The URL can be used to link to this page

Home My WebLink About195-1671a. 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 11-22-95 50-029-22613-00-000 PBU 13-36 195-167 13677' / 9079' PRUDHOE BAY, PRUDHOE OIL ADL 0028316 77-04213758 / 9088 2226 / 2207 Approx 1900' / 1900' N/A 0 11-13-22 N/A 12-14-95 4 4 4 5,931,654 5,924,186 5,923,706 687,318 688,741 689,593 MWD, GR, LWD/FE, Gyro, RES, CBL 1138' FNL, 3115' FEL, SEC.25, T10N, R14E 637' FNL, 3955' FEL, SEC. 25, T10N, R14E 3695' FNL, 5187' FEL, SEC.13, T10N, R14E 20" 91.5#H-40 Surface 110'Surface 110'30"260 sx Arctic Set (approx) 10-3/4" 45.5#NT-80 Surface 3432'Surface 3224'13-1/2" 1115 sx CS 111, 375 Class G 7-5/8"29.7#S-95 Surface 12368'Surface 8956'9-7/8"265 sx Glass G 5-1/2" 17#NT-80S Surface 13758'Surface 9088'6-3/4"285 sc Class G 4-1/2" 12232' 12167' n/a n/a 75' 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 / 8860' By James Brooks at 4:29 pm, Nov 30, 2022 Abandoned 11/13/22 JSB RBDMS JSB 121422 xGDSR-1/3/23MGR28JULY2023 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 Jerry Lau Jerry.Lau@hilcorp.com 907-564-5280 9043'12778' Sag River Shublik Sadlerochit 12365' 12404' 12778' 8955' 8973' 9043' 4 12778' 9043' 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), ou=Users Date: 2022.11.30 14:24:40 -09'00' Slickline tag TOC at 11,716' MD MIT failed on this plug - LDL showed competent tubing plug. ACTIVITYDATE SUMMARY 4/30/2022 ***WELL S/I ON ARRIVAL*** (p&a) RAN 3.84" NO-GO CENT & TAG TOP OF CP-2 TRSV @ 2,193' SLM (2,226' MD). RAN 3.84" NO-GO CENT, 12' x 1-1/4" STEM, FLAPPER CHECKER W/ 3.80" PINS, SD @ 2,193' SLM AGAIN & P/U CLEAN. RAN 2.25" CENT, T.E.L, 1-3/4" S.BAILER, SD @12,223' SLM. UNABLE TO WORK PAST. ATTEMPT TO LOC TT ON WAY OUT, SEE SLIGHT OVERPULL @ 12,214' SLM. ***WELL S/I ON DEPARTURE*** 5/14/2022 T/I/O= 600/525/200 Temp= SI Assist SL (Brush and Flush) Pumped 68 bbls crude down TBG to Assist SL. SL in control of well @ departure. FWHP= 300/525/200 5/14/2022 ***WELL S/I ON ARRIVAL*** (plug & abandonment) BRUSHED & FLUSHED TRSSSV @ 2226' MD. RAN 3.85" NO-GO CENT TO 2226' MD. RAN FLAPPER CHECKER TO TRSSSV. (FUNCTONING PROPERLY). LOCKED OUT 4 1/2" HES CP-2 SSSV @ 2226' MD. RE-RAN FLAPPER CHECKER TO CONFIRM FLAPPER LOCKED OPEN. ***WSR CONTINUED ON 5-15-22*** 5/15/2022 ***WSR CONTINUED FROM 5-14-22*** RIG DOWN. ***WELL LEFT S/I ON DEPARTURE*** 5/16/2022 T/I/O = SSV/340/250. Temp = SI. Injectivity test on C&B lines (P&A). Well is disconnected from the system. Injected 2.5 gallons of hydraulic fluid down control line @ 4000 psi. Pressure fell off as soon as pump is shut down. Well does not have a Balance line & Balance line port has 1/2" NPT plug installed in the wellhead. SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:30 5/21/2022 T/I/O = 240/365/200 (P&A) Tbg Injectivity Test 1150 psi @ 5 bpm, IA tracking steady ~1550 psi. Pumped 5 bbls 50/50 followed by 292 bbls 1% KCL and 38 bbls crude for freeze protect. FWHPs = vac/265/100 5/27/2022 Heat DSL transport to 80* 5/28/2022 T/I/O=vac/115/vac Assist Cemnent ( P & A ) Assist HES cement P&A plug #1 Load well with 290 bbls 1%KCL. 5bbl FW, 32bbl 14ppg class G, 2 bbl FW, displace cement to TTL with 184bbl warm diesel. Cement top ~12231', 6" foam ball depth ~12100'. **Complete** 6/3/2022 ***WELL S/I ON ARRIVAL*** TAGGED TOC W/ 2.25" CENT AND 1.75" S-BLR AT 11,716' SLM (11,749' MD) SRT & SPILL CLEAN UP 1.5 GAL - LUBRICATOR(human error) TAGGED TOC W/ 2.25" CENT AND 1.75" S-BLR AT 11,722' SLM (11,755' MD)** STATE WITNESSED HERRERA** ***WELL LEFT S/I ON DEPARTURE, DSO NOTIFIED OF STATUS*** 6/5/2022 T/I/O = SSV/120/Vac. Temp = SI. Cement C&B lines (P&A). Well is disconnected from the system. Pumped 0.5 gallons of fine cement down control line before locking up on pressure. Well does not have a Balance line. Tags hung on C&B lines. SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:45 Daily Report of Well Operations PBU 13-36 Daily Report of Well Operations PBU 13-36 6/8/2022 T/I/O = SSV/500/Vac. Temp = SI. PT C&B lines (P&A). Well is disconnected from the system. PT'd C&B lines to 3500 psi, PASS. SV, WV, SSV = C. MV = O. IA, OA = OTG. 08:45 6/9/2022 ***WELL S/I ON ARRIVAL*** RIH W/ 5' x 1.56" TUNING PUNCH. TAGGED TOC @ 11,730' MD. PUNCH HOLES IN TUBING AT 11655-11660' MD. CCL STOP DEPTH=11635.4', 19.6' CCL TO TS. 200# PRESSURE DECREASE AFTER SHOOTING, TIE INTO TUBING TALLY DATED: 12/22/1995 ***WELL S/I ON DEPARTURE*** 7/11/2022 ** INJECTIVITY TEST ** T/I/O= 380/476/0 Pumped 50 bbls diesel down TBG taking returns up IA to OTT. 3.8 bpm at 2450 psi. 3 bpm at 1175 psi. Then pumped 50 bbls diesel down IA taking returns up TBG to OTT. FWHP's= 0/41/0 7/18/2022 T/I/O = SSV/0/0. Temp = SI. Purge IA valve w/ N2 (post cement). RU N2 to choke trailer. Use N2 to sweep hardline/ Kelly hoses w/ N2 to open top tanks. Sweep N2 through IA valve. IAP increased to 550 psi. Monitor for 30 min, no change in pressure.. SV, WV, SSV = C. MV = O. IA & OA = OTG. 17:30. 7/18/2022 T/I/O=0/0/0 LRS Unit 76. P&A plug #2 of 3 (IA cement) (Also Pumping job log for halliburton cement crew) Assist Halliburton cement crew, LRS pumped an injectivity test. HES pumped 86 BBLS Surfactant, 11 BBLS water, 350 BBLS cement and a 5 BBL freshwater flush. LRS pumped 140 bbls brine and 5 BBL 50/50 Methanol. Cleaned out all surface piping with DSL. TOC in tubing ~9868'. Foam ball ~9539'. IA cemented to surface. FWHP=1800/0/200 ***Complete*** 7/21/2022 T/I/O= 81/50/0 AOGCC State witness MIT T to 2500 PSI. FAILED. See log for details, Multiple attempts FWHP= 80/50/0Kfgghhggvb 7/21/2022 T/I/O= 0/0/0 Pre AOGCC MIT-T MIT-T ***PASS*** at 1800 psi. Pumped a total of 4.4 bbls 50/50 meth down TBG to reach test pressures. Lost 150 psi in 1st 15 min. Lost 50 psi in 2nd 15 min. Bled back `~1 bbl. RDMO notify Pad-op. FWHP's 0/50/0 7/21/2022 ***WELL S/I UPON ARRIVAL*** (p&a) TAGGED TOC W/ 2.25" CENT & 1-3/4" SAMPLE BAILER @ 9249' SLM/ 9282' MD.(recovered sample) TAGGED 4-1/2" TRSV @/ 2226' MD W/ 3.84" NO-GO CENT. (for depth correction) TAGGED TOC W/ 2.25" CENT & 1-3/4" SAMPLE BAILER @ 9252' SLM/ 9285' MD.(recovered sample, AOGCC witnessed-Bob Noble) ***LRS PERFORMING MIT ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** 7/24/2022 T/I/O=0/40/0 MIT T Failed to 2350 psi (2600 psi max applied) (Pre MIT-T for State Witness) Attemp 7 times, 1.3bbls to get up to pressure , bled tbg back to start pressure got back 2bbls. 7/28/2022 T/I/O= VAC/26/VAC TEMP= S/I ( LRS UNIT 70) MIT- T to 2750 PSI **FAILED ** ( MULTIPLE ATTEMPS) ( SEE LOG FOR DETAILS) BLEED TBG TO 0 PSI . FWHP"= 0/20/0 () TAGGED TOC W / 2.25" CENT & 1-3/4" SAMPLE BAILER @ 9249' SLM Daily Report of Well Operations PBU 13-36 7/30/2022 T/I/O= 15/30/0. Temp = SI. MIT-T ***FAIL*** / LLR if fails (P&A) at max 2750 psi, target 2500 psi. Well has hardline r/u to TBG & OA. TBG FL @ surface. Pumped a total of 0.75 bbls diesel down TBG from 0 psi to 2750 in 10 min. Lost 355 psi in 1st 15 min. Lost 115 psi in 2nd 15 min for a total loss of 470 psi in 30 min **FAIL**. LLR = 0.7 GPM @ 2750 psi. Bled back ~1 bbl in 5 min. Notified Pad-op. FWHP's = 15/30/0. SV, WV = C. SSV, MV = O. IA, OA = OTG. 11:30. 9/4/2022 T/I/O= 0/9/VAC TEMP= S/I ( LRS UNIT 76) ** E-LINE ASSIST- LEAK DETECT LOG** PUMPED 1 BBLS DSL DOWN TBG TO REACH TEST PRESSURE . MAINTAINED 2400 - 2600 PSI ENTIRE LOG. ESTABLISHED LLR OF ~ .19 GAL/MIN, 11.34 GAL PER HR, .27 BBLS /HR OR .0045 BBLS/MIN . HAD A 4.2 GAL EVERY 22 MINUTE AVERAGE LOSS. E-LINE IN CONTROL OF WELL UPON DEPARTURE. FWHP'S= 0/6/VAC 9/4/2022 ***WELL SHUT IN ON ARRIVAL*** (LDL) MIRU E-LINE PT 300PSI LOW, 3500PSI HIGH LOG READ LDL FROM TD AT 9232' TO SURFACE WITH LRS PUMPING 2400- 2600PSI TOTAL LLR FOR LOGGING INTERVAL WAS .19 GAL/MIN (see pump report) NO LEAK DETECTED, LOG SENT TO READ SPECIALIST FOR ANALYSIS RDMO E-LINE ***WELL SHUT IN ON DEPARTURE*** 9/12/2022 T/I/O = 60/10/vac. Temp = SI. MIT-T (FAIL) LLR if fails (Plug & Abandon). Max pressure 2750 psi, target 2500 psi. No S-riser, ALspool. Well has hardline R/U toTBG and OA. TBG FL @ surface. Pumped a total of 1.4 bbls DSL down TBG to achieve 2750 psi. Lost 332 psi in 15 min, lost 109 psi in second 15 min. Extend test, lost 64 psi in third 15 min, lost 38 psi in fourth 15 min. Total loss in 60 min was 543 psi. Pressured TBG back up to 2750 psi, used 33.6 gal DSL. LLR of .56 gpm. Second Test: Pressured TBG to 2750 psi DSL. Lost 95 psi in 15 min, lost 39 psi in second 15 min, lost 36 psi in third 15 min, lost 33 psi in fourth 15 min. Total loss of 203 psi in 60 min. (FAIL). Pressured TBG back up to 2750 psi, used 25 gal. LLR of .41 gpm. Bled TBG to 50 psi, returned 1.84 bbls fluid. FWHP's = 50/10/vac. SV, WV, MV, hard line = C. SSV = O. IA & OA = OTG. 19:00. 9/27/2022 ***WELL SHUT IN ON ARRIVAL**** START RIG UP JOB POSTPONED TILL LATER DATE DUE TO PLAN CHANGE AND HAVING TO ORDER GUN CONFIR WITH TOWN AND WANTING TO STICK W/ HES GUN FOR JOB RIG DOWN EQUIPMENT WELL LEFT SHUT IN AND NOTIFY PAD OP OF DEPARTURE ***JOB POSTPONE TILL LATER DATE**** Daily Report of Well Operations PBU 13-36 10/19/2022 ***WELL SHUT IN ON ARRIVAL*** (ADPERF) MIRU E-LINE PT PCE 300PSI LOW, 3000PSI HIGH CORRELATE TO TUBING DETAIL RECORD DATED 22DEC95 PERFORATE TBG 3422' - 3432' WITH 3.125" 6SPF 60PHASE HSC WITH MAXFORCE FLOW CHARGES CCL-TS=7.7', CCL STOP 3414.3' RDMO E-LINE ***WELL SHUT IN ON DEPARTURE*** JOB COMPLETE 10/21/2022 T/I/O= 125/0/300 Injectivity Test (P&A) Pumped 4 bbl 60/40 methanol spear followed by 8 bbls of ambient diesel down the tubing, up the OA, taking returns to surface tanks. Established injection rate of 4 BPM @ 400 psi. Freeze protected surface lines w/ 3 bbls 60/40 methanol. FWHPs= 0/0/0 SV/MV=C, IA/OA=OTG, Hardline= C Well shut in upon departure. 10/23/2022 T/I/O = 0/0/0. Assist Haliburton cement crew. Pumped 5bbls 60/40, 25bbls 130*F diesel, 245bbls 80*F 9.8 brine, 5bbls 60/40 down hole in support of cement crew. Flushed surface lines / freeze protected with a total of 2bls 60/40, 10bbls diesel. FWHP's = 0/0/0. 10/23/2022 ***WELL SHUT IN ON ARRIVAL*** MIRU HES CEMENT VAN LRS PUMPED 5 BBLS OF 60/40, 25 BBLS OF 130*F DIESEL DOWN THE TUBING TAKING RETURNS FROM THE OA. HES PUMP 50 BBLS OF 160* FRESH WATER/SURFACTANT DOWN TUBING. LRS PUMPED 245 BBLS OF 80*F BRINE AND 5 BBLS METH SPACER. HES PUMPED 10 BBLS OF FRESH WATER. HES PUMPED 204 BBLS OF 15.8 PPG OF CLASS G CEMENT DOWN THE TUBING TAKING GOOD CEMENT RETURNS OUT OF THE OA. P&A SURFACE PLUG COMPLETE. FLUSHED SURFACE LINES AND TREE. 11/8/2022 ***P&A In Progress*** Pad Elevation = 45.6'. Tundra Elevation = 39.5'. Excavate to 12' below pad eleveation, 6' below tundra elevation. Set shoring box and rig mats. LDFN. 11/9/2022 ***P&A In Progress*** Set Goliath Wachs Saw 3' below tundra elevation at 36.5'. LDFN. 11/10/2022 ***P&A In Progress*** Cut wellhead 3' below tundra elevation at 36.5'. All annuli are cemented to surface and cement looks to be in good condition. LDFN. 11/11/2022 ***P&A In Progress*** During AOGCC inspection of cut wellhead, the inspector requested that another ~7" of pipe be removed prior to welding the marker plate. Re- install Goliath Wachs saw with cut line 14" below initial cut depth. LDFN. 11/12/2022 ***P&A In Progress*** Cut 14" below the initial cut depth. New depth of cut casing strings is 52" below tundra elevation. All annuli cemented to surface and cement looks to be in good condition.LDFN. 11/13/2022 ***P&A Complete*** AOGCC Rep (Guy Cook) verified cement in all annuli and the installation of the marker plate to the 20" conductor. Pulled the shoring box and confirmed cut casing strings are ~52" below tundra elevation. Pulled rig mats, backfilled and demarcated excavation. RDMO. Photo documentation can be found on the U Drive. 2022-1113_Surface_Abandon_PBU_13-36_gc Page 1 of 6 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO:Jim Regg DATE:11/13/2022 P. I. Supervisor FROM:Guy Cook SUBJECT:Surface Abandonment Petroleum Inspector PBU 13-36 Hilcorp Alaska LLC PTD 1951670; Sundry 322-162 11/11/2022: Traveled out to location and met with Robert Bryan (Hilcorp) to witness cement to surface, confirm cut-off depth, confirm the information on the marker plate was correct, and witness the installation of the marker plate. After measuring from the top of the pad down to the cut off casing and getting the information about pad depth and tundra depth from Mr. Bryan, I concluded that the casing was cut approximately eight inches high. Mr. Bryan agreed they needed to cut the casing again to get it at least 3 feet under original tundra level. I left location after informing Mr. Bryan to let us know when he is ready for us to witness. 11/13/2022: I returned to PBU 13-36 and again met with Mr. Robert Bryan to witness the well’s surface abandonment. This time the casing had been cut deep enough to be 3 feet 5 inches below tundra level. The identification plate was installed, and all the proper information was confirmed to be on the plate. I informed Mr. Bryan that the well could be buried prior to leaving location. Attachments: Photos (10) 9 9 9 9 pp casing was cut approximately p eight inches high. y casing had been cut deep enough James B. Regg Digitally signed by James B. Regg Date: 2023.04.07 12:28:43 -08'00' 2022-1113_Surface_Abandon_PBU_13-36_gc Page 2 of 6 Surface Abandonment – PBU 13-36 (PTD 1951670) Photos by AOGCC Inspector G. Cook 11/11/2022 – 11/13/2023 11/11/2022 – Cut casing competent cement to surface (L); Cut depth (R) 2022-1113_Surface_Abandon_PBU_13-36_gc Page 3 of 6 11/11/2022 – Marker Plate (L); Wellhead (R) 2022-1113_Surface_Abandon_PBU_13-36_gc Page 4 of 6 11/13/2022 – New cutoff (L); Marker Plate on Casing Stub (R) 2022-1113_Surface_Abandon_PBU_13-36_gc Page 5 of 6 11/13/2022 – Marker Plate weld views 2022-1113_Surface_Abandon_PBU_13-36_gc Page 6 of 6 11/13/2022 – Marker Plate weld views From:Rixse, Melvin G (OGC) To:AOGCC Records (CED sponsored) Subject:FW: [EXTERNAL] RE: 13-36 P&A - PTD: 195-167 Date:Thursday, September 15, 2022 4:45:42 PM Attachments:image001.png LP HC 13-36.pdf DS13-36 MIT-T to 2750 psi. 9-12-22.xls From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Tuesday, September 13, 2022 1:14 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: 13-36 P&A - PTD: 195-167 Mel, An acoustic LDL was run on 13-36 on 9/4/22 to determine the source of the failing MIT-Ts post reservoir/ IA P&A cement job. Calculated leak rate for the ~7 hrs of logging began at 1.3 gpm and reduced to 0.15 gpm for an average of 0.19 gpm @2500 psi. The initial station log above the cement top (Eline correlated tag 3x @ 9217’ MD) was executed for an hour at the highest leak rate and showed no leak signature. A full pass was logged with the leak active across the entirety of the well including stop counts across the patch and previous cretaceous leak depth. No leak signatures were found. On 9/12/22, two MIT-T’s were conducted to 2750 psi max applied pressure and extended to one hour to better understand the pressure fall off. In the first hour test the pressure loss for the 15 minute intervals were: -322 psi, -109 psi, -64 psi, -38 psi. In the second hour test the pressure loss for the 15 minute intervals were: -95 psi, -39 psi, -36 psi, -33 psi. Test passed in the first 30 min of the 2nd hr test. Similar to the LDL leak rate, during the MIT’s the leak path is loading up and progressively reducing the LLR as more fluid is pumped, stabilizing at an extremely low leak rate. During the initial station log above the cement top at 9217’ MD, the acoustic and temperature signals would have been the most prominent due to the LLR being the highest if a leak were present. Based on this information it is unlikely that the cement top is leaking. In contrast, by the time logging was executed across the patch and cretaceous leak the LLR was extremely low which may have made the leak undetectable. I have attached the digital MIT-T data for you to review if you like. While this isn’t an ideal situation I think we have good evidence that the tubing cement top is not leaking based on the LDL. Let me know what you think and if you approve moving forward with the surface cement part of the procedure or want to discuss it more on Thursday. Regards, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Oliver Sternicki Sent: Thursday, September 1, 2022 3:51 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: 13-36 P&A - PTD: 195-167 Roger, I’ll send it to you when we get it. Thanks, Oliver From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Thursday, September 1, 2022 3:36 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Subject: RE: [EXTERNAL] RE: 13-36 P&A - PTD: 195-167 Oliver, No change to the approved sundry unless the LDL shows leaking to the reservoir plug. AOGCC does want to see the log. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, September 1, 2022 2:12 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] RE: 13-36 P&A - PTD: 195-167 Alright, I’ll write up a program to get eline out there and execute it. Assuming no sundry change request needed since this is diagnostic work? Thanks, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Thursday, September 1, 2022 2:08 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] RE: 13-36 P&A - PTD: 195-167 Oliver, I could approve that. AOGCC would request to see the log before pumping cement. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Bryan, Aras From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, September 1, 2022 11:06 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] RE: 13-36 P&A - PTD: 195-167 Mel, We can run an LDL to confirm no flow past the cement top, this was proposed as one of the options in the previous conversation. Due to the low leak rate (0.7 gpm) we would propose to run an acoustic LDL. Logging program would look like this: 1. Baseline temp pass from surface to cement top with the well in static state. 2. Station log at the cement top while pumping (2600-2400 psi) on the tubing for ~1 hr, monitoring for a temperature shift or acoustic signal increase that would indicate flow past the plug. 3. Once station log is complete, log to surface while continuing to pump on the tubing. 4. Station log across patch/ cretaceous leak depth and over any other anomalies. This should give us good confirmation of where we are losing fluid to. Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Thursday, September 1, 2022 10:48 AM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] RE: 13-36 P&A - PTD: 195-167 Oliver, Please refresh my memory. Why can’t Hilcorp run a LDL to determine where the tubing is leaking? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Wednesday, August 31, 2022 10:29 AM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov>; McLellan, Bryan J (OGC) <bryan.mclellan@alaska.gov> Cc: Aras Worthington <Aras.Worthington@hilcorp.com> Subject: RE: [EXTERNAL] RE: 13-36 P&A - PTD: 195-167 Mel, I got some more information pertaining to discussion of 13-36 where we left off last week regarding tagging the cement top with coil tubing vs drill pipe on a rig. According to the Cerberus modeling we can put ~3600 pounds of downforce on the cement plug at 9285’ MD with 1-3/4” coil. Surface downforce with the injector can’t transfer any more weight downhole due the coil going helical in the tubing. Do you consider 3600 pounds to be “sufficient weight” in compliance with the plug confirmation requirements in 25.112(g)(1)? Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Friday, August 19, 2022 5:13 PM To: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Cc: Ryan Thompson <Ryan.Thompson@hilcorp.com> Subject: RE: [EXTERNAL] RE: 13-36 P&A - PTD: 195-167 Oliver, In my opinion both options are unacceptable. I would like to see pressure isolation across all annuli as near the reservoir as possible. I will discuss with staff and commissioners, then get back to you. Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). cc. Ryan Thompson From: Oliver Sternicki <Oliver.Sternicki@hilcorp.com> Sent: Thursday, August 18, 2022 12:03 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Subject: RE: [EXTERNAL] RE: 13-36 P&A - PTD: 195-167 Mel, The top of the Ivishak in 13-36 is at 12710’ MD so the initial reservoir plug with the cement top at 12231’ MD gives us good isolation. In general remedial cement tops come in high on the tubing side and a 500’ high tag is not uncommon. The reason for this is believed to be caused by internal corrosion of the tubing increasing the actual volume per foot compared to the calculated tubing ID used for cement displacement volumes. On 13-36, the L-80 tubing is 27 years old and a caliper in 2010 showed maximum wall penetrations of 32%. These differences in the actual vs mill spec volumes are not taken into account for displacement of the cement due to the inaccuracy in attempting to calculate the change in volume hence the cement top on the tubing come in shallow. To compensate for this we pump excess cement to ensure we have the needed coverage. How would you like to proceed based on the two options proposed by Ryan in the previous email? Thanks, Oliver Sternicki Hilcorp Alaska, Hilcorp North Slope LLC Well Integrity Engineer Office: (907) 564 4891 Cell: (907) 350 0759 Oliver.Sternicki@hilcorp.com From: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Sent: Monday, August 8, 2022 3:45 PM To: Ryan Thompson <Ryan.Thompson@hilcorp.com> Cc: Aras Worthington <Aras.Worthington@hilcorp.com> Subject: [EXTERNAL] RE: 13-36 P&A - PTD: 195-167 Ryan, I want to assure we have pressure isolation as near the reservoir as possible and in the tubing across the Ivishak confining zones. Why is your tag so high at 9252’MD? Mel Rixse Senior Petroleum Engineer (PE) Alaska Oil and Gas Conservation Commission 907-793-1231 Office 907-297-8474 Cell CONFIDENTIALITY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mel Rixse at (907-793-1231 ) or (Melvin.Rixse@alaska.gov). CAUTION: This email originated from outside the State of Alaska mail system. Do not click links or open attachments unless you recognize the sender and know the content is safe. From: Ryan Thompson <Ryan.Thompson@hilcorp.com> Sent: Monday, August 8, 2022 1:41 PM To: Rixse, Melvin G (OGC) <melvin.rixse@alaska.gov> Cc: Aras Worthington <Aras.Worthington@hilcorp.com> Subject: 13-36 P&A - PTD: 195-167 Hi Mel – For the 13-36 P&A, we would like to come up with a plan forward since the MIT-T following our second stage cement job did not pass. Here is where we are at: 1. We pumped 350 bbls of cement getting cement returns to surface in the IA, the IA is now cemented. Tubing is loaded w/ 9.8 brine. 2. SL tagged top of cement in the tubing @ 9252’ MD (AOGCC witnessed). 3. The MIT-T failed, starting pressure of 2750, lost 470 psi in 30 minutes. 0.7 gpm LLR. We propose 1 of the 2 options below. Option 1: Move forward with the surface cement plug, cementing tubing and OA from the surface casing shoe to surface. Option 2: 1. Eline set CIBP @ ~3600’ MD. 2. Dump bail 25’ of cement on the CIBP. 3. Slickline tag TOC (AOGCC witnessed). 4. MIT-T to 2239 psi passing pressure, 2500 psi max applied pressure (8956’ TVD depth of the 7 5/8” casing shoe x 0.25) 5. Move forward with the surface cement job as planned. Attached is the approved sundry. Please let me know your thoughts on proceeding. Thanks, Ryan The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are herebynotified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of theindividual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that the onward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibilityis accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. The information contained in this email message is confidential and may be legally privileged and is intended only for the use of the individual or entity named above. If you are not an intended recipient or if you have received this message in error, you are hereby notified that any dissemination, distribution, or copy of this email is strictly prohibited. If you have received this email in error, please immediately notify us by return email or telephone if the sender's phone number is listed above, then promptly and permanently delete this message. While all reasonable care has been taken to avoid the transmission of viruses, it is the responsibility of the recipient to ensure that theonward transmission, opening, or use of this message and any attachments will not adversely affect its systems or data. No responsibility is accepted by the company in this regard and the recipient should carry out such virus and other checks as it considers appropriate. Data Collection Report Chassis Left Scale Right Scale Serial Number 072842 073254 071034 Datatype Lower Upper Units PSI G PSI G Lower Upper -6 -5 -4 -3 -2 -1 0 -500 0 500 1000 1500 2000 2500 3000 PSI GPSI G Elapsed Time hh:mm:ss Run # 2 -12-Sep-22, 03:11:01, 12147 PSI G PSI G Document Number Document Name LeakPoint Survey Revision 1 Well Name 13-36 Analyst Joel Johns Field Name Prudhoe Bay Unit Survey Date 09/04/2022 Report Date 9/05/2022 Page 1 of 12 Archer LeakPoint™ Final Job Report Hilcorp 13-36 Prudhoe Bay Unit 09/05/2022 Rev 1 Document Number Document Name LeakPoint Survey Revision 1 Well Name 13-36 Analyst Joel Johns Field Name Prudhoe Bay Unit Survey Date 09/04/2022 Report Date 9/05/2022 Page 2 of 12 Archer LeakPoint™ Final job report Client: Hilcorp Well: 13-36 Field: Prudhoe Bay Unit Country: USA Survey date: 09/04/2022 Report date: 09/05/2022 Reference number: Field Engineer/Log analyst: B. Suhanek/Joel Johns Reviewed by: Revision: 1 Submitted by (Analyst sign)Approved by (Reviewer sign) Print name Print name Document Number Document Name LeakPoint Survey Revision 1 Well Name 13-36 Analyst Joel Johns Field Name Prudhoe Bay Unit Survey Date 09/04/2022 Report Date 9/05/2022 Page 3 of 12 Table of Contents Page 1 2 3 4 4.1 4.2 4.3 Introduction Executive summary Data Acquisition, presentation and analysis Interpretation of Data Summary of results Station Readings At Cement Plug Station Readings Across Patch 4 4 4 4 4 5 6 5 Appendix 1 Appendix 2 Appendix 3 Appendix 4 Conclusions/Discussion Operations Summary Pressure Data Well Schematic Sensor Configuration 7 8 10 11 12 Document Number Document Name LeakPoint Survey Revision 1 Well Name 13-36 Analyst Joel Johns Field Name Prudhoe Bay Unit Survey Date 09/04/2022 Report Date 9/05/2022 Page 4 of 12 1.Introduction A LeakPoint Survey was run in SRO mode with the objective: Determine the location leak causing failing MIT-T. 2.Executive summary A LeakPoint survey was performed to locate the leak causing failing MIT-T. A leak was established by pressuring the tubing to 2,600 psi and taking returns to the formation or cemented annulus. A rate of 0.19 gpm was maintained during the course of the log. No conclusive leaks were located. 3.Data acquisition, presentation and analysis Logging Summary Program Phase Tubing A-annulus B-annulus Comment Run 1 2600 0 0 0.19 gpm 4.Interpretation of data 4.1.Summary of results Depth ft.Comment No Conclusive Leaks Document Number Document Name LeakPoint Survey Revision 1 Well Name 13-36 Analyst Joel Johns Field Name Prudhoe Bay Unit Survey Date 09/04/2022 Report Date 9/05/2022 Page 5 of 12 4.2.Station Readings At Cement Plug Document Number Document Name LeakPoint Survey Revision 1 Well Name 13-36 Analyst Joel Johns Field Name Prudhoe Bay Unit Survey Date 09/04/2022 Report Date 9/05/2022 Page 6 of 12 4.3.Station Readings Across Patch Document Number Document Name LeakPoint Survey Revision 1 Well Name 13-36 Analyst Joel Johns Field Name Prudhoe Bay Unit Survey Date 09/04/2022 Report Date 9/05/2022 Page 7 of 12 5.Conclusion/Discussion x The 13-36 is currently under evaluation for P/A operations. The well has a cemented annulus has a cement plug installed at 9,285’ MD. A patch is installed from 5,454’ to 5,485’ MD. MIT-T failed to 0.7 gpm at 2,500 psi. A suspected cretaceous leak was reported in the PC at 5,450’ MD. A LeakPoint survey was run to determine the location of the leak causing the failing MIT-T. This would entail checking the cement plug, patch and remainder of the interval for leaks. x After tagging up on the cement plug, the tool string was placed near the top of cement. A leak was activated by pressuring the tubing to 2,600 psi and taking returns to the cemented annulus/formation. A one hour station reading was taken at depth followed by stations moving away from the plug. Section 4.2 shows the results of this portion of the logging operation. The acoustic tools showed base line readings indicating no leak was present in this area. The temperature measurements remained steady during this time period indicating no liquid movement deeper in the well. x To keep the leak active, it was planned to keep the tubing between 2,400 and 2,600 psi. Referring to the pressure measurements in Section 4.2, it was noted that elapsed time between pressure cycles went from 2.6 minutes to 23.3 minutes, approximately. Based on pressure loss over time in fixed volume, this equates to a 1.3 gpm rate reducing to 0.15 gpm. The average rate reported from the field was 0.19 psi. x Under the above conditions, a 30 fpm pass was taken from the plug to surface. Station readings were taken across the patch and across the suspected cretaceous leak area. The dynamic logging pass indicated no leaks. The station readings across the patch and cretaceous area yielded base line results also showing no signs of leak activity (Section 4.3). x The lack of discernable signal is likely due to the volume behind the leak loading up due to the cemented annulus restricting the flow path. It is typical to maximize rate and differential when executing a LeakPoint survey. In this case with the casing expanding a bit when pressured, this may produce diminishing returns under higher pressure. If further logging is required, it might be useful to test bleed off rate under lower pressures to attempt to increase the rate. x Utilizing an S300 (FlowPoint) sensor in stationary logging mode should be considered as well as an alternative. x Full API prints to be provided by Read Cased Hole. Document Number Document Name LeakPoint Survey Revision 1 Well Name 13-36 Analyst Joel Johns Field Name Prudhoe Bay Unit Survey Date 09/04/2022 Report Date 9/05/2022 Page 8 of 12 Appendix 1 – Operations Summary Date Time Description 4-Sep-22 8:00 Travel 8:30 Arrive - On Location 8:35 Safety meeting 8:45 Rig up equipment 9:15 Pass #1 - Surface test 9:27 Stab on Lubricator - Run 1 10:04 Pass #2 - BL Temp Downpass 11:45 Pass #3 - Pressure up tubing, sitting above cement in tubing 11:50 Begin 1-hr of recording w/ tbg at 2400-2600 psi per program Tubing cement is holding Pass #4 - Begin logging up. Informed by LRS that tubing appeared to be holding prior to beginning logging. RBIH to btm and do MIT-T (failed) 13:50 Pass #5 - Main 30 fpm Up Pass 15:58 Pass #6 - 1-min stops every 3' across patch per program (no leak) 16:28 Pass #7 - Continue Main 30 fpm Up Pass. LLR = 0.19 gpm. 19:27 Bump up in lub. Did not find definitive leak. Send Joel Johns the data. 20:15 Break Off Lubricator - Run 1 20:30 Travel 21:00 Arrive - Not On Location Document Number Document Name LeakPoint Survey Revision 1 Well Name 13-36 Analyst Joel Johns Field Name Prudhoe Bay Unit Survey Date 09/04/2022 Report Date 9/05/2022 Page 9 of 12 21:05 Service tools 22:00 End Ticket Document Number Document Name LeakPoint Survey Revision 1 Well Name 13-36 Analyst Joel Johns Field Name Prudhoe Bay Unit Survey Date 09/04/2022 Report Date 9/05/2022 Page 10 of 12 Appendix 2 – Pressure Data Date Time Tubing IA OA Leak Rate (bpm)Comments 4-Sep-22 10:00 0 0 0 N/A Begin BL Downpass 11:39 315 0 0 N/A Tools on Btm 11:50 2600 0 0 0.19 Begin 1-hr station stop on top of cement 12:50 2550 0 0 0.19 Begin 2-min stops every 3' from cement 13:12 2605 0 0 0.19 Begin MIT-T 13:51 2600 0 0 0.19 Begin Main 30 fpm Up Pass Document Number Document Name LeakPoint Survey Revision 1 Well Name 13-36 Analyst Joel Johns Field Name Prudhoe Bay Unit Survey Date 09/04/2022 Report Date 9/05/2022 Page 11 of 12 Appendix 3 -Well Schematic Document Number Document Name LeakPoint Survey Revision 1 Well Name 13-36 Analyst Joel Johns Field Name Prudhoe Bay Unit Survey Date 09/04/2022 Report Date 9/05/2022 Page 12 of 12 Appendix 4 – Sensor Configuration MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 13 Township: 10N Range: 14E Meridian: Umiat Drilling Rig: NA Rig Elevation: NA Total Depth: 13758 ft MD Lease No.: ADL 0028316 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 110 Feet Csg Cut@ Feet Surface: 10 3/4" O.D. Shoe@ 3432 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7 5/8" O.D. Shoe@ 12368 Feet Csg Cut@ Feet Liner: 5 1/2" O.D. Shoe@ 13758 Feet Csg Cut@ Feet Tubing: 4 1/2" O.D. Tail@ 12232 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Balanced 11755 ft 9285 ft 9.8 brine Wireline tag Initial 15 min 30 min 45 min Result Tubing 2510 2375 2273 IA 50 50 50 OA 0 0 0 Remarks: Attachments: I arrived on location and met with the Hilcorp representastive John Conrad. He wanted to tag the plug first. Wireline was rigged up and started in the hole. John said that they had pumped 360 BBLs of 14 ppg class G cement. Wireline hit bottom at 9285 ft MD. I had them hit down on it a few times. Wireline was pulled out of the hole and the bailer was checked. It was full of soft cement (felt like putty) with a diesel smell. A 2500 psi MIT-T was peformed - lost 135 psi in the first 15 min and 102 psi in the second 15 min. I ask John if he wanted to hold it for 45 min. He said no as they tried a pretest on it and it keeps losing 100 psi every 15 min. He said that they need to regroup. July 21, 2022 Bob Noble Well Bore Plug & Abandonment PBU 13-36 Hilcorp North Slope, LLC PTD 1951670; Sundry 322-162 none Test Data: F Casing Removal: John Conrad Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 11-28-18 2022-0721_Plug_Verification_PBU_13-36_bn 9 9 999 9 9 9 9 9 9 9 9 9 9 999 9 p A 2500 psi MIT-T was peformed - lost 135 psi in the first 15 min and 102 psi in the(py)pp p p second 15 min. I ask John if he wanted to hold it for 45 min. He said no as they tried a pretest on it and it keeps losing 100 psi every 15 min. He said that they need to regroup. James B. Regg Digitally signed by James B. Regg Date: 2022.09.13 14:59:41 -08'00' MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg DATE: P.I. Supervisor SUBJECT: FROM: Petroleum Inspector Section: 13 Township: 10N Range: 14E Meridian: Umiat Drilling Rig: N/A Rig Elevation: N/A Total Depth: 13758 ft MD Lease No.: ADL 0028316 Operator Rep: Suspend: P&A: X Conductor: 20" O.D. Shoe@ 110 Feet Csg Cut@ Feet Surface: 10 3/4" O.D. Shoe@ 3432 Feet Csg Cut@ Feet Intermediate: O.D. Shoe@ Feet Csg Cut@ Feet Production: 7 5/8" O.D. Shoe@ 12368 Feet Csg Cut@ Feet Liner: 5 1/2" O.D. Shoe@ 13758 Feet Csg Cut@ Feet Tubing: 4 1/2" O.D. Tail@ 12232 Feet Tbg Cut@ Feet Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore Bottom 13678 ft 11755 ft 15.8 ppg Wireline tag Initial 15 min 30 min 45 min Result Tubing IA OA Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Attachments: PBU 13-36 was drilled in 1995 as a Produced Water Injector. Well has been offline for extended period with well bore integrity issues in both casing and tubing. Hilcorp has determined the well to be not economically feasable to repair and put back in service. P&A per Sundry 322-162. June 3, 2022 Matt Herrera Well Bore Plug & Abandonment PBU 13-36 Hilcorp North Slope LLC PTD 1951670; Sundry 322-162 none Test Data: Casing Removal: Caleb Piaskowski Casing/Tubing Data (depths are MD): Plugging Data (depths are MD): rev. 11-28-18 2022-0603_Plug_Verification_PBU_13-36_mh 9 9 9 9 9 9 9 9 9 9 9 9 9 99 9 James B. Regg Digitally signed by James B. Regg Date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y Samantha Carlisle at 9:42 am, Mar 24, 2022 'LJLWDOO\VLJQHGE\%R<RUN '1FQ %R<RUN RX 8VHUV 'DWH %R<RUN 0*5$35 $2*&&WRZLWQHVVVOLFNOLQHWDJRIUHVHUYRLUDEDQGRQPHQWSOXJZLWK72&a 0' $2*&&WRZLWQHVV0,77DQGVOLFNOLQHWDJRI72&a 0' 3KRWRGRFXPHQW72&LQDOODQQXOLEHIRUHZHOGLQJSODWHDQGZHOGHGSODWHLQSODFH ; '65'/% GWV -/& Jeremy Price Digitally signed by Jeremy Price Date: 2022.04.11 14:01:29 -08'00' RBDMS SJC 041222 WΘ ϭϯͲϯϲ Wd͗ϭϵϱͲϭϲϳ tĞůůEĂŵĞ͗ϭϯͲϯϲ W/EƵŵďĞƌ͗ϱϬϬϮϵϮϮϲϭϯϬϬ ƵƌƌĞŶƚ^ƚĂƚƵƐ͗^ŚƵƚ/Ŷ ZŝŐ͗/ŶƚĞƌǀĞŶƚŝŽŶƐ ƐƚŝŵĂƚĞĚ^ƚĂƌƚĂƚĞ͗ϰͬϭϱͬϮϮ ƐƚŝŵĂƚĞĚƵƌĂƚŝŽŶ͗ϳĂǇƐ ZĞŐƵůĂƚŽƌǇŽŶƚĂĐƚ͗ĂƌƌŝĞ:ĂŶŽǁƐŬŝ WĞƌŵŝƚƚŽƌŝůůEƵŵďĞƌ͗ϭϵϱͲϭϲϳ &ŝƌƐƚĂůů ŶŐŝŶĞĞƌ͗ZǇĂŶdŚŽŵƉƐŽŶ ϵϬϳͲϱϲϰͲϱϮϴϬͬϵϬϳͲϯϬϭͲϭϮϰϬ ^ĞĐŽŶĚĂůůŶŐŝŶĞĞƌ͗ĂǀĞũŽƌŬ ϵϬϳͲϱϲϰͲϰϲϳϮͬϵϬϳͲϰϰϬͲϬϯϯϭ ƵƌƌĞŶƚŽƚƚŽŵ,ŽůĞWƌĞƐƐƵƌĞ͗ϯϱϭϳ ƉƐŝ Λ ϴ͕ϴϬϬ͛dsϳ͘ϳ WW'ͮ DĂǆ͘ŶƚŝĐŝƉĂƚĞĚ^ƵƌĨĂĐĞWƌĞƐƐƵƌĞ͗Ϯϲϯϳ ƉƐŝ ;ĂƐĞĚŽŶϬ͘ϭƉƐŝͬĨƚ͘ŐĂƐŐƌĂĚŝĞŶƚͿ >ĂƐƚ ^/ t,W͗ϯϮϬ ƉƐŝ ;dĂŬĞŶ ŽŶ ϮͬϮϭͬϮϬͿ DŝŶ/͗Ϯ͘ϰϱ͟ / Λ >dW DĂǆŶŐůĞ͗ϵϭΣ ĞŐ Λ ϭϯ͕ϬϮϬ͛D ,d͗ ƌŝĞĨtĞůů^ƵŵŵĂƌǇ͗ ϭϯͲϯϲŝƐĂWt/ĚƌŝůůĞĚŝŶϭϵϵϱĂŶĚůĂƐƚŝŶũĞĐƚĞĚŝŶϮϬϭϬ͘dŚĞǁĞůů ĐƵƌƌĞŶƚůǇŚĂƐďŽƚŚĂWůĞĂŬĂŶĚŚŽůĞƐŝŶƚŚĞ ƚƵďŝŶŐ ΘŚŽůĚƐůŝƚƚůĞǀĂůƵĞĨŽƌŝŶũĞĐƚŝŽŶĂƚ&^ϯ͘ dŚĞǁĞůůŝƐĐƵƌ ƌĞŶƚůǇĐůĂƐƐŝĨŝĞĚĂƐŶŽƚ ʹ ŽƉĞƌĂďůĞ͘ dŚĞWůĞĂŬǁĂƐ ŝĚĞŶƚŝĨŝĞĚ ΛϱϰϱϬ͛ďǇĂϮϬϭϭ>>;ϭďƉŵΛϭϮϬϬƉƐŝ>>ZͿ͘ DƵůƚŝƉůĞ ƚƵďŝŶŐůĞĂŬƐŝĚĞŶƚŝĨŝĞĚŝŶ ϮϬϭϮ;ϳϯϭϱ͕͛ϲϱϰϴ͛ ΘϱϬϬϲ͛Ϳ͘ ƵƌŝŶŐĚƌŝůůŝŶŐƚŚĞƐƵƌĨĂĐĞĐĂƐŝŶŐǁĂƐĐĞŵĞŶƚĞĚƚŽƐƵƌĨĂĐĞǁͬϮϬϬйĐĞŵĞŶƚǀŽůƵŵĞĂŶĚĂƚŽƉũŽďǁĂƐ ĐŽŶĚƵĐƚĞĚ͘ĂůĐƵůĂƚĞĚƚŽƉŽĨĐĞŵĞŶƚďĞŚŝŶĚƚŚĞϳϱͬϴ͟ ƉƌŽĚƵĐƚŝŽŶ ĐĂƐŝŶŐŝƐϭϬ͕ϵϱϳ͛D͘ KďũĞĐƚŝǀĞ͗ dŚĞŝŶƚĞŶƚŽĨƚŚŝƐƉƌŽŐƌĂŵ ŝƐƚŽƉĞƌĨŽƌŵĂĨƵůůWΘŽĨƚŚĞǁĞůůƉĞƌ ϮϬϮϱ͘ϭϭϮ͘tĞǁŝůůĞǆĐĂǀĂƚĞĂŶĚĐƵƚ ĐĂƐŝŶŐƐϯ͛ďĞůŽǁƚŚĞŽƌŝŐŝŶĂůƚƵŶĚƌĂůĞǀĞůĂŶĚŝŶƐƚĂůůĂŵĂƌŬĞƌƉůĂƚĞ͘ '/% WΘ ϭϯͲϯϲ Wd͗ϭϵϱͲϭϲϳ ϭ͘ ^ůŝĐŬůŝŶĞ Ă͘ ƌŝĨƚ ƚŽWdǁͬ ^Θd>͘ ď͘ dŚĞǁĞůůŚĂƐĂdZ^sƚŚĂƚĂƉƉĞĂƌƐƚŽďĞ ĨƵŶĐƚŝŽŶŝŶŐ͕ƚŚĞůĂƐƚĨůĂƉƉĞƌĐŚĞĐŬĞƌƌƵŶǁĂƐĐŽŶĚƵĐƚĞĚŝŶ ϮϬϭϮ͘ Ϯ͘ ^ƉĞĐŝĂůWƌŽũĞĐƚƐ Ă͘ ĞŵĞŶƚĐŽŶƚƌŽůͬďĂůĂŶĐĞůŝŶĞƐƚŽƐƵƌĨĂĐĞ͘ ϯ͘ , Ă͘ tĂŝƚŽŶĐĞŵĞŶƚϯĚĂǇƐ͕D/dĐŽŶƚƌŽůĂŶĚďĂůĂŶĐĞůŝŶĞƐƚŽϮϱϬϬƉƐŝ͘ ď͘ WĞƌĨŽƌŵ/&>ƐŚŽƚ͘ ϰ͘ &ƵůůďŽƌĞ Ă͘ WƵŵƉ/ŶũĞĐƚŝǀŝƚǇdĞƐƚ͕ƵůůŚĞĂĚ ŝŶƚŽƌĞƐĞƌǀŽŝƌ͘ x ϱ ďďůƐDĞK, x ϰϰϬďďůƐϭй<>Žƌ^t x &ƌĞĞǌĞƉƌŽƚĞĐƚ ǁͬϯϴďďůƐĚŝĞƐĞů x DĂǆƉƌĞƐƐƵƌĞϮϱϬϬƉƐŝ ΎΎΎEŽƚĞ ǁŝƚŚƚŚĞϰЪ͟ƉĂƚĐŚĂϳ͟ďĂůůƐŚŽƵůĚǁŽƌŬďƵƚĐŽŶƐŝĚĞƌƵƐŝŶŐĂϱ͟ďĂůůŝĨƚŚĞϮ͘ϰϱ͟ƉĂƚĐŚƌĞƐƚƌŝĐƚŝŽŶŝƐŽĨ ĐŽŶĐĞƌŶΎΎΎ ď͘ WƵŵƉ ZĞƐĞƌǀŽŝƌďĂŶĚŽŶŵĞŶƚƉůƵŐ͕dKŝƐƉůĂŶŶĞĚĂƚΕϭϮ͕ϯϬϬ͛DŝŶƐŝĚĞƚŚĞϰЪ͟ƚƵďŝŶŐ͘ ƵůůŚĞĂĚŝŶƚŽƚŚĞƌĞƐĞƌǀŽŝƌĂƐĨŽůůŽǁƐ͗ x ϱ ďďůƐDĞK, x ϭϬďďůƐĨƌĞƐŚǁĂƚĞƌ x ϯϮ ďďůƐ ϭϰƉƉŐ ĐůĂƐƐ'ĐĞŵĞŶƚ x ϱďďůƐĨƌĞƐŚǁĂƚĞƌ x &ŽĂŵĂůů x ϭϴϴ ďďůƐĚŝĞƐĞůĚŝƐƉůĂĐĞŵĞŶƚ x DĂǆƉƌĞƐƐƵƌĞϮϱϬϬƉƐŝ ΎΎΎEŽƚĞǁĞǁŝůůďĞƵŶĂďůĞƚŽƉƌĞƐƐƵƌĞƚĞƐƚƚŚĞƌĞƐĞƌǀŽŝƌĂďĂŶĚŽŶŵĞŶƚƉůƵŐĚƵĞƚŽƚŚĞƚƵďŝŶŐŚŽůĞƐĂŶĚƚŚĞ ŬŶŽǁŶWůĞĂŬ͘D/dͲ/͛Ɛ͕D/d͛ƐΘD/dͲd͛ƐŚĂǀĞĐŽŶƐŝƐƚĞŶƚůǇĨĂŝůĞĚƐŝŶĐĞϮϬϭϬ͘ ϱ͘^ůŝĐŬůŝŶĞ Ă͘ tĂŝƚŽŶĐĞŵĞŶƚϯĚĂǇƐ͘ ƌŝĨƚĂŶĚƚĂŐƚŽdKŝŶƐŝĚĞƚŚĞϰЪ͟ƚƵďŝŶŐ ʹ K'tŝƚŶĞƐƐĞĚ ď͘ WƵŶĐŚƚƵďŝŶŐǁŝƚŚϱĨƚŽĨƚƵďŝŶŐƉƵŶĐŚĞƐ ΛΕϭϮ͕Ϭϳϱ͛ ŽƌϳϱĨƚĂďŽǀĞdKŝŶƐŝĚĞƚŚĞϰͲϭͬϮ͟ƚƵďŝŶŐ͕ ǁŚŝĐŚĞǀĞƌŝƐŚŝŐŚĞƌ͘ ϲ͘ &ƵůůďŽƌĞ Ă͘ ZŝŐƵƉƚŽďĞĂďůĞƚŽƉƵŵƉĚŽǁŶƚŚĞƚƵďŝŶŐĂŶĚƚĂŬĞƌĞƚƵƌŶƐĨƌŽŵƚŚĞ/͘ ď͘ WƵŵƉƚŚĞĨŽůůŽǁŝŶŐ ƚŽǀĞƌŝĨǇdΘ/ĐŽŵŵƵŶŝĐĂƚŝŽŶ x ϱďďůƐDĞK, x ϱϬďďůƐĚŝĞƐĞů x DĂǆƉƌĞƐƐƵƌĞǁŚŝůĞƉƵŵƉŝŶŐϮϱϬϬ ƉƐŝ͘ WΘ ϭϯͲϯϲ Wd͗ϭϵϱͲϭϲϳ Đ͘ WƵŵƉƚŚĞĨŽůůŽǁŝŶŐĐĞŵĞŶƚƉůƵŐ͗ x ϱďďůƐDĞK,;ĂƐƌĞƋƵŝƌĞĚͿ x ϳϱďďůƐŽĨŚŽƚĨƌĞƐŚǁĂƚĞƌ;ΕϭϲϬĚĞŐ&ͿнƐƵƌĨĂĐƚĂŶƚ;ϮŐĂůͬŵŐĂů&ϭϬϯĂŶĚϮŐĂůͬŵŐĂůhKϲϳͿ x ϭϬďďůƐĨƌĞƐŚǁĂƚĞƌ x ϯϳϬ ďďůƐ ϭϰƉƉŐ ůĂƐƐ'ĐĞŵĞŶƚ;ΕϮϮ ďďůƐŽǀĞƌĐĂůĐƵůĂƚĞĚǀŽůƵŵĞͿ͘ x ϱďďůƐĨƌĞƐŚǁĂƚĞƌ x &ŽĂŵĂůů x ϭϰϮ ďďůƐϵ͘ϴƉƉŐďƌŝŶĞ x ϱďďůƐϲϬͬϰϬĨŽƌĨƌĞĞǌĞƉƌŽƚĞĐƚ x DĂǆƉƌĞƐƐƵƌĞǁŚŝůĞƉƵŵƉŝŶŐϮϱϬϬƉƐŝ͘ x ŽŶĨŝƌŵĐĞŵĞŶƚĂƚƐƵƌĨĂĐĞŝŶ/͘ x ĞŵĞŶƚƉůƵŐŝŶƚŚĞ/ǁŝůůďĞĨƌŽŵdƵďŝŶŐWƵŶĐŚĞƐƚŽƐƵƌĨĂĐĞ͘ x ĞŵĞŶƚƉůƵŐŝŶƚŚĞƚƵďŝŶŐǁŝůůďĞĨƌŽŵdƵďŝŶŐWƵŶĐŚĞƐƚŽΕϭϬϬϬϬ ͛D͘ ϳ͘ &ƵůůďŽƌĞ Ă͘ tĂŝƚŽŶĐĞŵĞŶƚϯĚĂǇƐ͕D/dͲdƚŽϮϱϬϬƉƐŝ ʹ K'tŝƚŶĞƐƐĞĚ ϴ͘^ůŝĐŬůŝŶĞ Ă͘ ƌŝĨƚĂŶĚƚĂŐƚŽdKŝŶƐŝĚĞƚŚĞϰЪ͟ƚƵďŝŶŐ ʹ K'tŝƚŶĞƐƐĞĚ ϵ͘ ůŝŶĞ Ă͘ WĞƌĨŽƌĂƚĞϰЪ͟ƚƵďŝŶŐĂŶĚƚŚĞϳϱͬϴ͟ ĐĂƐŝŶŐĂƚΕϯϰϭϮ ʹ ϯϰϯϮ͛DƚŽĞƐƚĂďůŝƐŚĐŝƌĐƵůĂƚŝŽŶƉŽŝŶƚĂŶĚ ƌĞŵŽǀĞŚǇĚƌŽĐĂƌďŽŶƐĨƌŽŵƚŚĞϭϬв͟ǆϳϱͬϴ͟ĂŶŶƵůƵƐĂŶĚĐŝƌĐƵůĂƚĞŝŶĐĞŵĞŶƚƉůƵŐ͘ ϭϬ͘ &ƵůůďŽƌĞ Ă͘ ZŝŐƵƉƚŽĐŝƌĐƵůĂƚĞĚŽǁŶƚŚĞƚƵďŝŶŐĂŶĚƚĂŬĞƌĞƚƵƌŶƐĨƌŽŵƚŚĞϭϬͲϯͬϰ͟ǆϳͲϱͬϴ͟ĂŶŶƵůƵƐ;KͿ͘ ď͘ ŝƌĐƵůĂƚĞ ƚŚĞĨŽůůŽǁŝŶŐƚŽĐůĞĂŶŽƵƚŚǇĚƌŽĐĂƌďŽŶƐĨƌŽŵƚŚĞĂŶŶƵůƵƐ͘ ;ŶŽƌĐƚŝĐWĂĐŬƉƌĞƐĞŶƚͿ x ϱ ďďůƐDĞK, x ϮϱďďůƐŚŽƚĚŝĞƐĞů;ŵŝŶϭϮϬĚĞŐ&Ϳ x ϱϬďďůƐŽĨŚŽƚĨƌĞƐŚǁĂƚĞƌ;ΕϭϲϬĚĞŐ&ͿнƐƵƌĨĂĐƚĂŶƚ;ϮŐĂůͬŵŐĂů&ϭϬϯĂŶĚϮŐĂůͬŵŐĂůhKϲϳͿ x ϮϮϬ ďďůƐŽĨϵ͘ϴƉƉŐďƌŝŶĞ ;ϴϬͲϭϬϬĚĞŐ&Ϳ Đ͘ ŝƌĐƵůĂƚĞƚŚĞĨŽůůŽǁŝŶŐƚŽĐĞŵĞŶƚƉůƵŐƚŽĐĞŵĞŶƚƚŚĞϭϬͲϯͬϰ͟ǆϳͲϱͬϴ͟ĂŶŶƵůƵƐĂŶĚƚƵďŝŶŐƚŽ ƐƵƌĨĂĐĞ͘ x ϱ ďďůƐDĞK, x ϭϬďďůƐĨƌĞƐŚǁĂƚĞƌ x ϮϬϯ ďďůƐŽĨϭϱ͘ϴƉƉŐůĂƐƐ'ĐĞŵĞŶƚ ;ϭϱďďůƐĞǆĐĞƐƐͿ͘ x DĂǆƉƌĞƐƐƵƌĞϭϱϬϬƉƐŝ ϭϭ͘ , Ă͘ ƐƐŝƐƚ&ƵůůďŽƌĞǁŝƚŚĐĞŵĞŶƚũŽďĂŶĚƉƵŵƉEϮĂĐƌŽƐƐƚŚĞǁĞůůŚĞĂĚƚŽƌĞŵŽǀĞĞǆĐĞƐƐĐĞŵĞŶƚĨƌŽŵ ƚŚĞǀĂůǀĞƐ͘dŚŝƐǁŝůůĂůůŽǁǀĂůǀĞƐƚŽďĞŽƉĞŶĞĚƉƌŝŽƌƚŽƚŚĞǁĞůůŚĞĂĚƌĞŵŽǀĂůƚŽĐŚĞĐŬĨŽƌƉƌĞƐƐƵƌĞ͘ ď͘ ůĞĞĚĂůůǁĞůůŚĞĂĚƉƌĞƐƐƵƌĞƐƚŽϬƉƐŝ͘ Đ͘ DŽŶŝƚŽƌǁĞůůŚĞĂĚƉƌĞƐƐƵƌĞƐϮϰŚŽƵƌƐĂĨƚĞƌƉƌĞƐƐƵƌĞƐǁĞƌĞďůĞĚƚŽϬƉƐŝ͘ ^ƉĞĐŝĂůWƌŽũĞĐƚƐ WΘ ϭϯͲϯϲ Wd͗ϭϵϱͲϭϲϳ Ă͘ ǆĐĂǀĂƚĞĂŶĚƵƚŽĨĨĂůůĐĂƐŝŶŐƐĂŶĚǁĞůůŚĞĂĚϯ͛ďĞůŽǁŽƌŝŐŝŶ ĂůƚƵŶĚƌĂůĞǀĞů͘dŽƉũŽďƚŚĞĐŽŶĚƵĐƚŽƌ ǆϭϬϯͬϰ͟ĂŶŶƵůƵƐ͕ĂůůŽƚŚĞƌĂŶŶƵůŝĂŶĚƚƵďŝŶŐǁŝƚŚĐĞŵĞŶƚĂƐŶ ĞĞĚĞĚ͘WŚŽƚŽ ĚŽĐƵŵĞŶƚĐĞŵĞŶƚŝŶ ĂůůƚƵďŝŶŐĂŶĚĂůůĐĂƐŝŶŐƐƚƌŝŶŐƐ͘ ď͘K'ǁŝƚŶĞƐƐ ĐĞŵĞŶƚƚŽƉƐŝŶĂůůĂŶŶƵůŝĂŶĚŝŶƐƚĂůůĂƚŝŽŶŽĨŵĂƌŬĞƌĐĂƉŽŶŽƵƚ ĞƌŵŽƐƚĐĂƐŝŶŐƐƚƌŝŶŐ͘ WƌŽǀŝĚĞϮϰŚŽƵƌŶŽƚŝĐĞƚŽK'/ŶƐƉĞĐƚŽƌŽĨƚŚĞƚŝŵŝŶŐŽĨƚŚĞǁĞůĚŝŶŐŽĨƚŚĞŵĂƌŬĞƌƉůĂƚĞŽŶƚŽ ƚŚĞĐĂƐŝŶŐƐƚƌŝŶŐ͘WŚŽƚŽĚŽĐƵŵĞŶƚǁĞůĚĞĚŵĂƌŬĞƌƉůĂƚĞ͘ Đ͘ ĞĂĚǁĞůĚŵĂƌŬĞƌĐĂƉŽŶŽƵƚĞƌŵŽƐƚĐĂƐŝŶŐƐƚƌŝŶŐ;ŽŶĚƵĐƚŽƌWŝƉĞͿƚŽƌĞĂĚĂƐĨŽůůŽǁƐ͗ ,ŝůĐŽƌƉ EŽƌƚŚ^ůŽƉĞ>> ϭϯͲϯϲ Wdη ϭϵϱͲϭϲϳ W/η ϱϬͲϬϮϵͲϮϮϲϭϯͲϬϬ 3%8 $3, WΘ ϭϯͲϯϲ Wd͗ϭϵϱͲϭϲϳ ƵƌƌĞŶƚ ^ĐŚĞŵĂƚŝĐ WΘ ϭϯͲϯϲ Wd͗ϭϵϱͲϭϲϳ WƌŽƉŽƐĞĚ^ĐŚĞŵĂƚŝĐ WΘ ϭϯͲϯϲ Wd͗ϭϵϱͲϭϲϳ sŽůƵŵĞĂůĐƵůĂƚŝŽŶƐ ZĞƐĞƌǀŽŝƌĞŵĞŶƚWůƵŐ ŽƚƚŽŵ dŽƉ W&sŽůƵŵĞ ϱϭͬϮΗ>ŝŶĞƌ ϭϯϲϳϴ ϭϮϯϬϬ Ϭ͘ϬϮϯϮ ϯϮ͘Ϭ dƵďŝŶŐŝƐƉůĂĐĞŵĞŶƚ ϰϭͬϮΗdƵďŝŶŐ ϭϮϮϯϭ Ϭ Ϭ͘ϬϭϱϮ ϭϴϲ ϳϱͬϴ>ŝŶĞƌ ϭϮϮϰϭ ϭϮϮϯϭ Ϭ͘Ϭϰϱϵ Ϭ͘ϱ ϱϭͬϮΗ>ŝŶĞƌ ϭϮϯϬϬ ϭϮϮϰϭ Ϭ͘ϬϮϯϮ ϭ͘ϰ dŽƚĂů ϭϴϴ͘Ϭ /ŶƚĞƌŵĞĚŝĂƚĞĞŵĞŶƚWůƵŐ ϳϱͬϴΗǆϰϭͬϮΗ ϭϮϬϳϱ Ϭ Ϭ͘ϬϮϲϮ ϯϭϲ ϰϭͬϮΗƚƵďŝŶŐ ϭϮϬϳϱ ϭϬϬϬϬ Ϭ͘ϬϭϱϮ ϯϮ dƵďŝŶŐŝƐƉůĂĐĞŵĞŶƚ ϰϭͬϮΗdƵďŝŶŐ ϭϬϬϬϬ Ϭ Ϭ͘ϬϭϱϮ ϭϱϮ ^ƵƌĨĂĐĞĞŵĞŶƚWůƵŐ ϭϬϯͬϰΗǆϳϱͬϴΗ ϯϰϯϬ Ϭ Ϭ͘Ϭϯϵϳϱ ϭϯϲ ϰϭͬϮΗƚƵďŝŶŐ ϯϰϯϬ Ϭ Ϭ͘ϬϭϱϮ ϱϮ dŽƚĂů ϭϴϴ RECEIVED STATE OF ALASKA • AKA OIL AND GAS CONSERVATION COMMON JAN 3 1 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Abandon L] Repair Well V Plug Perforations (J Perforate L] Other U Patch 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 ❑ - 195 -167 -0 3. Address: P.O. Box 196612 Stratigraphic❑ Service IS 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 22613 -00 -00 7. Property Designation (Lease Number): 8. Well Name and Number: . ' ADL0028316 ` PBU 13 -36 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field /Pool(s): . To Be Submitted PRUDHOE BAY, PRUDHOE OIL 11. Present Well Condition Summary: Total Depth measured 13758 feet Plugs measured None feet true vertical 9087 feet Junk measured None feet Effective Depth measured 13678 feet Packer measured See Attachment feet true vertical 9079.7 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20" 91.5# H -40 30 - 110 30 - 110 1490 470 Surface 3403 10 -3/4" 45.5# NT80 29 - 3432 29 - 3223.69 5210 2480 Intermediate None None None None None None Production 12340 7 -5/8" 29.7# USS -95 28 - 12368 28 - 8956.36 8180 5120 Liner 1523 5 -1/2" 17# NT8OS 12235 - 13758 8888 - 9087 7740 6280 Perforation depth Measured depth See Attachment feet 12850 - 13025 feet 13035 - 13065 feet 13200 - 13230 feet 13250 - 13325 feet 13325 - 13350 feet 13350 - 13375 feet 13375 - 13420 feet 13480 - 13550 feet 13625 - 13675 feet True Vertical depth See Attachment feet 9049.85 - 9052.91 feet 9052.67 - 9051.98 feet 9051.12 - 9051.97 feet 9052.53 - 9054.96 feet 9054.96 - 9055.89 feet 9055.89 - 9056.85 feet 9056.85 - 9058.79 feet 9062.61 - 9068.11 feet 9074.72 - 9079.4 feet Tubing (size, grade, measured and true vertical depth) 4 -1/2" 12.6# L -80 27 - 12232 27 - 8887.46 Packers and SSSV (type, measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12. Stimulation or cement squeeze summary: Intervals treated (measured): SCANNED MAR 0 5 2013 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 241 -1348 465 1697 240 Subsequent to operation: 0 0 0 0 0 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development ❑ Service El Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil ❑ Gas u WDSPtI GSTOR ❑ WINJ ❑ WAG 0 GINJ ❑ SUSP ❑ SPLUC0 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: 312 -084 Contact Nita Summerhays Email Nita.Summerha s•ib•.com Printed Name Nita Summerh- s Title Petrotechnical Data Technictian 0-7/ FIN Signatu / /� ,,/' �� _ Phone 564 -4035 Date 1/31/2013 V L- r , ,(0 BDMS FEB 0 1 2013 iC"' / / 1 3 Form 10 -404 Revised 10/2012 Submit Original Only • • Daily Report of Well Operations ADL0028316 RAN 3.84 NO -GO CENT,SAT DOWN @ 2189 SLM.ALL CLEAR. RAN 3.84 NO -GO CENT,W/ 10' 1 1/4 PPRONG W/ FLAPPER CHECKER TO 2189 SLM, TRSV FUNCTIONING. RAN 20' 3.7 DUMMY WHIPSTOCK TO 8000' SLM, NO PROBLEMS ENCOUNTERED. RAN 3.7 IBP EQ SLEEVE W/ 2 1/2 JUC TO 12,396 SLM. LATCHED IBP , TOOL SHEARED. 7/20/2012 * * * ** LAY DOWN EQUIP. FOR THE NIGHT . * * * * * * * * * * * ** * ** CONT -ROM TICKET 7/20/12 * * ** PULLED 3 3/8 BAKER IBP @ 12,396 SLM, MISSING BOTH 6" ELEMENTS AND STIFFENING RING. MADE 2 RUNS W/ 4 1/2 BRUSH, 3.5 3 PRONG WIRE GRAB. RECOVERED BOTH ELEMENTS AND STIFFENING RING.RDMO. 7/21/2012 * * ** LEFT WELL SHUT IN,TURNED WELL OVER TO PAD OPER. * * * ** 8/18/2012 SV, WV, SSV = Closed. MV = Open. IA & OA = OTG. NOVP. 19:50 INITIAL T /I /O = 50/0/0 RIG UP AND MAKE UP TOOL. RIH WITH HEAD /ERS /BAKER IBP. CONTINUE TO RIH. 8/19/2012 ** *JOB CONTINUED ON 21 -AUG- 2012 * ** SET 3 -3/8" BAKER IBP @ 12149.35 MOD ELEMENT (TOP 01- PLUG = 12143'). OAL = 11.05' - MAX OD = 3.375" - 1.375" FN (Sealing Elements = 2 x 6" & 1" stiffener ring) PERFORM PASSING CMIT TxIATO 2500 PSI WAS GOOD BLED PRESSURE DOWN TO 500PSI FINAL T /I /O = 500/500/0 8/20/2012 ** *JOB COMPLETE. WELL LEFT SI UPON DEPARTURE * ** ** *WELL S/1 ON ARRIVAL * ** EQUALIZED 3 -3/8" BAKER IBP @ 12,100' SLM 8/22/2012 ** *CONT. ON 8/23/12 WSR * ** ** *CONT. FROM 8/22/12 WSR * ** PULLED 3 -3/8" BAKER IBP @ 12100' SLM (lost part of stiffner ring) RAN 3.50" 3 -PRONG WIRE GRAB TO 12200' SLM (did not recover stiffner ring) DRIFT W/3.70" x 30' PATCH TO 6,000' SLM 8/23/2012 ** *WELL S/I ON DEPARTURE * ** ***WELL SHUT IN ON ARRIVAL * * *(E -LINE BAKER PATCH) INITIAL T /I /O = 50/0/0 PSI SET 4 -1/2" x 30' BAKER PATCH ELEMENT TO ELEMENT @ 5455' - 54 (TOP @ 5453.5') (PATCH SPECS = 35.86' OAL, 3.70" MAX OD, 2.45" MIN ID) TIED INTO PDS LDL DATED 03- DEC -2011 LRS WILL RETURN AT LATER DATE FOR MIT -IA FINAL T /I /O = 50/0/0 PSI WELL LEFT SHUT IN - NOTIFIED PAD OP OF STATUS 8/27/2012 ** *JOB COMPLETE * ** ?/1/0= 1/48/4. MI1 -TA * *FAILED ** to 2536 psi. (Mitigate TxIA) Pumped 35 bbls neat methanol into IA to reach test pressure. LLR of .90 bpm @ 2487 psi with 5 bbls neat. Pad op notified of well status and tree valve positions as follows: 8/28/2012 SV,WV,SSV= closed. MV =open. IA and OA open to gauges. FWHP= 31/40/3 • S Packers and SSV's Attachment ADL0028316 SW Name Type MD TVD Depscription 13 -36 PACKER 12176 8784.53 4 -1/2" TIW HBBP -T Packer 13 -36 PACKER 12235 8813.87 5 -1/2" BAKER ZXP PACKER TREE= FMC NEW STANDARD . • V €J FEAD = CMV SA. NOTES: H2S READINGS AVERAGE 125 AC1l1ATOFt = . BAKER C 13-36 ppm W ON ML WELL REQUIRES A SSSV KB. HJ=V = 75' WHEN ON ML WELL ANGLE >70 °Q12447'*** aF !3_E/ = TFW PKR MAX PT = 2500 PSI *** KOP= 1915' Max Angle = 91° @ 13082' I fib' H4 - 1/2° I CP 1RSV SSSV NP, D = 3.813" I Datum MD = 1220T III Datum TVD = 8800' SS GAS LFT MANDRB_S 110 -3/4' CSG, 45.5#, NT-8 LFE D = 9.953' H 3432° ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3536 3301 42 t£5 MIX DMY BK-5 0 11/21/00 2 7542 5934 51 F6 MIX DMY BK-5 0 11/21/00 1, 1 1 Z 3 10261 7689 49 t£S MEC DMY BK -5 0 11/24/11 ` 4 11859 8697 58 FE'S MIX DMY BK -5 0 11/24/11 Minimum ID = 2A5" @ 5455' - 5485' �__ - ..,„-` -„-` \ 4-1/2" BKR PATCH 5454' - 5485' IH4 -1/2" BKR PATCH, D = 2.45' (08/27/12) I B xi 1 12176' I I7 -5/8 X 4 -1/2" TM! HBBP-T PKR I I I I 12209' 1-14 -1/2" I-ES XN NP, D = 3.725" I 1 4-1/2" TBG, 12.6#, L -80, .0152 bpf, D= 3.958" H 12231' I— / \ I 12231' H4 -1/2" W.H. G D = 3.958° I 12220' HELM TT LOGGED 10/08/96 I (TOP OF 5 LNR H 12241' I 12228' H7 -58• X 5-1/2" TE BACK I 12235' 7 -58" X 5-1/2' ZXP UR TOP PKR 12241' H7-5/8 X 5-1f2" HMG LNR HANGER I 17 -5/8 LW, 29.7#, S 95 BUTT, .0459 bpf, D = 6.875' H 12368' I PERFORATION SUMA kRY I RE= LOG: GR RESIST 12106 -12/95 ANGLE AT TOP PEiF: 85° ( 12815' I Noire: Refer b Production DB for historical pert data SOLE SFF NTB VAL Opn/Sgz DATE 3-3/8' 4 12815 -12840 0 04/13/00 I 3-3/8" 4 12850 -13025 0 12/26/95 3-3/8" 4 13035 -13065 0 04/13/00 I 3-3/8" 4 13200 -13230 0 04/12/00 3-3/8• 4 13250 - 13420 0 12/26/95 3-3/8' 4 13325 -13350 0 04/12/00 2-7/8' 4 13350 -13375 0 04/12/00 3-3/8' 4 13480 - 13550 0 12/26/95 2 -78' 4 13625 -13675 0 04/11/00 I PBTD H 13678' . 4 . 4 . 4 ' 4y4 ' 4 ' I 4 1 5-1/2" LNR 17#, NT 80S NSCC, .0232 bpi, D = 4.892" H 13768' .4.0.0.0 DATE REV BY COMABJTS DATE REV BY COMABJTS PR UDHOE BAY UNIT 12/24195 ORIGINAL COMPLETION 12/19/11 TTW PJC SET BP WELL: 13-36 04/27/02 APftlh PERF CDFi 11ONS 01/16/12 TMWJM) ADDED H2S SAFETY NOTE FEFIMT No: '1951670 10/26/03 ATD/TLP SAFETY NOTE 07/30/12 MSS/JM) PULL BP (07 /21/12) API No: 50 -029- 22613-00 11/15/10 PJC DRAWING/ GLV CORRECTION 08/29/12 JGM'JM) SET 4-1/2" BKR PATCH (08/27/12) SEC 13, T10N, R14E, 3112.99' Fa & 1135.22' FM_ 02/09/11 M3/JM) ADDED SSSV SAFETY NOTE 09/11/12 PJC PATCH CORRECTION 11/29111 RCT/JM) GLV CIO (11 /24/11) BP Fxptoratlon (Alaska) DATE: 5- Nov -12 Stephanie Pacillo TRANS#: 6192 Data Delivery Services Technician Makana K Bender Scblumberger Oilfield Services Natural Resources Technician II WIRELINE Alaska Oil & Gas Conservation Commission 2525 Gambell St, Ste. 400 33 E-<< .. ��a ..: �. _.;Ave. Suite 100 Anchor ace, A, 9950 Anchorage, AK 99503 SI: Office: (907) 273 -1770 .: WELL ' SERVICE OH RESERV CNL IVIECH LOG DESCRIPTION DATE B/W COLOR CD's' ; NAME : ORDER #,'. DIST , ... DIST D1ST _ DIST: . : '',,'- ;LOGGED , ;RRNTSS,; PRINTS . .. Z -34 BTJO -00034 X USIT MSIP 8- Sep -12 1 1 CD H -02B C4W7 -00035 X PPROF 24- Aug -12 1 1 CD lir -29B C1 UB -00030 X LEAK DETECTION LOG 13- Sep -12 1 1 CD D -27A C2JC -00056 X LDL W/ WATERFLOW 5- Sep -12 1 1 CD L -100 C3NA -00041 X SFRT CH FORMATION RESIST!) 15- Oct -12 1 1 CD 06 -03A C4W7 -00036 X CEMENT BOND LOG 15-Sep-12 1 1 CD MPL -08 C600 -00036 X MEMORY INJECTION PROFILE 10- Aug -12 1 1 CD 15 -04B C600 -00045 X MEMORY PPROF 7- Sep -12 1 1 CD F -06A C3NA -00038 X PPROF W DEFT & GHOST 16-Sep-12 1 1 CD C -20C BCRC -00212 X MEMORY PPROF 1- Oct -12 1 1 CD 14 -27 C3NA -00039 X LEAK DETECTION LOG 17- Sep -12 1 1 CD V -221 BBSK -00135 X IPROF W/ WFL 22- Aug -12 1 1 CD MPC-42 C600 -00057 X MEMORY IPROF 9- Oct -12 1 1 CD MPC -28A C600 -00056 X MEMORY IPROF 9- Oct -12 1 1 CD MPL -16A C5XI -00033 X MEMORY IPROF 13- Sep -12 1 1 CD C -18B C600 -00053 X MEMORY PPROF 3- Oct -12 1 1 CD NK -22A BYS4 -00052 X LEAK DETECTION LOG 4- Sep -12 1 1 CD MPG -01 C2JC -00054 X RST WATERFLOW LOG 31- Aug -12 1 1 CD 13-36 BYS4 -00053 X LEAK DETECTION LOG 12-Sep-12 1 1 CD X X )1/14t...- 6,0e.04— Please return a signed copy to: Please return a signed c y to: BP PDC LR2-1 DCS 2525 Gambell St, Suite 400 900 E Benson Blvd APR 0 2 2013 Anchorage AK 99508 SCAN NED Anchorage AK 99503 0 , t -J J • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 August 10, 2012 . 163 Mr. Jim Regg • Alaska Oil and Gas Conservation Commission �± 333 West 7 Avenue � Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB DS -13 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 13 were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659-5102. Sincerely, 7 ,2 � Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) DS -13 Date: 10131111 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal 13 -02B 1990110 50029203246000 Sealed conductor NA NA NA NA NA 13-03A 2090480 50029203250100 Sealed conductor NA NA NA NA NA 13 -04 _ 1780630 50029203260000 Sealed conductor NA NA - NA NA NA 13-05 1811030 50029206260000 Sealed conductor NA NA NA NA NA 13 -06A 1972180 50029206420100 Sealed conductor NA NA NA NA NA 13 -07 1811290 50029206500000 Sealed conductor NA NA NA NA NA 13 -08A 1982150 50029206670100 Sealed conductor NA NA NA NA NA 13 -09 1811580 50029206710000 Sealed conductor NA NA NA NA NA 13 -10 1811650 50029206780000 Sealed conductor NA NA NA NA NA 13-11 1810760 50029206040000 0.0 NA 0.0 NA 11.1 10/31/2011 13 -12 1801420 50029205380000 Sealed conductor NA NA NA NA NA 13 -13A 2030360 50029208520100 0.4 NA 0.4 NA 11.1 10/31/2011 13 -14 1821710 50029208450000 2.0 NA 2.0 NA 13.6 10/6/2009 13 -15 1821570 50029208310000 Sealed conductor NA NA NA NA NA 13 -16 1821480 50029208230000 0.4 NA 0.4 NA 13.6 10/31/2011 13 -17 1820260 50029207180000 Sealed conductor NA NA NA NA NA 13-18 1820350 50029207240000 Sealed conductor NA NA NA NA NA 13 -19 1811800 50029206900000 Sealed conductor NA NA NA NA NA 13-20 1820090 50029207050000 Sealed conductor NA NA NA NA NA 13 -21 1820530 50029207890000 Sealed conductor NA - NA NA NA NA 13 -22 1820770 50029207490000 Sealed conductor NA NA NA NA NA _ 13 -23A 1820230 50029207150000 Sealed conductor NA NA NA NA NA 13 -24A 2042430 50029207390100 Sealed conductor NA NA NA NA NA 13-25 1820910 50029207610000 Sealed conductor NA NA NA NA NA 13-26 1820740 50029207460000 Sealed conductor NA NA NA NA NA + 13 -27 1961210 50029209490200 17.0 NA 17.0 NA 130.9 11/22/2009 13-28 1830600 50029209420000 5.0 NA 5.0 NA 144.5 11/19/2009 13 -29L1 2020690 50029209286000 Dust Cover NA NA - NA NA NA 13-30C 2080870 _ 50029207680300 Sealed conductor NA NA NA NA NA 13-31A 2051600 50029224590100 0.5 NA 0.5 NA 3.4 10/6/2009 13-32A 2012350 50029207980100 0.0 NA 0.0 NA 10.2 10/31/2011 13 -33 1821060 50029207730000 5.2 NA 5.2 NA 27.2 11/17/2009 13-34 1821360 50029208110000 0.3 NA 0.3 NA 11.1 10/31/2011 13 -35 1940410 50029224600000 0.9 NA 0.9 NA 5.1 11/17/2009 ,--or 13-36 1951670 _ 50029226130000 0.0 NA 0.0 NA 4.3 10/31/2011 13-37 2100820 50029234280000 3.8 NA 3.8 NA 33.2 10/31/2011 13 -98 1822070 _50029208780000 1.0 NA 1.0 NA 5.1 10/6/2009 • '' • SEAN PARNELL, GOVERNOR ' i i ALASKA. OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Garry Catron Petroleum Engineer BP Exploration (Alaska), Inc. 11 r� " 1 7 P.O. Box 196612 - Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 13 -36 Sundry Number: 312 -084 Dear Mr. Catron: St A NEF MAF 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, fri .0 /f — Cathy/P. Foerster // Chair d DATED this t� ay of March, 2012. Encl. P✓S' 3 /‘ It L 1 STATE OF ALASKA 1 I E E I E 9/ . ti A OIL AND GAS CONSERVATION COMMI ON s —.4W • APPLICATION FOR SUNDRY APPROVALS FFB 9 �6 2r42 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool❑ Repair Well 0' C)mange Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate❑ Pull Tubing '''L''"' - "•' `, Gast Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate❑ Alter Casing ❑ , Other: PATCH_ __ 0 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 195 -1670 ' 3. Address: P.O. Box 196612 Stratigraphic ❑ Service 0, 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 22613 -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: Spacing Exception Required? Yes ❑ No ❑ PBU 13 -36 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028316 PRUDHOE BAY Field / PRUDHOE BAY 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): 13758 , 9088. 13678 9080 12430 NONE Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 30 110 30 110 Surface 3403' 10 -3/4" 45.5# NT -80 29 3432 29 3224 5210 2480 Production 12340' 7 -5/8" 29.7# S 95 28 12368 28 8956 8180 5120 Liner 1517' 5 -1/2" 17# NT80S 12241 13758 8892 9088 7740 6280 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): SEE ATTACHED - - 4 -1/2" 12.6# L -80 29 12231 Packers and SSSV Type: 4 -1/2" HES CP -2 TRSV SSSV Packers and SSSV MD and TVD (ft): 2226 2207 4 -1/2" TIW HBBP -T PKR 12176 8860 5 -1/2" ZXP LNR TOP PKR 12235 8889 12. Attachments: Description Summary of Proposal ISI 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Development ❑ Service 0 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 7/1/2012 Oil ❑ Gas ❑ WDSPL p Suspended ❑ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG IS Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Garry Catron Printed Name Garry Catron Title PE ii1 Ci Signature � Phone Date ' L w 564- 4424 2/29/2012 Prepared by Nita Summerhays 564 -4035 COMMISSION USE ONLY //��Q�,� Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Z 1 Z Ogg Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test [ Location Clearance ❑ Other: Subsequent Form Required: /0-10 1 APPROVED BY Approved by: gy `� COMMISSIONER THE COMMISSION Date:3 — h, ) S MAR 0 7 201 - R 1 1 61 n A L Form 10-403 Revised 1/2010 / 7' Submit in Duplicate 13 -36 195 -167 PERF ATTACHMENT S3 N Name Operation a 5 PER Operation Code Meas Depth Top I Meas Depth Base ' Tvd Depth Top Tvd Depth Base � p p - - 13,025. 9,049.85 9,052.91 13 -36 1 12/26/95 PER 13,250. 13,420. 9,052.53 9,058.79 13-36 12/26/95 PER 13,480. 13,550. 9,062.61 9,068.11 13-36 4/11 /001 PER 13,625. 13,675. 9,074.72 9,079.4 13 -36 4/12/00 PER 13,350. 13,375. 9,055.89 I 9,056.85 13 -36 i 4/12/00 PER 13,325. 13,350. 9,054.96 9,055.89 13-36 4/12/00 PER 1 13,200. 13,230.; 9,051.12 9,051.97 13 -36 4/13/00 PER 12,815. 12,840. 9,047.631 9,049.37 13-36 4/13/00; PER 13,035. 13,065. 9,052.67 9,051.98 13-36 10/29/10 BPS 12,194. 13,675. 8,868.54 9,079.4 • 13-36 12/6/11 BPP 12,194. 13,675.1 8,868.54 13 -36 12/18/11 BPS 12,430., 13,675. 8,983.56 9,079.4 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS I BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN O UT SPS ISAND PLUG SET FIL FILL SQF SQUEEZE FAILED r- I MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS 1 MECHANICAL ISOLATED STC STRADDLE PACK, C LOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • TREE = WELLHEAD = FMC NEW STANDARD • --- APNOTES: H2S READINGS AVERAGE 125 ._ Abi ;— - E3F■kEJR — c 1 3-36 ppm WHEN ON MI. WELL REQUIRES A SSSV . . KB. ELEV = - 75' WHEN ON MI. WELL ANGLE > 70° @ 12447' ................ . BF. ELEV = , TM/ PKR MAX PT = 2500 PSI' KOP = 1915' Mex Angie = 91°@ 13082' I 2226' 1-14-1/2" HES CP-2 TRSV SSSV NIP, ID = 3.813" I Datum MD = — 1 Zzoi. IO Datum TVD = 8800' SS M 110-3/4 CSG, 45.5#, NIT-8 LHE, ID = 9.953" I-1 3432' 1 - 41 GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE . „ - Minimum ID = 3.725" @ 12209' Li 1 3536 3301 42 HES Ma DMY BK-5 0 11/21/00 2 7542 5934 51 HES MEX DMY BK-5 0 11/21/00 4-1/2" HES XN NIPPLE 3 10261 7689 49 HES EX DM' BK-5 0 11/24/11 4 11859 8697 58 HES MEX MTV BK-5 0 11/24/11 CE : sj I 12176' I X 4-1/2" TM/ HBBP-T PKR I _ 111 • [-- i n11§ HES XN NIP, ID = 3.725" I I 4-1/2' TBG, 12.6#, L-80, 0152 bpf, ID= 3.958" I 12231' I / \ I 12231' H4-1/2" TUBING TAR_ I 12220' ELMD TT LOGGED 10/08/96 I 12228 1H -'" X 5-1/2" TIE BACK 'TOP OF 5-1/2" LNR I 12241' I 12236' F-17_5/8" X 5 ZXP LNR TOP PKR I . 12241' 1 X 5-1/2" HMC LNR HANGER I I 7-5/8" LNR, 29.7#, S 95 BUTT, .0459 bpf, ID = 8.875" H 12368' -- -___—_-z. 12430' I BAKER IBP (12/19/11) I PERFORATION SUMMARY I REF LOG: GR RESIST 12/06-12/95 ANGLE AT TOP PERF: 85* @ 12815' I Note: Refer to R DB for historical perf data SIZE SA INTERVAL Opn/Sqz DATE ., 3-3/8" 4 12815 - 12840 C 04/13/00 3-3/8" 4 12850- 13025 C 12/26/95 1 1 3-3/8" 4 13035 - 13065 C 04/13/00 3-3/8" 4 13200 - 13230 C 04/12/00 I 3-3/8" 4 13250 - 13420 C 12/26/95 3-3/8" 4 13325 - 13350 C 04/12/00 2-7/8" 4 13350 - 13375 C 04/12/00 I 3-3/8" 4 13480 - 13550 C 12/26/95 2-7/8" 4 13625 - 13675 C 04/11/00 I PBTD I 13678' ................ ■ MA......0.0. 5-1/2" LNR, 17#, NT 80S NSCC, .0232 bpf, ID = 4.892" I—I 13768' . . DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 12/24195 ORIGINAL COMPLETION 11/29/11 RCT/JMD GLV C/O (11/24/11) WELL: 13-36 04127/02 APItlh PERF CORRECTIONS 12/16/11 LEC/ PJC PULL VVRP (12/06/11) PERMIT No: '1951670 10/26/03 ATLYTLP SAFETY NOTE 12/19/11 TTR/ PJC SET IBP AF1No: 50-029-22613-00 11/15/10 JCMPJC SET VVRP (1029/10) 01/16/12 TIVN/JMD ADDED1-25 SAFETY NOTE SEC 13, T1ON, R14E, 3112.99' FEL & 1135.22' FNL 11/15/10 PJC DRAWNG/ GLV CORRECTIONS 02/09/11 ' MB/J.() ADOED SSSV SAFETY NOTE II BP Exploration (Alaska) • • by 0 To: C. Olsen /J. Bixby Date: February 8, 2012 GPB Well WL Ops Team Leaders From: Garry Catron AFE: APBNRWOS DS13 Production Engineer Est. Cost: Subject 13 -36 Verify Tubing Secure and Patch IOR: 250 Step Desc Comment 1 S Drift w/ 30' 4 -1/2" Dummy Patch. Pull IBP. Set IBP (above pkr). CMIT -TxIA to 2500 psi; LLR if fails. 2 EP Run 30' Baker 4 -1/2" KB Patch (pending passing CMIT - TxIA). 3 FP MIT -IA to 2500 psi; LLR if fails (pending passing CMIT - TxIA). 4 SP Pull IBP (pending passing MIT -IA and 13 -15A Drill -by timing). i Current Status Injector — Shut -In for TxIA Max Deviation 91 Deg @ 13082' Min ID 3.725" @12,209' 4 -1/2" HES XN Nipple Last Tag 12/7/11 Drift w/12' of 3 -3/8" Dummy Perf Gun to deviation @ 12555' SLM Last Downhole Op 12/18/11: Set IBP @ 12421' ELM. Latest H2S value 140 ppm, nearby well 13 -08A, 2/28/11. WBS Safety Note: 125 ppm when on MI. Reference Log: PDS LDL, 12/3/11 Objective The objective of this program is to verify tubing secure for upcoming 13 -15A Drill -by, patch the tubing leak at 5463' MD and to bring the well back on Injection. Well History Well 13 -36 was originally drilled and completed as a horizontal Z4 pre - produced injector in 12/95. The well was initially put in production and 200' of perforations were shot in 4/00. In 11/00 the well was converted into an injector. Since conversion to injection, 13 -36 has received 14.4 BCF of MI in four slugs. The well was on PW injection when an IA pressure rise was noted on 9/15/10 and then an MIT- IA failed on 9/22/10 with a liquid leak rate of 8.1 gpm at 2500 psi. ALIT -TxIA to 2500 psi also failed on 11/6/11. Leak Detection Log's (LDL's) ran in October 2010 suggest that there are leaks at 5463' MD and 5483' MD, along with possible leaks at GLM's # 3 & # 4 and a temperature anomaly at 4508' MD without an acoustic signature. We dummied off the GLV's and ran another TecWell LDL in December 2011 which shows the GLV's are no longer leaking, no temperature anomaly at 4508' MD, and suggested that the WRP was leaking. Page 1 of 7 The leaking WRP was pulled iecember 2011. An IBP was set abovee perforations and a new CMIT-TxIA to 2500 psi passed after being monitored for 2 hours, giving confidence that there is integrity of the production casing. The 7- 5/8 "x4 -1/2" TIW HBBP -T Packer (Figure 1) has a port below the sealing element. It is suspected that this port is_ leaking_causin_gthe response_on_the and the failing CMIT- TxIA's with a tubing tail plug in the hole. The attached 3 -D view (Figure 3) from 2010 Caliper of leaking section shows pipe to be in good shape for setting of the patch. New sidetrack well 13 -27B is a horizontal producer that lies between injectors 13 -35 and 13 -36 that has fallen from - 4000 bopd initial rates in late September 2011 to - 600 bopd in January 2012. It is in need of pressure support from this injector. This program is designed to set a patch over the tubing leak at 5463' MD and potential leak at 5483' MD, and then test the integrity of the Inner Annulus to 2500 psi. cc: Well File For questions, comments, or concerns please call Garry Catron @ 564 -4424 (work) or 907 - 227 -7349 (cell). 13 -36 Patch Procedure Reference Log: PDS LDL, 12/3/11 Patch Specifications • 4-1/2" Single Set Baker KB, 30' Length • Alt components to be L -80 carbon steel • 2.37" minimum ID Depth Information • Setting depth: 5455' — 5485' MD • Patch Length: 30' element to element • Leak Location: TecWell identified a leak at 5463' MD and a potential leak at 5483' MD, referenced to WBS Revision Date 26- Oct -2003 • Tie -In log: PDS LDL, 20- Oct -2010 Jewelry Tubing 12/03/10 LDL Talley SSSV Nipple 2226 2215 GLM # 1 3536 3526 Top Packer 5455 Tubing Leak 5463 Potential Tubing Leak 5483 Bottom Packer 5485 GLM # 2 7542 7536 4 -1/2" XN Nipple 12209 / Patch (MD) 5455 -5485 Pre -job Notes: Page 2 of 7 • • , Ensure that patch•semblies are capable of running 2 -1/8" OD deflated IBP through them prior to running them in hole. 1. Slickline and Fullbore: a. MIRU SL. b. Drift w/ 30' Dummy Patch to 8000' SLM. c. Pull 3 -3/8" IBP @ 12421' ELM. d. Set 2- 1/8 "x4 -1/2" IBP in tubing above packer @ - 12158' ELM. Note: Please place IBP in first full joint above Tubing Collar @ 12166' ELM on Tie -In Log PDS LDL, 12/3/11. e. Run CMIT -TxIA to 2500 psi. • If fails, LLR and all units RDMO. • If passes, de- pressurize and SL RDMO. Proceed with Step 2. 2. E -line (Pending Passing CMIT -TxIA) a. RU EL. RIH w/ 30' Baker 4 -1/2" KB Patch. Set @ 5455' - 5485' MD. b. RDMO. 3. Fullbore (Pending Passing CMIT -TxIA) a. Run MIT -IA to 2500 psi. i. If passes, proceed to step 4. ii. If fails, LLR. Leave IBP in hole. RDMO. 4. Slickline (Pending Passing MIT -IA and 13 -15A Drill -by) Note: Passing MIT -IA to 2500 psi and 13 -15A Drill -by timing. Please call APE for go ahead. a. Pull IBP @ 12166' ELM. b. RDMO. Have DSO bring well on Injection. Page 3 of 7 i o — 8 8 8 __- __ 440 00 WE/ s ke, LEAK DETECTION - WLD 7 7 Of cv CV 03 4 XTU - HTU- CCL - TEMP - WLD . Pea4crivF DiaciNosrrc Swim, b , 03 - Dec - 2011 - co Company BP EXPLORATION (ALASKA ) , INC j t�,. __m r CL CU I -° ! V CU Wel 13 -36 t °'i2' co Q ca Field PRUDHOE BAY r R ; �° �.... c c a t or `m Q CD � U U County NORTH SLOPE State ALASKA _ _ _ _ _ # Sur face Location ® 1 ° r E i o o U ©that Services D. J J f coi : Q.5 J , € j 1 FSL & 92.74' FWL None ( F i -� d th 2 O s ua t , ► �' ' Q I ,, SEC: 13 TWP: 10N RGE: 14E Elevation U c z. Permanent Datum MJMSL Elevation 0,0 K .8.75.0 co -t, m a ° Lo Measured Fro RKB 75.0 FT, Above Perm. Datum D.F /A US....., ii ow API Sena! Number 50 -029- 22613 -00 I G.L N/A c s i f > D ate 1 03-Dec t : } .1 Run Number I One co P B T a Driller 13,878' WRP 12. ? lo Cl_ 0 P B T D Logger _ Not Tagged j _CO Bottom Logged Interval 12190' •T"' r. o o o iat Top Log Interval cn I co Open Hole Size NA O Type Fluid 60140 Meth -Water -6 N CV Max {dew Recorded Temp. F) 201 CL t lime Well Ready 2130 FINAL PRINT u, o t o . Time Logger on Bottom 1:50 ccoo o o j cv O Equipment Number SLB EL #2266 Location North Slope i i 0 C Service Invoice No _ �_ Recorded By D. Gain ^_ ^ 1 0 - Z • Witnessed By T. Wellman — —_. __ E A 1 v v Borehole Record Tubing Record —' O • i 0 \ — - Run Number i Bil I Fro m c To Size LB / Ft From To { V 0 (0 I a 0) N 4112" 12.60 Surface 12,231 -- _ - -- — j U a z Casing Record Size LB / Ft Top Bottom ;,:5 z 1 Surface String 10 314" 45.50 Surface 3,432' i l Prot String 7 5/8" 29 70 Surface 12 368 - Uner 5112" 17 00 12,241 _ 13.7 ♦_ - `-• , o t j 0 Liner LL O • co c a) 0 a - o , CO 1 . r "---- 4 ; v w — A WEU .$1ts LEAK DETECTION - WLD 8 , VI 1.0 1 I N C \ I N 1 , 1 1 i LL.I 4 i 4111C1i3NS*1 XTU - HTU - CCL - TEMP - VVLD M Cl.) 1 1 1 . .....,...., ( I ) , • 1 Paaktive MVOS* Semites, 1st, 03 - Dec - 2011 , E ,,. _ , .. 8 to ..,_,; , u I 1 ! CO . a Company BP EXPLORATION (ALASKA) INC. ■ u_ oa CA ! , , 0 1 —\Z .- C . 1 , 1 „,t'' . CO ' C _. _,-, ! c (I) III (71 .se In Well 13 - 36 x .. < , a.- CO L 0 n Field PRUDHOE BAY , ,- a (/) .st a c 0 ....... o >, County NORTH SLOPE State ALASKA . .s 1 i Surface Location Other Services 0 t .. 1 -.3 ■ 0 None M c\J 6 . e i 4--, i IL C ,, ,-C 1,584.96' FSL & 92.74' FWL N 1 — 1 , -.—t 0 CL 0 i a c0 o ; i i Lo 0 - Z < SEC: 13 11AR: 10N RGE 14E C Elevation . 3 1 Permanent Datum MSL Elevation 0 K8, g 75,0, 0 2. x i ,." , , - , s_ I E T 1 2 i Log Measured From RKB 75.0 FT Above Perm. Datum 0 F N/A 1 C _ t 8 3 i f: 8 0 I API Serial Number 50 GL N/A (ii cNi o V) t • 1 1 CO 1 1 Date : 03-Dec-2011 ' i ( it CA ' , , ' CO . - ---1. . Run Nu mber One 0 fa .7 CV , P B T D Driller 13 678 ' VVRP @12,194' - - t..— 1,... ru . > , T (..) 1 4 I P61 T 0 Logger ' Not Tagged o o c . ) . . 1 < --C- w" o o - ......A.A.4,4 ' ' ' --- (..'"..) ,,.. „ .,-.. . , +......-- . ...,--.1-- - I '''........ Bottom Logged Interval 12190' , - 1 Top Log Interval 20 Open Hole Size NA CB A CD 13 ;'' ' -I . 0 CD CU et CD Lii ko tk, 0 Type Fluid 60140 Meth-Water i a. c.'..` ,.. 4- 3, 40 (/) _ J 40 TIM Max Recorded Temp (deg 1 ) 201 - l a., 0 0 0 O Well Ready 2l30 -- FINAL _ _ ._ PRINT 7 ;: 8 2 1 2 1 8 8 a . IIIIIIIIIIIIIIIIIINIIIIIIII_ . 4-- c u , Tone Longer on Bottom __ ottom 1 50 SLB EL 62266 d at 0 c F". flit t'. ON • 0 o Equipment Number — I -1—.. _ s-. , , a Location Not, Slope 4 t1 0) ___ 1 — 1 o 3 ( ,,t ! r. I , z CD C . Service invoice No 632g - —.I .; — - bi o_ — • k(.. I e [Recorded By 0 Cain i -- .0 E -";:: 0 ' ,; 0 „ _ ___ ...I Witnessed B y , T. Wellman _ I i gi . g ! s a 1 2 Borehole Record Tubing Record , TO 1: ' E — - o 1 1 2 .) 0 111 C , CD (1) • Run Number it 1 Prom - I To Size ' La /Ft From ', r-, 0 so ct n -- (1 ,, p I,- 5 LLJ 4 1C' 12.60 Surface_ 12.231' t -it m a 1 1 3 I S f w c ro u) if Li.. ii ,i i s , 2 ,, (f), 3 e a 1 ___...____ ... ..... ________ ....._ f- _ , u co ) , --- --- . 1 3 L Size 7 LB/Ft po — I :ott I- o — m .. I NI 1 i 11 4--; Surface String 10 3/4'' 45 50 J432' I _ a iti a et. 0 - a 0 .2 § .....,t Prot Svalg 7 518" 29 70 ruria 12,368' i i_ liner ' 5 1/2" 17 a° 12,241' --- 13 . 75 Fr _ _ 1 e... 0 0 N CD) CO _ Liner -- — , I iii 0 1! j _1_71'1 1 LE . , -- - ---- -- ---- - — Depth: 5454.99 to 5489.98 Display Mode: Finger 1 Up Length: 34.99 Deviation:: 46 • Rotation: 98 Avg. Diameter: 3.96 Min. Diameter: 3.93 Max Pen.: 4% 54911 5481.2 5472., r% 2% 8% o% o% o% 4% 6!, Figure 3. 2010 Caliper showing integrity for section of tubing for tubing patch set from 5455' to 5485' on PDS LDL, 12/3/11. Page 6 of 7 , . 1---- TREE FMC NEW 5 111) WELLHEAD = CV/ SAFETY NO TES: H2S READINGS AVERAGE 125 ACTUATOR = BAKR C 1 3 -3 6 ppm WHEN ON MI, WELL REQUIRES A SSSV KB a. EV = 75' WHEN ON MI. WELL ANGLE > 70° @ 12447' rffiF LEV --. 11W PKR MAX PT = 2500 PSI*** KOP = 1915' Max Angle = 91"@ 13062' i Datum m MD = 12207' Datum TVD = 8800' SS 10-3/4" CSG. 45 5#. NT-8 LHE ID = 9 953" - 3432 J -441 GA S LIFT MANDRELS _ ST MD TV D DEV I TY 1 VV LATCH POP" DATE ] i Minimum ID = 3.725" @ 12209' lir ' 3535 3301 42 il iES ME< ' OW 13K-5 0 11/21 2 7542 5934 51 i HES VEX 1OW BK-5 0 "1 01/001 1 HES XN NIPPLE . I 3 10281 /569 49 1 HES ?VEX I LA BK-5 0 '1/24 4 11859 8697 58 1 HES MD( I OW BK 0 1 104 1 11 . ] 121764 — 7-518 X 4-1/2' TfVV HBE3P-T PKR I 11 12209' J-1_4 HES XN NIP, ID = 3,725 j 1 12 60. L-80, C152 OW, ID = 3 355" -311 \ 12231' 1---14-112" TUBNG TA L I p 12220' j-F_M 17 LOGGED7:95 L 12228' 1-1_7-5/8' x 5-1/2" TIE BACK I [TOP Or E,T1i7' 1 NR 1H 12241' t.'. .i:4, 12235' H r X 5-1/2" ZXP LNR TO? PKR 12241j X 5 FIN4C LNR HANGERJ 7 ..NR, 29 7# S 95 BUT 0459 bpi ID = 6 875" H 12368' 1 - 4 12430' 1-i BAKERSP (12/ PERFORATION SUMMARY REF LOG GR RES S T ' 2/06 -12/95 ! A fs.GLE AT TOP PERE 85' @ 12915 Note Re`er to Produc007 DB for histcrIcal pal data SIZE SF. INTERVAL Opn/Sqz DATE 3-3/8" 4 '2815 - 12840 0 04r 3/00 3-318" 4 '2850 - 13025 C 12/26/95 3-318 ' 4 . 3035 - 13065 C 04/13/30 3-318" 4 13200 - 13230 C 04/ 3-3/8" 4 I '3250 - 13420 C 12/26/95 3-3/8" 4 ' 3325 - 13350 C 04/12/00 2-778" 4 . "3350 - 13375 C 04/' 2/00 3-3/6" 4 . 1 3480 - 13550 - 12/26/95 2g/8" 4 '3625 - 13675 C oar 1/00 . . 1 . L PBTD - E" -- 4673 . • • • • • • • • - - " - - — - NYASY •••••••41 5-1 ," LNR 17% Nr 839 NSCC 0232 bp f IC --,- 4 892" H 13758 . A.9.4.4.4.9.0. [AT RR,' RY NTS RAT RFV 3', PRUDHOE BAY LNO I 12124195 ORIGINAL COMPLETION 11/29/11 R0 GLV C/0 (11/2411 ' ) WEL„ 13-36 04/27/02 AFYth PERF CORRECTIO Ns 12/16/11 LEG/ PjC PULL WRP(12J06/1 PFARMIT No "1951673 , ! 1 or2f-Ai AllY FLPSAEETY NO FE 1019/11 1T R/ RIG SET IBP AP No 5C-029-22613-00 . 11/15/10 JCMIRIC SFT WRP (1009/18) 01/16/12 TIAN/JMD AMFD I--(7S SAFETY NOT SFC13 T1ON R14=, 3112 9.c.' F.71. & 1135 27 FNI ' 11/15/10 PJC DRAW1N3/ GLV CORRECTOS [ 02109/11 MB/JMD ADDED SSSV SAFETY NOTE T BP Exploration (Alaska) Page 7 of 7 • • WELL LO( r I �71 TRANSMITTAL j ja PRoAcA Di A Nosric SERVicES INC. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE: Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following: BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka — LR2 -1 900 Benson Blvd.�� Anchorage, Alaska 99508 NOV 2 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 cl -aArd 3 1) Leak Detection - STP 29 -0ct -10 13 -06 BL / EDE 50 -029- 22613 -00 2) :. IJ , Signed: Date Print Name: PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD Su1TE C, ANCHORAGE AK 99518 PHONE: (907)245 - 8951 FAx: (907)245 - 88952 E-MAIL: pdsanchorageAmemor loaxom W EasrrE : , APff r.memorVloe.com C: \Documents and Settings \Diane Williams \Desktop \Transmit- BP.docx WELL LOG PROAciriw DAAGNOSTIC SERVICES, INC_ To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793 -1225 RE: Cased Hole /Open Hole /Mechanical Logs and/or Tubing Inspection(Caliper / MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2 -1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907) 245 -8952 1) Leak Detection - WLD 20 -0ct -10 13-36 BL / EDE 50 -029- 22613 -00 Signed: Date . Print Name: 1 " PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245 -8951 FAx: (907)24548952 E-MAIL: odsanchorage0t) 7 emorVIog.com WEBSITE : www.memorylo€I.com CADocuments and Settmp0me Williazns \Desktop \Ti- dmntit_BP.docx OPERABLE: 13-36 (PTD #19670) Passed UIC Compliance MITIA • Page 1 of 2 Regg, James B (DOA) From: NSU, ADW Well Integrity Engineer [NSUADWWeIIlntegrityEngineer@BP.com] Sent: Wednesday, July 30, 2008 9:12 PM ~ ~~ To: GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GC1/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr; Regg, James B (DOA); Maunder, Thomas E (DOA); Fleckenstein, Robert J (DOA); DOA AOGCC Prudhoe Bay Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer Subject: OPERABLE: 13-36 (PTD #1951670) Passed UIC Compliance MITIA Attachments: MIT PBU 13-36 07-27-08.x1s ~~~~ Hi all, Well 13-36 (PTD #1951670) passed a UIC compliance MITIA on 07/27/08. The MIT test form is included for reference. The well has been reclassified as Operable now that it is in compliance with testing requirements. «MIT PBU 13-36 07-27-08.x1s» Thank you, Anna ~Du6e, ~? E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 `'~~`~~~~' At ~ .~ ~~tC~9 From: NSU, ADW Well Integrity Engineer Sent: Thursday, July 24, 2008 5:43 PM To: GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GCl/3/FS3); NSU, ADW Well Operations Supervisor; Rossberg, R Steven; Engel, Harry R; GPB, Wells Opt Eng; GPB, EOC Specialists; GPB, Optimization Engr; 'Regg, James B (DOA)'; 'Maunder, Thomas E (DOA)' Cc: Roschinger, Torin T.; NSU, ADW Well Integrity Engineer; Bommarito, Olivia 0 Subject: UNDER EVALUATION: 13-36 (PTD #1951670) to place on injection to obtain UIC MITIA Hi all, Well 13-36 (PTD #1951670) was classified as Not Operable due to not having a UIC regulatory compliance MITIA in the last four years. The last AOGCC MITIA passed on 7/16/04. A MITIA was not conducted due to the well being shut-in for the FS3 facility shut-down. The well has now been reclassified as Under Evaluation so that the well may be placed on injection and an AOGCC witnessed MITIA may be obtained. An AOGCC witnessed MITIA is scheduled for July 27, 2008. The plan forward for the well is as follows: 1. Fullbore: AOGCC witnessed MITIA to 4000 psi while on water injection for UIC Regulatory Compliance. A TIO plot and wellbore schematic have been included for reference. Please call with any questions. Thank you, 4/16/2009 OPERABLE: 13-36 (PTD #1970) Passed UIC Compliance MITIA ~ Page 2 of 2 Anna ~Du6e, ~'. E. Well Integrity Coordinator GPB Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 From: NSU, ADW Well Integrity Engineer Sent: Friday, July 11, 2008 5:54 PM To: GPB, FS3 DS Ops Lead; GPB, FS3 OTL; GPB, Area Mgr Central (GCl/3/FS3) Cc: Townsend, S. Eliot; NSU, ADW Well Integrity Engineer; NSU, ADW Well Operations Supervisor Subject: NOT OPERABLE: 13-36 (PTD #1951670) Due for AOGCC MITIA compliance All, Well 13-36 (PTD #1951670) is due to its AOGCC MITIA for regulatory compliance. Given the facility shut-down, we are unable to complete this test by the due date. Therefore the well is being reclassified as Not Operable. We'll proceed with setting a TTP and conducting the test. After that we'll reclassify the well as Operable for regular injection. Please let me know if you have any questions. Thank you, Anna From: Townsend, S. Eliot Sent: Friday, July 11, 2008 1:46 PM To: NSU, ADW Well Integrity Engineer Subject: 13-36 Anna, Well 13-36 is a WAG injector currently classified as Operable. The well is due for its 4 year compliance test on 07/16/08. Due to the flow station 3 shut down, the well cannot receive water so that it can be properly pressure tested to 4000 psi while online. A plan has been submitted to the WBL to load the well, set a plug, and then perform an AOGCC MITIA to 4000 psi holding 1500 psi on the TBG. Per our converstion earlier today, the AOGCC has agreed to allow this test to satisfy the 4 year regulatory compliance test requirement. Until this work can be completed, the WI Status of this well should be changed to Not Operable to prevent out of compliance injection. Thanks, S. Eliot Townsend alt. Torin Roschinger GPB Wells Group Well Integrity Engineer (907) 659-5525 4/16/2009 ~ ~7 O ~~ L Q O ~ ~ ~ F- 'r O O O O .~ 0 o, T ,., G w 0 r ~"~ G O u~ G r- G oa I° ~~ N C6 G CO O k r CV CD G G G ti7 CCU G ~~ G h-- G SD O ro G m LCi O OLD G k N l!? G O7 G h- r Li 7 G G O T 1, G .~ ~ ~ I~~1 M _. ~. -.~ I- ~ 4. G _~ ~n G "-~ li 7 O G O i~D~ G °o o ° o ~ M Cpl r • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; tom.maunder@alaska.gov;bob.fleckenstein@alaska.gov;doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: FIELD /UNIT /PAD: DATE: OPERATOR REP: AOGCC REP: BP Exploration (Alaska), Inc. Prudhoe Bay / PBU / DS 13 07/27/08 Anna Dube Lou Grimaldi Packer Depth Pretest Initial 15 Min. 30 Min. Well 13-36 .Type Inj. W TVD 8,860' Tubing 575 575 575 575 Interval 4 P.T.D. 1951670 Type test P Test psi 2215 Casing 120 4,000 3,980 3,980 ~ P/F P Notes: 4-year UIC Compliance MITIA OA 30 220 220 220 Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPEINJ Codes D =Drilling Waste G=Gas I =Industrial Wastewater N =Not Injecting W =Water TYPE TEST Codes M =Annulus Monitoring P =Standard Pressure Test R =Internal Radioactive Tracer Survey A =Temperature Anomaly Survey D =Differential Temperature Test INTERVAL Codes I =Initial Test 4 =Four Year Cycle V =Required by Variance T =Test during Workover O =Other (describe in notes) MIT Report Form BFL 11/27/07 2008-0727_MIT_PBU_13-36_Ig.xls MEMORANDUM State of Alaska • Alaska Oil and Gas Conservation Comm DATE: Wednesday, July 30, 2008 Toy Jim Regg ~ ~ Q~j P.I. Supervisor ~~~ ~' ~" SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC 13-36 FROM: Lou Grimaldi PRUDHOE BAY UNIT 13-36 Petroleum Inspector Src: Inspector NON-CONFIDENTIAL Reviewed By: P.I. Suprv `I~~-- Comm Well Name• PRUDHOE BAY UNIT 13-36 Insp Num: mitLG080728160904 Rel Insp Num: API Well Number: s0-029-22613-00-00 Inspector Name• Lou Grimaldi Permit Number: 195-167-0 Inspection Date: ~/27izoos Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 13-36 Type Inj. W TVD 8860 IA 120 4000 3980 3980 p.T. 19s16~o TypeTest SPT Test psi 2zls OA 30 2zo 22o z2o Interval 4YRTST p~F, P Tubing sus sus sus sus Notes: ~~~~~~ ~ E ~ ~ 2~~$ Wednesday, July 30, 2008 Page l of 1 MEMORANDUM TO: "7l he 1'f( i z"?J1 04 . Jim Regg P.I. Super\'isor FROM: Lou Grimaldi Petroleum Inspector Well Name: PRUDHOE SAY UNIT 13-36 Insp Num: milLG040716154658 Rei Insp Num: State of Alaska Alaska Oil and Gas Conser\'ation Commission DA TE: Thur5da~. July 2~. 2004 SlIBJECT: Mechanlcallntegrit) TestS SP EXPLOR.4. TION lALASI\:...4.\ rNC 13-3ó PRUDHOE SA Y UNIT 13-36 Src: Inspector NON-CONFIDENTIAL Re,'iewed By: --,., P.I. Supr\' -.Jþ- Comm API \Vell Number: 50-0~9-22613-00-00 Permit Number: 195-167-0 Inspector Name: Lou GrimaldI Inspection Date: 7/16/2004 Packer Depth Pretest Initial 15 Min. 30 Min. 45.M in. 60 Min. Well 13-36 Type Inj. P TVD 9088 I IA (I .1000 3960 3960 P.T. 1951670 TypeTest SPT Test psi :!:!15 lOA 0 50 50 50 Interval .¡YRTST P/F p Tubing 680 600 660 660 Notes: Good test. no problems. Thursday. July 22. 200-t Page I of I TREE = FMC NEW STA r,,DARD WELLHEAD = QW a CTUA TOR = BAKER C KB. ELEV = 75' BF. ELEV = KOP = 1915' Max Angle = 91 @ 13082' Datum MD= 12207' Datum TVD = 8800' SS 13-36 SAFETY NOTES 2226' I--~4-1/2" I-ES CP-2 TRSV SSSV NP, ID = 3.813"I Minimum ID = 3.725" @ 12209' I 4-1/2" HE$ XN NIPPLE I GAS LIFT MANDRELS ISTI ~ ITW'I~'~vl ~"" IV'VI~c"I~"'q ~'^~'" II 113~6133011 42 IHESMEXI IBK-~ II II 1217542159341 51 IHESM~Xl I BK-~II II I3110~117~91 49 IHESM~Xl I BK-~ I II I4 111859186971 58 IHESM~XI I BK~ I I 12176' 12209' I--17-5/8" x4-1/2', TIW I-BBP-TPKR I 1-14-1/2" ~ES XN NIP, ID: 3.725" I 4--1/2" TBG, 12.6#, L-80, .0152 bpf, D =3.958" Id 12231' ITOPOF 5-1/2" LNR Id 12241' 12368' 7-5/8" LNR, 29.7#, USS 95, .0459 bpf, D :6.875" I-I PERFORATION S UIV/vlA RY REF LOG: GR RESIST 12/06-12/95 ANGLE AT TOPPERF: 84 @ 12815' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 12815 - 12840 O 04/13/00 3-3/8" 4 12850 - 13025 O 12/26/95 3-3/8" 4 13035 - 13065 O 04/1 3/00 3-3/8" 4 13200 - 13230 O 04/12/00 3-3/8" 4 13250 - 13420 O 1 2/26/95 3-3/8" 4 13325 - 13350 O 04/12/00 2-7/8" 4 13350 - 13375 O 04/12/00 3-3/8" 4 13480 - 13550 O 1 2/26/95 2-7/8" 4 13625 - 13675 O 04/11/00 r-~d 13677, I 5-1/2"LNR, 17#,NT80S, .0232bpf, ID=4.892" Id 13758' I 2231' 12220' Id4-1/2" TUBING TAIL IdELrvD 'IT LOGGED 10/08/96 DATE REV BY COMMENTS DATE REV BY COMMB'4TS 12/24/95 ORIGINAL OOrvlPL ETLON 01/09/01 SlS-SLT CONVE,~,E~,TO~ CANVAS 02/21/01 SlS-LG REVISION 08/02/01 RN/TP CORRECTIONS 04/27/02 A P/tlh PERF CORRECTIONS PRUDHOE BAY UNIT WELL: 13-36 PERMIT NO: 95-167 APl No: 50-029-22613-00 Sec. 13, T10N, R14E, 3112.99 FB_ 1135.22 FNL BP Exploration (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ H20 - MI SWAPS Pull tubing _ Alter casing _ Repair well _ Other_X 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 3690' FNL, 5187' FEL, Sec. 13, T10N, R14E, UM At top of productive interval 636' FNL, 3950' FEL, Sec. 25, T10N, R14E, UM At effective depth 1094' FNL, 3188' FEL, Sec. 25, T10N, R14E, UM At total depth 1135' FNL, 3113' FEL, Sec. 25, T10N, R14E, UM 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 110' Surface 3400' Production 12336' Scab Liner 1523' 5. Type of Well: Development __ Exploratory__ Stratigraphic_ Service__X (asp°s 687318, 59311~6) (asp's 688746, 5924 (asp's 689519, 5923748) (asp's 689593, 5923707) 6. Datum elevation (DF or KB feet) RKB 75 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 13-36 9. Permit number / approval number 195-167 10. APl number 50-029-22613-00 '11. Field / Pool Prudhoe Bay Field / Prudhoe Bay Pool 13758 feet 9088 feet Plugs (measured) Tagged PBTD @ 13673' (04/11/2000). 13673 feet Junk (measured) 9079 feet Size Cemented Measured Depth True Vertical Depth 20" 260 sx AS 142' 142' 10-3/4" 1115 sx CS III, 375 sx 3432' 3224' Class 'G' 7-5/8" 265 sx Class 'G' 12368' 8956' 5-1/2" 285 sx Class 'G' 13758' 9088' Perforation depth: measured true vertical Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) Open Perfs 12790'-12840', 12850'-13025', 13035'-13065', 13200'-13230', 13250'_~13420', ~ , 13480'-13550', 13625'-13670', ,'!i',',',.,,, , ,,' ',' ",,,,, ',, ,', Open Perfs 9045'-9049', 9049'-9053', 9053'-9052', 9051'-9052~', '9052'-9059', 9062'-9068', 9075'-9079'. ,.' 4-1/2", 12.6#, L-80 TBG @ 12231' MD. 7-5/8" x 4-1/2" TIW HBBP-T Packer @ 12176' MD. 4-1/2" HES CP-2 TRSV SSSV @ 2226' 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 01/04/2003 Subsequent to operation 01/29/2003 Oil-Bbl Representative Daily Average Production or Iniection Data Gas-Mcr Water-Bbl 2438 12999 Casing Pressure Tubing Pressure 1291 3586 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _ 16. Status of well classification as: Oil__ Gas__ Suspended_ Service WAG INJECTOR 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Title: Technica~)~NE[) ~A~ 0 7 20[]3 Date February25, 2003 DeWayne R. Schnorr Prepared by DeWayne R. Schnorr 564-5174 , Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 13-36 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 12/01/2000 1 2/O2/2OOO 12/06/2000 12/22/2OOO 12/23/2OOO 02/04/2001 02/17/2OO 1 03/16/2OO 1 07/07/2001 O2/22/2OO2 05/1 O/2OO2 12/24/2002 01/10/2003 02/24/2O03 MITIA PASSED, PRODUCER TO IN]ECTOR CONVERSION. ANN-COMM: PERFORM MIT IA FOR WELL CONVERSION WATER INJECTION STARTED. ANN-COMM: PREP WELL FOR STATE MIT TEST ANN-COMM: MITIA TO 2500 PSI PASSED (STATE WITNESS TEST) ANNCOMM: T/I/O = 925/50/50 TEMP=148, OAFL@ SURFACE, DSL&CRUDE. SCHMOO B GONE: SBG TREATMENT SWAPPED FROM WATER TO MI GAS. SWAPPED FROM MI GAS TO WATER. SWAPPED FROM WATER TO MI GAS. SWAPPED FROM MI GAS TO WATER. SCMOO-B-GONE--SBG: SCMOO-B-GONE SWAPPED FROM WATER TO MI GAS. TESTEVENT---INJECTION PRESSURE, PSI: 3,334 TYPE: MI VOLUME: 11,738 MSCFPD EVENT SUMMARY 12/01/00 PASSED MIT IA TEST. 12/02/00 PERFORM 3000 PSI PRESSURE TEST ON THE INNER ANNULUS FOR PRODUCER TO INJECTOR WELL CONVERSION. PASSED MIT TEST. 12/06/2000 WATER INJECTION STARTED. 12/22/00 PREP WELL FOR STATE MIT TEST 12/23/oo MITIA TO 2500 PSI PASSED (STATE WITNESS TEST). T/I/O = 1050/0/0 MITIA to 2500 psi PASSED. PUMPED 7 BBLS METHANOL TOTAL TO PRESSURE UP TO 2500 PSI. IA LOST 20 PSI IN 15 MINUTES AND TOTAL OF 30 PSI IN 30 MINUTES. FINAL WHP's = 1050/0/0. WELL ON LINE INJECTING PRODUCED WATER. 02/04/01 T/I/O = 925/50/50 TEMP=148, OAFL@ SURFACE, DSL & CRUDE. 02/17/01 225 BBL SBG TREATMENT, FROM THE WELL 03/16/2001 SWAPPED FROM WATER TO MI GAS. 07/07/2001 SWAPPED FROM MI GAS TO WATER. 02/22/2002 SWAPPED FROM WATER TO MI GAS. 2003 05/10/2002 SWAPPED FROM MI GAS TO WATER. Page I 13-36 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 12/24/02 PUMPED 248 BBLS SCHMOO-B-GONE & LET SOAK. FLUSHED WITH 186 BBLS OF SEA WATER. 01/10/2003 SWAPPED FROM WATER TO M! GAS. 02/24/2003 TESTEVENT --- INJECTION PRESSURE, PSI: 3,334 TYPE: MI VOLUME: 11,738 MSCFPD Fluids Pumped BBLS 10 DIESEL 7 NEAT METHANOL 15 METHANOL 206 FRESH WATER 269 SEA WATER 200 BORAX WATER 267 SCHMOO-B-GONE 974 TOTAL Page 2 STATE OF ALASKA ., ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Per/orate_ Pull tubing _ Alter casing _ Repair well _ Other _X (conversion to Inj) 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 3690' FNL, 5187' FEL, Sec. 13, T10N, R14E, UM At top of productive interval 636' FNL, 3950' FEL, Sec.25, T10N, R14E, UM At effective depth At total depth 1135' FNL, 3113' FEL, Sec. 25, T10N, R14E, UM 5. Type of Well: Development _ Exploratory__ Stratigraphic_ Service__X (asp's 687318, 5931656) (asp's 688746, 5924186) (asp's 689593, 5923707) 6. Datum elevation (DF or KB feet) RKB 75 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 13-36i 9. Permit number / approval number 195-167 / 300-120 signed 5/9/2000 lO. APl number 50-029-22613 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical 13758 feet Plugs (measured) 9088 feet PBTD Tagged @ 13673' MD on 4/11/2000. Effective depth: measured true vertical Casing Length Conductor 1 10' Surface 3357' Production 12293' Liner 1523' Perforation depth: 13673 feet Junk (measured) 9079 feet Size Cemented Measured Depth True vertical Depth 20" 260 Sx AS ,,, 110' 110' 10-3/4" 1115 sx cs III & 375 sx Class G 3432' 3224' 7-5/8" 265 Sx Class G 12368' 8956' 5-1/2" 285 sx C~ass G 13758' 9088' ORI6tNAL measured 12790'- 12840'; 12850'- 13025'; 13035'- 13065'; 13200'- 13230'; 13250'- 13420'; 13480'- 13550'; 13625' - 13670'. true vertical 9045' - 9049'; 9049' - 9053'; 9053' - 9052'; 9051' - 9052'; 9052' - 9059'; 9062' - 9068'; 9075' - 9079' RECEIVED 4-1/2", 12.6#, L-80 Tbg @ 12231' MD. 7-5/8" X 4-1/2" TIW HBBP-T PACKER @ 12176' MD. 4-1/2" HES CP-2 TRSV SSSV @ 2226' MD. Tubing (size, grade, and measured depth) Packers & SSSV (type & measured depth) DEC 1 5 000 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure Anchorage 14. Prior to well operation (producer) Subsequent to operation(injector) OiI-Bbl 241 Representative Daily Avera.qe Production or Iniection Data Gas-Mci Water-Bbl N/A 465 5OOO Casing Pressure Tubing Pressure 24O 1373 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations _X 16. Status of well classification as: Oil __ Gas __ Suspended __ Service WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~/~..~ ,~V',,,,.,~/~ Title DS 13 Surveillance Engineer Andy Parker Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 13-36i DESCRIPTION OF WORK COMPLETED CONVERSION FROM PRODUCER TO WAG INJECTOR Date Event Summary October-2000 Facility modifications were performed @ the drillsite to convert this well from a producer to a Water Alternating Gas (WAG) injector. 11/20/2000 - 11/22/2000: 12/02/2000: 12/02/2000: RIH & dummied off GLV's. Performed MITIA to 3000 psi - passed. Placed this well on water injection. Obtained injection information. Page 1 APPLICATION .FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate _ Change approved program _ Pull tubing _ Vadance _ Pedorate _ (Prod -> WAG InJ Conversion) Other _X 2. Name of Operator Phillips Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 3690' FNL, 5187' FEL, Sec. 13, T10N, R14E, UM At top of productive interval 636' FNL, 3950' FEL, SEC. 25, T10N, R14E, UM At effective depth At total depth 1135' FNL, 3113' FEL, Sec. 25, T10N, R14E, UM 5. Type of Well: Development __X Explorato~J __ Stratigraphic _ Service _ (asp's 687318, 5931656) (asp's688746,5924186) (asp's 689593, 5923707) 6. Datum elevation (DF or KB feet) RKB 75 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 13-36 9. Permit number / approval number 195-167 10. APl number 50-029-22613 11. Field / Pool Prudhoe Bay Oil Pool 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Size Conductor 110' 20" Surface 3357' 10-3/4" Intermediate 12293' 7-5/8" Liner 1517' 5-1/2" 13758 9088 13673 9079 feet feet Plugs (measured) Tagged PBTD @ 13673' on 4/11/2000. feet Junk (measured) feet Cemented Measured Depth True vertical Depth 260 Sx AS 110' 110' 1115 Sx CS III & 375 Sx Class G 3432' 3224' 265 Sx Class G 12368' 8956' 285 sx c~ass G 13758' 9088' ORIGINAL Perforation depth: measured true vertical Tubing (size, grade, and measured depth 12790'-12840'; 12850'-13025'; 13035'-13065'; 13200'-13230'; 13250'-13420'; 13480'- 13550'; 13625'-13670'. 9045'-9049'; 9049'-9053'; 9053'-9052'; 9051'-9052'; 9052'-9059'; 9075'-9079' 4-1~",12.6#,L-80Tbg @ 12231'MD. Packers & SSSV (type & measured depth) 7-5/8" X 4-1/2" TIW HBBP-T PACKER @ 12176' MD. 4-1/2" HES CP-2 TRSV SSSV @ 2226' MD. 13. Attachments Description summary of proposal __X Detailed operations program .,.,'ED 05 20¢ 14. Estimated date for commencing operation May 15, 2000 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __X Service Gas M Suspended~ 17. I here_by certily that the foregoing Is true a._nd correct to the best of my knowledge. Signed Title: .. PBRD WF/EOR Supervisor Gordon Pospisil Questions? Call Andy Parker @ 265-1614 D ate ..¢'/~/0 d Prepared b~ Paul Rauf 263°4990 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Plug integrity __ BOP Test _ Location clearance _ Mechanical Integrity Test ~'~ Subsequent form required 10- ~ O ~ Approved by order of the Commission Form 10-403 Rev 06/15/88 · .... ~-'<~GiNAL SIGNED, ElY Commissioner ~o¢o,~ed CoPY p, etUrr~ec~ - ~ SUBMIT IN TRIPLICATE PHILLIPS Alaska, Inc. A Subsidiary of PHILLIPS PETROLEUM COMPANY P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 DS 13-36 Conversion to WAG Injector The conversion of 13-36 from a Iow volume peripheral producer to a WAG injector, will provide support to periphery horizontal wells 13-27A and 13-08A, as well as vertical producer 12-36. All three of these wells are currently on-line and in need of pressure support. Reserve benefits will be realized from improved sweep efficiency and the injection of MI into this new pattern. This conversion requires minimal wellwork and surface facility modifications. Well 13-36 is a horizontal peripheral producer that was originally drilled and completed as a pre- produced injector in 1995. The well initially produced almost 6000 BOPD. After a year, total fluid production had fallen to less than 1000 BFPD. The well has not been hydraulically fractured. It produces through 415' of perforations in the cemented 5-1/5 liner. The well has produced approximately 750 MBO and 400 MBW. The reservoir pressure in this area is estimated to be approximately 3,350 psi. A static bottomhole pressure was obtained in the subject well last August. The measured pressure was 3,333 psi. Wellwork for this conversion includes pulling the existing gas lift valves and replacing them with dummies. Annular communication work will confirm the integrity of the casing and tubing strings. The facility work necessary to convert 13-36 to water injection service involves: cutting and capping the existing production line to the production manifold building, connecting jumper water and MI injection lines from the 13-06A injection lines, equipping the new water injection slot with a choke, check and drain valves. The existing production and gas lift facilities will be disconnected and abandoned in place. The well will be connected to water and MI service by "twinning" with 13-06A. Only one well can be on MI service at a time for the flow meter and choke valve to work properly. Installation of power to the well house heater and lights will also be required. O5 200 ARCO Alaska, Inc. is a Subsidiary of AtlantlcRIchfieldCompany STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Perforate _X Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator ARCO Alaska, Inc. 3. Address P. O. Box 100360 Anchorage, AK 99510-0360 4. Location of well at surface 3690' FNL, 5187' FEL, Sec. 13, T10N, R14E, UM At top of productive interval 636' FNL, 3950' FEL, Sec.25, T10N, R14E, UM At effective depth At total depth 1135' FNL, 3113' FEL, Sec. 25, T10N, R14E, UM 5. Type of Well: Development _X Explorato~._ Stratigraphic__ Service__ (asp's 687318, 5931656) (asp's 688746, 5924186) (asp's 689593, 5923707) 6. Datum elevation (DF or KB feet) RKB 75 feet 7. Unit or Property name Prudhoe Bay Unit 8. Well number 13-36 9. Permit number / approval number 195-167 10. APl number 50-029-22613 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 110' Surface 3357' Production 12293' Liner 1523' 13758 feet Plugs (measured) PBTD Tagged @ 13673' MD on 4/11/2000. 9088 feet 13673feet9079 feet Junk(measured) 0R I G! NAL Size Cemented Measured Depth True vertical Depth 20" 260 Sx AS 110' 1 10' 10-3/4" 1115 Sx CS III & 375 Sx Class G 3432' 3224' 7-5/8" 265 sx c~ass G 12368' 8956' 5-1/2" 285 Sx C~ass G 13758' 9088' Perforation depth: Tubing (size, grade, and measured depth) measured 12790'- 12840'; 12850'- 13025'; 13035'- 13065'; 13200'- 13230'; 13250'- 13420'; 13480'- 13550'; 13625' - 13670'. true vertical 9045' - 9049'; 9049' - 9053'; 9053' - 9052'; 9051' - 9052'; 9052' - 9059'; 9062' - 9068'; 4-1/2", 12.6#, L-80 Tbg @ 12231' MD. 7-5/8" X 4-1/2" TIW HBBP-T PACKER @ 12176' MD. 4-1/2" HES CP-2 TRSV SSSV @ 2226' MD. Packers & SSSV (type & measured depth) 13. Stimulation or cement squeeze summary APR 20 2000 Gas Co~ls, (Jor~l~lliSSl01~ Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure Anchorage 14. Prior to well operation Subsequent to operation Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure 101 - 382 46O 91 83O Tubing Pressure 229 242 15. Attachments Copies of Logs and Surveys run _ Daily Report of Well Operations __X 16. Status of well classification as: Oil __X Gas m Suspended __ Service 17. I hereby certify that the foregoing is true and correct tb the best of my knowledge. Erin Oba Title ARCO EngineeringSupervisor Date '7'" '- Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 13-36 DESCRIPTION OF WORK COMPLETED CT PERFORATING OPERATIONS Date Event Summary 4/11/2000 - 4/13~2000: 4/15/2000: MIRU CTU#5. PT'd equip to 4000 psi. RIH w/ Coiled Tubing conveyed perf guns & tagged PBTD @ 13673' MD. Shot 205' of Perforations tied into Reference Log (GR Resistivity 12/6- 12/1995) as follows: Add Perforations 12790' - 12840' MD (Zone 4) 3-3/8" carriers 13035' - 13065' MD (Zone 4) 3-3/8" carriers 13200' - 13230' MD (Zone 4) 3-3/8" carriers 13625' - 13670' MD (Zone 4) 2-7/8" carriers Reperforations 13325' - 13350' MD (Zone 4) 3-3/8" carriers 13350' - 13375' MD (Zone 4) 2-7/8" carriers All shots @ 4 SPF, random orientation, underbalanced pressure & 60° phasing. POOH w/ TCP guns. ASF. RD CTU. Placed well 13-36 on production. Performed a welltest. Awaiting the results of an oil sample taken for density analysis. Oil production value could vary by 20%. This well will be converted in the near future f/production to WAG injection status. The form 10-403 will be generated shortly. Page 1 APR 20 2000 Oil ,~ Gas C~s. ~ch0r~e rvices rilling 900 East Benson Boulevard, MB 8-1 · Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 December 14, 1998 Wendy Mahan Natural Resource Manager Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 RECEIVED Re: Annular Disposal Information Request Dear Ms. Mahan: DEC 'lq- 1998 Alaska 0il & Gas Cons. Commission Anchorage On October 28, 1998 you requested an update from Shared Service Drilling regarding Annular DispOsal Records from July 25, 1995 through present time. We compared your list with our records and are able to provide you with the following data: · Individual Annular Disposal Logs from the SSD database which coincide with the approved. wells on your attached AOGCC Annular Log. The.SSD records are proVided to you in the same order as listed on your log. · There were some wells on your list which were not injected into. These wells are identified as follows: ·Endicott wells 1.-03/P-16, 1,65/N-25, 1-59/0-24 EXploration well Pete's Wicked #1 · Milne Point wells E-22, E-23, F-O1, L-16, J-19, L-25, F-30, L-21, K-38, NMP #1 & #2, K-05, K-02, H-07, K-25, K-37, E-17, F-21, K-30, K-34, K,21i, F-66, K-06, K-54, K-33, F-49i, K-18 · PBU Wells E-38, 18-34, 15,42, 'S-29A, 15-46, B-36, 15-43, 11-38 · The reason many of these annuli were not used is because the waste materials generated from these wells were injected into other approved annuli. Hopefully the injection logs submitted with this letter will clarify this. In addition, please note that our records show: · The wells listed above in italics were permitted but not used for annular disposal. · The wells listed above in BOLD were not Permitted for annular disposal. Wells drilled after June 6, 1996 were required by SSD procedure to be permitted with a Sundry Approval (10-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and June 6, 1996 were automatically approved for annular disposal with the Permit to Drill. · We also provide you with a cumulative report from our database of records from July 25, 1995 through the present. From those records, we show the following wells not listed on your report were used for annular dispOsal: SCANNED NOV 1 ~ 200~ ,Annular Disposal Letter 12/14/98 · Endicott wells i-23/O-15, 1-61/Q-20, 2-40/S-22 Exploration well Sourdough #3 - ~' ° o ~5 4 , ~ Mflne Point wells F-06, H-05, ~-06, J-13, L-24 - ~s-~ ~.,, PBU wells-18-30, 18-31, 14~,~-43, ~-34, E-36, G-~A, =d S-33' ~z'~ Individu~ logs ~e provided to ~ou for these ~ogs as we~l. · Finally, our records show that the B-24 outer annulus was left open (see attached correspondence) Thank you for the opportunity to provide clarity to these records. If I can be of any further assistance please do not hesitate to contact me at 564-5183, or Karen Thomas, Environmental Advisor at 564-4305. Sincerely, Fritz P. Gunkel Shared Service Drilling Manager FPG/KMT cc: Dave Wallace - HSE Manager (w/out attachments) RECEIVED c, Ec !¢ 1998 A]~sks Oil & 6~s Co~s. OommissJo~ Anchorage ANNULAR INJECTION ~DATA ENTRY SCRFFN Asset ED.& ........................................... Rig Name ~.{tb.Qr~...l~F~ ............................. Inj Well Name .1.~:.~.§ .......................................... Permit Start ....... .1..0=~§:.~..~. ..... i Permit End .......J.~.~.l/[~...'... Sur Csg Dep ~.~.l ................. ' .............................. n,,t~ *Permit EXpires in 30 Days or Less* C umu l ative .... Rig-' ~[ Mud/Ct: Wash'i:: Well Total g .:- ~': Daily Data " d ~I Rig: ash . 6~-~-~:~ ............. I~~"14~ ...................... I~ ................. I .................. I~'~' ~soo DS 13-36 11~10/95 1784 1~~~'~-~854 .... ~~~ ~~ ~172 ~1~15/95 /0 /~7p ,~~'~-- , 75 bbls Cemt Rihse'~-i~r~-'?~"~' ...... 70 bbls water w/safeclean 4 bpm-750 I 4 bpm-1100 psi 1.5 bpm - 900 ps~ 3.0 bpm - 900 ps~ 3.0 bpm - 900 ps~ 2.0 bpm - 900 ps~ 2.5 bpm - 700 ps~ 4.0 bpm - 850 ps~ Crude Oil Open Sharrd SerVice Drilling Annd;Tar Injection'Volumes July 25, 199,5 until December 1998 Cumulative Report surface Casing Rig Inj Well Depth Legal Desc Endicott Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Cum Tolal & Ctgs Wash Fluids Fluids Freeze Freeze Slart End Slalus Doyon 15 1-19/I-18 5000 Sec. 36tT12N, .R16E 8,960 7,848 992 120 12/5/95 12/5/96 Open DoyOn 15 1-23/O-15 4246 2°20'FNL,.2087'FEW, SEC.36,T12N,R16E 32,084 30,604 i,160 200 120 9/30/95 12/31/95 Open O?~Y_0n_n_! 5__ ....... 1-33/M-23' 5013 3217'NSL, 2114'WEE, Sec 36,T12N, R16E 9,879 9,729 150 8/31/95 12/31/95 Broached Doyon 1_5 . 1-61/Q-20 4236 .3075'NSLt 220~'._W_ EL, Sec .!3.,_T?2N~ R~6E ._ 25,228. 2;I,~37 2,613 1,176 60 12/5/95 12/5/96 Open Doyot~ 15 2-40/S-22 4531 2020'FNL 2289'FEL Sec 36 T12N R16E 31 195 29,952 1,063 120 60 7/25/95 12/31/95 Open .=CA .... Do_y'_on~l~4 ....... 1_5~?7 ...........3_5.1_5~- 3648'NSL, 4956'WEL, Sec 22,T11N, R14E 3,002 903 2,009 90 11/7/95 12/31/95 Open 3oyon 14 DS 15-45 3829 4749' NSL, 5180' WEL, Sec.'22, T11N, 1,882 1,697 134 51 4/4/96 4/4/97 Broached 3_o.?_n_1~4 ._-~ ............. DS 15-48. 3548 ~ .... Sec; 22, T11N, R14E _ ......... 3,385 216 820 2,283 66 12/21/95 12/21/96 Open )oyon 14 DS 15-49 3667 4676' NSL, 5165' WEL, Sec. 22, T11N, 4,669 -' 1,559 1,141 1,904 65 2/21/96 2/21/97 Open )oyon 9 : 18-30 3930 1499'SNL, 26'WEL, Sec 24,T11N, R14E 2,266 936 380 800 150 7/25/95 12/31/95 Open )oyon 9 18-31 3680 3719'NSL, 64'WEL, Sec 24,T11N, R14E 6,086 2,250 1,100 2,565 171 7/26/95 12/31/95 Open )oyon 9 18-32 3830 3632'NSL, 41'WEL, Sec 24,T11N, R14E 3,311 1,861 200 1,100 150 8/24/95 12/31/95 Open )oyon 9 ' 18-33 4140 3690'NSL, 56'WEL, Sec 24,T11N, R14E 5,215 2,050 3,035 10 120 9/28/95 12/31/95 Open Jabors 18E 12-35 3543 348'NSL, 705'WEL, Sec 18,T10N, R14E 3,723 3,436 137 150 9/1/95 12/31/95 Open labors 18E 12-36 3452 63'FSL, 899'FEL, Sec 18,T10N, R15E 4,002 1,961 50 1,871 120 10/13/95 12/31/95 Open labors 18E 13-36 3431 1585'NSL, 5187~VEL, Sec 13,T10N, R14E 4,137 3,523 464 150 10/26/95 12/31/95 Open labors 18E 14-44 3288 2829'NSL, 1617'WEL, Sec 9,T10N, R14E 3,974 2,319 1,535 120 8/17/95 12/31/95 Open xplorati°n ool 4 Sourdough #3 4236 2245'FSL, 5067' FEL, Sec. 29, T~N, R24E 5,786 4,630 1,156 1/26/96 1/26/97 Closed lilne 27E MPK-17 3508 3648'NSL,2100'WEL, Sec. 03,T12NR11E 19,608 18,538 285 685 100 4/18/96 4/18/97 Open ' abors 22E MPC-23 4941 1038 NSL, 2404 WEL, Sec 10,T13N, 2,060 1,800 130 130 1/25/96 1/25/97 Open abors 22E MPC-25 8595 1143'FNL, 2436'FWL, Sec 10,T13N, R10E 1,905 1,465 . 300 140 1/5/96 1/5/97 Open abors 22E MPC-26 4704 1086 NSL, 2419 WEL. Sec 10,T13N, 5,228 4,483 555 190 12/19/95 12/19/96 Open abors 22E. MPC-28 5405 Sec 10,T13N, R10E 425 350 75 2/15/96 2/15/97 Open Page I .DEC 1 1998 Anchorago Shar.~d Service DHIling Annul'ar Injection Volumes July 25, 199{~ until December 1998 Cumulative Report Rig Inj Well· Nabors 22E MPF-06 Nabors 22E MPF-14 . .. Nabors 22E MPF-70 Nabors 22E MPH-05 Sudace Casing ' Cum Mud Cum Rig CumCompl Cum Form Cum Interm Cum Final Depth Legal Desc Cum Total & Ctgs Wash Fluids Fluids Freeze__ . Freeze 8766 Sec 06,T13N, R10E 1,927 1,731 ........... ........ 196 6690 Sec 06,T13N, R10E UM 18,717 17,107 1,270 .......... 340 6/3/96 7919 2189'NSL 2591'WEL, Sec 6,T13N, R10E 19,775 18,794 735 .. .... 190 .... 56 6/17/96 5335 2882'NSL 4028'WEL, Sec 34,T13N, R10E 8,283 7.711 382 190 8/19/95 __ 7304 2824,NSL 4044,WEL, Sec _34~T13N,_~.!0_E ...... 8,_5_15_ .... 8,335 ............................. 1~0 . _.8/5/95 1,680 250 80 70 9/21/95 Nabors 22E MPH-06 Nab°rs 22E MPI-07 · _. Nabors 22E MPJ-13 Disposal Period Start End 1/25/96 1/25/97 6/3/97 . . 6/17/97 2680 2339'NSL 3906'WEL, Sec 33,T13N, R10E 2835 2319'NSL 3179'WEL, Sec 28,T13N, R10E 12/31/95 Annulus Status Open .. Open Open Open 12/31/95 Open 1,280 1 2/31/95 Open 14,127 13,292 645 60 130 10/17/95 12/31/95 Open Nabors 22E MPJ-16 3112 Nabors 27E B-24 4080 915 70 11/12/95 12/31/95 Open 1,396 1125/96 1/25/97 Open 2317'NSL 3336'WEL, S__e_c _2_8713N, R10E 985 Sec 18,T13N, R11E UM 1,468 72 Nabors 27E MPF-22 8841 Sec 06,T13N, R10E UM 6,536 6;466 70 12/12/95 12/12/96 Open Nabors 27E MPF-25 3405 1857'NSL, 2696'WEL, sec 6,T13N, R10E ' 9,897 9,357 250 225 65 12/26/95 12/26/96 Open Nabors 27E MPF-37 6621 1931'NSL, 2643'WEL, Sec 6,T13N, R10E 7,032 6,887 70 75 7/25/95 12/31/95 Open Nabors 27E MPF-38 8561 1994'NSL, 2731'WEL, Sec 6,T13N, R10E 9,232 9,157 75 12/6/95 1_2/_.3.1_1_9_5 .... _O__p_en~.__ Nabors 27E MPF-45 6678 1979'NSL, 2608'WEL, Sec 6,T13N, R10E 17,562 17,381 181 7/31/95 12/31/95 Open Nabors 27E MPF-53 6750 2028'NSL, 2572'WEL, Sec 6.T13N, R10E 6,051 5,671 165 75 60 80 8/19/95 12/31/95 Open 1 2/31/95 Open Nabors 27E MPF-61 6585 2077'NSL, 526'WEL; Sec 31,T14N, R10E 5,732 5,657 75 8/31/95 Nabors 27E MPF-62 6059 2141'NSL, 2627'WEL, Sec 6,T13N, R10E 386 316 70 10/13/95 12/31/95 Open Nabors 27E MPF-69 5772 2125'NSL, 2502~VEL, Sec 6,T13N, R10E 9,740 91665 75 8/31/95 12/31/95 Open Nabors 27E MPF-78 7085 2237'NSL, 2555'WEL, Sec 6,T13N, R10E 8,476 7,456 40 775 65 140 9/12/95 12/31/95 Open Nabors 27E MPL-24 6515 3654'NSL, 5180'WEL, Sec 8,T13N, R10E 6,790 4,900 1,320 165 335 70 11/27/95 12/31195 Open WOA 18E F-33 3570 3332'NSL, 2174'WEL, Sec 2,T11N, R13E 1,468 183 660 465 160 2/21/96 2/21/97 Open 18E F-36 3691 2642'NSL, 2878'WEL, Sec 2,T11N, R13E 6,963 1,998 1,359 3,471 135 12/18/9_5_ __72/18/96 Open __ . ~)oyon 9 D-30 3456' 3625' NSL, 1066' WEL, SEC. 23, T11N, 5,261 2,811 1,275 1~035 140 1/31/96 1/31/97 Open ~oyon 9 D-31 3215 SEC. 26, T11N, R13E 150 150 4/20/96. 4/10/97 Open 3oyon 9 D-33 3222 2965' NSL, 1067' WEL, SEC. 23; TllN, 4,661 2,425 2,106 130 2/21/96 2/21/97. Open ~labors 18E S-43 3121' 4211'NSL,4503'WEL,SEC35,T12N,R12E 5,943 2,636 1,716 1,511 80 5/7/97 5/7/98 OPEN $¢ANNE NOV I g 200, Page 2 Shared SCi'/ice Dr..illing Ann~l~'r injeCtion Volumes July 25, 1995, until December 1998 Cumulative Report Surface Casing Rig Inj Well Depth Nabors 28E B-33 3504' ... Nabors 28E E-34 3664 . Nabors 28E E-36 3648 . Nabors 28E E-37 3810 Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Legal Desc Cum To~a! & Ctgs Wash Flu~s Fluids Freeze Freeze Slart End 969'SNL, 1898'EWL, Sec 31, TllN, R14E 3,974 2,842 857 195 80 5/1/96 12/31/96 168'SNL, 500'WEL, Sec 6, T11N, R14E 9,656 7,228 1,420 858 40 110 8/23/95 12/31/95 1706'SNL, 822'WEL, Sec 6,T11N, R14E 9,271 4,417 1,293 3,096 365 100 7/25/95 12/31/95 3391'NSL, 881'WEL, Sec 6,TllN, R14E 4,695 4,241 374 80 9/16/95 12/31/95 Annulus Slalus Broached . Open Open Open Nabors 28E E-39 3638 3358'NSL, 501'WEL, Sec 6,.T11N, R14E 2,250 Nabors 28E G-04A 3509 2917'NSL, 1974'WEL, Sec 12,T11N, R13E 5,937 ..... Nabors 28E G-21 3509 2911'NSL, 2368'WEL, Sec 12,T11N, R14E 11,430 Nabobs 28E S-24 2750 1633'SNL, 4228'WEL, Sec 35,T12N, R12E 20,261 Nabors 28E S-33 2958 1639'SNL, 1487'WEL, Sec 35,T12N, R12E 18,014 928 220 1,022 8O 8/28/95 12/31/95 Open _1_ ,_7_ 9_8_ .... 1_,824 2,315 ...................... !0/20/95 . 12/31/9~ ...... ~Pe.n 3,956 3,072 4,270 70 '62 9/8/95 12/31/95 Open 11,773 2,177 5,751 275 285 12/9/95 1 2/9/96 Open 6,813 2,431 8,392 270 308 12/1/95 12/1/96 Open Nab_o_rs__2_8~E __ _s_-4~1 ....... _33__3~ .... 4152' NSL, 45o4' WEL, Sec 35,T12N, 8,062 4,159 Nabors 28E S-42 3077 Sec 35, T12N, R12E 168 100 115 2/8/96 2/8/97 Open 68 3/13/96 3/13/97 Open Nabors 2ES H-35 3157 4535'NSL, 1266'WEL, sec 21,T11N, R13E 4,860 3,725 .555 480 20 80 10/26/95 12/31/95 Open Nabors 2ES H-36 3550 4478'NSL, 1265'WEL, Sec 21,T11N, R13E 1,452 857 100 410 85 10/26/95 12/31/95 Open SCANNED NOV Page 3 Alas h ared ri.l!ing TO: Blair Wondzell FROM: Chris West DATE: October 27, 1995 SUBJECT: MPB-24 Well Suspension APl # 50-029-22642 Blair; Please find attached a copy of the Form 10-403 to temporarily suspend this well as per AOGCC 20- AAC 25.110. As discussed this morning we propose 'setting three plugs in this well as detailed in the attached form. This will allow us to retain the wellbore for potential future sidetrack or service well use. We would like to keep the well's 9-5/8" x 7" annulus available for the injection of liquid 'wastes. There are no other well annulii on this pad for injection. The annulus for MPB-24 was approved for injection as part of the permit dated 25 January 1996. The annulus will be freeze protected before moving the rig. Thank you for your help in this matter. Please call me if I maY be of any assistance. Chris West Drilling Operations Engineer Nabors 27E (907)-564-5089 ,3 e o 1 o,;::~ '~ c a 1 H a t e r' 'i' ,!a 1 s I n v e n 't o r" y F' E ks: k:l l T D A T A T D A"I" A P L,.. IJ S IR i N R I: C VD D 9 5 "-' '1 6 7 E ~/R ,, ,,:~ R 9 $ ~ '1 6 '7 E 'd i:?..,/,:3 R '.:3,5 .... i67 '7:2/+'i · g. 5 .... 1 8 '? GeoQuest 500 W. International Airport Road Anchorage, AK 99518-1199 ATTN: Sherrie NO. 10525 Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 10/30/96 Field: Prudhoe Bay Floppy Well Job # Log Description Date BL RF Sepia Disk D.S. 01-4 PRODUCTION LOG 961 001 I 1 D.S. 01-05 ST TDTP 961007 I 1 D.S. 1-7A PRODUCTION PROFILE 960927 I 1 D.S. 3-21 PRODUCTION LOG 960922 I 1 D.S. 03-36 INJECTION PROFILE 961 004 1 1 D.S. 06-11 PRODUCTION PROFILE 960929 I 1 D.S. 6-14A STATIC PRESSURE SURVEY 961 007 I 1 D.S. 13-17 STATIC PRESSURE SURVEY 961 009 I 1 D.S. 13-36 STATIC PRESSURE SURVEY 961 008 I 1 D.S. 14-16 DUAL POROSITY COMP NEUTRON LOG 960922 I 1 D.S. 14-31 DUAL POROSITY COMP NEUTRON LOG 960922 I 1 D.S. 16-11 STATIC PRESSURE SURVEY 961 007 I 1 D.S. 16-18 PRODUCTION PROFILE 961 006 I 1 D.S. 4-21 96282 TDTPBORAX ~ '71 ~',~ 960919 I SIGNED: Please sign and return one'~opy of this transmittal to Sherrie at the above address. Thank you. DATE: IOV 0 8 199 Aiaska Oil & Gas Cons. Commtss~o~ Anchorage I-I F:! I I_1_ I IM CS S E FIL/I I-- 1= S WELL LOG TRANSMITTAL To: State of Alaska April 24, 1996 Attn: Larry Grant, AOGCC 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs/Tapes - DS 13-36 AK-MM-951264 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jun Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 1 LDWG formatted magnetic tape with LIS listing. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company D F! I I--I_1 ~ G WELL LOG TRANSMITTAL To: State of Alaska April 22, 1996 Alaska Oil and Gas Conservation Comm. Attn.: Larry Grant 3001 Porcupine Dr. ~ ,?- ! ~ ~ Anchorage, Alaska 99501 MWD Formation Evaluation Logs - DS 13-36, AK-MW-50116 & AK-MM-951264 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 DS 13-36: 2"x 5" MD Resistivity and Gamma Ray Logs: 50-029-22613-00 2"x 5" TVD Resistivity and Gamma Ray Logs: 50-029-22613-00 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia , / 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION ·/ELL COMPLETION OR RECOMP LETION 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. 95-167 3. Address 8. APl Number P. 0. Box 196612, Anchora~le, Alaska 99519-6612 5 o- 029-22613 4. Location of well at surface!;' ,;.::...~.~;~i~': :~ ~ 9. Unit or Lease Name 1585' NSL, 5187' WEL, SEC. 13, TION, R14E Prudhoe Bay Unit At Top Producing Interval . ~.f;~?~'_A.T~,~ .~0. Well Number 636' SNL, 3950' WEL, SEC. 25, T ION, R14E i', ~ i ' ~ "?;!'""~:~;'~,,~x.~--.,.¢ 13-36 ~.. ~ 1. Field and Pool At Total Depth ~ ~ ........... ::.-~ ,....~--~.'~:.Prudhoe Bay Field/Prudhoe Bay Pool 1137' SNL, 3110' WEL, SEC. 25, TION, R14E~'~ 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 75.10 ADL 028316 12.11/22/95Date Spudded 13.12/14/95Date T.D. Reached 14.12/24/95Date Comp., Susp. or Aband. 15. Water Depth,N/A iffeetOffshoreMSL 16.oneNO. of Completions 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD 19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 13758'MD/9088'TVD 13677'MD/9079'TVD YES [] kO [] 2217 feet MD 1900'(Approx.) 22. Type Electric or Other Logs Run MWD, GR, L WD/FE, Gyro, RES, CBL 23. CASING, LINER AND CEMENTING RECORD SE'I-LqNG DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Be'FI'OM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 110' 30" 260 sx Arctic Set (Approx.) 10-3/4" 45. 5# N T80 21' 3432' 13-1/2" 1115 sc CS III, 375 Class 'G' 7-5/8" 29. 7# USS95 27' 12368' 9-7/8" 265 sx Class 'G' 5-1/2" 17# NT-80S 12235' 13758' 6-3/4" 285 sc Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom and 25. TUBING RECORD interval, size and number) SIZE DEPTH SETIMD) PACKER SET IMD) 3-3/8" Gun Diameter, 4 spf 4-1/2" 12232' 12167' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 12850'- 13025' 9049'- 9053' Freeze Protect w/83 Bbls Diesel 13250' - 13420' 9052' - 9059' 13480'- 13550' 9062'- 9068' 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) January 8, 1996 Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL~BBL GAS-MCF WATER-BBL CHOKESlZE IGAS-OIL RATIO TEST PERIOD II~ IEl~w Tubing Casing Pressure CALCULATED..~ OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (corr) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips, and presence of oil, gas or water. Submit core chips. FEB 25 199G ~aska oii& Gas Cons. Commissiof~ Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. 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. Sag River 12365' 8955' Shublik 12404' 8973' Sadleroch it 12778' 9043' 31. LIST OF ATTACHMENTS 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed ¢~"¢ '~ ~~' Title SeniorDri//ingEngineer Date z~/7" Z7//¢' '~ INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Item 1' Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. Item 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. Item 16 and 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. Item 21- Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). Item 23: Attached supplemental records for this well should show the details of any multiple stage cement- ing and the location of the cementing tool. Item 27: Method of Operation' Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water In- jection, Gas Injection, Shut-in, Other-explain. Item 28: If no cores taken, indicate "none". FEB 2 5 1996 Form 10-407 ~aska Oil & Ga.,.; Cons. Commission Anchorage SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: Accept Date: 13-36 RigName: Nabors 18E AFE: I 1/22/95 Spud Date: I 1/22/95 Release Date: 4J0304 12/24/95 Nov 23 1995 (2) Rig moved 100 %. Rigged up BOP stack. Fill pits with Water based mud. Made up BHA no. 1 . Drilled to 510 ft. Nov 24 1995 (3) Drilled to 965 ft. Pulled out of hole to 300 ft. Drilled to 1805 ft. Pulled out of hole to 900 ft. Drilled to 2059 ft. Nov 25 1995 (4) Drilled to 2825 ft. Pulled out of hole to 1763 ft. Drilled to 3451 ft. Circulated at 3451 ft. Pulled out of hole to 754 ft. Circulated at 3451 ft. Pulled out of hole to 1951 ft. Circulat- ed at 3451 ft. Nov 26 1995 (5) Pulled out of hole to 925 ft. Pulled BHA. Rigged up Casing stabbing board. Ran Casing to 3431 ft (10.75 in OD). Circulated at 3431 ft. Mixed and pumped slurry - 497 bbl. Mixed and pumped slurry - 19 bbl. Rigged down Divertor. Rigged up BOP stack. Tested All functions. Nov 27 1995 (6) Tested BOP stack. Installed Wear bushing. Made up BHA no. 2 . R.I.H. to 3349 ft. Tested Casing - Via string. Drilled in- stalled equipment - Float collar. Circulated at 3461 ft. Drilled to 4474 ft. Pulled out of hole to 3431 ft. Drilled to 4568 ft. Nov 28 1995 (7) Drilled to 5500 ft. Pulled out of hole to 4432 ft. Drilled to 6148 ft. Circulated at 6148 ft. _,~d of Well Sumnmary for: ,..-36 Nov 29 1995 (8) Circulated at 6148 ft. Took Gyro survey at 6148 ft. Circulated at 6148 ft. Pulled out of hole to 208 ft. Pulled BHA. In- stalled Wear bushing. Made up BHA no. 3. R.I.H. to 6106 ft. Reamed to 6148 ft. Drilled to 6857 ft. Nov 30 1995 (9) Drilled to 7142 ft. Pulled out of hole to 6106 ft. Drilled to 7298 ft. Repaired Mud pump fluid end. Drilled to 7990 ft. Dec I 1995 (10) Drilled to 8145 ft. Circulated at 8145 ft. Pulled out of hole to 667 ft. Pulled BHA. Retrieved Bore protector. Made up BHA no. 4. R.I.H. to 8087 ft. Washed to 8145 ft. Drilled to 8725 ft. Dec 2 1995 (11) Drilled to 9166 ft. Pulled out of hole to 8087 ft. R.I.H. to 9124 ft. Drilled to 9710 ft. Serviced Mud pumps. Drilled to 10325 ft. Circulated at 10325 ft. Dec 3 1995 (12) Circulated at 10325 ft. Pulled out of hole to 682 ft. Pulled BHA. Made up BHA no. 5. Serviced Block line. R.I.H. to 10271 ft. Drilled to 10700 ft. Dec 4 1995 (13) Drilled to 10790 ft. Circulated at 10790 ft. Pulled out of hole to 667 ft. Pulled BHA. Tested BOP stack. Made up BHA no. 6. R.I.H. to 10770 ft. Drilled to 10852 ft. Dec 5 1995 (14) Drilled to 11490 ft. Dec 6 1995 (15) Drilled to 11533 ft. Pulled out of hole to 10600 ft. R.I.H. to 11523 ft. Drilled to 11813 ft. Circulated at 11813 ft. Pulled out of hole to 664 ft. Pulled BHA. Made up BHA no. 7. R.I.H. to 11800 ft. Page 2 _nd of Well Sumnmary for: ,.,-36 Dec 7 1995 (16) Drilled to 11919 ft. Circulated at 11919 ft. Pulled out of hole to 664 ft. Pulled BHA. Retrieved Bore protector. Made up BHA no. 8. R.I.H. to 3400 ft. Serviced Block line. R.I.H. to 11794 ft. Logged hole with LWD: Formation evaluation (FE) from 11730 ft to 11760 ft. Drilled to 12000 ft. Dec 8 1995 (17) Drilled to 12101 ft. Serviced Suction valve. Drilled to 12380 ft. Circulated at 12380 ft. Pulled out of hole to 10600 ft. R.I.H. to 12360 ft. Circulated at 12380 ft. Dec 9 1995 (18) Circulated at 12380 ft. Laid down 11696 ft of 5 in OD drill pipe. Pulled BHA. Retrieved Bore protector. Ran Casing to 3405 ft (7.625 in OD). Circulated at 3405 ft. Ran Casing to 8500 ft (7.625 in OD). Circulated at 8500 ft. Dec 10 1995 (19) Circulated at 8500 ft. Ran Casing to 12367 ft (7.625 in OD). Circulated at 12367 ft. Mixed and pumped slurry- 54 bbl. Dis- placed slurry- 564 bbl. Rigged down Casing handling equipment. Installed Seal assembly. Rigged up Kelly. Tested BOP stack. Made up BHA no. 9. R.I.H. to 4800 ft. Dec 11 1995 (20) R.I.H. to 12186 ft. Washed to 12245 ft. Drilled cement to 12382 ft. Tested Casing - Via string. Circulated at 12380 ft. Held drill (Kick (well kill)). Drilled cement to 12380 ft. Circulat- ed at 12380 ft. Pulled out of hole to 196 ft. Pulled BHA. Made up BHA no. 10. R.I.H. to 12360 ft. Drilled to 12390 ft. Per- formed formation integrity test. Dec 12 1995 (21) Drilled to 12578 ft. Circulated at 12578 ft. Pulled out of hole to 200 ft. Pulled BHA. Made up BHA no. 11. R.I.H. to 3400 ft. Serviced Block line. Dec 13 1995 (22) R.I.H. to 12570 ft. Drilled to 12799 ft. Page _nd of Well Sumnmary for: Dec 14 1995 (23) Drilled to 13171 ft. Circulated at 13171 ft. Pulled out of hole to 232 ft. Pulled BHA. Made up BHA no. 12. R.I.H. to 7000 ft. Dec 15 1995 (24) R.I.H. to 13171 ft. Drilled to 13758 ft. Circulated at 13758 ft. Laid down 150 ft of 3.5 in OD drill pipe. Dec 16 1995 (25) Laid down 1200 ft of 3.5 in OD drill pipe. Pulled out of hole to 232 ft. Pulled BHA. Made up BHA no. 13. R.I.H. to 12367 ft. Reamed to 13758 ft. Circulated at 13758 ft. Dec 17 1995 (26) Pulled out of hole to 12368 ft. R.I.H. to 13758 ft. Circulated at 13758 ft. Pulled out of hole to 141 ft. Pulled BHA. Removed Wear bushing. Installed Wear bushing. Rigged up Casing handling equipment. Ran Casing to 1530 ft (5.5 in OD). Ran Drillpipe in stands to 12368 ft. Circulated at 12368 ft. Ran Drillpipe in stands to 13758 ft. Circulated at 13758 ft. Dec 18 1995 (27) Circulated at 13758 ft. Held safety meeting. Pumped spacers - volume 90 bbl. Mixed and pumped slurry- 60 bbl. Retrieved downhole equipment- Rotating Liner hanger. Reverse circulated at 12228 ft. Cleared Circulating head. Circulated at 12228 ft. Pulled Drillpipe in stands to 600 ft. Laid down HWDP to 600 ft. Tested BOP stack. Made up BHA no. 14. R.I.H. to 4000 ft. Ser- viced Block line. R.I.H. to 6000 ft. Dec 19 1995 (28) R.I.H. to 12229 ft. Drilled cement to 12308 ft. Circulated at 12308 ft. Drilled to 12368 ft. R.I.H. to 13677 ft. Circulated at 13677 ft. Circulated at 13677 ft. Circulated at 13677 ft. Dec 20' 1995 (29) Circulated at 13677 ft. Tested Casing. Circulated at 13677 ft. Dec 21 1995 (30) Circulated at 13677 ft. Fill pits with Seawater. FEB 2_3 1996 Page 4 Gas Cons. C,~):mmissi.~fi _nd of Well Sumnmary for: ,¢-36 Dec 22 1995 (31) Circulated at 13677 ft. Pulled out of hole to 1509 ft. Pulled BHA. Conduct braided cable operations- 5/16 size cable. Ran Drillpipe in stands to 1594 ft. Dec 23 1995 (32) Ran Drillpipe in stands to 13550 ft. Perforated from 12850 ft to 13550 ft. Reverse circulated at 13550 ft. Laid down Drillpipe to 13550 ft. Worked on BOP - Top ram. Dec 24 1995 (33) Worked on BOP - Top ram. Ran Tubing to 12231 ft (4.5 in OD). Circulated at 12331 ft. Set packer at 12166 ft with 4000 psi. Rigged down BOP stack. Dec 25 1995 (34) Rigged down BOP stack. Installed Xmas tree. Freeze protect well - 83 bbl of Diesel. Serviced Fluid system. FEB 2 5 199G Ar~¢horage Page 5 gyro/data PRUDHOE BAY DRILLING DRILL SITE 13 WELL NO. 13-36 PRUDHOE BAY FIELD, E.O.A., ALASKA Gyro Multishot Survey Of 5" Drillpipe Survey date · 28 November 1995 ~ 1~//~ --~ APl # 500292261300 Job number' AK1195G309 FEB 2 3 199G .Aiaska ~1 & Gas Cons. Commission Anaho;'age SR309DOC Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 December 8, 1995 B.P. Exploration Petrotechnical Data Center, MB 3-3 Sharmaine Copeland P.O. Box 196612 Anchorage, AK 99519-6612 Re; DRILLSITE 13, WELL #12-36, PRUDEHOE BAY FIELD E.O.A. Enclosed please find one (1) original (3) copy and (1) disk of the completed survey of Well #12-36 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely Robe~ J. Shou~~ Operations Manager RS/fec Serving the Worldwide Energy Industry with Precision Survey Instrumentation CONTENTS JOB NUMBER :AK1195G309 DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND cHRONOLOGICAL REPORT SR309DOC gyro/data 1. DISCUSSION, SURVEY CERTIFICATION SHEET SR309DOC gyro/data DISCUSSION JOB NUMBER · ^K1195G309 Tool 080 was run in Drill Site 13 on ATLAS 5/16" Wireline inside 5 inch drillpipe. The survey was run without problems. SR309DOC gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER ' AK1195G309 The data for this survey and the calculations for this survey were obtained and performed by me according to standards arid procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the well site. Checked by :- ROB SHOUP OPERATIONS ENGINEER SR309DOC gyro/data 2. SURVEY DETAILS SR309DOC gyro/data SURVEY DETAILS JOB NUMBER: AK1195G309 CLIENT: PRUDHOE BAY DRILLING RIG: DRILL SITE 13 LOCATION: PRUDHOE BAY FIELD WELL: 13-36 LATITUDE: 70.2180 N LONGITUDE: 149 W SURVEY DATE: 28-November 1995 SURVEY TYPE : MULTISHOT IN 5 drillpipe DEPTH REFERENCE: MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 74.2 feet 5850' SURVEY TIED ONTO: N/A SURVEYINTERVAL: 100' from 0 feet to 1600 feet. 50' from 1650 feet to 3000 feet. 100' from 3000 feet to 5200 feet. 30' from 5250 feet to 5850 feet. UTM CO-ORDINATES: TARGET DIRECTION: 122.530 GRID CORRECTION: CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: STODDARD SR309DOC gyro/data 3. OUTRUN SURVEY LISTING SR309DOC A Gyr oda t a D i r e c t i ona i Survey for PRUDHOE BAY DRILLING WELL: DRILLSITE 13, 13-36, 5.5" D.P. Location: NABORS 18-E, E.O.A. PRUDHOE BAY, API#500292261300 Job Number: AKl195G309 Run Date: 28-Nov-95 07:40:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.218000 deg. N Sub-sea Correction from Vertical Reference: 74.2 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 122.530 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyr oda t a D i re c t i o n a PRUDHOE BAY DRILLING WELL: DRILLSITE 13, 13-36, 5.5" D.P. Location: NABORS 18-E, E.O.A. PRUDHOE BAY, API#500292261300 Job Number: AKl195G309 1 Survey MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA SECTION DEPTH feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. 0.0 0.00' 0.00 0.0 0.0 -74.2 0.00 0.0 0.0 0 - 5850 FT. GYRODATA MULTISHOT SURVEY RUN INSIDE DRILL PIPE ALL DEPTHS REFERENCED TO DRILL SITE 13 R.K.B. Page 1 HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .08 163.74 100.0 .1 25.8 .08 200.0 .04 193.34 200.0 .1 125.8 .05 300.0 .07 185.99 300.0 .2 225.8 .03 400.0 .17 146.78 400.0 .3 325.8 .12 500.0 .09 145.57 500.0 .5 425.8 .08 600.0 .08 179.16 600.0 .6 525.8 .05 700.0 .03 159.10 700.0 .7 625.8 .05 800.0 .11 155.23 800.0 .8 725.8 .08 900.0 .01 194.16 900.0 .9 825.8 .10 1000.0 .26 172.28 1000.0 1.0 925.8 .25 1100.0 .59 213.24 1100.0 1.2 1025.8 .43 1200.0 1.70 221.79 1200.0 .9 1125.8 1.12 1300.0 2.26 223.90 1299~9 .3 1225.7 .57 1400.0 3.12 228.32 1399.8 -.8 1325.6 .88 1500.0 4.10 220.04 1499.6 -2.0 1425.4 1.12 1600.0 5.79 219.61 1599.2 -3.1 1525.0 1.69 1650.0 5.10 220.21 1649.0 -3.7 1574.8 1.38 1700.0 6.37 221.66 1698.8 -4.5 1624.6 2.56 1750.0 7.18 225.05 1748.4 -5.6 1674.2 1.80 1800.0 8.12 226.25 1798.0 -7.1 1723.8 1.92 .1 .2 .3 .4 .7 .8 .9 1.0 1.1 1.4 2.0 3.7 6.9 11.5 17.8 26.4 31.1 36.1 42.0 48.6 163.7 169.5 176.4 168.3 160.9 161.0 162.3 161.5 161.3 163 .3 175.8 197.8 210.0 216.6 219.1 219.3 219.4 219.6 220.2 220.9 .06 S .16 S .25 S .44 S .63 S .76 S .86 S .98 S 1.08 S 1.31 S 1.96 S 3.49 S 6.02 S 9.24 S 13.79 S 20.42 S 24.06 S 27.83 S 32.11 S 36.76 S .02 E .03 E .02 E .09 E .22 E .26 E .27 E .33 E .36 E .39 E 1.12 W 3.48 W 6.87 W 11.20 W 16.72 W 19.77 W 23.04 W 27.10 W 31.86 W A Gyroda t a D i r e c t i o na i Survey PRUDHOE BAY DRILLING WELL: DRILLSITE 13, 13-36, 5.5" D.P. Location: NABORS 18-E, E.O.A. PRUDHOE BAY, Job Number: AKl195G309 API#500292261300 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet' VERTICAL SECTION feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. HORIZONTAL COORDINATES feet 1850.0 9.52 227.85 1847.4 1900.0 10.96 228.30 1896.6 1950.0 12.81 228.72 1945.5 2000.0 14.45 227~00 1994.1 2050.0 16o09 224.63 2042.3 -9 -11 -14 -17 -20 .0 .4 .3 .4 .4 1773.2 2.83 56.3 221.8 1822.4 2.89 65.1 222.6 1871.3 3.72 75.4 223.4 1919.9 3.37 87.1 224.0 1968.1 3.50 100.3 224.2 41.97 S 37.48 W 47.91 S 44.0f ) 54.73 S 51.81 ~ 62.64 S 60.54 W 71.83 S 69~97 W 2100.0 18.57 220.79 2090.0 2150.0 20.40 218.23 2137.2 2200.0 21.89 215.61 2183.8 2250.0 22.27 214.34 2230.1 2300.0 23.19 211.42 2276.3 -23 -25 -26 -27 -27 .0 .0 .3 .1 .3 2015.8 5.47 115.2 224.0 82.79 S 80.04 W 2063.0 4.03 131.8 223.5 95.67 S 90.64 W 2109.6 3.53 149.7 222.7 110.09 S 101.46 W 2155.9 1.23 168.4 221.8 125.49 S 112.23 W 2202.1 2.90 187.5 220.9 141.72 S 122.71 W 2350.0 23.77 210.21 2322.1 2400.0 24.10 208.84 2367.8 2450.0 24.65 208.09 2413.4 2500.0 24.92 207.82 2458.8 2550.0 25.74 206.84 2504.0 -26 -25 -24 -22 -20 .7 .6 .1 .5 .5 2247.9 2293 .6 2339.2 2384.6 2429.8 1.51 207.1 219.9 1.30 227.1 219.0 1.25 247.4 218.1 .59 268.1 217.3 1.85 289.1 216.6 158.82 S 132.91 W 176.47 S 142.91 W 194.62 S 152.74 W 213.13 S 162.57 W 232.13 S 172.38 W 2600.0 26.79 204.59 2548.8 2650.0 27.60 203.70 2593.3 2700 . 0 29 . 62 196 . 24 2637 . 2 2750.0 31.43 190.33 2680.3 2800.0 32.65 186.20 2722.6 -17 -14 -9 -- 10 .9 .5 .3 .9 .0 2474.6 2.89 310.9 215.8 2519.1 1.80 333.3 215.0 2563.0 8.20 356.4 214.0 2606.1 7.01 380.2 212.7 2648.4 5.01 404.5 211.1 252.07 S 181.9[ ) 272.92 S 191.32 W 295.40 S 199.44 W 320.10 S 205.23 W 346.33 S 209.02 W 2850.0 33.18 182.92 2764.6 2900.0 33.49 182.55 2806.4 2950.0 34.28 i80.63 2847.9 3000.0 35.18 178.23 2889.0 3100.0 36.94 176.00 2969.8 22 36 50 66 100 .8 .4 .7 .3 .4 2690.4 3.72 429.0 209.5 2732.2 .74 453.7 207.9 2773.7 2.66 478.8 206.4 2814.8 3.28 504.4 205.0 2895.6 2.19 557.1 202.1 373.41 S 211.18 W 400.85 S 212.49 W 428.71 S 213.26 W 457.19 S 212.97 W 515.97 S 209.98 W A Gyroda t a D i r e c t i o n a i Survey PRUDHOE BAY DRILLING WELL: DRILLSITE 13, 13-36, 5.5" D.P. Location: NABORS 18-E, E.O.A. PRUDHOE BAY, Job Number: AKl195G309 API#500292261300 Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL COORDINATES feet 3200.0 39.34 169.73 3048 3300.0 40.11 169.43 3125 3400.0 40.92 169.73 3201 3500.0 41.88 170.63 3276 3600.0 42.58 170.58 3350 .5 .4 .4 .4 .5 139.9 183.4 227.7 272.2 317.1 2974.3 3051.2 3127.2 3202.2 3276.3 4.56 611.6 199.3 .79 667.8 196.6 .84 726.3 194.3 1.13 787.1. 192.3 .70 850.0 190.6 577.17 S 202.23 W 640.03 S 190.67 703.92 S 178.92 769.09 S 167.64 W 835.39 S 156.67 W 3700.0 46.48 171.45 3421 3800.0 47.16 171.80 3490 3900.0 46.81 173.41 3558 4000.0 49.01 175.04 3625 4100.0 48.74 175.12 3691 .8 .2 .4 .4 .2 363.6 411.3 458.3 504.2 550.1 3347.6 3416.0 3484.2 3551.2 3617.0 3.95 916.3 189.2 .73 986.1 187.9 1.23 1056.8 186.8 2.52 1129.3 186.0 .28 1203.4 185.3 904.65 S 145.74 W 976.79 S 135.11 W 1049.30 S 125.70 W 1123.12 S 118.25 W 1198.17 S 111.79 W 4200.0 48.52 174.34 3757 4300.0 48.73 174.41 3823 4400.0 48.46 174.53 3889 4500.0 49.90 175.35 3954 4600.0 49.87 177.69 4019 .3 .4 .5 .9 .3 596.0 642.4 688.7 734.8 779.8 3683.1 3749.2 3815.3 3880.7 3945.1 .63 1277.2 184.7 .22 1351.1 184.1 · 29 1425.1 183.6 1.57 1500.0 183.2 1.79 1575.9 182.9 1272.90 S 104.90 W 1347.58 S 97.54 W 1422.24 S 90.31 W 1497.62 S 83.64 W 1573.95 S 78.99 W 4700.0 49.64 175.35 4083 4800.0 50.31 175.04 4148 4900.0 50.61 175.15 4211 5000.0 50.88 177.12 4275 5100.0 50.36 179.99 4338 .9 .3 .9 .2 .6 824.6 871.1 918.0 963.9 1007.1 4009.7 4074.1 4137.7 4201.0 4264.4 1.80 1651.8 182.6 .72 1727.8 182.3 .31 1804.3 181.9 1.55 1881.4 181.7 2.28 1958.5 181.6 1650.13 S 74.37 1726.44 S 67.96 W 1803.28 S 61.36 W 1880.53 S 56.14 W 1957.78 S 54.18 W 5200.0 51.09 178.23 4402. 5250.0 51.88 178.80 4433. 5280.0 51.94 178.44 4451. 5310.0 51.84 178.58 4470. 5340.0 51.34 178.87 4488. 1049.7 1071.6 1084.8 1098.0 1111.1 4327.8 4358.9 4377.4 4395.9 4414.6 1.55 2035.9 181.5 1.81 2074.9 181.4 .97 2098.5 181.4 · 51 2122.1 181.4 1.81 2145.6 181.3 2035.18 S 52.97 W 2074.28 S 51.96 W 2097.89 S 51.39 W 2121.48 S 50.78 W 2144.99 S 50.25 W A Gyro da t a D i r e c t i on a i Survey PRUDHOE BAY DRILLING WELL: DRILLSITE 13, 13-36, 5.5" D.P. Location: NABORS 18-E, E.O.A. PRUDHOE BAY, Job Number: AKl195G309 API~500292261300 MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SUBSEA SECTION DEPTH feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. 5370.0 51.22 179.43 4507.5 5400.0 51.18 179.68 4526.3 5430.0 49.71 179.97 4545.4 5460.0 49o15 179.90 4564.9 5490.0 49.05 180.38 4584.6 1124.0 4433'.3 1136.7 4452.1 1149.2 4471.2 1161.5 4490.7 1173.6 4510.4 1.51 2169.0 181.3 .67 2192.3 181.3 4.95 2215.5 181.3 1.89 2238.2 181.3 1.24 2260.9 181.3 5520.0 48.07 180.64 4604.4 5550.0 48.21 180.80 4624.4 5580.0 48.51 181.11 4644.4 5610.0 48.84 180.54 4664.2 5640.0 49.37 181.20 4683.8 1185.5 4530.2 3.31 2283.4 181.3 1197.3 4550.2 .60 2305.7 181.2 1209.0 4570.2 1.26 2328.2 181.2 1220.9 4590.0 .1.81 2350.7 181.2 1232.8 4609.6 2.42 2373.4 181.2 5670.0 49.63 181.25 4703.3 5700.0 49.74 180.71 4722.7 5730.0 49.83 180.87 4742.1 5760.0 49.96 180.91 4761.4 5790.0 49.02 181.38 4780.9 1244.6 4629.1 .89 2396.2 181.2 1256.6 4648.5 1.44 2419.0 181.2 1268.7 4667.9 .52 2442.0 181.2 1280.7 4687.2 .46 2464.9 181.2 1292.6 4706.7 3.37 2487.7 181.2 5820.0 47.69 181.86 4800.8 5850.0 47.18 181.71 4821.1 1304.1 4726.6 4.57 2510.1 181.2 1315.4 4746.9 1.73 2532.2 181.2 Page 4 HORIZONTAL COORDINATES feet 2168.39 S 49.90 2191.77 S 49.7~ 2214.90 S 49.65 2237.69 S 49.63 2260.36 S 49.68 2282.85 S 49.88 W 2305.19 S 50.16 W 2327.61 S 50.54 W 2350.14 S 50.86 W 2372.81 S 51.21 W 2395.62 S 51.70 W 2418.49 S 52.09 W 2441.39 S 52.40 W 2464.34 S 52.76 W 2487.14 S 53.21 W 2509.55 S 53.85 2531.63 S 54.54 W Final Station Closure: Distance: 2532.22 ft Az: 181.23 deg. A Gyr oda t a D i r e c t i ona i Survey for PRUDHOE BAY DRILLING WELL: DRILLSITE 13, 13-36, 5.5" D.P. Location: NABORS 18-E, PRUDHOE BAY FIELD, E.O.A. Job Number: AKl195G309SS Run Date: 28-Nov-95 07:40:00 Surveyor: TOM STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.218000 deg. N Sub-sea Correction from Vertical Reference: 74.2 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 122.530 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference A Gyroda t a D i r e c t i o n a i Survey PRUDHOE BAY DRILLING WELL: DRILLSITE 13, 13-36, 5.5" D.P. Location: NABORS 18-E, PRUDHOE BAY FIELD, Job Number: AKl195G309SS E .O.A. SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DOGLEG DEPTH DEPTH SECTION SEVERITY feet deg. deg. feet feet deg./ 100 ft. CLOSURE ~ DIST. AZIMUTH feet deg. -74.2 0.00 0.00 0.0 0.0 0.00 0.0 0.0 0 - 5850 FT. GYRODATA MULTISHOT SURVEY RUN INSIDE DRILL PIPE ALL DEPTHS REFERENCED TO DRILL SITE 13 R.K.B. Page HORIZONTAL COORDINATES feet 0.00 N 0.00 E 100.0 .05 185.70 174.2 .1 .06 200.0 .06 187.89 274.2 .1 .03 300.0 .14 156.89 374.2 .3 .10 400.0 .11 145.88 474.2 .5 .09 500.0 .08 170.49 574.2 .6 .06 600.0 .05 164.28 674.2 .7 .05 700.0 .09 156.23 774.2 .8 .07 800.0 .04 184.12 874.2 .9 .10 900.0 .20 177.93 974.2 1.0 .21 1000.0 .50 202.67 1074.2 1.1 .38 1100. 0 1.41 219.59 1174.2 1.0 .94 1200 . 0 2 . 11 223 . 36 1274 . 2 . 5 . 71 1300 . 0 2 . 90 227 . 19 1374 . 2 - . 5 . 80 1400 . 0 3 . 85 222 . 15 1474 . 2 -1 . 7 1 . 06 1500 . 0 5 . 37 219 . 72 1574 . 2 -2 . 8 1 . 54 1600.0 5.75 220.94 1674.2 -4.1 1.98 1700.0 7.67 225.68 1774.2 -6.4 1.86 1800.0 10.30 228.09 1874.2 -10.3 2.86 1900.0 13.78 227.71 1974.2 -16.1 3.51 2000.0 17.75 222.07 2074.2 -22.1 4.82 .2 168.1 .3 174.7 .4 170.4 .7 162.8 .8 161.0 .9 162.0 1.0 161.7 1.1 161.3 1.4 162.8 2.0 172.6 3.7 192.2 6.9 206.9 11.5 214.9 17.8 218.5 26.4 219.3 36.1 219.5 48.6 220.6 65.1 222.2 87.1 223.8 115.2 224.1 .14 S .03 E .23 S .02 E .39 S .07 E .58 S .18 E .73 S .25 E .83 S .27 E .95 S .31 E 1.05 S .35 E 1.25 S .39 E 1.79 S .21 E 3.10 S .87 %4 5.37 S 2.87 W 8.41 S 6. O0 W 12.63 S 10.10 W 18.75 S 15.34 W 25.97 S 21.43 W 34.53 S 29.58 W 45.21 S 41.09 W 59.41 S 56.97 W 79.15 S 76.70 W A Gyro da t a D i r e c t i o n a i Survey PRUDHOE BAY DRILLING WELL: DRILLSITE 13, 13-36, 5.5" D.P. Location: NABORS 18-E, PRUDHOE BAY FIELD, Job Number: AKl195G309SS E .O.A. Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet DOGLEG SEVERITY deg. / 100 ft. CLOSURE ~ DIST. AZIMUTH feet deg. HORIZONTAL COORDINATES feet 2100.0 21.58 216.15 2174.2 2200.0 23.15 211.55 2274.2 2300.0 24.18 208.73 2374.2 2400.0 25.20 207.49 2474.2 2500.0 27.25 204.08 2574.2 -26 -27 -25 -21 -16 .1 .2 .4 .8 .0 3.63 2.83 1.29 1.02 2.27 149.7 222~8 187.5 220.9 247.4 218.9 289ol 217.1 333.3 215.4 107.12 S 99.23 W 140.99 S 122.24 W 179.01 S 144.28 W 219.62 S 165.92 W 263.99 S 187.32 W 2600.0 31.18 191.16 2674.2 2700.0 33.25 182.83 2774.2 2800.0 34.86 179.09 2874.2 2900.0 37.08 175.65 2974.2 3000.0 39.60 169.63 3074.2 -2 25 60 102 154 .1 .9 .7 .6 .4 .18 .04 .06 .32 .30 380.2 212.9 453.7 209.1 504.4 205.5 611.6 202.0 667.8 198.4 316.63 S 204.42 W 379.71 S 211.48 W 446.94 S 213.07 W 519.37 S 209.55 W 598.17 S 198.36 W 3100 . 0 40 . 63 169 . 62 3174 . 2 3200 . 0 41.85 170 . 60 3274 . 2 3300 . 0 43 . 88 170 . 87 3374 . 2 3400.0 47. O0 171.72 3474.2 3500.0 47.33 173.79 3574.2 211 270 332 400 469 .8 .9 .6 .2 .1 .82 1.12 1.78 1.48 1.53 726.3 195.1 787.1 192.4 916.3 190.1 986.1 188.2 1129.3 186.6 681.03 S 183.13 W 767.14 S 167.98 W 858.43 S 153.03 W 959.93 S 137.60 W 1066.68 S 123.95 W 3600.0 48.81 175.10 3674.2 3700.0 48.57 174.35 3774.2 3800.0 48.52 174.50 3874.2 3900.0 49.90 176.05 3974.2 4000.0 49.67 175.71 4074.2 538 607 677 748 817 .2 .9 .9 .3 .9 .86 .52 .27 1.64 1.80 1203.4 185.5 1351.1 184.6 1425.1 183 . 8 1575.9 183.1 1651.8 182.6 1178.76 S 113.46 W 1291.99 S 103.02 W 1404.93 S 91.99 W 1520.48 S 82.24 W 1638.64 S 75.06 W 4100.0 50.44 175.09 4174.2 4200.0 50.88 177.09 4274.2 4300.0 50.77 179.00 4374.2 4400.0 51.73 178.64 4474.2 4500.0 49.10 180.13 4574.2 890.2 963.2 1031.0 1100.9 1167.2 .55 1.53 1.87 .80 1.59 1804.3 182.1 1881.4 181.7 2035.9 181.5 2145.6 181.4 2260.9 181.3 1757.76 S 65.27 W 1879.32 S 56.22 W 2001.25 S 53.50 W 2126.64 S 50.66 W 2248.39 S 49.65 W A Gyro da t a D i r e c t i o na i Survey PRUDHOE BAY DRILLING WELL: DRILLSITE 13, 13-36, 5.5" D.P. Location: NABORS 18-E, PRUDHOE BAY FIELD, E.O.A. Job Number: AKl195G309SS Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet DOGLEG CLOSURE ', SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. HORIZONTAL COORDINATES feet 4600.0 49.11 180.88 4674.2 1226.9 4700.0 49.34 181.22 4774.2 1288.5 4746.9 47.18 181.71 4821.1 1315.4 2.12 2.37 1.73 2373.4 181.2 2487.7 181.2 2532.2 181.2 2361.69'S 2479.29 S 2531.63 S 51.04 W 53.06 ~ ] 54.54 W Final Station Closure: Distance: 2532.22 ft Az: 181.23 deg. gyro/data 4. QUALITY CONTROL SR309DOC Quality Control Comparisons PRUDHOE BAY DRILLING DRILLSITE 13, WELL NO. 13-36 PRUDHOE BAY FIELD, E.O.A., ALASKA Job Number : AKl195G309 / AKl195G309 INRUN/OUTRUN Comparison INRUN OUTRUN INRUN OUTRUN Depth Inc Inc Delta Az Az 1000.0 .28 .26 .024 172.10 172.28 2000.0 14.39 14.45 -.060 226.56 227.00 3000.0 35.06 35.18 -.126 177.66 178.23 4000.0 48.79 49.01 -.219 174.34 175.04 5850.0 47.18 47.18 .000 181.98 181.71 For Inclinations Greater than 1 degrees: Average Inclination Difference = -.1011 deg. Average Azimuth Difference = -.3588 deg. Delta -.182 -.442 -.564 -.697 .268 gyro/data QUALITY CONTROL REPORT JOB NUMBER: AK1195G309 TOOL NUMBER: O8O MAXIMUM GYRO TEMPERATURE: 73.06 C MAXIMUM AMBIENT TEMPERATURE: 44.1 C MAXIMUM INCLINATION: AVERAGE AZIMUTH: 51.94 deg 182.1017 WIRELINE REZERO VALUE: 0 Feet REZERO ERROR/K: .003 CALIBRATION USED FOR FIELD SURVEY: 1243 CALIBRATION USED FOR FINAL SURVEY: 1243 PRE JOB MASS BALANCE OFFSET CHECK: -.25 POST JOB MASS BALANCE OFFSET CHECK~ · CONDITION OF SHOCK WATCHES -.01 USED 00 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY 5850.0 47.18 181.77 4821.1 2530.10S 52.26W FINAL SURVEY 5850.0 47.18 181.77 4821.1 2530.10S 52.26W SR309DOC gyro/data FUNCTION TEST JOB NUMBER ' AK1195G309 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 3800 47.16 47.16 47.16 47.16 47.16 AZIMUTH M.D. ft 1 2 3 4 5 3800 171.55 171.59 171.56 171.66 171.70 SR309DOC gyro/data 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR309DOC gyro/da a EQUIPMENT REPORT JOB NUMBER: AK1195G309 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 080 GYRO SECTION A0080 DATA SECTION C0031 POWER SECTION C0006 COMPUTER POWER SUPPLY PRINTER INTERFACE A0213 A0085 A0029 A0035 BACKUP TOOL No. 713 GYRO SECTION A0035 DATA SECTION C0058 POWER SECTION C0016 COMPUTER POWER SUPPLY PRINTER INTERFACE A0153 A0055' A0079 A0071 WIRELINE COMPANY: ATLAS WIRELINE CABLE SIZE: 5/16" RUNNING GEAR 2 1/2" SYSTEM TOTAL LENGTH OF TOOL: 18 feet MAXIMUM O.D.: 2.5 INCHES TOTAL WEIGHT OF TOOL: 220Lbs SR309DOC gyro/data CHRONOLOGICAL REPORT JOB NUMBER: AK1195G309 11/26/95 FINISH JOB AK1195G308 STANDING BY FOR JOB AK1195G309 11/28/95 0530: 0630 0715 O74O 0830 1045 1145 1230 LoAD OUT ARRIVED IN LOCATION PICK UP TOOL START RUN AT 5850' SURVEY OUT LAY DOWN TOOL BREAKDOWN TOOL RETURN TO ATLAS PROCESS SURVEY, POST RUN CHECK-OK. RETURN TO RIG, PRESENTED SURVEY SR309DOC SPi ~HARED SERVICES DRILLING PBU/13-36 500292261300 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/20/~i~ka0i{&6a$00n$.Oommissi0~OPERATOR: ARCO ALASKA INC Anchorage TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST C .Y-SUN DRILLING SERVICES /I.;'~ ~ PAGE 1 i ]-" ,/1'~--~ ,, ANCHORAGE AI.~SKA , ! ,: . ,t MWD SURVEY '.,DEC 2 9 i9-95 JOB NUMBER: AK-Mr -50116 KELLY BUSHZNG ELEV. = 75.10 FT. VERT. SECT. .00 .00 -75.10 0 0 N .00 E .00 .00N .00E 147.76 147.76 72.66 0 21 S 28.30 W .24 .40S .21W 241.85 241.85 166.75 0 13 S 46.00 W .17 .78S .48W 333.24 333.24 258.14 0 12 S 32.90 W .06 1.03S .69W 425.01 425.01 349.91 0 17 N 78.30 E .49 1.12S .55W .00 .03 .01 - .03 .14 517.07 517.07 441.97 0 9 N 1.50 W .33 .95S .33W 608.46 608.45 533.35 0 16 S 66.20 E .40 .92S .13W 700.67 700.66 625.56 0 10 N 81.40 E .17 .99S .22E 796.75 796.74 721.64 0 7 N 19.50 E .17 .87S .41E 890.31 890.30 815.20 0 18 S 83.90 E .33 .79S .70E .24 .39 .72 .81 1.01 984.65 984.64 909.54 0 7 S 3.20 W .35 .93S .94E 1078.64 1078.63 1003.53 0 31 S 48.70 W .48 1.32S .61E 1171.55 1171.52 1096.42 1 33 S 51.40 W 1.11 2.39S .70W 1265.94 1265.84 1190.74 2 35 S 52.40 W 1.10 4.50S 3.40W 1361.70 1361.49 1286.39 2 58 S 49.50 W .42 7.44S 7.01W 1.29 1.22 .70 - .45 -1.91 1452.97 1452.59 1377.49 3 54 S 44.90 W 1.05 11.18S ll.01W 1547.34 1546.69 1471.59 4 42 S 44.10 W .86 16.24S 15.97W 1638.20 1637.17 1562.07 5 43 S 40.40 W 1.18 22.37S 21.51W 1731.67 1730.04 1654.94 7 13 S 41.90 W 1.60 30.30S 28.45W 1822.61 1820.07 1744.97 8 52 S 49.40 W 2.16 39.12S 37.60W -3.27 -4.73 -6.10 -7.70 -10.67 1914.64 1910.57 1835.47 11 58 S 48.10 W 3.38 50.12S 50.10W 2007.34 2000.73 1925.63 14 52 S 45.50 W 3.19 64.89S 65.76W 2100.33 2089.69 2014.59 18 55 S 39.80 W 4.69 84.85S 83.93W 2195.08 2178.50 2103.40 21 52 S 35.40 W 3.51 111.05S 103.99W 2285.56 2262.09 2186.99 23 6 S 31.50 W 2.14 139.92S 123.03W -15.29 -20.55 -25.14 -27.96 -28.49 2380.97 2349.39 2274.29 24 29 S 28.10 W 2.05 173.32S 142.12W 2474.91 2434.74 2359.64 24 53 S 27.00 W .65 208.11S 160.27W 2567.29 2517.99 2442.89 26 28 S 25.10 W 1.93 244.07S 177.83W 2661.09 2601.41 2526.31 27 57 S 20.40 W 2.79 283.62S 194.36W 2755.55 2683.55 2608.45 31 21 S 9.20 W 6.87 328.69S 206.03W -26.63 -23.22 -18.68 -11.36 3.05 2846.96 2760.86 2685.76 33 11 S 2.00 W 4.65 377.20S 210.70W 2939.96 2838.26 2763.:16 34 8 S .60 E 1.86 428.73S 211.32W 3034.24 2915.33 2840.23 36 12 S 4.70 E 3.32 482.94S 208.76W 3127.96 2990.23 2915.13 37 40 S 7.10 E 2.20 538.95S 202.95W 3221.87 3063.40 2988.30 40 0 S 13.00 E 4.65 596.88S 192.61W 25.19 52.38 83.69 118.71 158.57 SP~ .Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/13-36 500292261300 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/20/95 DATE OF SURVEY: 121595 MWD SURVEY JOB NUMBER: AK-MW-50116 KELLY BUSHING ELEV. = 75.10 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL D I RE CT I ON RE CTANGULAR COORD I NATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3313.15 3133.39 3058.29 3469.21 3251.43 3176.33 3562.11 3320.37 3245.27 3656.05 3388.84 3313.74 3750.75 3454.82 3379.72 39 50 41 50 42 20 44 3 47 35 S 13.00 E .18 653.96S 179.43W S 12.30 E 1.31 753.54S 157.09W S 10.00 E 1.74 814.62S 145.06W S 9.20 E 1.92 878.02S 134.34W S 9.80 E 3.77 945.00S 123.12W 200.38 272.76 315.75 358.88 404.36 3844.09 3518.21 3443.11 3936.96 3581.14 3506.04 4028.62 3641.95 3566.85 4123.56 3704.57 3629.47 4216.69 3765.98 3690.88 46 50 47 49 49 2 48 25 49 4 S 8.30 E 1.43 1012.65S 112.34W S 6.80 E 1.59 1080.35S 103.38W S 5.70 E 1.60 1148.51S 95.92W S 5.70 E .65 1219.52S 88.83W S 4.40 E 1.26 1289.25S 82.67W 449.83 493.79 536.73 580.89 623.58 4309.92 3827.32 3752.22 4401.69 3888.17 3813.07 4495.35 3949.34 3874.24 4588.51 4009.13 3934.03 4682.03 4069.43 3994.33 48 38 48 17 50 8 50 1 49 40 S 6.10 E 1.45 1359.16S 76.25W S 6.20 E .39 1427.46S 68.89W S 5.00 E 2.20 1498.02S 61.99W S 4.90 E .15 1569.20S 55.82W S 6.20 E 1.13 1640.34S 48.91W 666.59 709.52 753.29 796.76 840.84 4776.62 4130.35 4055.25 4870.18 4190.04 4114.94 4962.88 4248.79 4173.69 5055.85 4307.72 4232.62 5149.78 4367.13 4292.03 50 8 50 34 50 46 50 33 50 58 S 6.40 E .52 1712.26S 40.97W S 6.90 E .62 1783.83S 32.62W S 4.80 E 1.76 1855.15S 25.32W S 2.40 E 2.01 1926.90S 20.80W S 2.10 E .50 1999.60S 17.95W 886.21 931.73 976.24 1018.63 1060.13 5243.84 4425.97 4350.87 5336.26 4483.66 4408.56 5429.05 4542.77 4467.67 5521.35 4603.53 4528.43 5613.99 4664.99 4589.89 51 34 51 9 49 42 47 57 48 55 S 2.20 E .65 2072.93S 15.19W S .80 E 1.27 2145.09S 13.30W S .60 E 1.58 2216.61S 12.43W S 1.40 E 2.01 2286.06S 11.22W S .30 E 1.37 2355.36S 10.20W 1101.89 1142.29 1181.49 1219.85 1257.98 5706.09 4725.03 4649.93 5800.01 4786.69 4711.59 5893.61 4849.52 4774.42 5984.67 4910.85 4835.75 6074.82 4971.07 4895.97 49 42 48 12 47 27 47 51 48 19 S .50 E .87 2425.20S 9.71W S 1.30 W 2.15 2496.02S 10.19W S 1.50 W .82 2565.38S 11.88W S 1.90 W .55 2632.66S 13.88W S 1.80 W .52 2699.71S 16.05W 1295.94 1333.62 1369.49 1403.98 1438.21 6168.70 5033.38 4958.28 6259.14 5093.28 5018.18 6351.88 5154.78 5079.68 6445.46 5217.15 5142.05 6535.38 5277.38 5202.28 48 30 48 32 48 22 48 1 47 52 S 1.10 W .59 2769.91S 17.82W S .90 E 1.66 2837.66S 17.94W S .20 W .90 2907.07S 17.52W S 1.00 W .74 2976.82S 18.25W S .00 E .84 3043.58S 18.83W 1474.46 1510.80 1548.48 1585.38 1620.78 SP~ .Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/13-36 500292261300 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/20/95 DATE OF SURVEY: 121595 MWD SURVEY JOB NUMBER: AK-MW-50116 KELLY BUSHING ELEV. = 75.10 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 6629.50 5340.29 5265.19 6722.98 5402.10 5327.00 6816.67 5463.92 5388.82 6911.43 5526.92 5451.82 7006.50 5589.78 5514.68 48 15 48 57 48 27 48 12 49 0 S 1.60 E 1.33 3113.58S 17.85W S 3.00 E 1.36 3183.64S 15.03W S 3.00 E .53 3253.94S 11.35W S 2.80 E .31 3324.64S 7.76W S 2.90 E .83 3395.87S 4.22W 1659.25 1699.30 1740.21 1781.25 1822.54 7101.46 5651.33 5576.23 50 10 7195.39 5711.30 5636.20 50 28 7290.10 5772.03 5696.93 49 46 7384.28 5832.92 5757.82 49 40 7477.24 5892.42 5817.32 50 43 S 2.60 E 1.27 3468.09S .75W S 2.80 E .35 3540.30S 2.65E S 3.00 E .76 3612.89S 6.33E S 1.50 E 1.22 3684.68S 9.15E S 2.40 E 1.36 3756.05S 11.59E 1864.30 1906.00 1948.14 1989.12 2029.55 7572.02 5952.55 5877.45 50 31 7665.03 6012.16 5937.06 49 45 7759.67 6073.01 5997.91 50 12 7850.15 6131.06 6055.96 49 58 7948.43 6194.71 6119.61 49 17 S 3.60 E 1.00 3829.21S 15.42E S 2.80 E 1.05 3900.49S 19.41E S 4.40 E 1.38 3972.82S 23.96E S 3.00 E 1.21 4042.07S 28.44E S 3.60 E .84 4116.83S 32.75E 2072.12 2113.82 2156.55 2197.57 2241.40 8042.75 6256.51 6181.41 8138.22 6318.79 6243.69 8233.77 6380.47 6305.37 8328.47 6441.41 6366.31 8422.48 6501.72 6426.62 48 5O 49 43 49 50 50 2 5O 9 S 4.00 E .57 4187.92S 37.47E S 3.00 E 1.22 4260.15S 41.88E S 4.30 E 1.05 4332.96S 46.53E S 4.50 E .26 4405.24S 52.09E S 3.30 E .99 4477.18S 57.00E 2283.61 2326.17 2369.24 2412.79 2455.62 8517.34 6562.20 6487.10 8611.90 6622.11 6547.01 8705.76 6681.16 6606.06 8799.30 6739.53 6664.43 8892.04 6798.41 6723.31 50 38 50 44 51 17 51 28 49 42 S 6.60 E 2.73 4549.97S 63.31E S 6.10 E .42 4622.69S 71.40E S 5.50 E .77 4695.27S 78.77E S 3.20 E 1.93 4768.13S 84.31E S 5.30 E 2.60 4839.57S 89.60E 2500.08 2546.01 2591.25 2635.11 2677.98 8986.05 6859.08 6783.98 9079.05 6918.91 6843.81 9173.94 6979.77 6904.67 9268.42 7040.44 6965.34 · 9363.49 7101.77 7026.67 49 54 50 1 50 10 49 56 49 42 S 3.80 E 1.24 4911.14S 95.30E S 3.50 E .28 4982.20S 99.83E S 4.10 E .51 5054.84S 104.66E S 5.10 E .85 5127.04S 110.46E S 4.00 E .92 5199.45S 116.23E 2721.27 2763.30 2806.43 2850.15 2893.95 9457.90 7162.94 7087.84 9552.64 7224.65 7149.55 9647.10 7286.36 7211.26 9740.74 7347.45 7272.35 9836.01 7409.68 7334.58 49 49 49 49 49 30 12 12 20 5 S 6.20 E 1.79 5271.06S 122.62E S 5.60 E .58 5342.56S 130.01E S 4.20 E 1.12 5413.81S 136.11E S 6.00 E 1.46 5484.49S 142.42E S 4.80 E .99 5556.31S 149.21E 2937.84 2982.53 3025.99 3069.31 3113.66 SP~-- ..Y-SUN DRILLING SERVICES ANCHOILAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/13-36 500292261300 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/20/95 DATE OF SURVEY: 121595 MWD SURVEY JOB NUMBER: AK-MW-50116 KELLY BUSHING ELEV. = 75.10 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 9931.71 7472.34 7397.24 10026.01 7534.16 7459.06 10121.97 7597.27 7522.17 10216.45 7659.60 7584.50 10308.62 7720.56 7645.46 49 5 48 57 48 47 48 38 48 33 S 4.10 E .55 5628.42S 154.83E S 4.60 E .43 5699.42S 160.23E S 3.30 E 1.03 5771.53S 165.21E S 5.10 E 1.44 5842.33S 170.40E S 5.30 E .18 5911.19S 176.67E 3157.17 3199.90 3242.88 3285.33 3327.64 10402.91 7782.97 7707.87 10497.63 7846.06 7770.96 10592.25 7909.11 7834.01 10686.12 7971.15 7896.05 10792.38 8041.38 7966.28 48 32 47 54 48 31 48 45 48 30 S 3.00 E 1.83 5981.67S 181.78E S 1.70 E 1.23 6052.24S 184.68E S 1.80 E .65 6122.76S 186.84E S 3.40 E 1.30 6193.14S 190.04E S 5.20 E 1.29 6272.64S 196.01E 3369.85 3410.25 3449.99 3490.52 3538.31 10884.84 8102.22 8027.12 10977.31 8162.78 8087.68 11071.91 8225.11 8150.01 11165.88 8287.48 8212.38 11258.44 8348.08 8272.98 49 15 48 56 48 39 48 10 50 1 S 11.30 E 5.04 6341.51S 206.02E S 16.30 E 4.10 6409.34S 222.67E S 20.80 E 3.59 6476.79S 245.30E S 22.20 E 1.23 6542.19S 271.06E S 23.50 E 2.27 6606.64S 298.23E 3583.79 3634.31 3689.65 3746.53 3804.10 11349.37 8405.20 8330.10 11442.96 8461.76 8386.66 11535.51 8515.57 8440.47 11630.63 8570.09 8494.99 11723.16 8622.80 8547.70 52 7 53 32 55 23 54 39 55 54 S 24.30 E 2.40 6671.30S 326.89E S 28.80 E 4.12 6737.97S 360.23E S 32.70 E 3.97 6802.66S 398.75E S 35.40 E 2.45 6867.22S 442.37E S 38.30 E 2.90 6928.06S 487.99E 3863.04 3927.00 3994.26 4065.76 4136.93 11815.88 8673.51 8598.41 11910.51 8723.37 8648.27 11999.26 8769.45 8694.35 12092.96 8817.63 8742.53 12184.71 8863.71 8788.61 57 46 58 40 58 46 59 21 60 22 S 39.30 E 2.21 6988.53S 536.62E S 44.60 E 4.86 7048.32S 590.38E S 48.00 E 3.28 7100.71S 645.21E S 51.20 E 3.00 7152.78S 706.41E S 56.50 E 5.12 7199.55S 770.46E 4210.45 4287.93 4362.33 4441.92 4521.08 12279.84 8911.33 8836.23 12321.19 8932.46 8857.36 12369.49 8956.86 8881.76 12400.23 8971.28 8896.18 12431.04 8983.72 8908.62 59 32 59 0 60 17 63 46 68 34 S 57.00 E .99 7244.71S 839.32E S 55.80 E 2.82 7264.37S 868.93E S 55.80 E 2.69 7287.80S 903.40E S 56.76 E 11.62 7302.87S 925.98E S 57.61 E 15.81 7318.13S 949.66E 4603.42 4638.95 4680.61 4707.76 4735.93 12461.67 8994.11 8919.01 12492.58 9003.04 8927.94 12523.39 9010.27 8935.17 12556.52 9015.64 8940.54 12587.04 9018.89 8943.79 71 43 74 41 78 8 83 11 84 34 S 57.96 E 10.34 7333.49S 974.03E S 58.43 E 9.72 7349.08S 999.18E S 58.42 E 11.17 7364.76S 1024.69E S 56.49 E 16.32 7382.35S 1052.24E S 56.70 E 4.57 7399.05S 1077.57E 4764.74 4794.32 4824.26 4856.94 4887.28 SPL .Y-SUN DRILLING SERVICES ANCHOtLAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/13-36 500292261300 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/20/95 DATE OF SURVEY: 121595 MWD SURVEY JOB NUMBER: AK-MW-50116 KELLY BUSHING ELEV. = 75.10 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES. DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 12618.04 9021.93 8946.83 84 9 12649.21 9025.43 8950.33 82 57 12679.75 9029.43 8954.33 82 0 12710.76 9033.79 8958.69 81 48 12741.84 9038.29 8963.19 81 32 S 56.63 E 1.37 7416.01S 1103.34E S 57.37 E 4.52 7432.87S 1129.32E S 57.78 E 3.41 7449.11S 1154.88E S 57.57 E .91 7465.52S 1180.82E S 58.47 E 2.99 7481.81S 1206.90E 4918.13 4949.10 4979.38 5010.08 5040.83 12772.56 9042.57 8967.47 12804.37 9046.35 8971.25 12834.41 9048.81 8973.71 12865.27 9050.17 8975.07 12896.17 9051.08 8975.98 82 26 83 54 86 40 88 18 88 18 S 57.95 E 3.40 7497.84S 1232.76E S 57.81 E 4.61 7514.63S 1259.51E S 57.88 E 9.19 7530.56S 1284.85E S 57.19 E 5.76 7547.11S 1310.86E S 56.95 E .78 7563.90S 1336.78E 5071.25 5102.83 5132.76 5163.59 5194.47 12927.34 9052.00 8976.91 12957.97 9052.85 8977.75 12989.00 9053.19 8978.09 13020.11 9052.76 8977.67 13051.06 9052.04 8976.94 88 16 88 33 90 12 91 20 91 19 S 56.80 E .49 7580.92S 1362.88E S 57.39 E 2.12 7597.56S 1388.58E S 58.29 E 6.09 7614.07S 1414.85E S 58.30 E 3.66 7630.42S 1441.31E S 58.34 E .17 7646.67S 1467.64E 5225.63 5256.25 5287.27 5318.37 5349.31 13081.76 9051.33 8976.23 13112.65 9050.68 8975.58 13143.52 9050.29 8975.19 13174.62 9050.38 8975.28 13205.38 9051.02 8975.92 91 20 91 3 90 24 89 15 88 22 S 58.76 E 1.37 7662.68S 1493.82E S 58.82 E .99 7678.68S 1520.24E S 60.69 E 6.41 7694.23S 1546.90E S 61.12 E 3.92 7709.35S 1574.07E S 61.00 E 2.92 7724.23S 1600.99E 5380.00 5410.87 5441.71 5472.75 5503.44 13236.23 9051.89 8976.79 13266.89 9052.78 8977.68 13298.13 9053.77 8978.67 13328.99 9054.86 8979.76 13359.88 9056.02 8980.92 88 24 88 16 88 5 87 52 87 50 S 60.94 E .22 7739.20S 1627.95E S 60.76 E .72 7754.13S 1654.71E S 60.61 E .75 7769.415 1681.94E S 60.34 E 1.13 7784.61S 1708.78E S 60.15 E .62 7799.93S 1735.57E 5534.22 5564.82 5595.99 5626.79 5657.62 13384.37 9056.97 8981.87 13421.76 9058.62 8983.52 13452.87 9060.42 8985.33 13483.65 9062.61 8987.51 13514.82 9064.91 8989.81 87 41 87 15 86 4 85 46 85 46 S 59.80 E 1.55 7812.18S 1756.76E S 59.62 E 1.25 7831.02S 1789.02E S 59.46 E 3.83 7846.76S 1815.79E S 59.48 E 1.01 7862.36S ~842.23E S 59.23 E .80 7878.20S 1868.97E 5682.07 5719.40 5750.43 5781.12 5812.18 13545.31 9067.42 8992.32 13576.13 9070.15 8995.05 13607.21 9072.86 8997.76 13638.40 9075.68 9000.58 13669.12 9078.57 9003.47 84 48 85 1 84 58 84 39 84 32 S 59.61 E 3.42 7893.66S 1895.13E S 59.68 E .78 7909.17S 1921.62E S 59.26 E 1.36 7924.90S 1948.29E S 59.11 E 1.10 7940.81S 1974.97E S 58.91 E .76 7956.56S 2001.19E 5842.55 5873.23 5904.17 5935.22 5965.79 SPi .Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 6 SHARED SERVICES DRILLING PBU/13-36 500292261300 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/20/95 DATE OF SURVEY: 121595 MWD SURVEY JOB NUMBER: AK-MW-50116 KELLY BUSHING ELEV. = 75.10 FT. OPERATOR: ARCO ALASKA INC TRUE SUB-SEA COURS COURSE DLS TOTAL MEASD VERTICAL VERTICAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DEPTH DEPTH DEPTH DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 13696.67 9081.30 9006.20 84 4 S 59.04 E 1.73 13758.00 9087.62 9012.52 84 4 S 59.04 E .00 7970.69S 2024.68E 5993.19 8002.07S 2076.99E 6054.18 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 8267.23 FEET AT SOUTH 14 DEG. 33 MIN. EAST AT MD = 13758 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 122.53 DEG. SPE .Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SH3kRED SERVICES DRILLING PBU/13-36 500292261300 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/20/95 DATE OF SURVEY: 121595 JOB NUMBER: AK-MW-50116 KELLY BUSHING ELEV. = 75.10 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -75.10 .00 N .00 E 1000.00 999.99 924.89 .96 S .94 E 2000.00 1993.63 1918.53 63.58 S 64.42 W 3000.00 2887.57 2812.47 462.96 S 210.15 W 4000.00 3623.19 3548.09 1127.01 S 98.07 W .0O .01 .01 6.37 6.36 112.43 106.06 376.81 264.38 5000.00 4272.26 4197.16 1883.80 S 22.91 W 727.74 350.92 6000.00 4921.14 4846.04 2644.02 S 14.26 W 1078.86 351.13 7000.00 5585.51 5510.41 3390.97 S 4.47 W 1414.49 335.62 8000.00 6228.38 6153.28 4155.82 S 35.23 E 1771.62 357.14 9000.00 6868.07 6792.97 4921.79 S 96.00 E 2131.93 360.31 10000.00 7517.09 7441.99 5679.86 S 158.65 E 2482.91 350.98 11000.00 8177.70 8102.60 6425.71 S 227.63 E 2822.30 339.39 12000.00 8769.84 8694.74 7101.13 S 645.68 E 3230.16 407.86 13000.00 9053.15 8978.05 7619.85 S 1424.20 E 3946.85 716.69 13758.00 9087.62 9012.52 8002.07 S 2076.99 E 4670.38 723.53 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SP. ~{Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SIiARED SERVICES DRILLING PBU/13-36 500292261300 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/20/95 DATE OF SURVEY: 121595 JOB NUMBER: AK-MW-50116 KELLY BUSHING ELEV. = 75.10 OPERATOR: ARCO ALASKA INC FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -75.10 75.10 75.10 .00 175.10 175.10 100.00 275.10 275.10 200.00 375.10 375.10 300.00 .00 N .00 E .02 S .01 W .54 S .29 W .86 S .57 W 1.15 S .77 W .00 .00 .00 .00 .00 .00 .00 .00 .00 475.11 475.10 400.00 575.11 575.10 500.00 675.11 675.10 600.00 775.11 775.10 700.00 875.11 875.10 800.00 1.06 S .34 W .86 S .27 W 1.00 S .14 E .91 S .39 E .78 S .61 E .01 .00 .01 .00 .01 .00 · .01 .00 .01 .00 975.11 975.10 900.00 1075.11 1075.10 1000.00 1175.13 1175.10 1100.00 1275.20 1275.10 1200.00 1375.33 1375.10 1300.00 .90 S .94 E 1.30 S .63 E 2.45 S .78 W 4.76 S 3.73 W 7.90 S 7.55 W .01 .00 .01 .00 .03 .02 .10 .07 .23 .12 1475.53 1475.10 1400.00 1575.84 1575.10 1500.00 1676.32 1675.10 1600.00 1777.10 1775.10 1700.00 1878.46 1875.10 1800.00 12.27 S 12.09 W 17.92 S 17.60 W 25.27 S 23.97 W 34.56 S 32.35 W 45.38 S 44.78 W .43 .20 .74 .31 .22 .47 .00 .78 .36 1.36 1980.87 1975.10 1900.00 2084.95 2075.10 2000.00 2191.43 2175.10 2100.00 2299.70 2275.10 2200.00 2409.22 2375.10 2300.00 60.29 S 61.02 W 81.13 S 80.78 W 109.97 S 103.21 W 144.65 S 125.93 W 183.65 S 147.64 W 5.77 2.41 9.85 4.07 16.33 6.48 24.60 8.27 34.12 9.52 2519.40 2475.10 2400.00 2631.38 2575.10 2500.00 2745.70 2675.10 2600.00 2863.98 2775.10 2700.00 2984.74 2875.10 2800.00 224.79 S 168.77 W 270.75 S 189.37 W 323.69 S 205.13 W 386.51 S 211.03 W 454.17 S 210.59 W 44 56 70 88 109 .30 10.18 .28 11.97 .60 14.32 .88 18.28 .64 20.76 3108.84 2975.10 2900.00 3237.15 3075.10 3000.00 3367.48 3175.10 3100.00 3500.98 3275.10 3200.00 3636.93 3375.10 3300.00 527.35 S 204.40 W 606.45 S 190.40 W 687.88 S 171.60 W 774.25 S 152.58 W 864.89 S 136.47 W 133.74 162.05 192.38 225.88 261.83 24.10 28.31 30.33 33.51 35.94 ~{Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE SHARED SERVICES DRILLING PBU/13-36 500292261300 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/20/95 DATE OF SURVEY: 121595 JOB NUMBER: AK-MW-50116 KELLY BUSHING ELEV. = 75.10 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD DIFFERENCE VERTICAL CORRECTION 3780.83 3475.10 3400.00 3927.97 3575.10 3500.00 4079.15 3675.10 3600.00 4230.61 3775.10 3700.00 4382.04 3875.10 3800.00 966.88 S 119.35 W 1073.73 S 104.17 W 1186.46 S 92.13 W 1299.74 S 81.87 W 1412.88 S 70.48 W 305.7 352.8 404.0 455.5 506.9 43.90 47.14 51.18 51.46 51.43 4535.54 3975.10 3900.00 4690.78 4075.10 4000.00 4846.65 4175.10 4100.00 5004.47 4275.10 4200.00 5162.44 4375.10 4300.00 1528.75 S 59.30 W 560.4 1646.98 S 48.19 W 615.6 1765.78 S 34.81 W 671.5 1887.25 S 22.70 W 729.3 2009.43 S 17.59 W 787.3 53.49 55.25 55.87 57.82 57.97 5322.60 4475.10 4400.00 5478.88 4575.10 4500.00 5629.37 4675.10 4600.00 5782.62 4775.10 4700.00 5931.45 4875.10 4800.00 2134.46 S 13.45 W 847.5 2254.52 S 11.98 W 903.7 2366.96 S 10.14 W 954.2 2483.06 S 9.90 W 1007.5 2593.25 S 12.62 W 1056.3 60.16 56.27 5O.50 53.24 48.83 6080.88 4975.10 4900.00 6231.69 5075.10 5000.00 6382.48 5175.10 5100.00 6531.98 5275.10 5200.00 6681.86 5375.10 5300.00 2704.24 S 16.19 W 1105.7 2817.09 S 18.27 W 1156.5 2929.94 S 17.60 W 1207.3 3041.06 S 18.83 W 1256.8 3152.67 S 16.65 W 1306.7 49.44 50.80 50.79 49.50 49.88 6833.53 5475.10 5400.00 6984.13 5575.10 5500.00 7138.57 5675.10 5600.00 7294.86 5775.10 5700.00 7449.88 5875.10 5800.00 3266.54 S 10.69 W 1358.4 3379.01 S 5.07 W 1409.0 3496.56 S .54 E 1463.4 3616.52 S 6.52 E 1519.7 3734.89 S 10.70 E 1574.7 51.67 50.60 54.45 56.29 55.02 7607.49 5975.10 5900.00 7762.93 6075.10 6000.00 7918.36 6175.10 6100.00 8070.99 6275.10 6200.00 8225.44 6375.10 6300.00 3856.53 S 17.13 E 1632.3 3975.31 S 24.15 E 1687.8 4094.08 S 31.32 E 1743.2 4209.13 S 38.95 E 1795.8 4326.61 S 46.05 E 1850.3 57.60 55.44 55.43 52.63 54.45 8380.93 6475.10 6400.00 8537.67 6575.10 6500.00 8696.07 6675.10 6600.00 8855.97 6775.10 6700.00 9010.91 6875.10 6800.00 4445.34 S 55.16 E 1905.8 4565.59 S 65.12 E 1962.5 4687.75 S 78.05 E 2020.9 4812.15 S 87.09 E 2080.8 4930.12 S 96.56 E 2135.8 55.50 56.74 58.40 59.89 54.95 SP. .Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 10 SHARED SERVICES DRILLING PBU/13-36 500292261300 NORTH SLOPE BOROUGH COMPUTATION DATE: 12/20/95 DATE OF SURVEY: 121595 JOB NUMBER: AK-MW-50116 KELLY BUSHING ELEV. = 75.10 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGU~ COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 9166.64 6975.10 6900.00 5049.25 S 104.25 E 2191.54 55.73 9322.25 7075.10 7000.00 5168.07 S 114.03 E 2247.15 55.61 9476.62 7175.10 7100.00 5285.21 S 124.15 E 2301.52 54.37 9629.87 7275.10 7200.00 5400.80 S 135.16 E 2354.77 53.24 9783.17 7375.10 7300.00 5516.49 S 145.76 E 2408.06 53.30 9935.93 7475.10 7400.00 5631.61 S 155.05 E 2460.83 52.77 10088.31 7575.10 7500.00 5746.25 S 163.75 E 2513.21 52.38 10239.90 7675.10 7600.00 5859.87 S 171.97 E 2564.80 51.59 10391.03 7775.10 7700.00 5972.77 S 181.32 E 2615.92 51.12 10540.96 7875.10 7800.00 6084.39 S 185.64 E 2665.86 49.93 10692.12 7975.10 7900.00 6197.64 S 190.30 E 2717.02 51.16 10843.45 8075.10 8000.00 6310.71 S 200.64 E 2768.35 51.34 10996.04 8175.10 8100.00 6422.86 S 226.76 E 2820.94 52.59 11147.31 8275.10 8200.00 6529.38 S 265.83 E 2872.21 51.27 11300.52 8375.10 8300.00 6636.22 S 311.10 E 2925.42 53.21 11465.54 8475.10 8400.00 6753.85 S 369.17 E 2990.44 65.02 11639.31 8575.10 8500.00 6872.98 S 446.49 E 3064.21 73.77 11818.86 8675.10 8600.00 6990.48 S 538.22 E 3143.76 79.55 12010.17 8775.10 8700.00 7106.91 S 652.18 E 3235.07 91.31 12207.76 8875.10 8800.00 7210.61 S 787.17 E 3332.66 97.59 12409.39 8975.10 8900.00 7307.40 S 932.97 E 3434.29 101.63 13632.15 9075.10 9000.00 7937.62 S 1969.63 E 4557.05 1122.76 13660.00 9077.70 9002.60 7951.87 S 1993.41 E 4582.30 25.25 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Date: RE: 17 January 1996 Transmittal of Data ECC #: 6551.00 Sent by: HAND CARRY Data: SBT/GR Dear Sir/Madam, Reference: 13-36 PRUDHOE BAY NORTH SLOPE, AK Enclosed, please find the data as described below: Tapes/Diskettes: 1 LDWG TAPE+LIS Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 Received by:. LARRY GRANT Attn. ALASKA OIL + GAS CONSERVATION 3001 PORCUPINE DRIVE ANCHORAGE AK, 99501. Dear Sir/Madam, Date: RE: 29 December 1995 Transmittal of Data ECC #: 6551.00 Sent by: HAND CARRY Data: SBT/GR Reference: ARCO JAi' 02 13-36 PRUDHOE BAY NORT~ SLOPE, Enclosed, please find the data as described below: Prints/Films: 1 SBT FINAL BL+RF Run # 1 Please sign and return to: Attn. Rodney D. Paulson Atlas Wireline Services 5600 B Street Suite 201 Anchorage, AK 99518 ~ ~~(907)563-7803 Received by: Date: December 29, 1995 AOGCC Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Re: Survey Data 13-36, Redistribution 18-28 Dear Mr. Grant, Enclosed are two hard copies of the above mentioned file(s). Well 13-36 MWD survey, surface to 13758' 6~ C~- I ~ Well 18-28 MWD survey being REDISTRIBUTED, destroy any previous survey data. Previous azimuth tie in point was incorrect due to typographical error. Tied into 18-28PB1 at 10,154.89', window point 10,174', interpolated depth 11,965' Please call me at 563-3256 if you have any questions or concerns. Regards, Sandra Lufkin Dept. Specialist Attachments. 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company MEMORANDUM State of Alaska Alaska Oil and Gas ConServation Commission TO: David Johnston, Chairman~ DATE: November 26, 1995 THRU: Blair Wondzell, P. I. Supervisor FILE NO: afnhkzcd.doc FROM: Doug Amos, C~o~3, - SUBJECT: Petroleum Inspector BOPE Test Nabors 18E Arco PBU DS13-36 Prudhoe Oil Pool PTD No. 95-167 Sunday,' November 26, 1995' I was called out to' Arco's PBU DS13-36 well at 2:00 AM.to witness the BOPE-Test on Nabors Rig 18E. When I arrived on location the drilling crew was in the final stages of nippling up the BOP stack, delaying the start of the test until 3:30 AM. As the attached AOGCC BOPE Test Report indicates there were no failures. The driller and his crew had excellent knOwledge of'their BOP equipment and . the required test procedure which made the test run smoothly. SUMMARY' Witnessed the BOPE test at Arco's PBU DS13-36 well on -. Nabors Rig No. 18E. 4 test Hours, 22 valves tested, no failures Attachment: AFNHKZCD.XLS OPERATION: Drlg: X Drlg Contractor: Operator: Well Name: Casing Size: 10 3/4" Test: Initial X STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSION BOPE Test Report Workover: Nabors DATE: -. Rig No. 1SE PTD # 95-'167 Rig Ph.# ARCO DS13-36 Set @ Weekly 3,431' Other Rep.: Rig Rep.: Location: Sec. 1/26/95 659-4608 Wayne Helms Don Dubois 13 T. 10 N R. 14 E Meridian Umiat TEST DATA MISC. INSPECTIONS: · Location Gen.: OK Housekeeping: OK (Gen) PTD On Location Yes Standing Order Posted Yes BOP STACK: Quan. Annular Preventer '/ Pipe Rams Lower Pipe Rams '/ Blind Rams 1 Choke Ln. Valves HCR Valves 2 Kill Line Valves Check Valve N/A Well Sign Drl. Rig. Hazard Sec. Yes OK Yes Test Press. P/F 3OO/3, OOO P 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P MUD SYSTEM: Visual Alarm Trip Tank OK OK Pit Level Indicators OK OK Flow Indicator OK OK Meth Gas Detector OK . OK H2S Gas Detector OK OK _ FLOOR SAFETY VALVES: Upper Kelly / IBOP Lower Kelly / IBOP Ball Type Inside BOP Test Quan. Pressure P/F I 500/5,000 P 500/5,000 P 500/5,000 P 500/5,000 P CHOKE MANIFOLD: No. Valves . No. Flanges Manual Chokes Hydraulic Chokes . ACcuMULATOR SYSTEM: System Pressure Pressure After Closure 200 psi Attained After Closure System Pressure Attained Blind Switch Covers: Nitgn. Btl's: 16 Test Pressure P/F 500/5,000 P 42 500/5,000 P I P Functioned Functioned 2 Master: 8 @ 2,1 O0 PSI 2,950 P 1,350 P minutes 37 sec. minutes 15 sec. X Remote: X Psig. Number of Failures: 0 TEST RESULTS ,Test Time: 4.0 Hours. Number of valves tested 22 Repair or Replacement of Failed Equipment will be made within 0 days. Notify the Inspector and follow with Written or Faxed verification to the AOGCC Commission Office at: Fax No. 276-7542 Inspector North Slope Pager No. 659-3607 or 3687 If your call is not returned by the inspectOr within 12 hours please contact the P. I. Supervisor at 279-1433 REMARKS: Good crew exceflent test/./// Distribution: orig-Well File c - Oper./Rig c- Database c - Trip Rpt File c- Inspector STATE WITNESS REQUIRED? YES X NO 24 HOUR NOTICE GIVEN YES X NO Waived By: Witnessed By: FI-021L (Rev. 12/94) AFNH KZCD.XLS TONY KNOWLE$, GOVERNOFI ALASKA OIL AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 October 26, 1995 Dan Stoitz, Senior Drilling Engineer ARCO Alaska Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit 13-36 ARCO Alaska Inc. Permit No 95-167 - Surf Loc 1585'NSL, 5187'WEL, Sec. 13, T10N, R14E, UM Btmhole Loc 4171'NSL, 3181'WEL, Sec. 25, TION, R14E, UM Dear Mr. Stoltz: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of injection wells must be demonstrated under 20 AAC 25.412 and 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before ddlling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission's petroleum field inspector on the North Slope pager at 659-3607. David W Chairman BY ORDER OF THE COMMISSION c: Dept of Fish & Game, Habitat Sect - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of work Drill [] RedrillFl lb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen[] Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) !10. Field and Pool ARCO Alaska, Inc. Plan RTE = 74.2 f e et Prudhoe Bay Field/Prudhoe 3. Address 6. Property Designation Bay Pool P. O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028316 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 2o AAC 25.025) 1585' NSL, 5187' WEL, SEC. 13, TION, R14E Prudhoe Bay Unit At top of productive interval 8. Well number Number 4730' NSL, 4057' WEL, SEC. 25, TION, R14E 13-36 U-630610 At total depth 9. Approximate spud date Amount 4171' NSL, 3181' WEL, SEC. 25, TION, R14E 11/23/95 $200,000.00 12. Distance to nearest 13. Distance to nearest well 4. Number of acres in property15. Proposed depth (MD and TVD) property line ADL 028315 1109 feet DS 13-7, 39'at 1773 feet 2560 13511'MD/9049'TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ~ooo feet Maximum hole angle 88 o Maximum surface 3330 psig At total depth (TVD) 8800'/4390 psig 18. Casing program Specifications Setting Depth s~ze Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 30" 20" 91.5# H-40 Weld 80' 30' 30' 11 O' 11 O' 260 sx Arctic Set (Approx.) 13-1/2" 10-3/4" 45. 5# NT80 BTC 3414' 29' 29' 3443' 3274' 1115 sx CS III, 375 'G', 250 sx CS II 9-7/8" 7-5/8" 29.7# 'JSS-95 BTC Mod 12107' 28' 28' 12135' 8932' 265 Class 'G' 6-3/4" 4-1/2" 12.6# L-80 BTC Mod 1006' 11985' 8855' 12991' 9032' 195 sx Class 'G' 6-3/4' 4-1/2" 12. 6# L-80 NSCT 520' 12991' 9032' 13511' 9049' Uncemented Slotted Liner slotted 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor Surface R F-' ,,., ~Ii V/ Intermediate Production OCT 2_ 0 199,5 Liner Perforation depth: measured ~~il & Gas Cons. true vertical LMch0rago · 20. Attachments Filing fee [] Property plat [] BOP Sketch [] Diverter Sketch [] Drilling program[] Drilling fluid program.m. [] Time vs depth plot [] Refraction analysisl-I Seabed report[] 20 AAC 25.050 requirementsl-I 21. I hereby certJf~ that the fercg,oi¢l~l is true and correct to the best of my knowledge'-'~ /- ~~///?/*" ' Date/¢r/¢ .~.~ Signed ~(" ,/¢&~_. ~ Title SeniorDrillin9 Engineer · Commission Use Only Permit Number APl number Apprqval date ,- See cover letter ~',.~'-//'~/~ ~ 5 O- 0 ~__¢ -- 2.- .2.. ~'/'/-.~ //¢ -r.~ ~ J~',,~--~ for other requirements Conditions of approval Samples required [] Yes '[~ No Mud log required []Yes [~ No Hydrogen sulfide measures J~ Yes [] No Directional survey required ~ Yes [] No Required working pressure for~j~i~! ~1~ ~/3M; 1~SM; 1-110M; 1-115M; Other: by order of Approved by David W. Johnston Commissioner me commission Date cate Form 10-401 Rev. 12-1-85 Submit I Well Name: Type of Well (producer or injector): Surface Location: Start of Horizontal Location: End of Horizontal Location: IDS 13-36 Well Plan Summary Pre-Produced WAG Injector 1585' FSL 5187' FEL Sec 13 T1 ON R14E 4730' FSL 4057' FEL Sec 25 T10N R14E 4171' FSL 3181' FEL Sec 25 T10N R14E I AFE Number: J4J0304 I I Rig: J Nabors 18-E ~-- I Estimated Start Date: I Nov. 23, 1995 I I Operating days to complete: I 30 IUD.' 113,511' I I TVD.' 19,049' I IRT-GL I KBE: 29.7' 74.2' I I Well Design (conventional, slimhole, etc.) I Slimhole Horizontal w/4-1/2" Solid by Slotted Liner Formation Markers: Formation Tops MD TVD (RKB) SV3 3443' 3274' 10-3/4" casing point K-10 9136' 7003' K-5 10323' 7776' Base HRZ 11369' 8457' Sag River 12135' 8932' 7-5/8" casing point Top Shublik 12186' 8953' Top Sadlerochit 12471' 9014' Start of Horizontal 12471' 9014' TD of Well 13511' 9049' 4-1/2" casing point Casin¢l/Tubing Proqram: ~p, y Y Hole Size Csg/ Wt/Ft Grade Conn Length Top Btm Tbg O.D. MD/TVD MD/TVD 30" 20" 91.5# H-40 Weld 80' 30'/30' 110'/110' 13-1/2" 10-3/4" 45.5# NT80 BTC 3414' 29'/29' 3443'/3274' 9-7/8" 7-5/8" 29.7# USS-95 BTC- 12107' 28'/28' 12135'/8932' MOD 6-3/4" 4-1/2" 12.6# L-80 BTC- 1006' 11985'/8855' 12991 '/9032' MOD 6-3/4" 4-1/2" 12.6# L-80 NSCT 520' 12991 '/9032' 13511 '/9049' slotted Tubing 4-1/2" 12.6# L-80 BTC- 11959' 26'/26' 11985'/8855' MOD !co~a OCT 20 Ancherag~ Logging Program: I L°gs: I 13-1/2" Hole MWD Directional 9-7/8" Hole I~--'~ ~ 6-3/4" Hole I ~'"~ ~onal/Resistivity Cased Hole: I CBL Mud Program: Surface Mud Pro"'perties: I 13-1/2" hole section: SPUD Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Initial 8.5 _ 300 40-60 30-60 50-80 9-10 15-25 Final 9.5 100-200 25-50 15-25 25-40 9-10 15-25 Hazards/Concerns Due to light gravel expectations, no real concerns in surface hole. Intermediate Mud Properties: I 9-7/8" hole section to top of Sag: LSND Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Initial 8.8-9.0 35-40 8-12 3-6 8-10 9.0-9.5 8-12 5,800' 9.5 40-45 10-12 4-8 8-12 9.0-9.5 6-8 Final 9.6-9.8 45-50 12-15 4-8 8-12 9-10 <6 HTHP-15.0 Hazards/Concerns Cretaceous overpressure expected, MW to be at least 9.5 ppg. Utilize hi vis sweeps to assist hole cleaning Monitor LSYP and increase if problems occur trying to clean the hole. Potential high torque could need lubricant use. Reduce APl fluid loss to <6 cc before drilling Kingak Section. If high torque is encountered, respond with lubricants. Note: The Jurassic shales may be particularly troublesome, so treat with Baranex, and Boreplate at 2.0 ppb each. Production Mud Properties: I 6-3/4" hole section: FIo-Pro for Horizontal Depth Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Initial 8.8-9.0 50-60 30-40 15-20 18-24 9.5-10.5 <6 Final 8.8-9.0 50-60 30-40 15-20 18-24 9.5-10.5 <6 Hazards/Concerns Lost Circulation a possibility due to overbalance in Sadlerochit. Differential sticking possible with overbalance situation. Perform/report daily checks on KCI concentrations in Xanvis KCI system. High torque may be experienced and should be countered with lubricants. Directional: I KOP: 11000' Maximum Hole Angle: ! Tangent Angle Close Approach Well: 88° 49° DS 13-7 (39' away at 1773' MD) and DS 13-11 (135' away at 3798' MD) ' b OCT 2 0 ~995 U~l & Gas Cons. Commission ~ch0rage Well Control: Well control equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. PROPOSED DRILLING AND COMPLETION PROGRAM WELL: DS 13-36 [ 21 - 25 - 10 - 14 ] 1. MIRU. NU diverter and function test same. 2. Drill 13-1/2" hole to + 3443' MD/3274' TVD. Run and cement 10-3/4" 45.5# NT-80 BTC casing to surface. . Install blowout prevention equipment consisting of 5,000 psi W.P. pipe rams, blind rams, and annular preventer. Function test BOPE to 5,000/250 psi. , Test 10-3/4" casing to 3,000 psi for 30 minutes. A formation leak-off test will be performed 10' below the 10-3/4" shoe. . . Directionally drill 9-7/8" hole to the top of the Sag River @ + 12,135' MD/8,932' TVD. Run 7-5/8" 29.7# USS-95 BTC-MOD casing string and cement with Class G cement to 1,000' MD above the casing shoe. Test casing to 3,500 psi. Drill a 6-3/4" hole 10' outside of 7-5/8" casing and test the formation to a minimum of 0.5 ppg over the mud weight to be used to drill the hole section. Displace mud system to FIo-Pro mud system. Directionally drill high angle section to TD at + 13,511' MD/9,049' TVD. Note - Carefully monitor torque and drag to ensure that parameters do not exceed the rating of 3 1/2" DP. Use lubricants as required. , Make a hole opener run with a 7-5/8" casing scraper spaced to scrape the packer setting depth. Run 4-1/2" 12.6# NT-80 solid by slotted liner with liner hanger. Liner will be set at TD and lapped +150' inside 7- 5/8" casing shoe. Cement the solid 4-1/2" liner with Class G cement. Release from hanger. Drill out cement between solid and slotted liner. RIH open-ended to TD. Displace well from FIo-Pro mud to filtered seawater. Spot lithium hypochlorite breaker across slotted liner length\ . 11. RU Atlas. Log bottom +300' of the 7-5/8" casing with CBL. Run 4-1/2" L-80 tubing with SSSV, GLM's, and 7-5/8" packer assembly. Set packer and test tubing annulus w/ 4,000 psi. Set BPV. ND BOPE. Freeze protect well to 2100' TVD through shear valve in top GLM station. Release rig. Drilling Hazards · No hydrocarbon-bearing zones expected above the Sag River formation. · Losses have been encountered drilling the Sag River, Shublik and Sadlerochit formations on DS 13. Be prepared for losses near any faults and formation interfaces between the Sag River, Shublik and Sadlerochit. · A minimum of 9.5 ppg mud weight will be used to drill the Cretaceous injection interval. This will allow a 84 psi trip margin over the expected 9.1 ppg EMW @ 5300' TVDSS. OCT 2 0 1995 u~l & Gas Cons. Commission Anchorage Disposal Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. Fluid Handling: All drilling and completion fluids can be annular injected. Request to have well DS 13-36 for annular pumping. Request to AOGCC for Annular Pumping Approval for DS 13-36: 1. Approval is requested for Annular Pumping into the DS 13-36 10-3/4" x 7-5/8" casing annulus. 2. As referenced in Area Injection Order #4, there are no drinking water aquifers in the Prudhoe Bay Field Eastern Operating Area (including the Lisburne Oil Pool), as the average level of Total Dissolved Solids (TDS) at the ambient water within the proposed project area is above 10,000 ppm. There are no domestic or industrial use water wells located within one mile of the project area. 3. The 10-3/4" casing shoe will be set at 3443' MD (3274' TVD) which is below the Permafrost and in shale formations in the Sagavanirtok above the Ugnu Formation. 4. The burst rating (80%) for the 10-3/4" 45.5# NT-80 casing is 4170 psig while the collapse rating (80%) of the 7-5/8" 29.7# USS-95 casing is 5760 psig. The break down pressure of the Ugnu formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping is calculated according to the following equation and is 2790 psi for a 10.0 ppg fluid in this well (Assumes worst case in which 7-5/8" casing is filled with gas). MASP = 4170 psig - ((fluid density ppg - 1.9) X 0.052 X 10-3/4" Casing Shoe TVD) 5. A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7/24/95 which demonstrates the confining layers, porosity, and permeability of the injection zone. 6. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. AREA WELL PREV VOL PERMITTED PERMITTED INJECTED VOL DATES (aBES) (aBES) Prudhoe Bay DS 13-36 0 0 Submitted for 1995 DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. OCT 2. 0 lc09 Ut[ & Gas Cons. Commission Anchorage 10-3/4" SURFACE CASING CEMENT PROGRAM - BJ SERVICES CASING SIZE: 10-3/4" PREFLUSH: 75 bbls fresh water ahead of lead slurry. LEAD CEMENT TYPE: COLD SET III ADDITIVES: retarder YIELD: 1.92 ft3/sx THICKENING TIME: > 4 hrs WEIGHT: 12.2 ppg APPROX. # SACKS: 1115 CIRC. TEMP: 40°F MIX WATER: 10.53 gps TAIL CEMENT TYPE: CLASS G ADDITIVES: 2% A-7 + 1.0 ghs FP-6L WEIGHT: 15.8 ppg YIELD: 1.15 ft3/sx APPROX. # SACKS: 375 THICKENING TIME: > 3-1/2 hrs MIX WATER: 4.95 gps TOP JOB CEMENT TYPE: COLD SET II ADDITIVES: WEIGHT: 14.95 ppg APPROX. # SACKS: 250 YIELD: 0.96 ft3/sx MIX WATER: 3.89 gps THICKENING TIME: Greater than 2 hrs @ 50°F CENTRALIZER PLACEMENT: 1. Run 1 bow type centralizer per joint for the first 15 joints. 2. Place the centralizers in the middle of each joint with a stop collar. CEMENT VOLUME: 1. Lead slurry from TD to surface w/100% excess (less the tail slurry volume). 2. Tail slurry volume 375 sx (to cover 500' of casing shoe w/100% excess). 3. Top job volume 250 sx. OCT 2 0 'tO"3:':; A~aS~ uli & G;~s Cons. Commissior~ Anchorage. 7-5/8" PROTECTION CASING CEMENT PROGRAM - BJ SERVICES CASING SIZE: 7-5/8" ClRC. TEMP: 140°F PREFLUSH: 20 bbls fresh water SPACER: 50 bbls BJ MCS-4 Spacer weighted 1.0 ppg above mud weight. TAIL CEMENT TYPE: CLASS G ADDITIVES: 0.3% FL-52 + 0.5% CD-32 + 0.1% A-2 + 1.0 ghs FP-6L WEIGHT: 15.8 ppg YIELD: 1.14 ft3/sx MIX WATER: 4.85 gps APPROX. # SACKS: 265 THICKENING TIME: 3-1/2 to 4-1/2 hrs FLUID LOSS: 100-150 cc/30 minutes FREE WATER: 0 cc CENTRALIZER PLACEMENT: 1. Run 1 Turbulators per joint from TD to 500' MD above shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 bpm. Mix the tail slurry on the fly. CEMENT VOLUME: 1. Tail slurry to 11,074' MD (1000' above shoe/Sag River) 2. 80' MD 7-5/8" 29.7# capacity for float joints. Note: No hydrocarbon bearing zones are expected in the Cretaceous interval Alaska U~l & Gas Cons. Commission Anchorage 4-1/2" PRODUCTION LINER CEMENT PROGRAM - BJ SERVICES CIRC. TEMP: 140° F BHST: 220° F at 8800' TVDSS. PREFLUSH: 20 bbls fresh water SPACER: 70 bbls BJ MCS-4 Spacer weighted 1.0 ppg above mud weight. CEMENT TYPE: CLASS G ADDITIVES: 150 ghs BA-86L + 0.6% CD-32 + 0.2% FL-33 + 0.2% A-2 + 0.5% gel + 2 ghs FP-10L WEIGHT: 15.7ppg YIELD: 1.17ft3/sx MIX WATER: 3.58gps APPROX. # SACKS: 195 THICKENING TIME: 45 min. @ Surface + 3-4 hrs @ 140°F FLUID LOSS: less than 50 cc/30 minutes @ 140°F FREE WATER: 0 cc at 45° angle. NOTE: Ensure that a thickening time test is performed that simulates the shut down time incurred while rotating off of the liner. Note gellation tendencies ( if any ) of slurry when consistometer is re-started after shutdown period - additional retarder may be required - consult w/cementer. CENTRALIZER PLACEMENT: 1. Run 2 right hand turbolators per joint in open hole, 2. Run 1 right hand turbulator per joint in lap, and none opposite intermediate casing shoe.. OTHER CONSIDERATIONS: Batch mix the cement slurry. Perform fluid loss test on the batch mixed slurry. Fluid loss should be 50 cc/30 min. or less. Report actual fluid loss on morning report. Displace @ 6-8 bpm. LINER CEMENT VOLUME: 1. Open hole (6-3/4" X 4-1/2") + 30% excess (adjust if a caliper log is run and it indicates severe washouts). 2. 4-1/2", 12.6# casing capacity below landing collar (80'). 3. 150' liner lap (6.875" x 4-1/2") 4. 200' of cement on top of the liner in the 7-5/8" casing. Alaska Oil & Gas Cons, Commission A~chorage _/-95 14:43 Anadrill DPC g07 344 2160 P.05 --. SHARED SERV ICES DRILL i NG ! DS13-36 (P5) VERTICAL SECTION VIEW III II Section at: 122.53 I AN/~R,L.L AKA-DPC TVD Scale.' :1 inch : ~200 feet i _~..,- A P ')VEl) FO~ "t FLA,N #~ , ) I ,.-'"'"" ..... Marker Identification MD BKB SECTN INCLN A) KB 0 0 0 0.00 C __ B) KOP/BUILD 1/t00 1000 1000 0 0.00 -C) BUILD s .5/t00 1500 149§ 2 5.00 ) .......................... O) BUILD 2/100 2000 1993 9 $2,50 D -- E) CURVE 2.5/100 2500 2469 24 22.50 F) ~0-3/4" CASING POINT 3443 3274 223 40.68 ) G) END 2.5/100 CURVE 3831 3548 395 49,36 E - - H) CURVE 10/100 11899 9796 4464 49.36 I] 7-5/8" CASING POINT ~2t35 8932 4630 63.87 J) END 10/100 CURVE 1247! 9014 4944 88.O7 )--- K) TARGET 1247! 9014 4944 88.07 L) 4-1/2' CASING POINT 1351J 9049.~ 5994' 88.07 __ : · ~_-l~- - ~. ..... L , ~'---. :: :::: ::::~ ~/~~..,...== ......... .... ... .. .... ..... .... . ~ . J ~ ~m I ' i ......... I .......... (Anadrjl] ic}95 t336~5 2.50.03 J2:OJ ~ P} 0 600 i200 t.800 2400 3000 3600 4200 4800 5400 6000 6600 7200 7800 Section Departure , , 14:44 Anadrill DPC 907 344 2160 P.07 SHARED SERVe'CbS Marker Ident i f 1cat ion MD N/S E/W ~I*' ~" o KOP/BUILD 1/100 1000 · ! DRILLING DS13-36 (PS) PLAN VIEW CLOSURE · 8223 feet at Azi'muth 165.83 DECLINATION.' +0.000 (El ",' SCALE ' ! inch ~ lfiO0 feet DRAWN - ~0/17/95 5600 ' ............... ! AI',I'ADRIL_ AK,,a.-DPC FEA, ;IBIL ITYPLA',,I E~XECUTi()~.- · , Aia,~ ~ {jii& ias Cons.CommJs.~or~ j,nchorage 4800 4000 3200 2400 1600 800 0 800 i600 2400 3200 4000 4800 5600 <- ~ESl ' £~$1 -> II [Anadrill (c]95 i336P5 2.5b.03 2:. 22 PH P) WELL PERMIT CHECKLIST COMPANY INI c ss WELL NAME GEOL AREA UNIT# PROGRAM: exp [] dev [] redrll [] serv~ ON,O F s.o OJ ADMINISTRATION ENGINEERING 1. 2. 3. 4. 5. 10. 11. 12. 13. Permit fee attached .................. N Lease number appropriate ............... N Unique well name and number .............. N Well located in a defined pool ............. N Well located proper distance from drlg unit boundary.. N Well located proper distance from other wells ..... N Sufficient acreage available in drilling unit ..... N If deviated, is wellbore plat included ........ N Operator only affected party .............. N Operator has appropriate bond in force ......... N Permit can be issued without conservation order .... N Permit can be issued without administrative approval.. N Can permit be approved before 15-day wait ....... N 14. Conductor string provided ............... 15. Surface casing protects all known USDWs' . ....... 16. CMT vol adequate to circulate on conductor & surf csg. 17 CMT vol adequate to tie-in long string to surf csg . . 18. CMT will cover all known productive horizons ...... 19. Casing designs adequate for C, T, B & permafrost .... 20. Adequate tankage or reserve pit ............ 21. If a re-drill, has a 10-403 for abndnmnt been approved. 22. Adequate wellbore separation proposed ......... 23. If diverter required, is it adequate .......... 24. Drilling fluid program schematic & equip list adequate 25. BOPEs adequate .................... 26. BOPE press rating adequate; test to ~6~6~ psig~ 27. Choke manifold complies w/API RP-53 (May 84) ...... 28. Work will occur without operation shutdown ....... 29. Is presence of H2S gas probable ............ GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... Y 32. Seismic analysis 9f shallow gas zones .......... 33. Seabed condition survey (if off-shore) ........ ~/~ N 34. Contact name/phone for weekly progress reports . . . ~. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: DWJ~ , Comments/Instructions: HOW/jo - A:~FORMS%cheklist rev 03/94 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, informati~)n 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. ~ubfile 2 is type:' L £APE HEADER PRUDHOE BAY UNIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 6 6656.00 STEVE LATZ MIKE WHITELY D.S. 13-36 500292261300 ARCO ALASKA, INC. SPERRY-SUN DRILLING SERVICES 23-APR-96 MWD RUN 7 PAUL ROBERTS MIKE WHITELY MWD RUN 8 PAUL ROBERTS MIKE WHITELY MWD RUN 9 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: PAUL ROBERTS MIKE WHITELY WELL CASING RECORD MWD RUN 10 RANDY KRELL MIKE WHITELY 13 I0N 14E MWD RUN 11 RANDY KRELL JOHN RALL 1585 5187 75.10 73.60 44.50 OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 2ND STRING 13.500 10.750 3432.0 3RD STRING 9.875 7.625 12375.0 PRODUCTION STRING 6.750 13758.0 REMARKS: MWD - GR/EWR4. ALL DEPTHS ARE MEASURED BIT DEPTHS. ALL MWD DATA PRESENTED WAS DOWNHOLE RECORDED. MWD RUNS 1 TO 5 WERE DIRECTIONAL ONLY & NOT PRESENTED. MWD RUNS 6 TO 8 WERE DIRECTIONAL AND NATURAL GAMMA PROBE (NGP/SGRD) UTILIZING SCINTILLATION DETECTOR. MWD RUNS 9 TO 11 WERE DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER MUELLER TUBE DETECTORS, & ELECTRO- MAGNETIC WAVE PHASE-4 RESISTIVITY (EWR4). WELL IS OVER 90 DEG. FROM 12985 TO 13154' MD. ~E HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; DEPTH INCREMENT: .5000 FILE SL/MMARY PBU TOOL CODE START DEPTH GR 10726.0 RP 12349.0 $ BASELINE CURVE FOR SHIFTS: GRCH CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH GR 11961.0 11963.0 11962.0 11964.0 11964.0 11966.0 11967.5 11969.5 11971.5 11973.0 12021.0 12022.0 12029.0 12032.0 12033.0 12034.5 12034.5 12035.5 12049.0 12052.0 12158.0 12157.5 12169.0 12168.0 12191.5 12191.0 12225.5 12227.5 12327.0 12327.5 12356.5 12357.5 12358.5 12359.5 12361.0 12362.5 12363.5 12365.0 12369.0 12370.0 12371.5 12373.0 12400.0 12402.0 12403.5 12404.5 12407.0 12408.5 12410.0 12412.0 12414.0 12415.0 12431.0 12433.0 $ MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD $ REMARKS: all bit runs merged. STOP DEPTH 13716.0 13722.0 (WALS , 21-DEC-95) EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 6 10790.0 11813.0 7 11813.0 11919.0 8 11919.0 12380.0 9 12380.0 12576.0 10 12577.0 13171.0 11 13171.0 13758.0 MERGED MAIN PASS. ALL MWD CURVES WERE SHIFTED WITH GR. CN WN FN COUN STAT /??SHIFT. 0U_ $ : ARCO ALASKA, INC. : D.S. 13 -36 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 196 Tape File Start Depth = 13758.000000 Tape File End Depth = 10725.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 48537 datums Tape Subfile: 2 317 records... Minimum record length: Maximum record length: 62 bytes 998 bytes .pe Subfile 3 is type: LIS FILE HEADER FILE NUMBER: 2 P~AW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 10726.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXI~ ANGLE: STOP DEPTH 11749.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 6. 06-DEC-95 ISC 2.11 5.01 MEMORY 11813.0 10790.0 11813.0 0 48.2 55.9 TOOL NUMBER NGP 66 9.875 3432.0 LSND-HT 9.90 51.0 9.3 800 4.4 .000 .000 .000 .000 .0 150.1 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 13-36 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MW-D 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 27 Tape File Start Depth = 11820.000000 Tape File End Depth = 10726.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6568 datums Tape Subfile: 3 90 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes ~pe Subfile 4 is type: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 7 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11749.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 11866.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 7. 06-DEC-95 ISC 2.11 5.01 MEMORY 11919.0 11813.0 11919.0 0 57.8 58.7 TOOL NUMBER NGP 184 9.875 3432.0 LSND-HT 10.00 46.0 9.6 600 4.4 .000 .000 .000 .000 .0 145.9 .0 .0 .00 .000 .0 0 CN WN FN COUN STAT ARCO ALASKA, INC. D.S. 13-36 PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 5 Tape File Start Depth = 11935.000000 Tape File End Depth = 11745.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 49681 datums Tape Subfile: 4 68 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes .pe Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 8 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11865.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMt/MANGLE: STOP DEPTH 12317.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA PROBE $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : REMARKS: MWD RUN 8. 08-DEC-95 ISC 2.11 5.01 MEMORY 12380.0 11919.0 12380.0 0 58.8 60.4 TOOL NUMBER NGP 184 9.875 3432.0 LSND-HT 9.80 45.0 9.5 600 4.4 .000 .000 .000 .000 .0 154.3 .0 .0 .00 .000 .0 0 CN WN FN COLIN $T~T : ARCO ALASKA, INC. : D.S. 13 -36 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GR MWD 68 1 AAPI 4 2 ROP MWD 68 1 FPHR 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 13 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 310 01 1 4 90 810 01 1 Tape File Start Depth = 12385.000000 Tape File End Depth = 11860.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 9722 datums Tape Subfile: 5 76 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes ~pe Subfile 6 is type: LIS FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 9 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12313.0 EWR4 12320.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 12540.0 12547.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : 12-DEC-95 ISC 2.11 5.01 MEMORY 12576.0 12380.0 12576.0 0 59.7 78.1 TOOL NUMBER 6.750 12375.0 FLO-PRO 9.00 73.0 10.7 38500 4.4 .110 .050 .100 .130 70.0 152 .0 74.0 70.0 .00 .000 .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 9. $ : ARCO ALASKA, INC. : D.S. 13-36 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F. 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 18 Tape File Start Depth = 12580.000000 Tape File End Depth = 12310.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 54010 datums Tape Subfile: 6 83 records... Minimum record length: Maximum record length: 62 bytes 998 bytes _pe Subfile 7 is type: LIS FILE HEADER FILE NUMBER: 6 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 10 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12534.0 EWR4 12542.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWN-HOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13129.0 13136.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : 14-DEC-95 ISC 2.11 5.01 MEMORY 13171.0 12577.0 13171.0 0 81.5 91.3 TOOL NIIMBER 6.750 12375.0 FLO-PRO 9.00 76.0 10.2 38500 4.4 .110 .050 .100 .100 70.0 179.0 74.0 70.0 .00 .000 .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 10. $ : ARCO ALASKA, INC. : D.S. 13-36 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 42 Tape File Start Depth = 13175.000000 Tape File End Depth = 12530.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units =.Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 20051 datums Tape Subfile: 7 107 records... Minimum record length: Maximum record length: 62 bytes 998 bytes ~pe Subfile 8 is type: LIS FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 11 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 13129.0 EWR4 13136.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 13717.0 13723.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE DGR DUAL GAMMA RAY EWR4 ELECTROMAG. RESIS. 4 $ BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM) : FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPER3~TURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): 15-DEC-95 ISC 2.11 5.01 MEMORY 13758.0 13171.0 13758.0 0 84.1 89.3 TOOL NUMBER 6.750 12375.0 FLO-PRO 9.00 68.0 9.8 36000 4.4 .105 .050 .100 .130 73.0 180.0 70.0 73.0 .00 .000 .0 0 REMARKS: CN WN FN COUN STAT MWD RUN 11. $ : ARCO ALASKA, INC. : D.S. 13 -36 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OPIMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 ROP MWD 68 1 FPHR 4 7 FET MWD 68 1 HR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 810 01 1 4 90 180 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 41 Tape File Start Depth = 13758.000000 Tape File End Depth = 13125.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 64147 datums Tape Subfile: 8 106 records... Minimum record length: Maximum record length: 62 bytes 998 bytes Ape Subfile 9 is type: LIS 96/ 4/23 01 **** REEL TRAILER **** 96/ 4/23 01 Tape Subfile: 9 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Tue 23 APR 96 l:41p Elapsed execution time = 2.31 seconds. SYSTEM RETURN CODE = 0 11826 Run i' 21 - DEC - 1995 Marked Line GR 12465 Logging Services rape Subfile. 2 is typ~ LIS TAPE HEADER PRUDHOE BAY UNIT CASED HOLE WIRELINE LOGS WELL NAME: OPERATOR: LOGGING COM]~ANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL- . ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD DS 13-36 500292261300 ARCO ALASKA INCORPORATED WESTERN ATLAS LOGGING SERVICES 17-JAN-96 6551.00 R. ECK W. HELMS 13 10N 14E 1585 5187 74.20 45.10 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 7.625 12366.0 PRODUCTION STRING 5.500 13758.0 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ GR GRCH 1 1 21-DEC-95 WESTERN ATLAS LOGGING SERVICES 29.70 17.00 ......... EQUIVALENT UNSHIFTED DEPTH ......... MARKED LINE GRCH. MAGNETIC MARKS USED FOR DEPTH CONTROL. ************************************************* *** THIS IS THE DEPTH-REFERENCE FOR THIS WELL *** PASS i WAS NOT DEPTH SHIFTED SINCE PASS i IS THE DEPTH REFERENCE FOR THIS WELL. FILE HEADER' FILE NUMBER: 1 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 11835.0 12425.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE PASS NUMBER: BASELINE DEPTH REMARKS: ......... EQUIVALENT UNSHIFTED DEPTH ......... PASS 1 (MAIN PASS). NO DEPTH SHIFTS WERE DONE SINCE THIS IS THE DEPTH REFERENCE. CN WN FN COUN STAT : ARCO ALASKA INC. : DS 13-36 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH - PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units API API API AP1 Log Crv Crv Size Length Typ Typ Cls Mod i GRCH GR 68 1 GAPI 2 TENS GR 68 1 LB 4 4 30 995 99 1 4 4 30 995 99 1 8 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 16 Tape File Start Depth = 11820.000000 .Tape File End Depth = 12480.000000 Tape File Level Spacing = 0.500000 Tape File Depth U~ .... 's = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 3964 datums Tape Subfile: 2 ll0 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfil~ 3 is type: LIS FILE HEADER FILE NUMBER: 2 EDITED CURVES Depth shifted and clipped curves for each run in separate files. PASS NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GRCH $ CURVE SHIFT DATA - PASS TO PASS BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: i START DEPTH 11855.0 BASELINE DEPTH 11869.0 11960.5 11961.0 11973.0 11974.0 11976.5 11981.0 11983.0 11984.5 11985.5 11986.5 11994.5 11995.0 12001.5 12003.5 12019.5 12021.0 12023.0 12029.5 12030.5 12034.5 12108.5 12122.5 12123.5 12124.5 12125.5 12147.5 12151.5 12153.0 12153.5 12155.5 12156.0 12157.0 12160.0 12166.0 12166.5 lf180.5 121~1.5 STOP DEPTH 12385.0 (MEASURED DEPTH) ......... EQUIVALENT UNSHIFTED DEPTH .......... GRCH 11868.5 11960.0 11961.0 11973.0 11973.5 11976.0 11982.0 11984.0 11984.5 11985.5 11986.0 11994.0 11995.0 12002.0 12004.0 12018.5 12020.0 12023.0 12029.5 12030.0 12034.0 12108.5 12122.5 12123.0 12123.5 12124.5 12147.5 12151.5 12152.5 12153.0 12155.5 12156.0 12156.5 12160.0 12165.5 12166.5 12180.5 12181.0 12190.0 12192.0 12194.0 12197.5 12206.0 12207.0 12228.0 12228.5 12234.5 12235.5 12236.0 12247.0 12249.5 12250.5 12266.0 12289.5 12299.5 12307.0 12324.5 12326.5 12344.0 12349.5 12350.5 12351.5 12352.0 12352.5 12353.0 12354.0 12354.5 12355.0 12355.5 12356.5 12367.0 12367.5 12375.5 12376.5 12377.5 12378.0 $ REMARKS: i 9.5 12~92.0 12194.0 12197.5 12206.0 12206.5 12227.5 12228.5 12234.5 12235.0 12235.5' 12247.0 12249.5 12250.0 12265.0 12289.0 12299.0 123 0'6.0 12324.0 12326.5 12343.5 12349.5 12350.5 12351.0 12351.5 12352.5 12353.0 1.2353.5 12354.0 12355.0 12355.5 1'2356.0 12366.5 12367.5 12375.5 12376.0 12377.0 12377.5 PASS 2 (REPEAT PASS). TENS SHIFTED WITH GRCH CN WN FN COUN STAT / ? ?MATCH2A. OUT : ARCO ALASKA INC. : DS-13-36 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape: dePth ID: F 2 Curves: Name Tool Code Samples Units i GRCH GR 68 I GAPI 2 TENS GR 68 I LB * DATA RECORD (TYPE# 0) API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 30 995 99 1 4 4 30 995 99 1 8 1014 BYTES * Total Data Records: 15 Tape File Start Depth = 11845.000000 Tape File End Depth = 12445.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 3604 datums Tape Subfile: 3 124 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile-4 is type: ~.IS FILE HEADER FILE NUMBER: 3 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 4 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11826.5 $ 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): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACOM CENT SBT CENT VDL CENT $ STOP DEPTH 12432.5 CASING COLLAR LOC. GAMMA RAY ACOUSTIC COMMON CENTROLLER SEGMENTED BOND TOOL CENTROLLER VDL SUB CENTROLLER 21-DEC-95 FSYS REV. J001 VER. 1.1 0006 22-DEC-95 13758.0 12473.0 11826.0 12465.0 1800.0 YES TOOL NUMBER 2330NA 1309XA 1633XA 1424XA 1424PA BOREHOLE AND CASING DATA OpEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGY' S CASING DEPTH (FT): .000 13758.0 .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): SEAWATER .00 .0 0.0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL): MATRIX: MATRIX DENSITY: .00 HOLE CORRECTION DO0 BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): .0 .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 PASS 1 (MAIN PASS). $ CN WN FN COUN STAT : ARCO ALASKA INC. : DS 13-36 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPES 64 ) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves'. Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod i GR GR 68 i GAP I 2 CCL GR 68 1 3 SPD GR 68 I F/MN 4 TTEN GR 68 i LB 5 TEN GR 68 1 LB 4 30 310 01 1 4 30 150 01 1 4 30 636 99 1 4 30 635 99 1 4 30 635 99 i 20 * DATA RECORD (TYPES 0) Total Data Records: 58 1014 BYTES * Tape File Start Depth = 11826.500000 Tape File End Depth = 12432.500000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 18515 datums Tape Subfile: 4 136 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each run in separate files; raw background pass in last file. PASS NUMBER: 3 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 11854.0 $ 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 12394.5 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACOM CENT SBT CENT VDL CENT $ CASING COLLAR LOC. GAMMA RAY ACOUSTIC COMMON CENTROLLER SEGMENTED BOND TOOL CENTROLLER VDL SUB CENTROLLER BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT): LOGGER'S 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: 21-DEC-95 FSYS REV. J001 VER. 1.1 2327 21-DEC-95 13758.0 12473.0 11826.0 12465.0 1800.0 YES TOOL NUMBER 2330NA 1309XA 1633XA 1424XA 1424PA .000 13758.0 .0 SEAWATER .00 .0 0.0 0 .0 .000 .000 .000 .0 .00 HOLE CORRECTION N). · .. BLUELINE COUNT RATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT): BASE NORMALIZING WINDOW (FT): .000 .0 .0 BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS): 0 FAR COUNT RATE HIGH SCALE (CPS): 0 NEAR COUNT RATE LOW SCALE (CPS): 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 2 (REPEAT PASS). $ CN WN FN COUN STAT : ARCO ALASKA INC. : DS 13-36 : PRUDHOE BAY : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 5 Curves-. Name Tool Code Samples Units i GR GR 68 2 CCL GR 68 3 SPD GR 68 4 TTEN GR 68 5 TEN GR 68 GAPI F/MN LB LB API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 4 30 310 01 1 4 4 30 150 01 1 4 4 30 636 99 1 4 4 30 635 99 1 4 4 30 635 99 1 2O * DATA RECORD (TYPE# 0) Total Data Records: 52 1014 BYTES * Tape File Start Depth = 11854.000000 Tape File End Depth = 12394.500000 Tape File Level SPacing = 0.250000 Tape File Depth Units = Feet. **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 16583 datums Tape Subfile: 5 130 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes Tape Subfile 6 is-type. ~IS 96/ 1/17 01 **** REEL TRAILER **** 96/ 1/17 01 Tape Subfile-. 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 17 JAN 96 8:58a Elapsed execution time = 1.15 seconds. SYSTEM RETURN CODE = 0