¡¡þ-ø; NO. ~ ALASKA NC H.J. GRUY AND ASSOCIATES To\al F,eld Production No, II Flowing Press ure (Casing) PSIG We! 10 flowing Press Ul'e (Casingl PSlG No Wel No.9 Flowing Pressure (Casing) PSlC Wel No.8 l "'Fl;;wing Pressure (C.sing) PSlG We 7 Flowing Preesu'r,o (Casing) PSlC No Wel No, 6 Flowing Pressure (Casing) PSlC We! No.5 Flowing Pressure (Casing) PSIC We! No. ~ Flowing Pressure (Casing) PSIG Wel v. 28, 177 14l,·S&O 17S.12'1 411,&1>'1 497. S'I2 ~Z8. 72 1 61¿,2&& 715,728 829,83Z 944.86¿ 077,486 ZSO, 97Z 4Z3.409 620, 143 830,89\ 079,844 Tufa Cumu!" I. I, I. I, I, 2, 28. In(e) 1I4,383(el 132.569 136,540 8S,923 31, ¡¿9fe) 83,545(e) 103,462(e) 114.104Ie) 115;030Ie) H2, &24Ie) 173,486Ie) 112.4H(e) 196,734Ie) 210. 7481e) 248,953 Producuan MCF Production MCF 0\ Productit:m MCF Prqduction MCF Production MCF Pr"d~ction MCF N.A. N.A. N.A. N.A. N.A. N.A. N,A. N.A. N.A. N.A. Production MCF 48,052(e) 82. 7941e) 91. illle) 92,0521e) 106,l3l(e) 138, 830(e) 137, 9911e) 157,4341e) 168,6491e) 135,431 N.A. N.A. N.A. N.A. N.A. N.A. N.A. N.A. N.A. N.A. N.A. N.A. N.A, N.A. Production MCF 69,930 132.569 136. 540 85,923 31,1291e) 35. 4931e) 20,6681e) 22,793(e) 22. 978(e) 26,493(e) 34. 6561e) 34, 4461 e) 39.300Ie) 42. 0991e) Well No. 2 Flowing Pressure Pr-oc:1uction (Casing) ~ PSIG 28,1771e N.A. 44,453(e N.A. ,. 1949 1950 1951 1952 1953 1954 1955 1956 1957 J958 1959 1960 1961 1962 196' 1964 2, 116,044 2,150,664 2. 188,8&5 2, ZlJ. 757 2.255,050 Z, 280. 241 Z.30Z,860 2, 3Z7, OIl Z,354.7f.9 Z,3'10,Z06 2.424,436 2,468.6'10 36,200 34.620 38,201 34.892 31.293 25, I'll ZZ,619 24.152 27.757 35.437 34,230 44,254 388.846 , 4 t" N.A, N.A, 950 950 955 955 960 960 960 960 950 ·950 935 522. 25.653 22,565 20,3&3 19,880 17,024 16.785 13.933 15,459 17,391 23. 005 22;202 27, 181 241.441 lJ3 N.A. 965 960 960 960 9&0 960 9&0 960 950 955 950 10.547 12,055 17,838 15,012 14.269 8,406 8,686 8,693 10.366 12,432 12,028 17,073 m:m 4 1/65 2/65 3/65 4/65 5/65 6/65 7/65 8/65 9/65 íO/65 11165 U/65 Total 2.515.442 2.557,685 2, &04, & 17 2,644,.05 2.1>76,404 2.701,030 2,726,070 2.753,396 2.782.289 2.818,309 2.860.045 2.906,202 46.752 42.243 41>,932 39.988 31,799 24.626 25.040 27.326 28,893 36,020 41,736 46.157 mm 935 935 935 950 950 950 955 950 955 945 925 935 28.067 27,659 30,788 25,560 19.688 16, 221 IS, 734 18,020 18,387 22.994 29,123 32,813 ~ 945 950 945 956 955 960 960 955 960 950 90 945 18,685 14,584 16,144 14.428 12, III 8,405 9.306 9,306 10,506 13,021> 12,613 13,344 EI';"ill 1/66 2/66 3/66 4/66 S/1>6 ,6/66 1/66 ~/66 9/66 10/66 11/66 lZ/66 Total T a l;\'~~~:~;i 3 o e g }::>O1 952.905 9'1&. 7H' OH,II48 084,090; 119,'11'> 148.514 17b,O~O 206.418 ~H, Qlb ~nO.:fl J¿9,,>Q8 lli-l. I.., ",4 2, 2. 3. J.. J. 3, 3, J. I, j, ], ,', 46,703 43.819 U,124 40.247 35,8¿0 211,599. 27,536 30.368 3],518 40.105 49.3Q ~1.I)~~J ~ 930 925 925 945 945 945 945 940 935 930 920 920 33,206 30,366 32,230 26,741 26,514 18,093 16.680 19,185 23,005 26,404 33, &01 38,030 324.055 945 945 945 945 945 .950 950 945 945 945 935 940 13,497 13,453 J4,894 13,506 9,306 10,506 10,856 11,183 10,513 13.901 15.756 13.956 ST."ffi 1/67 2/67 3/67 4/67 5/67 6/67 7/67 8/67 9/67 10/67 11/67 12/67 'Iotal · H.~..GRUY AND AS. TABLE 12 HISTORICAL PROnucnoll ÐATA SOUTH BARROW C"; FJJ:1.D NA V AL PETROLEUM RS¡¡¡aV-E NO. .. ALASKA NC ATES 'otal Field P roduc lIon No. II Flowing Pr~lis Ul'e (C.. , I1(tI PSIC We. No. 10 nowang Pres.ur~ ICa"inll) PSIG We No.9 FloWll1(t Pressure (Cuinl) PSIG Wel "W..n No. 8 Flowing Pre.sure (Cuing) PSlG 7 -.flowing Pressure (Casing) ~ No , W.I 6 -Flowin¡ Pressure ICasing) PSIG No Wel No.5 -F lowing Pre. sure (Cuing) PSIG W..I No.4 Flowing PreSJure (Cuing) PSlC Wel No.2 -Flowing Pressu.re (Cuing) PSlG Wel Tota Cumut.hve 3.435,304 3.490.227 3,543.048 3.591,250 3.629,898 3,661,558 3.692,502 3, 722.779 3.752.928 3,787.83 I 3.;833.219 3.885.308 53, 720 54.923 52,821 48,202 38,648 31.660 30,944 30.277 30. H9 34,903 45.388 52,089 šõf,""ñ4 Production MCr Production MCF <II PrOduction MCF ·...~'èuction cMCF 870 N,A. 665 665 830 835 830 815 Production MCF 640 11,682 22,276 13.720 16.506 11.496 12.406 12.410 101,136 905 905 915 920 940 N.A, 950 940 945 935 920 915 Production _MC' 36,974 38,967 37,215 34, 396 2+,609 13, 042 5,984 11,908 6,237 13,011 18,876 23.398 264,617 935 935 935 930 940 N.A. 945 945 945 940 935 930 Production MCF 16,746 15.956 15.606 13.806 13.399 6.936 Z.684 4,649 7.406 10,396 14, 106 16.281 m:97ï Production MCF <It P"oÒ1lC:tion 'MCF 1/6'8 2/68 3/68 ./U 5/68 6/68 7/68 8/68 9/68 "10/61 1l/68 n/68 '~ota 1 3,944.251 4,GOO,535 4,060,458 4,110,241 4,152, 143 4.185,382 4. ZZO, 511 4.Z57.424 4,291. ZZ3 4,344,925 4.404.049 4.41>6,870 58.943 56.284 59. 923 49,783 41.902 33,239 35.129 31>.913 39,799 47.702 59,124 62.821 šãT;'š6z .. 870 880 880 800 870 700 1,933 3,1199 4.U7 3.·893 3;-:446 ·<4;504 -18,754 .21;704 ',(,2.170 , j , 825 840 840 840 850 865 875 880 875 10,855 9.112 9,312 9.606 5,727 4.052 Z,657 3,651 3.936 3.255 4 4 62.171 905 910 900 910 920 930 925 925 920 31.032 31,206 33,493 23,1>11 20,281> 14,253 15,622 16,768 19.148 24,821 27,592 31,027 288,859 925 920 '120 915 935 925 925 925 920 915 17.056 15,966 17, 118 16.566 13,956 11,83S 12.013 12.601 13,269 IS, 122 12.774 10.086 168.362 ì 4! 1/69 2/69 3/69 4/69 -5/69 -6/69 7/69 8/69 '1/69 10/69 '11/69 '12/69 'Total 4.530.201 4.584.254 4.650. 811 4,711.414 4.761.430 4.801.344 4,831>,028 4.875.965 4.922.191 4,980.258 5.031,127 5.084.632 63.331 54,053 66.557 60,603 50,016 39.914 34,684 39,937 46,226 58,067 50.869 53.505 617.762 - 885 870 880 870 860 3.317 13. 505 - 3.440 4. '905 5.8691..) 8. 505(e) 39.541 r 685 675 790 S20 810 860 860 ~1. '09 '19,60'1 ·21.709 'U,505 t-17 ,~25 êlO,625 - J,1I96 '10.906 '10..0001") 10,·000(e) --m:1ii - 945 805 BID 870 860 9 5 4 o 7.139 9.213 9.109 11.252 10.000(e' 10,000(. 56. 731 - 885 885 890 - 915 880 880 875 860 31,527 25,328 34,752 31.896 23.500 15,784 16,774 20,205 22.508 25.280 25.000(e) 25.000(..) 297,554 900 875 820 850 860 10,086 9. III 10.092 9,202 5,974 10,771 10.519 9,273 5,724 - ãõ,""ffi 1/70 2/70 ;3/70 4170 '5/70 -6/70 7/70 '8/70 9/70 10/70 -11/70 U/70 Total 5, 151.097 5,213,641 5,279,782 5,337,270 5,383.285 5,420.303 5.455.518 5,493,461> 5,532,684 5.585,436 5,646,047 5. 711.335 66.465 62.544 66:141 57.488 46,015 37,018 35.-215 37, '148 3'1,218 52.752 60,611 65,288 i'Z6."7õ3 855 860 870 880 '880 880 880 875 865 880 855 860 19. 465(e) 18. Oil 18,297 16,203 17,229 11. 738 10. 536 13,829 14,199 J8.229 19.375 17.976 ï95,õi7 800 780 780 785 840 840 845 840 840 785 740 740 ;.to.500Ie) -9.1I~ 10.734 9.757 4.747 3.871 4,809 4,659 4.504 .6.124 10,387 ; 13.809 >"93,709 800 780 780 780 840 840 845 840 840 785 740 740 10, 500(~) 9,810 10.741 9.760 4.753 3.872 4.811 4.655 4,507 6,127 10.392 13,821 93.749 855 860 865 880 880 885 885 875 875 870 860 860 26.000(e) 24,904 26.358 21.763 19.286 15.7'14 15.059 14.805 16,008 22.266 20,440 18.698 Z"4ï;3'81 - 11 11 5 - 1,743 6 17 984 2,777 - 3/71 2/71 3/71 '4/71 !>1?1 6/71 7/71 8/71 9/71 10/71 11/71 12/71 Total 12 3 Table Page 2 of 5.780,349 5.846,420 5, '117. 61'1 5, 978. 53'1 6,1131,844 6.073, 766 6,110,807 6,150,421 6,198.131 6,252,562 1>.318,356 6,386,208 69,014 66,071 71.199 1>0,'120 53,305 41.922 37,041 39,614 47,710 ~4, 431 6~, 794 ~ 614,813 855 855 850 855 845 860 860 860 84~ 850 855 840 20,447 18.619 19, 708 16.47f, 14, 192 12.348 10. 895 12. 130 14, 309 18,509 18. 842 18.650 m:m I 720 745 720 780 800 810 830 830 820 805 740 740 13.031 12. 598 H.705 9.475 -S.I!>9 .... 85~ 3.574 3,568 4,504 4.673 9,!i39 '.t51 ·~.èju no 74~ no 785 800 810 830 830 820 80S 740 740 13.041> 12.602 11. 709 9,477 ., 163 4,852 3,575 3.571 4,505 4,677 9.541 9,252 94, '170 850 860 860 865 860 870 870 870 860 850 855 845 19,474 17" 392 21.504 18.230 16, 052 13.450 11.985 13, 394 17,478 19,222 18,842 18,651 205.674 '00 800 815 825 835 835 835 835 835 .835 850 850 3.016 4.860 6.573 7,264 6,739 6,421 .7,012 6,951 6,914 7.350 9.030 12,048 84, 178 9 1172 2/72 3/72 4/71. '5/71 6/72 7/72 8/72 9/72 10/72 11172 11./ 72 . . TABJ;o~Rj IDSTORJCAL PR'i':IcDI:rC~' . . DATA SOUTH BARR~ G n$:LD '-NAVAL P£TROLEtr~R.. YENO. ALASKA , NC H. J._ GRUY AND ASSOCIATES 10tal Fit'ld Produc.; No. II T1QW1ng Pres 5 ure ICasing) PSIG w" No. 10 Flowing Pressure CCasing) PSIG el No.9 Flowing Pressure CCasing) PSIG Wel Total Cumulative I>.~59. 150 6. 521.~58 6.605,~30 6.,669.011 6.122.1>18 6. 166. 8ll 6,809. 186 6,854,222 6.899,838 6.955,659 1,019,009 1.091.578 Ion 13,54l 67.108 77, 912 61.641 53,541 44.204 42,364 45,031> 45.1>11> 55.821 63,350 7Z,569 "7õ'W7õ Production MCF 845 860 855 850 840 825 825 Production MCF .6.65Z 2..358 4,913 7,889 8.944 U,915 15.701 19.026 77;4õ4 835 845 845 835 850 850 855 ~84O 830 830 Production MCF 19.IZ6 17,l90 11,81>9 17,389 13.811 J2,555 9,171 9.261 8.961 13. 166 13. 954 16.402 m:öZï No, 8 T lowing Pressure (Casing) ~ 735 740 140 170 BI5 8Z5 B25 BZO 800 800 ~ We!' No.7 F l;.w~ng Preø~ut~ (Casing) PSlG We 1 No.6 Flowing Pressure ICasing) PSIG We No.5 Flowi'ft¡ Pressure (Casing) PSlG Wel 4 Flowing Pressure (Casing) PSIG No Wel No.2 Flowing Pressure (Casing) PSlG We! Production MC' 10, U8 .JO,007 11. 168 6.674 5.06Z 4.017 811 ~.918 3.304 3.417 5;317 -5,649 "6ã."š9z 735 7"'0 740 170 8.10 800 8oZ5 SZ5 SZO 800 8DO Production MCr 10.127 10,011 11.171 6.676 5,064 4,018 3,032 Z,918 .3.304 3.423 5.3"74 5,651 70, 769 835 845 855 850 840 845 8S5 8S5 855 840 830 830 Production MC' 19, 127 17,289 22,120 18.345 13.669 lZ,555 lZ, 40 1 9.265 8.968 13. 162 13,957 16,402 171, 860 850 850 lI50 850 850 850 850 850 850 850 850 850 P'f'oductiol"l MC!' 15,034 -13, Jll 15.044 14,557 9,229 "&,701 11.976 J2,78Š n, 129 10,738 8,981 9,439 141,724 Production MC!' " Production MCF 1/73 Z/73 3/73 4/73 5/73 &/73 1/73 8/73 9/73 10/73 11/73 Il/71 Total 1.166.741 7, UI. 172 7,319,333 7,389,4Z0 7,448,023 7,494.044 7.536.229 7.579.102 7.629,598 7.100,431 7,775,318 7.856,451 75.163 74,431 78,161 70.061 58.603 46,021 42,18Š 42.873 50,496 rO,839 14,881 81,131 164,813 815 8Z0 8Z0 835 840 835 835 830 805 800 790 18.839 18,768 17.306 16,424 11.582 8.888 8.953 9.895 10.974 17.943 22,626 23,065 185.263 830 8Z0 820 8Z5 835 835 835 830 810 800 790 16, Z36 16, 362 17,64J 15, 878 14, 826 9,848 10.068 10. Z45 11.194 15.871 15.881 16.61Z ï7G."m 760 740 775 800 80S 805 805 790 745 760 ,no 7.207 7. Z30 8,098 7,153 5.587 4,217 3,355 '3,355 5,343 .,6,9Z4 ',.,568 7.682 :72,719 760 740 760 800 80S B05 805 795 745 760 725 7.209 7,233 8.098 6.850 5.589 4.220 3,358 3.359 5.345 4,927 4.577 7.689 72.454 830 825 8Z5 830 840 840 840 830- 820 800 795 16.236 J6,362 17,!.4Z 16,028 15,471 9.880 10.Z14 10. 772 n.664 17,964 17. 951 19,136 180. U2 850 840 - 845 830 845 845 835 835 830 1IZ0 9,436 8,476 '1.376 7.754 5,548 8.968 6,237 5.247 '4."976 ..5,210 5,278 ".947 i3.45i ,. # 1/74 2/74 3/74 4/74 5/74 6/74 7/74 8/74 '1/74 10/74 11/14 r 12/74 Total 7.941,253 8,014,7Z1 8.091.683 8. 161. 2Z6 8.Z23,065 8.269.780 8,115.496 8.364.805 '.419.705 8,489.659 8,569.314 8,655.991 86,802 71,468 16,962 69,543 61.819 46,115 45,716 4',309 54.900 69.954 19,655 86,677 mm 790 800 800 800 760 745 740 740 2.686 3.605 3,138 6.174 6.360 8,680 9.580 10.838 51,661 800 795 795 800 810 820 820 805 80S 795 795 785 21. 129 18. 132 1'1,42.7 14,838 J6,449 9.105 ".808 9.090 10.800 12.958 15.335 16.'08 'i7õ';'i79 790 795 795 795 800 ,805 800 800 800 795 785 780 19.9l6 1",018 16,701 11,768 13. 184 11.704 12.095 9.090 10.800 12,958 15.335 16. 808 Tñ;1i7 710 740 140 740 790 800 800 800 760 740 740 740 ''""9,121 '°6.891 7.696 "'.211 "'5.525 , '3,603 3.727 ,,6.171 6.351 <,8,671 '9.-574 <:1-0, 026 ..3.580 725 715 740 740 785 800 800 800 760 740 740 740 9,125 6. 'lO9 '7.692 4.220 5.527 3;605 3,733 6.173 6,360 8.674 9.575 10,029 83.622 800 800 800 795 800 80S 800 800 800 795 795 780 20,559 17,231 18.484 17.768 13.369 .11.704 12.095 9,091 10.801 12,958 15.3.35 16,808 176.203 820 82.0 820 820 820 830 830 830 830 815 815 815 ..942 6,in /('.96Z ·...7.32 5.099 3.389 3,520 3.520 3.4ZZ 5.054 4.921 5,360 6ï.Zõi 1/75 2/75 3'75 4/75 5/75 "'75 7/75 '/75 9/75 10175 11175 12/75 Total 8.740,507 8. 8Z5. 677 8, '113, 113 8, 989. 072 9. 055, 766 9,099.548 84.516 85. 170 87,696 75.699 66.694 43,782. 730 725 7Z5 130 745 160 ',774 9,558 9,682 8,257 6,257 3.053 775 755 765 785 790 785 16.702 17.275 11.885 lS.165 14,312 JO.038 775 755 765 780 790 785 16. 10Z J 7,275 17.885 15,365 14,1J2 10,038 730 725 7Z5 730 745 760 ''"I.7n ;'9,556 ~.fa79 ... Z54 il6. 254 13.051 130 725 725 730 74!> 760 9.775 9.558 9,682 8,257 6,256 3.053 775 760 no 785 790 785 16.702 11.275 17.885 15. 365 14,312 10.038 815 800 800 800 800 795 -5,08'1 4.673 '4.998 4.836 ·4.991 '4,511 1/76 2/76 3/76 4116 5/76 6/76 ~ ~ 1,031,398 ~ C,.aød Totals 12 Page 3 of. 3 Tab Ie 119 2.888, z~ 399. 388 ~ ~. I I I I I I I I , . I. I I i . H..J. GRUY AND ASSOC1ATES, INC. . .ð- .'" - .. · . · . · ¡ ..- ... ~-- -- .- "lID ~ ..,. -- - 1-- "J- -- -- - -- -- ~- ¡.- -- I I - - - '"" - · 7 J\ . it. ! - - , " - ¡;-r . , ....... .- .-.... r-'\ I Y A \ I · V\ \ I · ~ M I \ \t> ¡( \) V \I .^ J J i J V ¡¡y v "PI I I J , · ;. \ I \1 V 1\. V a J 2 . \ I # r-- - I' . V At:. 1001 1 'n iet" - . I . ~ 10 . · ~ . · .-- , · I · c · a · L.....-. a 2 LEGEND III e._rir ....-.. " , · '. . I 7 , . d fIGURE 6' -I 'i .. HISTORY OF PERFORMANCE . -, ... 2 .. AND Ii .. ~ . BASIS FOR ÉSTlMATE OF FUTURE DEMAND ~. 7 t "'" .. -' . "": f u - SOUTH BARROW GAS SAND 0 Ii . " II " c .. -. "i; -¡ 'i -: ò -: .. .. -¡ SOUTH BARROW FielD - . .. J .. -: ! ." -: NAVAL PETROLEUM RESERVE NO, 4, ALASKA t ~ ~ -: ~ a Ã SfPTEMIER, 197.6 H. 1 GRUY.& ASSOCIATES,INC. -2 c Ã f « .. IL .. IL HOUSTON, TEXAS 1 I I ~ , , E , 0 0 0 0 0 0 v v V L U V ...' V , I I , I . .... 1950 1951 1952 1953 1954 1955 1956 1957 1958 1959 1960 1961 1962 1963 1964 rm 1973 , 1949 19M 1966 1967 1968 1969 1970 1972 1974 1975 1976 1~77 1978 1979 1980 1981 1982. 1983 1984 1985 1986 1987 1988 1989 1990 1991 1992 1993 - - ! 1-1 ..I ..~ l~ ¡ ~ ,'- .~~ 11 Figure 6 . . ENGINEERING STUDY SOUTH BARROW GAS FIELD NAVAL PETROLEUM RESERVE NO.4 BARROW, ALASKA INDEX Page Number LETTER. . . . . 1 INTRODUCTION, .. CÞ .. .. 41 .. .. . 2 CONCLUSIONS , 2 RECOMMENDATIONS 3 DISCUSSION Location """ ".". Topography . , . . .. ..,... History of Development and Operations. Drilling and Completion Practices. Geo logy, . . , , . , . , , Reservoir Characteristics. Gas Analysis , , . , , Method of Operation. . Reservoir Performance. Gas in Place , . . . . Future Gas Demand and Productivity 4 4 4 8 8 11 12 12 13 16 19 SCHEDULES Summary of Basic Reservoir Data and Possible Volumes of Gas in Place, Productive Areas and Reserves. 1 Past Production and Predicted Demand (MCF/Day) 2 Pressure-Cumulative Recovery Relationships . , 3 Anticipated Productive Capacities - Wells Nos. 5 and 6 4 Geologic Data (Determined by Electric Log Analyses) . 5 Core Analyses. 6 Gas Analyses . 7 Individual Well Performance Data 8 Individual Well Completion Data. 9 . INDEX (Continued) MAPS Location Map. . . . . Line of Cross-Section Structure Map - Top of Jurassic Gas Transmission System . . . . PLATES Performance History - Total Gas Production. Performance History - Well No. 5. Performance History - Well No. 6. Performance History - Well No. 7. Performance History - Well No.8. BHPjl versus Cumulative Recovery. . Number 1 2 3 4 Number 1 2 3 4 5 . . 6 Flowing Tubing Pressure jl versus Cumulative Recovery Four Point Back Pressure Test - Well No.6. Cross Section A-A'. . . . . , . . . . . . . NATURAL GAS PLANT OPERATOR'S MANUAL 7 8 9 . . LEE KEELING AND ASSOCIATES PETROLEUM CONSULTANTS PHILTOWER BUILOING TULSA, OKLAHOMA 74103 (818) 587-5521 November 29, 1969 Department of the Navy Naval Petroleum and Oil Shale Reserves Washington, D. C. 20360 Attention: Emory C. Smith Captain, JAGC, USN Director Re: ENGINEERING STUDY Souto Barrow Gas Field Naval Petroleum Reserve No.4 Barrow, Alaska Gentlemen: Pursuant to your request, we have reviewed the performance of the South Barrow Gas Field. During the course of this investigation we have attempted to summarize as much data as possible into this report, including the oper- ator's manual for the gas plant, transmission lines and gas wells. The exact size of the gas field cannot be determined without additional drilling; therefore, we have estimated gas reserves ranging from 13,200,000 MCF to 20,200,000 MCF as of September 1, 1969. Actual reserves can be con- firmed once the reservoir is delineated. Information was obtained from files of the Naval Petroleum and Oil Shale Reserves, operating offices of the Naval Arctic Research Laboratory, Barrow, Alaska, Holmes and Narver, operator of the camp and field, and published in- formation. One of our representatives visited the gas field and transmission facilities accompanied by the field and plant foreman. Basic information has been summarized on various schedules which are listed on an accompanying index. Maps and Plates have been included to il- lustrate development of the field and related performance. We appreciate this opportunity to be of service. Yours very truly, LEE KEELING AND ASSOCIATES ~,q. ~~¿. . L..ee A·AKe,~n~ l c2/l/Ít C / (¡~'¡VÎy Kenneth Renber~ j/ /~/7~ /,/(~,--,~J ~~-&rLJL , Gordon L. Romine . . 2 ENGINEERING STUDY SOUTH BARROW GAS FIELD NAVAL PETROLEUM RESERVE NO.4 BARROW. ALASKA INTRODUCTION Lee Keeling and Associates were retained to review the performance of the South Barrow Gas Field. The purpose of the review was to: 1. Determine the volume of gas originally in place and remaining r~serves. 2. Determine the ability of the current gas wells to satisfy future demand requirements. 3. Recommend a location for an additional development well. (Submitted by letter dated October 9, 1969.) CONCLUSIONS 1. The quantity of reliable information available at the present time is insufficient to permit an accurate determination of gas in place or recoverable gas reserves; however, we have estimated a range of re- serves which are summarized as follows: Estimated Gas (MCF) Volume Originally in Place Recoverable Remaining Reserves at 9~1-69 Minimum 25,000,000 17,500,000 13,242,576 Maximum 35,000,000 24,500,000 20,242,576 2. Development to date has only partially defined the productive area. The size of the reservoir is estimated to be between 1,100 and 1,540 acres. 3. A depletion type drive appears to be the producing mechanism in the . . 3 South Barrow gas reservoir. 4. Demand for gas in the Barrow area has increased at an average annual rate of six to eight per cent. 5. Present wells will satisfy the demand for gas for a period of approxi- mately ten years, provided the demand increases at a constant rate of not more than ten per cent per year (based on minimum reserves) . RECOMMENDATIONS 1. Drill an additional well (No.9) at the location shown on Map No.2 to provide a standby well to meet maximum demand and to aid in defining the limits of the field. 2. Give consideration to increasing productive capacity of wells Nos. 7 and 8 with stimulation treatments. 3. Resume exploratory activities in Naval Petroleum Reserve No.4 to de- velop an alternate or supplementary fuel supply. 4. Test potential cased-off Cretaceous gas sands prior to abandonment of the existing wells. . . 4 DISCUSSION LOCATION The South Barrow Gas Field is located approximately four miles south- east of the Eskimo village of Barrow, Alaska, and about five miles south of Point Barrow, the northernmost point in the State. The general location of the South Barrow Gas Field is shown on Map No.1, a map of the State of Alaska. Map No.4 is a map of the South Barrow area and reflects the loca- tion of the field with respect to the village and Point Barrow. TOPOGRAPHY The South Barrow Gas Field is located on the Arctic Coastal Plain. The surface exhibits little relief and is characterized by swampy, lake- dotted tundra. With exception of the top few inches which thaw during the summer months, the ground is permanently frozen (perma-frost) to a depth in excess of 600 feet. HISTORY OF DEVELOPMENT AND OPERATIONS Initial Core Tests In 1944 a Naval Construction Battalion detachment established a camp on the beach between Point Barrow and the village of Barrow and drilled three shallow core testS. These tests were drilled primarily to (1) be- come familiar with drilling operations in an Arctic area and (2) test the drilling equipment that had been provided for that area. Two other core tests were drilled in the Barrow area during the next three years. Discovery of South Barrow Gas Field A gravity survey in 1946 showed that a small area south of the camp had the highest observed gravity in the Arctic Coastal Plain. A seismic refraction profile shot in 1948 revealed that strata encountered at a . . 5 depth of 6,700 feet in the Simpson Test No.1 (35 miles southeast of Barrow) apparently rose to 2,400 feet just south of Point Barrow. This work sub- stantiated the presence of the structural high indicated by the gravity survey. During the next twelve months three tests were drilled on the struc- ture. These were designated South Barrow Tests Nos. 1, 2 and 3. No.1 was located near Barrow camp and No.2 about four miles southeast of No.1. The third test was drilled about seven miles south of No.2. All ventures were drilled to depths sufficient to test the basement rocks. Nos. 1 and 3 resulted in dry holes, but South Barrow Test No.2 was the discovery well of the South Barrow Gas Field. The discovery well was drilled to a total depth of 2,505 feet and com- pleted in Middle-Jurassic and Pre-Mesozoic zones in April 1949. Initial flow tests indicated that the well produced approximately 500 MCF of gas per day at a flowing tubing pressure of 1,020 PSIG. Multi-point back pres- sure tests were not used to determine the open flow potential. Subsequent Development Shortly after completion of Test No.2, certain facilities at Barrow camp were converted from fuel oil to gas, and the well produced gas through- out the remainder of that year. In the spring of 1950 a standby well was spudded approximately 447 feet north, 28 degrees east of South Barrow No. 2. This well, South Barrow No.4, was drilled to a total depth of 2,538 feet and also completed in Jurassic and Pre-Mesozoic beds. The well pro- duced gas at the rate of 1,805 MCF per day. About the time the No.4 well was being completed in April 1950, sur- face installations at well No.2 were destroyed by fire. The fire occurred as preparations were being made to investigate a possible leak in the 7-inch . . 6 casing. After the well was killed with mud, an impression block revealed the collapse of the 7-inch casing, apparently by action of the perma-frost. The well, which produced approximately 65,000 MCF of gas, has remained in- active since that time, although it actually has never been plugged. South Barrow No.4 supplied gas to Barrow camp until September 1953, when the well was shut in because of saltwater production. Within six months the well was returned to active status and was produced until the completion of South Barrow No.6 in 1964 permitted the operator to shut it in permanently. It was plugged and abandoned in 1968. South Barrow No.5 was drilled as a replacement, or standby, for No. 4 in the spring of 1955 between wells Nos. 2 and 4. It was not drilled quite so deep as the two offsets and was completed only in the Jurassic. Production tests of No. 5 revealed its productive capacity to be comparable to that of No.4. This well is essentially water-free; however, it did produce approximately one barrel of water per day when well No.4 was on stream. South Barrow Nos. 6, 7 and 8 were drilled in 1964, 1968 and 1969, re- spectively, to satisfy the increasing gas demand. All three wells were bottomed in the Jurassic to avoid the water problems that were encountered in South Barrow No.4. No.6 has proved to be the most productive well in the field and currently supplies over 50 per cent of the total demand. Performance of the individual wells will be discussed subsequently. Completion data for all gas wells have been summarized on Schedule 9. Development in the field is shown on Maps Nos. 2 and 3. Gas Production and Demand Gas from South Barrow No.2 was used in Barrow camp for space heating almost immediately after the well's completion. Daily production from No. . . 7 2 reached a maximum of about 300 MCF in March 1950, the month before the well was lost. Production between the time of the loss of No.2 and the completion of No.5 in 1955 was erratic, primarily because of the water problem in the only producing well, South Barrow No.4. The completion of South Barrow No.5 assured a more constant supply of gas, and more facilities were connected to the gas system. Average daily production increased from approximately 300 MCF to about 600 MCF in 1963. This continually increasing demand led to the drilling of wells Nos. 6, 7 and 8. Daily production during the year 1968 averaged 1,511 MCF of gas. Available production data indicate that the daily average during 1969 will approach 1,650 MCF. A review of production and demand during recent years shows an average increase of six to eight per cent per year. During certain periods the in- crease was considerably higher because of the addition of new facilities to the system. Facilities currently connected to the distribution system include all governmental agencies in the Barrow area, as well as civilian consumers in the villages of Barrow and Browerville. All connected facilities are fitted for conversion to fuel oil, as an alternate, should the gas supply fail. Demand varies considerably with the different seasons. The fluctua- tions are illustrated by Schedule 2 which shows daily average production by quarters from 1955 to the present. This same information is shown graphically on Plate 1. It will be noted that the peak demand occurs during the first quarter of each year and is about 120 per cent of the annual daily average. Demand during the third quarter declines to about two-thirds of the annual daily average. Actual maximum daily rates during each first quarter are higher than . . 8 the daily averages shown on Schedule 2. Peak daily production rates usu- ally average approximately 125 per cent of the first quarter daily average, or 150 per cent of the annual daily average. Monthly gas production from each well and total field production since 1964 are presented on Schedule 8/ Also shown on Sthedu1e 8 are flowing tubing and casing pressures, as reflected in the monthly operations report. This information is shown graphically on Plates 1 through 5. DRILLING AND COMPLETION PRACTICES All wells in the field have been drilled with rotary drilling equip- ment owned by the Navy and operated by civilian contractors. The drilling operations were not entirely self-contained because of the proximity of the Barrow camp. Support personnel and services were obtained from the camp as needed. Drilling crews lived and boarded, with the exception of mid-tour meals, at the camp. Intermediate casing strings were installed in all wells to a depth of 900 to 1,000 feet and cemented to the surface. The long string, or produc- tion string, was set at a point above the producing zone and cemented. A pre-perforated, or slotted, liner five or five and one-half inches in diam- eter was hung from that point to total depth, Liners were not cemented. None of the wells have been acidized or fracture treated. GEOLeGY General As stated previously, basement rocks rise higher in the Barrow area than other areas in northern Alaska, and the area has been geologically designated the Barrow Arch. This arch separates the Arctic Coastal Plain to the east from the Chukchi Basin to the west. South of the Barrow Arch is the Colville Geosyncline and beyond that . . 9 the Brooks Range Geantic1ine. The latter marks the southern limits of the area referred to as North Alaska. The Arctic Ocean and a geologic province known as the Arctic Platform border the subject area to the north. In other parts of northern Alaska several thousand feet of Cretaceous and younger sediments are present above the basement complex; however, in the South Barrow area the sedimentary section has an approximate thickness of only 2,500 feet. Middle-Jurassic beds overlie unconformably the Pre- Mesozoic basement complex. Triassic rocks, present in South Barrow Test No.3 seven miles south of the field, are absent in the field area. The basement complex contains an unknown thickness of Pre-Mesozoic sediments. Producing Zones Three zones, including the lowest Cretaceous sand, the Jurassic and the Pre-Mesozoic, are open to production in the South Barrow Gas Field; however, it is believed that gas production is obtained almost exclusively from Jurassic rocks. The zones are shown on Plate 9, a cross-section based on electric logs. The lowest Cretaceous sand and the Jurassic have been opened in every well. The single known test including only the lower Cretaceous zone indi- cated that this formation would be unable to produce against current line pressures. (See Dri11stem Test No.1, Well No.5, on Schedule 9.) Pre- Mesozoic rocks were penetrated and opened in Nos. 2 and 4. Since the best wells in the field, South Barrow Nos. 5 and 6 which have produced most of the gas, have not penetrated the Pre-Mesozoic, the ability of the zone to produce gas is questionable. The Jurassic is encountered at an average depth of approximately 2,300 feet in the producing wells. Map No.3 which presents our interpretation of the geologic structure at the subsea depth of the Middle-Jurassic formation . . 10 indicates that the formation dips in a northerly direction. The complete Jurassic system was penetrated only in wells Nos. 2 and 4 which are located less than 600 feet apart. The system contains approxi- mately 120 feet of siltstones and sandstones with interbedded shales. A review of the available electric logs indicates net pay thicknesses of 45 and 29 feet, respectively, for wells Nos. 2 and 4. The sands have been de- scribed as olive-grey in color, very fine grained, slightly argillaceous and non-calcareous. Past drilling activity has been conducted within an area comprising only about 320 acres. Not one of the wells drilled thus far has served to define the productive limits of the reservoir. Map No.3 shows faults lim- iting the reservoir to the east and south; however, these faults have been based solely on seismic data. No tests have been drilled in the vicinity of the faults, and the available subsurface information is insufficient to con- firm their existence or location. None of the wells drilled in the northern part of the reservoir have encountered a gas-water contact or permeability barrier which could possibly form or delineate the reservoir limits. Pertinent geologic data concerning wells in the South Barrow Gas Field, as determined from a review of electrical surveys, well site geologists' reports and other sources, are presented on Schedule 5. Accumulation of Gas Factors affecting or causing the accumulation of gas are not definitely known because of lack of reliable data. Available information suggests that the accumulation is primarily the result of stratigraphic entrapment. Other Potential Gas Zones Shows of gas were reported in several lower Cretaceous sands during the drilling of wells in the South Barrow Gas Field. These zones are shown . . 11 on the cross-section referred to previously. Commercial production has not been established in any of these sands. With the exception of the lowest zone, which is open in every field well, there is no evidence that any other Cretaceous sands have been tested through casing perforations. Electric logs indicate the zones to be thin and tight; however, they are correlative throughout the area developed by wells drilled to date in the field. There are no known productive zones below the Jurassic in the vicinity of the field. RESERVOIR CHARACTERISTICS Reservoir Rock Properties Core analysis data are available for only two wells, South Barrow Nos. 2 and 4. These data are presented on Schedule 6. It will be noted that the cores do not represent the respective total production intervals, and the averages obtained are not considered to be representative of the formation; therefore, average rock properties utilized in calculations made during this investigation have been determined primarily by analyses of electric logs and results of performance data. Results of the log analyses are presented on Schedule 5 and summarized below: Porosity Connate Water 21 Per Cent 28 Per Cent It will be noted that these averages are higher than those shown on Schedule 6. Permeabilities were determined only for one well, No.2. Performance of the re~ervoir indicates that the permeability of the reservoir is con- siderably better than the measurements indicate. Reservoir Pressure The original reservoir pressure could not be accurately determined. . . 12 A reservoir pressure of 1.075 PSIG was obtained from a drillstem test con- ducted during the drilling of South Barrow No.4 in May 1950. This was the second gas well completed in the field which, up to this time, had produced only 65,171 MCF. The pressure was higher than the initial bottom~ hole pressure calculated from a wellhead pressure for the South Barrow No. 2, the discovery well. It appears that a pressure of 1,075 PSIG closely approximates the original reservoir pressure, and calculations made in connection with this investigation have been based on this estimate. GAS ANALYSES Gas samples produced from most wells in the South Barrow Gas Field have been analyzed, and the analyses are summarized on Schedule 7. As shown, the gas contains almost 98 per cent methane. It is a light, dry gas with a specific gravity of approximately 0.56. The gas is considered sweet because no hydrogen sulphide is present. Condensate production is negligible as indicated by the fact that it is blown to the atmosphere from traps along the transmission system. METReD OF OPERATION Because of the extreme temperatures of the area and the complete de- pendence of the facilities served on the gas supply from the South Barrow Gas Field, operation of the gas wells is considerably more involved and complex than the operation of similar gas wells located in areas not so remote and having more favorable climatic conditions. Around-the-clock supervision, therefore, is provided for the operation of the wells. Dur- ing winter months the wells are blown down once each week to prevent the formation of hydrates which wi 11 freeze and shut off the gas flow. In addition, denatured alcohol is added to prevent freezing of the hydrates. . . 13 A manual prepared by the gas plant foreman~ which enumerates duties and outlines procedures to be followed by operating personnel, has been included in an appended section to this report. A review of that manual will reveal the methods of operation and the problems involved in day to day operations. RESERVOIR PERFORMANCE General A total of 4,257,424 MCF of gas has been recovered from the South Barrow Gas Field to September 1, 1969. The production has been accomp- nied by a decline in reservoir pressure of approximately 80 PSI. The latest reservoir pressure available was calculated to be 999 PSIG from a shut-in wellhead pressure which had been obtained in May 1969. The reservoir performance has been summarized on Schedule 3. This schedule presents available shut-in wellhead pressures, corresponding cal- culated bottomhole pressures and cumulative recoveries to the test dates. The schedule also reflects the average flowing tubing pressures which have been determined for the month of December for each of the past four years for South Barrow wells Nos. 5 and 6. Cumulative field recoveries to the corresponding dates are also shown. Pressure-cumulative recovery relation- ships are presented graphically on Plates 6 and 7. The performance of the South Barrow Gas Field indicates that the pro- ductive area is considerably larger than the developed area. Initial well- head pressures determined for wells drilled in previously undeveloped areas are lower than the original pressure and reflect good communication, as well as partial drainage of the undeveloped portion of the reservoir. It will be noted on Schedule 3 that only one actual bottoronole pres- sure is available for the reservoir. All other bottomhole pressures have . . 14 been calculated from the available wellhead pressures. The pressures shown cannot be considered as true static reservoir pres- sures and are approximations only. In reservoirs developed as closely as the South Barrow Gas Field, stabilized conditions, which are necessary to determine true pressures, can be achieved only by shutting in all of the wells. This has not been possible because of the continuous demand for gas. With the exception of South Barrow No.5, which was shut in in June 1966 after it had produced for a period of approximately eleven years, all shut-in pressure measurements have involved new wells in previously unde- veloped areas. Although these areas are in communication with the devel- oped portion of the reservoir and have been partially drained, their average pressure appears to be somewhat higher than the average for the entire res- ervoir. The pressure obtained for South Barrow No.5 appears to be below the average reservoir pressure at the time of measurement. The performance of the wells reflects a reservoir with good permeabil- ity; however, it appears that sands in the central and western portions are considerably more permeable than sands located in the eastern area. Individual Well Performance Records of individual performance have been kept only since February 1965 and are presented on Schedule 8. This schedule has been referred to previously. Although a breakdown of individual well production prior to 1965 is not available, it is apparent that the major portion of the gas production has been obtained from wells Nos. 5 and 6. These wells still have good productive capacities and, as shown subsequently, either well could supply the current demand for gas. Flowing pressures for both wells average about 925 PSIG, . . 15 Performance data for well No.7 indicate that its deliverability under current operating conditions has been declining rapidl~ and it is operating at or near capacity under current conditions. Although only recently com- pleted, No. 8 is considered to be a marginal well; however, it should be pointed out that neither well has been acidized or subjected to fracture treatment. The possibility exists that the productive capacity of both could be significantly improved by stimulation. Active wells in the South Barrow Gas Field do not produce water. As mentioned previously, the gas flow from the South Barrow No.4, which was completed in the Pre-Mesozoic as well as the Jurassic, was shut off by salt- water, but the well has been plugged. Since none of the active wells are completed in the Pre-Mesozoic, it appears that the water in the No.4 well originated in the Pre-Mesozoic. Open flow potentials of the four active wells and maximum daily "safe" rates, as indicated by management, are shown below: Producing Rates (MCF/Day) Well Open Flow Estimated Number Potential "Safe Rate" 5 7,900 1,200 6 8,200 1,600 7 1,000 600 8 1,200 --2QQ Tota 1 18,300 4,000 "Safe" rates, established by management, have been based on a factor of about 20 per cent of the open flow potential. There is no reason to re- strict wells Nos. 5 and 6 to the rates shown above if the demand for gas were sufficiently great. Preference should be given to producing well No. 6 because of the close proximity of well No.5 to wells Nos. 4 and 2. An . . 16 excessive drawdown of well No.5 might pull water from well No.2 or possi- bly No.4. Producing Mechanism Performance of the Middle-Jurassic reservoir to date suggests that it is a depletion type reservoir. This conclusion has been based upon the following observations: 1. Measured wellhead and calculated bottornhole pressures of the new wells (Nos. 6, 7 and 8) indicate continuing decline in reservoir pressure. Active or limited water encroachment would replace the relatively small volume of gas produced and maintain the reservoir pressure. 2. Flowing tubing pressures exhibit a slight but steady decline. (See Schedule 3.) 3. None of the wells produce water at the present time. If encroach- ing water in the Jurassic zones had been responsible for the loss of well No.4, well No.5 which is located at a comparable struc- tural position should be producing some water. GA S IN PLACE Methods of Determination Two methods are normally used to determine the original volume of gas in place, namely, (1) volumetric calculations and (2) extrapolation of pressure-cumulative recovery relationships. Volumetric calculations are usually made for depletion type reservoirs only during the early part of their life before performance data become available, and involve determination of the total void space in the reser- voir rock present and capable of containing gas. This method requires knowledge of the areal extent of the reservoir and its thickness. It was . . 17 pointed out previously that the development of the field at this time is insufficient to develop these data. The extrapolation of pressure-cumulative recovery relationships usu- ally yields good results for a depletion type reservoir if good performance data are available. These include reservoir pressures obtained under sta- bilized conditions. As discussed, only a limited number of pressures are available, and these must be considered to be approximations of the true reservoir pressure. In view of the constantly increasing demand for gas from the South Barrow Gas Field, it is unlikely that the true static reservoir pressure will ever be measured until an alternate source of gas is discovered and the field can be shut in for testing. The performance data available at the present time make it possible to estimate a usable range of gas volumes, and the volumetric data developed can be utilized to determine if this range is reasonable. Results of addi- tional drilling and performance data obtained in the future will permit a considerable refinement of the estimates presented in this report. Pressure-Cumulative Recovery Relationship In order to determine a range of the volume of gas originally in place, extrapolations were made of two different pressure-cumulative recovery rela- tionships. One was based upon the decline in calculated bottomhole pressures and the other upon flowing tubing pressures. Two extrapolations were made of bottomhole pressure-cumulative recov- ery relationships. One was based on pressures obtained from new wells and yielded a maximum volume of gas. The other relied on one pressure taken in one of the older wells (No.5) and yielded a minimum. The results are shown on Plate 6 and have been summarized as follows: . . 18 Maximum Minimum Gas in Place (MCF) 37,600,000 25,000,000 Determination of the volume of gas in place by extrapolating the trend of the flowing tubing pressure-cumulative recovery relationship usually gives optimistic results and must be considered an approximate answer only. The pressures are only valid if producing conditions are similar. Extrapo- lation of the trend observed in wells Nos. 5 and 6 during the last five years indicates a volume of 36,800,000 MCF of gas in place. This volume is in fair agreement with the maximum volume determined previously. Volumetric Calculations Volumetric calculations were made to verify the reliability of the estimate of gas in place based upon performance data and to determine the size of the productive area on the basis of the estimates made. Since the average pay thickness is unknown, various assumptions were made and a range of areas was determined, These calculations are summarized on Schedule 1. These calculations assume a maximum volume of 35,000,000 MCF of gas orig~ ina11y in place. On the basis of an average pay thickness of 40 feet, the productive area of the South Barrow Gas Field has been estimated to be between approx- imately 1,100 and 1,540 acres. This range appears to be reasonable when the development pattern and possible productive limits of the reservoir are considered. Recoverable Gas Recovery efficiencies of depletion type gas reservoirs vary consider- ably and may range from a low value of 50 per cent to a high value of 85 per cent of gas originally in place. The efficiency depends primarily on . . 19 the permeability of the reservoir; however, other factors must be consid- ered. Performance of wells Nos. 5 and 6 indicates that the recovery efficiency in the central and western portion of the reservoir developed by these wells should approach the maximum. In contrast the performance history of wells Nos. 7 and 8 in the eastern part of the field (See Plates 4 and 5.) is indicative of a reservoir with extremely poor permeability and recoveries from the eastern portion will probably approximate the low- er value. Average gas recovery for the entire reservoir is estimated to be 70 per cent of the total gas in place. As shown on Schedule l~ the range of recoverable gas varies from a minimum of 17,500,000 to a maximum of 24,500,000 MCF. The maximum volume has been based on a volume of 35,000,000 MCF of gas originally in place as shown on Schedule 1. After deducting pro- duced gas, the remaining reserves range from 13,200,000 to 20,200,000 MCF. FUTURE GAS DEMAND AND PRODUCTIVITY Demand for Gas As discussed previous1y~ demand for gas from the field has continually increased. Schedules 2 and 8 reflect an increase in production in excess of 400 per cent since 1955, the year during which well No.5 was completed and assured a steady supply of gas. The annual increase has been about eight per cent a year since late 1964 when the village of Barrow was con- nected. Future demand for gas from the South Barrow Gas Field has been esti- mated assuming a constant annual increase of ten per cent. Anticipated future daily production, by quarters through the year 1980, has been pre- sented on Schedule 2. This schedule also shows annual average daily pro- duction and total annual production. . . 20 The total demand for gas during the year 1980 is expected to be about 1,719,200 MCF, representing an increase of about 285 per cent over present producing rates. As shown on Schedule 2, daily average gas demand is expected to be 4,710 MCF during 1980 with an average demand of 5,490 MCF per day during the first quarter. The peak day's demand during that quarter is estimated to be 7,100 MCF, assuming a peak demand factor of 150 per cent of the annual daily average. Future Productivity of Wells An investigation was made to ascertain if wells Nos. 5 and 6 will be able to deliver the anticipated volumes. (Review of the performance of wells Nos. 7 and 8 indicates that the volume of gas contributed by these wells in 1980 will be negligible.) Calculations performed during this in- vestigation were based on the following two assumptions: 1. Results of the back pressure test conducted for well No.6 in 1964 are still valid. 2. South Barrow No.5 has the same flow characteristics as well No. 6. The investigation consisted of assuming certain shut-in pressures and determining productive capacities for various flowing pressures utilizing the previously mentioned back pressure test (Plate 8). The results obtained indicated the capacity of one well and were doubled to determine the com- bined capacity of both wells. The results of the determination of productive capacities have been summarized on Schedule 4. This schedule shows capacities of the wells for various flowing pressures and approximate dates these capacities will be reached, Determinations have been made for both the maximum estimate of 21 37,600,000 MCF of gas originally in place and for the minimum estimate of 25,000,000 MCF. It is doubtful that the wells will be able to satisfy the anticipated demand during the year 1980 if the minimum estimate of gas originally in place is correct; however, the existing wells will be able to meet the demand until the early 1980's if the volume of gas in place approaches the maximum estimate. Installation of compressors will provide only temporary relief because the volume of gas remaining at the time a compressor is needed will be al- most negligible if consideration is given to the daily requirements. . . SOUTH BARROW GAS FIELD NAVAL PETROLEUM RESERVE NO, 4 BARROW, ALASKA SCHEDULE 1 SL~Y OF BASIC RESERVOIR DATA AND POSSIBLE VOLUMES OF GAS-IN-PLACE, PRODUCTIVE AREAS AND RESERVES Reservoir Pressure - PSIA (Measured in No.4) Pressure Base - PSIA (Alaskan Statuatory Base) 1,089.65(A) 14.65 Reservoir Temperature - °Rankin (Measured) Temperature - Base - °Rankin (Alaskan Statuatory Base) 525 520 Porosity - Per Cent of Pore Space (Log Analyses) Connate Water - Per Cent of Pore Space (Log Analyses) 21 28 Gas Gravity - Air = 1,0 (Average of Analyses - See Schedule 7) Deviation Factor (Calculated) 0.564 0,852 Gas-In-Place - MCF/Acre Foot (Calculated)(B) Possible Volumes(C) Gas-In-Place - MCF Reservoir - Acre-Feet 567 25,000,000 44,092 30,000,000 52,910 35,000,000 61,728 Possible Productive Area - Acres Net Thickness - 30 Feet 1,470 1,764 2,058 40 Feet 1,102 1,323 1,543 50 Feet 882 1,058 1,235 Recoverable Gas-MCF (70%) 17,500,000 21,000,000 24,500,000 Gas Reserves (9-1-69) 13,242,576 16,742,576 20,242,576 A - Approximate Original Pressure B - From Formula: G = 43.560 x P x CW x P R P B TB x- T R 1 x- l Where: G = Gas-In-Place - MCF/Acre Foot 43.560 = MCF/Acre Foot P = Porosity - Per Cent of Pore Space Cw Connate Water - Per Cent of Pore Space PR Reservoir Pressure - PSIA PB Pressure Base - PSLA TR Reservoir Temperature - Degrees Rankin TB Temperature Base - Degrees Rankin l = Supercompressibility (Correction Factor for Deviation from Boyle's Law for Perfect Gases) C - Based upon Extrapolation of Pressure - Cumulative Recovery Relationship. . . SOUTH BARROW GAS FIELD NAVAL PETROLEUM RESERVE NO.4 BARROW. ALASKA PAST PRODUCTION AND PREDICTED DEMAND (MCF/DAY) SCHEDULE 2 Past Production Total Annual Quarter Year Product ion Year First Second Third Fourth (MCF) Remarks 1955 377 284 259 345 345 114,950 Number 5 Completed in June. 1956 393 245 169 332 310 103,462 1957 406 263 206 380 342 114,104 1958 415 272 206 373 345 115,030 1959 467 321 230 441 398 132,624 1960 584 411 348 565 520 173,486 1961 623 392 343 538 517 172 , 437 1962 624 486 407 647 590 196,734 1963 689 490 461 677 632 210,748 1964 774 600 491 873 747 248,953 Number 6 Completed in March. Barrow Village con- nected in December. 1965 1,199 1,005 820 1,253 1,167 388,846 1966 1,495 1,061 894 1,363 1,313 437,515 1967 1,514 1,151 1,006 1,558 1,426 475,383 1968 1,776 1,304 1,005 1,456 1,511 503,724 Number 7 Completed April 1. 1969 1,927 1,374 1,650(E) 602,192(E) Number 8 Completed May 1. Predicted Demand 1970 2,120 1,510 1,240 1,760 1,810 660, 700 1971 2,330 1,660 1,360 1,940 2,000 730,000 1972 2,560 1,830 1,500 2,130 2,200 803,000 1973 2,820 2,010 1,650 2,340 2,420 883,300 1974 3,100 2,210 1,820 2,580 2,660 970,900 1975 3,410 2,430 2,000 2,830 2,920 1,065,800 1976 3,750 2,670 2,200 3,120 3 , 220 1,17.5,300 1977 4,125 2,940 2,420 3,430 3,540 1,292,100 1978 4,540 3,230 2,660 3, 770 3,890 1,419,900 1979 4,990 3,550 2,930 4,150 4,280 1,562,200 1980 5,490 3,900 3,220 4,562 4,710 1,719,200 (E) Es timated . . " SOUTH BARROW GAS FIELD NAVAL PETROLEUM RESERVE - NO.4 BARROW. Ar.ASKA PRESSURE-CUMULATIVE RECOVERY RELATIONSHIPS SCHEDULE 3 SHUT-IN PRESSURES Well Wellhead Pressure Bottomho1e Pressure Cumulative Recovery Date Number (PSIG) (PSIA) (PSIA/~) (PSIG) (PSIA) (PSIA/~) (MCF) April , 1949 2 1,020 1,035 1,196 1,069* 1,084 1,261 May. 1950 4 1,025 1,040 1.200 1,075 1,090 1,268 65, 171 March, 1964 6 995 1,010 1,162 1,040* 1,055 1,221 1,879,485 June, 1966 5 967 982 1,129 1,013* 1,028 1,184 2,676,404 May, 1969 8 955 970 1,115 999* 1,014 1,172 4,152,147 FLOWING TUBING PRESSURES Pressures (PSIG) Average Pressure Cumulative Recovery Well Number Average (PSIA) (PSIA/~) (MCF) 5 6 Dec. 31, 1965 968 960 964 979 1,125 2,468,690 Dec. 31, 1966 955 950 952 967 1,110 2 ,906,202 Dec. 31, 1967 943 940 942 957 1,097 3 381,584 Dec. 31, 1968 932 930 931 946 1,084 3,885,308 *Ca1cu1ated . . SOUTH BARROW GAS FIELD NAVAL PETROLEUM RESERVE NO.4 BARROW. ALASKA SCHEDULE 4 ANTICIPATED PRODUCTIVE CAPACITIES - WELL NOS. 5 AND 6 Shut-In Pressures (PSIA) Casing Bottomho1e Flowing Pressures (PSIA) Casing Bottomho1e Anticipated Capacity(A) (MCF /Day) Estimated Date Case I(B) Case II(C) 600 628 400 418 300 314 200 209 100 105 One Well Two Wells 2,600 5,200 3,210 6,420 3,600 7,200 3,900 7,800 After 8-1-81 Late 1977 400 418 200 209 1,820 3,640 After 1-1-81 Late 1980 100 105 2,110 4,220 300 314 200 209 980 1 , 9 60 After 1-1-81 After 1-1-81 100 105 1,280 2,560 200 209 100 105 680 1,360 After 1-1-81 After 1-1-81 (A) Calculations based on back pressure test of Number 6 (See Plate 8). (B) Case I - Gas-In-P1ace - 37,600,000 MCF. (C) Case II - Gas-In-P1ace - 25,000,000 MCF. Note: Determination of dates shown has been bæed upon projected producing rates shown on Schedule 1. · e SOUTH BARROW GAS FIELD NAVAL PETROLEUM RESERVE NO.4 BARROW. ALASKA SCHEDULE 6 CORE ANALYSES Well Number 2 We 11 Number 4 Depth Porosity (Per Cent) Permeability (Mi11idarcys) :Qepth Porosity (Per Cent) Permeability (Mi 11 idarcy s) (Feet) Normal Parallel Normal parallel (Feet) Normal Parallel Normal Parallel 2,330 20.8 20.6 32.7 70.0 2,360 10.86 11. 23 Imp. Imp. 2,331 20.1 78.0 108.0 2,368 15.92 12.36 Imp. 26.0 2,341 22.5 20.0 8.8 13.3 2,380 14.86 11. 99 Imp. Imp. 2,346 17 .0 <9.0 <9.0 2,387 N. M. 11. 82 N. M. Imp. 2,356 7.8 9.2 < 8.0 <9.0 2,413 N. M. 9.38 N. M. Imp. 2,375 21.4 13.2 17.8 2,419 N. M. 8.22 N. M. Imp. 2,378 21. 9 11. 7 19.5 2,428 11.60 11.50 Imp. Imp. 2,383 24.0 62.5 91.0 2,442 6.84 9.43 Imp. 0.1 2,397 16.1 10.4 <6.0 2,454 7.59 N. M. 2.0 N. M. 2,404 19.2 17.1 <11.0 2,460 10.04 9.03 Imp. Imp. 2,406 19.9 12.0 8.3 2,465 ( (N. M. 9.18 N. M. N. M. 2,416 15.4 5.7 < 5.0 2,475 ( 2,430 12.2 9.7 < 4.0 Aver?ge 18.4 16.6 u_ -Not Determined' ---- 11. 10 10.41 - _u NotDetermined- --- N.M. - Not Measured Imp.. - Impermeable < .. Less ThAn · e SOUTH BARROW GAS FIELD NAVAL PETROLEUM RESERVE NO.4 BARROW. ALASKA SCHEDULE 7 GAS ANALYSES Well Number 2 4 5 6 7 COMPONENTS (M:)le Per Cent) Methane 97.7 97.5 97.8 97.9 98.1 Ethane La 0.9 0.9 0.9 1.1 Propane 0.2 0.1 0.2 0.1 0.1 Butane 0.1 N.R. N.R. None N.R. Pentane Trace N.R. N.R. None N.R. Ni trogen N.R. ( La 0.9 0.6 ( ( Argon N.R. ( Trace Trace None ( 1.5 ( He li urn N.R. ( 0.03 0.03 Trace ( ( Carbon Dioxide 0.2 ( 0.1 0.1 Trace HEAT CONTENT (B. T . U. /Cubic Foot) 1,014 N.R. 1,012 1,010 1,016 SPECIFIC GRAVITY (Air = La) N.R. N.R. 0.566 0.564 0.563 N.R. - Not Recorded . . SOUTH BARROW GAS FIELD NAVAL PETROLEUM RESERVE NO.4 BARROW. ALASKA SCHEDULE 8 INDIVIDUAL WELL PERFORMANCE DATA Well Number . . 5* 6 7 8 TOTAL FIELD Production Flow Pressures Production Flow Pressures Production Flow Pressures Production Flow Pressures Production (MCF) Tubing Casing (MCF) Tubing Casing (MCF) Tubing Casing (MCF) Tubing Casing (MCF) Cumulative to 1-1-64 1,830,891 1,830,891 1964 - January 21,194 --Not Availab1en 21,194 February 27,400 --Not Availab1en 27,400 March 21,768 --Not Available-- 21,768 April 8,826 --Not Availab1e- 11 , 700 --Not Availab1e-- 20,526 May 9,105 --Not Availab1e- - 10,689 --Not Availab1e-- 19,794 June 4,700 --Not Availab1e-- 9,545 -- Not Availab1en 14,245 July 4,855 --Not Availab1en 7,921 --Not Availab1en 12,776 August 5,946 --Not Availab1en 10,571 - - No t Availab1en 16,517 September 5,694 --Not Availab1e-- 9,694 --Not Availab1e-- 15,388 October 7,859 --Not Availab1e-- 14,595 --Not Availab1e-- 22,454 November 7,426 --Not Availab1e- - 13,791 --Not Availab1en 21,217 December 10,658 --Not Availab1en 25,016 --Not Availab1e-- 35,674 1964 - Total 135,431 113,522 248,953 1965 - January 10,547 --Not Availab 1en 25,653 --Not Availab1e-- 36,200 February 12,055 980 965 22,565 960 950 34,620 March 17,838 970 960 20,363 960 950 38,201 April 15,012 975 960 19,880 965 955 34,892 May 14, 269 970 960 17,024 965 955 31,293 June 8,406 970 960 16,785 970 960 25,191 July 8 , 68 6 970 960 13,933 970 960 22,619 August 8,693 970 960 15,459 970 960 24,152 September 10,366 970 960 17,391 970 960 27,757 October 12.432 965 950 23,005 960 950 35,437 November 12,028 965 955 22,202 960 950 34,230 December 17,073 965 950 27 , 181 955 935 44,254 1965 - Total 147,405 241,441 388,846 *Includes production from Nos. 2 and 4. Note: Production by Wells Not Available Prior to February. 1965. Volumes Shown Prior to that Date are Estimates. . . SOUTH BARROW GAS FIELD NAVAL PETROLEUM RESERVE NO.4 BARROW. ALASKA SCHEDULE 8 SHEET 2 INDIVIDUAL WELL PERFORMANCE DATA Well Number . . . . . . Production (MCF) 5* Flow Pressures Tubing Casing Production (MCF) 6 Flow Pressures Tubing Casing Production (MCF) 7 Flow Pressures Tubing Casing Production (MCF) 8 Flow Pressures Tubing Casing TOTAL FIELD Production (MCF) 1966 - January 18,685 955 945 28,067 955 935 46,752 February 14,584 960 950 27,659 955 935 42,243 March 16,144 960 945 30,788 955 935 46,932 April 14,428 965 950 25,560 960 950 39,988 May 12,111 965 955 19,688 960 950 31,799 June 8,405 960 960 16,221 960 950 24,626 July 9,306 960 960 15,734 960 955 25,040 August 9,306 960 955 18,020 960 950 27,326 September 10,506 965 960 18,387 960 955 28,893 October 13,026 960 950 22,994 955 945 36,020 November 12,613 955 945 29,123 940 925 41,736 December 13 , 344 955 945 32,813 945 935 46,157 1966 - Total 152,458 285,054 437,512 1967 - January 13,497 955 945 33,206 940 930 46,703 February 13,453 950 945 30,366 935 925 43,819 March 14,894 950 945 32,230 935 925 47,124 Apr i 1 13,506 950 945 26,741 955 945 40,247 May 9,306 950 945 26,514 955 945 35,820 June 10,506 955 950 18,093 955 945 28,599 July 10,856 955 950 16,680 955 945 27,536 August 11,183 950 945 19,185 950 940 30,368 September 10,513 950 945 23,005_ 945 935 33,518 October 13,901 950 945 26,404 940 930 40,305 November 15,756 935 935 33,601 925 920 49,357 December 13,956 935 940 38,030 930 920 51,986 1967 - Total 151,327 324,055 475,382 *Inc1udes production from Nos. 2 and 4. . . SOUTH BARROW GAS FIELD NAVAL PETROLEUM RESERVE NO.4 BARROW. ALASKA SCHEDULE 8 SHEET 2 INDIVIDUAL WELL PERFORMANCE DATA Production (MCF) 5* Flow Pressures Tubing Casing Production (MCF) 6 Flow Pressures Tubing Casing Production (MCF) 7 Flow Pressures Tubing Casing Production (MCF) 8 Flow Pressures Tubing Casing TOTAL FIELD production (MCF) Well Number . . . . . . 1966 - January 18,685 955 945 28,067 955 935 46,752 February 14,584 960 950 27,659 955 935 42,243 March 16,144 960 945 30,788 955 935 46,932 Apr i 1 14,428 965 950 25,560 960 950 39,988 May 12, III 965 955 19,688 960 950 31,799 June 8,405 960 960 16,221 960 950 24,626 July 9,306 960 960 15,734 960 955 25,040 August 9,306 960 955 18,020 960 950 27,326 September 10,506 965 960 18,387 960 955 28,893 October 13,026 960 950 22,994 955 945 36,020 November 12,613 955 945 29,123 940 925 41,736 December 13 , 344 955 945 32,813 945 935 46,157 1966 - Total 152,458 285,054 437,512 1967 - January 13,497 955 945 33,206 940 930 46,703 February 13,453 950 945 30,366 935 925 43,819 March 14,894 950 945 32,230 935 925 47,124 April 13 , 506 950 945 26,741 955 945 40,247 May 9,306 950 945 26,514 955 945 35,820 June 10,506 955 950 18,093 955 945 28,599 July 10,856 955 950 16,680 955 945 27,536 August 11, 183 950 945 19,185 950 940 30,368 September 10,513 950 945 23,005 945 935 33,518 October 13,901 950 945 26,404 940 930 40,305 November 15,756 935 935 33,601 925 920 49,357 December 13,956 935 940 38,030 930 920 51,986 1967 - Total 151,327 324,055 475,382 *Inc1udes production from Nos. 2 and 4. . . SOUTH BARROW GAS FIELD NAVAL PETROLEUM RESERVE NO.4 BARROW. ALASKA SCHEDULE 8 SHEET 3 INDIVIDUAL WELL PERFORMANCE DATA Production (MCF) 5* Flow Pressures Tubing Casing Production (MCF) 6 Flow Pressures Tubing Casing Production (MCF) 7 Flow Pressures Tubing Casing Production (MCF) 8 Flow Pressures Tubing Casing TOTAL FIELD Production (MCF) Well Number . . . . . . 1968 - January 16,746 930 935 36,974 910 905 53,720 February 15,956 935 935 38,967 915 905 54,923 March 15,606 930 935 37,215 920 915 52,821 April 13,806 900 930 34,396 925 920 48,202 May 13,399 940 940 24,609 940 940 640 880 870 38,648 June 6,936 N.A, N.A. 13 , 042 N,A. N.A, 11,682 N.A. N.A. 31,660 July 2,684 950 945 5,984 960 950 22,276 720 665 30,944 August 4,649 945 945 11 , 908 945 940 13,720 740 665 30,277 September 7,406 945 945 6,237 955 945 16,506 875 830 30,149 October 10,396 940 940 13 ,011 945 935 11,496 885 835 34,903 November 14, 106 930 935 18,876 930 920 12,406 870 830 45,388 December 16,281 930 930 23,398 930 915 12,410 855 815 52,089 1968 - Total 137 , 971 264,617 101,136 503,724 1969 - January 17 ,056 925 925 31,03"2 925 905 10,855 865 825 58,943 February 15,966 920 920 31,206 915 910 9,112 875 840 56,284 March 17,118 920 920 33,493 915 900 9,312 875 840 59,923 April 16,566 925 915 23,611 920 910 9,606 875 840 49,783 May 13,956 925 935 20,286 925 920 5,727 875 850 1,933** 870 870 41,902 June 11 , 835 925 925 14,253 940 930 4,052 855 865 3,099 880 880 33,239 July 12,013 925 925 15,622 935 925 2,657 890 875 4,837 880 880 35,129 August 12,601 915 925 16,768 935 925 3,651 910 880 3,893 880 800 36,913 1969 - Total (9 Months) 117,111 186,271 54,972 13,762 372,116 Cumulative to 9-1-69 2,672,594 1,414,960 156,108 13,762 4,257,424 *Inc1udes production from Nos. 2 and 4. **Inc1udes Est. Volume of 520 MCF production during Completion & Testing. . . SOUTH BARlOW GAS 'lEU) NAVAL PETROLEUH RESERVE NO.4 BAlUIOI/. ALASKA SCIIIDULI! 9 INDIVIDUAL WELL COMPLETION DATA Cad"" In.talled Plug Location in See tion 14, Initial Test Data Oil Strin2 Liner Total Back Well Township 22N, Range 18W Completion Ooen-Flow Pressures (PSIG) Size Depth Size Top Leng th Perforations Depth Depth Number (Umiat Meridian)* Datum Date (MCF IDay ) Shut-In Flowing (Inches) (Feet) (Inches) (Feet) (Feet) Interva1- Feet (Fee t) (Feet) Remarks 2 542 Ft_éFrom West Line and 35' K.B, April 15, 1949 507** 1,020 1,020 2,260 5 1/2 2,224 280 2,282-402 2,505 2,417 DST 1 & 1992-2030 - open 1 hr, 10 min.; wk. blow of air 649 Ft. F,:om North Line 2,473-504 Rec'd 250' mud - no show.. DST 2 & 2314-91 - open 57 min, - fair blow air inc. to .trong blow gas in 12 min, - left 33 stand. of D,P. and tester in hole.. No fluid recovery DST 3 - 2381-2443; open 30 min. . wk. blow of air. held 95' GCM; flow pressure T5TH. . DST 4 - 2260-65 - Open 29 min, - wk. blow of air, Changed to gas at end of test, Rec'd 168' IIGCM. 4 767 Ft. From Wes t Line and 43 K,B, ~y 9, 1950 1,805** 1,000 275 10 3/4 2,317 Surface 2,502 2,343-502 2,538 DST 1 - 2317-90 . open 3 hr.... 14 min, - Lt. blow incr. 552 Ft. From North Line to strong, Est. 5" MCF/Day. Rec'd 75' GCM. DST 2 - 2389-420; Open 3 hrs, 15 min. GTS 6 min. Rec' d 52 Ft. Mud. OST 3 - 2472-538 - Open 3 hrs. 51 min.; fair blow of gas; flowed mud after 45 min. then sal t water. Rec I d 640' saltwater; BHP 1075 PSI. DST 4 - 2520-38 - Open i hr. 7 min.; wk. blow incr. to strong - 15 min. FloWed 200 KCF/Day. flowed mud after 42 min. then sal twater; Rec I d 525 I saltwater; BHP 1075 PSI. 5 622 Ft. From West Line and 38 K,B. Junp 17, 1955 1,460** 1,000 960 7 2,320 5 3/4 2,298 160 2,325-455 2,458 DST 1 - 2215-2325 - Open 1 hr. 15 min. Lt. blow incr. 812 Ft, From North Line 1>0 485 KCF IDay in 30 min. F low press. less than 200 PSI. No flu id recovery. 6 2,483 Ft, From West Line 40 K,B. ~rch 24, 1964 8,200 995 958 2,276 5 1/2 2,209 154 2,276-362 2,363 DST 1 - 2276-2343; open 2 hrs, 10 min, - Flow 2,700 MCFI ,and 1,337 Ft, From North day in 44 min. Incr. to 3,400 KCF/Day in 1 hr. 54 min. Line Rec'd 20' mud. ISIP - 1029; FP 479-628 FSIP - packer failed. 222 Ft. From Ea. t Line and 36 K.B, April 1, 1968 None Reported 2,238 5 1/2 2,200 149 2,230-349 2,351 . 2,042 Ft. From North Line 8 309 Ft. From Wes t Line and 31 K.B. Kay 1, 1969 2,000 955 935 2,261 2,166 192 2,261-358 2,359 115 Ft, From North Line in Section 13. Note: Well No, 2 . 7-inch casing collapsed. Jonked since April,. 1950. Well No.4· Temporarily abandoned ~y, 1968. * Determined fram ORREL Sheet 17. **Reported Flow Rate. · · · ) , / , , , , , v.sS~'./" ,~ ---.- ~ o 50 100 1I11t. . , SCALE ð . ç\~ ~ þ . 0 þ , . . \ ALASKA LOCATION MAP LEE KEELING AND ASSOCIATES PETRO~EUM CONSU~TANTS TULSA SAN ANTONIO ¡ MAP NO. I R 18 W ~ 10 II 12 15 T 22 N 13 Faults Based on Origino/ Seismic Work 22 23 24 -LEGEND- o Location . Drilling . 011 Well * G;:¡s We!, ~ Abandoned Well 4- Dry Hole -23/3 SUbsea Top 0 t Jurassic o I 1000' I SCALE 2000' I STRUCTURE MAP TOP OF JURASSIC SOUTH BARROW FIELD NPR NO, 4 ALASKA LEE KEELING AND ASSOCIATES PETROLEUM CONSULTANTS TULSA SAN ANTONIO MAP NO 3 Contour Interval: 10 Feet STRUCTURE MAP TOP OF JURASSIC SOUTH BARROW FIELD NPR NO, 4 ALASKA LEE KEELING AND ASSOCIATES PETROLEUM CONSULTANTS TULSA SAN ANTONIO MAP NO 3 R 18 W 10 II Faults Based on Original Seismic Work 22 23 - LEGEND- o Location . D ri II ing . 011 Well * GiJ5 We!, .11' Abandoned Well + Dry Hole -2313 Subsea Top ot Jurassic o I Cantour Interval: 10 Feet 1000' I SCALE 2000' I ~ 12 T 22 N 24 0(.' 'f." 0(.0 " -LEGEND- Location * Go. Well ;11 Abandoned Go. Well - Gas Pipeline Line <::::. r e <:" ("' \S' o "'t- ~p. C; T 23 N ("' V Ci' o o "'t- . 18 17 18 17 13 16 R 18 W R 17 W 2000' 6000' . , SCALE GAS TRANSMISSION SYSTEM BARROW AREA ALASKA LEE KEELING AND ASSOCIATES PETROLEUM CONSULTANTS TUL.A SAN ANTONIO MAP NO.4 t&.. U ~ I U) 0:: w ~ 0:: ct :> o >- m z o ~ u :> o o 0:: Q. U) ct C) w C) ct 0:: w ~ >- -J ct o 0,000 )000 00 . PERFORMANCE HISTORY SOUTH BARROW GAS FIELD TOTAL GAS PRODUCT ION . .... " T .. .. I , , . ~ ~ , , - , , , '" " I ~ II , ,,-j ~ . ..& i. ~ .~ I' ..... ... . '- .& , . I ..... .L P-4 ~ -, '" , ~ " ,... 11- .. I. .. . ,. , , .. ." 11 I ! ..: III '"' II! III '"' iii ... t ..: III '"' ... iii W '"' ... iii III ... .. iii III '" ... ..: W '"' .. II: III ... ~ .. III ... ... .. III '"' It III .. ..: ¡ t ..: III ... iii ... ... ..: III ... ... ... ... w ... w ... ... .. ... .. .. ... ... .. .. .. ... ... .. ... .. ... L II: ... . ... II: L .. . L ... .. .. ... .. II: ... .. ,. ~ ~ III ~ C ~ III III C ~ III III : :> ... ... c :> III III : :> III :!: c :0 III III C :0 III III : :0 ... C :> = III : :0 ... :!I c :0 = :!I : III ... ~ ~ = ... C ~ ... III ; ;;¡ ... . ... .. . ... .. ... ... ... . ... lit ... ... ... II: ... ... ø . ... ... ... ... ... . ... ... ... lit . ... ... '" ... .. . ... .. . 10 PLATE L.EE KEEL.ING AND ASSOCIATES PETROLEUM CONSULTANTS . I PERFORMANCE HISTORY SOUTH BARROW GAS FIELD WELL NO. 5 , , I- GAS PRODUCTION ... I.... 111 UII .. 11 . 111 .1 11 , 1& - II ~ 11 I ¡oJ ~ " /II'" I iii , F.tp. I 5 . 00,000 0,000 5 ,000 , ( ( ( .. ( ( l ( , . 100 LEE KEELING AND ASSOCIATES PETROLEUM CONSULTANTS PLATE 2 . . 100,000 PERFORMANCE HISTORY SOUTH BA R ROW GAS FIELD WELL NO.6 GAS PRODUCTION .. "-I . . II.. II "' 1\ , IN , I' "'I II . ~ . ." ,I V I '- tv I -- F.T.p. I 5 .. - · · l ( · · , 0,000 ; ( · ( ,000 1969 y œ ~ ~ I.&J C =- ¿i o :II ., en I 19>70 u cC ~ ~ I.&J C =- UJ Q 2 ~ (/) I 19'71 u a: ~ ~ U I.&J C ::» I.&J ..... Q 2 ..,. en Q I 1972 I 100 ~ ~ ¡ ~ ~ a 2 ~ en Q I 1964 I a: ~ ~ c => '" :II ... en 1965 u a: ~ t ..... C :II I.&J Q 2 ., cn I 1966 U IX ~ ~ I.&J C =- loW CII 2 ~ en I 1967 U Œ ~ ~ u UJ C :II I.&J ..... o:l!..,.cnQ I 1968 I a: ~ ~ c => '" :II! ... en a: ~ ~ u c ~ ..... I.&J 2 '"':I en 0 19173 I LEE KEELING AND ASSOCIATES PETROLEUM CONSULTANTS PLATE 3 . . PERFORMANCE HISTORY SOUTH BARROW GAS FIELD WELL NO. 7 - -GAS PRODUCTION I.. , I F.T.p. I 5 ua:~~u 1&1 C :t W 1&1 o :II ~ en 0 I 1968 I '" ~ :t u 10 C :t I.IJ I&J a "":I en 0 1977 I u œ ~ ~ u ,¿J C J I&J W Q :IE ~ U) 0 I 1972 I u a: ~ ~ 1&1 C( ~ L&J o 2E ~ U) I 1974 u a: ~ ~ u UJ C J I.IJ W o :II ~ U) 0 I 1975 I œ ~ ~ u c ~ W 1.&.1 :II "":J U') 10 1969 I a:: ~ :i: c,j <C :t I.&J I&J 2 ~ U) 0 1970 I . LIJ ~ It: Z Q. .. ::> ... a ... CI) Œ ~ ~ .. ::> ... :IE ... CI) 0: ~ ~ u C :t ..... w :II .., U) 0 1976 I 1971 1973 LEE KEELING AND ASSOCIATES PETROLEUM CONSULTANTS PLATE 4 100,000 ,... :z: .... 2 0 :¡¡ ..... l1. U ~ 0,000 2 0 .... U ::J 0 0 0:: Q. U] <I C) ,000 CJ U] Q. - w 0:: ::J U] U] w 0:: Q. CJ 2 aJ ::J .... C) 2 ;: C IJ. . . PERFORMANCE HISTORY SOUTH BARROW GAS FIELD WELL NO.8 . I ---- - -- - GAS PRODUCTION - - F. T. P. I 5 c,j Œ ~ ~ U &&.I c( :) .... 1.&.1 Q :E ~ en c I 1969 I U Œ ~ ~ IoU C ~ ..... o a ~ en I 1972 u ø:: ~ t YJ C :::t W a 2 ~ en I 1973 u a:: ~ t w 4 :::t W 10 2 -:t en I 1974 U Œ ~ ~ LI.I C ::) W c :I -:t en I 1975 u a:: ~ ~ u W C( :J ..... UJ c :I -:t CI) C I 1976 I aë ~ t u C :::t w W . '-:t en Q 1978 I a: ~ t: u C :J '" W a -:t en Q 1977 I a:: ~ t: c.j C ::Þ \AI .... :I ., U) Q 1970 I Œ ~ ~ ... ::> '" :a .. '" 1971 LEE KEELING AND ASSOCIATES PETROLEUM CONSULTANTS PLATE 5 100,000 ... > < C ... 1.1 (. OIl ... - 0,000 ;;¡¡ c ... (. C C Q a u < c: ,000 - c: u a - 1.1. Q: C/ C/ 1.1. Q: Q, c:: 2 a: - I- CJ 2 ~ o ...J lI.. 100 . <0 - - I <Ø Ø) 1'1') <Ø ,<0 - I I <Ø CD 10 Ó - - BHP 10 GO VS CUMULATIVE RECOVERY z - Ó ó -t z z SOUTH BARROW GAS FIELD - .... ~ 1200 I. 800 a. :I: 600 II . 400 200 o 20 2 22 4 24 6 26 8 28 10 30 12 32 14 34 16 36 18 38 o 20 40 r-111..111...ATI\,r- nr-"^",-,.,.,, I. ^'~" """'" .."'..., ..... --- .... 200 . ILl a:: ::::> en 800 ~ a:: D- e> z CD ::::> 600 l- e> z 3: . 400 200 o 20 40 FLOWING TUBING PRESSURE VS CUMULATIVE RECOVERY r 10 co SOUTH BARROW GAS FIELD co-co .... ~ I CO-GO N I-CO N - I -N I... - , I .... ! 18 38 16 36 14 34 12 32 10 30 P""1""Iio". f"\r-,,^ " r- 8 28 AT . ... r 6 26 4 24 2 22 o 20 11 2 ~ 9 ~ 6 7 ~ !1 (ì 7 8 1,00 . , 9 9 8 8 . PLOTTED DATA +t+t 7 FLOW RATE 2 2 6 6 PSI -PF (MCF/DAY) FOUR POINT BACK PRESSURE TEST 5 367 56 ,195 5 1440 94 ,455 SOUTH BARROW GAS FIELD 4 2780 235 ,248 II III WELL NO.6 4 3840 395 ,760 .- 3 O~EN FLOW = 8~00 M CF/DAY . -- 2 2 ,Jf' I; 1 I 1,00 9 9 8 8 7 . 7 6 6 5 4 I- I . 3 Mil 3 2 2 1. ~ ..L ~ 100 3 4 7 8 9 2 7 8 2 3 t 5 6 7 8 9 O( o 10,000 100,000 1,000,000 2 2 PSI - PF PLATE 8 NO.7 EL36' * o o !! NO.6 EL 40' -* NO.4 E L. 43 % A A -2000 CROSS SECTION A-A' SOUTH BARROW GAS FIELD LEE KEELING AND ASSOCIATES PETROLEUM CONSULTANTS TULSA SAN ANTONIO PLATE 9 ....... ......... . ..' f.~ .' ': £. ~ ) o o !! tD. 235 8 Ñ o o N N o o If) N LK 24 LK 22 LK 20 LK 19 LK 15 LK 17 LK \I üfi LK7 LK 5 LK 3 ~ o o !!! o o o N ----- lD. 2538 , -2000 U) ~ o w U <It ~ w a:: u NATURAL GAS PLANT OPERATOR'S MANUAL Revised February 1969 by A. F. Crane Gas Plant Foreman 0 PREFACE This manual is intended to serve as a guide for the gas plant operator by acquainting him with the scope of natural gas operations and outlining his duties and responsibilities for the operation and maintenance of the plant. It is impossible for any manual to anticipate all possible contingencies that may confront the operator; therefore, it will be necessary for him to exercise his own best judgment when such instances arise. INDEX Zae Description of the Gas System ........................ 1 General Responsibilities ............................. 11 Operating and Maintenance Instructions ............... 16 . . 1 . DESCRIPTION OF THE GAS SYSTEM 1.1 For the purpose of this manual the gas system is considered to con- sist of the following component parts: A. The production and control system. B. The transmission system. C. The distribution system. 1.2 The production and control system is located approximately five miles south of the Point Barrow base camp and consists of the following fa- cilities: A. Gas well No. 5. B. Gas well No. 6. C. Gas well No. 7. D. Control and Treatment plant. E. Electric power plant, 1.3 The transmission system consists of a single 4" main pipeline lead... ing from the gas plant control house to a "y" juncture (designed for orifice metering complete with by~pass at each take-off; the orifices installed in each line presently serve as a safety measure to restrict the flow of gas in the event of a rupture in the transmission pipeline) 400 feet downstream of the control house from which one 4" welded pipe- line (Schedule 40, 4.026" ID) runs 4.5 miles to the Point Barrow base camp gate station and one 6" API high test welded pipeline (Schedule 20, 6.313" ID) runs 5.4 miles to the City of Barrow at which point a tee connection permits pipe runs to the Bureau of Indian Affa~rs' two gate stations along with Barrow Utilities' Browerville gate station and 1 . . Barrow Utilities' Barrow gate station; a 4" tee connection located 1/2 mile upstream of the base camp gate station from which a 4" welded pipeline (Schedule 40, 4,026" ID) runs 3/4 mile to the gate station, Main Station POW; a 4" tee connection to the Point Barrow base caQlP pipeline, located 100 feet upstream of the base camp gate station, from which a 2-1/2" threaded and coupled pipeline (x strong pipe, 2.441" ID) runs 800 feet to a single building, the Point Barrow base camp power plant and turbine power plant gate station, All transmis- sion pipelines are laid on drums over the surface of the tundra and have a number of expansion loops, traps and control valves, Trans- mission pressure is 200 PSIG (pounds per square inch gauge), 1,4 The distribution system at the Point Barrow base camp is made up of standard pipe of nominal sizes from 3/4" to 6" with both threaded and coupled (Dresser compression type expansion couplings) connections and laid in a fill of sand and gravel to a depth of 3 feet. The dis- tribution system at POW Main is made of of nominal 2" and 4" welded standard pipe and laid on drums, (The Point Barrow base camp and POW Main gas systems, though operated independently, are interconnected so that either location may be served from either gate station in the event of an emergency.) The Bureau of Indian Affairs and Barrow Utilities, Inc" have surface-piped distribution systems utilitizing standard and x-strong pipe of nominal sizes from 3/4" to 4" with both threaded and coupled (Rologrip and Dresser couplings) connections, The pipelines are supported by drums and poles. Barrow Utilities, Inc" operates two separate non-government distribution systems with the Barrow gate station providing gas service to Barrow proper and 2 . . the Browerville gate station supplying gas to Browerville. Distri- bution pressure is 20 PSIG. 1.5 All gate stations are equipped with meters for the measurement of gas for distribution. The government gate stations use Foxboro orifice type meters, rotary meters and diaphragm type displacement meters; the non-government Barrow gate station is equipped with a Rockwell rotary type meter (An identical type meter is available as a standby meter.), while the non-government Browerville station employs a Rock- well diaghragm type positive displacement meter (A standby meter is not installed.). The gas is measured under standard conditions of a pressure base of ¡4.65 PSIA (pounds per square inch absolute) and a temperature base of 600 F in accordance with the standards set by the State of Alaska. 1.6 Gas wells designated No.1 and No.3 were drilled in structures at distant locations from the South Barrow gas field and were unproduc- tive wells. 1.7 Gas well No.2, completed successfully in 1949, was drilled in the South Barrow gas field. Natural gas was then utilized as a fuel for structural heating purposes at the Point Barrow base camp. The well was abandoned in 1950 after a fire,which destroyed the surface plant, and it was not reactivated because of casing collapse. 1.8 Gas well No.4, located 447.24 feet northeast of gas well No.2, was in the process of completion when the well No. 2 surface plant was destroyed by fire in 1950. Thus, gas service to the Point Barrow 3 . . base camp was interrupted for only a few weeks. Well No.4 was drilled to a depth of 2,538 feet and almost 100 feet deeper than nec- essary, for exploratory purposes, and water was encountered in opening upon a second gas horizon. Water intrusion in the well prevented its full productive capacity from being utilized, and the condition wor- sened gradually over the years. In April 1968 an attempt was made to rehabilitate the well by cementing off the lower zone. A serious casing leak was noted and the well was cemented in and abandoned. 1.9 Well No.5, located 157.54 feet northeast of abandoned well No.2 and 289.70 feet southwest of well No.4, was drilled in 1955 to a depth of 2,~56 feet and presence of water was not evident. Production from well No.4 was then restricted as well No.4 and well No.5 handled the load requirements of the Point Barrow base camp, Main Station POW and, in August 1958 upon completion of the transmission pipeline to Barrow, the government agencies in Barrow. 1.10 Gas well No.6, located 1,925 feet southeast of gas well No.5, was drilled in the South Barrow gas field to a depth of 2,363 feet and completed in April 1964. Its distance from the water conditions sur- rounding well No.5 (through its proximity to well No.2 and well No. 4) along with being high in the gas sands should keep the well free of water intrusion for many years. Well No.6 permitted shutting in well No.4, restricting production from gas well No.5 to approxi~ mately 30% of the demand requirements and addition of non-government gas service to Barrow proper and Browerville upon completion of their distribution systems in the winter of 1964-1965. 4 . . 1.11 Gas well No.7, located 2,672 feet southeast of gas well No.6 (4,597 feet S 730 E of gas well No.5), was drilled to a depth of 2,351 feet and completed in April 1968. The well is a poor producer ("tight" gas sands) and has a water problem. 1.12 The initial shut-in wellhead pressure of the first gas well, No.2, was 1,015-1,020 PSIG (pounds per square inch gauge). The present wellhead static pressures (shut-in pressures) of gas wells Nos. 5, 6 and 7 are 950 to 960 PSIG. 1.13 The open flow potential of gas wells Nos. 5 and 6 approximates 8.0 MMCFD (8,000,000 cubic feet per day). The open flow potential of gas well No.7 is 0.9 MMCFD. Taken as a "rule of thumb", the maxi- mum safe productive rate of flow is 20% of the open flow potential, or roughly 1.6 MMCFD for wells Nos. 5 and 6. The low permeability of the gas sands characteristic of well No. 7 permits a greater per- centage, 50% or more, of the open flow potential as the maximum safe productive flow rate. However, gas well No.5 is subject to migratory water encroachment (Water intrusion would impair seriously the produc- tive capacity of the well.) and the full productive capability of well No.5 cannot be utilized. Presently, its safe productivity is established at 550 MCFD (550,000 cubic feet per day) as a result of the presence of water during a flow rate of 700 MCFD. Thus, the maxi- mum safe productive flow rate of 1.6 MMCFD can be handled only by well No.6. 1.14 The combined or total safe capacity of the 3 existing gas wells is 2.6 MMCFD. The total peak demand in 1969 should approximate 2.3 MMCFD. 5 . . 1.15 The head of each gas well with necessary valves, lubricating tanks, Chiksan swivel joints and piping is enclosed in a small building equipped with an explosion-proof electric heater and lights. 1.16 Gas is transported from each gas well at wellhead pressures through 2-1/2" threaded and coupled pipe lines (x-strong tubing, 2.441" ID, EU, 6.5# API Seamless, 8 RD T&C, J-55, R-2) to the control and treat- ment plant. These gathering lines are supported about 3 feet above the surface of the ground by brackets welded to pipe poles and pro- vided with expansion loops. 1.17 The control and treatment plant consists of a pressure reducing sys- tem, Willis "L" type rotary adjustable flow beans for controlling amount of flow from each gas well, lubricating and odorizing facil- ities housed in a single structure. A conventional dehydrating plant, one normally utilized in gas production and treatment systems, is not fully a part of the equipment handling the moisture and/or hydrate problems associated with natural gas. The gas from each well, under a pressure of approximately 950 PSIG, is simply piped to indi- vidual separators (tanks) containing a supply of denatured ethyl alcohol. Some of the alcohol from the separators also entrains with the gas to facilitate the operation of two sets of regulators which reduce the pressure in two ~tages (950-500-200 PSIG) for a transmis- sion pressure of 200 PSIG. (The regulators are enclosed in explosion- proof electric heating units to inhibit freezing.) Traps located along the transmission lines to the Point Barrow base camp and Barrow serve to contain the heavier hydrocarbons for periodic b1owdowns. 6 . . Odorizing equipment, located on the transmission main, is housed separately in an annex adjoining the control house, and the gas odorant (Mercaptan) is administered to the gas through a manual con- trol valve. 1.18 The electric power house consists of 3 electric power units; namely, a 75 KW prime mover (natural gas-fired G-13000 Caterpillar engine), a 50 KW electric set (oil-fired D-8800 Caterpillar engine) and a 35 KW Kohler electric plant (natural gas-fired Waukesha engine) located in separate, adjoining buildings about 125 feet from the control and treatment plant. Present load is 35 KWH. 1.19 The operator's quarters are located in the same building housing the 35 KW Kohler electric plant. Communications to the Point Barrow base camp are provided through radio and telephone. Adjoining the opera- tor's quarters is a garage for housing a vehicle. 1.20 At the Point Barrow base camp 93 buildings, including Arctic Research Laboratory buildings, are served by natural gas. A total of 30 Dravo or National Champion heating units of 400,000-800,000 BTD capacity, fitted for conversion to fuel oil, supply primarily the heating re- quirements of the warehouses, shops, fire station, airport hanger and Arctic Research Laboratory buildings. In addition, two 200 HP boilers in the stem plant, fitted for conversion to fuel oil, are gas-fired; two 128 HP Waukesha engines in the water distillation plant are gas- fired; three 495 HP Cleveland marine engines in the electric power house, fitted for conversion to fuel oil, are gas/oil-fired; a 675 KW turbine power plant is gas-fired. (The old Arctic Research· 7 . . Laboratory buildings are heated partially by gas and partially by steam with a sewer line utilidor to these buildings containing a steam trace and supply line; the new NARL building is supplied gas fuel for heating and other purposes.) 1.21 At Main Station POW six electric power plants (60 KW generators) are gas/oil-fired; one Dravo of 400,000 BTU capacity located in the ga- rage and two Dravos of 1,000,000 BTU capacity located in the airport hangar, fitted for conversion to fuel oil, are gas-fired. In addi- tion, a FECO airport building is equipped with a gas-fired furnace that is fitted for conversion to fuel oil. 1.22 All the government agencies in Barrow, i.e., BIA complex, Alaska Native Service facilities, U. S. Weather Bureau, National Bureau of Standards, are served with natural gas. The Bureau of Indian Affairs controls the transmission pipeline from the South Barrow gas plant to Barrow and provides distribution service to various government agen- cies. BIA also operates a power house and the electric power plants, including a 750 KW turbine plant, are gas-fired; their water distil- lation plant incorporates gas-fired engines. 1.23 Barrow Utilities, Inc., distributes gas to approximately 300 commer- cial and residential buildings in the Barrow-Browerville area. BUI also provides gas service to the old BIA School, U. S. Weather Bureau and National Bureau of Standards. 1.24 Fifty per cent of the gas consumption is by the military, thirty per cent by other government agencies and twenty per cent by the non- government agency. 8 . . 1.25 The Point Barrow base camp contractor, under the Air Force, is re- sponsib1e for initiating monthly natural gas system reports and providing therein non-government gas consumption data for the Director of the Office of Naval Petroleum and Oil Shale Reserves, Washington, D. C. Barrow Utilities, Inc., the sole non-government utility using natural gas, is invoiced by the Office of Naval Petroleum and Oil Shale Reserves prior to the 15th of the month following each month's report of non-government gas consumption as read from the master meters' indexes and determined by the contractor on the last day of the month. The contractor is also responsible for the proper calibration of the "Emcorector" and "Temcorector" of the master meters and measurement and quality tests to insure the accuracy of the metering devices and correctness of reports on non-government consumption data. (Seals are maintained in place on all emergency by-pass valves upstream of the master meters in the non-government gate stations.) 1.26 Gas analysis, gas well No.5: Methane Ethane Propane Nitrogen Argon He lium Carbon Dioxide 97.8 % 0.9 % 0.2 % 1.0 % Trace 0.033% 0.1 % Calculated gross BTU/cubic foot, dry at 600 F and 30" mercury: 1,012 Spec ific gravity: .5659 1.27 Gas analysis, gas well No.6: Methane Ethane Propane Nitrogen Argon 97.9 % 0.9 % 0.1 % 0.9 % Trace 9 . . Helium Carbon Dioxide 0.032% 0.1 % Calculated gross BTU/cubic foot, dry at 600 F and 30" mercury; 1,010 Spec Hic gravity: .5639 1.28 Gas analysis, gas well No.7: Methane Ethane Propane Nitrogen Argon Helium Carbon Dioxide 98.1 % 1.1 % 0.1 % 0.6 % 0.0 % Trace Trace Calculated gross BTU/cubic foot, dry at 600 F and 30" mercury: 1,016 Spec Hic gravity: .563 1.29 A minimum of three eight-hour shifts is required for the daily oper- ation of the gas plant, transmission and distribution systems at the Point Barrow base camp and Main Station POW, i.e., an operator-foreman and two operators. 1.30 The gas plant personnel are employees of Holmes & Narver, Inc., the contractor. 10 . . the Project Engineer so that remedial action may be initiated and, if necessary, all agencies affected may be notified promptly. 2.6 No repairs shall be attempted while gas lines or equipment are under pressure. 2.7 Clothing, tools and other miscellaneous items shall be stowed in a proper place and not hung or laid over piping, valves, switches or equipment. 2.8 Work areas and aisles shall be kept clear at all times. 2.9 Loitering of persons not concerned with the operation or maintenance of the plant is prohibited. 2.10 Caution. All light bulbs inside and outside gas well No.5, gas well No.6, gas well No. 7 and the control and treatment plant are sealed in explosion-proof protectors. Whenever a light bulb is to be re- placed at any of these buildings, the power supply to the building must be turned off. 2.11 Warning. The pole lights to well No.6 extend above the high volt- age (2,300 volts) power line. The operator on duty shall not attempt to replace lights bulbs in this area; this job is the responsibility of a lineman. 2.12 Warning. In the event of a fire inside or outside gas well No.5, gas well No.6, gas well No.7 or the control and treatment plant, the following procedure shall be adhered to: A. Call the Fire Department immediately through the radio located 12 . . in the vehicle or via the radio (Call "Base 1".) or telephone (1 long ring) located in the operator's quarters. B. Shut down the power supply to the building on fire at the switch panel located in the operator's quarters. C. In the event communications are ineffective, drive the vehicle to the Point Barrow base camp Fire Department to report the fire and then notify the Foreman-operator. WARNING. DO NOT GO NEAR OR ENTER THE BUILDING AT ANY TIME IN AN ATTEMPT TO EXTINGUISH ANY FIRE. D. Provided communications are effective, attempt to isolate the gas flow from any gas well on fire or to and from the control and treatment plant should it be on fire by closing the valve/ valves located on the gathering and/or transmission pipelines distant from the building/buildings on fire. Note: Transmis- sion pressure may be maintained for a time from one gas well in the event of a fire at a gas well and/or the control and treat- ment plant by operating a by-pass on the gathering lines and a manual control valve on the transmission line distant from the fire. 2.13 Warning. In the event of a fire inside or outside the power plant structures, operator's quarters or garage, the following procedure shall be adhered to: A. Call the Fire Department immediately via radio or telephone from the operator's quarters, if practical. (Note: Escape from the operator's quarters may be made through the front entrance or by way of the rear doors leading to and from the toilet, and a 13 . . ladder is attached to the building outside the toilet should heavy snow drifts block a path leading from the building.) B. Should the operator's quarters be on fire, remove the vehicle from the garage, if practical, and use its radio to call the Fire Department. C. Shut down the power supply to the building/buildings on fire, if practica L D. Shut dow the gas supply to the building/buildings on fire. Note: A 1" master gate valve is located 100 feet upstream of all the buildings which, upon closing, will shut off the supply of gas to all the buildings. E. Make use of available fire extinguishers located in all build- ings to fight the fire, if practical. Always be sure of an available escape route. F. Should all communications fail, follow steps C, D and E and then drive the vehicle to the Point Barrow base camp Fire De- partment to report the fire and notify the Foreman-operator. G. In the event all communications fail and the vehicle is unob- tainable, follow steps C. D and E and remain on duty, if practical. Failure of any operator to return to the base camp at his appointed time would prompt his relief to obtain other transportation and investigate. 2.14 Any use made of any fire extinguisher shall be reported immediately via radio or telephone to the Fire Department and then to the Foreman- operator, 2,15 When using the gas well vehicle, it is the duty of each operator to 14 . . maintain radio contact with the base camp as per instructions. 2.16 A daily log shall be kept of the operation and maintenance of all gas plant facilities. The Foreman-operator shall be responsible for main- taining the daily logs and notifying the Project Engineer as noted under 2.5. 2.17 Operators should maintain a "flagged" road to the gas plant facili- ties, attach a drag to the vehicle when necessary and feasible while traveling to and from the plant. 15 . . 3. OPERATING AND MAINTENANCE INSTRUCTIONS 3.1 Experience has demonstrated that during high productive rates of flow in the winter months each gas well must be blown down at least once a month, preferably twice a month. However, any sudden decline in well head pressures necessitates an immediate blowdown. A lubri- cant, denatured ethyl alcohol, should be administered through the tubing (5-10 gals) and casing (20 gals) to clean the perforations, help dis- integrate any ice-bridging effect, and minimize plugging of the tub- ing as a result of formation of hydrates during the blowdown. 3.2 During the summer months when lower rates of flow prevail, less fre- quent blowdowns are normally required. In any case, each well under production must be given a blowdown at least once every six weeks to determine presence of water and the well's condition by noting primarily the response of the casing pressure during and after blowdown i.e., the degree of smoothness of the pressure in declining and increasing toge- ther with its rapidity. If the pressure is erratic or hesitant in de- clining during blowdown or slow (6 minutes or longer) in building back to its normal static pressure reading after blowdown, a subnormal condi- tion is indicated requiring use of denatured ethyl alcohol, further blow- downs and other measures. 3.3 It is permissible to blow down either well or lubricate the tubing while the well is under production; however, since production is taken from the 7" casing, it is necessary to shut-in the well when lubricating the casing (allow at least 20 minutes after lubrication for the alcohol to "work" to the bottom of the well bore) or resorting to measures re- storing either well to a normal condition. 16 . . 3.4 Well No. 5 and Well No. 7 must handle the full load requirements while Well No. 6 is shut-in for treatment. Since high withdrawal rates from Wells No. 5 and and No. 7 for any protracted period of time will result in water encroachment, Well No. 6 should not be shut- in for more than 25 minutes after lubrication. 3.5 The following procedure shall be observed in blowing down a well: A. Close Nordstrom valve (2") located on top of tubing head. B. Bleed gas from 1/2" or 3/4" needle valve to relieve pressure from tubing gauge. C. Remove tubing gauge. D. Remove 2" half union from tubing head. E. Install and secure blowdown extension pipe with its half union on the tubing head by inserting pipe through opening in roof of well house. F. Start blowdown by opening fully 2" Nordstrom valve located on top of tubing head, same valve noted under "A". G. Note reaction of casing pressure and time check initial discharge of gas, lull time (if any), discharge of fluids, discharge of gas after fluids have been emitted. CAUTION: DO NOT CONTINUE THE BLOWDOWN AFTER FLUIDS HAVE STOPPED. FLOWING IN AN ATTEMPT TO COMPLETELY CLEAR THE VAPOR AS FREEZING AND PLUGGING OF THE TUBING CAN RESULT. H. Close 2" Nordstrom valve noted under "A" to terminate blowdown. I. Remove extension pipe and close opening in roof. J. Replace mounting including tubing gauge and open 2" Nordstrom valve. 17 . . Ko Time check restoration of tubing pressure and casing pressure. L. Record results in daily log. 3.6 Under present well head pressures, a discharge of alcohol from a well will result for a time interval of 2-4 seconds based on a use of 20- 30 gals of alcohol for lubrication. Therefore, emission of fluids for more than 4 seconds under the conditions noted will indicate a degree of water intrusion and a "dry" blowdown, that is, one without the use of alcohol, should be effected to confirm the indication. 3.7 The presence of water in any well calls for immediate action to re- duce production from the well through use of a smaller orifice in the well's Willis adjustable flow bean. 3.8 If demand requirements will not allow curtailment in production from a well suddenly showing signs of water encroachment, con,tinued pro- duction will result in greater water intrusion and eventual loss in the productive capacity of the well. 3.9 To effect reduction in production, demand may be lessened by having certain gas-fired equipment of all agencies converted to use of fuel oil until such time as demand subsides from peak load requirements. 3.10 The condition noted in 3.9 would require an immediate study of future demand to determine the need for drilling another gas well. 3.11 The gas from each well passes through an individual separator in the Control and Treatment Plant at approximately 950 psig. Each separator is equipped with an external alcohol reservoir of five gallons capacity which, during high rates of flow, shall be filled 18 . . twice a day, and the separator blown down twice a week. The smooth- ness of gas flow through the regulators will govern normally the amount of alcohol that should be used. 3.12 The alcohol level in No.5 separator shall be maintained between the two try-cocks while a half full level in the gauge glass shall be kept for No.6 and No.7 separators. 3.13 A tank of 1,100 gallons capacity is located by the Control and Treat- ment Plant. The level of the alcohol must be checked every two weeks and filled from drums through use of a hand pump whenever the tank indicates a half-full level. 3.14 The hand pump that is used inside the Control and Treatment Plant for administering alcohol to the lubricators has a gate valv.e installed below the pump. This valve must be closed after using the pump to insure against loss of alcohol from the outside tank. 3.15 Volume production from a gas well is controlled through the use of each well's Willis adjustable flow bean located in the control piping system downstream of the separators and directly upstream of the regu- lators. 3.16 A full range of bean orifice sizes from 3/64 of an inch through one inch in 1/64 of an inch increments is provided. 3.17 Each Willis bean has six slots and each slot contains an orifice of a different size which may be rotated into the line of flow. To in- sert an orifice of a different size into the Willis bean, proceed as follows: 19 . . A. Tighten flow plug "A" and open bleeder valve. B. Push inward the red colored pin in loading plug "c" and make a 1/4 turn in either direction, clockwise or counter- clockwise. (Note: Insure plug is in positive stop.) C. Remove loading plug "C". D. Pick out old orifice insert and slide in replacement. E. Replace loading plug "c" and make a 1/4 turn. F. Close bleeder valve. G. Crack open lock screw "A" and red colored pin in plug "c" should "pop" out to its original position. H. Tighten lòck screw "A". 3.18 To rotate bean to an orifice of a different size, proceed as fol- lows: A. Bleeder valve closed. B. Loosen lock screw "A". C. Rotate shaft "B" clockwise until desired orifice is slightly past "Flow Line" mark. D. Rotate shaft "B" counter-clockwise to positive stop at "Flow Line" mark. E. Tighten lock screw "A'.'. 3.19 Well No.5 is restricted through use of orifices ranging from 13/64" (summer) to 16/64" (winter) which allow presently approximate rates of flow from 280 MCFD to 580 MCFD. During the winter months, Well No. 6 is restricted through use of a 20/64" orifice which will limit the flow to 2.0 MMCFD but normally provide for a flow considerably below 1.6 MMCFD when producing with gas wells No. 5 and No.7. Well No.7, 20 . . under critical flow, is limited to a flow rate of 400 MCFD through use of a 9/64" orifice. 3.20 The rate of flow through an orifice choke under critical flow condi- tions i.e., upstream pressure is greater than twice the downstream pressure, is governed primarily by the pressure drop across the ori- fice and gauges are installed for this purpose. However, since the upstream pressure is not greater than twice the downstream pressure, normally, use of pressure valves upstream and downstream of the ori- fice, a Willis correction chart, and a Willis bean size Estimator (computer) will determine the approximate rate of flow. Instructions are located on the wall inside the Control and Treatment Plant. 3.21 Once the gas flows through the orifices, the gas from Well No. 5 and Well No. 6 combines and flows through two sets of regulators. For flexibility and emergency purposes, valves are available in the con- trol piping system to separate the gas flow from each well immediately downstream of the orifice and through separate regulators and/or a man- ually operated Shaffer by-pass valve. Well No. 7 has a lower wellhead pressure than Nos. 5 and 6 while producing (800-830 psig). Therefore, this well flows through a separate regulator or under critical flow to place the well under controlled production for transmission. 3.22 Each set of regulators is adjusted to reduce the pressure in two stages, that is, from an inlet pressure of approximately 950 psig to 500 psig and then from 500 psig to a transmission pressure of 200 psig. Through step-down pressure reduction and use of two sets of regula- tors, regulatory control is enhanced and chances of "freezing" at the orifices of the regulators are lessened. 21 . . 3.23 The regulators are equipped with I1Paracril" cold weather type dia- phragms, and any failure in the diaphragms will shut down the reguT lators. The first stage regulator with an inlet pressure of 950 psig and an outlet pressure of 500 psig along with a 1-1/211 orifice has a maximum capacity of 9,000 standard cubic feet per minute; the second stage regulator with an inlet pressure of 500 psig and an outlet pres- sure of 200 psig along with a 1-1/2" orifice has a maximum capacity of 5,000 standard cubic feet per minute. 3.24 Each set of regulators is housed in a sheet metal enclosure equipped with two 2 KW Electromode explosion-proof heaters. The heating units are thermostatically controlled by Crouse-Hinds explosion proof controls (thermostats), and the correct temperature for the regulators has been established at l20oF. (Explosion-proof circuit breakers are located outside the Control House on the east side of the building.) Occasion- al minor adjustments of the regulators, which are dome (pressure) loaded, and the sheet metal vents are necessary when pronounced changes occur in the rate of flow. 3.25 A relief valve is located in the Control House on the transmission line immediately downstream of the regulatory controls and set at 275 psig. 3.26 The Control House is heated by Electromode explosion-proof heaters. Total rated output, 24 KWH. 3.27 All Nordstrom valves in the system are equipped with grease and stem packing fittings. Valves used at any time shall be lubricated by turning the lubricating plug clockwise until pressure is noted, and the lubri- cating plugs may be removed while the valves are under pressure to 22 · . insert additional sticks of lubricant. All valves shall be lubricated once during the summer months with "Nordosea1ll No. DC-234-S, minus 400F to plus 4000F valve lubricant or approved equal. 3.28 All Chiksan joints shall be lubricated once during the summer months with Type No. 7 non-fibrous Chiksan lubricant. 3.29 All pressure gauges shall be calibrated for accuracy periodically, at least once during the summer months. A Crosby dead-weight tester is located in a cabinet inside the operator's quarters. 3.30 A Fisher Wizard, series 4100-U, automatic shut-down control is located on a panel board at each gas well. The control actuates a Fisher con~ troller located on the flow line off the well head. In the event of a rupture of a flow line from a well, the Fisher controller at the well will close automatically. 3.31 Each Wizard control is equippéd with a pressure control knob for ad- justing the controlled pressure point and a proportional band for selecting the desired range of control. 3.32 If the controller for any line closes, the line must be inspected for breaks and repairs completed before reopening the control valve. To restore a line to service after repairs have been completed, proceed as follows: A. Open the by-pass valves around the controller at the well and build-up line pressure to the normal operating pressure of the line affected. B. Hold down the reset button on the panel board for the controller affected until the pressure gauge on the panel board indicates 23 . . 17-18 psig, at which time the Fisher controller will open and the gauge on the panel board will increase to the system pressure of 22 psig. C. Close the by-pass valves at the well. 3.33 The Wizard controls shall be tested once during the summer months. To test the controls of a well, proceed as follows: A. Shut down the gas flow of the well to be tested downstream of the separator and, if necessary, by-pass the Willis bean/beans of the other well/wells to maintain demand requirements. B. Shut-in the well at the well head upstream of the controller. c. Bleed the gathering line pressure of 950 psig from the 1/2" needle valve downstream of the Wizard connection öff the well head piping. System pressure of 22 psig at the panel should decline to zero pressure and the controller should close when line pressure of 950 psig declines to the percentage value of the set pressure as indicated by the setting of the proportional band. D. Close the 1/2" needle valve and open by-pass valve/valves at well head to build up line pressure to 950 psig. E. Reset as noted under 3.32, B. Controller should open. F. Open valve upstream of controller at the well and close by-pass valve/valves. G. Open valve downstream of the separator to resume production from the well, and close by-pass valve/valves of the other well/wells. 3.34 The Control House can be isolated from the system and production main- tained for transmission through operation of a by-pass on the gathering line and a manually operated Shaffer bean valve located on the trans- mission line approximately 150 feet downstream of the Control House. 24 . . In the event manual control is necessary, extreme caution must be exercised to prevent excessive build-up of pressure in the trans- mission main. 3.35 In the event any gathering line leading from any well to the Control and Treatment Plant becomes plugged as a result of formation of hy- drates, the condition can be relieved or eliminated through a re- duction of pressure in the line affected and/or use of denatured ethyl alcohol through the lubricating tank located on the flow line off the well head of each gas well. 3.36 The odorizing equipment is housed separately in a wing of the Control and Treatment Plant and located on the transmission main. The tank of 15 gallons capacity shall be filled with Ethyl Mercaptan or ap- proved equal whenever the glass level indicates a minimum supply. A needle point, throttling valve and sight glass flow indicator are located on the outlet of the tank. A flow shall be regulated man- ually from 8 to 17 drops per minute on the basis of one drop per min- ute per 100,000 cubic feet of production. Should alcohol be added to the odorizer to inhibit freezing, the flow rate should be altered ac- cordingly. Daily checks by the Foreman-operator shall be made at the gate stations located at the Point Barrow base camp and Main Station POW to insure proper odorization of the gas. 3.37 Four traps with drain valves are provided on the transmission line to the Point Barrow base camp and shall be blown down every two or three days during the winter months, as required during the summer months. 25 . . 3.38 Auxiliary power plants shall be started and placed in service at least once every two weeks to ascertain their condition. 3.39 Oil changes and lubrication of engine accessories shall be accomplished at 300 hours of running time. Routine maintenance of engines and lubri- cation of generator and exciter bearings shall be required and accom- plished as prescribed in "Operation and Maintenance Instructions" man- uals. 3.40 A daily power plant log shall be maintained as per instructions, and the Foreman-operator shall submit a power plant log monthly in dupli- cate form to the Project Engineer. 3.41 An adequate supply of alcohol, diesel fuel, lubricating oil, gasoline, solvent and grease shall be maintained at the plant. 3.42 Storage space is available in each power plant building for drums and/ or cans of lubricating oil, solvent and grease. Minimum supplies shall be on hand at all times through withdrawals from outside storage. 3.43 The Foxboro flow meters and/or regulators, located at the Point Bar- row base camp, power plant, and Main Station POW gate stations shall be operated and maintained by the Foreman-operator. 3.44 Foxboro flow charts shall be changed daily and the daily charts from the BIA gate station shall be secured weekly. 3.45 All Foxboro orifice meter charts shall be computed by the Foreman-oper- a~or in accordance with principals and practice of flow meter engineering set forth by Foxboro and Gas Measurement Committee Reports Nos. 2 and 3 of the American Gas Association. Charts shall be filed for reference. 26 . . 3.46 The Foreman-operator shall obtain meter readings on the last day of the month at the non-government gate stations in Barrow-Browervi11e. He shall perform the duties outlined under paragraph 1.25. 3.47 Inspection and repairs of all regulators shall be initiated by the Foreman-operator, and it is his duty along with qualified operators to perform the work. 3.48 The Foreman-operator shall maintain necessary supplies and equipment and determine the availability of material essential to the operation. 3.49 It is the duty of the Foreman-operator to inspect periodically all natural gas facilities and make recommendations to the Project Engin- eer. Andrew F. Crane Gas Plant Foreman 27 ~,. -\'''''''\\ ,r""~.; (ì ¡:." "7' i.~ " \, , ;.. ~ ..~..\:~:........,-;._.>~.., Ii:. '.,'.' l ....,,', ~. (,-, .... ~!~,.~.. ·...V, : · ,: ,..'4. ", ~ ) ... ... , . ~ ï ,{ti ¡~1'.: ~.~X;'·ý':j.'fXJ!~ri;. ~y , .' .......... . J, ,., ,_. \... ·14 '..,.,...." "V" ";:".- 'f- ....::0. '". '- .," t _ - :. J./ \,<y.,.p... .,. <,<!)." ·.loJ ,..,. ..~...,J," "#'o':'.~.., '''Tt.. (" 0° ..... ,_. t..:.:..,.'.~. .....··,ot,!.)· , " .. "/f) '.' ~ \ t l' \'-.. .' ,': .'. .- . -...........,..... . _ J ·--.,-·"··"-··--7___'·...·-.···· " . . Naval Petroleum Reserve No. 4 Barrow Gas Field Engineering Report on Gas Reserves and Future Prediction for Recovery of Natural Gas from the Barrow Gas Field, Barrow, Alaska """--''''.-,..,,,,~," ,'20 ~ /9.. O. R. ERFI Commander, CEC, USN Petroleum Engineer . . Barrow Gas Field Reservoir Study Introduction: A reservoir engineering study was conducted on the Barrow, Alaska gas field to determine the amount of gas' initially in place, the re- coverable gas reserves, and a prediction of future recovery based on past pressure and production history and related to current and future production rates. The reservoir parameters used for the study are listed in enclosure (1). A volumetric gas balance was conducted on an IBM 7094 computer using a computer program developed by Commander O. R. Butterfield, CEC, USN. This program uses the water influx equa- tion published by William Hurst and contained in various petroleum engineering texts. Initial gas in Place: The quantity of gas initially in place in the reservoir (G) was de- terminedto be 27.5 billion standard cubic feet of gas. This value was calculated from a seventeen year production history and balanced with a least mean squares curve fit to the pressure history of the field~ The curVe fit was obtained with a maximum of 2% deviation from the mean calculated (G). Reserves: With due consideration given to the water influx expected into the reservoir and based on current rate of consump~ion the recoverable gas was calculated to be 17.7 billion SCF ofthi~ amount 2.7 billion SCF. . . had been produced prior to June 30, 1966, the cut off date for input data for the study. Future Prediction for Gas Recovery: A prediction for future gas recovery has been included as enclosure (2). This prediction is based on the values given above for initial- gas-in-place, recoverable gas, current rate and production to date. At a rate equivalent to the current producing rate it is seen that the re- servoir will be completly intruded by water within thirty years. It is expected that the reservoir pressure will not drop below 850 psia, but the wells will be flooded out at that time. An increase in production rate caused by increased gas consumption at Barrow will result in com- mensurate shortening of the productive life of the field. 2 . NAVAL PETROLEUM AND OIL SHALE RESERVES l'\,~¡~Ri..)h' GAS FIELD NPR .It. " ~ßASE. PRESSURE BASE FOR STANDARD CONDITIONS. . = INC.CURRENT NUMBER OF PRODUCTION INCREMENTS. . = ~,\/\\. m:~mE.R OF PRODUCING WELLS AT ANY TIME .. = G~tFORMATION VüLUME FACTOR FOR WATER IN ßßL/STß = (C't\V,5CF OF VAPOR PER BARREL OF CONDENSATE .,. = R!_EFFLCTIVE RESERVOIR RADIUS IN FEET. . . . . = Ot~'TfhSU05l:A RE,SERVOIR DATUM IN Ft::ET. . . . . . = TG'P. RESERVOIR TEMPERATURE IN DEGREES RANK INE . = PC,PSEUDOCP.ITICAL PRESSURE IN PSIA. . . . . . . = TC,P~tUDOCRITICAL TEMPERATURE IN DEGREES RANKINE= 5GI,INITIAL GAS SATURATION AS FRACTIoN. . . . . = O,PCkOSITY AS FRACTION. . . . . . . . . . . . . = ^H,AVERAGE THICKNESS OF RESERVOIR IN FEET . . . = SG.SPECIFIC GRAVITY OF WET GAS. . . . . . . . . = U,VISCOSITY OF AQUIFER WATER IN CENTIPOISE .. = AK.WATER PERMEABILITY OF AQUIFER IN DARCIES . . = TIME,DALANCE INTERVAL IN DAYS . . . . . . . . . = SGR,RESIDUAL GAS SATURATION AS FRACTION. . . . = S~C,CONNATE WATER SATURATION AS FRACTION. . . . = MAX. PERCENT DEVIATION FOR BALANCE. . . . . . . = LI~ITtMAX. NUMBER OF.. ITERATIONS FOR BALANCE. . = ~^VA~ PETROLEUM AND OIL SHALE RESERVES ~ARRüW GA5 FIELD NPR 4 . 14.650 35 2. 1.00.0 83.1 3725.0 2377.0 525.0 671.4 344.9 0..750 0..145 40.0 0.5646 1.000 0..0.04 182.5 0..350. 0..250. 2.0 80 ._ .~"..W'.' .... ... T I;,¡E PRESSURE Z 6G,BBL/SCF DEL BG RES. WITH..BßL 0 10B6.000 0.8525199E 00 O.2067847E-02 O. O. 1 1084.900 0.S526356E Co. 0.2070225E-02 0.2377637E-05 0.6797637E 05 2 1033.400 0.8S27936E 00 O.2073476E-02 0.S628128E-05 0.1679266E 06 3 1082.300 0.8529097E 00' 0.2075865[-02 o.a017902E-05 O.2566402E 06 4 1080.300 0-.8531209E CO- d O.20eOZ23E-02 O.12376C3E-04 o..4071350E 06 5 1078.700 0.85329CIE CO 0.2083722E-C2 o..1587483E-04 0.539b537E:: 06 6 10.76.90.0 C.85348o.7E CO. 0.2087672£-02 0.19S2404E.-o.4 0.6910148E C6 7 1075.600- 0.8536166E 0.0 0.2090532E-02 0.2268498[;-04 o..826ü794E 06 8 1074.500 0.853'1354E 00. Oe2o.929:ï9E-02 0.2511145E-04 0.9464502E 06 9 10'74.700. 0.8537142E 00 0.2C92517E-02 O.2466986E-04 0.9839210E 06 10 1015.400 0.8536399E .0.0,_ _ C. 2090913E-02 0.2312579E.-o.4 o..9b32002E 06 II 1075.100. C.8536717E 0.0 0.2091635E-02 0.2378726E-04 o..I040260E 07 12 1073.700 0.8538205E 00 0.209'.727E-02 o..2687945E-o.4 o..1161615E 07 13 10'12.700 0.8539268E 0.0 0.2096941E-C2 0.2909335£-04 o..1283953E 07 14 1011.700 0.85'.0332E 0.0 0.2099159E-02 0.31311 65E-04 O.1406937E 07 15 1071.100 0.8S40912E 00 0.210C492E-02 0.3264475E-04 0.1503459E 0.7 16 1069.900 0.0542251E 00 0.2103163E-02 0.3531569£-04 o..1633334E 07 17 1069.100 o..aS43104E 00 0.2104947£-02 0.3709967E-04 o..1746SJ40E 07 ¡8 1068.0.00 0.8544279E 00 0.2107405E-02 0.395574CE-04 0.188o.'t97r-: 07 19 1067.300 o..8545027E 00 C.2108972E-02 O~4112421E.-04 o..1992785E 07 20. 1066.200. O.8546204E 00 0.2111438E-02 0.'.359C73E-04 o..2146334E 07 21 10.65.200 0.8547274E 00 0.2113685E-02 0.4583760E-04 O.2277573~ 07 22 , 1063.400_ .0.05492C3E 00 0.2117741E-02 0.4989328E-04 C",2473'>38E 07 23 1062.000 0..8550705£ 00 0.2120905E-C2 0.S3C5765E.-04 o..2653312E 01 2 it 1060.400 0.8552425E 00 0.212'.532E-02 O.5663501E-04 0.2G53939E 07 ~nclosure 1 . . 25 1059.000 0.8553931E 00 O.2121716f:-02 0.5986833E-04 O.3028739E 01 26 1051.200 O.S555871E 00 0.2131622E-02 0.639742U:-04 O.324C)668E 07 27 - 1055.500 ... 0..8551705E 00 ().2135713E-02 0.6786556E-04 O.3460300E 07 28 lO~3.500 0.85590671: 00 O.2140308E-02 O.72460~6E-04 O.36972!i5E 07 29 1051.600 0.8561924E 00 0.2144690E-02 O.7664290E-04 O.3926f14/tE 07 30 1049.200 0.8564527E 00 0.2150250E-02 0.82402201::-04 O.4205652E 07 31 1047.800 O.a566048E 00 0.2153505E-02 0.8565767E-04 0.4479115E 07 32 1043.000 0.8571276E 00 0.216473£'E-02 O.9688878t:-04 0.4936286E 07 )3 1039.100 _ _0.8575540E 00 0.2113942£-02 0.1060944E-03 0.536b'160[ 07 34 1033.100 0.8582121E 00 0.2188247£-02 0.1203998E-03 0.5910100E 01 L.~'¡.S. G.5CF= 0.27790467E 11 WATER INFL.UX CONSTANT= 8412.60424805 -. .- .. .-. TINE PRESSURE. DEL P WATER INFLtBBL PERIODIC G CHI< PERCENT DEV. 0 1086.000 o. O. " - 1 1084.900 1.100 O. 0.Z859009E 11 2.0773 2 1083.400 1.500 0.1l319Z0E 05 O.l782584E 11 0.1273 '. 3 108l.300 1.100 0.3301764E 05 0..2789041E 11 0.3596 / 4 ..1080.300 ,2.000 .. 0.S810903E 05 O.2820178E 11 1.4801 5 1070.700 1.600 0.9690421E 05 0.2789003E 11 0.3583 b 1076.900 1.800 0.1.c~09966E 06 0.Z!304766E 11 0.9255 ( 7 1075.600 1.300 O.1932442E 06 0.2793192E 11 0.5090 8 1074.500. , 1.100. 0..Z475130E 06 O.2783340E 11 0.1545 9 1074.700 -0.200 0.3035537E 06 0.2757889E 11 -0.7613 10 1015.400______ .~O. 700.... 0.3491551E 06. 0.2741723E 11 -:.3430 11 1075.100 0.300 O.3653126E 06 O.2753355E 11 -0.9245 12 1073.700 1.400 0.4258996E 06 0.·Z759412E 11 -0.7065 13 1072.700 1.000 0.4786155E 06 0.Z768114E 11 -0.3934 14 1011.700 1.000 0.5339808E 06 O.2781961E 11 0.3208 15 1071.100 0.600 0.5928304£ 06 0.2789509E 11 0.3765 16 1069.900 1.200." O.6509't68E 06 O.2781130e: II. 0.0966 1'7 1069.100 0.800 0.7161S-IlE 06 0.2718147E 11 -0.0324 13 1068.000 1.100 0.78191S1E 06 0.Z777176F: 11 -0.0673 19 1067.300 0.700 0.a526401E 06 O.Z172443E 11 -0.l376 20 1066.200 1.100 0.9230245E 06 0.2s06352E 11 0.9826 21 1065.200 1.000 0.9987116E 06 0.Z789982E 11 0.3935 22 1063.400 - -."-'---. 1.800. 0.1077125£ 07 0.2798198E 11 0.7107 23 1062.000 1.400 0.1166620e: 07 0.28020:HE 11 0.8271 24 1060.'tOO 1.600 0.1259424E 07 0.2a12939E 11 1.2196 25 1059.000 1.400 0.135a631E 07 0.2789625E 11 0.3806 26 ...1057.200 1.800 0.1461341E 07 0.2795388E 11 0.5080 27 1055.500 1.100 0.1572236C 01 0.2782063E 11 0.10B5 29 10S3.500 2.000 O.168853Y:- 07 O.2712160E 11 -0.2478 29 1051.600 _~J._. ___. 0.181333L 1.900 01 0.Z750435E 11 -1.0296 30 1049.200 2.400 0.194413L 07 0.2744491E 11 -1.2434 31 1041.800. 1.400 0.206610;, :, 07 0.Z793692E 11 0.!>210 32 1043.000 4.800 0.222653/, f, 07 0.2196766E 11 0.6376 33 1039.100 3.900 .. 0.240434(; ,: 0.2792428E 11 0.4815 07 - 3~__ _____t03}..1 º-º__.__.___ ~ .000 0.259~31:>L 07 O.2753648E 11 -0.9139 _ .u,..__ _ ____'~n._'_"______._ __,~.__ .<. _ _+. ~_. Enclosure 1 ~""_."_""_ _.....___._... . u.._. _._...__ .'. --_...-........._--_..~-_......._~.-._--~-,. '._" --.....-...--......- ~.- -.-.".. .... - .. ~. ~- -. - - .-- . . NAVAL PETROLEUM AND OIL SHALE RESERVES .BARROW GAS FIELD NPR4. TIHE PRESSURE Z 8C;,ßßL/SCF DEL BG RES. WITH. ,ßßL 0 1086.000 0.8S25199E 00 O.2067847E'.-02 o. O. 1 1064.804 .. .. O.8526394E 00 0.2070303E-02 0.2455170E-05 0.679"!9'..2E 05 2 1083.364 O.S527974E 00 0.2073553E-02 0.5705951E-05 0.1679329E 06 3 1082.264 0.85c29134E 00 0.2075943E'r'02 0.8095812E-05 0.2?66't<;9E 06 4 1080.264 0.8531246E 00 0.2080302E-02 O.1245429E-04 0.4071503E 06 5 1078.664 -' O.8532939E 00 0.2083801E-OZ 0.1595332E-04 O.539674CE 06 6 1076.864 O.8534846E 00 0.2087750£-02 0.1990283E-04 O.6970411E 06 .7 .1075.564 . ... 0.853622'..C .00.. 0.2090611E-02 0.2276397E-04 0.B26910'IE 06 8 1074.464 O.S531392E 00 0.2093038E-02 0.2519059E-04 0.94648601:: 06 9 1074.664 O.8531180E 00 0.2092SC)7f::-OZ 0.2474905E-04 0.9839532E 06 10 1075.364 0.8536437Ë 00 O.2091052E-02 O.23204"15E-04 O.9832373E 06 .._11 . 1075.064 0.S5367'55E 00 O.2091714E-02 0.2386636E-04 O.1040300E 07 12 1073.664 O.8538243E 00 O.2094806E-02 0.2695870(;-04 0.1167659E 07 ¡3 . .1072.664 --0..8539306£ 00.. O.2097020E-02 O.2917281E-04 O.12B4001E 07 14 1071.664 0.8540370£ 00 0.2099239E-02 0.3139119£-04 0.1406991E 07 15 1071.064 0.654101QE 00 0.21005"72C:-02 0.3272443E.-04 O.1503516E 07 16 1069.864 0.8542289E 00 0.21032/.3E-02 0.35395531:.-04 O.163339óE 07 17 1069.064 0.8543143E 00 O.2105027E-02 0.3717968E-04 0.1746907£ 07 18 1067.964 0.S544317E 00 O.21074U5E-02 O.3963755t:-04 0.IS80568E 07 19 . 1 0 (, 7. 264 ._ .0.8545066E 00. _ O. 21090~2E-02 0.4120456E-04 0.1992061E 07 20 1066.164 0.85't624ZE 00 .0.2111519E-02 0.4367117E.-04 0.Z146416E 07 21 1065.164 0.8541312E 00 0.2113766£-02 0.4591S25E-04 0.2277659E 07 22 1063.364 0.S549241E 00 0.2117822E-02 C.4997419E-04 0.2473632E 07 23 . - 1061.964 O.S550744E 00 O.2120986E-02 0.S313882E-04 0.2653413E 07 Z4 1060.364 0.8552463E: 00 O.2124614E~02 O.5676632E.-04 0.Z854048E 07 .___25 .-.--1058.964 O.8553970E 00_ .O.2127797E-Ol O.5994987E.-04 0.3028855£ 07 26 1057.164 0,,8555909£ 00 O,,2131904E-02 0.6405613£='-04 O.3249793E 07 27 1055.464 0.8557744E 00 O.2135195E-02 0.6794712E-04 0.3460433£ 07 28 1053.464 0.8559906E 00 0.Z140391E-02 0.7254307E-04 0.369739SE 07 29 1051.564 0.S561962E 00 0.21447731:-02 0.76-92564£-04 0.3926996E 07 30 1049.164 0.856~566E 00 0.2150333E-02 O.8248549E-04 0.4205815E 07 .31 1 047 .764. ._. 0.S566087E 00 _..:.0.215.3589E-OZ 0.8574114E-04 O.4419289E 07 .32 1042.964 0.8571315E 00 O.2164821E-02 0.96973031::-04 0.493641S1:: 07 33... 1 039.064. . 0.S575579E 00 0.2114027E-02 0.1061794E-03 0.5367169E 07 34 1033.064 O.8582166E 00 O.21S8333E-OZ 0.1204857E-03 0.5910932£ 07 L.r4.5, G,SCF= 0.Z7538074E 11._ .. WATER INFLUX CONSTANT= 847S.702880G6 TIME PRESSURE DEL P WATER INFL,BSL o 1086.000 O. 00 1 1004.864 1.136 O. _.- .2__._..1083.364... 1.500 ._ 0.1l779Ü7E 05 3 1082.264 1.100 O.3385447E 05 4 1080,264 2.000 O.S931481E 05 5 1078.664 1.600 O.985730~E 05 61016.864 ].,,800 0.14315771.: 06 7 1075.564 1.300 0.1959548E 06 8____._1074.464._______ 1.100.___ 0.25078 34E 06 9 1014.664 -0.200 O.3073927E 06 10 . _..1075,364.._....._-0.700. ..O.353/+768E 06 - --. .-.. _.. PERIODIC G CHK 0.216t3827E 11 .0.2736670E 11 O.2751983E 11 0.279289BE 11 O.2764947E 11 0.2782938E 11 O.2711730E 11 O.2761756E 11 O.2733703E 11 0.Z"f13930E 11 . Enclnsure 1 PERCENT DEV. 0.5454 -0.6223 -0.0663 1.4195 0.4045 1.0576 0.6508 0..2886 -0.7301 -1.4481 . . 11 1075.064 0.300 O.3900397E 06 0.2724587E 11 -1.0611 12 1073.664 1.400 0.4310641E 06 0.2732308E 11 -0.7801 13 ... " 1 O'7Z. 664..._. __1.000 ...0.4643102E 06 0.2-f41221E 11 -0.4570 14 1071.664 1.000 0.5402244£ 06 O.27("1111E 11 0.l676 15 1071.064 0.600 O.S996485E 06 O.2162056E 11 0.2995 16 1069.864 1.200 0.658331BE 06 0.2154767E 11 0.0348 17 1069.064 0.800 0.7241630E 06 0.2750614E 11 -0.1087 18 1067.964 1.100 0.7905'.75E 06 O.2749970E 11 -0.139ft . 19 1067. Z 64 _. __..____.._ 0.700.. . 0.B61930'tE 06 0.2744674E 11 -0.3317 ~O 1066.164 1.100 0.9329718E 06 0.2778593E 11 0.9000 21 1065.164 1.000 0.lOO9356Œ 07 I 0.2162090E 11 0.;008 22 1063.364 1.800 0.1088401E 07 0.2771721E 11 0.650S 23 1061.964 1.400 0.1178785E 07 0.27750S0E 11 0.7714 24 1060.364 1.600 0.127241BE 07 0.2786212E 11 1.1767 25 .1058.964__,.____1.400._ . .O.1372510E 07 0.Z762884E 11 O.j296 26 1057.164 1.800 0.1476U8E 07 O.Z16t!939E 11 0.5495 27 1055.464 1.700 0.15ß79ß4E 07 0.275·5721E 11 0.0695 28 1053.464 2.000 0.1705289E 07 O.2746105E 11 -0.2797 29 1051.564 1.900 0.1831163E 07 0.2724492E 11 -1.0646 30 1049.164 2.400 0.19b30B7E 07 O.2718937E 11 -1.2663 31 1047.764 1.400 0.2106270E 07 O.2767655E 11 0.S028 32 1042.964 4.800 0.Z247897E 07 O.l172504E. 11 0.6789 33 1039,064 3.900 0.2427203E 07 O.2768867E 11 0.5469 34 1033.064 6.000 0.2ó19162E 01 O.2731586E 11 -0.8070 . -_...._-_.__...~_.... _.. ... ..-----.-.-.-.---.-.--..-- ._. ----_._.__._~ -------.---....- -.-----.--.----..---- .-.-.-..:....--...-. ..~ ._--~ .-.. ..~_.. +....,. ... .-.-.-.....-----. - I ~ -.-..-..-._.. . -- ._-. . ._.. -.. ..._.-. --..- -." "'"'- ..-...- .-...............,.,........ ...--------.---------...------ ".. . --.-. - _.' _...--.- -- -.- .'..-.....- n_ "_",_ ._.__ _. _..._._______._____...._._._ .._'... _ ""'_." ___._. .._.._".._ _ 4"_ ______._ __.___.... ...---......--..-'..-.,.--..---.-----.-----......- ...- . . ._.. .._. _....._.. ·._u_.. ._~ ... ~ _...~ - . -.. ..-. - ".- ..~-_.._... --_.~. .-. .-...-. .- -.-..-. -. ..- ---..-.. -----~..--_...~_..- ..------...--....---..-- ~-_..-.-... . - .~....__.._._..--"---_. ..- _...._..._~. .n. "__.. _. __. _ .. __ _-__ _. _. _ .,.... -. ....-..-... ..-.- ...-...--....-.-..-...----..,,----. -..-.........-..-..- .- .-.. -..-....-... ." .... ..... ...~ .-. ~.._."...... ."-~ ,-_.... .. _ _h .~. _.__ __. ..... _ "__ Enclosure 1 -";--'. . . NAVAL PETROLEUM AND OIL SHALE RESERVES BARROW GAS FIELD_NPR_4 RESERVOIR PRODUCTION FOR FUTURE PERFORMANCE ÞREOICTION AVERAGE' DAILY DRY GAS PRODUCTION IN SCF . . AVERAGE DAILY CONDENSATE PRODUCTioN IN STS AVERAGE DAILY WATER PRODUCTION IN STB . . . I - · - 1400000.00 0,0'2 O.O!> · = · = INITIAL CONDITION$ INITIAL PRESSURE IN PSIA. . INITIAL GAS IN PLACE-IN SCF MAXIMUM FLOODAULt RESERVOIR INITIAL GAS COMPRESSI6ILJTY . . .. . . . . . - 1086.00 0,21538014E 11 30310420.0'0 0.8525199 - .. .. ., . . . . . . - VOLUME IN BARRELS = FACTOR. . . . . . = "." .~. _. FUTURE PREDICTION TINE PRESSURE .._.__ _., NET 'INFLUX... GP~'l DELTA P DRY GAS 35 1027.94 0,284821251: 0'7 0.29565340E 10 5.12 O'.29565309E 10 36 1022.61 0.30939655£ 0'7 0.32120343E 10 5.33 0.32120309E 10 37 1011.56 0.33601205E 0'1 0.34675346E 10' 5.05 0.3467S309E 10 38 10'12.10 0.36425583E 07 0.37230349E 10 4.86 0.372303091:. 10 39 1008.06 O.39397006E 07 O'.39785352E 10 4.64 0.391853C9E 10 .40 100'3.59 O.42499197E 0'7. 0.42340355E 10 4.47 O.423l.0309E 10 41 999.28 0.45722629E 07 0.44895358E 10 4.31 0.44895309E 10 .42 995.08____ 0.49058291E 07 0.47450361E 10 4.20 O.47450309E 10 43 991.02 0.S25O'2335E 01 O.50005363E 10 4.06 0.50005309E 10 h 44 987.04 0.S6046362E 01 0.52560366E 10 . .. 3.98 0.52560308E. 10 45 983.20 0.59689431E 01 0.55115369E 10 3.84 O.S511S3ú8E 10 ..____46 .___ 979.45. _ 0.63422072E 07 O.57670372E 10 3.15 0.57670307E 10 47 975.80 0.67242094E 01 0.60225374E 10 3.b5 0.60225307E 10 48 972.22- . - O.71144564E 07 0.627B0377E 10 3.58 O.62780306E 10 49 968.73 0.75126070E 07 0.65335380E 10 3.49 0.65335307E 10 - - 50 . _.965.33 0.79181908E 07 O.67890382E 10 3.40 0.67690306E 10 51 961.97 O.83320108E 01 O.70445385E 10 3.36 0.70445306E 10 52.__ ..958.69-__.. .O.a7525786E 01 0.7300038ôE 10 3.28 0.73000305E 10 53' 955.49 O.91199691E 07 0.15555391E 10 3.20 0.75555305E 10 .54 952.33___ 0.96138085E 07 0.·fSl10393E 10 3.16 O.·7811030'd: 10 55 949.22 0.10054225E 08 O.80665396E 10 3.11 0.80665305E 10 56 946. 1 7 _ . 0.10501018E 08 0.S3220390E 10 3.05 O.83220304E 10 57 943.11 0.10954015E 08 O.S5775401E' 10 3.0'0 0.S5775304E 10 _ 5fJ.__ 940.20 Q.11413110E 08 . O.aS3301t03E 10 _ 2.97 0.88330303£ 10 59 937.30 O.1l878219E 08 O.90a85406E 10 2.90 0.90885302£ 10 60 934.44 0.12348969E 08 0.93440408E 10 2.86 0.93440301E 10 61 931.64 0.12825355E 08 O.95995411E 10 2.~W O.95995300E 10 - . _ 62, . 928.85 ..... 0.13307064E 0.8 0.98550412E 10 2.19 0.98550300E 10 63! 926.12 0.13794366E OB 0.lO'l10541E 11 2.73 0.10110530E 11 ..__~.b4. __.._..923.42. _ , 0.14286815E 08 _ .n 0.10366041E 11 2.10 0.lO'J66029C 11 65 920.75 0.14784455E 08 0.106215l~2E 11 2.67 O.10621529t: 11 66. 918.15 0.152B1241E 08 0.10a770J~2E 11 2.60 0.10U77029E 11 67 915.55 0.15794661E 08 0.111325/,2E 11 2.bO 0.lll32529E 11 ó8. 912.96_ .. O'.16307110E 08 0.1138BO'·2E 11 2.59 0.113f\8029E 11 69 910.42 . 0.16824588E 08 0.11643542E 11 2.54 O.11643529E 11 70..__....__.901.92...__._.0.17346715E 08 - 0.11899043E 11 .... . .2. .50 0.11R990¿9E 11 71 905.44. .0.17813367E 08 0.12154543E" 11 2.4E1 O.1215452t;!:;; 11 72 ...... 902.98 _.,._.O.18404620E 0'8 0.12410043E 11 2.46 O.12410023E 11 Enclosure 2' f '---~. 7'3. 74 __75 76 77 78 79 80 61 û2 &3 ti4 85 H(' ~7 b8 L\9 90 91 C" ,c... 93 900.57 898.16 895.76 89:1 ~ 4·(: 891OJv9 888,,75 ÖS6",45 88/{qlB PR1~9.2 879$68 (J 17 ",48 £;7:;",24 8 ¡' 3 .. (I 7 870.37 H6tì.73 866.57 a 6'io,,4) 8621>30 860.18 Ü5::1eOi3 855.,~[1 . o~ lH9;\¡.Ol:¡55E ()J] t1~.194f~\) ?o£ on ()<JI;~002~:'!Cht: i)g O~20~5,'7¿'(,22 OF f) ~ 2, J 1. 2 f' f; ~.~ (~:':, ('~?XÓ~?'/M\;';:~5E Oß (¡$.~~22~·6¡)73E 08 O.2~'.HL~f:/j!:E 05 Qr~2.33tJ2 iE.08 01# 2 :3 9 5 " 1 ~:) /~ E Of::;, O.2453~).3i10t: OH ùot25H 1347F... 08 Ot<2570,3700E 08 0",,26293603£ 08 O.26!:'H3TflEJE 06 0.27:,3536.(;2, 08 0.21::087046£ on O!lZ86'?2.5¿4E 08 0.,l9301B2¿IE: oa 0" 2991 f;-960t 03 {)$30531789E OH ALL WELLS HAVE FLOODED our ," . .-.-. -_....~,..," - ·__·__..__.__,·.·.·_~·._u_ ...~...._~_.___~._.... _.. __. ._.__ ..___ - .....-.... ...... _. ...-.._-~...........~.. .-.-- .-...---.---.-.... ...... w.· ~..__~_.~_... ·._............_..__..w.__ ~_ .~._..... ~_... ._",. ___ '~_"_'''_~'_'_ ....." . ... '.- ...~...- '-'-" ...-.- -- .-..-......-....-..-.----....-,,-...-...--... ,.----.. ...... ,. ......- ..' - .. '- _.._---...- .........~... ...-.~. .-. ._..-...__......._----,.--..~ Encl~ ~u.r!t ~? (/;¡; 1266~;~¡i,Jr 1; 0;; 1,f.9~:~ lOt~':.~ ~ " ~...,... () ~., 1 :,~ I '7 Ô ::j (¡ .,:\ ~ 1, ~~ o ~ 13~Ji 2 ~)i*.~'~ r j, 1- {) ~·l J6~Ü 1. ~~i¡r-i~E 11 ()" }.3'9'~jCti¡i~C l1 C*àl¡-li)g::)_:'ttjE l,'~ () ~ lif i1 :~; it Q 4 Ii e' II Ü..l,'t709'>/,<3( tl o'~ tt+';t;:: ::r j, t ï:) ,. 1 ~.~ ? 0 ~J ~,~ t t 1 041 1ÔO"~ÓCi ¡ O~1)"1:315/t"~: u o ..159B7iJ't6E n O.lIJZ'.2~5:tcS 11 0.. ¡ 6(t9íì046E 11 O.1615Vj(.6f 11 Ú ~ P'()090'~ 7E II O.172645l~6E 11 O,,17520041E 11 0. 1n7554 7E 11 . "I:\' «'.1;. ~; ~í~ .~ ~ 'I! !.o ?,H, ...Jl ~d,ji ;r. ,)0 ~~ ~ :r::'¡r .2 ø ;~~ ~!¡ ;.~ ~~ ;,C ,;ft ~/; (J ~! ~'t ~í¡' ~~17 l.20 2d·4 2~f.b 2",14 2t\13 2.12 2.10 2.10 l ~ ¡ ¡ > 0_ t >~ ; L d 11 U ~1J,:~.':i ;* .:; .~i' i- ..." C. O",lÓ;;b7C),27ë. 11 o ;;', l ,~, ;¿: ¿f- .~~ 5 ~; "'t E :. 1 o ~ ll) ¿~. (} .~.~ 7 E 1 1 () ;,?, 1 -6 7:~:; 33 ¿ 7 ~, ',f O'i£ ;L 700S o¿ 70. 11 O,,112t)i~5.2ÓË 1.1 (L.17S2002'{,f. 11 O,~17-'7:;':j26L u ~~._-...: i , i .~JJ) . ftii}c'barl}~S, AlaE)·~;:\l . SOTJrn r~/~T?J10t4;r TEST ~SS'Llt :'·TO.. L Lithologic Descri'0tion South BG1"rOW Test. ":"611 1\To.. SŒ?""ARY h. is located a? Tat.· 710 1f/l r'¡;;'."'~¡¡ ~'.¡_?o""'C:" 1!~<' 0 v..... I,) .. __:? :;>:.;,.t:4 ',.~ ~ I" "'G" _~.."" "' r í L.iJ..89" W."' Idt'"',' ". """'.... í\" 28-0 17' .<'.. " ... IT,' -, 11'- 2 '- ..,. . ~!'? ." -~ --..--.- fv_~ l.~~ i~t..OJ.. ;:-;011'''11 öarrow ~es"(, -·,,:~e_ ~'·~O,~ -' ~GO 1')'11:LCl"1 ~"r, 1.s an aJ.:ternate" It was befì:Ul on -;:al"'ch 10" 1950, a:''ld completed as a g8.s':!ell on '~:)y 9.: J.95o¡!l produc;,;ing fr01TI "the Jm'assic and nbéJ.sementlr ,. 'Öue to lmitization of' the the ele-vation of t))G: ro ·b<lr.'.I dr:Lve bushing is 8' higher ã,bove the ground than it Y.-as at South Barl·O'W' :Jo" 2; as ground elevations of the two' 'wells are ap"'Oroxim<::1tely equf'J< 3' Shúllld be subtrf1.cted f¡oom aXly depth in South Ra:r'I'O"J'i No", 4. to get a.,\'l eq1.1h·a1ent point in South B.clX'roY! No.. 2" [~!yprQ1dmately lOOt of Gub:U.: cliSt,l!, f-1and and g"i'2.'tml (liurd:.el"!la.ry) rests directly 01'1 FtrD."Jl S!1¿:!.3 .':!f '701:1'-:: B;t the lmüermost "I..··n:i.t of the Un1ia:t formation (I;(fvJ'el'" n9.TlUshtÙ g!>o~p, I,~~er Cretaceous (1))0 'Zone D~ encountered at 161hv, coutinues to 1~70!~ y.;he1"e an abru:pt chan[re from gray shale '>(;0 black, PJ1'I'itio~ slightly sandy shale marks the t.op of Zones !\,~C "Undifferentiated", '1'11e conglQmeratic base of7.ones 1\-0 rests on Jurassic, ijhe contact bein¡;; at 23~2~; the greenish 51!r..y shaly ~Jurassic S3tld cont.in,ues' tCI the s:Hiceolls shale !\basement" a:t 2h71 t " Total depth is 2538 f 'iJ 'T'\:¡'l:mty-fol1l" cores were taken" yr.L th 169; of l"'ecoveY"j"" Casing (10 3/4") wa,s set at 2317~:< before drilling deeper; 711 casing vms 12lld.-- ed at 2502': 'with perforations from 23h3' to 2502' r.. Tu.bing W'a8 lO'1'-i-ered to 2h6S' jJ and an ostimGted ma..xil!1Ul1l flow rate of 4000 'reF, with a. small amo1lr."1t of salt wat.er (1082 gra.ins per g~.ù.lon) was recorded on April 20" 'rhe ¡veIl 1I'W.G then shut. in, 'lnd maintained casing and tubing pressu;re of 1020 Ibs." 'lli"'lt:il ~Tay 9:J \'lhen 211 :tndiea.Led. flow of 1805 'ICF 1.T.i.th a..2L./64:1 bea.'1 was e!:'t.;¡:"fJJ.ish8C1." LITqOT~OGY ThÆJ £'0110'..-1..11[; description is'based on data from cores, ditch samplaG, electric log and ~æl1 ~eol0¡~stls report; are dete~ninations are largely' based on micro- faunal s·t1Jà:i.es by ¡.Tarlan R" Pergquist a.."'ld "'rs,þ TTel,an TJoeblictl" Core ~ E~o~r;[ """s¡">..,.·¡...,.to ~ OJ''' ~__~f;"v-.:...~ O-19\' 19-3.3~ 33-11ht Ditch Height of rotary drive bllsh'ÍVlr; a,bove groundo ~o ·sænDlas taken. Sample~ frQm .33 ~ to I1h' "were caught. in the eel:.&!" and ~L't'e no':..:. t.rul~y· reprcsentat.i.v6 of t/he inter"írals they represent. Q 11 (Arctic Cont1"A.ctor I s Geologist; B Report., we:;;k ending "m"ch 12, 1950)" The sa;¡ne rø·~ -port de,,:crihes the :tormatioy."\ :in this int)9rva..l as tlsoft gl"':r\Y clay 811::1.1e TTlth a '£'81;'.' thin sc,:::!.t.tered sand 1ense;::¡11 '" 'rIa shed <:~a.mp10s are composed of loose sand and occasional subal1G1.11ar to ~rounded black Gher;~ pebbl(~s.> The sEnd is predominal'l"i..:.ly fine to VG:;:"Y fine gx·a:i.ned~ sübang-ülm" to rO'UYideè, often has frosted. surfaces, and :Ls largely clear' RESTRICTED FOR OFFICIAL USE' ONLY :JL.3 COpy NO .......:_--........ /~ ~oo ~T)n or white ÿ,'u.artz.. CI'ear!i aniitiar quartz grains with unwea.thered surfaces are sca:G.tered tr..rough,.", out.. There is a. £;!:"adual ChaL"1ge from the upper såmp!es to the sample,. taken a.t 120', yihich con- tains Cretacéous microfossils ~ Yellow qua:rl,z and black chert.. grains are common in the upper samples, but decrease rlthdepthOo 1!. taint gray-green tinge, the result of rm increase in gray q\la.rl~ grains and green(glauconit&?) p911ets, replaces the yellOt<1=- ish color, with depth. Angularit.y increásas slight- 17; sphericity ar.td grainsize decrease,. The base of the Gubik,., below which the distinctive Gubik charac- teristics (röundness~ ;reUow quartz, pebbles) are merely contamination, is impossible to. determine.. PeUets of so1'% light gray- clay, first occurring at 110', show no beddir.g, am may be drllling mud, ël~ from the Gubik" or Cretaceous cl.ay shale.. Seismic shot holes in the vicinity (Party 41, 1948. line 27~ holes 1...9) encountered pre-Gubik microfossils a.t dapths from 9Qf to 160' (130t 1£"'1 the nearest hola to South Barrw No" 4). Clay) médium light gray:t bentonitic, ocoasion¥- ally silty, noncalcareous" veT1 slightly micaceo'lls" with r~ carbonaceous particles", Loose sand in the ditch samples is subangula.l'", very tine grained, whit.') . or clear quarts with some gray quartz and chert, and l"'a.1:'e green. (glauconite?) pellets, pyrite s.nd caroorÞ aceous particles ~ The electr-lc log of this interval is distorted by permafrost; the geologist. s report notes a slight amount of sandi' increa.sing somewha.t with depthe. Cl~, med1:um H.ght gray $ rarel;r silty ~ very slightly micaceous, noncalcareou.s, with rare carbon.... aceous 'particles $ SarXl similæt to that described abow is present in the samples in ~ amounts (lO-9œO: it is beU.a"t'ed to be contamina.tion from. above~ as the elect..ric log giws no indication of sand in this interval.. Clay as above; with a slight, amount of silttrt.ODe" light medium gray, slightj,y mieaeeous, noncalcaroou$í)1 ClðT shale1l similar to clay- above, but harder; pyrite inCl"aases to common.. 3~.nœrl:.one -v-ery .fine grained, very silty, a.rgil~< la.ceous medium l:lght gray slightly calcareous; the sand is sinlilGr to the unconsolidated sand dese~ibed abova" with rare pyrite, caroon~C\~mlS part.toles, grÐffi.'! pellets", 134o-1598~ Ditoh Clay shale, medium light gray, slightly snt,y~ slightly :m:i.C&CeoM., Z011e E SLower Cretaceo'tls (1)) microfossils a..."'"e IN:l.l'a to common from 120~ to 1$98", CO!~ - ~~pt,h REH.::t17 ~ . 120-700 1 Ditch 700-900' Ditch 900-1220' Ditch 122(þ,.l280' Ditch 126Q....1340' Ditch 2 . .3 . Gore Depth B~ove!l P~gc..r2:pti0E: 1 1598-16031 10'0" Claystone, medium. gray to medium da1>k £T<'(tJ moderately hard, irregular fracture, reicaceous noncalcareous, scattered carbonaceous flakes~ Zone F, ror~ánifera þresent~ 2 16,o8-1618t 10 rOil 5'6" Claystone as above.. h'6" Clay s1-¡ale., medium dark gray, "poker eM,pl: frl?c"t,ure, moderately soi"èi; laminae &"'1d l"are l'~n3es (up to 1/Sf! thick) silt~ne, medium e-1"ay to med.ium light gray, micaceot1s~ non- ca1ca..~ous, with scatt.Æred i'lakes ca.rbol'lace..~ 0115 material, make up 5-10% of the core.. Dip J.ø'o <> Zone E for&~inifeTa Drcserit. Probable base of Zone E &'1d top of Zone D is at l61h'; this is based on: a) Schlumberger correlation VrltÌ1 South Barrov! Test ""ell no., 2; b) a lithologie Cha.."l[;8 from claystone to clay shalc; and c) a sudden drop from cOr.lí1lOn Zone E: f"orminifera to t1'\f'O poorly preseI"',¡ed f'oraminitDra in the next 30 feet of cere" 3 1618-1628' 9'611 Clay" shale as above", 7.one E forami:rÜ!era absent; microfossils ~ Vc3!J'- rare.. , 4 1628-16381 910ft Btì~n Of£3n Clay sl',a1e as above;> grading into Claystone, medium fJ.'ay to medium dark f!:l'ay~ moderately ha.."'I::l" irreg....üar frac·ture3 slight-· ly micaceous,noncalcareousj 'with carbonized fragmentary pl2X1t rema:î.ns, 110 silt laminae" ;; 1638-16h8' lOt on . 2ø6n 716n Clayst.one ,,1.8 above!> Clay shale as above.. '''icrof'ossils very rare.. 16;;0=19701 Ditch 81a;y- shaleJr modium d8!"k grajr; slightly silt.y, ·~J.ightly c3.2?'bonaceol1s, micaceous, and clay shale, mediu.lli gray to mediï.ml light gray:þ sli[:ht..·, 1;y' ~dltYj ;nicaceous,. The proportion of medLu.ì1 dark ~ra:r sn·<llp 1. ~-;cre.9..Sf'S from rare at 16~o~ to ,'lbout half of' th¡;. sam!')le-s from V120' rlO'ml S'!:.r'~8ks of san.-'/st,one, v~rv nee s:rail'l~d, s11t.y·,µ light rr~enish ~r~Y. vprv calcarpou3, occur. at 1725-1 "h'51l, 1750-1760!, 1 Rno t, and 1900-10201 '" '1'h"" S:liì1Î ctrains .~ rr suhan"1.tlar3 whi.te and clear OU~l"tZjl W1 th oC<'asional grrw crJartz, carbonaceous -oarticlps, and rat"p ryyrite, frp.en \'ìell~tsjl and mic.'=!. f' akeso · ~]ore - "en-"'" ~:.: L!e~?,~l h Desertion __"'II 1 (fhe top of Zones .t:.-C u.ndifferentia:ted {Jase of Zone n). is placed at 1970'" The contact is marked by the first occurrence of 7...o1'1os fi.-C rJÌcro~ fossils, and, an abrupt cha.nge in litholofY from medium [;ray clé\V shale above to dark gl"ay, carbonl:lceousþ pyritic shale with clear quartz grains~ as described below~ 1970-2320' Ditch 6 2320...23291 9'on 1~6n 7'6" 7 2329~234ov 10ton 2tOn 0'2" "('Ion ~ v 23h0-23.50r 7,on O~L.II 6 t Sf! Cla;r shal Ð, d~..l'"k gray, carbona,ceou::1, "'With scattered vt!fry fine to coarse grains of clero:' quartz. sand... rounded to very well rounded, sameti..'"'les frosted or pitted.. Chert grains are also prese1'1t, as saz....d or rarely as sma.ll black pel/cl:?fI.. Pyrit.e is abundant thl"our:hout ; often as plroTt rêPlac~~ent; carbonaceous particles are cOl'$ion from 197CP to 2050' :;a.buRdant betv...ee~ 2050 f and 2180 t, and common to '!are from 21öO 1 to 2320f~ Zone A-C undifferentiated microfossils are common to rare ~ streaks óf sandstone, very fine grained~ si1ty~ medium light gray, ca1carG()u:~), comoosed of angular to subane:ulro:- £'1"'ains of cle;C):r:, white and ff.t'ay qua:vtz :md gray and black che>rt~· Trlth COW~Qn caTt~naceous and pyritic particlesJ occur at 20451, 2097 v Jt 2150 t, and 2308 v.. 3rovm lLüestone pa~ticle$ are rare~ Cla..v shale" medium gray, non-calcnreous" v'"er"j' slightly micaceöus" poker chip fract'U1"e; dip '2_~o ,. Contains scattered fish bone fragments and rare carbonaeeous particles~ Clay shale" medium dark gray, infiltrated with mud.. nicrofossils a.bundant.. Gla.ystooo, s11 ty to 811 t-free) medium to, medium da.rk gray, :m:tce,ceousj vrith stl-eaks and lines of 1?pi te.. Basal 2« contains oval patches, \1þ to 1/8" diamet,eT, of lichter color clay, possibly intr&fo~rtational conglomerats$ . Cn<'!1ystone, dark g.ray)) ca.!'bcna~eous, with sca.t..... tered. rounded <""rains of clea!" quart.z:; ranging in size from silt to coarse sand~. Clay shale" m.edium darl~ gr:,:¡;y,. m.icaceous, ¡,.rith streaks and :anes of pyrite; infiltrated vJith mud.. '~icrorossils abu..'I'ldant.. Claystone, silty, dark grçr.h 'with abundant streaks and lines of pyrite, grading into Conglomerate, blaclc, with clay ma:trix, and grains rang:il1g in size from silt to pebbles 111 in dia.meter.. The pebbles ~tt'e llsuaJ..l;¡r very 'Vie11 rOUl1ded black chert, rarely of grayish ql1.artz" .,.. GO:C8 ~?{~pt}l ~1"'Ir "".Ý-::..t.E.. í'\ .. ¡ 'i '. .les'0r1"p'"Gl,pl1 Sand-size gra-: 118 -':::.na1"il~;T úf clear quartz, occasionally pitted or frosted, the larger ones are ver-::/ well rounded, but round", ness decreases generally ,'lith sÜ;e" some of the s!tla..ller grai.ns being sub angular '-' Pebbles jI sand and silt all OCCllr at random throughout the sec.tion, V<I"i. th no visible SOl"tirsg or bedding '" PjI--ri ta s~creaks and lines are common.. '!icrofossils are rare.. 9 23!?O-235hv 2tOlt The rock recovered from this core is in small fragments; they are composed of conr:lomerate as described above; and of sandstone sL~i13r to t11at in core 10" Two or three f'rarments. of the CQn~lomerate had a good oil q:dor and pave a dark brown residue in GCl/.¡,; one contained a well rounded pebble of da:r'k gray quartzite 211 in diarneter.. '~icrofossils absent.. 0~ the basis of litholo~ff, the sand section below 2352' is correlàted ~rlth the section ¡J.";)T;). 23281 to basement in South Parr01~.r t:!o.. 2~ :,:..n() ....lith part of the 101'rer Jurassic secti.on found in Sout..t.¡, BarrO".¡ ~!o.. :'~ Dips of 2-Sc in the Cretace- ous, and, possible di¡-,~oi ~~_:!..~.OO i..n the ,T"rassic indicate a. possible angular uncon..;> fOrfa.:'.ty betweBn themo;. 10 2351.).-236&' lot Sandstonê... very ti..'"le f'.Taíned, very silty, lirht rreenish r:ray" non-calcareous, poorly to mode~a.tely indurated; irrep~lar~ discontìnuous~ partings of mèdium dark gray clay are common to abunô.~.üt ~Y!~ indicate a possible dip ot' 10.- 1~0 .. The sa..'1d grain.::.: are subangular to anzn- la!', often "lith pitted or T"ros·t.ed surfaces" and are composed of e:le.'9.r quartz, with some vrhi'\:.c '-l1:w.x'tz, rare vr'r,ite or gray chert.. Sa:mples from 23~6 and 236o~ shcvled a yellow cut and ðirty :relloYf- brov-m resiò'U.D in CC14" "orosi ty . 2':1\601:> ~ -~.,- X5;'df .., t .LL,.¿J/.} 2360N 10.85% Þ !J:).-rite (marcasite?) nodule shell (pelecypod?) fl'aø:¡ents 2361 t .' . ""ic1"ofossih, absent" Permeability}} i¡l1perrneable f! occurs at 2363 t ; are pl."I':!sent at 11 2364.-23731 CH .,J Sandstone as aboV€, grading to short (1-211) sections at' olive gray argillaceous siltstone at 2365' and 2371 f " .~ :v"elloW' clit and diri')y yellow-bro"",'!l resid"U~! were obtained in CCll, I:' 2"'70. ~, .J.rom .:;'" Porosity 23·58P- ~--·-î2 $3~~ 236ôN 1~a9~ '~icrof'ossils rare" Per'ù1.eabili ty --26 illèf: ~ impertneable *r,fu.ddy Surfé\.CêS of all permeability plugs from South Barrow No", , _,...... the presence of discontinuous clay partings in the sa.m,.ra~··:':'...,u in per&eabil:lty rC3.dings lower th~""'l the p!'Obe.ble permeability of t,h@¡ ':v.t'li1ation<. Core ·1" "I.' :;!!!.f! t,~:. 12 2373-2,383' 13 2J82~390f , ~ . ~eco-¡¡'e!"l 9 t 1 ~ OH 8; 011 3! .3 'I on 2390-2409' 2' 6" Ih 15 2400....2410; 3'0" 16 2410...2420 t 10 ~ 0:1 17 2h20-2425u 5.'iOIt 6 Descltion « "': Unconsolidatedsand mi.."Ited nt..l1 InUe!,1' Sandstone as 1.'1 Core 10 above; a yell0'9 cut and d1.rty brownish yellow residue in CC14 from 2.381 v " 2':)80p E2.i1sm ,Pe,~6~bi~~o/ ..} 0 , imp!3rmeabYe 238O¡~ 1l¡. <> 86% It ~lf:t~rofossils Tare" Sandstone as in C01"e 10 above; a pale yellow ~ut and dirty yellow residue were obtained in CC1h !ran 2390~ G . POl"'Osi~ 2387P r.r;g p Microfossils absento Permeability :iIiq)ermeàF1¡i\ Sands"GOOe I very £'1.."1e era.ined~ very siltY'ø lig...)¡·t gree-uish gr~:t non-calca...-coæ, moderately i""dU!",,· ç¡t:;.ed.. Has abundant irregular, discontinuous Pal"t...~ ings of medium dark gray clay, and t'ar9 strea..1œ fine sand", Sand grains are auhmgular, often vdtb. pit.ted or trosted surfaces, and are composed of -clear q'lJ.artz.., with some white ~z and rare whH.e 01" graY' chart and green pellets ( glauconite?) g and a good. oil. «;.dor "fIas present throughout_ and a. pale yellow cut and ysl10w residue were obtainèd in GG14 from 2396'0 'Microfossils a.bsent. Sm"ldstone a.s in. core 14 above; good odor oil thr01.1gh:- o~t., with pale y,aJ.low O'llt and yellow residue in eCl). at 2ho5'J, One 2" section a.t 2406' is well indurated: calcareous ~ ''tl.crofo32;ils absent.. Sa!1dstone as in' core lh a.bove; pçssibla dip, indi-,-, ca1:.ed by clay pay·tinge It is 10-1><'.. Fair to good oil odor is present. throughout; a strmr colored aut:. pale yellow resid'\le il'1 0014 at 2414' ð Porosit;[ Permeability 2413P9 i>~~ tmpermeablê" 2419P 8..22% It ~icroìossils absent. Sandstone as in core 14 above; poorly preserved fra.gment of cephalopod at 2420 t. ~ 2" of calcareous well indurated S311dstone occurs at 2424 t; f'air to good oil odor tr.;J."oughout:l vii th atrar'" colored cut and pale yellml ::f~ain at ~~L!23 t .. Microfos~i15 v·ary rare.. 2428P 2Ìt28N Uicrofossils ~,::¡uo .;~... ("1"11 a+ 'Jj'31t .i.u '" -'--> \.;<"......1.1 ..., '-L.t " at, 2432 t ,~ 'l'he bottom h" of the cú!:'e is durated, bu.t 110t. calcareous" P01""Osity 11:~% ~ 11..6% absent", Per:m-sabili ty . impel"ïoeable n ,.' ....,-' 2hL'· ",or' t ~ ~,¡...._ c ~ ,~...,<:._~.," .... 2h42P 2h42H 1~icrofossils Sandstone as in core 14 above; pyritized pla."1t( 1) fragments a.t 2436 ~ 11 24.39 t and 2443 t " Faint oil odor throughout; straw colored cut ß pale yellow residue ~.n C01L. at 2440w" Porosity Permeability ~ 4jc!. -;-~ -" --~ .iJ /... \..' ø..... :!t.C.. 6.8i$.b absent</! ' impemeable 10'0" 21.ili5-2455~ 7tOn Sa..~dstone as in Core 14 above; well indura:ted~ slight¡y calcareous sandstone 2" thick at 2453~o Faint oi~ odor throughout; stl"'a\'f colored cut, pale yel1a-1'ì" resid'De in C014 at 24:;0 ~ " Porosity Pe~eabilU;y 2454N --~59% . '2,,0 rod.. - ~:ricrofossils ve!j~ rare" 2i¡.55-2l¡6)· 10~O¡; Sandstone as in core 14 aboiTe; a.t 24631 is cal·". careo"Ö.s¡;, well indurated sa.."1dstone 2" thick~ Fai.lrb oil odoy- -throughout; straw colored cut: pale :r6J..··" 1....... '^""'S"'(i"e ."... ;"t"'!!· _.,t. I'}~.~r\ ~ _VV'ri ¿ ç,;. ..L. ,,-U- J..L.L ....h..J..""'!¡. c:.ùF '-4V,V' ..;,. Porosity Permeability 2h6op -:- 9 ,,03~ - impeTmeable' 11icrofe,ssils absenG<r> 2460E lo..o4<'{ tI 2h6;;~,24 7~ ' 2 ~ 611 2 · 6" SandstonE3 p 811 ty 1} a.rgillaceous g yellowish gray» non...calc8.l"'eous 7 :l1'regulæ intercalations of mad-· ium dark gray clay al'e abundant:! and indicð,te a possible 10=15° dip. The sand is fine to ver:¡ fine gr~5 "\'led;! a.\':I.d consists alrr..~st entirely of su"t>· angu.lar cleè1J":' or 'fldhite quartz: with a small aIT'¡,)'li....tt, of grtiIW quar-tz 8:nd chert o. No oil odoX' was noted; no cut and only a faint greaS',Y" stain as residuG Wi':' , obtained in eCl!, ') One fragment had a porosit:f ge18%~ .... 1. fragrnt::::'::i:", of g:'8::,?'5 sh ?fJ:Y ~herti' 3/b..1i :in dia.111eter,r 3u1> angular, nt.h sU:bc;onchoidal fract,ür-e.. . , 3 fragments g!'a;~ish black siliceous axgillite2 1/4,~3/i.~¡' , in dia..1J'\e"'~er G They are almost as hard as t.he d1GY"G;; subas."1gu1,aI': with ¡:mbconc}¡oidaJ. cleav'age; the rock is d~n~c1 !1:nd homcg~ne{"¡1.~~s,) .and no bedclil"1g orot-tiS"!:' ~, , ~..-. s"t·r:...1Gt~'il.1.:'iJ;;~ a1âB "v':"JBJi..nJ...e ~ ~,~j,..(.:~c;fo's':~jJ.I[-;? &b8eTI':~ 21J?5-<¿1~?8 ~ 247~=2536t 2·~ 2~36....2538f 0;611 Ditch 1'0" . . . --,-:¡.--. 20~25 sul:}~ngr¿:~.2...r ft"~1gJ1811t8, ~~"~:lita '. ~r¡,~E~{~ì..,c. ish black siliceous 8l"giilite as dE:seribød ~Ü)O<ïi'3.:, J; few rragmerrí:.s have calcite veinlets 1 UJillt< or 1.es8 quartz veinlets are also present, but are smaller é:nd. rare 0 .å. black carbonaceous (graphitio:~'?) film is pres=· . ant on one or two pieces. 1 subangular fragment"' !tt in diameter ~ of dark gl"eeniah gray to 011 ve gray chert. Black argillite from. 2475' to 2510'; a little gray chert is present in the sample from 2510sto 2521'" slightly more is found .from 2521' to 2530 I, and more than half of the sample from 25301 to 2536' is gray chert.. The entire recoV"eq- of this core is in the form of sub- angular fragments ;r-2" in diameter.. Four types of rock are present: a) Grayish black siliceous argillite as in Core 230 (2 or 3 fragments).. b) T..ight to medium gray chert, with waxy lust.er.. trans- lucent on thi:n edges I and conchoidal fracture <> Small cracks occasionally are bordered 1idth a slight yellOl,7- ish stains t and a few specks of p;yTi te are present OD one fragment.. (~O% c'f the material recovered).. c) ~edium gray tlO dark gray fragment.s 'hhat are similar to the black rock frc,m Core 23 in most characteristics!) but which have been made lighter in color by' varying a:¡;l::rm:j.~,s of gr~ to light gray chert present. in veins or small ir~, regular masses <> A small patch of' microscopic pyri t.e crySw -I:,als occurs o¡':¡ vile f'ragment$ The chert-argillite boundal"Jf is often sharp, but in some cases appears gradational... The chert often contains fine dark gray or black lines of em:'-·, bonaceous or graphitic (?) material ; it often surrounds or interfingers with irregular areas of the darker argil- lite. It.s presence ts probably the result of gradual re",,· pla.cement of the arg:tllite with cryptocrystalline silica" Carried to completion, this process might result in the gray "pure" chert described above.. (a1..."nost 5œ of the material recovered). d) 'rrell rounded fragments of graY!J non-calcareous :l'ock~ "!<ffegascopica.lly, it is composed of small, in-egularly len- ticular masses of gray chert embedded ir~ a light tomedi\."ill1 gray, soft" chalky mass which also contains fine parallel laminae of da.rk gray to black carbonaceo11s(?) material" "'acroscopica1ly, the earthy mass is 'white, and con'tie.ins a fine neifirork of the bla.ck shiny material; '\rary-i~ from a delicate marbled VE~ining to a heavy uhoneJrcombr¡ in vl'lich small patches of the white material are enclosed.. A few oil stains and gas bubbles 'were reported in the geologist! s report from this material.. The appearance of the rock sug- gests that H, has been formed by leaching of. the æ"gillite: either du:ring 01' after the formation of the chert.. (5 or 6 fragments) Ii> Flor·ance RuckerJ¡ Geologist ~Íay 18" 1950 /r¡2 t ~~ ß"'c} --- SOUTH BARROW TEST WELL 1 Location: Lat 71°19'12" N., long 156042'16" W. Elevation: Ground, 5 feet; derrick floor, 18 feet. Spudded: August 15, 1948. Completed: November 11, 1948. Dry and abandoned. Total depth: 3,553 feet. South Barrow test weJll, the first of the deeper tests near Point Barrow, was drilled for more information about the age and character of the rocks in the area. Seismic work had shown the region to be unusually high structurally. The test well, located 1,500 feet inland from the shore of the Arctic Ocean and less than a mile southwest of Barrow Camp (see fig. 50), was on a site which had the most favorabJe foundation conditions in the vicinity of the anomaly. "n:'//~/7 7 - i .5ô, /34" Ý c) W '~-:j I- áJr-!~ d / ~__ . 2.:1 =I 2 ~ é /-I,.)€ " i 1.8; 1--3 if..! , JJ Llt/t, I~e..,. I"r'"""ÚI'-;.r H"~N<?I,~ D¡ C~;""j (¡?úblW: CLfíkŒ.O,ß/"rl é~{t!dlN''''''''' u_JC7;J..,"~, : 7 i R ..lr BARBO W COBE RIG TEST 1 j,...,., I ~.J ß,c ¡,'" J,," '"' "'" "" "~u': u iÝ i W Location: Lat ilo19'25" 1';" long 156039'02" \Y. 11.!/ / t? 7_ f u / Elevation: Ground, 10.4 feet; top of surface pipe, 13 feet. pc. ~~ '2.':"> .l::..;'!"c- I(.!fj----LD~_____.~___· ; Spudded: September 17, 1944. Q. ~ r I .,.J,," ~ ¡ 2. =1 ~ 2-3 ! 18 . Completed: October 7, 1944. l)ry and abandoned. { 84-0 ~ t:; """ . I : Total depth: 344 feet. z.- G, 4- ¿::- ,..J U ÞJ~ . ( tf:' ~"Þ( ....... .. .--- ~""' :, 18 '" , SOUTH BARROW TEST WELL 2 Location:Lat 71°15'49" N., long 156°38'03" W. Elevation: Ground, 23.5 feet; kelly bushing, 34.5 feet. Spudded: December 18, 1948. Completed: April 15, 1949. Gas well; junked and abandoned. Total depth: 2,505 feet. ~. búrro;v ')~-,-.¡. ¡}Jc?11 J.I;.~_ --~~'-~G, 4 I -¡(.aU 11.:>.£"/ : 14 j 22.. ¡ /5 " ß~/ (~........ fJ, LJ~ :) ....~{)( \ \)" , j I i I "-1 .-¡ 1 L ¡ . ; ; 1_..-......-......- ¡ $" 134 t' r c) uJ Îp.:Ill¡fl, 1/ Jd. 3 I'~ 2./ (Lot- (,oJ. /"I,JC I 05"" I (to~ J. /."Jµ,c ¡ . I ¡ : 2A-1.LI i ¡ ¡ ì ì I ! I . I \ ! !"'--------~.----,¡__.~"- 1 \ ¿- /J. .-. . jI I ! I ¡ Jb tötÎ"rè~v I ~.rll?//J ~ i ¡ \ ~. ¡- I r be j 4-~z, (~M.. W. Uµ-6 ¡ , I 92-" I FWI\ N. LI¡Je' I ì I SOUTH HARROW TEST WELL 3 JJocation: J>at 71 °09' 46" N., long 156°34'44" W. Elevation: Ground, 30 feet; kelly bushing, 4'1 feet_ . (L! Spudded: June 23, 1949. " bt i Completed: August 26, ] 9'19. Dry and abandoned. 1)1" A _! Total depth: 2,900 feet. I~;,,,," i The third test well drilled in the Barrow area is South ¡ Barrow test well 3, about 7 miles south by enst of South 1\ . Barrow test ,veIl 2. (See fig. 50.) The well site is in .., _4-___ , SOUTH BARROW TEST WELJ.-.1.- -- Cf) -ðQ(." I,ocation: Lat 71 °15'51" N., long 156~37'50" W. J Elevation: Ground, 24 feetj kelly bushIng, 43 feet. Spudded' March 9, 1950. 0- 000 Complet~d: May 9, 1950. Shut in gas well. Produces 1,8 <>, cubic feet per day. Total depth: 2,538. South Barrow teat well 4 is 447 feet N. 28° E. of South Barrow test well 2 and was drilled to tap the ~. Attachment II (b) 14- ¡ 2L 18 ¡ ¡ I I I I ¡ I i I I IB \ I 1 I , , ,.... ',," r( ... . "-- 0~{'d /1 \~f ð"D :......... --.../ MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Co~ission \ TO: Dan Seamount, it- y Commis$ione~ v¿., ~ THRU: BlairWondzell, ~ P. I. Supervisor i(/'i/Ðð DATE: August31,2000 SUBJECT: Barrow Gas Field South Barrow Field FROM: John H spaUldi~,r J ò(~¡,.f 5 Petroleum Inspector - 2 8 "On5 SC.~NNEC oC!· t.. '",. ., AUQust 31. 2000: I traveled to the Barrow Gas Field to review their records for "proper': Plug and Abandonment procedures on the following wells. South Barrow Test well # 4 prD 100-026 : ~, There is no data on any type of P&A. From our records it appears that the well was drilled in 1950 by the U.S. Navy. production was apparently curtailed in 1968. The well still has a coverlwellhouse over it, there is still wellhead attached. As the accompanying pictures denote the area around the well head is covered in water. I was unable to find anyplace that would show there was a reserve pit, it is quite possible that the reserve pit was removed. I suggest that before writing this well off as P&A'd, that the US Navy be contacted in an effort to find out where cement in the well bore might be. I recommend that this well have the well house removed, the well head removed, the casing blinded off and at a minimum a mound of gravel or dirt placed around the well to keep the water from impacting the casing· as well as mitigating a safety hazard. South Barrow # 7 NSB-07DP. PTO 187-075: According to Halliburton's job log and billing statement this well was P&A'd 3-29- 88, the AOGCC records show the well was removed from production status .and P&A'd on 11/17188. The well has a dry hole marker that appears to be placed in the cement after the well head was removed - no welded cover. From the pump reports it appears that cement was circulated down the production tubing with returns being taken thru the annulus. Once cement was observed at surface the annulus valve was shut in, squeeze pressure was obtained and a volume was placed behind pipe or into the formation. Considering the depth of these wells (shallow) this is probably a good cement job, therefore a prettv (lood P&A. , . /\ \ I recommend that the well be dug out 3' below anginal grade, dasings cut off and a welded cover be placed on the casing stub. As these wells are close to town this would mitigate a safety concern of mine with the winter snow machine traffic. ZOOIr! XVd CO:Z! £00Z191/60 . . .--------.. "----- ' -~ South Barrow # 12. PTD 100-035 and South Barrow # 18. pro 100-046: These wells were P&A'dat about the same time as we/( number 7, same contractor and the same procedure was used. Contractor billings were used to obtain this information as well. No. Sundries were applied for or issued for these 3 wells. . As noted in the pictures the casing on well # 12 is tore up some, and it appears that the dry hole marker has been placed in the cement at the top of the casing. There is no evidence of a reserve pit in the area. Wel118 as shown in the pictures, has the same type of surface abandonment, with the exception of the reselVe pit area, The reserve pit area has been broached and some of the gravel has been removed.' . I recommend that these three wells be cut off 3" below original grade the casing stubs blinded with a welded cap and a mound of gravel placed over the casing. Facilities While in Barrow I visited the facilities that are currently in use. These will be feplac~d .in the near future. The new facilities are on loc~tion but have not been commlssloJ1ed as yet . . -~ I was particularly interested in the current and future tACT metering $ystems. When at peak usage this meter handles about 6mmcf daily, a relatively small amount. I am not familiar with the current Rockwell "Electro Corrector» system that is in use, this is a charted turbine meter. This meter is "'checked" on a monthly basis and is compared to the Barrow Utilities Sales meter. This meter is calibrated on an annual basis. In the new facilities there are 3 separate runs, one for each field with a "Daniels" computerized orifice plate meter. These will feed ìnto a 4" line that contains the IIDaniels" LACT meter. The new facilities are quite a step up from where they are today. SUMMARY {by Blair Wondzell}: 1. South Barrow wells 7,12, and 18 appear to be properly plugged but should be cut off at least 3' below original ground level and a marker plate installed. 2. South Barrow well #4 does not appear to be properly plugged; the well house should be removed, downhole plugs installed and casings cut off at least 3' below original ground level and marker plate installed. 3. The AOGCC should make an annual inspection that would coincide with the calibration of the gas meters. Attachment: Pictures ~ ;i'~,\Ij¡~~{;:\~'~':\savåld \::~~~~~'~~':..............' ..' ". coo IrJ XVd CO:ZT 900Z/91/60 Jp'Eö hnage 320x240 pixels . .. ~. ---'---' .~ Subject: pictures Date: Tue, 05 Sep 200015:17:05 -0800 From: John Spaulding <john_spaulding@admin.state.ak.us> Internal Organization: AOGCC To: Blair E Wondzell <blair wondzell@admin.state.ak.u.s> Blair, how are these coming. thru. js ~. -"- /'\ ~ 10f3 f700~ Roc.lwe 1\ It ~. L. \ C'"(ec.,"w"ò Cor~+O(" s C3 ~ (8 9/14/00 12:07 PM XVd CO:ZT ~OOZ/~T/60 ~ r~f.t.f¡~gð;320x240 pixelS . . , -- ~ .~ ~. ~ 2 of3 £OOIrl ss ~7 S 3 ß: 19 G ß .~ f '2.. 9/14/00 12:07 PM XVd CO:Zl £OOZI£1/60 , JpJI;,G hñage:320x240 pixc:la . , .~ .. ~ ~ 513 .tr 4. Name: Untit1ed~l.pdd ~Untit¡ed~ l,pdd Type: applicationlx-unknown-content-type-pdd~auto _file Encoding: base64 ~ ,,--.... \ ~ 300 9/14/00 12:07 PM 900~ XVd vO:Zl SOOZIS1/60 '.¡ . . NORTH SLOPE BOROUGH DEPARTMENT OF PUBLIC WORKS UTILITIES-FUEL P.O. BOX 69 BARROW, ALASKA 99723 TEPHONE NO. 907-852-0390 FAX NO. (907) 852-0327 FAX TRANSMITTAL Organization 5rel/€ /v\.c /'r....,:¡.zN...s IiO&t::c::... TO; Name Fax No. ~ 76 - 75-42 FROM: 57E 1/£ /\(\bG- IZ~£ DATE: G , 1..$' o,,~ . Total number of pages, including this page 6 MESSAGE: ST~.v£J A Ti¡:c.flED TÞ D~H I oS í)/ê LE/7E2.. SEA AAðVNí D~7E1) FJ2ð,^^ Jðh'.N SPA¿Nj}):rJ.l~ ¡:h.16-L/.-s.:r ..3 J. Zå,:,o " PLEI-S£ ¿£r ~Jt K./JO\N I~ Yð1/ A{€,Ej) ¡:)/'JYTJI$JJ(¡; £1..SJ!" ~7J~ PLEASE CALL US IF YOU DON'T RECEIVE ALL PAGES. : -'. r· ......- t,f '.. ~ \ .,'.. .' ."., , '. '~'-. r~, ;..' t. ..:j ." î ~..:. i ~J r:. .,") , , .,1. -\>,;~ O~~1 8- G¡ji¡ CA.Ai<&ì. ().;,;·Hlr,\.ti!i«; 100~ ;!¡J\~\':J''J.:j~' YVd CO:Z1 900ZI91/60 EXPLANATION . OIL WELL ~ GAS WELL . OIL AND GAS WELL + OIL SHOW-ABANDONED ~ GAS SHOW-ASANOONED '* SUSPENDED GAS WELL . ~ OIL AND GAS SHOW ABANDONED -<1- DRY AND ABANDONED . SUSPENDED OIL WELL . .- -- --------- --- - ---.--.----------.---- .;.. ... r B~RROW ARE~~'~ 0 c . .~~I.AGEAK I .. 4 " S.BARRO ';, ~D SE I WA:~~~P: ~ ~~B~Y" l . . SIMPSON I . CA "'.. , +. f . iifT".< Yo ,. '0.'" tSIMPSON 2 ULL CL~FF K' U .Ä~-.r'tð. .. É. SI~PSQtLl_~. J. W. DALTON I ... ~ '.m..:~¥ ...,~~·SIMPSONI. ,.".~.. W.T.FO~ANI ~t>-pEARDI'-'--'" '1 ' " ,r~::.x DREW. ~-;fê . . ( ..'~ "", ¡ - r~' £!.J \~ ~ Ii' . POINT," ìdCAPE HALKETT I , .~, ~. --+ _..j. --<.. ··~·.UGR. 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() I: L._ I ""~~=.f.:,:~.-.JL.....! .L~ J ~c . _ ¢"T -.....;;, . ;-SENTINEL " ,'_' +""'::,,___ ¡ .. t' ,'. ') , J . .' , -----. . i" 'HILL I t~. - .),r: :;:r-::-~:c " . . (, . . . . 4Q~,fEI~ GUBIK ;"'., .. ," . "'-._. . . ,_ t. _ . ~~ . TITALu'K.!k : WOLF~. SE.ABEE I'" I . j .. ... .) ,\ V' - \y CREEK' + t ,_, ' ~. ,L , ' 1,2,3,.., - ,.rrc:7' UMIAT _ F~"'/-:/ : . 'G:) . . .., í" "..-T AREA GUBIK 1__ . "~; _ r~·-~, I ''I . ~ t ' . ,._/. 2 J-"L..L,/ _ -:-! . -'. - -4-~WUNA I . ~. -<;P-r'KNIFEBLADE~ i.' ¡ 'ï'..( . ~..-:...' -:-'" ... '... I . -~ . .. r· "..._,'-'..1, 2,2A...r -*- t' ,": t...- .. . -:' - :--~...-i· i"'\: ' - ~ . ';:[ y .'. . \..; . rI . , . I' ~- ;.,., ~,. ..." GRANDSTAND I r-' .: -- : -L - -- . . i : -~--=-- ~.. i i r, ; r.' .( .~.:....:. - .. ~~ . ¡.. ,~,. i I t. ~'CT-_L... .~~ ' ... ...,. .......... , I' v õ;,,-.J"'" -"'.;\,' : -' ~............ ! , '\. " . . "~LlSBURNE I v~ i . €. -Y¡' . t.~"'7 ~G~_ i I 5? MI, I .¡.!r~ _f\~~'" i 75 Km. ~O¡O O~O -\.! e ! ""\' I ,., "' 'W -----+- .--- .---...-----..--.-. c; r I C " It + + ~ . , , If U J' ,. , I~ -¢- + ..- -$- ~ ~ ~ ~ ~ ~ ~ .v- i$- ~ ~ -<>- ..- ~ ~ ; \- ì+ + - . . - .v- . I - =':"~'::'E.C~ I _ ::.. ." --~:::' - - ~ I' -V- ~~T~~~~~C..._ tNDEX MAP-PET·48 NPRA TEST WELLS ANt) SELECTED CORE TESTS. 1944-53 1974 -81 ALASKA 25 I o ~~ o 25 NPR , 50 ~-_._--- -- - --_.,~_. ---- --. TETRA TECH REPORT NO.8200 --.-- BARROW AREA I ARCON BARROW I S. BARROW I S, BARROW 2 S. BARROW4 S. BARROW 5 S, BARROW 6 S, BARROW 7 S. . BARROW 8 S, BARROW 9 S. BARROW 10 S, BARROW II . S. BARROW 12 S, BARROW 13 S. BARROW 14 S. BARROW 15 S, BARROW 16 S. BARROW 17 S. BARROW 18 S. BARROW [9 S,BARROW 20 AVAK I UMIAT AREA I UMIAT \ UMIAT 2 UMIAT 3 UM IA T 4 UMIAT 5 UMIAT 6 UMIAT 7 UMIAT 8 UMIAT 9 UMIAT 10 UMIAT II FIGURE 2 i£ o \ 8 - !.~·h..':"~t"·.':"'~~ . ..Old" .. .·.a\.j' Hells (1944-:'3) . Well Name Avak -, lOö-Oé)"?- south Barrow-l /00 -083 South Barrow-2 /OD-ðE)'! South -Barrow-3 l(}D ~ó~ i South Barrow-4 IOO~08' F:i:sh Creek-lIDO -)ðÌ) I G1tandstand-l 100 -(þ5"3 I Gubik-l fOb-/):} I ¡ I Gubik-2 IDO-:J:J{) . Kaolak-l 100 -a~ , I Knifeblade-l JðO - IÌ).I Knifeblade-2 10D - .Ac99 Knifeblade-2A ì:s 1'\0 J(""iPe.lølG.de 6- z.\eaåe-l OUmalik-l ¡OO-II"! - Eas-t oumalik-l 100 116 Simpson-l I [)()-I"~ NiJlf"fh S/n,p::",q-I lOD....OI'fr Squ'are Lake-l J 00 -/{l,.. Tita.luk-l 10o-/~Ò . Topagoruk-l ¡DO -,qt Ea'~t Topagoruk-l I ~t) Umiat-l IDD -Qút1 I \ \ I ì \ 1 t I t ) loó-~'D 100-(:).( / Umiat-4 100 ,81:;). . Umiat-5 100 -g/3 I --I Umiat-6 /()Ù -;}.Iq¡ ..... Umiat-7 I()Ó _~I ~ i I Umiat-8 /op -;) l" ì Umiat-9 Jó ö -Q/1 J Umiat-10 toD-f)l1f Umiat-ll IDO "'Q/~ I Wolf Creek-l IbO-111~ ¡. Wolf Creek-2 /UO-\I'~ ! Wolf Creek-3 I d) -# ID¡ _._. _nO _~_.~_."_.. ~ ,....-.. ~_........_.-_.-- Umiat-2 Umiat-3 . "Intermediate" Wells at Barrow. (1955-1974) . . South Barrow-5 IÖÖ -t;>d."6 South Barrow-6 'oo-od'1 ., South Barrow-7 16b'-o3D South Barrow-B I 6Ó! -03/ , South Barrow-9 IOD-é:ß;;J. South Barrow-10 lcÞ-ó33 south Barrow-ll I($> -ó'3~ ~ I t I South Barrow-12 /ðO-ò~ ~ . ÌI .. -- ----..----.---....--...... /.f6