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185-314
1a. Well Status:Oil Gas SPLUG Other Abandoned Suspended GINJ WINJ WAG WDSPL No. of Completions: 2. Operator Name: 3. Address: 4a. Location of Well (Governmental Section): 4b. Location of Well (State Based Plane Coordinates, NAD 27): 5. Directional or Inclination Survey: 6. Date Comp., Susp., or Aband.: 1b. Well Class: 7. Date Spudded: 14. Permit to Drill Number / Sundry: 15. API Number: 16. Well Name and Number: 17. Field / Pool(s): 18. Property Designation: 19. DNR Approval Number: 20. Thickness of Permafrost MD/TVD: 21. Redrill/Lateral Top Window MD/TVD: 8. Date TD Reached: 9. Ref Elevations: KB: 10. Plug Back Depth MD/TVD: 11. Total Depth MD/TVD: 12. SSSV Depth MD/TVD: 13. Water Depth, if Offshore: GL: BF: Development Service Exploratory Stratigraphic Test 20AAC 25.105 20AAC 25.110 Surface: Top of Productive Interval: Total Depth: Yes No(attached) Surface: TPI: Total Depth: x- x- x- y- y- y- Zone- Zone- Zone- Submit electronic information per 20 AAC 25.050 (ft MSL) 22. Logs Obtained: List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data within 90 days of completion suspension, or abandonment; or within 90 days of acquisition of the log, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page only if necessary. CASING WT. PER FT.GRADE TOP BOTTOM TOP BOTTOM HOLE SIZESETTING DEPTH TVDSETTING DEPTH MD CEMENTING RECORD AMOUNT PULLED CASING, LINER AND CEMENTING RECORD23. Yes No Yes No 24. Open to production or injection? If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd or liner run): 25. TUBING RECORD SIZE DEPTH SET (MD)PACKER SET (MD/TVD) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic information DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED 27.PRODUCTION TEST Date of Test:Hours Tested: Flow TubingPress. Casing Press: Oil-Bbl: Oil-Bbl: Gas-MCF: Gas-MCF: Water-Bbl: Water-Bbl: Choke Size: Gas-Oil Ratio: Oil Gravity - API (corr): Production for Calculated 24-Hour Rate Test Period Method of Operation (Flowing, gas lift, etc.): WELL COMPLETION OR RECOMPLETION REPORT AND LOG Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 2/19/1986 50-029-21520-00-00 PBU 04-26 185-314 6232' / 5494' PRUDHOE OIL ADL 028324 70-03910866' / 8880' None 1900' (Approx) N/A 0 12/4/23 N/A 3/8/1986 ASP4 ASP4 ASP4 5951975 5955672 5955768 713256 716503 716644 DIL/ Sonic/ GR/ SP, DEN/ NEU/ GR/ Cal, CBL/ CCL/ GR, Gyro 3785' FSL, 1352' FEL, Sec. 26, T11 N, R15E, UM 3693' FSL, 1496' FEL, Sec. 26, T11 N, R15E, UM 91' FSL, 429' FWL, Sec. 26, T11 N, R15E, UM 20"91.5#H-40 Surface 114'Surface 114'30"1700# Poleset 13-5/8"68# / 72#K-55 / L-Surface 2497'Surface 2497'17-1/2" 2500 sx Arcticset III& 400 sx Arct 9-5/8"47#L-80 Surface 10522'Surface 8588' 12-1/4"500 sx Class' G' 7"29#L-80 Surface 10865'Surface 8879'8-1/2"300 sx Class' G' none Surface ( Control & Balance Li 4 gals of Finecem Cmt 3255' Tbg x IA 177 bbls of 15.8 ppg Class G Cmt 2390' Tbg x OA , OA top job 220 bbls of 15.8 ppg Class G Cmt , 8 gals of 15.6 pp Not on Production N/A 33 65 323-173 PRUDHOE BAY Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Date First Production: Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov By Grace Christianson at 1:47 pm, Jan 04, 2024 Abandoned 12/4/2023 JSB RBDMS JSB 011024 xGDSR-1/19/24 28. CORE DATA Conventional Cores(s): Yes No Sidewall Cores(s): Yes No If Yes, list formations and intervals cored (MD/TVD, From/To), and summarize lithology and persence of oil, gas or water (submit separate pages with this form if needed). Submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results per 20 AAC 25.071 no matter when acquired. 29. GEOLOGIC MARKERS and POOL BOUNDARIES: (list all encountered)30. FORMATION TESTS Well tested? Yes No If yes, list intervals and formations tested, briefly summarizing test results. Attach separate pages to this for, if needed, and submit detailed test information, including reports, per 20 AAC 25.071. MD TVDNAME Permafrost - Top Permafrost - Base Top of Productive Interval Formation Name at TD: 31. List of Attachments: Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: This form and the required attachments provide a complete and concise record for each well drilled in Alaska. Submit a current well schematic diagram with each 10-407. Submit 10-407 and attachments in PDF format to aogcc.permitting@alaska.gov. All laboratory analytical reports from a well must be submitted to the AOGCC, no matter when the analyses are conducted per 20 AAC 25.071 Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Well Class - Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. TPI (Top of Producing Interval). The Kelly Bushing, Ground Level, and Base Flange elevations in feet above Mean Sea Level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Report the Division of Oil & Gas / Division of Mining Land and Water: Plan of Operations (LO/Region YY-123), Land Use Permit (LAS 12345), and/or Easement (ADL 123456) number. Report measured depth and true vertical thickness of permafrost. Provide MD and TVD for the top and base of permafrost in Box 29. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data within 90 days of completion, suspension, or abandonment, whichever occurs first. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Pursuant to 20 AAC 25.071, submit detailed descriptions, core chips, photographs, and all subsequent laboratory analytical results, including, but not limited to: porosity, permeability, fluid saturation, fluid composition, fluid fluorescence, vitrinite reflectance, geochemical, or paleontology. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. General: Item 1a: Item 1b: Item 4b: Item 9: Item 15: Item 19: Item 20: Item 22: Item 23: Item 24: Item 27: Item 28: Item 30: Item 31: INSTRUCTIONS Bo York Operations Manager David Wages David.Wages@hilcorp.com 907.564.5006 ~1900 ~1900 860810545 N/A Well Service Reports, Wellbore Schematic, Well Photos Sadlerochit GOC Base of Sadlerochit 10545' 10560' - 10598' 10756' 8607' 8620' - 8653' 8787' Sadlerochit 10866' 8880' Form 10-407 Revised 10/2022 Submit in PDF format to aogcc.permitting@alaska.gov Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2024.01.04 07:19:34 - 09'00' Bo York (1248) ACTIVITYDATE SUMMARY 7/30/2023 ***WELL S/I ON ARRIVAL*** (P&A) DRIFT W/ 4-1/2" BRUSH & 3.78" G. RING TO 3,300' SLM PULLED BK-DGLV AT ST# 7 (3,255' md) ***WELL S/I ON DEPARTURE*** 8/2/2023 T/I/O = SSV/10/220. Temp = SI. Cement control & balance lines (P&A). No AL or wellhouse. Bled control and balance (C/B) lines to 0/0+ psi. Flushed C/B lines with 2.5 gal Hyd fluid each. Pumped 2+ gal Finecem cement down each C/B line. SV, WV, SSV = C. MV = O. IA & OA = OTG. 14:00. 8/6/2023 T/I/O = SSV/100/230. Temp = SI. PT C&B lines to 500 psi. Control line @ 6:00 = 0 psi, Balance line @ 12:00 = 0 psi. Pressured Control line to 500 psi. Monitored for 30 mn. No change in pressure. Pressured Balance line to 500 psi. Monitored for 30 min. No change in pressure. Bled C&B lines to 0 psi. Final WHP's = SSV/100/230. SV, WV, SSV = C. MV = O. IA, OA = OTG. 14:20 8/24/2023 Pre Cement Circ Out (PLUG AND ABANDONMENT) Pumped 250 bbls 100* crude down Tbg, Up IA and taking returns to open top tank. DSO notified of well status per LRS departure. SV,WV,SSV=C MV=O IA,OA=OTG All hardline and CT blocks SI. *Tags hung on MV and IA 8/26/2023 HES Cement (P&A)- HES pumped 177 bbls of 15.8 ppg Class G Cement to fill IA from open pocket @ 3,255' MD to IA Surface. 500' of cement in tubing. Estimated top of cement in tubing 3,255' to ~2,755'. Good cement returns at surface, 15.71 ppg. Fluid in tubinig- 5 bbls of fresh water, 42 bbls of 9.8 brine and 15 bbl 60/40. 8/26/2023 T/I/O= 0/0/254 (PLUG AND ABANDONMENT) - LRS pumped 10 bbls of 60/40 to fill lines and establish flow. Halliburton pumped Surfactant, Fresh Water, and 15.8 ppg cement according to the pump program. LRS dropped foam ball, pumped 42 bbls of 9.8 ppg Brine and 15 bbls of 60/40 to freeze protect well. LRS pumped 23 bbls of 9.8 brine and 5 bbls of Diesel to flush surface lines through the wash-up and choke skid, out to the open-top tanks. Valve Positions - SVx3/WV/SSV/IA= Closed, MV= Open, OA= OTG FWHPs= 1500/660/380 8/31/2023 T/IA/OA= PRE AOGCC State test MIT-T target 2250PSI MAP 2500 PSI 9/1/2023 JOB CONTINUED FROM 08-31-23 Pre AOGCC state test, perform MIT-T, target 2250 PSI, 2500 PSI MAP ::::::MIT-T PASSED::::::: 2505/0/132, 15 min loss of 60 PSI, 30 min loss of 21 PSI FWHP= 0/0/132 S/W/SSV/M/IA/OA= S/S/S/O/OTG/OTG 9/1/2023 ***WELL S/I ON ARRIVAL*** RAN 2.25'' CENTRALIZER 2' x 1.875'' STEM, 2'' SAMPLER BAILER TO 2,436' SLM RAN 10' x 3.14'' DUMMY GUN DRIFT TO 2,436' SLM AOGCC ADAM EARL WITNESSED TAG. ***WELL S/I O DEPARTURE*** Daily Report of Well Operations PBU 04-26 Daily Report of Well Operations PBU 04-26 9/1/2023 AOGCC MIT-T (Plug and Abandonment) MIT-T to 2453 *** PASSED*** Target = 2250 psi. Max applied = 2500 psi. Pumped .4 bbls diesel down TBG to achieve test pressure. TBG lost 47 psi in the 1st 15 min. TBG lost 18 psi in the 2nd 15 min. Total loss in 30 min = 65 psi. Bled TBG psi back to 342 psi. Bled back ~ .4 bbls. Witnessed by HIlcorp WSS Jerry Cullpepper and State Rep Adam Earl. DSO notified of well status upon LRS departure. Tag hung on SV. FWHP's = 342/0/140 9/11/2023 ***WELL S/I UPON ARRIVAL*** MIRU HES ***CONTINUED ON 12-SEP-2023 WSR*** 9/12/2023 ***CONTINUED FROM 11-SEP-2023 WSR*** PT PCE 300PSI LOW, 3000PSI HIGH PRESSURE BEFORE TB: 1000PSI IA: 0PSI OA: 100PSI PUNCH TUBING AND CASING TO CREATE T X OA WITH 3.125 10SPF HSC W/ MAXFORCE FLOW CHARGES INTERVAL 2390' TO 2400' PRESSURE AFTER TB: 600PSI IA: 0PSI OA: 100PSI RDMO HES E-LINE ***WELL S/I UPON DEPARTURE*** READY FOR FULLBORE 9/12/2023 T/I/O=0/0/260 Confirm TxOA Communication (Plug And Abandonment) Pump 1.7 bbls Crude down TBG, OA tracked to 1000 psi. Bled back 1.6 bbls. FWHP=0/0/280. Casing valves OTG 9/16/2023 T/I/O=7/0/42 Circ-Out TxOA to diesel ( P&A ) Pump 100 bbls hot diesel & 100 bbls ambient diesel down tbg taking returns up OA to OTT FWHPs=4/0/5 9/29/2023 T/I/O=0/0/0 Assitst Cement Crew (PLUG AND ABANDONMENT) Pump 25 bbls 120* Down TBG taking returns up OA to tanks. HES pumped cement job. Flush surface lines w/ Diesel. FWHP=0/0/0 9/29/2023 HES Cement (P&A) Tubing and OA Cement to Surface. HES pumped 220 bbls of 15.8 class G cement down the tubing and up the OA through holes at 2,400' ELMD. Cemented tubing and OA from 2,400' to surface. T/IA/OA are cemented to surface. 11/14/2023 Conduct ACWR meeting with FS2 DS lead, FS2 safety, DS04 drillsite operator, equipment operator and Worley well support lead. Pad elevation = 31.6'. Tundra elevation = 21.6'. Excavate 17' below pad elevation and 7' below tundra elevation. Cover excavation and LDFN. 11/19/2023 *** P&A*** In Progress. The tundra line in the excavation is very obvious and measured 10' below pad elevation, Pad elevation=31.6, Tundra elevation is 21' 6"' elevation.. Pictures taken to document tundra elevation.Set shoring box and rig mats. Cut wellhead off 4" below tundra elevation.All annuli are cemented to surface and cement appears to be in good condition. Pad elevation=31.6', Tundra elevation =21.6" elevation, Cut depth =17' 6"' elevation. WIl move over and cut 04-12 before contacting the AOGCC so they can inpect both cut at the same time. Job Inprogress. 12/3/2023 *** P&A In Progress *** Removed sandy cement from conductor to 9" below cut. AOGCC Inspector (Austin McLeod) verified void in conductor and cement tops in all annuli. Performed cement top job in conductor with 8 gallons of 15.6 ppg AS-1 cement. Daily Report of Well Operations PBU 04-26 12/4/2023 *** P&A Complete *** AOGCC Inspector (Austin McLeod) verified cement top job, verbiage on marker plate and welding of marker plate. Photo document marker plate installation. Pull shoring box and backfill excavation. 2023-1204_Surface_Abandon_PBU_04-26_am Page 1 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: 12/5/2023 P. I. Supervisor FROM: Austin McLeod SUBJECT: Surface Abandonment Petroleum Inspector Prudhoe Bay Unit 04-26 Hilcorp North Slope LLC PTD 1853140; Sundry 323-173 12/3/2023: I traveled to location and met with Rob Bryan of Hilcorp to witness the surface abandonment of the well after it had been cutoff four feet below tundra grade. The OOA (surface casing X conductor annulus) had a nine-inch void that needed topped off. All other strings had cured hard cement to surface. 12/4/2023: I went back after the top job was completed. Cement integrity checked with a sledgehammer on all strings. The OOA top job section was not quite as cured as the rest of the cement but still hard. Marker plate was ¼ inch in thickness, had all required information bead welded to it and did not extend beyond the conductor. I found no issues with this inspection. Attachments: Photos (5) 2023-1204_Surface_Abandon_PBU_04-26_am Page 2 of 4 Surface Abandonment – PBU 04-26 (PTD 1853140) Photos by AOGCC Inspector A. McLeod 12/3 -12/4/2023 Surface casing by Conductor annulus void 2023-1204_Surface_Abandon_PBU_04-26_am Page 3 of 4 2023-1204_Surface_Abandon_PBU_04-26_am Page 4 of 4 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section:26 Township:11N Range:15E Meridian:Umiat Drilling Rig:n/a Rig Elevation:n/a Total Depth:10886 ft MD Lease No.:ADL 028324 Operator Rep:Suspend:P&A:X Conductor:20"O.D. Shoe@ 114 Feet Csg Cut@ Feet Surface:13 3/8"O.D. Shoe@ 2497 Feet Csg Cut@ Feet Intermediate:O.D. Shoe@ Feet Csg Cut@ Feet Production:9 5/8"O.D. Shoe@ 10522 Feet Csg Cut@ Feet Liner:7"O.D. Shoe@ 10865 Feet Csg Cut@ Feet Tubing:5 1/2 x 4 1/2"O.D. Tail@ 10295 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm)Depth (Top)MW Above Verified Fullbore Bottom 3255 ft 2436 ft Wireline tag Initial 15 min 30 min 45 min Result Tubing 2500 2453 2435 IA 0 0 0 OA 142 142 142 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: Jerry Culpepper Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): I traveled to PBU 04-26 to witness a wireline tag and pressure test of an upper cement plug for P&A. Jerry Culpepper was the Hilcorp rep. on the job. Tagged top of cement @ 2,436 ft MD. The sample bailer produced a good sample of set-up cement. Wireline tool string consisted of 8 feet of 2 1/8-inch weight bar, oil jars, spanges, 2 1/4inch centralizer, and a 3-ft sample bailer. 250lb hanging wt. Pressure test went as per chart above. September 1, 2023 Adam Earl Well Bore Plug & Abandonment PBU 04-26 Hilcorp North Slope LLC PTD 1853140; Sundry 323-173 none Test Data: P Casing Removal: rev. 3-24-2022 2023-0901_Plug_Verification_PBU_04-26_ae 7. If perforating: 1. Type of Request: 2. Operator Name: 3. Address: 4. Current Well Class:5. Permit to Drill Number: 6. API Number: 8. Well Name and Number: 9. Property Designation (Lease Number):10. Field: Abandon Suspend Plug for Redrill Perforate New Pool Perforate Plug Perforations Re-enter Susp Well Other Stimulate Fracture Stimulate Alter Casing Pull Tubing Repair Well Other: Change Approved Program Operations shutdown What Regulation or Conservation Order governs well spacing in thes pool? Will planned perforations require a spacing exception?Yes No 11. Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): PRESENT WELL CONDITION SUMMARY Perforation Depth MD (ft): Perforation Depth TVD (ft):Tubing Size: Tubing Grade: Tubing MD (ft): Packers and SSSV Type:Packers and SSSV MD (ft) and TVD (ft): Casing Length Size MD TVD Burst Collapse Exploratory Stratigraphic Development Service 12. Attachments: 14. Estimated Date for Commencing Operations: 13. Well Class after proposed work: 15. Well Status after proposed work: 16. Verbal Approval: 17. I hereby certify that the foregoing is true and the procedure approved herein will not be deviated from without prior written approcal. Proposal Summary Wellbore schematic BOP SketchDetailed Operations Program OIL GAS WINJ WAG GINJ WDSPL GSTOR Op Shutdown Suspended SPLUG Abandoned ServiceDevelopmentStrastigraphicExploratory Authorized Name and Digital Signature with Date: Authorized Title: Contact Name: Contact Email: Contact Phone: AOGCC USE ONLY Commission Representative: Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Location ClearanceMechanical Integrity TestBOP TestPlug Integrity Other: Post Initial Injection MIT Req'd? Spacing Exception Required?Yes Yes No No Subsequent Form Required: Approved By:Date: APPROVED BY THE AOGCCCOMMISSIONER PBU 04-26 Hilcorp North Slope, LLC 3800 Centerpoint Dr, Suite 1400, Anchorage, AK 99503 185-314 50-029-21520-00-00 ADL 0028324 10866 Conductor Surface Intermediate Production Liner 8880 79 2463 10490 574 6232 20" 13-3/ 8" 9-5/8" 7" 29" 5494 35 - 114 34- 2497 32 - 10522 10291 - 10865 2500 35 - 114 34- 2497 32 - 8588 8395 - 8879 none 470 1950 4760 7020 6232 , 10309 , 10690 1490 3450 6870 8160 None 5- 1/ 2" 17# x 4- 1/ 2" 12.6# 13Cr80 30- 10295None Structural 4-1/2" TIW HBBP-T No SSSV 10197 8320 Date: Bo York Operations Manager Andrew Ogg Andrew.Ogg@hilcorp.com 907.659.5102 PRUDHOE BAY Current Pools: PRUDHOE OIL Proposed Pools: PRUDHOE OIL STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 Comm. Comm.Sr Pet Eng Sr Pet Geo Sr Res Eng Form 10-403 Revised 10/2022 Approved application is valid for 12 months from the date of approval.Submit PDF to aogcc.permitting@alaska.gov 5/10/23 323-173 By Kayla Junke at 10:48 am, May 10, 2023 Digitally signed by Bo York (1248) DN: cn=Bo York (1248) Date: 2023.05.06 10:52:00 -08'00' * AOGCC to confirm cement quality in all annuli before welding marker plat. *Photo document TOC in all annuli before welding plate and photo document welded plate in place. MGR25MAY23 DSR-5/10/23 10-407 MDG 7/5/2023 GCW 07/05/2023 07/05/23 Brett W. Huber, Sr. Digitally signed by Brett W. Huber, Sr. Date: 2023.07.05 15:15:39 -08'00' RBDMS JSB 071123 P&A Well:04-26 PTD:185-314 API:50-029-21520-00 Well Name:04-26 Permit to Drill:1853140 Current Status:Suspended API Number:50-029-21520-00 Estimated Start Date:5/1/2023 Estimated Duration:14 days Regulatory Contact:Carrie Janowski First Call Engineer:Andy Ogg 307-399-3816 Second Call Engineer:Tyson Shriver 406-690-6385 Current Bottom Hole Pressure:Perfs cemented, hydrostatic at cement top (6232’ MD, 5494’ TVD)= 2182 psi Max. Anticipated Surface Pressure:2500 psi Max treating pressure Last SI WHP:399 psi Min ID:3.958”, 5-1/2”x4-1/2” XO @ 2270’ MD Max Angle:48 deg @ 5429’ MD Well History: 04-26 was drilled and completed in 1986 as a Z1 producer. A 1997 RWO installed new 5-1/2” chrome tubing from surface to 2534’ MD and 4-1/2” chrome tubing from 2534’ to 10295’ MD. In January 2008 the well underwent a Sealtite treatment to repair 4 small PC leaks. On 12/22/2012 the well failed a MIT-IA on two attempts, raising suspicion of 04-26 being the culprit for the gas migration seen in the SE corner of DS-04. Follow up diagnostic work proved 04-26 was the conduit for gas migration and reservoir P&A was performed. An RBP was set in the production liner @ On 05/11/2013 a fullbore cement plug was placed in the production liner from 10309’ to 10605’ MD. On 06/02/2013 a balanced intermediate cement plug was placed in the 4-1/2” tubing and 4-1/2”x9-5/8” annulus from 6232’ to 10008’ MD and a subsequent CMIT-TxIA passed to 2864 psi on 06/19/13. The well entered suspended status on 06/16/2013 Objectives: Perform a full P&A on the well by placing cement to surface in the 5-1/2” x 9-5/8” annulus with cement from 2755’-3255’ MD in the tubing. Place a cement plug across all annuli from surface to ~2400’ MD. Excavate and cut casings 3’ below original tundra level and install marker plate. Procedure: AOGCC Witness: All AOGCC witnessed operations require a minimum of 24-hour notice to AOGCC inspectors of the timing of the operation so they can be available. SL: 1. Drift to GLM #7 @ 3255’ MD. 2. Pull DGLV from sta #7. Leave open pocket for cementing DHD : 1. Cement control and balance lines. Well Support : 1. Nipple down production tree, install dry hole tree for cementing. FB : 1. Confirm circulation through open pocket. P&A Well:04-26 PTD:185-314 API:50-029-21520-00 FB Cement: 1. Pump the following down the tubing, up the IA. Max pressure while pumping= 2500 psi. A. 5 bbls MeOH B. 75 bbls hot (160degF) fresh water + surfactant C. 10 bbls fresh water D. 177 bbls (20 bbls over calculated volume) 14-15.8 ppg Class G cement E. 5 bbls fresh water F. Foam ball G. 42 bbls 9.8 ppg brine H. 15 bbls 60/40 for freeze protect. I. Confirm cement at surface in IA. a. Cement plug in IA will be from open pocket to surface. b. Cement plug in tubing will be from 2755’ MD to open pocket @ 3255’ MD. SL: 1. Drift to TOC ~2755’ MD. EL: 1. Perforate 5-1/2” tubing and 9-5/8” casing at 2390’-2400’ MD. 3.125” MaxForce-FLOW or similar. A. Perforate 5-1/2” tubing and 9-5/8” casing from 2390’-2400’ MD to establish circulation point for cementing. B. Apply 1000 psi to 5-1/2” prior to perforating, record before/after pressures C. Note any pressure changes FB Cement: 1. Circulate the following down the tubing and up the 9-5/8”x 13-3/8. Max pressure while Pumping =1500 psi. (No Arctic Pack Present) A. 5 bbls MeOH B. 25 bbls hot diesel (min 120 degF) to confirm circulation C. 75 bbls hot (160degF) fresh water + surfactant D. 10 bbls fresh water E. 220 bbls (25 bbls over calculated volume) 14- 15.8 ppg Class G cement or until uncontaminated cement is seen at surface F. Top of cement will be at surface in the tubing and 9-5/8”x13-3/8” annulus. Confirm cement at surface in OA. DHD: 1. Assist fullbore with cement job and pump N2 across the wellhead to remove excess cement from valves. 2. Bleed all wellhead pressures to 0 psi. 3. Monitor wellhead pressures 24 hours after pressures were bled to 0 psi. Special Projects: 1. Excavate and cut off all casings and wellhead 3’ below original tundra level. 2. AOGCC witness of cut-off casings before any top job commences. 3. AOGCC witness cement tops in all annuli. Top off with cement as needed. 4. Bead weld marker cap on outermost casing string. Photodocument all steps and AOGCC witness of installed cap. Marker cap to read as follows: P&A Well:04-26 PTD:185-314 API:50-029-21520-00 Hilcorp North Slope, LLC PTD # 185-314 Well: PBU 04-26 API # 50-029-21520-00 P&A Well:04-26 PTD:185-314 API:50-029-21520-00 Figure 1: Current WBS P&A Well:04-26 PTD:185-314 API:50-029-21520-00 Figure 2: Proposed P&A WBS By Samantha Carlisle at 8:21 am, Sep 13, 2022 By Anne Prysunka at 4:35 pm, Aug 11, 2022 Suspended Well Inspection Review Report Reviewed By: P.I. Suprv Comm ________ JBR 09/02/2022 InspectNo:susLOL220806125540 Well Pressures (psi): Date Inspected:8/6/2022 Inspector:Lou Laubenstein If Verified, How?Other (specify in comments) Suspension Date:6/16/2013 #313-190 Tubing:399 IA:121 OA:223 Operator:Hilcorp North Slope, LLC Operator Rep:Ryan Holt Date AOGCC Notified:8/5/2022 Type of Inspection:Subsequent Well Name:PRUDHOE BAY UNIT 04-26 Permit Number:1853140 Wellhead Condition Wellhead in good condition free of visible issues. Surrounding Surface Condition Surrounding area free of debris. Condition of Cellar No cellar Comments Location verified using Pad Map. Supervisor Comments Photo (1) attached Suspension Approval:Sundry Location Verified? Offshore? Fluid in Cellar? Wellbore Diagram Avail? Photos Taken? VR Plug(s) Installed? BPV Installed? Friday, September 2, 2022 9 9 9 9 9 9 9 9 2022-0806_Suspend_PBU_04-26_photos_ll Page 1 of 1 Suspended Well Inspection – PBU 04-26 PTD 1853140 AOGCC Inspection # susLOL220806125540 Photos by AOGCC Inspector L. Laubenstein 8/6/2022 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Service ❑ Stretigrephic ❑ Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program L Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Suspend Inspection E 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work5. feet Permit to Drill Number: 185-314 3. Address: P.O. Box 196612 Anchorage, Development Q Exploratory ❑ Contact Phone: +1907 564 4127 AK 99519-6612 1 Stratigraphic ❑ Service ❑ 1 8. API Number: 50-029-21520-00-00 7. Property Designation (Lease Number): ADL 028324 8. Well Name and Number: PBU 04.26 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 1 10. Field/Pools: 11. Present Well Condition Summary: Service ❑ Stretigrephic ❑ Total Depth: measured 10866 feet Plugs true vertical 8880 feet Junk Effective Depth: measured 6232 feet Packer true vertical 5494 feet Packer Casing: Length: Size: MD Structural Service ❑ Stretigrephic ❑ Conductor 79 20" GINJ ❑ Surface 2463 13-3/8" Sundry Number or N/A if C.O. Exempt: Intermediate 10490 9-5/8" Production Contact Name: Montgomery, Travis J Liner Trevis.Montgomery[a)bp.cem /�e-7 1 I Contact Phone: 574 7" Perforation Depth: Measured depth: None feet True vertical depth: feet Tubing (size, grade, measured and true vertical depth) Packers and SSSV (type, measured and We vertical depth) 12. Stimulation or cement squeeze summary Intervals treated (measured): 35-11 4 34-24 97 32-105 22 10291-1 0865 PRUDHOE BAY, PRUDHOE OIL RECEIVE 6232, measured 10309, 10605, 10690 feet JUN 2 5 2019 measured None feet A measured 10197 feet OGCC true vertical 8320 feel ( � �� 5-1/2" 17# x 4-1/2" 12.6# 13Cr80 41/2" TIW HBBP-T Packer Treatment descriptions including volumes used and final pressure: TVD: Burst: Collapse: 35-114 1490 470 34-2497 3450 / 5280 1950/2670 32-8588 6870 4760 8395-8879 30-10295 10197 8160 7020 30-8398 8320 Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Esu- Tubing Pressure Prior to well operation: Suspended Subsequent to operation: 4. Attachments: mxiwied per 20 MC 25.07025.071,625283) 15. Well Class after Work: Daily Report of Well Operations Q Exploratory ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after Work: Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ 7. 1 hereby certify that the foregoing is true and correct to the best of my knowledge I Authorized Title: SI Sp ialist Authorized Signature. Date-. Development Q Farm 10404 Revised 04/2017 III\I Submit Original $BDMSL& 2 6 2019 f A710 Service ❑ Stretigrephic ❑ Oil ❑ Gas ❑ WOSPL ❑ WAG ❑ GINJ ❑ SUSP Q SPLUG ❑ Sundry Number or N/A if C.O. Exempt: NIA Contact Name: Montgomery, Travis J Contact Email: Trevis.Montgomery[a)bp.cem /�e-7 1 I Contact Phone: +1907 564 4127 Only Daily Report of Well Operations 04-26 ACTIVITVI)ATF RI IMMGRV T/I/O = LOTO/90/220. Temp = SI. Pre -Suspended Well Inspections. No wellhouse. AL disconnected. 5/29/2019 SV, WV = LOTO. SSV = C. MV = O. IA, OA = OTG. 23:05 T/I/O = SSV/90/220. Temp = SI. WHPs (Pre suspended well inspection). No wellhouse or grating. AL spool has been removed. 5/30/2019 SV, SSV = C. WV = LOTO. MV = O. IA, OA = OTG. 13:15 TWO = SSV/90/220. Temp = SI. AOGCC SU Inspection (Regulatory Compliance). State witnessed by Adam Earl. Pictures taken. 6/2/2019 1 SV, WV = C. IA, OA = OTG. 14:00 Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: 04-26' Field/Pool: Prudhoe Bay I Prudhoe Oil Permit # (PTD): 1853140 API Number: 50-029-21520-00 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 6/13/2013 Surface Location: Section: 26 Twsp: 11N Range: 15E Nearest active pad or road: DS -04 Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Pad or location surface: Clean Location cleanup needed: None Pits condition: N/A Surrounding area condition: Clean Water/fluids on pad: No Discoloration, Sheens on pad, pits or water: No Samples taken: None Access road condition: Good Photographs taken (# and description): Sign, Wellhead Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Cellar description, condition, fluids: Clean Rat Hole: N/A Wellhouse or protective barriers: Cattle Guard Well identification sign: Yes Tubing Pressure (or casing if no tubing): SSV Annulus pressures: IA= 50, OA= 200 Wellhead Photos taken (# and description): Yes Work Required: None Operator Rep (name and signature): Josh Prowant— AOGCC Inspector: Adam Earl Other Observers: Inspection Date: 6/2/2019 AOGCC Notice Date: Time of arrival: 2:00 PM Time of Departure: Site access method: Access Road 6/1/2019 2:10 PM ju - - --one 77 - 0 r -, ,. �- i. ' - gym•♦ �-. - �.�i�__►' �."� I. I (I 0433B C04220. 23 V C W 02A -2`4C 22 1 34-20 1-3-24 ¢14402 j tl 0422AP61 — GNI-01 Ll- 30 _ D433 A0424 try -415 042° - G14404 D4_3�=.PBL— — .J11-33 70427 ONI-03 04 Y_ ii -as -04-1- ? PIWG LT-1XK r 04- 34A _ _. L'�28 0423 L431 - 11-32, 0419 04 B1 D4-D5R — Q4 it 043E D4 a _ i DS1 '133PBi 04-0 j> 11-37 ,ti yet . 113-c -04aa kP Q4-� PB1 04-ai A4 -?1 A-PE2 $ 34-1!!A - 34-41-'F'21191 f D423.AL1P61 �'" S41 - D411 0429. 0413 04-42 l •? 04 14 04-12 --04-14F'B1 J D411A aa -D- D439PE1 0448 ':'-- DO- 34/A�09-41 F'- 0431 ;' "35 DD9-15A II _ `.4?9 it D4- 323 0 _432 D4314' it -is 0 D430P�1 �I � �, •r 04-51 ._, D4 39 -A 01 04-D9 � P610p9-34A 09-081 C D4030415 Y 48 D9 34R 62 040t_04-Q4A {y 0447 — � D09 -33A3 P 09- 35A �l .-. Q9.42 -OgIl -- -4ZQQ_ TREE= I FMC VYB-LHEAD = FMC ACTUATOR= BAKER 0103. E.B/ = 65' BF. E LEV = 33.08' I(OP _? Max Angle = 48- @ 6135' DatunMD= 10848' Data TVD= 8800'55 SUSPENDED 04_26 SAFETYNOTES: GAS COMM. OA TOATMOSPHH/£ (UNRELATED TO PRIOR 1996 REPAIR, DOWNHOLE BETWEEN 13-3/8' AND 20' OA COMM. APPEARS TO BE®30'ITn(N JTI—r:li/nMP Tan—Di Ir -e em IN DATE REV BY I COMMENTS DATE REV BY COMMENTS 03112186 ORIGINAL COMPLETION 0526/13 TJHPJC STA # 7 EMPTY (05/24/13) 10104/97 D78 RUIO 0528/13 PJC GLV STATION NUMBERING 01/31/12 JMJMD TREEC/O(01/12112) 06/18/13 RBNPJC 2NDS7FAGEC6fT(06102/13) 0529/12 MS&.m PULLED DSSSV PLUG (0525/12) 07/10/13 PJC TNR CMT CORRb::'TIONS 1227112 Msw m SET PVO PTUCVGLV C/O (12fWl2 0620/19 JNUJMD ADDED BF & SUSPENDED 0525113 TJWRIC PULL E/O & BP(O5/06113) PRUDHOE BAY UNIT VALL: 0426 PERMIT M: 9853140 AR No: 50-029-21520-00 SEC26, T11 N, R15E, 92' FSL & 429' FAL BP Fxpleration (Alaska) E '12 06 06 02 97 97 13 Suspended Well Inspection Report InspectNo: susAGE190618100615 Date Inspected: 6/2/2019 Inspector: Adam Earl Well Name: PRUDHOE BAY UNIT 04-26 Permit Number: 1853140 Suspension Approval: Sundry i4 313-190 " Suspension Date: 6/16/2013 ' Location Verified? 0 If Verified, How? Other (specify in comments) Offshore? ❑ Well Pressures (psi): Tubing: IA: OA: Wellhead Condition good condition Condition of Cellar cellar filled in, a few small pieces of wood but clean Surrounding Surface Condition no sheen, or issues Comments location verified by pad map Supervisor Comments Photo attached Type of Inspection: Subsequent Date AOGCC Notified: 6/1/2019 Operator: BP Exploration (Alaska) Inc. Operator Rep: Josh Prowant Wellbore Diagram Avail? ❑� Photos Taken?❑ Fluid in Cellar? ❑ 50 BPV Installed? ❑ 200 VR Plug(s) Installed? ❑ Wednesday, August 14, 2019 Suspended Well Inspection — PBU 04-26 PTD 1853140 AOGCC Inspection Rpt # susAGE190618100615 Photo by AOGCC Inspector A. Earl 2019-0602_Suspend_PBU_04-26_photo_ae.doex Page 7 of 7 • RECEIVED STATE OF ALASKA .3KA OIL AND GAS CONSERVATION COMMISSION FEB 12 2014 REPORT OF SUNDRY WELL OPERATIONS AOGCCOperations Abandon Lf Repair Well U Plug Perforations U Perforate LJ Other U spended�Ipection Performed: Alter Casing ❑ Pull Tubing Stimulate-Frac ❑ Waiver ❑ Time Extension❑ Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development Exploratory ❑ 185-314-0 3.Address: P.O.Box 196612 Stratigraphies Service ❑ 6.API Number: Anchorage,AK 99519-6612 • 50-029-21520-00-00 7.Property Designation(Lease Number): 8.Well Name and Number: • ADL0028324. PBU 04-26 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): • PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 4 10866 feet Plugs measured See Attachment feet true vertical 8880.04 feet Junk measured None feet Effective Depth measured ` 6232 feet Packer measured 10204 feet true vertical 5494.09 feet true vertical 8325.75 feet Casing Length Size MD ND Burst Collapse Structural None None None None None None Conductor 79 20"91.5#H-40 35-114 35-113.99 1490 470 Surface See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Intermediate None None None None None None Production 10491 9-5/8"47#L-80 31-10522 31-8588.38 6870 4760 Liner 574 7"29#L-80 10291-10865 8394.93-8879.21 8160 7020 Perforation depth Measured depth 10545-10560 feet 10598-10608 feet 10620-10626 feet 10649-10682 feet 10710-10730 feet 10730-10750 feet True Vertical depth 8608.12-8621.01 feet 8653.69-8662.29 feet 8672.62-8677.79 feet 8697.58-8725.8 feet 8749.57-8766.45 feet 8766.45-8783.25 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and true vertical depth) 4-1/2"TIW HBBP-T Packe 10204 8325.75 Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): RBDMS_____MAY 1 1 2014 Treatment descriptions including volumes used and final presNrn AUG 1 4 2014 13. �r►�M Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development❑✓ ' Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil ❑ Gas ❑ WDSPI❑ GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP 0 . SPLUdJ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email Garry.Catron@BP.Com Printed Name Garry Catron Title PDC PE Signature .24C,e7(./N Phone 564-4424 Date 2/11/2014 / F 4, //z / 1 q ,On07 Form 10-404 Revised 10/2012 Submit Original Only 04-26 185-314-0 Plugs Attachement SW Name Date MD Description 04-26 • 6/2/2013 6480 Cement Plug in Tubing 04-26 5/11/2013 10309 Cement Plug on IBP 04-26 5/7/2013 10605 4-1/2" Baker IBP 04-26 3/15/2005 10690 IBP • m 0o000O00 R O O I� O Cp N � C N CO I- 0 00) CO O� (0 C) ,C (9 N- CO sr 0) I- � co I CO N- o) N M (0 if) CO 0) OLoCflch chr- coI-- CAO co 10 CI to CO CO N N CO M CO 0) 10 co to co co M0) cochI- N co Ll) CO N f� N N N co lto 0) '4' co OON L° O N N CI N CI 0) 00 %- N C) (\J M O co M r- N N C Q po 0 co Lo V = 00 J Y J ° (/) N CO r 0 - O 1 M M -- CN N O . • C J •- N N • Z O 0 C U U W W 0 0 H > > 00 AO0OLLLLLZZ ' ZWOCCcemm OZrze » » O Q crJ U) H H CC) _ t O °_ Q) � E f0 C 0 CO r-1 4J 111, al a a, ° • LC) 0 i N Z ° a 0 • m a fi 0 0) 4' M p j=7, r-I u Prudhoe Bay Unit Well 04-26, PTD 1853140 Suspended Well Inspection Report BP Exploration Alaska (BPXA) completed a suspended well inspection of PBU 04-26 on 11/03/2013. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). • Suspended Well Site Inspection form documenting the well pressures and site condition. AOGCC Inspector John Crisp witnessed the inspection. • Wellbore Diagram illustrating the current configuration of the well. • Pad map showing the well location and other wells within % mile radius of the surface location. • Photographs showing the condition of the wellhead and surrounding location. Supplemental Information: • PBU 04-26 is located on a pad with active producing wells and/or service wells. • The strata through which the well was drilled is neither abnormally geo- pressured nor depleted. • The well is secured with cement in the liner from an Inflatable Bridge Plug at 10,605' to 10,309'. There is a second cement plug from a gas lift mandrel at 10,088' to 6,232' in the tubing and estimated 6,444' in the IA. • The well is mechanically sound as proven by a CMIT-TxIA pressure test of the top cement plug to 3,000 psi on 6/19/2013. BJO 11/06/2013 Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: 04-26 Field/Pool: Prudhoe Permit#(PTD): 1853140 API Number: 500292152000 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 6/16/2013 Surface Location: Section 26 Twsp: 11N Range: 15E Nearest active pad or road: Spine road going to DSO4 (grind inject plant) Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1)a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Active production pad location looks good Pad or location surface: good Location cleanup needed: NO Pits condition: No active pit for well#26 Surrounding area condition. good Water/fluids on pad: N/A snow covered Discoloration, Sheens on pad, pits or water: N/A Samples taken: No Access road condition: Good Photographs taken (#and description). NO Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition All in working order. SSV is closed Cellar description, condition, fluids. N/A snow covered Rat Hole: NO Wellhouse or protective barriers: Guard in front of wWellhead Well identification sign: Yes Tubing Pressure(or casing if no tubing): N/A SSV is closed Annulus pressures: IA=0 psi OA= 0 psi Wellhead Photos taken (#and description): Yes 6 photos,2 photos of back side of wellhead, one photo of the right side, one photo of left side, one photo of the front of wellhead, and photo of the sign Work Required: None Operator Rep(name and signature) Jack Disbrow AOGCC Inspector: John Crisp Oth r Observers: Kevin Parks Inspection Date: 11/3/2013 AOGCC Notice Date: 11/1/2013 Time of arrival: 12:50 PM Time of Departure: 1:15 PM Site access method. Truck TREE FRAC ^SAFETY NOTES: GAS COMM.OA TO ATMOSPHERE, WELLHEAD= FMC ACTUATOR= BAKER C Q 4-2 6BETVVEEN 13-3-3/8"AND 20TO PRIOR ")QOM M.AIR,DAP EAP RS TO MiAL KB.H EV_ 65' BE@ 30'(TOOL JT)'CHROME TBG'PLUGS SET IN BF.ELEV= KOP= _ ,�...._._._. .._ ? XN NIP OR BETWEEN PKR&XN NIP WILL NOT PASS PRESSURE TEST. Max Angle= 48'@6135' Ctitum MD= 10848' Datum ND= 8800'SS 0 2270' H5-1/2"CAM BAL-O SSSV NP,ID=4.562" 13-3/8"CSG,72#,L-80,D=12.347" -_I--- 2497' I, • 2534' H5-1/2"X 4-112'XO,D=3.958" 5-1/2"TBG,17#,13-CR,.0232 bpf,D=4.892" H 2534' 1------_ GAS LFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE TOP OF CENE IT-TBG (TAGGED 06/12/13) 6232'SLM 7 3255 3245 16 KBMG DIM BK 0 12/22/12 ESTlNIAT®CMT N LA (06/02113) — 6444-I00$86 5786 5192 47 KBMG DMY BK 0 05/21/06 5 7273 6203 47 KBMG 'DMY BK 0 03/27/06 ' y l 4 8235 6890 42 KBMG "OM' BK 0 07/18/02 �t 3 9041 7484 44 KBMG "DIM BK 0 10/04/97 Minimum ID = 3.958" @ 227a' ► 2 9978 8154 43 KBMG *MY BK 0 10/04/97 5-1/2" X 4-1/2" XO 1 10088 8236 r 41 KBMG 'EMPTY - 05/24/13 -log Viti.N,ilk 'S#1-5= COVERED BY CEENT ^e le.i6W4k L K... x 10197' H9-518"X 4-1/2"TNI HB-BRT FKR I 111 10273' H4-1/2"OTIS XN NP,u=3.725" TOP OF 7"LNR H 10291' 4-112'TBG,12.6#,13-CR,.0152 bpf,D=3.958" —E1-0295' / \ 10295' _H4-1/2"WLEG,D=3.958" •1•/•1.1.1.1•/•1 1111/11111111111 10310' —I ELMD TT LOGGED 08/28/06 11111111 11111111 11111111 10309'SLM HTOP OFCENMYT(05/11/13) 9-5/8"CSG,47#,L-80,D=8.681" ---I 10522' HA 1111111111111111 1111111111111111 1111111111111111 1111111111111111 PERFORM/ON SUMMARY 111111111111111 REF LOG:Bt-CS ON 03/08/86 111111111111111 ANGLE AT TOP PERF: 31°@ 10545' 11111111111111t'1 111111111111111 Note:Refer to Production DB for historical pert data 11111/1/1111i1 SIZE SPF INTERNAL OpnI Sqz SHOT SOZ 441.114660- 10605' H4-1/2"BKR BP(TAGGED 05/06/13) 3-3/8" 6 10545-10560 C 04/07/11 I 3-3/8" 6 10598-10608 C 03/14/05 3-3/8" 6 10620-10626 C 03/14/05 I 3.318" 6 10649-10682 C 02/16/09 4 10710-10730 C 11/12/94 I 4 10730-10750 C 06/08/87 10690' -14-1/2'BKR BP(03/14/05) PBTD —H 10725' 1111111! 1/1/111111111 111111111111111' 1/1///4 11111111 11111111 7"LHR,29#,L-80,.0371 bpf,D=6.184' H 10865' 111111111111111 1:1:1:1:1:1:/1 TD H 10866' DATE REV BY COMMENTS DATE REV BY CON?&NTS PRWI OE BAY UNT 03/12/86 ORIGINAL COMPLETION 05/26/13 TJI-VPJC STA#7 E PTY (05/24/13) WELL 04-26 10/04/97 D16 RIND 05/26/13 PJC GLV STATION NJNBERNG F1RMT No:'1853140 01/31/12 JMJND TREE C/O(01/12/12) 06/18/13 RENYPJC 2N)STAGE cur(06/02/13) AR No. 50-029-21520-00 05/29/12 MSS/JND R LUQ[SSSV PLUG(05/25/12) 07/10/13 PJC LN2 CMT CORRECTIONS SEC 26,T11N,R15E,97 FSL&429'FVVL 12/27/12 PASS/JIM SET EVO PLUG/GLV CIO(12/22/12) 05/25/13 TJWPJC PRL EVO&IBP(05/06/13) L BP Exploration(Alaska) Ir... 1 Enter/Exit I 1 ■3s Z //// 695' I 1 I ■ 34r \ 7 ♦/ 1 _/ (/i I r — ,a... 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WELL PRODUCER • or 1 WELL INJECTOR A DATE : 12/2/2010 SCALE : 1" = 300' MAP DATE : 2010 PBU - DS 4 WELL SLOT W/CONDUCTOR 0 bs14495 mxd DS -4 & Grind & Inject July 13, 2013 � Approximate Scale-5:- 1"= ' DMC0169801" 1; aerometric400 - ti' . . _to. 1 . • ` . . . \tt ,,,,,.), t.fick, ., •+ ,: ,,,, .. i 1 ... . . r...)...,,,, 0— .. --- . .------ y . . . ....e. -:;.?...„., . , . . . .4, . „, , ..,_ ,1 . s...„..., _ ,.......,,,i „lot.: - .. , . _____, . . ., ... _ ..c. _., . ....„...„\ ..... .,:,-..-......m. . - . .„......„. , ,... .,.. i - . s Ar.: gym- ; / n o L F �/ . , /. v le ., xM ` / ° *' J f t ,. s '' J al j , -4 iii,v. Ir . , . ‘ 4ifel I ' 010 1 yAV I if111l - C 4 4 1 VIII 11 j ' 40 "40 a" I i/; 1 s .. a6 1 I F Mb li, ± 1 4 4 e '1111141111161"*"— . Back of Well Head p 1 l ' lliri ' I i r� ilk G •• 1/41111 TL. , y.� i k * 619 ' •ltiljilirr` A /1161111111.- ' ii;:' .)1114.,il ,:,,,,,irer,740airk..,:,,,,I eil 1 filL war t ..r, A.. 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Well Status: ❑Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned ®Suspended lb. Well Class 20AAC 25.105 20AAC 25.110 0 Exploratory 0 Stratigraphic 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions Zero .0 Development 0 Service 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: _ BP Exploration(Alaska) Inc. • 6/16/2013 • 185-314. 313-190 • 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 2/19/1986 • 50-029-21520-00-00 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 3/8/1986 ' PBU 04-26 '. 91'FSL,429'FWL, Sec.26,T11 N, R15E, UM 8. KB(ft above MSL): 65.00 15.Field/Pool(s) Top of Productive Horizon: , 3694'FSL, 3784'FWL, Sec.26,T11 N, R15E, UM GL(ft above MSL): Prudhoe Bay/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD) 3786'FSL, 3928'FWL, Sec.26,T11 N, R15E, UM 6232' 5494' 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) • 16. Property Designation: Surface: x- 713256 y- 5951975 Zone- ASP4 - 10866' 8880' - ADL 028324 -' TPI: x- 716503 y- 5955673 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 716644 y- 5955769 Zone- ASP4 None 18.Directional Survey: 0 Yes ®No 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900'(Approx.) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-Drill/Lateral Top Window MD/TVD: DIL/Sonic/GR/SP, DEN/NEU/GR/Cal, CBL/CCL/GR, Gyro • N/A 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT.PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 35' 114' 35' 114' 30" 1700#Poleset 13-3/8" 68#/72# K-55/L-80 35' 2497' 35' 2497' 17-1/2" 2500 sx Arcticset III&400 sx Arcticset II 9-5/8" 47# L-80 30' 10522' 30' 8588' 12-1/4" 500 sx Class'G' 7" 29# L-80 10291' 10865' 8395' 8879' 8-1/2" 300 sx Class'G' - 24. Open to production or injection? ❑Yes 0 No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ND) (MD+TVD of Top&Bottom;Perforation Size and Number): 5-1/2",17#x 4-1/2",12.6#,13cr8o 10295' 10197'/8320' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes 0 No • DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED en 10309'- 10605' C14 Bbls Cement SCANNED APR 2 3 2014 6232'- 10088' 250 Bbls Class'G' 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Production N/A Date of Test Hours Tested Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes 0 No • Sidewall Core(s)Acquired? 0 Yes 0 No . If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed). Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 250.071. \.\& None RBDMS JUL 11 2013) Fnrm 1n.4m Rauicorl 1n/9M9 r`(NAITIAII ICrN!NM DC\/CDCC R1hmi4(lrininml(Ink/ ... 29. GEOLOGIC MARKERS(List all formations an( :ers encounter 30. FORMATION TESTS NAME MD ND Well Tested? ❑Yes ®No- Permafrost Top If yes,list intervals and formations tested,briefly summarizing test results. Attach separate sheets to this form,if needed,and submit Permafrost Base detailed test information per 20 AAC 25.071. Sadlerochit 10545' 8607' None GOC 10560'-10598' 8620'-8653' Base of Sadlerochit 10756' 8787' Formation at Total Depth: 31.List of Attachment: Summary of Daily Work Reports,Well Schematic Diagram 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Joshua Stephens,564-4998 Email: Joshua.Stephens@bp.com Title: Drilling Technologist Printed Name: Joe Lastufk n Signature: / ' Phone 564-4091 Date:///10 /3 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Submit Original Only 04-26, Well History (Suspension) Date Summary 05/06/13 PULL 4-1/2" HES EVOTRIEVE FROM 10,169' MD. DRIFT W/3.25"CENT/TEUSB,TAG IBP @ 10,605' CORR. ELM (no sample). DRIFT W/3.50 CENT/TEU3.50" LIB,TAG IBP @ 10,605'CORR. ELM (pic of IBP fish neck). NOTE: IBP IS—32' BELOW WHERE INITIALLY SET(04/08/11)-—7'OF PRIOR CLOSED PERFS ARE NOW OPEN. 05/06/13 T/I/0= 110/500/300.Temp=SI. LEL monitoring (Assist SLB S/L).AL spool removed. Monitored LELs throughout S/L operations. No LELs detected. SLB S/L in control of well. 05/07/13 T/I/O= SSV/510/40.Temp=SI.WHP(secure).AL disconnected. IAP&OAP unchanged.0% LEL's detected. OA has integral installed=inspection not current. SV,WV, SSV=C. MV=O. IA, OA=OTG. NOVP. 16:20. 05/08/13 T/I/0=250/500/60.Temp=Sl.Assist FB(Secure). LELs=O%through out job. LRS in control of well upon departure. 0010. 05/08/13 T/I/O=SSV/510/40.Temp=SI.WHP(secure).AL disconnected. IAP&OAP unchanged.0% LEL's detected. OA has integral installed=inspection not current. SV,WV, SSV=C. MV=O. IA, OA=OTG. NOVP. 16:00. 05/08/13 T/I/0=250/500/60 Temp=S/I Injectivity Test(P&A) Pumped into tbg a 4 bbl meth spear followed by 285 bbls 90*crude. established an injectivity of 5 bpm @ 920 psi. See pump log for details. Final WHP's 250/550/60 SV,SSV,WV=closed MV,IA,OA=open DSO notified upon departure. 05/09/13 T/I/O =SSV/510/40.Temp=SI. Monitor WHPs(secure).AL disconnected. IAP&OAP unchanged.0% LEL's. No mercaptan detected in area. OA has integral installed=inspection not current. SV,WV, SSV=C. MV=0. IA, OA=OTG. NOVP 16:30 Hrs. 05/10/13 T/I/O = SSV/510/40. Temp=SI.Assist SLB(monitor LEL's).AL Disconnected. IAP&OAP unchanged. 0 % LEL's. Ne mercaptan detected in area. Integral installed on OA=inspection not current. No well house. P Sub&Hard line rigged up from tree cap to OT. SV, WV, SSV=C. MV=0. IA, OA=OTG. NOVP 0000 Hrs. 05/10/13 T/I/0= 103/523/30 Temp=SI (Obj: Fullbore P&A)Assist Cement pumpers Post cement. Pumped 3 bbls of meth to FP surface lines for Cement Pumpers. 05/10/13 Initial T/1/O: 107/521 /30. PJSM, MIRU SLB& LRS. PT EQUIP TO 4,000PSI. SLB PUMPED 150 BBLS 1%KCL @ AVG RATE OF 7BPM W/700 PSI.ON TBG, IA-PSI @ 1030 PSI. 05/11/13 T/I/O= 103/520/30 LRS Assist SLB Cement(Obj: Fullbore P&A) Spear 5 bbls of 30*f meth followed by 53 bbls of 80*f diesel to FP the Tbg. IA, OA=open WH in control of SLB Cement crew. Hung FP tags on Master Valve and ROS FHWP=VAC/750/150. 05/11/13 T/I/O=SSV/510/40.Temp=SI.Assist SLB (monitor LEL's).AL Disconnected. IAP&OAP unchanged.0 % LEL's. Ne mercaptan detected in area. Integral installed on OA=inspection not current. No well house. P Sub&Hard line rigged up from tree cap to OT. Bled IAP from 970 psi to 490 psi in 15 min (fluid) due to thermal expansion. SLB in control of well. 0445 Hrs. Page 1 of 4 e 04-26, Well History (Suspension) Date Summary 05/11/13 CMT SQUEEZE JOB. PUMPED 11 BBLS OF 15.8#NEAT W/3 BBLS OF 15.8#W/15 PPG AGGREGATE FOR A TOTAL OF 14 BBLS CMT PUMPED. NO SQUEEZE PRESS, WELL IS ON A VAC. TOTAL FLUIDS PUMPED AS FOLLOWS: 250 BBLS 1%KCL, 10 BBLS CHEM WASH, 7 BBLS FW, 14 BBLS CMT, 112 BBLS 1%KCL,5 BBLS METH, 53 BBLS DIESEL.TOTAL VOLUME 451 BBLS. IT TOOK 220 BBLS TO CATCH PRESS. MAX PSI 750 PSI, MAX RATE 7 BPM.AVG TREATING PSI 230 PSI, AVG RATE 6 BPM. FINAL PRESS T/I/O-13/745/150. 05/11/13 T/I/O=SSV/560/60.Temp=SI.Assist SLB&Hard line crew(monitor LEL's).AL disconnected.0 LEL's. No mercaptan detected in area. P Sub&Hard line rigged up to TBG to OT. Integral installed on OA=inspection not current. IAP increased 70 psi since night shift bleed per WSL. OAP increased 20 psi overnight. SV,WV,SSV=C. MV=0. IA&OA=OTG. NOVP 15:00 Hrs. 05/12/13 T/I/O=SSV/610/40.Temp=SI.WHPs(secure).AL disconnected. IAP increased 50 psi overnight. IA has integral installed =inspection current. Integral on OA=inspection not current. 0% LEL's. No mercaptan detected. SV, WV, SSV=C. MV=O. IA, OA=OTG. NOVP. 09:25. 05/12/13 T/I/O=Vac/610/40.Temp=SI.WHPs(Secure).AL spool dropped. 0% LEL's. Need a ladder if wanting to open SSV. SV,WV, SSV=C. MV=0. IA, OA=OTG. NOVP. 17:30. 05/13/13 T/I/O=Vac/610/40.Temp=SI.T& IA FLs(Fullbore Request).AL disconntected.T FL @ 160'(4 bbls). IA FL @ 400' (18 bbls). LELs=0%. SV,WV, SSV=C. MV=0. IA, OA=OTG. NOVP. 13:30 hrs. 05/14/13 T/I/O =Vac/610/40.Temp=SI.WHPs(secure).AL disconnected. Functioned SSV open for TP. No change in WHPs over night. Closed SSV upon departure. SV,WV, SSV=C. MV=O. IA, OA=OTG. NOVP. 15:04. 05/16/13 DRIFTED W/3.50"CENTRALIZER, 3.0"SAMPLE BAILER, S/D @ 10,309' SLM. TAG XN NIPPLE W/ 3.75"GAUGE RING @ 10260'SLM (13'CORR.TO MD @ 10273'). LRS MADE 3 ATTEMPTS TO MIT T TO 3000 PSI. MITT FAIL. 05/16/13 T/I/0=30/571/0 Temp=SI Assist S-line MIT-T to 3000 psi*FAILED*(Plug and Abandon) Pump 11.5 bbls 30*diesel down TBG to reach test pressure of 3000 psi. Lost 42 psi in 1st 15 min, lost 37 psi in 2nd 15 min for total of 79 psi in 30 min test. FWHP=500/580/0 Slickline in control of well upon departure CV's=OTG. 05/17/13 T/I/O= 165/578/30.Temp=SI. MIT-T to 3000 psi w/Diesel-FAILED (Pre P&A).AL disconnected. Integral installed on OA=inspection not current.TBG FL @ surface. Pumped—2.75 bbls of Diesel to pressure up TBG from 165 psi to 3000 psi.TBG decreased 98 psi in 1st 15 min and 53 psi in 2nd 15 min for a total loss of 151 psi in 30 min. Bled TBG from 2945 psi to 180 psi psi in 15 min (-3.2 bbls). Attempted 7 tests. See log for details.Job Complete. Final WHPs= 180/565/30. SV,WV,SSV=C. MV=0. IA, OA=OTG. NOVP 17:00 Hrs. 05/24/13 PULLED STA#1 BK-DGLV FROM 10,092'SLM (10,088'MD)AND LEFT POCKET EMPTY. 05/26/13 T/I/O=SSV/570/50.Temp=SI.WHPs(Secure).AL disconnected. Integral installed on IA=inspection current. Integral installed on OA=inspection not current.Tee&block valve installed on IA. 0% LEL's. SV,WV, SSV=C. MV=0. IA, OA=OTG. NOVP. 1630. Page 2 of 4 04-26, Well History (Suspension) Date Summary 05/28/13 T/I/O=SSV/570/50.Temp=SI. WHPs(Secure).AL spooll is dropped. No well house on well.WHPs unchanged since 5/26.Tee&block valve installed on IA. Integral is installed on IA=inspection current. Integral is installed on OA=inspection not current. LELs=0%. SV,WV,SSV=Closed. MV=Open. IA,OA=OTG. NOVP. (1830 hrs). 05/30/13 T/I/0=540/570/50.Temp=SI.WHPs(Secure).AL spool is dropped. No well house.Tee&block valve installed on IA. Integral installed on IA=inspection current. Integral installed on the OA=inspection not current. LELs=0%. SV,WV,SSV=Closed. MV=Open. IA,OA=OTG. NOVP. (1700 hrs). 06/02/13 1/1/0=600/600/60 Temp=S/I Assist cementers(P&A) Pumped 5 bbls MEOH& 130 bbls 80*diesel down tbg for annular Freeze protect plus 20 extra. SLB pumped cement mix. pumped 59 bbls 80*diesel down tbg for tbg freeze protect.to assist cementers. FWHP's=500/0/300 Cementers in control of well at departure. 06/02/13 T/I/0=SSV/570/60.Temp=SI.Assist FB w/cementing ops(P&A).AL spool removed. Monitored LELs (0%)&assisted SLB&FB as needed. See log for details. LEL's=0%on 4-26 entire job.Job complete. SV, WV, SSV=C. MV=0. IA, OA=OTG. NOVP.23:45. 06/02/13 Pump 5 bbls Meth Spear, 100 bbls 1% KCI Sweep130 bbls Diesel IA Freeze Protection,250 bbls of Class"G"CMT w/o Aggregate.Chased w/2 bbls Fresh Water, drop CMT Plugs, chase w/5 bbls Fresh Water, 53 bbls 1% KCI, and 59 bbls of Diesel Freeze Protection. Estimated TOC in TBG @ 6480', Estemated TOC in IA @ 6444'. Estimated Length of CMT @ 3608'. CIP @ 22:00 hrs 02June2013. 06/03/13 T/I/O= SSV/0+/80.Temp=SI.WHP's(gas migration). Integral installed on IA=inspection current. Integral installed on OA=inspection not current. CV, SV, SSV=C. MV=0. IA, OA=OTG. NOVP. 0750 hrs. 06/05/13 T/I/0=SSV/0/40. Temp=SI.WHPs(gas migration).AL spool dropped. LELs=0%.Well house removed. OAP decreased 20 psi since 04:30. SV,WV, SSV=C. MV=0. IA, OA=OTG. NOVP. 16:35. 06/05/13 T/I/O= SSV/0+/60.Temp= SI.WHPs(gas mitigation).AL spool dropped. LELs=0%.Well house removed. SV,WV, SSV=C. MV=0. IA, OA=OTG. NOVP. 04:30 hrs. 06/06/13 T/I/0=SSV/0+/60.Temp=SI.WHP's(Gas migration).AL spool removed. No change in WHP's overnight. SV,WV, SSV= C. MV=0. IA, OA=OTG. NOVP. 1345 hrs. 06/07/13 T/I/O=ssv/0/60.Temp=SI. Monitor WHPs(gas mitigation).Al spool dropped. No well house. LEL's= 0%. No mercaptan odor detected in area. SV,WV,SSV=C. MV=0. IA, OA=OTG. NOVP 08:30 Hrs. 06/08/13 T/I/O=ssv/vac/60.Temp=SI. Monitor WHPs(gas mitigation).AL spool dropped. No well house. 0% LEL's. No mercaptan detected in area. Integral installed on IA=inspection current, Integral installed on OA=inspection not current. SV,WV,SSV=C. MV=0. IA, OA=OTG. NOVP 08:30 Hrs. 06/09/13 T/I/0=ssv/vac/60.Temp=SI. Monitor WHPs(gas mitigation).AL spool dropped. No well house. LEL's= 0%. No mercaptan detected in area. Integral on IA=inspection current, Integral installed on OA =inspection not current. SV, WV,SSV=C. MV=0. IA, OA=OTG. NOVP 09:00 Hrs. 06/10/13 T/I/0=ssv/vac/60.Temp=SI. Monitor WHPs(gas mitigation).AL spool dropped. No well house. LEL's= 0%. No mercaptan detected in area. Integral on IA=inspection current, Integral installed on OA =inspection not current. SV,WV,SSV=C. MV=0. IA, OA=OTG. NOVP 08:45 Hrs. Page 3 of 4 • 04-26, Well History (Suspension) Date Summary 06/12/13 T/I/O=SSV/0+/50.Temp=SI.WHPs(gas migration). 0% LEL's.AL spool dropped. IA&OA have integrals installed=inspection current. IAP increased to positve pressure. OAP decreased 10 psi since 06/10/13. SV,WV, SSV=C. MV=O. IA&OA=OTG. NOVP. 0815. 06/12/13 T/I/O=ssv/0+/60. Temp=SI.Assist SL(secure).Al spool dropped. No well house. LEL's=0%. Monitor LEL's while SL is on well. SL in control of valves.TP&IAP bleed to 0 psi. Control&Balnce line bled to 0 psi.Job complete. SV,WV,SSV= C. MV=0. IA, OA=OTG. NOVP 18:00 Hrs. 06/12/13 DRIFTED W/3.70"CENT&3"BAILER,TAGGED TOC AT 6232'SLM (sample of cement recovered). 06/13/13 T/I/0=SSV/0+/60.Temp.=SI.WHPs control and balance line psi (gas migration).AL spool dropped. No well house. LELs=0%. Control line=0+psi. Balance line=0 psi. Small leak detected on control line @ 12 oclock. SV,WV, SSV=C. MV=0. IA&OA=OTG, NOVP. 0800 hrs. 06/14/13 T/I/O=SSV/0+/50.Temp=SI.WHPs control and balance line psi (gas migration).AL spool dropped. No well house. LEL's=0%. Control line=0+psi. Balance line=0 psi. Small leak detected on control line @ 6 o'clock position of tree.Wiped clean with rag. IA&OA have integrals=inspection current. SV,WV, SSV=C. MV=0. IA, OA=OTG. NOVP. 08:50. 06/14/13 T/I/O=SSV/0+/60,Temp=SI. Repair leaking control and balance lines. Control and Balance lines are weeping gas/fluid from gland nut assemblys. Stung into test void separating control lines from hanger test void(1200 psi), bled to 0 psi.Adjusted gland nuts. PT void to 5000 psi, leaks mitigated. Cleaned up well head. 06/16/13 T/I/0=20/04/29 Temp=Sl Assist DHD MIT TBG 3000 psi PASSED (Fullbore P&A) Pumpewd 1.8 bbls of 50*meth down TBG to reach 3000 psi for MIT TBG 1st test 1st 15 min lost 65 psi 2nd 15 min lost 39 psi for a total of 104 psi ini 30 min RE-psi w/.0 2nd test 1st 15 min lost 33 psi 2nd 15 min lost 29 psi for a total of 62 psi in 30 min RE-psi w/.0 3rd test 1st 15 min lost 32 psi 2nd 15 min lost 24 psi for a total of 56 psi Re-psi w/.0 4th test 1st 15 min lost 25 psi 2nd 15 min lost 23 psi 3rd 15 min lost 20 psi for a total of 68 psi in 45 min Bleed TP down bleed back aprx.2 bbls Wing shut swab shut ssv shut master open casing valves open to gauges Final Whp's=10/4/30. 06/16/13 T/I/0=20/4/29.Temp=SI.Assist FB w/MIT-T. (P&A).AL spool dropped. No wellhouse. LEL's=0%. Monitored LEL's for LRS unit during MIT-T. C/O w/day shift&monitored for LEL's, LEL's=0%. LRS to re- MIT-T. See log for details. Final WHP's= 18/9/33. LRS in control of well on departure. 06/16/13 T/I/0= 153/7/33 Temp=Sl MIT TBG 3000 psi***PASS***(Fullbore P&A) Pumped 1.5 bbls of ambient meth to reach test psi. bled back—1.5 bbls of meth. Pumped 1.5 bbls of ambient meth to reach test pressure. 15 min Tbg lost 130 psi/IA gained 2 psi. 30 min Tbg lost 54 psi/IA gained 0 psi.Total Tbg lost 184 psi/IA gained 2 psi. bled back—1.5 bbls of meth.Well SI upon LRS departure SV,WV,SSV=C MV=O CV's=OTG FWHP's 18/9/33. 06/19/13 CMIT PASSED to 3000 psi. MIT-IA PASSED to 3000 psi. CMIT-TxIA: Pump 8 bbls to achieve test pressure.Tubing/IA lost 85/74 psi 1st 15 min and 37/36 psi 2nd 15 min for a total loss of 122/110 psi over 30 min test. Bleed psi's, approx 6 bbls. MIT-IA: Pump 4.3 bbls meth to achieve test pressure. IA lost 149 psi 1st 15 min and 43 psi 2nd 15 min for a total loss of 192 psi over 30 min test. Bleed IAP, approx 5 bbls. FWHP 0/0/40 SV,WV,SSV=closed, MV=open, IA and OA=OTG. Page 4 of 4 TTREE • FAAC SA NOTES: GAS COMM.OA TO ATM'OSPI-32E, WE LI-EAD= FMC ACTUATOR= BAKER C 4 2 6BETWB34®318"Aft 20TO PRIOR 9)OA CO 96 REF'AIR,M.AAPPEARS TO WTIAL KB.ELEV= 65' BE@ 30'(TOOL JT)""CFROM E TBG' 'PLUGS SET IN BF ELEV= XN MP OR BETWEEN PKR&XN NP WILL NOT PASS KOP= _? Max Angle= 48'@ 6135' PRESSURE TEST. Datum MD= 10848' Datum TVD= 8800'SS Q 2270' —5-1/2"CAM BAL-O SSSV NIP,ID=4.562" 13-318"CSG,72#,L-80, I I0=12.347" - 2497' • 2534' H5-112'X4-112X0,ID=3.958" 5-1/2"T8G, 1711,13-CR,.0232 bpf,ID=4.892" —{ 2534' GAS LIFT MANDRELS ST M7 IVD DEV TYPE VLV LATCH PORT DATE TOP OF CEMBYT-TBG (TAGGED 06/12/13) — 6232'SLM 7 3255 3245 16 KBMG DMY BK 0 12/22/12 ES-MATED CMT IN IA (06/02/13) — 6444-10088 °SAW t? 6 5786 5192 47 KBMG DMY BK 0 05/21/06 5 7273 6203 47 KBMG `DMY BK 0 03/27/06 4 8235 6890 42 KBMG 'DMY BK 0 07/18/02 4.44..11111Aitiolli, 3 9041 7484 44 KBMG 'DMY BK 0 10/04/97 Minimum ID = 3.958" @ 2270' 2 9978 8154 43 KBMG 'DMY BK 0 10/04/97 5-1/2" X 4-1/2" XO 1 10088 8236 X41 KBMG "E MY - 05/24/13 STA'S4 1 -5= COV Ea BY CI]VETIT .470151 I I 1%.9V 10197' —19-5/8"X 4-1/2"TW HB-BP-T FKR I 10273' —14-112"OTIS XN NP,ID=3.725" I TOP OF 7"LNR 1-{ 10291' 4-1/2"TBG, 12.6#,13-CR,.0152 bpf,D=3.958' H 10295' / \ 10295' —14-1/2'WLEG,ID=3.958" x'1'1'1'1'1'1'17 X1111111/1111111 10310' H ELM)TT LOGGED 08/28/06 11 11111111111111 J 11111111 10309'S LM l TOP OF CEMENT(05/11/13) 9-5/8"CSG,47#,L-80,ID=8.681^ H 10522' 1111111111111111 W 1111111/1/11111 1111111111111111 41111111/1111111 PERFORATION SUMMARY 11/1/11/111111 REF LOG:BRCS ON 03/08/86 X11/1111/111111 ANGLE AT TOP FERE: 31°@ 10545' .11/111111/11/1 11 1111111111111 Note:Refer to Production DB for historical perf data 411/1111 SIZE SPF NTERVAL Opn/Sqz SHOT SQZ �11A1.111' 10605' --4-1/2"BKR BP(TAGGED 05/06/13) 3-3/8' 6 10545-10560 C 04/07/11 3-3/8" 6 10598-10608 C 03/14/05 111 3-3/8" 6 10620-10626 C 03/14/05 ' 3-3/8' 6 10649-10682 C 02/16/09 4 10710-10730 C 11/12/94 ' 4 10730-10750 C 06/08/87 10690' H4-1/2"BKR BP(03/14/05) PB7D —I 10725' X111"' ....1 11111111 4444.4.111/111 :11111111111114' 411/1/1111111111 7"LNR,29#,L-80,.0371 bpf,HD=6.184" H 10865' �111111111111�114 TD H 10866' DATE REV BY CON/MEWS DATE REV BY COMMENTS PRUDHOE BAY WIT 03/12/86 ORIGINAL COMPLETION 05/26/13 TJFVPJC STA#7 EMTTY (05/24/13) WELL: 04-26 10/04/97 D16 FANO 05/26/13 PJC GLV STATION NUMBERING FERMI No:n1853140 01/31/12 JMVJMD TREECIO(01/12/12) 06/18/13 RENVPJC 2N7 STAGE CMT(06/02/13) AA No: 50-029-21520-00 05/29/12 M15S/JMD PULLED DSSSV PLUG(05/25/12) 07/10/13 PJC LNR CMT CORRECTIONS SEC 26,T11N,R15E,9Z FSL&429'FWL ' 12/27/12 MSS/JMD SET EVO FLUG/GLV C/O(12/22/12) 05/25/13 TJI-VPJC PULL EVO&BP(05/06/13) BP Exploration(Alaska) • PTA l85 Ferguson, Victoria L (DOA) From: Ferguson, Victoria L (DOA) Sent: Wednesday, May 22, 2013 2:37 PM To: 'Worthington, Aras J' Subject: RE: PBU 04 -26 P&A Sundry(PTD 185 -314, Sundry 313 -190) Aras, The current tag and pressure test of the bottom cement plug is acceptable to the AOGCC. Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 SCANNED JUN 1 4 2013 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferqusonalaska.gov From: Worthington, Aras J [mailto:Aras.Worthington @bp.com] Sent: Wednesday, May 22, 2013 2:27 PM To: Ferguson, Victoria L (DOA); Stephens, Joshua L Cc: DOA AOGCC Prudhoe Bay Subject: RE: PBU 04 -26 P&A Sundry(PTD 185 -314, Sundry 313 -190) Victoria, Pursuant to our phone conference call can you please confirm that our current Tag and PT of the bottom cement plug is acceptable to the AOGCC and that no further interventions are required before we pump the next cement plug? Josh Stephens will follow up with you requesting approval to extend the length of the upper cement plug as we discussed. Thanks for your consideration, Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 Cell: (907) 440 -7692 From: Ferguson, Victoria L (DOA) [ mailto :victoria.ferguson @alaska.gov] Sent: Tuesday, May 21, 2013 4:23 PM To: Worthington, Aras J; Stephens, Joshua L Cc: DOA AOGCC Prudhoe Bay Subject: RE:PBU 04 -26 P&A Sundry(PTD 185 -314, Sundry 313 -190) Aras, 1 EINEM • As stated in the sundry "04 -26 is suspected to be a conduit for the gas migration to surface resulting in LEL readings in surrounding well houses. The purpose of this reservoir P &A is to isolate the Ivishak and eliminate it as a possible gas source in the IA." As such our inspector has inspected the contaminated cement sample obtained from the first plug as well as the SL string tag and determined that the following is required. Use service coil to clean out below the contaminated cement to get to competent cement and sample. Also tag plug with at least 600 #. Please contact the AOGCC inspectors to witness cement sample and tag. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferqusonAalaska.00v From: Worthington, Aras J ( mailto :Aras.Worthington(abp.com] Sent: Tuesday, May 21, 2013 3:43 PM To: Ferguson, Victoria L (DOA) Subject: 04 -26 P&A Sundry Victoria, The sundry number for this well is: 313 -190 The PTD number is: 185 -314 Thanks for taking a look at this. Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564-4102 CeII: (907) 440 -7692 2 p r 6g5- 31 4- Ferguson, Victoria L (DOA) From: Ferguson, Victoria L (DOA) Sent: Wednesday, May 22, 2013 4:43 PM To: 'Stephens, Joshua L' Subject: RE: PBU 04 -26 P&A Sundry(PTD 185 -314, Sundry 313 -190) Joshua, Your procedure is approved as submitted for the second stage of cementing. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer JUN 4 h State of Alaska SCANNED JUN 1 4 ZD13 Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.ferqusonalaska.qov From: Stephens, Joshua L [mailto:Joshua.Stephens @bp.com] Sent: Wednesday, May 22, 2013 4:25 PM To: Ferguson, Victoria L (DOA) Subject: PBU 04 -26 P&A Sundry(PTD 185 -314, Sundry 313 -190) Hi Victoria, We are requesting a minor change to the procedure and sundry on the plug and abandonment for 04- 26(PTD 185 -314, Sundry 313 -190). The original program called for bringing the cement top to 8,500'MD but after an internal review we feel it's best to bring the TOC up to 6,500'MD to cover all know production casing leaks in the 9 -5/8" string. This will further reduce risk and enable the confirmation of plug integrity via pressure testing. I have attached the revised procedure for your review; the changes are indicated by red text. Please let me know if the state agrees with the changes and we will proceed with the second stage of cementing. Thanks, Joshua Stephens Well Intervention Engineer Office: 907 - 564 -4998 Cell: 903 - 816 -0183 WO global wells organization 1 • • Memorandum To: C. Olsen /J. Bixby Date: March 26, 2013 GPB Well Ops Team Leaders Code: APBRISKM From: Joshua Stephens Welt Interventions Engineer (903)816 -0183 (907)564 -4998 Subject: 04 -26 Reservoir P&A IOR: N/A Est. Cost: $80,000 Please perform the following procedure: 1. S Pull 4 -1/2" Evotrieve, D &T IBP 2. F Injectivity Test. 3. F Fullbore P&A (Cement Perfs) with 11 bbls of class G cement. Plan TOC at 10,337' MD. 3. F MIT -T to test cement. 4. S D &T cement. Pull DGLV in Sta #1 (10088' MD). 5. F Fullbore P&A (Balanced Plug) with 250 bbls of class G cement. Plan TOC at 6,500' MD. 6. S D &T cement. 7. F MIT -T to test cement Current Status: Not Operable Producer Last Test: 05/10/2011 4 BOPD; 1531 BWPD; 3657 Mscf form gas Max Deviation: 48 degrees @ 6,135' MD Minimum ID: 3.725" @ 10,273' MD Last Downhole Op: 12/22/2012 Set 4 -1/2" EvoTrieve © 10,161' SLM Last TD Tag 04/24/11 3.25" LIB to IBP @ 10,545' MD Latest H Value: 04/27/2011 80 ppm H2S Program Objectives: Perform reservoir P&A to mitigate gas migration to surface. History Well 04 -26 was drilled in 1986 as a Z1 producer. WC remained below 10% until mid -1990 after which it steadily rose to over 90% in 1994. Z1 was frac'd in 1994, however the oil rate remained relatively constant despite the increase in GFR. A 1997 RWO placed new chrome tubing in the well. 21P perfs were shot in November 1994. An IBP was set over the 14P/21P perfs and 23P/24P perfs were shot in March 2005 resulting in a 600 BOPD boost at uncompetitive GOR. A second IBP was set over the 23P in August 2006 to shut -off water production and 24P perfs were shot to perform a LoSal SWTT. • • Following a series of failed pressure tests, 04 -26 was deemed NOT OPERABLE and shut -in May 2007. A September 2007 TecWel LDL identified 4 small PC leaks that were later repaired in January 2008 with Sealtite. The post- repair production behavior from the 24P had uncompetitive GOR. The uppermost IBP was pulled in February 2009 and 22P perfs were added; asphaltenes were recovered along with the IBP. Water increased to nearly 10000 BFPD, oil /gas rates began to fall, and the GOR remained high.In 2011 15 feet of perfs were shot in the 25P and an IBP was set to isolate all zones below. The well was later shut in in 2011 for high GOR. On 12/22/2012 well 04 -26 failed MIT -IA on 3 attempts, raising suspicion of 04 -26 being a culprit for the gas migration seen in the SE comer of DS -04. To verify this theory, the following detailed evaluations were conducted: a. IA Fluid level depression (slow leak 1 gpm) until FL stabilizes, depressure 04 -26 IA and monitor BUR and FL increase (On 12/30/2012, the LEL's on all the DS4 SE wells fell to near zero. LEL's readings remained zero 12/31/12 to 1/19/13. Until when LEL's returned 01/20/13, inside 3 well houses; the likely source of gas being the liquid level depression test on well 4 -26), b. tagged annular gas with mercaptan and it was observed in front of wells around 4 -26 and inside 4 -31 well house by consistent LEL observers (though only observed on 1 day). . Based on the diagnostics above, 04 -26 is suspected to be a conduit for the gas migration to surface resulting in LEL readings in surrounding well houses. The purpose of this reservoir P&A is to isolate the Ivishak and eliminate it as a possible gas source in the IA. A full P&A will not be conducted until the well is evaluated for other options and all diagnostic work is completed. PROCEDURE SLICKLINE 1. Pull 4 -1/2" EvoTrieve from 10,169'MD FULLBORE 1. Perform an injectivity test by pumping 1% KCL followed by freeze protect. Pump the injectivity test at max rate not to exceed 3000 psi. Pump schedule is below. a. 5 bbls meth spear b. 290 bbls 1% KCL c. 58 bbls of diesel (freeze protect) 2. Be ready to bleed IA and OA during pumping operation. FULLBORE 3. Perform a fullbore cement P&A per RP. Planned TOC in the Tin liner is 10,337' MD. See [Appendix A] for the detailed procedure. FULLBORE 4. Perform a MIT -T to 3000 psi to test cement plug. Use any non - freezable fluid for test. If pressure test fails contact town before proceeding. SLICKLINE 5. Drift and tag cement top with a 2.5" centralizer / s- bailer. Ensure a sample of cement is obtained and note in AWGRS. Gauge down to a smaller centralizer if necessary. 6. Pull DGLV from Sta #1 at 10,088' MD and leave pocket empty. A catcher sub is not required as an additional cement job will be pumped after this operation. If this pocket is covered in cement or cannot be pulled for any other reason, a -line will need to punch holes above the current TOC. FULLBORE 7. Perform a fullbore cement balanced plug per RP. Planned TOC in the TBG and IA is 6,500' • • MD (approximately 3,588' above the open pocket at 10'088 MD). See [Appendix B] for the detailed procedure. SLICKLINE 8. Drift and tag cement top with a 2.5" centralizer / s- bailer. Ensure a sample of cement is obtained and note in AWGRS. Gauge down to a smaller centralizer if necessary. FULLBORE 9. Perform a MIT -T to 3000 psi with diesel. Perform a CMIT -IA to 3000 psi while keeping 1,000 psi on tubing tide cctbtich LLR. Note: there arc known caring aks in the 9 5/8" casing; we do not expect it to past a- pror..cure test. APPENDIX A: Fulibore P &A Operation for 04 -26 From: Josh Stephens — Wells Group PE Contact: 903 -816 -0183 Tubing /Casing Data Tubing OD ID Capacity bbl /ft 5 -1/2 ", 17# 13 -Cr 5 -1/2" 4.892" .0232 4 -1/2 ", 12.6# 13 -Cr 4 -1/2" 3.958" .0152 Liner OD ID Capacity bbl /ft 7 ", 29# L -80 7" 6.184 .0371 Casing OD ID Capacity bbl /ft 9 -5/8 ", 47# L -80 9 -5/8" 8.681" .0732 Annular Capacity Capacity bbl /ft 9 -5/8" X 4 -1/2" .0535 " - 9 -5/8 X 5 1/2 " .0438 Notes: • SLB to use their portable panel to take control of SSV. • SLB to bring climbing harnesses for accessing top of well house. • Diesel to be heated to 70 deg to prevent thermal expansion while waiting on cement. • Track IAP and OAP during pumping. IA and OA may be fluid packed and thermal effects may cause annulus pressure to increase. Be prepared to bleed if necessary. Cement Window Target TOC is 10,337' MD Highest allowable TOC is 10,140' MD Deepest allowable TOC is 10,445' MD Perf Info Top open perf 10,545' MD Bottom open pert 10,560' MD Total Footage (of open perfs) 15' Total Footage (between top and bottom) 15' (0.28 bbls) Cement Design: BHST —170 deg F. SBHP — 3300 psi. BHCT —140 deg F Density = 15.8 ppg Mix on the fly Thickening time = 3 to 4 hrs. Fluid Loss = 80 -120 cc/30 min Requested Volume is 11 bbls. Pump time = 35 minutes at assumed rate of 5.0 bpm Volumes: Requested TOC (10,337') to Btm Perf (10,560') = 8.27 bbls Requested TOC (10,337') to Top Perf (10,545') = 7.72 bbls Shallowest TOC (10,445') to Top Perf (10,545') = 371 bbls Calculated TBG volume from surface to desired TOC 10,337' MD = 177.8 bbls WC -TOC if well locks up with cement at the Top Perf (10,545'): 10,141' MD. Plan Forward: Grease Crew • • Grease all tree valve cavities, including SSV. Ensure wing is shut and indicate (tag) that wing is to remain closed for entire job. Monitor pressure on IA and OA during pumping Heat diesel in tanks to 70 °F prior to arrival of SLB Cementers DHD FL's on TBG and IA. If IA pressure is greater than -0 psi, bleed any gas off IA to -0 psi. During the P&A, be ready to bleed IA and OA pressure if the IA or OA pressures up during the cement job (above 1000 psi) due to thermal expansion. Rigup Crew Rig up iron for Fulibore Cement job - with ball launcher loaded with two 7" foam balls. Typically 2 balls are loaded but the minimum requirement is one). Include the horse trailer or 4 way manifold so that SLB only needs to rig up to trailer. Ensure all valves are accessible with the tree scaffolding. If valves are not accessible, it will be necessary to rig up additional scaffolding. Schlumberger Rig up portable panel to take control of SSV PT all iron, 200 -300 psi for low PT; 4,000 psi for high PT (per SOP pressure testing requirements) Close lateral valve Ensure SLB has transducers to monitor IAP and DHD is monitoring OAP. Pump Schedule (pump at max rate not to exceed 3500 psi in all cases except where noted) • 5 bbl meth spear • 264 bbls 1 % KCL - To kill and fluid pack well. 5.0 -8.0 bpm. This will also line out well and ensure stable injection prior to pumping cement. • 10 bbis chemical wash • 5.0 bbis 15.8 ppg "G" cement • 3.0 bbis 15.8 ppg "G" cement with 15 ppb aggregate • 3.0 bbis 15.8 ppg "G" cement • 2.0 bbis water - To clear lines Divert flow thru ball launcher and drop ball(s). Open workover valve then low- torque, in that order. • 5.0 bbis water behind ball Open side outlet of cement manifold so we are pumping into both inlets • 112 bbls ofl %KCL • 58.7 bbis of diesel 170.7 bbls of fluid (KCL diesel) will put the cement at the requested top. With 167.5 bbis of fluid away, the leading edge of cement will be close to the top pert. Slow rate to -1.0 bpm and pump cement to the perforations. Do not exceed 170.7 bbls of diesel /KCL (177.7 bbls of TOTAL cement displacement). If well squeezes off: (increase of 1000 psi or more starting when cement reaches perfs) • Max squeeze pressure is 2500 psi • Hold pressure for 30-60 minutes, then bleed down to 500 psi If no squeeze pressure is achieved: (less than 1000 psi increase after cement reaches perfs) • After design displacement, shut -in well and rig down. Wash up cementers • RD SLB cementers CaII Valve Shop to service Tree (Post Cement) Check WHP in 6 hours. If pressure exceeds 2000 psi, bleed back to 500 psi. • • APPENDIX B: Fullbore Balanced Plug Operation for 04 -26 From: Josh Stephens — Wells Group PE Contact: 903- 816 -0183 Notes: • SLB to use their portable panel to take control of SSV. • SLB to bring climbing hamesses for accessing top of well house. • Do not u -tube after displacing cement and shutting down; this could inadvertently push cement back up into the TBG. • Returns will need to be taken from the IA for the cement circulation. Returns can either go to tanks of back to the facility. It is recommended that returns are setup to go to the facility to minimize fluid disposal. • Track OAP during pumping. The OA is fluid packed and thermal effects may cause annulus pressure to increase. Be prepared to bleed if necessary. Cement Design: BHST —170 deg F. SBHP — 3267 psi. BHCT —140 deg F Density = 15.8 ppg Mixon the fly Thickening time = 3 to 4 hrs. Fluid Loss = 50 -80 cc/30 min Requested Volume is 110 bbls. Pump time = 22 minutes at assumed rate of 5.0 bpm Suggested plan forward: Grease Crew Grease all tree valve cavities, including SSV. Lock wing in closed position. Rigup Crew Rig up iron for a Fullbore Cement job — with ball launcher loaded with two 7" foam balls. Typically 2 balls are loaded but the minimum requirement is one). Include the horse trailer or 4 way manifold so that SLB only needs to rig up to trailer. Ensure all valves are accessible with the tree scaffolding. If valves are not accessible, it will be necessary to rig up additional scaffolding. At a minimum, return tanks that can hold at least 200 bbls is needed if the facility needs to shut in and returns must go to tanks after the cement has been pumped. Once the cement is pumped, the job must be continued until cement is displaced to required TOC. It is recommended that sufficient tank capacity be on location to take the entire job to tanks if necessary. DHD During the P&A, be ready to bleed OA pressure if the OA pressures up during the cement job (above 1000 psi) due to thermal expansion. Schlumberger Rig up portable panel to take control of SSV PT all iron, 200 -300 psi for low PT; 4,000 psi for high PT (per SOP pressure testing requirements) Close lateral valve Ensure DHD is monitoring OAP. Fluids Needed: 312 bbls - 1% KCL 190 bbls - Diesel • • 250 bbls —15.8 Class G Cement (plus —90 bbls fresh water for cementers) (p ) Pump Schedule: All fluids will be pumped down the TBG and up the IA out to the facility (or a return tank). Pump at max rate not to exceed 3000 psi. • 5 bbls meth spear • 100 bbls 1% KCI — To begin sweeping hydrocarbons from TBG and IA. • 130 bbls of diesel — annular freeze protect plus 20 bbls excess • 212 bbls of 1% KCL • 250 bbls of 15.8 ppg "G" cement (no aggregate) • 2.0 bbls fresh water — To clear lines Divert flow thru ball launcher and drop ball. Open workover valve then low - torque, in that order. • 5.0 bbls fresh water behind ball Open side outlet of cement manifold so we are pumping into both inlets • 53 bbls of 1% KCL • 58 bbls of diesel Total displacement of cement should not exceed 119 bbls. This will put the TOC in the TBG at 6500' MD (and TOC in the IA at 8500' MD). Do not u -tube even if a pressure differential exists after pumping schedule. Wash up cementers RD SLB cementers Call Valve Shop to service Tree (Post Cement) • • Current Configuration „ FTC SAFETY NOTES: GAS COMM. OA TOATMOSPHERE, WELLHEAD = FMC ACTUATOR = t3AKE3 C 4 *+2 (UNRELATED BETW� 13-3/8" AND 2W) OA COMM. APPEARS E TO BF. ELEV = BE @ 30' (TOOL JT) •"" CHROME 713G ""'PLUGS SET IN XN NP OR BETWF3�1 T35T. P$(R 8, XN NIP WILL NOT PASS ? KOP= � PREBSURET Max Angle = 48 'i 6135' Datum MD = 10848' Datum7V0= - -- 8800' SS 0 2270' H5 -112" CAM BAL -O SSSV NP, D= 4.562 13-3/8' CSG, 72#, L -80, D = 12.347" — I 2497' I ' I 2534' 1--15-v2 X 4-1/2" XO, D= 3.958- I 5.1/2° TBG, 17 #, 13-CR .0232 bpf, D= 4.892" H 2534' 1"" -.-------"+ GAS LET MANDRELS _1ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3255 3245 16 KBMG DMY BK 0 12/22/12 2 5786 5192 47 KBMG 0M' BK 0 05121/06 3 7273 6203 47 KBMG DMY BK 0 03/27106 4 8235 6890 42 1(5143 DMY BK 0 07/18/02 5 9041 7484 44 KBMG DMY BK 0 10/04/97 Minimum ID = 3.725" @ 10273' 6 9978 8154 43 KBMG DM) BK 0 10/04/97 4 -1/2" OTIS XN NIPPLE 7 10088 8236 ' 41 KBMG DMY BK 0 02/16/08 . I 10169' H4- 1/2"I S EVOTRIEVEPLUG(1222112) I I 10197' H9 -518" X 4 -1/2" 1W FIB -BP-T F4(R I I I 10273' H4 -1/2" OTIS XN NP,D = 3.725' I ITOP OF 7" LN2 I—I 10291' I 4-112' TBG, 12.64, 13-CR, .0152 bpf, D = 1958" H 10296' I X F 10296' I— I4 -1/2" WLEG, D = 3.958' I I 10310' Haim TT LOGGED 08/28/06 I 1 9-5/8' CSG, 47 #, L -80, D= 8.681" H 10622' I-41 ■ PBFPORAl1ON SUMMARY ' 10568' 5' SIUGGITS (04124111) 11W LOG: BRCS ON 03/08/86 ANGLEATTCPPF3iF: 3f° 10545 �3tz 10573' H 3-3/8" BKRX- FLOW BP (04108/11) Nate_ Refer to Production DB for historical perf data ' SIZE SPF INTERVAL SHOT DATE SW 33/8" 6 10545 - 10560 0 04/07/11 I 3-3/8' 6 10598 - 10608 C 03/14/05 3-3/8' 6 10620 -10626 C 03/14/05 33/8" 6 10649 - 10682 C 02116/09 4 10710 - 10730 C 11/12/94 4 10730 - 10750 C 06/08/87 1:0680' H4-1/2 BKR BP (03/14/05) I PBTD 10725' 4444444' •444444► / i +l•f ∎ 4.1 + 1 + 1 4 T LIB 294, 1 -80, .0371 bpf, D = 6184 F f 10866' I x + + 4 + 4 + 4 + 1 + 4 + + + 1 4 4 4 4 + 4 + 4 + 4 + 4 + 4 + 4 TD 10866' DATE RB/ BY COMWEN S DATE REV BY COM ENTS PRUDHOE BAY (NT 03/12/86 CAGINAL COMPLETION 0428/11 TA/PJC DUMP SLUGGITS (04/24/11) WEIL: 04-26 10104/97 D16 RWO 08/28/11 TAW PJC SET DSSSV PLUG (08/26/11) PERMIT No: '1853140 02/07/09 SWC/SV RILL BP(02/05/09) 01/31/12 AN .SAD TRMC/O (01 /12/12) AR No: 50- 029 - 21520 -00 02/17 /09 RR(/SV ADPBZF (02/16/09) 05/29/12 MSS/ND RILLED D6SSV PLUG (05/25/12) SFr= 26, T11t' R15E, 97 FSL & 429' PM. 10)02/09 DS/PJC 13MO TT LOGGED (0828106) 12/27/12 MSS/JMD SET EVO R.l1G/GLV C70 (12/22/12) 04/23111 TTWIPJC SET BP/ PEPF(04/07- 08/11) I BP Expbration (Alaska) • • Proposed Configuration TREE INC SAFETY NOTES: GAS COMM. OA TO ATMOSPHERE, WELL FtAD- FMG KB 11 TOk BAKER C 04-26 ( BETW�I ®3/8" AND 20") OA CO. . TO BF _ lV 65' /3E@ 30' (TOOL JT) "'* CHROMETBC *""PLUGS SET IN XN MP OR BETWEEN PKR & XN MP WILL NOT PASS KOP= 7 PRESSURE TEST. Max Angle _ 48` @6135' Datum Mn 10848' Datum ND 0 D = 8800' SS 2270' 1 - 1/2" CAM BAL-0 SSSV NF', D = 4 -562" 113 -3/8' CSG, 72#, L -80, D = 12.347' --I 2497' 1 2534' - {5 -1/2" X 4 -1/2" XO, D= 3.958" I 5-1/2" TBG, 17#, 13-CR, .0232 41,13= 4.892" H 2534' l''"'"" ---..."'_ GAS LIFT MANDRELS ' TOC 6,500' MD I sri ND 1 WI) �DLVJ TYPE VLV MATCH FORT DATE 1 3255 3245 16 KBMG OAT BK 0 12122/12 2 5786 5192 47 KBMG DMY BK 0 05/21/06 3 7273 6203 47 Kt3MG DMY BK 0 03/27/06 Est. TOC in 9 -5/8" 9,129' MD 4 8235 6890 42 KBMG DMY BK 0 07/18/02 5 9041 7484 44 KBMG DMY BK 0 10804/97 Minimum ID =3.725" @ 10273' 6 9978 8154 43 KBMG DMY BK 0 10/04/97 4 -1/2" OTIS XN NIPPLE 7 10088 8236 ' 41 KBMG DMY BK 0 02/16/08 ---- Planned BOC 10,088' MD �, —% 10197' I- {9 -5/8" X 4 -1/2' TNY FB-BRT FKR I • —I 10273' I - 4-1/2" OTIS XN NIP,D = 3.725" I [TOP OF 7'LNR 10291' Planned TOC 10,337' MD {4- 112" TBG, 12.6#, 13 -CB, .0152 bpf, D = 3.958' - 1--r 10295' I - 7 I ' 10295' H 4 1 / 2 ' 1 13 = 3 9 5 8 ' I 10310' I ELmo TT LOGGED 08/28/06 9.518 CSG 47# L -80, D = 8 -681' H 10627 � Pl an ned BOC 10,560' MD PERFORATION SUMMARY ' 10568' H 5' SLUGG(TS (04124/11) REF LOG: BHCS ON 03/08/86 - - --- ANGLEATTOPPERF: 31" @ 10545' 10573' I- 33/8" BKRX- FLOW EP (04108/11) Note Refer to Roduction t>t3 for historical pert data ' SIZE SPF NTEF8/AL SHOT [SATE SOZ 3-3/8' 6 10545 - 10560 0 04/07/11 ' 3-3/8" 6 10598 - 10608 C 03/14/05 3-3/8" 6 10620 - 10626 C 03/14/05 3-3/8' 6 10649- 10682 C 02/16/09 ' 4 10710 - 10730 C 11/12/94 4 10730 - 10750 C 06/08/87 1 0 8 9 0 • _ I PBTOI- 10725' 41111 1 • 4141N 4 ' /44411 44 ►►H41' # 4 41 4 4 1 4 4 1 4 4 4 44 1 17' LNR, 29 #, L -80, .0371 bpf, D = 6.184" I--I 10865' I 41 114►( TD 10866' i�1111140 DATE REV BY CONVENTS DATE REV BY COMMENTS FRUD -OE BAY UHT 03112186 ORIGINAL COMPLETION 04 /28/11 TA/PJC DUMP SLUGGTTS (04 /24/11) WELL: 04-26 10104/97 D16 RWO 08/28/11 TAW PJC SET DSSSV PLUG (08/26/11) F-i1 111 No- '1853140 02/07/09 SWC/SV FULL EP(02/05/09) 1_01/31/12 ,Li'M) TREECJO(01 /12/12) API No: 50- 029 - 21520 -00 02/17109 RRKISV ADPERF (02116109) 05129/12 MSS/JT D PULLED DSSSV R_UG (05/25112) SEC 26, T11 N, R15E, 92' ESL S 429' PM 10/02/09 DS/PJC EAM) TT LOGGED (08/28/06) 12/27/12 MSS/JMD SET EVO PLUG/GLV C/O (12/22/12) 04/23/11 TTW/PJC SET IBP/PERE(04/07- 08/11) j BP Exploration (Alaska) • • PTV 05 Ferguson, Victoria L (DOA) From: Ferguson, Victoria L (DOA) Sent: Tuesday, May 21, 2013 4:23 PM To: Worthington, Aras J'; 'joshua.stephens @ bp.com' Cc: 'aogcc.inspectors @alaska.gov' Subject: RE:PBU 04 -26 P&A Sundry(PTD 185 -314, Sundry 313 -190) Aras, As stated in the sundry "04 -26 is suspected to be a conduit for the gas migration to surface resulting in LEL readings in surrounding well houses. The purpose of this reservoir P &A is to isolate the Ivishak and eliminate it as a possible gas source in the IA." As such our inspector has inspected the contaminated cement sample obtained from the first plug as well as the SL string tag and determined that the following is required. Use service coil to clean out below the contaminated cement to get to competent cement and sample. Also tag plug with at least 600 #. Please contact the AOGCC inspectors to witness cement sample and tag. Thanx, Victoria SCANNED JUN 14 2013 Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave, Ste 100 Anchorage, AK 99501 Work: (907)793 -1247 victoria.fe rq uson @a laska.gov From: Worthington, Aras 3 [mailto:Aras.Worthington @bp.com] Sent: Tuesday, May 21, 2013 3:43 PM To: Ferguson, Victoria L (DOA) Subject: 04-26 P&A Sundry Victoria, The sundry number for this well is: 313 -190 The PTD number is: 185 -314 Thanks for taking a look at this. Aras Worthington Wells Intervention Engineer BP Alaska Inc. Office: (907) 564 -4102 Cell: (907) 440 -7692 1 w \� I //77 s THE STATE Alaska Oil and Gas ®f l l l l Conservation Commission * h , GOVERNOR SEAN PARNELL 333 West Seventh Avenue (4'41L)S *P Anchorage, Alaska 99501 -3572 Main: 907.279.1433 Clint Spence SCANNED APR 2 5 2093 Fax: 907.276.7542 Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 8 5 3 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 04 -26 Sundry Number: 313 -190 Dear Mr. Spence: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr.. Commissioner 2 DATED this day of April, 2013. Encl. A' , STATE OF ALASKA ALASOPOIL AND GAS CONSERVATION COMMQION RECEIVED APPLICATION FOR SUNDRY APPROVAL APR 2013 20 AAC 25.280 1. Type of Request: ❑ Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved ProgramAOGC ® Suspend ❑ Plug Perforations ❑ Perforate ❑ Pull Tubing ❑ Time Extension ❑ Operations Shutdown ❑ Re -Enter Suspended Well ❑ Stimulate ❑ Alter Casing ❑ Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 185 - 314 • 3. Address: 6. API Numbe ® Development ❑ Service P.O. Box 196612, Anchorage, Alaska 99519 -6612 50.029- 21520 -00 -00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 04 -26 . Will planned perforations require a Spacing Exception? ❑ Yes No 9. Property Designatior 10. Field / Pool(s): ADL 028324 1 Prudhoe Bay / Prudhoe Bay - 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10866' - 8880' ` 10725' 8762' 10690', 10573', 10169' None Casing Length Size MD TVD Burst Collapse 1 Structural Conductor 79' 20" 35' - 114' _ 35' - 114' 1490 470 Surface 2462' 13 -3/8" 35' - 2497' 35' - 2497' 3450 / 4930 1950 / 2670 Intermediate 10492' 9 -5/8" 30' - 10522' 30' - 8588' 6870 4760 Production Liner 574' 7" 10291' - 10865' 8395' - 8879' 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10545' - 10750' 8608' - 8783' 5 -1/2 ", 17# x 4 -1/2 ", 12.6# 13Cr80 10295' Packers and SSSV Type: 9 -5/8" x 4 -1/2" TIW HB -BP -T Packer Packers and SSSV 10197' / 8320' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ❑ BOP Sketch ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: May 1, 2013 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG ® Suspended . 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Josh Stephens; 564 -4998 Printed Name: lin pe e Title: Engineering Team Leader Email: Joshua.Stephens@bp.com Signature: Phone: 564 - 5709 Date: Ly //,? Commission Use Only Conditions of approval: Notify Commission so that a representative may witness 3-0 Sundry Number: tp `Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance yn Other: n h / RBDMS APR 2 5 1113 1v 17 7 � j z0, „,, s_ lM +v w/ � ILt 5 S Spacing Exception Required? ❑ Yes ❑ No Subsequent Form Required: / 0 —• 4 d APPROVED BYj �% �'�j Approved By: / COMMISSIONER THE COMMISSION Date: GG ✓✓✓[[[ ---� Form 211 pproved application is valid for 12 months from the date of ap roval I Submit In Duplicate \/ (1) nwc, 0 -terio, • • Memorandum To: C. Olsen /J. Bixby Date: March 26, 2013 GPB Well Ops Team Leaders Code: APBRISKM From: Joshua Stephens Well Interventions Engineer (903)816 -0183 (907)564 -4998 Subject: Reservoir P&A IOR: N/A Est. Cost: $80,000 Please perform the following procedure: 1. S Pull 4 -1/2" Evotrieve, D &T IBP 2. F Injectivity Test. 3. F Fullbore P&A (Cement Perfs) with 11 bbls of class G cement. Plan TOC at 10,337' MD. 3. F MIT -T to test cement. 4. S D &T cement. Pull DGLV in Sta #1 (10088' MD). 5. F Fullbore P&A (Balanced Plug) with 110 bbls of class G cement. Plan TOC at 8,500' MD. 6. S D &T cement. 7. F MIT -T to test cement Current Status: Not Operable Producer Last Test: 05/10/2011 4 BOPD; 1531 BWPD; 3657 Mscf form gas Max Deviation: 47 degrees @ 5,935' MD Minimum ID: 3.725" @ 10,273' MD Last Downhole Op: 6/02/2012 Set 4 -1/2" EvoTrieve @ 10,161' SLM Last TD Tag 06/01/10 3.25" LIB to IBP @ 10,545' MD Latest H Value: 04/27/2011 80 ppm H2S Proaram Objectives: Perform reservoir P&A to mitigate gas migration to surface. History Well 04 -26 was drilled in 1986 as a Z1 producer. WC remained below 10% until mid -1990 after which it steadily rose to over 90% in 1994. Z1 was frac'd in 1994, however the oil rate remained relatively constant despite the increase in GFR. A 1997 RWO placed new chrome tubing in the well. 21P perfs were shot in November 1994. An IBP was set over the 14P /21P perfs and 23P/24P perfs were shot in March 2005 resulting in a 600 BOPD boost at uncompetitive GOR. A second IBP was set over the 23P in August 2006 to shut -off water production and 24P perfs were shot to perform a LoSal SWTT. • • Following a series of failed pressure tests, 04 -26 was deemed NOT OPERABLE and shut -in May 2007. A September 2007 TecWel LDL identified 4 small PC leaks that were later repaired in January 2008 with Sealtite. The post - repair production behavior from the 24P had uncompetitive GOR. The uppermost IBP was pulled in February 2009 and 22P perfs were added; asphaltenes were recovered along with the IBP. Water increased to nearly 10000 BFPD, oil /gas rates began to fall, and the GOR remained high.In 2011 15 feet of perfs were shot in the 25P and an IBP was set to isolate all zones below. The well was later shut in in 2011 for high GOR. ✓ On 12/22/2012 well 04 -26 failed MIT -IA on 3 attempts, raising suspicion of 04 -26 being a culprit for the gas migration seen in the SE corner of DS -04. To verify this theory, the following detailed evaluations were conducted: a. IA Fluid level depression (slow leak 1 gpm) until FL stabilizes, depressure 04 -26 IA and monitor BUR and FL increase (On 12/30/2012, the LEL's on all the DS4 SE wells fell to near zero. LEL's readings remained zero 12/31/12 to 1/19/13. Until when LEL's returned 01/20/13, inside 3 well houses; the likely source of gas being the liquid level depression test on well 4 -26), b. tagged annular gas with mercaptan and it was observed in front of wells around 4 -26 and inside 4 -31 well house by consistent LEL observers (though only observed on 1 day). . Based on the diagnostics above, 04 -26 is suspected to be a conduit for the gas migration to surface resulting in LEL readings in surrounding well houses. The purpose of this reservoir P&A is to isolate the Ivishak and eliminate it as a possible gas source in the IA. A full P&A will not be conducted until the well is evaluated for other options and all diagnostic work is completed. PROCEDURE FUL .BOR P E r 1. Perform an injectivity test by pumping 1.5 TBG volumes of 1% KCL followed by freeze protect. Pump the injectivity test at max rate not to exceed 3000 psi. Pump schedule is below. a. 5 bbls meth spear b. 290 bbls 1% KCL c. 58 bbls of diesel (freeze protect) 2. Be ready to bleed IA and OA during pumping operation. FULLBORE 3. Perform a fullbore cement P&A per RP. Planned TOC in the 7in liner is 10,337' MD. See [Appendix A] for the detailed procedure. FULLBORE 4. Perform a MIT -T to 3000 psi to test cement plug. Use any non - freezable fluid for test. If pressure test fails contact town before proceeding. .A„-x 4 r n , ttry: ; . ✓.rnv:.xt;..r .Xf r` '..,;. kt«xY=.. .` .tr- ,.. 5. Drift and taq cement top with a 2.5" centralizer / s- bailer. Ensure a sample of cement is obtained and note in AWGRS. Gauge down to a smaller centralizer if necessary. 6. Pull DGLV from Sta #1 at 10,088' MD and leave pocket empty. A catcher sub is not required as an additional cement job will be pumped after this operation. If this pocket is covered in cement or cannot be pulled for any other reason, a -line will need to punch holes above the current TOC. F40, z,,aif,:;;+.rvi+ ...'r�.. ,°-�r •t... e. - ., ,�-vs n, r r , r.'% �%._,..w,x;.!s ., z.�k ,�, ""..rw 41 7. Perform a fullbore cement balanced plug per RP. Planned TOC in the TBG and IA is 8,500' 888 � MD (approximately 1,588' above the open pocket at 10'0 ee p ix for tfie detailed procedure. 1 8. Drift and tag cement top with a 2.5" centralizer / s- bailer. Ensure a sample of cement is obtained and note in AWGRS. Gauge down to a smaller centralizer if necessary. 9. Perform a MIT -T to 3000 psi with diesel. Perform a MIT -IA to 3500 psi while keeping 1,000 psi on tubing side establish LLR. Note: there are known casing Teaks in the 9 -5/8" casing; we do not expect it to pass a pressure test. • • APPENDIX A: Fullbore P &A Operation for 04 -26 From: Josh Stephens — Wells Group PE Contact: 903 - 816 -0183 Tubing/Casing Data' ... , . s Tubing OD ID Capacity ' bbl /ft 5 -1/2 ", 17# 13 -Cr 5 -1/2" 4.892" .0232 4 -1/2 ", 12.6# 13 -Cr 4 -1/2" 3.958" .0152 Liner OD ID Capacity bbl /ft 7 ", 29# L -80 7" 6.184 .0371 Casing OD ID Capacity bbl /ft 9 -5/8 ", 47# 1 -80 9 -5/8" 8.681" .0732 Annular Capacity Capacity bbl /ft 9 -5/8" X 4 -1/2" .0535 9 -5/8" X 5 -1/2" .0438 Notes: • SLB to use their portable panel to take control of SSV. • SLB to bring climbing harnesses for accessing top of well house. • Diesel to be heated to 70 deg to prevent thermal expansion while waiting on cement. • Track IAP and OAP during pumping. IA and OA may be fluid packed and thermal effects may cause annulus pressure to increase. Be prepared to bleed if necessary. Cement Window Target TOC is 10,337' MD Highest allowable TOC is 10,140' MD Deepest allowable TOC is 10,445' MD Perf Info Top open perf 10,545' MD Bottom open perf 10,560' MD Total Footage (of open perfs) 15' Total Footage (between top and bottom) 15' (0.28 bbls) Cement Design: BHST — 170 deg F. SBHP — 3267 psi. BHCT — 140 deg F Density = 15.8 ppg Mix on the fly Thickening time = 3 to 4 hrs. Fluid Loss = 80 -120 cc/30 min Requested Volume is 11 bbls. Pump time = 35 minutes at assumed rate of 5.0 bpm Volumes: Requested TOC (10,337') to Btm Perf (10,560') = 3.4 bbls Requested TOC (10,337') to Top Perf (10,545') = 3.1 bbls Shallowest TOC (10,445') to Top Perf (10,545') = 1.5 bbls Calculated TBG volume from surface to desired TOC 10,337' MD = 177.8 bbls WC -TOC if well locks up with cement at the Top Perf (10,545'): 10,141' MD. Plan Forward: Grease Crew • • Grease all tree valve cavities, including SSV. Ensure wing is shut and indicate (tag) that wing is to remain closed for entire job. Monitor pressure on IA and OA during pumping Heat diesel in tanks to 70 °F prior to arrival of SLB Cementers DHD FL's on TBG and IA. If IA pressure is greater than -0 psi, bleed any gas off IA to -0 psi. During the P&A, be ready to bleed IA and OA pressure if the IA or OA pressures up during the cement job (above 1000 psi) due to thermal expansion. Rigup Crew Rig up iron for Fullbore Cement job - with ball launcher loaded with two 7" foam balls. Typically 2 balls are loaded but the minimum requirement is one). Include the horse trailer or 4 way manifold so that SLB only needs to rig up to trailer. Ensure all valves are accessible with the tree scaffolding. If valves are not accessible, it will be necessary to rig up additional scaffolding. Schlumberger Rig up portable panel to take control of SSV PT all iron, 200 -300 psi for low PT; 4,000 psi for high PT (per SOP pressure testing requirements) Close lateral valve Ensure SLB has transducers to monitor IAP and DHD is monitoring OAP. Pump Schedule (pump at max rate not to exceed 3500 psi in all cases except where noted) • 5 bbl meth spear • 264 bbls 1% KCL - To kill and fluid pack well. 5.0 -8.0 bpm. This will also Tine out well and ensure stable injection prior to pumping cement. • 10 bbis chemical wash • 5.0 bbis 15.8 ppg "G" cement • 3.0 bbls 15.8 ppg "G" cement with 15 ppb aggregate . p -- - - - -- -- - - -- - - -- ---- - - - - -- -- • 2.0 bbis water - To clear lines Divert flow thru ball launcher and drop ball(s). Open workover valve then low- torque, in that order. • 5.0 bbis water behind ball Open side outlet of cement manifold so we are pumping into both inlets • 112 bbis of 1 %KCL • 58.7 bbls of diesel 170.7 bbls of fluid (KCL diesel) will put the cement at the requested top. With 167.5 bbis of fluid away, the leading edge of cement will be close to the top perf. Slow rate to -1.0 bpm and pump cement to the perforations. Do not exceed 170.7 bbls of diesel /KCL (177.7 bbis of TOTAL cement displacement). If well squeezes off: (increase of 1000 psi or more starting when cement reaches perfs) • Max squeeze pressure is 2500 psi • Hold pressure for 30 -60 minutes, then bleed down to 500 psi If no squeeze pressure is achieved: (less than 1000 psi increase after cement reaches perfs) • After design displacement, shut -in well and rig down. Wash up cementers • • RD SLB cementers CaII Valve Shop to service Tree (Post Cement) Check WHP in 6 hours. If pressure exceeds 2000 psi, bleed back to 500 psi. 1 APPENDIX B: Fullbore Balanced Plug Operation for 04 -26 From: Josh Stephens — Wells Group PE Contact: 903 - 816 -0183 Notes: • SLB to use their portable panel to take control of SSV. • SLB to bring climbing harnesses for accessing top of well house. • Do not u -tube after displacing cement and shutting down; this could inadvertently push cement back up into the TBG. • Returns will need to be taken from the IA for the cement circulation. Returns can either go to tanks of back to the facility. It is recommended that returns are setup to go to the facility to minimize fluid disposal. • Track OAP during pumping. The OA is fluid packed and thermal effects may cause annulus pressure to increase. Be prepared to bleed if necessary. Cement Design: BHST — 170 deg F. SBHP — 3267 psi. BHCT —140 deg F Density = 15.8 ppg Mix on the fly Thickening time = 3 to 4 hrs. Fluid Loss = 50 -80 cc/30 min Requested Volume is 110 bbls. Pump time = 22 minutes at assumed rate of 5.0 bpm Suggested plan forward: Grease Crew Grease all tree valve cavities, including SSV. Lock wing in closed position. Rigup £-rew Rig up iron for a Fullbore Cement job — with ball launcher loaded with two 7" foam balls. Typically 2 balls are loaded but the minimum requirement is one). Include the horse trailer or 4 way manifold so that SLB only needs to rig up to trailer. Ensure all valves are accessible with the tree scaffolding. If valves are not accessible, it will be necessary to rig up additional scaffolding. At a minimum, return tanks that can hold at least 200 bbls is needed if the facility needs to shut in and returns must go to tanks after the cement has been pumped. Once the cement is pumped, the job must be continued until cement is displaced to required TOC. It is recommended that sufficient tank capacity be on location to take the entire job to tanks if necessary. DHD During the P&A, be ready to bleed OA pressure if the OA pressures up during the cement job (above 1000 psi) due to thermal expansion. Schlumberger Rig up portable panel to take control of SSV PT all iron, 200 -300 psi for low PT; 4,000 psi for high PT (per SOP pressure testing requirements) Close lateral valve Ensure DHD is monitoring OAP. Fluids Needed: 450 bbls - 1% KCL 170 bbls - Diesel • • 110 bbls —15.8 ppg Class G Cement (plus —90 bbls fresh water for cementers) Pump Schedule: All fluids will be pumped down the TBG and up the IA out to the facility (or a return tank). Pump at max rate not to exceed 3000 psi. • 5 bbls meth spear • 100 bbls 1% KCI — To begin sweeping hydrocarbons from TBG and IA. • 130 bbls of diesel — annular freeze protect plus 20 bbls excess • 320 bbls of 1% KCL • 109.2 bbls of 15.8 ppg "G" cement (no aggregate) • 2.0 bbls fresh water — To clear lines Divert flow thru ball launcher and drop ball. Open workover valve then low- torque, in that order. • 5.0 bbls fresh water behind ball Open side outlet of cement manifold so we are pumping into both inlets • 84 bbls of 1% KCL • 58 bbls of diesel Total displacement of cement should not exceed 149.5 bbls. This will put the TOC in the TBG at 8500' MD (and TOC in the IA at 8500' MD). Do not u -tube even if a pressure differential exists after pumping schedule. Wash up cementers RD SLB cementers Call Valve Shop to service Tree (Post Cement) 1 1 �' • • Current Configuration TREE = PVC SAFETY NOTES. GAS COMM. OA TO ATMOSPHERE, WELLHEAD= FMC _., (UNfELATID TO PRIOR 1996 RB'A DOWN TOLE ACTUATOR = BAKER C 04-26 IR, BETWEEN 13 -3/8" AND 2O") OA COMM. APPEARS TO KB ELEV = 65' BE@ 30' (TOOL JT) "-- CHROME TBG'PLUGS SET IN BF B Ei1= XN MP OR BETWEEN PKR & XN MP WILL NOT PASS KOP= 7 PRESSURE TEST. Max Angle = 48° 0 6135' Datum M3= 10848' _ DatumIVO= — 8800' SS 2270' H5- 1/2' CAM BAL -OSSSV NP, D =4.562" I 113 -318" CSG, 72#,1-80, D= 12.347" H 2497' -- 2534' H5-1/2- X 4-1/7' XO, D= 3.958' I 5-1/2' TOG, 17 #,13 -CR, .0232 bpf, D= 4.892' 2634 " 4 ' GAS LFT MANJIIRS 'ST, ND TVD 'DEV TYPE VLV LATCH PORE DATE .I i 3255 3245 16 KBIUG DRY BK 0 12/22112 f I 2 5786 5192 47 KBI G DPAV BK 0 05/21/06 3 7273 6203 47 KBMG DMY BK 0 03/27/06 4 8235 6890 42 KBMG CNN BK 0 07/18002 5 9041 7484 44 KBMG DMY BK 0 10/04/97 Minis num ID = 3.725" @ 10273' 6 9978 8154 43 KBMG OMY BK 0 10104197 4-112" OTIS XN NIPPLE 7 10088 8236 '41 KBMG DRY BK 0 02/16008, I 10169' H4-1/2" H£5 EVOTRENE PLUG (12/22112) I 1o19r H9-5/8' X 4-112' TAN HB -BP-T PKR I r I 10273' H4 -1/2" OTIS XN NP,D = 3125' I TOPOF - 1IIRT 10291' 1 4-1)7' TOG, 12.6#, 13-CR, .0152 bpf, D= 3.958" H 10295' I I ► 10295' H4 -112' VN.EG, D= 3.958', 103101 Hahn Tr Loc 0 s/2am [ 9-518" COG, 47 #, 1-80, D = 8.681' H 10622' 1 --• FERFURATIONSUMMARY f 10568' H5SLIIGGITS(04/24/11) I REF LOG: BEDS ONO3/08/86 6 ANGLE AT TOP HBiF: 31° 0 10545' �® 10573' H 3-318' BKR X FLOW BP(04 /08/11) f Note: Refer to Reduction DB for historical pert data ' SIZE SPF NT RVAL SHOT DATE St7Z 3-3/8" 6 10545- 10560 0 04/07/11 ' 3-3/8" 6 10598 -10608 C 03/14/05 3-3/8" 6 10620 -10626 C 03/14/05 3-3/8" 6 10649 - 10682 C 02/16/09 ' 4 10710 - 10730 C 11/12/94 4 10730 - 10750 C 06108/87 10690' 1 -112" BKR BP (03✓14/05) IETID 10725' J .44444.' 4444444 44411 4'41 . 4444 .40444441 I 444444.4 7' LM , 29#, L - 80, .0371 bpf, D = 6.184` ion" �f + 4 1 TD I — I 10866' I .4`41444 +4441`4 DATE REV BY COM ENTS DATE REV BY COMMENTS PRUDHOE BAY MT 03/12/86 ORIGINAL COMPLETION 04/28/11 TA/PJC DUMP SLUGG/TS(04/24/11) WELL: 04-26 10/04/97 016 RWO 08/28/11 TAR/ PJC SET DSSSV RUG (08/26/11) PB2Mf No: '1853140 02/07 /09 SWJSV PULL BP (02/05/09) 01/31 /12 JMJM) TREE C/O (01 /12/12) AR No: 50-029-21520-00 02/17 /09 RRK/SV ADPf F (02/16/09) 05/29/12 MSS/J/4/0 PULLED DSSSV RUG (05/25/12) SEC 26, T11N R15E, 92' FSL & 429' PAIL 10/02/09 . DS/PJC B_MD TT LOGGED (08/28/06) 12/27/12 MSS/JM0 SET EVO RUG/GLV 0O (12/22/12) 04/23/11 Tf W/PJC SET BR PERF (04/07-08/11) I BP Exploration (Alaska) .•• • • Proposed Configuration TREE = FNC WEi LHfAD= « SAFETY NOTES: GAS COMM. OA TO ATMOSPHERE, ACTUATOR= BAK62 04-26 (SATED TO PRIOR 1996 FAIR, DOWMiOLE Bbl/ _ BETWEEN) 13 -3/8" AND 20 ") OA COMM. APPEARS TO KB. .. _._.._._.._..__ BF. a.Er/ _ BE@ 30' (TOOL JT) "` CHROME TBG ""PLUGS SET IN - --- XN MP OR BETWEEN PKR & XN PIP WILL NOT PASS Kam -- Wx Angle = 48' - 6135' PRESSURE TEST. Datum M3= 10848' 0 DatumTVD= 8800 SS LJ 2270' 5 172' CAM BAL -O SSSV NP, ID- 4.562 "1 13 -3 /8' CSG, 72#, L-80,1)=12.34 T 248T • 2534' 5 X 4 XO, D = 3.958" 5-1/7 TBG, 17 #, 13 .0232 bpf, D= 4.892' j- I_ 2534' �"------------ GAS LIFT MANDRELS Planned TOC 8,500' MD ST NO TVD DEV T 'TYPE VLV LATCH FORT DATE 1 3255 3245 16 KBMG DMY BK 0 12/22/12 2 5786 5192 47 KBMG DMY 8K 0 05/21/06 3 7273 6203 47 KBMG DMY 8K 0 03/27/06 Est. TOC in 9 -5/8" 9,129' MD 4 8235 6890 42 KBMG DMY BK 0 07/18/02 5 9041 7484 44 KBMG DMY BK 0 10/04/97 Minimum ID = 3.725" @ 10273' 6 9978 8154 43 KBMG DMY BK 0 10/04/97 4 -1/2" OTIS XN NIPPLE 4. 7 10088 8236 '41 KBMG MN BK 0 02/16/08 Planned BOC 10,088' MD 101ST — 9- 5/8' 1/2' TAN EBBRTPKR ' • .`--I 10273' H4- 1/2' OTIS XNNP,D =3125' ToPOF 7"H 10281• Planned TOC 10,337' MD 4-1/2" TBG, 12.6#, 13 .0152 bpi, ID= 3.956" H 10216' I-- I Ai, -- I 10295' I— 4-1/2" WLEG, D = 3.958 " I 10310' -- 1 BAC IT LOGO 08128/06 1 9- 5/8"CSG,47 #,L -80,D= 8.681' I- , 10522' I_ Planned BOC 10,560' MD CERFORATION SUNMYARRY 1 10568' {— 5' SLUGGTTS (04/24/11) REF LOG: BRCS ON 03/08/86 ANGLE AT TOP PBRE. 31' @ 10545 10573' H3-3/8" BKR X- FLOW BP (04/08111) Note. Refer to Roduction DB For historical pert data ' SEE SPF t1TERVAL SHOT DATE SQL 3-38" 6 10545 - 10560 0 04/07/11 ' 3-3/8" 6 10598 - 10608 C 03/14/05 3-3/8" 6 10620- 10626 C 03/14/05 3-3/8" 6 10649 - 10682 C 02/16/09 4 10710 - 10730 C 11/12/94 4 10730 - 10750 C 06/08/87 106g0 - 1 /2' BKR R31)(03/14/05) PB1DI 10725' 1liiiil! 1111$14« i$ii$14 1111$11+ 4 •1 •1 •/ j 7" LNR, 29#, L -80, .0371 bpf, D = 6.184" I --I 10865' I *•••••••4 4 1 1 i i 1 1 1 1 1 i 4 1 1 1 1 I TD -, 10866' 1.4.4.1:4.4.1.4. DATE REV BY COME :NTS DATE REV BY CONVENTS PRIAHDE BAY UNT 03/12/86 ORIGINAL COMPLETION 04/28/11 TA /PJC (X1,1'SLUGGTTS(04 /24/11) _ WEIL: 04-26 10/04/97 016 FaNO ~ —� 08/28/11 TAR/ PJC SET DXSSV PLUG (08/26/11) Y WflMT No: r 1853140 02/07/09 SWY'7SV FULL IBP(02/05 /09) _ _ 01/31/12 MAO TREE CIO (01/12/12) AR No: 50- 029 - 21520 -00 02/17/09 I�2K/SV ADHERE (02/16/09) �— 05/29/12 MSS/JM3 PULLED DSSSV P_UG (05/25/12) SEC 26, T11 A( R15E, 92' FSL & 429' RM.. 10/02/09 DS/PJC ELM) TT LOGGED (08/28/06) - T2/27/12 MSS/J14/ SET EVO PLUG/GLV C10 (12/22/12) 04/23/11 TTW /PJC SET BPI PERF (04/07-08111) BP Exploration (Alaska) m m STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMISSIO REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Other CRI 5 elk? (isp) Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate El Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development 0 Exploratory ❑ " 185 -3140 3. Address: P.O. Box 196612 Stratigraphic El Service ❑ 6. API Number: Anchorage, AK 99519 -6612 a 50- 029 - 21520 -00 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADLO- 028324 ,P PBU 04 -26 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10866 feet Plugs (measured) 10573, 10690 feet true vertical 8880.04 feet Junk (measured) None feet Effective Depth measured 10725 feet Packer (measured) 10204 feet true vertical 8762.24 feet (true vertical) 8326 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 79' 20" 91.5# H -40 35 - 114 35 - 114 1490 470 Surface 40' 13 -3/8" 68# K -55 35 - 75 35 - 75 3450 1950 Surface 2422' 13 -3/8" 72# L -80 75 - 2497 75 - 2497 4930 2670 Production 10491' 9 -5/8" 47# L -80 31 - 10522 31 - 8588 6870 4760 Liner 574' 7# 29# L -80 10291 - 10865 8395 - 8879 8160 7020 Liner Perforation depth: Measured depth: SEE ATTACHED - _ - - True Vertical depth: _ _ _ _ Tubing: (size, grade, measured and true vertical depth) 5 -1/2" 17# 13Cr80 28 - 2542 28 - 2542 4 -1/2" 12.6# 13Cr80 2542 - 10302 2542 - 8404 Packers and SSSV (type, measured and true vertical depth) 9 -5/8 "x4.5" TIW HB -T PKR 10204 8326 RECEIVED 12. Stimulation or cement squeeze summary: , =' h t li 201 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Alaska Oil & 6as Cons. Commission &ntcn rage 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 0 -, Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ,,, IO Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGE GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed N. me J e Last , -A I I Title Data Manager Signatu - VLSI Phone 564 -4091 Date 4/18/2011 NIP RB APR 2' 0 2df V7,2 Zo // Form 10 -404 Revised 10/2010 � Submit Original Only O / 04 -26 185 -314 PERF ATTACHMENT . Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 04 -26 6/8/87 PER 10,730. 10,750. 8,766.45 8,783.25 04 -26 11/12/94 APF 10,710. 10,730. 8,749.57 8,766.45 04 -26 3/14/05 APF 10,598. 10,608. 8,653.69 8,662.29 04 -26 3/14/05 APF 10,620. 10,626. 8,672.62 8,677.79 04 -26 3/14/05 BPS 10,690. 10,725. 8,732.61 8,762.24 04 -26 10/29/05 BPS 10,270. 10,271. 8,377.97 8,378.78 04 -26 2/24/06 BPP 10,270. 10,271. 8,377.97 8,378.78 04 -26 8/2/06 BPS 10,615. 10,620. 8,668.32 8,672.62 04 -26 8/4/06 BPP 10,615. 10,620. 8,668.32 8,672.62 04 -26 8/28/06 BPS 10,615. 10,710. 8,668.32 8,749.57 04 -26 11/9/06 FIL 10,608. 10,615. 8,662.29 8,668.32 04 -26 12/11/07 BPS 10,163. 10,167. 8,293.77 8,296.88 • 04 -26 3/26/08 BPP 10,163. 10,167. 8,293.77 8,296.88 04 -26 2/5/09 BPP 10,615. 10,620. 8,668.32 8,672.62 04 -26 2/5/09 BPS 10,690. 10,725. 8,732.61 8,762.24 04 -26 2/16/09 APF 10,649. 10,682. 8,697.58 8,725.8 04 -26 4/7/11 APF 10,545. 10,560. 8,608.12 8,621.01 04 -26 4/8/11 BPS 10,573. 10,710. 8,632.18 8,749.57 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN • OH OPEN HOLE • • 04 -26 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 4/6/20111 ** *WELL SHUT -IN ON ARRIVAL * * *( ELINE - A DPERF) I INITIAL TWO = 2000/2000/900 RIG UP ELINE WITH 15' 3 -3/8" HSD POWER JET, CURRENTLY RIH ** *JOB IN PROGRESS, CONTINUED ON 7- APRIL - 2011 * ** 4/7/20111** *JOB IN PROGRESS, CONTINUED FROM 6- APRIL - 2011 * * *( ELINE - ADPERF /XFLOW /IBP) SHOT ADD PERFORATIONS, INTERVAL = 10545' - 10560', 3 -3/8" 3406 POWERJET HMX, 6 SPF, 60 DEG PHASING. "CCL TO TOP SHOT = 8.5', CCL STOP DEPTH = 110536.5', DEPTH REFERENCED TO GEARHART CEMENT BOND LOG, DATED 121- MAY -1986. CONFIRMED ALL SHOTS FIRED ON SURFACE. LAID DOWN FOR 1 THE DAY. RU ELINE WITH STP FOR X -FLOW CHECK, RIH WITH STP. ** *JOB IN PROGRESS, CONTINUED ON 8- APRIL - 2011 * ** 4/8/20111 ** *JOB IN PROGRESS, CONTINUED FROM 7- APRIL - 2011 * * *( ELINE - 1ADPERF/XFLOW /IBP) LOG DOWN /UP PASSES FROM 10400' - 10638' AT 40, 80 FPM, STOP COUNT AT 110580' FOR CROSSFLOW. CROSSFLOW IDENTIFIED BETWEEN NEW PERFORATIONS AT 10545'- 10560' AND 10598'- 10608'. SET BAKER 3 -3/8" CROSSFLOW IBP, MID ELEMENT SET DEPTH = 10580', TOP OF IBP = 10573', FISHING NECK = 1.75 ", 2000# JAR DOWN TO EQUALIZE, 5500# JAR UP RELEASE. POSITIVE INDICATION OF SET. DEPTH REFERENCED TO 1GEARHART CEMENT BOND LOG DATED 21- MAY -1986. FINAL VALVE POSITIONS: SSV, SWAB, WING = CLOSED, MASTER = OPEN, I IA/OA = OTG. FINAL T /I /O = 2000/2000/900 1 ** JOB COMPLETE, WELL SHUT -IN ON DEPARTURE * ** FLUIDS PUMPED BBLS 2 DIESEL 2 METH 4 TOTAL TREE = + FMC WELLHEAD = FMC SAFETY S: GAS COM M. OA TO ATMOSPHERE, ACTUATOR = AXELSON (UNRELA TO PRIOR 1996 KB. ELEV = 65' 04-26 BETWEEN 13 -3/8" AND 20 ") OA COM M. APPEARS TO BF. ELEV = BE@ 30' (TOOL JT) """ CHROME TBG """ KOP= Max Angle = '' 48 @ 6135' Datum MD = 10848' Datum TVD = 8800' SS 2270' H5 -1/2" CAM BAL -0 SSSV NIP, ID = 4.562" I 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2497' I A ■ 2534' H5 -1/2" X 4 -1/2" X0, ID = 3.958" I 15 -1/2' TBG, 17 #, 13 -CR, .0232 bpf, ID = 4.892" H 2534' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE ID 1 3255 3245 16 KBMG SO BK 20 03/26/08 2 5786 5192 47 KBMG DMY BK 0 05/21/06 3 7273 6203 47 KBMG DMY BK 0 07/18/02 4 8235 6890 42 KBMG DMY BK 0 07/18/02 Minimum ID = 3.725" @ 10273' 5 9041 7484 44 KBMG DMY BK 0 10/04/97 4-1/2" OTIS XN NIPPLE 6 9978 8154 43 KBMG DMY BK 0 10/04/97 7 10088 8236 42 KBMG_ DMY BK 0 _02/16/08 NMI *MI 10197' I — I9 - 5/8" X 4 -1/2" TIW HB -BP -T PKR I 10273' H4 -1/2" OTIS XN NIP,ID = 3.725" I I TOP OF 7" LNR 1 — I 10291' 4 -1/2" TBG, 12.6 #, 13 -CR, .0152 bpf, ID = 3.958" I-I 10295' I / \ I 10295' I — I4 - 1/2" WLEG, ID = 3.958" I I 10310' I — I ELMD TT LOGGED 08/28/06 I 19 -5/8" CSG, 47 #, L -80, ID = 8.681" H 10522' I II rl ViS — //no ' '‘") PERFORATION SUMMARY I REF LOG: BHCS ON 03/08/86 ANGLE AT TOP PERF: 31° @ 10598' Note: Refer to Production DB for historical pert data I SIZE SPF INTERVAL Opn/Sgz DATE 3 -3/8" 6 10598 - 10608 0 03/14/05 L 10690' H4-1/2" BKR IBP (03/14/05) I 3 -3/8" 6 10620 - 10626 0 03/14/05 3 -3/8" 6 10649 - 10682 0 02/16/09 4 10710 - 10730 C 11/12/94 4 10730 - 10750 C 06/08/87 I PBTD H 10725' I 4 I N III i * i�i i + � i � i 0 4 17" LNR, 29 #, L - 80, .0371 bpf, ID = 6.184" 1 10865' , I TD I-J 10866' 40A.4.4.....N. DATE REV BY COMMENTS i DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/12/86 ORIGINAL COMPLETION 04/06/08 PJC GLV CORRECTIONS WELL: 04 -26 10/04/97 D16 RWO 02/07/09 SWC/SV PULL IBP (02/05/09) PERMIT No: r 1853140 10/07/07 TTR/TLH TTP SET (04/06/07) 02/17/09 RRK/SV ADPERF (02/16/09) API No: 50- 029 - 21520 -00 03/08/08 JIM/PJC PULL WRP & TTP (12/09/07) 10/02/09 DS /PJC ELMD TT LOGGED (08/28/06) SEC 26 T11 N RISE 1351.04 FEL 1494.37 FNL 03/08/08 JIM/PJC SET 4-1/2" WRP (12/11/07) 03/29/08 KD /SV GLV C/O & PULL WRP (03/26/08) ® BP Exploration (Alaska) 10/08/09 $C�{IAII�fBP��P ? � yyiV 1i l' L U UJ NO. 5410 Alaska Data & Consulting Services Company: State of Alaska 2525 Gamb.9 Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 - 2838 Attn: Christine Mahnken ATTW Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job If Log Description Date BL Color CD MPC -05A 11661124 M DRY PROD PROFILE 01 /25!07 1 1.4-03 AY1M -00032 PRO PRO DUCTIONPROFILE 09/09109 1 1.5 -05 AP30 -00061 DUCTION PROFILE 09/15/09 1 03 -24A AZCM -00042 LDL 09/14/09 1 07 -328 BOCV -00027 JEWELRY LOG/GR W /PRESS /TEMP /15109 1 W -214 AY54 -00095 INJECTION PROFILE 09H2109 1 04.26 B5JN -00014 PRODUCTION PROFILE / — 09125/09 1 07 -21 AYS4-00098 PRODUCTION PROFILE — 09/17/09 1 • W -04 B8K5.00003 PRODUCTION PROFILE 09/24/09 1 P2 -53 AP30.00060 PRODUCTION PROFILE 09/13/09 1 S-43 AWLS -00037 PRODUCTION PROFILE 09/25/09 1 12 -23 AWLB -00035 INJECTION PROFILE 09/19/09 1 05 -38 AYTO -00029 LDL 09/18/09 1 W -29 AWJI.00050 MEM INJECTION PROFILE 09120/09 1 W -30 AYIM-00034 PLUGSACK W/X -FLOW CHECK 09112/09 1 3- 37/L -35 B3S0.00024 PRODUCTION PROFILE V 09116/09 1 NK -09 AP30.00057 USIT 09107/09 1 W-07A AWJI.00047 MEM CEMENT EVALUATION 09/07/09 1 11 -10 AYTU -00054 USIT jG MIS 08/28/09 1 02 -068 ANHY-00111 USIT 09121/09 1 G -18A AWJI-00048 MEM CEMENT BOND LOG 09!17109 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 . ' �V Schiember er NO Alaska Data Consulting Services Coi 2525 Gambell Street, Suite 400 r O I �t 2UvJ Anchorage, AK 99503 -2838 ATTN: Beth Well Job Log Description Date BL H -26 BOCV -00028 PRODUCTION LOG 'i, ,Q 615 10/06/09 1 12 -31 B14B -00076 INJECTION PROFILE t 7 j- on -4 3 10/12/09 1 P2 -21 BOCV -00029 PRODUCTION LOG 19L j.-O -22. 10/07/09 1 12 -35 B2NJ -00029 MEM PROD PROFILE 6" O i 10/04/09 1 12 -30 B3SO -00030 INJECTION PROFILE t )7_0_ Can /U, a a_ 10/11/09 1 K -19AL1 B69K -00028 LDL /�3 i '-3-I 10/18/09 1 C -19B B5JN -00016 SCMTahp bh 5 6 10/11/09 V -i 05 AYS4 -00100 INJECTION PROFILE U i oo a r 31 ti .,5' 10/05/09 1 OWDW -SE B69K -00021 RST j o 0 p39 2 y 09/23/09 1 OWDW -NW B69K -00022 RST CI 3 09/24/09 1 OWDW -SW 869K•00023 RST A, to 6. 1 04 -26 B5JN -00014 RST 7j/4/ /t 09/26/09 1 12 -05A 40015441 OHM D/L D EDIT „Al air ,t. 07/26/07 2 M -19B 09AKA0028 OH MWD/LWD EDIT a s /9 L.--- 01/29/09 2 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. A 1—.1 BP Data Center LR2 1 2 A 900 E. Benson Blvd. • • ~ ~~ ~s . ~l SARAN PAUN, GOVERNO R ~ CUI~SER~TI0111 n o 333 W 7th AVENUE, SUITE 100 ~ I t. ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Robert Chiwis Production Engineer BP Exploration Alaska Inc. PO Box 196612 ~~~~~~~~ N~V 1 ~ ~,~~~ r~ Anchorage, AK 99519-6612 (~ 5 t Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBt,j,.,44- 26 Sundry Number: 307-339 ` ~ ~-~ -'- Dear Mr. Chiwis: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of November, 2007 Encl. Sincerely, l~ ~'{~~' TATE FALA KA ~ R~~E~YG: l S O S ALASKA OIL AND GAS CONSERVATION COMMISSION~~ APPLICATION FOR SUNDRY APPROVAL NOV ~ ~ 20rf 20 AAC 25.280 ~{8Sk8 011 1. Type of Request: Abandon Suspend Operational shutdown Perforate An~n~f~ Othe Alter casing ^ Repair well Q Plug Perforations^ Stimulate ^ Time Extension sealtite Change approved program^ Pull Tubing ^ Perforate New Pool^ Re-enter Suspended Well ^ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Developmenl0 Exploratory ^ 185-3140 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 50-029-21520-00-00 7. If perforating, closest approach in pool(s) opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 04-26 , Spacing Exception Required? Yes ^ No ^ 9. Property Designation: 10. KB Elevation (ft): 11. Field/Pools(s): _ ADLO-028324 65 KB - PRUDHOE BAY Field / PRUDHOE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10866 ~ 8880.04- 10725 8762 10240' 10615' 10690' NONE Casing Length Size MD TVD Burst Collapse Conductor 79 20" 91.5# H-40 Surface 75 Surface 75 3450 1950 Surface 2497 13-3/8" 72# L-80 Surface 2497 Surface 2497 1490 470 Production 10522 9-5/8" 47# L-80 Surface 10522 Surface 8588 4930 2670 Liner 561 7" 29# L-80 10291 10865 8395 8879 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): C 10730 - 10608 8766.45 - 8662 5-1/2" 17# 13Cr80 28' - 2534' C 10620 - 10626 8673 - 8678 4-1/2" 12.6# 13Cr80 2534' - 10295' C 10710 - 10730 8750 - 8766 - C-10730 - 10750 8766 - 8738 - Packers and SSSV Type: 9-5/8"X4-1/2" TIW HB-BP-T Packers and SSSV MD (ft): 10197' 12. Attachments: Descriptive Summary Proposal ~ 13. Well Class after proposed work: Detailed Operations Program ^ BOP Sketch ^ Exploratory ^ Development ~ Service ^ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/19/2007 OIL Q GAS ^ PLUGGED ^ ABANDONED ^ 16. Verbal Approval: Date: WAG ^ GINJ ^ WINJ ^ WDSPL ^ Commission Representative: Prepared by Gary Preble 564-4944 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Robert Chivvis Printed Name Robert Chiwis Title Production Engineer Signature Phone 564-5412 Date 11/5/2007 COMMISSION USE ONLY Numb r: ~ ~J l S d diti f N tif C i i th t t ti it C : ve may w un ry e on ons o approva y omm on so a represen ness o ss a a Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Other: ~ ~~'l~i ~ ~ ~d~/ Subsequent Form Required: ~,,,(~ APPROVED BY //' ~' O 2 ONER THE COMMISSION D t ~" SS a e: Approved by: I Form 10-403 Revised 06/2006 ;~ R~ ~ N ~ ~ Submit in Duplicate TREE _ WELLHEAD = - FMC ~ ACTUA~vl2 = , AXELSON KB. ELEV = 65• BF. ELEV = - -- KOP Max Angle = 48 @ 6135' Datum MD = 10848' Datum TV D = 8800' SS 13-3/8" CSG, 72#, L-8Q, ID =12.347" ~--~ 2497, 5-1/2" TBG, 17#, 13-CR, .0232 bpf, ID = 4.892" 2534' TOP OF 4-1 /2" TBG 2534' Minimum ID = 3.725" @ 10273' 4-1 /2" OTIS XN NIPPLE TOP OF 7" LNR ~ 10291' 4-1/2" TBG, 12.6#, 13-C R, .0152 bpf, ID = 3.958" 10295' 9-5/8" CSG, 47#, L-80, ID = 8.681" I-i 10522' PERFORATION SUMMARY REF LOG: BHCS ON 03/08/86 ANGLE AT TOPPERF: 31° @ 10598' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10598 - 10608 C 03/14/05 3-3/8" 6 10620 - 10626 C 03/14/05 4 10710 - 10730 C 11/12/94 4 10730 - 10750 C 06/08/87 PBTD 10725' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" I~ 10865' TD I~ 10866' 04-26 f O' S NOTES: GASCOMM.OATOATMOSPHERE, (UNRELATED TO PRIOR 1996 REPAIR, DOWNHOLE BETWEEN 13-3/8" AND 20") OA COMM. APPEARS TO BE @ 30' (TOOL JT) **CHROM E TBG*" 2270' 5-1/2" CAM BAL-O SSSV NIP, ID = 4.562" 2534' ~ 5-1/2" X 4-1/2" XO GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3255 3245 16 KBMG DMY BK 0 04/06/07 2 5786 5192 47 KBMG DMY BK 0 05/21/06 3 7273 6203 47 KBMG DMY BK 0 03/27/06 4 8235 6890 42 KBMG DMY BK 0 5 9041 7484 44 KBMG DMY BK 0 6 9978 8154 43 KBMG DMY BK 0 7 10088 8236 42 KBMG DMY BK 0 04/24/07 10197' 9-5/8" X 4-1/2" TM/ HB-BP-T PKR 10240' SLM 4-1/2" WRP(04/16/07) 10273' 4-1/2" OTIS XN NIP,ID = 3.725" 10273' 4-1/2" TTP (04/06/07) 10295' 4-1/2" TBG TAIL WLEG ELMD TT NOT LOGGED 10615' I-14-1/2" BKR IBP (08/28/06) 10690' ~--~4-1/2"BKR IBP (03/14/05) DATE REV BY COMMENTS DATE REV BY COMMENTS 03/12/86 ORIGINAL COMPLETION 10/07/07 TTR/TLH TTP SET (04/06/07) 10/04/97 LAST WORKOVER 08/28/06 RRD/PAG SET BKR IBP @ 10615 04/08/07 CJN/PAG GLV GO (04/06/07) 05/01/07 JLJ/TLH GLV C/O 04/2M07 &IBP CORRECT. 05!30/07 RJGTLH 3RD IBP SET (04116/07) PRUDHOE BAY UNff WELL: 04-26 PERMff No: 1853140 API No: 50-029-21520-00 SEC 26 T11 N R15E 1351.04 FEL 1494.37 FNL BP Exploration (Alaska) .- r ~~'~ ~ ~ Seal-Tite International Seal-Tite International Jena I-Ti1-e Procedure 500 Deer Cross Drive BP Alaska We1104-26 Madisonville, LA 70447 International Casing Leak Repair Telephone: 985-875-1292 ~ d v a me e d s e a r a n r re c h n o r o g y Facsimile: 985-875-0687 October 31, 2~~7 http://www.seal-tite.net Objective: Repair Casing Leaks Identified by WLD on Sept 07. Obtain a passing MIT on the IA. Mechanical Considerations: We1104-26 well failed the required MIT. Subsequently a TecWel WLD log located four leaks at 7,303', 7,438', 7,523' and 7,610'. The combined leak rate for all events was 0.3-0.8 gpm at 3000 psi. The proposed procedure will involve displacing the annulus to brine, then spotting a sealant pill across the leak locations until annulus integrity has been restored. The well will then be restored to normal service. Currently the well has a WRP set in the tubing at 10,240 (just below the packer at 10,197') and there is a procedure on the WBL to reset the WRP higher and MIT-T. This procedure is pending a successful MIT-T after resetting the WRP ! Volumes: 5 1/2" 17#/ft = 0.0232 bbUft x 2534' = 58.8 bbls 41/2" 12.6 #/ft = 0.0152 bbUft x 7663 = 114.8 bbls Total tubing volume to bottom GLM = 173.6 bbls 9 5/8" x 5 1/2" = 0.0438 bbUft x 2534' = 111 bbls 9 5/8" x 41/2" = 0.0535 bbUft x 7663 = 410 bbls Total casing volume to bottom GLM = 521 bbls See mechanical sketch and tubing detail for additional info. Contact: Seal-Tite International Neil Cary 985-875-1292 Intended Procedure: Meet with field personnel; review well history and verify condition of well as matching information in previous correspondence. Hold pre-job safety meeting and review procedure. 2. R/U triplex on tubing. Bleed IA to zero -make sure that it is fluid packed and monitor during tubing test. • 3. Pull bottom gas lift valve at 10,088' 4. Circulate down tubing and up annulus with 10.2 ppg CaC12 (Note: 10.2 CaC12 has a rated freeze point of -21 F, 10.7 CaC12 has a rated freeze point of -49 F). If a greater freeze point is desired modify fluid accordingly. Sealant weight will be blended based on final fluid weight selected. 5. Continue circulating until entire tubing and annulus are full of 10.2 CaC12. Capacity of tubing is +/- 174 bbls. Capacity of annulus is +/- 520 bbls. Total capacity +/- 694 bbls. 6. Pressure system to 3000 psi. Obtain a base line pressure fall off and confirm estimated leak rate. 7. Blend 7 bbls of Flo-Seal to a weight of 9.8 ppg or +/- 0.4 ppg less than weight of selected brine. 8. 1Z/U triplex pump on annulus. R/LT a choke manifold to take brine returns from tubing back to tank or truck. 9. Pump sealant into IA, taking returns from tubing. 10. Displace sealant down IA with 220 bbls diesel, taking returns up tubing. Note: Total displacement to top leak is 232 bbls. Compression of fluid below leak is 1.6 bbls. Compression of fluid in tubing is 1.8 bbls. Compression of diesel above sealant is 3.9 bbls. Therefore the above displacement volume will put the top of sealant +-1/2 bbl above the top leak once the system is pressured to 3000 psi. 11. Close choke on tubing and continue to pump diesel until the IA is pressured up to 3000 psi. 12. Monitor IA pressure and tubing pressure as sealant moves down annulus toward leak. Bump up IA pressure as required to maintain 2800 - 3000 psi. Estimated sealant travel time is as follows for different leak rates: 0.2 gpm - 0.09 ft/min 0.5 gpm - 0.225 ft/min 0.8 gpm - 0.36 ft/min 13. Although the total leak rate is estimated to be 0.5 - 0.8 gpm, it is unknown at this time how much each leak is contributing. As each leak is encountered, the pressure decline should reduce and therefore sealant travel time will be reduced. Once the top leak is sealed, tubing pressure can be bled off to move the sealant downhole to the next leak. A minimum sealant contact time of 12 hours is required for each leak. Adjust procedure accordingly to provide this contact time. 14. Once the sealant has reached the bottom leak or IA integrity has been restored, reduce the IA pressure to 1500 psi and allow sealant to cure for 3 days. 15. Install the dummy gas lift valve in the bottom mandrel. • .} 16. MTT-IA to 3,000 psi. Establish LLR if fails. DNC 10 / 31 /07 Kt:.t., I:: I v t:u . STATE OF ALASKA . ALAS OIL AND GAS CONSERVATION COMM ON OCT 1 0 2006 REPORT OF SUNDRY WELL OPERATIØNSOiI & Gas Cans. COOImission 1. Operations Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Q\~~ge Performed: Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 WaiverD Time Extension 0 Change Approved Program 0 Operat. Shutdown 0 Perforate 0 Re-enter Suspended Well 0 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development P Exploratory 185-3140 3. Address: P.O. Box 196612 Stratigraphic Service 6. API Number: Anchorage, AK 99519-6612 50-029-21520-00-00 7. KB Elevation (ft): 9. Well Name and Number: 65 KB PBU 04-26 ADLO-028324 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool 8. Property Designation: Total Depth measured true vertical 10866 8880.04 feet feet Plugs (measured) Junk (measured) 10615 None Effective Depth measured 10725 feet true vertical 8762 feet Casing Length Size MD TVD Burst Collapse Surface 40 13-3/8" 68# K -55 35 - 75 35 - 75 3450 1950 Conductor 79 20" 91.5# H-40 35 - 114 35 - 113.99 1490 470 Surface 2422 13-3/8" 72# L-80 75 - 2497 75 - 2496.57 4930 2670 Liner 561 7" 29# L -80 10304 - 10865 8405.51 - 8879.21 8160 7020 Perforation depth: Measured depth: 10598' - 10750' True Vertical depth: 8654' - 8783' - - - Tubing: (size, grade, and measured depth) 5-1/2" 17# 13Cr80 28 - 2542 Packers and SSSV (type and measured depth) 9-5/8"x4.5" TIW HB-T PKR o o o 1 0204 o o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): cI'^~IN~:;;~) v\"tr~... \;: o\J.;:....~ RBDMS 8Ft 0 CT 1 J 2006 Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 51680 0 0 o 0 0 15. Well Class after proposed work: Exploratory r Developmént P 16. Well Status after proposed work: Oil P Gas WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Oil-Bbl 1034 o Tubing pressure 300 o 13. Service x Contact Gary Preble WINJ WDSPL Title Data Engineer Signature Phone 564-4944 Date 1 0/5/2006 Submit Original Only ,. . . .. 04-26 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY PULLED 1" DGLV FROM STA #1 @ 8719' SLM (POCKET LEFT OPEN). MAKE MULTIPLE RUNS SAILING PLASTIC COATING OFF 5.5" XX PLUG @ 8898' 0' MD) ON 8/30/06 WSR*** BAIL PLASTIC COATING OFF 5.5" XX PLUG @ 9008' SLM. ATTEMPT TO PULL XX TTP @ 8902' SLM. *** CO NT ON 08/31/06 *** 8/31/2006 *** 08/30/06 *** @ 8902' SLM, WORK WIRE FOR 1 HOUR, POOH, WORK THRU SLIDING & SSSV NIP, OOH W/ XX TTP. DRIFT TO PROPER DEPTH OF 9350' SLM. *** WELL LEFT S/ AND NORMALED UP, NOTIFY DSO OF DEPARTURE*** FLUIDS PUMPED BBLS I 1 . DIESEL 1 .. TOTAL Œ "L- '-' L.- I L. L.I . STATE OF ALASKA _ ALA Oil AND GAS CONSERVATION COM~ON REPORT OF SUNDRY WELL OPERATIONS SEP 2 7 2006 uaska Oil & Gas Cons. Commission 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): Plug Perforations 0 Perforate New Pool 0 Perforate 0 4. Current Well Class: Development .~ Stratigraphic Stimulate 0 Other 0 WaiverD Time Extension 0 Re-enter Suspended Well 0 5. Permit to Drill Number: 185-3140 Exploratory Service 6. API Number: 50-029-21520-00-00 9. Well Name and Number: 65 KB PBU 04-26 ADlO-028324 11. Present Well Condition Summary: 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE Oil Pool 8. Property Designation: Total Depth measured true vertical 10866 8880.04 feet feet Plugs (measured) Junk (measured) 10690 None Effective Depth measured 10725 feet true vertical 8762 feet Casing length Size MD TVD Burst Collapse Surface 40 13-3/8" 68# K-55 35 - 75 35 - 75 3450 1950 Conductor 79 20" 91.5# H-40 35 - 114 35 - 113.99 1490 470 Surface 2422 13-3/8" 72# l-80 75 - 2497 75 - 2496.57 4930 2670 Liner 561 7" 29# l -80 10304 - 10865 8405.51 - 8879.21 8160 7020 Perforation depth: Measured depth: 10598' - 10750' True Vertical depth: 8654' - 8783' - - ,. ".. Ai. .. \~ I! '-. ;fJ~(rœ'~' \~,d." Tubing: (size, grade, and measured depth) 5-1/2" 17# 13Cr80 28 - 2542 Packers and SSSV (type and measured depth) 9-5/8"x4.5" TIW HB-T PKR o o o --..---,'¿"I . 10204 o o o 12. Stimulation or cement squeeze summary: Intervals treated (measured): RBDMS 8Ft 0 CT () :1 2006 Treatment descriptions including volumes used and final pressure: Prior to well operation: Subsequent to operation: 14. Attachments: Copies of logs and Surveys Run Daily Report of Well Operations X Oil-Bbl 1034 o Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 51680 0 0 o 0 0 15. Well Class after proposed work: Exploratory Development P 16. Well Status after proposed work: Oil i~ Gas WAG Tubing pressure 300 o 13. Service Contact Gary Preble WINJ WDSPl 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title Data Engineer Signature Phone 564-4944 Date 9/22/2006 AL Submit Original Only . . 04-26 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 8/1/2006 SET INFLATABLE BRIDGE PLUG AT 10614.5' CORRELATED TO SLB CNUGR DATED 01/06/2001. TREATED WITH HOT CRUDE PRIOR TO SETTING. 21.5" OF SEALING PRESENT ON EITHER SIDE OF CENTER ELEMENT. IBP DID NOT COMPLETELY SET. TOOL STUCK IN HOLE AT 10614.5'. IBP WEAKPOINT BROKEN AT BELVILLE PULL DISCONNECT. 1 3/8" EXTERNAL FISHING NECK LOOKING UP AT 10606'. ON WSR ON 08/02/06 /1350/985 Hot Tubing for E -line IBP job [Well Shut In] Pumped 100 bbls Crude at 180* , followed by 60 bbls. 1 % KCL heated to 190* at 1.5 BPM. Increased Pump rate to 4 bpm and pumped 215 bbls of 150* F1 % KCL. Freeze protected Tubing with 55 bbls Crude FWHP= 0/1640/980 FROM 8/01/2006 DEPARTURE. ***WELL S/I ON ARRIVAL *** PULLED IBP @ 10580' SLM ***WELL S/I ON DEPT.*** FLUIDS PUMPED BBLS 155 CRUDE 275 1 % KCL 430 TOTAL 04-26 (PTD #1853140) Classified as Problem Well e All, Well 04-26 (PTD #1853140) has been found to have sustained casing pressure on the IA. The TIO pressures were 2310/2230/1040 when a TIFLfailed on IA repressurízation. J:-A 5GP ZZ3ù~.' /û40fG: Ivtsvp 6 'Ô7Qf'$; ~ "ATup V . - '-""i , The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: Set Dummy GLVs 3. DHD: Re-TIFL 32-. t'L. ÒA 53fjJf-J 11.3~ A wellbore schematic has been included for reference. «04-26.pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you, }lnna (])u6e Well Integrity Coordinator GPB Wells Group Phone: (90r) 659-5102 Pager: (90r) 659-5100 x1154 pressvves oK- fer G94Cì?- ' .se / ( Jæek(,--J t Content-Description: 04-26.pdf Content-Type: application/octet-stream Content-Encoding: base64 LŒ.tl kLS 'iSP ¡V\;~~ L\XLtl,~ ~J .:JÅy-ùA j ~) I I ö,Ar- '1 11 (Ät(~ I \-7- LoLl£.- ; ,,,.AÞX-1 press/JIxL It&LOV0~C! {'S 'Z.øùO f'<& ; JK'fl Ski(~-> I of I 5/19/2006 3 :04 PM TREE = WELLHEAD = ACTUATOR = KB. ELE:V := BF. ELE:V = KOP= II/lax Angle = Datum MD := Datum TVD = ? FMC AXELSON 65' ? 48 @ 6135' 10848' 8800' SS 113-3/8" CSG, 72#, L-80, ID =12.347" 15-1/2" TBG, 17#, 13-CR. .0232 bpf, 10 = 4.892" I ITOPOF 4-1/2" TBG I e 04-26 . Minimum ID:::: 3.125" @ 10213' 4·1/2" OTIS XN NIPPLE TOPOF 7" LNR I 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, 10 = 3.958" I 19-5/8" CSG, 47#, L-80, ID = 8.681" , 10291' 1 0295' ÆRFORA TION SUMMARY REF LOG: BHCS ON 03/08/86 ANGLE AT TOP ÆRF: 31° @ 10598' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10598 - 10608 C 03/14/05 3-3/8" 6 10620 - 10626 C 03/14/05 4 10710 - 10730 C 11112194 4 10730 - 10750 C 06108187 IPBTD I I T' LNR, 29#, L-80, .0371 bpf, ID = 6.184" I LfÐ DATE 03/12186 10/04/97 07/20/02 04/02/05 09/24/05 02/24/06 REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOVER JBITLH GLV UPDATE NBFITLH PERF/IBP SET (03/14/05) EZUTLH WAIVER SFTY NOTE DELETED TEUPJC PULL XXN PLUG @ 10273' 10725' 10865' 10866' RE:V BY COMMENTS JRP/PJC GL V ClO ST MD 1 3255 2 5786 3 7273 4 8235 5 9041 6 9978 7 10088 SA NOTES: GAS COMM. OA TO ATMOSPHERE, (UNRB..ATEDTO PRIOR 1996 REPAIR, DOWNHOLE BETWEEN 13-3/8" AND 20") OA COM M. APPEARS TO BE@ 30' (TOOL JT) **CHROMETBG** 2270' -i 5-1/2" CAM BAL-O SSSV NIP, 10:= 4.562" TVD 3245 5192 6203 6890 7484 8154 8236 GAS LIFT MANDRELS DE:V TYÆ VLV LATCH 16 KBMG SO BK 47 KBMG DMY BK 47 KBMG DMY BK 42 KBMG DMY BK 44 KBMG DMY BK 43 KBMG DMY BK 42 KBMG DMY BK PORT DATE 16 03127/06 o 03127106 o 03/27/06 o o o o 10197' -19-5/8" X 4-1/2" TIW HB-BP-T PKR I 10273' -14-112" OTIS XN NIP,ID - 3.725"1 10295' -14-1/2" TBG TAIL WLEG I H ELMD TT NOT LOGGED I 10690' ELM -13-3/8'IBP(03/14/05) I PRUDHOE BA Y UNIT WELL: 04-26 ÆRMIT No: "1853140 AP1 No: 50-029-21520-00 SEC 26 T11 N R15E 1351.04 Fa.. 1494.37 FNL BP Exploration (Alaska) e e Noflfle of Prudhoe Bay Waiverev Well WELL: 04-28 WELL TYPE: Producer· ArtIfIcial lift DATE: 11-02-02 --... Production Data: 8121102: 253 BOPD. 7510 BWPD. 1.5 MM5CFD. Pressures: Flowing 51 Tubing 190 psi 600 psi 9-518" ANN 1580 psi 1450 psi 13-318" ANN 1320 psi 1080 psi REASON FOR NOTICE: IA X OA Communication TUBING BY 1I-ðI8" COMMUNICATION? YES_ . NO -..!!- · TIFL - Passed 07125102. 9-518" BY 13-318" COMMUNICATION? YES -..a..... NO_ · Trends indicate slow OA pressurization; OAP tends to stabilize above 1000 psi. · MIT-OA Passed to 2400 psi - 09105102. · PPPOT-IC Failed - 09116102. IMPORTANT CONSIDERATIONS I COMMENTS: · 2 Levels of Protection are competent tubing and the surface casing has been tested to 1.2 times the max operating pressure. · ThIs supercedes previous waiver dated 10109102. PLAN OF ACTION: Any deviation from this waiver must be pre-approved by the Wells Group. -.. -. Operating pressure of the 13-3/8" annulus must not exceed 2000 psi. -. Monitor well head pressures and log daily. · Perform the following waiver compliance testing: . Annual MIT -QA to 2400 psi wlfluid levels. r"\t:L;t: I VI:: 0 Al& all AND ~:~T~g~~~;A~ON COM.SION DEC 0 5 2005 REPORT OF SUNDRY WELL OPERATIONS Alaska Oil & G" Cons. CommissÍI [] Stimulate 0 Other 0 nc orea. o Waiver 0 Time Extension 0 o Re-enter Suspended Well 0 5. Permit to Drill Number: - 4 1. Operations Abandon 0 Repair Well 0 Performed: Alter Casing 0 Pull Tubing 0 Change Approved Program 0 Operat. Shutdown 0 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 65 KB 8. Property Designation: ADl-028324 11. Present Well Condition Summary: Total Depth measured 10835 true vertical 8854.26 Effective Depth measured 10725 true vertical 8762.24 Casing length 40 79 2422 561 Size 13-3/8" 68# K-55 20" 91.5# H-40 13-3/8" 72# l-80 7" 29# l-80 Surface Conductor Surface Liner Perforation depth: Measured depth: 10598 - 10608 Closed True Vertical depth: 8653.69 - 8662.29 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of logs and Surveys Run Daily Report of Well Operations Oil-Bbl o o x Plug Perforations Perforate New Pool Perforate 4. Current Well Class: Development M Stratigraphic [J feet feet feet feet Exploratory Service 9. Well Name and Number: 04-26 10. Field/Pool{s): PRUDHOE BAY Field/ PRUDHOE Oil Pool Plugs (measured) 10690, 10273 XXN Junk (measured) None iÇANNED DEC 1 6 2005 Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure o 0 0 o 0 0 15. Well Class after proposed work: Exploratory Development ;?' 16. Well Status after proposed work: Oil M Gas [J WAG MD 35 - 75 35 - 114 75 - 2497 10291 - 10865 10620 - 10626 Closed 8672.62 - 8677.79 5-1/2" 17# 4-1/2" 12.6# 9-5/8"x4.5" TIW HB-T PKR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal TVD 35 - 75 35 - 113.99 75 - 2496.57 8394.93 - 8879.21 Burst 3450 1490 4930 8160 Collapse 1950 470 2670 7020 10710 - 10730 Closed 8749.57 - 8766.45 10730 - 10750 Closed 8766.45 - 8783.25 13Cr80 13Cr80 28 - 2534 2534 - 10295 10197 R8DMS BFL DEC 062005 Tubing pressure o o Service GINJ 0 WDSPL WINJ 0 Sundry Number or N/A if C.O. Exempt: N/A Title Data Mgmt Engr Date 11/30/2005 Phone 564-4424 Form 10-404 Revised 04/2004 ORIGINAL Submit Original Only e e ... 04-26 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10/29/2005 ***WELL WAS SHUT-IN UPON ARRIVAL***(Secure Well) DRIFT TO XN NIPPLE, LaC @ 10258' SLM, TIGHT SPOT @ 9377' SLM XXN TTP SET @ 10258' SLM TEST PLUG BY BLEEDING TBG PRESSURE DOWN FLOW LINE, FLOW LINE WILL NEED TO BE RE-FREEZE PROTECTED BLED TBG DOWN FROM 2280 PSI TO 1550 PSI ABOVE PLUG ***CONTINUE ON 10/30/2005 WSR*** 10/30/2005 T/I/0=1600/1050/520. SI. Bleed WHPs < 300 psi (L TSI). IA FL 3953' (187 BBLS). Bled TBG from 1600 to 250 psi in 20 minutes. Bled lAP from 1050 psi to 250 psi in 2 hours. IA FL fell from 3953' to 4891' (938'). Bled OAP from 520 psi to 280 psi in 10 minutes. Final WHPs=250/250/280. 10/30/2005 Continued on 10-31-05 Standby to load crude. 10/31/2005 Continued from 10-30-05 T/I/O = 0/250/300 Pumped 5bbls meth and 41 bbls crude and 5 bbls meth to pressure up @1500 psi. to freeze protect flowline for wireline FWHP = 0/250/300 FLUIDS PUMPED I BBLS I n/a TOTAL Schlumbepgep Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Z-15 I'S~·- a:? L5-17A 1 C>·j -)..J.3 DS 04-26 I J ~....- JI"f S-14A ',1;j ~ - 0 '1' G-27 I J'lt-I r <D DS 05-20B ~ t '-j .- J..) V E-37A :t c ç - út, J-. D-29 I ~ ..;-- 1..s- J L2-28 Ii.;' $- - C j .>- C-13A ¡ q 7 - I L( J OWDW-SW/I,j t ... .J. 3 y 06-08A ¡qr-t q r 12-29 J 3'f - t '.~ "2- C-19B). Cì '.:. - C '::: r' G-27 J ~I\s - I ç~ F-02A ?. v;;- .. (: vi tf 03-33B ).:0 j- - 6/~ MPK-22 Ä G5-- c.).. 2.. BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: Job# 11084273 11075898 11072873 10893047 10942221 10942220 10928640 11084274 11076453 11075900 10893096 11062628 11072867 10928632 10942221 10928630 10913011 10893106 )1 SC!~NNED SEP 0 FJ 2005 Log Description PPROF W/DEFT/GHOST/CALlPER MEM PPROF W/DEFT/GHOST PRODUCTION PROFILE LEAK DETECTION LOG MEM PPROF & IPROF MEM INJECTION LOG MEM PPROF,IPROF & WARMBACK RST RST MCNL RST -BORAX CHANNEL DETECTION LOG RST RST MCNL MCNL MCNL USIT PDC-GR USIT Date 07/08/05 07/03/05 07/30/05 10/17/04 06/29/05 06/26/05 06/14/05 07/09/05 07/27/05 07/05/05 03/24/05 05/17/05 07/07/05 05/12/05 06/29/05 05/08/05 03/19/05 04/20/05 ~ ,t~\-- 08/30/05 NO. 3460 I g5- Zrtlf Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay BL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Color CD i 3:1 J. 3 í.3..tJo/ i .} ~ J S- j J).). (¡¡ j.} :¿¡7 ):l2.J..8 j.1 ). 2 (;/ J ~ ^ 3~ 13 l. J i '~J. J 'J.... Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 995,g3,-2l38 ..~." .j¡¡" , ATTN: Beth /]/ 1/ /') f Received by: 'if1--vn-v\(~- ~ . (I / · V ~"~r) , STATE OF ALASKA ) EJ',' -tø: ALASKA Oil AND GAS CONSERVATION COMMISSION JUN 0 6 2005 . REPORT OF SUNDRY WELL OPERATlql~~il~' cunii1lÌ$Sion 1. Operations Performed: . 11\, 1:'~I~~t¡~,~·~ AbandonD Repair Well 0 PluQ Perforations[K] Stimulate D I",JdtnerO Alter Casing 0 Pull Tubing 0 Perforate New Pool D WaiverD Time Extension 0 Change Approved ProgramD Operation Shutdown 0 Perforate IKJ Re-enter Suspended WellD 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. 4. Current Well Class: Development ŒJ Exploratory D 5. Permit to Drill Number: 185-3140 6. API Number 50-029-21520-00-00 P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 65.00 8. Property Designation: ADL-028324 11. Present Well Condition Summary: Stratigraphic D Service 0 9. Well Name and Number: 04-26 10. Field/Pool(s): Prudhoe Bay Field 1 Prudhoe Oil Pool Total Depth measured 10866 feet true vertical 8880.0 feet Effective Depth measured 10661 feet true vertical 8707.9 feet Plugs (measured) Junk (measured) 10690 None Casing Conductor Liner Production Surface Surface Length 79 561 10491 40 2422 Size 20" 91.5# H-40 7" 29# L-80 9-5/8" 47# L-80 13-3/8" 68# K-55 13-3/8" 72# L-80 MD TVD Burst Collapse 35 114 35.0 114.0 1490 470 10304 - 10865 8405.5 - 8879.2 8160 7020 31 - 10522 31.0 - 8588.4 6870 4760 35 75 35.0 75.0 3450 1950 75 - 2497 75.0 - 2496.6 4930 2670 SCANNED JUN 1 4: 2005 Perforation depth: Measured depth: 10598 - 10608, 10620 - 10626 True vertical depth: 8653.69 - 8662.29, 8672.62 - 8677.79 TubinQ ( size, Qrade, and measured depth): 5-1/2" 17# 13Cr80 4-1/2" 12.6# 13Cr80 @ 28 @ 2542 2542 10302 Packers & SSSV (type & measured depth): 9-5/8"x4.5" TIW HB-T PKR 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: @ 10204 13 Prior to well operation: Subsequent to operation: Oil-Bbl 65 805 Representative Daily Average Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 1.3 7582 1900 51.8 0 1900 Tubing Pressure 226 1036 14. Attachments: Copies of Logs and Surveys run_ Daily Report Qf Well Operations _ x 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: Oil ŒJ Gas D Development ŒJ Service D Signature Garry Catron Garry Catron ,;J ~ r¿~ WAG D GINJD WINJD WDSPLD Prepared by Garry Catron (907) 564-4657. Sundry Number or N/A if C.O. Exempt: NIA 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Title Production Technical Assistant Phone 564-4657 Date 6/3/05 f ,I RBDMS 8Ft .JUN () 7 2005 Form 10-404 Revised 4/2004 i \,..' \, I '",' II 1'___ ) 04-26 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 03/14/05 PERFORATED 105981·10608,106201-106261, AND SET TOP OF 3-3/8" IBP AT 106901. 04/02/05 Sand plug set @ 106611-106901 FLUIDS PUMPED BBLS No Fluids Pumped o ITOTAL Page 1 TREE=. WELLHEAD = ÄClÙÄrÖR; kB.äéJ; BF.E[EV~ KOP= ...."..,..,.",.",.......,;......,;..'...;,.....,...,.',..'"". Max A~~le = Datum MD = bâtuïïïTVD';' .. ? FMC AXELSÖN ..... ..",,,Y.,, ."... W 65' ') ? .;...,.......,..""..,...,..,..".."'."..... 48 @ 6135' .,....".",..,.."..,.."."..... 1 0848' 8800' SS 113-3/8" CSG, 72#, L-80, ID =12.347" l-f I 5-1/2" TBG, 17#, 13·CR, .0232 bpf, ID = 4.892" 1-1 2497' 2534' 1 TOP OF 4-1/2" TBG l-f 2534' Minimum ID = 3.725" @ 10273' 4-1/2" OTIS XN NIPPLE I TOP OF 7" LNR l-f 10291' 14-1/2" TBG, 12.6#, 13-CR, .0152 bpf, ID = 3.958" l-f 10295' 04-26 e µ 1 'f ~- L 2š: ~ I . I 9-5/8" CSG, 47#, L-80, ID = 8.681" l-f 10522' µ DA TE REV BY COMMENTS 04/02/05 NBFfTLH ÆRF/IBP SET (03/14/05) ÆRFORA TION SUMMARY REF LOG: BHCS ON 03/08/86 ANGLE AT TOP ÆRF: 31° @ 10598' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 3-3/8" 6 10598 - 10608 0 03/14/05 3-3/8" 6 10620 - 10626 0 03/14/05 4 10710-10730 C 11/12/94 4 10730 - 10750 C 06/08/87 I PBTD l-f 10725' 1 I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 1--1 10865' 1 ~-f 10866' 1 DATE 03/12/86 10/04/97 03/26/01 07/20/02 1 0/09/02 11/08/02 REV BY COMMENTS ORIGINAL COM PLETION LAST WORKOVER CORRECTIONS GL V UPDATE W A IV ER SA FETY NOTE WAIVER SAFETY NOTE RNlTP JBITLH JA LIKK KB/TLH ~ x ., x x x ) .. x.. ... -.. x ) ) SAFE)oTES: *** IA X OA COMM. OPERATING PRESSlIr{E OF THE 13·3/8" ANNULUS MUST NOT EXCEED 2000 PSI (11/02/02 WAIVER)*** GAS COMM. OA TO ATMOSPHERE. (UNRB.ATED TO PRIOR 1996 REPAIR, DOWNHOLE BETWEEN 13-3/8" AND 20") OA COMM. APPEARS TO BE @ 30' (TOOL JT) **CHROM E TBG** 2270' l-f 5-1/2" CAM BAL-O SSSV NIP, ID = 4.562" ~ 2534' l-f 5-1/2" X 4-1/2" XO 1 GAS LIFT MANDRELS ST MD TVD DEV TYÆ VLV LATCH PORT DATE 1 3255 3245 16 KBMG DOME BK 16 07/19/02 2 5786 5192 47 KBMG DOME BK 16 07/19/02 3 7273 6203 47 KBMG SO BK 28 07/19/02 4 8235 6890 42 KBMG DMY BK 5 9041 7484 44 KBMG DMY BK 6 9978 8154 43 KBMG DMY BK 7 10088 8236 42 KBMG DMY BK 10197' 1--19-5/8" X 4-1/2" TIW HB-BP-T PKR 1 10273' 1--14-1/2" OTIS XN NIP,ID = 3.725" 1 10295' 1-f4-1/2" TBG TAIL WLEG 1 1--1 ELMD 11 NOT LOGGED I ~ I 110690' ELM 1--13-3/8' IBP (03/14/05) 1 I PRUDHOE BA Y UNIT WELL: 04-26 ÆRMIT No: "1853140 API No: 50-029-21520-00 SEC26 T11N R15E 1351.04 Fa 1494.37 FNL BP Exploration (Alaska) STATE OF ALASKA ALASKA ~ AND GAS CONSERVATION COPh'r~SSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: []Operation Shutdown [--I Pull Tubing 2. Name of Operator 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 91' NSL, 429' EWL, SEC. 26, T11 N, R15E, UM At top of productive interval 1585' SNL, 1500' WEL, SEC. 26, T11 N, R15E, UM At effective depth 1507' SNL, 1378' WEL, SEC. 26, T11N, R15E, UM At total depth 1494' SNL, 1356' WEL, SEC. 26, T11N, R15E, UM [] Stimulate i---J Alter Casing [] Plugging [] Perforate [~Repair Well []Other 5. Type of well: [] Development I--I Exploratory I--I Stratigraphic I-]Service 6. Datum Elevation (DF or KB) 65' RKB 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number 04-26 9. Permit Number / Approval No. 10. APl Number 50-029-21520 1. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 12. Present well condition summary Total depth: measured 10866 feet true vertical 8879 feet Effective depth: measured 10745 feet true vertical 8778 feet Casing Plugs (measured) Junk (measured) PBTD Tagged at 10745' (02/20/95) Length Size Cemented MD Structural Conductor 80' 20" 1700# Poleset 114' Surface 2462' 13-3/8" 2500 sx Arcticset III, 400 sx Arcticset II 2497' Intermediate Production 10492' 9-5/8" 500 sx Class 'G' 10522' Liner 574' 7" 300 sx Class 'G' 10291' - 10865' TVD 114' 2497' 8588' 8395' - 8878' Perforation depth: measured 10710' - 10750' true vertical 8748' - 8782' Tubing (size, grade, and measured depth) 5-1/2", 17#, 13Cr NSCC to 2534'; 4-1/2", 12.6#, 13Cr, NSCT 2534' - 10295' Packers and SSSV (type and measured depth) 13. Stimulation or cement squeeze summary Intervals treated (measured) TIW HB-BP-T pacer at 10197'; Camco BaI-O SSSV Nipple at 2270' Treatment description including volumes used and final pressure Gas C0p.~. comm~,3n Anc, t~age 14. Prior to well operation: Subsequent to operation: Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl 15. Attachments [] Copies of Logs and Surveys run [] Daily Report of Well Operations I16. Status of well classifications as: [] Oil [] Gas [] Suspended Casing Pressure Tubing Pressure Service 17. I hereby certify thane foregoing/.i.~)ue_~and correct to the best of my knowledge Signed James Smith ~ ~ Title Senior Drilling En~lineer, Acting / ~ Prepared By Name/Number: Date //./~,/'/~2 Terrie Hubble, 564-4~28 .~ Submit In Duplicat Form 10-404 Rev. 06/15/88 Progress Report Facility PB DS 04 Well 04-26 Rig Doyon 16 Page 1 Date 16 October 97 Date/Time 24 Sep 97 25 Sep 97 26 Sep 97 27 Sep 97 28 Sep 97 00:00-00:30 00:30-05:00 05:00-06:00 06:00-06:30 06:30-08:00 08:00-11:30 11:30-12:30 12:30-13:30 13:30-15:00 15:00-18:00 18:00-18:30 18:30-20:00 20:00-23:00 23:00-04:00 04:00-06:00 06:00-06:30 06:30-09:00 09:00-15:00 15:00-15:30 15:30-17:30 17:30-23:00 23:00-03:30 03:30-06:00 06:00-06:30 06:30-06:45 06:45-07:00 07:00-08:30 08:30-09:00 09:00-11:30 11:30-11:45 11:45-18:00 18:00-18:30 18:30-20:30 20:30-21:30 21:30-23:30 23:30-03:00 03:00-03:15 03:15-04:00 04:00-06:00 06:00-06:30 06:30-08:30 08:30-09:30 09:30-15:30 15:30-21:30 21:30-23:30 23:30-00:00 00:00-05:00 05:00-06:00 06:00-06:30 06:30-08:30 08:30-13:30 13:30-18:00 18:00-18:30 18:30-19:00 Duration 1/2 hr 4-1/2 hr lhr 1/2 hr 1-1/2 hr 3-1/2 hr lhr lhr 1-1/2 hr 3 hr 1/2 hr 1-1/2 hr 3 hr 5hr 2hr 1/2 hr 2-1/2 hr 6hr 1/2 hr 2hr 5-1/2 hr 4-1/2 hr 2-1/2 hr 1/2 hr 1/4 hr 1/4 hr 1-1/2 hr 1/2 hr 2-1/2 hr 1/4 hr 6-1/4 hr 1/2 hr 2hr 1 hr 2hr 3-1/2 hr 1/4 hr 3/4 hr 2hr 1/2 hr 2 hr 1 hr 6hr 6hr 2 hr 1/2 hr 5hr lhr 1/2 hr 2 hr 5 hr 4-1/2 hr 1/2 hr 1/2 hr Activity Held safety meeting Rig moved 100.00 % Installed Fluid system Held safety meeting Fill pits with Seawater Circulated at 10190.00 ft Tested Casing Circulated at 10190.00 ft Rigged down Wellhead primary components Rigged up BOP stack Held safety meeting Rigged up BOP stack Tested BOP stack Installed Drillpipe retrieval string Conducted electric cable operations Held safety meeting Laid down 0.00 ft of Tubing Conducted electric cable operations Laid down 0.00 ft of Tubing Circulated at 101910.00 ft Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations Held safety meeting Conducted electric cable operations Laid down 0.00 ft of Tubing Circulated at 10195.00 ft Removed Tubing hanger Laid down 2000.00 ft of Tubing Held drill (Kick while tripping) Laid down 6000.00 ft of Tubing Held safety meeting Laid down 2195.00 ft of Tubing Tested Bottom ram Made up BHA no. 1 Singled in drill pipe to 2740.00 ft Held drill (Kick while tripping) Rigged up Kelly/top drive hose Singled in drill pipe to 3000.00 ft Held safety meeting Singled in drill pipe to 4000.00 ft Installed Drillstring handling equipment Singled in drill pipe to 10186.00 ft Jarred stuck piPe at 10186.00 ft Circulated at 10186.00 ft Serviced Block line Pulled out of hole to 10186.00 ft Laid down fish Held safety meeting Made up BHA no. 2 R.I.H. to 10191.00 ft Washed over string at 10191.00 ft Held safety meeting Circulated at 10191.00 ft Progress Report Facility PB DS 04 Well 04-26 Rig Doyon 16 Page 2 Date 16 October 97 Date/Time 19:00-23:00 23:00-00:00 29 Sep 97 00:00-01:00 01:00-04:45 04:45-05:00 05:00-06:00 06:00-06:30 06:30-10:30 10:30-11:30 11:30-13:00 13:00-15:30 15:30-16:00 16:00-16:30 16:30-18:00 18:00-18:30 18:30-19:00 19:00-00:00 30 Sep 97 00:00-01:30 O1:30-02:30 02:30-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-14:30 14:30-18:00 18:00-18:30 18:30-19:00 19:00-20:00 20:00-20:45 20:45-23:30 23:30-23:45 23:45-01:30 O1 Oct 97 01:30-03:45 03:45-05:30 05:30-06:00 06:00-06:30 06:30-10:00 10:00-11:30 11:30-12:00 12:00-14:30 14:30-15:30 15:30-18:00 18:00-18:30 18:30-20:00 20:00-02:30 02 Oct 97 02:30-04:00 04:00-04:15 04:15-06:00 06:00-06:30 06:30-07:30 07:30-08:30 08:30-10:00 10:00-11:30 11:30-14:30 Duration 4 hr lhr 1 hr 3-3/4 hr 1/4 hr 1 hr 1/2 hr 4 hr 1 hr 1-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 1/2 hr 1/2 hr 5 hr 1-1/2 hr lhr 3-1/2 hr 1/2 hr 1 hr lhr 6hr 3-1/2 hr 1/2 hr 1/2 hr 1 hr 3/4 hr 2-3/4 hr 1/4 hr 1-3/4 hr 2-1/4 hr 1-3/4 hr 1/2 hr 1/2 hr 3-1/2 hr 1-1/2 hr 1/2 hr 2-1/2 hr lhr 2-1/2 hr 1/2 hr 1-1/2 hr 6-1/2 hr 1-1/2 hr 1/4 hr 1-3/4 hr 1/2 hr lhr lhr 1-1/2 hr 1-1/2 hr 3 hr Activity Pulled out of hole to 445.00 ft Pulled BHA Made up BHA no. 3 R.I.H. to 10201.00 ft Fished at 10201.00 ft Circulated at 10201.00 ft Held safety meeting Pulled out of hole to 10225.00 ft Pulled BHA Made up BHA no. 4 R.I.H. to 9000.00 ft Serviced Block line R.I.H. to 10215.00 ft Fished at 10215.00 ft Held safety meeting Circulated at 10217.00 ft Pulled out of hole to 0.00 ft Pulled BHA Made up BHA no. 5 R.I.H. to 7000.00 ft Held safety meeting R.I.H. to 10206.00 ft Serviced Block line Milled Permanent packer at 10225.00 ft Pulled out of hole to 1000.00 ft Held safety meeting Pulled out of hole to 426.00 ft Pulled BHA Made up BHA no. 5 R.I.H. to 5000.00 ft Held drill (Kick while tripping) R.I.H. to 10227.00 ft Milled Permanent packer at 10227.00 ft Circulated at 10257.00 ft Pulled out of hole to 10000.00 ft Held safety meeting Pulled out of hole to 450.00 ft Pulled BHA Retrieved Wear bushing Tested Well control Installed Wear bushing Ran Drillpipe in stands to 6000.00 ft Held safety meeting Ran Drillpipe in stands to 10258.00 ft Pulled Drillpipe in stands to 0.00 ft Laid down 100.00 ft of Tubing Held drill (Fire) Ran Drillpipe in stands to 3000.00 ft Held safety meeting Ran Drillpipe in stands to 5000.00 ft Tested Casing - Via annulus Ran Drillpipe in stands to 10281.00 ft Tested Casing - Via annulus Circulated at 10239.00 ft Progress Report Facility PB DS 04 Well 04-26 Rig Doyon 16 Page 3 Date 16 October 97 Date/Time 14:30-15:30 15:30-15:45 15:45-16:30 16:30-18:00 18:00-18:30 18:30-01:00 03 Oct97 01:00-01:15 01:15-06:00 06:00-06:30 06:30-18:00 18:00-18:30 18:30-06:00 04 Oct 97 06:00-06:30 06:30-09:30 09:30-15:00 15:00-18:00 18:00-18:30 18:30-23:00 23:00-03:30 05 Oct 97 03:30-06:00 Duration lhr 1/4hr 3/4 hr 1-1/2 hr 1/2 hr 6-1/2 hr 1/4 hr 4-3/4 hr 1/2 hr 11-1/2 hr 1/2 hr 11-1/2 hr 1/2 hr 3hr 5-1/2 hr 3hr 1/2 hr 4-1/2 hr 4-1/2 hr 2-1/2 hr Activity Laid down 2000.00 ft of 5in OD drill pipe Held drill (Fire) Serviced Block line Laid down 2960.00 ft of 5in OD drill pipe Held safety meeting Laid down 5320.00 ft of 5in OD drill pipe Held drill (Spill) Ran Tubing to 1000.00 ft (4-1/2in OD) Held safety meeting Ran Tubing to 7500.00 ft (4-1/2in OD) Held safety meeting Ran Tubing to 10299.00 ft (5-1/2in OD) Held safety meeting Circulated at 10196.00 ft Rigged down BOP stack Rigged up Surface tree Held safety meeting Rigged up Surface tree Freeze protect well - 150.000 bbl of Diesel Rig moved 0.00 % STATE OF ALASKA ALASKA-OIL AND GAS CONSERVATION COmmISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate Pull tubing ~ Alter casing ~ Repair well Other X 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 91' FSL, 429' FWL, 9cc 26, T11N, R15E, UM At top of productive interval 1585' FNL, 1500' FEL, Sec 26, T11N, R15E, UM At effective depth 1507' FNL, 1378' FEL, Sec 26, T11N, R15E, UM. At total depth 1494' FNL, 1356' FEL, Sec 26, T11N, R15E, UM 5. Type of Well Development X Exploratory Stratigraphic Service ORIGINAL 6. Datum of elevation(DF or KB) 65 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-26 9..~.Permit number/approval number 8~-314 10. APl number 50 - 029-21520 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10866 feet 8879 feet Plugs(measured) PBTD Tagged @ 10745' MD (2/20/95) Effective depth: measured 10745 feet true vertical 8778 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 1700# Poleset 114' 114' Surface 2462' 13-3/8" 2500 Sx AS III & 400 Sx AS II 2497' 2497' Production 10492' 9-5/8" 500 Sx Class G 10522' 8588' Liner 561' 7" 300 Sx Class G 10865' 8878' Per[oration depth: measured 10710 - 10750' true vertical 8748 - 8782' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10246' MD; 4-1/2", 12.6#, L-80 PCT @ 10325' MD. Packers and SSSV (type and measured depth)Baker 3H Packer @ 10236' MD; Camco BaI-O SS~jfl\ ~~]VE~JE)'EL,/~ 13. Stimulation or cement squeeze summary Intervals treated(measured) see Attached Treatment description including volumes used and final pressure APR 1 7 199G Alaska Oil & C~as Cons. Commission Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure 362 3OO 28O8 1125 2168 8377 Tubing Pressure 599 302 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil X Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si~ned ~'~ /)q/I' ~ Title Engineering Supervisor Date 4 -/5 - f¢o Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE 4-26 TUBING PATCH INSTALLATION DESCRIPTION OF WORK COMPLETED 1/27/96' Ran a Leak Detection Log which indicated a leak was present at GLM#4 at 7291' MD. 2/24/§6 · RIH & set a 2.992" ID AVA Tubing Patch in the 5.5" tubing at 7285 - 7305' MD (seal to seal). Returned the well to production & obtained a valid production test. RECEIVED APR ? 7 !996 Oil & A~chorsge GeoQuest 500 w, International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10047 Company: Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 3/1/96 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia Survey Performance Disk Calculation Letter .--" ., D.S. 3-33 ..... __~r-I'- {[O COMPENSATED NEUTRON LOG-CNT-D 960214 1 1 , D.S 4-19 o~-b~.,-( DUAL BURSTTDT-P 960209 1 1 : '~1,, V! D.S. 4-26 ~' ~-- ,3 ~.~ I_EAK: DETECTION LOG 9 6 01 2 7 1 1 D,S, 5-4 'l '4 - 0 ~-rfI DUAL BURST TDT-P 9 6 01 2 9 I 1 D.S, 5-25 o~q '- (2. I DUAL BURST TDT-P 9 6 01 2 6 I 1 D.S, 14-10 9(3 -I)t) DIGITAL ENTRY & FLUID IMAGING 96021 5 I _ 1 D.S. 1...4-10 2b - ~3 PRODUCTION PROFILE 96021 5 1 1 D.S. 18-30 q ~,'"" ¢¢1 STATIC PRESSURE SURVEY 9601 30 I 1 ,. 'D.S. 18-33 q~-- l~]~ STATIC PRESSURE SURVEY 960130 I 1 ,. = , S I G N E D' _~~___ ~~ DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie RECEIVED RECEIVED Company: {~2 2 1995 2_ £ '~995 Alaska 011 & Gas Cons. Commissiol~ Anchorage Alaska 0it & Gas Cons. commission A~ChOr~ge Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Floppy Well Job tf Log Description Date BL RF Sepia DIR MWD Disk , , D.S. 18-!,,1 95067 DUAL BURST TDT-P .g'~,)'-~_~.__~' 021895i 1 D.S. 4-26 95079 CNTG /-_L r~ ~-~ 0 022195 1 , , , ....... 3/22/95 SIGNE . DATE: Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. . Schlum GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO.9296 Company: 3/2/95 Alaska Oil & Gas Cons Comm Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 Well Field: Prudhoe Bay Floppy Job # Log Description Date BL RFSepia Mylar Disk 9~-/o7 "2 5-- '?3 :D.S. '1-2~"x~ LEAK DETECTION 021 995 I '1 D.S. 4-1-"2~ 'TUBG PUNCHER RECORD 021 895 1 1 D.S. x~. RESER,VOIR SATURATION .. 0221 95 1 1 DiS.4~.'~6~ CNT-G 0221 95 I 1 ........ D.S. 4-19 P~F RE.RD 0 21 7 9 5 1 1 o s D.S. 4-48~ P~F REtaRD 0 21 3 9 5 I 1 , , D.S. 6-3N~ PRODUC~ON LOG ,,, 0 2 21 9 5 1 1 D.S. 7-4A~ PERF RECORD 0 21 5 9 5 I 1 ~.s. 9-2~X ( {NF~TA~LE ~RmDnE PL'Ua 0217S S ~ 1 ~.S. *-~ ~ PmFRE~RD 02~ O9S I 1 ~.S. S-4S ~ PmF RE. RD 02209 S I 1 O.S. 13-2~ {NF~TASLE SR~DaE PLUa 02~7SS ~ 1 D.S. 11-4~ PROD pROnLE 0220SS ~ 1 D.S. ~S-~ 3 PRODPROnLE 0220SS ~ 1 D.S. 18-~ r DUAL SURST TDT-P 021 895 ~ 1 D.S. 11-~ 9 S 0 S 8 OUAL BURST TDT-P 0 21 ~ 9 5 1 D.S. ~~%-qS SS0s7 DUALSURSTTUT-P 020SSS 1 SIGNED' RECEIVED Alaska 011 & (las Cons. Commission Please sign and return one copy of this transmittal to Sherrie at the above address. Thank you. Anchorage STATE OF ALASKA ALASI,:, OILAND GAS CONSERVATION ~VlMISSlON REPOR'FOF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown Stimulate Plugging Perforate X Pull tubing Alter casing Repair well Obher 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 91' FSL, 429' FWL, Sec. 26, T11N, R15E, UM At top of productive interval 1585' FNL, 1500' FEL, Sec. 26, T11N, R15E, UM At effective depth 1507' FNL, 1378' FEL, Sec. 26, T11N, R15E, UM At total depth 1494' FNL, 1356' FEL, Sec. 26, T11N, R15E, UM 5. Type of Well Development , X Exploratory Stratigraphic Service .... t \[ 6. Datum of elevation(DF or KB) 65 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-26 9. Permit number/approval number 85-314 10. APl number 50 - 029-21520 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 10866 feet 8879 feet Plugs(measured) PBTB Tagged @ 10736' MD (11/8/94) Effective depth: measured 10736 feet true vertical 8770 feet Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Conductor 80' 20" 1700# Poleset 114' 114' Surface 2462' 13-3/8" 2500 sx AS III & 400 sx AS II 2497' 2497' Production 10492' 9-5/8" 500 sx Glass G 10522' 8588' Liner 561' 7" 300 sx Class G 10865' 8878' Perforation depth: measured 10710-10750' true vertical 8748-8782' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10246' MD; 4-1/2", 12.6~, L-80, PCT @ 10325' MD Packers and SSSV (type and measured depth) BOT 3H pkr @ 10236' MD; Camco BaI-O SSSV @ 2227' MD r,, r ~,,'" I'"" 1% I l" 1"% 13. Stimulation or cement squeeze summary Intervals treated(measured) See Attached Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation KEL, EIVEM JAhl 2 4 "1995 ~:.~.,~k~ o:i & Gas Cons. Commission Representative Daily Average Production or Injection Data ~t'lilj;il~il~' OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure 654 1782 6871 - 302 829 1573 6996 - 366 15. Attachments Copies of Logs and Surveys run Daily Report of Well Operations 16. Status of well classification as: Oil :X Gas .--- Suspended Service. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ¢~ '~. ~ Title Engineering Supervisor Form 10-404 Rev 06/15/88 cc: KZ, JWP. Date SUBMIT IN DUPLICATF~ 4-26 PERFORATING OPERATIONS DESCRIPTION OF WORK COMPLETED I I/8/94: RIH & tagged PBTD at 10736' MD. I I/1 2/94: MIRU & PT equipment. Added perforations: 10710 - 10730' MD (Z1) Ref. Log: BHCS 3/8/86. Used a 2-1/8" carrier & shot 4 spf at 90 degree phasing. POOH w/perf gun. RIH w/perforating gun & shot 20' of add perforations as follows: Rigged down. Returned the well to production w/gas lift & obtained a valid welltest. RECEIVED JAN 2 4 ~995 Aiaska 0il & Gas Cons. Commission Anchorc '~ GeoQuest 500 W. International Airlm~rt Road Anchorage, AK 99518-1199 ATTN: Shertle NO. 9121 Company: Alaska Oil & Gas Cons Comm , Attn: Lam/Grant I 3001 Porcupine Drive Anchorage, AK 99501 11/22/94 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar D.S. 4-06 '"~6--~C~ ~'~. INJEO PROFILE (11-7-94) 1 1 D.S. 4-16 ~ ~,..-- 0 ~/- ~' PROD PROFILE (11-6-94) 1 1 D.~. 7.16 ~ ~LL STATIO SURVEY (11-2-94) 1 1 D.S. 9-07 ~ ~,' 0~ TUBG ouT RECORD (11-8-94) 1 1 D.S. 9-30 ST 1 ~ ~- J~ ~ INJEO PROFILE (1i-5.94) 1 1 D.S. 15-~9 ~ ~- Il ~ BO~OMHOLE PRESS SURVEY/PDO (11-9-94) 1 1 D.S. 2-~1 ~/-~ j,~ LEAK DETECTION (11-11-94) 1 1 D.S. 7-25 PERF REOORD (11-11-94) 1 1 D.S. 11-36 ~- 0~ LEAK DETEOTION (11-9-94) 1 1 D.S. 15-41 9 ~-~ PERF RECORD (11-12-94) 1 1 ,D.S.~I ~ ~- ~V STATIC PRE~URE SURVEY (11-1~-94) 1 1 D.S. 17-1 ~6~ ~~ TUBG PATCH RECORD (11-9-94) 1 1 SIGNED Please sign and return one copy of this transmittal to Sherrle crt the above address. Thank you. STATE OF ALASKA ALASKA _AND GAS CONSERVATION CC AISSION REPORT OF SUNDRY WELL OPE'RATIONS 1. Operations performed: Operation shutdown Stimulate X Plugging Pull tubing Alter casing Repair well Perforate Ot~er 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 4. Location of well at surface 91' FSL, 429' FWL, Sec. 26, T11N, R15E, UM At top of productive interval 1585' FNL, 1500' FEL, Sec. 26, T11N, R15E, UM At effective depth 1507' FNL, 1378' FEL, Sec. 26, T11N, R15E, UM At total depth 1494' FNL, 1356' FEL, Sec. 26, T11N, R15E, UM 5. Type of Well Development Exploratory Stratigraphic Service RECEIVED · OCT 141994 0il & Gas Cons. Commission Anchoraga 6. Datum of elevation(DF or KB) 65 RKB feet 7. Unit or Property Prudhoe Bay Unit 8. Well number 4-26 9. Permit number/approval number 85-314 10. APl number 50 - 029-21520 11. Field/Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Sudace 2462' Production 10492' Liner 561' 10866 feet 8879 feet Plugs(measured) PBTD Tagged @ 10823' MD (7/29/94) 10823 feet 8843 feet Junk(measured) Size Cemented Measured depth True vertical depth 20" 1700# Poleset 114' 114' 13-3/8" 2500 sx AS III & 400 sx AS II 2497' 2497' 9-5/8" 500 sx Class G 10522' 8588' 7" 300 sx Class G 10865' 8878' Pedoration depth: measured 10730-10750' true vertical 8765-8782' Tubing (size, grade, and measured depth) 5-1/2", 17#, L-80, PCT @ 10246' MD; 4-1/2":, 12.6#, L-80, PCT @ 10325' MD Packers and SSSV (type and measured depth) BDT 3H pkr @ 10236' MD; Camco Bal-O SSSV @ 2227' MD 13. Stimulation or cement squeeze summary Intervals treated(measured) See attached. Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation Representative Daily Averaqe Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure 565 923 4699 -- 847 ~" 1405 7679 -- Tubing Pressure 264 301 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations , 16. Status of well classification as: Oil. x Gas Suspended Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Engineering Supervisor -- Form 10-404 Rev 06/15/88 1240/14 KRF cc: KZ, JWP Date /¢//~'/~ SUBMIT IN DUPLICATE 4-26 DESCRIPTION OF WORK COMPLETED ROPE TREATMENT & HYDRAULIC FRACTURE TREATMENT OF ZONE I 7/18/94: MIRU & PT equipment. Pumped N2 to depress liquid level in the wellbore to 9920' MD, then RIH & set a 4-1/2" Shear Plug assembly in the XN Nipple located at 10312' MD, in preparation for a ROPE treatment. PT equipment to 8500 psi, then pumped N2 down the tubing to rupture the Shear Plug for a ROPE Treatment of the perforations located at: 10730 - 10750' MD (Z1) Ref. Log: BHCS 3/8/86. Shear Plug ruptured early at 4830 psi. RIH & pulled the ruptured Shear Plug. RIH & set another 4-1/2" Shear Plug assembly in the XN Nipple for a Re-ROPE of the perforations. Rigged down. 7/19/94: MIRU & PT equipment. Pumped N2 down the tubing to Re-ROPE the perforations (listed above). Pressured up to 5000 psi w/N2, then switched to pumping 53 bbls Slick Meth Water to rupture the Shear Plug at 7528 psi. Rigged down. 7120/94: RIH & pulled the ruptured Shear Plug. 7125/94: MIRU & PT equipment to 9500 psi. Pumped a Hydraulic Fracture Treatment using 20/40 mesh proppant, through the perforations (listed above). Pumped: Resumed Resumed a) 400 bbls 20# Pre Pad Gel @ 10 - 30 bpm, followed by b) Shutdown. ISIP @ 792. pumping Data Frac: c) 243 bbls 40# Crosslinked Pad @ 5 - 20 bpm, followed by d) 249 bbls 20# Flush @ 20 bpm, followed by e) Shutdown. ISIP @ 1980. pumping Fracture Treatment: 95 bbls Crosslinked Pad @ 20 bpm, followed by 394 bbls # Crosslinked Slurry w/proppant concentrations @ 2 - 12 ppg, followed by f) g) h) i) 249 bbls Flush, followed by Shutdown. Placed a total of 67,500 lbs of proppant into the formation. 7128/94: RIH w/CT & jetted a fill cleanout down to 10815' MD. 7~29~94: RIH & tagged PBTD at 10823' MD. Rigged down. RECEIVED OCT 1 4. 1994 Alaska 0il & Gas Cons. Commission Returned the well to production w/gas lift & obtained a valid welltest. Anch0ra~e ~ W. infematlonal Airport Road Anchorage, Al( 99618-1199 ATTN: Sherfle NO. 8852 Company: Alaska Oil & Gas Cons Comm , Attn: Larry Grant 3001 Porcupine Drive Anchorage, AK 99501 8110/94 Field: Prudhoe Bay Well Log Description BL RR Sepia RF Sepia Mylar ~"~'"-"'~ D.S. 4-26 LEAK DETECTION (7-15-94) 1 1 '2c~"'r- ~ D.S. 4-2 BAKER IBP (7-17-94) 1 1 c/,z- ?~__ D.S. 12-10A PERF RECORD (7-15-94) 1 1 ~""'~---Q~. D.S. 13-27 PROD PROFILE (7-13-94) 1 1 -?-~-.Q¢ D.S. 7-01 PROD PROFILE (7-13-94) 1 1 -r_[(.- ") ~1 . D.S. 17-8 INJECTION PROFILE (7-19-94) 1 1 ~-~-~, D.S. 16-16 INJECTION PROFILE (7-14-94) 1 1 '~-...¥r~ D.S. 5-5 TUBING CUTTER RECORD (7-17-94) 1 1 '~'.~ .- ~t-~ D.S. 17-19 PROD PROFILE (7-16-94) 1 1 -'~ ~" 1.~ .p.S. 6-7 DUAL BURST TDT-P (7-13-94) 1 1 __ '- ./,} SIGNED: DATE: Please ~ign and return one copy/of this transmittal to Sherrle at the above address. Thank you. ARCO Alask~ Inc. P.O.Box 100360 Anchorage, Alaska 99510 DATE: ~17-93 2-3 2-8 2-12 2-16 3-9 15A 4-7ST 4-39 c~_~7 [5-15A tS-15A q:~-/~t ** 5-17A 6'10 6-10 ~6-24 ~- ~U ~6-24 8-24-93 8-27-93 8-28-93 8-27-93 8-21-93 8-17-93 8-28-93 8-22-93 8-25-93 8-22-93 8-23-93 8-19-93 8-19-93 8-26-93 8-20-93 8-20-93 8-24-93 8-20-93 8-24-93 8-27-93 8-21-93 8-18-93' 8-19-93 8-21-93 8-25-93 Prod Proffiel ~%1~~ Run Peri Record ~5-~z~ o Run TBG Cut Record Run CNL (~ 1 ~o- ~ t~.~z.. Run Peri Record lzo~-lz~z~ R,,- Peri Record ~m-tzza% Prod Proffie Prod Proffie ~ I~,-I Burst TDTP 1, 5" '~l%%'lil~Sch 1, 5" a~$-~ Sch 1, 5" Sch 1, 5"~v~0-a~t~ Sch 1, 5" Sch 1, 5" Sch 1, 5" Sch 1, 5"~-az~ Sch 1, 5" ~ ~ ~ ~o---Sch ~ ~ z%q Peri Record ~%~-t~o~ R!!n 1, 5" Sch CBT Color CETImz~-- ~r ~ R-n 1, 5"~ch' P~ Record ~ ~ct/~;~~ D,,-! Burst TDTP R,,- 1, 5" ~Z.~. Sch ~mm-a Prod Profile ] 51~'~l~le~Run 1, 5,,~%~o Sch %5°~0 CNL ~t~0-q~ R.- 1, 5" Sch Prod Proffie USIT Color I~,-l Burst TDTP D.-I Neutron R~_m 1, 5" ~0o --- Sch~Z~2 R-_n 1, 5" ~0k-~q--Sch t~ R;,- 1, 5" t~zoo-- Sch %.t~o Run 1, 5" ItZ~o--. Sch~170~ Sonya Wallace ATO-1529 # CENTRAL FILES # CHEVRON # BPX # STATE OF ALASKA # CMNT CHAP~,U~T # EXXON # MOBIL The correct APl# for 4-24 is 50-029-21508-00. The APl# for 5-17A is 50-029-20271-01. DATE ' 4-4-9i F;;FF:'Ii:.;I;..'r..."NCIE' ARCO CASED HOLE F:'INAL;~' 2 .... t 9 2 .... i t - 9 t F:'F;.: C) D LJ C ]" ]: 0 N F'I:;; C) F: :3 ..- 2 ;.'i .-. i 6 - 9 tL E A K D Ii.;. T F C T I 0 N "z....".~r t ..... i ::::~-. ~::' t S F:' I N N E R / T E: M F' ,..., ...i . .. ., ;.*."'..-4 ?;- ~ 7-9 ~ INJECT I ON S .... t ~.!;. ..7, - ~ 7 -' 9 t I N,..I r_.i: C T I 0 N ~, -,.... 6 i .-.'.S-9 ~ F'IT$ ~' "~i '"~, 6 .... 9i PITS ,..) "- ~.., .. ~.' 7 .... ~6 :3 .... ~4-9~ F'I'f',.? 7'"'S4 3; .... 15 .... 9~ INJECTION/TEMP ii-9 i .... '?'"'9~ F'IT$ ti ....... 28 ~ i,.. '"~'"9''~ PRO][)UCTION PROF ~ S. - ~ 9 S '- ~ 6 - 9 ~ I N. ,J F" C 'f' I 0 N t :3'-'20 S .... I 7 -9 ~ I N d E C T I 0 N i S""2SA ;'_~- ~ 6-9~ INUECTION t5 .... Ii 2-~3;-9~ F'FRF BREAK -DOWN ~/_~ '- "~,._,_'-~-'~.3-9 ~,= SF"rNNER/INdECTiON ~ 8..- J ~ .3-8- 91 F' I I'S F'I.. E: A :";' E .:916N I:;~Ii:'CEIVED BY I"IAVI'.': A NICE AND DAY' R UN i , 5:" RtJN. i: ,...'~"&5' F;,'UN' t ,.5" RtJN i, .5" F;.:UNt , 5" F;..'UN i, 5" RLJN 2, 5:" 1=4 U N I, .5" RLJN i, 5:" RUN i, 5" RLIN i, 5:" RUN i , .5" RUN i; 5" RUN i, 5" RUN t , 5:" RUN i ,.5;" RUN i, D" RETURN 'rilE ATTACHED COPY AS RECEiF'T OF DA'fA SHARON WII...,S'ON ...... A T 0 - t 5 '2 9 · · .,,.. . , DI$1'RIBUI']:ON ~ CENTRAL. "~'" .. ·: ;~, '~ ,v, ~' '.,,, :, .: .- , ~. D' ~' !~l~: ~.~:a~:'~:~;'";""~'<i~'''/: ' ~ ~ . .., : ;~,..~ ~'~..:. ~ ~-~,,.'- ",'~----'~'-- "---- '"" -',?A'~ ;' ..... :":*: '~. :" :'.;'~;';'.V:'r(!' 'v;~.'..~ :r . 'I'I.-IE~. CORRECT AF'I~ PHILLIPS F'B BELL FILES ._ R & D BF, X .................... " ....... STATE OF ALASKA TEXACO ........... · F'OR-.t6~2. I$ 5e-e29-2e544, · · · I"IF;,'S CAM(](] .I--I F;..' S C A M CCI C A i"l C 0 i..i F;.: S H F<..S' C A M C 0 C A Pt C [) H R ;~.' !..I i:;:. CAMCO CAMCO CAMCO H R S I"i F.'.S ARCO ALASKA, INC. F'.O, BOX 100360' ANCHORAGE, ALASKA 995t DATE' 8-tt-89 REFERENCE: ARCO CA£ED HOLE FINALS 2-t 4 7-t 4-89 PIT£ 2-22 7-t 6-89 PITS 4-22 8-4-89 COLLAR/F'ERF 4-26 7- t 2-89 TEMP 7-5 7-t 9-89 GR/CCL 7-7A 7-30-89 SPINNER/TEMF' ?-t 4 7-28-89 SF'INNER/TEMP 7-3J 7-23-89 COLLAR t t -t 8 5-1 8-89 I'MD i I -24 5-t 7-89 TMD t t -25 7-t 2-89 TEMF' t 2-30 7-23-89 COLLAR t 4-i 5 7-20-89 PITS t 4-~ 6 7-t 7-89 PITS i 4-20 7-2i -89 PITS i 4-24 7-22-89 PITS RUN t, 2 RUN t, 2 RUN t ,- 5 RUN t , 2 RUN t, 5 RUN ~ , 5 RUN t, 5 RUN i , 5 RUN t, 5 RUN i, 5 RUN i , 2 RUN t, 5 RUN t , 5 RUN ~, 5 RUN t, 5 RUN t, 5 PLEASE SIGN AND RETURN THE ATTACHED COF'Y AS RECEIF'T OF DATA. RECEIVED BY HAVE A NICE SALLY HOFFECKER AT0-1529 Oil & con . Ns a Anchorage "&5' · ¥ · · · CAMCO CAMCO ATLAS CAMCO CAMCO OTIS OTIS CAMCO HLS HLS CAMCO CAMCO CAMCO CAMCO CAMCO CAMCO DISTRIBUTION CENTRAL FILES ~ PHILLIPS CHEVRON F'B WELL FILES D&M R&D EXTENSION EXPLORATION ~ BPX EXXON ~ SI'AI'E OF ALASKA MARATHON ~ TEXACO MOBIL * THE CORRECTED AF'I~ FOR t4-t6 IS 50-029-20608. ARCO ALASKA., F',.O, BOX ~002:60 ANCHORAGE, ALASKA 995i OATE' 7 '"8-89 REFEI;,'ENCE' ARCO PRESSURE DATA 5--i 5 '7-'?-89 BHP--S']"ATIC GRAD]:ENT FILS 5-2'2 7-9-89 B HF'--.~"'i'AT I C GRADIENT fILS 4-i 6--2::i--89 BHF'--5,"I'A T I C GRADIENT HL£' 4---2,5 ,-"-~ 2-89 BHF'--::,,'TATIC GRADIENT CA~'~CO 7-i6 6-T30-89 BHP--Si"AFIC GRADIENT FiLS 9-6 '?..-5-89 BHP--;~"FA'i".[ C ~.~R~D l F'N F HI._S 9--7 7--.5.'.-89 BHP--:~'TAT IC GRADIENT HLS 9.--9 '?-6-89 BHP--STA'F!C GRADIENT fiLS 9-24 7-7-89 BHP--S i"Ai" I C GRADIENT klLg' 9-28 '7-6-89 BHF'--ST,ql' i C GRADIENT HLS i i -25 7--i ':2-[:39 BHP--STA'FIC GRAD].ENT CAMCO i6-i 7-5-89 BHP--S'i'ATIC GRADIENT MLS ~6-6 7-8-.89 BHP--STATIC gRADIENT HLS J 6-8 7-8-89 BHk'--STATIC GI:;,'ADiEN F HLS J 6-t 2 7-9-89 BHP--:~'TATIC_ GRADIENT HLS J6-20 '?-8-89 BHP--STATIC GRADIENT HLS J6-24 7-6-89 BHP--STATIC GRADIENT ..... HLS ..... F'WDW2-J 7-9-89 BHP--$TA'FIC GRADIENT CAMCO HAVE A NICE DAY! ~ALLY HOFFECI<ER ATO-~ 529 I:'I_EA5"E SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. DISTRIBUTION · -- -~;.. '~' CENTRRL P-ZEES '. ~ F'H.[LL]:F'5' CHEVRON ... ' PB WELL FILES D & M '~ R & D EXTENSION EXPLORATION ~ BF'X EXXON" ""' ~ '"' ' -.- STATE OF' ALA;~'KA MARATHON .-~' TEXACO MOBIL ARCO ALA.?KA: INC,. F'~O. BOX i (~,¢,36C, ANCHORA(;E, ALA~I-.'..A 995i (3 DATE - 6-9-89 REFERENCE' ARCO CASED HOLE FINALS' S-9 ~-'~"')-8~_. ,.:., , PRODUCTION F'ROFiLE RUN "'S-24 5-'.22-89 GR SPEC .TOOL RUN ~, -~" 3-29 .5-26-'89 GR SF'EC TOOL RUN '~'4-t5 5-i 7,i9-89 TEMF' RUN i, ~' 4-26 5-i9-89 F'RODUCTION PROFILE RUN 1, -"- 4-3~ 5-t8-89 PRODUCTION PROKILE RUN t, "'-.,'~- t .-,'z 5-2r~, ~_".) t -89 I'EHF' RUN i , ---5-'i 7 5-'2~-89 F'RODUCTION PROFILE RUN i , ~7-?A 5-28-89 F'ERF RECORD RUN t, '~" 9-i4 5-22-89 INJECTION F'ROF.rLE RUN t, ----"1--~-t t 5-2t-89 PITS RUN t , '"'~i2-t9 5-2i-89 INJECTION PROFILE RUN i, ~t 4-t 3 '5-27-89 COLLAR/F'ERF RUN t , -'-- t 8-2t 5-22-89 CBT RUN t, ~ OWDW-NW 5-24,25-89 F'ITS RUN i, ~OWDW-3:E 5-25-89 F'I'!'$ RUN i , ~ ") F' --~ OWDW-$W .,-..4-89 ITS RUN i, PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIF'T OF DATA. RECEIVED BY ATO-t 529 ~ .... Anchorage DZSTRZBUT~ON APPROVED ~__ TRANCe 89~5t CENTRAL FILES · CHEVRON-~':.; .~. D&M. :.. EXI'EN$IO~'-EXP'LORATION EXXON MARATHON-.,- :'-- MOBIL PHILLIPS F'B WELL FILES R & D BPX STATE OF ALASKA TEXACO CAMCO ~'CH SCH C A i"J C ("1 r'AHCO C: A Pi C 0 C A ~ C 0 CAMCO CAMCO CAt, CO CAHbO ATLAS CAHCO CAMCO CAMCO 995 ~ () 3-t0 4-"2 4-5' 4.-.? 4-..t.,. q' 4-.2(.) 4..."~6 '"~-'..5 5-t7 '?~..3(:) 7 -3 (') 9-28 t t-26 t 8'"' 9 t8-23 FLEASE ,:fig AF','CO CAS'ED HOI..E I= ]: NAI_,.? 5""6-89 F'ROD, F'I:;,'OF ILE/LEAK DE:TEC'! ].ON RUN i , '.5'-"4-89 'Fli"'HF'/FrI_LJID DENS'II'Y KUN t , .5-'20-89 C O L. I... A F~ / F:' I~!:F;~ F: F;;LJNi '5-.t 8.-.89 CNL-.GAMHA RUN t, 5- t 8- iii 9 D ]: f:' F l' Ii:: H P R U N t, '.5 - .3 .... 89 I N,J E C T i 0 N F' R U I::' I L E I;: U N i, 5.-..3-1:'¢9 IN,JECTION PF~:OF']:L.E/TE. HP RLJN t 5-2~-89 CNI_-G~HH~ RUN i, 5 .... t9-89 CNL.-GAHHA RLJN t 5- t ?-89 CNL.-bAHH~ RIJN 5 - 5 .... 89 I N,.J E. C l' .1:0 N F:' R 0 F ]. L F f.-.: U N 4--~ ..-89 COI..I_~R/I::'IF'RF RUN J , 5-t 8-.89 CNL.-GANHA F(LJN t 3 .... 29-89 COLLAR/F'E:RF RUN :3--29-89 COL. I_AR/PIERF RLJN '5-17--89 DU~L BUR$'F I"D'I'-P RUN 5-t'?-89 CNL RUN t 3.-30-89 COLI_RR TO :~'E'F F'~'I'CH RUN t, 5-t(.)-87 I..F.:'AK DE:'i'ECTION RUN t, '5-.'.5- 89 IN,JECTION F'ROF'r LE/TEHP RUN 5 .... 8.". 89 I::' I.. U I D D E N 5' I T ¥ / 'ir' E i,t P R LJ N 'l 5-8..-89 F'LU 1' g DE:N,S' L'I'Y/TFHP RUN 3-:~6....89 COLLAR/PERF RUN t , N AND IRE:TURN THE ATTACHED COPY AS RECEIF"F [)F:' DATA. C A i"'i C 0 C A H C 0 ATI..A$ AI'I_AS; A'I" L.A Zx:' C A H L'. ("1 C A f,~ C 0 A i"L_AS' ¢:i i" I... A,'!;' A I' I..A;~' CAHCO HL$ A TL.~5' I--ILS kll..5' $C~.-! 5' C H F-ILS CAHCO C~MCO C A M C o C A H C 0 I-IL. 5' RFCE]:VED BY HAVE A NICE DAY! ..?ALL. Y I-I[IFFECKER A'IFO- t 529 Alaska Oil &2;cShoC~;s~; Commissio. D 15'TR I BU'fI ON ~' CENTRAL FILES ~'~ F'H:I_'LI__I_'F',? · . .,I'IE:.VRON F:'B WELl_ F'ILE..S' I) & M Fl & D ~." E. XTIENS'].ON EXf:'LORAI'ION .$ BF:'X '"' EXXON ',,""' ,.~"I"ATF' OF" ~L.A;S'I<A '1" i"~ARA I'FION .,-"'1' IEXACO · "' HOBTL T ARCO ALA~'KA, INC F'. 0. BOX ANCHORAGE, ALASKA ':.295 J 0 DATE REFERENCE' ARCO MAGNETIC TAF'E(5') WITH i-2i 5-t6-89 CNL i-Se 5-i0-89 CNL 'i-32 5-i0-89 CNL 3-9 5-i8-89 CNL 4-2 5-20-89 CNL 4-5 5-i9-89 CNL 4-7 5--i9-89 CNL ,..4-26 5-t8-89 CNL 5-4 5-ii-89 CNL 6-~ 5 t~-8~ , CNL 6-24 5-i2-89 CNL 7-3 5-t~-89 CNL '7-34 5-t2-89 CNL ~2-~ 5-~-89 CNL t4-3 5-t4-89 CNL PLEASE $IG N AND RETURN T HE ATTACHED COPY LISTING(~) JOB$383~ JOB~i 4 JOB:~38i 5 JOB~:'3836 JOB~S84i JOB~SSS9 JOB~SSS5 JOB~SSi'? JOB,S825 j0~S8~4~ JOB,S82'? JOB~3823 JOB$3826 .JOB,S828 A£ RECEIPT OF DATA~ A FLAS ATLA£ Al'LAS ATLAS Al LAS Ai'L. AJ! A'I I_A~' A I" L A i;' A I' L A ~.' A'f'LA,~ ATLAS ATLAS' A'I'LA,S' ATLAZ AI'LA~ RECEIVED BY HAVE A NICE DAY! SALLY HOFFECKER ATO-t5~9~ APPROVED ~.~_ TRAN$~ 89:-- DISTRIBUTION CENTRAL F-ILE$ (CH) CHEVRON D & M TAMMA~.~-B~OWN ~OH) · EXX.ON'j:~ "'~" ' ,MAF~AIHON '~Y" .. .'-. -- .... .~,' ~':~tTM 0:. ' ~ PHILLIPS F'B WELL FILES R & D BF'X $'¥ATE OF ALASKA TEXACO THE CORRECTED AF'I$ FOR I£' 50-(~29-208~6. p--.. Alaska Oil & Gas Cons. CcmraMsion Anchorsge ARCO ALASKA, ]:NC~ P,O~ BOX JO0360 ANCHORA£;£~ ALA,~'KA 995J 0 DATE: 9-2-88 REFERENCE: ARCO PRESSURE DATA 4-26 6-29-88 5-2 8-t 4-88 5-4 8-3-88 ?-28 8"26'-88 7-29 8-26-88 ?-2~ 8"26"88 t6-4 8"t 8-88 ~ 6~'~ 4 8-~ 2"88 BHF'--PBU OTIS BHP ....FLOWING GRADIENT CAMCO BHP--PBU OTIS BHP--$TAI'IC GRADIENT CAMCO BHF'--$TATIC GRADIENT CAMCO BHP--$TATIC GRADIENT (NOl' STABLE) CAMCO BHF'--$TATIC GRADIENT CAMCO BHF ..... FLOWING GRADIENT CAMCO PLEASE SIGN AND RETURN THE ATTACHED COPY AS RECEIPT OF DATA. - HAVE A NICE "~ ~'~ ~'~ Oil & Gas ~ons, Coi~r~liS$iO]l SALLY HOFFECK ER Ap, chorage A'FO-t 529 I'RAN$ ~88557 ~ '~ 5 '~ ~"'~ ~ ,~ I'° AFF'Ru~c.D ......................................... DISTRIBUTION CENTRAL FILES CHEVRON I) & M EXTENSION EXF'LORATION EXXON HARATHON HOBIL F'HILLIPS' PB WELL FILE,~ R & D ,~AF'C STAT~'" OF ALASKA TEXACO STATE OF ALASKA ALA-.,...A OIL AND GAS CONSERVATION COi..__.,ISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend [] Operation Shutdown [] Re-enter suspended well C Alter casing Time extension [] Change approved program [] Plugging [] Stimulate [] Pull tubing [] Amend order ~ Perforate ,~. Other 2. Name of Operator ARCO Alaska, Inc. 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 91' FSL, 429' FWL, Sec. 26, T11N, R15E, UM At top of productive interval 1585' FNL, 1500' FEL, Sec. 26, T11N, R15E, UM At effective depth 1507' FNL, 1378' FEL, Sec. 26, T11N, R15E, UM At total depth 1494' FNL, 1356' FEL, Sec. 26, T11N, R15E, UM 11. Present well condition summary Total depth: measured true vertical 5. Datum elevation (DF or KB) 65' RKB 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 4-26 8. Permit ~m_~ 9, APl number 5o-- 029-21520 10. Pool ~rudhoe Bay Oil Pool fee~ 10866 feet 8879 feet Effective depth: measured 10820 feet true vertical feet 8841 Casing Length Size Conductor 80' 20" Surface 2462' 13-3/8" Production 10492' 9-5/8" Liner 561' 7" Perforation depth: measured NONE true vertical NONE Tubing (size, grade and measured depth) 5~" L-80, tbg w/tail @ 10325'MD 2 , Packers and SSSV (type and measured depth) 3H net r~ 1ri?AR' RAI -A qqqV · '2997' 12.Attachments Description summary of proposal ~'I 13. Estimated date for commencing operation Plugs (measured) Junk (measured) Cemented Measured depth True Vertical depth 1700# Poleset 114' 114' 2500 sx AS 111 & 2497' 2497' 400 sx AS 11 500 sx Class G 10522' 8588' 300 sx Class G 10304-10865' 8405-8878' , RECEIVED ~aska 0ii & Gas Cons. Commission,,. tLr~chorage Detailed operations program ~ BOP sketch rD 14. If proposal was verbally approved Name of approver Effective Immediately Date approved 15. I hereby,,certify that the foregoing is true and correct to the best of my knowledge Signed/~}~f~,-~-j ,~~ Title Oper~l;ions Engineering Managpr Commission Use Only Conditions of approval Notify commission so representative may witness I Approval No. [] Plug integrity ~ BOP Test [] Location clearanceI Approved byp¥ l~!~!i[ ~. ~,~i~1~ (265-6315) Form 10-403 Rev 12-1-85 '"" ,turned Commissioner by order of the commission Date 2"////~ -/~ Submit in triplicate ARCO Alaska, Inc. requests the permission to waive the production profile prescribed in Conservation Order 165, Rule 11a. Only 20' of perforations were shot in 4-26. All of the perforations were shot in Zone lb thereby negating the need for a spinner survey. Additional p_er_forations in Zone_._1 are planned. The timing of the perforations, however, is af~6~'-i~h~-P-ih~i'~-~ai~- six month time period has passed. A production profile will be run subsequent to the additional Zone I perforation. STATE OF ALASKA ~ ALASK/~OIL AND GAS CONSERVATION C~ivlMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well OIL [~ GAS [] SUSPENDED [] ABANDONED [] SERVICE [] 2. Name of Operator 7. Permit Number ARCO Alaska, Inc. 85-:314 3. Address 8. APl Number P, 0. Box 100360, Anchorage, AK 99510 50- 029-21520 4. Location of well at surface 9. Unit or Lease Name 91' FSL, 429' FWL, 5ec.26, T11N, R15E, UM Prudhoe Bay Unit At Top Producing Interval 10. Well Number 1585' FNL, 1500' FEL, Sec.26, TllN, R15E, UM 4-26 At Total Depth 11. Field and Pool 1494' FNL, 1356' FEL, Sec.26, TllN, R15E, UM Prudhoe Bay Field 5. Elevation in feet (indicate KB, DF, etc.) I 6. Lease Designation and Serial No. Prudhoe Bay 0i 1 Pool RKB 65'I ADL 28324 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp. or Aband. I 15. Water Depth, if offshore 116. No. of Completions 02/19/86 03/08/86 06/08/87*I N/A feet MSLI 1 17. Total Depth (MD+TVD) 18.Plug Back Depth (MD+I'VD) 19. Directional Survey 20. Depth where SSSV set i 21. Thickness of Permafrost 10866'MD, 8879'TVD 10820'MD, 8841 'TVD YES [~ NO [] 2227' feet MDI 1900' (approx) 22. Type Electric or Other Logs Run D IL/Sonic/GR/SP, Density/Neutron/GR/Cal, CBL/CCL/GR, Gyro 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE ITOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91 .5# H-40 Surf 114' 30" 1700# Poleset 13-3/8" $8.0/72.0# K-55/L-80 Surf 2497' 17-1/2" 2500 sx AS Ill & 400 sx AS II 9-5/8" 47.0# L-80 Surf 10522' 12-1/4" 500 sx Class G 7" 29.0# L-80 10304' 10865' 8-1/2" 300 sx Class G 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 10730'-10750'MD 8766'-8783'TVD 5-1/2" 10325' 10236' Perforated w/4 spf 26. ACID, FRACTURE, CEMENT SOUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT& KIND OF MATERIAL USED N/A 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) June 14, 1987I Flowing Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE IGAS-OILRATIO 06/16/87 6 TEST PERIOD I~ 251 93 0 30°I~70 Flow Tubing Casing Pressure CALCULATED.~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 215 350 24-HOUR RATE ~ 1005 372 0 29.8 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NoneRECEIVED JUL 2 0 1987 Alaska 0il & Gas Cons, Commission Anchorage *Note: Drilled RR 3/12/86, Tubing run 8/8/86, Perforated well 6/8/87. Form 10-407 Rev. 7-1-80 WC3/20:DANI Submit in duplicate / CONTINUED ON REVERSE SIDE 29. [ , GEOLOGIC MARKERS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recovered and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadl erochi t 10545' 8607 ' N/A C0C 10560 ' -105! 8 ' 8620 ' -8653 ' Base Sad] erochit 10756' 8787' 31. LIST OF AITACHMENIS None 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~~~~j TitleAssOciate Engi"eer INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5' Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21' Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- lng and the location of the cementing tool. Item 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". Form 10-407 June 16, 1986 Mr. Randy Ruedrich ARCO Alaska, Inc. P. O. Box 360 Anchorage, Alaska 99510 Re: Our Boss Gyroscopic Survey Job No. AK-BO-60029 Well: DS 4-26 Field: Prudhoe Bay Alaska Survey Date: May 21, 1986 Operator: D. Harger Mr. Ruedrich: Please find enclosed the "Original" and one (1) copy of our Boss Gyroscopic Survey on the above well. Please note that a magnetic tape of the survey will be sent to Standard AK Prod. Co. and Exxon as per request of Jo Ann Gruber. Thank you for giving us this opportunity to be of service. Sincerely, NL SPERRY-SUN, INC. Ken Broussard District Manager Enclosures NL Sperry-SunlNL Industries, Inc. RO. Box 190207, Anchorage, Alaska 99519-0207, Tel. (907) 522-1737 ARCO ALASKA. WELL 4-26 PRUDHOE BAY ALASKA I NC. .=.F ERR¥ -.:, _IN WELL SURVEYING COMF'ANY ANCHORAF~E ALASKA COMF'UTATION [,ATE MAY 22, 1.986 VERTIF:AL '._--;ECTIFIN C:ALCLILATED ALONG CLCISI_IRE PAGE I DATE OF SURVEY MAY 21, 1986 BOSS GYROSCOPIC SURVEY ._lOB NUMBER AK-30-60029 KELLY BUSHING ELEV. = 65.00 FT. OPERATOR-D. HARGER '1- R U E S U B - S E A F: 0 U R S; E MEASURED VERT I C:AL VERT 1CAL I NF:L I NAT I ON DEPTH DEF'TH DEPTH DEG M I N 0 0.00 -65.00 0 0 135 1:34..9:Z: 69..98 I 28 2:35 234. ?5 169. 95 1 26 335 3.'_'-:4.91 26.9. '.-? 1 i 31 4:":5 434.88 36.9.88 I 27 .~.-,= ~.-, ,-,,-- ,:,~ .-.,/. ._ ..:,.., ._ ._-4 46.9 ,;.,._ . ,:,._, . I .. 6:35 6:'::4.82 56'.-?. :32 I 18 7:35 734.79 669.79 1 12 835 :334.77 76.9.77 I .9 935 .934.75 869.75 I 5 1035 1034.74 'F/6'.-?. 74 0 51 1135 11:34.72 106.9.72 I 2 1235 1234· 71 116'.-.'~. 71 I 6 13:35 1334.6';',' 12/_-..9. ,/_-,9 I 0 14:35 14:34.68 1 :'::./-,_ ':.?.. (:,,=,' '-' 0 !54 1535 1534.67 1469.67 0 40 1635 1634.66 156.9.6/_-, 0 37 1735 1734.66 166.9.66 0 15 1835 18:1.-':4.65 176.9.65 0 31 1.9:35 1 '.:.~ 34.64 186.9.64 1 10 20:35 20:34.62 1.96.9.62 i 13 2135 21 :]-:4./-.,0 2069.60 i 5 2235 2234.5:E: 216.9 · 58 i 18 2335 2334· 55 2269. 55 i .9 2435 24:34.54 236.9.54 i 1 · ",~.-.:,.~ .":, .,=; -':, z~ '-;'::, '::'4/-,9 .~'.'::' 1 · " ..I .,.i ._d:. '-- '--~' ][ . '-. d.. .,.._ . . -#. d.. 26:'::5 '.':_'6:34.50 256.9.50 1 1 2/_-.6:5 2684.46 261.9.46 2 36 2'735 27:34.35 266.9.35 4 48 2835 28:]-::3.72 2768.72 7 56 COLiR SE DFiG- L E G D I RECT I ON :--;EVER I TY DEGREES DEG/100 N 0. 0 E 0.00 S 55.8 .9 W 1.09 '.;; 55 =r · .~.,) W 0.04 '._-'; 54. 0 W 0.10 S 56.60 W ~:).10 S 48.89 W 0.20 ._-, .~'~.60 W 0 15 .c; 49. :3.9 W 0.10 '-' 4.9:30 W 0.06 S 50,50 W 0. F,8 S 5';.'. 0 W 0.24 S 55 '"" . c. ~ W 0.20 .... ,~..:.7 W 0.07 S 66.._.c"-?.. W 0 .20 S 87.80 W 0.:37 N._-..'" 9 . "-: ~'~ W 0 . ._'.-'2 .-. ,_-,o .~,:~ W 0 11 N 84.89 W 0.37 S 7'7.60 W 0.28 N /-.,3.5(:) W 0.6:4 N 66.60 W ~]).0:3 N 69 '~"~ . ._-,c W N 40 ~' ] . ..,L W 0.63 · ~,..,. 19 W 0.18 N._, ';'/-_, . :$:0 W .... 0, 1 ._?~ '-."~ 8.9 0 N .. .... W .21 N 10. '-r ._-,.) W ...,o. :-~'-? E ' 4;' .. 7 N 63.:_-30 E 4.68 N 64. ':":~ E :]': 15 TOTAL RECTANGULAR COORD I NATES'' NORTH/SOUTH EAST/WEST C). 00 0.00 0.97 S 1.43 W 2.40 S 3.5:--: W 3..90 S 5.65 W 5.38 S 7.79 W 6.91 S 9.80 W 8·46 S 11.62 W 9.86 S 13.30 W 11.21 S 14.87 W 12.48 S 16.37 W 13.54 S 17.69 W 14.50 S 19.03 W 15.54 '.-; 20.5"..'.~ W 16.42 S 22.21 W 16.81 S 23.80 W 16.83 S 25, 18 W 16..90 S 26.31 W 16..95 S 27.07 W 17.02 S '27.74 W 16.66 S 2.9.11 W 15.78 S :31.00 W 15.02 S 32.87 W 13.82 S 34.50 W 12.13 S 35.82 W 10.5.9 S 36..9:3 W 9.02 S 37.88 W 7.05 S 3:E:.51 W 5.78 S 37.73 W 4.14 S 34.??7 W 0.69 N 24..98 W -VERT I CAL SECT I ON ( 0.00 -1.6.9 -4.17 -6.71 -.9.26 -11.76 -14. 1:3 -16.31 -18.36 -20.32 -21.9.9 -23.61 -25.44 -27. 1 .9 -28.5'7 -29 -._ 0 3 -:3¢). 91 -31.4:3 -32.11 -32. '77 -33. ~0 -33.75 -3:3.43 -:3:3.07 - 32.5.9 -:31.58 -30.12 -27.04 -16.66 ARCO ALASKA, WELL 4-26 PRUDHOE BAY ALASKA I N F:. SF'ERRY-:E;UN WELL oI_RVEYING COMPANY ANCHORAGE ALASKA COMF'LITATION DATE MAY~_'-'2, 1'.~86 VERTICAL SECTION F:AI_CLILATEI-I ALONG F:LO'.E;URE PAGE 2 DATE OF SURVEY MAY 21, 1'.~8/:, BOSS GYRCISCOF'IC SLIRVEY dOB NUMBER AK-B0-60029 KELLY BUSHING ELEV. = 65.00 FT. CIPERATOR-D. HARGER TRUE SUB-SEA COURSE MEASURED VERT I CAL VERT I C:AL I NCL I NAT I i_-iN DEF'TH DEPTH DEPTH DEG M I N 2'~35 29:32.52 2867.52 '~ 44 3035 3030. 'F~/:, 2965. 'F~6 10 28 3135 :3128.81 306:3. :31 13 19 3235 3225.5?/ 3160.59 15 50 3335 3321,3'.:) 3256, 39 17 26 3435 3416.24 3351.24 1.9 25 :3535 350'?. '70 :2:444. '.-.?c) 21 :33 3/:,35 3601.75 3536.75 25 0 3735 :3690.92 :3625. ?.'~2 28 46 3835 3777.47 3712.47 31 18 39:35 3861.78 3796.78 33 43 4035 3'.-343.76 :3878.76 :36 6 4135 4023.85 3958.85 :37 26 4 ~ .:,.. 4101 17 40 :::/-,. 17 41 15 4:335 4174.82 410'F~. :s:2 43 5:2 4435 4246.82 4181. :::2 44 1 4535 4318.56 4253.56 44 18 4635 43'~0. 10 4325. 10 44 19 47:-:5 4461.27 4396.27 44 55 ,=,.:,._, 4 .~,.:, ...'., 10 4467 10 44 . .-- ..¢' 49:35 4/:,02.73 45::37.7:3 45 15 5035 4/:,72.53 4607.53 46 11 51 :'::5 4741.73 4676.73 46 12 52:;:5 '4810.72 4745.72 46 3:;: 5:3:35 4:--:79.4:3 4814.4:3 46 :39 543.'_;'i 4'.-.'./48.22 46:8.'_;:. 22 46 '2:3 55:35 5A 17. :37 4952. :'::7 46 6 56:;:5 5086.85 5021.85 45 51 57:35 5156.2:3 5('~91.28 46 I 1 5:=::35 5225. 1'9 5160.19 46 41 COURSE D I RECT I ON DEGREES DOG-LEG SEVER I TY DEG/100 N 58.39 E N 55.50 E N 56. :E:O E N 47.60 E N 46.50 E N 47.30 E N 4:3.6, cE) E N 41.69 E N 44.10 E N 43.50 E N 43.10 E N 41.6.9 E N 40.60 E N 40.1':.? E N 3'.-.?. 50 E N ':'-:9, 50 E N 37.'~.39 E N .-,c ,-,_,;, ~:, 7. ,:, .. E N 40.3(.') E N 40.19 E N 40.10 E N 39.89 E N 3'.~'~. 6? E N 3'.-.?. 60 E N 38, 8'i.) E N .'3'F,'. c") E N ::38.8'i..'/ E N :38. N 38. N 39. TOTAL RECTANGULAR NORTH/'._:;OLITH C:CuZIRD I NATES ........VERT I CAL EAST/WEST :_:;ECT I ON 2.01 8.12 N 11,54 W -:2.0:3 0. :3.9 17.69 N 3, 16 E 1._,"". 02 2, 87 2'~'/.. .1/:, N 2A ,~..'-'.'9 E .:,'-'~._,. 1:.':: 3.41 44./:,7 N 4£). 02 E 5'P. 96 # . . I 64 64 20 N 60 98 E :::8 ._4 I i- i' · .- · · .~.~ .:,'"~,= 7~-~ N 84 07 E 120 10 · .-.'--.' 49 110 . :37 N 108.9.~._, = E 1Fl=._ .j. (.)"-...., :_--'. 5;4 1 '"" · .-.~ 4/:, N 1.-.= 69 E 194.._,:, ! . ..~! ._1. · ..,'~', '-.72. 172 .54 N 166. ..?]';' E.. 2:3'.'f/ .78 ;L:', 54 208,/:,7 N 201 . 1.5 E ...~,.~":":", ~:Z-- '.--' 4:3 247 78 N .-'-"-"-'.:,,=,. 2 =-"~ '"" ") · .':-TL c.~, N 276 · .~,6 E 400.77 1.48 :~: :~ 5 .1:3 N 315 .95 E 460 . ._.s,_,,::' · "3,~z.-~ '") '-' ~-~ '-~ .-~ I::; · r.~ .-, .-, · ,-~ ~-, ~,,:,.:,, 41 N .:,._7 02 E · ... · '-'.~ .::.:, N 4Ac:~ :3 2.66 4.-,~.. '-'-' _ . ...... I~1 I~1 0 15 4o~.,. ,-,o . ,.-,:, N 444· 49 E 6/:,0. 0. :3(.') ~ '-' '-"-' · _,4z:, 68 N 4oo, 76 E 7:30, - ?~,~ 0. :~5 .. ~'6, 48 N .=,:~:~:_._. 34 E 7'.-.??. ,_.-, 0.66 650. ".~,. 1 N 57,'-3. .J'='-.~ E 869. '77 0.09 7c]4.09 N /:,24.2(.) E 940, 45 '='-' 9 . :?, 0.40 7 ~,,:,. 1.N 66'?/'. '" o..., E:. I c') 1 i 1 0. ':'~5.... 813. c')S. _ N 71~,.,. 87 E 1")'~'''-',. c.,--, f,O_ c'). 15 '-' '" . .),d E I 154 64 o,/.-,,:,.5C) N 762 c'"' . O..:,'-'~'.-, ?24,24 N 808 .27 E 1226, '-'qo,_ cI) . 5 2 9 E:C). M I N o._, 4.2 4 E 1 ~'.'.~ ¥. 3 5 A. 2 7 10 3 6. '- ~' .'.~._, N 8'.-.? 9.8 7 E 1:3 71.71 0. ::: 0 1 A':.? 3.13 N '~ 4 5.2 8 E 14 4 3.7 3 . ' .............. i ............. 0'~ ,..,~, I 1 .26 N 5(] E ' "-":' 49 '~9C). '-:5~ E 515.4(') -- ,- . . ' .-~ ~. A'-'-) E 0 37 12 (') 5 5 c') N 1 (.)._-,.~ 15 E 1 .-,o 7.1 ';': 26 ""'"' :190 E 0.66 1 1 . ,:, ..' N 1080 ,7.5 E 1/-,_ ?,_ '~'. . :38 ARCO ALASKA WELL 4-26 PRUDHOE BAY ALASKA I NC. '.:;F'ERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA C:OMF'UTATION r~ATE MAY 22, 1986 VERTIF:AL SEE:TION CALCULATED" ALONG RLOSLIRE PAGE 3 DATE OF SURVEY MAY 21. 178~:, BOSS GYROSCOPIC SLIRVEY dOB NUMBER AK-BO-6Oi.~'~- KELLY BUSHING ELEV. = 65.0£) FT. OF'ERATOR-B. HARGER T R LIE :--; LI B- 8 E A C[i IJ R S E MEA'.31JRED VERT I E:AL VERT I CAL I NCL I NAT I ON DEF'TH DEF'TH DEPTH DEG M I N 59:35 6035 /-,,135 6235 6335 6435 6535 6635 6735 6835 6935 7135 7235 73:35 7435 7535 7635 77'35 7835 7935 80:::5 8135 8235 84:35 8535 ,-,/., Q, ,_1 8735 ,~ ,~, .~, ... 53/-`-, 1. :'::4 5296.34 5428.54 536:3.54 5495.68 5430.68 5563.02 5498.02 5630.72 5565.72 5698.4? 5633.49 5766. :30 5701.3£) 58:34. '70 5769.90 5903.72 5838.72 5971.93 5906. '~.)3 6039.6:6 .5::~74.86 6108.18 604:-:. 18 /.,176.43 6111.43 6244.51 6179.51 6313.23 6248.23 636:2.48 6317.48 6452.26 6387.26 6522. :32 6457. :3:2 6594.65 6529.65 6667.66 6602.66 6741. 16 6676. 16 6815.07 6750.07 6889.45 6824.45 6964.27 6899.27 7037~. 07 6'F~74.07 7113.47 7048.47 7187.46 7122.46 7261.06 719/.,. 06 7334. 14 726':.?. 14 47 2 47 37 47 55 47 '43 47 37 47 47 30 47 6 46 15 46 45 47 13 47 11 46 36 47 19 46 52 46 18 46 2 45 26 44 47 43 22 42 49 42 32 42 41 43 41 '23 41 45 42 5 42 26 42 46 43 19 COLIRSE D I REC:T I ON DEGREES N 40.19 E N 40. ('_') E N :39.8'F~ E N 40.60 E N 41.3'?~ E N 42.19 E N 42.10 E N 42.80 : N 4:3. 10 E N 43.60 E N 43 '~" · 0(.) N 44. 0 N 44; :39 N 44 N 45 "'"' N 456~"'-' N 45.:99 N 45.60 N 45. i9 N 45.19 N 44 '"" N 44.'89 N 4..,. 0 N 44.50 N 44. :30 N 44.10 N 4:3. :39 N 43.80 N 43.60 N 4:3.39 DOG-LEG :SEVER I TY DEG/100 O. 74 0.60 0.32 O. 56 O. 60 O. 75 O. 36 O. 66 O. 87 0. 62' 0.49 0.15 0.81 0.58 '0',' 60 0.31 0.63 0.72 1.41 TOTAL RECTANGULAR COORD I NAT~S ............ gERT I CAL NORTH/SOUTH EAST/WEST SECT I ON 1:317.9:3 N 1:374. 17 N 1430. ',-}4 N 1487.50 N 1= '~ 29 · J4 .... N ~.,;',-,. 16N ::,._,.~. 67N 170/.,. 9C) N 1760.15 N . 1812.91 N 1865.78 N 1°.-;'18.66 N .... 1971.01 N 2023.00 N 2074.6./:, N '"~ 1 ,"'. ~::t 2175.,~.- ~.3 N 2225.80 N 56 N ~.~:7.J. '~'~'::'-"'~ 5 7 N 1127.42 E 1732.20 1174.78 E 18£)5.60 1222.32 E 1879.52 1270.21- E' 1 :~53.52 1318.71 E 2027.38 13/-,,7.76 E 2100. 1417.~11 E 2174.46 14/-,,6.71 E 2247.95 151 ~:,. 28 E 2320.69 1566 ~ 08' E 23.93.24 1616.60 E 2466.37 1667.4.9 E 2539.76 "i718'40 E 2612~'77 176.9.76 E 2685.83 1821.6'~ E 2759.05 '1'- "' .... -= '-"':'"" '/'" ~ 7.:, . 5~, E ~ ,; .... 1. 1 '""'= '2'~03. .',,:._.. 2'7 E 1:;/76.57 E 2975.29 '2027.02 E 3046'10 2076.39 E 3115.63 2124.75 E 3183.94 2172.60 E 3251.71 2220.20 E 3319.05 2267.25 E 3385.87 2313.67 E :3452'21 '-' '-"= '-' ":' 518 z...:,._, ;,..94 E ...... 57 2406. :36 E :3585. :38 2452.95 E :3652.64 2499.73 E 3720.34 2546.71 E 3788.60 ARCO ALASKA, WELL 4-26 PRUDHOE BAY ALASKA INC. SF'ERRY-SUN WELL SURVEYING COMF'ANY ANCHORAGE ALASKA COMF'UTATION [;ATE MAY 22,, 1986 VERTICAL .SECTION C:ALC:LILATED ALONG CLO'.S:URE PAGE 4 DATE OF SURVEY MAY 21, 1986 BOSS GYROSCOPIC SLIRVEY dOB NUMBER AK-BO-600~9 ......... KELLY BUSHING ELEV. = 65,00 FT. OPERATOR-D. HARGER TRUE SUB-SEA COLIRSE MEA:E;URED VERT I C:AL VERT I CAL I NCL I NAT I ON DEF'TH DEF'TH DEPTH DEG M I N COURSE DOG-LEG DIRECTION SEVERITY DEGREES DEG/100 TOTAL RECTANGULAR COORD I NATES ......... VERT I CAL NORTH/SOUTH EAST/WEST ..,E_.T I ON. 8935 7406.70 7341.70 43 37 9035 7478.94 7413.94 43 51 9135 7551.15 7486.15 43 40 9235 7623.18 7558.18 44 9 9335 7694.69 7629.69 44 32 9435 7765.81 7700.81 44 47 ,~5c, 5 ,-,.--,~ - 7,:,.:,:,.63 7771 63 45 2 96,'-' ~ 7907 1:2: ' '-' '"' 45 18 · z, ~, . 7 ,:, 4 .:. 1 ._,':' 9735 7977.81 7912.81 44 45 98:35 8049.21 7984.21 44 7 9935 8121.59 8056.59 4:3 7 I ' (''-'~ '=' '- ~ 0)~,._, ,_, 1~.-,. 36 8130.36 41 47 10135 8:271.21 8206.21 39 30 10235 8349.21 8284.21 37 57 10335 8430.08 8365.08 34 5 10435 8513.57 8448.57 32 41 10535 859:3.58 8533.58 30 50 10635 8684.58 8619.58 30 31 10735 8769.68 8704.68 32 48 10835 8853.28 8788.28 33 44 10866 8879.06 8814.06 33 44 HOR IZONTAL I]ISPLAC:EMENT = N 43.39 E 0.:30 2856.03 N 259:3.99 N 43.60 E 0.27 2906.18 N 2641.59 N 4:=:. 6c) E 0 1 '~ '-"- '= .....:.1._! 6, '" ·,. . ,' ,_, N 268'F;. 29. N 43.39 E 0.50 3006.59 N 2737.04 N 43.39 E 0.38 3057.:38 N 2785.07 N 43.30 E 0.26 3108.50 N 2833.33 N 43.39 E 0.26 3159.84 N 2881.79 N 43.30 E 0.27 3211.41 N 2930.48 N 43. 19 E 0.55 3262.94 N 2978.95 N 43.39 E 0.64 3313.90 N 3026.96 N 44. 0 E 1.08 3363.78 N 3074.63 N 44.80 E 1.44 3412.01 N 3121.85 N 46.50 E 2.5:3 3457.55 N 3168.41 N 48.50 E 1.99 34'.:.)9. 83 N 3214.52 N 52.19 E 4.44 3537.40 N 3259.72 N 53.80 E 1.65 3570.53 N 3303.65 N 55.80 E 2.13 3600.88 N 3346.64 N 58.50 E 1.41 3628.56 N 3389.50 N 57.30 E 2.36 3656.47 N 3433.'?~5 N 57.60 E 0. 'PS 3/--.85.98 N 3480.19 N 57.60 E 0.09 3695.21 N :349'4.7:3 E 3:357.41 E :2:'~'26.56 E :2:,.::-.,...:, 5.7:3 E 40,65.1 O, E 41 '~ · _ ._,. 00 _ 4.- 0._. 30 _ 4 ..' 7._,. 9 O, E 4:2:46,. 82 E 4417.56 : 4487. ~':' _ 4._,-_,6.57 E 4624.06 _ 4c,,:,.. · 14 E 4751.54 - ,.-, -),~ ,2, ..:,' 4,:,~ .. · """- E 4864. 15I' E 4915.7.5~ E 4.-,'6._ :30 E .~C, 16. 1 '"" E ._,06 :;..'_--:4 E ~C '-" · J .),:, ¢,. C) 3 ~' ""-' /..., ,., .:. :, . ex=: FEET AT NORTH 43 DEG. 24 MIN. EAST AT MD = lO:::/-.6... THE CALCULATIC, N F-I:.,,UL. ED..RE.:, ARE BA.:,ED ON THE I_I.:,E OF THREE DIMENSIONAL RADILi:2; OF C:URVATI_IRE METHOD ARCO ALASKA, WELL 4-26 PRUDHOE BAY ALASKA I NC. SF'ERRY-::;UN WELL SURVEYING COMPANY ANCHFIRAGE ALASKA COMPUTATION DATE MAY '-"-' -'..', 1986 PAGE 5 DATE OF SURVEY MAY 21, 1':'.~::-:6 dOB NUMBER AK-BO-60029 KELLY BUSHING ELEV. = 65.00 FT. OPERATOR-D. HARGER INYERPOLATED VALUE'.--; FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE MEASURED VERT I C:AL DEF'TH DEPTH SLIB-SEA TOTAL VERT I CAL RECTANGULAR COORD I NATES: MD-TVB DEPTH NORTH / SOLITH EAST/WEST D I FFERENCE VERT I CAL CORRECT 0 ,ri,. ,[z~ 0 - 65. ,[], 0 0. ¢~,0 0. O, 0 0. ('i, 0 1000 '.-.-*'.-7,'F¢. 74 'F'34.74 1:3.22 S; 17.2::: W 0, 26 200 .... 0 1 ':.) 9,:.) . (:, :3 19:34 ./-_, ..,":' 16.t.'; c.,'-' ':',., :30 . .... ":' '":.',:. W 0.37 :":: 000 2.9 ?,' 6. ~:; ':' ,_. '- ..... , 2931.55 14.09 N . '.-' 09 W ~.45 4000 :':: 91 .~] 4 :=: ::: :=:.~ o 48 274.65 N 262 '~ ,.4 E 84. ~'-' · --. m .... # · F,(') 00 464:3 '-' ') ='-"-' 699 67 E :3 ~ 1 7 (') .... · :, (_ 4._,,_-, o. 30 79:3.67 N . . 60 (') ([) ~ ..,.-~ "" .... "%'?. 74 ...~i .._~_":' ~ "'.'. 74 1 .... '~ ~,4. ._,'--'/s, N11F,:-: .' - 16 E ¢,/_- .' ~'-' . ~._,'-.'/- 7000 6016.07 5951.07 1900. 19 N 1/:,49.6.5 E '.-.-~8:3.9:3 '-" ¢ ' ~ ""-' /-,ASO. ?,:R '.--'404 11 N '-" 1F,.-=, 90 E 12:~4 /-2 ,:, 0 .~ 0 671 ,..,.._-, c ........... . ...... ,-o-- -~.~].-., o,-,,- .... ,,-,,-,,--, /. ,-, .-,/..-,~ ,.-,/. ~ o o o ..._ .:,. 71 7 ..,,:, ,:,. 71 .-: ,:,,:,,-~. :,-' N ~: :, ..'.-,. c, :. E 1546 .29. 10000 ::: .... 169.26 ::: 104.26 :3:395.46 N .:: 1 0._. 42" ~ E 1°'''''',_, .:,,.,. 74 ':":' '- '::P, '-'/' ':~: '-'-' 1 N E '- '-' 10SA/-, .... ~ .... 7 :.~ .0/_-, ,_. 14 .06 .:, ~,; ..,. ~ :3494 .7'3.. 1 -7c, 6 .94 O. 26 0.11 3.08 81.07 267.1'8 :310.56 321.67 300. '70 261.67 284· 45 156.20 THE RAL. F:UI_ATIF~N F RUL. EDJRE.:. ARE BASED F~N THE I",,:."., ~"'~ <7;7, :; ,";; !' ,,. ~! · . LI:S;E F~F THREE DIMENSIONAL RADIUS OF CI.IRVATURE METHOD. ARCO ALASKA: WELL 4-26 PRUDHOE BAY ALASKA MEASURED DEPTH 65 165 2/:_,5 365 465 565 /_-,65 765 865 965 :1.065 1165 1265 1365 1465 1565 1/_-,65 176,5 I NC. :E:PERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMF'UTATION DATE MAY '-"-' . o:- ~"." , 1 '~"-'/' DATE OF '.:;URVEY MAY 21, ,_lOB NUMBER AK-BO-60029 KELLY BUSHING ELEV. = OPERATOR-D. HARGER · . . INTERPOLATED VALLE.:, FOR EVEN 1F)O FEET OF SUB-'.:;EA DEPTH TRUE VERT I CAL DEPTH c-II c- .... B-,.,EA TOTAL VERT I CAL RECTANGULAR COORD I NATES MD-TVD DEF'TH NORTH/SOUTH EAST/WEST DIFFERENCE VERT I CAL C:ORRECT I ON 0.00 /-,5.00 165.00 265.00 36,5.00 465.00 565.00 /.,65.00 765.00 865.00 965.00 1065.00 1165.00 1265.00 i"'A =' . 00 4 .....00 1565.00 1665.00 176,5.00 -65. (:)(') 0.0C) 0.00 ('), 0(') 0.00 0.04. S 0.07 W 0.00 10(-). 00 1.40 '.:-; '-..-'. 07 W 0.0:3 200.0(') 2.83 S 4.15 W 0.06, :--: 00. (') 0 4 .37 ._,':' 6.30 W 0 .10 40(:~.00 5.81 S 8.43 W 0.1:3 500.00 '7.41 S 10. :'-:7 W 0.16. 600.00 8.89 S 12.15 W 0.19 7 c~. 0,00 10 .2 ::::.. S 1 .:,'-'. 79 W 0 .21 :::oo.00 11 61 ::, 1 ~ 34 ..... -' ~,. W 0 '-"-' · ~.'. 900. (')0 1 ,,~'". 84 S 16 .,_,~..,..v~ W 0 . .-'-' .., ~' 1 (')00.00 13. b.: 1 S 18. ') ~' ' C.., W 0.27 1100.00 14.81 S 19..48 W O.%"L-,-' 1200.00 1 .~ '" :36, '~' .... :, ~ 1. O:B W ¢'). 30 1:300.00 16 .64 S .:~.'"'". 70 W 0.._-L~" ':' 14 00 0 0 16,:,"'~:'-' ':' ~'-' 4 ':":' ~.~;, W 0 ":'"' 17l(')(')_... 00 16,. :3:3 S ~.._.':'fi 54 W O. 34 1600.00 16,. 94 S 26,. 64 W ("). :34 1 '700 ..... 00 16 '-:.):'::._,':' 27 . zl'-' W 0 .34 O. 00 0.0:3 0.03 0.0:':: 0.0:3 0.03 0.03 0.02 0.02 0.02 0. O1 0.02 0.02 0.02 0.01 0.01 0.01 0.00 F'AGE 6 1986 65.00 FT. ARCO ALASKA, WELL 4-26 PRUDHOE BAY ALASKA MEA'.:;URED DEPTH 1 'F~65 2065 2165 .-., .-:,/_ · ' d~. -' .-- 2465 · ",'= z. ~ '26,65 · ':,'FA ~ 286,6 3069 :2:172 "":~ '3 '7 ~ .-,:-::,-,.-) .:,'-'705 .. , : :. [7:? ~,_., , I NC:. SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE MAY 22, '1986 PAGE 7 DATE OF SURVEY MAY 21, lt-.786 JOB NUMBER AI<-BO-6,00-~z~ .............. KELLY BUSHING ELEV. = 65.0C) FT. OF'ERATOR-D. HARGER INTERPOLATED VAL. LIE:--: FOR EVEN 100 FEE]' OF SUB-SEA DEF'TH TRUE VERT I F:AL DEF'TH SUB-SEA TOTAL VERT I CAL RECTANGULAR COORD I NATES MD-TVD DEPTH NORTH/:_~OLITH EAST/WEST D I FFERENCE VERT I CAL CORRECT I ON 1800.00 17.08 S 28.01 W 1900.00 16.38 S 29.67 W 2000.00 15:52 S 31.60 W 2100· 00 14.82 S 33.41 W 2200.00 13.30 S 34. '.~5 W 2300.00 11.63 S 36..17 W 2400.00 10.16 S :3 '7.26 W 2500.00 8.50 'S :38.14 W 26(:)0.00 6. :34 S :38.41 W 2700.00 2.89 S :32.40 W 2800.00 2.58 N 21.04 W 2900.00 11.04 N 6.79'W 3000.00 21.42 N 8.63 E :310 C). 00 34.2 9 N 27. =; = 3200.00 52.21 N ' -48.28 'E 3300.00 73.65 N 70.94 E 3400.00 97.67 N 96.77 E 3500,00 127.15 N 124.59'E 3600,00 162.52 N 156.'~2 E 0·35 0.37 0.39 0·41 0.43 0.45 O. 4'7 O. 49 O. 52 0.78 1.58 2.96 4.67 7.27 10. 'P7 15, 72 21.77 29.68 40.60 0.00 0.02 0.02 0. (:)2 0. (:)2 0.02 0. (')l.-..' 0.L..-')'-' 0'. 03 0.27 · ,~(.) "' 1'. 37' 1.72 2.60 · ~. 7<:) 4.75 6.05 7'."F/2 · 10.91 ARCO ALASKA WELL 4-26 PRUDHOE BAY ALASKA MEASURED DEPTH :3820 · =, ,.-~ .=o ,_1 ..._1 I__I 4061 4187 4321 4460 4599 4740 4881 5024 5168 5313 5459 5603 5747 5893 6040 6189 633'7 INC. :s;PERRY-F;UN WELL SURVEYING F:OMPANY ANCHORAF~E ALASKA C:OMF'UTATIr~N EEATE MAY '-"-' . _ _ · .'~-, 19:=:/-. PAGE 8 DATE OF SURVEY MAY 21, 1986 dOB NUMBER AK-BO-60029 KELLY BUSHIN6 ELEV. = 65.00 FT. OPERATOR-D. HARGER ' INTERPOLATED VAI_UES FOR EVEN 100 FEET OF '.=;UB-SEA DEF'TH TRUE VERT I CAL DEF'TH SUB-SEA TOTAL VERT I CAL REC:TANGULAR C:OORD I NATES MD-TVD DEPTH NORTH/SOUTH EAF;T/WEST D I FFERENC:E VERT I CAL CORRECT I F~N ._ 7o._,. 3865. 3965. 4065. 4165. 4265. 4365. 4465. 4565. 4665. 4765. 4865. 4965. 5065. 5365. 5465. 5565. C) 0 00 00 00 00 00 00 00 00 00 00 O0 O0 00 O0 00 O0 00 00 3700.00 203.17 N 195.93 E 55.41 ::: ::: c) C) . 00 249. :35 N 2:_9.9.47 E 7::-:. 88 3900.00 301.E;2 N 286.87 E 96.29 4000.00 360.00 N 337.18 E 122.56 4100.00 428.10 N 394.38 E 156.42 4200.00 502.44 N 455.66 E 195.28 4300.00 577.66 N 517.61 E 234.91 4400.00 653.05 N 581.00 E 275.28 4500.00 729.11 N 645. :35 E 316.43 4600.00 807.03 N 710.84 E 359.12 4700.00 887.18 N 777.58 E 403.62 4800.00 968.62 N 844.64 E 448.98 4900.00 1050.64 N 910.95 E 494.32 5000.00 1131.64 N 976.23 E 536:. 62 5100.00 1212.60 N 1040.83 E' 582.60 5200.00 1294.50 N 1107.65 E 628.11 5300.00 1377.24 N 1177.36 E 675.43 5400.00 1461.85 N 1248,'26 E 724.39 5500.00 1544.92 N 1320.14 E 772.94 14.81 18.46 22.42 26.27 33.86 38.86 :39.63 40.37 41.16 42.69 44.50 4.5 :::6 45.34 44.30 43.97 45.51 47.33 48.95 48.55 ARCO ALASKA, WELL 4-26 PRUDHOE BAY ALASKA MEASURED DEPTH 66,.:,._ 677R ~ '.;' ":, Z]. 7(-.)72 721 7364 75(I) 9 765:'-: 7794 7'=/'~ 1 :9067 m--m ."m ') 0.,~ (..-" ,.-., .j, ..q ._ :96,(')4 ,_ 740 :E:877 9015 .... -C.' · · ~ "~ .., .... I NC:. SF'ERRY-SUN WELL SURVEYING COMF'ANY ANCHORAGE ALASKA COMF'UTATION DATE MAY .... ~ 1986 PAGE DATE OF SURVEY MAY 21, 1986 dOB NUMBER AK-B026002'9 ........... KELLY BUSHING ELEV. = 65.0(]) FT. OF'ERATOR-D. HARGER I NTERF'CmLATED VALUES FCIR EVEN 1C)0 FEET OF SUB-SEA DEF'TH TRUE VERT I CAL DEF'TH SUB-SEA TOTAL VERT I CAL RECTANGULAR COORD I NATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERT I CAL CORRECT I ON ._, r-, ::,._,. (') 0 5765.00 '"F Fl 00 ,.~., '...", ._ . 5965.00 6065.00 ./_-, 1/- ?] (]0 /.--,/. ~ :.'~ -.' ::,.-,. 0 6:365.00 64A5.00 6565.00 66 :-,._, 0 CD 67 ....,. 00 ~-:, ..-',._~. (')0 6?65, 0C) 7065, (")0 71,:. ~ 00 ".'/- H (")C) 7..:, 6._ 0 (") 748 .... C) 0 S.: '.S~ · ,::., ~ 5600.00 1625.57 N 5700.00 1705.88 N 5800.00 1783.12 N 5'F/00.00 1860.37 N 6C)0C). 00 1938.1 '.-? N 6100.00 2014.21 N 6200.00 2090.01 N ,'.:,.:, (.)(.. C) 0 216:3 . ..-~.'-"-' N 6400. O0 22:34.86 N 6500. O0 2:'-:04.80 N 6600.00 2371.11 N 6700.00 2436.37 N 6:F:00. O0 2500.47 N 6'.-700.00 2563.88 N 7000.00 2627.63 N 7100.00 26'.-72.74 N 7200.00 275'.-?. 15 N 7 :_'-:C) 0.00 :2 8 2 7.18 N 74C)(:). 00 28'26.48 N 1._.':"--~.. ~.':'. 61 E 820.4 ._ 14/-,.~. 76 E '-'/- '-' __ o:,c,. 10 15:37.77 E 'FY 1:3.,.,='-._.~ 1611.42 E '25'2.80 168/-, '" . _..-,8, E 1007 01 17 61.01 E: I .).:, o. 1:3 1 ,:,.-, 7, 26, E 109'2. ':? 7 1912.25 E 1144. I ':'/''' ~ 0.-, .~ o._, .... z E 1188.1 2(')5/~, 47 E 1'~~2''~. .... ~. , 17 21 '.'"'": 01 E 1 '-"/' , '~: .-:, ~. 1,:,'-'"',:,. C)4 E 1302 ~-'._ I 97 E 1:1.:::37 '"~' 2314.1:~:_ E 137(.'), '-'" '-"~:~/- 06 E 1404 77 2438.73 E 143'2. 2.5(-.)2, :24 E 1475, 36 2566' 72 'E 151'2,43 · 'l i ---I,--.i .'m ~ · .'¢,o~...~~u, E ! 55¢]~.. 66 47.51 47./-5 ~ 43 46.27 47.21 46.1'-',. 48,. 84 44.86 43, '"'-' ._'i ._-, 41. (')2 :37.20 · .:,._,. 97 33.7:3 3:.":. :34.79 35.81 37.'07 ARCO ALASKA, WELL 4-26 PRUDHOE BAY ALASKA I NC. SF'ERRY-SUN WELL F;URVEYING COMPANY ANCHORAGE ALA:=;KA COMPUTATION DATE MAY 22, 1.96:6. DATE OF :=-;URVEY MAY 21, ,_lOB NUMBER AK-BO-60029 KELLY BUSHING EL_EV. = OF'ERATOR-D. HARGER ,.. INTERPOLATED VAI_UES FOR EVEN 10C) FEET OF '.=;UB-F;EA DEPTH TRUE SUB-SEA Tr~TAL MEASURED VERT I CAL VERT I CAL RECTANGULAR COORD I NATE:=; MD-TVD DEPTH DEPTH DEPTH NORTH/F;OUTH EAST/WEST DIFFERENCE VERT I CAL CORRECT I ON 915 4 7 ~/- 5 ('} (1) 7 5 (3 (') 0 0 ~ .. 6,._, '-' = _ ... --, .- .-,,.~ ~ .-, z ,:~ ......... ~._, N ~,_-;o.41 E 1589. 14 ':~'~":~':'.. ~ ..._, 7 _,6._, .00 7600.00 3036 .17 N 476 .... 01 E 1628. ~,':'5._ 943:3 776 ._,. 00 7700.00 :3107 .9. 1 N ~oo~':'""-":'. 77 E 1668.86 9~7~]. _ _ '~'-'~o :,._,:'. 00 7800.00 '.31o~.)'-' '. 49 N 2901. :31 E 1710 .15 9716 7';/-,Fi r)O 7900 00 '""'5'-' 68 N 2970 '-'~ ......... :,~._ .~. . ~._ E 1751.96 ':~:::~7 ~:('~/-,~ 00 8000.00 '-"-"-': ')'-' '-' ]'-' . .......... c,.:,~._,, c c, N ¢,c .:,7.49 E 1792 00 9 9 9 4 :31 o._ 0 0 ':' 1 C)C) C) 0 '-"-"~ '~' 7 2 ':' · :,.:, .. ~. N 10 2.71 E 1 ,=z'-"-"-y '-'~ 012 6 '""-' Pi ':' 4 ~ 4 (')::: N ~._, oz6._. ¢')0. 8200 .00 ._,_._ _. 3164 .6'P E 1861 . '- ~' (') 2 Fl 4 :~ ::: A ~. 00 83 (') 0 00 '-' 5 '~ 322:3 .... ........... :,._~ 7.79 N ,65 E 1~:5W, 91 0377 .:,'-' e ~ o' ._5.00 '-'o 4 O' c'~ . 00 .:~'-' ~, ~ ~._, 1 . :~_.9 N :3278 . ¢,~'"" E 191. ~.'~' 17 C~495 ""~ ~ o._, 6 ._, 00 '-' ~ '3 p "" ~'-''; 5" '-' '-' '-',3 ,:,..,,.., 00 ._,;~ N 04 E 19:~0.87 . _ .~, .~,.~,~. 061 '~' o ~ ~ ~ .-, .-,.-, ~.-, ~ .... o c .... 00 :~:_ A_ ~'). ~3.. 00 .=, 6 ~ ~. ~.,.=, N ~'~: :~:_ _~ 9. .66 E 1 '~ 47.27 0729 ,:, 76._ 00 8700 00 ::: A 54.84 N :34:31 41 E 1 '~/-, 4.44 ..o~; ,:,,:, 6._. () 0 8800.00 :=:/-, 9 ("). 17 N 3486.80 E 1 ':~; o4'". O'F~ ('):=:/~,A '"'" ":* - - ' ..... :,,:, 7;. 06 ::::~ 14 .06 ._':: 69. 5._ 21 N :3494 .73 E 1 '~.. ,_'R o'. '? ~ 38.48 39.21 40.50 41.30 41.81 40.04 37.25 32.70 27.96 22.26 18.70 16.40 17.16 19.66 2.85 THE CALCUL. ATION F'ROCEDLIRES LISE A LINEAR IN'I'ERPOLATION BETWEEN THE NEAREST 20 FOOl' MD (FROM RAJ IL._~ OF RURVATURE)F'-UINT.:,": PAGE 10 1 'P:=:/:, ,_ 65.00 FT. ARCO ALASKA, INR. WELL 4-2/-. PRUDHOE BAY ALASKA SPERRY-SUN WELL SURVEYING COMPANY ANCHORAGE ALASKA COMPUTATION DATE MAY 22, 1786 INTERPOLATED VALUES FOR SPECIAL SURVEY POINTS PAGE 11 DATE OF SURVEY MAY 21, 1786 dOB NUMBER 'A~:]-BO'60(~i2.~ KELLY BUSHING ELEV. = 65.()0 FT. OPERATOR-D. HARGER MEASURED DEPTH TRUE VERTICAL DEPTH SUB-SEA VERTICAL DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MARKER 10545 10560 10598 106?2 10756 10820 10835 10866 8607. 16 8620.04 8652.71 8733.53 87:E:7. 33 8:.,:40. 81 8853. 2:-': 887'.:). ¢)6 ,:,-_ 4.-'. 16 8555. 04 8587. 71 8668. 53 8722. 33 :E:775. F': 1 8788. :2::: 8814.06 3603.77 N 3608. O? N 3618.74 N 3643.88 N 3662.61 N 3681.52 N 3685. '~8 N :'::6?5.21 N :335('). 88 E · --i --i r-- ,_",.: .... 7.24 E 3373.47 E 3414.35 E 3443.52 E 3473.16 E 348£). 1':.-~ E 34?4.7:} E TOP SADLEROCHI]' GAS/OIL CONTACT GAS/OIL CONTACT TOP ZONE lB BASE SADLEROCHIT PLUGBACK TD '.SURVEY DEPTH TOTAL DEPTH DRI[..[..ER ARCCI ALA'.:;KA, INC:. WELL 4-26 '.:;TRAT I GRAPH I C ::;UMMARY DERIVED U'._:;INC~ DIL DEPTHS AND SPERRY SUN SURVEY DATA MARKER ........ MEA'.-';URED DEF'TH TVD TH I CI<NE'._=;:=; BKB BKB SUB-SEA VERT I CAL TOP SADLEROCHIT GA L=: / 01 L ~z: 0 N T A C T G A :=; / ri I L C~;~N T A C T TOP ZONE lB BASE SADLEROCHIT PLUGBACK ]"D 1(')545 :--:/-,07 16 '"= .. .... =,._,4'--.' 16 10560 8620.04 8555.04 105'....-¢8 8652.71 8587.71 106'F, 2 8733.53 8668.5:3 10756 8787.33 8722.33 10820 8840.81 8775.81 :::879.06 8814.06 TOTAL DEPTH DRILLER 1 "-' COORB I NATES WITH RE-F. TO-'WELLHEAD (ORIGIN- .91FSL 429FWL) SEC 26 T11N R15E 3603.77N 3608.0~N 3618.74N 3643.88N 3662.61N 3681.52N 36~5.21N 3350. :_--::_RE '-"-'F, --' 24~ · ..,'~ .,.:~ ._ / 337:':;. 47E :2:41 4.35E :}44:3.52E 3473.16E 34'~4.73E '1 ) FROM L I NEAR EXTRAF'OLAT I ON' BELOW DEEF'EST,r4._ TAT I UN' . .~:'-' ) r'-_.UMF'U~'ER" PRnRRAM_ _ - SF'ERRY '.=,UN ..... THREE D I MEN~S; I I]NAL RAJ' ~ I U.S OF L.'"IJRVA]' 'LIRE" . I- " ...... ' "' -I "" I DATA _:~i~I_:I_IL.A I"IuN AN[, INTERFC. LATION BY RA[ IUS I"'IF CI_IRVATURE ~.. COMF'UTATION BATE MAY ...."-' · .:...'., 1 '.".":"86 " " ..-",=, 6 DATE OF ~LIRVEY MAY 21, 1"-'-' .JOB NJMBER AI.::'-BFi-/-,,r)(')'::"::, I<ELL. Y BU'.:;HING ELEV. = 65.0(:) FT. 5CgLE :- ~ !bCh TO ICO0. CO / iOOO. O qK-OO-OOG29 TRUE NORTH I -tO00. O0 -3000. C0 -2ooo. co ~.~ ~OCC. CO 2CCC. 22 6CCO. C~ 10866 0.00 5CRLE ; - t INCH T0 2000.00 / 2000.0 PRUOHOE sql qRCO RLRSKR. 1NC. AEt. L 4-26 HRY 21, ~986 qK-~80-60029 2000. C0 4C00. C0 6COC. CO 8000.00 .CCC0. CSt I 2.'33 C. o,~ I 400°~.. CC VER'i ;C:flL PROJEC-[ .'ION I ~CC3. CC RECEIVED AUG 2 6 !.,8o ........ s Cons. 6ommissb~ Ancb. crsoa STATE OF ALASKA ALA&~..~ OIL AND GAS CONSERVATION COM>,~-~SION APPLICATION FOR SUNDRY APPROVALS 1. Type of Request: Abandon [] Suspend ,~ Operation Shutdown [] Re-enter suspended well [] Alter casing [] Time extension ~,, Change approved program [] Plugging [] Stimulate [] Pull tubing ~ Amend order ~ Perforate ~ Other [] 2. Name of Operator ARCO Alaska, Inc, 3. Address Post Office Box 100360, Anchorage, AK 99510 4. Location of well at surface 91' FSL, 429' FWL, Sec. 26, T11N, R15E, UN At top of productive interval 1585' FNL, 1500' FEL, Sec. 26, T11N, R15E, UM At effective depth 1507' FNL, 1378' FEL, Sec. 26, T11N, R15E, UM At total depth 1494' FNL, 1356' FEL, Sec. 26, T11N, R15E, UM 5. Datum elevation (DF or KB) 65' RKB feet 6. Unit or Property name Prudhoe Bay Unit 7. Well number DS 4-26 8. Permit nu8r~b_~r1 4 9. APl number 50-- 029-21520 10. Pool Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured Effective depth: Casing Conductor Surface Production Liner Perforation depth: true vertical measured true vertical Length 80' 2462' 10492' 561' measured true vertical NONE NONE 10866 feet 8879 feet 10820 feet 8841 feet Size Plugs (measured) Junk (measured) Cemented Measured depth 20" 1700# Poleset 13-3/8" 2500 sx AS 111 & 400 sx AS 11 9-5/8" 500 sx Class G 7" 300 sx Class G ~bing(size, grade and measured depth) 5½", L-80, tbg w/tail @ 10325'MD Packers and SSSV(type and measured depth) 3H pkr @ 10236', BAL-O SSSV @ 2227' True Vertical depth 114' 114' 2497' 2497' 10522' 8588' 10304-10865' 8405-8878' 12.Attachments Description summary of proposal J~ Detailed operations program [] BOP sketch 13. Estimated date for commencing operation June 1, 1987 14. If proposal was verbally approved Name of approver Date approved 15. I hereby c~rtify that t,~e fo~rego],ing is true and correct to the best of my knowledge Signed ,,~//¢-'/~¢.~//,~/~_~ Title Operations EngineeringManager Date Commission Use Only Conditions of approval Notify commission so representative may witness [] Plug integrity [] BOP Test ~ Location clearance Approved by -Commissioner Approval No...~ .- S-~--3 by order of the commission Date,~'-~,~ '~ -"2 -~ Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Alaska, Inc. proposes to perforate DS 4-26 at a selected interval within the Sadlerochit Sand of Prudhoe Bay Unit. Upon perforating, the well will be flowed for clean-up. All wireline work will be done through a 5000 psi WP BOP/Lubricator, tested to 1.2 times the maximum expected surface pressure. The surface-controlled SSSV will be installed at the conclusion of the perforating and clean-up operation. Ref' BHCS log 3/8/86 Proposed Perforation Interval' 10700' - 10750'MD ARCO ALasl<m, lno. Ancho)"mge, A[mzka ~75i0 I)AI'E: June 2~, t~87 REFERENCE: ARCO Cased HoLe Final 2-i6 6-7-87 Co[Jar & F'erf.. Run t, 5" :',¢1~6' 6-8-87 Co[Jar & F'erf, Run 1, 5" i'7--3 6-i2---87 CoL tar & F'erf. Run t, 5' i7-it 6-i6-87 Lea~ Def. Temp. Survey ~ear Gear Gear Otis F'[e'..; .. sign and return the attached copy as receip$ of data, Received By HAVE A NICIF DAY! Rosanne Peek Al'O-tSO9., Approved Anchorage D I S T R I B tJ'r I 0 N -~ F'hi t L i ps F'B Wel[ Fi les R & I) -~'" Sohio '.- .State of Alaska ~'m' Texaco STATE OF ALASKA ALA[. ., OIL AND GAS CONSERVATION coM'~,,;SSlON REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Alter Casing [] Other ~ 2. Name of Operator 5. ARCO Alaskat Inc. Operation shutdown [] Stimulate [] Plugging [] Perforate ~ Pull tubing [] 3. Address P.O. Box 100360 Anchorage, AK 99510 Datum elevation (DF or KB) RKB 65 ' 4. Location of well at surface 91'FSL~ 429'FWL, Sec.2G, T11N, R15E, UN At top of productive interval 1585' FNL, 1500' FEL, Sec.26, TllN, R15E, UM At effective depth 1507' FNL, 12,78' FEL, Seco26, T11N, R15E¢ UN At total depth 1494' FNL, 1356' FEL, Sec. 26, T11N, R15E, UM 6. Unit or Property name Prudhoe Bay Unit 7. Well number ~-26 8. Approval number 67 9. APl. number 50-- 029-21520 10. Pool Prudhoe Bay 0il Pool Feet 11. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 80' Surface 2462' 10866'MD 8879'TVD 10820 'MD 8841 'TVD Size 20" 13-3/8" Producti on 10492 ' 9-5/8" Liner 561 ' 7" feet feet feet feet Plugs (measured) None Junk(measured) None Cemented Measured depth True Vertical depth 1700# Pol eset 114'MD 114'TVD 2500 sx AS I I I & 2497 'MD 2497'TVD 400 sx AS Il 500 sx Cl ass G' 10522'MD 8588'TVD 300 sx Class G 10304 '-10865 'MD 8405 '-8878 'TVD Perforation depth: measured None true vertical None Tubing (size, grade and measured depth) 5-1/2", L-80, tbg w/tail (~ 10,325' Packers and SSSV (type and measured depth) 3H pkr @ 10,236', BAL-O SSSV @ 2227' RECEIVED .AUG 2 -¢,. ~aska Oil & Gas Cons. Commission ,Anchorage 12. Stimulation or cement squeeze summary /A Inl~ervals treated (measured) Treatment description including volumes used and final pressure 13. N/A Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure 14. Attachments (Completion Well History w/Addendum, dated 8/06/86) Daily Report of Well Operations ,~. Copies of Logs and Surveys Run ~ 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Form 10-404 Rev. 12-1-85 (DAM) SW0/090 Date Submit in Duplicate ARCO Oil and Gas Company Daily Well History-Final Report Instructions: Prepare and submit the "Final Report" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submilted also when operations are suspended for an indefinite or appreciable length of time. On workovers when an official test is not required upon complelion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation it space is available. District Alaska Accounting cost center code North Slope Borough I County or Parish Alaska Field ILease or Unit JWoII no. Prudhoe Bay ADL #28324 I 4-26 Auth. or W.O. no. ~Title AFE 804011 I Completion State Pool 102 Operator ARCO Alaska, Inc. Spudded or W.O. begun AP1 #50-029-21520 Complete Date and depth as of 8:00 a.m. 8/07/86 8/08/86 IA.R.Co. W.I. 21.66% JDate 8/06/86 Old TD Released rig Complete record for each day reported Iotal number of wells (active or inactive) on this Dst center prior to plugging and I bandonment of this well our - I Prior status if a W.O. I 0930 Hrs. 7" f/10,304'-10,865' 10,820' PBTD, RIH w/5½" CA 9.4 ppg NaC1 ~ccept rig @ 0930 hfs, 8/6/86. ND tree, NU & tst BOPE. RU DA, RIH w/gage ring/JB to 10,810' WLM, POOH. RIH w/8.42" gage ring/JB to 10,284' WLM, POOH, RD WL unit. RU & RIH w/5½" CA. 7" f/10,304'-10,865' 10,820' PBTD, Press tst tbg Diesel in tbg & ann/9.4 ppg NaC1 in 7-" lnr Rn 248 its, 5½", 17#, L-80 8RD AB Mod tbg & 2 its, 4½", 12.6#, L-80 BTC tbg. Displ well to diesel. Press tst tbg. Set BPV. ND BOPE, NU & tst tree. Pmp 50 bbls diesel f/freeze protection. RR @ 1600 hfs, 8/8/86. (Bal-O-Nipple @ 2227', 3H Pkr @ 10,236', XN Nipple @ 10,312' Tailpipe @ 10,325') IDate RECEIVED New TD PB Depth 10,820' Kind of rig . 1600 Hrs. 8/8/86 Rotary Classifications (oil, gas, elc.) Type completion (single, dual, etc.) Oil Single Producing method Official reservoir name(s) Flowing Sadlerochit Potential test data Well no. Date Rese~oir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR Gravity Allowable Effective date corrected . The above is correcl For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 87. Drilling Supervisor ADDENDUM WELL: 5/21186 8/05/86 4-26 RU Gearhart, rn CBL/CCL/GR f/10,818'-10,300' w/1000 psi & 0 psi. RD Gearhart. RU Sperry Sun, rn gyro f/surf-10,818', RD sperry Sun. Att to Arctic Pak well by pmp'g 2 BPM, 1500 psi. Press inc'd to 4000 psi & fell instantly to 800 psi. Pmp 105 bbls crude into well. Wait on W/O rig. RECE!"¥ D Drilling Supervisor Date Telecopy No. (907) 276-7542 August 11, 1987 ADMINISTRATIVE APPROVAL NO. 213.10 Re: Waivers to Rule lla of Conservation Order No. 165 for Prudhoe Bay Unit w. ell DS 4-26. D. F. Scheve Operations Engineering Manager ARCO Alaska, Inc.. P. O. Box 100360 Anchorage, AK 99510-0360 Dear Mr. Scheve: By application dated August 7, 1987, on behalf of ARCO Alaska, Inc., you requested a waiver to Rule lla, Conservation Order No. 165 for Prudhoe Bay Unit well DS 4-26. The well is producing from 20 feet or less of perforations, and all perforations are in zone lB. Since all flow would necessarily enter from this zone, a productivity profile as required by Rule lla of Conservation Order No. 165 is not needed until additional zones may be perforated. :. Therefore, under authority of Rule 2 of Conservation Order No. 213 the Commission hereby waives the requirement of Rule lla of Conservation Order No. 165 for Prudhoe Bay Unit well DS 4-26. Lonnie C. Smith Commissioner BY ORDER OF THE COMMISSION jo/3 .AA213 ARCO A£aska, I~c F',.O, Box t Ar~chorage, Ai.a.~ka 99ff;t DATE' JuLy 6, i987 REFERENCE' ARCO F're~sure Data 4-26 6-t4-.87 Static Gradient F'Lea~-e sign a~d return the at'tached copy @s receip'~ of data, HAVF-- A NICE DAY' ~]~~~".o Rora~e Peek~ / ' ~ I'RANZ¢ ~:87~45 ~ gl:~ :'" T' OV E'd ................ DISTRIBUTION Cetera-al Fi Les -~ F'hi [LiF, s Chevro~ F'B Wet [ Fi [es' · "' D & H ~ -.- ~ R & D Exte~io~ Exploratio~ .'.~.Sohio · ..~' Exxo~ ~- State of ALazka Hara t'hon ~ Texaco -.-~' Hob i [ ARCO A Anchormge, ALaska 995~ I)ATE: June 25, ~987 REFERENCE: ARCO Cesed Hole Final 2-~6 6-7-87 CoLLar & F'erf. Run 4-2.6 .6-8-87 ColLmr & F'erf. Run t'7--~ &-~2-..87 CoL Lar & Perf, R~n t, 5" t7-tt 6-t 6-87 Leak De'~. Temp. Survey Ge~ O~i~ F:'Le.;.... ~ign and rekurn ~he atSached copy as receipt of HAVE A NICE: DAY! o ]98? Ro~anne Peek A T 0-- t 5 2 9 L...-" Alaska 011 & Gas Cons. Commission An~ora~ Approved ............................................... D I ~"TR I BUT I ON ARCO ALaska, Inc. F'.O. Box iO036e Anchorage, ALaska DATE: June 2 7,i98& REFERENCE: ARCO Cased HoLe Final ~2-4 6-t -86 Spinner Survey Run I 5' ~'~=3-5 6-t4-86 GE Spinner log Run t 5' -9 6-t 9-86 Spinner log Run t 5" -~9 6-~5-86 GR/Spinner Log Run t 5" ~3-2i 6-i 8-86 GR/Sp inner log gun i 5' ~-25 5-2e-e6 Cement bond log Run t 5' ~-26 5-2i-86 Cement bond Log Run i 5' ~8-8 5-6-86 Cemnet bond tog Run ~ 5' Otis Camco Camco Camco Camco Gearnart Gearhart Gearharf PLease sign and return th.e~a~ached copy as receipt of data. Received By ...... ~~~ HAVE A NICE ;~i:-~i~' Linda Hu[ce AT0-t529 TRAN$ ~86483 DISTRIBUTION Central Fi Les Chevron Extension Exp [orat ion Ex xon Harm then Hob i [ Phi LLips F'B Well Fi Les R& D $oh i o State of ALaska Texaco STATE OF ALASKA ALASK;,--,~.)IL AND GAS CONSERVATION COMM~.,..~iON APPLICATION FOR SUNDRY APPROVALS 1. Type of Request,,: Abandon ~ Suspend ~ Operation Shutdown ~ Re-enter suspended well ~ Alter casing ~ Time extension [] Change approved program ~ Plugging [] Stimulate ~ Pull tubing ~ Amend order .~ Perforate ~ Other 2. Name of Operator 5. Datum elevation (DF or KB) ARCO Alaska, Inc 65' RKB 3. Address 6. Unit or Property name P. O. Box 100360 Anchorage. AK 99";10 Pr'-'dhoe Bay Unit 4. Location of well at surface 7. Well number 92'FSL, 429'FWL, Sec.26, TllN, R15E, UM 4-26 At top of productive interval 8. Permit number 1580'FNL, 1304'FEL, Sec.26, TllN, R15E, UM (approx.) 85-314 At effective depth 9. APl number 1465'FNL, 1335'FEL, Sec.26, T11N~ R15E, UN (approx.) 50-- 029-21520 At total depth 10. Pool 1448'FNL, 1315'FEL, 5ec.26, T11N, R15E, UM (apProx.) Prudhoe Bay Oil Pool feet 11. Present well condition summary Total depth: measured true vertical 1 0,866 feet Plugs (measured) None 8856 feet Effective depth: Casing Conductor Surface measured true vertical Length 80' 2462 ' 10,492 ' 561 ' feet Junk (measured) 10,820 feet N o n e 8818 Production Liner Perforation depth: measured None true vertical None Size Cemented Measured depth 20" 1700# Poleset 114'MD 13-3/8" 2500 sx AS I I I & 2497 'MD 400 sx AS II 9-5/8" 500 sx Class G 10,522'MD 7" 300 sx Class G lO,304'MD- 10,865'MD Tubing (size, grade and measured depth) None Packers and SSSV (type and measured depth) None True Vertical depth 114'TVD 2497 ' TVD 8574'TVD 8395'TVD- 8855'TVD 12.Attachments Description summary of proposal [] Detailed operations program ~ BOP sketch [] Wel 1 Hi story 13. Estimated date for commencing operation October~ 1986 14. If proposal was verbally approved Name of approver Date approved 15. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~ ~ ~ Title Associate Engineer Commission Use Only ( DAM ) SA/020 Conditions of approval Approved by Date Notify commission so representative may witness I Approval No. [] Plug integrity [] BOP Test [] Location clearance ^~o~d Cop,/ ~' w~,,~ ""' ';"""''~ Commissioner the commissionbY order of Date Form 10-403 Rev 12-1-85 Submit in triplicate ARCO Oil and Gas Company Well History- Initial Report - Daily Inslructlone: Prepare and submit the "Initial Report" on the fimt Wednesday aflel' a well is spudded or workover operations are started. Dally work prior to spudding should be summad;ed on the form giving inclusive dates only. District Alaska Field Prudhoe Bay Auth. or W.O. no, AFE 804011 lCounly, parish or borough North Slope Borough ADL #28324 or Unit JTitle Drill IState Alaska Parker #191 AP1 50-029-21520 Operator ARCO Alaska, Inc. SpuddedorW.O. begun IData IHour Spudded 2/19/86 0130 Hrs. ARCO W.I. 21.66% Prior status if a W.O. Oat. and depth as of 8:00 a.m, 2/19/86 2/20/86 2/21/86 2/22/86 thru 2/24/86 2/25/86 Complete record for each day reported 20" @ 114' 605', (491'), Drlg surf hole Wt. 8.5, PV 28, YP 72, PH 9.5, WL 14, Sol 2 Accept rig @ 1800 hfs, 2/18/86. NU diverter sys. 0130 hfs, 2/19/86. Drl 17½~ hole to 605'. Spud well @ 20" @ 114' 1666', (1061'), Fsh'g Wt. 9.1, PV 25, YP 45, PH 8.5, WL 20, Sol 8 Drl surf hole to 1666', rotary torqued up & twisted off DP. TIH w/fsh'g tls. 20" @ 114' 2501', (835'), Rn'g 13-3/8" csg Wt. 9.3, PV 8, YP 29, PH 8.5, WL 20, Sol 9 Fsh @ 413'. TIH, latch on fsh w/tapered spear, TOH w/fsh. 17½" hole to 2501'. RU & begin rn'g 13-3/8" csg. Drl 13-3/8" @ 2497' 4255', (1754'), Drlg Wt. 9.1, PV 5, YP 7, PH 9.5, WL 18, Sol 5 Rn 59 its, 13-3/8", L-80, 72# + 2 its, K-55, 68# csg w/FS @ 2497', FC @ 2413'. Cmt w/2500 sx AS III & 400 sx AS II. Displ using rig pmps. CIP @ 1430 hfs, 2/22/86. ND diverter. NU & tst BOPE. TIH to 2413', DO FC & cmt to 2473', est csg to 2000 psi. Drl cmt + 10' new hole. Conduct formation est to 11.3 ppg EMW. Navi-Drl & surv 12¼" hole to 4255'. 2456', Assumed vertical 2649', 1.8°, N36.2E, 2648.9 TVD, -7.00 VS, 4.4S, 5.50W 2927', 10.0°, N65.2E, 2924.8 TVD, 22.80 VS, 10.2N, 22.00E 3143', 13.8°, N54.2E, 3136.5 TVD, 64.10 VS, 31.9N, 59.00E 3420', 19.4°, N47.2E, 3401.5 TVD, 144.3 VS, 86.1N, 118.3E 3974', 34.5°, N43.2E, 3893.4 TVD, 394.9 VS, 268.5N, 290.1E 4130', 37.9°, N40.2E, 4018.7 TVD, 487.6 VS, 338.4N, 351.4E 13-3/8" @ 2497' 5456', (1201'), Navi-Drl Wt. 9.3, PV 6, YP 9, PH 9.0, WL 20, Sol 6 Navi-Drl & surv to 5456'. 4224' 41 0° N40 2E, 4091.3 TVD, 547.2 VS, 384.0N, 389.9E s · S · 4690', 44.7°, N41.2E, 4425.9 TVD, 870.3 VS, 632.9N, 5138', 46.4°, N39.2E, 4738.7 TVD, 1189.9 VS, 879.1N, 803.2E The above ia correct For form proparatlo~-an~i~'lstributlon, see Procedures Manual, S'ectlon 10, Drilling, Pages 86 and 87. Date 4/04/86 ITM Drilling Superintendent ARCO Oil and Gas Company Daily Well History--Interim Instruction": This form is used during drilling or workover operations. If lesting, coring, or perforating, show formation name in describing work performed. Number all drill stem tests sequentially. Attach description of all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or represenlative test on "Final" Iorm. 1) Submit "Interim" sheets when filled out but not less frequently than every 30 days, or (2} on Wednesday of the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completion. District Field Alaska JCounty or Parish IState North Slope Borough Alaska ILease or Unit Well no. ADL #28324 4-26 ?rudhoe Bay Date and depth as of 8:00 a.m, 2/26/86 2/27/86 2/28/86 3/01/86 thru 3/03/86 3/04/86 Complete record for each day while drilling or workover in progress 13-3/8" @ 2497' 6487', (1031'), TIH Wt. 9.3, PV 10, YP 7, PH 9.5, WL 16, Sol 9 Drl & surv 12¼" hole to 6487'. 5294', 46.7°, N39.2E, 4845.90 TVD, 1302.60 VS, 966.80N, 874.70E 5603', 46.3°, N39.2E, 5058.50 TVD, 1526.00 VS, 1140.60N, 1016.50E 5915'. 47.2°, N40.2E, 5272.70 TVD, 1751.90 VS, 1315.80N, 1160.60E 6382', 47.5°, N42.2E, 5587.90 TVD, 2095.70 VS, 1576.30N, 1386.10E 13-3/8" @ 2497' 7587', (1100'), Drlg Wt. 9.4, PV 8, YP 9, PH 9.5, WL 9.8, Sol 8 Drl & surv 12¼" hole to 7587'. 6600', 47.2°, N42E, 5735 TVD, 2255 VS, 1695N, 1493E 6973', 47.3°, N43E, 5990 TVD, 2528 VS, 1894N, 1679E 7344', 47.0°, N46E, 6243 TVD, 2799 VS, 2086N, 1870E 13-3/8" @ 2497' 7970', (383'), Drlg Wt. 9.6, PV 7, YP 5, PH 9, WL 7.6, Sol 8 Drl & surv 12¼" hole to 7970'. 7718', 45.2°, N45E, 6502 TVD, 3069 VS, 2279N, 2063E 7790', 44.6°, N44E, 6553 TVD, 3120 VS, 2312N, 2099E 13-3/8" @ 2497' 9807', (1837'), Drlg Wt. 9.7, PV 13, YP 9, PH 10, WL 7.5, Sol 9 ADC: $889,457 Drl & surv 12¼" hole to 9807'. 7967', 43°, N44E, 6681TVD, 3242 VS, 2399N, 2184E 8154', 42.1°, N45E, 6818 TVD, 3369 VS, 2489N, 2273E 8586', 42.5°, N43E, 7139 TVD, 3658 VS, 2698N, 2423E 8835', 43.4°, N43E, 7322 TVD, 3827 VS, 2824N, 2587E 9115', 43.8°, N45E, 7524 TVD, 4020 VS, 2963N, 2721E 9676', 45°, N44E, 7923 TVD, 4414 VS, 3248N, 2993E 13-3/8" @ 2497' 10,020', (213'), Drlg Wt. 10, PV 14, YP 10, PH 10, WL 6.4, Sol 10 Drl & surv 12¼" hole to 10,020'. 9833', 44.1°, N44E, 8035 TVD, 4525 VS, 3327N, 3070E The above is correct Signature For form preparati~-n and ~istributio~- see Procedures Manual S~ction 10, Drilling, Pages 86 and 87 JDate ITiUe 4/04/86 Drilling Superintendent ARCO Oil and Gas Company g~, Daily Well History--Interim Inllrucl|olls: This form is used during drilling or workover operations. If testing, coring, or perforating, show formation name in describing work performed. Number al) drill slam testa sequentially. Attach description o! all cores. Work performed by Producing Section will be reported on "Interim" sheets until final completion. Report official or representative test on "Final" form. 1) Submit "llllerirn" sheets when filled out but not less frequently than every 30 days, or on We(Jnesday ot the week in which oil string is set. Submit weekly for workovers and following setting of oil strin§ until completiom District Field Alaska ICountyor Parish State North Slope Borough I ILoaso or Unit ADL #28324 Alaska Prudhoe Bay IWell no. 4-26 Date and depth as of 8:00 a.m. 3/05/86 3/06/86 3/07/86 3/08/86 thru 3/10/86 3/11/86 Complete record for each day while drilling or workover in progress 13-3/8" @ 2497' 10,540', (520'), Short trip Wt. 10.1, PV 16, YP 8, PH 9.5, WL 6.4, Sol 11 Drl & surv 12¼" hole to 10,540', short trip. 10,055', 40.8°, N45E, 8199 TVD, 4674 VS, 3433N, 3175E 10,475', 32.1°, N54E, 8535 TVD, 4925 VS, 3599N, 3363E 13-3/8" @ 2497' 10,540', (0'), POOH Wt. 10.0, PV 14, YP 8, PH 9.5, WL 6.4, Sol 11 Rm f/10,350'-10,540', C&C, POOH. Chg top pipe rams to 9-5/8". RIH w/spear, jar & pull wear bushing. Instl new bushing. TIH to 10,446', rm to 10,540', C&C, POOH & prep to rn csg. 9-5/8" @ 10,540' 10,540', (0'), Instl wear bushing Wt. 9.9, PV 16, YP 10, PH 9.5, WL 6.6, Sol 10. RU & rn 241 jts, 9-5/8", 47#, L-80 BTC csg w/FC @ 10,436', FS @ 10,522'. Cmt w/500 sx C1 "G" w/.75% D-65 & .2% D-13R. Displ using rig pmps, bump plug. CIP @ 0115 hrs, 3/7/86. Chg out pack-off. Chg to 5" rams &tst. Instl wear bushing. 7" @ 10,865' 10,866', (326'), POOH w/5" DP Wt. 9.7, PV 14, YP 8, PH 10, WL 6.6, Sol 10 TIH w/8½" BHA to 10,434', DO flt equip, cmt+ 10' new formation to 10,550'. Conduct leak-off tst to 11.2 ppg EMW. Drl 8½" hole to 10,866', hole tight. Short trip 4 stds, RIH, wsh & rm f/10,672'-10,641', pull into csg. TIH, wsh & rm f/10,609'-10,866', CBU, POOH to log. RU Gearhart, rn DIL/Sonic/GR/SP f/10,866'-10,520'. Rn Density/Neutron/GR/CAL f/10,866'- 10,520', cont w/GR to 2497', RD Gearhart. TIH to 10,702', rm to 10,866', CBU, POOH. RU & rn 13 its, 7", 29#, L-80 BTC csg w/FC @ 10,820', FS @ 10,865', LC @ 10,734', Mkr Jt @ 10,519', TOL @ 10,304'. Cmt w/300 sx C1 "G" w/5% KC1, 1% D-60, .2% D-46 & .15% D13R. CIP @ 0415 hrs, 3/10/86. Rel f/hgr & POH w/5" DP. 7" @ 10,865' 10,291', (0'), TIH w/7" scrpr Wt. 9.7+, PV 18, YP 12, PH 10.5, WL 6.8, Sol 10 PU 3½" DP, std back in derrick. TIH, tag cmt@ 9925' 10,291', CBU, POH. MU 7" scrpr, TIH. , drl to The above is correct For form preparation and dis~bution see Procedures Manual Sectibn 10, Drilling, Pages 86 and 87 Drilling Superintendent · ! AtlanticRichfieldCompany ~} Daily W II History-Final Report Inltructions: Prepare and submit the "Final Repart" on the first Wednesday after allowable has been assigned or well is Plugged, Abandoned, or Sold. "Final Report" should be submitted also when operations are suspended for an indefinite or appreciable length of time, On workovers when an official test is not required upon completion, report completion and representative test data in blocks provided. The "Final Report" form may be used for reporting the entire operation il space is available. District Alaska Field Prudhoe Bay ICounty or Parish Lease or Unit Title North Slope Borough ADL #28324 IAccounting cost center code State Alaska IWell no. 4-26 Auth. or W.O. no. AFE 804011 Drill Parker #191 Operator ARCO Alaska, Inc. Spudded or W.O. begun AP1 50-029-21520 Spudded Date and depth as of 8:00 a.m. 3/12/86 3/13/86 A.R.Co. W.I. 21.66% IOate 2/19/86 I Complete record for each day reported I otal number of wells (active or inactive) on this DSt center prior to plugging and ~ bandonment of this well I our ] Prior status if a W.O. 0130 Hrs. 7" @ 10,865' 10,291', (529'), LD DP 9.4 ppg brine wtr TIH w/scrpr to 10,259', wsh thru lnr lap 10,259'-10,331'. TIH, tag cmt @ 10,663' Drl cmt to 10,820', CBU. Tst 9-5/8" & 7" csg & lnr lap to ~000 psi. Displ well w/700 bbls 9.4 ppg NaC1 brine. Circ & filter brine, rev circ & filter brine, LD DP. 7" @ 10,865' 10,820' PBTD, RR 9.4 ppg brine wtr POOH, LD DP. Displ 424' w/diesel. ND BOPE, NU tbg spool, tst 9-5/8" pack-off to 5000 psi. NU &tst tree to 5000 psi. Instl BPV. Winterize 13-3/8" x 9-5/8" ann w/60 bbl crude/10 bbl diesel. RR @ 2130 hfs, 3/12/86. Old TO I New TO I PB Depth I 10,866 ' I 10,820' Released rig I Dato IKind of rig 2130 Hrs. 3/12/86 Rotary Classifications (o11, gas, etc.) I Type completion (single, dual, etc.) Oil ] Single Producing method I Official reservoir name(s) Flowing [ Sadlerochit Potential test date Well no. Date ;Reservoir Producing Interval Oil or gas Test time Production Oil on test Gas per day Pump size, SPM X length Choke size T.P. C.P. Water % GOR ~Gravity Allowable Effective date corrected The above Is correct 4/04/86 Drilling Superintendent For form preparation and distribution, see Procedures Manual, Section 10, Drilling, Pages 86 and 67. STATE OF ALASKA ~ ALASKA O.~_.AN D GAS CONSERVATION CON...~,ISSION ~ MONTHLY REPORT OF DRILLING AND__ ___WORKOVER OPERATION '(. Dritling we~ ~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-314 3. Address 8. APl Number P. O. Box 100360, Anchorage, AK 99510 50- 029-21520 92' FSL, 429' FWL, $ec.26, T11N, R15E, UM 4. Location of Well at surface 6. Lease Designa.tionand Serial No. ADL 28324 5. Elevation in feet (indicate KB, DF, etc.) 65 ' RKB 9. Unit or Lease Name Prudhoe Bay Unit 10. Well No. 4-26 11. Field and Pool Prudhoe Bay Fi eld Prudhoe Bay Oil Pool For the Month of March ,19 86 2. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well ~ 0130 hfs, 2/19/86. Drld 17-1/4" hole to 2501'. Ran, cmtd, & tstd 13-3/8" csg. Drld 12-1/4" hole to 10,540'. Ran, cmtd, & tstd 9-5/8" csg. Drld 8-1/2" hole to 10,866'TD (3/8/86). Ran logs. Ran, cmtd, & tstd 7" csg. PBTD = 10,820'. Secured well & RR ~ 2130 hrs, 3/12/86. 13. Casing or liner ru.n and quantities of cement, results of pressure tests 20", 91 .5#, H-40, weld conductor set (~ 114'. Installed w/1700# Poleset. 13-3/8", 72.0#/ft, L-80, BTC csg w/shoe 2497'. Cmtd w/2500 sx AS II1 & 400 sx AS II. 9-5/8", 47.0#/ft, L-80, BTC csg w/shoe 10,522'. Cmtd w/500 sx Class G. 7", 29.0#/ft, L-80, BTC csg f/10,304' - 10,865'. Cmtd w/300 sx Class G. 14. Coring resume and brief description None 15. Logs run and depth where run DIL/Sonic/GR/SP f/10,866' - 10,520' Density/Neutron/GR/Cal f/10,866' - 10,520'; GR to 2495' 6. DST data, perforating data, shows of H2S, miscellaneous data None 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. NOTE--Report/on this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska /1 Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DAM2/MR05 Submit in duplicate A R C O A I. a .'.-~' k a, I 'n c'. 99.5 t ~'~ DATE:' Apri L '7, t986 R E F E R F.i: N C E · A R C 0 M a cj 'ne .1: i c Tapes' w/L i :.:.t: '"'"'DY 4-26 3-8-86 ~ D S' 4 .... 28 ':~ --' ''~- o z. DS t S..-98 2-'i 6-86 'x.,., D £' t 6 "',:. ''~ 4 :?:'-',:. ''~'?'''' !ii 6 I::' I. e a .-..': e : i ,.:j 'n a 'n (:t 'r' e '!' u. ¥' r'~ '1: i"~ e .:'.:; '[' .1.. a (:: h e d c o p y a .'_-"- ',," e,.': e J ?. :.?:, ,::: e , ,, :.:.:, ,_., ........................... :l:'r' ma C:a 'r' I. i'n Alaska 0il & Gas Cons. Commission A T 0 ..... i-~"' ,.-_'" <;'. F Am0rage "l' R A N S' :~: 8 & 2... '') 8 da Ta ~, D I E-: i' R ]: B U 'T' ]: 0 N :,I: C e 'n t: 'r'a I. I::' i I. e .'..:': -~ P h i i. L i P s' .. c:,'o l.d e I. I. ~::' ,. CI"~ ev'r' o'n , ~ ...... i I e:ii: D ?!.,. M R & D .1t, Ii!: ::,, t: e 'n.? i o 'n Iii: x I:: I. o'c a t: i o'n .,,. ,]{-.' c:, h i o '"' ['!: x x ;';'n '"' ~i:-I- .... .,. ... -,. . a 't' e .,.':, 'F A I. a ..:-.': I.:- a i"/a 'r' a t.. h o r'~ 'i" e x a c: ,'.::, i"'i (::, I:.', i I. ARCO AL~.-I<a, Inc F:'. O. Box A'r'~cl-, or a g e, A L~:l<a 995J0 DATE]* Apr i L R [..-F- E i~< E NC E · 7, t986 ARCO Open HoLe F inaL.~ -'~"'D,S' 4--i.:6 5--8--f. t6 BHC::.:.:,' Ru.n i "" D,':? 4.-26 3-..-9-86 CDI_ ~ D,? 4-'26 5-9-86 CDL/CN.L ... ~.. "" r, ? 4-26 ,_, -' ,::, -',::, 6 DIL "'" ',"') S:' 4 .... ':?. 6 S ...... ?- 86 ('.; a m m a F::. a ¥ "-J D,? 4 .... 2-:'.6 Run i R u n i Run i r_'~" & 5" c.';. ,n I--" II ..) G o [;- o Go Go ~0 HAVE A N ',': (:.'.'Iii: 9 Aia~lm 0il o ~ b~s. Commissio~ ]:',"ma C:ar I. ir, A'i" 0 - i 429 F Anchorage da+.a ~ I) I S' T F;..' I B U T I 0 N A L a :~i: I< a STATE OF ALASKA y_ ALASKA ~ AND GAS CONSERVATION CO~vllSSlON !1. Drilling well I~ Workover operation [] 2. Name of operator 7. Permit No. ARCO Alaska, Inc. 85-314 3. Address 8. APl Number P. 0. Box 100360, Anchorage, AK 99510 50- 029-21520 4. Location of Well atsurface 92' FSL, 429' FWL, Sec.26, TllN, R15E, UM 5. Elevation in feet (indicate KB, DF, etc.) 65 ' RKB 6. Lease Designation and Serial No. ADL 28324. For the Month of. February , 19 86 9. Unit or Lease Name Prudhoe Bay' Unit 10. Well No. 4-26 11. Field and Pool Prudhoe Bay Field Prudhoe Bay 0il Pool 12. Depth at end of month, footage drilled, fishing jobs, directional drilling problems, spud date, remarks Spudded well (~ 0130 hrs, 2/19/86. Drld 17-1/4" hole to 2501'. Ran, cmtd, & tstd 13-3/8" csg. hole to 8287' as of 2/28/86. Drld 12-1/4" 13. Casing or liner ru.n and quantities of cement, results of pressure tests 20", 91.5#, H-40, weld conductor set ~ 114'. Installed w/1700# Poleset. 13-3/8", 72.0#/ft, L-80, BTC csg w/shoe 2497'. Cmtd w/2500 sx AS Ill & 400 sx AS II. 14. Coring resume and brief description None 15. Logs run and depth where run None RECEIVED MAR ! 4 1986 16. DST data, perforating data, shows of H2S, miscellaneous data None Alaska 0il & Gas Cons. Commission A,qch-3rage 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. SIGNED (~ ~ ~.~ TITLE Associate Engineer DATE ~-J2--~L~ NOTE--Report/~/n this form is required for each calendar month, regardless of the status of operations, and must be filed in duplicate with the Alaska Oil and Gas Conservation Commission by the 15th of the succeeding month, unless otherwise directed. Form 10-404 DAH/MR30 Submit in duplicate December~, 1985 Mr. K. M. Le Acting Regional Drilling Engineer ARCO Alaska, Inc. P. O. Box 100360 Anchorage, Alaska 99510-0360 Re: Prudhoe Bay Unit DS 4-26 ARCO Alaska, Inc. Permit No. 85-314 Sur. Loc. 92'FSL, 429'F~L, Sec. 26, TllN, R15E, UM. Btmhole Loc. 1432'FNL, l159'FEL, Sec. 26, T!IN, Rt5E, UM. Dear Mr. I,e: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not indemnify you from the probable need to obtain additional permits required by law from other governmental agencies prior to commencing operations at the well site. To aid us in scheduling field work, please notify this office 24 hours prior to commencing installation of the blowout prevention equipment so that a representative of the Commission may be present to witness testing of the equipment before the surface casing shoe is drilled. Where a diverter system is required, please also notify this office 24 hours prior to commencing equipment installation so that the Commission may witness testing before drilling below the shoe of the conductor pipe. ,~~ trRly~yQurs, · C. V. C~atterton Chairman of Alaska Oil and Gas Conservation Commission BY ORDER OF THE COMMISSION be Enclosure CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Mr. Doug L. Lowery ARCO Alaska, Inc. Post Office B(>....~00360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 December 23, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT: DS 4-26, Permit to Drill Dear Mr. Chatterton: Enclosed are: An application for Permit to Drill DS 4-26, along with a $100 application fee Diagrams showing the proposed horizontal and vertical projections of the wellbore o Proximity plots ° A diagram and description of the BOP equipment A surface hole diverter system might not be used for this well. We estimate spudding this well on January 3, 1986. If you have any questions, please call me at 263-4277 or Kevin Grimes at 263-4610. Sincerely, K. M. Le Regional Drilling Engineer (Acting) KML/KJG/tw PD/L202 Enclosures RECEIVED Alaska Oil & Gas Cons. Comrn/ssi0n ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany STATE OF ALASKA ALASKA 't::~rL AND GAS CONSERVATION C~MlSSlON PERMIT TO DRILL 20 AAC 25.005 lb. Typeofwell EXPLORATORY E~DEVELOPMENTOiL. DEVELOPMENT GAS [] MULTIPLE ZONE la. Type of work. DRILL REDRILL DEEPEN 2. Name of operator ARCO Alaska, Inc. 3. Address P. 0. Box 100360, Anchorage, Alaska 99510 4. Location of well at surface 92' FSL, 429' FWL, Sec.26, T11N, R15E, UH At top of proposed producing interval 1580' FNL, 1304' FEL, Sec.26, TllN, R15E, UM At total depth 1432' FNL, 1159' FEL, Sec.26, T11N, R15E, UM 5. Elevation in feet (indicate KB, DF etc.) 6. Lease designation and serial no. RKB 65' ADL 28324 12. Bond information (see 20 AAC 25.025) Federal Insurance Company Type Statewide Surety and/or number //8088-26-27 9. Unit or lease name Prudhoe Bay Unit 10. Well number 4-26 11. Field and pool Prudhoe Bay Fi eld Prudhoe Bay 0il Pool Amount $500,000 13. Distance and direction from nearest town 14. Distance to nearest property or lease line 15. Distance to nearest drilling or completed 6 mi. NE of Deadhorse miles 429 feet 4-12 well 38' @ 2978' feet 16. Proposed depth (MD & TVD) 17. Number of acres in lease 18. Approximate spud date 10935'MD, 8866' TVD fec. t 2560 01/03/86 19. If deviated (see 20 AAC 25.050) 20. Anticipated pressures 3356 psig@ 80°F Surface KICK OFF POINT 2600 feet. MAXIMUM HOLE ANGLE 44.7 o (see 20 AAC 25.035 (c) (2) 3958 .psig@ 8866 ft. TD (TVD) 21 Proposed Casing, Liner and Cementing Program . SIZE , Hole I Casing 30" I 20" 117-1/2" 13-3/8" [ 13-3/8" · 12-1/4" 9-5/8" 8-1/2" 7" Weight 91.5# 68.0# 72.0# 47.0# 29.0# CASING AND LINER Grade Coupling/ H-40 Wel~ ~-55 IBTC/ L-80 [BTC! -8o /BTO/ 22. Describe proposed program: SETTING DEPTH Length 80' 34' I 34' 46' 2420' 10516' MD TOP TVD 34' 34' I 80' I 80' 31' I I 31' 688' 10247' I 8377' I MD BOTTOM TVD 114'I 114 80'I 80 2500'I 2500 10547'1 8590 10935'I 8866 QUANTITY OF CEMENT (includestagedata) 2000# Poleset 2300 sx AS I11 & 400 sx Class G 500 sx Class G 300 sx Class G ARCO Alaska, Inc., proposes to directionally drill this Sadlerochit development well to 10,935'MD (8866'TVD). A 20", 2000 psi annular diverter may be installed and operationally tested prior to spud. The 13-5/8", 5000 psi, RSRRA BOPE stack will be installed and tested (rams 5000 psi, annular 3000 psi) weekly upon installation and operationally tested each trip. After reaching TD, logs will be run across selected intervals. The well will be completed using a workover rig at a later date. A 5-1/2" tubing string with gas left mandrels and packer will be run and set above the Sadlerochit. A downhole safety valve will be installed and tested upon completion of the job. Selected intervals will be perforated in the Sadlerochit formation and reported on subsequent reports. Reserve pit fluids will be disposed of down the 9-5/8" x 13-3/8" annulus of this well. The 9-5/8" x 13-3/8" annulus will be left with a non-freezing fluid during any interruption in the disposal process. Upon completion of the disposal process, the annulus will be sealed with 300 sx of cement followed by Arctic Pac. The wells 200' or less from well 4-26 are: wells 4-11, 158' @ 2446'TVD; well 4-13, 60' ~ surface; well 4-14, 180' @. surface; well 4-27, 111' @ 1956'TVD. SIGNED (-~-~t',~~ ~' TITLE Regional Dr lg Engr.(Acting)DATE The space below for Commission use Samples required []YES ~xlO Permit number APPROVED BY Form 10-401 -77// CONDITIONS OF APPROVAL Mud log required I-lYES BO Approval date .. 12d30/85 _ ' Fl /-' I Directional Survey required I APl number I~YES E]NO I 50-- ~-0.~..~'- SEE COVER LETTER FOR OTHER REQUIREMENTS !985 ,COMMISSIONER DATE December by order of the Commission Submit in triplicate Rev 7-1-R0 Z G_] OZ looo 2000 3000 4000 5000 6000 7000 8OOO 9000 10000 0 1000 2000 3000 4000 5000 6000 ! 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 i , , , , , ~ , , lO' CASING T~tD == 114 ARC 3 AL.a,SKA, INC. -~;CALI= I IN SHL: 92' :SL, 429' FWL, ~3-3/8' CASING TVD = 2500 ~EC.26, T11N, R15E, UM(A~PROX) (OP TVD = 26~0 ~.5 THL:1530' FNL,1250' FEL, I 7'~8 ~ -11 ~FC.2R. ','11N~ RI~F; 1 12.b 17.5 ~ DS 4-1e 22. ~ / -,~ 2.5 37.5 &2.5 EOC TVD=4213 M)=4388 DEP =664 ~ )S 4-a~ N 44 DI G 33 MINE ~133 F; {TO TARGET) / A VERA~ E ANGLE 44 DEG ~4 MIN K-10 TVD -- 7485 MD - 898 Z DEP ~ 3886 9-6/8' CASING TVD- lBg0 MD - 101i50 OEP -49g . LCU TVD =:8800 MD = 10564 DEP = 50)9 TOP SADLEROCHIT TVD = 8600 MD = 1(1564 DEP = 5039 = ~' ~G~S' CO/~S. GlO C(INTACT TVD = 8655 MD = ~C,842 DEP BASE SAI3LEROCHIT TVl3-8795 MD- 10839 DEP--5202 TD TVD = 8886 MD = 10939 DEP = 5272 7000 0 1000 0 1000 2000 3000 4000 VERTICflL SECZION 5000 8000 2000 3OOO 4000 __J 5000 w GLO 6000 n~ 7000 8000 tooOo 7000 9000 E - N COOROINRTES o -1000 0 0 0 O 8 CZ) CE) O O O CZ) C~ 0 1000 2000 3000 4000 5000 6000 ~HI' ~2' P~:I ~2~' P~ ~EC.28, T'~N, ~15E, ~ (APP~OX) THL:I~30' :NL, 12~0' F ~1., 5EC.26, T!~IN, R15E, t ~ OS 4-26 5 DS~ -- 5133' N :658 E : 631 075 ~L~ska Oil & Gas ions, Corniness >n ' _ I I I I ] I I I I I I I I I I I I [ I [ I I I I I I I t 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 - ~ 000 0 ~ 000 2000 3000 ~000 5000 EO00 E - N COOROINF]TES E - 1,4 COORDINRTES o - 1000 0 1000 2000 3000 ~tO00 5000 6000 (~ IIII I III IIIIIIIII IIIIIIIII IIIIII 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 o OS ~-26 z ~ ~ OS ~-18 ~ 8891 581 3 z os O00'Ro ~ NFITES 100 200 300 "tOO -300 -200 -100 500 I I i t I I I t I I I I' I t t I I II I I I I I I I I I I I I I - . ' ' . OS 4:- 26~ ~38 658 '2E73 ~62' ~~p-~ '665 /~378~ ~ ~o~. I~ ~ .~159 =13 ~ 'D',, 4-12 -300 -200 - O0 0 100 200 ~ 500 E - N COOROINBI~S DEC Alaska Oil & Gas Cons. Commission Anchorage SURFACE I-tOLE D IVEI~-rER SYSTEM ARCO ALASKA !NC. SCHEMATIC IO" Ni'D. (}PR. BALL VAL~ ¥¥ELL ~ ISEE DE IAIl I IO' HYD. 0Pti. VALVE NIE "TEE:" I cus. . I RESERVE PIT NOT i!: FI.OII~ INE DR ILL lNG RISER 20O0 PSI ~ ANNI,~AR PRE VENTOR LIN[ Valves on diverter lines open automati- cally when the annular nreventer is closed. · )It ILL SPOOL gONDUC P IP£ IO' HYDRAUL lC OPERATED BALL VALVES "DETAIL" 20260 t 0~.03 PlP~ ~ I 10. 14. 18. 1. C2ic~ exJ Fill accl2Acor rear. ir Co proper 3. ~~ ~, ~ c2oN ~1 ~ S~~lF 4. ~ ~ ~ ~. ~ ~le l~r ~ 4S ~ cl~ ~ ~ 1200 p~i ~ ~3-s/8" ~ s~ ~ 6. ~ ~ ~ ~ ~ ~ ~ld ~ a~ 9. bl~ ~ ~~ ~o ~ ~L ~ ~ 1~ ~ Te~ ~~ ~ws co SO00 ~. ~ ~ ~~ ~ bl~ p~r ce~ ~. ~ ~ s~ co ~~ ~r. ~ ~1~ ~ ce~ m a wk ~ ~- ci~ly race ~ ~ly. · Alaska 0il & ~as Cons, Oommt.~*ron. A~c~orage t~Yised ~/21/84 ARCO Alaska, In. Post Offic~x 100360 Anchorage, Alaska 99510-0360 Telephone 907 276 1215 r. : : November 7, 1985 Mr. C. V. Chatterton Commissioner State of Alaska Alaska Oil & Gas Conservation Commission 3001 Porcupine Drive Anchorage, AK 99501 SUBJECT' Conductor As-Built Location Plat - DS 4 (Wells 19, 25- 28, 33) Dear Mr. Chatterton- Enclosed is an as-built location plat for the subject wells. you have any questions, please call me at 263-4944. Sincerely, d. Gruber Associate Engineer JG/tw GRU12/L79 Enclosure If RECEIVED NOV l !985 Alaska 0il & Gas Cons. Commission Anchorags r~ ARCO Alaska, Inc. is a Subsidiary of AtlanticRichfieldCompany · I0 · 9 · 8 · 7 · 6 e 5 · 4 · 20 · 21 · 22 · 24 · II e Grid North is i'5°58'Eost No.4 i" = 4000' VlClNITY MAP Cond ASP ZONE 4 COORDINATES WITHIN SECTION 26 SECTION OFFSETS WLO GLO I9 Y=5 952- 791.73 I_~T= 70o16'264559" 2_54 X : 713 057.60 LONG = 148°16'55.2442-" 53 ¥ = 5 952. 55~.46 I_AT = 70° 16'24.1266" 304 X = ;ri3 !i4.53 LONG =!4~3°16' 55.7795" ~5 Y = 5 · 952- 092.02 I_AT = 70°16' 19. 5094" 404 X : 713 2~.7.65 LONG=148°I6'30.8718" ;?6 Y =5 951 975.43 I_AT = 70°16 '18.~552" 429 X = 715 ~.,5.$9 LONG = 148° 16' 30.1453" 678 208 WITHIN SECTION 35 WLO NLO 27 Y = 5 951 858.74 x: 715 284.25 28 ¥=5 951 742.10 X= 713 512.58 LAT = 70°16'17.2001" 453 26 LDNG = 148°16' 29 4172 LAT= 70°16~16.0455" 478 144 LONG= 148°1G' 28.6~9" .. ee~e~eeeeeeee .... · .~ CERTIFICATE OF SURVEYOR I HEREBY CERTIFY THAT I AM PROPERLY REGISTERED AND LICENSED TO PRACTICE LAND SURVEYING IN THE STATE OF ALASKA AND THAT THIS PLAT REPRESENTS A LOCATION SURVEY MADE BY ME OR UNDER MY DIRECT SUPERVISION, AND ALL DIMENSIONS AND OTHER DETAILS ARE CORREGTx- LEIVED DA~'E / SURVEYOR v ~laska Oil & Gas Cons. C;or. miss~ Anchoraoe LEGEND WLO- WEST LINE OFFSET SLO-SOUTH LINE OFFSET NORTH LINE OFF~ ..... CONDUCTORS AS-BUILT ....... THIS SUR~_Y. .. ;ARCO No. j ARCO Alaska , Inc. AS- BUILT DRILL SITE 4 CONDUCTORS LOCATED IN PROTE~¢TED SECTIONS 26 & $5~ TIlN, RI5E U.M,- PREPARED BY LOUNSBURY 8~ ASSOCIATES, INC. 72:5 w 6th AVF_~ ANCHORAGE,ALASKA ,DATE: 10/29/~5, , CHKD. BY: GEL SCALE: i": 400' · ,~., ,.. ....~,,~ .'~. ,.,,~.,,, ,, .~ '.' .~,:, i.,~.,..,~,.,~,~,",,: ~_,~..~ ; ,, . / ' "" :' ·'/('2 th~u 8) , '3~" .... ~S web'11 'located proper distance' from property line ................. ~--~ 4, Is well located Proper distance from other wells ,, ,' ................. "i". ;ii:'. '. _ 5~ "Is. sufficient' undedicated acreage available in this po°l ............ ! · . "6~ Is well to be deviated and is wellbore plat included .,., ........... ~ " ~i ~:.~ $3.~. 7~' 'Is oPerator the only affected party ............... ,. ................. · s. c,, .for, ,a t' . ........................ (3) Admin /~,-~b 9 Does operator have~a bond in force .................................. 71 '~9 thru 12) 10, 'Is a conservation order needed ....................................... ' /a -fxz is - 11, administrative approval needed .................................... · (10 12) 12 'th 1 ber ' and . Is. e ease hum appropriate ..................................... (4) Casg ~]-~ ,/~&~./~y' 13. ts conductor string provided ......................................... '(13-~hru ~1)[ .14, Is enough cement used to circulate on conductor and surface ......... 15, Will Cement tie ih surface and intermediate or production strings ,,, kn ve 16. Will cement cover ail' own producti horizons ..................... 17. Will surface casing protect fresh water zones ........................ 18, Will all casing give adequate safety in cOllapse, tension and burst,, 19, Is this well to be kicked off from an existing welibore...,,,,,, .... 20. Is' old wellbore abandonment procedure included on 10-603 ............ 21. Is adequate wellbore separation proposed ............................ (5) BOPE ~ /~/~A/ED~ 22. Is a diverter system required ....................................... (22 thru 26~ 23. Are necessary diagrams of diverter and BOP equipment attached 24. Does BOPE have sufficient pressUre rating - Test to .D~fr~ , 25, Does the choke manifold comply w/API RP'53 (Feb 78) · · ee · · e e e · e · ee . e e e e 26. Is the ,presence of H2S gas Probable ................................. (6) Add' ~7-~ /~,/~fj' '27 Additional requiremen,ts · · eeeee~ee .eee eeee eee e eeeeeeeeeeeeeee.eeee.eeee " /~X' ~,ec,,,,t '.~/1"~ ~.~,./g,' 4.- · . ;., _ · . , _ . . Geology: Engineering: . . awr rcs/ ? m, fd WVA~_ ~ HJH .ff~..~ INITIAL GEO. UNIT ON/OFF POOL CLASS. STATUS AREA NO. SHORE ,'er: 03/13/85 6.011 Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Permitting Process but is part of the history, file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. 0 :ili: i :17;, ~::i: 5.!i () f'l ' f"i i" "~ i 0 i 0 ',"~ () 5 4. I ~;) 0 'i 2 0 4 ~:::, () ,.q 2;: 2 () ,":..,,... ,..,n ~.-~ T E H :3 ?'! E F:: '.;.? i!:~ i_ ,'ii; S ',":-: F: H E; [:i: C;; [:.:. C;; ¢:i P T F: 14 <, E; {"i E F:: (.7-: E: C., ,--" 'C: 7 L~ !J l..i .{ U PRO~RAM:u L~SrAN~ .~ REVISTON:_ 5.1 ,PART NUMB=R:. _ W5790-P:32~ Start of execution: Mon 22 MAY 89 11:29m **** REEL HEADER **** LIS 89/18/05 ATLAS 01 'LIS CUSTOMER FORMAT TAPE' ***~ TAPE HmADER **** LIS 89118105 3535 01 'THREE PASS CN/MS AT 10761-10480 FEET' FILE e 1 PASS 1.001 **** FILE HEADER **** 1024 CN WN FN COUN STAT : ARCO ALASKA, I'¢ : D.S.-&.-26, PRUDHOE BAY : PRUDHOE BAY : NORTH SLOPE : ALASKA , FORMAT RECORD (TYPE# 64) ONE DEPTH DER FRAME TAPE D~PTH UNIT : FT I 2 CURVES : NAME I GR 2 TTEN CODE SAMPLE# UNIT 68 I API 68 t LB BYTES 5 CCL 68 1 VOLT 4 6 SSN 68 I CTS 4 7 CSSN 68 1 CTS 4 8 LSN 68 I CTS 4 9 CLSN 68 1 CTS 4 0 CN 68 I PCT 4 I CNC 68 1 PCT 4 2 CNRA 68_ I C/"~, 4 * DATA RECORD (TYPE# O) 994 BYTES * DEPTH GR CCL SSN CN CNC 10761.000 ~.~ 1000000;-03- 0.1000000E-03 0.1000000E-03 0.1000000E-03 0.1000000~-03 10711.000 3~.30634 3.000000 241.2625 24.20087 28.20087 10661.000 35.97058 1-000000 234.0851 24.47603 28.47603 10611.000 45.08960 0.0000000 196.6360 27.42149 31.42149 10561 .000 27.74321 0.0000000 210.4160 2~ =~8~6 2~ 55~26 · .. i .; .,¢ ~ I 10511.000 89.58798 0 0000~ ~ . ~0~ 1~5.o448~ 73.99335 77.99335 TTEN CSSN CNR$ 0.1000000E-03 0.1000000E-03 0.1000000E-03 973,3281 241.2625 0,8344835E-01 957.0645 234.0851 0.$282566E-01 9&7,1504 196.6360 0.7676882E-01 925,6567 210,4160 0.8739150E-01 92,B.9751 135.8448 0.4478856E-01 LSN 0.1000000E-03 0.1000000E-03 118.3241 80.531~5 11.61288 77.55299 -16.81648 60.38206 -31.27808 73.55424 -18.95758 24.33719 SPD CLSN 0.1000000E-03 0.1000000E-03 25.~9741 20.13295 24.99750 19.35~24 24.~9750 15.09552 24.99750 18.38857 24.99750 6.084295 TOT6L DATA R ~ORub .STARTING TAP¢ D=PTH = ~IL~ TRAILER **** 30 10761.00 ENDING TAmE DEPTH = 10480.00 FILE # 2 **** FILE 2.002 HEADER 1024 * FORMAT RECORD (TYP=~ 64) ONe,_ DEPTH. ~ ,D=R. ~RAME 12 CURVES : NAME 1 GR 2 TTEN TEN 5 CCL 6 SSN 7 CSSN $ LSN 9 CLSN 10 CN 11 CNC 1~ CNRA CODE SAMPLE# UNIT BYTES 68 ! bPI 4 68 I LB 4 68 1 LB 4 68 1 F/MM 4 68 1 VOLT 4 68 I CTS 4 68 I CTS 4 68 I CTS 4 68 1 CTS 4 68 1 PCT 4 68 1 PCT 4 68 1 C/C 4 DATa RECORD DEPTH CCL CN 10761.000 30.u mO000 0.0000000 10711.000 3.000000 24.15089 10661.000 6.000000 23.70346 10611.000 O.O00000O 26.15058 I 0561. 000 0.0000000 20.36580 10511.000 O.O000000 71. 65"z6~ ' (TYPE# O) GR SSN CNC 0,0000000 50.00000 0.0000000 41.76482 243.1799 pR 15089 43.83Q57 231.5188 27.70346 45.85133 uj.8686 30.15068 28.22841 224,3334 24.36589 96.25677 136.50~9 75.65536 99~ BYTES * TT~N CSSN CNRA 0.0000000 50.00000 0.0000000 967.3342 243.17~9 0.8356261E-01 948.390t 231.5188 0 · 8~60081 ;-01 950.8242 205.8686 0.79251175-01 923.6499 224.3334 0.9332252~-01 923.8184 136.5049 0.453380~E-01 T E N LSN -100.0000 0.0000000 96.32451 81.28297 5.251796 78.34676 -1 5. $6763 65.26128 -26.~7904 83.74139 -22.30832 24.75546 SP9 CLSN 0.0000000 O.O00000O 24.99750 20.32074 24.997,50 19.53669 25.99741 16.31532 25.99741 20.93535 25.9'9741 6.188868 TOT&L DATA RECORDS : STARTING TAP= DEPTH = =ILE TRAIL:R~ **** 3O 1C, 761.00 ENDING TAPE DEPTH = 10481 .00 FiLE PASS **** FILE HEADER **** 1024 * FORMAT ONE DEP RECORD (TYPE# TH PER FRAME TAPE DEPTH UNIT : FT 12 CURVES : NAME CODE SAMP 1 GR 68 1 2 TTEN 68 1 3 TEN 68 1 ~ SPO 68 1 .= CCL 68 1 6 SSN 68 1 7 CSSN 68 1 8 LSN 68 I 9 CLSN 68 1 10 CN 68 1 1! CNC 68 1 17 CNRA 68 1 64) LE# UNIT BYTES API 4 LB 4 LB 4 F/MM 4 VOLT 4 CTS 4 CTS 4 CTS 4 CTS 4 PCT 4 PCT 4 C/C 4 * DATA RECORD DEPTH CCL CN 10760.000 30.00000 0.0000000 10710.000 ...,~. OOOO00 22.47156 10660.000 3.000000 22.83585 10610.000 0.0000000 24.35413 10560.000 0.0000000 18.08397 10510.000 O,OOO0000 95.52655 (TYPE# GR SSN CNC 0.0000000 50,00000 0,0000000 40.54832 247.2522 26,47156 47.41075 226.5621 26.83585 59.25012 213,018t 28,354!3 26.52644 238.0243 22,08397 91,18581 1 36. 2060 99,52655 O) 994 BYTES * TTEN CSSN CNRA 0.000000 50.0000 0.O00000 950,097 247,252 0,8761 09 932.342 226,562 0.866969 933.706 213.018 0.831002 914,524 238,024 0.100456 913,251 136,206 0.409839 2 2 OE-01 3 1 8E-01 3 1 6E-01 7 0 5E-01 TEN LSN -100,0000 0,O000000 115.2369 86.64795 1.012296 78.56891 -14.06020 70.80742 -22.56177 95.64415 -22.50351 22.32906 SPD CLSN 0.0000000 O.O000000 24.99750 21 .6o199 25.03911 19.64224 24.99750 17.70186 24.99750 23.91104 24.99750 5.582262 TOTAL DATA RECORDS STARTING TAPE DEPTH FILE TRAILER **** 30 1 0760, O0 ENDING TAPE DEPTH = 10480,DO **** TAmE LIS 89/18/05 TRAILER **** TOTAL RECORDS IN THIS [OGICAL TAPE : 103 **** REEL TRAILER *~** LIS 89/18/05 ATLAS 01 TOTAL RECORDS IN THIS LOGICAL REEL : 104 TOTAL RECORDS iN THIS PHYSICAL REEL: 104 End of execution: Mort 22 MAY 89 11:302 Elapsed e~:ecu~ion time : I minute , 37.0 seconds, SYSTEM RETURN CODE = 0 C{,]~,~PAhtY NA~,~E : ARCO ALASKA INC... wgl.,b ~!A~tE : D.,~. 4-26 FI~I,,,D NAME : PRUDHDE BAY BOROUGH ~ ~OPTN SLOPE ~P! NUMBgR ~ REFERE~CE NO : 95079 [$ Taoe Verification Listlnq ~hlumberger AlasKa ComputIno Center OPlGIN' : FLIC CONTINUATION ~ : P~EVIOUS ~E~h : CO~ENT : ARCO ~LASKA INC., PR~I!)?,IOE BAY, DS 4-26, 5002921520 **** TAPE NEADER **** 8MRViC~71 NAME : EDIT DA'r~: : 95t(t]/18 OPI~IN : FblC TAPF NA~E : g507g CONT'.I~U~.TION ~ : ~. P~EVIOLJS TAPE ~ CON~ENT : ARC[~ ALASKA INC,, PRUDBOE BAY, DS 4-26, 500~921520 TAPE PPuoHnE BaY CASK[) HOLE wIPELINE bOGS WELL NA~,E Ami NUMBER: OPEPATOR: LOGGING COMPANY: TaPW CREATION DATE: jOB NUMBER: OPEPATO~ WITNESS: SURFACE .LOC~TIU~ SECTION: TOWNSHIP: R ~ NGE: FN L FEb: FWL EI.,EVATI~N ( FT KEL, LY BUSHING: DERRTCK FLOOR: gROUND bEV~b~ WKL, L CASING RECORD ~ ST s'rwI~:G ?~D STPI~IG 3RD STRING PROD{.ICTION 5TNING 5,0~92J, 52000 ~RCO AL~SK,~ INC. SCHL, U~BERGER ~ELL SERVICES 18-MAR-95 95079 SCHWARTZ [%0I,KOV ATZ 26 1SE 429 65.00 64.00 28.00 OPEN W~]L,E CASING DRILLERS CASING 6IT SIZE (IN) SIZE (IN) DEPTH (FT.) WEIGHT ([.,B/FT) 9,500 7,000 10865,0 29,00 5,500 10246,0 17,00 CURVE SH.[FT [)ATI - AbL PARSES T(1 ST~NDARD(MEASUPED DEPTH) PAGE: :tS Ta!~e chlumher ~AS Verification Listino get AlasKa ComputinO Center E[.~I'N~i; CURVE FOR SHIFTS bDWG TOOL CODE: BCS !.,DWC. CU~'V~ C('j)}SE: CR PASS N[.)~E~ER: DATE Ii,,OGGED ~ r4 ASEL.][ N E DEPTH 88888,0 !0730,0 ~0701,0 ~069~.5 10692 0 ,o68 :o 10677,5 ~.0669,0 1.0658,0 ! 0655,5 ~0644,0 1 064~ 0 10628,5 ~0621,0 10593,0 10586,0 10577.0 ~,0569,0 ~056~,5 10547.0 !0539.0 100,0 PE~ARKS: ........ --EQUIVALENT GRCH CNTG 88888 88888,5 I0730,5 ~069~.5 ~0692.5 10684.5 10677.5 10670.0 1,0658,5 10654.0 10644.5 10640,0 10628.0 10623.0 10620,0 10610,5 10592,5 10584.5 10576.5 10568.0 10561..5 1.0547,0 10538.0 99,0 100,0 21-~AR-1995 10:22 DEPTH---.------- '[~4E INFORMATION PER'rAINING TO TME OPEN HOL~; LOG SUCH AS .baGGING DATE LOGGING CO~.~ANY. PASS NUMBER AND RUN NUF,IBEP WAS N6T PROVIDED wITH THE TAPE SUPPLIED By THE TEE DEPTH CORPECTION SHOWN ABOVE REFLECT CASED HOLE GW TO OPEN HOLE GR AND CASED HOI.,E E{',IPH TO OPEN HOLE GR. ALL UTH~iR CNT CIlRVES WERE CARRIED WIT~ THE ENPH SHIFTS. PAGE: **** FILM NEA!)E~ **** FILE NA~E ! JOlT ,001 SERVICE : Fbi(: VER~IUr~ : O01C01 D~'~ : 95/03/18 ~!lX REC SIZE : 10~.1 Ell~E TYPE : LO L~ST FII,E : Tame Verification Listin~ :hlumberger A!as~a Computino Center 21-MAR-J995 10:22 EDITiiD CURV~]S DeDtb shifted and clipped Ci.lr'ves for each pass in separate files. PASS NUUBER: 1 D~PTH I MCREk~Et~T: 0.5000 L[)WG TOOL CODE START DEPT~{ STOP DEPT~{ r,~CH 107 . 04 0 CNTC 10730.0 10404.0 CURVE S;.IlWT DATA - PASS TO P~SS(f~EASURE',D DEPTt4) BASELINE CURVE FOR SINIFTS ----------EQUIVALENT UNSMiFTED DEPTH---------- BASELINE DEPTH ~E~A~KS: T~IS FI[,E COST,INS PASS ~J. OF T~E CMTG. MO PASS TO PASS SHIFTS WErE AD~LIE[) TO THIS DAT~. LIS FOR~AT DATA PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EM ** 1 66 . 2 6~ 0 3 73 64 4 66 1 5 66 6 73 7 65 8 69 0.5 9 65 FI 11. 66 16 12 6~ 1~ 65 0 15 6~ 68 16 66 1 0 66 O IS ~ame Veri, ficat:ion Listlnq :hlumberger .~lasKa Computin.,q Center 21-M'AR-} 995 I0:22 PAGE ** SET I.D NPH~ CNTG PU-S 50~, E~P~ Ck2TG PU-S CPHI CNTG PU-S 501 NPAT CNTG CRAT CNTG ENRa, CNTG 501, NCN'r CNTG CPS 50 P'C,N T CNTG CPS 501 CFTC CNTG CPS C~TC CNTG CPS 50~ CFEC CNTG CPS 50~ CNEC CNTG CPS 50 G~C~ CNTG G,~PI 501 TENS G~ E~ ~ bOG TYPE CL, ASS ~40D NUMB SAMP ELKM CODE (HEX) 014 O0 0 O0 1 1 4 8 O0 00000 0!4 O0 000 O0 0 1 1 1 4 68 0000000000 014 O0 000 O0 0 I 1 I 4 014 () 0 000 00 0 1 I 1 4 014 00 000 00 0 1 1 ], 4 014 O0 000 O0 0 I I 1 4 01,4 90 000 O0 0 I 1 1 4 0 ~. 4 00 000 00 0 1 I 1 4, 014 O0 000 O0 0 1 1 1 4 0!4 O0 000 O0 0 1 ~. 1 4 O14 O0 000 O0 0 1 I I 4 0!,.4 00 000 00 0 1 ! 1 4, 014 O0 000 O0 0 1 1 1 4 01 4 O0 000 09 0 1 1 1, 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 CNTG hR 501,014 O0 000 O0 0 1 1 1 4 68 0000000000 BCS GAPI 50101,4 O0 000 O0 0 1 1, 1 4 68 0000000000 * * D A T .a * * DEPT. 10827,500 uPgI.CNTG -999,250 ENPH,CNTG _-~99g 250 CPH.T.,. CNTG N~AT.CNTG -999,250 CR~T.CNTG -ggg.250 ENRA. C~,~TG -_, 90:250 NCNT.CNTG FCN~,CNTG -999.25() CFTC.CNTG -g99,250 CNTC,CNTG -999,250 CFEC.CNTG CNEC.CNTG -909,250 GRCH. C~<'T(; -qgg,~sO TENS,CN'TG -999,250 GR.BCS DFpT, 10404,000 N PM i. CN'.['G 49,550 ENP},{, CNTG 47,621 CPHI,CNTG NPAT,CNTG 4.359 CRAT.CNTG 4,121 ENRA.CNTG 6.261 NCNT.CNTG FCI'4T, CNTG 330.156 CFTC.CNTG 353,553 CNTC.CNTG 1460.090 CFEC.CNTG C~EC,CNTG ~6Q9,895 GRCH,CNTG 85.~25 TENS,CNTG 1515,000 GR.BCS ** END [)F DATA -99g,250 -999,250 '999,250 64,100 44,563 ~534.1~7 431,249 -999,250 **** FILE FILE NAME SFRVICE DATE ~AX RFC 5TZ~ FTL,~ TYPE: LAST FII,E TRAIl, ER **** : EDIT . O01 : [:'L !C : O01Cnl : 95103118 : 10.'2.4 : b () [$ Tape Verificatior~ Listin¢~ ~-hlur, berr?~er' AlasKa Computln0 Center 21-~qAR-1.995 1.0:22 PAGE: ***, FTLF HEADFR FILE NA~E : ED!% .002 S~;.RVICE : FLIC V'ERSIO?~ : O0~COl D~TK ~X ~KC SIZE : 1.024 FILE TYPE : LO LAS? FI bF': HEADER F."II~F NtJ~4BER: Dep P~$8 N DEPTH ~'~I LF S t.,DW eNT ~URVE SHIFT BA. SE[,INE i, D W G P~SS CURVEI!~ th shifted and U'~BER: I NCRE~.'EN T: G TOOL cllpoed curves 2 0. 500O START DEPTH 10730°0 for each pass in separate files, S~OP DEPTH 10404,0 10404,0 DATA - PASS TO P,ASS(HEASURED CURVE FO~ SHiWTS CUPVF CODE: GRCH MUmBleR: 1 .......... E 0 ! I I V A L E.; N T GRCH C N'.i?G 1C. 729.5 10716,5 ~071~,5 10710°0 1070~,5 ,! 07135 °n .1. 0702.0 10697,5 1069~to5 1.0693,n 1. 069.~ .5 1066 ~J. 5 1(;6B6,5 1(~68a,5 1.06~2,0 1 O68 1,0 10676,5 10672.5 1_06~9.0 0666.0 BASELINE ] 0729,5 } 0716,5 ~0713.5 ~()70~.5 !070~.5 ~ 0701.. 5 10697 5 10693~5 ~ 069~, 5 ~0691.0 ~06~.5 ~068~.5 ~0681 .5 ~0680.5 ~0676.5 10679.5 ~066~.5 ~0665.5 DEPTH) UN,SHIFI. E.L DEB H ..... --- Tape Ver!ficstion t, istin~ :hlumberger AlasK8 Compu. tJ.n.g Center 21-~4AR,-1905 10:~2 PAGE~ o69 ~. 5 065 , 5 0653,5 0652,5 064.9,5 064:8,5 0645,5 0641,5 0637,5 0625,5 0621,5 061.7'5 060~.5 0605,5 0604 5 O60 ~ ~ 5 0597,5 0596,5 0592,5 0589,5 05~5 5 0584 5 058O 5 (.)576 5 0573 5 0572,5 0569,5 0568,5 0563 5 0557 5 0553 5 054O 5 ~0548,5 .1 O545 5 10541,5 ~0537,5 1.0531,0 !.052~,5 10527.5 10524.5 10518,0 1050~.5 10504,5 !. 0500 ~ lO494.n. 1o497..5 0488 5 . 0487~0 ~ (;477.5 ~ 0472.5 .1. 0z~69,5 ! Oat, 4,5 1.0653,0 1,0608.5 0605.0 10597,0 10592,5 10584,5 1O580,0 10576,0 1.0572,5 1056~.0 10549,0 10544.5 10528.5 10525,0 10509.0 ~050a.5 10500.5 10497.n 10492.0 1048 ~. 5 1 (:479.. 5 1 ()A69.0 10464,.5 10661.. 5 1,0657.0 !. 0653.5 1, o64e., 5 1.0646.0 1064~.5 10638,0 10626.0 10621,5 .10.617,0 10605.0 10601,5 10597,0 10,589,0 10585.5 10573.5 10569.0 10564.0 ~0558.0 1,0553 5 10549~5 .10546.0 1,0542,0 10537,5 10530.0 1O527.5 1.0519.5 1u493.5 10477,5 !046~.5 ['$ Ta~e Ve,r.f~icatio. l.,istIno :hltlmberqer A]asK, a ¢'~omput,Incl Center 10:22 1 0460,5 10460.0 1 0448,5 !,0448,0 ~. 0444,5 1, 0443,5 1044,1,5 10441 ~, 0440,5 l 0a, 40,0 ~, 0~36,5 ! 0436, O ~ 04'2~,5 1O424.5 10a, 24.0 .100.0 99.5 ! O0 !~EMARKS: THIS FILE CONTAINS PASS #2 OF THE CNTG, T~E DEPTH CORRECTI{}NS SNOWN ABOVE REFLE:CT PASS ~2 GRCH TO PASS G~C~t A.~,~D PASS ~2 ~:NPH Tn pASS ~1. gNPH A L 0I. ER CNT ' l'i..F: ~:NPH SNI~TS CURVES WE;RE CARRIED WI'TH "i , . LIS F~RUAT DATA PAGE: DATA FOR'~AT SP .CIFICATION RECDRD ** TYPE ¥ ALUE; mm 1 66 0 2 66 0 3 73 6O 4 66 1 $ 66 6 73 7 65 ~ 68 0,5 9 65 It 66 17 lP 68 13 66 0 14 65 FT lfi 66 68 16 66 1 0 66 mmmmmmmmmmm!MM m m m Mmm mMmmmmmmmm !D mRr3gR ~ bOG TYPE C[.~ASS ~.![.)P NUMB SA31P ~bEM CODE (HEX) !)~PT FT 50~,0 _ O()g 0 2 1 4 n8 O0 O 0000 NPHI CNTG PU-S 50~014 O0 000 0O 0 ~ 1 1 4 68 0000000000 Tape Verification Listino :hlumberger AlasKa Computino Center 21-MAR-1995 10:22 PAGE: L. N.I. I'..q.E,[~ C~'I API I API A Ni,IMB ,SI~, R~ .... R pR C II) ORDER # hDG; TYPE CPA~S ~[)D NLI~B SAMP ELE~ CODE E N P ~ t G P [ ;- ~ 1, n 14 00 00 00 0 CDJ{T CN,G PU-S 50~()~ O0 000 00 0 2 1 ~ 4 68 0000000000 T' 1 4 68 000 0 000 NRAT CNTG 50! 01,4 O0 000 O0 CRAT CNTG 50~01,4 O0 000 O0 ENR~ Ci'~ TG 50~.014 00 000 O0 NC'NT CNTG CPS 501014 0(,) OOU OO FCNT CNTG CPS 50~014 00 ()O0 00 C F T C C N T G C,D S 5 () i 014 00 0 t) 0 00 CNTC CNTG CmS 5010:14 00 000 00 CFEC CNTG CPS 501014 00 000 O0 CNEC CNTG CPS 501014 00 000 00 0 2, 0 2 0 2 0 2 0 2 0 2 0 2 0 2 0 9 1 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 6~ 0000000000 1 4 68 0000000000 1 4 68 0000000000 1 4 68 0000000000 i 4 68 0000000000 1 4 68 0000000000 DEPT. 10730.000 NPHI.CNTG 21.755 ENPH.CNTG 22 42,4 N~4T. CNTG 2 ,629 CRAY. CNTG 2.596 ~J ~.a .CU'.,.rG . :601 FCNT.CNTG 986.768 CFTC.CNTG ~()28 252 CNTC.CNTG 2609 351 CNEC, CH"CG 279q,781 GRCH, C~'OT~ 999:250 TENS,CNTG 1550:000 CPHI ,CNTG NCNT CNTG CFEC."CN'~G 19.491 2651,574 608,467 ** END OF DATA ** **** FT[jE TRAI!,ER **** FILE NAME : EDT3' .002 SERVICE : ~LTC V~RSION : O01C01 D~T~ : q510311.8 MAX REC SIZE : !024 FILE TYPE : LO bAST FII~E : **** FILE ~EADER **** FILF NA~E : ~I.)IT ,003 SERVICE : VI'.~IC VERSION : O0!CO1 DATE ~AX RFC SIZE : 1.024 FILE TYPE : LAST FILE : FTLW [{E~DER iS Tane Vet!fl, cation Listinq 'blumberqer Alaska Compt,ltinq Center 21-~AR-1,995 10:22 PAGE: and clipped 3 ,,~000 curves for each Pass in seoarate ,files. F T L w ED'.[ TEl:) CURVES DePth Shifted PASS DEPTH INCREMENT: F*!.L~ SIJ M~q ~ ~Y LDWG TqOt CODE C N T G , VE SHIFT DAT.A PASS TO P *S ....... '~ . ~ ~" ~ .... BASE~,IN'E CURVE .~.,.R oHIFTS BASELINE DEPTH 10730 10726 ! 0722,, ! 071,[~ 1 07 0 Q 10706 10702 1069~ 10694 1069o !068.6 1 ()68~ 1.0678 10674 10646 10642 ~0638 !061.4 10610 10606 ~ 0602 10598 10590 l_05~fi ! 0569 ~056 1056 1056 1056 1055 1.055 1055 !055 5 5 5 5 5 5 5 5 5 5 5 5 5 5 5 .5 .5 ~ 5 ,5 ,5 ,5 ,5 .5 ,5 .5 5,5 ~.5 7.5 4,5 --- ....... EQUIVALENT 1.0730,5 1 O727.0 ~ 0722 5 10710,0 10707,0 10703,5 !.069o,n 1.0695,5 10691,5 !0687.0 ~0~83,~ il 067q, ~0675,0 10647.0 J0643.5 ~0639.0 ~0615,0 lOalO.5 10606,5 10603,0 1059~,5 1.059o.q 10587,0 I O570, n .~ 0567,0 10566,5 10563.5 10562.0 i055q,n !.055 R, 5 I. O555.0 1 O554.5 I...tNSHI~,.I. ILD DEPTH ...... .... [$ ,rape Veri~f.J. cation bistino .-hlumberqer AlasKa Computlr~.o Center 21-i'qAP,-!. 995 1,0:22 PAGE: 10 1.0550.5 .10549,5 ,10546,5 10545,5 1,0542 5 I 0541 5 !, 0538 5 10534 5 1. 0529 5 i 0529 0 I 0525 5 ! 0524 5 ! 0509 5 1 0506,5 !. 0505,5 10501 .5 10497.5 ! 0494 5 ,.,!,0493 5 !04@F, 5 10483 0 1. 0473 5 10469.5 ~ 04,.61,5 !. 0457 5 ~0450i~ ~ o44g ~ ~ 0445.5 1.0442.5 1 0441 5 ~ O438."5 ~0437.5 ~0425.5 ~1 042:1,. 5 10417.0 1.0413.0 100,0 LTS FOR.~ AT 1. 055(}, 0 10546,5 10542,0 10530,0 ! 0526.5 1O510.5 1. 05O6.0 1,0502.5 10498.0 1.0493.5 10473.5 1,0469.0 10461.0 10457,5 10'44Q,5 1..0446.0 ~0442.0 I (i:)438.5 10430.5 1 O426.0 10421.5 10 0.0 1.(3550.5 1.0547.0 1.0543.0 10539,5 10535.0 10530.0 10525.0 10507.5 1()501.0 10494,5 1,0485.0 10469.0 !0451.5 10442.0 10438.0 10415.0 10412.5 99.5 THIS VILE CLqf,,!TAI'r,tS PASS ~3 OF TIlE CNTC,. T!qE DEPTH CoRPE;CTI[;~,~S $}tClwf,,! AB(.IVE RE~'t, ECT PASS ~3 GRCH TO PASS GRCH AI'~D PASS ~3 ENPH TO PASS ~1, [TNPH. A[.~[., OTHER CNTG CI.lt~vgS WEPE CARRIED ~'ITN THE ENPH SHIFTS. DATA #1 wane ~Verlf.!catl. on l,isting :hlumberger AlasKa Computlnq Center 1,0:22 ** R , . ....... . A~A FORe, AT S'PECIFICATI[";tN PECO~[~ ** ** 0 0 60 1 0.5 17 0 1 1 DFPT NPH? CN E~}PH CN CPHY CN N~IT CN C~AT CN ENRA NCNT CN FCNT CN CB,TC CN CNTC CN CFEC CN CNEC C~ GPCH CN TENS CNTG ERV LINI'T: SE~V CE /~PI ORDER # hOG "'"F;'" ..... ....... 50101., O0 TG PU-$ 501014 O0 000 O0 () TG Pt!-S 501014 00 000 O0 0 TG PU-$ 501.014 O0 GO0 O0 O T G 5 0 1. 01. 4 0 0 0 0 0 0 0 0 TG 501014 O0 000 O0 O TG 50!.01,4 O0 000 00 O TG CP,5 501014 O0 000 O0 0 TG CPS 5010~4 O0 OOO 00 0 TG CPS 501 O14 O0 ()00 CO 0 TG CPS 501014 O0 000 O0 0 TG CPS 50101 4 O0 000 fi0 0 TG CPS 501014 00 OOO O0 O TG G,~PI 501014 O0 OeO O0 0 [.,B 501014 O0 OOC O0 0 , ~ APl ~Pl: ILK NU E ~E, PPOCEBS TYPF CLA~S MC')[) NL,IM,B SA~,P EGEM CODE (HEX) .;---;;--. ...... . ......... ............. .. ........ .-;;-- 0 0 0 ,3 1 4 68 00000000 1 1 4 68 0000000000 3 3 I 1 4 68 0000000000 3 1 1 4 68 0000000000 3 ! I 4 68 0000000000 3 1 1 4 68 0000000000 3 1 1 4 68 0000000000 3 1 1 4 68 0000000000 3 1 1 4 68 0000000000 3 1. 1 4 68 0000000000 3 1 1 4 6~ 0000000000 3 1 1 4 b8 0000000000 3 1 1 4 68 0000000000 3 ! I 4 68 0000000000 3 1 1 4 68 0000000000 mmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmmm#mmmmm 11 DEPT. NmA~.CNTG FCNT.CNTG C~EC.C~TG 10730.000 2.789 852.750 2601.375 NPNI, CNTG CRAT. CNTG CFTC. CNTG GRCH. C~!TG 24.EB4 ENPH.CMTG 32.073 CPHI.CNTG 2.76~ ENRf~.CNTG 4.871 NCNT.CNTG ~99.~75 CNTC.CNTG 2365.383 CFEC.CNTG -q99.~50 TEN$.CMTC 1490.000 20.770 2368.625 534.031 IS Tare Vertficatio~ !,istl. no :hlUmberger Alaska Comput.~.n0 CenteX' 2 ~ -,~'!AR-~ 995 .PAGE: 12 END OF DATA **** FILE TR A I I,~'[!:F: FILE NA~E : EDIT ~ERVICE : FblC VERSION' : 00~, CO1 D~TF : 95103/18 ~ Al XREC 61'g~; : FILE TYPE : 1.,O L~ST FI I,E : **** FILE HEhDE~ **** FILE NA.~fE : EDIT .004 SERVICE : FLIC VERSION : D~'rE : 95/03/18 M.~,X REC SIZE : ~,024 FII..,~ TYPE ~ LO LgST FILE : FILw [lEADER AVEPAGED Compensated ¢;eutron: Arithmeti, c average o~ edited passes for all curves. Pulsed Neutron: UBaverage0 edited Pass I Gamma RaV and backround counts; arithmetic average of edited Static baseline D~sSes for all other curves. DEPTH I~C~E~ENT 0.5000 P~SSES INCI..,UDE¢ IM ~VERAGE LDWG TOOL CCiD~; PASS ............ cE~ARKSI T~!S ~'~[1.,~ COiqTA~S TH~ A~ITUMETIC AVERAGE OF THE THREE C~'~TG DASS~S. ALL DEPTH CORRECTlY[iS WF,~E ~,IADE BEFORE THE AVERAGE wAS S FORMAT DATA '$ Tar. e Veri.~!ication L, istl. r~c~ :hltlmt~erger AlasKa Computil~.a Center 2', I-~IAR-1995 I0:22 PAGE; SET TYPE - 64EB ** TYPE ~EPP CODE VALUE 1. 66 0 2 66 0 3 73 5~ 4 66 ~. 5 66 6 73 7 65 9 65 1~. 66 12 6S 13 6~ 14 65 15 66 16 66 0 66 ~ 5 ** SE;T TYPE - CH~%N * ID DRDE~ ~ D[~PT FT 50 ],014 00 NDHI C['~AV PU-S 5()~0~,4 O0 000 NRAW CNAV 50~.0~ 4 oO 00() CDH~ CNAV PU-S 50~,.0~4 O0 000 CDA~' CNAV P!I 501014 O0 ENPW CNAV PU-S 5010~.4 O0 000 EK'R~ CNAV CPS 50!0~4 O0 000 NCNW CNAV CPS 501014 O0 O0O FCN~ CNIV CPS 50~914 Ou 000 CWTC C~'~ A V CPS 501i~.a 00 000 CNTC CN,~V CPS 50!01a 00 CFMc C;~AV CmS 50J. 0!4 O0 CNEC CNAV GAPT. 501014 G~C~ CB~V L8 50~014 00 APl A TYPE CLASS .......oo PI FII.,~; M NUMt~SIZE REPR PRDC ESS [{{,)D N{I~B SA~P MLEM CODE (HEX) ;'"X ....... ......... ' " '""';"" ! 4 60 0000000 O0 00 0 4 1 1 4 68 0000000000 O0 0 4 1, 1 4 6~ 0000000000 oO 0 4 1 I 4 68 0000000000 O0 0 4 i I 4 68 0000000000 O0 0 4 1 1 4 68 0000000000 oo o ~ 1 1 4 68 0o00000000 O0 0 ~ 1 1 4 68 0000000000 O0 0 4 1. 1 4 68 0000000000 OO 0 4 1 1 4 58 O00000OO00 OO 0 4 1 1 4 6~ 0000000000 O0 0 4 1 1 4 6~ 0000000000 O0 O 4 1 1 4 68 O000000OO0 O0 0 4 ! 1 4 68 0000000000 1,3 ** OATA ** DEp'v. 107 30. 000 b!PHI. CNAV CROAT. CI~AV 31.871 EL, P H, FCNT. C.~iAV 9a-9.0o2 CFTC.CHAV C~EC. C[.~ A V -999.250 GRCH. C~,~AV 23.495 NRAT.CNAV 2.777 CPHI.CNAV 4.~48 EERA.CNAV 2458.305 MCNT.CNAV 24.5~.~q CNTC.CMAV 555.695 CFEC.CNAV 1533.180 2,691 915.351 2687.518 IS Tar~e Ver~.~icat~.on List~nq .~hlumberger Al. asEa Comput. lng (;enter 10:22 ** END OF' DATA ** **** FILE TRAII, E~ **** FII.,~ NA~E : EDIT ,004 VERSION : 00~.C01 D~T~i : 05103/'}8 MAX REC SIZE : ~024 FILE TYPE : LO LAST FILE : **** FILE H~A[)ER **** FILE NA~E : EDIT .005 SERVICE : WL!C VERSION : O01CO1 DATE; : 95103/18 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE WEADMR FILE NU~BER 5 RAw CURVES Curves and 1o0 header data tor each pass in separate P~SS NI,IMBER: 1 DFPT ~.~ IMCREMENT: 0,5000 FTLF SUmmaRY VENDOR TflOI.., CODE START DEPTH STOP DEPTH CN (1 0 lO . , LOG HEADE~ DA~A m~TE LOGGED: S[)FTWA~E VERSION: TI~E LOGGE]~ ON Bf~TTt')~!: TD DRILLER (FT): wi) .LOGGER (FI): wOp LOG I>~TERVAL (~'f'): P. OTTOM LOG INTERVAL (FT): LOGGING SPEED (FP~R): DEPTH CrJr4T~Of, ~S~[) (YES/MO): TOOl., ,S']~I~G (T[JP TO VEhDO~ TOOL CODE TOOL TYPE ~i-FEb-95 40.2 1954 t092o.0 10732.0 lOaO0.O 10728.0 1800.0 NO ~lles: raw backoroun, d pass In last fi 2t-FEB-95 !iS Tape Verification bistinq .~hlumberoer AlasKa Computl. nq Center 21-~AR-1995 10:22 PAGE: 15 CNTG C,NTG CNTG $ T ELF,~,~ ETI~ Y CARTRIDGE G.6M~A ?,AY CARTRIDGE COmPENSATeD NEUTRON CC~PENSATEO NEUTReN COMP[~]NSATED NEUTRON ROREHDLE AND C~SING [)ATA DR%LLERS CASING DEPTH (FT): LOGGERS CA, SING DEPTI-{ (FT): BOREHOL[~] CONDITIONS FLUID TYPE: FLUID DENSITY SURFACE TE,~PERAT[tRE (DEGF) BOTTOM F~OI,,E T~q'oE~ATUPE (DEf~F): FLUID SAblN!TY (PPM) FLUID LEVEL (FT) FLUID RATE WATER CUTS (PCT): GAS/OIL RATIO: C~{OKE (DEG) TCCB 421 SGC SA 60 CNC GA 125 NSR FA 2290 1,0522.0 NEI,ITROM TOOL TOOL TYPE (EPI'r~ERa~L (JR THERaAI,,): M~T~IX: MATRIX DENSITY: HOLE CORRECTION DEAl') CRUDE EPITHERMA, L SANDSTONE 2.65 BLIj~TL!NE C(]U~51T RATE NORMALIZATION IN OIb ZONE ?0p N[IPM.~LIZING WINDOW (FT): BASE NORMA[,IZtNG WIND[]W (FT): DLUE[.,I~E COUNT RATE SCAL~']S SET BY FIELD ENGINEER FAR COllie,iT RA~E b~]w SC.ALE (CPS): W~ CFOUNT ~ATE HTG;'~ SCALE (CPS): NEaR COONT R~TE bOW SCALE (CPS): k'E~R COUNT RATE HIGH SCALE (CPS): # RFMSRKS: TOOL STANDOFF TIED INT[] MMCS DATED LOGGED ] 3/~ CNT-G (EPlTMERMAL ~ND T~ERMAL DETECTORS) PU~PED OE~[) CRODE BEFORE LOGGING wELL... 400 9BLS. bOGGED PASSES ~T ]0 FmM ~{ILE INJECTING 1.5 BPM (400 PST). Gh~qA R&Y bgG A~OVE 10530' NOT AFFECTEO BY PREVIUO$ RST LOG. BELOW ~0550' G~ COUNTS HIGH FROM RST ~OG DONE JUST ~EFnRE CNL, $ [.,IS FORNi~T iS Tane Verification bistinq :hlumberqer AlasKa Comp~lti. ng Center 21-MAR-1995 i() :22 PAGg: 1¸6 DATA FOR~,~AT SPEC!'FICSTIf]~,~ RECORD ** SET TYPE - CHAN ** . .... ....... . ........... .........; .. -.......-~--~...- .......... .. .....-.-~... ......................~:)~ :: :oJoT~ 'oo ..... o:~'":o ..... o" ...... $ '~. ............ 1 ~ ..... "'~. .... ":"""'""":""o ooooooo ' P'I 50!0t4 O0 000 O0 0 5 1 1 4 6~ 0000000000 EUR~ PS1 C~tEC PS1 RCEF PS!, RCE~ PSI TNpN TNR~ PSi RTN~ NPO~ PS1 RCNT PSi RCFm CNTC PS! CFTC 501014 O0 CPS 501014 O0 CPS 50~0~4 nO CPS 501014 O0 CmS 501014 PU 501014 O0 PU 501.014 O0 501014 O0 501014 OO pll 501o14 oo C~S 501014 00 CPS 501014 C~S 501,014 00 CmS 501014 00 000 O0 000 nO 0o0 O0 000 O0 000 O0 000 O0 000 00 000 O0 OOO O0 000 O0 0 O 0 00 00 0 00 0 o 0 00 000 O0 4 4 4 4 4 4 4 4 4 4 4 4 4 4 68 68 68 6" 68 68 68 68 68 68 68 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 Gq PSI GIPI 50'0!4 0() OOO O0 ~ 5 1 I 4 68 0000000000 TEN m8J hR _ ..Orz~ ~0 . 00 0 5 6~ 00000000 ** L)AT~ ** 'S Ta. De Verification Listing :hlUmberger Alaska Computing Center 21-~AR-1995 10:22 PAGE~ 17 DFPT 10743 000 ~C PSI, 20.2 412 pH PS1 ~1,937 RCNT PS~ 2500,408 GRIPS1 ~5.625 D~iPT. 10396.000 E!qPil.PSl CMEC.PS1 ~967.994 PCEF.PS! TwP+I.PS1 52.867 T!qRA.PS1 RCMT,P$~ 1685,408 RCFT.PS1 G~,PS1 55,563 TEMS.PS1 ** EMIl) OF OAWA ** 37.4'79 ENRA.PSI 488.789 ~CEN.P$1 2.7b0 RTgR.PS1 ~72.08~ CNTC.P$1 1055.000 43.124 ENRA.PSI 520.393 ~CEN.P$1 4.292 RTNR.PS1 348.580 CNTC.P$1 1515,000 2522,816 MPOR,PS1 2458.273 CFTC,PS1 5 890 CFEC.P$! 3065~g52 NPHI,p ~ PSi 4 087 NPOR..~$1 1617~590 CFTC,PS~. 488.381 24,~39 2.1, 37' 906.923 503,914 52.677 51.51.9 362.9~2 **** FIbE TRAILER **** FILE NA~E : EDIT .005 S~RVI, CE : WblC VERSION : 001C01 DATF : 95103115 MAX REC SIZE : ~0~4 FILE TYPE : LO L~ST FILE FILM NA~E : EDIT S~RVICE : FLIC V~RSION : 001C0! D~T~ : 95/03/18 ~AX RFC SIZ~ : 1024 FILF TYPE : T..,O LAST FiLE FIbF HEADER F%LV NUMBER 7 RAW CURVES Curves and loq header data for each pass in separate PASS NUMBER: 2 D~P~}t I~C~E~ENT: 0.50o0 FTLF SU~bARY VENDOR T{)OL CODE START DgPTN STOP DEPTH c[i'rG 10742.0 0 $ LOG HEADER DATA DAT~; bOGGED: files; raw bacKaround pass in last fi ~l-FEg-95 !Fane Verlflcation bisti, n.o 'hlumherger Alaska Computl. nq Center ~I,-MAR-~ 995 10:22 PAGE: 18 ~OFTWARE VERSION; TD I)RILL~R [FTI: TD LOGGER(FT): TOP LOG INTERVAL (FT): ~OTT0~ LOG i~ITERVAi,, (FT): LO~G!NG SPEED (FPH~): DEPTH COMTROL USED (YES/MO): 40,2 1.95.4 1O820 0 1,0400.0 10728.0 1,,800.0 NO 21 -FEB-9 5 TOOL STRING VENDOR TOOL CODE TOOL TYPE CNTG CO~E~iSATED NEUTRON TOOL NUMBER SGC SA 60 CNC GA 125 CTSM BA 328 NSR FA 2~90 BOREHOLE AM!) CASING DATA OPEN HObE BIT 8TZ~ DRILLERS CA~Ii~]G D'~' EPr,t (FT): LOGGERS CASING D~PT;'{ (FT): 10522.0 ROREMOLE CONDITIONS Ft, LtlD TYPE: FLUID DEMSITY SURFACE TEMPERATURE (DEGF): BOTTO~ MDbE TE~PERATdRC (DEGF): FbUID SALINITY (PPB): FLUID LEVETj (FT) FLUID R~'r~ W~T~ CUTS G~S/OrL RATIO: DEAO CROOE TOOL TYPE (EPIT~ER~aL OR THERMAL): }~&TmIX: M~TRIX DEN$I'rY: HOLE COPRECWlON (IN): EPITHE~MAL SANDSTONE 2.65 BLUELINE COIINT RATE NORMALIZATION IN Olb ZONE TOP NOPM~blZING WINDON (F'r): 8AgE NOR~AT.,IZING W!Nf)OW gDtlELINE COUNT N.a. TF~ SCAbES SET BY FIELD ENGINEER F~.R CUItNT RATE LOW SCABE (CPS): FAq COUNT RATE HIGm ,.qC~LE (CPS): NEaR COUNT RaTE LOW $CabE (CPS): ~JEaR COUMT RaTE HIGH $CA!.E (CPS): # RFMLRK$: TOOL STANOOFF (IN): TIED INTO t~HCS PATED 3-8-86 iS !rape Verification Listing. ~hlumberoer AlasKa Computin~ Center 21-~AR-1995 10:22 LOGGED 3 3/8 CNT-G (EPlTMER~,IAL AND T~{E.~.M/%L DETECTORS) PIlhl, ~.D D~;,AD C~tjDE; E~]FOR. E LOGGING WELL,.. ,~00 BBbS, LOGGf;D PASSES .AT ]0 FOg WHI[.,E INdECTING ( 400 PSI ], GA~A RaY LOG ABOVE 10530' NOT AF~'ECTED BY DREV'ItjOS RST bOG. BEI.~O~ 10530' (;R COUNTS HIGH FRO~,.~ RST BOG DONE JUST ~TS Fr,IRNAT DATA PAGE: 19 ** ~ATA FORMAT SPECIFICATION PECORD ** I 66 0 2 66 0 ] 73 72 4 66 1 5 66 6 73 7 65 B 68 0,5 1~ 66 14 1~ 68 13 66 0 14 65 15 66 68 16 66 0 66 ** S6T TYPE - CMAN ** '''NAM~ .......... SER~ U~i~'~~''~I A~i'';'i'';P .......... PI FiLE N~MB ..... N .~''~i.. ........... ZE REPR ~'''''''CES$ ID ORDt£R ~ LO(; TYPE CLASS MOD NUMB SA~P ELEI~ CODE (HEX) .............D~P~ ~'''~. ...... 1014 ~; .............. 000 O0 ~'''~ .... T ................. 1 4 g~ .........00000;';;'''0 0 ENPH PS2 PU 501014 O0 000 O0 0 6 1 I 4 68 0000000000 ENRa P$2 501014 CFEC PS? CPS 50!014 O0 000 C~.~EC P$2 CPS 501014 O0 000 nO 0 6 RCEV PS~ CPS 50%014 oo OOO O0 0 6 RCE[: PS2 CPS 50101.4 O0 000 O0 0 6 1. NPH? PS2 PU 501014 O0 000 O0 0 6 TNP~ P$2 Pll 501014 O0 000 O0 0 6 TN~ oS~ ~0101.4 O0 000 O0 0 6 ! RTNP PS~ 501U14 nO OOt) O0 0 6 bPO~ PS2 PU ~0!014 O0 000 O0 0 6 1 68 68 68 6~ 68 68 6~ 68 O000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 0000000000 Tame verification List.lnq C :hlumherger Alaska ComputinO enter 21-MA~-1995 10:22 PAGE: -...........-~ ..... .---:.-... ..... . ....... ............ ........ -;-----~ ...... ..-..-,..~-. ~c~',' ~s~ c~ ~o,o~ oo ooooo o ~ ~ ~ 4 6~ oooooooooo c~c ,s~cps~o~,o,,4 oo ooooo o ~ ~ ~ 4 ~ oooooooooo CFTC P$~ CPS50!.014 O0 000O0 0 6 1 I 4 68 0000000000 ~ ~s~ ~:~so~,o~ oo ooooo o ~ ~ ~ 4 ~ oooooooooo 2O ' ~T . E PS2 4 464 CFEC.PS2 l,)KP 10742 0()0 BNP;q. PS2 28.1,15 NRA. S' ' CMEC]PS2 2794,(.)5V F~CE.F. P82 626.438 RCEN', P~.. 2 2676,256 NP'HI,PS2 'I:NP~4 PS2 17.979 T~qPh,PS2 2 474 RTNR.PS2 2,525 N'POR.PS2 RCt~,*: [~S~ 2502.359 RCF'r. PS2 1009:171 CN'rC.PS2 2548.6'75 CFTC,PS~ G~.PS2 ~2'563 TEMS,PS2 975.000 DFP'r. 1,0387.000 KNPH.P$2 49.196 ENRA.PS2 6.385 CFEC.PS2 C~EC. PS~ 2,.691.371 ~CEF. PS 2 441.756 RCEN. ~S2 252~. 770 NPHI. PS~ TN [.,~, PS~ 54.708 NR~.:PS2 4.461 ~TNR.PS2 4.474 NPOR.PS2 RCNT.DS~ 137.3.544 RCF'r. PS2 305..307 CNTC*PS2 1.419.726 CF~TC.PS2 G~.PS~ 79.813 TEMS..¢$2 1450.000 ** EklD []F BATA ** 625.916 19.861 17.979 t049.490 421.500 55.748 57'675 314,928 **** F ~, !SE TRAI%ER **** FILE t,!.A~.,E : EDIT ,006 VERSION : O0~.C01 DaTF: : 9510:~I18 MAX RKC SIZ~ : 10.?.,4 FII, V TYPE : !.,0 L~ST FILE : **** FILE ~4 MA [.)KR **** FII, F NA~M : EDIT .007 SFRVICE : ~'1, I C VER$ I0:': : oO ! CO:l, DaTE : 0510:]/18 ,~AX RKC SIZE : !02~ FILF TYPE : LO [-' T k,F ;~EADER Tame Veri,(ication 1,0ist, Ir~q :hlumber~=er Alaska Computing, Center 21-~AR-1995 1,0;22 PAGE: 21 CURvEs Curves and lo<~ header data ior each pass in semarat, e PaSS NU,~4i!.~ER: 3 DEPTH I NCNE~E~IT: 0.5000 # F!L~ SLI~ARY VI~,;NDOR T~OL CODE START DEPTH , LOG STOP OEPTH DAT~C LOGGED: $OFTI~ARE VERSION: TIME LOG~ER ON · I) L)RILLER (FT) ~'D b0GGERfFT): ~('.)T".FO~ bOG INTERVAL (FT) I,OGGING SPEED (FPHR) DEPTH C[]MTR(]L USEt) (YES/NO): TOOL SI..~IMG (Tt']P T(] BOTTOM) VENDOr. TO[')!i., CODE TOOL TYPE C N T C C~JTG CNTG C ~ TG CMTG $ GA:~A R~Y CARTRIDGE COiqPENSATED NEUTRON COfqP~]NSATEi) NEUTHON CO'~PE~S~TEI') NEUTRON ,~OREHO[,E AND CASING DATA OPEN HOLE -BIT SIZE DRILLERS CASING DEPTH T, OCGERS CAS.ING DEPTH (MT): gi. IREHO[,E CONDITIO~gS FLU ID TYPE FLUID DENSITY (LB/Gl: SUPWACE TM~PE~AT~I~E (DEGF): BOTTO~ HOL~] TE~PERATtJ~E (DEGF): FLUID SALINITY (PPIS): FL!ltD LEVEL (FT) FI, UID R~TE ,~T ~ELLHEAD (BPM): WATER CUTS (PC'F): GAS/OIL CHOKE (DEC) ~E~IT~OM TOOL TOOl., TYPE (FPI'lTgE~MaL OR THKR~AI,): ~-thTg IX DENSITY: HObg CORRFCTiO¢~ (TN): files; raw background pass in last, fi 2I-FEB-g5 40.2 1954 10820.0 10732.0 1800.0 21-FEB-95 TOOb NU~BER SGC SA 60 CNC GA 125 CTS~q SA 32B NS~ ~.h 2290 10522.0 DEAD CR UD~_: EPITHERNAL SANDSTONE 2.65 '$ Tape Verification bist]nt~ :hlUmber¢ler AlasKa ComputfnO Center 21 -~,~AR-! 995 10122 PAGE: 22 # BLUEbINE COUNT RATE NOR~ALIZATiON ,IN OIb ZONE TOP MO~,~ALIZING wINDOW BASE NORMALIZING ~,,i'INDOW BLIntz]LINE COUNT RhT~ SCALES S~T 8Y FIELD ENGINEER VAR COUNT RATE LO~ SCALE (CPS}: FAR COUNT RATE F~IG;,.I SCAbE (CPS): NEAR CUUMT RATE 5[)W SCabE (CPS): NEAR COUNT RATE t,'{IGH SCAL~7: CCPS): T[}OL STANDOFF (IN)t TIC;I) INTO BHCS DATED POGGED ~! 3/~ C~}T-G {ED'ITF~ERMAL AND THERMAL DETECTORS) PU~.~PED DEAD CRUDE BEFORE LOGGING WELL,,, 400 BBL8, bOGGED PASSES AT 30 FPM WHILE INJECTING 1,5 (40O 2S'!), GAtq~A RAY LUG ABOVE 10530' NOT ~FFECTED BY PREVIOUS RST LOG. BEbOW 10530' GR COUNTS HIGH FROM RST bOG DONE JUST BEFORE CNL, LIS FORe, AT DATA ** DATA F'QRI'~AT SPECIF!C, ATI[7tN RECORD ** ** SET TYPE - 64EB. ** TyP~] REP~ CODE VALUE l 6~ 0 2 66 3 7.11 4 66 5 66 6 72{ 7 65 9 65 1~ 66 17 68 13 66 14 65 15 66 16 66 0 66 0 72 1 0.5 14 0 68 t IS Tame Verif. lcation l'..,istlnq zblumberger Alaska ComputJ..r~q Center 2J.-~AR-! 995 10:22 DEDT ENPH PS CFEC PS CNEC PS RCEP PS RCEM PS NPHI DS T~P~~ PS T~R~ PS R~NP PS RCNT PS RCF~ ~S C~TC PS Gm PS 0 ~. 0 ! 4 ... 0 t) 0 00 0 714001 6800000000 3 PU .~():1014 O0 000 O0 0 7 ,1. I 4 68 0000000000 3 501014 O0 000 O0 0 7 1 1 4 60 0000000000 3 CPS ~01014 O0 000 o0 0 7 1 I 4 68 0000000000 ~ CPS 50~. 0~.4 O0 000 O0 0 7 1 1 4 6~ 0000000000 3 CPS 501014 O0 ()00 O0 0 7 1 1 4 68 0000000000 3 CPS 501014 O0 000 O0 0 7 1 1 4 68 0000000000 31 p~t 50~.0!4 O0 000 O0 0 7 1 I 4 60 0000000000 3 PU 50 ~ 0,1.,4 O0 OOO O0 0 7 1 1 4 68 0000000000 3 501014 O0 000 O0 0 7 1 I 4 68 0000000000 3 50~,.014 O0 000 O0 0 7 1 1 4 68 0000000000 3 Pti 50.101 4 O0 000 O0 0 7 1 1 4 68 0000000000 3 CPS 501014 O0 000 O0 0 7 i I 4 6.8 0000000000 3 CPS 501014 O0 000 O0 0 7 ! ! 4 68 0000000000 23 * * I) A T A D~PT. CNEC.PS3 D.EP~ T~pN.DS3 R C ~.i'~. PS 3 GP .PS3 ** END OF 10744.500 2629.963 20.269 2435.485 02.750 10395. 500 3006.282 44.419 1.554.1o5 DATA ENPH. P$3 RCF~F. PS 3 TNRA.PS3 , C r'.C. PS3 TENS.PS3 RCEF.PS3 TNRA.PS3 RCFT.PS3 TENS.PS3 33.384 526.~33 2.643 887.906 890.000 40.249 543.~77 4.215 354.543 1395.000 ENRA,PS3 mCEN.PS3 RTNR,P$] CNTC.P$3 ENRA.PS3 RCEN.PS3 RTNR.P$3 CNTC.PS3 5.00! 251,9.081 2 697 2394~445 5.6,10 2989.594 4,043 1568.411. CFEC.PS3 NPHI.PS3 CFTC.PS3 CFEC.P$3 NPHI.P$3 NPOR.PS3 CF'TC.PS3 525.895 22.605 20.269 923.380 533.000 51,277 45.728 380.526 SERVICE VERSION DATE ~AX REC SIZE FILE TYPE L~ST FILE TRAi[,EP **** EDIT .o07 001C01 102,i [$ Tape Verlficat!.on Listing :hlumberger AlasKa Computin~ Center 21-~{AR-~995 10:22 PAGE: 24 **** TAPE T R A,I] LE~,~ SERVICE NA~E : ~DIT D.~TE : 95/0311.8 OPlGIN : M,blC T~PE ~A~E : 95~')7q CONTIMU ATI[.]N ~ P~EVIOUS TAPE COMMENT **** REEL TRA ILEP~ SFRVICE N~ME : ~D!T DA. TE : 95/03/1,8 ORIGIN : ,~ [,I C REEl'., ~AME : 95079 CONTINIJ/~TION # : PREVIOUS REEl..., : COM~E~T : ARCO ALASKA INC,, PRUDHOE B.i%Y, DS 4~26, 5002921.520 * ALASKA COMPUTING CENTER * ****************************** * ....... SCHLUFiBERGER ....... * ............................ ****************************** COMPANY NAFiE : ARCO ALASKA, INC. WELL NAFIE : DS 4-26 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292152000 REFERENCE NO : 98608 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/11/23 ORIGIN : FLIC REEL NAME : 98608 CONTINUATION # : PREVIOUS REEL : COF~4ENT : ARCO ALASKA INC., PRUDHOE BAY, DS 4-26, API# 50-029-21520-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/11/23 ORIGIN : FLIC TAPE NAME : 98608 CONTINUATION ~ '. 1 PREVIOUS TAPE : COM~fF2Fr : ARCO ALASKA INC., PRUDHOE BAY, DS 4-26, API# 50-029-21520-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: DS 4-26 API NUMBER: 500292152000 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 23-NOV-98 JOB AFUMBER: 98608 LOGGING ENGINEER: VETROMILE OPERATOR WITNESS: SHUMWAY SURFACE LOCATION SECTION: 26 TOWNSHIP: 1 iN RANGE: 15E FNL: FSL: 92 FEL: FWL: 429 ELEVATION(FT FROM MSL O) KELLY BUSHING: 65. O0 DERRICK FLOOR: 64. O0 GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 8. 500 7. 000 10865.0 2ND STRING 3RD STRING PRODUCTION STRING CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: FDN LDWG CURVE CODE: GR RUN NUMBER: PASS ~ER : DATE LOGGED: 08-MAR-86 LOGGING COMPANY: GEARHART BASELINE DEPTH 88888.0 10712.0 10702.5 10702.0 10699.5 10695.0 10694.5 10691.0 10690.5 10682 0 10677 5 10677 0 10675 5 10675 0 10669 5 10665 0 10664 0 10649 5 10648 5 10644 5 10644 0 10641 0 10637 0 10636 5 10632.0 10631.0 10627.5 10627.0 10624.0 10623.0 10619.5 10616.0 10610.0 10601.0 10592.0 10589.0 10588.5 10583.0 10576.5 10572.0 10568.0 10563.0 10559.5 10553.5 10547.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GR CH CNTG 88889.0 88889.0 10713.0 10713.0 10702.5 10702.5 10700.0 10695.5 10692.0 10682.5 10677.5 10675.5 10669.5 10665.0 10650.0 10644.5 10641.5 10636.5 10630.0 10627.5 10623.0 10619.5 10616.5 10608.0 10602.0 10592.0 10590.0 10583.5 10576.0 10573.0 10567.5 10563.0 10559.5 10555.0 10548.0 10700.0 10695.5 10692.0 10682.5 10677.5 10675.5 10669.5 10664.0 10650.5 10644.5 10641.5 10636.5 10630.0 10627.5 10623.5 10619.5 10616.5 10608.0 10601.0 10592.0 10590.0 10583.5 10576.0 10573.0 10567.5 10563.0 10559.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 10547.0 10540.5 10541.5 10535.5 10536.0 10525.5 10525.0 10525.0 10517.0 10515.0 10515.0 10513.0 10514.5 10510.0 10509.5 10506.5 10504.0 10503.5 10500.0 100.0 96.5 $ REMARKS: 10548.0 10541.5 10536.0 10525.0 10515.0 10513.0 10506.5 10500.0 96.0 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CNTG DATA AQUIRED ON ARCO ALASKA'S DS 4-26 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #1 AND THE FDN GAMFIA RAY, ALSO PASS #1 NPHI AND THE FDN GARDA RAY, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE~BER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUM~ER: 1 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10718.0 10492.5 CNTG 10722.0 10492.0 $ CURVE SHIFT DATA - PASS TO PASS (M~ASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: .......... EQUIVALENT UNSHIFTED DEPTH .......... BASELINE DEPTH GRCH CNTG LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: REFiARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #1. NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 68 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 15 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUM~ NI]M~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP EL~4 CODE (HEX) DEPT FT 1224664 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 1224664 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 1224664 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 1224664 O0 000 O0 0 1 1 i 4 68 0000000000 NRAT CNTG 1224664 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 1224664 O0 000 O0 0 1 1 1 4 68 0000000000 ENRA CNTG 1224664 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTG CPS 1224664 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 1224664 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 1224664 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 1224664 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 1224664 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 1224664 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTG GAPI 1224664 O0 000 O0 0 1 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: NAME SERV UNIT SERVICE API API API API FILE ~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELEM CODE (HEX) TENS CNTG LB 1224664 O0 000 O0 0 1 1 1 4 68 0000000000 CCL CNTG V 1224664 O0 000 O0 0 1 1 1 4 68 0000000000 GR FDN GAPI 1224664 O0 000 O0 0 1 1 1 4 68 0000000000 ** DATA ** DEPT. 10846.000 NPHI.CNTG -999.250 ENPH. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS. CNTG GR.FDN 105.273 DEPT. 10450.000 NPHI.CNTG -999.250 ENPH. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS.CNTG GR.FDN 103.560 -999.250 CPHI.CNTG -999.250 NCNT. CNTG -999.250 CNEC. CNTG -999.250 CCL.CNTG -999.250 CPHI.CNTG -999.250 NCNT. CNTG -999.250 CNEC. CNTG -999.250 CCL.CNTG -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION · O01CO1 DATE : 98/11/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: PASS NUMBER: 2 DEPTH INCREMF2Fr: 0.5000 FILE SUf4~zARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10717.0 10493.5 CNTG 10723.0 10494.0 $ CURVE SHIFT DATA - PASS TO PASS (M~g~ DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUblBER: 1 BASELINE DEPTH 88888.0 10713.0 10711.0 10708.5 10703.0 10702.5 10699.0 10691.0 10681.0 10676.5 10675.5 10671.0 10669.5 10664.0 10657.5 10650.5 10643.5 10642.0 10640.5 1O639.0 10631.0 10627.0 10622.5 10620.5 10609.5 10608.0 10605.5 10604.5 10600.5 10597.0 10583.0 10578.0 10576.5 10575.5 10572.0 10569.5 10568.0 .......... EQUIVALENT UNSHIFTED DEPTH .......... G R CH CNTG .............. 88888.0 88890.0 10713.0 10715.0 10712.5 10709.5 10703.0 10703.0 10700.0 10692.0 10692.0 10682.5 10677.5 10676.0 10671.5 10669.5 10664.0 10658.5 10650.5 10644.5 10642.5 10642.0 10639.0 10639.0 10630.5 10627.0 10627.5 10623.5 10620.5 10608.0 10607.0 10605.0 10604.5 10601.0 10597.0 10583.5 10584.0 10578.5 10576.0 10576.0 10573.0 10570.5 10567.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PA GE: 10562.5 10561.0 10558.0 10552.5 10552.0 10546.5 10546.0 10542 5 10540 0 10537 5 10535 5 10533 5 10529 5 10526 0 10525.5 10517.0 10515.0 10512.5 10504.5 10504.0 100.0 $ 10561.5 10559.0 10554.0 10548.0 10541.5 10536.5 10533.5 10525.5 10515.0 10513.0 105 O1.5 97.5 10563.0 10553.0 10547.0 10544.0 10538.5 10529.5 10526.5 10511.0 10502.5 98.0 REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS #1, ALSO NPHI PASS #2 AND NPHI PASS #1, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: TYPE REPR CODE VALUE 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFIB NUFIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUF1B SAMP ELEM CODE (HEX) DEPT FT 1224664 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 1224664 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 1224664 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 1224664 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTG 1224664 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTG 1224664 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 1224664 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 1224664 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTG CPS 1224664 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 1224664 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 1224664 O0 000 O0 0 2 1 1 4 68 0000000000 CNEC CNTG CPS 1224664 O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNTG CPS 1224664 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTG GAPI 1224664 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTG LB 1224664 O0 000 O0 0 2 1 1 4 68 0000000000 CCL CNTG V 1224664 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10723.000 NPHI.CNTG 25.276 ENPH. CNTG 25.813 CPHI. CNTG NRAT. CNTG 2.951 CRAT. CNTG 2.704 ENRA.CNTG 4.288 NCNT. CNTG FCNT. CNTG 893.292 CNTC. ClTTG 2398.025 CFTC. CNTG 903.018 CNEC. CNTG CFEC. CNTG 685.452 GRCH. CNTG -999.250 TENS. CNTG 3296.000 CCL.CNTG DEPT. 10493.500 NPHI.CNTG -999.250 ENPH. CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG FCNT. CNTG -999.250 CNTC.CNTG -999.250 CFTC. CNTG CFEC. CNTG -999.250 GRCH. CNTG 82.202 TENS. CNTG -999.250 CPHI. CNTG -999.250 NCNT. CNTG -999.250 CNEC. CNTG -999.250 CCL.CNTG 24.372 2586.731 2939.555 -0.003 -999.250 -999.250 -999.25O -999.250 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: **** FILE TRAILER **** FILE NAFIE : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION · O01CO1 DATE : 98/11/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE LDWG TOOL CODE START DEPTH STOP DEPTH GRCN 10716.0 10493.0 CNTG 10722.5 10497.5 $ CURVE SHIFT DATA - PASS TO PASS (FiEAS~ DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 10714.0 10713.5 10708.5 10704.5 10703.0 10699.5 10690.5 10690.0 10688.5 10683.5 .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH CNTG 88887.0 88889.5 10713.0 10715.0 10709.5 10704.5 10702.5 10700.5 10692.0 1O692.0 10690.5 10684.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: 10 10681.0 10682.5 10676.5 10677.5 10674.5 10675.5 10676.0 10669.0 10669.5 10667.0 10667.5 10664.0 10665.0 10664.0 10657.5 10658.5 10648.0 10650.0 10650.5 10644.0 10644.5 10643.5 10644.5 10638.5 10639.0 10638.0 10639.0 10636.0 10636.5 10632.5 10633.0 10632.0 10631.0 10626.5 10627.0 10627.5 10621.5 10622.5 10620.0 10620.5 10616.5 10617.5 10612.5 10612.0 10612.0 10611.5 10609.5 10608.0 10607.0 10606.0 10604.0 10604.5 10600.5 10601.0 10600.0 10600.0 10596.0 10596.0 10594.5 10595.0 10591.5 10592.0 10584.5 10586.0 10582.0 10583.5 10580.0 10581.0 10576.0 10576.5 10576.5 10573.5 10574.0 10571.5 10573.0 10569.0 10569.5 10570.0 10567.5 10567.5 10567.0 10567.5 10565.5 10566.0 10563.5 10564.5 10562.5 10563.0 10562.0 10563.0 10560.5 10561.5 10558.0 10558.5 10557.0 10556.5 10555.0 10555.0 10546.5 10547.5 10545.5 10547.5 10540.0 10542.0 10541.5 10537.5 10538.5 10539.0 10535.0 10536.5 10529.0 10529.5 10525.0 10526.5 10524.0 10525.0 10518.5 10518.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: 11 10516.0 10515.0 10514.5 10513.0 10507.0 10504.0 10503.5 10500.5 100.0 97.0 $ 101.5 REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #3. THE SHIFTS SHOWN ABOVEREFLECT CORRELATIONS BETWEEN GRCH PASS #3 AND GRCHPASS #1, ALSO NPHI PASS #3 AND NPHI PASS #1, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERVUNIT SERVICE API API API API FILE NUM~ NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) .................................................................. l .................... DEPT FT 1224664 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 1224664 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 1224664 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 1224664 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTG 1224664 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTG 1224664 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 1224664 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTG CPS 1224664 O0 000 O0 0 3 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: 12 NAME SERV UNIT SERVICE API API API API FILE NUMB NUFIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP ELaM CODE (HEX) FCNT CNTG CPS 1224664 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 1224664 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 1224664 O0 000 O0 0 3 1 1 4 68 0000000000 CNEC CNTG CPS 1224664 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 1224664 O0 000 O0 0 3 I 1 4 68 0000000000 GRCH CNTG GAPI 1224664 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTG LB 1224664 O0 000 O0 0 3 1 1 4 68 0000000000 CCL CNTG V 1224664 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10722.500 NPHI. CNTG 27.270 ENPH. CNTG 28.453 CPHI.CNTG 25.693 NRAT. CNTG 2.934 CRAT. CNTG 2.838 ENRA. CNTG 4.528 NCNT. CNTG 2572.584 FCNT. CNTG 859.888 CNTC. CNTG 2419.108 CFTC. CNTG 883.396 CNEC. CNTG 2936.466 CFEC. CNTG 648.513 GRCH. CNTG -999.250 TENS. CNTG 3319.000 CCL. CNTG -0.004 DEPT. 10493.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI. CNTG -999.250 NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA. CNTG -999.250 NCNT. CNTG -999.250 FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG -999.250 CFEC. CNTG -999.250 GRCH. CNTG 84.832 TENS. CNTG -999.250 CCL. CNTG -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: 13 FILE NUMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmetic average of edited passes for all curves. DEPTH INC~ O. 5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS 1, 2, 3, CNTG REF~J~<S: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF PASSES 1,2, &3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUFIB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFIB SAMP ELE~ CODE (HEX) DEPT FT 1224664 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 1224664 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1224664 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNAV PU-S 1224664 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1224664 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNAV PU-S 1224664 O0 000 O0 0 4 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: 14 NAME SERVUNIT SERVICE API API API API FILE NUFiB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUM~ SAMP EL~4 CODE (HEX) ENRA CNAV 1224664 O0 000 O0 0 4 1 1 4 68 0000000000 NCNTCNAV CPS 1224664 O0 000 O0 0 4 1 1 4 68 0000000000 FCNT CNAV CPS 1224664 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1224664 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1224664 00 000 O0 0 4 1 1 4 68 0000000000 CNEC CNAV CPS 1224664 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNAV CPS 1224664 O0 000 O0 0 4 1 1 4 68 0000000000 GRCH CNTG GAPI 1224664 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10722.000 NPHI.CNAV 25.226 NRAT. CNAV 2.844 CPHI.CNAV 24.443 CRAT. CNAV 2.701 ENPH. CNAV 25.576 ENRA.CNAV 4.266 NCNT. CNAV 2534.905 FCNT. CNAV 881.646 CNTC.CNAV 2432.690 CFTC. CNAV 915.285 CNEC. CNAV 2954.655 CFEC. CNAV 693.262 GRCH. CNTG -999.250 DEPT. 10492.500 NPHI.CNAV -999.250 NRAT. CNAV -999.250 CPHI. CNAV -999.250 CRAT. CNAV -999.250 ENPH. CNAV -999.250 ENRA. CNAV -999.250 NCNT. CNAV -999.250 FCNT. CNAV -999.250 CNTC. CNAV -999.250 CFTC. CNAV -999.250 CNEC. CNAV -999.250 CFEC. CNAV -999.250 GRCH. CNTG 77.081 ** F_aVD OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: 15 FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCRE~fENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH CNTG LOG HEADER DATA DATE LOGGED: 10752.0 SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 10494.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAIV~VA RAY CNTG COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF): FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : 12 -NOV- 98 8Cl -205 10724.0 10724.0 10496.0 10721.0 1800.0 TOOL NUMBER ........... SGC- SA CNT-G 8.500 10865.0 CRUDE E P I THERMAL LIMESTONE 2.71 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: 16 BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 2500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 6500 TOOL STANDOFF (IN): REMARKS: LOG TIED INTO GEARHART CBT LOG DATED 21-MAY-1986 PUMPED 290 BBL CRUDE TO KNOCK WELL DOWN @ 5 BPM PUMPED BBL CRUDE DURING LOGGING @ 1 BPM PUMPED 10 BBL DIESEL TO CLEAR LINES LOGGED THREE PASSES AT 30 FPM TAGGED TD AT 10734' NO FIELD GOC PICK THIS FILE CONTAINS THE RAW DATA FOR PASS #1. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 * * SET TYPE - CHAN * * NAME SERV UNIT SERVICE API API API API FILE NUiVlB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUFiB SAMP ELE~I CODE (HEX) DEPT FT 1224664 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1224664 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: 17 NAME SERV UNIT SERVICE API API API API FILE NUMB NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD AU3M~ SAMP ELEM CODE (HEX) ....................................................................................... ENPH PS1 PU 1224664 O0 000 O0 0 5 1 1 4 TNPH PS1 PU 1224664 O0 000 O0 0 5 1 1 4 TNRA PS1 1224664 O0 000 O0 0 5 1 1 4 RTNR PS1 1224664 O0 000 O0 0 5 1 1 4 ENRA PS1 1224664 O0 000 O0 0 5 1 1 4 CFEC PS1 CPS 1224664 O0 000 O0 0 5 1 1 4 CNEC PS1 CPS 1224664 O0 000 O0 0 5 1 1 4 RCEF PS1 CPS 1224664 O0 000 O0 0 5 1 1 4 RCENPS1 CPS 1224664 O0 000 O0 0 5 1 1 4 RCNTPS1 CPS 1224664 O0 000 O0 0 5 1 1 4 RCFT PS1 CPS 1224664 O0 000 O0 0 5 1 1 4 CNTC PS1 CPS 1224664 O0 000 O0 0 5 1 1 4 CFTC PS1 CPS 1224664 O0 000 O0 0 5 1 1 4 NPOR PS1 PU 1224664 O0 000 O0 0 5 1 1 4 GR PS1 GAPI 1224664 O0 000 O0 0 5 1 1 4 TENS PS1 LB 1224664 O0 000 O0 0 5 1 1 4 CCL PS1 V 1224664 O0 000 O0 0 5 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 ** DATA ** DEPT. 10752.000 NPHI.PS1 46.140 ENPH. PS1 TNRA.PS1 4.073 RTNR.PS1 4.250 ENRA. PS1 CNEC. PS1 2098.338 RCEF. PS1 250.803 RCEN. PS1 RCFT. PS1 503.221 CNTC.PS1 2068.791 CFTC. PSi GR.PS1 28.125 TENS.PSi 2040.000 CCL.PS1 DEPT. 10494.000 NPHI.PS1 53.796 ENPH. PS1 TNRA.PS1 4.573 RTNR.PS1 4.743 ENRA.PS1 CNEC. PS1 2617.840 RCEF. PS1 388.318 RCEN. PS1 RCFT. PSl 253.255 CNTC. PS1 1323.243 CFTC. PSi GR.PS1 92.231 TENS. PSI 3210.000 CCL. PS1 97.229 TNPH. PS1 8.353 CFEC.PS1 1917.423 RCNT. PS1 517.700 NPOR.PS1 0.005 55.742 TNPH.PS1 6.586 CFEC.PS1 2319.460 RCNT. PS1 280.726 NPOR.PS1 -999.250 48.142 251.212 2179.655 48.142 62.187 405.087 1395.521 65.673 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE · FLIC VERSION · O01CO1 DATE : 98/11/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: 18 **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NI]MBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH ........................... CNTG 10785.0 $ LOG HEADER DATA STOP DEPTH .......... 10492.5 DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAM~A RAY CNTG COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT): 12 -NOV- 98 8C1-205 10724.0 10724.0 10496.0 10721.0 1800.0 TOOL NUMBER SG C - SA CNT- G 8.500 10865.0 CRUDE LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: 19 FLUID RATE AT WEL~ (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL LIFiESTONE 2.71 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 2500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 6500 TOOL STANDOFF (IN): RI~4ARKS: LOG TIED INTO GEARHART CBT LOG DATED 21-MAY-1986 PUMPED 290 BBL CRUDE TO KNOCK WELL DOWN ® 5 BPM PUMPED BBL CRUDE DURING LOGGING ® 1 BPM PUMPED 10 BBL DIESEL TO CLEAR LINES LOGGED THREE PASSES AT 30 FPM TAGGED TD AT 10734' NO FIELD GOC PICK THIS FILE CONTAINS THE RAW DATA FOR PASS #2. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE- 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: 2O TYPE REPR CODE VALUE .............................. 14 65 FT 15 66 68 16 66 1 0 66 1 .............................. ** SET TYPE - CHAN ** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUM~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~I CODE (HEX) ....................................................................................... DEPT FT 1224664 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1224664 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS2 PU 1224664 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PS2 PU 1224664 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1224664 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 1224664 O0 000 O0 0 6 1 1 4 68 0000000000 ENRA PS2 1224664 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS2 CPS 1224664 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC PS2 CPS 1224664 O0 000 O0 0 6 1 1 4 68 0000000000 RCEF PS2 CPS 1224664 O0 000 O0 0 6 1 1 4 68 0000000000 RCENPS2 CPS 1224664 O0 000 O0 0 6 1 1 4 68 0000000000 RCNTPS2 CPS 1224664 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 1224664 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1224664 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 1224664 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PS2 PU 1224664 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1224664 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1224664 O0 000 O0 0 6 1 1 4 68 0000000000 CCL PS2 V 1224664 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 10785.000 NPHI.PS2 22.110 ENPH. PS2 31.551 TNPH. PS2 TNRA.PS2 2.492 RTNR.PS2 2.600 ENRA. PS2 4.804 CFEC. PS2 CNEC. PS2 1827.648 RCEF. PS2 379.790 RCEN. PS2 1670.071 RCNT. PS2 RCFT. PS2 635.042 CNTC. PS2 1585.126 CFTC. PS2 653.314 NPOR.PS2 GR.PS2 39.685 TENS.PS2 2102.000 CCL.PS2 -0.005 DEPT. 10492.500 NPHI.PS2 59.670 ENPH. PS2 61.680 TNPH. PS2 TNRA.PS2 4.956 RTNR.PS2 5.147 ENRA.PS2 6.881 CFEC. PS2 CNEC. PS2 2643.855 RCEF. PS2 405.052 RCEN. PS2 2504.257 RCNT. PS2 RCFT. PS2 285.201 CNTC. PS2 1335.044 CFTC. PS2 279.958 NPOR.PS2 GR.PS2 88.550 TENS.PS2 3231.000 CCL. PS2 -999.250 20. 816 380.410 1670. 071 20. 816 73.751 402.915 1396.785 73.805 ** END OF DATA ** LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: 21 **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 7 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUFff4ARY VENDOR TOOL CODE START DEPTH CNTG $ LOG HEADER DATA DATE LOGGED: 10785.0 SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): STOP DEPTH 10492.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAMMA RAY CNTG COMPENSATED NEUTRON $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 12-NOV-98 8Cl -205 10724.0 10724.0 10496.0 10721.0 1800.0 TOOL NUMBER ........... SGC-SA CNT-G 8.500 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: 22 DRILLERS CASING DEPTH (FT): LOGGERS CASING DEPTH (FT): 10865.0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EPITHERMAL LIMESTONE 2.71 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT): BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 2500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 6500 TOOL STANDOFF (IN): REI~RKS: LOG TIED INTO GEARHART CBT LOG DATED 21-MAY-1986 PUMPED 290 BBL CRUDE TO KNOCK WELL DOWN @ 5 BPM PUMPED BBL CRUDE DURING LOGGING @ 1 BPM PUMPED 10 BBL DIESEL TO CLEAR LINES LOGGED THREE PASSES AT 30 FPM TAGGED TD AT 10734' NO FIELD GOC PICK THIS FILE CONTAINS THE RAW DATA FOR PASS #3. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE .............................. 1 66 0 2 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: 23 TYPE REPR CODE VALUE .............................. 3 73 76 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 13 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN** ....................................................................................... NAME SERV UNIT SERVICE API API API API FILE NUF~ NUM~ SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD ~ SAMP ELEM CODE (HEX) ....................................................................................... DEPT FT 1224664 O0 000 O0 0 7 1 1 4 NPHI PS3 PU 1224664 O0 000 O0 0 7 1 1 4 ENPH PS3 PU 1224664 O0 000 O0 0 7 1 1 4 TNPH PS3 PU 1224664 O0 000 O0 0 7 1 1 4 TNRA PS3 1224664 O0 000 O0 0 7 1 1 4 RTNR PS3 1224664 O0 000 O0 0 7 1 1 4 ENRA PS3 1224664 O0 000 O0 0 7 1 1 4 CFEC PS3 CPS 1224664 O0 000 O0 0 7 1 1 4 CNEC PS3 CPS 1224664 O0 000 O0 0 7 1 1 4 RCEF PS3 CPS 1224664 O0 000 O0 0 7 1 1 4 RCEN PS3 CPS 1224664 O0 000 O0 0 7 1 1 4 RCNT PS3 CPS 1224664 O0 000 O0 0 7 1 1 4 RCFT PS3 CPS 1224664 O0 000 O0 0 7 1 1 4 CNTC PS3 CPS 1224664 O0 000 O0 0 7 1 1 4 CFTC PS3 CPS 1224664 O0 000 O0 0 7 1 1 4 NPOR PS3 PU 1224664 O0 000 O0 0 7 1 1 4 GR PS3 GAPI 1224664 O0 000 O0 0 7 1 1 4 TENS PS3 LB 1224664 O0 000 O0 0 7 1 1 4 CCL PS3 V 1224664 O0 000 O0 0 7 1 1 4 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 68 0000000000 * * DA TA * * DEPT. 10748.000 NPHI.PS3 31.463 ENPH. PS3 TNRA.PS3 3.115 RTNR.PS3 3.250 ENRA.PS3 CNEC. PS3 2115.238 RCEF. PS3 252.784 RCEN. PS3 RCFT. PS3 507.209 CNTC. PS3 1585.126 CFTC. PS3 GR.PS3 68.032 TENS.PS3 2496.000 CCL.PS3 97.262 TNPH. PS3 8.354 CFEC.PS3 1932.865 RCNT. PS3 521.803 NPOR.PS3 -O.OO6 30.628 253.196 1670.071 30.628 LIS Tape Verification Listing Schlumberger Alaska Computing Center 23-NOV-1998 12:22 PAGE: 24 DEPT. 10493.500 NPHI.PS3 TNRA.PS3 4.478 RTNR.PS3 CNEC. PS3 2651.127 RCEF. PS3 RCFT. PS3 269.169 CNTC. PS3 GR.PS3 90.062 TENS.PS3 52.344 ENPH. PS3 4.538 ENRA.PS3 388.703 RCEN. PS3 1332.063 CFTC. PS3 3208.000 CCL.PS3 64.362 TNPH. PS3 7.007 CFEC. PS3 2402.701 RCNT. PS3 299.026 NPOR.PS3 -999.250 57.920 380.970 1430.047 57.009 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : O01CO1 DATE : 98/11/23 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/11/23 ORIGIN : FLIC TAPE NAME : 98608 CONTINUATION # : 1 PREVIOUS TAPE COf4~ENT : ARCO ALASKA INC., PRUDHOE BAY, DS 4-26, API# 50-029-21520-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/11/23 ORIGIN : FLIC REEL NAME : 98608 CONTINUATION # : PREVIOUS REEL : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, DS 4-26, API# 50-029-21520-00 * ALASKA COMPUTING CENTER * . . ****************************** . ............................ ....... SCHLUMBERGER ....... . ............................ ****************************** COMPANY NAME : ARCO ALASKA, INC. WELL NAME : D.S. 4 -26 FIELD NAME : PRUDHOE BAY BOROUGH : NORTH SLOPE STATE : ALASKA API NUMBER : 500292152000 REFERENCE NO : 98046 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JAN-1998 16:54 PAGE: **** REEL HEADER **** SERVICE NAME : EDIT DATE : 98/01/29 ORIGIN : FLIC REEL NAME : 98046 CONTINUATION # : PREVIOUS REEL : COM~4ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-26, API# 50-029-21520-00 **** TAPE HEADER **** SERVICE NAME : EDIT DATE : 98/01/29 ORIGIN : FLIC TAPE NAME : 98046 CONTINUATION # : 1 PREVIOUS TAPE : COF~4ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-26, API# 50-029-21520-00 TAPE HEADER PRUDHOE BAY CASED HOLE WIRELINE LOGS WELL NAME: D.S. 4-26 API NUMBER: 500292152000 OPERATOR: ARCO ALASKA, INC. LOGGING COMPANY: SCHLUMBERGER WELL SERVICES TAPE CREATION DATE: 29-JAN-98 JOB NUMBER: 98046 LOGGING ENGINEER: BAILEY OPERATOR WITNESS: G. SARBER SURFACE LOCATION SECTION: 26 TOWNSHIP: lin RANGE: 1SE FNL: FSL: 92 FEL: FWL: 429 ELEVATION(FT FROM MSL O) KELLY BUSHING: 65.00 DERRICK FLOOR: 64.00 GROUND LEVEL: WELL CASING RECORD OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 9.675 10522.0 47.00 2ND STRING 7.000 10865.0 29.00 3RD STRING 5.500 2534.0 17.00 PRODUCTION STRING 4.500 10295.0 12.60 CURVE SHIFT DATA - ALL PASSES TO STANDARD(MEASURED DEPTH) LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JAN-1998 16:54 BASELINE CURVE FOR SHIFTS LDWG TOOL CODE: LDWG CURVE CODE: GR RUN NUMBER: PASS NUMBER: DATE LOGGED: 08-MAR-86 LOGGING COMPANY: GEARHART BASELINE DEPTH .............. 88888.0 10717.5 10714.5 10709.0 10708.5 10700.0 10697. 0 10694.5 10690. 0 1O686.5 1O686. 0 10680. 0 10679.5 10676.5 10675.5 10675.0 10672.0 10670.5 10669.0 10664. 0 10663.0 10654.5 10654.0 10648.5 10643.5 1O643.0 10639.0 10638.5 10632.0 10631.5 10627.0 10621. 0 10618.5 10614.5 10613.5 10609.0 10603.5 10598.0 10597.5 10592.5 10591.0 10587.0 10585.0 10582.5 10575. 0 .......... EQUIVALENT UNSHIFTED DEPTH GRCH CNTG .............. 88886.5 88886.0 10707.0 10701.0 10697.5 10695.0 10692.0 10687.0 10680.5 10677.5 10675.5 10674.0 10671.5 10669.5 10665.0 10655.0 10649.5 10644.5 10640.5 10630.5 10627.5 10623.5 10619.5 10616.0 10608.0 10602.5 10599.0 10592.0 10590.0 10586.0 10585.0 1 O583.5 10576.0 10715.5 10713.0 10707.0 10701.0 10697.5 10695.0 ! 0692.0 10687.0 10680.5 10677.5 10675.5 10674.0 10671.5 10669.5 10665.0 10655.0 10649.5 10644.5 10640.5 10630.5 10627.5 10623.5 10619.5 10616.0 10608.0 10602.5 10599.0 10592.0 10590.5 10586.0 10585.0 1 0583.5 PAGE: LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JAN-1998 16:54 10574.5 10566.5 10566.0 10563.5 10558.5 10546.5 10542 0 10539 0 10535 5 IOS3S 10526 0 10524 5 10516 5 10515.0 10510.0 10509.5 10503.5 10503.0 10500.0 10499.5 10499.0 10497.5 10497.0 10492.5 100.0 $ REFIARKS: 10567.5 10563.0 10559.5 10547.0 10544.0 10538.5 10534.5 10525.0 10515.5 10513.0 10508.5 10503.0 10500.5 10499.0 10495.5 98.0 10576.0 10567.5 10563.0 10559.5 10547.0 10544.0 10538.5 10534.~ 10525.0 10515.5 10513.0 10508.5 10503.0 10500.5 10499.0 10495.5 10491.5 99.0 CONTAINED HEREIN IS THE LDWG FORMATTED CASED HOLE CNTG DATA AQUIRED ON ARCO ALASKA'S DS 4-26 WELL. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEN GRCH PASS #1 AND THE BASE GAI~4A RAY, ALSO NPHI PASS #1 AND THE BASE GAIVlF1A RAY, CARRYING ALL CNTG CURVES WITH THE SIGMA SHIFTS. $ $ PAGE: **** FILE HEADER **** FILE NAME : EDIT .001 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separace files. PASS NUMBER: 1 DEPTH INCREMENT: 0.5000 FILE SUM~IARY LIS Tape Verification Lis~ing Schlumberger Alaska Computing Cen~er 29-JAN-1998 16:54 PAGE: LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10711 . 5 10488.0 CNTG 10717.0 10489.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: PASS NUMBER: BASELINE DEPTH .............. $ .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CAFfG REM_ARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #1. THERE ARE NO PASS TO PASS SHIFTS APPLIED TO THIS DATA. $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** .............................. TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 64 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 16 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JAN-1998 16:54 PAGE: "* SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELI~4 CODE (HEX) DEPT FT 1173645 O0 000 O0 0 1 1 1 4 68 0000000000 NPHI CNTG PU-S 1173645 O0 000 O0 0 1 1 1 4 68 0000000000 ENPH CNTG PU-S 1173645 O0 000 O0 0 1 1 1 4 68 0000000000 CPHI CNTG PU-S 1173645 O0 000 O0 0 1 1 1 4 68 0000000000 NRAT CNTG 1173645 O0 000 O0 0 1 1 1 4 68 0000000000 CRAT CNTG 1173645 O0 000 O0 0 1 1 1 4 68 0000000000 F2VRA CNTG 1173645 O0 000 O0 0 1 1 1 4 68 0000000000 NCNT CNTG CPS 1173645 O0 000 O0 0 1 1 1 4 68 0000000000 FCNT CNTG CPS 1173645 O0 000 O0 0 1 1 1 4 68 0000000000 CNTC CNTG CPS 1173645 O0 000 O0 0 1 1 1 4 68 0000000000 CFTC CNTG CPS 1173645 O0 000 O0 0 1 1 1 4 68 0000000000 CNEC CNTG CPS 1173645 O0 000 O0 0 1 1 1 4 68 0000000000 CFEC CNTG CPS 1173645 O0 000 O0 0 1 1 1 4 68 0000000000 GRCH CNTG GAPI 1173645 O0 000 O0 0 1 1 1 4 68 0000000000 TENS CNTG LB 1173645 O0 000 O0 0 1 1 1 4 68 0000000000 GR BCS GAPI 1173645 O0 000 O0 0 1 1 ' 1 4 68 0000000000 ** DATA ** DEPT. 10846.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS.CNTG -999.250 GR.BCS DEPT. 10450.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CNTG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG -999.250 TENS.CNTG -999.250 GR.BCS -999.250 -999.250 -999.250 105.273 -999.250 -999.250 -999.250 103.560 ** END OF DATA ** **** FILE TRAILER **** FfLE NAME : EDIT .001 SERVICE · FLIC VERSION · O01CO1 DATE : 98/01/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JAN-1998 16:54 PAGE: **** FILE HEADER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 2 DEPTH INCREMENT: 0.5000 FILE SUMMARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10716.5 10491.5 CNTG 10719.0 10489.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH 88888.0 10716.5 10713.5 10711.5 10710.0 10707.5 10706.5 10706.0 10704.0 10703.5 10702.5 10699.0 10694.5 10691.5 10690.0 10686.0 10684.5 10683.0 10681.0 10679.5 10676.5 .......... EQUIVALENT UNSHIFTEDDEPTH .......... GRCH CNTG .............. 88891.5 88888.0 10711.0 10710.0 10707.0 10703.0 10701.0 10693.0 10687.5 10686.0 10681.5 10677.5 10716.5 10713.0 10711.5 10709.0 10708.0 10703.5 10701.0 10696.0 10692.5 10687.0 10682.5 LfS Tape Verification Listing Schlumberger Alaska Computing Center 29-JAN-1998 16:54 PAGE: 10675.5 10676.0 10674.0 10675.5 10675.0 10671.5 10671.0 10668.0 10669.5 10666.0 10666.0 10664.0 10665.5 10662.0 10664.0 10663.0 10658.0 10660.5 10656.0 10658.0 10655.0 10655.5 10653.0 10653.5 10651.0 10652.0 10648.0 10649.5 10647.0 10649.0 10645.0 10646.0 10644.0 10644.5 10643.0 10644.5 10641.0 10643.0 10638.5 10640.5 10638.0 10640.0 10636.0 10635.5 10635.0 10635.5 10632.5 10632.5 10631.5 10631.0 10628.0 10627.5 10626.0 10626.5 10625.5 10625.0 10622.0 10623.5 10619.5 10622.0 10618.5 10619.5 10617.0 10616.0 10616.0 10614.5 10615.5 10618.5 10613.0 10613.5 10610.0 10608.5 10609.0 10608.5 10606.5 10607.0 10605.5 10604.5 10603.5 10602.5 10601.5 10601.0 10600.5 10601.5 10599.0 10599.0 10594.5 10594.0 10597.5 10593.0 10592.0 10591.5 10591.0 10589.5 10590.0 10588.0 10589.0 10589.0 10586.0 10586.0 10583.0 10583.5 10582.5 10583.5 10578.5 10578.0 10576.5 10578.5 10574.5 10576.0 10574.0 10576.0 10572.0 10574.0 LIS Tape Verificat~ion Lis~ing Schlumberger Alaska Computing Center 29-JAN-1998 16:54 PAGE: 10571.5 10569.5 10565.0 10562.0 10561.5 10560.5 10558.5 10557.5 iOSSS.$ 10554.0 10552.5 10549.0 10547.5 10546.0 10545.5 10542.5 10540.0 10538.0 10537.0 10536.5 10535.5 10534 5 10533 5 10531 0 10528 0 10524 5 10523 0 10521 0 10520 0 10517 5 10516 0 10514 0 10511 0 10510 0 1O508 5 10507 5 10505 5 10503 5 10500 5 10499.5 10499.0 10495.0 10494.5 10492.5 10491.0 100.0 $ 10573.5 10568.5 10563.5 10559.0 1 oss 6.0 10552.5 10549.0 10547.0 10541.0 10538.5 10534.5 10532.0 10529.5 1 O525.0 10520.0 10518.0 10513.0 10509.5 10506.5 10499.0 10495.5 10492.5 101.5 10567.5 10563.0 10561.0 10560.0 10555.5 10553.0 10547.5 10544.0 10540.5 10536.0 10533.5 10531.0 10529.0 10527.0 10525.0 10524.5 10519.5 10515.5 10512.0 10510.0 10505.0 10502.0 10498.0 10495.5 10494.0 10491.5 99.0 REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #2. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #2 AND GRCH PASS ~1, ALSO NPHI PASS #2 AND NPHI PASS #1, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT EATA LIS Tape Verification Listing Schlumberger Alaska Computing Cen=er 29-JAN-1998 16:54 PAGE: ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS rD ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173645 O0 000 O0 0 2 1 1 4 68 0000000000 NPHI CNTG PU-S 1173645 O0 000 O0 0 2 1 1 4 68 0000000000 ENPH CNTG PU-S 1173645 O0 000 O0 0 2 1 1 4 68 0000000000 CPHI CNTG PU-S 1173645 O0 000 O0 0 2 1 1 4 68 0000000000 NRAT CNTG 1173645 O0 000 O0 0 2 1 1 4 68 0000000000 CRAT CNTG 1173645 O0 000 O0 0 2 1 1 4 68 0000000000 ENRA CNTG 1173645 O0 000 O0 0 2 1 1 4 68 0000000000 NCNT CNTG CPS 1173645 O0 000 O0 0 2 1 1 4 68 0000000000 FCNT CNTG CPS 1173645 O0 000 O0 0 2 1 1 4 68 0000000000 CNTC CNTG CPS 1173645 O0 000 O0 0 2 1 1 4 68 0000000000 CFTC CNTG CPS 1173645 O0 000 O0 0 2 1 1 4 68 0000000000 C~EC CNTG CPS 1173645 O0 000 O0 0 2 1 1 4 68 0000000000 CFEC CNTG CPS 1173645 O0 000 O0 0 2 1 1 4 68 0000000000 GRCH CNTG GAPI 1173645 O0 000 O0 0 2 1 1 4 68 0000000000 TENS CNTG LB 1173645 O0 000 O0 0 2 1 1 4 68 0000000000 ** DATA ** DEPT. 10719.000 NPHI.CNTG 22.984 ENPH. CNTG 24.744 CPHI. CNTG 18.181 NRAT. CNTG 2.641 CRAT. CNTG 2.663 ENRA.CNTG 4.097 NCNT. CNTG 2768.427 FCNT. CNTG 1094.833 CNTC. CNTG 2663.257 CFTC. CNTG i090.089 CNEC. CNTG 3200.646 CFEC. CNTG 781.181 GRCH. CNTG -999.250 TENS. CNTG 1485.000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JAN-1998 16:54 PAGE: 10 DEPT. 10489.000 NPHI.CNTG 60.424 ENPH. CNTG 59.594 CPHI.CNTG 59.064 NRAT. CNTG 4.514 CRAT. CNTG 4.717 ENRA. CNTG 7.147 NCNT. CNTG 1491.947 FCNT. CNTG 291.996 CNTC. CNTG 1358.947 CFTC. CNTG 294.398 CNEC. CNTG 2777.216 CFEC. CNTG 388.592 GRCH. CNTG -999.250 TENS. CNTG 1450.000 END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .002 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/29 MAX REC SIZE : 102~ FILE TYPE : LO LAST FILE : FILE HEADER FILE NTJMBER: 3 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NIIMBER: 3 DEPTH INCREMENT: 0.5000 FILE SUMFIARY LDWG TOOL CODE START DEPTH STOP DEPTH GRCH 10714.0 10490.0 CNTG 10720.0 10490.5 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS LDWG CURVE CODE: GRCH PASS NUMBER: 1 BASELINE DEPTH .......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH SNTG LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JAN-1998 16:54 PAGE: 11 88888.0 10713.0 10708.0 10704.5 10702.5 10702.0 10698.5 10695.0 10694.5 10690.0 10685.0 10684.5 10683.5 10680.5 10675.5 10674.0 10672 0 10670 5 10668 0 10662 0 10658 0 10655 0 10650 0 10648 0 10647 5 10643 0 10638 0 10637.0 10635.5 10633.5 10631.5 10628.0 10626.5 10626.0 10621.0 10619.5 10618.5 10615.5 10614.0 10611.5 10608.5 10605.0 10603.0 10600.5 10599.0 10596.5 10595.5 10591.5 10591.0 10590.0 10588.5 10586.0 10583.0 10582.0 10581.5 88889.0 10705.5 10703.0 10701.0 10697.5 10691.5 10687.5 10685.0 10681.0 10677.5 10669.5 10664.0 10649.5 10644.5 10640.5 10635.5 10631.0 10627.5 10623.5 10619.5 10615.5 10610.5 10608.0 10603.0 10599.0 10592.0 10590.0 10583.5 10580.0 10578.5 88889.0 10714.0 10707.5 10702.0 10696.5 10692.5 10687.5 10682.5 10675.5 10674.5 10671.5 10658.5 10655.5 10652.0 10649.5 10644.5 10640.0 10635.5 10633.0 10627.0 10622.0 10618.5 10616.0 10608.0 10605.0 10601.5 10599.0 10597.0 10591.5 10589.0 10582.5 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JAN-1998 16:54 PAGE: 12 10577.5 10576.0 10575.5 10573.5 10568.5 10568.0 10566.5 10562.0 10561.0 10559.5 10558.0 10556.5 10553.5 10547.0 10545 5 10545 0 10541 5 10540 0 10536 5 10535 5 10534 5 1O533 5 10532 0 10529.5 10525.5 10524.5 10520.5 10520.0 10518.5 10516.5 10515.5 10514.5 10513.0 10510.5 10509.0 10503.5 10502.0 10500.5 10496.5 10494.0 10493.0 10492.5 10491.5 100.0 $ 10578.0 10576.0 10569.0 10567.5 10563.5 10561.0 10559.0 10547.0 10543.5 10540.5 10538.0 10534.5 10531.0 10528.0 10525.0 10519.5 10518.0 10515.5 10510.5 10509.5 10501.5 10498.5 10495.5 10492.5 100.0 10578.5 10576.0 10568.5 10563.0 10560.0 10555.5 10549.5 10547.5 10544.0 10540.5 10536.0 10533.5 10531.0 10525.0 10519.5 10515.5 10512.0 10504.0 10500.5 10498.0 10494.0 10492.0 100.5 REMARKS: THIS FILE CONTAINS CASED HOLE CNTG PASS #3. THE DEPTH SHIFTS SHOWN ABOVE REFLECT CORRELATIONS BETWEEN GRCH PASS #3 AND GRCH PASS #1, ALSO NPHI PASS #3 AND NPHI PASS #1, CARRYING ALL CNTG CURVES WITH THE NPHI SHIFTS. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JAN-1998 16:54 PAGE: 13 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 60 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 17 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1173645 O0 000 O0 0 3 1 1 4 68 0000000000 NPHI CNTG PU-S 1173645 O0 000 O0 0 3 1 1 4 68 0000000000 ENPH CNTG PU-S 1173645 O0 000 O0 0 3 1 1 4 68 0000000000 CPHI CNTG PU-S 1173645 O0 000 O0 0 3 1 1 4 68 0000000000 NRAT CNTG 1173645 O0 000 O0 0 3 1 1 4 68 0000000000 CRAT CNTG 1173645 O0 000 O0 0 3 1 1 4 68 0000000000 ENRA CNTG 1173645 O0 000 O0 0 3 1 1 4 68 0000000000 NCNT CNTG CPS 1173645 O0 000 O0 0 3 i 1 4 68 0000000000 FCNT CNTG CPS 1173645 O0 000 O0 0 3 1 1 4 68 0000000000 CNTC CNTG CPS 1173645 O0 000 O0 0 3 1 1 4 68 0000000000 CFTC CNTG CPS 1173645 O0 000 O0 0 3 1 1 4 68 0000000000 CN~C CNTG CPS 1173645 O0 000 O0 0 3 1 1 4 68 0000000000 CFEC CNTG CPS 1173645 O0 000 O0 0 3 1 1 4 68 0000000000 GRCH CNTG GAPI 1173645 O0 000 O0 0 3 1 1 4 68 0000000000 TENS CNTG LB 1173645 O0 000 O0 0 3 1 1 4 68 0000000000 ** DATA ** DEPT. 10720.000 NPHI.CNTG 21.298 ENPH. CNTG 23.622 CPHI.CNTG NRAT. CNTG 2.528 CRAT. CNTG 2.567 ENRA.CNTG 3.971 NCNT. CNTG FCNT. CNTG 1034.201 CNTC. CNTG 2702.085 CFTC. CNTG 1040.495 CNEC. CNTG CFEC. CNTG 828.766 GRCH. CNTG -999.250 TENS.CNTG 1510.000 20.323 2905.262 3291.045 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JAN-1998 16:54 PAGE: 14 DEPT. 10490.000 NPHI.CNTG -999.250 ENPH. CNTG -999.250 CPHI.CNTG NRAT. CNTG -999.250 CRAT. CNTG -999.250 ENRA.CNTG -999.250 NCNT. CAFfG FCNT. CNTG -999.250 CNTC. CNTG -999.250 CFTC. CNTG -999.250 CNEC. CNTG CFEC. CNTG -999.250 GRCH. CNTG 68.125 TENS. CNTG -999.250 -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .003 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .004 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/29 MAX REC SIZE : 102~ FILE TYPE : LO LAST FILE : FILE HEADER FILE NTJMBER: 4 AVERAGED CURVES Compensated Neutron: Arithmeuic average of edited passes for all curves. DEPTH INCREMENT 0.5000 PASSES INCLUDED IN AVERAGE LDWG TOOL CODE PASS NUMBERS .......................... 1, 2, 3, CNTG $ REMARKS: THIS FILE CONTAINS THE ARITHMETIC AVERAGE OF PASSES 1,2, &3. THE DATA WAS CLIPPED AND DEPTH SHIFTED BEFORE THE AVERAGE WAS CALCULATED. $ LIS FORMAT DATA LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JAN-1998 16:54 PAGE: 15 ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB *~ TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 56 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 18 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** N~4E SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1173645 O0 000 O0 0 4 1 1 4 68 0000000000 NPHI CNAV PU-S 1173645 O0 000 O0 0 4 1 1 4 68 0000000000 NRAT CNAV 1173645 O0 000 O0 0 4 1 1 4 68 0000000000 CPHI CNAV PU-S 1173645 O0 000 O0 0 4 1 1 4 68 0000000000 CRAT CNAV 1173645 O0 000 O0 0 4 1 1 4 68 0000000000 ENPH CNAV PU-S 1173645 O0 000 O0 0 4 1 1 4 68 0000000000 ENRA CNAV 1173645 O0 000 O0 0 4 1 1 4 68 0000000000 NCNT CNAV CPS 1173645 O0 000 O0 0 4 1 - 1 4 68 0000000000 FCNT CNAV CPS 1173645 O0 000 O0 0 4 1 1 4 68 0000000000 CNTC CNAV CPS 1173645 O0 000 O0 0 4 1 1 4 68 0000000000 CFTC CNAV CPS 1173645 O0 000 O0 0 4 1 1 4 68 0000000000 CNEC CNAV CPS 1173645 O0 000 O0 0 4 1 1 4 68 0000000000 CFEC CNAV CPS 1173645 O0 000 O0 0 4 1 1 4 68 0000000000 G~CH CNTG GAPI 1173645 O0 000 O0 0 4 1 1 4 68 0000000000 ** DATA ** DEPT. 10717.000 NPHI.CNAV 19.454 NRAT. CNAV 2.306 CPHI.CNAV CRAT. CNAV 2.447 ENPH. CNAV 23.815 ENRA.CNAV 3.992 NCNT. CNAV FCNT. CNAV 1166.440 CNTC. CNAV 2782.950 CFTC. CNAV 1156.639 CNEC. CNAV CFEC. CNAV 815.824 GRCH. CNTG -999.250 17.691 2989.344 3254.505 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JAN-1998 16:54 PAGE: 16 DEPT. 10488.000 NPHI.CNAV -999.250 NRAT. CNAV CRAT. CNAV -999.250 ENPH. CNAV -999.250 ENRA.CNAV FCNT. CNAV -999.250 CNTC. CNAV -999.250 CFTC. CNAV CFEC. CNAV -999.250 GRCH. CNTG 35.938 -999.250 CPHI.CNAV -999.250 NCNT. CNAV -999.250 CNEC. CNAV -999.250 -999.250 -999.250 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .004 SERVICE · FLIC VERSION : O01CO1 DATE : 98/01/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : ***3 FILE HEADER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NUMBER 5 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS NUMBER: 1 DEPTH INCR~qENT: 0.5000 FILE SUM~D~Y VENDOR TOOL CODE START DEPTH 'CNTG 1O743.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR): DEPTH CONTROL USED (YES/NO): STOP DEPTH 10486.5 O1-NOV-97 CP 44.2 1328 O1 -NOV-97 10815.0 10731.0 10500.0 10726.0 1800.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JAN-1998 16:54 PAGE: 18 (THIS IS PASS #2 ON THE FIELD PRINT). $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELEM CODE (HEX) DEPT FT 1173645 O0 000 O0 0 5 1 1 4 68 0000000000 NPHI PS1 PU 1173645 O0 000 O0 0 5 1 1 4 68 0000000000 ENPH PS1 PU 1173645 O0 000 O0 0 5 1 1 4 68 0000000000 TNPH PSl PU 1173645 O0 000 O0 0 5 1 1 4 68 0000000000 TNRA PS1 1173645 O0 000 O0 0 5 1 1 4 68 0000000000 R~NR PS1 1173645 O0 000 O0 0 5 1 1 4 68 0000000000 ENRA PS1 1173645 O0 000 O0 0 5 1 1 4 68 0000000000 CFEC PSl CPS 1173645 O0 000 O0 0 5 1 1 4 68 0000000000 CNEC PS1 CPS 1173645 O0 000 O0 0 5 1 1 4 68 0000000000 RCEF PS1 CPS 1173645 O0 000 O0 0 5 1 1 4 68 0000000000 RCEN PS1 CPS 1173645 O0 000 O0 0 5 1 1 4 68 0000000000 RCNT PS1 CPS 1173645 O0 000 O0 0 5 1 ! 4 68 0000000000 RCFT PS1 CPS 1173645 O0 000 O0 0 5 1 1 4 68 0000000000 CNTC PS1 CPS 1173645 O0 000 O0 0 5 1 1 4 68 0000000000 CFTC PS1 CPS 1173645 O0 000 O0 0 5 1 1 4 68 0000000000 NPOR PS1 PU 1173645 O0 000 O0 0 5 1 1 4 68 0000000000 GR PS1 GAPI 1173645 O0 000 O0 0 5 1 1 4 68 0000000000 TENS PS1 LB 1173645 O0 000 O0 0 5 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JAN-1998 16:54 PAGE: 19 ** DATA DEPT. 10743.000 NPHI.PS1 23.156 ENPH. PS1 34.636 TNPH. PS1 TNRA.PS1 2.673 RTNR.PS1 2.752 ENRA.PS1 5.122 CFEC. PS1 CNEC. PS1 2780.657 RCEF. PS1 543.758 RCEN. PS1 2480.542 RCNT. PS1 RCFT. PS1 1064.304 cArrc. PS1 2751.838 CFTC. PSi 1047.768 NPOR.PS1 GR.PS1 19.344 TENS.PSI 985.000 DEPT. 10486.500 NPHI.PS1 59.263 ENPH. PS1 42.452 TNPH. PS1 TNRA.PS1 4.653 RTNR.PS1 4.260 ENRA.PS1 5.832 CFEC. PS1 CNEC. PS1 2878.144 RCEF. PS1 462.294 RCEN. PS1 2617.281 RCNT. PS1 RCFT. PS1 299.012 CNTC. PS1 1537.030 CFTC. PSi 356.377 NPOR.PS1 GR.PS1 45.188 TENS.PSi 1490.000 20.738 542.840 2992.034 20.738 48.589 493.471 1675.019 48.468 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .005 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/29 M~DfREC SIZE : 1024 FILE TYPE : LO LAST FILE : **** FILE HEADER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE : 98/01/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : FILE HEADER FILE NTgMBER 6 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file PASS N73MBER: 2 DEPTH INCREMENT: 0.5000 FILE SUM~L~RY VENDOR TOOL CODE START DEPTH STOP DEPTH CNTG 10746.0 10488.0 LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JAN-1998 16:54 PAGE: 20 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG I1TTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO) O1 -NOV-97 CP 44.2 1328 O1 -NOV-97 10815.0 10731.0 10500.0 10726.0 1800.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GR GAIV~w~A RAY CNTG COMPENSATED NUETRON $ TOOL NUMBER ........... SGC-SA-664 CNC-GA-63 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLERS CASING DEPTH (FT) : LOGGERS CASING DEPTH (FT) : 10865.0 BOREHOLE CONqgITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF) : BOTTOM HOLE TI~4PERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM): WATER CUTS (PCT) : GAS~OIL RATIO: CHOKE (DEG) : CRUDE 10.0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): EP I THERMAL SANDSTONE 2.65 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 5500 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 14000 TOOL STANDOFF (IN): REMARKS: TIED IN TO GO CBL DATED 5-21-86. LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JAN-1998 16:54 PAGE: 21 THE PURPOSE OF THIS LOG WAS TO MONITOR GOCAND TO DETERMINE EXTENT OF GAS PRESENT IN UPPER ROMEO @ 10650' TO 10690'. INJECTION TOTALS: CRUDE=425 BBLS, DIESEL=lO BBLS. LOGGED AT 3 BPM INJECTION RATE AFTER PUMPING 1 1/2 BHV'S AT 6 BPM. SOME GAS CAME BACK IN DURING PUMP SHUTDOWN OF ABOUT 3 MINUTES WHILE CHANGING TO SECOND TANKER. PASS #1 IS NOT INCLUDED ON OVERLAY OR AVERAGE BECAUSE OF GAS REENTRY. APPARENT GOC= 10606' THE UPPER ROMEO IS GAS SATURATED. THIS FILE CONTAINS THE RAW DATA FOR PASS #2. (THIS IS PASS #3 ON THE FIELD PRINT). $ LIS FORMAT DATA ** DATA FORMAT SPECIFICATION RECORD ** ** SET TYPE - 64EB ** TYPE REPR CODE VALUE 1 66 0 2 66 0 3 73 72 4 66 1 5 66 6 73 7 65 8 68 0.5 9 65 FT 11 66 14 12 68 13 66 0 14 65 FT 15 66 68 16 66 1 0 66 1 ** SET TYPE - CHAN ** NAME SERV UNIT SERVICE API API API API FILE NUMB AKIFIB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) DEPT FT 1173645 O0 000 O0 0 6 1 1 4 68 0000000000 NPHI PS2 PU 1173645 O0 000 O0 0 6 1 1 4 68 0000000000 ENPH PS2 PU 1173645 O0 000 O0 0 6 1 1 4 68 0000000000 TNPH PS2 PU 1173645 O0 000 O0 0 6 1 1 4 68 0000000000 TNRA PS2 1173645 O0 000 O0 0 6 1 1 4 68 0000000000 RTNR PS2 1173645 O0 000 O0 0 6 1 1 4 68 0000000000 LIS Tape Verification Listing Schlumberger Alaska Computing Cen~er 29-JAN-1998 16:54 PAGE: 22 NAME SERV UNIT SERVICE API API API API FILE NUMB NUMB SIZE REPR PROCESS ID ORDER # LOG TYPE CLASS MOD NUMB SAMP ELE~ CODE (HEX) ENRA PS2 1173645 O0 000 O0 0 6 1 1 4 68 0000000000 CFEC PS2 CPS 1173645 O0 000 O0 0 6 1 1 4 68 0000000000 CNEC PS2 CPS 1173645 O0 000 O0 0 6 1 1 4 68 0000000000 RCEF PS2 CPS 1173645 O0 000 O0 0 6 1 1 4 68 0000000000 RCEN PS2 CPS 1173645 O0 000 O0 0 6 1 1 4 68 0000000000 RCNT PS2 CPS 1173645 O0 000 O0 0 6 1 1 4 68 0000000000 RCFT PS2 CPS 1173645 O0 000 O0 0 6 1 1 4 68 0000000000 CNTC PS2 CPS 1173645 O0 000 O0 0 6 1 1 4 68 0000000000 CFTC PS2 CPS 1173645 O0 000 O0 0 6 1 1 4 68 0000000000 NPOR PS2 PU 1173645 O0 000 O0 0 6 1 1 4 68 0000000000 GR PS2 GAPI 1173645 O0 000 O0 0 6 1 1 4 68 0000000000 TENS PS2 LB 1173645 O0 000 O0 0 6 1 1 4 68 0000000000 ** DATA ** DEPT. 10746.000 NPHI.PS2 28.336 ENPH. PS2 32.663 TNPH. PS2 24.762 TNRA.PS2 2.957 RTNR.PS2 3.045 ENRA.PS2 4.930 CFEC.PS2 530.050 CNEC. PS2 2613.089 RCEF. PS2 530.947 RCEN. PS2 2331.060 RCNT. PS2 2785.138 RCFT. PS2 895.725 CNTC. PS2 2561.550 CFTC. PS2 881.809 NPOR.PS2 24.762 GR.PS2 17.000 TENS.PS2 995.000 DEPT. 10488.000 NPHI.PS2 47.370 ENPH. PS2 49.670 TNPH. PS2 46.688 TNRA.PS2 4.001 RTNR.PS2 3.952 ENRA.PS2 6.422 CFEC. PS2 454.466 CNEC. PS2 2918.660 RCEF. PS2 430.163 RCEN. PS2 2544.243 RCNT. PS2 1576.136 RCFT. PS2 351.629 CNTC. PS2 1457.294 CFTC. PS2 344.149 NPOR.PS2 46.961 GR.PS2 41.500 TENS. PS2 1470.000 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .006 SERVICE : FLIC VERSION : O01CO1 DATE ' : 98/01/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : LIS Tape Verification Listing Schlumberger Alaska Computing Center 29-JAN-1998 16:54 PAGE: 26 ** END OF DATA ** **** FILE TRAILER **** FILE NAME : EDIT .007 SERVICE : FLIC VERSION : 001C01 DATE : 98/01/29 MAX REC SIZE : 1024 FILE TYPE : LO LAST FILE : **** TAPE TRAILER **** SERVICE NAME : EDIT DATE : 98/01/29 ORIGIN : FLIC TAPE NAME : 98046 CONTINUATION # : 1 PREVIOUS TAPE : COMMENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-26, API~ 50-029-21520-00 **** REEL TRAILER **** SERVICE NAME : EDIT DATE : 98/01/29 ORIGIN : FLIC REEL NAME : 98046 CONTINUATION # : PREVIOUS REEL : COM~4ENT : ARCO ALASKA INC., PRUDHOE BAY, D.S. 4-26, API# 50-029-21520-00
