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00- v3 Q. • OF Ziti•���kIV�%C� THE STATE �t �r°,� i�L c:f 1�LINL`° LlmeirndL Conservation it` Division of Spill Prevention and Response Contaminated Sites Program GOVERNOR SEAN PARNELL 610 University Ave. ALA£s$ Fairbanks,Alaska 99709-3643 Main:907.451.2181 Fax:907.451.2155 July 11, 2013 Wayne Svejnoha Supervisory Minerals & Energy Specialist 222 W 7th Avenue, #13 SCANNED MAR 1 1 2014 Anchorage,Alaska 99513 Re: BLM Legacy Wells Dispute Dear Mr. Svejnoha: 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 Alaska: 2013 Legacy Wells 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 AOGC 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 are 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 or 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 limited 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. o>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 Wayne Svejnoha 2 July 11, 2013 The BLM 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 future when 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) This 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 SI 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 CERCLA 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 Characterization Report and cleanup plan under 18 AAC 75 is required. DEC recommends that BLM incorporate into the strategic plan 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. (:•\CAAA\rc\FoAP.,1 Fn.41:r:oc\r;..;14,,,FPri P.oi AoP.,riec\DOT\RT.M\Proiects\Leeaev Wells\7 11 13 Letter to BLM on Legacy Wells.docx Wayne Svejnoha 3 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, 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 G:\SPAR\CS\Federal Facilities\Civilian Federal Agencies\DOI\BLM\Projects\Legacy Wells\7 11 13 Letter to BLM on Legacy Wells.docx o 2 M CO>.� -o a t m ,N 1 a) N a a -o ° ° N m ai Q? a d U c° a) co a) co ca ca ca a m o CO Ca (a m a) Ca Ca m CO c N 0 U = i° m CO Ca a) ca 0 ns .N o) ca ca m is m m m as co o) ca c U a a a a a a a a 4, ° a a a a s a a a a ay 0 0 0 0 0 0 0 0 a 0 0 0 0 0 0 0 0 0 0 cca ° Q u) c c c c c c c c a C C C CC C C C C 0 Z 'a - a) Y a) a) a) a) N >.- C) C) a) a) a) a) a) a) 0 o a) 0 0 0 0 - 3 Y o 0 0 0 0 0 0 0 - ° t U L L L L a L `) .c .0 L t L L L - C .t u C C C C .O N -O _C w C C C C C C c (a a= V a) o = = = > N 2 a= a a d co o a) C) a) 0) o .N J N N N N N N teaa)) N 0 co C N ° _ A p N N N N a C Co N N N E h C D a o -c 0 ° a > 5 > > U ° a a a a ° S a a a a a 5 S 5 S E -Z o U N = c c a) o U c 30 c = o = c c c Ca o a a UU' r v co c c c c Cl) c 0 c .n 0) c c c ro c c c c c N co o) CO < U)) C C C -o -o '0 3 m < 4 0) -o -`O -0 C OC C a -o lc a > L 0- C 0 co O o a �0 a f° a f° a co a S a m C 0 a -O N a h a N a N a N a f-C4 a f-C4 a N Z CO O) a ' '- a o- - a a) a- a• a•- a o- a.- a 0- < = _ .c.:'-. 2- C Y C ,..°- 0 Y O Y U 3 N Y C Y C Y Y _ C Y C Y C Y C ` O- a — = G= C= G= G= C= O OW - 0 - 0 - 0 - O = 0 = 0 -• - N = 0 = 0 = 0 = ow - o - o - o = o Cl) C - s-t Q Q-o 3 -0 3 -`0 3 � 3 -`0 3 - 3 CO 0 n p 3 - 3 a 3 v 3 Q a 3 - 3 -0 3 - 3 Q -C r ° (oa r a) 0_ 0_ V . 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C C- C C Q Q C ° a c m o = c4 i = 3 0 - 3 C E 0 3 0 Tn o -) o cmi ., 'r m -0 m a a a n. a a a _ 0 = O n Y U ~ 0Ea) c .� -c a ac) c aot `0E0oam a a a- a a a (Y ac cCO o a m II' s 3 a 3 o a a E c 0 o E C c o a a CC CC CC CC a E E CY I ° ( a w c o a) a) c) o, n c Z o) n a - m a) o ai m m 2 2 I I 2 L = ti y 0 a • Q d 'O E a) co c C ,, m (n m m U .0 m r • ti ,C t 'y a) an a -0 -o a -o -o -0 0 0 m o a o o c E co.) o a' = a) .) r O N o a) a) a) a) a) a) a) w v) a) °) C m t/7 T < m )n - U ` a) >, m = O m L a7 a) a) a) a) aJ a) a) y m )n ('i C a v) mOa `o O _0 O0_ U) ca (7) F- si 3 -`o C I— Z Z Z Z Z Z Z CO CO 0 3 0 X (I x 14- 11 1I /) C `' ( U 3 3 3 3 3 3 N C - N 0_ U w N 0 m C C C C C C '> _ c � r i c, 0o2 2.ca gZ,OPE 4 NORTH SLOPE BOROUGH or -°�oDEPARTMENT OF PUBLIC WORKS Division of Fuel and Natural Gas Facilities P.O. Box 350 \.rte °i,, t_ . Barrow, Alaska 99723 Phone: 907- 852-0489 Fax 907- 852-0327 August 14, 2009 SCANNED APR 2 2 2014 Ms. Cathy P. Foerster Commissioner Alaska Oil and Gas Conservation Commission 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Re: 20 MC 25.300 (Request for Information)—Status of Oil and Gas Wells Dear Ms. Foerster, This letter is in response to your request concerning the status of the North Slope Borough, (NSB), Gas Wells SB - 8, SB - 11, EB— 15 and EB— 19. Currently all four wells are suspended. The NSB plans to drill several wells in both the East Barrow and Walakpa gas fields in 2010 and 2011. As part of the drilling program we tentatively plan to plug and abandoned Wells SB-8, SB-11, SB-13, EB-15, EB 19, EB 20, and NSB-2. As our drilling program firms up I will be able to provide you with our final plan and schedule. In addition we are still evaluating returning well SB-9 to production and reworking Well EB-21. Attached is a chart of the BGF wells showing their current status and our future plans. Wells that are already plugged and abandoned are not included in this chart. If you are in need of addition information you can contact me at 852-0285 or at kent.arinage( north- sloDe.orq Sinc y, Kent M. Grinage Division Manager, Fuel and Natural Gas cc: Marvin Olson, Director Enclosure Barrow Gas Field Well Status — July 2009 South Barrow NSB - 1 1870710 production N/A NSB - 2 1870720 production plug and abandon SB - 6 1000290 production N/A SB - 8 1000310 suspended plug and abandon SB - 9 1000320 suspended return to production SB - 10 1000330 production N/A SB — 11 1000340 suspended plug and abandon SB — 13 1000370 suspended plug and abandon East Barrow EB — 14 1000380 production N/A EB — 15 1000450 suspended plug and abandon EB — 19 1000410 suspended plug and abandon EB — 20 1000420 suspended plug and abandon EB — 21 1901120 Production Work over New Well Methane hydrate Ualiqpaa Walakpa 2 1000480 production N/A Walakpa 3 1901700 production N/A Walakpa 4 1901710 production N/A Walakpa 5 1901720 production N/A Walakpa 6 1901730 production N/A Walakpa 7 1911550 production N/A Walakpa 8 1911560 production N/A Walakpa 9 1911570 production N/A Walakpa 10 1920070 production N/A 4 New Wells production · e UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Office of National Petroleum Reserve in Alaska 345 Middlefield Road Menlo Park, California 94025 DATA TRANSMITTAL Date: October 29, 1981 To: Will i am Van Al en Alaska Oil and Gas Conservation Commission 3001 Porcupine Drive Anchorage, Alaska 99501 ITEM/ ITEMS Gamma-ray logs of following wells: (11) S. Barrow #9 Wa1akpa #1 S. Barrow #15 S. Barrow #18 S. Barrow #19 Dal ton #1 W. Dease #1 Foran #1 N. Ka1ikpik #1 E. Simpson #2 Tuna1ik #1 From: ~i!I(D1i!I~ L. S. Page U. S. Geological Survey Office of National Petroleum Reserve in Alaska 345 Middlefield Road, Mail Stop 87 Menlo Park, California 94025 Please acknowledge receipt on this memo and return in self addressed envelope attached. hE It" CEIVED NOV 1 Ù 19 Alaska Oil & 8) Ga.~ Cons Mrt11òragé COl17rnlsSiofl ft.... cei~,t 2! ~veace......~..o~~ledged~ . t" / "r/ .' ...""1./ ~ ¿,/'C'"~, . Name ,.,., t, ,', - ., ,~ . --- ,.. . .' '. MEMORANDUM TO: M. F. Westfall FROM: J. M. McCarthy SUB.J: South Barrow No. 9 - Log Analysis . Jwxe 26, 1978 Attached for your information and transmittal to the USGS is an !;ngineer:i:ng Memoranda by Steve Lewis concerning computeriz~d log interpretations· of the .logsuite from the· South Barrow No. 9 well. Steve has analyzed and compared the original Schlumberger Saraband interpretation, the Gruy Dual Mïnera1 interpTetation, and the new Saraband run using the revised program. A copy of the memorandå has been sent to H. J. Gruy for their use along with' copies of the new Saraband log analysis. It is anticipated that Gruy will rerun their analysis wi.thcorrecte4 data. However, this will probably not be done until core analysis work currently being conducted by Core Lab is completed. ,/ . # Å JJ/1/kf' /i-£/¿r t4. M. McCarthy Attachment ." ..¡~, ' ~ , ~ . ,'.~ , ,. ... . . ... ENGINEERING MEMORANDA June 19, 1978 . , Re: South Barrow Well No. 9 - Comparison and Contrast of Scblumberger Saraband Log Analysis and H. .1. Gruy Dual Mineral Log Analysis The Schlumberger Saraband log analysis program and·tbe H. J. Gruy Dual Mineral log analysis program are both iterative log analysis programs which process digitized data extracted from standard well logs through combinations of graphical and mathematical analysis techniques to derive reservoi~ parameters such as porosity, permeability, saturation, and clay content. The graphical and mathematical methods employed in botb programs are standard throughout the industry and are the same as those used in . , manual log analysis. The advantage of programatic log analysis is that many of the basic equations are interdependent and can be best solved in an iterative fasbion. Also of merit is the greate~speed and accuracy of statistical analysis and data processing inherent in computer analysis. Although tbe Schlumberger and Gruy programs are very similar in their method of solution, there is one primary d~fference. The Gruy program allows for the input of three different matrix densities while the Saraband program uses but one matrix density. As a result, the Gruy program has greater flexibility in compensating for m1.xed ör: "dirty" lithologies. The input data to this . type of program is easily divided into two types on the basis of origin. The first type of data is the digitized wêll log data from the suite of logs being analyzed. This data r~flects tbe measurement of physical parameters in and around the wellbore and sbou1d be identical regardless of the type of analysis being performed. Presented in Table I are some of the nonvariable input parameters in use in the Schlumberger and Gruy analyses. Discrepancies, primarily in the Gruy data, are due to analyst error. The second type of data are, unfor'tunate1y, much more nebulous. Although the equations used in log analysis have been proven valid through years of usage, they are often empirical solutions of observed data. As a result, the many constants, exponents, and limits employed in these solutions can vary considerably. One of the major-perturbations in these parameters is the presence of indistinct or mixed lithologies. Therefore, these factors often must be der~ved from offset well data, area experience, tbe analyst's experience, and sometimes by intuition. Table II presents an aray of input par~eters of the "variable" type. Of primary interest is the change of these values between the two Saraband runs. Yb11e tbe porosity and saturation parameter cbanges a~~ due to increased offset well data and area experience, the clay content parameters from tbe first Sar~band run are simply in error. Although the' cause of this error is speculative, the fact is th~t all tbe Gamma Ray limit values input in the first Saraband·run are more tban twice what would be a reasonable interpreation of tbe actual Gamma Ray log. . . .Engineering Memoranda ~ South Barrow Well No. 9 - Comparison and Contrast of Sch1umberger Saraband Log Analysis and H. J. Gruy Dual Mineral Log Analysis Page 2 . AÍthough there is some variation between the second Saraband input and the Gruy input, these values show close agreement considering the differences in the programs and the backúp data available to the two analysts. Table III presents a comparison of the results of the three analyses in question. In light of what we now know about the ·reservoir and the per- formance of the well, it is my opinion that the first Saraband log is· obviously incorrect, the second Saraband is probably somewhat pessimistic, while the Gruy analysis is somewhat optimistic. The selection of net pay is based on a 65% water saturation cutoff. The water saturations calcu- lated show the greatest v~riation and are the main factor in my opinion of the quality of the two analyses. Stephen K. Lewis Reservoir Engineer ""--- r . , TYPE Wmud Rm Rmc Rmf Tm Tres Depth Bit Size . . 0'. TABLE I . COMPARISON OF INPUT PARAMETERS SOUTH BARROW GAS WELL NO. 9 2374' TO 2437' SCHLUMBERGER SCHLUMBERGER SARABAND SARABAND RUN 1 RUN 2 10.0 10.7 2.75 .- 2.75 . 3.76 3.76 2.36 2.36 60°F 600F 54°F 750F 2450 2450 8.75 8.625 /' ., H. .J. GRUY DUAL MINERAL 10.6 2.48 3.11 2.28 55°F 75°E' 2105 8.62 , . . '." TA:BLE II . SCHLUMBERGER SARABAND AND B.J. GRUY DUAL MINERAL COMPARISON OF INPUT PARAMETERS SOUTH BARROW WELL NO. 9 SCHLUMBERGER SCHLUMBERGER B. J. GRUY , P AMMETER RUN 1 RUN 2 DUAL MINERAL TYPE P ARA..}ofETER 4/17/70 4/26/7.8 1977 Porosity Matrix 2.65 2.65 2.65 Parameters Density 2.71 2.71 Dry Clay 2.84 2.98 2.53 Density Neutron 0'.37 0.47 0.25 PQrosity of Clean Clay Density 0.13 0.04 Porosity of Clean Clay Compaction Factor 1.00 1.00 1.20 .... -·;Saturation Formation 0.40 0.25 0.35 Parameters Water Resistivity Clay 1.00 6..00 3.60 Resistivity Upper Limit 13.00 8.00 of Shale Resistivity Clay Content Lower Limit 170.00 60.00 70.00 Parameters of Gamma Ray in Sha1ey t"ormation Upper Limit .240.00 108.00 of Gamma Ray in Shaley Formation Upper Limit 130.00 36.00 of Gamma Ray in Clean Formation G~.mma Rav 70.00 28.00 25.00 . , . . .. '. TABLE III COMPARISON OF DERIVED RESERVOIR fARA11ETERS SOUTH BARROW GAS WELL- NO.9· 2374' - 2437' WATER % CLAY NET PAY POROSITY SATURATION IN NET PAY SCHLUMBERGER SARABAND 4/17/50 4' 17.6% 62.5% 0.0% SCHLUMBERGER 30' 15.8% 55.6% 5.6% SARABAND 4/28/78 R. J. GRUY 42' 15.1% 50.2% 17.4% DUAL MINERAL \ / \, , . UNITED STATES . DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Office of National Petroleum Reserve in Alaska 345 Middlefield Road Menlo Park, California 94025 April 17, 1978 ~ ~ ~:.~, ,--.... ~, ........... Mr. Harry H. Kugler Division of Oil and Gas Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99501 ~-,: t. ..¡~.'" . . ,}>. r":· Dear Mr. Kugler: He are sending you, under separate cover, sepia and blue line prints of logs on the following wells from NPRA: East Teshekpuk #1 South Barrow #6 South Barrow #7 S9u;tJL;§~ILo~8 q:~~.~~~~~~-~ South Barrow #11 South Barrow #12(East area) South Barrow #13 South Barrow #lLf(East area) , ."..... ~'.."'~- 4',~-, n~'" F:-:-' ~. Lists of the logs for each well are attached and those we are sending to you are enclosed within the red outline. The letters "s" and "p" indicate "sepia" and "print". ....".,---.r; ... . ,.....,.;¡, ~~. ~,~ :;-">4Ii..,. ~. These logs are not to be released to the public until their availability is announced by the Environmental Data Service of NOAA in Boulder, Colorado. NOAA will be the primary distribution agency arid their release of the data will be authorized by the Office of National Petroleum Reserve in Alaska at the proper time. t:::;.1I' .' ~_ > - tt- ( , I!{;",' ..~~, Please acknowledge receipt of the logs and your under- standing of the release procedure by signing the attached copy of this letter and returning it in the self-addressed envelope. Very truly yours, ,0.." A ~0; / -;¡?-. ,( Û(j../(-1I.--'( l¿J &i'1vz,.z.~ Robert D. Carter ,,',.. ¡. "' ~~, "->:>' /Ýo /,'?('/ ~ drJ é/.. .z.,.? '" ? 8 ~()K ~~.\;, ~~ ,,","""': ' ~ r '. e . Page -º-- of 11 WELL NAME: South Barrow #9 ITEM TYPE LOG SCAL E BASE RUN DATE LOG INTERVAL COPIES REQUESTED l. IES 5 F 2 4-7-70 1102'-2448' F;S ,P 2. IES 2 F 2 4-7-70 1102'-2448' F,S,P 3. BHC 5 F 1 4-7-70 1102'-2449' F,S,P 4. BHC 2 F 1 4-7-70 1102'-2449' FJS,P 5. FDC-GG 5 F 1 4-7-70 11 02' -2448' F,S,P 6. SNP 5 F 1 4-8-70 2448'-2450' F,S,P 7. CBL 5 F 1 3-29-70 100'-1088' F,S,P 8. CBL 5 F 2 3-29-70 100'-1088' F,S,P 9. 'CBL 5 F 3 4-13-70 100'-2437' FsS,P 10. Dr'1 (ARrow Plot) 5 V 1 4-8-70 11031-2447' F S,P ll. Saraband 5 F 1 4-17-70 11 00' -2450' F S,P 12. MPL 5 F 1 4-8-70 1102'-2446' F S,P ð · .' UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY Office of National Petroleum Reserve in Alaska 345 Middlefield Road Menlo Park, California 94025 January 3lt 1978 Mr. Harry W. Kugler Division of Oil and Gas Alaska Department of Natural Resources 3001 Porcupine Drive Anchorage, Alaska 99504 (I ¡ (\.'t) R /'\ -}, ..<: , I v' "\ ""\ f 14\ ",,-..ù.Q..;.~ l-,,"'r~ .. r )U.:tL í-8~ r\)'J v\.; ~ Dear Harry: The enclosed lists detail a large number of chips from I-foot intervals in cores (South Barrow 2, 6,~, 12, 13) that we had ass.essable in Menlo. They have been shipped in~'{oxes as noted on the list. ;t ~ Unless you refuse to deal so haphazardly, we will keep shuffling chips to you as we have a chance to sample. Currently, most will come from Doc's work in Anchorage. Hopefully, you will keep a systematic record so that in a year or so we can mutually define the gaps in your collection and fill them specifically. Catching up on the pre-Husky material will be a big job that will be justi- fied by having your library as complete as possible for the succeeding generations. We'll be getting to the post-Husky cuttings and the pre-77 well material shortly. Regards, ~ Irvin L. Tailleur [:(tCEIVED FED -6 1SJ78 Enclosures D;vislon of Oi and Gas C¡¡nss;w,;¡on At)û!Jornqc I< 'Ø1r óitJ ;pr: CL1V' .) j¿~ ~rrD ? I· , i~~ " f' Hr:-. ,/~~' ~-¡..'.'...'.' ../:r --.,." '. r. " ~ "IIì.~."" ~...'- ~(.' ..,..,., ~~~- rr ¡ I' ! L ~. ~ ~:. i...·ft·~ -- "",.,~,.. ., ~~~ l t - ~. . 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NAVAL PETROLEUM AND OIL SHALE RESERVE NO.4 DRilliNG REPORT GAS WEll NO.9 SOUTH BARROW GAS FIELD BARROW, ALASKA Prepared For DEPARTMENT OF THE AIR FORCE ALASKAN AIR COMMAND Under CONTRACT NUMBER F65517-69-C..oOO1 by E. l. Herbst Holmes & Narver, Inc. Drilling Superintendent, Geologist and Drilling Engineer for Gas Well No.9 AUGUST 1970 . HOLMES & NARVER9INC. A RESOURCE SCIENCES COMPANY 828 SOUTH FIGUEROA STREET LOS ANGELES, CALIFORNIA 90017 Advanced Technology/Engineering/Construction / Management! Maintenance & Operation . . TABLE OF CONTENTS Page PART I / ABSTRACT 1 PART II DRILLING EQUIPMENT AND SUPPLIES ACCESSORY BUILDINGS HEA TING PRINCIPAL EQUIPMENT ITEMS 5 5 6 7 PART III PROCUREMENT OF SUPPLIES 15 RIG UP 15 MANPOWER, 17 SERVICE COMPANY SUPPORT 19 ./ COMPOSITE WELL SUMMARY 24 / / MUD PROGRAM 32 GEOLOGY 34 ./ CHRONOLOGICAL DRILLING SUMMARY 41 DEMO BILIZA TION 43 WELL NO.9 RECORD DISPOSAL 46 DRILLING AND COMPLETION COSTS 47 1 . . Page PART IV EQUIPMENT STATUS 50 PART V SUGGESTED PROGRAM FOR DRILLING GAS WELL NO. 10 58 MINOR RIG REPLACEMENT PARTS REQUIRED 60 RELATED RECOMMENDATIONS FOR DRILLING 62 SAFETY 64 ii GAS WELL NO. 9 DRILLING REPORT PART I ABSTRACT . . ABSTRAC T Gas Well No.9, located within the South Barrow Gas Field of the U. S. Navy Petroleum and Oil Shale Reserve No. 4 was drilled, evaluated, and completed as a natural gas (methane) producing well during the period March 19 to April 15, 1970, The well location is approximately 5 miles south of the shore of the Arctic Ocean near Point Barrow, Alaska, and 200 miles west northwest of the Prudhoe Bay Operations. Drilling operations were carried out by Holmes & Narver, Inc., of Los Angeles, California, prime contractor to the U. S. Air Force for mainten- ance, operation and related construction at the Point Barrow Navy Research S-~te. This site is the base of operations for the Naval Arctic Research Lab- oratory operated by the University of Alaska under contract with the Office of Naval Research. Holmes & Narver's Project Manager is Carroll C. Livingston, and the Drilling Superintendent on Gas Well No. 9 was Emmett L. Herbst. Funding for the drilling and associated work was provided by the Office of Naval Petroleum and Oil Shale Reserves by transfer of funds to the U. S. Air Force. Contract administration was handled by the Contracting Officer, Alaskan Air Command, Major George T. Gehrig, at Elmendorf Air Force Base, Anchorage, Alaska. The well was drilled and cored to a total depth of 2,450 feet and, on initial production test, flowed at a maximum production rate of 6 MMcf/d. On subsequent test after 9 days of on- stream production, this rate had increased to 7.8 MMcf/d at a measured reservoir pressure of 993 psia. No water was produced on either test. Production from Gas Well No. 9 was turned into the local field gas gather- ing system on May 21, 1970. Gas produced from the well, together with that produced from the other wells of the South Barrow Gas Field, is used as domestic fuel for the Eskimo village of Barrow, which has a growing population now in excess of 2,500 persons, and by the Point Barrow Navy Research Site complex, as well as the DEW Line station POW -Main. Well No. 9 was drilled to prove additional field reserves and to provide critical production backup capacity for the expanding demand which, in the past year, has increased from 1. 592 MMcf/d to 2.018 MMC£/d, with peak demands from 2.2 MMcf/d to 2.374 MMcf/d. The drill rig, together with other major drilling components and support equipment were, for the most part, items retained at Point Barrow by the Naval Arctic Research Laboratory, the Office of Naval Petroleum and Oil Shale Reserves, and the Colorado Oil and Gas Company, following termination of the Navy's exploration and drilling operations at Petroleum Reserve No. 4 in 1953. - 1 - . . The South Barrow Gas Field producing formation is known as the South Barrow Sand of Jurassic age. In the drilling of Gas Well No. 9 this~ formation was topped by core lithology at a depth of 2,379 1/2 feet, kelly bushing measurement (KBM), and was penetrated 70 1/2 feet for a total well depth of 2,450 feet. The sandstone reservoir, which underlies a black shale conglomerate of 200/0 + smooth beach stones, is comprised of fine-grained, gray- brown, soft to firm sandstone. The sand is very slightly argillaceous to clean, with fair to good porosity and permeability. It has a strong gas odor, a trace of brown stain, an even yellow fluorescence and a yellow-white cut. The upper 4Q feet of the pay formation was deter- mined by core analysis to have marginal productive permeability. The lower 30 feet has fair to good permeability and is the main pro- ducing section. Coring of Well No. 9 was stopped while in good pay sand an estimated 45 feet above the field water contact of 2,495 feet to reduce the probability of water entry into the gas production. To minimize drilling fluid damage and possible water blocking of the producing formation, conversion to 60/0 diesel mud was made at a depth of 2, 230 feet. A production string of 7~inch O. D., 38-pound/foot casing was set in the top of the pay sand and cemented to the surface through a formation packer shoe and a DV collar. A 2-joint section of pre- perforated 5-inch liner was hung free through the pay zone. A tubing string of 2 7/ 8-inch pipe with 7 joints of 2 3/ 8-inch pipe on the lower end was hung to approximately 8 feet off bottom. Structurally, the well came in 100 feet low to Well No.6, the closest producing well of the field, and approximately 60 feet lower than previous field mapping extrapolations had indicated. By good correlation character the well is 45 feet low to Well No.4, 112 feet low to Well No. 8 and 140 feet low to Well No.7. Coring, additional logging, and testing of the upper gas zone of the field pay sand, and of the permafrost showed the following: (1) The upper sands have significant residual oil satura- tion and, although thin, have gas productive capability. (2) The conglomerate formation that overlays the pay sand, contrary to previous indications, is a fairly soft shale conglomerate with black polished quartzite beach stones to 200/0 of the matrix rather than a typical well-cemented hard rock conglomerate. - 2 - . . (3) The South Barrow Field pay sand in Gas Well No. 9 is a fairly clean sand with only a minor shale content compared to the sha1ey sand found in the cuttings of Gas Well Nos. 7 and 8. (4) Radioactivity dating of a piece of well-preserved, partially petrified wood found in a core at a depth of 2409.75 feet may indicate that the producing formation is not necessarily of Jurassic age. (Sample turned over to the Naval Arctic Research Laboratory at Point Barrow for study. ) (5) The overall section below the surface pipe to total depth is moderately hard and competent, and far more resistant to softening by drilling fluid than the drilling samples alone had indicated. (6) The depth of the permafrost at the South Barrow Field is 1, 250 feet. Actual drilling and waiting on cement time for Gas Well No. 9 was consider- ably less than that for the previous wells in the South Barrow Field. How- ever, coring, drill stem testing, logging, and velocity survey operations undertaken to further evaluate the field reservoir, and the related addi- tional trip time involved in these operations, brought the overall opera- tional period to 28 days. This is approximately the same period as was required on previous wells in the field for drilling and completion alone. Although the drilling program was significantly expanded to obtain from Well No. 9 a maximum of field reservoir data and section evaluation, the total cost of the well was less than for previous wells due to effective cost controls. No significant mechanical or operational problems were experienced due to lack of supplies, waiting on service companies, labor disputes, program changes, weather or other reasons. Several equipment innovations, and changes in methods of rigging resulted in greater ease of operations and savings in rig time over previous years. An exceptionally good job of cementing the well casing resulted from the use of Fondu cement with conventional cementing techniques, and the application of some very new and extreme techniques developed by Mr. Richard Murphy of the Office of Naval Petroleum and Oil Shale Reserves, for use with type G cement. Several days of waiting on cement rig time were thus saved in comparison wi th previous wells in the South Barrow Field. - 3 - . . Grateful acknowledgement is extended to Petroleum Engineer, Mr. Richard Murphy of the Office of Naval Petroleum and Oil Shale Reserves, Washington, D. C., and to Mr. James Dalton, Naval Arctic Consultant for Petroleum Reserve No.4, Fairbanks, Alaska, both of whom actively participated in the drilling operations. Their around-the-clock, overall active participation, and the contribution of their Arctic operational expertise materially assisted in the successful, economical, and safè drilling, testing and completion of Gas Well No.9. Particular appreciation is also ext~mded to Mr. W. J. Jacoby, the Tool Pusher from Las Vegas, Nevada., whose ageless experience, ability to innovate and sense of humor kept the rig running through the many weather and mechanical problems typical of an Arctic operation. - 4 - GAS WELL NO. 9 DRILLING REPORT PARTII EQUIPMENT . . DRILLING EQUIPMENT AND SUPPLIES All primary drilling equipment and the bulk of replacement parts used for drilling Gas Well No. 9 were Government-owned items which had been in storage for many years at the Point Barrow Site. One significant addi- tion, however, was the purchase from Colorado Oil & Gas Company of a National (Ideal) C-Z50, 7 1/4- by IS-inch mud pump powered by 4 (Quad) 6-71 General Motors diesel engi.nes. This unit was previously rented from the Colorado Oil and Gas Company inventory remaini.ng in the Barrow area for use in the drilling of Gas Well No. 8 in 1969. In addition, all Aquagel and weight material (Baroid) for the drilling mud, and the salt used for bringing in the well was purchased from the Colorado Oil and Gas Company inventory. Purchases of equipment and supplies for the drilling operations, including $36,000 for the mud pump unit, totalled $83,300. In some cases it was cheaper in total to purchase equipment rather than pay the combined cost of rent, standby time, multiple trip air transportation and possible loss of rig time. All of the non·-expended items purchased will be needed again on subsequent drilling operations. Principal items of this category include a set of 4 l/Z-inch elevators, Z each 4 liZ-inch drill pipe pup joints a 7 S/8-inch Christensen diamond core bit, and a Bakel' left-hand square thread sub for use with 13 3/8-inch and smaller duplex casing shoes. The Halliburton Cement Head for 7 -inch casing intended originally to be pur- chased was returned to the supplier with only shipping cost charged to the well. ACCESSORY BUILDINGS In addition to the drill rig, there were 16 service structures utilized at the drilling site as follows: Drilling tool warehouse (at end of catwalk) Pump house C-Z50 pump (main pump) Pump house Gardner Denver (auxiliary and mud mixing pump) Mud tank house Boiler house Water storage tank house Light plant Shop Halliburton pump house Cement storage shed Mess hall Latr ine Four-man sleeper hut (wheel mounted monster) - 5 - . . Crew change house Welding house Geologist/mud logger I swanigan With the exception of the canvas lean-to cement shed with a snow floor, and the C-250 pump house which was set on timbers, all structures were either sled mounted or equipped with pipe runners or skids. HEATING As is normal for wintE:r Arctic drilling operations, an adequately heated environment was essential£or the operating efficiency of both personnel and equipment. Although the overall average temperature was moderate (in the range of -200F) during the operation with only occasional drops to about -500F, continual compensation for changes in wind velocity, direc- tion, and the chill factor (to -lOOOF) were necessary to minimize equip- ment failure. Location and arrangement of heat sources were adapted to the immediatp ape:ratlunal ::,,~quirement. As has been noted on other occasions in the Arctic, the workmen could usually withstand extremely low working temperatures better than could the equipment. The drill rig was fully enclosed with canvas and heated by 3 steam radiator units with 1/2-HP motors located on the rig floor and 3 others placed in the sub~ structure under the floor. These were augmented by Herman Nelson heaters as necessary to keep the BOPs warm and operable. The hazard of drill stem testing within the enclosed rig was minimized by opening all doors periodically during the test and reverse circulating through the drill pipe prior to bringing the test tools out of the hole. The C-250 pump húuse was more than adequately heated by the pump engines, while the mud tank house was heated with a steam coil con- nected to the boiler. All other buildings were heated with diesel-fueled circulator-type heaters. Heaters remaining from the 1969 operation were checked out and new wind-proof chimneys installed as required; 7 new and 4 used heaters were purchased and installed. A separate gravity feed fuel tank consisting of a 55 -gallon oil drum mounted on the exterior of each structure sufficed for fuel storage. Additional heat wherever required was provided by 7 Herman Nelson aircraft-type, wheel-mounted, gasoline-fueled heaters. Flexible 6- and l2-inch hoses were used to direct the heat to points required. Steam heat for the rig floor, substructure, blowout preventors (BOPs), mud house, and for steam cleaning was provided by a Kewanee type automatic controlled diesel-fired boiler generally capable of holding 48 pounds of steam. However, due to the age and general condition of the boiler, and the low outside temperatures, only 10 to 18 pounds of steam could be held. This deficit was made up by judicious placement - 6 ~ . . of the Herman Nelson heaters mentioned above. These heaters and the boiler required continual maintenance and repair. One full time laborer was assigned to each tour with the primary duty of fueling the circulator heaters and the Herman Nelsons. The heavy equipment operators and the mechanic on each tour also assisted with the heaters and fueling as their time permitted. PRINCIPAL EQUIPMENT ITEMS Dri~l Rig A Cardwell Model H, unitized rotary rig with double drum, normal manual controls, cathead and rotary drive assemblies was used. The other principal items of drilling equipment consisted of a single- engine drawworks, powei'ed by a D-8800 Caterpillar engine; a 100- ton Baash-Ross traveling block with 3 each 30-inch sheaves cut for I-inch drilling line; an Emsco type AB-4, 60-ton rated swivel; Web,.. Wilson break-out tongs with heads for all sizes of tubular goods handled; various sizes of drill pipe, collars, casing and tubing slips; an Ideal 17 1/2- by 44-inch rotary table; and a Martin Decker weight indicator. Derrick An eighty-foot American Standard derrick, reinforced with 4-inch pipe to which had'been added a nominal I2-foot vertical extension to raise the crown block assembly above the normal water table position to permit easier handling of doubles of Range 1 drill pipe was used. The derrick, including crown and substructure, was completely enclosed with canvas and heated. Due to the local high winds and the added resistance resulting from the full canvas enclosure, the rig was provided with 12 guys extending out to a set of 4 anchor posts frozen in the permafrost. To avoid the slow process of having to lay down the tubing on each of the several trips out when using tubing in lieu of drill pipe, a firmly mounted heavy timber platform approxi- mately 8 feet high was built on the rig floor to permit tubing racking within the derrick. Rig Foundation and Substructure The drawworks, derrick, 13-foot high substructure and the pipe skid assembly were previously coupled together as a massive single unit with a double runner sled combination. The sled portion was equipped with a heavy tongue on each end to permit skidding from one location to another by pulling and pushing with dozer tractors, The rig was - 7 - . . moved to the site of Gas Well No. 9 and guyed in position following completion of the Gas Well No. 8 operations in 1969. Typical of foundations in permafro st areas, the rig foundation con- sisted of a 4-foot thick beach gravel pad, approximately 35 by 55 feet, in which were emplaced 4 each 12- by 12-inch timbers 30 feet long set flush with the surface of the pad and frozen in place with a water spray for stabilization and prevention of settling due to vibration. The drill rig was centered over a 24-inch diameter conductor casing cemented 10 feet deep in an augered hole on the tundra prior to final placement and shaping of the gravel pad. The gravel pad was neces- sary to prevent thawing of the permafrost during the short Barrow summer season and the resultant differential settlement and possible damage to the rig. Mud Pumps One Gardner-Denver FO-FXO-E 7 1/4- by 10-inch mud pump powered by a Caterpillar D-13 000 engine was used for mud mixing and as an auxiliary circulating pump. Some old 5 I/4-inch liners which were in stock were tried with the pump in the hope of getting more pressure for mud mixing. However, the old liners wore out rapidly and were replaced with new 6 1/ 4-inch liner s which were found to be a more efficient size and type. One National (Ideal.) C-250, 6 1/4- by IS-inch mud pump powered by 4 (Quad) 6-71 GM diesel engines was used. This pump had been recovered from open beach storage, overhauled and rented from Colorado Oil & Gas Company for driHing operations on Gas Well No.8 in 1969. It was purchased outright for the Gas Well No. 9 operations and will be available for subsequ'ent drilling programs. This pump, even though old, is very good with the rig for shallow hole drilling. The cellar jet, field fabricated for the previous well, was again used in lieu of the 4-inch Marlow diaphram type electric cellar pump. The Marlow pump although repaired and put in operational order was put in storage in the tent warehouse at the Point Barrow Site Camp. Mud Pit One ISO-barrel capacity Medaris type steel tank, equipped with 3 each 2-vane type tankjets, a top mounted flow trough with selective mud flow gates, a.nd one external wrap of steam line with heat vanes surrounding the tank approximately 12 inches above the base, made up the mud reserve system. Accessory equipment included the usual jet-type mud mixing equipment and hopper. - 8 - . . As recommended last year, a sand trap was field fabricated and installed on this tank. The trap worked very well except for the locally fabricated door through the side of the tank which was difficult to open, and even more difficult to close and seal properly after cleaning the tank. Generally the door would freeze shut with a 4-inch plus layer of ice making it very difficult to open. Then after the trap had been cleaned it was time consuming to get the door closed and sealed properly. A shop··type door is required to eliminate this problem. The same type of trap door problem as has occurred in prior years was again experienced with the main tank drain/ deanout door. To eliminate leakage, a piece of plate was welded over the opening after the final cleanout. For future operations a patented tank door, or a 13 3/8 ··inch threaded collar with its top edge welded flush with the tank floor, and a screw-in piece of 13 3/ 8-inch pipe are required. Shale Shaker Two Medaris (Link Belt) standard-type shakers with ZO-mesh screens, each powered by a single 3 -HP electric motor were used. Both steam and water lines were available for periodic cleaning of frozen mud and cuttings from the shaker screens. Blowout Pr eventer s One Shaffer 45 Ram Gate, manually operated type, equipped with blind rams and various other size rams to handle all sizes of tubular goods was utilized with no problem. One Hydrill TypE: GK unit, equipped with a low temperature rubber seal; a self-contained, remotely located pressurizing unit; a remote control electric switch located on the rig floor; and a ground level manual control lever at the main control unit located in the C -Z50 pump house adjacent to the rig floor steps was again used. One floor preventer with a 9-inch crossover sub from 3 1/z- to 4 liZ-inch FH thread was kept at hand on the rig £1001' for stabbing into the 4 lIZ-inch FH drill pipe in the eve.nt the well started to unload during a trip. Light Plant Unit No.1: D-8800 Caterpillar engine, with a 50-KW, 3-phase, 60- cycle, ZZO/440-volt, 84/168-ampere generator. - 9 - . . Unit No.2: D-13000 Caterpillar engine with a 75-KW, 3-phase, 60- cycle, 1l0/220/440-volt, 841 l68-ampere generator. These generator units together with distribution panels and accessory equipment were located in a skid mounted wanigan. Prior to start of Gas Well No. 9 operations, the D-8~00 engine was checked over and found to be in good shape with only minor tune up work required. The D-13 000 engine was found to be in very poor shape requiring a major overhaul including replacement of the crankshaft. This remedial work was accomplished, and the engine performed very efficiently during the entire operation, Both generator units were again checked over prior to spudding and found to need cleaning and minor repair. In the course of operations, the primary D-13 000 unit generator armature failed and had to be machined true to prevent out-of-round damage and excessive wear. Prior to another drilling operation, the armature of the D-8800 unit should be similarly machined true in a lathe. This work can be performed with existing base camp equip- ment. Cement Pump The cement pump was a Government-owned Halliburton skid-mounted 2-pump unit installed in a heated wanigan. The unit consists of 1 vertical duplex, double action cement pump, 4- by 10-inch type, powered by a Model 4-71 GM diesel engine; and 1 horizontal right angle drive AC water pump, powered by a second GM Model 3-71 diesel engine. This unit is very old but operated dependably during the Gas Well No. 9 operations. Rig Water Supply A total of 8, 100 gallons on-site storage capacity in 5 tanks was main- tained as follows: Tank # 1 Tank #2 Tank # 3 Tank #4 Tank # 5 Boiler House Water Storage Wanigan Water Storage Wanigan Rig Floor Rig Floor 500 gallons 3,100 If 2,300 If 1,100 If 1,100 II Dr ill Pipe One hundred twenty-five joints of 4 1/2-inch API FH, 16. 6-lb. 1ft. , range 1 type, with 5 5/8-inch OD nominal (less wear) tool joints were used. - 10 - . . Support Equipment To facilitate movement of supplies and personnel from the Point Barrow Camp to the drill site and for handling on-site materials under all weather conditions, the following equipment was made available to the drilling operation from the Air Force inventory at Point Barrow. Equipment Assi~ned Full Time Three each Power Wagons, World War II, with original ambulance- type bodies fitted out with DC-3 aircraft tires. Two each Pick-up Trucks, 2-seater fitted with oversized truck tires. One each Carryall, Van-type with oversized tires. One each Water Truck, lZUO-gallon capacity. One each Fuel Tanker, 4400-gallon capacity, consisting of 4 each T6B steel pontoons and associated piping, mounted on a tractor- towed Michler -type freighting sled. One each Water Tanker, 2200..gallon capacity, consisting of 2 each T6B steel pontoons and associated piping, mounted on a tractor-towed wanigan mounted on a sled fabricated from steel pipe. Both tanks were fully enclosed in a diesel-heated structure. One each Trackmaster, personnel transport type. Four each Freight Sleds, Michler No. 9,..type (for handling tubing and other heavy hauling requirements). One each Bulldozer, International TD25B (D-8 equivalent). One each ForkLift, Tracked (D-4 equivalent capable of working in snow) . One each Fork Lift, small size, rubber tire-mounted for handling materials in the camp warehouse, and adjacent hard-packed snow area. Equipment Available Part-Time (as needed) Two each Bulldozer, International (D-8 equivalent). One each Crane, Traeke-d, International boom-type (cherry picker). - 13 - . One each Front-end Loader. One each Dump Truck. One each Trackmaster. . - 14 - GAS WELL NO. 9 DRILLING REPORT PART III OPERATIONS . . PROCUREMENT OF SUPPLIES Procurement of drilling and operational supplies, spare parts and arrange- ments for rental equipment and specialty services for Gas Well No. 9 operations was initiated by the Holmes & Narver Point Barrow office in January 1970 following basic planning for the well in December 1969. These supplies were in addition to those procured and sea-lifted to Barrow by the Navy in the summer of 1969 which consisted of 1, 000 sacks of Class G cement, 27 joints of 9 S/8-inch casing and 4 joints of S-inch OD perforated pipe. Excluding the U. S. Navy advance sea shipment an approximate total of $83, 000 worth of drilling items and supplies, plus $69,000 worth of specialty services were procured. Delivery dates were closely coordinated with the planned drilling schedule and the availability of military aircraft in order to effect maximum possible economy of operatlOn. L,:,r~l procurement of supplies in Anchorage and coordination of shipments to Point Barrow via military aircraft was very effectively handled by Mr. Don K. Gray, the Holmes & Narver liaison representa- tive in Anchorage. RIG UP Rig up and equipment overhaul was performed during the period January 14 to March 16, 1970, by non drilling craft labor to meet a target spud in date of Monday, March 16, 1970. However, the actual spud in date was changed to 0001 hours March 19 because an awkward commercial. flight schedule to Barrow would otherwise have necessitated payment of weekend premium pay to the drill crews and resulted in the inability to utilize one drill shift while in pay sta.tus. Even though by so doing, there was a calculated risk of missing the scheduled spud in date, the rig up crew was kept small and was built up gradually in order to control costs and enhance the selection and hiring of the best possible personnel. Initial work of constructing the access road to the well site was delayed for lack of sufficient snow to protect the tundra until the latter part of January. The work was then performed using a single operator. Three mechanics were phased in beginning in late January to perform major equipment overhaul on an as-needed and parts available basis. This timing permitted all overhaul work, where practicable, to be performed in heated structures and in camp where shop facilities were available. Following the overhaul work and the completion of the snow road to the well site these mechanics were able to follow through on schedule with the installation of equipment at the drill site. - 15 - . . As noted previously, the drill rig was skidded into position at Gas Well No. 9 site and positioned on a 4-foot thick beach gravel pad, placed on undis- turbed tundra following completion of Gas Well No. 8 in the spring of 1969. Unfortunately the early thaw that spring precluded the predigging of the cellar in 1969 and necessitated the excavation of the cellar and the place- ment of the timber cribbing this year before other work could proceed on Gas Well No.9. Since all of the enclosing substructure canvas pa.nels were frozen in and destroyed in moving the rig off the Gas Well No. 8 location, it was necessary to rebuild the panels for Gas Well No.9. To preclude a similar problem on future wells, a series of 2-foot wide, easily removable plywood panels were placed around the exterior of the substruc- ture between the gravel pad and the base of the canvas panels. This worked out well and at the close of the job all the canvas and some of the plywood panels were saved and are reuseablefor subsequent operations with only minor repairs required. To assist in overall rig up operations the power line, which normally is extended to each well house following completion of a well, was installed as part of the rig up. Although the power available from the gas field plant was limited, the availability of power at the Gas Well No. 9 site early in the operation was most helpful and is recommended for subse- quent operations whenever practicable. Furthermore, by installing the power line early, a trouble-free country telephone installation was made possible, This proved to be very useful as a jobsite safety measure during the many severe winter storms, and for ordering and coordinating personnel and supplies with the main camp. The overall layout of the drill site, including rig orientation, placement of equipment and positioning of structures was developed by the U. S. Navy Petroleum 4 representatives (see Figure 1 page 65). Basically, the arrangement was the same as the site configuration used for Gas Well No. 8. Although this arrangement is operationally compact and efficient, the fire hazard is increased by the close proximity of structures, and par- ticularly by the placement of the boiler adjacent to the rig. Mud, steam, water, fuel and cement flow lines were installed in approxi- matelya I-month period by 2 journeyman fitters, The daily accomplish- ments of these 2 men, even under the more severe weather conditions this year, was noticeably superior to that of the larger group assigned last year. Their work attitude and professional competence was of the best and greatly assisted in keeping the total job on schedule. In view of problems encountered last year, the 8-inch mud return line was replaced with ala 3/ 4-inch line. This larger line was installed in 3 sections with dresser sleeve connections, a cleanout plug at the first elbow away from the rig and a welded metal rather than a wood trough connection to the - 16 - . . mud tank trough. This arrangement worked very efficiently and only plugged once with cement due to oversight on the part of the drillers. Several other line changes were made which improved operations and avoided freeze-up. These included installation of a simple series of plug valves on the 2-inch mud feed line for selective mud transfer. This precluded the necessity of changing union connections and the use of chicksans to divert the flow of mud. It permitted direct operation of the cellar jet, the piping of mud to the Halliburton pump for cement displace- ment, the operation of the kill line, the bypassing of mud through the flow line and established the ready availability of a mud line on the rig floor for controlled reverse circulation following a drill stem test. In addition, check valves were installed in the various steam and water lines. Traps and lines for return condensate, water and mud were repositioned for rapid gravity drainage to minimize freeze-ups. A steam-heated, fully enclosed and insulated flow line was installed for drill stem test operations and for displacing the well for final completion. A I-inch fuel line was installed for periodic pumping of fuel from the tanker sled to day tanks for the rig engine, the mud pUITlpS, the boiler and the Halliburton pump unit. The electrical distribution system salvaged from the 1969 operation and carefully labeled for reuse, was again installed using the camp electri- cian on a part-time basis rather than hiring a full-time electrician for the rig. Due to the basic piecemeal design and general cold weather deterioration, the system was inefficient and required almost daily main- tenance to keep it in operation. For future drilling operations, the entire system should be redesigned by a competent electrical engineer familiar with drilling requirements and methods. Further reuse of the existing system would not only be inefficient and costly, but would be a distinct safety hazard to rig equipment and personnel. As part of the rig up, the canvas enclosure for the rig was repaired and patched by the 2 rig carpenters. All wanigan structures were repaired and put in first class condition prior to spudding. The interior of the mess hall wanigan was repainted. Storage shelves were built in the shop and oil field warehouse for more efficient use of available space and protection of fragile items. MANPOWER All drilling operations for Gas Well No. 9 were performed by Holmes & Narver, Inc., of Los Angeles, California, under the direction of their Project Manager for the Point Barrow Navy Research Site, Mr. Carroll C. Livingston, with Mr. E. L. Herbst as Drilling Superintendent and Geologist, and Mr. W. J. Jacoby as Tool Pusher. - 17 - . . On-site inspection and engineering services for the drilling program were performed by Mr. R. V. Murphy, Petroleum Engineer from the Office of Naval Petroleum and Oil Shale Reserves, Washington, D. C., and Mr. James Dalton, Consultant to the Naval Petroleum and Oil Shale Reserve 4, Fairbanks, Alaska. By interpretation of precedence established in prior drilling operations in the South Barrow Gas Field and current labor agreements in effect for the Point Barrow Research Site, the use of union labor for all craft assign- ments and drilling crews below the rank of Drilling Superintendent was again deemed mandatory for this operation. All wages and fringe benefits included in the amended 1970 Union and General Contractors Rate Book Agreement Guide were paid weekly to the union personnel through the Holmes & Narver Point Barrow office. All shift differentials, premium time, portal-to-portal pay and jobsite hot meal requirements were met. By union request the shift differential pay for all crafts working 3 shifts was divided equally between the shifts so that all men of each craft would receive equal pay for the hours worked regardles s of shift as signment. The 1969 union requirement to pay the derrickman the same scale as the driller, and other minor problem requirements were deleted by the union. Standard drilling crews consisting of a driller, a derrickman, and 3 floormen under the direct supervision of a union tool pusher were hired to man the rig on a 7-day week, 24-hour per day basis. In support of the Equal Employment Opportunity program, 1 Eskimo was included in each of the 3 shifts as a floorman at the roughneck pay rate. In addition to the normal three 5-man drilling crews, 3 bulldozer oper- ators, 3 heavy duty mechanics, 3 teamsters and 5 laborers divided into 3 shifts provided round-the- clock support service to the drilling opera- tion. Rigging up, installation of production line, construction of the well house and general maintenance/drilling support services were provided by 2 carpenters and 2 pipefitters full time and 2 pipefitters and 1 electrician part time. Other specialized and support craft labor was obtained on an as -needed call-out basis from the main camp labor force. Although the total labor force used for drilling Gas Well No. 9 was less than that of previous years, Holmes & Narver, in compliance with the intent of the Equal Employment Opportunity program, succeeded in increasing the proportion of Eskimos assigned to the work force. Out of the total work force of 36 people working full time on the drilling operation, 12 were local Barrow village Eskimos. Of the 12 initial Eskimo hires, the skills represented were 3 roughnecks, 4 laborers, 2 carpenters, 2 operators and 1 secretary. - 18 - . . Of these, 1 was the labor foreman and another the carpenter foreman. Both of these men were highly dependable, capable and did an excellent job. The turn-over rate, although high for such a short job, was some- what improved over last year. Although each hire was picked with care and it was made clear that for safety as well as production no drinking on the job or reporting for work under the influence of liquor would be tolerated, it was necessary to terminate 3 Eskimos for infractions. In addition, I Eskimo roughneck requested release because of aggravation of an old disability. Except for 1 bulldozer operator, it was possible to replace all terminated men with other indigenous personnel. Although the problem of absenteeism continued to be experienced with local per- sonnel, it was somewhat less than in 1969. However, it was made clear in statements to management by several Eskimo employees that they did not want to continue with steady work and that, had the job continued another few weeks, they would have quit. For planning a long term or remote drilling job, this problem should not be underestimated. No absenteeism or drinking problems were experienced with the union drilling personnel brought in from Anchorage. The working harmony and overall attitude of the men toward getting the job done was decidedly improved over last year. The designation by the union of a capable union steward, Mr. Frank Parchmen, added much to the success of the operation. His honesty and i.nsistence on fair play both ways commanded the respect of both labor and management, and permitted all problems to be immediately and amicably resolved at jobsite. One major problem common to other Arctic drilling operations was again encountered. Unlike drilling in other parts of the world, the ordinary driller on an Arctic job is incapable of running the larger crew required and handling all the routine problems arising on his shift. This made it necessary for both the superintendent and the tool pusher to be on hand almost around the clock to keep the rig running and to plan ahead with the multitude of alternatives necessary for effective production. With the resultant total fatigue, communications can break down and the job can suffer. The obvious remedy is to assign 2 tool pushers to the job and have each work only l2-hour shifts. SERVICE COMPANY SUPPORT In addition to the regular jobsite crews, the specialized services and equipment common to oil industry practices were utilized. Although - 19 - . . it had been planned that these services would be provided on a call-out basis, in each case it became necessary to hold the personnel and equip- ment at jobsite with a resultant increase in third party cost above that estimated. This problem was further aggravated by the inordinate increases in standby rates for men and tools now charged by the service companies. Two examples are: Schlumberger $25 per hour standby for their dipmeter tool alone, and United Geophysical $500 per day for equipment. The necessity for having the service companies stand by was: 1. The unpredictably fast advancement of the drilling operations, 2. To avoid loss of rig Ume at the rate of approximately $5, 000 per day while awaiting arrival of service company support, 3. To cuu.nhu.a.~~ nr'P\ratiop s with the schedules of aircraft flights transporting men and special equipment, 4. To insure against slow down in drilling operations because of aircraft flight delays on account of weather, and 5. To maintain overall continuity of operations without endanger- ing the hole. -º ementing The Halliburton Oil Well Cementing Company (HOWCO), with offices in Anchorage, provided a cementing service operator for the Govern- ment-owned cement pump for each of the 3 casing cementing jobs. Of the 2 operators involved (only 1 was on- site at a time), the second man was also trained to run drill stem tests. This precluded the additional cost of having another service man on standby at jobsite for cementing the 7 -inch production string. Drill Stem Testing The Halliburton Company, Anchorage, also provided drill stem test equipment and an operator for running the 2 open-hole tests made on the welL As stated above, this technician also provided cement- ing servides for the 7 -inch casing string. - 20 - . . Mud Engineering Services The Baroid Company, Anchorage, provided 1 engineer for con- tinuous on-site mud engineering services for the period March 18 to April 11, 1970. Mud Logging Services_ The Baroid Company, Anchorage, also provided a portable mud logging unit with continuous mud gas detector, automatic gas chromatograph and related equipment and 2 operators for the mud logging operation through the interval 1, 117 to 2,450 feet TD during the period March 25 to April 13. Well Logging Services A Schlumberger wire line services crew of 3 men, with a self- contained skid-mounted logging unit, 11 sets of instruments including the very expensive, high resolution dipmeter tool, and perforating equipment for both casing cement squeeze work and perforating for production, were retained on location during the period March 25 to April 14. The initial arrangements and approximate cost for these services were resolved between the Schlumberger Company Manager, Anchorage, and a Holmes & Narver representa~ive in early March 1970. Unfortunately, the Schlumberger representative passed away at his desk 2 days later with no record of the agreement having been made. At the conclusion of the drilling operations a $20, 000 difference in the total billing, based on published Schlumberger price schedules, was submitted for payment. In a subsequent meeting between the Holmes & Narver representative and Schlumberger management in Anchorage the Company com- mendably revised their invoices to the originally negotiated rate schedule on the basis of the Holmes & Narver notes of the first meeting. Special Wire Line Services As part of the Gas Well No. 9 operations, the Sperry-Sun Well Surveying Company of Anchorage performed a high resolution temperature survey on Gas Well No. 7 after that well had been off production for a prolonged period. This survey was made to establish the general up-hole temperature gradient, depth of - 21 - . . permafrost and the producing reservoir static temperature for the South Barrow Gas Field. This survey was run twice during the period April 9 to 13 and through the interval 1,100 to 2,300 feet. The C. A. White Wire Line Well Service Company, Soldatna, Alaska, provided a wire line pulling unit and lubricator from the Prudhoe Bay area operations along with an operator from the Kenai area to assist in performing the above Sperry-Sun tempera- ture survey on Gas Well No.7. Velocity Survey United Geophysical Company, Anchorage, performed a down-hole velocity survey in Gas Well No. 9 using the Schlumberger Wire Line for geophone positioning. The 5 shot holes predrilled by Holmes & Narver were loaded and detonated by United Geophysical. Record data reduction was performed by United Geophysical for transmittal to the Petroleum Reserve Office in Washington, D. C. Coring Christensen Diamond Products Company of Anchorage provided all necessary coring equipment and the coring operator. The equipment consisted of a new 5 3/ 4-inch by 3 a-foot vented core barrel with chrome lined inner tube obtained on a rental/purchase basis, the purchase of I each 7 5/8- by 3 1/2-inch drag core head with dianlOnd inserts and conventional 7 5/8- by 3 1!2:...inch diamond core head. The coring engineer was provided on a stan- dard daily service charge rate for the period of March 27 thru April 8. Core Analysis American Stratigraphic Company of Anchorage handled all core analysis work. Core samples were air freighted to Anchorage. The analysis results were telephoned to Barrow pending later written confirmation by mail. Recording Unit A complete, overseas-type packaged, recording unit was obtained from the Geolograph Oil Field Service Company of Oklahoma City on a daily rental basis. This recording unit was installed and maintained by the tool pusher without incurring the added cost of a service man. - 22 - . . Tool Rentals Arrangements were made with Denali Services, Fairbanks and Anchorage, to handle tool rental services, special machining services, and the provision of fishing expertise and equipment should any of these become necessary. During the course of the operation only 2 pup points of drill pipe and 1 set of elevators were obtained on a rental/purchase basis. These items were subsequently purchased. - 23 - . . COMPOSITE WELL SUMMARY Gener al Data Well name - South Barrow Gas Well No. 9 General location - Naval Petroleum and Oil Shale Reserve No.4, South Barrow Gas Field, approximately 5 miles southeast of the Eskimo village of Barrow, Alaska, and approximately 5 miles south of the Arctic Sea Specific location - 588 feet north, 2,258 feet west of the southeast corner of Section 11, T22N, R18W, UPM Operator - Office of Naval Petroleum and Oil Shale Reserves, Washington, D. C. Drilling Contractor - Holmes & Narver Inc., Point Barrow, Alaska, and Los Angeles, California, under contract to the U. S. Air Force (contract number F65517-69-C-000l) Rig type - Cardwell Model H, double drum, single engine rotary, with American Standard fully canvas enclosed 80-foot guyed derrick, unitized on a nominal 13 -foot high sub- structure mounted on a shop made steel pipe sled with steel- shoed runners 18 feet apart (outside measurement) Datum - All down hole measurements referenced to top of .kelly bushing (kelly bushing measurement-KBM) Total depth - 2, 450 feet (driller IS measur ement) Hole deviation - 1/2 degree at 182 feet 1 3/4 degrees at 1, 117 feet 2 degrees at 1, 985 feet 2 degree s at 2, 360 feet 1 1/2 degrees at 2,449 feet Core data - Cut 8 cores, 201 feet, recovered 172 1/2 feet. .. 24 - . . Upper Gas Zone Core 1 - 1,987 to 2,016 feet, recovered 0 feet (partial recovery in Core 2) 2 feet siltstone - no show Core 2 - 2,016 to 2,020 feet, recovered 6 feet (included part of Core 1) 4 feet siltstone -. no show Core 3 - 2, 030 to 2, 059 feet, recovered 21 1/2 feet (plus '7 1/2 feet on next run) 27 feet shale and 2 feet sandstone stringer ~lth good gas sho.w and trace of oil C,J.ic ~ Z, 05') to 2,081 1/2 feet, recovered 29 feet (also part of previou.s core) 27 feet shale and 2 feet sandstone stringer ~ith good gas ahoV\:': Core 5 - 2,080 1/2 to 2, 109 feet, recovered 28 feet 25 1/2 feet shale and 2 1/2 feet sandstone with gas show Main Pay Zone Core 6 - 2,361 1/2 to 2,389 1/2 feet, recovered 28 feet 18 feet alternating shale and shale conglomerate 10 feet Barrow Pay Sand, good_gas show, low porosity Core 7 - 2,389 1/2 to 2,419 1/2 feet, recovered 30 feet 30 feet sandstone, good gas show, fair visible porosity, good gas ~how througho\!t (well-preserved piece of wood found at depth of 2,409 3/4 feet) Core 8 .- 2,419 1/2 to 2,450 1/2 feet, recovered 30 feet 30 feet sandstone, good visible Eorosity and gas show Hydro(;~rbon Sh0':Y~ Cores - 2, 049 to 2,051 1/2 feet - 2 II2 feet gas (few drops of free oil) 2,078 to 2,080 1/2 feet - 2 feet gas 2,105 to 2,107 feet - 2 feet gas 2,366 to 2,367 feet ~ 1 foot gas (strong oil odor) 2,376 to 2,377 feet - 1 foot gas 2,379 1/2 to 2,4.50 feet (total depth-TD) - 70 1/2 feet gas .- 25 '" . . Others ~ 2,155 to 2,158 feet 2,199 to 2,200 feet 2,300 to 2,302 feet 2,336 to 2, 339 feet Drill Stem Tests (DST) Upper Gas Zone ~ DST No.1, interval 1,995 to 2,130 feet, 130 foot water cushion. No test, packer seat failed. DST No. lA, interval 2,037 to 2,130 feet. 130 foot water cushion. Odorless methane gas to surface in 25 minutes. Estimated production rate 1/4 MMcf/d. Tool open 3 hours, 40 minutes. Maximum final flow pressure 1238 psi. No closed-in pressure due to packer seat failure. Main Pay - DST No.2, interval 2,338 to 2,450 feet, 130 foot water cushion. Methane gas to surface in 2 minutes. Estimated production rate 2 MMcf/d. Tool open 63 minutes. Maxi- mum final flow pressure 586 psi. Maximum closed-in pres sure 1026 psi. Productive Formation - South Barrow Gas Sand (Jurassic age). By core data a massive bedded, fine-grained, firm to soft, friable in part, fairly clean, non-calcareous, non-fractured sand, under- lying several shale conglomerate stringers. Sand formation not fully penetrated. Productive Zone - 2,379 1/2 to 2,450 feet (TD) Projected depth of water contact 2,495 feet +. Completion Method - Semi-open hole. Seven-inch casing cemented to top of pay zone with preperforated liner extending through the pay. Productive Capability - 7.8 MMcf/d at measured reservoir pressure of 993 psi. Drill Hole Sizes - 26 inches (nominal), from surface to 29.2 feet KBM 18 5/8 inches from 29.2 feet to 174 feet (drilled 9 5/8-inch hole, opened with 12 l/4-inch bit on 18 5/8-inch hole opener). - 26 - . . 12 1/4 inches from 174 feet to 1,117 feet. 8, 5 I 8 inches from 1, 117 feet to 2,450 feet (TD). Casing Sizes (Overall Measure) Conductor - 1 partial joint, 24-inch OD (nominal) to 29.2 feet KBM Surface - 4 joints, 13 3/8-inch T & C, 8rd, R-3, N-80, 54.5 lb. 1ft. to 163 feet Intermediate - 27 joints - 9 5/8-inch T & C, 8rd, R-3, N-80, 40 lb. 1ft. to 1, 100 feet Production - 78 joints (including 3 pup joints), 7-inch T & C, 8rd, R-3, N-80, 38 lb. 1ft. to 2,384 feet Liner - 2 joints, 5-inch OD, 77.62 feet, 181b. 1ft., J-55, R-3, extreme line thread, preperforated; pipe set 1 foot off bottom at 2,449 feet. Top of liner hung at depth of 2,371. 38- feet or 12.58 feet above base of 7-inch casing. Tubing - 73 joints, 2,232 feet - 2 7/8-inch Hydril CS 6.5 lb. 1ft., and 7 joints, 210 feet, 2 3/8-inch Hydril CS 5.31b. 1ft. landed in orange peeled 7 -inch casing 1 foot above bottom of casing and 7.88 feet above bottom of hole. Casing Accessories 24-inch conductor (29.2 feet) - No accessories. 13 3/8-dnch surface (163 feet) - Baker duplex cement wash-down whirler, left-hand stab in float shoe (Product Number 250-02). Two centralizers placed 41 and 122 feet respectively above top of shoe. 9 5/8-inch intermediate (1,100 feet) - Baker cement wash-down whirler float shoe (Product Number 100-20). One each Baker cement float collar (Product Number 101-81) 41. 17 feet above top of float shoe;", Two each HOWCO centralizers 82. 52 feet and 205.42 feet above shoe. - 27 - · . 7 -inch production (2, 384 feet) - HOWCO formation packer shoe. Baffle plate at second joint 53 feet above shoe. Four each centralizers, 25.48, 114.72, 643.67 and 1,250.52 feet above top of packer shoe. One each HOWCO DV collar 1, ISO. 41 feet above top of shoe (1, 201. 84 feet setting depth). 5-inch liner (77.62 feet, interval 2,371. 3S to 2,449 feet) - Burns Hanger with lead seal packo££, set at 2,371. 3S-feel:. Bottom:--ð-f-...: liner orange peeled and welded shut at jobsite with 3 -inch spade base welded into the peel. 2 7 Is and 2 3/8-inch tubing string - No accessories. Landed with pack-off assembly inside unit- ized well head. Well Head - lO-inch(nominal), 2000 psi working pressure Shaffer unitized forged steel casing and tubing head; series 600, R-53, drilled API, flange up; 4 each 2-inch line pipe side outlets; 9 5/8 inch slip over to weld base, with landing guides for centering in 13 3 IS-inch 54.5 -lb. cas- ing (Part No. 363738). 10-inch (nominal) by 7 -inch fluted casing landing mandrel with low temperature packing unit for 7 -inch, 8rd, T & C casing, thread down, 4 threads per inch, left-hand stab-in acme, thread up (Part No. 363786). 10-inch (nominal) by 2 7 IS-inch Hydril CS tubing hanger (59AJ Shaffer type) with low temperature pack off. 10-inch 2000 psi working pressure series 600, R-53, top flange, with 3 -inch line pipe, male, neck up. Control Valve - Kerotest gate valve, Type rrJII, screwed ends with lubricated integral seats. Ends threaded for 3- inch, 8 threads per inch, API line pipe, 2000 psi working pressure and 4000 psi test rated. - 28 - . . Casing Cementing Operations 24-inch conductor - set approximately 10 feet below cellar floor in augered hole and cemented back to cellar floor level. 13 3/8-inch surface - cemented to surface with 206 sacks Fondu cement. WOC to total o£'"36 hours and drilled out. 9 5 IS-inch intermediate - cemented to surface with 429 sacks Fondu cement, WOC to total of 44 1/2 hours. Found top of cement would take weight of string but would jet away, getting softer with depth. Tem- perature of first mud returned from I, 100-foot depth, 40oF. WOC to total of 60 hours. Cement set improved but not satisfactory per cuttings returned. WOC to total of 75 hours - Ran CBL No.1, log results indefinite. Put heat on mud tank and began circulat- ing up to 66°F mud. WOC to total of 105 hours - ran CBL No.2. Log results same as CBL No. 1. Cement, however, would not jet away at 750 psi pressure, and cuttings showed a medium hard set in the casing. Drilled out shoe and pressure tested cement at 550 psi for 5 minutes with no bleed-off. Drilled out approximately 7 feet of hard cement fill below shoe, further indicating a good cement job. - 29 - . . 7 -inch production - cemented to surface in 2 stages with 480 sacks of cement. Stage 1 - pumped 280 sacks Class G cement preceded by lO barrels of water treated with 100 pounds of caustic soda through the casing shoe. Displaced last 10 barrels of cement over a 4-hour period using the Murphy Squeeze Technique. Stage 2 - pumped 200 sacks of Fondu cement thru DV collars. Displaced cement by con- ventional method with good excess returns to surface. WOC 48 hours, tagged very hard cement and drilled out 65 feet of hard cement to shoe. Ran CBL No. 3 - log showed excellent text- book bond below DV collar and an, ordinary indefinite bond above the DV collar. 5 -inch liner - no cement required. 2 7/8-inch tubing - no cement required. - 30 - . . Logs Run Service Run Interval Date Com.pany Type of Log No. Logged Casing/Hole Size 3/28/70 Schlumberger Cement Bond 1 100-1088' 9 5/ 8"-casing 3/29/70 Schl umber ger Cement Bond 2 160-10881 9 5/8"-casing 4/30/70 Schlumberger Induction 1 1101-2105' t8 5/811-hole to 1987' 7 5/8"-hole to 2109' 4/7/70 Schlumberger Induction 2 1102-2448' 8 5/8"- hole 4/7/70 Schlumberger Sonic w/Caliper 1 11 02 - 2449' 8 5/8"- hole 4/7/70 Schlumberger Density w/Caliper 1 1102-2448' 85/8'I-hole 4/8/70 Schlumberger Neutron Para sity 1 1102-24481 8 5/8"- hole w /Caliper 4/8/70 Schlumberger Proximity Log - 1 1102-24461 8 5/8"-hole Micro Log w/ Caliper 4/8/70 Schlumberger High Resolution 1 1103-2447' 85/8"-hole Continuous Dipmeter II Computed 1 " II II Digital 1 II II 4/13/70 Schlumberger Cement Bond 3 100-2437' 7" -casing 4/17/70 Schlumberger Saraband 1100-2448' 8 5/8"- hole 4/11/70 Sperry-Sun {TetnP~rature Log 1 50··2300' 2 3/8"- tubing in 4/12/70 Sperry-Sun Gas Well No. 7 2 50-1400' 2 3/8"- tubing 4/8/70 United Seismic Velocity 1 1150-24301 8 5 / 8"- hole Geophysical 3/29/70 Baroid Mud Log 1 1117-2450' 8 5/8"- hole to 4/9/70 - 31 - . . MUD PROGRAM Similar to previous field wells, a Gel/Q-Broxin low-water-loss mud was used for drilling Gas Well No.9. Prior to drilling into the main pay sand for theoretical prevention of water blocking, up to 7% diesel fuel by volume was added to the system. This type of mud program was again found to be ideally suited to the South Barrow Field and the com- plexity of operations necessarily undertaken on a shallow gas well con~ structed under Arctic conditions. Aquagel and Baroid stock materials were procured from the Colorado Oil & Gas Company stocks stored on the beach near the camp site following closeout of the U. S. Navy drilling operations in 1953. Some problem was experienced in digging this material out of the snowbanks and thawing it to a rig useable condition. Other mud materials were purchased from the Baroid Company, Anchorage. The volume of mud materials used on Gas Well No. 9 was significantly different from that used for Gas Well No. 8 as can be seen by the following comparison. Gas Well No. 9 Gas Well No. 8 Aquagel (lOa-lb. sacks) 116 82 Baroid (lOa-lb. sacks) 551 252 Q-Broxin (50-lb. sacks) 86 102 Cellex (50-lb. sacks) 21 17 C Q (50-lb. sacks) 0 2 Caustic soda (50-lb. sac ks ) 5 3 Bi carb of soda (lOa-lb. sacks) 3 18 The increased volume of materials used on Gas Well No.9, particularly Aquagel & Baroid, resulted in part from the drill stem test operations, coring and the additiãnal hole made. Some loss resulted from mud tank door leakage and from the inexperience of some of the drilling hands who failed to follow the explicit instructions provided by the mud engineer and the tool pusher regarding proper mud transfer procedures, the use of Cellex and Q-Broxin, and the fundamentals of mixing, handling and con- ditioning mud. - 32 ~ . . For the upper portion of the hole, down to 1,100 feet, a nominal 10.6- lb. /gal., 45 viscosity, 5CC or less water loss, low-sand mud was desired. The natural clays of the formation, however, tended to increase the weight to about lllb. / gal. with significant increase in viscosity and sand content. Although this condition could have been easily treated by running a good stream of water into the system, some crew members attempted to alleviate the condition by adding more Q-Broxin and CeUex until instructed otherwise. Due to the low factor of safety in drill stem testing a multiple stringer gas zone in a shallow hole with only 1. rnud tank available for reserve, the mud weight was increased to 11 pounds per gallon for test purposes. While conditioning the mud to this weight, it was found that the gas zone would initially gas-cut mud weighing up to 10.8 pounds per gallon. At one point, trip gas recognizably cut II-pound mud. However, on a succeeding trip 11. I-pound mud was not affected and the mud weight was progressively reduced. The lower portion of the hole responded well to 10.7 pounds per gallon, 45-50 viscosity mud, however, follow- ing the open hole drill stem test of the pay sand and reversing out the drill stem good 10. 9-pound mud was cut to where it began unloading and put up to 200 psi on the BOPs. As with previous wells, this mud program was satisfactory for all operations through both the permafrost and pay zones, for formation evaluation, for logging and for running casing. . - 33 - . . GEOLOGY Field Setting The South Barrow Gas Field, including Well No.9, is a shallow, 5-well producing, gas field covering an assumed productive area of about 1,000 acres, with at least 1 more location to drill. Two other gas wells were drilled on the structure, 1 of which burned subsequent to completion, and another that apparently was lost through permafrost action which, in time, resulted in collapse of the casing. Both wells are now reportedly plugged. . The gas entrapment type of closure of the productive formation referred to as the South Barrow Gas Sand of Jurassic age is not fully known. The general opinion stated by some engineers famil- iar with the region tends toward the trap having stratigraphic closure with the gently dipping sand reservoir formation of Jurassic age abuting unconformably against the overlying creta- ceous clays. The zone of interface, marked by a conglomerate gravel bed, is assumed to be evidence of an unconformable con- tact. Some engineers familiar with the area believe closure is provided by faulting and/or pronounced facies change within the South Barrow Gas Sand itself. Others have expressed thoughts that the gas entrapment closure results from the thick permafrost zone overlying a large, gently dipping, metamorphic basement complex. Since detailed geological studies are not available to the wellsite geologist, the above opinions are mentioned solely to illustrate the trend of thoughts expressed. Stratigraphy Stratigraphically, Gas Well No. 9 is more nearly similar to Gas Well No.6, although correlation with other field wells is good down to picking the actual top of the Barrow Pay Sand. A consistent log pick of the top of pay sand compatible with core data from Gas Well No. 9 is somewhat arbitrary and subject to individual judgement. Primary stratigraphy differences occur within the several gas sand stringers in the interval 2,050 to 2,380 feet. These thin sand beds are lenticular in nature with noticeable thickening, thinning and changes in facies between wells. The general relationship and thick- ness of the sands across the field are represented by the following correlations: - 34 - . . Gas Well No. 9 Gas Well No. 6 Gas Well No. 8 Gas Well No. 7 Depth Thicknes s Depth Thickness Depth Thickness Depth Thickness Ist Sand 2048' 2' 1965' 2' 1958' I' 1930' 1 ' 2nd Sand 2078' 2' 1990' 0' 19861 2' 1960' 5' 3rd Sand 2104' 2' 2015' 3' 2012' 5' 1990' 10' 4th Sand 2155' 3' 2078' 1 ' 2062' 1 1/2' 2035' 4' Other thin sand stringers in the interva¡ follow the same pattern. From Gas Well No. 9 core data and from mud logs of other wells. it appears that each sand stringer is gas charged to some degree. Structure By good correlation characters, Gas Well No.9. at the top of the first Upper Sand, is structurally: 83 feet low to Gas Well No. 6 90 feet low to Gas Well No. 8 118 feet low to Gas Well No. 7 This structural difference increases with depth. At the last good corre¡ation point immediately above the indefinite log character top of the Barrow Pay Sand, the structural difference of Gas Well No. 9 is as follows: 45 feet low to Gas Well No. 4 100 feet low to Gas Well No, 6 112 feet low to Gas Well No. 8 140 feet low to Gas Well No. 7 Lithology Gener a1 Lithologically Gas Well No.9, based on non-recorded cutting observations made while drilling down to 1, 117 feet, and cuttings logged bom there to total depth, is generally similar to the other field wells. (For a detailed sample description of the field refer to the Drilling Report for Gas Well No. 8 and the mud logs. ) - 35 - . . Permafrost The depth of the field permafrost zone was measured for the first time as part of the Gas Well No. 9 operations and found to extend to a depth of 1,250 feet. The depth of the permafrost zone was determined by a Sperry-Sun wire line, high resolution temperature survey. This survey, although actually made on Gas Well No.7, was included for cost purposes as part of the Gas Well No. 9 operations. Prior to logging, Gas Well No. 7 had been off production for several months and had had an opportunity for the down hole temperatures to stabilize. The permafrost depth of 1,250 feet is based on the conventional defi- nition that the permafrost zone is that zone of the earth's crust wherein the temperature remains continuously lower than 320F throughout the years. This definition is used rather than specifying a zone wherein moisture changes from liquid to solid by freezing, as such a change of state will depend in part on salinity, density and pressure and not on tempe..l~tl1"e alone. Regarding the different definitions of permafrost, it was again noted in Gas Well No.9, as it had been observed in Gas Well No.8, a change in drilling character took place at a depth of 750 feet without any recognizable change in lithology of the cuttings recovered. This observation may relate to the speculation that this zone represents a change in the permafrost character with a matrix moisture change of state from solid to liquid, still at temperatures lower than 32oF. Up-Hole Section Based on observation of drill cuttings, the section down to a depth of 1,200 feet is dark gray to black, very soft (at least when wet), sticky clay (gumbo), with traces of fine-grained sand and silt-size particles, and rare traces of gray nondescript, very small carbonate fragments. As shown by the Schlumberger logs, and in part by the Baroid mud log, 2 nominal 60-foot sand zones at 1,300 and 1, 750 feet were pene- trated. Both sands appeared to be porous and wet, and capable of causing water production problems if not properly cemented of£. Little sand was actually found in the cuttings from either of the sand intervals. The sticky shale seemed to mask everything and preclude an accurate interpretation of the cuttings. - 36 - . . Coring in the interval 1,987 to 2,109 feet clearly indicated that the up-hole formation of both shales and sands is much more competent than the field rock bit cuttings had indicated. Although a Christensen diamond insert drag bit was used for 2 cores, the formation was found to be too hard for a drag bit. However, a conventional diamond bit easily cut the materia], at about a 12-minute-per-foot rate with no problems in recovery or operations. Although the recovered cores were competent, small fragments put in water on a test basis rapidly became soft, slick and gummy similar to the rotary bit cuttings. Cores tak~n of the IIUp-Hole Gas Zone, II which tried to blowout in Gas Well No.8, showed this zone in Gas Well No. 9 to consist of 3 nominal 2-foot thick sand stringers each separated by 20 to 25 feet of dense shale. These sands were permeable and porous and each had a good show of gas. One of the stringers (interval 2, 049 1/2 to 2,051 1/2 feet) bled out a few drops of live dark brown oil when first taken from the core barrel. By mud log, a deeper fourth sand stringer in the interval 2, 155 to 2, 158 feet also had a good show. In fact, each thin detrital stringer above the main pay, and in the interval 2,050 to 2,380 feet, a.ppeared by mud log to be gas-charged. On the first attempt to run a drill stem test, the packer seat failed and th~ test was rerun. The drill stem test (DST No.1) of the 3 core stringers in the test interval 2,040 to 2, 130 feet indicated an absolute open-hole flow rat~ of about 1/4 MMcf/d at an apparent virgin reservoir pressure of over 1000 psi. Unfortunately the packer seat again gave way before a closed-in pressure reading was obtained. Although these upper sands are of marginal economic potential at present, core data and tests of the interval proved the following: 1. The up-hole clay/shale formations are made up of competent rock, contrary to previous drilling sample character. 2. The several high-pressure thin gas stringers are very capable of causing a serious blowout if proper drilling practices and control systems are not utilized. 3. The high permeability and porosity of the cores cut in these stringers, together with their known lateral development and thicknes s improvement in parts of the field, indicate that selective well completion could add to the reserves and the total productive life of the field. - 37 - . . Conglomerate Zone (top 2, 362 1/2 feet KBM) Full recovery coring of the conglomerate zone which overlies the mC!.in pa.y sand showed that this zone is not the hard, well indurated competent formation Ü was previously assumed to be from observa- tion of drill cuttings. The 17 -foot zone was found to consist of 3 shale conglomerate beds, each 2 to 3 feet thick, with the 10wer 2 beds each covered by ¡ foot of sand with some oil/gas show. The lower bed rests on the main pay sand with a sharp contact and is separated from the next zone by the 1 foot of sand cover previously mentioned, plus a 7 1/2-foot thick shale bed. The middle and upper conglomerate beds are separated by only 1 foot of sand. The top conglomerate bed is overlain, with sharp contact, by firm bla.ck shale typical of the up- hole formation. The sbale conglomerate is comprised of black, crumbly in part, gritty shale with an estimated 20% by volume content of black, well- rounded and polished fragment:;¡ and pebbles of beach gravel type quartzite, predominantly in the range of I to 2 inches in diameter with some pieces up to 3 inches. The conglomerate quartz pieces are generally imbedded in the shale and many of them do not touch each other. Although the shale is only firm to medium hard in texture, it tightly retained the hard quartzite fragments during coring. The core was cut and remained in gauge through each of the zones (all 0.£ which were penetrated in the same core) with no barrel jam- ming, crumbling, or wash out of the core. The conventional diamond bit cut through the wall pebbles with a sbarp edge and with very little if any evidence of mechanical loosening of the pebbles from the shale matrix by either the bit or the barrel. The core of the conglomerate clearly showed the following for at least the Gas Well No. 9 area of the field: 1. The conglomerate is a shale conglomerate and not a brittle, highly cemented, hard cap rock as had been inferred by cuttings in previous wells. 2. The conglomerate proper has no reservoir potential. 3. This conglomerate has insufficient strength to make it a dependable formation for setting an open-hole formation test packer, or for setting a formation packer shoe for cementing casing. - 38 - . . 4. Due to the transitional nature of the zone the electric logs through this zone do not fully denote the existing sharp contact between the pay sand proper and the con- glomerate. If this holds true throughout the field some downward revision of the pay formation top may be in oJ;'der for accurate gas reserve calculations. Barrow Pay Sand (top 2,379 1/2 feet KBM) The Barrow Pay Sand by core lithology was topped at a depth of 2, 379 1/2 feet (KBM). Coring was begun 1 foot above the top of the overlying conglomerate zone and continued to total depth in the pay sand with 100% recovery. Although still in good pay sand at total depth, and with improvement of permeability with depth, the well was bottomed approximately 45 feet above the water contact as projected from the water contact reached in Gas Well No.4. A total of 70 feet of section was opened up for production, of which the upper 4 1/2 feet of low permeability sand was subsequently cased and cemented of£. The pay sand is a gray-brown, very fine-grained non-calcareous sand, firm to friable with occasional hard streaks. The sand had a good gas show throughout, a good gas odor, an even light ,brown stain, an even yellow fluorescence and a yellow-white cut. Unlike the section indicated by cuttings in other wells, the sand in Gas Well No. 9 was almost non-argillaceous. By core analysis of samples taken from each foot of core, the best production will be from the lower 30 feet of the hole. This zone has a porosity of 20%+ and consistent perme- ability in the range of 50+ millidarcy per foot. The upper 40-foot zone also has good pJ;'oductive capability but is somewhat harder and tighter. Water saturations of the significantly permE:able zones is primadly in the 53 to 57% range. Residual oil saturations were generally less than 5%. A drill stem test of the full pay zone showed the following: - 39 - . . DST No.2 (interval 2,338 to 2,450 feet, 130 foot water cushion) Gas to surface - 2 minutes Estimated production rate - 6 MMcf/d (AOF) - 63 minutes Tool open Tool closed in Tool reopened Pressure recordings IF 844 psi FF 581 psi CI 1023 psi - 40 - - 89 minutes (due to flow line freeze-up problems) - 39 minutes lliH 1398 psi FHH 1366 psi . . CHRONOLOGICAL DRILLING SUMMARY March 17 - Crew 2. A 4-man union drill crew from Anchorage arrived Barrow; checked in; spent rest of travel day (2 hours) at rig; started motors; picked up blocks; etc. March 18 Crew 2. At rig for final rig up. One local Eskimo £1oorman joined crew. Crews 1 and 3. Each a 4-man union drill crew from Anchorage arrived Barrow; checked in; spent rest of travel day (2 hours) at rig. Crew 3. Reported to rig at 1600 hours to drill rat hole; mixed mud; picked up equipment to spud. One local Eskimo hire joined crew. I March 19 - Crew 1. Reported to well at 0001 hours. One local Eskimo joined crew. Spudded well at 0145 hours, 3/19/70. Drilled 9 5/8-inch hole to 182 feet. Opened hole to 18 5/8 inches to 116 feet. March 20 - Opened hole to 18 5/8 inches to 174 feet by 0800 hours. Ran 163 feet of 13 3 18-inch casing. Cemented to surface with 206 sacks Fondu cement. Ma.rch 21 - woe; extended stand pipe 5 1/2 feet; cleaned out sand trap; searched tundra for Eskimo who wandered away from the rig. March 22 ... Drilled 12 1 14-inch hole to 470 feet. March 23 - Drilled 12 1/4-inch hole to 947 feet. March 24 - Drilled 12 1/4-inch hole to 1,117 feet by 0930 hours. Set 1,100 feet, 9 5/8-inch casing. Cemented casing to surface with 429 sacks Fondu cement. Welding shack, along with trailer-mounted welding machine caught fire and burned; total loss. March 25 - woe; installed unitized head; emptied and cleaned solids out of mud tank. - 41 - . . April 7 - Cut Core No. 8 to 2, 450-feet TD; full recovery; reamed core hole; ran Schlumberger rES, Sonic and Density Logs. April 8... Ran Schlumberger Neutron Porosity, Proximity Microlog, continuous Dipmeter Log and United Geoph.ysical Seismic Velocity Survey; conditioned hole. April 9 - Ran DST No. 2 (2,338- to 2, 450-feet TD); gas to surface in 2 minutes; estimated flow capability 2+ MMcf/d. April 10 - Conditioned hole; laid down drill pipe; ran 7 -inch casing into top of pay sand; set cement packer shoe at 2,384 feet; pumped (1st stage) 289 sacks Type G cement through shoe and ~;.;;¡:l::~Qrt ¡:;lowly over 4-hour period. April 11.- Pumped (2nd stage) 200 sacks Fondu cement through DV collar to surface; wac at 0400 11our!f,l. April 12 - wac; landed casing in unitized head; put new 6 1/2-inch liners in Gardner-Denver pump; picked up tubing, casing scraper and bit to drill out 7-inch casing. April 13 - Tested casing; drilled out 65 feet of hard cement from 7 -inch casing and cleaned out 8 5 18-inch hole to bottom with 5 3 14-inch bit; began Schlumberger CBL Log run; (total wac time 67 hours). April 14 - Finished CBL Log Run No.3; found excellent bond; hung 77 3 14..feet pre-perforated 5 -inch liner through pay zone; ran and hung 2,232 feet 2 7/8-inch and 210 feet 2 3/8-inch tubing. April 15 - Dis-placed mud with salt water and rocked well in with field gas; tested well; established flow rate 4 to 6 MMcf/d, rigged down with rig crew; drill crews released 2400 hours. DEMOBILIZATION Rig down was performed by a small non-drilling crew made up of support perso,nnel who had worked on the well while drilling. - 43 - . . 'I;'be boUe:r was kept operational for 2 days after well completion to provide steam for thawing structures and rig loose for moving. Various drilling supplies and unused cement were returned to the drilling ware- house (Building 61) at the main camp for storage. The majority of drilling equipment and tools were cleaned and placed in the drilling tool wanigan for easy aCCeSS and storage. The swivel and blocks were wrapped with visqueen and stored on the rig floor. The BOPs mis- cellaneous spare high pressure valves, hand tools, spare pump and engine parts, and miscellaneous casing tools and supplies were stored in Building 61. The steam heaters were left in place on the rig and weather - sec.ured with canvas . Wanigans, other structures and equipment were brought to the follow- ing locations, except for the rig which was skidded to the site of Gas Well No. 10. To Base C amI? Drilling Tool Wanigan Gardner-Denver Pump Wanigan Mud Tank Wanigan Boiler Wanigan Water Storage Tank Wanigan Light Plant Wanigan Halliburton Pump Wanigan 4-Man Sleeper (monster) Wanigan Change House Wanigan C-250 Pump (wrapped canvas) To Well No.7 Area Mes sHall Wanigan Latrine Sled Geologist/Mud Logger Wanigan Substructure Enclosure Panels (stored on sled) C -25 0 Pumphouse Panels (stored on sled) Cement Shed Panels (stored on sled) FAA Rack Area Drill Pipe (left on sleds) Drill Collars (left on sleds) Excess Casing, 13 3/ 8-inch, 9 5/ 8-inch, 7 -inch, and tubing (put on racks) ~ 44 - . . To provid~ ~n a.ccurate record of the drilling supplies and parts remaining on hand at the Barrow camp, and to assist in determining basic requirements for further drilling a detailed inventory list of ~quipment a'Q.d supplies was prepared by the Tool Pusher, Mr. Jacoby and the Navy ConsUltant, Mr. James Dalton. This list was for- warded to the Washington Office of Naval Petroleum and Oil Shale Reserves. Rig Relocation The sled-mounted unitized rig and substructure was skidded off the Gas Well No.9 location on April 29, 1970 and placed on a temporary gravel pad adjacent to the drilling location for Gas Well No. 10. The derrick was guyed to preset deadmen for wind protection. It was originally planned to complete the No. 10 location as part of the Gas Well No. 9 operations. However, shortage of funds precluded ,fun completion of the site. As a result., the following minimal work remains to spot the rig in drilling con- figuration. 1. Auger 10-foot hole and set lower section of the Gas Well No. 10, 24-inch conductor pipe in pOf;:iition. 2. Auger hole and slip lower section of rat hole pipe in position. 3~ Assemble precut cellar timbers "(stored on site) in position on frozen tundra surface. 4. Install deadmen for guying derrick on final location. 5. Skid rig off temporary pad and remove foundation timbers. 6. Bulldoze gravel from temporary pad to form a nominal 4-foot thick gravel pad around the surface- set cellar timbers, conductor and rat hole pipe, and shape new pad to final specifications, 7. Relocate rig foundation timber s in new pad and spray pad with water to freeze- set the gravel and timbers. - 45 - . . 8. Bulldoze snow access ramps to each end of the new 4-foot high gravel pad. 9. Skid rig on the pad and guy derrick to deadmen. lO. Cut off former temporary deadmen and clean-up location. WELL NO.9 RECORD DISPOSAL Drilling records, including copies of Tour Reports, Core Descriptions, Core Analyses, Daíly Drilling Summaries, Casing and Cementing Details, Schlumberger Logs, Baroid Mud Log, Velocity Survey, Tem- perature Survey, Mud Records, Drill Stem Tests, Drilling Samples, Ccx".;, 0øolograph Records, and Weekly and Final Cost Reports were distributed as follows: 1 copy (originals) Holmes & Narver Point Barrow office, 1 copy Holmes & Narver, Inc., Los Angeles, California (exluding Geolograph Report and Accounting Records), 1 copy Naval Petroleum and Oil Shale Reserve Office attention Mr. E. P. Bowler, Washington, D. C., 2 sets unwashed bulk drilling samples in cloth bags stored in Building 61 at Point Barrow Navy Research Site, 2 sets washed samples in cloth bags stored in Building 61 at Point Barrow Navy Research Site, and 2 sets washed and hot pan dried drilling samples, includ- ing 1 foot of core chips, in paper bags, stored in Building 61 at Point Barrow Navy Research Site. All cores (less analysis samples and core chips) were packed and stored in carefully marked wooden boxes in Building 61 at the Point Barrow Navy Research Site. All accounting records were retained at the Holmes & Narver Point Barrow office. - 46 - . . DRILLING AND COMPLETION COSTS The total final estimated cost of drilling and completing Gas Well No. 9 is $399, 800. This includes the well house and the field production line from the well to the pressure reducing plant. This final estimated cost is broken down as follows: Labor (including supervision) $ 216,700 G&A 2. 167 3rd Party Services 69.446 Transportation 9,687 Purchases 83,300 Fee 17,500 Tax 1, 000 Total $ 399,800 Excluded from these costs, as for previous field well cost summaries, are the prorated costs for routine base camp support such as food and lodging for personnel, small hardware items, fuel, water, use of Government-owned heavy equipment and vehicles (primarily WWII vintage) and cost of Air Force transported freight. Although the total cost for Gas Well No. 9 appears to approximate that for wells drilled previously in the South Barrow Field, the effective- ness of the stringent cost control effort made by Holmes & Narver throughout the project is evident in the fact that the total cost of Gas Well No. 9 includes costs of additional formation evaluations and major equipment purchases and overhaul not performed in previous field drilling operations. These additional costs totalled approxi- mately $135,000 and are summarized a.s follows: Additional Operations and Reservoir Evaluation Approx. Cost 1. Approximately 100 feet of additional hole required $ 1, 000 2. Ten percent increase in labor costs over 1969 21, 000 3. Major overhaul of light plant 5.000 4. Major overhaul of HOWeO cement unit 2,000 - 47 - . . Additional Operations and Reservoir Evaluation Approx. Cost 5. Cut 201 feet of core $ 4,500 6. Core analysis of 86 samples (excluding air freight) 914 7. Seismic Velocity Survey (including wire line charges) 2,900 8. Drill Stem Testing 4,771 9. Sperry-Sun Temperature Log (Gas Well No.7) 3, 733 10. Fully equipped 2-man mud logging operation {:Effe1"P,nce) 1,300 11. Geo1ograph Recorder 450 12. Additional Sch1umberger Formation Logs, (Dipmeter, Density. Porosity, Gamma Ray and Saraband ) 10,000 13. Additional rig time to perform the above (21 hole-trips, minimum of 7 days) 28, 000 Additional Major Purchases 1. C-250 Mud Pump and Diesel Quad Engines $35,943 2. Fondu cement (for cementing casing in permafrost) 7,776 3. Diamond Core Head (not damaged and fully reusable) 6, 000 Another element impacting on the cost but not susceptible to an accurate cost estimate was the drilling of Gas Well No.9 several weeks earlier in the season than Gas Well No.8. This meant that rigging up was performed during the coldest part of the winter with very short periods of daylight. Significant as the co st control was, it must al so be noted that a considerable amount of good fortune contributed to the 1970 drilling operation. An unusually compatible and experienced - 48 - . . client/contractor management team and particularly efficient union personnel were responsible for an operational effective- ness which it may not always be possible to duplicate. This factor should be considered and appropriate allowance made in cost estimating and funding for future drilling operations. - 49 - GAS WELL NO. 9 DRILLING REPORT PARTIV EQUIPMENT STATUS AND RECOMMENDATIONS FOR FUTURE OPERATIONS . . EQUIPMENT STATUS The equipment used for drilling Gas Well No. 9 in the South Barrow Field is owned by the Office of Naval Petroleum and Oil Shale Reserves. Although very old, it is currently in good basic condition for further drilling of similar wells. As with any drilling equipment, routine repair and replace- ment will continue to be required but, with the improvements made in 1969 and 1970, the basic plant is generally in good shape. The principle defi- ciencies are the moderate requirements for repair of the C-250 mud pump engines ¡ and the design and installation of a new electric distribution system for the rig. It is emphasized, however, that because of the age of the rig and equipment (other than down hole tools) it may be difficult or impossible to secure replacement parts when the need arises. The potential hazard of costly delays waiting for an important part will become more acute each year, and should be recognized in preparing cost esti- mates and funding appropriations. Following are comments regarding the condition of the main features of the equipment, based on observation and discussions with the operating personnel. (For more specific engine mechanical requirements refer to Mr. Jerry Fries! field notes on file in the Holmes & Narver office, Barrow. ) Drawworks The Caterpillar D-8800 drawwork engine was given a light overhaul while rigging up. This included replacing 4 valves, installing new valve guides, grinding valve seats, along with a general clean up and tune up, and the ins tallation of a long-needed electric start system. This work corrected the serious engine power deficiency encountered in 1969. During the operation the engine started using oil and gave other indications of the need for a major overhaul prior to drilling another well, e, g., cylinders glazed, excessive end play in crank.shaft, requires new bearings, thrust plates, pistons, liners, etc. The drawworks and brake system proper is in fair shape. However, a set of new brake blocks for the lower drum should be ordered and held in reserve as the existing ones are worn and could fail at any time. (Requires 18 each Cardwell HL 775 type brake blocks and 90 each flathead bolts, 5/16 by 7/8 inch. ) - 50 - . . Drilling Line The present drilling line is showing the effects of wear and corrosion and should be replaced by a new one. This line was slipped after Gas Well No. 8 was drilled but due to localized wear now requires replace- ment. The partial reel of drilling line in open- beach storage for several year s adjacent to Building 61 also shows the effects of corro- sion and is not recommended as a safe replacement. Derrick Enclosure Panels The canvas derrick enclosure panels are showing the effects of sun, age and wear. It is possible that with careful patching they may hold up for sometime. However, if the rig is not used for drilling by early 1971 a special effort should be made to repair and patch the canvas that year, otherwise the late winter winds will damage them beyond repair. A lot of repair work was required this year following a February storm. Had the panels not been promptly repaired, it is doubtful that they would have been salvageable following the storms in late April. Substructure The substructure is in sound shape but is becoming seriously corroded and in need of sand blasting and proper protective painting. In addi- tion, both tongues for skidding the rig require rebuilding prior to final positioning of the rig on the Gas Well No. 10 drill site. Boiler The boiler equipment, although marginal in size, will suffice for the drill rig if it is carefully tended, the use of steam is limited, and auxiliary heat is provided from Herman Nelson heaters. This boiler was carefully ch~aned and adjusted prior to spudding Gas Well No. 9 and gave no particular trouble. An extra burner and electric motor assembly were kept available at job site as stand-by equipment. Sight glasses (for water) were replaced on the boiler this year and new ones installed on each of the 5 make-up water storage tanks. To reduce refueling labor requirements during future drilling operations considera- tion should be given to conversion of the burner to use natural gas. - 51 - . . Heating Due to the lack of boiler capacity the conveniently mobile Herman Nelson heaters, although more hazardous around a natural gas well, were again used for heating. These units, as before, were found to be: incapable of round~the··dock steady operation for any long period of time. Although these units were important to the expeditious completíon of the job, the increase:d fire hazard, their inopportune failure times, constant maintenance and fueling require- ments were a big problem. Procurement of a unit~type heater of proper design, similar to those being u.sed by the North Slope companies, should be evaluated as a possible solution for rig and substructure heating. This would not eliminate the need for Herman Nelson heater support for other equipment, but would, at least remove them from the higher fire hazard areas. Gardner Denver Mud Pump (7 1/4 by 10 inch) The Gardner Denver pump with a Caterpillar D..1300 diesel engine is in good condition. Prior to spudding the well the engine for this auxiliary down hole and mud mixing pump was tuned up and performed well. At the dose of the wen 6 1/ 4-inch liners (used), new heads and rods were installed. C-250 Mud Pump National Ideal ('7 1/4 by 15 inch) Although this pump and the quad GMC 6-71 diesels again p(':rformed well, some work will be required prior to the next welL The pump was left with 6 ] /4-inch liners, If a 12 1/4-inch or larger diameter hole is drilled 7 1/4- or 7 II2-inch liners and heads should be installed. The diesel engines now require a major overhaul based on an inspection of the No. 3 engine on which the head was pulled. This engine was also found to have a broken ring. It is probable that new cam shafts, rocker arm assemblies, follower rollers, liners, rod and main bearing kits, rings, new dutch discs, governors and a kit for the power transfer gear box win be ré:quired. Now that this pump has been purchased it is recommended that the pump and quads each be installed in separate pipe- sled wanigans designed to permit assembly and disassembly of the unit without removal from the wanigan. Due to the weight factor the design may be somewhat complex but would be effective in reduction of overall rigging-up costs and protection of this valuable equip- ment between jobs. - 52 - . . The 3 1 /Z-inch string of drill pipe, which was not used on Gas Well Nos. 8 or 9 and remains in open storage on the beach, was given a cursory inspection which revealed that considerable corrosion had set in. To minimize further damage it is recommended that, as soon as possible after the snow melts, the tool joints be brush-cleaned, doped, and equipped with new thread protectors. The available thread protectors were boxed and stored adjacent to the drill pipe pending expenditure approval and favorable weather conditions. Miscellaneous Equipment and Modifications Swi vel The Emsco AB-4 swivel was repaired and outfitted with new parts for use on Gas Well No.9. There were no operational problems and the swivel remains in good shape. However, Holmes & Narver was advised that, due to the extreme age of the equipment, the manufacturer can no longer furnish spare parts. The last parts received from Jordan Company have been used. It is recommended that action be taken through the Jordan Company, or some equally reliable organization, to locate and procure a more modern swivel for use on future drilling projects. Elevators A set of used 4 l/Z-inch elevators were obtained on a purchase/ rental basis. The purchase option was subsequently exercised. These elevators are in good condition. The old set which is too badly worn for economical repair, has been retained for possi- ble emergency use as a spare floor spider or slips. Due to the degree of wear under no circumstances should they again be used for handling pipe on the blocks. The 13 3/ 8-inch elevators are in need of repair; prior to reuse they should be rebuilt or at least have a new latch spring installed on the latch mechanism. - 55 - . . Fueling System Fueling of the many exterior diesel tanks for the circulator heaters in the wanigans by hand pumping from drums is difficult and costly. The procurement of a simple portable electric motor-driven gear type fuel pump is highly recommended. Where practical, installa- tion of fueling lines to central fuel tanks would be most helpful. Such a centralized fueling system has been installed for fueling the various engines. Painting The paint has scaled off both mud pumps and the bare metal is now rusting badly. During the Gas Well No. 9 job, on a time available basis, the laborers wire brushed both units preparatory to painting. It is recommended that these units, now stored in camp, be pulled into a heated structure and painted prior to the next drilling job. It is also recommended that the HOWCO cement pump, the draw- work, the drawwork motor, adjacent rig parts, and the rig sub- structure be cleaned and painted. To provide more effective rig floor lighting it is also recommended that the inside canvas around the rig floor to the first girt be given a light spray of aluminum paint. Movable Monkey Board The present monkey board system continues to be awkward for the derrickmen due to both its fixed vertical and lateral positions in the derrick. It is believed that significant! y improved efficiency and safety would be realized in making trips, running pipe han- dling collars and using tubing if a movable monkey board is insta.l1ed. The fabrication could be accomplished at the rig using jobsite materials with only minor new hardware items required. It is recommended that this field fabrication be included as part of the next rig up. Road Drag The snow drag which was furnished by the base camp for con- structing and maintaining the rig access roads for Gas Well Nos. 8 and 9 is too short for effective operations over the rougher tundra terrain. The short drag causes serious progressive buildup of snow ridges which reduce the usefulness of the road and require periodical use of the snow blower plow and other heavy equipment to open the road. - 56 - . . To alleviate this problem it is recommended that a simple steel drag of appropriate length for tundra work be fabricated and made a part of the equipment available for drilling operations. This drag can then be routinely pulled behind a bulldozer or a fuel, water or freight sled as they traverse the road, thus giving it a dressing as they go. Shale Shakers These units, although old, operated quite satisfactorily and are in good condition for further use. One electric motor did fail resulting in some secondary down time. This breakdown was due to failure of the crew to recognize the problem and to effect a timely switch to the other unit. Fortunately this happened while drilling above the gas zone and while no gas was cutting ou~ of the lTIlld in the close confines of the building. To minimize similar fire/explosive hazards in the future, it is recommended that the electric motors on the shale shakers be replaced with hydraulic motors in conformity with common safety practice in the drilling industry. - 57 - GAS WELL NO. 9 DRILLING REPORT PART V SUGGESTED DRILLING PROGRAM FOR GAS WELL NO. 10 . . SUGGESTED PROGRAM FOR DRILLING GAS WELL NO. 10 Based on established field production requirements, and the methods and procedures developed through experience on Gas Well Nos. 8 and 9, the following program, utilizing the existing on site inventory of tubular goods and equipment, is recommended for the drilling of Gas Well No. 10. 1. Set lower section of 24-inch conductor pipe to minimum of 10-foot depth below tundra surface in augered hole and cement to surface. Drill rat hole with auger and set rat hole pipe. Assemble precut cellar timbers (now on loca- tion) around conductor pipe. Bulldoze gravel (hauled to site at cloFle of Gas Well No. 9 operations) into position around the cellar timbers and rat hole pipe to form a minimum 4-foot thick pad on undisturbed tundra. Shape pad; install foundation timbers and freeze in place; skid rig onto pad and place in drilling configuration. 2. Drill 12 I/4-inch hole to 135 feet. If some scientific group desires and has the funding, this zone could be continuous cored for the most part. Open hole to 22- inch diameter to 125 feet (12 1/4-inch bits and hole opener in stock). 3. Set l6-inch OD (minimum 15 lI8-inches ID) casing to 120 feet (casing in stock). 4. Cement to surface with Fondu cement through drill pipe and stab in shoe (shoe, subs, centralizers, and 90 sacks Fondu cement in stock). 5. Drill 12 1/4-inch hole to 1,320 feet. 6. Run rES and Side Wall Neutron Porosity Log with Gamma Ray and Caliper from bottom of hole to base of 16-inch casing. 7. Open hole to 15 -inch diameter to 1, 310 feet (hole opener in stock and dressed). 8. Set 10 3/4-inch OD casing to 1,300 feet (10 3/4-inch casing, float shoe, float collar and cement head in stock). - 58 - . . 9. C~ment to surface with Fondu cement. Use Murphy hesita- tion squeeze method for displacing cement. Precede cement with 10 barrels of water pretreated with 100 pounds caustic soda (WOC - 48 hours). 10. Run Cement Bond Log. 11. Install Shaffer Unitized Head and Nipple up BOPs. 12. Drill 9 S/8-inch hole to approximately 50-100 feet above con- glomerate (9 5 18-inch conventional rotary rock bits in stock). 13. Run correlation IES log. 14. Drill 9 5/8-inch hole to approximately 10 feet above shale conglomerate. 15. Continuous core through the shale conglomerate zone and the Barrow Pay Sand to total depth. Have sample core analysis made from. each foot of sandstone core recovered (conventional diamond core head 7 5/8 by 3 1/2 inch in stock). 16. Open and condition core rat hole to total depth. 17. Run logs; suggest IES, Formation Density, and Sidewall Neutron Porosity with Gamma Ray and Caliper Log combination. 18. Run DST of Barrow Pay Sand if any doubt exists about the well being a commercial producer. 19. Set 7 -inch casing equipped with float shoe, float collar and 7 centralizers to total depth (float shoe, float collar, and 7- inch centralizers in stock). 20. Cement 7 -inch casing to surface with Fondu cement. Use modified Murphy cement displacement technique. Precede cement with 10 barrels of water treated with 100 pounds caustic soda. 21. WOC - 48 hours. 22. Run Cement Bond Log. - 59 - . . 23. Drill out cement to bottom of casing with tubing, 5 3/ 4-inch bit, and well casing scraper in the string. 24. Perforate 7-inch casing for production; test and squeeze if applicable. 25. Hang tubing. 26. Bring well in by slow rocking with field gas. 27. Rig down and skid rig to prebuilt storage area and guy. 28. Install production lines, production house, and related util- itie s. MINOR RIG REPLACEMENT PARTS REQUIRED In addition to the norm.a.l major operational supplies which are not listed, the following small items are critical to the operation and need to be put in jobsite drilling inventory. For Gardner-Denver Pump 6 each junk rings, brass 48 each rubber rings (Skinner brand, no substitutes) I set of 8 valve seats 1 set of 8 valves I set of piston rods, API No. 3 taper For National C-250 Pump 2 sets of piston rods" API No. 5 taper 1 set of piston heads, 6 1/4-inch, complete 2 sets of piston heads, 7 I/4-inch, complete 2 sets of piston head rubbers, 6 I/4-inch 2 sets of piston head rubbers, 7 1/4-inch - 60 - . . 1 set of liners, 7 1/4-inch 1 set of liners, 6 1/4-inch 4 each American valves 24 each inserts for American valves Repairs for Cameron Flex Seal Valves (For Type 5, Figure 35088-4-1-1, size 4-inch, 2000 WP) 4 each hubs "h . ö eac wear rl!lgs (For Cameron Flex Seal Valves 4-inch, screwed, 4000 # test, manufac tur ed prior to 1953) 8 each hubs 8 each gates 16 each rubbers 16 each wear rings Miscellaneous Small Parts 2 each pipe wipers, 4 1/2-inch (Bettis or BJ brand - see camp. catalog 1969 Vol. I, page 908) 1 each pipe wipers, 2 7/8-inch 4 each tong pull backs (page 909) 2 each elevator balancing straps (page 909) 200 feet manila rope, 1 lI8-inch 200 feet manila rope, I-inch 200 feet sash cord - 61 - . . 1 set 3/ 8-inch jets for 12 1/ 4-inch Hughes bits 2 sets lIZ-inch jets for 12 1/4-inch Hughes bits 1 set 9/16 -inch jets for 12 1/ 4-inch Hughes bits 1 each 9 5/ 8-inch OSC 3 J Hughes bit (in case the conventional bits in stock drill too slowly) RELATED RECOMMENDATIONS FOR DRILLING 1. Continue to use a carefully controlled low water loss mud and mud program similar to that used for Gas Well No.9. 2. Use automatic Geolograph Recorder throughout all operations and require that the drillers identify their operations on it. The low cost type of unit rented for Gas Well No.9 is ideal for this rig. However, management care must be exercised to see that the drillers are not permitted to avoid using it for their own conve- nience and motives. 3. Use a 2-man mud-logging unit similar to that used on Gas Well No. 9 from the bottom of the 10 3/ 4-inch casing to total depth. This unit is extremely valuable for down hole safety of the well and personnel as well as recording of formation/production data. 4. Provide some see-through method and/or dependable communica- tion system from the driller I s rig floor position to the mud pump operator's position. The present 3- to 5-man yelling relay system through the various doorways is slow, inefficient, subject to human error, and costly in both rig and labor time. 5. The daily recording by the Drilling Superintendent of manhours charged to each segment of the operation, and subsequent weekly dollar-cost runouts (a practice begun on Gas Well No.9) proved to be a very effective cost control tool. It also assisted in the efficient scheduling of personnel and the redetermination of priorities in the event of program changes. The use of this daily/ weekly cost control system on future drilling operations is highly recommended. - 62 - . . 6. It was the practice on the Gas Well No.9 operations to have the third party service companies stand by continuously during the drilling so as to be immediately available when required. This can be very expensive in view of the extremely high standby rates now effective in Alaska for both equipment and personnel. It is recommended that the rigid application of this modus operandi be discontinued and the use of standby be restricted to a practicable minimum. Particularly careful but flexible planning and shrewd foresight will be necessary for the timely scheduling of the service companies and the mainten- ance of continuity in the operations. In spite of the best planning there may be occasional rig shut downs for a few hours or a few days because of delayed aircraft flights or changed down hole condi- tions, but it is believed that, overall, this method of calling in the service companies only when, and for as long as they are required, will result in lower costs to the Government. Consideration must be given to the judicious use of charter or commercial aircraft flights for transportation of service company men and equipment in lieu of complete dependency on Air Force flights which are often necessarily delayed. 7. Make clear in advance to the union leaders and to the drillers sup- plied for the job, that any driller who is not capable of and willing to keep an accurate meaningful tour report and pipe tally will be promptly replaced. 8. Assign 2 tool pushers to the operation for full time on-site super- VISIon. The experience of drilling Gas Well Nos. 8 and 9 has clearly shown that the rate of production of the crews is directly related to the amount of detailed, aggressive, on-site supervision provided. It has also been apparent that drillers, particularly union drillers, are incapable of taking the full responsibility for running their shifts, The driller must necessarily stay on the rig floor most of the time to supervise his crew which is usually short on experience. He therefore cannot apply the motivation required to keep the rest of the diversified crafts working effectively. In fact, most of the time the drillers themselves require considerable supervision and direction because of their inexperience in oil field drilling operations. It is strongly recommended that 2 tool pushers be assigned to the next operation. Each of these men would work a regular 12-hour shift under the direction of the drilling superin- tendent. - 63 - ï t x )( -,-II Z ~ 1 V ~ /;.. 3 " X 1\ 0-- .L. (Ji i ~, t i ! 8 i /i !'lZJ4 . ; . , ' ì / "\ I I 00] ! ¡ ! f. I i L ZJ I ' I 11 "'B BI I~! fBITlI9 ~ Er-LG_þ> 13 Figure 1 ~ ~ t7 24 .-- ! 20 21) ShOP'~r '~~ (19. . and Head 18 Galley. e at 20' elearane - GAS WELL NO. 9 Rig Site Layout 20' Scale: , -¡ ! zz ' , -' . LEGEND I Hous e Drilling Too Walkway Pipe Rack Drill Rig Storage Hot Water Pump Cement Howeo .ng House Cement Stagl Mud Logger Mud Tank Hvdrill C~250 Pump Q.lad Diesels GD Pump Fuel Sled Water Tank Boiler Water Sled Light Plant Shop Galley Head Sleeper Area Mud Dump House Crew Change 1 2 3 4 5 6 7 8 9 10 11 12 13 14 15 16 17 18 19 20 21 22 23 24 . . J k r, '. 1.4 DEPARI~~gFS~~~E~TER'¡,g~; iN GEOLOG IGAL SU RVEY ¡ ~) I [ 'NEll COMPlETIÓN OR RECOMPLETlON REPORT: AND :. LOG * QII. 0 W¡¡;LL ¡¡un.., '0 , IS ~r In· . atr,. . n~ Dn . t.:ve¡ d'=' 8id~) /", ' Form "POroVl.,}.. ~ . ~ : Buùget Durell,! No.. :,2.,.1¡3ú5.6. ':J. l.t:ASCDF.šïïiNÃT"iõÑ-¡îiï,SEIIIAL NO. (.,..... '. ....¡ NAVAL PETROLEUM RESERVÈ' No. 4 6. 1~INP.I'\~"..ALL~.iiia; ~R T~~B!l .:~AM¡: .... ".'~' " : ", ... ,.:,. ~.:,":,'7' la. TY.PI:: 01" WELL: ,:AS r:tl 'O;LI. Ò DRTO Other '!~ ; 7. U!'IIT "'OREEMENT N...M¡¡ - '·.t .. . " '. ,. .. .. ,.. f: - ...... ; .', .. .' ., ,. .... I :.; I· .~ 1] J' ! 'c' ". . .. 3. '";; ~~2;'''~;:OING 6.C~;~;~:;';:~:-~A;~'"~;~~:-~.~.-;~J6:;---J ~ I 1"; ."'". "" N:~ ".L~:;,:: ". I.oCATION Oi' WELL (Repo~t location clearlu and i" acco~dancc with an f State r,cquircment,), SOUTH.· BARRC'^,.GAS· FI ELO C'· At;urtace ~88' N &: 22.58' W OF SE CORNER OF SEe II, T22N, RI~Wr' u:¡.¡! - ..,f l~:,;.~C~~}~R.~~..,~IIDI'O:K"'.~.[\:.;~::VEY At :top prod. IntervllI reported below SAAf ~ . i I ',,: ~~~: I'!, J22N. ~R 18\1, '" UP~I~, :.'.. At :total depth SAME ! ;-:;.'! .., .,' ::. <:. '. :~ ~ ,,~~"::,~:"C~ :.;':~"~"'~',.";:=:~=~~~=~~' .J,::.=:E:~::~,::~,,;=,,~~.J=,I ::r:~~=:TED ~~!~~f~;:~' .. I :1;~::::~ .. 1~. D~-r,lJ SPUPD¡¡;D 116. D...TE T·r! B.CACHED I,Š~;?"'TE.CO)!I'L. (Re~.~v to I~O~ 118. ELE.V....T~ONS (DF. BI.'B, liT, GR..~TC.t': /19. ,fJLEV.CASINGUE~~ )-19-70 4-7-70 ';'f; 4-15-70 ,;'~ ~ ,. I RKB.29' Gl16~ ....: <~.'.. ' 16' 20. T~1L D;l!. WP ... TVD ,21. tL:G<;~~K T-:;-IT;~; TVD ./.22. ~G. ;1, )~¡~l:\,COMPr·· :,,¡'i,3' ~~,i~~:~5.¡ n~.o..,~.TA"'L'~L.Y,:' ~;':.:,L..~ :1:: ~:'Uo~,.,: ~OOL~ 2450 . ~'l.NON::: '" -."SINGLE;·. 1 I " _ . :: .~~. ; ::,Ot~CIN? .1~l~!t~~L(S.). Oi" ~~IS~ C~\!~i:&~r;~..~~·,~OTT?,~~: N~?(~~:~rG.;%~r . !:.)1 "1" . ';'.:~'.~.-_":'_'. ;~~...'. .~.:,_"i.... ~,;-,,'._;.'.,..~.:... .,t.:..,~.'.: . .2.~ :;tSy:t~~?~~U ~ SOUTH :!3AR~OW GAS SAND·JJµ~AŠSICt:,.~~ ,.. . Top 2J74!. . 66Ú~1-I ~or :P~NETRATED ~ _ .: ~ - ..:. ,.;...... ... : '¡ ~.: ", . '~ '-·O-ES LOG PiCK) ',::':- :. ;':' , ! !:-,:~ 26. T:r~¡¡ ELECTRIC ...ND OTHER LOGS RUN :'~ .. ::: ';. '0 ....; :f ;;-;:'.: '.:::¡.:. ¡ :'.. :: ; , '~'I 27, WAS WI!:LL C~.R~P;; ;~ liES, C,Bl, FOC, Bre, .P;'\L-:Sf\?~ SARASA/-ID. ~lëLL VELÔC"¡ry .SUR~',V, Pl,UD', LOG; O¡;OLOGRA?ii. C{¡i;ì:....\'~ pES . y¡;s . 28;· , . .,::: .~ _ .CASING itECORD·i(Repodall itrinU88ct in well) .. ";,,.. .... ':.., ," ; ~'~ " .C...SINO SIZE 50 WEIORT. LB./FT,' ., -DEPTH SET ()!D) .;:: HO.Li""šïz& :¿ ;-:- CEMEN'l'ING ItReORD "'MOUNT PULLED \. TYPE 01" COMPLETION: ¡ N¡;W rY1 WOItt{ 0 ; '\"Ia.r, .t!J onm PEt;..· EN o pr,U<i 0 o...eK IUFI'". 0 ItESYR. Oth..r I :.,;. ¡ ~j S. tAR~! ;?R, ~.~"'S~~N"'Mö1 ,', f.;. ~.. ~ :':; ~. :.:..... ,\ .. \.~ .-. . To r::~:' , ;..' :·.···1'·· 2. I'iAßrE Oh' O..Io:R"'TOR , OFFICE OF NAVAL PETRQLEUM AND OIL SHALE RESERVES t; f ! . h ~ 9.;"W£LL .:~o. :; .,~: ~.-: ~4 ~' ;: ;1 " " '", . . ... ~¿NO;. :;;. .:= ;,; ; ~'~.~j ; ....- I, ")/811 ~9 51all :711 NGïE: ~;. C·J . i" '" 54..5: ,'. ,:163' 40.0,::: -, " ;.. IIIO~. )8.0~' ;".":': .2384' 711 DV COLLAR SET Q 1.202';: 280 SÃS .. ~, )LINERRECORD :..,.. ..' ¡" ··ls'51" . :. , 8 i ~.>:IZ.1/4":~ " '\·:!.'s·5Ia" ,.'.... :,¡ . .. . ..J sacw D'JeolLARAI\D ~OO C~IT TO SURFACE II '11 " '. I II f' ':. ... II \-1/ 206 sxs Fo~;)u II 429· II,.., II tI 480'~ J200FONCU:&' 280 "CL,.1.SS. G), DV COLU.I? TUBING IŒCORD '","' , . SXS AGOVE 29. .. \~ :.::~ ~.. ': : .30. " 31. TO~I~!D): fl BOT1;.o$I.(MD)l~.. :S"'CKS ÇE~,IE~TOI ,S,CRE¡;~ (MD) . I. SIZE l DEPTH SE:T (MI;» 2371'~," :~2.c~9'::; ,. r-;Ol-;E _ ..··-SEE ìTEM JI. 22J2'~2 7/~I'OD EVE . ¡ ,').: ,.,.~:'.~;:~..C:¡ .~~/:: ,'),."'J ..' L, "..:;. ;... ·210'-2 .'/8"OD EL'E 2'(.~2'.. I\C:;;;. PER~'ORA>:IO:j n;:CORP (Inte~ Ja¡, Biz" a~cl fiumbe~t ~¿ 32;:·: ':3 ·ACID. SHOT. FRACTURE. CEMENT SQUZ·EZZ. ETO. I ,.. ,.0>(.0 ===.g : ,,}~ .:g~ DEPTH: INTERVAL ()ID) AMOUNT AND KIND OF )[...T;:mAL Us;:p· "'.' . · ': . ~IZ¡; OD, PACKER SET (MD) ¡ 5" - .__h~__~~. _... -..._--- ...~._'. ---_.,.._,.~-,-'- -.--..--.-- 23711 TO 2;49' ~R~-~,RFOKATED lIN~R 0.060" X 211 X 6° U~J~RCUT ¡ N'O~E . ~., o' ~ NONE .. . ~ "'- .. _. " '-",~ / . ...... ;' ~..;~.. o ~..~:~:i.-....., ,.~~ ;~ ~~~o: ~~ . -\' ," :':' 'I _0 i -.~ . ,. - , " 'to" ':~ .:;~ I; :.. ;; :., 33.' ..' PRODUCTION I .'~ ,o.~ :i · DATE :~R;~L7P:ODUCTION . _, 'I.PIIODUC.:-¡O~ &!E.!~?E, (~I,o.;~~~I/I:~ l.ilt,. IU1ll~in./I-'iZî ar-/~pc( pump) , '. DATiJ Oil' TEST HOUR.S .TE:STED . ·.I.tC.:0/Áa'Ð.~~.'5ZE/~.,..1 PROD'N. FOR 01L--8BL. .. GAS-MC~'. W...T¡,:n-BBL.IIIAS'OIL RATIO .. 5-)0-70 .. 4' ... :: v TEST P¡;R~~>. ~ .:;: :NOÑc > r = .:. ¡. 560:~ ~~O;:{,·· :;:':':, ,: :,.: .., '-, ~ ':' ",J)w~ T~¡)lNO P¡;;¡gS. CASINO PRESSUItt: I' ~~~:igií~T~~TE:! OIl~.nUI... ; v, '.1 ., .'. GAS-) C~'.' W"'TER-UBL, ........:¡ I. OIL G_i\A~ITY~A. :,'~. (,C.O,.R:,:.> · 900 S¡:,tlT-I~ 920 S~JT-H¡ . ------:->. NO¡";::'. I.AOF'7.à}~~c~/Ò ~'Oi'.'::' 3r DIS:OSI>:¡ON Oli' GAS (Sold, u8ed lo~ Iud, vented, etc.) . I. .. ~, ! , ' .; ,·,1 I FUEL:' :;.'! :;./ . . W¡;LL STATUS (P~QduCill¡¡ O~ " ,hut·ill) ::;' ;, :PRO¡)UC 1r,~C " T¡':ST.WIT~ESS¡;D BY .. 1-''R. A~"'D~f.\'¡ C~ÅN;:: ." ~. 3:;. LIST 0, ...T'l·...CIJM ~NTS . ··<:1', ' . ........~.._.....-... ..;~, ~ _S.U:C,H:lC_!..():-;s~..--'ES1 ~ FDC,'SF.C, ·P.\1L' lOT, srj;:'iI~j··lCGè:·:.::: ..' . 3G. I hereby caUfy that th"foreiOïñ;: and attached lñfornÏí\tlon--ls com¡JIët.~ nnd correct U6 ùl'tcrmlned from nil avall..hle ,recorùs SIGNjW qd(~~~Þ~~"L!~[[;:'C'1t'L~:~ TITLÐ ~~~~~~~'["2IQt~~:~~:~tC~\JEL-~:::::>~AT~~' , 9-)-';0 .' V ~ {~::i·· -' .. .. ...J .. " ~,J ". . ·;'0·:' :($CC.I/15:,u,:f!onS and.St?accsforAdd¡tionq.r'p~t~ ~.~' Rcycr,sc Side) .' '. , . o. '. . 0" ;.' ,. ,.0 .'.~ ~, : .; ." 0': .:~, . . ~ :.' .', " .,,, . . ... . . . .. ~; .- NSTRUCTlONS , . ., , t·: I ·1 ! I r ,:: ,.. , , . , I I . . ¡ .¡ ¡, ..., 1\· I . , "" ~~! ;.. .,,1 ~ ! . _f"~:,: f' ! ~··.!I . : ,;:~> .1 j'7J.' : i,~~ i-I,' .r:!.,·' . .,",' , f~, ,J' i, 1 ~'~':; ~-: .. GI:!Ì1cra!: ~'hI9 form Is desIgned tor submitting acotnplete.Rnd correct well completlonreport and log. on ,ntrtYP~,ot lânds ""nd leases to :elther a Federal agency or a S~te· agency, :··or both. pursuant to appIicableFcderal and/or State laws and regulations. Ânynecessary special instructions concerning the use of. this form and the number ot copies to be " ·suùmltted, particularly with regard to local, area, or regionalprocedur¢s and practices, either arc sbown. below or will be i~sued b" or may þe (Jbtn.ined froro, the local;F~dcr!ll ,: and/or State oíl1ce. See Instructions on items 22 and 24. and 3,3, below regarding separate reportsfor;::>cparal.c eoropletlq,ns.. ' .<:.: :".1 ì::; '.; ¡ li·;'1. ~ . ."If not filed prior to the time this sunÙnary record is submJtteq, copies·of all currently available logs (drmers,~geologlsts,·s:Hnple and core analysis. aU types electric, etc.); fõrmü.....' '. tion anù lJre"sure tests, and directional surveys, should be attached hcreto, to thc cxtcnt reqµired by applicable lfederal and/or.State la~s and regulations. ..AU attachments. ::·s!JOJld bc listed on this form, see item 35.: :'.:; ,.; : :i ¡ ! .~'.: I", :::;. "i .., '.<, ¡ ~·,--·-'i 7. ~i :~:. -: : =-:: .:' -.=- -- ~d . Iter,! 4: If there are no applicable $,~te requireroents,locatlons on Federal or Indian land should be descrIbed, In accordance wlth J!:ederal, requirements. Consult local State: '·,or Federal office for specific instructions. . J ,",",: ¡ ': ¡ c'; l.s:.: : ; ) ,,, . ',.,.".,~: ' ",¡ ; ~-:: ;~. ,~;,:,' ;;' -' :::: ~;: ;~:3 ·.Hem 18: IlH1icate·\vllich elevatIon is used as reference (wllerenototherwlse shown) for dep~b measurements given In.,other spaces on this form and In any attacbments.: 0.", :Jtl:!ms 22 ond 24: If this weU is completed for separate production from more than 0lle interval zone (multiple completion"), s.o state in Hem 22, and In Item 24 show the producing- ·;intèrval, or intervals, top (s) ,èbottom (s) and 'name (s) (if any) for only the interval reporte\ilnltem 83. Submit~' s~parllte report. (pageLon this form, adequateiy identified, ; for each addition:].i interval to be separately produced, showing·the additional 'data pertinent. to such interval. :' ~ :..' ',,::; :: ~ c: I:¡~: :-:! :: ¡ "'i;· '- ,', : Iten, 29: "Sack8 Cellicllt": Attached suppiemental records for this well should ·sllò\v.the detail,s of any multiple stage cementing a~d the loêation of the cementiñg tool.· -;¿ ~. " Hem 33: Submit ~ separat~ compietion report on. this for,lll f~~..;c~.h int.erv~l, t_1? b~ separatt>~y. pro~uced. .. (See I.~stru~tl?p f9r item.s 22 and 24_,abov~,) . ,j __.! :'1 ~ ~ ¡ ....~': :.. ;~..;. '-t :::. ~ 'I; I ! l ! ~ ::".L:..:. 1_. ~: I_~;~: >;.;' :'''!~: ¡ ~ j (..., ,I I:, !-~~ -: ." ....¡ '.0'1 ~1 -'I -, oJ: ,., _ "- I' I 'I ,;0 "I~I""'::'-I ~,l'l' ,......~.. I" I ··1 _1-- ------.--- -,----- '-:: " i--'-'~'I:; i I I'. .';1';;<·~ .'<.10. ! I ,: ...., ,-- \'" I I I I ..' r; ~ t ';' I \--' .. ;.. 1'''''(,.'; I w, I '~t:'1 t~; . ...a......... . ~ ':,;,. ::. ~:' : :~:.... I I ~'.'!. . ·;'::~,·:--··I I I =1'=:~I'.i1 I:.:.! I ¡:".,c'~1 . "'. ~ ~" ~ :~~ ::_1 t ~.:.. ~ : ..) I 'I·· ¡ It ~ L~ :;';' . ¡ . ê3: : - i 1JJ ':; j .'~ ! ;. .: . :~ ~ 1 - ¡.\ I +: t ~. ~,;::,I.,?¡ oi " I·.:¡ ·';.,l ;, ,:, I ,,",~,..:-.¡ .,1 /...1 i. I~~ ¡~¡ ¡g ¡ . .!I'~I !:~'It :.', ¡ ¡ 1'1,1 ~~-:. - ." , . ,-',' ;;1' ---- ..' ,', 1 u... J., ~ . , L:.. '_ .'''' ,. "-"" . ... . ~,.....!, '.'- ;\ '- 10.. -. ::\ ¡., 'I i I ...;¡,W)..In;.., ,.:1. =: :,4.' I:', 0 I 0:'.1 ,,'"<. ;:., '" ¡ ..'. .. "'. " J. . ì ' · 'c-," I :: I ·1 I C' . I , ;;;.. ' <;. ' \ ~;:;::; , "I ,IÙ :, " , I' .' ,. .. . ' (:t' : ;":c.::, ! I i"':' I .... ì t. t- ....1... ..; ..:.. f"J; ! C I '_.1 (jJ , -1 . ø>',":,~ C:1 r, . \..,,, :~.~'. _.' ¿--J...! ..,}-_ .: t !S j :':'j! 't; ,- "\ '; I ~.~.. r:~~·~~2!~·.,1 ~.: \ ..:(\..1 ¡ i:::~ ¡ ~ '.- :.~I ....~, ~, i '~t_ ;~:;!7. Sl"~~rARY OF POROUS ZONES: (."; -- ".n ',;~: ::¡ 1 ~;:: ::' ::i~ I :., ¡ ~~ . ïJ ..! :.;v;';: I :,' ¡ I,''; I .~ ". , :'., 1;110\1 AI.I. BIPORT-tYT ZOYES OF'POROSITY AND CONTENTS THEREOF; COl\ED INTERVAt..S; AND At.t. Dl\It.t.-STEU TESTS;-INCLUDING 3S.'! . i .':-. . :s: ~::'.. :'" ~ DEl'1.'f{ ISTtRVAL T~STED. cusmON t;SED. ,TIME TOOL OPEN, FLOWING AND SHU::'IN~PR~SS.uR,EB. AND,_.aECOVÐRI.E8 ì?:; ~: ::;1 I t ~'è. ! .~ T'f -, -. '. __ .. -", . '-. _ , , '. ¡ r-. .. , . ;... è:,' i ;;·i~O!\~IAT!ON '':'' "TOP. ì ~., BOTT011 : ~.." ¡ ';;;' '~.' \ DESCRIPTION..CONTEN~S. ETC.,~ ~I ; i "", __ "'I Top' ,¡ )) ~~ I :;~ÒR~ (!)' : ~ 1:9¡fr ~¡ :.;.: ~'~0¡6,~ : ~·'\;;);REhoJi~~::·~SI·.~~·C~I~TII:NS~fi:ë;.,( ~R~~"(H~ ~¡-~i ! £!;i'; ~~ II., (2) ;-.-20!6 ;.1:.: 2020' i RECVD.t' -. r:1,ILLED·OUTTOCH.\NaE TO DO:.:vT~:,HEAD _ SILTSTÓr-;E I ;::,! t~~..",.·,{~) 20~O·::! .,!·'j,20r,9·· ¡ '··".·'129'::~S"AI.fDST";:Ò!(,5~ ·20~9'¿",..20512.""C:i.RES.T SHA l"E ~;: " '.. , '>O.J . ,/ " , _I '"'," ~ '. " . . I I .. ...1 ~,," :3:; ~ "~,{4} 20)9·,· 'zi :: 208~--'- ....II'-:,2'...··':,...·"SS 207ei!""20Bcr;!,R(ST'SIIf,t.Ii.· ~~¡~:::; f,.ì . f,,:.,¡ (i~".'.{5) 208o-~ ¡ ';:~·2'09 D2>29~'-;·SS2.105-2107;t, r-:;:ST SfJAlE,;4. ~:¡~";~;..:s: ~¡ ~;',¡ ~ 11:: (6) 1.1 236IfC:; i~¡ ;"123Ð9t " ¡ 28' -·ss .23_66-2367, 237~.2}l7,~37:~~2t~9k!,;REST ~~.'\lE;d ~. \'~ "..,.(7) ::: 2)131[:" y ~12~!9';l.. " 130'... ~s ALL..__.;____." ':'!.~ i~'0 ;', . I -=:; t.í :). ,.~ n'. (ß) '? ~I,I~·~·~ ,.. "Ji 20(50 II '·"3O-~' .;; S5'" L i I 'j : '.,.', ,0 .~, ~I P' ' ¡ '''' ~:.~! ~ ~~;r\;. '- -'" =~ ~ jª~ i .:d·) .'. -.,. ;.~¡::: ¡~, I .1 ,~·;~~tfi !~ß'· ~¡-~,jo~! ~'t -;-z, ! :; ~... U' ~ ! . Ooj ~ \, '- ~-: J I ;7. j 1 f\J : ! I I ~.:, .., I·;~ ~tW ~. ~l! t -) .~, ;!: ¡ \ ~~ =: ~ S ,-- _-7--;.J ~~; ;. . : ! '., i :~¡I ! ,-'I ~:'.. ,L' j.€! ~.:~ Sf-_I ;f.:¡ \ DSr '{I} ,. ', 99} ¡: ::;¡ 2130: PACKEtt FAILED. _, ..,:.;:' -":,:;: ,~: ;::~.~ :-". :,¡ ~¡ï':;l ~. ( :- ".,-(2) ,\ ~20o!9" ,~~, ~ 2130 pm:~.sTA81L11.EDrJ ~OOPS.l,G or{·'/s" ORIFICE f'LATE·.... .~! ~{'.! :~:: j~ ;:. 'l ~>;:.;.. ~i· :::: ;(2" CRr ric^!. :fLC'" pr:tJVí!n . ESTII!""!ED Flt'JI>a66 fJ£.F/r5.¡ ~~~ !: ~i_ : i 2 ?;-::> , ~:. Ji. ¡.. .: ¡;: CH~œ'!i\T".CRf,PH';~AMP'lE: C.I~- 235,000 f'.PJ.1,Ca ": 95.!.?00; ~r ! :. :~ ~ : .. ¡ ':;.~ :.;::;": ~j ,':1· r ..:: fP14, '.~- 200.-':¡:A,. Ci, .-(00 r:P~.; ~. ;.;. ~...,,! ;f:.! ",:: (3) ~' ~ ··~);!f':· ;-:¡ 2~50:: . t- PRESS. STA¡jlllwr~@ ~IO PSIG em þ'~I: ORIF(èE "LAtE.:! si :: í:>? ":-.J : --' ,---, ':, 1 ~~ (2" CiHTIClil Flcrd PROV1:P. . TEST 1I~~CN::lUSIVE:~ :::: ... ~. ;;- ~~. . j .,) . . .-' . . . . .'. .'. . -. ':. ',' . ,,,; i'$'· ";:..:i '. ",. j ~ r'~OV¡:R ~RESSURE m:.ten STHI opa,nl-:G P,\~T I AllY::,' '£ ¡ Ii :ii" .~. ;. ~ ~~: ~: }¡ I c ¿, ClCiCGED WITH ~~I:tIQSOtIO Dfll\.UNG FlÙtD. :\'¡~lL\ICtJLÐ,i ........ : I r ~, ! l- ~ f ... t ';; -.~, \ . ~) _1.1 . . , :. ,.). '..J I l.oI '..:. ' ;<:,:.. ,i :. ,p.. .j I .*. 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I 7ð.3- 6"8' Z 7t)!J~ Ar'-! 7o.:J ·A)o"'- "l.. 7¿J.3- f)c ~ If) ¡¡ 7'0 :l ~ P,/= / ,/þ'- ¿w-:Z. ""!'!""-" 7.::;>;1- [),l-..J 7¡)!1 - ZJd·· 4- 70;1· 0..-1....' /,,{),j. ZJt'·· I 7~J"l)("}'~ I I)~ :z 7tJ3- lJe' '3 'lA! - tJ (' 0 .¡.. lð.9 - t'c!··.5 ~, ,Pre ,.í7t'uc.r AC'-!lv/;:leJ ((y--¿lC~';Þ'!/) '.~ . / A'/¿.¡o/' //:'''c!, d:....¡-J.Ît"'I·¡r (:'"I'//"//)/'-""."S' C" m'p A ì ~ (i -A,) .5: zt. "v., .!1 ;:VI!!/ Clh1rq....d -lcl .í.l:l 11'.>",1 ....,......... --,''0'''' 8"1 z;jO,J IP ¡ez, n..- t!:' t-r;,"/'/ 11t>(..1) f'" .r. t! 9 ('tII?J·/r. Ym ¡.J-fi:", Þ1 ;(; N e :.r ZI /to .:J ,-10 I? :e, ~r lø l' /é:,,¡....:I 1'I'C)l,;i/Pd ¡ . -Jì '//f ",inli/r~:l '/, , -I; ,P ,..I. /Wlu./ 1)5'1 ')1/.:;),:'1)'<:>1'1/ I Z;r':It~·n.1.,J( (vff)?/~-#" ",¡! If) I1J IN',,;/ &;u .}Í.I'PI'/ ~I ,,'/ ~ <! /ó ¡".o ........,.....,.......H..m....'.....,_.....·.._..,.. ........__.,.t.......,..:.........."¡..,.........'''...,,...,.,. Rt.?¿'...h;';' 4 ;;1'/:.' ..J 9. No..9 .-,,' ,-' "~".."'·,'h~"'"._."'_",,"__' >"~_i' t'o ì?JI,aæ''1{ ,.t:;'Ô;:» .-r;':l¡" M> ;i1.-..d (~'Atl¡..-t. $ ~·t>;;''¡,'C'¡."(;i¡'1 ~vl Ju ....9 (' /,i'>,/).:/1'·" 7ë> I'Î~?) f' "ø 'l~!J r If/ Jl" tI./2..r $'.8. #0 T A"/ ·lj ',f ./ ',I '7 o,~ If" 'j ··"!,O r" i!" J(f- Ki? ,., ç} P"c:/, ¿''(,¡nd. P,;.t\"" ¿'......,tc: ./ ¡ . 1 ~ .~ ,r: ¿:'?l": ~,tt / < e~ ':':~f~,) ,) (~ 0; ~,~ a uJ ;f"'.'j r"-I ¿, . 'pel cr; l".ø>IUY·I"'· H~ 1/ ði.l~Þ" W(fl/ t: ¡:::r'¿¡('" e /7¡;ve ,:Ply !( " ..... "';;:';1 _ 2·}"~ t,~,... ~-j It' J/þr.;'i'" ,.-./1., ,,(" .... ¿lip n/"";J/JJ ¡.... C),,t:. 1;") ... ../ ". . 709 De-S 17 April, 1970 70Q De ~1ove Rig, Equipment & Materials to n~w Location/ Storage Areas Provide Inventories of residual materials, equipment parts and rig components. Such inventories to be basic for determining requirements for future drilling activities. Inventories should reflect location of items. Suggest that Inventories be prepared for following catagories of property: (1) Mud, Cement, Chemicals (2) Equipment replacement Parts (a) C-2S0 Pump fluid End- Power End (b) G.D. 7 1/4"£10" Pump fluid End-Power End (c) Swivel Parts (d) Drawworks Parts (ë) Well Completion Equipment Parts (f) line pipe standard & extra heavy (g) High pressure pipe fittings new & used (h) High pressure valves new & used Prepared by J W Dalton Signed by R. V. Hurphy R V Murphy, Petroleum Engineer . . ~~~ SCHLUMBERGER WELL SERVICES A DIVISION OF SCHLUMaE~GER TECHNOL..OGY CORPORATION 5000 GULF FREEWAY P. O. BOX 2175 HOUSTON, TEXAS 77001 April 17, 1970 PLEASE REPLY TO HOUSTON !.OG COMPUTING CE,.-:¡¡;R 5000 GULF ¡::Rs'£,V/AY fiOUSTON, TEXAS 77023 u. S. Navy Anchorage, Alaska Gentlemen: Enclosed are the computed results of SAL~AND on your well in Point Burrow, Alaska. This computation consists of a computed log and tabular listing. A pamphlet describing the use of these items is included in the back of this booklet. The parameterß used for this analysis are listed on the log heading. Several potentially productive zones are indicated by this analysis. The amount of hydrocarbons in place can be determined from the computed tabular listing. This is done by using the "Total Hydr()carbon Feet" column of the listing and subtrac.ting the numbers at the top and bottom of each zone of interest to get the total hydrocarbon volume per acre. . Of course these results are only interpretations of the enclosed log and have been computed by and measured against a'model. Since this model is based upon many assumptions and since the data input is subject to error in transmission and computation, Schlumberger obviously cannot warrant or guarantee these interpretations. Therefore, they are made, like all other Schlumberger interpretations, subject to the provisions of parà- graph 7 of our current General Terms and Conditions. We believe this information will be beneficial in the evaluation of your well. If further explanation would be helpful, please ask us. Thank you, 1'~~ J. Jones .. EB/ad . . _W,.¡.,&ì(f" 4.I,/"6,'t.I.1 1,..PUI.fleN ,.Ti: ..,I,,.,a QI;I'Í'Jt·!t :" '\i..... ¡' f;.~t 'I>I~I ..,~,y .'¡,I',1 ,'..,. I"" rill II 4 '.'''':11 "'lIil..' '''';'1 ,';t,1 .~1.lt f.ltf 1.ilt.1 "t~¡ ""l ~.. "I'~l&.,".! ,; .' 0. Q ,. . I',;. ft .' If! '..1: f..'¡" ptt aft"" ~I' II.~I, ... .'Ii.... aU;I. I.... " t,f 16. II"M I;;"Q.. .0,. . 4',. .,o0 i4'.. I). t. 481' y 4iUfÂY '·in., Oi"'''' a.60 1$.5· .100 o. ,.. 1.... t ~. .a. I. a. t. .' o. t.. 0" .oe .,0 .'GG o. . a . 10. 16. *' ,.... laa. 11)_ 110'0. ... .tl'; .' ,~ t. I. 0, I., o. .... .'~ .a.. a. .. .aD t. t. .$" '- 0.. c. .'0 .0 .300 0',. o. Q. ,c. .. ... '" '~.." .¡,. ,'"," I. I. ,;. I. ." .0" o. . -. . . I,'t:., ¡ a ;" 4. 6 1 . , 100 It £. I' 14 ti$' If t7 11 ., 8'0 al¡ a.' II .. as 2õ t I I) f¡· ø at' I' 0- , GOt) a a o· I) ... , tt t {) Q I') D .." 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'''''t tete' ...,.. i¡.J..At, 1':.., Jø." \.1t.H ~.lt"'$Ji t I 4 & 0 $" 84-1,1 ¡.¡-e j:1"':J,'" . ,. 'AcW'·U·'j· . ·J'1··';¡¡¡ I\c. ""I ft..c;#;c '.J" ';/ ..t· e "-;Vift1r:· ~..-;: --;:~ :. c:: +.tlY:'.ø:~<-i '-:-;:Jifc_ -s,::< ¡-r E::~,o:~:''::' _ -,' . - " .." . '. ,- - ,,-,,-' ',." . -' . ~ la. ""'1. ì't. 11'+'. titll.' Y f o. f> ::t q. .: .., he^, ..,~ a.. .a'. 1:. t. .. Q,,* Q:. 0:. .(JO· .0$ *' o. t. .'. "- ..;0 (:h. t. ., .iQt) . . (,'$:i · t a , 4 I t 1 . , 10 11 I·,. i' .. 11 1,4 t., 11 i. ao a. a.J i. IA 25 26 & · a 0 0 Q 0 0 ¡ 8 ~ C I 1.1 a a 0 & Q e e 0 GOD 0 'tt.~'ijT ttit6;..I,ea·¡ *~a. a..o. f. itao.~ t#:.'" t'f!Øf. .1'0' , ~. 'i( .« aft: i..I~O -':¡1f.t:'Ícl1f 1~:1 á,¡"".Gf:lffJð-., At~,Ii'....~'c.~ ,,~,,'- --'X,---··' 'oj."--._:,>,_,,- -"""."'- '.- '''' _.~:._ .?': .-_.",-.. __;,l~:tft~~~.. t,~t.,. t~"5 t?t.è;I·;¡;¡'I:f¡t,.. 11','" "*"'''',_&.¡ M I, 'lfll.O· ¡'f'''.'¥'~. Ð!.'iii ;:.:;f ~,.,g"'Iþ t1,:t.a t ~":f.~" . A lo'tiht<"",. .., 1504.0 . PER". ,'....,tt¥ MiiI , .:1 1 i .\1 .4 .0 .0 .0 .0 .0 .0 '''Z a*'i ".' i.t 1:_"' '~J .,.4 7.4 ';ta tt' toJ to£) taD . .t ..; Ita lee 14; ... I' J! II',." ä~.J .1:.48 ;3..11 ~>'I ~"".'''~:-'''' a.10 If;,t. '.iit ~'.'I,.,Q· ..'é.& . P'¡;R~. ,:,;...¡ lV ~Ð .0 ..::i\ t ¡ f . f J a t .t 1 .1 ~œ .4 a:' ...Q s" ~.Q: 1,- '1 , 6.1 ~a.,. J.<, , 100 $;{tf.); fiOS . It a'l tA '. i; · i · · .. f'i 1<·' e ¡., If · " ., t~ .. I. , o at,.,. 21.,Oj .;;(.;j:$ y 3;.l.«!} a.,j,ß ,..i8' t;"QI .'.01 a.04 Ð?-Hiri .__~:.""- C.- Q ?ERM. i'4Ð 1 .1Þ .0 .Q .:, ~I .t .i .1 ..1J ~. ., 2 .0 .0 .¡ .1 .8 .1 .1 i · 3 .a .~ .~ ., , .. ¡ I ì · 6 i · i · i I 2 · .t .0 . .~..A..."".,. -~~.,yt.;:I't~~,~;'.' x tt.a . . 2 ~ 6 ~O P ltftM,. P"iJ'.:lJ,t¥ {!f'i . íti~;fM . . 709 De-4 16 April, 1970 709 De Move Rig, Equipment & Materials to new Location or StÐrage Areas Disposition of Wannigans ~10ve Store On Gràvel Pad adjacent to S.B. No. 7 Mess Hall (Pipe Sled) Head (Timber Skids) Geologist Wannigan (Michler) Store in Pt. Bàrrow Camp Quad Engines on Skid (tarp) C-250 Pump on Skid (Tarp) Howco Wannigan (Pipe Sled) 50/75 KW Generator Wannigan (Pipe Sled) ~fud Tank Wannigan (Pipe Sled) Gardner Denver Pump Wannigan (Pipe Sled) Boiler Wannigan (Pipe Sled) Water Storage Tank Wannigan (Pipe Sled) Shop (Pipe Sled) Change House Wannigan (Ripàler) Tool Pusher's Sleeper (Rubber Tires) Oil Field Whse Wannigan (Pipe Sled) Store on "FAA" Pipe Rocks Residual (from SB Mo. 9) Tubular Goods 4 1/2 Drill Pipe All Drill Collars Kellys 7"-38# Csg 9 5/8" Gag (Over) . 709 De-4 13 3/8" Csg 2 7/8ft TulJing 2 3/8 Tubing 5" Liner Page 2 . ~.._____._.._..._.. ____________ __u .__~_ ________ ___ -~--_.~-_.._._.._.... - - Prepared by J W Dalton Signed by RV Murphy R V Murphy, Petroleum Engineer . . 709 De-3 16 April, 1970 709 De Move Rig & Equipment to New Location or Storage Area Rig Dowb (1) Lay down & prepare for storage all tubular goods (2) Prepare Derrick Section at Rig for storage; (Lay down blocks, store tools, loose equipment, Kelly Drive Bushing, bails, elevators, clamps, Hydril BOP-Shallow Gate and associated. parts in O.F. ~~se Wannigan or in Bldg #61. Take ~part flow' lines; mttd, water, steam, condensate, diesel fuel.) (3) Secure (tarp) Traveling block, connector, drawworks, drawworks engine. (Martin Decker Wt Indicator to Bldg #61) 3 (3) Prepare individual wannigans for .move to storage areas. (4) Break & prepare for storage Mud, water, steam, condensate & fuel lines. (5) Disconnect/Store electric Wiring. (6) Dismantle C-250 Pump House. Prepared by J W Dalton" Signed by Murphy R V Murphy. Petroleum Engineer · .. 709 De-l (Revised) 11 April, 1970 709 De Move Rig to New Location and/or Storage Area A. Clear rig storage area of snow (Site of storage area is a4jacent to prospective S.B. No. 10 Location) B. Do Not Set Conductor Pipe or Install Cellar C. Do Not Set Rat Hole Pipe D. Place minimum gravel embankment: approx. 4' deep x approx. 30' wide x approx. 45' long, shape & compact. E. Set & freeze in 10"x20" timbers on top of embankment (to support rig) per sketch. F. Construct & set ÎlR'augered holes, tour each guy line anchors (per sketch) G. Move rig from S.B. No.9 to this storage site and tie down to guy anchors. (over) Prepared by J W Dalton Signed by R V Murphy R V Murphy, Petroleum Engineer Page 2 709 De -1 NOTE: 0 A Gravel stockpile far Rig Foundation adjacent to prospective S.B. No. 10 location was about 60% completed during interval 13-15 April, 1970. Only other storage area in South Barrow field consists in gravel till remaining from Cardwell Rig storage site occupied during interval 1955-1963, this is adjauent to S. 8. No. 2 Well. Examined this site, 4-16-7n and found it to have practically disappeared, and no guy anchors evident. Therefore, less costly and more convenient to complete gravel pad & store rig adjacent to prospective S. B. No. ln location. HOIMES AND NARVER INCORPORATED EQUIPMENT & HOLE DATA Barrow Sand 29' KB 69' Kelly bushing 2449' 8 5/8" 130' 2199' 2338' 2320' . FLUID SAMPLER DATA Date 4-9-70 Sampler Pressure Recovery: Cu. Ft. Gas cc. Oil cc. Water cc. Mud Tot. Liquid cc. P.S.I.G. at Surface Kind of Job OPEN HOLE Tester MR. BRACK Drilling Contractor Gravity Gas/Oil Ratio ° API @ OF. cu. ft./bbl. Formation Testeci Elevation Net Productive Interval All Depths Measured From Total Depth Main Hole/Casing Size Dril/ Collar length Drill Pipe Lengt , Packer DepthCs) Depth Tester Valve Surface Choke RESISTIVITY CHLORIDE CONTENT Recovery Water _ @ _ of. ppm Recovery Mud _ @ _ of. Recovery Mud Filtrate _ @ _ of. ppm Mud Pit Sample _ @ _ of. Mud Pit Sample Filtrate _ @ _ of. ppm Mud Weight vis cp TYPE AMOUNT Depth Back Cushion water 130 Ft. Pres. Valve Recovered Feet of Reversed out. Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of . ~i~~e~er 308254-C NORTH SLOf'E H?"i?urton ANCHORAGE District Witness R. V. MURPHY SMS J.D. I.D. 2 7/8" 3.826" Bottom Choke 5/8" , MAILED . , APR 24 1970 Hallif'urton Company O~[1C:Ll. Oh:.;::,:;'";¡,~ Remarks Tool opened with a strong blow with gas to the surJace in 2 minutes, flow line froze UP. Tool openen for a 63 minute first £low. CLoseQ for En 89 minute first closed in pressure. Reopened for a 39 minute second flow and 982 Gauge No. 985 Gauge No. 2321 Ft. Depth: 2446 Ft. Depth: Ft. 24 Hour Clock ~lt!our Clack Hour Clock Blanked Off YPP, Blanked Off P ressu res Pressures Pressures Field Office Field Office Field Office 1310 1319 1407 1398 431 801 500 844 528 535 576 581 1009 1006 1023 1026 431 432 478 482 528 536 576 586 1009 1005 1023 1023 took a 67 minute second c10séd in pressure. TEMPERATURE . Gauge No. Depth: Est. of. 2424' Actual 73°F. ~anked Off Initial Hydrostatic Initial t;"& Flow ¡¡;.¡¡ Final "- Closed in Initial Flow Final Closed in Initial 1:"& Flow :¡:.¡: Final I-~ Closed in Final Hydrostatic "" Co 0'- u~ QQ VI"- 1363 1366 1310 1298 PRINTED IN U.s.A. ¡::-npl\lf A TI nl\J TJ:"C:;T n ^ T ^ TIME Tool Opened Tool Closed Reported A.M. 5: 19 fI;:M. I'F.M . 1: 48 P.M. Computed Minutes Minutes ~ ~ 63 63 .. 88 89 > t'"' > 40 39 CI1 67 67 ~ LITTl.E'S 83429 ISM '/8--.,1. 14..Is Ft. Ft. V>,.. .... ~~ ....,.. :EO ~~ , -. S'g <p CI1V1 [%jOQ (")~ I-' 1-'2 , N-Þ- N IV Z.. , IV I-' VI 00 OQ ~ : C:::~ "d Zc. to:<; ~ .p. c . cr. . Ft. 2: ~ 0-< "'''1:1 3 tz:I :; to3 z~ ,") 0 ~ ~ !i ~ ~ ~ ~ Ft. Ft. cr. tr. ~ . Z \C Co ? ~ 2 t:. ~ ~ --c- ~ N >:!!to:<; Z ;;~ P oc.. ~ .. !1 ... o 3 ~ en .... ~ CI1 o ~ ::I: t:d ~ ~ ~ N U, U, OC , -fN .. +:- ~+:- :1.": ! ¡ < o <" .. g c: :3 -< Z ~ ::I: CI1 t'"' o "d [%j c::: . CI1 ,..Z co > ~ ~ o :E :s .. , n o 3 "0 o ~ Z o 3 o " f I I::__L 1..1......:......"'+.....1 ;...."" :"'''NI ton 1nnn no c Casing perfs. Gas gravity Spec. gravity Dote Time a.m. p.m. '~ . ¡ t :., I J II I PRINT~D .... U Co Choke Size . . Bottom chok.. Oil gravity Chlóride" Surf. temp GOP I"pm Res. OF Ticket No. 308254-C @ 'F Surface Pressure psi Gas Rate MCF Liquid Rate BPD Remarks Flow test conducted by J.W. Dalton, Andrew Crane & R.V. Murphy on April 9, 1970 using a 2" critical flow prover set up with a 1/2" orifice plate. Zone tested 2338-2449' OBSERVATIONS TIME (~) PRESSURE (PSIG) TEMP . of ° 1212 410 27 1217 410 25 ,~";. 1222 407 25 1227 407 28 1232 415 30 nnnJ""'\IIr"TIf""\ \'1 Tr-t""'T n^T^ l.ITTLE S 83432 5M C/69-~...... 308254-C Ticket No. 24 hour 9180 Clock No. 2321 Depth 982 I I I Gauge No. Third Closed In Pressure Third Flow Period Second Closed In Pressure Second Flow Period First Closed In Pressure '\ First Flow Period e PSIG Temp. Corr. log t + fJ fJ Time Def .000" PSIG Temp. Corr. Time Defl .000" PSIG Temp. Corr. 536 1. 254 978 .977 991 .823 ~7 .719 999 .642 1001 .583 1002 .534 1003 .494 1003 .460 1004 .430 1005 .400 1005 logt+fJ fJ Time Def .000" 000 0201 0402 0603 0804 1005 1206 1407 1608 1809 20UL 225** PSIG Temp. Corr. 432 538 665 653 649 536 000 0273 0546 0819 1092 13 3 b'd. PSIG Time Def Tc~~· .000" 535 986 998 1001 1003 1004 1005 1006 1006 1006 1006 10~ log t + fJ fJ 946 692 558 471 409 363 326 296 272 251 231 Time Def .000" 000 0265 0530 0795 1060 1325 1590 1855 2120 2385 2650 295* PSIG Temp. Corr. 276 1019 (252 minutes- flow 1 ~ne froze ~p.) 000 I 801 0297\ 483 0594 475 499 499 503 554 535 Time Def .000" 000 841 4 5 6 7 8 0891 9 1188 --.!..2.----!.1485 11 .1782 2 2080 o 1 2 3 4 5 . hour 24 9181 586 993 1010 1016 1019 1020 1021 1022 1023 1023 -- 1023 1023 1. 252 .974 820 .717 .640 .581 .532 .492 .458 429 400 Clock No. 000 0201 0402 0603 .0804 ---" .1005 .1206 .1407 .1608 .1809 .2010 .224** 482 568 691 685 681 586 2446 000 0269 0538 0807 1076 131** Depth 581 946 1002 692 1015 558 1020 471 1022- 409 1023 363 1024 326 1025 296 1025 272:- 1025 251 ]])"26 231 1026 Minutes '4~'3 L.ITTL.'. la411 10M ./,.-,., 6 RE DATA minutes J PRF"~~I 7 = **Last ~PF"C:I A 8 to 9 minutes 8 is equal interval Gauge No. 985 o .000 401 .000 1 .837--¡ 1059 .0265 -:2~252 m~nutes- .0530 3 fÏow l~ne .0795 '4 froze fp.) .1060 5 .000-, 844 .1325 t .0297-s3-Ž- ----:1590 7 .0594 520 .1855 -8--~oä91 5~ .2120 9 .1 i88 593 -:2385 10 .148-5 545 .2650 II .1782 601 . 295,-r 12' -:2Õ80 581 - - 12 14 15 I Readinq Interval REMARKS: I 9 If ,-rLast ¡ ; li-=i~=~¡-++iD-~;-+---::-e=t-~,=tH+-+-='" TICKET NO. -h--t-: \ i ¡ ~= i--¡ --rwlTfT' ,-.-- - +-+++ I ¡-:::I-:- -,....-+- ~ I I \ --~. , ¡ ,¡ , I . , , , j' I \ BT GAUGE NO. I , 1 I I I t ' I I, r --f--tj ; \ \ ¡ I \ I \ i+ï1l1-t\-~-- Jcf;¿ -I Ui Ii f' ill"'" ¡ "1 ¡ ;7 f S j ¡ ¡ i ! ¡ j II, 1\ ¡ ¡. . I " I I I.! ! I I! ¡ i I "", I: I' I ¡ i: '¡' : ¡II' i' '1: I I ¡ 'I I i Ii,· .::; I "t . I 1 : I I I ¡I, l \.1 I II I II \ i ,. I I ! I ! I 1\ 1 if I ,I III I 1 II \~I·-'· .r ~,I; \ \ II II I . I¡ ¡ Ii !: I' Ii III ¡ 1\'1'1'" II i: j i¡' '. , Iii!, i ! ,I \ II i I i Ii' I I 1° i,J . i III I i II I l;"" ,¡II i: I ¡ II ! II Ii Il I II! I : I I I Ii F' I}-! ' I II I ! 'I ¡ .\:. I t I II I ' I ¡ "I ~, ! I ,! I' I I - i \ ! I ' - I \ ! : I , I I I I I I ! I II I '\ I ~I III I I , . ; III II III, 11 '~II i: III, ,I I I I¡II Ii I i III i I I t I ~ r-T i Iii i 'I I I I !¡i ! Ii ,ii!! 1,1, I: I I )\ II!I i, II,! 1,li t: Ii !III Ii -Ii i·1 Ii: ¡¡-1Ii (I I II ;I-,~-i '- II I JiliT~¡ ¡i I ill :' ~ ¡I! ii I ¡¡,I !' ,-+¡hI1¡!: '\'_~II: 1-1--1111 I ¡i.' 'I ¡I, III ~ ¡III ¡' , '~--L___' I If'll I I ,I II II' -'11, ,I:, 1 IE R---+i I I .! I " : I - I ' , ! -i--t ' I ;-- I -;--, . --I- ¡ , I I I i I : I I -+-+-t- I I I !-'-+-+T-- I ,--- ;¡. , ; 't; "'I ---+-t--r--r--t I 1_"- ¡: ¡;! I : i+r - : ! I! !. ! I =U-' I ! [ -- +-----+--t,i~ '1.. '! ~ I ¡ :!.-- I I I '11ï-1--W-.-L.- I.' ¡---rru II ¡1::t_1 I ~l.., -I. - I,. 1,11 1\ \ I I II, -, , I, i I I i ¡:! I-n-~~r-Jtl ¡ I tit ¡-- ¡t~T n=---==~t=l-¡-t=++- It i-Tt-¡-¡ , I I!, I I' ", rl" ; I ¡'" I I " I --n- I '\ I I I 11 - 1 i I ': i: -~--+----~rt-t--~+-r--+-~++mï-+-~-~-¡-¡ ·11 'l 1 ' , - !! ~:!! : i i j-=t-~~: ¡ ¡ ¡'I' ,II III II'-II! ¡-r-¡ t~--- i'l ! I -I ; '- 1l.J±=t:i=-+t-¡ !1 lili,i;11 \1, +: I , II ,1 mli.!. I: I ,~t++--fl i I 9,f/O I I ~?ò I I ç:ro I /Þ~f~ I/ú/' rJ I ' /tJ,c/Ó1 I /06tJ I . . r-vTn^nn ^Tr-n r'¡1 r-C-C- 1 1=" rR^PH .3éJ J:¿sV"- C. INITIAL FINAL o <) o <) I ¡ 1 I I i I I I I 'J I! ¡ ¡ I i (?) . Gas Production . 982 985 Ticket Number 308254-C PRESSURE PRESSURE 1319 1398 Elevation 29 ft. 1298 1366 1 st Flow MCF Initial Time 801 844 Production . 2nd Flow 2502* MCi' 63 Rote Final 535 581 3rd Flow MCF Closed In Pressure 89 1006 1026 Hole Size 8.625 In. Initial 39ime 432 482 Footage Tested 69 ft. Final 536 586 Mud Weight 11.1 Ibs./gol. Closed In Pressure 67 1005 1023 Gas Viscosity 0.014 CP Initial Time Gas Gravity 0.6 Final Gas Compressibility 0.845 Closed In Pressure Temperature 73 'F 1st 1012 1031 2nd 1013 1032 3rd 1st 992 1011 2nd 994 1014 3rd No calculations attempted for the first flow period since no flow rate was established. Calculations based on the reported surface pressures and 1/2 inch orifice plate. *The flow rate used may be high since the charts indicate that the flow pressure has not stabilized during the second flow period. SUMMARY Transmissability Theoretical Flow Capacity Average Effective Permeability Indicated Flow Capacity Damage Ratio Indicated Flow Rote Theoretical Potential Rote Approx. Radius of Investigation Potentiometric Surface ::: NOTICE: Kh µ EQUATION 1637 Q. ZT m B.T. Gouge No. Depth FIRST 982 2321' SECOND THIRD UNITS B.T. Gauge No. 985 Depth 2446' FIRST SECOND THIRD 54119 50089 md. ft. cp Kh µ Kh h Kh hi 3200 Q. µ. ZT log(0.472 b/rw> (Kh>. = Ps2 _ Pp2 Kh - K - Kl µ 701. 2 md.ft. 757.7 md. md. 10.98 10.16 115. 6 116.5 6.55 6.02 3480 3693 2951 3040 22815 22226 19344 18295 MCFD md. ft. DR = Thea. Flow Cop Kh Indicated Flow Cap (Kh>. OFl = Q. Ps2 Max. Ps2 - Pp2 OF2 = Q. P. Min. Ý Ps2 - Pp2 OF3= OFt DR Max. OF4 = 'OF2 DR Min. MCFD MCFD MCFD b ::::: y Kt or y Kto bl ::::: yKl t or yKt to 33. 32.6 Pot. = (EI - GD) + (2.319 Ps) 53 -24 ft. ft. ft. These calculations ore based upon information furnished by you and taken from Drill Stem Test pressure charts, and are furnished yau for your information. In furnishing such calculatIons and evaluations based thereon, Halliburton is merely expressing its opinion. You agree that Halliburton makes no warranty express or implied as to the accuracy of such calculations or opinions, and that Halliburton shall not be liable for any loss or damage, whether due to negligence or otherwise, in connection with such calculations and opinions. PRIf'ltT£O IN U.S.A. II'ITr-nnr-H'~T^Tln \'lC- ^ "In r^1 rill ^Tln \.lC; L.ITTLE'S 83"'" 15M 1/I9--U.g .....---... 11 - II ~ ª e '10! ' .! ¡. ~ ;¡ i. " j ~ ¡II: ]1 ~ t: f - ~ 'I I: ~¡ , ~ . . ~ ~. . ... ..... rr: 1 J! ~ ~ Tt lj ;¡ E ~ -~ ~ Ii .µ tl ...... II ,I ( I· ~ tUJJ ~!·I.· ! ! ( . Reversing Sub. . . . . . . . . . . . . . . Water Cushian Valve ........... Drill Pipe Drill Collars ...................... . ......... ............. Handling Sub & Choke Assembly .... Dual CIP Valve ................... Dual CIP Sampler. . . . . . . . . . . . . . . . . . Hydro-Spring Tester ................. Multiple CIP Sampler . . . . . . . . . . . . . . . Extension Joint . . . . . . . . . . . . . . . . . . . . AP Running Case . . . . . . . . . . . . . . Hydraulic Jar . . . . . . . . . . . . . . . . VR Safety Joint ................... Pressure Equalizing Crossover ... . . . . . . Packer Assembly . . . . . . . . . . . . . . . . . . . Distributor. . . . . . . . . . . . . . . . .. . . . . . . Packer Assembly . . . . . . . . . . . . . . . . . . . Flush Joint Anchar ................. Pressure Equalizing Tube ............ Blanked-Off B.T. Running Case ....... Drill COIläi'f= .Pipe. . . . . . . . .. . . . . . . . Anchor Pipe Safety Joint ............ Packer Assembly . . . . . . . . . . . . . . . . . . . Packer Assembly . . . . . . . . . . . . . . . . . . . Anchor Pipe Safety Joint Side Wall Anchor . . . . . . . . . . . . . . . . . . Drill Collars ...................... Flush Joint Anchor . . . . . . . . . . . . . . . . . Blanked-Off B.T. Running Case ....... . 30S254-C 0.0. 1.0. LENGTH DEPTH 5 3/4" 2 3/4" 1.00' 4Js" 3.826" 2199' 6 1/4" 2 7/S" 130' 3 7 / 8" 7.90' 3 7/8" 5/S" 5.U' 2320' 3 7/S" 3' 4.37' 2321' 3 7/S" 5.158 7 1/4" 6.428 233S8 '.' 5" IJs" 3S8 4~" 64.63' 3.826" 5" 1~n losS' 5" 3~" 1. 528 5" 2" 4.06' 2446' Of4 = Theoretical Open Flow Potential with/Damage Removed Min. . . . . P s = Extrapolated Static Pressure . . . . . . . . . . . . . . . . . . . . . Psig. P F = Final Flow Pressure . . . . . .. ............. Psig. POI = Potentiometric Surface (Fresh Water') ..................... Feet Q - Average Adiusted Production Rate During Test . . . . . . . . . . . . . . . . bbls/doy . FLUID SAMPLER DATA Date 4-9-70 Sampler Pressure Recovery: Cu. Ft. Gas cc. Oil cc. Water cc. Mud Tot. Liquid cc. P.S.LG. at Surface OPEN HOLE Kind of Jab Tester MR. BRACK HOIMES AND NARVER INCORPORATED SM S Drilling Contractor . ~i~~e~er 308254-C NORTH SLOPE H?lIi~urton ANCHORAGE District Witness R. V. MURPHY Gravity GaslOil Ratio ° API @ OF. cu. ft./bbL Formation Tested Elevatior. Net Productive Interval All Depths Measured From Total Deptr. Main Hole/Casing Sizf' Drill Collar length Drill Pipe length Packer Depth(s) Depth Tester Valve EQUIPMENT & HOLE DATA Barrow Sand 29' KB 69' Ke lly bushing 2449' 8 5/8" 130' 2199' 2338' 2320' RESISTIVITY CHLORIDE CONTENT Recovery Water _ @ _ of. Recovery Mud _ @ _ of. Recovery Mud Filtrate _ @ _ of. Mud Pit Sample _ @ _ of. Mud Pit Sample Filtrate _ @ _ of. Mud Weight vis TYPE AMOUNT Cushion water 130 ppm r>pm ppm cp Depth Back Ft. Pres. Valve Surface Choke Recovered Feet of Reversed out. Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of ,~ LD. LD. 2 7/8" 3.826" Bottom Choke 5/8" .. ~ & ~ " o 3 _i ~ MAILED APR 24 1910 Halliburton Ccm¡nny OL,ICJ:l. o:,:.~~~~·:': Remarks Tool opened with a strong blow with gas to the surface in 2 minutes, flow line froze up. Tool opene~ for a 63 minute first flow. Closed for an 89 minute first closed in pressure. Reopened for a 39 minute second flow and 982 Gauge No. 985 Gauge No. 2321 Ft. Depth: 2446 Ft. Depth: Ft. 24 Hour Clock 2l,Hour Clock Hour Clock Blanked Off YP~ Blanked Off Pressures Pressures Pressures Field Office Field Office Field Office 1310 1319 1407 1398 431 801 500 844 528 535 576 581 1009 1006 1023 1026 431 432 478 482 528 536 576 586 1009 1005 1023 1023 took a 67 minute second c10séd in pressure. TEMPERATURE Gauge No. Depth: Est. of. 2424' Actual 73 OF. Blanked Off Initial Hydrostatic Initial t;] Flow ~'t Final 0.. Closed in Initial Flow Final Closed in "" Initial ~ 0 Flow ¿.¡: Final ....æ Closed in Final Hydrostatic "" Co 0,- u~ ",'" ",0.. 1310 1298 1363 1366 PRINTED IN U.S.A. ~(""\PI\) ^TJ(ìf\.1 TJ:"~T Iì^T^ TIME Tool Opened Tool Closed Reported A.M. 5 : 19 P<M. ParA. 1:48 P.M. Computed Minutes Minutes ~ So 63 63 & 88 89 ~ 40 39 tI) 67 67 ~ LITTLE'S 83429 ,SM ./_'-31. 14-1' ,.-_...... Ft. Ft. "'r- C "& 0~ . . - CI'. -ir- . :EO un 2: . 0 I:!: :Þ ;gO ,," <: '? t< tI) VI :;">C t:t:I 00 o t1'J (') 00 ¡; 1-3 Z:;t ...... () 0 ......2 3 &; I CO NÞ !i N N Zv ~ I N ...... \.II t1'J 00 00 ~ :<: : :;t c:: :e: ;3 I'd ZO ""= ~ ~ CI'. ~ . t:E: . Z ..c C": p 0 \:it 2 t:E: \:it -I ~ æ N ... >:!!""= Z 'co P &- 00. tI) ~ ::I: t;¡: N ~ U; U; OC ~ , -iN æ ~ ...+:- a.'" 5" ... CO ¡ Ft. Ft. Ft. < o <" & 9 c ~ Z ~ ~ tI) ~ ~ I:X1 c:: . tI) r-Z CO > ~ ~ o :IE " co ~ n o 3 "tI o " -< Z o 3 co 1 \ w !:II:: :J c.n c.n w 0:: ~ TIME: ~ . s:"t'h Horizontal line Eaual to 1000 D.S.I. Casing perfs. Gas gravity Spec. gravity Date Time a.m. p.m. ~RINTEO IN U.S.A. Choke Size . . _ Bottom choke Oil gravity Chloridec; Surf. temp GO!? I'pm Res. OF Ticket No 308254-C @ OF Surface Pressure psi Gas Rate MCF Remarks Liquid Rate BPD Flow test conducted by J.W. Dalton, Andrew Crane & R.V. Murphy on April 9, 1970 using a 2" critical flow prover set up with a 1/2" orifice plate. Zone tested 2338-2449' OBSERVATIONS TIME (~) PRESSURE (PSIG) TEMP . of. 1212 410 27 1217 410 25 '. 1222 407 25 1227 407 28 1232 415 30 Ï'lÏ'I,....~llrTI".....1 Tr-t"""T nJ\T^ LITTLE S ,'432,M ../69-4!;.U... 308254-C Ticket No. 24 hour 9180 Clock No. 2321 Depth 982 Gauge No. Third Closed In Pressure Third Flow Period Second Closed In Pressure PSIG Temp. Corr. Log t + 8 8 Time ßef .000" PSIG Temp. Corr. Time Def .000" PSIG Temp. Corr. 536 Logt+8 8 Time Def .000" e 978 991 997 999 1001 1002 1003 1003 1004 1005 1005 1.254 .977 .823 .719 .642 .583 .534 .494 .460 .430 .400 000 0201 0402 0603 0804 1005 1206 1407 1608 1809 2010 225** PSIG Temp. Corr. 432 538 665 653 649 536 Second Flow Period First Closed In Pressure First Flow Period Time Def .000" PSIG Temp. Corr. 535 986 Logt+8 8 Time Def .000" PSIG Temp. Corr. 276 1019 Time Def .000" 000 0273 0546 0819 1092 1331** 998 1001 1003 1004 1005 1006 1006 1006 1006 10~ 946 692 558 471 409 363 326 296 272 251 231 000 0265 0530 0795 1060 1325 1590 1855 2120 2385 2650 295?'< mLnutes- 1Ii. n e up.) 801 483 475 499 499 503 554 535 froze 000 022L 0594 0891 1188 1485 1782 2080 000 841 (252 flow o I ') 3 4 5 {, 7 8 9 o 2 4 5 . Minutes 14..'3 LITTLS·. ...a. 10M ./....-,.. hour 24 1010 1016 1019 1020 1021 1022 1023 102L 1023 1023 SPECIAL PRESSURE DATA 586 993 9181 1. 252 .974 .820 717 640 581 532 492 458 429 400 6 minutes Clock No. .000 .0201 .0402 .0603 .0804 .1005 .1206 .1407 .1608 .1809 .2010 ~4** 7 = 482 568 691 685 681 586 **Last 2446 000 0269 0538 0807 1076 131** 8 minutes Depth 581 1002 1015 1020 1022 1023 1024 1025 1025 1025 1026 1026 8 interval is equal to 9 946 692 558 471 409 363 326 296 '1.'7"2" 251 231 985 000 0265 0530 0795 1060 1325 1590 1855 2120 .2385 .2650 .295* 9 ,I *Last I I I Gauge No. G .000 I 401 1---:837--¡ 1059 -:2~252 mtnutes- 3--IIow 1tne 4 froze µp.) 5 .000 I 844 t .0297 I 532 7 .0594 520 8 .0891 I 537 9 .1188 I 593 10 . 148-5 545 11 .1782 I 601 12- .2080 I 581 :~ I 15 I ReodinQ Interval REMARKS: "RINTED IN U...A. I I - I i ) , '::::. , '. ! I , II I I' I \ I I , i I I I -I I -I I II I I . I I I i I I I ¡ ¡ I , I I I i I I I I I I I I I ! I I I : I I ¡ I' I I I! I ! , : I I ï I I , II I 'I ! II ¡ I ¡ ¡ , ! ¡ !Ii19f1I ; I I I , , I II I! I ¡ I I I, , I II , , , I rt~--..-.-~, ¡'" I ¡ I ¡ ¡ I II -- : ! I Ijl~i L I¡:I 11 ¡~._~~ Ii. 1..-:1 :¡,II~ I I, .\ ,I ! I r-~-~~-~ lill~¡-' n', 11--1 i I j V~ ¡ 'I·' I \ I I II i, ,I I I \! I I Ii f I \! I I' I I I t -::l i -¡ Ii II I , ! ¡ Iii III! 1111 I ~fO . I I 4 r II,: : I , 'I t, i I I ¡ II' I , I ! 1 I I ,I , ! I I I I ! ! I I I' I i i ~ ¡ II ~,\I ' I! \" 1 I I I I I \c;l I ! I I I , I I ~ I ! 'Ii \~ I III ~ ,f" I III ì ~ t¡ t ~ i! I~' ~: Ii, ¡ I , , i ' \ . ¡ II ! I II ¡ I I~\·. ~, ! II I ¡ I ì 1 ! ! ! il, IIII , ~ i I I : j i i: i i ~-L ¡ I! I i'l ,11'11, ,t.. i ~- II: ¡ 'I III, I I ì I II -¡ ¡ I II I I II ¡ III , I I I ! ! I,:! ¡ I : I! I I 1 , I I \ II! I \ ¡ ~ - i I, I ¡ ii' III II . \ II 'I' I \ I ¡ I I II I,! .' I IlJJ I I : I I: I ¡ I \ --I' ¡ I I 11\ .--1-! I ¡ I! t I I I, I, 1'\+++1' I I! ' ¡,I; ¡ill II I\iiti II' III i 'ji: 'I 11,1, r\-tttt I 1\' II" , II ¡ II \'TTT #' :' i' I -t"¡; II ! ¡ ¡ ¡1rl,- , II : ' :" I , LLLL I' I I ¡III ~_. il I ,-TTTT ,II, . ¡ ¡ 1.1 ¡ 1 .11 ¡ _ II ! I, i 11 ¡ II ! ¡ Ii l i mrTl i /(ls1J' I Iv,,? rJ I /t';/ó I /ð&tJ I I I . TICKET NO. 3CcÝ2~C I I , I I I I ! I i I II I I I I , , I I I ¡ , I II I' II ' , I I ! . I I ' I I I I BT GAUGE NO. INITIAL FINAL . , i I I ! 11 i i I , i I : I 9~ô I Jð'Z ~j'.5 o <) (0 <) I! ~ I, ¡ 'TT! :1 \I ., I i ¡ I i ' II , I}. 1\,..1 ~ ( I ! I I I ¡ I I, I I Q r-VTn^n~1 ^Tr-n nnr-l'""""l'"""" nr- rnj\nl I f0 . Gas Production . ~. T. Gouge Numbers 982 985 Ticket Number 308254-C PRESSURE PRESSURE Initial Hydrostatic 1319 1398 Elevation 29 ft. Finol Hydrostatic 1298 1366 1 st Flow MCF Initial Time 801 844 Production . 2nd Flow 2502* MCF 63 535 581 Rote 1 st Flow Final 3rd Flow MCF Closed In Pressure 89 1006 1026 Hole Size 8.625 inw Initial 39ime 432 482 Footage Tested 69 ft. 2nd Flow Final 536 586 Mud Weight 11.1 Ibs'¡gal. Closed In Pressure 67 1005 1023 Gas Viscosity 0.014 CP Initial Time Gas Gravity 0.6 3rd Flow Final Gas Compressibility 0.845 Closed In Pressure Temperature 73 'F 1st 1012 1031 Extrapolated 2nd 1013 1032 Static Pressure 3rd 1st 992 1011 Slope P /1 0 2nd 994 1014 3rd Remarks: No calculations attempted for the first flow period since no flow rate was established. PRODUCT Transmissobility Theoretical Flow Capacity Average Effective Permeability Indicated Flow Capacity Damage Ratio Indicated Flow Rote Theoretical ,:Potential Rate ;Ji cC} ~Approx. Radius ~ of :llnvestigation ~ .... Potentiometric ~Surfoce ::; '; ¡ .\ J NOTICE: I...... ,. ." Calculations based on the reported surface pressures and 1/2 inch orifice plate. *The flow rate used may be high since the charts indicate that the flow pressure has not stabilized during the second flow period. SUMMARY B.T. Gouge No. Depth FIRST 982 2321' SECOND B.T. Gouge No. 985 Depth 2446 ' FIRST SECOND THIRD UNITS md. ft. cp Kh µ. EQUATION 1637 Q. ZT m 54119 50089 THIRD - Kh Kh µ. ll- K Kh h Kl Kh """h." 757.7 701. 2 md. ft. md. md. 10.98 10.16 115.6 116.5 6.55 6.02 3480 3693 2951 3040 22815 22226 19344 18295 MCFD 3200 Q. µ. ZT Log(0.472 b/rw) (Kh). = P.2 _ Pp2 DR - Theo. Flow Cop Kh - Indicated Flow Cap (Kh). md. ft. OFl = Q. p.2 Max. P.2 _ Pp2 OF2 = Q. P. Min. V P.2 - Pp2 OFs = OFl DR Max. OF4 = 'OF2 DR Min. MCFD MCFD MCFD b :::: V Kt or V Kto bl :::: V Kl t or V Kl to ft. 33. 32.6 ft. Pot. = <EI - CD) + (2.319 Ps) 53 -24 ft. These ca.lculations ore based upon information furnished by you and token from Drill Stem Test pressure charts, and ore furnished you for your Information. In furnishing such calculations and evaluations based thereon, Halliburton is merely expressing its opinion. You agree that Halliburton ;jOkes no warranty express or implied as to the accuracy of such calculations or opinions, and that Halliburton sholl not be "able for any loss or amage, whether due to negligence or otherwise, in connection with such calculations and opinions. 1 \ITt::'nnnr-TJ\TI(",,) \'Ir- ^ I\.ln rJ\ I rill ^TI(ì \I~ I.ITTI.E"S 8341. 1M 3/~' ~ ~ ~ ~ "Ie,!' :4 Ii !: t Î ¡ ! l"- I IT ~ 'I O!. I ~ ;- í ! . r- .,. ~'; .: §. 4-:4: '11.110 ~ n Il ¡¡;J ~ TT ]j :1 Ii ~ ~ Ç;=J rn ~ ~ . Reversing Sub . . . . . . . . . . . . . . . . . . . . Water Cushion Valve ....,........ Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CIP Valve ................... Duol CIP Sampler . . . . . . . . . . . . . . . . . . Hydro-Spring Tester ................ Multiple CIP Sampler . . . . . . . . . . . . . . . Extension Joint . . . . . . . . . . . . . . . . . . . . AP Running Case . . . . . . . . . . . . . . . . . . Hydraulic Jar . . . . . . . . . . . . . . . . . . . . . VR Safety Joint ................... Pressure Equalizing Crossover ......... Packer Assembly . . . . . . . . .. . . . . . . . . . . Distributor ....................... . Packer Assembly . . . . . . . . . . . . . . . . . . . Flush Joint Anchor ................. Pressure Equalizing Tube ............ Blanked-Off B.T. Running Case ....... Drill œlfäTf' .Pipe. . . . . . . . . . . . . . . . . Anchor Pipe Safety Joint ............ Packer Assembly . . . . . . . . . . . . . . . . . . . Ii n I, Packer Assembly . . . . . . . . . . . . . . . . . . . - 4 iV, Anchor Pipe Safety Joint ..... ;, I ~ -- Side Wall Anchor . . . . . . . . . . . . . . . . . . Drill Collars ..................... . Flush Joint Anchor ................. Blonked-Off B.T. Running Case . O.D. 5 3/4" I.D. 2 3/4" 4~" 6 1/4" 3.826" 2 7/8" 3 7/8" 3 7/8" 5/8" 3 7/8" 3' 3 7/8" 7 1/4" 5" l~" 4~" 3.826" 5" v~" 5" 3%" 5" 2" 308254-C LENGTH 1.00' DEPTH 2199 ' 130' 7.90' 5.11' 2320' 4.37' 2321' 5. 15 ' 6.42' 2338' '::' 38' 64.63' 1.58' 1. 52 ' 4.06' 2446' OF3 = Theoretical Open Flow Potential wit OF4 = Theoretical Open Flow Potential with/Damage Removed Min. . . . . MCFjD P s = Extrapolated Static Pressure . . . . . . . . . . . . . . . . . . . . . Psig. n_~_ . FLUID SAMPLER DATA Pressure Cu. Ft. Gas cc. Oil cc. Water cc. Mud Tot. Liquid cc. Gravity Gas/Oil Ratio P.S.LG. at Surface ° API @ OF. cu. ft./bbl. Date 4-9-70 RESISTIVITY CHLORIDE CONTENT Kind of Job OPEN HOLE Tester MR. BRACK Drilling Contractor Formation Tester! Elevation Net Productive Interval All Depths Measured From Total Depth Main HolelCasing Sizp Drill Collar lengt ' Drill Pipe length Packer DepthCs) Depth Tester Valve Recovery Water _ @ _ of. ppm Recovery Mud _ @ _ of. Recovery Mud Filtrate _ @ _ OF. ppm Mud Pit Sample _ @ _ of. Mud Pit Sample Filtrate _ @ _ of. ppm Mud Weight vis cp TYPE AMOUNT Depth Back Cushion water 130 Ft. Pres. Valve Recovered Feet of Reversed out. Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Surface Choke . Ticket 308254-C Number NORTH SLOP!!: H?"i~urton ANŒORAGE District Witness R. V. MURPHY SM S 2 7/8" 3.826" Bottom Choke 5/8" APR 24 1910 Hallihurton Company O~.;lCJ.l. Ci::J~:~;::: MAILED ., HaIMES AND NARVER INCORPORATED EQUIPMENT & HOLE DATA Barrow Sand 29' KB 69' Kelly bushing 2449' 8 5/8" 130' LD. 2199' . LD. 2338' 2320' took a 67 minute second closed in pressure. , Gauge No. Depth: Blanked Off Pressures Pressures Pressures Field Office Field Office Field Office 1310 1319 1407 1398 431 801 500 844 528 535 576 581 1009 1006 1023 1026 431 432 478 482 528 536 576 586 1009 1005 1023 1023 1310 1298 1363 Remarks Tool opened with a strong blow with gas to the surface in 2 minutes. flow line froze up. Tool opene~ for a 63 minute first flow. Closed for En 89 minute first closed in pressure. Reopened for a 39 minute second flow and TEMPERATURE Est. OF. 2424' Actual 73 OF. Initial Hydrostatic Initial t; -g Flow ¡¡;.~ Final ~ Closed in Initial Flow Final Closed in -.:;"0 Initial ~ 0 Flow :<;.¡: Final I-~ Closed in Final Hydrostatic ""0 Co s·¡: Q Q "'~ 982 Gauge No. 985 Gauge No. 2321 Ft. Depth: 244ñ Ft. Depth: Ft. 24 Hour Clock 2410ur Clock Hour Clock Blanked Off yP~ Blonked Off 1366 TIME Tool Opened Tool Closed Reported A.M. 5: 19 P:M. PF./rA. 1:48 P.M. Computed Minutes Minutes '" ã 63 63 CD 88 89 ~ 40 39 CJ) 67 67 ~ V\r- "" "'" ., 2- -ir- ~o "0" '. ª :;a 0 :>:> 'P c . CI . !:< :x: < .... Ft. Ft. CJ)IJI trJoo (')~ I-' 1-'2 I N~ N N z.. IN I-' \.JI 0000 ~ :: c=:e:: "tI ZO "'= r- ., ~ t> :; ~ z ~ o C ~ & c ;:! Ft. :x t> tI ~ ~ < t> Ft. Ft. :;j + cr. ~ ~ . z" ? C": C :;t 2 t>: :;t ---,::, >:!!"'= l;!!.. OD. -f CD !!'o " Z· ? ~ CD ? ." o 3 ~ .. .. ~ CJ) § ::r: < b; ~ ~ ~ " u u o I -f" co + .. + ¡~ ! l g c ~ < Z ~ CJ) tot ~ tz1 c: . cr. . 2 1;"> o < :; !'< o· ~ :> CD , g 3 ~ ~ Z o 3 co Casing perfs. Gas gravity Spec. gravity Dote Time a.m. p.m. ~"'TED'... U.S.A. Choke Size . . Bottom choke Oil gravity Chloride~ 308254-C Surf. temp GOR I'pm Res. OF Ticket No . @ of Surface Gas Pressure Rate psi MCF Liquid Rate BPD Remarks Flow test conducted by J.W. Dalton, Andrew Crane & R.V. Murphy on April 9, 1970 using a 2" critical flow prover set up with a 1/2" orifice plate. Zone tested 2338-2449' OBSERVATIONS TIME (~) PRESSURE (PSIG) TEMP . of. 1212 410 27 1217 410 25 1222 . 407 25 1227 407 28 1232 415 30 ppnl1llrTln \. TF~T I1^T^ LITTLE S 81432 5M "/6~-.n,,:..l ,. Gauge No. First Flow Period Time Detl. PSIG .000" Temp. Corr. o .000 276 1 .841 1019 2 (252 minutes- 3 flow line 4 froze up.) 5 .000 801 6 .02971 483 7 .0594 475 8 .0891 499 9 .1188 499 10 .1485 503 II .1782 554 12 .2080 535 I:: . 14 15 982 I Time Detl. Log t + /J .000" 0 First Closed In Pressure .000 .0265 .0530 .0795 .1060 .1325 .1590 .1855 .2120 .2385 .2650 .295* Gauge No. 985 I o .000 I 401 'I .000 1 .837-1 1059 .0265 2- (252 m~nutes- J .0530 I 3 flow l~ne 1.0795 4 froze tp.) '.1060 5 .000 844 .1325 t.. .0297 532 .1590 7 .0594 520 .1855 8 .0891 537 .2120 9 .1188 593 .2385 . 10 .1485 545 .2650 11.1782 601 .295* 12 .2080 581 .946 .692 .558 .471 .409 .363 .326 .296 .272 .251 .231 .946 .692 .558 .471 .409 .363 .326 .296 . 2-n:- .251 .231 I Depth PSIG Temp. Corr. 535 986 998 1001 1003 1004 1005 1006 1006 1006 1006 1~ Depth 581 1002 1015 1020 1022 1023 1024 1025 1025 1025 1026 1026 2321 ' Second Flow Period Time Detl. PSIG .000" T¿'6':r .000 .0273 .0546 .0819 .1092 .1331*'* 2446 ' .000 .0269 .0538 .0807 .1076 .131** 432 538 665 653 649 536 482 568 691 685 681 586 Clock No. 9180 Second Closed In Pressure Time Detl. Log t + /J .000" /J .000 .0201 .0402 .0603 .0804 . 1005 .1206 .1407 .1608 .1809 .2010 .225** Clock No. .000 .0201 .0402 .0603 .0804 .1005 . 1206 .1407 .1608 .1809 .2010 ~4** 1. 254 .977 .823 .719 .642 .583 .534 .494 .460 .430 .400 1. 252 .974 .820 .717 .640 .581 .532 .492 .458 .429 .400 1 ~ 14 15 Reodinq Interval 9 ! 8 8 6 REMARKS: *Last interval is equal to 9 minutes. **Last = 7 minutes. PRINTED IN U.a.A. PSIG Temp. Corr. 536 978 991 997 999 1001 1002 1003 1003 1004 1005 1005 9181 586 993 1010 1016 1019 1020 -- 1021 1022 1023 -1Q.7-L 1023 1023 SPECIAL PRESSURE DATA \ Ticket 24 hour No. Third Flow Period Time Detl. ieS~~. .000" Corr. 24 hour .308254-C Third Closed In Pressure Time Detl; Log t + 8 .000" 8 PSIG Temp. Corr. . e Minutes LITTLB'. .'.28 10M ./..-,., '4.!3 ~ 0'\, ~ +q:, ... 01 o -.J \~ t\ J ~ I I I . I . I, I I ! I , ! I ¡ : ¡ I II , t'~~+1 I II' I ¡ I i I 19/01 " ~ - L ~ ' I·.'''~''D ,. . . I ¡ j ¡ ¡ I ¡I TICKET NO. 3é)ð.2~ C. ,t · ¡ I II i 1 BT GAUGE NO. INITIAL II I I ;,; I FINAL I . j.....--- \ 0 I 'I ¡ n. ~fZ 0 I, , ()~ I.., <) 0 ~ð'S- I i' I I i\ I ' I oJ, t ~ 'Sì I \/ \ . \ , \ \ --: ,}. "' .', '\ ' , l~ \ )1 I \ I i k¡ I '0 I -.; I I I "':;1 ¡, ,D.. I \~ ¡ .' :) t r .. ') , I t I ¡ I' I, I I ! ¡ ¡ I I 'i ' I! ¡; 1/ ! I i I I . ~ II. ! I , j ¡ ¡ I I I' . I f' 11 I! ~ I II I ¡ I ¡ i I ! ii, ¡ ! I I I ¡ I : /i ¡ ¡ ¡ ,If ¡ I I ~ Ii' !! 'I; I II. ¡' j; I G I I , I ! J I ~ [. ! : I ,¡ I ¡ I' I - ~I II' J I I ~. '. I I I ¡ 'I'¡,; I :! I I \ \' I, II : I 'i /1, ; í î I I: II ¡ I I ¡ I ¡ ¡ : ¡ I t . ~_--I-~~I I I : I ¡ i ! I t ¡ : i II ~ ! , ¡ I .. 'I r I' f III1 ¡I' I ¡ 'ì ; ¡ I , ::! " , I" : I I ! ' I I '-4,1 I ! I : I; ': , ! ,i ¡ , II" ill ¡ .- ~-¿~! JI ¡ í- I I f:TJrt¡ ¡; " ~., I I n-, . Tt- ,-r-r-¡¡ I ' I'! , , : ! i-': I Iii I' -; \ !¡ II; " I ! i: !: IT-T :' t} I I ' ¡ I r I 1fT, ~ I ¡ - æ' I ' I . ¡ +¡---i--!-+-t-- : ¡ I! i. I III " i I , : . :tHf~ t::t;' 11+' 1--- ittt- I !:- I I I ¡ I Ii! I µl , ~--'1 -+- , ~-t--; +--~t---i ,I ¡ R I I I I ' , " I I,,' J I 'I I , I I I' i I ,-;It t I I', f : t I I ~, : - itm-r+ '-~.. -f.----trrt-~~·- : ,¡ I I ' " I I I -r-r---., I 7-++'- -,' i I I --H ,-+-t-H+ , , I 1'--11-' , 'I" II 1,1, I ¡ \~ Ti----¡-T' 1---t---~--r-H--j-rTt--·..¡ I; I 'I ' ';+11 - t-t·I-- I .-¡- "---H---- -Hî +--r' +1- --++++ ,- Ii !I:: I \ 'f' I :,11 I Wi ,!II II" tl: r i j! " 1'ï1' i 1 ¡ I î',--\ir-+r+·=-=t=t=l¡ 11- '- -~~Ll£E~ft~J-1+lb+C: ¡Ii I I I I ¡; r ¡1 I . --rfl1=H-1='-t+H-+H-,-·-~. , I -p- 1 I 9bÒ I I ;:?:fO /Ps1Jj I/CÎ/ 0 I ~ /t',0> I I /C/"c? I EXTRAPOLATED PRESSURE GRAPH I I , I I ¡ I , , , , ¡;:.' G-~- "--'..... . Gas Production . 982 985 Ticket Number 308254-C PRESSURE PRESSURE ¡ol Hydrostatic 1319 1398 Elevation 29 ft. Fi¿al Hydrostatic 1298 1366 1 st Flow MCF Initial Time 801 844 Production 2502* Rate 2nd Flow MCF Final 63 535 581 3rd Flow MCF 1st Flow 89 1006 1026 8.625 Closed In Pressure Hole Size in. Initial 39ime 432 482 Footage Tested 69 ft. 2nd Flow Final 536 586 Mud Weight 11.1 Ibs./ go J. Closed In Pressure 67 1005 1023 Gas Viscosity 0.014 CD Initial Time Gas Gravity 0.6 3rd Flow Final Gas Compressibility 0.845 Clôsed In Pressure Temperature 73 'F 1st 1012 1031 Extrapolated 2nd 1013 1032 Static Pressure 3rd 1st 992 1011 Slope PI1 0 2nd 994 1014 3rd Remarks: No calculations attempted for the first flow period since no flow rate was established. Approx. Radius b :=: v' Kt or v' Kto of Investigation b '-. v' K v' K t 1 '-. ~ or ~ Potentiometric Pot. = <EI - CD) + (2.319 Ps) Surface ~:: PRODUCT Transmissability Theoretical Flow Capacity Average Effective Permeability Indicated Flow Capacity Damage Ratio Indicated Flow Rate Theoretical Potential Rate NOTICE: IN U.S.A. Calculations based on the reported surface pressures and 1/2 inch orifice plate. *The flow rate used may be high since the charts indicate that the flow pressure has not stabi1izèd during the second flow period. SUMMARY B.T. Gauge No. Depth FIRST 982 2321' SECOND UNITS B.T. Gauge No. 985 Depth 2446 ' FIRST SECOND EQUA nON Kh 1637 Q. ZT µ - m Kh Kh - µ µ K Kh h Kl Kh h1 THIRD THIRD 54119 50089 md. ft. cp 757.7 701.2 md.ft. md. md. 10.98 10.16 115. 6 116.5 6.55 6.02 3480 3693 2951 3040 22815 22226 19344 18295 MCFD 3200 Q. µ. ZT Log(0.472 b/rw) (Kh). = Ps2 _ Pp2 DR = Theo. Flow Cap Kh Indicated Flow Cap (Kh). md. ft. OFl = Q. Ps2 Max. Ps2 - PF2 OF2= Q. Ps Min. v Ps2 - PF2 OFs= OFl DR Max. OF4 = 'OF2 DR Min. MCFD MCFD MCFD ft. 33. ft. 32.6 53 ft. -24 These calculations ore based upon information furnished by you and token from Drill Stem Test pressure charts. and ore furnished you for your information. In furnishing such calculations and evaluations based thereon. Halliburton is merely expressing its opinion. You agree that Halliburton makes no warranty express or implied os to the accuracy of such calculations or opinions. and that Halliburton sholl not be liable for any loss or damage, whether due to negligence or otherwise. in connection with such calculations and opinions. INTFRPRFTATIONS ANn rAI rill ATI()NS LITTLE'S 83414 1M 3/69---5J ~ /..---........, e W I .' L.J tdi Ü ~.!.' I , .' . ~ I .1 - .' I Ir ,.... I. I.... ·0 - I V' .:.. ìô I r- ~ -- i . ~ f ·1 ¡g r<i! n !Vli ,~ J[ .."'-'-~ "I i r-;; ii.._.'.... - I~~I .. :n t1 ;n ~ I ct3 rn fi tRINTED IN U...A. . Reversing Sub . . . . . . . . . . . . . . . . . . . . . Water Cushion Valve ............... Drill Pipe ....................... DrillCollars ...................... Handling Sub & Choke Assembly Dual CIP Valve ................... Dupl CIP Sampler . . . . . . . . . . . . . . . . .' . Hydra-Spring Tester. .....'........... Multiple CIP Sampler . . . .' . . . . . . . .' . . . Extension Joint . . . . . . . . . . . . . . . . . . . . AP Running Case ................. . Hydraulic Jar . .................... VR Safety Joint ................... Pressure Equalizing Crossover . . . . . . . . . Packer Assembly . . . . . . . . . . . . . . . . . . . Distributor. . . . . . . . . . . . '. . . . . . . . . . . . Packer Assembly . . . . . . . . . . . . . . . . . . . Flush Joint Anchar ................. Pressure Equalizing Tube ............ Blanked-Off B.T. Running Case ....... Drill Ceftãi'f' .Pipe. . . . . . . . . . . . . . . . . Anchor Pipe Safety Joint ............ Packer Assembly . . . . . . . . . . . . . . . . . . . Packer Assembly . . . . . . . . . . . . . . . . . . . Anchor Pipe Safety Joint Side Wall Anchor . . . . . . . . . . . . . . . . . . Drill Collars ...................... Flush Joint Anchor ................. Blanked-Off B.T. Running Case . 308254-C O.D. I.D. LENGTH DEPTH 5 3/4" 2 3/4" 1.00' 4~" 3.826" 2199' 6 1/4" 2 7/8" 130' 3 7/8" 7.90' 3 7/8" 5/8" 5.11' 2320' 3 7/8" 3' 4.37' 2321' 3 7/8" 5.15' 7 1/4" 6.42' 2338' 5" 1~" 38' 4~" 3.826" 64.63' 5" 1~" 1.58' 5" 3~" 1.52 ' 5" 2" 4.06' 2446' FOIIIPMFNT nATA /~~...-:;;..\. LlTTLI:'& 1141' 11SM ./.9--tS. 15 /I = TheoretlcClI Open Flow PotentlClI with/Damage Removed Min. . . . . MCF/D Ps = Extrapolated Static Pressure . . . . · . . . . Psig. PF = Final Flow Pressure . . . . . . . . . . . · . . . . Psig Pot = Potentiometric Surface (Fresh Water' · . . . . Feet "THI'!IN 7':HE"Jl?j.... (,/~.lJ.u.J,C.~fif#.f~ . .. . ." ". '" ... . .... ......;.~I,. . ... '. u ..IJ:~ I.·.·. -. ···..··.&.·.1. .......W..i!IC.....' .ÐIPTH~. .....0I.0Cf .. B~;·.··.··§·_' .. . , . I.·· è. ~,~t" . ,. . . .¥ ..1, .~'~ð~t>.;3.:.,:~. /Ùvfi)$TOM/!i flltY.4111V; Y/£", "/. .rql~H7'>0:. If l'"?W: .~;;.. "'~..r III f.,."".,.d,r.J'./ I, I..... .r_,-r,Þf ,l''SJ!/p' ". . '.. . .t.l-,:;:::¡:-¡..- ".,.. 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FLUID SAMPLER Ticket Number DATA Gravity Gas/Oil Ratio ° API @ OF. cu. ft./bbl. 308254-A NORTH SLOPE Halliburton District ANCHORAGE MR. MURPHY MR. DALTON Drilling MR. HE.RBST . Contractor HOLMES AND NARVER, INCORPORATED DR EQUIPMENT & HOLE DATA Formation Tested LowerCretaceous stringer Elevation 29 KB Net Productive Interval 4- 2' sand s All Depths Measured FrolT"Kelly B_u~hing Total Depth 2130' Main Hole/Casing Size 8 5/ 8" OR Drill Collar Length 130' Drill Pipe Length 1880' Packer DepthCs) 2040 ' Depth Tester Valve 2022' Surface Choke Dote 4-4-70 Sampler Pressure Recovery: Cu. Ft.· Gas cc. Oil cc. Water cc. Mud Tot. Liquid cc. P.S.LG. ot Surface Kind of Job OPEN HOLE MR. BRACK Witness Tester RESISTIVITY CHLORIDE CONTENT Recovery Water _ @ _ OF. Recovery Mud _ @ _ OF. Recovery Mud Filtrate _ @ _ of. Mud Pit Sample _ @ _ of. Mud Pit Sample Filtrate _ @ _ of. Mud Weight 11. 1 vis ppm ppm LD LD. 1 7/8" 3.816" 40.!'5~ TYPE Bottom Choke 5/8" AMOUNT water 130' Ft. Depth Back Pres. Valve Cushion Recovered Feet of REVE RSED OUT ~ .. p Recovered Feet of ~ 0 3 Recovered Feet of ~ ~ ~ Recovered Feet of < 0 ¡ Recovered Feet of Remarks MISRUN TEMPERATURE Gauge N0'982 Depth: 10?1 24.::: Blonked Off_ Blanked Off Gauge No. Depth: Gouge No. 985 Depth: 2126 Ft. 24 Hour Clock Blanked Off Yes TIME Ft. Hour Clock Ft. Hour Clock en Tool x~ S Opened 2 :39 P.M. ~ Tool XXà~ Closed 6! 18 P.M. Reported Computed Est. 50 OF. 2125' Actual 73°F. Pressures Field Office 1242 Pressures Pressures Field Office Field Office 1173 Initial Hydrostatic Initial 'E] Flow ¡¡:~ Final ~ Closed in Initial Flaw Final Closed in 'C" Initial ~ 0 Flow ë·~ Final -~ Closed in Final Hydrostatic Minutes Minutes MLSRUN MISRU~ . 1:>" Co 0_ ~Æ 1173 1242 V!r- .... n<o ., !t ~r- :eo 0" .0 t~ ;00 ~~ c:: tr. . ~ ~ !;~ ~~ ~i-'3 !'> 0: z eg a~ t-' Z ~:x1 t-' ~ ,~ :::: sand S N NN~t;d Ft. Z.. ::s:J 'NÞtn Ft. t-' V1 ::s:J ~~ ~ Ft. c::::e:: . "dO . H- z~ ~ t::: z . ~ \0 Ft. Ft. C') o ~ ::s CD -J::&. ?:¡'O 3~ t'- .. z ? tn 0 ;¡ N :::z:: 0 .¡::.. ~ 0 > , ~ !~ ~ 1(..) _0 a. - . I g c ~ ~ ~ = ~ a ;; ;c::: a' IS ocn ~ . !w: f~ .¡ z o j > ~ tn ~ f w ~ :;:) V) V) w ~ 0.. .. ^ ^^ , ) r- . . FLUID SAMPLER DATA Ticket Number 308254-B 4-4-70 Dote Sampler Pressure Recovery: Cu. Ft. Gas cc. Oil cc. Water cc. Mud Tot. Liquid cc. P.S.LG. at Surface Halliburton District Kind of Job Gravity Gas/Oil Ratio ° API @ OF. cu. ft./bbL ANCHORAGE MR. MURPHY MR. DALTON Drilling MR. HERBST Contractor HOT,MF.S AND NARVER, INCŒ PORATED DR EQUIPMENT & HOLE DATA Formation Tester! Lower Cretaceous stringer sands Elevation 29' KB Net Productive Interval 4-2' sands All Depths Measured From Kelly Bushing Total Depth 2130' Main Hole/Casing Size 8 5/8" OH Drill Collar Length 130 Drill Pipe Lengt¡' 1880 ' Packer Depth{s) 2040 ' Depth Tester Valve 2022' Surface Choke OPEN HOLE Tester MR. BRACK Witness RESISTIVITY CHLORIDE CONTENT Recovery Water _ @ _ of. Recovery Mud _ @ _ OF. Recovery Mud Filtrate _ @ _ OF. Mud Pit Sample _ @ _ of. Mud Pit Sample Filtrate _ @ _ of. Mud Weight 11. 1 vis TYPE AMOUNT Cushion wa ter 130 ppm r'pm LD. ·LD. 2 7/8" 3.826" 40-50 f1pm cp Depth Back Ft. Pres. Valve Bottom Choke 5/8" Recovered Feet of REVE RSED OUT Recovered Feet of Recovered Feet of Recovered Feet of Recovered Feet of Remarks Opened tool for 219 minute flow with ,q strone; hlot.¡ @ 2:39. P.M. Gas to surface in 25 minutes. Tool off bottom @ 6:18. "'r- .... ~~ -ir- ~g ,~ 5'g 'P VI :noo ro 00 ~ :: c:: . en . ~ <: to<: r- ~'"d "'t>1 CD~ Z á=~ 30 ..&; fi s ..... .....1<"' , ~N ~.. ZN , VI .....00 :JO :: ~~ Ft. . 0 "dH'l zen t>1 (") o t1 ::s (1) t1 o H'I Ft. Ft. ~~ .þoCIÐ t>1 ~ t>1 Ft. Ft. ~\O ~ z ? ~ ~~ z ? :: .. ? ... o 3 ~ !!\. ~ >:!! ¡;J!.. aD. en o c:: ~ ::x:: t:d > ~ ~ < o <" CD N o ~ o I ~N "'t-" êrU) D.o I ... I {;' c No calculations attempted since no closed in pressure was recorded due to the ~ unseating of the packer when attempting to close the tool. z 0 Gauge No. 982 Gouge No. 985 Gauge No. ~ TEMPERATURE TIME Depth: 2023 Ft. Depth: ?1?6' Ft. Depth: Ft. 24 Hour Clock 24 Hour Clock Hour Clock Tool x~ en C Est. 50 OF. Blanked Off - Blanked Off Yp.!,; Blanked Off Opened2 : 39 P.M. S ~ 00 2125~ Tool x~Mcx . Actua I 73 OF. Pressures Pressures Pressures Closed 6 : 18 P.M. ~ Field Office Field Office Field Office Reported Computed r-<: Initial Hydrostatic 1,191 1188 1253 1258 ã..c: Minutes Minutes CD 65 68 120 161 ~ 0 _'tJ Flow Initial 0 ~ ",0 1052 1166 1100 1238 ... .="¡: Final 219 219 CD " ..... n a. Closed in 0 'tJ'tJ Initial ~ Co Flow > ~ 0·- Final u" Z alai > ",a. 0 Closed in :I en CD "E"8 Flow Initial ~ :E-\: Final ¡...... a. Closed in Final Hydrostatic 1127 1168 1198 1243 w 1:1II: ;:) c.n c.n w ~ Q.. ~f Each l al to 1000 p.s.i. Gouge No. First Flow Period Time Defl. PSIG .000" Temp. Corr. o .000 1 '.0680 2 . 1360 3 .2040 4 .2720 5 .3400 6 ,4080 7 .4760 8 .5440 9 .6120 10 . 6800 11 .7450 12 13 14 15 Gouge No. o . 000 1 . 0676 2 .1352 3 .2028 .. . 2704 5 .3380 6 .4056 7 .4732 8 . 5408 9 .6084 10 .6760 11 . 7400 12 13 14 15 Reading Interval REMARKS: PIIINTED IN U...A. 68 298 407 328 383 524 631 715 659 481 1161 1166* 161 358 450 382 435 580 685 770 712 533 1235 1238* 982 First Closed In Pressure Time Defl. Lag t + (J .000" (J 9'q') I Depth PSIG Temp. Corr. Depth 2023' Second Flow Period Time Defl. PSIG .000" Temp. Corr. 2126' ?O * T.ast interval equal to 19 minutes Clock No. 9180 PSIG Temp. Corr. SPECIAL PRESSURE DATA Second Closed In Pressure Time Defl. Log t + (J .000" (J Clock No. 9181 h I Ticket 24 our No. 308254-B Third Flow Period Time Defl. PSIG .000" ~o~f.' hour )\ Third Closed In Pressure Time Defl. Log t + (J .000" 9 PSIG Temp. Corr. . 24 . Minutes LITTL.·. ...a. 10M ./''--'1, I..... E' ;J.:.J I~.' ..~ - ¡ . tt - ! Reversing Sub . . . . . . . . . . . . . . . . . . . . . Water Cushion Valve ............... 308254-B . Drill Pipe ........................ Drill Collars ...................... Handling Sub & Choke Assembly ...... Dual CtP Valve ................... Dual CIP Sampler . . . . . . . . . . . . . . . . . . Hydro-Spring Tester ................ 0.0. 5 3/4" 1.0. 2 3/4" LENGTH 1.00' DEPTH :101: :1 ¡i IT ~: I l- i i , ¡o- I i ¡. - I i Multiple CIP Sampler . . . . . . . . . . . . . . . Extension Joint . . . . . . . . . . . . . . . . . . . . AP Running Case . . . . . . . . . . . . . . . . . . Hydraulic Jar ." "'.. . . . . . . . . . . . . . . . VR Safety JOin~. . . . . . . . . . . . . . Pressure Equalizing Crossover ...... . . . 4%" 6~" 3.826" 2 7/8" 1880' 130' Packer Assembly . . . . . . . . . . . . . . . . . . . Distributor ....................... . 3 7/8" 7.90' Packer Assembly . . . . . . . . . . . . . . . . . . . Flush Joint Anchor ................. : . . Pressure Equalizing Tube ............ . .. - r . . Blanked-Off B.T. Running Case ....... - b...J ~ ~. D.!:ill. .pipe. .4%. FH . ......" : ¡ Anchor Pipe Safety Joint ............ Packer Assembly . . . . . . . . . . . . . . . . . . . 3 7/8" 5/8" 5.11 ' 2022' 3 7/8" 4.37' 3" 20231 3 7/8" 5.15' 7\" 6.42' 20401 5" 1%" 38" 4%" 3.826" 43.21' Packer Assembly . . . . . . . . . . . . . . . . . . . - : I¡ 'I"""'! Anchor Pipe Safety Joint 5" 1%" 1.58' 'v" ........... . II' - m Side Wall Anchor . , ................. . ® ~. Drill Collars e .. 0·.................... . . ~ ~x~adJRr Temp. . Case. . . . . 5" 3\" 1.52' H-T-500 Blonked-Off B.T. Running Case ...... . 5" 5" 4.06' 2126' OF3 = Theoretical Open flow Potential wit OF4 = Theoretical Open Flow Potential with/Damage Removed Min. . . . . MCF/D P s = Extrapolated Static Pressure . . . . . . . . . . . . . . . .. ........ Psig. P F = final Flow Pressure . . . . . . . . . . . . . . . . . . . . . . . . . . . . . . Psig. P or = Potentiometric Surface (fresh Water *) ...................... feet Q = Average Adjusted Production Rate During Test . . . . . . . . . . . . . . . . bbls/clay Q 1 = Theoretical Production w /Damage Removed . . . . . . . . . . . . . . . . . . bbls/da'f Q" = Measured Gas Production Rate .... . . . . . . . . . . . . . . . . . . . . . . . . MCfjD FLUID . SAMPLER DATA P.S.J.G. at Surface Sampler PressurE' Recovery: Cu. Ft. Gas cc. Oil cc. Water cc. Mud Tat. Liqu~d cc. Gravity Gas/Oil Ratio ° API @ RESISTIVITY Recovery Water _ @ _ of. Recovery Mud _ @ _ OF. Recovery Mud Filtrate _ @ _ of. Mud 'Pit Sample _ @ _ OF. Mud Pit Sample Filtrate _ @ _ of. Mud Weight 11. 1 vis TYPE AMOUNT water 130' Cushion Recovered Recovered Recovered Recovered Recovered Remarks TEMPERATURE -J Est. 50 OF. 2125' Actual 73°F. Initial Hydrostatic ~ " Initial ~.e Flow ¡¡:~ Final a. Closed in Initial Flow Final Closed in ~" Initial ..0 Flow ~.:: Final I-~ Closed in Final Hydrostatic ~" 1:0 0·- y... ..GI VIa. Feet of Feet of Feet of Feet of Feet of Gauge N0'982 Depth: '0'':\ '4';: Blanked Off_ Ft. Hour Clock Pressures Field Office 1173 MISRUN 1173 OF. cu. ft ./bbl. CHLORIDE CONTENT rpm 40- :'9, Ft. Depth Back Pres. Valve REVE RSED OUT MISRUN rpm f'pm 308254-A NORTH SLOPE Halliburton District ANCHORAGE MR. MURPHY MR. DALTON Drilling MR. HERBST Contractor HOLMES AND NARVER. INCORPORATED DR EQUIPMENT & HOLE DATA Formation Testeti LowerCretaceous stringer Elevation 29 KB Net Productive Interval 4-2' sands All Depths Measured From Ke 11y B_uJ;hing Total Depth 2130 ' Main Hale/Casing Size 8 5/8" OH Drill Collar Lengt , 130' Drill Pipe Lengt , 1880' Packer DepthCs) 2040 ' Depth Tester Valve 2022 ' . Date 4-4-70 Ticket Number Kind of Job OPEN HOLE Tester MR. BRACK Witness Surface Choke Gauge No. 985 Depth: 2126 Ft. 24 Hour Clock Blanked Off Yes Gauge No. Depth: Ft. Hour Clock Blanked Off Pressures Field Office 1242 Pressures Field Office MlSRUtI 1242 J.D. I.D 2 7/8" 3.8'6" Bottom Choke 5/8" TIME en Tool xxAJ&boc S Opened 2: 39 P.M. ~ Tool xXÅ~ Closed 6: 18 P.M. Reported Computed Minutes Minutes "'r- .... !'~ , - "'¡r- ~o "On .2- , -. ;UO :1:1 'P c:: 00 , ~ ~ Cf)V1 i~ It) 00 ;; ~ ~ og z¡g Q..... t-'Z ~~ t-' c:: I R'> X sands N NN~':d Ft. z.. :%j IN~oo Ft t-' V1 :%j . 00 þt! ~: ~ Ft. c:: ~ . '"dO . M1 Z;n ~ t<: z . 11 \D Ft. Ft. n o Ii ::s It) ---t:C. ~~ 3~ í~ z 11 ~ ~ ." a 3 ~ .. ¡;- ... en 0 c::: ~ N ;:¡:: 0 ~ t¡: 0 > :::ø . ¡g ~N ..I-' ~ ¡~ ã - .. I 9 c ~ êi ~ ;:¡:: '§ ~ ~ Q ... ... r-C:: 3· ;; oen ~ . i ,~ ;~ 11 ~ z o i > s: en ~ w Œ :) V) V) w Œ Q. ] 1 'f I:_..t.. .........i...........+,.,! 'no I=nllnlt.... lnnn ne: ¡'¡A ~ J (2/U'-î;) . ." ... . REPORT OF ANALYSIS F. S. - 1255 a M.S. N -S 1495 .H' ·0.00 OBS. PRES. '64.2 CAL. PRES. 62.8 STATE- ·Al~,~K^ COUNTY... 'NOT Gt VE '" FIELD- BA RR OW 'S WELL NAME- ¡SOUr H BARROW NO. 9 LOCA TION- u.s. NAVAL PETROLEUM RESERVEOWNER_- U.,:S.; NAVY DATE COMPLETED- NOT GIv'EN DA'rE SÁMPLED- , 04/OZIno SAMPLED B¥- P.J(h 6!VEN- ¡l1 ~ ~rì..l NAME OF PRODUCING FORMATION- eRE T- DEPTH IN FEET":'- 9. 04 0 . JMT :::z, ¿) '-'ð -J /3.::> THICKNESS IN FEET- ¡, OPEN FLOW, MCFjD- f~;.~T . '9-e-. ) (2.0q,,~s.l) (2.o7<ý-Ro) (:Z1c:/3-c:;5"· \N 0 T -'r.;-nu:'ÌIf. / b 6 f1 C F /Ð . ~)-.~ ?þ I: Q rt -Ire ~ SHUT IN WELLHEAD PRES., PSIG... 'NO T : CI ¡>"J' .:.., jJ . 0 ?,/(çý.vl'/n c,¿p....~/t1lr-r-& CHECK OF DATA- THE WELL DATA ARE ACCURATE, ( -, ...)WITHOUT COR~ECTION,(--X-) AS CORRECTED ABOVE. REMARKS- . ^ ANALYSIS- METHANE 98.4 0/0 NORMAL PENTANE 0.0· 0/0 0.6 ., 0.0 ETHANE 0/0 ISOPENTANE '. 0/0 TRACE , 0.0· , i'~OPANE 0/0 CYCLOPENTANE 0/0 . 0.0 .-. 0.0 NORMAL BUTANE 0/0 . HEXANESPLUS 0/0 0.0 . 0.9· ISOBUT ANE 0/0 NIT~OGEN 0/0 SPECIFIC GRA V o .561 .- . .'. , . \ OXYGEN 0.0· % .- ARGON 0.0 % HYDROGEN 0.1 % H2S ,- 0.0· % 0.0 . <;02 % HELIUM 0.03 0/0 TOTAL 1 00 ..0 % ·'1008. CALCULATED GROSS BTU/CU. FT., DRY AT 60 DEG. F AND 30 IN. MERCURY- PERMISSION FOR RELEASEI Permission is hereby granted for the Bureau of Mines tø release the above data, together with similar data released by other operators as public information and os parts of a series of papers on analyses of gases from various fields, states, or regions. ,. COMPANY :./' BY .L TITlE . 'REPORT OF ANALYSIS . F. s. .. 12558 STATE- . ALASKA FIElD- :)" r.n (ì~~ s "-51495 .H"· 0.00 M.S.· OBS. PRES. 64,.2 CAL. PRES. 62.8, ·i" Soúni BAR. , CÓtJNTY-· . ~Å~~R~~VkE~ÊRVE ~.4 ·w~tLtiI~ii:' ISÖu..t.J1. BARRO,~ NO.· 9 LOCATtON- sÍ;~¡Sl¡4~~Vrr:;~f.~J~r;o~f<r-~WNER- - U~:S~.,~NAVY - , DATE COMPLETED- ~ ¢ T (ìIl\. -II . 'DAtE SAMPLED- '04' ~ il 0 . SAMPLED BY- ft(t.~ ~i~ ,.... \ JAMES DALTON ANDR.V. tIAIRPHY \ ' NAME OF PRODUCING FORMATION- . CRET- \ DEP1'HIN FEET':' Dst~o'~ -'!!I'O THIC~N :$SI~FE~!-6~-(204~. (2078-80), (2103-05) . SHU·.TIN· WELLHEAD-¿S.,P·S·IG·..···· NeT. (I 'NO"'i tlV~N"' r-m; OPEN FLOW, MCF/O':" . atlLD-UP INCÒllllPLETE dT,EST ·.66 flt.F/D ON 1/8" ORIFIce CHECK OFDA T A- THE WELL DATA ARE ACCURATE, (. ) WitHOUT CORRECTION, ( . . x ,)AS CORRECTED ABOVE. REMARKS-CRITICAL Fl."" P~VËR PRESSURE t.E';EU~O"'.. 400 PSI8 FOrt IS MIMlTES.. S.G.ASSUMED ~ .564, Z - .885. Fp _ .27','. FT- '.04' (l8'F).F,- '."2.F" - 1.06,.WEU SMUTINO SURFACE Nit INITIAL S" IH.. L. '. . .._~ -0 "-. ". . emDER.TO ~YOID UNSEATINOPACKER. PRESSURE'ÍlJILD UP FOR OllIE HOUR - ~S,"I' 'TO "mi. (WlLLHlAD "$SURD) ANALYSIS... PACKlR MI.:íD BEFORE Fsip CGÞPLITI MHHANE '9f\~4 '% ETHANE . .,0..6 %'. PROPANE TRACE % ¡ ., 0.0 .t NORMAL BUT ANE . % ISO BUT ANE , 0.0 % SPECIFIC GRÁ V 0.561 ' . .. 0.0- NORMAlPEtiIT ANE , % , 0.0' ISOPENTANE % . 0.0- CYCLOPENTANE .,,; , HEXANES PLUS ·...··0.0· Nl't~oGEN . O·~9'" OXYGEN · ¡ 0.0 % J t I. CALCULATED 'GROSS ~TÚ/CU. Ft., DRY AT 6ODEG. F AND 30 IN. MERCURY- . '1008. 0.0- % 0.1 ~~ 0.0' .% 0.0 % 0.03 % 1 ·100.0, . % i ~ . PERMf.SSION FOR RELEASE: . '-~' -"Permission is herebygrôå'lted ~r the Burea.. of Mines ~reiease the above data, together with Iimilotdotor.eIØd by other opétators..'Qs public in'o_t"", 0,", .0S,PCllrtl· ofo .... of pOpen on analyses of oases ~ và.;qUi field.. ste..., or region": ... . ' . . ,.""f, , . . COMizA~':'@'. .~. ..... :'...;,::..........).. . ...............'............................'...~........................ . '. .~, - . .,' -,,-. ,.,. . BY.' .'., ...0:) .', ......... .., . nTlÆpcþ'.;jIf&¢,l.::$~. ~¡'<ét,ilÍ f/AV Aj~ . Rf~I(OtHA-¢'{),'lS8~1e 'If,. ~.~ tt¥IJttt . . ;.(, ' .) , '/ ··.·.·.·.·.·...115..·.·.'. .'............!II"............'. ............................. ..... .. .... . ¡f~~e j or z.1I;ti'tt". D.\'tE .y-.z - 7" - OpmTOR .l.I.J'# {JET RES.TIT . to ~/()C¡ FT. RÆ. .l..J' I lJJCATIONßI)RRf)~ /JLlJf /(,q FIELD~ BI9/ui'QW" (;/fJ" fíil.li WELL 9 FORMA'nON I/PfJEi( ~IJS 2ðNE PIlEV'tlWJ Clu'ES Cø"lZ L/ rNØ'fIÞ.(;.~ ..¡ COif£, TonES ()() jVø, Tfi. 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"': & &'I9S ðO"If, Goe>D v,..s:. ..ï:i .8:/1".. pIA..J.r 8AN .r7;l1A/. 6VéA..l Y6i.'ØW;&'l,qO; lip""o e.ølJ. IJIt r Yã<. CI4T; c..ðl1f6 ALl.. 8IløK£N ùp "AI'->", I.TJ 1'1..'''' II" *......7' I'"r p.,rJ", 3,,~/y J'p_,/c.liesrU ~ItEI.." 1M....ff:.¡lør l7t~... Tic.- .J'ilHoI'/c' CORE DESCRIPTlut-4 l;!¥ £~j.¡"n~ CUKf1.UnMLlHêS .·.j··Nðlfî.lEJ( 'TKI'C, TIPE & SIlECNltlJnAJtl1t' ?~x..~ DIll, C-lrÞc. ,. tp .zIt: TIPE & SIlE(Jlllil.JraHBP J'"'~·~3~" )(3.' op1i&'rOR#A-~(þ(,.' IJNJ G'(i~ .. C N¡f!J?6".usINÐr.*o~, o~, ~; . . 709:De - Construct Well Control House, and place same over welL Prepared by: J. W. Dalton R. V. Murphy, Petroleum Engineer /' A. Construct Well House, frame same size and same method as usèd in SB No.8. 709-De-2 April 2, 1970 B. Move Well House over well after Rig is towed off gravel pad. (Includes re- shaping gravel pad to accommodate well house). Set timber support piling if necessary. .. . . 709-Dc-2 April 2, 1970 709-De.- Construct Well Control House, and place same over well. A. Construct Well House, frame same size and same method as used in SB No> 8. B. Move Well House over well after Rig is towed off gravel pad. (Includes re- shaping gravel pad to accommodate well house). Set timber support piling if necessary. Prepared by: J. WO Dalton R 0 V 0 Murphy, Petroleum Engineer . . 709-Dc-2 April 2, 1970 709-De - Construct Well Control House~ and place same over welL A. Construct Well House, frame same size and same method as used in 5B No.8, B. Move Well House over well after Rig is towed off gravel pad. (Includes re- shaping gravel pad to accommodate well house). Set timber support piling if necessary. Prepared by: J, W. Dalton R. V 0 Murphy, Petroleum Engineer " . . 709-Dc-2 April 2, 1970 709-De - Construct Well Control House~ and place same over. well. A. Construct Well House, frame same size and same method as used in SB No~ 8., B. Move Well House over well after Rig is towed off gravel pad. (Includes re- shaping gravel pad to accommodate well house). Set timber support piling if necessary. Prepared by: J. W. Dalton R. V . Murphy, Petroleum Engineer r---. . . ~~ 709-De-l April 2, 1970 709-De - Move Rig to next well location, (S. Bo No. 10) Ao Clear location area of snow. B. Set approximately 20 ft. of 23-5/8", 5/16" wall, slip joint conductor pipe, center line welL Cement same in augered hole. , Sketch to be provided. ' C. Set approximately 25 ft.. of 11-3/4" O. D. casing rat hole pipe -j>er sketch. D. Construct embankment, (beach gravel), for rig foundation. Shape of fill to be 36fx 63' x 4'-6" deep with 1 to 1 slope on sides and ends. Thisltem includes loading, hauling andshapîngo Conductor pipe and rate hole pipe to be incorporated in filL NOTE: Would appreciate separate cost on this item. E. Set, level and freeze in 10" x 20" timbers on top of gravel pad - rig foundation. per sketcho F 0 Construct and install inaugered holes four each rig derrick guy line anchors. G. Mov~ Rig from S. B. No.9 to S. B. No. 10and guy same to Derrick Anchors. Prepared by: Jo W 0 Dalton R. V. Murphy, Petroleum Engineer . . 709:De-l Apri1 2, 1970 709-De - Move Rig to next well location, (S. B. No. 10) A. Clear location area of snow. B. Set approximately 20 ft. of 23-5/8", 5/16" wall, slip joint conductor pipe, center line well. Cement same in augered hole. Sketch to be provided. . C. Set approximately 25 ft. of 11-3/4" O. D. casing rat hole pipe per sketch. D. Constt,:'uct embankment, (beach gravel), for rig foundation. Shape of fill to be 36'x 63' x 4' -6" deep with 1 to 1 slope on sides and ends. This item includes loading, hauling and shaping. Conductor pipe and rate hole pipe to be incorporated in fill. E. Set, level and freeze in 10" x 20" timbers on top of gravel pad - rig foundation. per sketch. NOTE: Would appreciate separate cost on this item. F. Construct and install in augered holes four each rig derrick guy line anchors. G. Move Rig from S. B. No. 9 to S. B. No. 10 and guy same to Derrick Anchors. Prepared by: J. W. Dalton R . V. Murphy, Petroleum Engineer . . 709-De-1 April 2, 1970 709-De - Move Rig to next well location, (5. B. No. 10) A. Clear location area of snow. R Set approximately 20 ft. of 23-5/8", 5/16" wall, sUp joint conductor pipe, center line well. Cement same in augered hole. Sketch to be provided. C. Set approximately 25 ft. of 11- 3/4" O. D. casing r at hole pipe - per sketch. D. Construct embankment, (beach gravel), for rig foundation. Shape of fill to be 36' x 63' x 4' -6" deep with 1 to 1 slope on sides and ends. This item includes loading, hauling and shaping. Conductor pipe and rate hole pipe to be, incorporated in fill. NOTE: Would appreciate separate cost on this item. E. Set, level and freeze in 10" x 20" timbers on top of gravel pad - rig foundation. per sketch. F. Construct and install in augered holes four each rig derrick guy line anchors. G. Move Rig from S. B. No.9 to S. B. No. 10 and guy same to Derrick Anchors. Prepared by: J. W. Dalton R. V. Murphy, Petroleunl Engineer . . i{ ':~ ,----,. 709-De-1 April 2, 1970 709-De - Move Rig to next well location, (S. B. No. 10) A. Clear location area of snow. B. Set approximately 20 ft. of 23-5/8", 5/16" wall, slip joint conductor pipe, center line welL Cement same in augered hole. Sketch to be provided. C. Set approximately 25 ft. of 11-3/4" O. D. casing rat hole pipe - per sketch. D. Construct embankment, (beach gravel), for rig foundation. Shape of fill to be 36'x 63' x 4'-6" deep with 1 to 1 slope on sides and ends. This item L'1cludes loading, hauling and shaping. Conductor pipe and rate hole pipe to be incorporated in fill. NOTE: Would appreciate separate cost on this item. Eo Set, level and freeze in 10" x 20" timbers on top of gravel pad - rig foundation. per sketch. F. Construct and install in augered holes four each rig derrick guy line anchors. G. Move Rig from S. B. No.9 to S. B. No. 10 and guy same to Derrick Anchors. Prepared by: }. W. Dalton R. V. Murphy, Petroleum Engineer . . 709-De-2 April 2, 1970 709-De- Construct Well Control House» and place same over wen. A. Construct Well House, frame same size and same method as uséd in SB No.8. B. Move Well House over well after Rig is towed off gravel pad. (Includes re- shaping gravel pad to accommodate well house). Set timber support piling if necessary. Prepared by: J. W 0 Dalton R. V 0 Murphy, Petroleum Engineer ,~ . . ~, 709-De-l April 2, 1970 709-De - Move Rig to next well location, (5. B. No. 10) A. Clear location area of snow. B. Set approximately 20 ft. of 23-5/8", 5/16" wall, slip joint conductor pipe, center line well. Cement same in augered hole. Sketch to be provided~ c. Set approximately 25 ft. of 11-3/4" O. D. casing rat hole pipe - per sketch. D. Construct embankment, (beach gravel), for rig foundation. Shape of fill to be 36' x 63' x 4'-6;1 deep with 1 to 1 slope on sides and ends. Thisitem includes loading, hauling and shaping. Conductor pipe and rate hole pipe to be incorporated in fill. NOTE: Would appreciate separate cost on this item. E. Set, level and freeze in 10" x 20" timbers on top of gravel pad - rig foundation. per sketch. F. Construct and install in augered holes four each rig derrick guy line anchors. G. Move Rig from S. B. No.9 to S. B. No. 10 and guy same to Derrick Anchors. Prepared by: J. W. Dalton R. V. Murphy, Petroleum Engineer · P.O. BOX 2127 . ANCHORAGE. ALASKA . F~ , I !'i !:¡ AMIRSCA. SI.AY.GRAPHIC COMPANY CORE ANALYSIS REPORT , , Company Well No. Field County State Homes & NarverJ Inc. South Barr011 If9 South Barrow, NPR 114. . nate April 1, 1970 T .ocatio.. Formation nepthR Core No. 2 nrilling Fluid Tab. No A-488 C-Crack F-Fracture H-HorÎ&oatal O-Opesa LEGBND NP-No Pn&tan 1S-laauffideDt Sample 8-IlIcht 1t-81Û1 V-VenJcal v_v... Alaska ..PKCTlva PU....A.ILI" W1'URATIO... aAMPI.. I._IIND D_Ht ...... POIIOSITY MIu.IDAlICla % POll. SPACK % POIIK .....a CONHAft NO. P&IICIØIT NORIIIQHT"I. vallTlCAL RUIDUAI. OIl. TOTAl. WATIØt WATU 1 201lt"â 14.9 0.51 0 85.0 2 2015~ 13.0 0.19 0 91.6 3 2016~ 14.0 0.70 0 :95.2 4 2017!z 14.1 0.70 0 ~93.0 5 2018!¿ 13.8 ,0.50 0 ;87.ì 6 20191-~ 14.3 0.81 0 87.0 1I0l.UalUTY MUD III % ACID 'ACID , pages . DATE .3 "3tJo/3/ - '/0 ,;( 0 Jr.; FEE:!' CUT .2'1 , ,"'I' 0, i ,f'7', FT. d.J!.L. / ... /1 "A/ 0..2. l:f 2 '9~'''/(I.OV 2 . I \!(IP ,...~ I · · ) i i -0 fCo ~ z~~ "'~ ::¿ H~' ¡:.'" O.f·.....- ~;:: u X .~ êš H f-< ~..<~ .;(. ~ Š DEPrH ~. tf')o:>J LITH- OLOGY DESC RI PI'I ON .. ....~ î I --------. .---'--..-.-.-- _._-~--- 2,' jlo /?£c. c c'rf' IE ;? [ C .:J (.., é'f/(. 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COHfANY M(./J1L.sý,4/¡9~ 1/£1(. eHAIJ T'4N.rëAlD/¡ .f!ß()t);· ·····1 I ;1 I to :lø.S'"' FT. R&;. ~/~ 1~,fUN . ? ~ 1.-ð:J'/iufLI WIT# C'OA/t.I/ilVrrOJV/JL j)/I9/ho/Vf) CI9TC~€I(. !J"T7o/'J1 .J';9't0 d.aLIIIS . ... .. §B~ ~~ ~ 8~~ ~ § 2.9 C' C,< T - ~ ~ wt ~ o ,..J - .---.-- 13 13 I~ 12. It¡ -- 13 ~ 12- - IL 13 /8 . 1.3 I~ /1- 12- 13 1'1 1'1 1.1- 3 :rJ.ð 3 '1 J¡ð.' ItJ I "".3 11.. , . j T pa.e I or '2. ' ". ' DATE J¡-/-J'ð - OPIID:TOR (j..!' I¥ /lE 7: ~,RJ. JY ~ :j '\ .~ .., LOCATION ß/),fRtJ~ /JLAJK/J FIELDJ?4IA.RðW Qcj. ÑGJ.nì 1.1to"l" T ~ 9 n~ FORMATION tI'~E~ ~A.J' ZðJlE CI>/lÆ:, /'l",E,I9L). c:ý .5''-//1 TY¡tJE \ ßÞ<TAIi/h£LY J..ððS£ Ý r/lI/J8L£, "JÃÞlj31> THE C/lTCIt5/i..J ¡¡ ~2 r~ '01 DESCRIPTION J LITH- ÐEPTIt" OLOer 2~ . I ---:. SíI/lLé OK C'.fAY f. /Jt./lc..K, /)1/1.fJIV¡£ I ¡¡ 31 - - -- FIIf/J1' Tð /J(/EI> liP.. .pit. ry /ÄI ,Pl9lfr: í _ - /l/olV CAI.C-. /HIC, OCC.A.J' ¿~Q..rê G~J'Rrz.1 32.. - - .-.. ' - - - (!I.€/M To IJLI( IIVè:..I.. cø",. WcDlfPJ rt/8£ $: 33 --_-~- EtI/&c:I t..uTH FN XL.A/ I'Y~ (lOÞ1. '"3J.¡ _- - _ -, -- ~J !:i f>1 -- ~t)~-- -- . -- ...... --. 3'': - :...:.~... ~ ',:) J'¡ ì --..-.. 3?- IJ :_ . , ð-- ß~ ---- - -#} 3'1 -.= .=. - ! I,') .;d : "I , 'I ~ ~ 11-- ~o 1(0 -_- ...:_- .--. !II --.-'- --, --- --. t¡L..-: _ - ú3 .:- --.. 7' -,- -1-. ,--'- ¥y -~~. _ a ¿0I //)o.r eo J"ÞliÞKr 9n ,r ý" r.( er ~o¥,..r-~:..-. IJI~ sG.ce.s PI,^' 1,II4¿e.'/'/"..,¡' /~ J"~/c.. , 'I ~~! ,il '.:. ·.1. ~ "'~ ¥' --:.... -:.. - -- -- J¡7 --=.. -:..-. ~~ ~ .f"'. --- -- "II'- -.... --- 'I'I-::;;-:~'" .5)/JII/O.$/øNE - 7""r brn, fJ,,'¡ /He"', ",-(Tlvo '.7 _ p..{..,.;~,¡ ¡; T sIze,"¡eac-.( fþu·.jy ecu,,/y ",.-7e.l) ':- J.. ð,f"'t> -'J--.'-";,'. II 0." i c:I. //.8 ~~:;:{:;. . fJ/ a 'j'" <- t., c/o,.... S''tJ 0.., , z. '7"" /,re , ~ .Ç"I_:::'::'!:;. 'lIe-to v/,/c... .(6Ne.,.. ciA' ¡leaf /lf1A/ .,,..., Ý:c1~7r //., ;r ši~.'::·~·· .'ê:Jl" /Ió~V/.. J:.//Cc1/c..... 1'. .}H./. Jar/ ¡".!tJOf.~. .~;"cl." . L'rI ~. rAIÅ lð :¡,.,..¡ .;¡ ~J ó./ur; tf! (JeJf, .6r7 Ye/ r, að T c.w." ·....4 ß/løICEAilCø//é S'4C.~"N /lP,PA4'1( .2l'" 8J,·~C. "'6~pfJ TIP.' E& SIl."b:' CII~/.J76AJJ'£" ? '~"v3~. " urcHslC.lIl,£IJ OU.r .t'£IIElfIJLJ)ADP-S ÞF FA/!£ i,:l'\.. "17' ON« 41f.""~ o/I.W#ENId"",kE.N ~"H bill. .'fflb;& SIl:-~:/~ rs:.sG~ S-~~~l ~ I. èo!tED~tUpnûN bï~¿:~ OPl!&\'fOR IlAA",f) . .t.11V()6l¡'COKP~Y#4-"¡~ C/flil.fTGP.f4')) 1)lA.AItCÞO. "3 CAS WÆLL? to ~O..f( FEI'l'Ctrl' :l.? ..1/Ý., F'1'. REC. ..... . """-<" ":"" " , ' , 'C'O;R::E:RE· "~po ··OR· ·'T'"'· . . ... '" .: :., ,. " ,.' 'V'_i'>'-;;U'-" ,',,-., Pagé2.. of.2. DAges . DATE 1/--I-?t> ~ ,.. H ~ o . '*' e i;~~ ¡g D~ ~ ~,.ßÐn /3 - _.fIl/9L/£ I ßI.I(, /J'1/1.TJIVt I F/IfPl, sn. ry' b'v ..r3__~__ ,P19~T: ,LOCI./'£ .PIiJ,I9A1(i.- q>r¿ (;./tS Jf) To .y /JtiOr ø ./" ;;Te'1' ßI..K ,AØ"IV ;)£() 4> .Il COM. tcJØIC M 7ù6e.S aJ h//e./ ~/ l-ñ~Oo' j(t..¡!t/ /,,'-',( Cllnt"JI.s>altf& H ,.. wI' /'"Ie. J'e.cÃ7ð1Ñ" DESCRIPl'ION "'Nß~YSIS ~ --- " ~17I/.r '7 ~ ' 0 r SIu/e.. Cor Co W,)J rec) 1110;'" W/ a-1l1E Y /1~"é'1( l3é/4Jt; t..P.S¡:J ()J<) TI'I£ I U )ru If . 12.. ! /3 I /2. II EJýp CORE. #3 - - - - " - - - t, - .. - . . 709-DQ-1 March 16, 1970 ZQ9::J::)<1..Qri!ling aI!(15~ml1pletion of well with crews on site; "Jl1ç!ll<:I~~ installation of well control valves and piping .(tree), 1:>:r!I1i!1g}nwell by ll~il!ggas from existing system, (tem¡:>OEary supplYJ~ipe line); and installation of controls and piping for blow down and production test. On completion of work entailed in thisjs>!> order~. a<:~ivity associated with movingrig off found- __,'" ...... .~..",.,..~-. ',..... ·····..,'i...·· .-...".... ,- , ation.~d may proceed - on completion of production testing. Prepared by: J. W. Dalton /P 1f7/J~~ R. V. Murphy ¡ f) Petroleum Engineer Naval Petroleum and Oil Shale Reserves Office . . 709-Dd-5 March 14, 1970 709-Dd - Drilling and Completion of Well Run temperature survey in S. B. ...No. 7 to locate bottom. of permafrost zone in Sollth Barrow Gas Fi(:~ld. Instrument and instrument men to be provided by Sperry-Sun, P.O. Box 6207. Annex, Anchorage, Alaska. Ted Ashby - Distric.t Manager, telephone number - 277-7992. Wireline, power unit, lubricator and operator to be furnished by C. A. White Wire Line Service, P.O. Box 962,' Soldotna, Alaska Operator'" Dude Oglesby, teleph~ne number - 262-4496 (Soldotna). Estimate Çost~P,r9ç~duraIP?Jª; Sperry-Sun, instrument and operator to be flown from Anchorage to j()h.f3iteand return: cost $9.50 per shot with minimum at $280.00 plus travel plus stilIîdbyor delay after 16 hours - @ $10.00 per hour. Wire line, power-unit, and lubricator to reflown from Deadhorse on NARL OC-3 A/C. St¡;mdard Oil Company of California will assist free of charge in loading and unloading at Deadhorse. Cost: $32.50 per hour with 12 hours minimum plus $150.00 per day. Standby plus travel.Wireline operator to come from Soldotna or Deadhorse. NOTE: A. Sperry-Sun equipment weighVabout 150 pounds. B. Wire line unit - 29" x 5' x ?, wheel mounted, weight - 2100 pounds; power unit - 6'-8" x 52-1/2" x 41", skid mounted, weight - 2750 pounds; tool box, skid mounted, weight - 800 pounds. Total weight $650 pounds. C. Crane needed to pick up 20' lubricator and set down through well house opening. . D. Temperature survey to be run at 50' intervals, starting at 100' GL to TD. Total of about 40 shots at $9. SO/shot = $380 plus delay time. E. Estimated time to complete survey - 10 hours after arrival of equipment and men at camp. Prepared by J. W. Dalton R. V. Murphy - Petroleum Engineer -. . ,. March 14, 1970 709-Dd-5 709-Dd - Drilling and Completion of Well _ Run t~I11~rature surve)'in S. B. No. 7to locate bottom of permafrost zone in South Barrow GasF-Ü~ldo mstrument arid instrument men to be provìded by Sperry-Sun, P,,-O. <Box 6207<Annex,_Anchorage"Alaskao, .,' Ted Ashby - . District Manager, telephone nunîber -'277 ';'7992. Wireline, power unit, lubricator and operator to be furnished by C. A. White Wire-Line Setvice,P.O: Box 962, Soldotna, Alaska, Operator -Dude Oglesby, telephone numbér - 262-4496 (Soldotna). & Procedural Data: NOTE: ~.". Sperry-Sunìnstrument and operator to be flown from Anchorage to . job sitea,ndreturn: ,cost $9.50 per shot with minimum at $280.00 plus travel plus stâ.ndbfor delay after 16 hours - @ $10.00 per hour. Wire line, power-unit, and lubricator to be flown from Deadhorse on NARL DC-3 A/C. St~ndard Oil Company of California will assist free of charge in loading and unloading at Deadhorse. Cost: $32.50 per hour with 12 hours minimum plus $150.00 per day. Standby plus travel. Wireline operator to come from Soldotna. or . Deadhor se. A. Sperry"'Sun equipment weight - about 150 pounds. B.· Wire line unit: 29" x 5' x ?, wheel .mounted, weight - 2100 pounds; power unit - 6'-8" x 52-1/2" x 41",'· skid mounted, weight - 2750 . pounds; tool box, skid mounfeg;-weight - 800 pounds. Total weight 5 650 pounds . . .t; .. C. Crane needed to pick up 20' lubricator and set down through well house opening. D. Temperature survey to be run at 50' intervals, starting at 100' to TD. Total of about 40 shots at $9. SO/shot = $.380.plus delay time. E. Estimated time to complete survey - 10 hours after arrival of equipment and men at camp. Prepared by J.. W. Dalton R. V g Murphy - Petroleum Engineer . ~ 1'}: . ,.. '" '\: !;t. \)~ t':, -1 '. I -I t ¡-D~.~- ,~ -<-- .~ 'VoIRI! flt';t/'/~ -- 55/;iO 7· !ì ~ ') \\i <~ ..... ~ ~ .-l1 '- Ç" "'" <I n .;¡ " 1= tf 1 . ! ! ,-'---'"'\ ! ;--- -- --( t- - -I. \..J ~" E j ¡ ¡ i :;¡ .. .... ""'~ -. ,.. ~ . } r· . ::.. !-' Ç} .ç) '" --,_.J 1< /~ ' - "" -~...'- . . 709-Dd-4 709-Dd March 14., 1970 Provide Assistance in Seismic Reference Shooting Program A. Locate and auger 5 holes in quadrant N. E. of Well. Holes to be equidistant from well - 500 feet to 530 feet from well; anp with not less then 100 feet interval between holes. (dis- tanées from well to each hole to be measured to closest foot). Diameter and depth of holes to be 8-inch to 13-inch and 20 feet to 24 feet respectively. B. Holes to be loaded and fired by representative of united Geo- physical Company who will provide explosives, caps, firing line, and necessary blasting machine and instruments. Prepared by J. W. Dalton , . Î /4 ln1~~, R. t. Murphy I 1 Petroleum Engineer Na val Petroleum and Oil Shale Reserves Office . . 709-Dd-3 709-Dd - Drilling and Completion of Well March 14, 1970 PrQyide blow down line for getting rid of ITIud from well a.nd for ma:idng production. test. A. Provide system of valves, piping and gages necessary for "rocking in" well and for production test, per sketch. B. Provide piping from well to point about 100 feet outboard from S. B. No.9 O. F. warehouse. This piping to be con- tained in wooden box about 10" x 12" in section which will also contain I-inch steam line, (fed from connection to existing steam line near cellar), to prevent freezing. Box housing 2-inch h. p. gas line and I-inch steam line to have constant grade away from well with no dips. 2-inch line to be anchored to preclude movement during use. Sketch to be provided. Prepared by J. W. Dalton fJlìfL ¡¿ R .(~. Murphy ~ 7 Petroleum Enginker Naval Petroleum and Oil Shale Reserves Office . . 709-Dd-2 709-Dd - Drilling and Completion of Well Prqvide Gas Supply For Bringing in Well March 13, 1970 From existing 2-inch valve on gas transmission line between S. B. No. 8 and P. R. Station install temporary line approximately 600 feet in length to point near S. B. No. 9 line to consist of 2-3/8-inch hydril C. S. tubing T & C, obtainable from Navy furnish stocks - Mona Lisa racks. Line to be laid on empty drums stationed each 20 intervals. Line to follow coarse that is staked on ground. NOTE: Line to have 2-inchh.p. WECO unions and 2-inch Texst~am valves at point of beginning and at localities near rig to facil- itate control and dismantling. Sketch of this temporary line to be provided. J. W. Dalton - Prepared by ¡Jl~l(} R./~. Murphy ! ~ Petroleum Engi eerC Naval Petroleum and Oil Shale Reserves Office . . 709-Dc-9 709-Qç - Rigging Up P~!form Nec~ss~J:"r,"Pre-Spud" Work. March 7, 1970 Provide essential rigging-up services, not otherwise covered by job orders - such as examining and servicing drilling equipment and tools with view toward having rig ready for operation upon arrival of crews (17 March -18 March, 1970). Prepared by: J. W. Dalton ¡:iQMurPhY ¿ Petroleum Engineer Na val Petroleum and Oil Shale Reserves Office Fonn P-l REV. 9-30-67 SUBMIT IN TRI ~ (other instruCtiO~ :;:;:: ~e~~~ ~Y# OIL AND GAS CONSERVATION COMMITTEE koJ., ðv' ",yr 5. yL_O c, ..J _, f.,~,,~ C'I' ì STATE OF ALASKA f)05 j~ z, ø1 ~ ¡J 'J:r- 1a. TYPIÐ 01' WORK APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK DRILL ŒJ DEEPEN 0 PLUG BACK 0 6. LEASE DESIGNATION AND SERIAL NO, ~. None 7, IF INDIAN, ALLOTTEE OR TRIBE NAME b. TYPIÐ 01' WIÐLL OIL 0 GAS rvl WIÐLL WIÐLL lAJ 2. NAME OF OPERATOR Director, Naval Petroleum and Oil Shale Re8erve8 3. ADDRESS OF OPERATOR OTHIÐR SINGLIÐ rv1 ZONIÐ ~ MULTIPLE 0 ZONE None 8. UNIT FARM OR LEASE NAME . South Barrow 9. wELL NO. Rm 1848, Munition8 Bldg., Wa8hington, D. C. 20360 4. LOCATION OF WELL At surface 5881N and 22581W of SE Corner of Sec 11, T22N, Rl8W, UPM #9 10. FIELD AND POOL, OR WILDCAT At pro,posed prod. zone South Barrow Ga8 Field 11. SEC., T., R., M., (BOTTOM HOLE OBJECTIVE) Section 11 T22N, Rl8W, UPM 1.2. Same 13. DISTANCE IN MILES AND DIRECTION F:tOM NEAREST TOWN OR POST OFFICE· 5 mile8 Southea8t of the City of Barrow, Ala8ka 14. BOND INFORMATION: None TYPE Surety and/or No. 15. D¿~'Á~i¿::~g~::~is<?¿'ED. 5 mile8 to PROPERTY OR LEASE LINE, FT. ~ (Also to nearest drig, unit, if any) water ~ 18. DISTANCE FROM PROPOSED LOCATION· TO NEAREST WELL DRILLING, COMPLETED, OR APPLIED FOR, FT. Amount t . t . 14· NO. OF ACRES IN LEASE errl Orld.L 23,680,000 AC , . 17. NO. ACRES ASSIGNED TO THiS WELL 160 ~ . 19. PROPOSED. DEPTH 20. ROTARY OR CABLE TOOLS 20001 24001 Rqtary 21. ELEVATIONS (Show whether DF, RT. GR, ete.) GR-161, KB-281 23. 22. APPROX. DATE WORK WILL START' 19 March 1970 PROPOSED CASING AND CEMENTING PROGRAM SIZE OF HOLE 18 5/81! 12 1/41! 8 5/81! 8 5/81! SIZE OF CASING) WEIGHT PER FOOT 13. 3/8" OD" 54.5# 9 5/8" OD 40# 7" OD 38# 51! OD 17# GRADE J-55 N-80 N-80 SETTING DEPTH 180' 1100' 2300' 2400' Hang @2250' QUANTITY OF CIi:MIi:NO;: 180 sks. 384 Sk8. 312 sks. Perf Liner D~ /j, "'.(..'<:- -._- F¡'/(s /3ð'D P ¡¡f; z,0oò Thi8 application is. being filed for information purposes. Please see Director, Naval Petroleum and Oil Shale Reserve letter serial 394 of 27 August 1968 R E eEl Vf D fy;Ar? Ii .... iP', '·'''Y··'' I:J/U DIVISiON or O¡lÞ.ND GAS IN ABOVE SPACE DESCRIBE PROPOSED PROGRAM: If proposal is to deepen or plug back, give data on Pres!n~~~¿~Ñ'¡; zone and proposed new productive zone. If proposal is to drill or deepen direct .onally, give pertinent data on subsurface locations and measured and tru~v: teal depths.· ~ ~ut preve"jtér program. 24. I here eertj,!~æ ~o¥~<Í~ A8sistant Director, Naval SIGNED ur~ne P. Bowler DATE 6 March 1970 Pet~um & Oil Shale Reserves (This space fo~ate offiee use) CONDITIONS OF APPROVAL, IF ANY: 1 SAMPLES AND CORE CHIPS REQUIRED OTHER REQUIREMENTS: D~ D~ = 1, . DIRECTIONAL SURVEY REQUIRED A.P.I. NUMERICAL CODE' DYES 0 NO SO ~ 02-3 - 2-0003 PERMIT NO APPROVAL DATE APPROVED BV TITLE. ·See Instructions On Reverse Side . t>ATE fIÞ .' IN,STRUCTIO'N'S General A filing fee of $50.00 must accompany application for permit to drill, to deepen or to plug back. Checks shall be made out to State of Alaska Department of Revenue. This form is d¡esigned for submitting proposals to perform certain well operations, as indicated, on all types of lands and leases for appropriate action by the State agency, pursuant to applicable State laws and regulations. Any necessary special instructions concerning the use of this form either are shown below or may be obtained from the Petroleum Branch, D'ivision of Mines and Minerals. l,tem1: Use this form, with appropriate notations, if the proposal is to' redrill to the same reservoir at a different subsurface location or redriH to a new reservoi r Item 13: Attach hereto a ne'at, accurate plat or map, drawn to scale, showing the site or proposed site for this location, distanc~s from section line, I~ase line if any, and other information that is pertinent. Refer to Section 2051 of Oil a~d Gas Regulations Item 14: Enclose drilling bond on Form P-2 with this application for permit to drill, to dleepen, or to,þlug back unless covered by other suitable bond. Ite,m 15 and 18: If well is to be, or has been directionally drilled, use subsurface location of hole in any present or objective productive zone. . 1.~<!~.Y iVLJ,i . (Other instructions on reverse side) .i.Juv.þ....:.. ..1..d.Ü:~u.U J, ¡ :>. 'c.1""... ~'~'.'" UNITED STATES DEPARTMENT OF THE INTERIOR GEOLOGICAL SURVEY G. LEASE DESIGNATION~AND$ERIAL NO. None;:: ., . 6., IYINDIAN, ALLOTTEE·OR TBIBE NAME ,!, ~6ne;," :." ;}, ',7. 'UNIT AGREEME.NT N~MID ¡; la. TYPID 011' WORK APPLICATION FOR PERMIT TO DRILL, DEEPEN, OR PLUG BACK DRILL I!J DEEPEN 0 PLUG BACK 0 . QUANTI!1:- ò.F ÇEMENT ",' G sk·s ~ Q ,~? t;~ ~~:" :': ;S sks 'cO ',. C, ',0 ;;~ ~ ~~~ ~ H ~... ~..~,~, ~~. ~~.,. ".:-,,_,~' ;" r-.~ ~ .-:.:. ;:.- .~ -' ~,2,."'" -. ~ r·.... "',' t.:~ {þ _ r- N :..~. ..,:J ti 2 ,~. ~~. ~'21 ~,~ ~ ~i ~:;:? N ~ !-.t l,~ ..~~ \b ':-- :.',:; ¡::; ç .. t:' ,".,! Î-,~¡: - ," ,...., -...... ,¡j,~ c.;,!::'~~. ¡-,,:l.,::'" ç, ¡.i..~ ;:';' ::. l;.') 2 ~ .-. '.- ~ :;:.1:,...: ...",..) ~~ ;~ ,~.~ ~!~ (~.~~> :, ~;~ ~'[ ;~.~~'. ~.; ~.:t,,' ,f.:',:. . t5 .......l' ;q¡; - :~ ' ~ f~ :.~,_~:. fj ~ ~}, ';]. .b~ ; ~.~~". ~ ;~ ¡; ::. G,; ~'~ j:') '" .'. ,., ;r~ P. I..:.' ....,:,... f... I ,:;) ~.::.i.· ~.'I_,., ~;.:'~~_':.'. ~_~~.; (!; '"'" .~'~ S' : :: .' L:~ ":.'--:-,; ~.,~,.~. '.,,_:. ~~ ..., ") L.-.;. .~. ~ - ~ þ~ H ::':' 0 (~ ~,-' {.~ '" ~'., (.<...1' tJ: ~ S c ~. ~~; ~.~ ~..,~.·,i,: ~,'c~. ~ ~ t;/ ~ 1;',1 , '.. CI .... .' " 2:~~~'~ !.oj . _".,' ~.f} ~.~ ~.~ :~~ ,.~"I ;,,' \_, .:, . ^ :':~~ IN ABOVID SPACE DESCRIBID PROPOSED PROGRAM: If proposal is to deepen or plug back. give data on present prQduétiv'if zon~'.a:iîd ..proposed1.n.\lwproductive zone. If proposai is to dr1ll or deepen directionally, give pertinent data on subsurface locations and measured :iin(iruever.tic:il ·,I,epths; ;~G1ve blowout preventer program. if any.· :c: :3,. .2; I;; ". ;,;" .,. .. .'. 24. Assistant Director, Navâì~;' "; '5;; ~';~. ,} ,'. {;, SIGNIDD Eugene P.. Bowler TITLE Petroleum & Oil Shale'Res~~ii) '6 March' 1970 b. TYPID 011' WELL OIL 0 WELL 2. NAME 011' OPERATOR Director, Naval Petroleum and Oil Shale Reserves !XI MULTIPLID ZONE GAS IV! WELL ~ SINGLE ZONE OTHIDR 3. ADDRESS 011' OPIDRATOR Rm. 1848, Munitions Bldg., Washington, D. C. 20360 4. LOCATION 011' WELL (Report location clearly and in accordaDce with aDY State requirements.*) At surface 588'N and 2258'W of SE Corner of Sec 11, T22N, Rl8W, UPM At proposed prod. zone Same 14. DISTANCE IN MILES AND DIRIDCTION II'ROM NEAREST TOWN OR POST OIl'II'ICIiI* 5 miles southeast of the 10. ~~~¡~~g: ~~O:E~:~~SED* 5 miles PROPERTY OR LEASE LINE, II'T.w;:¡+prs (Also to nearest drlg. unit Hili!; 'tr!In')') 18. DISTANCE II'ROM PROPOSED LOCATION* TO NEAREST WELL, DRILLING,. COMPLIDTlDD. OR APPLIED FOR, ON THIS LEASE. FT. City of Barrow, Alaska to terri toria116. NO. 011' ACRES IN LEASE 23,680,000 AC 19. PROPOSED DEPTH 21. BLBVATIONS (Show whether DF. RT. GR. etc.) 2000' GR-16 ' GR-28 ' 2400' 23. PROPOSED CASING AND CEMENTING PROGRAM SIZE 011' HOLID WEIGHT PER II'OOT SETTING DEPTH SIZE 011' CASING 18 5/8" 12 1/4" 8. 5/8" 8 5/8" 13 3/8" 9 5/8" 7" OD 5" OD . Perf Liner 54.5# 40# 38# 17.# 180' 1100' 2300' 2400' Hang@225ü' OD OD (This space for Federal or State oðice use) PIDRMIT NO. APPROVAL DATID APPROVED BY CONDITIONS 01' APPROVAL, III' ANY: TITLID ·5,. II1$truçtiOI'l$ On R i!y~". Side o~ None ~ =- :.:8. '.F~M OR LEASE NAME . :~? South· Barrow ....:; C'J ':9. WELL N.O. ~.: ;J. ,~ #'9 ¡~ :..i. ç:. ,.~ ;') ;,:,'\ :i ..0 _,. ,lO.FIELD AND POOL, OR'YU:..DCAT 17. 7.'SoÜth Barrow Gas,.):'ield ." ,11. SEC.. T., R., M., OR BLK.::" ;.:;. . ·AND SURVEY OR AREA,;· :::: S ~;, Séc,tion 11 'J:':.0" " T22N, Rl8W;' UPM~ ;'; .' -~t~~j;;::::~~SHJ~:T;;a NO,;' 011' ·ACRES ASSIGNED~;'. TO> THIS W.ELL c. ·c· I:. ,:; 160 Aq ~:. :(~ '~~~~ ~:f :'~:~ :; 20. RO;r¡\RY Olt:, ~.ABLE ;TOOL~; ~'j:¡ J Rqt?ry > ~:~ <',. ~ ~ 1~ 2i~,ÄP~:;~:~i :i1:,nrL START* ., o ~ ;} S2 ;.:¡ I .~~, ~":: ~'3 .'. .'.;') I·" ·0 ;~ 180 384 ªl~ :"1 :::. ~t.."" t; " ~ ~~. :7 :') n";/ t: :r,.¡.; ',iI' .,,-;;. '. '":"I ;'''1 ~i t_ Q (: ¡ .~. . .:~. \;, ',' ~~: ......',... ;.} ~~ j :çó., ~.~ ::..,. ~~; ~:.2.. ~ t~ ... '-.f'¡ ...)<-~ ,_1,·. C·::':,. \) '* .. :", ".. ¡:." 8 ;; ~~> f~ ... '.~l ~:.,~... .,::: ~~ ¡.~ g~ ~ ~-' :;~ .3 . DATIiI . :.-. ....., i'-I' ':~~' ..4 ~:" jv~ (""~ ~ ~ 0 :":"' r.-' ... . ' ,. '~!- 1-1 M C;;';T¡ :> ;;.:. ~f~, : ;~(~;~ ..:.. t;J l'~ .~. '-~ ~:-: " \.'¿ ":' ..... '.t; ~ ¡.L:;' ..... -.'-.' '. . . ~:.:_ ;1 hi'-¡ ," ~: !iOa 4l' F': ,,~:: '-~ :':'P. ;~ V~ ~" f :. d 03 01',)[ R NO: w,)09-D,c:.§. " r ..~~.~ebruar}f. 1970 . PRO,ÆCT: 709-Dc Ri gging Up _____...,.'....--'''' ,'"",.,... "_'."_-9'A'_'" ,~," ~ _ G¡::·JECrIV~ :___M~I1,s,~_a 1.1_~~g E.l,~c~ri ca 1 Di str..i bu~i.~!, Syst.em; 7?/~g_ KW Generat()!:'~,_,~ _,_...J'I~!'lgª,l1_~º".. r..1g..~.I}A ..~uppor~.~D,9 cOIl1P.2l1ents: ~'''-'''-''''''''-.,,''''''''.,;._'''''''-'''''''' ,. -:'.""'-~''''' ...' '- '. A .M,~k!L~p"~imum .U.S~,O(J),recut...\~iring<s~or:~d/i nsta 11.e.~ in rig..C;0I1lP()..I).~.nts . ~ __ ªnJ!.Jlf..S()J'}:tr.Q.t~,.ªr:td, .....~.'!'Ittçh,~g.~ ªr:.J.!l~!~.11~~., 1n. B o.iJ!r.. .HOll~.~,·, _,,>c........___ ~"..,."'"" __, . A_ ......ç:,""...",.."......,-.,;__...._._. __ ""........""......'.c..~_,-""'___,.....","_."'...'_.~'·,',',."_..."....~_~~" ............."'.,..-,,'_.____...._'.... :',.',_' .__-',"'".."__..~,......,.u'~" '... ....--#'-'.......',,.... ,~..__._..':>O',..,., .......'40 :..~ ...."..." '~'-,...O#4t Pr.Q1-:EDt¡¡\~ : Note : Explosion proof switch gear. wiring and lighting and equipment are to be used on rig and in mud tank wanigan. '- E. P . Bowler . Assistant Director Prepared by: D.W. Dalton · . J;> S}:~i\ 1',,) ~:- (,.' ~ ...." ;,-,i 1.; f ',~ O¡i,DER fiC): 709-Dc-5 !J',;(L 15 February, 1970 ......""'"'~__......"',p·,.,_,..~,c."',_..'~.,.. , ¡'¡1C-1:;CT: ' 709-Dc Rigging Up -~,~----"^.,,:........,....-,,., ,.."".-.,-->--" -", ',,',. . ,¡; iVt~ In accordance with plans and sketches to be provided install ~""_"_ ......'v·.;.·. ..'.:r.. ., .. ~. nominal l-inch diesel fuel service lines from electric ~"'"'-'- ' ~.... oJ"·,'..·.... -'..,. centrifugal transfer pump in Gardner-Denver 8-1/4" x 10" wanigan to: --..--"'_,..".._......,,_,._r-'_~..__-..., '. "-' " ·._,-*·.~".·t. '.' ""~,..#·..,."_..,,,-....''\I'I'<...'"'.__-dI<...t4'_,,·_-'''~__.._',..·,·,...·,..,,''- -...,.--...."...;..,..,-...._"',.-.... (1) Day Tank - GMC Quod. - C250 Pump ___....."'___,.....__..._.._ ...;:.'-^-,"",'~ "'.-.... ~" ..,-, ·~"""'."""~~'·"4...: '.""'~ -".,~"'" __......<..';O'--...._,_..""'~~.~,'~._~....;,...."'._~"'.,,. -(2)' Day Tank - Drawworks Engi ne _'__'__"-' ,~-.._. -., ''''._.~ '-.'_ .'''''.. ...,<' ,. ,_--.. '..-_._.,~~. _,...."-..,_._.~',_:____..-....,.....'''''"'',..,...-_. .~,.,.._....,,......_·...,,,.,_......·'.....'''_a.~.,'__,..'''~.....,_..,·..,. (3) Day Tank - Kewanee Boiler _.... 17'&, ~,.".. '~""_" -"-''''-'_'':-'~'_'~'. ~" _ ". .",....'.-....' - '"- '"" _ '.'",," " _.,:,.. .. , ."_~___ ..,...._ , .......' ..! "'_' 4......._...~.-,..._.'''.,. ._~._.....-...,.,__:j.. (4) Day Tank - D13000 Engine - 7-1/4 x 10 Pump. P¡:;OCfDURE: ~ ,/\ E.P. Bowler, Assistant Director Prepared by: D.W. Dalton .' "\ . . ';J[i P;':~'~'EÜJ~¡-:: <C~^_ '-'. r·;·.){, {~~. "S~'~/\ S 'DU,::~ t ~~ -...'J, ,- .. ;¡," : ~. /, Y:; ~~ ~.; ',' f ¡j ~ " .J!~1~~1 'R MC: 709-Dc-4 U.\. ; 15 February. 1970 PRu~n:GT;_._,...Z.9~:-o.,~...:-.Ri gg~ng U~ i,i,'.' '.':¿;._,.._.}n.acc~.rdance wit~ plans and sk~tch~s t~ be pro~ided inst~Jl steam ser~ice lines from Kewanee boiler to rig and mud tank wanigan. _...~,." _,,' _, L,~.,..""".,....".'__,d,.l.. .,."''''_,,',-.,,. _ ,",,,,, _",'''..... .,'"...~,...,....","_-"',,',. ~',~,_ ". .,;.,.,,'..._,'........__,." ._." """',' .__,,_.; ".-"'.~...."".-,,.~.--.... ,. ~ ~,,, _"~,,.....,._ ,.,,__~',w,......'...,."'_.'" ,_ """"," ", 2-inchline with standard pipe and fittings from boiler to mud tank wanigan. ----,'.,..'......--...--....-.".:....,~..... "''''--',,''',,-, ,." ,'....,,-, ·.._','1__,··,'_ '+0-'-'" ',~,...,.;>"'_,*'_",.__".,,, .',_, .~. .j --'''''".,',......',..,.,.¿,......,__.,.'''',.,'.....,.'."',.,, ...~_~~_,_...___, "M'" "$''''_''. .....,__......,'~"',,,. ,.to "--~.' ..~._.....',._, '''.. 't'___ ""M~' ,~ ...' " ~. ~ '.-'.".' ,. . ','-"," ,'.....··H.,",""''''....,.. Combination 1-1/2-inch and 2-inch standard pipe and fittings from boiler to rig; ','-->:. '-'" -_..,~ "._," ";", .~, . ,,' ,'. '..."', "...., '" ,. ," ""--"'''~,''- ~3 unit heaters - Derrick f1CQr level). (2 unit heaters in rig substructure). (2) l-i nch condensate return 1 i nefrom mud tank wani gån to B·oil er feed water storage tank. l-inch condensate return line from unit heaters on derrick floor and substructure to water storage pontoons on Derri ck floor. Note: 0.) E.P. Bowler. Assistant. Director Prepared by: J.W. Dalton . . 709-Db-25 5 Febr~arY,.J970 709-Db Preparation & movement of materials and equipment to ~lell site, including rehabilitation of systems. Using as much of existing telepho~~systelT1.{PR,?tatiºntqÇamp), as ,pr.acti ca 1 extend service fr()m"ç~r!1p tO~ª,}IO. ~.""Ir1.C:IY~ªt~:"~",.,,,, activi ation of telephone in ~lavy "oçcupi ed Jame~~J"élY,hu~j!LCª 'I1P.,.~~". ",-,,,,,,,,"_~,_,,,,_,,_,;,,,.,,-~,,,,,,,,,,.._..._";,t'.,. E.P. Bowler, Assistant Director Prepared by: J.W. Dalton . . þ .J 709- Db-24 5 February, 1970 709-Db Preparation & movement of structures & equipment to well šite;maintênance & operation @ well site. ',.,...~"~ ','..o~"__',_ ",.,,~~ 'c""-=."'·_,,",~ Perfor:l!'~g~neral labor work incidental to main objective; particularly suchr.~,":occuring tasks as fueling Herman Nelson heaters and fuel -.-,..;.;........~.-_.... ,; tanks 2~ vari ous \'Jani gans, general clean ~e~ .sno.~. remo~~.~_.~F..,'^:~.~~:., _.,"",..,.2i. ~.egs.~l, e tc . --_..~",..':""',".,:; <""'~'""''''\='';-'.'''''.,,,,~..-,,,,-=,,,,,,,,,,,,,,,,,.~,.., ._.--"-.....""",--,,.,.. ,.~.:,>"::..""".~~"'--,<-.,,,,,""'~"'~-~' -- ~';';'"c . -..{-i..--_-~:";;O'.-,;_",,~:_·,,:.';:';;;'O''=_.~_·.,..:c_~+'_<·,,~..:_:;;:;";<'<_,,,""_',<c,~~,,",,~,~ E.P. Bowler, Assistant Director Prepared by: J.W. Dalton Note: . . _ c> ?09-Ga-2 5 February, 1970 70~'7GaGeneral Acc(Junts. . RecordJªbor ~xpend~q in servicing and maintenance of equipment, (tractors, vehicles,and other equipment), used in preparation for,. and. dri lJingof_?outh_~~_.rror/NC?,~ 9. >·_'"':·,-:';-~-_;'7"_"··,· ·~"':"':"."","¡;;-C""-'"J-_·;'__,,,,"_'""_O<Wø_,,,,,,-,,,,",:..,~~,,",,-,,,_,~_ This work is principally accomplished at Pt. Barrow Camp. E.P. Bowler, Assistant Director Prepared by: D.W. Dalton . . 709-Dc-3 January 17, 1970 l09-Dc Rig up Install Water Service Lines Using residual materials from 1969 F.Y. Program to maximum extent possible, install water distribution lines throughout rig and auxiliary equipment and structures including valves, fittings, gages and controls: per sketches and drawings to be furnished. INSTALLATIONS INCLUDE 1. 211 fill line water storage wanigan (2 cylindrical tanks of 2481 gallons and 2205 gallon capacity) to receive hose discharge from tank trucks and ~'/ater It/ani gan. 2. 1 1/211 flow line water storage wanigan (pump) to: a. Boiler Feed Water Storage Pontoon b. Mud Tank Water Manifold c. Water Storage Pontoons (Derrick Floor) 3. From water storage pontoons (211 line) to HO\;JCO tanks - gravity f1oVJ. 4. From Water Storaqe Pontoons to hose connections on derrick floor (Opposite rotary table) (Check installed pump and piping system) r E. P. SOIt! 1 e r Assistant Director ~~ ~~~"~'S;;¡;'0Y':~:;;:;:;:;'~:~;;;"":"':,' ,:/''S~::;-::''~~ ~:",,:i~,~-.>_'> . c ~ F ~ , f t i t ~ . . 709-Dc-2 January 17, 1970 Rig up - Mud flow lines Using residual materials from 1969 F.Y. Program to maximum extent possible, install all mud flow lines necessary to drill the well. Including all assåciated valves, fittings, gages and manifolds; including: 8" suction line, C250 pump to mud tank (hose) 6" suction line, 7 1/4 x 10 pump to mud tank (hose) 4" discharge line, C250 pump to rig standpipe connection 4" di scharge 1 i ne, 7 1/4 x 10 pump to 411 outl et connect; on of C250 pump· 2" discharge line, C250 pump to rig 211 manifold, with branch to mud tank manifold. 2" discharge line, 7 1/4 x 10 pump to mud tank manifold, with branch to 2" outlet connection at C250 pump. 10 3/4" flOtAl line from well pitcher nipple to mud tank. Insulated and/or in wooden covered box where exposed. 'r-- NOTE: Plans and sketches for above to be provided. '\ ~ ......'.,\ .~ .\\ E . P. BOt-/l e}~ Assistant Director ~""""""'i·?~r·-"'-'·'_·~~';¡;>"'~~£__-::"~;7.:;¡;¡Z;=I<';r;::7.~:' '. . . 709-Db-23 .January 17, 1970 709-Db Recof)structttl1ltJ~r.. frame, canva?sheathed 1 e,an-to adjacent to JJO}!ǺoJ1.aDigan fQX'storpge and hanciling 9.f ce,ment. . --. C""·_'.'~'·'"'--'-'~,"·" ,..., _ : ..","._M-';""""~'_ ~=.':""'_":'_.=.,_..", ..',._,:-= NOTE: (1) Structure to be built on compacted snow embankment. (2) Use residual panels from 1968 program to maximum extent possible. (3) Approximate size 161 wide x 20' long x 12' high. .", ,r-- E.P. ßm'ller Assistant Director ~\~ . . 709-Dc-1 (Page 2) 709-Dc January 17, 1970 .PQs5ti Qn Equi pm~nt/StY'uctures/r:1ateri a 1 s qt No. 9 Location Assemble at site, properly situate, block up and level up the follm'lÎng wani gans and structures: . HOHCO Geologist Wanigan G.D. 7 1/4 x 10 pump Ke\'Janee Boiler 75/50 KW Generators Mess Hall - 1st Aid Sleeper Wooden Stairs (Derrick Floor to Pipe Rack) Ramp (Derrick Floor to Dolly Walk) O.F. Harehouse [\"1ud Tank Water Tank Wanigan Shop Heat /7' \ ~~\\.\'( \,-: \ \)~ '-- -'.~' E. P. Bowl er Assistant Director . . 709-Dc-10 JaI1Uary 17, 1970 709-Dc (Positioning of Materials - Rigging Up.) v!arehousing and hauling of personnel and materials from Point Barrow Camp to South Barrow Gas Well No.9 on a continuing basis, including: A. Mud, cement, chemicals ß. Construction materials and supplies, tools, parts, food C. Water for drilling operations D. Fuel, (Diesel oil and motor gasoline and lubes) XXXXXXXXXXI. Personnel '(t'1anhaul during drilling operations) F Ha rehous i ng '",- ,\~\, <OO~", _ ^,~' \ '\ '" --....J . .... .r- E.P. 8owlet~ Assistant Director _ ~. '--'-'" ,.",~_-. .-....-~~"'"'_..~--,'1<-:-""','>::.."'¡:;::::~.; . . NAVAL PETROLEUIvl RESERVE NO.4, ALASKA South Barrow Gas Field F.Y. 1970 Program Well No. 9 JOB ORDER NO: ;709- Dc-l DATE: .2 December 1969 PROJECT: 709-Dc Positioning of rig, auxiliary equipment, materials, and strÜctures. OBJECTIVE: PROCEDURE : The arrangement of, structures and wanigans will have the same patt·ern' as was in effect in the ·drilling and completion I:>f South BarrO'i/l No.·8; a sketchshowingth.e requi.red space relationship ofthevariousauxili·ary strucuures (wanigans) g1Jch as boiler, mud tank, pumps , etc., to each other and· to the· rig will be provided. This arrangement will permit optimwïI re-use of flowline . piping and electric wir:i,ngthat wasdismantléd on conclusion of S .B. No. 8 program. It is conducive to providing efficient use of labor in that engine men (mechanics) can monitor per- formance of boiler-quad engines on C-250pump,electrical system (switchgear is concentrated in boiler wanigan), and pumps, and "itðlving f·or water distribution, and while· so engaged be within close proximity to drilling ·crew. (};J -i CÈ/~-~P. Bowler Ij.Ss..istant Di~e prepa.red by J. n "7/) · \(1\'}.1 j)erJ);I¿ / 'jJ I ...o~ W. "Dalton PAl- TOtJ ''0 ~ -------- ------ ·' ~. . NAVAL PETROLEUM RESERVE NO.4, ALASKA South Barrow Gas Field J::.Y. 1970 Program Well No. 9 JOB ORDER NO: 709-Db-2l PROJECT: 70f..Db OBJECTIVE: Senice Water Storage Wanigan, CONTENTS: one cyl.tank, cap. 2481 ..l~.; Ou~ Gyl.t~&k, G~~. 2205 gals.; en. 8J.c_ poy&r-d centrifugal pu.p¡ one o.f. space h.a~.r; associated piping. DATE: Nov. 16, 1969 PROCEDURE : Insure that structure and contents are in good operating condition. Make fOllowing iaprove.ent: To each tank install sight glass or a siaple uncomplicated .ethod of indicating water level in each tank. E. P. Bowler Assistant Director . . NAVAL PETROLEUM RESERVE NO.4, ALASKA South Barrow Gas Field F.. Y. 1970 prog·ram Well No. 9 JOB ORDER NO: 709-Db-20 DATE: Nov. 16, 1969 PROJECT: 709-Db OBJECTIVE: Service/Repair - Ste.. Unit Heaters for Rig PROCEDURE: The noraal coaple.ent of ste.. unit heaters on Cardwell Rig is fi ve : three are used on Derrick Ploor and two are used in sub-structure (one with vara air directed toward B.O.P.'s - in cellar), one near rear of sub-structure with w.ra air blowing toward front of rig. At the present time two of the S unit heaters are situated on derrick floor, and three are situated in Bldg. 61. All five of these unit heaters should be serviced and such elect~ical and ..chanical repairs .s .ay be necessary to place the. in lood working order should be co.pleted. IX:I NOTB: (1) All of these heaters are equipped with explosion proof .otors and wiring and switch gear. (2) One of the five did not function veIl during 8.B. No. 8 progr.. (the one located closest to cellar), it was observed to operate at about 1/3 of capacity. E. P. Bowler Assistant Director . . NAVAL PETROLEUM RESERVE NO.4, ALASKA South Barrow Gas Field F.Y. 1970 Program Well No. 9 JOB ORDER NO: 709-Db-19 PROJECT: 70t-Db OBJECTIVE: ~p.iCial ð tr./a.~.ent - two joints of 7"-38' csg. and two JO At.. .,-5. 'ell. - ~...vc ru.t.n~ :i11 1<"". to improve properties relative to obtaining good cement job. DATE: Nov. 16, 1969 PROCEDURE: Using sand b1astinK process or wire brush treatment, clean up two joints of 7'-3" eSI. and two joints of 9-S/8tf o.d. ClI. - these will b. the joints first into hole when running casing and should b. positioned with this procedure in mind. . E. P. Bowler Assistant Director . . NAVAL PETROLEUM RESERVE NO.4, ALASKA South Barrow Gas Field ~.Y. 1970 Program Well No. 9 ~, JOB ORDER NO: 709-Db-18 PROJECT: 709-Db OBJECTIVE: She.the Cardwell Rig - Derrick - Drawworks/Bngine/Tank Compartment and ~ub-structure. DATE: Nov. 16, 1969 PROCEDURE : (1) Patch canvas on derrick - .any rips and openings to be closed. (2) Provide canvas panels on exterior of sub-structure - all sides extending fro. ground level to derrick floor. (3) Patch canvas sheathing - Drawworks/Engine/Tank compartment. NOTE: ae-use panels that were stored at conclusion of S.I. No. 8 progr.. to .aximum extent possible on item (2) above. E. P. Bowler Assistant Director . . NAVAL PETROLEUM RESERVE NO.4, ALASKA South Barrow Gas Field F.Y. 1970 Program Well No. 9 JOB ORDER NO: 709-Vb-l' DATE: Nov. 16, 1969 PROJECT: 70'-Db OBJECTIVE: Select and condition 160' approx. of 13-3/8- casing. s_ 1s located at "Point". j_....JIII Find two each casing cIampa for above and put same in good condit.ion. PROCEDURE: Prom .tocks at Point ..lect approx. 160' of 13-3/8" O.D. TIC cuing. Insure threada are in c¡ooà condition, clean inside wi th air I brush and <Jre... all threads and prot:ect. threada. Look for and, hopefully, find two 13-3/8- casine¡ c1ampa to use with above c:aainc¡. HDd,:þ;'''' -/~O /,;' C''',m:1 C'þ,.,? ~,_.,""~_\ ¥/ -.----''''.,~¡ r------ ''7 l!! . ·~-::Jl._../} E. P. Bowler Assistant Director . . NAVAL PETROLEUM RESERVE NO.4, ALASKA South Barrow Gas Field F.Y. 1970 Program Well No. 9 JOB ORDER NO: ia 709-Db-16 . PROJECT: 709-Db OBJECTIVE: Provide power at. S.8. no. 9 locat.ion tor 'temporary WI. W1111.8 ri99in9 up. DATE:NOV. 16, 1969 PROCEDURE : From exisUng power line, ¡>i\. .Ution t.o S.B. no. 7, provide temporary power for \188 while riqc¡!nq up - unt.il such Ù.. as rig venerat.ors are on 8i te and operaUn9'. Presume minimum line work and poles consiø1:ent with safet.y will be accomplished/provided and that .tep down transformer and requisite kind and quant:it.y of out.lete will be provided. E. P. Bowler Assistant Director . . NAVAL PETROLEUM RESERVE NO.4, ALASKA South Barrow Gas Field F.Y. 1970 Program Well No. 9 JOB ORDER NO: 709-Qb-14 PROJECT: 709-Db OBJECTIVE: Select: and ccmdit.ion 2500 ft.. of 7· O.D. 38' API R2 N80 TiC easing (I.D. 5.9~O" anC uu-~./t5Ø) DATE:Nov. 16, 1969 PROCEDURE: u.. all of above t.ype (qov~. ~~t!) casing that. 1s st.ored on "FAA" racks; make up the balance from privat.ely owned .-tacks at · Point" . Insure that. threads are in usable condit.ion, clean In.ide of easinq with air, brush and 91"41"8 all thread., and inst.all protectors on pin and box ends. Pluq ends'of pipe prior t.o 8et.t.inq on rig pipe racks. Check each joint of cuing .elected with Go-NO Go q.ge to precludemix1n9 any 7· 0.4. 28. caq. vit.h t:he 7·-3.t ceq. ~.t 1s requ1red. E. P. Bowler Assistant Director I ,1:- ~ . '., ,". '(.l: . :'.": ,~ "', là~' .,,,,~,~,,,.;~!¡ït;;¡¥¡~"~~F''''ft· :,¡~ j ,';: I' ;, ,'" :,' .." : ,.'y' .... :. ;,. J ;} Þ t,:· ~ ~~ " ~., ,'I. . 1 L [i f' .~ ~ , ~ , .., ::', " ." ,... .. :.', 0, . . ;. l;:~ ·;·.i :' f ~r';;:~ ,.!. .', .: . . . ..' ...:' ,... ;;','C:;,c ' :~'L > ¡ :';: ;:..., ,:~ '. ~,., ", '., .., ...', "', ,.,., " ~) 11/ .."". . i.,,,,_..,,,..; .,.,J.,.... .." .. ,,'..' , ", ,; :-. :":, 1:..t "';: . ;~',::,'»;,,:., t:~'i\ ',: ~:'; ,~>, c.':~:: ~::"> ~::, " .. : "..".'.".;:;;';'.' if, "'",,. ;:'~ ,~ . ,1 .::.:."..~'; ,'..... , . ::,"" ,:,. ':,: ,:... ., " , .... '.' " ... '..'. ,...,,, .. . "....". , ., ,...... , .' ". ,." '. :. ...., :.., . ;"··,,·;:.-:,è·... ' " SOU'pt.BARROW GASWEL::¡ N Q,,:': :";:, ;:;" ..,::::DRrLLI~G~P~?;G~;;ii:;:',:::::::·:;>,,,"~,~:,' '~'. ., ",~ :.E~,cL~r f~~~'i~~~2~~r;;:~npr~tft:J;~t~[1~ pun« l~'estimated: 'i6t<aboye '~iìà~Líevel,·'. ,.:;",';:. ';: ' .pY:~bus.hinJ~'" es ti.màted,~r~aboVe' sea leve1:":',:,, « ~~~~:"~~~=~~;d:IITi~/~:r~;P:~~":: : ", ,~~ ~.~:lnt~in~d:;fx¡;,~p,erat.:t "þ~itii)n.~::ät;~l:t, '~it~11~~t::~i!1~:E1;;i~:~~:~~~~~I~rh:, :;" ' E!ci~:: and the co~umn 01:.. fluid slUí.µ J:>ema:¡..ntained to.1 b.~sur- ,aè.~ :;~tdl,times ~¡paJ:ticular 11 ,wh'ilé ~ pulling the drillipipe .. :...f;"'J'~:·,~',N;:~\ :):::.~:"::,<:¡:~;r~'::¡;":d'·; ':' ./<: ·,·,,:·';c,c; .:' t:9rill'idepth: of: àboüt:. :2100' ~:conve.rt:to . 011 ,èmulSion .. type: mud (àb.Oi£;5 '!to 1'per·centdieselfu~1):'.~ Keèp drilling 'Inud,:d~tisH fio~~.1, 5 ,to"ao' poundsper'c~bièf9C¡'!='¡»~API . funnel 'vis,c:ositÿ;; ..fi, o\t<;>'.: 50.....~èconds and.water'loss.~rom SJ:o lcc.,or:less:unless. :" ~~~~s7~~i~ected by ~h~:, mud 'e~,~~~ee;r", if, one i~ p1: . Te~iWi~~~~¡f:Þrev,ert'~~f~';~~ter? \:ðht::~~~:, ~:i.~s~: tif6 S~J' ,~,,' per"day' the·resfter·;"" "::..; "', ,; , . {'. < :<, '~ !è ' i~t:'; :;, ~1.s~ff:¿i"¡f ~ r to surf ace k '. "..;.¡;,:.:,.,P.1..,".~.;':.;,;..:.an,~~,·.....:'.~,:su~:,a;c. e,. ,'. ~~~,_,.¡.Sing,: iràiJii~::';':~ck~,,:~-'~ ., · ~.co\:d of al1oper~c ndJ,itn~LSupednten,dent:·~Ç>.á .", þompletion. repott . after , co' :l~~,if~}tt, :~~.e.,,~~~+(,~~,~~:, :E;:\t· ":~,. >¡ c': '£'1,::' ~.:,;" .:'? drtilirig'program herein.'set: orth'may be ,ëhangedúpon· ';l: it~en 01:' ,ver'Qal instrùctions'·o( the Direct:or~ Naval Petro'" OU.;'Sh,alèi:'Resèrves ::.or-,hi u thoiized';?represen tãtive .~1~2f;£Vr ,i~,,' ¡]ti~":;"; ,i: ," d~~ream':àdequatè : '¿tòìi~; ~p~·~;~~~:j~,,~/"f;.de '. ~ "~·.1 G7,. Xf~~~ ;£f ,.~ '~~ " ,'~c,' ...., . .~ <~' ?: ~' C ~~ ". ~f~; ! " "j. .,:: C,, '.. .'.. .,; :,"> ': ~';':~ ," L<'~^: ,.". c. :~¡ ¡ ,,'. ,:" . ¡c.·..,' '? :.' .; : ,f' ",.. '<.~';',:, .. .,.' " -~¡ ~ .. ..,. ;., . , :~~;':: : ~: ". " },,~~¥~ ~)......,' .,J -, :,"J ".., "r -·t¡ ¡. , "' . ., .. ;; .. f -:...., ..:..: :~¡ ,'> ...:: .... ,C·'. ,... t '; . . :,." :::: . L : - .: ':. " ,':,'-- :.,. . . .:. .... ., ., :.:. .". .. .':'.. :;. '.,. ,.. " : ~ '! "~,;,,, .:, :~?,~~'"'; ,>,,:: j,¡.,,,,,,,,, - , ' ""~:-:¡~,Æ\}~t':«, ,'~"-", ,..:,~~ ':. i!8f\:'~';> :::', ;-:i' ., .. : '.',: L7~.":"(X::'~' .:;..~.:. "..., :¡i: -:.,'. : -.;: i:;=':. ,.. ,,' '-:: ,- :,,:. ,:,. I:f~C "..:,::.., '.:.~' :-;;,; -. .,., .,:.,.'. C·" .,: :': '>;~<';";:'.. ' " ," ,. ", ¿,: .'",;- ," ',~ -,' :.. -:: ' '.', '>" > '.:--:.; :.' ,. ,..: :,' , .; ,: , .' ..:- '..';'.. _, pipe~, about"~60', ~' .1'''''' ,_., do~ :(tf~f1:;' .: ... ',' ..'. .'~ -: ... ,:;. ~:,,;, ::~:'\~; '...' ',.':. ,..-' .:, :,,:' '. ...... >:' .,' <: ',' ,'.: ':":,..; , . 'UU}"; ,^Y;ð rì"~ ¡." :..:.... ';;:":cêmeñt~1th3% ',~ ...:- ;-....., .' ;,. .. " ' ' . , 8~::F..for·:pe~maf!C)st:' ·~"l· ,.-:",,,. .",,~. '~"-':~ "' ::~.; '.:, ;;;¡ .,. .:¡;:, .., '; 3/8" O.~.: .,.. '" ~ :1 ;. . '.,.;;" ...!~t::.¡;- .._.;.:,.' : ." ..: ,. ...,' :'. ..""":. :,.... ,.;..:...,::;, '.. - " ':r,:'Js .'. :..:: ".;"".,., '~;'- " l.: :: ,..; -- '~, '~;;'t.... ',' .~, '~'.. . .,' .... :',' .: :u i" :,." " ';,"',. ~' 3" .,.,'.: ._;;" ,;....~..':., ~ ~~ ;,;. ·;i,'· h:U é ,," ," ',,' '... ,: ',,: :" ,;., , ,', ','" ',.,;, ,~,._,. ':-;:7 .ano:'c' c,,' . ,~ .,C,'" .' .,.; ..,." > ::: : .,; ·'.7 :.' :',5: '.;i.. :'¡.~ ,... ..;¡.. :. T::- '..:: _..~ ,~~ ':t,\ .:~'~-;." Ii.¡:;().,. .' ".'> '.....j jp<"; ''''": i. ·'·C· ~IH '....i·. . .,' '.' . :: " " '.'.' ..c.. . :' ':. .".. . -. .,>^ a t:. '... -....'.'.. ..... og~_ '~ ; Ì'!. ~.. " , ,., . ",,;,'1 or k " ... .. ":: :~~'( N~80 i .; <; f'lY '.",. .' ' . ". , .- - ~. ... '- :-;: . . "C'.' ,-. ::' ,~. --, .1:: ,.:<',' '... ';';' ..: ::' .. .. ..;, 'i:: .~. .; . .... :;; ., . .': ... T-' ,- l.';:' .'·CO..l . .. .'.,. ";',':-"'. " '};ji ':.... .:'~ ,..":'" .. :-',- ." :2 :' ~~~i2": '/' ,fr. . "Fi'·" ., ~ ' ::;-;': :;';':::':', ., :! · ··F.,.',· '. ..'.. ,,' .,;. .L·,';·;':'::: ,'c'): ."O', ...., !:',. : ',' \:.,~!.: ":. :\::::.:' :'~:::::.. ,,:.J,:' ..;.':::,.. :,.. . Q~~~:J . . i. ;,. {: ,'. .; ~" ., .,. . t·~. '.~-:,. ~.': 1-S\/¡),tr.:&?:.:~;':~ "ex f .t , ! . " , ~ i ~f; t· :, 5 ¡ . Lj~ ;\' ¡"..;-''''''~ , ,. '~ :: i, :" ,.,. ., >'.':" v;", . ",¡, . . "":,:·,i.L~. '" .'...,"',:., .,.:: "' : ,::,,' ..,' .', ., ;';, ". , 'J )(k m¡,~':i: '. . ,..; .. ,";;':' ~ . ·'C ...... , ,..... ~;¡ ;;', ~,:' ;; -,;" ·nm '....1 '"'".., <: ',;:"'.".'. .:;","'),., .:,. :;-~, <~-, l~~~i~~~~:~;~ .., .",'~''';:> .', }~T'. ~þ, ~ ~;;~ .,.', :.,..'.: " .. .j ~ ,'.;' , ".'..(,' ~., .,¡ ';''., 'c·, ...', :-: r~Yg:':;:",: . ,·r ....'\.::., .,.'" .. '.,., 'c. ..:, .,'. ;.:. ; ':.".. ,'.: . ':", ;,; :, .'. 'hi> ,':;; :')/ '...::.". .:, :......'.: '. ,:.; v . ,. .:.'" 1'\ ... .. ,', " . .r ,.¡, ,. c· . -:::,~: c, ..:).. ,;<~i " .'. ::~. .,,~', '., .., " . , ,-c.'.'; ,~..; ,_'.':"',':. '; ". _..'~ ' ;,:: : ,...:. ...n;.'·...'..', ,. . .. .. , c.. .... ',... ;c· .,', " ,::, : -.. - c. ' ... . .., " .". c,. ..;'.." :. .... ',; ., .O;:.,i·' -::.:- '., ·"·'..c . r~~~;~ .. .,:c'.., " .. '. .'.. 'C' ,.,. ;r: I: '/ ·i.'::"'",;:' ::::::=:::::' ,,,.,." . ',. ,.' '" .c,..'.'. A .{'.[:-=:.:i;¡;;~] ...: .'.. i··· .,. :lj '.' L :.: ..:-;-. ; , ;: , .' ::::":" '."'. :\, .. ,..··i.. ,',. :..,. ,,< :',: <>~" . J' '.':" " .) " ;;'. \. , .C,"'·.] --,. :/ ~.. ..". .. : :.,., '~ ". .. :j' .'. ... .",,".: '7' :,; ì .¡ : i ,~......,..- ~~ ~:.' ":t~{~:o:~.w;.;-;v-:-~~ ;'I".... ~ ~ "'="«:":;..?J"'-a . ~. . NAVAL PETROLEUM RESERVE NO.4, ALASKA South Barrow Gas Field F:,' Y. 1970 Program Well No. 9 JOB ORDER NO: 709-Db-lO PROJECT: 709-Db OBJECTIVE: Repair/service Swivel (EMSCO type AB-4 SN 58) DATE: 4 November 1969 PROCEDURE: Procure: 2 new wash pipes complete for above,. 1 new goose neck with gaskets for above, Wash pipe packing for above, 1 set bearings complete. Disassemble swivel and install a new wash pipe and new bearings (if required) - also new goose neck - if latter deemed required; insure that packing is lubricated, not put in dry. E. P. Bowler Assistant Director . ~# . NAVAL PETROLEUM RESERVE NO.4, ALASKA South Barrow Gas Field ~.Y. 1970 Program Well No. 9 JOB ORDER NO: 709-0b-9 DATE: 4 November 1969 PROJECT: 709-0b OBJECTIVE: Service/repair Generators: (75kw unit w/Cat 013000 Enqine, ßN lF7l50 (50kw unit w/Cat 08800 enqine, SN 2833235 PROCEDURE : Inspect enqines and qenerators: Repair/service as required. NOTE: Some mechanical troubles were experienced with each qenerator durinq S. B. No. 8 drillinq proqram. In one instance the couplinq between 013000 enqine and 75 kw qenerator failed and was repaired. In another instance enqine trouble caused temporary shut down of 50 kw set, and the plant was restored to use by rObbinq parts from an unused similar enqine in camp. Considerinq these plants are used in other proqrams and that no thorouqhrepair job haS been done on them since prior to the winter of 1963-64, continued use requires capability of repairinq both plants on an emerqency basis. Therefore, in lieu of complete overhaul of electrical and mechanical components, the following procedure is to be followed: Insure both plants are in qood runninq order ateary date (Oec.1969), search out source of spare parts locally or from rearword locality to where same can be delivered on quick notice (like in one day.) NOTE: As a new 50 kw Caterpillar qenerator set costs $6,000.00 it may be more favorable to buy a new set than to qet into a major repair proqram. E. P. Bowler Assistant Director . . NAVAL PETROLEUM RESERVE NO.4, ALASKA South Barrow Gas Field F,.Y. 1970 Program Well No. 9 JOB ORDER NO: 709-Db-8 PROJECT: 709-Db DATE: Nov. 4, 1969 OBJECTIVE: Repair Service G.D. Pump System: (i.U. pump ¡-1/4 x 10, Mod. J:'-O-J:"XO-E, SN 109094 Caterpillar Engine Mod. D13000, SN 353244. PROCEDURE: Inspect and service D13000 engine. NOTE: At end of S.B. No. 8 program: D13000 engine in very good shape - nuses no oil, has good oil pressure, no leaks in oil or coolant system, starting engine in good shapc_" Pump power end: "Good condition." Pump fluid end: "Poor condition.- Inspect and service or repair as required the power end of pump. Note the repair work accomplished for S.B. No. 8 program. Inspect and effect repairs 0 n fluid end of pump. Repair/replace defective parts. Also locate and assemble all locally available spare parts for GD 7-1/4 X 10 pump (power end and fluid end) ready for use and for preparing supplemental parts order. I,-! (., ¡,__f f-" E. P. Bowler Assistant Director . ~: . NAVAL PETROLEUM RESERVE NO.4, ALASKA South Barrow Gas Field F.Y. 1970 Program Well No. 9 JOB ORDER NO: 709-Db-7 DATE: Nov. 4, 1969 PROJECT: 709-Db OBJECTIVE: Service/Repair HOWCO Cementer PROCEDURE: Notes on condition, May, 1969, as follows: Horizontal pump - fluid end - Left in good operating condition Filled with diesel fuel. Vertical pump: fluid end - Left in good operating condition Filled with diesel fuel. GMC 371 Engine: GMC 471 Engine: In good condi tion. Poor condition - see notes below. - Torque Converter: ) In good condition. Mod. DF 100 21 TC ) Spec. No.90552 SN 43041) Repairs required GMC engine, Mod. 471 R-C57, #471-30476: Complete rebuild job - incl. new crankshaft, carn shaft, new bearings, pistons and liners. Replacement parts include: 1 ea. crankshaft assy. stand 15152743 4 ea. washer crank bearing thrust 5159353 1 ea. seal crank, front 5151392 1 ea. seal crank, rear 5150846 5 sets bearing shell crank 5152918 1 ea. gasket flywheel housing 5150054 4 sets bearing shell rod 5150106 1 set gasket kit head overhaul 5191934 4 ea. bearing carn & balancer end 5158922 4 ea. washer, cam end thrust 5158917 6 ea. bearing carn intermediate 5150025 1 ea. gasket, balance weight cover 5150071 1 ea. gasket, oil pan New liners (were in stock. at Barrow, May '69) New pistons (were in stock at Barrow, May '69) (continued on page 2) E. P. Bowler Assistant Director -1- ot-"2... . ~F . NAVAL PETROLEUM RESERVE NO.4, ALASKA South Barrow Gas Field E:'Y' 1970 Program Well No. 9 JOB ORDER NO: 709-Db-7 (page 2) DATE: N9V. 4, 1969 PROJECT: 709-Db OBJECTIVE: PROCEDURE: (continued) Fluid End Pump,: Gave satisfactory performance during drilling of S. B. No. 8 All the existing parts at Pt. Barrow should be located and assembled in one bin in 'Warehouse No. 61. Additionally, a supplier (HOWeO - Jordon Supply Co.), should be contacted re availability of replacement parts for fluid ends. Due to the age of this equipment it is anticipated that parts supply may be difficult to obtain. Mfgrs. nomen- clature is as follows: Mfgr. Date: Mfgr. Date: Horizontal Unit w/tank: 4CG-2097 Vertical Unit: 34B-2095 E. P. Bowler Assistant Director -2-of '2.. . ~. . NAVAL PETROLEUM RESERVE NO.4, ALASKA South Barrow Gas Field F..Y. 1970 Program Well No. 9 JOB ORDER NO: 709-Db-6 PROJECT: 709-Db DATE: Nov. 4, 1969 OBJECTIVE: Service Drawworks Engine Cat D8800 SN 6S7648 and Drawworks MECHANIC'S NOTES: RE d8800 Engine at end of drilling J?ro¡ram, S.B. No.8: ~: . Good running condition: uses some oil when idling, oil pressure very good, no antifreeze leaks, no fuel leaks. Starting engine O.K. but hard to start when warm." PROCEDURE : From the above informed comment - and the fact that the engine does not have as much power as one would like at maximum drilling depth - it is believed that the repairs/ servicing should be concerned with governor function, check for maladjustment and replace worn parts, valve guides (possible leakage), and possibly complete head job. Also intake air system should be thoroughly cleaned. Inspect Chain Drives: Rotary table and Drawworks. deficiencies reported S.B. No.8. Inspect Break: No deficiencies reported S.B. No.8. No Drawworks: Inspect/Service:. No deficiencies reported S.B. No.8. E. P. Bowler Assistant Director . . NAVAL PETROLEUM RESERVE NO.4, ALASKA South Barrow Gas Field F.Y. 1970 Program Well No. 9 JOB ORDER NO: 709-Db-S PROJECT: 709-Db OBJECTIVE: Condition Boiler (Kewanee Fire Tube 3S HP series 3X No.S'8) DATE: November 4, 1969 PROCEDURE: Condition/Service Kewanee Boiler (at Pt.Barrow Camp) to insure that when this equipment is towed to location and positioned adjacent to rig that it is in good operating condition and ready for use. NOTE: (1) Items that will require special attention include: (a) Burner:insure same is operative and that requisite replacement parts are on hand for emergency use. (b) Electric centrifugal feed pump. (cracked housing- brazed during early May 1969). (c) Fire box - insure same is clean. (d) Standby "Penberthy" injector: insure same is operative. (e) Tubes - insure same are clean. . (f) Pressure gages - insure that same operate properly. (g) Popoff valve - insure same operates properly - pops off at 100 PSI. (h) Electrical controls. NOTE: (2) Previous experienpe with this boiler in instances of drilling S.B. Well, 17 and i8 was to the effect that some time consuming deficiency was encountered about the time boiler was fired up for use. E. P. Bowler Assistant Director . ~.'I<.'.. ~ -~' ',". . NAVAL PETROLEUM RESERVE NO.4, ALASKA South Barrow Gas Field F.Y. 1970 Program Well No. 9 ...~. JOB ORDER NO: 670-Db-4 670-Db DATE: 31 October 1969 PROJECT: OBJECTIVE: Load two rig pipe racks, in accordance with sketch to be provided by locaJ. Navy .tœp, wi't.h follow1ny L\2Lula..L qoods: PROCEDURE: (1) 5 joints (approx. 150 linear ft. total) of 13-3/8", 54. SOt, C.S.G. T&C. (I.D.-12.6l5") (From C.O.& G stocks at "Point"). (2) 1000 ft. 9-5/8A O.D. R3, 401, N80, eSG, T&C from c.o.& G stocks at "Point". fir pn-lnfahfJ )/AVY OWl?ed .s+Oc.Ir:.s (3) 2500 ft. 7" O.D. 38i, T&C, API N80 R2 Csg. I.D. 5.920" D.D.- 5.795", from "FAA" pipe racks and, as required to complete the total quantity, from c.o.& G stocks at Point. NOTE: Check .all 7" Csq with the Go-No-Go qaqe and reject all but 7" - 381 esq. - (4) 2500 ft. about 125 joints 4-1/2" API F.B. drill pipe, Rl, residual from S.B. No.8. (5) 80 jts (2500') 2-7/8" Hydril tbg. 6.5', R2, E.U. from PAA . racks - fill out from "Mona Lisa" racks. (6) 6 jts 180' 2-3/8" Bydril tbq, R2, from FAA racks - fll1 out from Mona Lisa racks. (7) 120' 5" O.D. slotted stream line, liner, flush jt. Sec. the from FAA racks - fill out from Mona Lisa racks. (8) 40' 5" O~Ð. blank stream line liner, flush jt. Sec. the from FAA racks - fill out from Mona Lisa racks. -(9) two 7-3/4" O.D. x 30' drill collars, 6-!/a" API Req.box & pin. Four 6-1/4" O.D.x 30'drill collars, 4-1/2" I.F. box & pin. Four 4-5/8" O.D.x 20' drill collars, with 3-1/2" RJ tool jts. All above drill collars residual from S.B. No. 8 (10) one NEW Kelly 4-1/4" square x 33' w/4-l/2" F.B. pin down & 4-l¡yr-API reqular L.B. the box up. (l~) 11-3/4" rat hole pipe (resid. "crDOked one" from S.B.No. 8). E. P. Bowler Assistant Director . ~. . NAVAL PETROLEUM RESERVE NO.4, ALASKA South Barrow Gas Field ~.Y. 1970 Program Well No. 9 JOB ORDER NO: 709-Db-3 DATE: 29 October 1969 PROJECT: 709-Db OBJECTIVE: Replacement of stoves removed from Auxiliary ti L.ul\'1.U.Leti Ly .r-,J:,CO PROCEDURE: Procure!? Seven each oil fired space heaters, 50,000 BTU/hr capacity with carburetors, and with necessary quantity of 68 draft regulators, 68-90° adjustable ells, 6" smoke stack sections (all qalvanized). NOTE: Prefer plain ruqqed serviceable space heaters wi thout electric fans, wi t:hout thermostats, without attached tanks. E. P. Bowler Assistant Director . ~: . NAVAL PETROLEUM RESERVE NO.4, ALASKA South Barrow Gas Field I:.. Y. 1970 Program Well No. 9 JOB ORDER NO: 709-Db-2 DATE: 28 October 1969 PROJECT: OBJECTIVE: PROCEDURE: 709-Db (1) Set pipe racks (four) and dolly walk on appropriate timber Þ~ockinq on ·window" side of Derrick. Sketch of location to be provideC1 Þy local Navy Rep. (2) Set ~o additional pipe racks now at rig site in area (selected by local Navy Rep) for intermittent storage of tubular goods during F.Y. 1970 drilling program S.B. No. 9 E. P. Bowler Assistant Director . ~~~. . NAVAL PETROLEUM RESERVE NO.4, ALASKA South Barrow Gas Field E;.Y. 1970 Program Well No. 9 JOB ORDER NO: 709-Db-l PROJECT: 709-Db DATE: 28 October 1969 OBJECT lVE : Relocate access road to S. B. No. 9 PROCEDURE: (1) Stake access road from existinq road (Beach to PR station); to S.B. No.9; use same location - includinq same 4 n gas line crossing - as used during winter of 1968-69. (2) Grade access road with steel/drag/motor patrol to proVide snow surface suitable for use of wheeled vehicles. Stake road at 200' centers in conventional manner to facilitate use during bad weather. (3) Provide maintenance as required for above access road during F.Y. 1970 operations. E. P. Bowler Assistant Director . . NAVAL PETROLEUM RESERVE NO.4, ALASKA South Barrow Gas Field F.Y. 1970 Program Well No. 9 JOB ORDER NO: 709-Da-2 709-Da DATE: 25 October 1969 PROJECT: OBJECTIVE: Grade Riq Area PROCEDURE: Drag and grade area surrounding the rig to provide a smooth snow surface for placement of pipe racks, auxiliary structures, and parking/storage space for equipment and materials. NOTE: A plot plan of rig site showing location of racks, wanigans, storage space for equipment and materials will be provided by local Navy Rep. E. P. Bowler Assistant Director . . NAVAL PETROLEUM RESERVE NO.4, ALASKA South Barrow Gas Field E.:.Y. 1970 Program Well No. 9 JOB ORDER NO: 709-Da-l DATE:October 24, 1969 PROJECT: 709-D_ Install Cellar OBJECTIVE: PROCEDURE: Excavate hole to contain S'-O" X S'-o" x 4'-0" deep (I.D.) timber frame cellar. Fabricate and position using 3" x 12" or 4" x 12" timbers. No bottom (floor) is required. Back fill with embankment mat.erial. Timber frame structure is to be centered about exist- ing conductor pipe. NOTE: 20" conductor pipe cemented: May, 1969. R1g gravel fill pad completed: May, 1969. Rig guy anchors/guy lines completed: May, 1969. E. P. Bowler Assistant Director "'··;'..·.r"".~ "'__ :1 (J , i'···,-,t .>'"'''"''"''......-.'''..--¡-..''.. ..', .......:.:;;;...~:...:;.:^'~>.,..^'~~.,;.,.,..,........;.~-\ I ¡;r..... .........·."C"-~ _.-.... -' .- ",-.-.^. . '.. .. ..,.' .-....------ '. . í- '¡i; '. ¡ f...,,"""........... ......... .. ~=n,"". c. ,c> '.. ...~,,~~.Jt:.) __. ·".·,.·~"._.1P"'.·~~'f '"''Ii'~ /"""'; i·.¡ t; ~, íK tt"'_. ~..,,,i· ..,.......".,;,..;.;''1 r ...' ,.'. f ';.'~ . ,. , "';_ , c. t .;'.,- ., '. ~ L., ~ ,,, \f .1 . h ::> C, (.¡I ~ ¡ ·F';" 2 ?A.ut 196L NAVAL I'ETh'OLt:lJM AND on. ,';HALE RESERVES WASHINGiON. D C. 20360 f2~¡ yj (.¡q r,~ i:,~~ Ii [;;¡ t1 n !-:·:î !! î' ¡j 1'9 Serial: M~. Thomaa R. Marshall Petroleum Supervisor Department of Natural Resources State of Alaska 3001 Porcupine Drive Anchorage, Alaska 99504 F) 1'" IA ::; 'd ;$ \'1 r,j t" ~ [:1 l,~ ;,/ Q ¡î 11 ~ \1 ¡~' r¡ ~ I I Dear Mr. Marshall: Thank you very much for providing this Office with two copies of your current oil and gas conservation regulations. With reference to your request for a well completion report on the re- cently completed gas well in the South Barrow Field, I am pleased to advise that it will be forwarded to you under separate cover as soon as possible. In connection with your comments regarding drilling permits, I must decline to accept your premise that such permits are a prerequsite to drilling operations by the United States Navy in Naval Petroleum Reserve No.4. While this Office does not intend to apply for drilling permits prior to conducting future operations on the Reserve, we do desire to cooperate to the fullest extent possible and will, therefore, be happy to furnish information ordinarily required by your regulations. Sincerely, ¡ ¡ HOWARD N. MOORE Captain,JAGC, USN Director 0,..' r .r< \- "' \ I r ...' 1_ ~ :>"" ~ .~} f!.... ~, i.. '-- l. ¡ v L f\LJ G :¡ n 1Bß8 O¡VIS¡()J'i (jr 0ji1¡"1[,~3 bA¡t",H~P/\l3 ¡'J.h"l ') ('¡ : \;.).......; ,. :,~·h..:'. .,......~~~ . . "Old" .. I.a,,)' \';ells (1944-53) Well Name Avak -, IOO-Of}"?- South Barrow-l /00 -083 South Barrow- 2 100 -ö¡}'-! South . Barrow-3 laD .;o~ I South Barrow-4 I Ó OtOólG. F:i:sh Creek-lIDO -)cð j GJiandstand-l 100 -<þ5"-..3 - I Gubik-l fbb-.fJ:) I ¡ I Gubik-2 I DO -:):J ~ . Kaolak-l IDO -f)':;)~ ' I Knifeblade-l J(JO - /t9. / YJ1:i:feblade-2 J ()D - .~c9 Knifeblade-2A ì:s "'ow J.(,,¡Pe.lokw'e 6- 11eaåe-l OU1'nalik-l I DÖ-fl<! Eas-t OUInalik-l IDD -116- Simpson-l Il>O-I"'~ NlJiI"fh S/",p'::þq-I }OD..-Dlf" Squ'are Lake-l J 00 _//(, Tita.luk-l 10ò-IQÖ Topëlgoruk-l Joe -tq fJ j i Ea~t Topagoruk-l lo:J-tOIt) Umiat-l IOC -QC:/1 \. 1 .. Umiat-2 Jot> -';)/0 UmÚit-3 foo-C}.II Umiat-4 100 ,é)f;J Umiat-S / DO -~H3 Umiat-6 tOD -;;'1<1\ Umiat-7 If:;Ó -é)/~1 I Umiat-8 lOP -dl~ j Umiat-9 ¡ðD -Q/1- j Umiat-lO tDD-é)I1f Umiat-ll lDO "'G/'7 I. Wolf Creek-l I ()O-~ I ~ Wolf Creek-2 IVO-:\ (?5 ! Wolf Creek-3 J(i)-ì I&) ..., ._--,. -~,.__.-.". .-.-. ~ .... ._~, .~--...-._._-, .--- ~ , .. ~ 1 ~ , t J - J j I , . "Intermediate" Wells at Barrow. (1955-1974) , - South Barrow-S ID6 -t);;)1f South Barrow-6 100-0:;;/1 South Barrow-7 16b'-0"3D South Barrow-B l06!-031 South Barrow-9 IOO-tß;J. South Barrow-IO Idj-a33 South Barrow-ll I($) -63J.( South Barrow-12 /óO-ð~ .~ í I t ~ . . __.__'. ..__..._~..._. __" ~n .. .~,,_...__..__....__.. 'i6 EXPLANATION . OIL WELL ~ GAS WELL . OIL AND GAS WELL + OIL SHOW-ABANDONED .:q. GASSHOW~ANDONED .. SUSPENDED GAS WElL . f OIL AND GAS SHOW ABANDONED ~ DRY AND ABANDONED . SUSPENDED OIL WELL . ~ , - , .- , ',~ ... BIARROW ARE~.......... , ~,...~. TULAGEAK I S.BARRO . . ;"~~~D SE I WALAKPA ~ 1Kb BAYr't" i . SIMPSON I , C A " , . . , +. i"ALAKPA 2jfF- ~. . .~ ,-'~, ,," .~. SIMPSON ~2 J. W. DALTON I ~,. I I -. <U,(A~AK J ~ .1' t· É. SI~PSQN.l_... W. T FO~AN I ULL CLI,FF .-""" .. SIMPSON I. t.". ~ f . . . '~... .: ' . "'? -'. ,(~ =x £. ~~~W - . ~;fêCÅPE HALKETT I PEARD t ~,. -.L. 1, ',' -~, ~ r \~- ~ k POINT I """'tJ . ........ ..' r' 'f ~ S. SIMPSON ,. ~ '... . . ~' - _J._. . :r9fAGORUK ~. ~. " r - t:!t.......; . TESHEPUK~ ¥2-' ATIGARU ! ' KUGRU'A I r-J~'- 4} ~E.r¡;fi0P, J~UK I ''''.t....,. ".. . ., POINT I.... ' -+-- -r . r t . I . - --'. "-. '" .. '" -' . ( PIKPUK..l. ?=,"". ...-~ HARRISON i L h-~--,. ':\,. S.MEADE I; . ., . '.* ''\S'c- .N. KALlKPIKl /~_",,...: BAY\! ~' i ·T~}-·' L, ,'tit:"", () 'F! \- .y. , ,vtFl,HCREEK!¿'L§¡f; \ j ./f ~,.-..'_.,-+--.~--~ --. :"\..' '. ~. ~'.~." ...·N:INIGOKi."'*-£i·?..:J:'~¿RH.EEKµ, /'/ .~ :)"^~'KI ~ ' , 'n~ ~- . ''!-- t ~ ~1 ,,',',' ',:J )'¡;l~ j ;' -.. . ---..:,!" -' .~-~~---.:- =~-~ -;;:::.: ~. ·..c.l~ I ·.~G.~S :. ~. I.NIG.OK'I +1 _ ITKILLlK~ -. +þ::="""'" --- -- -----..-~~- ~r-'- .-. t:~~ . "~ + y , .f\lVER 1 I t, ... --"-'--:~~~~ ~ -- - - - +- . . ~. .,~~. I \ . . _(In~stry) I ~, T- .------.-..,...~. RUMA.JK I ~ " . \ I r~~ \~.---~_. -. -.. . +--. - -. . . .y. ¥f. .OUM~~~KOWKT~K I. _ .. ,. \ ¡; l I ~ i' '··T'''· l~ r' - ¡ '.. r-· . ,-"-. , .. '. ......1. -.. ....-......;" .:' . \ .SEN1mEt I L' ~, ',' .,-.J"; .rt.;.. + "'!L.,~,~) '~~.I _.; ~. .' . 7 . ; . .. . """""'-, S.Q·UA~E, . l ..Æ1 I .....r'~···. , ) ~ . . .__~ "IS .-~-- . ..~-+---~-,- '.. '.... " ' . { . . . . ' y LAKE'I--~. , GUBIK t~-T:' _.-,~ --j ,-1---7 ·--:fT.l .:".-:->" ..ÇjTITALtlK~ ~~~F~' ., S~,A~EE,.I ...·....&...I , ,', '-:...".. . --.. - - -'--r-- . .. . .(b . ·0 \y I 23 _ ,....--7 UMIAT T ~- , . "\ . . I.\... r'- t. . .. _T AREA GUBIK . i !'. - (;",~/~i__ .' " . ~ . :!j . .' ·.t . . .. --/'- . 2 · r ~l_L.F'd,' ~ ..'. t'WUNA I , ;! ,._~;?i::'3--/, 4- --j. ¡ .r--'"' ! ~~,:","'-'è'-<-':~l .~. ·:r 7 GRANDSTAND 1 ' ,:.: -t -. -- . -- . . . .'v--.'.!:~_.' ~.. ..~. I ~'. .~,.; ,. - '.. b . i ".- '. ~---=-- . i r-· , (-1 -- ~:.-.. . .' '. : : :: . . : <.: . . i r·'···,·..·...-.._-.-_-L . ì " ,~ ,-. .' . . ',. '¡......... .. I : I ~-.·ì""-· ~~ .,..( ." -' ..~........' . .', I,'v '" ~~ "" .... __ I \; ....'\.~~ ¡ . . G~ . .. . ~LlSBURNE I t.k-.n ~~.~_. I 5PMi. ! \<~~ _f\~~'. i 15 Km. 001.,0 O~O --t:,! ep ¡ \: I J.. .. ~___ --r-- '"--~,- - --..--.------...-....- - I-~ f C It G þo o C E" 4-1' + + . . , , " " . , tI I o I 25 , ¡;;;:¡ T.T"A T.CHo INC_ l!!J~ PIII:M'I' -- - ....- INDEX MAP- PET-4a NPRA TEST WELLS AND SELECTED COHE TESTS. 1944 - $3.1914 - 81 ALASKA .HPR ò 25 5'0 ~ _._-.J.W.BRUYNL"","¡-:Ï",;,-:-- 'I "~·"-··'E.C.~ .=..." --~-:. -- . "TErRA TECH REPORTÑÕ~82õõ'-'- I~ -¢- + .. . ~ ~ ~ ~ ~ ~ ~ -V- *" ~ ~ -<:>- ... ~ ~ .; I- ,+ + ; . . ; -+- . ; ; -+- BARROW AREA I ARCON BARROW I S. BARROW I S. BARROW 2 S. BARROW 4 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 \6 S. BARROW 17 S. BARROW 18 S. BARROW 19 S.BARROW 20 AVAK I UMIAT AREA I rb cO <::::) \ ~ o UMIAT I UMIAT 2 UMIAT 3 UM!A T 4 UMIAT 5 UMIAT 6 UMIAT 7 UMIAT 8 UMIAT 9 UMIAT 10 UMIAT II FIGURE 2
