The URL can be used to link to this page

Home My WebLink About195-0241a. Well Status: GINJ Oil 1b. Well Class: 5 Exploratory Service BP Exploration (Alaska), Inc 14. Permit to Drill Number/Sundry 195-024 4/5/1995 4/10/1995 GL PRUDHOE BAY, PRUDHOE OIL 4a. Surface: Top of Productive Interval: Total Depth: 917' FNL, 382' FEL, Sec. 34, T11N, R15E, UM 4101' FNL, 942' FWL, Sec. 36, T11N, R15E, UM 4281' FNL, 1286' FWL, Sec. 36, T11N, R15E, UM Surface: x- y- Zone -712476 5950945 ASP 4 11. Gas SPLUG 5Abandoned 20AAC 25.105 Suspended 20AAC 25.110 WINJ WAG WDSPL No. of Completions: 3/20/2020 15. 50-029-20096-01-00 16. PBU 04-04A Well Name and Number: Surface / Surface 30.10 17. TPI:y- Zone -719172 ASP 4x-5947952 Total Depth: x-y-Zone -719520 ASP 45947782 13136' / 9132' None DNR Approval Number:19. 70-039 5. Directional or Inclination Survey: Yes No Submit electronic and printed information per 20 AAC 25.050 (ft MSL) 20.Thickness of Permafrost MD/TVD: MWD / GR, Sonic, IRT / GR CASING WT. PER FT.GRADE SETTING DEPTH MD TOP BOTTOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED Location of Well (Governmental Section): Field/Pool(s): Date Comp., Susp., or Aband.:6. Total Depth (MD/TVD): CASING, LINER AND CEMENTING RECORD TOP BOTTOM 22. SETTING DEPTH TVD 13-3/8" 9-5/8" 7" 157.5# 94# 72# 47# 29# H-40 N-80 S-95/N-80 N-80 Surface Surface Surface 11811' 2704' 12134' 12565' Surface Surface Surface 8332' 8497' 2704' 8725' 8-1/2" 12-1/4" 17-1/2" 229 sx Fondu 600 sx Fondu 1000 sx Class 'G', 350 sx PF II 700 sx Class 'G' 25. GRADE PACKER SET (MD/TVD) 26. 7" 26# x 5-1/2" 17# x 4-1/2" 12.6# L-80 11887' DEPTH INTERVAL (MD)AMOUNT AND KIND OF MATERIAL USED PRODUCTION TEST27. Date First Production: Not on Production N/A Date of Test: Flow Tubing Press Oil-Bbl: Oil-Bbl: Gas-MCF:Water-Bbl: Oil Gravity - API (corr): Method of Operation (Flowing, gas lift, etc.): Gas-Oil Ratio:Choke Size: Water-Bbl: See Attached Open to production or injection?Yes No 524. If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): B 112'39"30" 20"Surface 1190'26"1000 sx FonduSurface1190' 11763' / 8308' Gas-MCF: Production for Test Period Calculated 24 Hour Rate Hours Tested: Casing Press: 112' ACID, FRACTURE, CEMENT SQUEEZE, ETC. TUBING RECORD DEPTH SET (MD) Yes No 5Was hydraulic fracturing used during completion? Per 20 AAC 25.283 (i)(2) attach electronic and printed information ADL 028325 & 028324 319-322 Other 12. SSSV Depth (MD/TVD): Ref Elevations BF Surface (attached) KB Form 10-407 Revised 3/2020 Sr Pet Eng Sr Pet Geo Sr Res Eng STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Development Stratigraphic Test 2.Operator Name: 3.Address: P.O. Box 196612 Anchorage, AK 99519-6612 7. Date Spudded: 8. Date TD Reached: 9. 10. Plug Back Depth(MD/TVD): 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 64.00 Water Depth, if Offshore:13. N/A One API Number: Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, 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 if necessary 23. 18.Property Designation: 21.Re-drill/Lateral Top Window MD/TVD: 12565' / 8725' 1870' (Approx.) 5 Submit within 30 days of Completion, Suspension, or Abandonment 6 By Samantha Carlisle at 1:29 pm, Apr 21, 2020 Abandon Date 3/20/2020 HEW RBDMS HEW 4/22/2020 xGSFD 4/23/2020 DSR-4/23/2020MGR05MAY20 If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Permafrost - Base Formation at total depth: Contact Name:Smith, Travis T Contact Email: travis.smith1@bp.com Authorized Name:Lastufka, Joseph N Authorized Title:SIM Specialist Authorized Signature with Date:Contact Phone:+1 9075645412 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level 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. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. 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. 12578' 8732'Sadlerochit - Zone 4 Zone 4 28.CORE DATA Conventional Core(s) Yes No 5 Sidewall Cores Yes No 5 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. Well Tested? Yes 12578'8732' Top of Productive Interval 12578'8732' Form 10-407 Revised 3/2020 Submit within 30 days of Completion, Suspension, or Abandonment 30. FORMATION TESTS29. GEOLOGIC MARKERS (List all formations and markers encountered): NAME MD TVD Permafrost - Top No 5 31. Summary of Daily Work, Photo Documentation, Wellbore Schematic DiagramList 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. Joseph N Lastufka Digitally signed by Joseph N Lastufka Date: 2020.04.21 10:51:27 -08'00' WWEL L NAME:04-04A 226.Ac i d , Fr ac t u r e, Cem en t Sq u eeze, Et c . Depth Interval (MD) Amount & Kind of Material Used 2614' - 2619' Tubing / Casing Punch 1763' 110 Bbls Class 'G' 1669' - 1674' Tubing / Casing Punch 751' 192 Bbls Class 'G' 690' - 695' Tubing / Casing Punch 298' - 303' Tubing / Casing Punch Surface 104 Bbls Class 'G' Surface 1.21 Bbls SqueezeCrete Surface 4.5 Bbls AS I Daily Report of Well Operations PBU 04-04A 11/11/2019 Initial T/I/O/OOA =0/0/105/218 Temp=S/I. (LRS Unit 76 - Circ Out Well Pre Cement) Pumped 3 BBLS 60/40 & 5 BBLS DSL down TBG, to pressure TxIA to 1500, OA did not track. Bled IA to zero psi. Verify TxIA Circulation at 2 BPM @ 80 psi pumping down TBG and up IA to return tanks Pumped 6 bbsl Diesel down OA to pressure to 1200 psi. TxIA Did not track. Circ out Postponed. Casing valves OTG. FWHP=490/490/0 11/18/2019 T/I/O/OO=100/50/12/30 (LRS Unit 76 - Assist SLB Cement Crew: IA Surface Cement Job) Pump the following down the tubing, taking returns up the IA, to surface Return Tanks: 5 bbsl 60/40 spear, SLB Pumped Cement, Flushed w/63 bbls 9.8# Brine. Freeze protect w/ 6 bbls 60/40. 11/18/2019 (SLB Fullbore Pumping Crew: IA Surface Cement Job) Pump the following down the tubing, taking returns up the IA, to return tanks: 5 bbls 60/40 methanol, 10 bbls Freshwater, 110 bbls 15.8 ppg Class G Cement, 2 bbls Freshwater, 1x8" Wiper Ball. LRS pumps 63 bbls 9.8 ppg NaCl Brine, 6 bbls 60/40 meth. ***TOTAL DISPLACEMENT=2 FW + Foam Ball + 63 NaCl + 6 Meth = 71 bbls. 71 bbl/0.0383 bpf = ~1850' MD*** Lower MV Tagged, IA Casing Valve Tagged. Grease Crew called. FWHP = 700/0/0 Tubing TOC @ ~1850' MD/TVD Tubing BOC @ 2614' MD/TVD IA TOC @ Surface IA BOC @ 2614' MD/TVD 11/21/2019 ***WELL S/I ON ARRIVAL*** MIRU HES 4863 ***JOB CONTINUES ON 22-NOV-19 WSR*** 11/22/2019 T/I/O/00= 5/0/5/219, LRS Unit 46, Assist E-Line (PLUG AND ABANDONMENT) *** MIT-COMBO*** WSR continued to 11-23-19 11/22/2019 ***CONTINUED FROM 21NOV19 WSR*** STATE WITNESS (Guy Cook) TAG TOP OF CEMENT AT 1763'. LRS PERFORM PASSING MIT-T TO 2250 PSI. PUNCH THROUGH 7" TUBING AND 9-5/8" CASING @ 1669'-1674', 4-5/8" BH, 6 SPF, 45 DEG PHASE. ***JOB CONTINUES ON 23NOV19 WSR*** 11/22/2019 T/I/O/OO=0/3/9/227 LRS unit 46 ***ASSIST HALIBURTON ELINE*** (PLUG AND ABANDONMENT) Pre state witness MIT T **PASSED** to 2437 psi. Max applied pressure 2500psi, Target pressure 2250 psi. Pumped 1.6 bbls 60/40 (Methanol) down TBG to reach test pressure. 1st 15 min TBG lost 20 psi. 2nd 15min TBG lost 13 psi. Total 30 min loss of 33 psi, Bled back 1 bbl. AOGCC MIT-T to 2492 psi PASSED. Pumped 1.2 bbls 60/40 meth. Tbg lost 83 psi in 1srt 15 mins and 40 psi in 2nd 15 mins for a total loss of 123 psi in 30 min test. PASS. Bled Tbg to 0 psi and got back ~1.1 bbls. ELine in control of well per LRS departure. FWHP's=0/3/2/223 IA,OA,OOA=OTG Daily Report of Well Operations PBU 04-04A 11/23/2019 ***CONTINUED FROM 22NOV19 WSR*** RDMO ELINE ***JOB COMPLETE*** 11/23/2019 T/I/O/OO= 5/0/5/219, LRS Unit 46, ****WSR continued from 11-22-19***** Assist E- Line (PLUG AND ABANDONMENT) Pumped 7.5 bbls 60/40 meth on multiple attempts to see communication from Tbg to OA. Didn't see communication. Left 1000 psi on Tbg to see if slow commincation will happen. ELine in control of well per LRS departure. FWHP's=1000/2/130/230 IA,OA,OOA=OTG 11/24/2019 T/I/O/OO=80/100/200/250. (LRS unit 76 - Check TBG/OA communication) Pumped a total of 1.2 bbls 60/40 down TBG to check OA communication. Attempted to get communication by maintaining 2400 psi to tbg. After ~ 3 hours communication estabished between TBG/OA. Pumped 65 bbls of 180* F diesel down TBG taking returns up the OA to OT tank. Followed diesel with 65 bbls of 180* brine down TBG taking returns up the OA to OT tank. Freeze protected surface line with 1 bbl 60/40 meth. Pumped 50 bbls of 120* F F103 Surfactant followed by 180 bbls of 100* 9.8 brine down TBG up the OA out to OT tank at 5 bpm. Freeze protected TBG with 12 bbls 60/40 and U-tubed into OA. ***Continued on 11/25/19*** 11/25/2019 ***Continued from 11/24/19*** (LRS unit 76 Freeze protect surface lines) Flushed surface lines from choke trailer to OT tank with 4 bbls 60/40 meth. RDMO. IA/OA/OOA=OTG. Swab/Companion=Shut. FWHP=40/100/40/100 11/26/2019 T/I/O/OO= 15/20/0/415 (LRS unit 76 - Assist cement crew) Pumped 5 bbls 60/40 to verify circulation down TBG up the OA to OT tank. Displaced cement with 25 bbls 9.8 brine down TBG taking returns up the OA to OT tank followed by 4 bbls 60/40 meth. Flushed washout loops on well and surface lines through choke trailer to OT with 9 bbls 60/40 meth. RDMO. **OA=Shut and flagged**, IA/OOA=OTG Swab/MV=Shut. FWHP=10/0/0/350 11/26/2019 SLB Cementing - Surface T x OA Cement Plug (PLUG AND ABANDONMENT) Pumped the following down TBG with OA returns to OTT: LRS pumped 5 bbls 60/40 to establish circulation, SLB pumped 10 bbls Freshwater spacer, 192 bbls 15.8 PPG Class G Cement, 2 bbls Freshwater flush, dropped foam ball, LRS displaced with 25 bbls 9.8 PPG NaCl, 4 bbls surface FP. Total displacement = 31 bbls. ***LRS in control of well upon departure*** TBG TOC = 800' MD, OA TOC = Surface TBG / OA BOC = 1670' MD 12/3/2019 T/I/O/OO=0/0/100/350 LRS unit 46 assist E-Line W/ AOGCC MIT-T (PLUG AND ABANDONMENT) Road unit to location/ Spotted Equipment/ PJSM *** WSR continued on 12/04/19*** 12/3/2019 ***WELL SHUT IN ON ARRIVAL***(perf) RIG UP E-LINE ***JOB CONT ON 12/4/19 WSR*** 12/4/2019 ***CONT FROM 12/3/2019 WSR***(perf) PERFORM PASSING STATE WITNESSED MIT-T(see lrs wsr). STANDBY ON WINDS. ***CONT ON 12/5/19 WSR*** Daily Report of Well Operations PBU 04-04A 12/4/2019 *** WSR coninued from 12/03/19*** LRS unit 46 assist E-Line W/ AOGCC MIT-T ***PASSED*** (PLUG AND ABANDONMENT) Pre- AOGCC MIT-T PASSED to 2333 psi. Max applied Pressure=2500 psi Target Pressure=2250 psi. Pressure TBG to 2493 psi with 1.02 bbls of 60/40 meth. MIT-T lost 109 psi in the 1st 15 minutes and 51 psi in the 2nd 15 minutes for a total loss of 160 psi during a 30 minute test. Bled TBG to 18 psi recovering ~ .6 bbls. Pumped 2 State Witness FAILing MIT-Ts (SEE LOG). RD from CT. RU to ELine PAS. Pumped 2 PASSING practicing MIT-Ts (SEE LOG). Pumped .5 bbls 60/40 meth down Tbg for State Witnessed AOGCC MIT-T to 2385 psi ***PASS*** Took Tbg to 2503 psi. Tbg lost 85 psi in 1st 15 mins and 33 psi in 2nd 15 mins for a total loss of 118 psi in 30 min Test. PASS State Witnessed by Adam Earl. HEL in control of well upon LRS deparutre. CV's= OTG Tags hung. FWHP's - 1/2/70/400 12/5/2019 ***CONT FROM 12/4/2019 WSR***(adperf) TAG TOC AT 751' ELMD W/ 2 1/2" SAMPLE BAILER, CEMENT SAMPLE IN BAILER. PEFORATE 690'-695' WITH 2.125" DEEPSTAR MILLENIUM CHARGES, 6SPF, O DEG PHASED, DECENTRALIZED. CCL TO TOP SHOT OFF SET 6', CCL STOP DEPTH 684'. ***WELL SHUT IN ON DEPARTURE*** 12/5/2019 T/I/O=330/-8/85/375 Temp= S/I (LRS Unit 42- Assist E-line with Injectivity test/Plug and Abandonment) Pumped 1.7 bbls 60/40 down TBG up OOA to establish small communication after EL shot perfs, then pumped 3.3 bbls 60/40 down TBG up OOA to open top tank, TBG pressure increased to 2000 psi and OOA had ~50-90 psi and saw minimal returns to tanks. Never could get constant injection rate. E-line rigged down. Pumped 3 bbls 60/40 to flush surface lines from OOA to OT tank. Heated diesel on unit tanks to 90* and pumped 2 bbls down surface lines to get cold 60/40 clear. Pumped 0.3 bbls 90* diesel down OOA and bled to OT tank multiple times trying to clear annulus. Pressured up and worked TBG with 12.8 bbls 80* F diesel attempting to establish communication. TBGP rose and fell while pumping down TBG at min rate. TBGP fell off after shut down. Possibly filling voids downhole. OOA max 1200 psi per WSL Miles Shaw. Pressured up OOA with 0.45 bbls diesel to 1150 psi. No communication to TBG. Bled OOA to OT. ***Continued on 12/6/19*** 12/6/2019 ***Continued from 12/5/19*** Worked well by pumping 90* diesel down TBG trying to establish communication through perf to OOA. Pumped 30 bbls 90* diesel down TBG.While pumping at min rate TBGP would come up and down indicating some break through to voids possibly but no clear communication to OOA. TBGP broke over and started to establish LLR ~0.38 bpm @ 1400 psi. See log for details. Pumped an additional 20 bbls of 180* diesel down TBG @ ~0.4 bpm @ ~ 1100 psi to warm up well and try to establish communication with OOA Per WSL Miles Shaw. No communication established to OOA. Pumped a total of 2.45 bbls 90* diesel down OOA pressuring up to 1200 psi , letting soak and bleeding OOA to OT tank, pumped .50 bbls each time. Saw no indication of communication to TBG. Flushed all surface hardline to OT tank with 4 bbls diesel. Double swab valves closed, MV closed, IA OA OOA OTG. Final Whp's= 508/vac/91/0 Daily Report of Well Operations PBU 04-04A 12/7/2019 T/I/O/OO=500/0/0/120 Temp=SI (Plug and Abondonment) Attempt to Pump down OOA w/ 0.5 bbsl 80* Diesel before pressuring to 1000 psi. Pumped a total of 3.2 bbls 90* diesel down OOA pressuring up to 1000 psi , letting soak and bleeding OOA to OT tank, pumped .30 bbls each time. Saw no indication of communication to TBG Double swab valves closed, MV closed, IA OA OOA OTG FWHP=500/0/0/0 12/10/2019 T/I/O/OO = 480/VAC/90/70. Temp = SI. WHPs (FB request). Dryhole P&A tree installed. SV, MV = C. IA, OA, OOA = OTG. 10:00 12/12/2019 ***WELL SHUT IN ON ARRIVAL***(hes eline - perf) MIRU ELINE. ***CONT ON 12/13/19 WSR*** 12/13/2019 T/I/O/OO= 450/0/85/0 (LRS Unit 42: Circ-Out - Plug and Abandonment) Rigged up and loaded fluid ***WSR Continued on 12/14/2019*** 12/13/2019 ***JOB CONT FROM 12/12/19 WSR***(perf) PERFORATE FROM 297.5'-302.5' W/ 2.125", 6 SPF, 0 DEGREE PHASED DEEP STAR STRIP GUN LOADED W/ 2.125" MILLENIUM CHARGES. ***WELL TURNED OVER TO DSO*** 12/14/2019 T/I/O/OO = 310/0/90/330. Temp = SI. Cellar watch (Assist with circ out). Vac truck on location evacuating clear fluid from conductor (~every 10 min) post circ out. Blue goo has come out of the conductor and into the secondary containment (~1/2 gal). Currently monitoring WHPs and assisting with vac out conductor (~every 25 min, clear fluid), 15 bbls total at 23:59 Cont on 12/15/19 12/14/2019 ***WSR Continued from 12/13/2019*** Pumped 5 bbls of Diesel down TBG, up the OOA, into the Open Top Tank to confirm communication between TxOOA Heated 9.8 ppg Brine Upright Tank #072 to 120* for upcoming well work Circulated 50 bbls of 180* diesel and 12 bbls of 120* 9.8 brine down TBG up OOA over to OT tank. Monitored Micro Motion for return rates and temps. (see log, did not get 1:1 returns). Let soak for 1hr. Pumped 49 bbls of 120* Surfactant with 2gal/mgal F103 and 2 gal/mgal U067 followed by 116 bbls of 120* 9.8 ppg brine down TBG up OOA to OT tanks. Monitored Micro Motion for returns. (see highly detailed log - unsuccessfully adjusted rate to see if could establish 1:1 returns). 48 bbls brine away, FW in conductor thawed and needed to be continually vac'd out. Pumped 4 bbls 60/40 down OOA up TBG to OT, pumped 1 bbl 60/40 down TBG up OOA to OT to leave 3 bbls in OOA (~18') and 1 bbl in TBG (~26') for freeze protect. Freeze protected surface lines with a total of 6 bbls 60/40. DHD and vac truck on location vacing conductor as needed. Choke Trailer SI - Hardline to tree SI - SV, SV= SI - CVs OTG Tags hung Final WHP= 308/0/97/330 Daily Report of Well Operations PBU 04-04A 12/15/2019 Cont from 12/14/19 T/I/O/OO = 310/0/90/320. Temp = SI. Cellar watch (Assist with circ out). Vac truck on location evacuating clear fluid from conductor (post circ out). Blue goo has come out of the conductor and into the secondary containment (~1/2 gal). Currently monitoring WHPs and assisting with vac out conductor (28 bbls total at 23:59). Cont on 12/16/19 12/16/2019 Cont from 12/15/19 T/I/O/OO = 200/0/90/320. Temp = SI. Cellar watch (Assist with circ out). Vac truck on location evacuating clear fluid from conductor (post circ out). Blue goo has come out of the conductor and into the secondary containment (~1/2 gal). Currently monitoring WHPs and assisting with vac out conductor. 40 bbls total at 23:59. *** Continue on next day WSR *** 12/17/2019 *** Continued from previous day WSR *** T/I/O/OO = 200/0/90/320. Temp = SI. Cellar watch (Assist with circ out). Vac truck on location evacuating clear fluid from conductor (post circ out). Blue goo has come out of the conductor and into the secondary containment (~1/2 gal). Currently monitoring WHPs and assisting with vac out conductor. Total of 41.5 bbls in 3 days. Final WHPs = 200/0/90/320. SV, MV = C. IA, OA, OOA = OTG. 05:30 12/18/2019 T/I/O = SV/0/90/300. Temp = SI. WHPs (Eval Conductor Flow). No wellhouse or flowline. Flow cross installed on top of second SV. Kelley hose rigged from flow cross to OOA & reverse out skid. Conductor has overflown with clear fluid and frozen. The sombrero that was installed around the conductor has filled with ice and fallen off. The high temp plastic surrounding the conductor has been dislodged in the wind. Will need to return when the wind dies down. Upper SV = C. Lower SV = C. IA, OA, OOA = OTG. 14:30 12/19/2019 T/I/O = SV/0/90/300. Temp = SI. WHPs (Eval conductor flow). No Wellhouse, flowline or AL. Temporary scaffolding rigged installed. Size and amount of glaciation has not changed since 12-18-19. Removed old visqueen and sombrero. Installed new visqueen. Upper SV = C. Lower SV = C. IA, OA, OOA = OTG. 10:00 12/19/2019 SLB Cementing Services Job Scope: T x OOA cement P&A from 300' to surface. RU SLB cement pump on TBG and pumped the following. 10 bbls FW spacer, 104 bbls of neat 15.8 ppg Class G cement taking returns from OOA. Good cement at surface in OOA. Block in casing valve at OOA & Swab valves. Wash up surface lines. RDMOL **Job Complete** 15.8 ppg Class G Cement in TBG and OOA TOC in TBG/OOA = Surface BOC in T/ OOA = 300' MD 12/20/2019 T/I/O/OO = 0/0/30/0. Temp = SI. Assist Special Projects (Eval fluid in conductor). Vac truck on location. Clear fluid is coming out of the conductor. The conductor is almost 100% covered in ice. Vac truck is evacuating fluid from secondary containment in cellar. Unable to estimate fluid amount on vac truck at this time. SV, MV = C. IA, OA, OOA = OTG. 02:45 12/22/2019 T/I/O=0/0/0. Pre P&A Excavation. RD 3" McVoy I/A valve. RU 3" 5000 integral. Torqued to API spec. RD 2" O/A Gray valves. RU 2" 5000 integral. Torqued to API spec. Job Complete. See log. Final WHP's 0/0/0. Daily Report of Well Operations PBU 04-04A 12/23/2019 T/I/O/OO = ?/?/0/?. Temp = SI. OA FL (SCE&R call in). No wellhouse, flowline, AL or scaffolding. Casing valves are removed. OA FL @ 120' (7 bbls). All wellhead strings are cemented. SV, MV = ?. No IA or OA casing valves. SCE&R left in control of all valves. 1/9/2020 T/I/O/OO = 0/0/0/270 Temp + S/I WHP (SP request) Dryhole P&A tree installed. TOC in OA @ 131' = ~22.9 bbls OOAP stable @ 280 psi for 48hrs Swapped mechanical gauge for Annolog to monitor pressure build up. Reading on gauge 270 psi Prior weekhistory 12/30/2020 OOA valve was removed and crew began preping OOA for cut. During process team stated getting variable solids mixed with fluids returned to surface, After 24 hrs the solid content cleaned up and started measuring the fluid volume returned. Crude was returned at first and once it cleared up samples were recoved and delivered to the GPB lab. The last sample was reported to have a high Cloride content. Below is the time table and recovery volumes during open bleed. 1/1/2020 @ 17:30 0 gal Start 1/2/2020 @ 03:00 4 Gal 1/2/2020 @ 11:00 4 Gal 1/3/2020 @ 20:00 4 Gal 1/4/2020 @ 6:00 4 Gal 1/4/2020 @ 15:45 4 Gal -36° 1/5/2020 @ 00:30 4 Gal .-39° 1/5/2020 @ 10:30 4 Gal .-42° 1/5/2020 @ 20:30 4 Gal .-40° 1/6/2020 @ 6:45 4 Gal .-47° All Clear Fluid at this point. 1/6/2020 @ 15:25 4 Gal .-41° 1/7/2020 @ 3:12 4 Gal .-43° 1/8/2020 @ 10:00 4 Gal Shut in returns from OOA and released Vac unit. Total recovery was 5 bbls 1/11/2020 Bleed OOA and hold open bleed on OOA. Cont on WSR 1/12/20 1/12/2020 ***Cont from WSR 1/11/20*** Hold open bleed on OOA and monitor returns. 33.5 gallons total volume of brine and trace crude collected to date. ***comtinued on 1/13/20*** 1/13/2020 ***Cont from 1/12/20*** Hold open bleed on OOA and monitor returns. 45.86 gallons total volume of brine and trace crude collected from 8 AM on 1/11/2020 to 5 PM on1/13/2020. ***Comtinued on 1/14/20*** 1/14/2020 Perform BUR over night (18 psi). Hold open bleed on OOA returning 18 gallons since 06:45 on 1/14 2020. ***Continued on 1/15/20*** 1/15/2020 ***Continued from 1/14/20*** Maintained open bleed on OOA and monitor returns for 24 hrs, returning 16.26 gallons of fluid. Daily Report of Well Operations PBU 04-04A 1/16/2020 ***Continued from 1/15/20*** Maintained open bleed on OOA and monitor returns for 24 hrs, returning 14.5 gallons of fluid. ***Continued on 1/17/20*** 1/17/2020 ***Continued from 1/16/20*** Maintained open bleed on OOA and monitor returns for 5 hrs, returning 3 gallons of fluid. Removed sweep 90° and installed 1502 cap with gauge (24-581). 1/19/2020 Bleed OOA to 0 psi, collect sample (pre P&A). OOA FL @ surface. Obtained sample. Bled OOAP from 137 psi to 0+ psi in 2 min (9.04 gallons). Monitored for 30 min. OOAP unchanged. Final OOAP = 0+. OOAP = OTG. 00:30 1/21/2020 T/I/O/OO = ?/?/?/155. Temp = SI. WHPs (post bleed). No wellhouse, flowline, AL or scaffolding. Casing valves are all removed. All wellhead strings are cemented. Heaters on wellhead working properly. SV, MV = ?. No IA or OA casing valves, OOA = OTG. 14:00 1/24/2020 *** Maintain Open Bleed On OOA ***. Maintained open bleed on OOA for 8 hrs, Returning 16.3 gal of fluid. 1/25/2020 *** Maintain Open Bleed On OOA ***. Maintained open bleed on OOA for 11.5 hrs, returning 7 gallons of fluid. 1/26/2020 *** Maintain Open Bleed On OOA ***. Maintained open bleed on OOA for 12 hrs, returning 7.5 gallons of fluid. 1/27/2020 *** Maintain Open Bleed On OOA ***. Maintained open bleed on OOA for 10 hrs, returning 5 gallons of fluid. 1/28/2020 *** Maintain Open Bleed On OOA ***. Maintained open bleed on OOA for 6 hrs, returning 3.5 gallons of fluid. 1/29/2020 *** Maintain Open Bleed On OOA ***. Maintained open bleed on OOA for 11 hrs, returning 5 gallons of fluid. 1/30/2020 *** Maintain Open Bleed On OOA ***. Maintained open bleed on OOA for 12 hrs, returning 5 gallons of fluid. 1/31/2020 *** Maintain Open Bleed On OOA ***. Maintained open bleed on OOA for 11 hrs, returning 5 gallons of fluid. 2/1/2020 *** Maintain Open Bleed On OOA ***. Maintained open bleed on OOA for 10 hrs, returning 4.5 gallons of fluid. 2/2/2020 *** Maintain Open Bleed On OOA ***. Maintained open bleed on OOA for 4 hrs, returning 2 gallons of fluid. 2/3/2020 *** Maintain Open Bleed On OOA ***. Maintained open bleed on OOA for 9 hrs, returning 4 gallons of fluid. 2/4/2020 *** Maintain Open Bleed On OOA ***. Maintained open bleed on OOA for 10 hrs, returning 4 gallons of fluid. 2/5/2020 *** Maintain Open Bleed On OOA ***. Maintained open bleed on OOA for 10.5 hrs, returning 4.5 gallons of fluid. 2/6/2020 *** Maintain Open Bleed On OOA ***. Maintained open bleed on OOA for 9.5 hrs, returning 4 gallons of fluid. 2/7/2020 *** Maintain Open Bleed On OOA ***. Maintained open bleed on OOA for 5 hrs, returning 2 gallons of fluid. 2/8/2020 Maintain open bleed on OOA. Collected sample of fluid discharging from OOA. Tracked amount of fluid discharged. Returned 4.51 gallons in 10 Hrs. 2/9/2020 Returned 4.74 gallons in 13.5 hrs (overnight). Hold open bleed on OOA. Returned 2.23 gallons in 10 hrs. Daily Report of Well Operations PBU 04-04A 2/10/2020 Returned 4.3 gallons in 14.5 hrs (overnight). Hold open bleed on OOA. Returned 3.44 gallons in 10 hrs. 2/11/2020 Returned 4.3 gallons in 13 hrs (overnight). Hold open bleed on OOA. Returned 3.28 gallons in 10 hrs (days). 2/12/2020 Returned 2.25 gallons in 13 hrs (overnight). Hold open bleed on OOA. Returned 3.02 gallons in 10 hrs (days). 2/13/2020 Returned 3 gallons in 14 hrs (overnight). Hold open bleed on OOA. Returned 3.44 gallons in 11 hrs (days). 2/14/2020 Returned 4.31 gallons in 13 hrs (overnight). Hold open bleed on OOA. Return 4.03 gallons in 11 hrs (days). 2/15/2020 Returned 4.3 gal overnight (nights). Hold open Bleed on OOA. Had drum emptied during night Returned 3.44 gallons in 10 hrs (days). 2/16/2020 Returned 3.87 gallons in 14 hrs (over night). Hold open bleed on OOA. Returned 3.34 gallons in 10 hrs (days). 2/17/2020 Returned 4.73 gallons in 14.5 hrs overnight). Hold open bleed on OOA. Returned 2.15 gallons in 9.5 hrs (days). 2/18/2020 Returned 6.03 gallons in 13.5 hrs (overnight). Hold open bleed on OOA. Returned 1.72 gallons in 10.5 hrs (days). 2/19/2020 Returned 3.44 gallons returned in 12.5 hrs (over night). Had drum emptied at night. Hold open bleed on OOA. Returned 3.1 gallons in 11 hrs (days). 2/20/2020 Returned 5.08 gallons in 14 hrs (overnight). Hold open bleed on OOA. Returned 2.15 gallons in 9.5 hrs (days). 2/22/2020 Returned 3.44 gallons in 12 hrs (overnight). Hold open bleed on OOA. Returned 3.86 gallons in 11.5 hrs (days). 2/23/2020 Returned 3.44 gallons in 12 hrs (overnight). Hold open bleed on OOA. Returned 2.8 gallons in 9.5 hrs (days). 2/24/2020 Returned 4.5 gallons in 14 hrs (overnight). Hold open bleed on OOA. Returned 2.37 gallons in 9.5 hrs (days). 2/25/2020 Returned 4.09 gallons in 13 hrs (overnight). Hold open bleed on OOA. Returned 2.58 gallons in 10 hrs (days). Bakerlock threaded union on OOA for upcoming cement job. SI OOA bleed with 300 psi gauge installed. 2/26/2020 Adjust visqueen around well head. OOA jewelery not covered after drum was evacuated on night shift. OOAP increased 5 psi after visqueen covered jewelery. Continue monitoring throughout day shift for OOAP increase. 2/28/2020 Job Scope: OOA Inj test. SI casing pressure on OOA 180 psi. 5 min injectivity test w/ 9.8 brine .64 gpm @ 900 psi. Final OOAP 290 psi 2/29/2020 Job Scope: Locate TOC in OOA Bled OOA from 230 psi (4.8 gallons in 45 seconds. Monitor 1 hour. Removing casing valve and tag TOC @ 1'. Unable to tag line, wire, or hose w/ chain weight deeper than 1' in either side of OOA wellhead outlet. Snow removal and build hooch for cementing operations. 3/1/2020 Job Scope: Remove OOA jewelery & replace with new jewelery. Cleaned threads on wellhead & baker locked new jewelery on OOA outlet. 3/3/2020 Job Scope: Cement OOA leak w/ 14 ppg Sqzcrete pumped a total of 1.2 bbls. .6 bbls to displace free water, .21 bbls to achieve max pressure 1000 psi, and additional .4 bbls sqz'd away to achieve final sqz pressure of 1000 psi. Held 30 mins. Final presssure 960 psi. *** 0pen OOA to gauge 3/4/20 @ 8 am - zero pressure*** 3/6/2020 Job Scope: Check cemented OOA. Cement @ the 6 o'clock position is set up, the cement @ the 12 o'clock position is more water then cement @ this time. Daily Report of Well Operations PBU 04-04A 3/7/2020 Job Scope check cement. 6 O'clock OOA port cenent 0 psi and has cement to surface. 12 O'clock OOA port had 80 psi on it bled to 0 psi in 2 minutes along with gas cap(sample taken). Remove 1/4 turn valve and found solid cement on bottom 1/2 and broken pieces on top 1/2 of void. 3/8/2020 Hold open bleed on OOA. SI for 16 hrs 1 psi, open 1/4 turn and bleed to 0 psiin ~1 minute returning 4.3 gallons. Held open bleed for 9 hrs returning 4.3 gallons. 0.86 total returns for the day. 3/9/2020 Hold open bleed on OOA. Left well shut in over night (15 hrs) 0 psi on it at 0800 hrs bled off ~1cup fluid and hend open bleed for 11 hrs with very slow drip. Vaced fluid out of conductor returning 2.50 gallons. 3/10/2020 Hold open bleed on OOA. Left shutin over night (13 hrs), open 1/4 turn valve @ 06:30 with no pressure on OOA and got very little fluid returns (~1/4 cup). 3/11/2020 Start excavating cellar did not finish will continue tomorrow, Cover hole with rig mats. 3/12/2020 Excavate celler for P&A 66" from bottom of tundra, 9' 5" over all depth 14' wide by 14' long. Cover cellar with rig mats. 3/16/2020 Set shoring box in excation and set saw for cut. 3/17/2020 Cut wellhead 3' 6" below tundra, Started at 11:20 AM completed cut at 1:40 PM prep for top job cement in all Csg strings to surface. OA measured at 86'. 3/18/2020 OA top job. Fill OA using SLB cementers . Tagged top of cement with plumb bob @ 86'. Top fill OA with~4.5 bbls 15.7 ppg AS1 cement. Sample left in bucket by shoring box. 3/21/2020 AOGCC Inpspection after surfcae cement top-off. Inspected by A. Earle. Note 3 seeps of water from conductor through very hard cement. Not permitted to weld on cap. Must have BP town Eng contact AOGCC Eng. to discuss. 3/22/2020 **P&A***. Used vac truck to remove ~ 30 gal of fluid from spill containment around conductor. Welded top cap onto the conductor & pictures taken. Will monitor for 7 days before backfill. MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg� ��(z DATE: 3/29/2020 P. I. Supervisor FROM: Guy Cook SUBJECT: Surface Abandonment - Final Petroleum Inspector PBU 04-04A BPXA , PTD 1950240; -Sundry 319-322 3/29/2020: 1 arrived on location and met with Rob Liddelow (BPXAO and we talked about the well. The marker plate was previously welded to the cutoff well (3/20/2020), but burial was held for leak monitoring. When I looked into the cellar, I could see no signs of fluid anywhere around the casing. The ground was frozen with little to no snow coverage, so fluid would have been obvious if it had been present. I gave the go ahead to bury abandoned well PBU 04-04A. Attachments: Photos (6) 2020-0329_Surface_Abandon_Final _PBU_04-04A gc.doex Page 1 of 4 �•; r�1' -":.. gib' � I L� �rtr dw •; • `Y I a 4 ►� aa 1 � � '� .�` ��"�,�•�.: � yam: "7 ! a MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg ,\ 3131,7 DATE: March 23, 2020 P. I. Supervisor FROM: Brian Bixby SUBJECT: Surface Abandonment Petroleum Inspector PBU 04-04A - BP Exploration PTD 1950240; Sundry 319-322 3/23/2020: 1 arrived at PBU 04-04A and got with Arvell Bass (BPXA Wells Group) to inspect the marker plate. I verified the correct information on the marker plate. The marker plate was welded to the cut-off well prior to my arrival. Photos provided by Mr. Bass show the cutoff with cement to surface, the marker plate information, and the weld. Attachments: 3 Pictures ' Supervisor's Addendum: AOGCC Inspector Adam Earl confirmed solid cement to surface for all strings of pipe on 3/19/2020 but observed water seepage from the cemented conductor (video taken; filed in electronic well file). AOGCC allowed BPXA to weld the marker plate to the well by email dated 3/20/2020 but required the well to remain unburied for 7 days to monitor for water seepage. 2020-0323_Surface_Abandon_PBU _04-04A_bb. docx Pagel of 3 Surface Abandonment — PBU 04-04A (PTD 1950240) Marker Plate Information Photos courtesy of BPXA 3/23/2020 Cement to surface Marker plate info 2020-0323_Surface_Abandon_PBU_04-04A_bb. docx Page 2 of 3 Plate welded conductor 2020-0323_Surface_Abandon_PBU_ 04-04A_bb.docx J3 Page 3 3 MEMORANDUM TO: Jim Regg I �q'Z 71101 tq P.I. Supervisor FROM: Adam Earl Petroleum Inspector Section: 34 Township: Drilling Rig: n/a Rig Elevation: Operator Rep: Nathan Williams Casing/Tubing Data (depths are MD): Conductor: 30" , O.D. Shoe@ Surface: 20" , 0. D. Shoe@ Intermediate: 13 3/8" , 0. D. Shoe@ Production: 9 5/8" , 0. D. Shoe@ Liner: 7" ' 0, D. Shoe@ Tubing: 7"x5.5"x4.5"'O.D. Tail@ Plugging Data: Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: December 5, 2019 SUBJECT: Well Bore Plug & Abandonment PBU 04-04A ' BPXA PTD 1950240; Sundry 319-322 11N Range: 15E Meridian: Umait n/a Total Depth: 13,136 ft MD Lease No.: ADL028325 Suspend: P&A: X 112 - Feet 1190 - Feet 2704 - Feet 12134 - Feet 12565 Feet 11887 Feet Type Plug Casino Removal: Csg Cut@ na Feet Csg Cut@ na Feet Csg Cut@ na Feet Csg Cut@ na Feet Csg Cut@ na Feet Tbg Cut@ na Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Fullbore - Balanced 2600 ft MD 751 ft MD Wireline tag OA 72 72 - 72 P OOA 417 417 418 Initial 15 min 30 min 45 min Ramd} Tubing 2503 2418 2385 IA 0 0 0 OA 72 72 - 72 P OOA 417 417 418 Remarks: On 12/4/19 1 traveled out to PBU 04-04A to witness a wire line tag and MIT -T for the abandonment plug. The weather was building fast and it was decided the tag would have to wait until the winds were back to 30mph or less. The Pump truck was rigged up through a choke trailer and several leak paths came into play. We attempted the test twice before they rigged up directly into the pump -in sub below the wireline's lubricator. The Tubing pressure test went as per chart above. I returned early the next morning (12/5/19) to witness the plug tag. Tool string was two weight bars, spangs, and a bailer, giving 325lbs down weight. TOC was tagged @ 751 ft inside the tubing; the tubing -casing and casing -casing annuli were cemented to surface. A good sample of hard cement was in the bailer. Attachments: none , rev. 11-28-18 2019-1205_Plug_Verification_PBU_04-04A_ae.docx MEMORANDUM TO: Jim Regg I`ep 1q t('7 P.I. Supervisor / FROM: Guy Cook Petroleum Inspector Section: 34 Township: Drilling Rig: N/A Rig Elevation: Operator Rep: Brenton Nicholson Casing/Tubing Data (depths are MD): Conductor: 30" O.D. Shoe@ Surface: 20" O.D. Shoe@ Intermediate: 13 5/8" O.D. Shoe@ Production: 9 5/8" O.D. Shoe@ Liner: 7" O.D. Shoe@ Tubing: 7" x 5.5 x 4.5"O.D. Tail@ Plugging Data: Test Data: Remarks: State of Alaska Alaska Oil and Gas Conservation Commission DATE: November 22, 2019 SUBJECT: Well Bore Plug Verification PBU 04-04A - BPXA PTD 1950240; Sundry 319-322 11N Range: 15E Meridian: Umiat - N/A Total Depth: 13136 ft MD Lease No.: ADL0028325 Suspend: P&A: X - 112 - Feet 1190 - Feet 2704 - Feet 121352 - Feet 12565 - Feet 11887 Feet Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet Type Plug Founded on Depth Btm Depth To MW Above Verified Fullbore Balanced 2614 ft MD, 1763 ft MD' 9.8 ppg Wireline tag 3 3 - P OOA 223 223 223 Initial 1 S min sn min dF min Tubing 2492 2409 2369 ' IA 4 4 - 4 - OA 4 3 3 - P OOA 223 223 223 I arrived on site and met with Brenton Nicholaus with BPXA. We discussed the job and I had them add 100 lbs to their toolstring, giving them approximately 300 lbs of weight to acquire a sample. I also had them swap their 1.75 -inch drive -down bailer with a ball valve to a 3 -inch drive -down bailer with a flapper valve. They tagged to top of cement at 1763 ft MD wireline on the first run and retrieved a sample of fully cured cement. After the passing MIT -T, they tagged again at 1763 ft MD wireline. The MIT -T was performed with a Little Red Services pump truck with current calibrated gauges and 60/40 methanol -water mix. This well has an OOA and during the entire test the pressure on the OOA stayed at 223 psi. BBLS in = 1.2; BBLS out = 1.1 Attachments: None rev. 11-28-18 2019-1122_Plug_Verification_PBU_04-04A_gc THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Travis Smith Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU 04-04A Permit to Drill Number: 195-024 Sundry Number: 319-322 Dear Mr. Smith: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.00gcc.alaska.gov Enclosed is the approved application for the 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC 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, �zcj�" Jessre L. Chmielowski Commissioner DATED this -1 day of October, 2019. RBDMS!LVLV OCT 0 71019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 REGENEU 1. Type of Request Abandon 0 Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown.❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program,fl Plug for Redrill ❑ Perforate New Pool ❑ Reenter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4, Current Well Class: Exploratory ❑ Development 0 5. Permit to Drill Number: 196-024 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stretigrephic ❑ Service ❑ 8. API Number: 50-029-20096-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 04-04A 9. Properly Designation (Lease Number): 10. Field/Pools: ADL 028325'& 028324 PRUDHOE BAY, PRUDHOE OIL ' 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (a): Total Depth TVD(fi): Effective Depth MD: Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 13136 -J3?ry ( 10156 7485 10156.11814 12579 Casing Length Size MD TVD Buret Collapse Structural Conductor 80 30" 32-112 32-112 880 Surface 1159 20" 31-1190 31-1190 1530 520 Intermediate 1 2675 13-3/8" 29-2704 29-2704 5380 2870 Intermediate 12107 9-5/8" 27-12134 27-8497 815017510/6870/9140 5080/4130/4760/7330 Liner 754 7" 11811 - 12565 8332.-8725 8160 1 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12565- 13135 8725 - 9131 7" 26# x 5-1/A' 17# x 4-1/2" 12.6# L-80 24-11887 Packers and SSSV Type: 5-1/Y Baker SB -3 Packer Packers and SSSV MD (ft) and TVD (ft): 11763/8308 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stretigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: July 18, 2019 15. Well Status after proposed work: Oil ❑ Vow ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name. Smith, Travis T be deviated from without prior written approval. Contact Email: travis.smithlCZIbp.com Authorized Name: Smith, Travis T Contact Phone: +1 907 564 5412 Authorized Title: Engi er Authorized Signatu Date: COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: ^ I - s ^ - 'L / Plug Integrity l7/ BOP Test ❑ Mechanics) Integrity Test O� Location Clearance Other- Pj d T� dor— I/I'✓•'/e #1.� C&. 5' dEsc.ri6Bof �S®MSS'' 0� 0 7 tuts Post Initial Injection MIT Req'd? Yes No ❑/. Spacing Exception Required? Yes ❑ No L3 Subsequent Form Required. l6 - ye - APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: LD y 'C� 1 ORIGINAL 144,e©96C�r7,P 76,,�O Submit Form and Form 10-003 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate by "Alll 04-04A P&A: Surface Plug Intervention Engineer Travis Smith (907) 564-5412 Production Engineer Meredyth Richards (907) 564-4867 Expected start date: July 1811, 2019 History 04-04A was completed in 1971 with a Gen 1 wellhead and three string casing design. The outer casing string is set in permafrost. GWO has determined that these wells are at risk for sudden wellhead movement, as demonstrated by 02-03A and 02-02A. As such, the AOGCC has requested this well be plugged and abandoned to mitigate HSSE consequence associated with this potential risk. The first cement plug was pumped on April 30, 2019. On May 12, 2019 this plug was tagged with a TOC at 10,156' SLM and passed a CMIT-TxIA to 2500 psi. This well is a contingent option for a rig decompletion of a 02-02A three -string analog well. Objective Place surface cement plugs in the wellbore. Excavate and cut casings 3' below original tundra level and install marker cap. Procedural steps Relay or E -line / Fullbore 1. Perforate at 2,600' MD through 7" tubing and 9-5/8" casing. 2. Establish returns pumping down the tubing to both the IA and OA. 3. Pump surfactant wash to remove hydrocarbon from OA. Pump the following schedule down the tubing, taking returns from the OA at maximum pump rate with a 2500 psi maximum pump pressure. ➢ 5 bbl McOH spear ➢ 50 bbls hot diesel ➢ 100 bbls hot 9.8 ppg brine i. Shut down for 1 hour to let diesel soak in OA and loosen Arctic Pack ➢ 50 bbls surfactant wash: freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal UO67 ➢ 260 bbls of 9.8 brine for sweep Fullbore 2. Rig up to pump down the tubing and take returns from both the IA and OA. Pump the following schedule: ➢ 5 bbls McOH spear ➢ 10 bbls freshwater spacer ➢ 300 bbls of 15.8 ppg cement per design ✓ ➢ 2 bbls freshwater spacer ➢ Foam Ball ➢ 42 bbls 9.8 ppg brine displacement Monitor returns from the OA for clean cement. As soon as cement is seen at surface, open the IA and shut-in the OA. Take returns from the IA for the duration of the job. Cement should be seen at surface from the OA with a total of 250 bbls of cement away. Pump the full displacement volume of 42 bbls even if clean cement is seen from the IA earlier—it's important to suppress the foam ball to target depth in order to allow access for the next stages of the P&A. TOC in tubing should be around 1100' MD. Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2,000 psi in 48 hrs. Thickening Time: Minimum 4 hours Relay or E -Line / Fullbore 1. Perform MIT -T to 2,500 psi. Provide adequate notification for AOGCC witness of MIT and tag. 2. Tag TOC in tubing. 3. Perforate Cad --950' MD (-150' above TOC) through 7" tubing, 9-5/8" casing, and 13-3/8" casing. Fullbore 1. RU to pump down the tbg and take returns from the OOA. Pump the following: ➢ 50 bbls hot diesel ➢ 37 bbls hot 9.8 ppg brine i. Shut down for one hour to let diesel soak in OOA and loosen Arctic Pack ➢ 50 bbls hot surfactant wash: freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal UO67 ➢ 210 bbls hot 9.8 ppg brine 2. Once clean brine is consistently returned from the OOA indicating that all hydrocarbons have been circulated out of the annuli, pump OOA and tubing cement plug as follows down tubing. Top of cemW will be at surface in both the OOA and the tubing. ➢ 5 bbls McOH ➢ 5 bbls freshwater spacer ➢ 205 bbls 15.8 ppg cement per design Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 ppg Slurry Temperature: between 80° and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2,000 psi in 48 hrs. Thickening Time: Minimum 4 hours Special Projects 1. Excavate and cut-off all casings and wellhead 3' below original tundra level. Top job the 30" x 20" annulus and all other annuli and tubing with cement as needed. 2. Install marker cap on outermost casing string (conductor, if present). Provide a minimum of 24 hours notice to AOGCC Inspector of the timing of the weldi g the marker pla onto th casing stub. Photo `T Lc�i TN G�i17�rc1 % 5'u Gr ..y r�/74a .r zJ�� to P%!o �e d©L urvr e.t c��r,.pti 7 7c Sur bac C� document the condition of the tubular stub immediately after cutting the wellhead, after topping off with cement (if necessary), and after installing the marker plate. 3. Bead weld marker cap on outermost casing string (30" Conductor) to read as follows: BP Exploration Alaska, Inc. 04-04A PTD # 195-024 API # 50-029-200096-01 P46 r/C doe Ukyex DATE REV BY I COMMENTS 11 DATE JREVByi 110a 71 ORIGINAL COMPLETION Ilowzins LWjxmu GLV 00(0324/19) 12MMM ROWAN 34 RM WWI TB6 PUNCH (04HN79) 9Y17MS SIDETRACK(SUMMUED) 105MIO TWJMD CEAENT RUG(04MI9) OU2'.M19 TTSNAI) OORRBMw20'CSG 06/OSH9 JNJJAU TAGG®TOC (OY12119) 02WJ19 KPTJW DRY HOLE TREE OBr. JNJJAD UI41AT®COND D�IH 0327719 WJMD PULLED 7- DB PLUG (0321119) PRUDHOE BAY UM VYELL: D4 -04A PffW No: 1950240 API ND: 50-029-200915-01 T11N, R15E. 910' FNL S 382' FEL BP Exploration (AYaka) VYHl)¢AD= BAKER ACRNTOR= EEIMOVED 0KB. DB/ = 64' BF. 8" 34-98• KOP= 7 Mat Argil = 83° i6100• Datum K)= 12847 DadmND= BBDO SS MR -M Fin 133/8' CSG. 779, KBO. o = �� I7' TBCsFC. 26#. L-80..0383 apf, D = 8276' 28 Minimum 10 = 3.80" X11875' 4-1/2" OTIS XN NIP MILLED OUT 3 TOP()F CMT(OS/12/19)E3T BOT 70158'--1 & w CMT (4130119) RRCH(0411G119)�- ll/91/-- IG -Fr, 17#. L-80 HF?—AT-F— f. TDM { f• D=4.89Y [TOP OF 3GFC. 12.6#, 4, D - 3.950' CSG. 47#, KE PHiPORATON SL "'ARY Rff LOG: ANGLEATTOP PffZF: Note: Refer b Production DB for I tortcal pert data 04-04A SUSPENDED SAFfTT' NDT6: 112S OVER 30OPPM NP, roc i cr wsrrla R ST MD ND DEV TYPE VLV LATCH PORI —i DATE 1 2989 2988 6 AM1G DMY F- (D21/95 2 5592 5002 61 AOAG OW RK 0 0321/95 3 7420 5914 57 MOA:' DMO' RK 0 12A5189 4 8147 6329 53 WA3 OW RK 0 12105/89 5 8741 6683 55 MM DAM RK 0 0323/95 6 9295 6993 57 MMG OM1' RK 0 12M5189 7 9877 7303 58 VM OW Po( 0 12/05189 8 10438 7593 59 WAG DIN f6( 0 0323195 -9 11056 7907 60 MMC OMT/ RK 0 09115/00 •i 11658 8208 60 MMIG RK® NONE 0 03"24/19 5TA 110= LATCH BNOKENOFFANDPfiVMi1U 1-[ wr 'STA #B=COVE3RBD IN CE PAE NT OOT TO 3Ar - 17870' F3AD 7-T LOG 77/77?7 7' MLLCUI WNDDW (04.04A)12566-12578 12576' - 13136' OPHf FEOLE GATE IfB/ BY OOMM34f^ DATE REV BY COMMHITS 10123/71 ORIGI CbAAPLETiOM 0327119 M9JMD CIV GO(03124/19) 12AMM ROWAN 34 RW OVM19 U TBGPIICH(04/16119) 84MMS SQtTRACK( 19 T4i'JWCB BUPRUG(04/3(Y79) 0123/19 TB/JMD f 2(r CSG OF3'Ett 06/05'19 JMJJMD TAGGEDTOC(05112/19) 02A72/19 KWJMD OW FDLETREE 0621/19 JAlJJMD l -VT OOOOPD 013TH 0327/19 L"JMD PULL®7' OB RUG (0321/19) . LE3:THP7RWP92 ONTO FSH (OCV10I95 Ff&OHOE BAY I.NT WELL: 04-W PEFOAT No:'1950240 ARM: 50-029-20096-01 SEC 34, T71 N R15E, 916' FNL & 387 FEL SP EXPIDFation (Alaska) I N O LA 0) Q O LO r Z D J_ 0 G W Co 0 2 s O o 2 Y V Q a 3 0 Q a` ♦2 W r C � = O U 0 � m a Y H m Q Y 0 m L- 0 0 Q X W 0. co Barrels of Oil per Month or Barrels of Water per Month 0 0 0 0 0 0 0 C 0 0 0 O 0 0 � N O N L A 0 N A N N C I O N C O 0 N A m c N IV c I m c 0 00 m N R r emi C N O ti c m O O O O O H O 00 O O O O N O O .0+ ollem 110 -seg JO y;uoVN Jad („j3vy,,) seg jo;aaj :)lqn:) puesnoyl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations U JU Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdpCv74 r% r% ❑ Suspend ❑ Perforate ElOther Stimulate ❑ Alter Casing 11 Change 'Approved Program ❑ Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other: Secure Reservoir/ Suspend Inspection 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development m Exploratory ❑ 5. Permit to Drill Number 195-024 Junk 3. Address: P.O. Box 196612 Anchorage, 12579 feet AK 99519-8612 Slretigraphic ❑ Service 1 6. API Number: 50-029-20096-01-00 7. Property Designation (Lease Number): ADL 0028325 & 028324 8. Well Name and Number: PBU 04-04A 9. Logs (List logs and submit aleatoric and printed data per 20AAC25.071): 10. Field/Pools: Packer true vertical 8308 feet PRUDHOE BAY. PRUDHOE OIL 11. Present Well Condition Summary: Burst: Conductor 80 30" Surface 1159 Total Depth: measured 13136 feet Plugs measured 10156, 11814 feet 754 true vertical 9132 feet Junk measured 12579 feet Effective Depth: measured 10156 feet Packer measured 11763 feet We vertical 7485 feet Packer true vertical 8308 feet Casing: Length: Size: Structural TVD: Burst: Conductor 80 30" Surface 1159 20" Intermediate 2675 13-3/8" Intermediate 12107 9-5/8" Liner 754 7" 29# N-80 Perforation Depth: Measured depth: 12565 - 13135 feet True vertical depth: 8725 - 9131 feet feet MD: TVD: Burst: Collapse: 32-112 32-112 880 31-1190 31-1190 1530 520 29-2704 29-2704 5380 2670 27-12134 27-8497 8150/7510/6870/9140 5080/4130/4760f7330 11811-12565 8332-8725 8160 7020 Tubing (size, grade, measured and true vertical depth) 7" 26# x 5-1/2" 17# x 4-1/2" 12.6# L-80 Packers and SSSV (type, measured and 5-1/2" Baker SB -3 Packer true vertical depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): descriptions including volumes used and final pressure: 24-11887 24-8371 11763 8308 3. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Pnor to well operation: Suspended Subsequent to operation: 14. Attachments: (reywreaper20MC25.wa.25.o71, 2125.210) 15. Well Class after work: Daily Report of Well Operations (71 Exploratory ❑ Development ® Service ❑ Stratigraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil ❑ Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ IGSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP m SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 319-032 Authorized Name: Worthington, Area J Contact Name: Smith, Travis T Authorized Title: Imervevptgns & Integrity Engineer /J , Contact Email: travisamithl0tip.mm Authorized Signature: ':C/lA/iL/ Date: S/r1T� �G� Contact Phone: +1 907 564-5412 Form 10-404 Revised OV2017 '40 T- —, t� RODMS_1 i✓ JUN 10 2019 Submit Original Only T/I/O/00 = 240/120/0+/200. Temp = SI. WHPs (WIE request). No AL, flowline, or wellhouse. Dryhole tree installed. Temp scaffold installed. TP increased 200 psi, IAP unchanged, OAP decreased 130 psi & OOAP increased 200 psi since 1/21/19. 3/1/2019 SV = C. MV = O. IA, OA, OOA = OTG. 1400 hrs. T/1/0/00 = 230/120/0+/200. Temp = SI. WHPs (WIE request). No AL, flowline, or wellhouse. Dryhole tree and temporary scaffold installed. TP increased 10 psi, IAP and OAP unchanged and the OOAP decreased 30 psi since 03/01/19. 3/15/2019 SV = C. MV = O. IA, OA, OOA = OTG. 15:00 ***WELL S/I ON ARRIVAL***(Plug & abandonment) PULLED P -PRONG FROM PLUG BODY @ 2,173' SLM / 2,206' MD. DRIFTED W/ 6.05" G -RING TO 2,177' SLM / 2,206' MD PULLED 7" DB -PLUG BODY FROM SVLN @ 2,206' MD SET 4-1/2" WHIDDON CATCHER ON WRP @ 11,807' SLM / 11,814' MD MADE 1 ATTEMPT TO PULL EO -PRONG FROM STA#10 RKED-DGLV (Unable to latch) MADE 2 ATTEMPTS TO PULL STA #10 RKED-DGLV FROM 11,658' MD (Unable to latch, PCT in bait sub) RAN BAITED 5-1/2" OM -1, 7" EXT, 1-5/8" JD (Coreless) TO STA#10 (Latched glv, kot left in glm) 3/21/2019 ****CONT JOB ON 3/22/19**** Assist S -Line arrive on location and spot unit. Standby for Slickline. ***WSR Continued on 03- 3/21/2019 23-2019*** ****CONT. JOB FROM 3/21/19*"* (Plug & abandonment) MADE 2 ATTEMPTS TO PULL STA #10 RKED-DGLV FROM 11,658' MD (Jar45 min up to 1500 lbs, Shucked jd dogs) RAN BAITED 5-1/2" OM -1, 7" EXT, 1-5/8" JD (Coreless) TO STA #10 (Latched giv, kot left in glm - 91" oal) 3/22/2019 ***JOB INCOMPLETE, RDMO DUE TO HIGH WINDS*** 3/22/2019 **WSR Continued from 03-21-2019*** Assist S -Line, Job postponed due to high winds ****CONT JOB FROM 3/22/19**** (Plug & abandonment) MADE 2 ATTEMPTS TO PULL STA#10 RKED-DGLV FROM 11,643' SLM / 11,658' MD PULLED BAITED 5-1/2" OM -1 FROM 11,643' SLM / 11,658' MD (JD pulling tool left in hole) RAN KJ, 5-1/2" OM -1, 1.70" LIB TO STA #10 @ 11,654' SLM / 11,658' MD (Impression of RK latch stop/no-go) 3/23/2019 ****CONT JOB ON 3/24/19**** ****CONT. JOB FROM 3/23/19**** (Plug & abandonment) RAN DBL KJ, 3.0" G -RING, RATTLED ALL GLMS TO CATCHER @ 11,814' MD PULLED 4-1/2" WHIDDON CATCHER FROM 11,814' MD (Recovered JD, RKED eq rod, latch core, body, wobble ring & spring) LRS PUMPED 100 BBLS CRUDE TO TEST CIRCULATION THROUGH STA #10 GLM (1.6 bpm @ 2,500 psi) LRS BEGIN SURFACTANT WASH / 9.8 PPG BRINE CIRC OUT STANDBY DUE TO FLOW STATION 2 / DS -04 SHUT DOWN (445 bbis pumped when pad S/I) 3/24/2019 ****CONT JOB ON 3/25/19**** T/1/0/00=59/26/8/200 Assist S -Line (Plug & Abandonment) Established injection rate of 1.6 PBM @ 2500 psi. Pumping down Tbg. taking returns up IA to 04-51 FL.w/ 5 bbis 60/40, 100 bbis Crude. Pumped 97 bbis surfactant wash followed by 445 bbis 9.8 Brine. Pad SI and circ 3/24/2019 out shut down until flow path obtained. ***WSR Continued on 03-25-2019*** Daily Report of Well Operations 04-04A ***WSR Continued from 03-24-2019*** Pumped 370 bbls (815 bbls total) 9.8 Brine down TBG taking returns up IA. Freeze protected w 12 bbls 60/40. U -Tube FP into IA. Freeze protect 04- 51 FL w/ 5 bbls 60/40, 87 bbls Crude. ***CMIT TxIA PASSED*** to 2378/2375 psi, (2450 Max, 2200 Target) Witnessed by Bob Noble Pumped 4.2 bbls 60/40 down Tbg. to reach test pressrue. Loss of 25/25 psi 1 st 15 3/25/2019 mion, Loss of 11/13 psi 2nd 15 min. Bled back 5.5 bbls. FWHP=290/295/128/280 T/I/O = 260/272/126 Temp = SI. FL & AL lines removed. No wellhouse. Job Scope: Cement Conrol & Balance lines to SSSV for Plug and Abandonment. Slickline and LRS on well performing circ out and AOGCC CMIT TxIA (Bob Nobles Mixed 14.0 ppg SqueezeCrete and, Injected 1.2 gallons down control line and 1.1 gallons down balance both locked up and held_ pressure. Well is warm after circ out. Performed passing pressure tests on both lines. See 3/25/2019 log for details. ***Job Complete*** ****CONT. JOB FROM 3/24/19**** (Plug & abandonment) LRS COMPLETED REMAINDER OF CIRC OUT PER SOR (-355 bbls) LRS PERFORMED PASSING CMIT-TxIATO 2200 PSI AOGCC witnessed by Bob Noble D&T W/ 3.70" CENT, 3.50" LIB, SID @ 11,846' SLM (AOGCC witnessed by Bob Noble, no impression) RAN 3.70" CENT, 2.50" S. BAILER, SID @ 11,846' SLM (Sample of pct) ****WELL LEFT S/I & DSO NOTIFIED OF STATUS UPON DEPARTURE**** 'NOTE: STA#10 GLM = SHEARED LATCH, RKED EQ ROD PULLED 3/25/2019 NO-GO & VALVE BODY LEFT IN POCKET T/I/O/00 = VacNac/110/7. Temp = SI. Assist ops with OOA repressurization. OOA FL @ surface. 3/26/2019 **Continued on 03/27/19 WSR** **Continued from 03/26/19 WSR** T/I/O/00 = VacNac/110/350. Temp = SI. Assist ops with ODA repressurization. ODA FL @ surface. Bled OOAP from 460 psi to 10 psi in 15 minutes to BT(0.5 bbl). 3/27/2019 ***Continue on 03/28/19 WSR*** **Continued from 03/27/19 WSR** T/I/O/00 = VacNac/110/445. Temp = SI. Assist ops with OOA repressurization. ODA FL @ surface. 3/28/2019 **Continued on 03/29/19 WSR** **Continued from 03/28/19 WSR** T/I/O/00 = VacNac/110/460. Temp = SI. Assist ops with OOA repressurization. ODA FL @ surface. Bled OOAP from 475 psi to 300 psi to BT (10 gals). Monitored WHPs. 3/29/2019 **Continue on 03/30/19 WSR** **Continued from 03/29/19 WSR** T/I/O/00 = VacNac/110/460. Temp = SI. Assist ops with ODA repressurization. OOA FL @ surface. Bled OOAP to 30 psi 1x (-5 gal). 3/30/2019 **Continued on 03/31/19 WSR** **Continued from 03/30/19 WSR** T/1/0/00 = VacNac/100/50. Temp = SI. Assist ops with OOA repressurization. Dry hole tree. OOA FL @ surface. Monitor WHP's and bleed as necessary. FWHP's = VacNac/100/10. 3/31/2019 SV, MV=C. IA, OA, ODA = OTG. 10:10. TWO = Vac/0/100/13. Temp = SI. WHPs (Post bleed) OAP increased 1 psi in 12 hrs. 4/1/2019 V = C. IA, OA, OOA = OTG. 16:15. 0 = VACNAC/100/12. Temp = SI. WHPs (Post bleed). No wellhouse, AL, or flowline. rTemporaryscaffolding installed. TP, IAP, and OAP unchanged, and OOAP increased 2 psi ht. 4/1/2019 V = C. IA, DA, ODA = OTG. 04:00 Daily Report of Well Operations 04-04A T/1/0/00 = Vac/0/100/15. Temp = SI. WHPs (Post bleed). OOA FL @ surface. No wellhouse, AL or flowline. Temp scaffolding installed. OOAP increased 2 psi in 17 hours. SV, MV = C. IA, OA, ODA = OTG. 20:30 4/2/2019 T/I/O/00 = Vac/Vac/100/13. Temp = SI. WHPs (Post bleed). OOA FL @ surface. No wellhouse, AL or flowline. Temp scaffolding installed. OOAP increased 1 psi overnight. 4/2/2019 SV, MV = C. IA, OA, OOA = OTG. 03:30 T/1/D/00 = Vac/0/100/18. Temp = SI. WHPs (Post bleed). OOA FL @ surface. OOAP increased 3 psi in 20 hours. 4/3/2019 SV, MV = C. IA, OA, ODA = OTG. 17:00. ***WELL S/I ON ARRIVAL*** (p&a) RELAY UNIT #46 RAN 5-1/2" D&D HOLE FINDER (see log)... HOLDS PRESSURE ONLY ABOVE STA #1 @ 2931' SLM 4/14/2019 ***CONT. ON 04/15/2019 WSR*** ***CONT. FROM 04/14/2019 WSR*** (p&a) HES RELAY UNIT #46 LOGGED PDS 40 ARM CALIPER FROM 11,795' SLM TO SURFACE... GOOD DATA (SEE PDS LOG FOR OBSTRUCTION @ 135' MD) RAN 5-1/2" D&D HOLE FINDER TO 3980' SLM, TBG HOLDS PRESSURE W/ NO TxIA COMMUNICATION 4/15/2019 ***CONT. ON 04/16/2019 WSR*** ***CONT. FROM 04/15/2019 WSR*** (p&a) HES RELAY UNIT #46 SET 5-1/2" D&D HOLE FINDER @ 11,608' SLM... 1000 psi PRESSURE TEST PASSED SHOT 0 PHASE 6 SPF TUBING PUNCH FROM 11,740'- 11 745' MD CCL TO TOP SHOT=12.3' CORRELATE TO TBG. TALLEY DATED 05 -DEC -89. 4/16/2019 ***JOB COMPLETE / DSO NOTIFIED*** T/I/O/OOA = 03/11/99/36. Temp = SI. WHPs (WIE Req). No wellhouse, Al, or Flowline. Temp scaffolding installed. Dry hole tree. TP increased 3 psi, IAP increased 11 psi, OAP decreased 1 psi, OOAP increased 20 psi since 4/2/19. 4/17/2019 SV, MV = C. IA, OA, OOA = OTG. 21:15 T/I/0/00=0/0/100/0 (LRS Unit 42 -Assist SLB Cement Crew: Plug & Abandon) Pump 5 bbl 60/50 spear to confirm flow path. SLB pumped cement. Flushed w/ 275 bbls 9.8 Brine Freeze protect w/ 10 bbls 60/40. U -Tube FP into IA. SV,MV, Ball launcher Closed. Casing valve OTG. 4/30/2019 FWHP=426/440/120/0 Initial T/1/0= (SLB Unit 28803 - TAA Balance Cement Plug) Pump the following down the tubing, up the IA, to OTT. LRS pumped 5 bbls 60/40 spear. SLB pumped 5 bbls freshwater. 90 bbls 15.8 ppg Class G cement, 5 bbls freshwater spacer. Launced 1 x8" foam ball. LRS displace cement down the tubing and into the IA w/ 275 bbls 9.8 ppg NaCl brine and 10 bbls 60/40. U -Tubed 60/40 to freeze protect TxlA to —150'. FWHP=426/440/124 15.8 ppg Class Cement TxIA Est. TOC in TBG and IA = 10440' MD / 7632' TVD 4/30/2019 Est. BOC in TBG and IA = 11740' MD / 8296' TVD T/I/O/OOA = Vac/Vac/110/270. Temp = SI. WHPs (WIE Req). No wellhouse, Al, or Flowline. Temp scaffolding installed. Dry hole tree. 5/3/2019 SV, MV = C. IA, OA, OOA = OTG. 03:30. Daily Report of Well Operations 04-04A ***WELL S/I ON ARRIVAL***(p&a) TAG TOC @ 10,152' SLM W/ 2.50" SAMPLE BAILER, 3.50" CENT (recovered wiper sponge) PERFORM PASSING PRE STATE CMIT TxIA TO 2500psi STATE WITNESSED TAG TOP OF CEMENT W/ 3.50" CENT, 2.50" SAMPLE BAILER @ 10,156 LM eff 'ones PERFORMED PASSING STATE WITNESSED CMIT TxIATO 2500psi 'eff jones 5/12/2019 RE, PAD OP NOTIFIED OF WELL STATUS*** T/I/O=vac/vac/108/285 Temp=Sl Assist Sline w/ AOGCC CMIT-TxIA (PLUG AND ABANDONMENT) AOGCC CMIT-TxIA **PASSED** to 2456/2393 (State witnessed by Jeff Jones) Pumped 8.27 bbls DSL down Tbg/IA on 2 CMIT-TxIA pre state test. 2nd Pressured up Tbg and IA to 2494/2500 psi. (Max 2500 psi, Target 2250 psi). Tbg/IA lost 9/23 psi in 5th 15 mins and 8/20 psi in 6th 15 mins for a loss of 17/43 in the last 30 mins of the test. See log for details. **PASS** per WSL Grimes. AOGCC State witnessed CMIT-TxIA pumped 5.9 bbls diesel down VIA to achieve test pressure. 1st 15 min T/IA lost 31/64 psi. 2nd 15 min T/IA lost 15/31 psi, 30 min total loss of 46/95 psi. PASS per WSL Lee Grey. Bled T/IAP, bled back — 5/12/2019 15.8 bbls. RDMO. SL in control of well upon LRS departure. CV's=OTG. FWHP=0/0/110/330 T/I/O/OOA = 10/120/110/320. Temp = Sl. WHPs (WIE Req). No wellhouse, Al, or Flowline. Temp scaffolding installed. Dry hole tree. 5/16/2019 SV, MV = C. IA, OA, OOA = OTG. 1510 hrs. T/I/O/OOA = VAC/63/106/347. Temp = SI. WHPs (WIE Req)/ Pre-Suspended Well Inspections. No wellhouse, Al, or Flowline. Temp scaffolding installed. Dry hole tree. TP decreased 10 psi, IAP decreased 57 psi, OAP decreased 4 psi, OOAP increased 27 psi since 5/16/19. Sombrero around well at ground level and another just below OOA valve. Sombrero on ground has water & hydrocarbon mixture in it. 5/29/2019 SV, MV = C. IA, OA, OOA = OTG. 21:00 T/I/O/OO = Vac/63/106/347. Temp = SI. AOGCC SU Inspection (Regulatory Compliance). State witnessed by Adam Earl. Pictures taken. 6/2/2019 SV, WV = C. IA, OA = OTG. 14:00 Suspended Well Site Inspection Form Initial Inspection Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: 04-04A Field/Pool: Prudhoe Bay / Prudhoe Oil Permit# (PTD): 1950240 API Number: 50-029-20096-01 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 2113/2016 Surface Location: Section: 34 Twsp: 11N Range: 15E Nearest active pad or road: DS -04 Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Clean Pad or location surface: Location cleanup needed: Pits condition: Surrounding area conditic Water/fluids on pad: Discoloration, Sheens on Samples taken: None 01.1 Access road condition: Good Photographs taken (# and description): Sign, Wellhead Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: Clean Cellar description, condition, fluids: Clean Rat Hole: NIA Wellhouse or protective barriers: Cattle Guard Well identification sign: Yes Tubing Pressure (or casing if no tubing): 0 Annulus pressures: IA= 50, OA= 150, OOA= 300 Wellhead Photos taken (# and description): Yes Work Required: None Operator Rep (name and signature): Josh Prowant — AOGCC Inspector: Adam Earl Other Obgervem Inspection Date: 6/2/2019 AOGCC Notice Date: 6/1/2019 Time of arrival: 1:30 PM Time of Departure: 1:40 PM Site access method: Access Road 11 �' 11 r cauriaa ' �"�• n� �+'�Jb'Y. UL Ape v�l�� .want Aon a.vt �, ��■ r xm� I77 s, w i r' _ r s • ;;. _- - Imo._ �:. >� , . _ tea, pp '�F r fir••}• t a s - s xQ k .s y s ix1 � _?d• �e .v�+� � {'_Iy " se .#+9 � }. w'a'r ,dC d4 ,"gi�� ibn�•, •xo a �r ,�� taVc.. 'i.. •. � A :,.frit.:• f`r�a.y. * {'�.. t�i`�� K�'��"'wid.,ex:�T �' t�t.. 4I 11 WELL #04-04 , CAUTION This Tree and Wellhead may suddenly move upward 0 c � i5 TRff= DRY HOLE VWLLHEAD= BAKERC ACTUATOR= REIMED OKB. ELEV = 64• BF. R IV= 1 KOP= 2988 Max Angle = 63'@616i' Datum MD= 12847' WtumTVD= 8800'SS GOND. 11 113' 04-04A SUSPENDED 20" CSG, 9411, H-40. ID =18.936" 1190' 13-3/8" CSG, 72#, "0, ID =12.347" 2704' T TBG -IPC, 2611, L-80,.0383 bpf, ID = 6.276" 289T Minimum ID = 3.80" @11875' 41/2" OTIS XN NIP MILLED OUT X.E37 TOP OF CMT (05/12/19) EST BOT 10156' - -11740' TBG & IN CMT (4/30719) D = 4.892' TOP OF 7" LNR I 4-12' TBG -M 12.6#, L-80 BTC—M, .0152 bof. D = 3.958' PERFORATION SUTAMARY REF LOG: ANGLEATTOPPERR Note: Refer to production DB for historical perf data .0371 bpf, ID = 6.164" SAFETY NOTES: HRS OVER 30OPPM GAS LFT MANDRELS ST M) I ND I DEVI TYPE VLV LATCH R7RT DATE 1 2989 2988 6 MUG DW RK 0 0321195 2 5592 5002 61 MFAC DW R( 0 0312IMS 3 7420 5914 57 NMM DW RK 0 12105189 4 8147 6329 53 NTA' LOMY R( 0 12/M89 5 8741 6683 55 MIAC 4/1'/ RI( 0 03123/95 6 9295 6993 57 MG DMY RK 0 12105/89 7 9877 7303 58 kM DIM RK 0 12115169 8 10438 7593 59 ATM ON Til( 0 032395 9 11056 7907 60 NMG OW RK 0 09/15/90 '10 1 11658 8208 60 KM, RED NOW, 0 0324/19 'STA #10 = LATCH BROKEN OFT AND PRONG PULLED OUT 'STA #9 = COVERED IN CEMENT X 5-1/2" BKR SB -3A PKR ID = 4.850" BKR FALLOUT IXTESION, ID = 6.625' 17-518"X 4-12" XO. ID = 3.990"1 I(MILLED OUT TO 3.80- - 04195) 11886' 4-j4SUB 11887' 11887' 4-1l2' TUBING TAIL 11870' E]AID TT LOG??R?h? 12134' T MLLOUT WNDOW (0"") 12565'-12578' 12520' 12575' -13135' oPEN HOLE DATE REV BY COIAA3m 11 DATE REV BY COMMENTS 10230`/1 ORIGINAL COMPLETION 0327/19 MH/.AAD 7955(0324/19) 12A5/89 ROWAN 34 FWJ0 0422/19 IDCWJMD TBG PUNCH(04116/19) 04117195 SDETRACK(SUSPE♦11H1) 05/02/19 THH/JMD CEA3NTFLUG(04/30/19) 0123/19 TTS/.MD OOMM=20-CSG DEPTH 06/05/19 JNL/.MD TAGG®TOC(05/12119) 02!02/19 I0'/JMD DRY HOLETREE 0327119 MM/JMD FULLE307-DB PLUG. (03121/19) 1/17/95). LE'THPTRRPPER TCHED ONTO FISH (06/10/95 IU -U PRUDHOE BAY UNIT WELL 04-04A PERMIT No: 1950240 AR ND: 50-029-20096-01 SE3C 34, T11 N, R15E . 916' FNL & 382' FEF BP Exploration (Alaska) Suspended Well Inspection Report InspectNo: susAGE190618095939 Date Inspected: 6/2/2019 Inspector: Adam Earl Well Name: PRUDHOE BAY UNIT 04-04A Permit Number: 1950240 ' Suspension Approval: Completion Report Suspension Date: 4/17/1995 Location Verified? ❑.i If Verified, How? Other (specify in comments) Offshore? ❑ Type of Inspection: Subsequent Date AOGCC Notified: 6/1/2019 Operator: BP Exploration (Alaska) Inc. Operator Rep: Josh Prowant Wellbore Diagram Avail? ❑O Photos Taken? 21 Well Pressures (psi): Tubing: Fluid in Cellar? ❑ IA: 50 BPV Installed? ❑ OA: 150 VR Plug(s) Installed? ❑ Wellhead Condition very tall well head/tree, several valves, Looks in good condition ' Condition of Cellar no cellar area, has a wire line drip pan around it/scaffold set up around as well Surrounding Surface Condition good Comments location verified by pad map Supervisor Comments Photos(3)attached Wednesday, August 14, 2019 s�14 _•, �8 j WELL 4 11ON06 i r- .. -Tom MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regge�l (,//ZI/y DATE: May 13, 2019 P.I. Supervisor SUBJECT: Well Bore Plug & Abandonment PBU 04-04A FROM: Jeff Jones BPXA Petroleum Inspector PTD 1950240; Sundry 319-032 Section: 34 Depth Btm Depth To MW Above Township: 11N Range: 15E Meridian: Umiat 2393 Drilling Rig: NA 112 Rig Elevation: NA Total Depth: 11232 ft MD Lease No.: ADL 0028323 Operator Rep: Suspend: P&A: X — Casing/Tubing Data (depths are MD): Casing Removal: Conductor: 30" O.D. Shoe@ 112 Feet Csg Cut@ Feet Surface: 20" O.D. Shoe@ 1190 - Feet Csg Cut@ Feet Intermediate: 13 3/8" O.D. Shoe@ 2704 - Feet Csg Cut@ Feet Production: 9 5/8" O.D. Shoe@ 12134 Feet Csg Cut@ Feet Liner: 7" O.D. Shoe@ 12565 Feet Csg Cut@ Feet Tubing: 7" x 4 1/2" ' O.D. Tail@ 11887 ' Feet Tbg Cut@ Feet Plugging Data: Test Data: Type Plug Founded on Depth Btm Depth To MW Above verined Fullbore Bridge plug 11814 ft MD N/A 2393 P OA 112 112 112 Initial 15 min 10 min 45 min Result Tubing 2502 2471 2456 IA 2488 - 2424 2393 P OA 112 112 112 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Witnessed pressure test (CMIT TxIA) only. Test against tubing plug at 11814 ft MD and IA packer at 11763 ft MD -holes punched in first joint of tubing above IA packer. Repeat CMIT TxIA witnessed on 3/25/19 by AOGCC Inspector B. Noble (PASS) Attachments: none rev. 11-28-18 2019-0512_Plug_yerification_PBU_04-04AJj MEMORANDUM TO: Jim Reg9 P.I. Supervisor 1 FROM: Bob Noble Petroleum Inspector Section: 34 Township: Drilling Rig: NA Rig Elevation: Operator Rep: Jim Lenzner Casing/Tubing Data (depths are MD): Conductor: 30" - O.D. Shoe@ Surface: 20" O.D. Shoe@ Intermediate: 133/8- - O.D. Shoe@ Production: ---9-5/8-, Feet O.D. Shoe@ Liner: 7" , O.D. Shoe@ Tubing: 5 1/2" 4 1/2" -O.D. Tail@ Plugging Data Test Data: State of Alaska Alaska Oil and Gas Conservation Commission DATE: March 25, 2019 SUBJECT: Well Bore Plug & Abandonment PBU 04-04A BPXA PTD 195024b; Sundry 319-032 11N Range: 15E- Meridian: Umiat NA Total Depth: 9131 ft MD Lease No.: ADL 028325 Suspend: P&A: X 112 Feet 1190 Feet 2704 Feet 12134 Feet 8725 Feet 11887 Feet Casing Removal: Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Csg Cut@ Feet Tbg Cut@ Feet T e Plu Founded on De th Btm De th To MW Above Verified Tubing 11814 ft MD Wireline tag Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: 11 Wireline retrievable plug set it tubing and gas lift valve at 11658 ft pulled prior to witness of plug verifications. Performed combination TxIA pressure test. Attachments: none rev. 11-28-18 2019-0325_Plug_Verification_PBU_04-04A_bn Initial 15 min 30 min 45 min Result Tubing 2414 2389 1 2378 IA 2413 2388 2375 _ P OA 131 130 130 Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: 11 Wireline retrievable plug set it tubing and gas lift valve at 11658 ft pulled prior to witness of plug verifications. Performed combination TxIA pressure test. Attachments: none rev. 11-28-18 2019-0325_Plug_Verification_PBU_04-04A_bn THE STATE 01ALASKA GOVERNOR MIKE DUNLEAVY Travis Smith Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 04-04A Permit to Drill Number: 195-024 Sundry Number: 319-032 Dear Mr. Smith: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax 907.276.7542 vrww. a ogcc. al a s ka.gov Enclosed is the approved application for the 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 AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this 5—day of February, 2019. SCANNED FEB 0 6 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.260 JAN 2 5 2019 1. Type of Request: Abandon 0 ' Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well 0 • Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Expt loraory [I Development 0' 5. Permit to Drill Number 195-024 ' 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigrephic ❑ Service ❑ 6. API Number: 50-029-20096-01-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 04-04A " 9. Property Designation (Lease Number): 10. Field/Pools: ADL 028325 & 028324 PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total DepthMD (ft): Total Depth TVD(ft): Effective Depth MD' Effective Depth TVD: MPSP (psi) Plugs (MD): Junk (MD): 13135. 9131 • 2205 2205 2205.11814 12579 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 30" 32-112 32-112 880 Surface 1159 20" 31-1190 31-1190 1530 520 Intermediate 1 2675 1 13-3/8" 29-2704 29.2704 5380 2670 INermediate 12107 9-5/8" 27-12134 27 - 8497 8150/7510/6870/9140 5080/4130/4760/7330 Liner 754 7" 11811 - 12565 8332-8725 8160 1 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12565 - 13135 8725 - 9131 7" 26#x6 -1/7'17#x4 -I12" 12.6# L-80 24-11887 Packers and SSSV Type: 5-12' Baker SB -3A Packer Packers and SSSV MD (ff) and TVD (ft): 11763/8308 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: February 5, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date. GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned 0 - 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Smith, Travis T be deviated from without prior written approval. Contact Email travisamRMabp.com Authorized Name: Smith, Travis T Contact Phone: +1 907 564 5412 I Authorized Title: Engineer Authorized Signature: Date: / N COMMISSION USE ONLY Sundry Number. Conditions of approval: Notify Commission so that a representative may witness r. Plug Integrity,., ity ❑ BOP Test El Integrity Test Ly/ Location Clearance Other: �//j I �6 �O CJ'. O 0 -$$C e—.1 Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception Required? Yes 11No 0/ Subsequent Form Required: APPROVED ^7 Approved by: s�COMMISSIONER COMMISS C ONVTHE Date: Forth 10-403 Revised 04/2017 ORIGINAL BBDMS±V4B05 Approved application is valid for 12 months from the date of approval. Wt Ito4TtSlq 2019 2-64 Submit Form and Attachments in Duplicate by Z 04-04A P&A Intervention Engineer Travis Smith (907) 564-5412 Production Engineer Meredyth Richards (907) 564-4867 Expected start date: February 51" 2019 History completed and three string casing des ✓ string is set in perms cost. GWO has determined that ese we s area risk for sudden wellhead movement, as demonstrated by 02-03A and 02-02A. As such, the AOGCC has requested this well be plugged and abandoned to mitigate HSSE consequence associated with this potential risk. Objective Place cement plugs in the wellbore. Excavate and cut casings 3' below original tundra level and install marker cap. Procedural steps DHD 1. Attempt to establish injectivity down the SSSV control line. 2. If successful, fill the SSSV control line with one control line volume of cement for isolation. Slickline (or Relay) / Fullbore 1. Pull DB plug from BAL-0 SSSV nipple at 2,205' MD. 2. Pull dummy valve from GLM#10 at 11,658' MD. 3. Circulate down tubing and up IA with surfactant wash followed by 9.8 ppg brine: ➢ 5 bbls McOH 100 bbls surfactant wash: freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal UO67 800 bbls 9.8 ppg brine. �, 9.8 ppg brine is a good freeze protectant down to -5°F. U-tube in some McOH to preventicigAga at surface. 4. Perform CMIT-TxIA toJ,-660-psi. Pr 5. Re -set dummy valve in GLM#10 at 1 6. Tag top of WRP plug at 11,814' MD. uate notification for AOGCC witness of MIT and to Relay or E -line 1. Run gamma ray log and caliper survey from TOC to surface (log all the way into the tree: this log is for future subsidence surveillance/analysis). 2. Fire tubing punch above t produc}}}}ion packvr to provide circhapoin fe m �nt. O)i,-,ccS �Q Fullbore 1 a —C`e_T' . 1. Remove IA gate valves and replace with integral valves at WSL discretion. 2. Pump cement job down tubing with returns from IA. at —2,200' MD in the tubing. ➢ 5 bbls McOH ➢ 700 bbls of Class G cement per design ➢ Foam wiper ball ➢ 2 bbls FW spacer ➢ 82 bbls 9.8 ppg brine The top of cement in the IA will be at surface and Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab pp +/- 0.1 ppg Pressure Slurry Temperature: between 800 and 110°F 0 Fluid Loss: 40-200cc (20-100cc/30 min) 3,000 Compressive Strength: 2,000 psi in 48 hrs. 2,500 Thickening Time: Minimum 5 hours 2,000 Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 130 3,000 2:00 120 2,500 3:00 110 2,000 4:00 100 1,500 7:00 80 1,000 15:00 40 0 Relay or E -line / Fullbore 1. Perform MIT -T to 2 2. I ag TOC in tubing. 3. Perforate at —1,800' MD through 7" tubing and 9-5/8" casing. Fullbore 1. Rig up to pump down the tubing and take returns from the OA. Pump the following: ➢ 50 bbls diesel and tag. ➢ 70 bbls 9.8 ppg brine ➢ Shutdown for one hour to let diesel soak in OA and loosen Arctic Pack ➢ 50 bbls surfactant wash: freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal U067 ➢ 195 bbls 9.8 ppg brine 2. Once clean brine is consistently returned from the OA indicating that all hydrocarbons have been circulated out of the annuli, pump OA surface cement plug as follows down tubing. The TOC in the OA will be at surface and at —800' MD in the tubing. ➢ 5 bbls McOH ➢ 5 bbls freshwater spacer ➢ 145 bbls 15.8 ppg cement per design ➢ Foam wiper ball ➢ 2 bbls FW ➢ 28 bbls 9.8 ppg brine Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab ppg +/- 0.1 pp Pressure Slurry Temperature: between 80° and 110°F 0 Fluid Loss: 40-200cc (20-100cc/30 min) 1,000 Compressive Strength: 2,000 psi in 48 hrs. 0 Thickening Time: Minimum 4 hours 0 Cement R rnp for Blend Time Temp Pressure 0:00 90 0 1:00 70 1,000 2:00 60 0 3:00 50 0 4:00 40 0 7:00 40 0 15:00 30 0 Relay or E -Line 1. Perforate @ —700' MD through 7" tubing, 9-5/8" casing, and 13-3/8" casing. Fullbore 1. RU to pump down the tbg and take returns from the OOA. Pump the following: ➢ 65 bbls diesel ➢ 27 bbls 9.8 ppg brine ➢ Shut down for one hour to let diesel soak in OA and loosen Arctic Pack ➢ 65 bbls surfactant wash: freshwater + surfactant; 2 gal/mgal F103 and 2 gal/mgal UO67 ➢ 175 bbls 9.8 ppg brine 2. Once clean brine is consistently returned from the OA indicating that all hydrocarbons have been circulated out of the annuli, pump OCA and tubing cement plug as follows down tubing. Top of cement will be at surface in both the OOA and the tubing. ➢ 5 bbls McOH ➢ 5 bbls freshwater spacer ➢ 155 bbls 15.8 ppg cement per design Cement Type/weight: Class G 15.8 ppg mixed on the fly. Field blend to be =lab pp +/- 0.1 ppg Slurry Temperature: between 800 and 110°F Fluid Loss: 40-200cc (20-100cc/30 min) Compressive Strength: 2,000 psi in 48 hrs. Thickening Time: Minimum 4 hours Cement Ramp for Blend Time Temp Pressure 0:00 90 0 1:00 70 1,000 200 60 0 3:00 50 0 4:00 40 0 7:00 40 0 1500 30 0 Special Projects P t� O � o L C wr' t C'^'��`'I )s 1. Excavate and cut-off all casings and wellhead 3' below original tundra level. Top job the 30" x 20" annulus and all other annuli and tubing with cement as needed. 2. AOGCC witness cement tops in all annuli 3. Bead weld marker cap on outermost casing string (30" Conductor) to read as follows: BP Exploration Alaska, Inc. 04-04A PTD # 195-0240 API # 50-029-20096-01 iw rue<= nxris[i4 MD TVD DEV HEV = 6t' PORI' DATE 1111910 'ATSIPJC SET DB FLETG (11113110) 2989 2988 6 NMG DIM W _ _? 5592 30' OHO, Angio =_- _. 63• @ 6100' 0 03,21185 1m AD = 12847' 5914 57 1157 50, D - rmTVD= SSW SS 4 8147 6329 53 20' CSG. 94#._1}40, D= 18.936' 1 13-3/e' c G 72k, u e0, o - 12.04T :-t 2704• TBGPC, 2600, L-80, 0383 5pf, D = 6 276- 1= 2897' Minimum ID = 3.80" @11875' 4-112" OTIS XN NIP MILLED OUT D=4.897 .0152 W. D = 3-958' s-ae' GSA. 4700, r+40. 0 = 8.68 r PEWOPATION SUMMARY F4F LDH ANG-EATTOPP97F-: Nrte. Refer to noducmn DB for Iriatorcal pert data 290, E480, .0371 6p1, D= 6.164' I--� 13200' 04-04A I'/ l fTES"WS GVM 30r.. SUSPENDED hii TW i �: 1lgx �rllcr XO. 13 �-4 *07 lilll §j —r4s L-2- wlcl�i-s ST MD TVD DEV TYPE VLV LATCH PORI' DATE 1111910 'ATSIPJC SET DB FLETG (11113110) 2989 2988 6 NMG DIM W 0 0 IMS 2 5592 5002 61 KW DIM RC 0 03,21185 3 7420 5914 57 AMC,' OMY RC 0 17J09B8 4 8147 6329 53 LM DAY RC 0 120989 5 8741 6683 55 AMC OMY FOC 0 03/23195 6 9295 6993 57 AMO OW FK 0 12!0989 7 9877 7303 58 AMG DI.Y EK 0 12JM89 8 10438 7593 59 AMC OW IK 0 0323195 0 11066 7007 60 M.1C OAN F44 0 12A05=10 11658 8208 60 MUG DAY IKP 0 1200989 11763' ave' x S 12' BKR St13A PCR D= 4.850^ .11776' 1-98' BKR IJLLOUT EXTUC1CN, D=6.625' -4 11784' 7-98' X 412- :[O, D = 3.990'I Li/P fYTF YN W MILLED OUI TO 3.10^- 049 ,1l e8ir 11s„ BKR SFHARDDT SIB 1168T 4-117 TlbfdG rA� 11870' aADTTLoc7�m�» r MLLOUT WN)DWj 4 aa> tzs6s'-tzs76 ` 12575'- 13135' oPe4HOLE STUCK BR 8 MOTOR 7195). LEFT FW TRRIPFHi DATE I RB/ BY COM 3m DATE I REV BY COM INFS Rd10HOEB.AY UNT WELL 04-W P]TMT W' 1950240 ARM 50-02!42009601 SEC 34, T11µ R15F 916' R4- a 387 FEL 10/Y3771 JORKUNAL COMPLETION 1111910 'ATSIPJC SET DB FLETG (11113110) 12/06,2! ROWAN 34 IWM 1111910 OOP/PJC FSHIIPDATE(06/1OMS) 0417195 SIOErMCK SUMB40M 0903111 MB/JMD DRAWNG C0R7EMDHS 10fOV10 FVM TFEECIO 05/09111 AD GLV DEPTH COR4�:TDFL4 14/.10!10 KISV ORANR4C CORIIE1IOPS 01/23119 TT'S/JMD CrORt13 D2lr CSG DEPTH 11138comaOon(Alacka) 11/1570 JK(YPJC SETT w(11/08110) Tw= 6-318•rALCO : Proposed P&A SAFENOTES: HnOVfR3OCPPM 04-04A " WELLMAD = BAKMC ACTUATOR= A)CaSM statils K B. ELEV = 64' :SUSPENDED - OF. RRY = ? SIDETJIACK(SUSPBDf� KOP= 2988 507,6—ow, �113' 1* LAM BAL-0 SSSV W. 0- &LUI 115750. ;.] i .08 FASOP /,]I H;, FLwovuio) I Gr @ 6100' Datum ND 1254T N 90. 0-1±.347- +-t 27" 393—bPf,'ID=656' I4 2697- �MIMMUM 11) = 3.80- @11875' JM Mi"iT'O 412" O-T�IS XN NIP MILLED OUT D=4.892' vfkaf-JrAff ".l. aK. 12 601, 1 -80 BTO&k ID=395W 10. 47#. f W. C) = &W Pew.(MTDN Sumkokw W LOG ANGLEATTOPP9W [-7;UW 290__N80, .0371 bpf, D=6.184- DATE D=6.154- X 6 1R• XO. 0- 4.1 GAS LFT LPANDW .1; 11761' 35/S Y --117 SM S&U PAR, 13. 4.950- 1177F 47-5J8-BKRW-LOtJT0MMlCKlD=6.625' TO &8r - 11887 7-MLLCUTWK)cyW( 12676•-13136' -JCFe4IDLE DATE I FE.V BY I CON&OM DATE REV VBY� COW3,1T5 TVD DEV TYPE I VLV LATCH PORT DATE OMPJr F13HLFE)ATE(06/10M) 0477195 SIDETJIACK(SUSPBDf� 2989 2988 6 LM DOW R( 0 owilm JA/SV DROW06 COIi CTIONS ountig 2 5582 SM 61 WAS DW FK 0 03421195 X: 3 7420 5914 57 LL40 DW w 0 12mas 4 8147 6329 53 AMG OW W 0 12051139 §X* "" 5 8741 6683 55 KM DW W 0 0323(95 6 9295 6993 57 AMC OW W 0 1210589 X 7 9677 7303 58 AMC DMY R( 0 12105189 X 10438 7593 59 LM OW W 0 0312385 ..X 0 110% 7007 60 LOAD OW nK 0 Ivordaul X 10 118, '708 , 60 LM, OW FW 0 JIMMI 11761' 35/S Y --117 SM S&U PAR, 13. 4.950- 1177F 47-5J8-BKRW-LOtJT0MMlCKlD=6.625' TO &8r - 11887 7-MLLCUTWK)cyW( 12676•-13136' -JCFe4IDLE DATE I FE.V BY I CON&OM DATE REV VBY� COW3,1T5 lorwi JORIGINAL COMPLETION I1115/10 'NEGPJC SET DB FLUG (I 1113110) 12006M RDWAN 34 FM 1111510 OMPJr F13HLFE)ATE(06/10M) 0477195 SIDETJIACK(SUSPBDf� 0510-311-1 MEVAO DPAMC CDRFFCTDNS 1010410 R\VSV TRIECto 05109111 JKU GLV DEP11HCORFELTIOM *�,o JA/SV DROW06 COIi CTIONS ountig I-TSIAU CORECTM20rCSG22Ej� lwil—vio &C/PJC SET VWV(IIJO&10) LEFT HIP TRF44M I UE FRLICHOE RAY UHT VYR-L 044)4A PERU W- 1950240 ARM 50-029-20MO-01 �C34,TIIKR15F.916FW8387 RP Bcplwabon (Alaska) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISaiON REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend IO Perforate 0 Other Stimulate 0 Alter Casing ❑ Change Approved Program 0 Plug for Redd! ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Suspend Well Inspection IZI 2 Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5 Permit to Drill Number: 195-024 3. Address. P.O Box 196612 Anchorage, Development II Exploratory 0 AK 99519-6612 Stratigraphic ❑ Service ❑ 6. API Number: 50-029-20096-01-00 7. Property Designation(Lease Number): ADL 0028324 8. Well Name and Number PBU 04-04A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 13136 feet Plugs measured 2205/11814 feet iiL C E I'T E P true vertical 9091 feet Junk measured 12579 feet C Effective Depth: measured 2205 feet Packer measured 11757 feet ' U Z i Lu iJ true vertical 2205 feet Packer true vertical 8258 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural 79 30"STOVE PIPE 35-114 35-114 Conductor 1160 20"94#H-40 33-1194 33-1194 1530 520 Surface 2686 13-3/8"72#N-80 32-2717 32-2717 4930 2670 Intermediate See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Production Liner 749 7"29#N-80 11816-12565 8287-8673 8160 7020 Perforation Depth' Measured depth: 12578 13135 feet True vertical depth: 8680-9090 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and 4-1/2"Baker SB-3A HYD PERM PKR 11757 8258 true vertical depth) 12 Stimulation or cement squeeze summary: Intervals treated(measured). Treatment descriptions including volumes used and final pressure' " ttt4" 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation. Subsequent to operation: 14.Attachments:(required per 20 AAC 25 070 25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations IZI Exploratory 0 Development I1 Service 0 Stratigraphic ❑ Copies of Logs and Surveys Run 0 16.Well Status after work Oil 0 Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ WINJ 0 WAG 0 GINJ ❑ SUSP f3 SPLUG ❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge Sundry Number or N/A if C.O.Exempt Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature q „ ioil f� _ Phone +1 907 564 4.424 Date 46-_to -2 d k� Form 10-404 Revised 5/2015"` yr-L q/Z /5mit Onginal Only A !, RBDMS� AUG 2 4 2015 m - o 0 0 0 0 0 0 o OO o m N r o M m m N N _ o0 O CO o r-- r-- O CO O V N Lo O U N o 0 0 0 0 0 O 0 0 0 0 M M Lo — N- Lo M m - J- M 7 Lo rn = Lo 00 N- O) = N N v m = v eo r- co ao r- ao r- r- o0 co C0 ' O M00 6) rn v M CO CO V r O) Lo o N- co M V c0 00 N co N M Lo m 00 oom N 00 M i i i lllll i i i • i I- M CO ' N = LC) Lo M N O V M M 00 00 m O m M M M N O = M C) N N 00 N (0 (0 (0 (0 (0 (N (0 • _ OO Lo N- ocom Loco O = d- M Lo O o O Lo a0 V m , 2: 2 i i Q O Lo M N m ,rL'') Lo O m o r- M M M N O O O N (N r- M Ln = 00 N 0 • CL W O In Lo o m o O aO O o o 00 L (n oZo w = a) w = * LO * WLL0ZJ * (p 'N N V M V M A g = N W O O 00N N OO _ Op _ - U WoC" n °DLnoo - EN o Lo mm , °' , d) `o o co co mO o (0 10 (0 o mmCC= m - - comm C N- o O co N 00 " co 00 0) N- N M N N M r- N a0 `- J W W W W W Q < < < < < 1:7) 00 0 0 0 0 •c � U w W W W W W 21-6222 U 0 fXCC a c Z Z Z c z eLw w w w W w m m m H 0 D H H H H z » > MUwZZZZZ F- HH 0 f c -7 3CO \ \ _) / » 2 § \ \ T.)- < / 2a@ Tv � ƒ = U a 77 / ci cn > E E E C U) \ $ \ Co o >- ® O 0 E E e 22 ) m % a 2 \ / \ ¥ O < / 5 'Cr) .- = 4 e 3 wJ ƒ & 13 0M 0 / 0 ° t 03 $ $ 6 *m a \/ § J / ° > ± — > RS � / F D 2 o .(7) -on fm _0 E __ ° E _ .- UE f U �%.g _ 0 = 2 Fr- < § \ 2 2 H < r a \ / & Co® co R O < • Suspended Well Site Inspection Form 5 Year Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UNIT 04-04A Field/Pool: PRUDHOE BAY/ PRUDHOE OIL Permit#(PTD) 195024 API Number: 50-029-20096-0100 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 4/17/1995 Surface Location: Section: 34 Twsp: 11N Range: 15E Nearest active pad or road: DRILL SITE 04 Take to Location Digital camera Map showing well location/Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Clean, active pad Pad or location surface: Graded grave! Location cleanup needed: None Pits condition: good, rain/snow water Surrounding area condition: clean Water/fluids on pad: rain water Discoloration, Sheens on pad, pits or water: none Samples taken: none Access road condition. good Photographs taken (#and description): (1) barricade and surrounding area Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2)well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead/tree/valve description, condition: McEvoy Gen 1 WH, CIW master, FMC tree, clean, can only verify 20" casing annulus valve position, open to gauge. Cellar description, condition, fluids: backfilled with gravel Rat Hole: N/A Wellhouse or protective barriers: yes, barricade Well identification sign: Yes, correct Tubing Pressure (or casing if no tubing): N/A SSV closed and no scaffolding Annulus pressures IA= 120psi OA=200 psi 00A=140 psi Wellhead Photos taken (#and description): (3)wellhead, tree Work Required None Operator Rep (name and signature): Whitney Pettus '# I' AOGCC Inspector: Waived by Chuck Scheve Other Obs:yr Ryan Hayes Inspection Date: 8/3/2015 AOGCC Notice Date: 8/2/2015 Time of arrival: 3:45 PM Time of Departure: 3:55 PM Site access method Truck E y — co = d< a _ _ a -a C7 CI •_ ... In 3 O a W C - C :7 a47 `.) v > `^. rn L = - = c�V Q 4J C J Ste, .. 01 In N ES f —I a a I I I III a rsi vi c! 00 v M .-1 N 4 �1 d Q ON\ \ % Yy C W N Ja p o 32cr, . \ 4....0 A M t 0 0 i • g d ocn 41. 4414 4' u?i < ..i* 34" p y t. bN g .. , A .400, 4 mmd mCnW5yn• 4por .Arw.imwiN,.._ t'm\ � mme P . 4/, E -692 g 7I p& MU n C 6 Z O It 1 , \ • o p OAowar 111‘ / N, CL Ilk /If kkk, *, Ai4t, 4.6.1**4 a a 144v fYl N P..uai+.",yaQ .ii Aallhh„g _. :10}$1i. • /''''� M xC'0 U.�,i�aya�M m ani l 8 0 , 8 0� . ID U <# 0O 0Oim O 4i ..—.."'',° 1.111o O g .., i - .. .. /- -, V A ; . . . _. WI . , I 1- \ ,1... ....:\ , • .... . ,.: . ,i • . , _, • .• , _ ...., . . , _, ,,..... ____:• , .. _____. _,•••-.71 _ _ _ ., - 1.• isimagb. . . 4 ..4 I : .......___..„,.. , . . ' - ' - - _ ... ..trlittr.- ":"7"'''. '1 .,-.,t-,.;-• - - - - : . ... - . .. -.. • * , • , : , ,...••.01'p;1 -----.--,-''......;,.. • • — - -- . - --• 1-. , . . . ..... . . . •. , :;:-,--:„.-_--..- • . .- -. - -.. . • - .• - .-•• -.• -----, ;:::';''';::';'-'''' ' ' WELL: —04A ----' '.- 7.. :• '•'' . •-:-- _ . . . •„ .- . . . „ • , ., , . . . . • - • .. • , . • • -•- . - - •'•.:,..',,.......-.: •''.-••,'-.•• '.:: ''' -.-' . ., - ;-..,., , ,,, - • - ' OWNER Prudhoe ReY Udit „ .. . , . , f :, '''',,,,.6.' '.,...F.•,.1. '., ,'. ,'' .'...f . C'.., .' .:"'.1,:::'',,,:: OPERATOR . -----.„ k - - ' . ' '' : ::NUMBER ; ... • -- . , _ - , ,. .. . - -•••••,---4-,•:.--••-•,---.7-- ,11, -,'" --,2. •-•...' -- ,'• . , •, _ 4-.3_,•_.•-',--• '-,!,.;."...:-.* .:,,-?-,* .• - .,• •' .".,- .-.- •„, , , k••• ...,.•„, -,...- .---... . ,•. •.s...,. •*t5".. -'-7, ••', •-•','. -.-.„-,, ,-'. • L.L1 .ApnELN . •-p.r:•• -.• , ' •- --, ,, • • . . . . . ‘:•-• ' • r'''-4,. . : ... --- Ns.,....----4-4:: • ---'. %.-• 1:-.-'.-%.. ..;.- . --. --7.... •:,2 ‘, ,. ,, - , •. ,.. .... . . . . . -• -..a....,,,,,- f,..,....:.. 4 7'.. -%t.- ..--...''. -:-..:'- • , . , . . . .•. • - _ ' - , .. .'..-' - .- ' _ .. ' -', • '.. _ 4.....-..... q.'-- - . . . . l'r;;:'- • .'"... . ..,..-1,.:',f."-:!, ...„,-,',.• ',....:-...„...:,•••-.•!?,..i. 40,-;'-,• '-N-.;....,•••e=v; .„4,7.... -:•.+"...4•.•-'11 Z 7...•' :-....7.--,,i 1,-„,...,;,;..,-.......--,.z...5.:_..-,.,.,•..: --.••,,,t,....•••••--, _..,-•. 1 . ,i!, •'• '-..^•'':-•-„:••••'.',....-' - -4•••••..••i:v.r.'"i:'""'-';;;..•-•.:-•:•••,,••-•• --=•-, ;...9'.%;.'rt.. ..774%....,•-•-•i'','.,,i4-,;.-•.-.'•••-•'1- -:.7-,--.., ...-' '-f".::- .. f.,.-.."•:ix:.• -',f-...- • •.••;,„•••7'..-.!• '.•.,•,..-:.7.:-..;-,•;-, '..Z.,—•••1:'''•• ',--*•:,:-';;:•:•''...61 •.- ..,.','-:' 7.7*."'.. ,-,'!•-••s:...7•';'' •'.T.: ,- ro.lf.P.'..7-•-:..;'''''' ''--':•-•••''•'•• •-• •...- .. '''• 4••••• •• .-''''- ....•' •' '' .-', •' ' ••''' - • •• , t ,t. ! „: fs i e ' ' i . /`- =` - r ,. r._ ,. j_ _ _ • .. 5- i . •• • • i z a y a ., i • 5 • Y •1 i;,' -t p` +a 'a i u p?i lot 5 ti tFJ '.. a lfr ' g', r.,, 4 b*�'�' ,„4, .„.,,,i ,(` �6, � haw _ . 1 i� .z..,1 ., , .Q. , , .. , .. ' - 11'11161" ...,, f t. ,i, � ,.,..: -4' . - / .,.. ,) ,,,,,,,,.., ..., ,ii,,, -, it ... .. X' ‘,„,-•.. wit. r �. ,` L ... ..r %II. . ,.,. . . ..., ,. ,. . _ . t ;, T .. , . . ... ,..e..: U. I a r ,v i`,, t x 11• I . TREE= 6-3/8"CALICO WELLHEAD= BAKER C 04-0 4A SAFETY NOTES:H2S OVER 300PPM ACTUATOR= AXELSON KB.ELEV= 64' SUSPENDED BF. ELEV= ? KOP= ? II � II Max Angle= 63°@ 6100' 30"CONDUCTOR, H 113' [I 2205' —7"CAM BAL-O SSSV NIP,ID=5.937 Datum MD= 12847' 157.5#,ID= Datum TVD= 8800'SS 2205' —I7"DB PLUG(11/13/10) 20"CSG,94#,H-40, ID=18.936" H 971' II,/ 2897' —7"X 5-1/2"XO, ID=4.892" 13-3/8"CSG,72#,N-80,ID=12.347" — 2704' iii GAS LIFT MANDRELS 7"TBG-IPC,26#,L-80, .0383 bpf,ID=6.276" 897 ST MD TVD DEV TYPE VLV LATCH PORT DATE I L 1 2989 2988 6 MMIG DMY RK 0 03/21/95 2 5592 5002 61 MMIG DMY RK 0 03/21/95 3 7420 5914 57 MMIG DMY RK 0 12/05/89 Minimum ID = 3.80" @11875' 4 8147 6329 53 MMIG DMY RK 0 12/05/89 4-1/2" OTIS XN NIP MILLED OUT 5 8741 6683 55 MMIG DMY RK 0 03/23/95 6 9295 6993 57 MMIG DMY RK 0 12/05/89 7 9877 7303 58 MMIG DMY RK 0 12/05/89 8 10438 7593 59 MMIG DMY RK 0 03/23/95 9 11056 7907 60 MMIG DMY RK 0 12/05/89 10 11658 8208 60 MMIG DMY RKP 0 12/05/89 5-1/2"TBG-IPC, 17#,L-80 BTC-M, --I 11763' I------ 11763' H 9-5/8"X 5-1/2"BKR SB-3A PKR,ID=4.850" .0232 bpf, ID=4.892" L 11778' H 7-5/8"BKR MILLOUT EXTENSION, ID=6.625" 11784' —7-5/8"X 4-1/2"XO, ID=3.990" TOP OF 7"LNR — 11811' 11814' I-14-1/2"WRP(11/08/10) i 11875' 4-1/2"OTIS XN NIP (MILLED OUT TO 3.80"-04/95) 11886' H4-1/2"BKR SHEAROUT SUB 4-1/2"TBG-IPC, 12.6#,L-80 BTC-M, — 11887' 1-----______1 \ 11887' H4-112"TUBING TAIL .0152 bpf, ID=3.958" 11870' H ELMD TT LOG????'7? 9-5/8"CSG,47#,N-80, ID=8.681" -f 12134' 7"MILLOUT WINDOW(04-04A) 12565'-12578' TOC H 12520' �, 14 4 14 / 12575' -13135' H OPEN HOLE PERFORATION SUMMARY �A�A�A�•�ka, REF LOG: 12579' FISH-STUCK BIT&MOTOR ANGLE AT TOP PERF: (04/17/95). LEFT HIP TRRIPPER Note:Refer to Production DB for historical perf data LATCHED ONTO FISH(06/10/95) SIZE SPF INTERVAL Opn/Sqz DATE TD 13135' 7"LNR,29#,N-80, .0371 bpf,ID=6.184" —I 13200' , DATE REV BY COMMENTS DATE REV BY' COMMENTS PRUDHOE BAY UNIT 10/23/71 ORIGINAL COMPLETION 11/15/10 WEC/PJC-SET DB PLUG(11/13/10) WELL: 04-04A _12/05/89 ROWAN 34 RWO 11/15/10 OOP/PJC FISH UPDATE(06/10/95) PERMIT No: 1950240 04/17/95 SIDETRACK(SUSPENDED) 05/03/11 MB/JMD DRAWING CORRECTIONS API No: 50-029-20096-01 10/04/10 RM/SV TREE C/O 05/09/11 JMD GLV DEPTH CORRECTIONS SEC 34,T11 N,R15E,916'FNL&382'FEL 10/30/10 JA/SV DRAWING CORRECTIONS 11/15/10 JKC/PJC SET WRP(11/08/10) BP Exploration (Alaska) Pages NOT Scanned in this Well History File XHVZE This page identifies those items that were not scanned during the initial scanning project. They are available in the original file and viewable by direct inspection. File Number of Well History File PAGES TO DELETE Complete RESCAN [] Color items - Pages: Grayscale, halftones, pictures, graphs, charts- Pages: Poor Quality Original- Pages: [] Other- Pages: DIGITAL DATA [] Diskettes, No. [] Other, No/Type OVERSIZED [] Logs of various kinds [] Other COMMENTS: Scanned by: Beved~ Vincent Nathan Lowell Date: ~-'~ -I [] TO RE-SCAN Notes: Re-Scanned by: Bevedy Dianna Vincent Nathan Lowell Date: Is~ • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/21/10 Inspector: Chuck Scheve Operator: BPX Well Name: PBU 4 -04A ' Oper. Rep: Ryan Holt PTD No.: 1950240 - Oper. Phone: 659 -5766 Location Verified? No Oper. Email: If Verified, How? Onshore / Offshore: Onshore Suspension Date: 04/17/95 Date AOGCC Notified: Sundry No.: Type of Inspection: Wellbore Diagram Avail.? No Well Pressures (psi): Tubing Photos Taken? Yes IA 460 by operator ✓ OA 0 {t Condition of Wellhead: No Wellhouse, barricade in place. Full tree left on well with no access to valves. Flow line remove and blinded. Condition of Surrounding Surface Good Location: Follow Up Actions Sign identifying well needs to be installed. Needed: Attachments: REVIEWED BY: Insp. Supry '$ . ,Q $0/ Comm t_ _ PLB 08/2010 Suspended Well PBU 4 -04 8 -21 -10 CS.xls MEMORANDUM • State of Alaska • Alaska Oil and Gas Conservation Commission TO Jim Regg DATE: Friday, December 03, 2010 P.I. Supervisor I21", -1 ly'I i a SUBJECT: Mechanical Integrity Tests C l BP EXPLORATION (ALASKA) INC 04 -04A FR Jeff Jones PRUDHOE BAY UNIT 04 -04A Petroleum Inspector Src: Inspector Reviewed By: P.I. Supry NON - CONFIDENTIAL Comm Jones PR DH E BAY IT 4- 4A -2 1- • Jeff Well Name. U O UN o o API Well Number: 50 029 0096 0 00 Inspector Name Je . P Insp Num mitJJ101110183245 Permit Number 195 - 024 - 0 Inspection Date: 11/10/2010 Rel Insp Num: Packer D epth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well 04 -04A ' Tape Inj. T N TVD 8260 IA 410 410 415 1 415 415 1950240 r SPT 2500 OA 120 120 130 130 130 P.T.D� �peTest� Test psi -�- Inter OTHER' P/F P - Tub ing L 380 l 2500 2420 2310 2310 -- - - -- - -- — - - - -- — -- —� - - - -- - 1 Notes: MIT -T on a shu in suspend well. No well house. 3.6 BBLS diesel pumped. 1 well inspected, no exceptions noted. Friday, December 03, 2010 Page 1 of I r A L z T\�, A SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSE RVATION COMM ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Gary Preble Data Management Engineer J BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 04 -04A Sundry Number: 310 -386 Dear Mr. Preble: $i N NG 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. Sincere J r an Co issione DATED this dday of November, 2010. Encl. STATE OF ALASKA ALASKL AND GAS CONSERVATION CO O L l� i APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Change Approved Program ❑ Suspend ❑ Plug Perforations ❑ Perforate❑ Pull Tubing ❑ Time Extension ❑ Operation Shutdown ❑ Re -enter Susp. Well ❑ Stimulate[] Alter Casing ❑ RENEW SUSPENSION ❑ 2. Operator Name: 4. Current Well Class: 5. Permit to Drill Number: BP Exploration (Alaska), Inc. Development ❑ Exploratory ❑ 195 -0240 3. Address: P.O. Box 196612 Stratigraphic ❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 50- 029 - 20096- 01 -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 04 -04A 9. Property Designation (Lease Number): 10. Field / Pool(s): ADLO- 028324 PRUDHOE BAY Field / PRUDHOE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13135- 9091.18. 13135 9090.35 2205' 11814' 12579' Casing Length Size MD TVD Burst Collapse Structural Conductor 115 30"157.5# B GRADE SURFACE 115 SURF 115 880 Surface 1190 20" 94# H -40 SURFACE 1190 SURF 1190 1530 520 Intermediate 2704 13 -3/8" 72# N -80 SURFACE 2704 1 SURF 2704 4930 2670 Production 12134 9 -5/8" 47# N -80 SURFACE 12134 1 SURF 8447 6870 4760 Liner 767 7 "29# N -80 11811 12758 8284 8800 8160 7020 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): C 12758 - 13135 8680-9027 7"26# L -80 URFACI 2897 - 5 -1/2" 26# L -80 2897 11784 4- 1/2 "26# L -80 11784 11887 Packers and SSSV TVDe: 9- 5/8 "X5 -1/2" BAKER SB -3A PKR Packers and SSSV MD and TVD (ft): 11763 8261 12. Attachments: Description Summary of Proposal ❑ 13. Well Class after proposed work: Detailed Operations Program ❑� BOP Sketch ❑ Exploratory ❑ Development ❑Q - Service ❑ 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: 11/30/2010 Oil ❑ Gas ❑ WDSPL ❑ Suspended _ ❑✓ 16. Verbal Approval: Date: WINJ ❑ GINJ ❑ WAG ❑ Abandoned ❑ Commission Representative: GSTOR ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Gary Preble Printed Name GaryPvlble Title Data Management Engineer Signature Phone Date 564 -4944 11/16/2010 Prepared by Gary Preble 564 -4944 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: Plug Integrity ❑ BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑ Other: -A ( � v► li e lv c d O AA Z S N T 6 -Jas Copts. cluffi1 Ision Subsequent Form Required: APPROVED BY Approved by: COMMISSIONER THE COMMISSION Date: RBDM q RIGINA 11 /7 -, ® r /iv Form 10 -403 Revised 1/2010 Submit in Duplicate 0 • Prudhoe Bay Oil Pool well 04 -04 Technical Justification for Application for Renewal of Suspension Status November 15, 2010 Well Status 04 -04A was suspended on 04/17/95 after a failed sidetrack attempt. Coil drilled to a depth of 13135' MD then stuck the drilling motor and bit in hole at 12579'MD. Additional tools were also lost during attempts to recover the fish. BP Exploration (Alaska), Inc. completed a suspended well inspection of PBU 04 -04A on 08/21/10. The results of that inspection were submitted with a Report of Sundry Well Operations (form 10 -404) on 09/17/10. The wellbore diagram showed the well cemented back to 12520' MD securing the well. However, no record of such a cementing operation was found. A recent slickline tag reached 12553' MD, near the casing window. A MIT -IA passed, but a pressure test of the tubing failed indicating communication to the formation Mechanical plugs_ were set in the tubing string at 11814' and 2205' MD to secure the well. T he pressure test of the lower plug to 2500 psi was witnessed by AOGCC inspector Jeff Jones on 11/10/10. The upper plug was set and tested to 2000 psi on 11/13/10. A revised wellbore diagram is attached. The well is mechanically sound as indicated by a passing MIT -IA to 2000 psi on 10/28/10 and the pressure tests of the mechanical plugs. The well will not allow the migration of fluids, will not damage freshwater or producing or potentially producing formations, will not impair the recovery of oil or gas, and is secure, safe, and not a threat to public health. The strata through which the well was drilled is neither abnormally geo- pressured or depleted. Condition of the Wellhead and Surface Location Prudhoe Bay Unit well 04 -04A is located on an active, well maintained pad with clean gravel. The pit and surrounding area are in good condition. There is no discoloration and no sheens on the pad, pits, or in nearby water. During the inspection, it was discovered the well sign was missing. A new sign has been ordered and will be placed at the well. The current well pressure readings are T /I /O /OO = 80/450/180/360. Request BPXA requests approval for renewal of the existing suspension status for 04 -04A. A variance to the provisions of 20 AAC 25.110 (c) (2) is also requested under 20 AAC 25.112 (i) to allow the well to be remain suspended in its current condition. All hydrocarbon intervals are isolated and there are no underground sources of fresh water in this area. MLB 11/15/10 - WELLHEAD= BAKER SAFETY NOT TRFE, 6 3/8' CALICO ES: H2S OVER 300PPM ACTUATOR = AXELSON 4 -0 4A KB. ELEV = 64 BF. ELEV = ? KOP= ? I Max 63 le An = ' 30" CONDUCTOR 113 9 °� 6300 2205 7" CAM BAL -O SSSV NIP,ID= 5.937 Datum MD = 12847' 1 157.5#, ID = DatumTVD= 8800' SS 2205' 7" DB P ( 11/1 3/ 1 0 20" CSG, 94 #, H - ID = 18.936" 971' 2897' 13 -3/8" CSG, 72 #, N-80, ID = 12.347" 2704' GAS LIFT MANDRELS 7" TBG -IPC, 26 #, L-80_0383 bpf, ID = 6.276" 2897 ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 2989 2988 4 MMIG DMY RK 0 03/21/95 2 5592 5002 60 MMIG DMY RK 0 03/21/95 3 7420 5914 57 MMIG DMY RK 0 12/05/89 Minimum ID = 3.80" @11875 4 8147 6329 53 MMIG DMY RK 0 12/05/89 4 -1/2" OTIS XN NIP MILLED OUT 5 8741 6683 55 MMIG DMY RK 0 03/23/95 6 9295 6993 57 MMIG DMY RK 0 12/05/89 7 9877 7303 58 MMIG DMY RK 0 12/05/89 8 10438 7593 59 MMIG DMY RK 0 03/23/95 9 11056 7907 60 MMIG DMY RK 0 12/05/89 10 11568 8163 60 MMIG DMY RKP 0 12/05/89 5 -1/2" TBG -IPC, 17 #, L -80 BTC-M, 11763 11763 9 -5/8" X 5 -1/2" BKR SB -3A PKR, ID = 4.850" .0232 bpf, ID = 4.892" 11778 7 -5/8" BKR MILLOUT EXTENSION, ID = 6.625" 11784 7 -5/8" X 4 -1/2" X0, ID = 3.990") TOP OF 7" LNR 11811' 11814 4 -1l2" WRP (11/08/10) 11875 4 -1/2" OTIS XN NIP (MILLED OUT TO 3.80" - 04195) 11886' 4 -112" BKR SHEAROUT SUB 4 -1/2" TBG -IPC, 12.6 #, L -80 BTC-M, 11887' 11887 4 1/2" TUBING TAIL' 1. 0 bpf, ID = 3.958" 11870' ELMD T T LOG ? ? i ? ? / ?? 9 -5/8" CSG, 47 #, N-80, ID = 8.681" 12134' 7" MILLOUT WINDOW (04 -04A) 12565'- 12578' ToC 12520' 1 2575' - 13135 OPEN HOLE PERFORATION SUMMARY REF LOG: 12579' FISH- STUCK BIT & MOTOR ANGLE AT TOP PERF: (04/17/95). LEFT HIP TRRIPPER Note: Refer to Production DB for historical pert data LATCHED ONTO FISH (06/10/95) SIZE SPF INTERVAL Opn /Sqz DATE � a TD 13135' 7 "LNR, 29 #, N-80_0371 bpf, ID = 6.184" 13200' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/23/71 ORIGINAL COMPLETION 11/15/10 WEC/PJC SET DB PLUG (11/13/10) WELL: 04 -04A 12/05/89 ROWAN 34 RWO 11/15/10 OOP /PJC FISH UPDATE (06/10/95) PERMIT No: 1950240 04/17/95 SIDETRACK (04 -04A) API No: 50- 029 - 20096 -01 10/04/10 RMISV TREE C/O SEC 34, T11 N, R1 5E, 916' FNL & 382' FEL 10/30/10 JA /SV I DRAWING CORRECTIONS 11/151101 JKC/PJC I SET WRP(11 /08/10) BP Exploration (Alaska) Page 1 of Z --- Schwartz Guy (DOA) ) From: Schwartz, Guy L (DOA) Sent: Monday, November 08, 2010 12:47 PM To: 'Bill, Michael L (Natchiq)' Cc: AK, D &C Well Integrity Coordinator Subject: RE: Suspended wells List ( wells with IA or tubing pressure) DS 4 -04A ( PTD 195 - 024) Mike, The commission would like to request a witnessed test on the bottom plug for the suspend status. If the Inspectors can't make it be sure they chart the pressure test. Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: Bill, Michael L (Natchiq) [mailto: Michael. Bill @bp.com] Sent: Monday, November 08, 2010 12:43 PM To: Schwartz, Guy L (DOA) Subject: FW: Suspended wells List ( wells with IA or tubing pressure ) fyi Mike Bill Well Integrity Group Drilling & Completions 907 - 564 -4692 Office 907 - 564 -5510 Fax From: AK, D &C Well Integrity Coordinator Sent: Saturday, October 30, 2010 2:22 PM To: 'Schwartz, Guy L (DOA)' Cc: Bill, Michael L (Natchiq); Kara, Danny T; AK, D &C Well Integrity Coordinator Subject: RE: Suspended wells List ( wells with IA or tubing pressure ) Guy, Well 04 -04A (PTD #1950240) has had the following work done over the last few days: 10/27/2010: Slickline tagged bottom at 12,553' slickline depth with a sample bailer that recovered cement. 10/28/2010: MIT -IA to 2000 psi passed. 10/29/2010: MIT -T to 2500 failed. Established a 0.2 bpm injection rate at 1930 psi. The current plan forward is to secure the well with two pressure tested mechanical plugs in the tubing; a tubing tail plug and a plug set in the SSSV nipple. 11/8/2010 Page 2 ofAZ If you have questions or concerns, please call either Mike Bill or myself and we will be happy to discuss the well. Regards, Jerry Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 From: Schwartz, Guy L (DOA) [ mailto:guy.schwartz @alaska.gov] Sent: Friday, October 29, 2010 10:48 AM To: AK, D &C Well Integrity Coordinator Cc: Bill, Michael L (Natchiq) Subject: RE: Suspended wells List ( wells with IA or tubing pressure ) Jerry, I got through most of the suspended wells ... thanks for the TIO plots. Guess I was looking for an email from Mike Bill and missed yours with the TIO plots a few weeks ago. Can you check on DS44A ... this one has unknown cement placement. The well sketch is also a little strange and it is hard to tell what is really going on down at the window. It shows a tieback to the 4 ' / 2 " tubing tail but is that really there ? ?? The IA wasn't bled either ... at least I didn't see an updated pressure from the listed 460 psi. Can you outline your plans to determine cement placement and status of the current downhole plugs ( whatever that may be) ... Thanks, Guy Schwartz Senior Petroleum Engineer AOGCC 793 -1226 (office) 444 -3433 (cell) From: AK, D &C Well Integrity Coordinator [ mailto :AKDCWellIntegrityCoordinator @bp.com] Sent: Thursday, October 28, 2010 3:13 PM To: Schwartz, Guy L (DOA) Cc: Bill ichael L (Natchiq) Subject: nded wells List ( wells with IA or tubing pressure ) Guy, I sent an e-mail on October 3rd that had the followup mation on the wells. I can resend if needed. Jerry Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659 -5102 Cell (907) 752 -0755 Pager (907) 659 -5100 Ext. 1154 11/8/2010 STATE OF ALASKA ALASKAW AND GAS CONSERVATION COMMISS* REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate 1:1 Other Q INSPECT Performed: Alter Casing ❑ Pull Tubing[:] Perforate New Pool ❑ Waiver❑ Time Extension ❑ WELL Change Approved Program ❑ Operat. Shutdown ❑ Perforate ❑ Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development Q Exploratory ❑ \ 195 -0240 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 ` 50- 029 - 20096 -01 -00 8. Property Designation (Lease Number) : %. 9. Well Name and Number: \ ADLO- 028324 TABU 04 -04A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 1313 feet Plugs (measured) 12520' feet true vertical 9091. feet Junk (measured) 1258 feet Effective Depth measured 1313 feet Packer (measured) 11763 true vertical 9090.35 feet (true vertical) 8261 Casing Length Size MD TVD Burst Collapse Structural Conductor 115 30" 157.5# B GRADE SURFACE - 115 SURF - 115 880 Surface 1190 20" 94# H -40 SURFACE - 1190 SURF - 1190 1530 520 Intermediate 2704 13 -3/8" 72# N -80 SURFACE - 2704 SURF - 2704 4930 2670 Production 12134 9 -5/8" 47# N -80 SURFACE - 12134 SURF - 8447 6870 4760 Liner 767 7 "29# N -80 11811 - 12758 8284 - 8800 8160 7020 Liner Perforation depth: Measured depth: C 12758 - 13135 True Vertical depth: 8680-9027 _ _ Tubing: (size, grade, measured and true vertical depth) 7"26# L -80' " SURFACE - 2897 SURFACE - 2897 5 -1/2" 26# L -80 2897-11784 2897-8271 4 -1/2" 26# L -80 11784 - 11887 8271-8322 Packers and SSSV (type, measured and true vertical depth) 9- 5/8 "X5 -1/2" BAKER SB -3A PKR 11763 8261 12. Stimulation or cement squeeze summary: Intervals treated (measured): SEP 1 7 2010 Treatment descriptions including volumes used and final pressure: Ab*11111 R 41 isill CVO, WNV Aft 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory[] pavelopment u Service ❑ Daily Report of Well Operations X 16. Well Status after wotW SUSPENDED Oil Gas WDSPL GSTOR ❑ WAG ❑ GINJ ❑ WINJ ❑ SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Pre Printed Name Gary Pre a Title Data Management Engineer Signature Pb 564 -4944 Date 2 SEP Form 1 - Ily Z C 'i ifs '40K //A Prudhoe Bay Unit Well 04 -04A, PTD 1950240 Suspended Well Inspection Report BP Exploration (Alaska) Inc. (BPXA) completed a suspended well inspection of PBU 04 -04A on 8/21/10. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f)). • Suspended Well Site Inspection form documenting the well pressures and site condition. AOGCC inspector Chuck Scheve witnessed the inspection. • Wellbore diagram illustrating the current configuration of the well • Pad map showing the well location and other wells within one - quarter mile radius of the surface location • Photographs showing the condition of the wellhead and the surrounding location Additional pertinent information: • PBU 04 -04A was suspended on 4/17/95 after an unsuccessful coiled tubing sidetrack attempt. • PBU 04 -04A is located on a pad with active producing wells and /or service - wells. • The strata through which the well was drilled is neither abnormally geo- pressured or depleted. • The most recent wellbore diagram indicates the well is secured with cement. However, well file records do not document the placement of the cement. P lans are underway to determine the exact downhole condition and any additional work to ensure the well meets suspension requirements. • Passing inner annulus and tubing pressure tests prior to the sidetrack attempt indicate that portion of the well is mechanically sound. MLB 09117/10 Suspended Well Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UNIT 04 -04A Field/Pool: PRUDHOE BAY Permit # (PTD): 1950240 API Number: 50029200960100 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 4/17/995 Surface Location: Section: 34 Twsp: 11N Range: 15E Nearest active pad or road: Prudhoe Bay Drillsite #4 Take to Location Digital camera Map showing well location /Aerial photos Brief well history Wellbore diagram showing downhole condition Latest Sundry or Completion report Past Site Visit documentation Site clearance documentation Pressure gauges, fittings, tools Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Good Location cleanup needed: No Pits condition: Clean Surrounding area condition: Clean Water /fluids on pad: No Discoloration, Sheens on pad, pits or water: None Samples taken: None Access road condition: Good Photographs taken (# and description): 5; general site and wellhead Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Wellhead /tree /valve description, condition: Good Cellar description, condition, fluids: Gravel level Rat Hole: N/A Wellhouse or protective barriers: Barricade Well identification sign: No Tubing Pressure (or casing i - ubing�: NIA Annulus pressures: 460 psi 0 psi OA 220 psi OOA Wellhead Photos taken and des ption): 5; general site and wellhead Work Required: Wellhouse sign ordered Operator Rep (name and signature): Torin Roschin er r - - h. :E, r—� °'" AOGCC Inspector: Chuck Scheve Other Observers: Ryan Holt Inspection Date: 8/21/2010 AOGCC Notice Date: 8113/2010 Time of arrival: 9:40 AM Time of Departure: 9:50 AM Site access method: Access Road TREE ? • WELLHEAD - MCEVOY IR AFETY NOTES: 1-12S OVER 30OPPM ACTUATOR= MCEVOY AXE -SON 04 -04A KB. ELEV = 64' BF. R EV KOP = ? Max Angle = 63 @ 6300' 2205 7" CAM BAL -O SSSV NlP ID= 5.937 Datum MD = 12847' Datum TVD = 8800' SS GAS LIFT MANDRELS STA MD TVD DEV TYPE MAN LATCH 1 2988 2988 4 CA /MMIG RK 2 5592 5002 60 CA /MMIG RK 13 -3/8" CSG, 72 #, N-80, ID = 12.347" 2704' 3 7420 5914 57 CA /MMIG RK 4 8147 6329 53 CA /MMIG RK Minimum ID = 3.80" @11875' 5 8741 6683 55 CA /MMIG RK 6 9295 6993 57 CA /MMIG RK 4 -1/2" OTIS XN NIP MILLED OUT 7 9877 7303 58 CA /MMIG RK 8 10438 7593 59 CA /MMIG RK 9 11056 7907 60 CA /MMIG RK 7" TBG -IPC, 26 #, L -80, 0.0383 bpf, ID = 6.276" 289T 10 11568 8163 1 60 CA /MMIG RKP TOP OF 5 -1/2" TBG -IPC 2897 2897 X 7" X i 11763 9 -5/8" X 5 -1/2" BAKER SB -3A PKR 11778 5 -1/2" BAKER MLLOUf EXTENSION TOP OF 4 -1/2" TBG -IPC� 11784 11784 7 - 5/8" X 4 - 1/2" XO TOP OF 7" LNR 11811 11875 4 -1/2" OTIS XN NIRMILLOUT, ID = 3.80" 11886 4 -1/2" BAKER SHEAR SUB 11887 4 -1/2" TUBING TAI 11870' ELMD TT LOG NOT A VAILABLE 9 -5/8" CSG, 47 #, N -80, ID = 8.681" 12134 PERFORATION SUMMARY 7" MILLOUT WINDOW REF LOG: BHCS ON 10/15/71 12566'- 12573' ANGLE AT TOP PERF: 57 @ 12600' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE 2 12600 - 12610 S 09/17/93 PBTD 12520 2 12614 - 12626 S 09/21/90 6 12625 - 12640 S 08/02/94 2 12900 - 12908 S 09/17/93 2 12908 - 12910 S 09/17/93 12582 4 DRLL MOTOR AND BIT 6 12960 - 12962 S 09/17/93 6 12962 - 12967 S 09/17/93 6 12967 - 12968 S 09/17/93 6 12980 - 12986 S 09/17/93 6 12986 - 12990 S 09/17/93 TD 13135 7 "LNR, 29 #, N-80, 0.0371 bpf, ID = 6.184" 13200 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/23/71 ORIGINAL COMPLETION 05130/06 DTM WELLHEAD CORRECTION WELL: 04 -04A 12/05/89 LAST WORKOVER PERMIT No: 1950240 12/21/00 SIS -MWH CONVERTED TO CANVAS AN No: 50- 029 - 20096 -01 01/09/01 SIS-LG REVISION SEC 34, T11 N, R15E 4021.73 FEL 4421.95 FNL 02/17/01 GSN /tp CORRECTIONS 11/02101 WB/TP I SURF LOC CORRECTIONS BP Exploration (Alaska) L i er/Exit 35 i 695' — 34 20 <En 21 22 Ta k 4901 Tr 23 Lo n,9 24 0 ✓/ 19 ; r Arum 1 18 Stara e 230 17 33 Area 1s O 10 47 • 38 36 4 6 Q 9 bo 8 A o —... -.__ _.._• N 41 39 49 25 48 Y 12 915 13 491 49 11 43 4901 14 Enter /Exit 28 Fmergen�y Ge nerator 4902 45 29 42 30 - 45 4 811 31 6 32 f 37 Enter /Exit `� 5 230' 4 225' in co 3 LO 2 40 j_ _ 1 D 1508' WELL PRODUCER ■ or C WELL INJECTOR A DATE :01/05/2009 SCALE: 1" = 300' MAP DATE: 2007 PBU - DS 4 WELL SLOT W /CONDUCTOR ❑o bs14495.dgn S - 4 &Grind & Inject �! " July 14, 2009 i Approximate Scale: 1' " =40U 2009- 19c -6 -17 ALTN)* 1LTRK Y 4 1 5 1 t o t a r -, s` r .r } t t r _ s � AM i q �,, 1'j• f J r � �7hlC�d �7s ,� 5' �S C�(I � wi r p` `;s,• y`( 1 S 1. M ! 3� �d i �y J �� ;� �� N .�=� �; �,� - �; <; ¢� i I �� a .;, >: � ; PE R H I T 9 5 '~ 0 2 4 i"q 'S F' 7 R C' P .-.9 5 ~' 0 2 4 N G P/' R 0 P 95. .... 0:>4~. 73 93 S~,.) .9 ri l VD · ' Dal.e i2/ 0 J/ Fi: I.J i"-.! Il:,/::,, 1 J:{: ..... R [-: ,2 ',./C' Ar"e cir'y d'i:tch sarnpies Was the we'i'i cor'ed? THE MATERIAL UNDER THIS COVER HAS BEEN MICROFILMED ON OR BEFORE JANUARY 03,2001 M PL E ATE IA L U N D W E R TH IS M ARK ER spenn -sun WELL LOG TRANSMITTAL To: ARCO Alaska Inc. Jl~ August 26, 1995 Attn: Larry Grant, AOGCC /~/~ ~/~G P.O. Box 100360 ~.~ Anchorage, Alaska 99510-0360 MWD Formation Evaluation Logs - DS 4-04A, AK-MW-50026 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 4-04A: 2" x 5" MD Gamma Ray Logs: 50-029-20096-01 2" x 5" TVD Gamma Ray Logs: 50-029-20096-01 1 Blueline 1 Folded Sepia 1 Blueline 1 Folded Sepia RECEIVED 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TRANSMYITAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Atm.: Howard Okland 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - DS 04-04A AK-MW-50026 August 21, 1996 The technical data listed below is being submitted herewith. Please acknowledge receipt by remming a signed copy of this transmittal letter to the attention of.' Jim 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, AJaska 99518 ° (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMisSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1 Status of Well Classification of~Cer~f'ce'.~Vell '-"/,-2 OIL [~ GAS r--] SUSPENDED [~ ABANDONED [~ SERVICE [~ 2 Name of Operator 7 Permit Number ARCO Alaska, Inc 95-24 3 Address 8 APl Number P.O. Box 100360, Anchorage, AK 99510-0360 50-029-20096-01 4 Location of well at surface 9 Unit or Lease Name 916' FNL, 382' FEL, Sec. 34, T11N, R15E, UM. ~'~J~' ~"'~?"~ PRUDHOE BAY UNIT AtTop Producing Interval ~ ~-~. .... '.-.,' ~ ~0 Well Number 4-04^ At Total Depth ~' ' 11 Field and Pool 1261' FWL, 860' FSL, Sec. 36, T11N, R15E, UM. PRUDHOE BAY FIELD 5 Elevation in feet (indicate KB, DF, etc.) 6 Lease Designation and Serial No. PRUDHOE BAY OIL POOL 64' RKB ADL 28324 12 Date Spudded 13 Date T.D. Reached 14 Date Comp., Susp. or Aband. 15 Water Depth, if offshore 116 No. of Completions 4/5/95 (milled window). 4/10/95. 4/17/95 (Suspended) N/A feet MSLI 1 17 Total Depth (MD+TVD) 18 Plug Back Depth (MD+TVD) 19 Directional Survey 120 Depth where SSSV set 21 Thickness of permalrost 13135' MD / 9091' TVD 13135' MD / 9091' TVD YES [~ NO [~I 2205' feetMD 1870'(approx) 22 Type Electric or Other Logs Run MWD/GR; Sonic; IRT/GR. 23 CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD CASING SIZE WT. PER FT. GRADE TOP Bo'FrOM HOLE SIZE CEMENTING RECORD AMOUNT PULLED 30" 157.5# B Surf 115' 39" 229 Sx Fondu Neat 20" 94# H-40 Surf 1190' 26" 1000 Sx Fondu Neat 13-3/8" 72# N-80 Surf 2704' 17-1/2" 600 Sx Fondu Neat 9-5/8" 47# RS-95, N-80 Surf 12134' 12-1/4" 1000 Sx Class 'G'& 350 Sx PF II 29# N-80 I 11811' 12578' 8-1/2" 700 Sx Class 'G' 7" 24 Perforations open to Production (MD+TVD of Top and Bottom and 25 TUBING RECORD interval, size and number) SIZE DEPTH SET (MD) PACKER SET (MD) 7" / 5.5" / 4.5" Tbg 2897' / 11784' / 11887' 11763' * 3.75" Openhoie: 12578 - 13135' MD (8680 - 9027' TVD). ~26 ACID, FRACTURE, CEMENT SQUEEZE, ETC * a 3.75" Hole Opener BHA is stuck in openhole at 12582' MD (top of fish' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED N/A 27 PRODUCTION TEST Date First Production Method_ of Operation (Flowing, gas lift, etc.) Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE J GAS-OIL RATIO I TEST PERIOD I~ Flow 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. *NOTE: See 4-4A Coil Tubing Drilling Operations Summary attached. * This 10-407 submitted as required per 10-401 Permit issued 3/8/95. J U N -" 6 !995 Atr, s~,~ {Ji~ & Gas Cons. Commission Anchorr Form 10-407 Submit in duplicate Rev. 7-1-80 CONTINUED ON REVERSE SIDE 30. GEOLOGIC MARi~RS FORMATION TESTS NAME Include interval tested, pressure data, all fluids recoverd and gravity, MEAS. DEPTH TRUE VERT. DEPTH GOR, and time of each phase. Top Sadlerochit 12578' $732' N/A RECEIVF..D d u N - 6 31. USTOF ATTACHMENTS ~B$~,~ Ut~ & Gas CUllS. Summary of 4-04A Coil Tubing Sidetrack Drilling Operations. AQchor~' 32. i hereby certify that the foregoing is true and correct to the best of my knowledge Signed ~.~ .~....~~T~.~"~'~C')O'~itle ~n¢ineeringSuperv,sor Date 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". Form 10-407 4-04A DESCRIPTION OF WORK COMPLETED COILED TUBING SIDETRACK DRILLING 4/5/95 · RIH w/drilling BHA & drilled 3.8" pilot hole through the cement plug to 12574' MD. POOH w/BHA. & RIH w/milling BHA, oriented in pilot hole, & drilled from 12572' to 12574' MD. POOH w/BHA. & RIH w/concave milling BHA, & started milling window in the 7" liner from 12565' to 12569' MD. MU MU 4/6/95 · Continued milling window to 12574' MD, then POOH w/BHA. MU & RIH w/milling BHA. milling window to 12578' MD. Reamed window & displaced well to FIo-Pro. POOH w/BHA. Completed 4~7~95 · MU & RIH w/drilling BHA & drilled 3.75" sidetrack wellbore from 12575' to 12665' MD. Surveyed & circulated hole clean while POOH w/BHA. MU & RIH w/drilling BHA & continued drilling 3.75" hole to 12800' MD. 4~8~95 · Drilled to 12869' MD. POOH w/BHA. MU & RIH w/drilling BHA & drilled to 12885' MD. 4~9~95 · Drilled to 12956' MD where BHA stuck. Circulated 30 bbls Hi-Vis sweep, followed by 53 bbls Crude. BHA came free. Displaced back to FIo-Pro & continued drilling to 13047' MD. 4/10/95' Drilled to 13135' MD. POOH w/BHA. RU SL & made 2.75" dummy runs; both stopped at 11870' MD. RIH w/multishot; tool stopped at 12532' MD. 411 I 195 · RIH w/MWD/GR survey on CT. Took survey to 12895' MD, then POOH & PU drilling BHA. RIH washing down from 12590' to 13135' MD. Circulated & conditioned hole. Spotted lube pill from 13135' to window. POOH w/BHA. RD CTU#2. RU CTU#1. 4/12/95- RIH w/IRT/GR. Logged down from 12343' to 12600' MD; could not go deeper. POOH w/logging tools. RIH w/Sonic & logged down from 12420' to 12580' MD. POOH w/Sonic tool. RD CTU #1. RU CTU #2. 4/13/95: PT equipment. MU & RIH w/drilling BHA to bridge at 12580' MD. Attempted to drill through bridge w/no progress. POOH to sweep twice to TT at 11887' MD. Circulated at 12510' MD while increasing MW to 9.1 ppg. Circulated OOH w/BHA. MU & RIH w/3.75" hole opener BHA. Reamed to 13100' MD. POOH w/BHA & tools stuck at 12581' MD. Worked pipe. 4/14/95' Worked stuck pipe. Disconnected from BHA & POOH w/CT. MU & RIH w/fishing tools. Tagged fish at 12579' MD & attempted to fish stuck BHA. POOH w/fishing tools. MU & RIH w/fishing BHA. Latched & jarred on fish. Released fish & POOH. 4115195: MU fishing BHA & RIH to latch fish. Jarred on fish; no movement. Relatched fish & continued jarring. Released from fish & POOH. Released from fish & circulated. 411 6~95 - 411 7~95' RIH w/washpipe but could not pass 12548' MD. POOH. MU & RIH w/muleshoe; could not pass 12548' MD. POOH. RIH wFI-FL &tagged fish at 12582' MD. POOH. FP wellw/Meth Water. RD CTU. CTU work on the well has been suspended. A future Rig cement P&A of the 4-04A Rig drilled 4-04B Sidetrack wellbore are currently being evaluated. ! % ~",,, ~,~ L/V ~U Alaska 0il & Gas Cons. Commission SPF~ -SUN DRILLING SERVICES ANCHORAGE ALASKA ARCO ALASKA INC PBU/4-04A ~00292009601 .ORTH SLOPE BOROUGH COMPUTATION DATE: 4/20/9 TRUE SUB-SEA COI/RS COURSE MEASD VERTICAL VERTICAL INCLN DIRECTION DEPTH DEPTH DEPTH DG MN DEGREES PAGE 1 DATE OF SURVEY: 041195 MWD SURVEY JOB NUMBER:/'~AK~W-50026 KELLY BUSHiN~"'iELEV..~?_,, 64.00 FT. OPERATOR: ARCO '~.~A,/,~NC DLS TOTAL '~., RECTANGULAR COORDINATES VERT. DG/100 NORTH/SOUTH EAST/WEST SECT. 12575 8678.00 8614.00 12612 8700.03 8636.03 12635 8715.43 8651.43 12669 8738.44 8674.44 12769 8807.45 8743.45 57 48 S 54.80 E .00 49 2 S 56.00 E 23.84 46 52 S 57.00 E 9.93 47 54 S 58.31 E 4.13 45 0 S 65.52 E 5.96 3328.70S 6591.00E 7378.40 3345.57S 6615.42E 7407.94 3355.00S 6629.66E 7424.97 3368.38S 6650.80E 7449.95 3402.59S 6714.67E 7522.40 12869 8880.06 8816.06 41 43 S 63.93 E 3.47 13136 9091.11 9027.11 33 42 S 63.90 E 3.00 3431.85S 6776.70E 7590.83 3503.60S 6923.28E 7753.82 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7759.32 FEET AT SOUTH 63 DEG. 9 MIN. EAST AT MD = 13136 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 119.00 DEG. ~,, 1,;, Oil & Gas Cons. Cor~'lmission Anchor: SPE~-"~-~-SUN DRILLING SERVICES ANCHOR_AGE ALASKA PAGE 2 .~CO ALASKA INC PBU/4-04A .~00292009601 ORTH SLOPE BOROUGH COMPUTATION DATE: 4/20/95 DATE OF SURVEY: 041195 JOB NUMBER: AK-MW-50026 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 12575 8678.00 8614.00 13136 9091.11 9027.11 3328.70 S 6591.00 E 3897.00 3503.60 S 6923.28 E 4044.89 147.89 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ARCO ALASKA INC PBU/4-04A ~.500292009601 30RTH SLOPE BOROUGH COMPUTATION DATE: 4/20/95 SPY~-- -SUN DRILLING SERVICES ~' ~ ANCHORAGE ALASKA DATE OF SURVEY: 041195 PAGE JOB NUMBER: AK-MW-50026 KELLY BUSHING ELEV. = 64.00 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 12575 8678.00 8614.00 3328.70 S 6591.00 E 3897.00 12706 8764.00 8700.00 3382.35 S 6674.70 E 3942.68 12847 8864.00 8800.00 3425.51 S 6763.62 E 3983.33 12978 8964.00 8900.00 3462.88 S 6840.11 E 4014.69 .. 13103 9064.00 9000.00 3495.48 S 6906.71 E 4039.21 13135 9090.27 9026.27 3503.36 S 6922.78 E 4044.73 45.68 40.65 31.36 24.52 5.52 THE CALC~TION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS RECEIVED Oil & Gas Oon$. OommissJon ARCO ALASKA INC PBU/4-04A 500292009601 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/20 SP~-~-Y-SUN DRILLING SERVICES /95 ' ~ PAGE 1 ANCHORAGE ALASKA DATE OF SURVEY: MWD SURVEY JOB NUMBER: AK-MW-50026 KELLY BUSHING ELEV. = 64.00 FT. OPER3ITOR: 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. 12575 8678.00 8614.00 57 48 12612 8700.03 8636.03 49 2 12635 8715.43 8651.43 46 52 12669 8738.44 8674.44 47 54 12769 8807.45 8743.45 45 0 S 54.80 E .00 3328.70S 6591.00E 7378.40 S 56.00 E 23.84 3345.57S 6615.42E 7407.94 S 57.00 E 9.93 3355.00S 6629.66E 7424.97 S 58.31 E 4.13 3368.38S 6650.80E 7449.95 S 65.52 E 5.96 _ 3402.59S 6714.67E 7522.40 12869 8880.06 8816.06 41 43 S 63.93 E 3.47 13136 9091.11 9027.11 33 42 S 63.90 E 3.00 3431.85S 6776.70E 7590.83 3503.60S 6923.28E 7753.82 THE CALCULATION PROCEDURES A_RE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7759.32 FEET AT SOUTH 63 DEG. 9 MIN. EAST AT MD = 13136 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 119.00 DEG. RECEIVED APR ?-- 7 1995 ~,laska Oil & Gas Cons. Commission Anchorage ORIGINAL SF~Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASICA INC PBU/4-04A 500292009601 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/20/95 DATE OF SURVEY: 041195 JOB NUMBER: AK-MW-50026 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 12575 8678.00 8614.00 13136 9091.11 9027.11 3328.70 S 6591.00 E 3897.00 3503.60 S 6923.28 E 4044.89 147.89 THE CALCULATION PROCEDURES ~RE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. S~-~=RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC PBU/4-04A 500292009601 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/20/95 DATE OF SURVEY: 041195 JOB NUMBER: AK-MW-50026 KELLY BUSHING ELEV. = 64.00 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 VERTICAL DIFFERENCE CORRECTION 12575 8678.00 8614.00 3328.70 S 6591.00 E 3897.00 12706 8764.00 8700.00 3382.35 S 6674.70 E 3942.68 45.68 12847 8864.00 8800.00 3425.51 S 6763.62 E 3983.33 40.65 12978 8964.00 8900.00 3462.88 S 6840.11 E 4014.69 31.36 13103 9064.00 9000.00 3495.48 S 6906.71 E 4039.21 24.52 13135 9090.27 9026.27 3503.36 S 6922.78 E 4044.73 5.52 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS SPFJ'-~-Y-SUN DRILLING SERVICES ANCHORAGE ALASKA ARCO ALASKA INC NORTH SLOPE BOROUGH COMPUTATION DATE: 4 / 2 0 / 9 5 DATE OF SURVEY: MWD SURVEY JOB NUMBER: AK-MW-50026 KELLY BUSHING ELEV. = 64.00 OPEKATOR: ARCO ALASKA INC DUPEtI ATE 041195 FT. 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. 12575 8678.00 8614.00 57 48 12612 8700.03 8636.03 49 2 12635 8715.43 8651.43 46 52 12669 8738.44 8674.44 47 54 12769 8807.45 8743.45 45 0 S 54.80 E .00 3328.70S 6591.00E 7378.40 S 56.00 E 23.84 3345.57S 6615.42E 7407.94 S 57.00 E 9.93 3355.00S 6629.66E 7424.97 S 58.31 E 4.13 3368.38S 6650.80E 7449.95 S 65.52 E 5.96 .. 3402.59S 6714.67E 7522.40 12869 8880.06 8816.06 41 43 S 63.93 E 3.47 13136 9091.11 9027.11 33 42 S 63.90 E 3.00 3431.85S 6776.70E 7590.83 3503.60S 6923.28E 7753.82 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 7759.32 FEET AT SOUTH 63 DEG. 9 MIN. EAST AT MD = 13136 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 119.00 DEG. RECEIVED APR 2 7 1995 Alaska Oil & Gas 6ons. OommisSiOl'l Anchorage DUPLICATE SPF3-~.Y-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 ARCO ALASKA INC PBU/4-04A 500292009601 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/20/95 DATE OF SURVEY: 041195 JOB NUMBER: AK-MW-50026 KELLY BUSHING ELEV. = 64.00 FT. OPERATOR: ARCO ALASKA INC INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES MD-TVD VERTICAL NORTH/SOUTH EAST/WEST DIFFERENCE CORRECTION 12575 8678.00 8614.00 13136 9091.11 9027.11 3328.70 S 6591.00 E 3897.00 3503.60 S 6923.28 E 4044.89 147.89 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. SPF~RY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE ARCO ALASKA INC PBU/4-04A 500292009601 NORTH SLOPE BOROUGH COMPUTATI ON DATE: 4 / 20 / 95 DATE OF SURVEY: 041195 JOB NUMBER: AK-MW-50026 KELLY BUSHING ELEV. = 64.00 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 VERTICAL DIFFERENCE CORRECTION 12575 8678.00 8614.00 3328.70 S 6591.00 E 3897.00 12706 8764.00 8700.00 3382.35 S 6674.70 E 3942.68 45.68 12847 8864.00 8800.00 3425.51 S 6763.62 E 3983.33 40.65 12978 8964.00 8900.00 3462.88 S 6840.11 E 4014.69 31.36 .. 13103 9064.00 9000.00 3495.48 S 6906.71 E 4039.21 24.52 13135 9090.27 9026.27 3503.36 S 6922.78 E 4044.73 5.52 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS C! I::i ILL I I~1 G S ~ !:!~./I I~ ~ S AOGCC Larry Grant 3001 Porcupine Dr Anchorage, AK 99501 Re: Survey Data - 4-04A Dear Mr. Grant, Enclosed are two hard copies of the MWD survey(s). Well 4-04A Tied in at 12,575' Please call me at 563-3256 if you have any questions. Sincerely, Sandra Lufkin Region Assistant Enclosures. April 26, 1995 RECEIVED APR 2 / ,1 ,J Alaska Oil & Gas Cons. Commission Anchorage 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 John~~, Chairmah,,~,,~ DATE: April 6, 1995 THRU: Blair Wondzell, ~r~j,~ FILE NO: P. I. Supervisor FROM: Lou Grimaldi, ~r~ SUBJECT: Petroleum Inspector QF9JDFCD.DOC Rig BOPE inspection Nabors 3NS/Dowell CTU #1 ARCO well # DS4-4 Prudhoe Bay Field PTD # 95-24 Thursday, April 6, 1995.: I traveled to Arco's DS-4 in the Prudhoe Bay Field to make a Rig BOPE inspection on Nabors rig 3NS/Dowell CTU #1. The rig was drilling ahead when I arrived, i found all BOPE equipment to be in place and in better external condition than my previous inspection. All equipment was in apparent good working order. I discussed the proper entrys to be made in our BOP test form with Gary Goodrich (Arco rep.) who will pass this on to his relief Jeff Hupp. Access to the rig was OK. The location surrounding the rig was clean. SUMMARY: I made a Rig/BOPE inspection on Nabors 3NS/Doweil CTU #1. Attatchments: QF9JDFCD.XLS cc: Bruce Smith (Arco CTU supervisor) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RIG / BPS INSPECTION REPORT OPERATION: Drig Contr: Operator: Location: Drilling X Workover Cmpl. UIC DATE: Well Name DS 4-4 Dowell Rig No. CTU #2 Rep. Arco Rep. Gary Goodrich Section 34 T. 11N R. 15E M. U 4/6/95 PTD# 95-24 Rig Ph.# INSPECTION ITEMS (A.) B.O.P. STACK Wellhead fig wkg press Stack wkg press Annular preventer Pipe rams Blind rams Stack anchored Chke/kill line size All turns ( chke & kill Ln.) HCR valves (chke & kill Ln.) Manual valves (chke & kill Ln.) Connections (Flgd, Whd, Clamped Drilling spool Flow Nipple Flow monitor Control lines fire protected INSPECTION ITEMS (B.) CLOSING UNIT Working pressure Fluid level Operating pressure Pressure gauges Sufficient valves Regulator bypass 4-way valves (actuators) Blind rams handle cover Driller control panel Remote control panel Firewall Nitrogen power source (backup) Condition (leaks, hoses, ect.) REMARKS: IN COMPLIANCE IN COMPLIANCE INSPECTION ITEMS MUD SYSTEM Pit level floats installed Flow rate sensor Mud gas separator Degasser Separator bypass Gas sensors Choke line connections Trip tank INSPECTION ITEMS (D.) RIG FLOOR Kelly cocks (upper, lower, IBOP) Floor valves (dart, ball, ect.) Kelly & floor valve wrenches Drillers console (flow monitor, flow rate indicator, pit level indicators, gauges) Kill sheet up-to-date Gas detection monitors H2S & methane) Hydraulic choke panel Choke manifold INSPECTION ITEMS (E.) MISC. EQUIPMENT Flare/vent line All turns targeted downstream choke lines) Reserve pit tankage Personnel protective equip, avail. All Drillsite Supervisors Trained For Procedures H2S probes Rig housekeeping IN COMPLIANCE IN COMPLIANCE IN COMPLIANCE RECORDS: Date of Last Rig / BPS Inspection Date of Last BOP Test Resulting Non-Compliance Items: Non-Compliance not corrected & Reason: Date Corrections Will Be Completed: BOP Test & Results Properly Entered On Daily Record? OK 4/4/95 Kill Sheet Current? Distribution: orig - Well File c - Oper,/Rig c - Database c - Trip Rpt File c- Inspector AOGCC REP: OPERATOR REP: FI-022 (Rev. 3/93) Louis R Grimaldi QF9JDFCD.XLS ~LA~KA OIL AND GA~ CONSERVATION COM~IISSION TONY KNOWI_ES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 March 8, 1995 Von Cawvey Engineering Supervisor ARCO Alaska, Inc. P O Box 100360 Anchorage, AK 99510-0360 Re: Prudhoe Bay Unit 4-04A ARCO Alaska, Inc. Permit No. 95-24 Sur. Loc. 916'S & 382'W of NE cr, Sec. 34, TllN, R15E, UM Btmnhole Loc. 849'FSL & 4034'FEL, Sec. 36, TllN, R15E, UM Dear Mr. Cawvey: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill 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. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a test of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Da~y~Wi ~ohnston5 ' Chairman BY O~ER OF T~ CO~ISSION dlf/Enclosures cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA AD-,oH OIL AND GAS CONSERVATION COMMI,-%SION PERMIT TO DRILL 2O AAC 25.OO5 la. Type of Work Drill __ Redrill X lb. Type of Well Exploratory__ Stratigraphic Test Development Oil .~_ Re-Entry__ Deepen _ Service _ Development Gas __ Single Zone x_~ Multiple Zone 2.. Name of Operator 5.Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska, Inc. RKB 64' 3. Address 6. Property Designation P. O. Box 100360, Anchorage, AK 99510-0360 ADL~ ~2'..~.~_~-/z ,~,,~,~ Prudhoe Ba¥/Prudhoe Bay Oil 4. Location of well at surface 7. Unit or property Name 11. Type Bond (see 20 AAC 25.025) 916' S & 382'W of NE cr, Sec 34, T11N, R15E, UM Prudhoe Bay Unit Statewide At top of productive interval 8. Well number Number 1005' FSL & 4316 FEL, Sec 36, T11N, R15E, UM 4-04A #U-630610 At total depth 9. Approximate spud date Amount (Proposed) 849' FSL & 4034' FEL, Sec 36, T11N, R15E, UM March, 1995 $200,000 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) property line 382 feet No Close Approach 13093' MD / 9040' TVD 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035(e)(2)) kickoff depth 12575' MD Maximum hole angle 58° Maximum surface 3000 psig At total depth (TVD) 3500 psig 18. Casing program Setting Depth size Specification Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD 'I-VD MD TVD (include stage data) 3-3/4" 2-7/8" 6.4 13CR- FOX 1250' 11843' 8300' 13093' 9040 20 bbls L80 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured 13200 feet Plugs(measured) Cement Plug below 12651' MD. true vertical 9072 feet Effective depth: measured 12651 feet Junk (measured) true vertical 8719 feet Casing Length Size Cemented Measured,depth True Vertical depth Structural 115' 30" 229 Sx Fondu 115' 115'RECEIVE[ Conductor 1 150' 2 0" 1000 Sx Fondu Neat 1 150' 1 1 50' Surface 2640' 1 3-3/8" 600 Sx Fondu Neat 2704' 2704' Production 12070' 9-5/8" 1000 Sx CIG & 350 Sx PF II 12134' 8483' Liner 1389' 7" 700SxClG 13200' 9072'FEB 23 ]995 Perforation depth: measured 12625 - 12640' ~t~$ka 0il & Gas Cons. C0m true vertical 8705 - 8713' Anoh0ra 20. Attachments Filing fee x Property plat __ BOP Sketch __x Diverter Sketch _ Drilling program x_z_ Drilling fluid program __ Time vs depth plot_ Refraction analysis _ Seabed report _20 AAC 25.050 requirements _ 21. I hereby certify that the foregoing is true and correct to the best of my knowledge Titlle Engineering Supervisor Date , [ ) Commission Use Only Perrr~t Num J APl number~__~ I Approv,~)date~, J See cover letter for o? -' /",.~J other requirements Conditions of approval Samples rec~i,red __Yes ~ No Mud log required __ Yes ~ No Hydrogen sulfide measures.,~Y e s N o Directional survey required ,~ Yes N o - Required working pressure for BOPE ~2M; ~ 3M- __ 5M' __ 1 OM' ~ 1 5M 500 psi for CTU Other:Original Sigr 0 0avid W. d0h~]s:[0o by order of k~/~/? Approved by Commissioner the commission Date Subm [iplicar~ DS 4-4A CT Sidetrack and Completion Intended Procedure Objective: Directionally drill a twin well from the existing wellbore. Complete with 2-7/8" liner. Intended Procedure: P&A existing interval. ~ Ap?m~q) ~ 9~" 0;4~ Mill window in 7" casing at-12,575' md. Drill to the base of Sadlerochit while dropping angle to -42°' Run openhole logs. Run and cement 2-7/8' chrome liner. Perforate, return well to production. RECEIVED FEB 2,5 1995 AlaSka 0il & Gas Cons. Commission Anchora" February 10, 1995 DS 4-4A Operational Notes/ Potential Drilling Hazards H2S production, 320 ppm measured on 10/7/94 BHP: 3550 psi @ 8800' ss (7.8 ppg EMW), BHT 187 °F (estimated values based on offset wells). No over pressured zones are anticipated. Maximum anticipated WHP w/ full column of gas' 2750 psi. Expected GOC: 8650' ss. Suspected gas underruns at 8752'-55~, 8770'-75', 8804'-08', 8860'-65' ss. Potential high perm intervals in Victor Zone 3 (8615' ss) and Romeo Zone 2A (8800~ ss). These intervals warrant consideration for lost circulation or high rate gas production during underbalanced operations to address differential sticking concerns. AlasKa Uti & Gas Cons, C0[nmission Anch0ra ~- February 10, 1995 ARCO Alaska, Inc. PRUDHOE BAY UNIT DISBURSEMENT. COUNT P.O. BOX 102776 ANCHORAGE, AK 99510-2776 ALASKA DEPT OF REVENUE 3001 PORCUPINE ANCHORAGE AK 99501 PAGE 10" 1 JANUARY 25, i995 TRACE NUMBER: CHECK NUMBER: 225072414 225072414 AMOUNT PAID : $100.00 PAY ENTITY: 0201 VENDOR NO: N00072020221 INQUIRIES: (907)263-4422/4988 (FAX) P.O. BOX 103240 ANCHORAGE, AK 99510-3240 !NVOICE DATE INVOICE NUMBER vOUCHER GROSS AMOUNT DISCOUNT ADJUSTMENT NE'- A,M, OUN'~ $1 oo. co VRO 11995SDH01 i:!i;;) ::!:: ::C06~:p.:BSo;~S~.It'4:: $100. O0 ;-i!i !: ! i ::i;:-iDR-i]:iil~Li:~N~!! !~][RM I T F E E FOR WE L L 4-O4A . · "' RECEIVED FEB 2 3 1995 AlaSka 0il & Gas Cons. Commission Anchor~_ :-. PLEASE DETACH BEFORE DEPOSITING CHECK ARCO Alaska, Inc. Prudhoe Bay Unit Disbursement Account P.O. Box 102776 Anchorage, AK 99510-2776 PAY TO THE ORDER OF: ALASKA DEPT OF REVENUE CHECK NUMBER 225O72414 JANUARY 23, 1995 *** VOID AFTER 90 DAYS *** 73-426 839 0997609 EXACTLY *********** 100 DOLLARS AND O0 CENTS ¢*********** I00.00 .The First National Bank of Chicago-0710 Chicago, Illinois Payable Through Republic Bank Shelbyville, Kentucky TRACE NUMBER: 225072414 ITl LfI RECEIVED FEB 2 5 1995 Ai~ska Oil & Gas Cons. Commission Well ......... : DS04-04A(CT) (P3) Field ........ : PRUDHOE BAY, DS04 Computation..: MINIMUM CURVATURE' Units ........ : FEET Surface Lat..: 70.26901066 N Surface Long.: 148.28158338 W Legal Description Surface ...... : 4362 FSI, 382 FEL Tie-im/KOP...: 1030 FSL 4356 FEL Target ....... : 1005 FSL 43i6 FEL BHL .......... : 849 FSL 4034 FEL STATION M~AS INCLN IDENTIFICATION DEPTH ANGLE TIE-IN/KOP 12575 57.81 12600 53.19 ~ ....... TA3~GET ....... 12634 47.00 ~j DROP 1/100 12634 47.00 END 20.12/100 CURVE 12634 47.00 Anadrill Schlumberger Alaska District 1]11 ~ast 80th Avenue Anchorage, AK 99518 (907) 349-4511 Fax 349-2487 DIRECTIONAL WELL PLAN for SNARED SERVICES DRILLING [,3 -I~ (_iD DJ o] --,d r, ) LOCJ~TIONS - ALAS~ Zone: 4 X - Coo rd Y - Coord S34 TllN RiSE I~4 712475.66 5958944.68 S36 TllN R15E L~4 719157.68 5947803.43 S36 Tl114 R15E L~4 719197.78 5947779.60 S36 TllN R15E ~4 719484.29 5947631.20 PR0POSED WELL PROFILE DIRECTION VERT-DEPT~S SECT AZIMUTH BKB SUB-S DIST 125.22 8678 8614 7378 122.81 8692 8628 7399 119.00 8714 8650 7425 119.00 8714 8650 7425 119.00 87].4 8650 7425 Prepared ..... : 02/09/95 Section at...: 119.00 K~ elevation.: 64.00 ft Magnetic Dcln: 29.575 E Scale Factor.: 0.9 Convergence..: +1.61. ANADRILL AKA-DPC FEASIBILITY PLAN NOT APPROVED FOR EXECUTION PLAN - _ _z.~:. : ._~,.~.~,~-,...-_. RELATIVE-COORDINATES FROM-THE-WELLHEAD 3328.77 S 6591.00 E 3340.30 S 6608.06 E 3353.72 S 6630.41 E 3353.72 S 6630.41 E 3353.72 S 6630.41 E END 1/t00 DROP 12700 46.34 I19.~0 8759 8695 7473 3376.99 S 6672.39 E 12800 45.34 119.00 8829 8765 7545 3411.'77 S 6735.14 E 12900 44.34 119.00 8900 8836 7615 3445.96 S 6796.81 E 13000 43.34 119.0~ 8972 8908 7685 3479.54 S 6857.39 E 13093 42.41 119.00 9040 8976 7748 3510.16 S 6912.63 E STATE-PLANE TOOL DL/ X Y FACE 719157.68 5947803.43 tS'?L <TI 719175.06 5947792.39 156~. %.1 719197.78 5947779.60 LS i. 1 719197.78 5947779.60 LS 20.1 719197.78 5947779.60 LS 2~.1 TD 719240.40 5947757.53 L$ 1.0 719304.10 5947724.53 LS 1.0 719366.71 5947692.11 £,S t.0 719428.21 5947660.25 LS 1.0 719484.29 5947631.20 1.0 13093 42.41 119.00 9040 8976 7748 3510.16 S 6912.63 E 719484.29 5947631.20 1.0 IA.n.F*d['LI ¢c)9Fi C4C. 4~i'.~. I'¥1.b2 9:38 .AI~ t) ..... SH'ARFq " ' VICES DRT-' LING iii i __ j .I..I ~1 i i Marker Ioen%:flc~c~on WO §KB $1~CTN :INCLN ~ ........ ,~ ....... ,~, ~,, ~,~ ,~.oo VERTICAL SECTION VIEW C) D~0P ~/100 !26~4 87~ 7425 ~7.00 D) END 20.~2/~0~ Curve t86~4 87~4 74~ 47.00 El ~ND 1/I00 ~OP 13093 9040 7748 42.4~ Section at' 119,00 Fl TO ~3093 ~40 7748 42,4~ TVD Scale.' ~ inch = 200 feet 7900 .... )Oep Scale.' ~ inch : 200 ~eet , Drawn ' 02/09/g5 :~nadr ~ ] ] Sch ]um~erger ii ................... BiO0 ......... ~ ............. i . ................ ___ s2oo- ' I '7 :~~[~ ............... 'Ag A-DPC ~ ~ FEASIBILI~ P~N ~oo ' : mGT--A~;'~' '~u v:u I:OR I IVl ~ ~/I , ' EXDCUT(ON · ........................ ' i ......................................... 8600- - . ".. , . [ I : ~ , 8700 -~ , , 1 ~80~- - ~ .............................................................. , . 8900 ~ ' ~% .... , I ~ i ....... i .......... , AgLLIVL~2 ........ ; ........... : ~F~ p 3 199~ ~00 ,, ,, , ~ ~ ' : , ' : Al~s~ Oil & fas Cons. Commis : 6900 7000 7100 7200 7200 7400 7500 7600 7700 780C, 7900 Be, co a~OO 8~00 8300 Sect ion Departure -- . .l .,, i( IIll Ill · · . ~ - .. · ; FEB 9 ' 95 1 1: i 3 , 987 349 248T F'AGE. ltl -d Z, SHARED SEi~ViCE~ DRILL]:N6 ' ' DS04-04A (CT) (P3) PLAN VIEW illii i iii i i CLOSURE ' 7753 feet aL Az]rmth JJ6.92 . . ' ............ i ....... i ..... 3100 DECL [NAT [ON ' 29 575 E . , , S.C~tLE · j inch = J00 teet ' DR~ ....... 02/09/95 .................... ~ ............... .~5o BI ....... fan6E] ..... ~2 CI DR~ I/100 126~4 3354 , 66~ i , O] E~D 20.12/100 CURVE 1~3~- 3354 6630 · ' .... ~} ER0 J/100 DROP 13093 ''. 3510 69~3 fl 1~ 13093 ~0 69t3 . ANADRI[I AKA.DPt ' : .......................... ~EA~ I B ILI . i .. ~OT, NPPFtOVI :D F()R : ............ : · '~~ ........ i, R-CEI ~ - ' i ..... F:B 2', 1995 ~sk~ Oi & 6as 6 )~s~Gom' ]issio, ; i - ~ ............ Ancho : ~ .. ........ 355~ ' ~ - . . I / I / b]O0 6350 6400 6450 6500 6550 6600 6650 6700 6750 6ilO0 6850 6900 6950 7000 7050 7100 7150 /200 EaSl -> I~]aO~ ~ I I It i ~ fl~a~l~ ~ ~ ~ q qt ~ ti L ..... , ~ ~ ~ ~ . Fuel Shop Water Mud Pump Room 60/40 I Trplx Electric Charge Pump Preferred Major Equipment Layout for CT Drilling DrillingEquipment Trailer C T Drilling Wellhead Detail ~ CT Injector Head ~ Stuffing Box (Pack-Off), 10,000 psi Working Pressure I- '""',"r RECEIVED Methanol Injection--~ I, ~-- ~ E"r~ 2 3 1995 Offs 7" WLA Quick [ Connect "-"-' .~i,¢ 5k~, ~[{ & Gas Cons, Commission I I Anchor~ ,= 4-1/16" ID CT BOP Stack ~ 10,000 psi Working Pressure 2" Pump-In Blind Rams or Combination Cutter/Blinds Cutters or Combination Cutter/Blinds Slip rams Pipe rams Flange Flanged Fire Resistant Kelly Hose To Dual ChokeManifold Optional Flanged / / Manual Valve HCR Optlonah Space with spool pieces or valves to top of wellhouse as shown Alignment Guide Flange Optionally Made-up Dudng Drilling \ 6"-8" Line To Plant ;' (28") 2.0' (24") Test Gauge ~ 1.67' (20") Approximate top of Wellhouse Annular BOP (Hydril), 5-1/8" ID ' 3.167' (38") 5,000 psi working pressure Ram Type Dual Gate BOPE ~ Manual over Hydraulic 7-1/16" ID with Pipe/Slip Rams Manual Valves 5.75' (69") 1.427' (17-1/8") t 5.604' (67.25') Top of Pad Level 0.458' (5.5") Mandatory SSV Optional Manual Master Valve or Hydraulic SSV (24.5' for SSV) ~Tubing Hanger X Fire Resistant Kelly Hose to Flange by Hammer Up 1/4 Turn Valve on DS Hardline 10' from Tree 9-5/8" Annulus 13-3/8" Annulus ; STATE OF ALASKA ALASKA ' AND GAS CONSERVATION C~ISSION' APPLICA'I ION FOR SUNDRY APPROVALS 1. Type of Request: Abandon X Suspend Operation shutdown Alter casing Repair Well Plugging X Change approved program Pull tubing ' , Vadance 2. Name of Operator ARCO Alaska, Inc. 3. Address P.O. Box 100360, Anchorage, AK 99510-0360 5. Type of Well Development X Exploratory , Stratigraphlc Service I 4. Location of well at surface 916'S & 382' W of NE cr., Sec. 34, T11N, R15E, UM At top of productive interval 946' E & 1184' N of SW cr., Sec. 36, T11N, R15E, UM At effective depth 1341' E & 913' N of SW cr., Sec. 36, T11N, R15E, UM At total depth 1375' E & 889' N of SW cr., Sec.36, T11N, R15E, UM 12. Present well condition summary Total depth: measured 13200 feet true vertical 9072 feet Re-enter suspended well Time extension Stimulate Pe'rfor~te Other 6. Datum of elevation(DF or KB) 64 RKB feet 7; Unit or Properly Prudt'ioe Bay Unit 8. Well number 4-04 9. Permit number 71-11 10. APl number 50 - 029-20096 11. Field/Pool Prudhoe Bay Oil Pool Effective depth: measured 12651 feet true vertical 8719 feet Plugs(measured) Cement/Sand Plug below 12651' MD ORIGINAL Junk(measured) Casing Length Size Cemented Measured depth True vertical depth Structural 115' 30" 229 sx Fondu 115' 115' Conductor 1150' 20" 1000 sx Fondu neat 1150' 1150' Sudace 2640' 13-3/8" 600 sx Fondu neat 2704' 2704' Production 12070' 9-5/8" 1000 sx CI G/350 sx PF II 12134' 8483' Liner 1389' 7" 700 sx CIG 11811-13200' 8280-9072' Perforation depth: measured 12625-12640' true vertical 8705-8713' Tubing (size, grade, and measured depth) 7", 26#, L-80 @ 2897' MD; 5-1/2", 17#, L-80 @ 11784' MD; 4-1/2", 12.6#, N-80 w/tail @ 11887' MD Packers and SSSV (type and measured depth) Baker SB-3A pkr @ 11763' MD, Camco BaI-O SSSV @ 2205' MD 13. Attachments Description summary of proposal X Detailed operations program BOP sketch X 14. Estimated date for commencing operation 15. Status of well classification as: January 1995 Oil X Gas 16. If proposal was verbally approved Name of approver Date approved Service 17. I hereby certify that the foregoing.? true and correct to the best of my knowledge. Signed ~ ~' ~R Title Engineering Supervisor 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- 0ri inal By · David'W. Approved by order of the Commissioner Suspended , I Approval ~,~._,.. Approved Copy Returned Form 10-403 Rev 06/15/88 DTK cc: KZ, JWP SUBMIT IN TRIPLICATE · 0 r CHECKLIST COMPANY INIT AREA ~7C~~) UNIT# PROGRAM: exp [] dev [] redrll/~ serv [] // JO s.o ADMINISTRATION ENGINEERING 1. Permit fee attached ................... N 2. Lease number appropriate ................ N 3. Unique well name and number ............... N 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary.. N 6. Well located proper distance from other wells ...... N '7. Sufficient acreage available in drilling unit ...... N 8. If deviated, is wellbore plat included ........ . N 9. Operator only affected party .............. N 10. Operator has appropriate bond in force ......... i N 11. Permit can be issued without conservation order .... N 12. Permit can be issued without administrativeapproval.. N 13. Can permit be approved before 15-day wait ....... N APPR 14. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. :i /2. Conductor string provided ................ Y N Surface casing protects all known USDWs ......... Y N CMT vol adequate to circulate on conductor & surf csg.. Y N CMT vol adequate to tie-in long string to surf csg . . . Y N CMT will cover all known productive horizons ...... ~ N Casing designs adequate for C, T, B & permafrost .... ~ N Adequate tankage orreserve pit ............ /--~'~ N If a re-drill, has a 10-403 for abndnmnt been approved.~._Y~ N Adequate wellbore separation proposed ......... .~ N If diverter required, is it adequate .......... ~ Drilling fluid program schematic & equip list adequate -O N BOPEs adequate ..................... ~Y~ N BOPE press rating adequate; test to -~O~ psig.~ N GEOLOGY 29. Choke manifold complies w/API RP-53 (May 84) ...... ~ ~ Work will occur without operation shutdown ....... ~ N~ Is presence of H2S gas probable ............ ~~ ~/J ~'~, 30. Permit can be issued w/o hydrogen sulfide measures .... Y 31. Data presented on potential overpressure zones ..... 33. Seabed condition survey (if off-sbors) ....... /. Y N 34. Contact name/phone for weekly progress reports . ./.. Y N [exploratory only] GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/jo - A:~ORMS~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, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. _ape Subfile 2 %s type: LIS TAPE HEADER PRUDHOE BaY I/NIT MWD/MAD LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB DATA D.S. 4-04A 500292009601 ARCO ALASKA, INC SPERRY-SUN DRILLING SERVICES 13-AUG-96 MWD RUN 1 JOB NUMBER: AK MW 50026 LOGGING ENGINEER: B. JAHN OPERATOR WITNESS: HUPP/BASS SURFACE LOCATION SECTION: TOWNSH I P: RANGE: FEL: 22 1996 FWL: ,~ o 'o ELEVATION (FT FROM MSL 0) KELLY BUSHING: _~Cj~l~t~t,,~, __ .00 DERRICK FLOOR: A~0i~0i~a~¢ GROUND LEVEL: WELL CASING RECORD OPEN HOLE CAS ING MWD RUN 4 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: MWD RUN 5 B. JAHN B. JAHN HUPP GOODRI CH DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 13.375 2704.0 9.625 12566.0 7.000 12566.0 3.750 12664.0 MWD - GR. LOCATION: N 70:16:08.438 W 148:16:53.700 ALL DEPTHS ARE MEASURED BIT DEPTHS. ALL GAMMA RAY DATA PRESENTED IS DOWNHOLE RECORDED. GAMMA RAY TRACE IS SMOOTHED 2. RATE OF PENETRATION IS SMOOTHED TO 4. WINDOW CUT IN CASING FROM 12566'. MWD RI/NS 1 - 4 WERE MILL RUNS. ONLY THE GR & ROP FROM RUN 1 & THE ROP FROM 4 ARE PRESENTED. MWD RUN 5 DROPPED ANGLE TO 47 DEG. MWD WAS LAID DOWN. MWD RUN 6 WAS USED TO WIPE & OBTAIN SURVEYS. NO DATA IS PRESENTED HERE. NO DEPTH SHIFTS WERE APPLIED AS THIS IS THE DEPTH REFERENCE FOR THIS WELL. FILE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GR 12471.0 12626.0 $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN N© MERGE TOP MERGE BASE 1 12496.0 12574.0 4 12574.0 12579.0 5 12585.0 12664.0 MERGED MAIN PASS. CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 4-04A : 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 Tape File End Depth = 12664.000000 = 12471.000000 Tape File Level.Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1162 datums Tape Subfile: 2 93 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 3 i's ty~e: LIS FILE HEADER FILE NUMBER: 2 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 1 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12471.0 $ 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 12550.0 05-APR-95 MSC 1.32 / PCWD 1.16X DEP 2.042 / NGP 5.74 MEMORY 12574.0 12496.0 12574.0 0 57.8 57.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA RAY $ TOOL NUMBER NGP 201 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 3.800 12566.0 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: BIOZAN/SEAWATER 8.60 .0 .0 15000 .0 .000 .0 ,000 150.1 .000 .0 .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN): EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 1. CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 4-04A : 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 AAP I 4 2 RO P MWD 68 1 F PHR 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: 3 Tape File Start Depth = 12580.000000 Tape File End Depth = 12471.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 Tape Subfile: 3 Minimum record length: Maximum record length: 658 datums 66 records... 62 bytes 1014 bytes Tape Subfile 4 i~ ty~e: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and loH header data for each bit run in separate files. BIT RUN NO: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERS ION: 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 07-APR-95 MSC 1.32 / PCWD 1.16X DEP 2.042 / NGP 5.74 MEMORY 12579.0 12574.0 12579.0 0 57.0 57.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA RAY $ TOOL NUMBER NGP 126 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT) : 3.800 12566.0 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: BIOZAN/SEAWATER 8.60 .0 .0 15000 .0 .000 .0 · 000 145.9 .000 .0 .000 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 0 REMARKS: MWD RUN 4. ONLY THE ROP CURVE IS PRESENTED. RUN 4 WAS A MILLING RUN & IS ONLY PRESENTED HERE CN WN FN COUN STAT TO FILL A SMALL GAP BETWEEN RUNS 1 & 5. ARCO ALASKA, INC. D.S. 4-04A PRUDHOE BAY NORTH SLOPE ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units 1 ROP MWD 68 1 FPHR 4 API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 90 810 01 1 * DATA RECORD (TYPE# 0) Total Data Records: 574 BYTES * Tape File Start Depth = 12585.000000 Tape File End Depth = 12550.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1305 datums Tape Subfile: 4 65 records... Minimum record length: 62 bytes Maximum record length: 574 bytes Tape 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: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 12547.0 $ 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 12626.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE NGP NATURAL GAMMA RAY $ 07-APR-95 MSC 1.32 / PCWD 1.16X DEP 2.042 / NGP 5.74 MEMORY 12664.0 12585.0 12664.0 0 46.9 57.8 TOOL NUMBER NGP 126 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 3.750' 12566.0 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: FLO- PRO 8.70 67.0 9.3 48O00 5.6 .000 .000 .000 .000 .0 70.0 .0 .0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : .0 REMARKS: MWD RUN 5. CN WN FN COUN STAT : ARCO ALASKA, INC. : D.S. 4-04A : 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 2 ROP MWD 68 1 FPHR 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: 3 Tape File Start Depth = 12664.000000 Tape File End Depth = 12540.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 1406 datums Tape Subfile: 5 66 records... Minimum record length: 62 bytes Maximum record length: 1014 bytes Tape Subfile 6 i~ ty~e: LIS ~s/ s/13 01 **** REEL TRAILER **** 96/ 8/14 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 14 AUG 96 2:28p Elapsed execution time = 0.71 seconds. SYSTEM RETURN CODE = 0