The URL can be used to link to this page

Home My WebLink About209-013STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEIVED H IM 1 0 '0(110 Ia. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 Suspended ❑ 1b. Well Class-:®®-fiL� 20AAC 25.105 20AAC 25.170 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero �P�lt v lopme❑nt5lratl IService apRfd 2. Operator Name: 6. Date Comp., Susp., or Abend.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 5/24/2018 209-013 ' 378-088 3, Address: 7. Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 2/19/2009 50-029-20902-02-00 ' 4a. Location of Well (Governmental Section): e. Date TO Reached: 16. Well Name and Number: 2/25/2009 107-20B ' Surface: 1596' FNL, 633'M, Sec. 34, T11 N. R14E, UM ' 9 Ref Elevations KB 58.00 ' 17. Field/Pool(s): Top of Productive Interval: 4774' FNL, 3096' FNA-, Sec. 34, TI IN, R14E, UM GL 27.30 BF 29.71 PRUDHOE BAY, PRUDHOE OIL Total Depth: 3755' FNL, 2755' FWL, Sec. 34, TI IN, R14E, UM 10. Plug Back Depth(MD/TVD): 18, Property Designation: 6832'16248' ADL 028309 4b. 41b. Location of Well (State Base Plane Coordinates, NAD 27) 11. Total Depth (MD/TVD): 19. DNR Approval Number Surface: x- 676844 • y- 5949344 ' Zone - ASP 4 • 11869'1 9042' 74-064 TPI: x- 679388 y- 5946225 Zone - ASP 4 12. SSSV Depth (MD/1VD): 20 Thickness of Permafrost MD/ND: Total Depth: x- 679021 y- 5947236 Zone - ASP 4 None 1900' (Approx.) S. Directional or Inclination Survey: Yes ❑ (attached) No 0 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Wndow Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) MD/TVD: • 9820r/ 8632' ' 22. 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 MWD DIR, RES! GR, MCNL / GR / CCL 23. CASING, LINER AND CEMENTING RECORD CASING Wf, PER FT GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H40 31' 111' 31' 111' 30" 19000 Poleset 13-3/8" 72# L-80 30' 2517' 30' 2517' 17-1/2" 1600 sx Fondu, 400 sx PF'C' 9-5/6" 47# L-80 28' 9627' 28' 8486' 12-11W* 500 sx Class 'G', 300 sx PF'C' 7" 29# L-ro 9314' 9820' 8259' 8632' 8-1/2" 375 sx Class'G' 3-1/2-3-3/16" 9.2#/6.2# 1- 1 9319' 11869' 8262' 9042' 4-1/8" 121 sx Class'C' X2-71&' 6.16# 24. Open to production or injection? Yes ❑ No 0 25, TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): GRADE DEPTH SET (MD) PACKER SET (MD/TV 5-1/7'17# L-80 6858' - 9358' 9272'/ 8229' 1 T�. x 4-1/2" 12.6# L-80 Po4� 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DATE Was hydmulicfmcturing used during completion? Yes ❑ No 0 Per 20 AAC 25.283 (i)(2) attach electronic and printed —��--�+--Fi VERIFIED information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED See Attached 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, gas lift, etc): N/A Date of Test: Hours Testetl: Production for Test Period y Oil -Bbl: Gas -MCF: Water -Bbl: Choke Sb. Gas -Oil Ratio: Flow Tubing Press Casino Press:Celculaletl 24 Hour Rale �► Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity - API loom: Form 10-407 Revised 52017 CONTINUED ON PAGE 2 Submit ORIGINAL only RBDMS-` JUN 19 2010 � f r/ly fG 28. CORE DATA Conventional Core(s) Yes ❑ No ® Sidewall Cores Yes ❑ No m 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. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 10777' 9001 • separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. 42SB - Zone 4A 9933' 8709' CGL - Zone 3 10087' 8784' Base of CGL - Zone 2C 10260' 8856' 23SB - Zone 2B 10472' 8913' 22TS 10638' 8960' 21 TS - Zone 2A 10777' 9001' Formation at total depth: Zone 2A 10777' 9001' 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Raese, J. Kyle Authorized Title: SIM IF111st Contact Email: john.raese@bp.com Authorized Signature: f Contact Phone: +1 9075644629 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 10407 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 la. 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 ib. Well Class Service wells: Gas Injection, Water Injection, Water-Altemating-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 forth 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 MO 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. Form 10-407 Revised 5/2017 Submit ORIGINAL Only WELL NAME: 07-20B 26• Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 8858' 22 Bbls Class'G' 8838'- 8843' Tubing Punch 7296' 87 Bbls Class'G' 6856' Cut & Pull Tubing 6832' Set Whipstock T/1/0=700/145/310 Temp=Sl Injectivity Test. ****On arrival cellar seemed to be glaciated. Cellar full of ice. At about the 5:00 to 6:00 position there was some gray stuff (RG 2401) coming up through ice. Injectivity after well kill was 5 bpm @ -900 psi, Final injectivity after formation charged up and stabilized was 5 bpm @ -1300 psi. During the injectivity test the RG 2401 was bubbling, with what looked like water, once it hit surface it froze. After pump job some more RG 2401 had found its way to surface at about the 11:00 position****. Pumped 5 bbls of 60/40 followed by 58 bbls of crude followed by 577 bbls 1 % KCL down the tbg for injectivity test. Flush surface line with 2 bbls 60/40. Pumped 58 bbls 4/7/2018 of crude down the tbg to freeze protect.FWHP=0/418/325 T/I/O = SSV1290/270. Temp = SI. Eval Blue Goo. AL disconnected. Cellar is full of ice even with wellhouse floor. Blue Goo is coming up between the starting head & the ice almost 360° around starting head. 1-2 cups blue goo on top of ice. 4/8/2018 SV, WV, SSV = C. MV = O. IA,OA = OTG. 14:45 Initial TWO = 2371/309/253. Temp = S/I. (SLB Unit 28803 - Reservoir P&A) Pump the following down the TBG: 10 bbls 60/40 290 bbls I% KCI 22 bbls 15.8 ppg Class G Cement ***ESTIMATED TOC=9320' MD*** 210 bbls Diesel Valve Positions as follows: SV, SSV, WV = Closed. MV=Open. CV=OTG. Hang FP & Caution Cement Plug Downhole Tag on MV. 4/24/2018 Final T/1/0= 140/194/440 (LRS Unit 42 - Heat Diesel Pre Cement Job) Heated diesel transport of 260 bbls to 90*F for 4/24/2018 Cementjob. Rolled 378 bbls to reach temp. ***WELL S/I ON ARRIVAL***(sidetrack) RAN 3.50" CENT & 2.50" S.BAILER. TAG TOC AT 8850' SLM (sample cement), AOGCC WITNESSED TAG (Adam Earl). LRS PERFORMED PASSING 2500# MIT -T (AOGCC REP WAIVED WITNESS OF PRESSURE TEST 4/27/2018 ***CONT ON 4-28-18 WSR*** T/I/0-0/400/270. Assist Slickline with state witness (AOGCC) 2nd MIT -T to 2685 psi **PASSED** (max applied 2750 psi, target 2500 psi). Pumped a total of 5.1 bbls of 30* F diesel to reach test pressure. 1st 15 min. TBG lost 26 psi, 2nd 15 min. TBG lost 20 psi. Additional 15 min TBG lost 18 psi for ttl loss of 38 psi in a 30 minute test. AOGCC rep Adam Earl waived witnessing MIT -T. Bled back -4.4 bbls. Hung info tag on WV. SL in 4/27/2018 control of well upon LRS departure. IA/OA=OTG FWHP's= 0/0/270 ***CONT FROM 4-27-18 WSR***(sidetrack) DRIFTED TO 8854' SLM WITH 8' OF 2.125" STEM & 2,25" BAILER FOR MTT. RAN PDS MTT LOG FROM 6000'- 7800' PER PROGRAM.(good data) BRUSHED TREE/ BPV FOR 20MINS W/ 5-1/2" BRUSH. 4/28/2018 ***WELL S/I ON DEPARTURE, DSO NOTIFIED OF WELL STATUS*** `** WELL SI ON ARRIVAL *** (SLB E -LINE TBG PUNCH) INITIAL TWO = 0/0/300 PSI, MIRU, PT TO 1500PSI RIH W/ MPD/5' TUBING PUNCHER (4SPF, 0 DEG, 21 SMALL CHARGES)/SPD. TUBING PUNCHED INTERVAL = 8837.7'- 8842.7'. CCL TO TOP SHOT = 5.7', CCL STOP DEPTH = 8832'. LOST 200 PSI IN TUBING AFTER FIRING. TAGGED TOC AT 8858'. TIE INTO WELL SKETCH, DATED 4-26-18 FINAL T/I/0 = 110/0/300 PSI 4/30/2018 ***JOB COMPLETE, WELL LEFT SHUT-IN ON DEPARTURE*** Daily Report of Well Operations 07-20B TWO= 107/0/263. (LRS Unit 46 / SLB Cement Unit 28803 - Pre -RST P&A Balance Plug) Pumped the following fluids down TBG w/ IA returns to Production via 07-19 flowline: LRS: 5 bbls 60/40 Spear LRS: 540 bbls Freshwater Sweep LRS: 160 bbls Diesel IA Freeze Protect (130 bbls + 30 bbl excess) LRS: 200 bbls Freshwater IA Spacer SLB: 87 bbls15.8 PPG Class G Cement SLB: 7 bbls Freshwater Flush (2 bbls ahead / 5 bbls behind ball launch) LRS: 98 bbls Freshwater TBG Spacer LRS: 70 bbls Diesel TBG Freeze Protect Total displacement = 175 bbls *** ESTIMATED TOC = 7543' MD **' 5/2/2018 FWHP= 653/434/346 T/I/O=vac/vac/258 Assist Slickline CMIT TxIA (PRE -RST) Rig up. ***WSR continued 5/3/2018 on 05/04/2018*** **"WELL S/I ON ARRIVAL'**(Sidetrack) RIG UP SWCP 4522 5/3/2018 ***CONT ON 5-4-18 WSR*** ***CONT FROM 5-4-18 WSR***(sidetrack) BRUSHED TREE/ BPV PROFILE W/ 5-1/2" BRUSH. DRIFTED W/ 2.00" CENT & 1-3/4" S.BAILER, TAGGED TOC @ 7296' SLM.(recovered sample) DRIFTED TBG W/ 4.40" CENT & 2.50" S.BAILER, TAGGED TOC @ 7296' SLM.(no 5/4/2018 issues) TWO = 0+/80/230. Temp = SI. Inflow Test (eval cement plug). AL spool dropped. Verified all wellhead valved open to wellbore. Bled TP to BT from 0+ psi to dead 0 psi in —1 min (gas). Continously monitored for 30 min. Zero flow observed to bonded metal bucket during monitor. Final WHPs = 0/80/230. 5/4/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 22:30. ***WSR continued from 05/03/2018*** Assist Slickline CMIT TAA (POST CEMENT) . Max applied pressure = 3750 psi, Target pressure = 3500 psi. Cmit TxIA failed 3 times. Pumped a total of 9.6 bbls diesel down TxIA to reach test pressure. Bled TxIA back to 1000/1000. Slickline to RIH and tag cement, drift run for Eline. LRS to rig up after slickline has departed. CMIT TxIA **PASSED** to 3736/368,1. Max applied pressure = 3750 psi/ Target pressure = 3500 psi. Pumped a total of 7.37 bbls dsl to reach test pressures. Test #4 15 min TxIA lost 46/82. 30 min TxIA lost 30/61. Total TxIA loss in 30 mins = 76/143. **FAIL** Test #5 15 min TxIA lost 6/12. 30 min TxIA lost 7/9. 45 min TxIA lost 4/9. Total loss in 45 mins= 17/30. Bleed TxIA back to 50/55. Bled back 7.9 bbls. Tags hung on 5/4/2018 IAC/WV on departure. Valve positions=SV,SSV,WV=closed MV,OA, IA= open. FWHP= T/I/O = SSV/80/240. Temp = SI. Bleed IA & OA to 0 psi. (Assist Valve crew). IA FL @ Near surface, OA FL @ Near surface. Bled IAP from 80 psi to 0 psi in 5 minutes, (all fluid, —10 gallons). Bled OAP from 240 psi to 0 psi (2.7 bbl of fluid returned) in 3 hours. Rig down & monitor for 15 minutes. No change in IAP, OAP increased to 0+ during 15 minute monitor. Final WHP's = SSV/0/0+. 5/7/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 06:35 Daily Report of Well Operations 07-20B T/I/O = SI/0/0. (Piggy Backs). RU Temp #67 to IA Torqued to 640 FT LBS, PT'd against IA 350/3500 PSI (Pass) Charted and Retained. RU Temp #68 to OA, Torqued to 640 FT LBS, PT'd against OA 350/3500 PSI (Pass) Charted and Retained. Verified VR plug in Companion OA, Installed alemite fitting in Companion OA blind flange, Torqued to 401 FT LBS, PT'd against VR Plug 350/3500 PSI (Pass) Charted and Retained. Verified VR plug in Companion IA, (IA VR Plug siezed in profile could not remove), Installed alemite fitting in Companion IA blind flange, Torqued to 401 FT LBS, PT'd against VR Plug 350/3500 PSI 5/7/2018 (Pass) Charted and Retained. RDMO. ***Job Complete*** ***JOB STARTED ON 10 -MAY -2018*** (SLB ELINE TBG CUT) INITIAL T/I/O = 0/0/0. SPOT -IN EQUIPMENT. 5/10/2018 ***JOB CONTINUED ON 11 -MAY -2018 ***JOB CONTINUED FROM 10 -MAY -2018*** RIH W/ 4.15" POWERJET CUTTER AND CUT TUBING AT 6856'. ALL LOGS CORRELATED TO PDS MEMORY THICKNESS TOOL LOG DATED 28 - APRIL -2018 WELL LEFT S/I ON DEPARTURE. FINAL T/I/O = 30/30/0. 5/11/2018 ***JOB COMPLETE 12 -MAY -2018*** T/I/0= 10/0/19 Temp. = S/I (LRS Unit 72 - CMIT-TxIA Post Jet Cut) CMIT TxIA ** PASSED** to 3590/3578 psi. on 3rd attempt. Max applied pressure = 3750 psi. Target pressure = 3500 psi. Pumped a total of 8.4 bbls diesel down IA to achieve test pressure. Test #3 1st 15 min. TxIA lost 21/22 psi. 2nd 15 min. TxIA lost 17/17 psi. Total loss in 30 min = 38/39 psi. Bled TxIA pressure to 28/2 psi. Bled back a total of -8.5 bbls. Tags hung on IA and WV upon departure. Valve positions -SV, SSV, WV = closed, MV = open, IA and OA = OTG. 5/12/2018 FWHP's = 28/2/23 T/1/0=250/250/20 Pre Parker 272. Set 5" Gray "K" BPV #606. R/D production tree, R/U dryhole tree #02. Torqued to API specs. PT to 300/5000 psi. Pass. PT tree cap to 500 psi. 5/15/2018 Pass. ***Job Complete*** See log for details. Final WHP's BPV/0/0. T/l/O = BPV/4/8. Temp = SI. WHPs (pre RWO). Wellhouse & grating removed. Dryhole tree installed. IAP increased 4 psi, OAP increased 8 psi from 5/15/18. 5/16/2018 MV = O. IA, OA = OTG. 04:30 North America - ALASKA - BP Operation Summary Report Page i Common Well Name: 07-20 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date. 5/20/2018 End Date X3-01 BYQ-C: (7,639,602.00 ) Project: PBU Site: 07 Rig Name/No.: PARKER 272 Spud Datamme: 1/30/1983 12:00:OOAM Rig Release: 6/13/2018 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000900 Active datum: 07-20C Actual @74.24usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 5/20/2018 12:00 - 12:30 0.50 MOB P _ -0.06 PRE BEGIN RON EVENT WITH PARKER 272 AT 12:00 ON 5/20/18 SKID CATTLE CHUTE AND RIG FLOOR INTO MOVE POSITION 12:30 - 13:00 0.50 MOB P -0.06 PRE LOWER MAST TO HEADACHE RACK - 400 KLBS SET ON RACK 13:00 - 15:30 2.50 MOB P -0.06 PRE PULL MUD AND UTILITY MODULES AWAY FROM DRILL MODULE. PULL DRILL MODULE OFF DS11-23 WELL. LINEUP MODULES ON PAD AND HOLD PRE -MOVE MEETING WITH 1530 - 21:00 5.50 MOB P-0.06 PRE SECURITY MOVE PARKER RIG 272 FROM DS11 70 DS07 - MOVE ALL THREE MODULES IN LINE - 10.7 MILES TOTAL MOVE - MOVE MODULES ONE AT A TIME AND USE EXTRA SPOTTERS AROUND POWER LINES NEAR FS2 21:00 - 2230 1.50 MOB P -0.06 PRE SPOT DRILL MODULE OVER WELL 20. MATE MUD MODULE AND UTILITY MODULE UP AGAINST DRILL MODULE - SHIM AND SECURE MODULES 22:30 - 23:30 1.00 MOB P -0.06 PRE GENERAL RIG UP OPERATIONS THROUGHOUT RIG - RIG UP INTERCONNECTS - COMPLETE CHECKLIST FOR RAISING MAST -SPOT CUTTINGS BOX_ 123:30 - 00:00 0.50 MOB P -0.06 PRE RAISE MAST 528 KLBS OFF HEADACHE RACK 5/21/2018 00:00 - 02:00 2.00 MOB P -0.06 PRE GENERAL RIG UP OPERATIONS: - SKID RIG FLOOR INTO DRILLING POSITION. POSITION CATTLE CHUTE AND RAISE EPIPE CAT - INSTALL IAAND OA PRESSURE GAUGES 1 - RIG UP MANRIDERS - TAKE ON 8.3 PPG FRESHWATER TO PITS - RIG UP RIG FLOOR, MODULE ROOFS, 8 INTERCONNECTS ACCEPT PARKER RIG 272 AT 02:00 02:00 - 07:30 5.50 RIGU P -0.06 PRE GENERAL RIG UP OPERATIONS - BRIDLE DOWN, RIG UP BLOCKS AND TOP I DRIVE, CALIBRATE BLOCKS - UN -PIN FORUM CRANE - PERFORM POST DERRICK RAISE INSPECTIONS - RIG UP RIG FLOOR EQUIPMENT - RIG UP ALL SURFACE LINES AND PRESSURE TEST MUD LINES TO 4500 PSI - QUADCO REP ON LOCATION TO CALIBRATE PVT, FLOW SENSORS AND GASWATCH -CALIBRATE BLOCKSAND PERFORM CROWN CHECK - WELLS SUPPORT ON LOCATION TO RIG UP FLOWBACK TANKAND HARDLINE TO WELL CELLAR Printed 6/15/2018 4:28:05PM *All dephts reported in Drillers Depths' North America - ALASKA - BP Operation Summary Report Common Well Name: 07-20 Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/20/2018 Project: PBU Site: 07 Rig Name/No.: PARKER 272 Spud Daterrime: 1/30/1983 Rig Contractor: PARKER DRILLING CO. CHARTED MIN WITH FRESH WATER FROM Active datum: 07-20C Actual @74.24usft (above Mean Sea Level) Date From - To Him Task Code NPT (hr) _6740-11 0:30 - 11:00 3.50 WHSUR P 11:00 - 16:30 7.50 WHSUR 1830 - 21:00 2.50 WHSUR 21:00 - 22:00 1.00 BOPSUR P P it Page 2 AFE No End Date: X3-018YQ-C: (7,639,602.00) BPUOI: USA00000900 Total Depth Phase Description of Operations (usft) _ -0.06 PRE PRESSURE TEST BPV TO 3500 PSI FOR 5 CHARTED MIN WITH FRESH WATER FROM MUD PUMPS TO CONFIRM BARRIER FOR NIPPLE DOWN - PASSING TEST, NO PRESSURE OBSERVED ON OA OR TREE SIMOPS: - CONTINUE GENERAL RIG UP AROUND RIG - PRESSURE TEST BACKSIDE OF CHOKE VALVES -0.06 PRE NIPPLE DOWN DOUBLE 5-1/8" VALVE DRYHOLE TREE AND ADAPTER FLANGE - CAMERON REP BLED OFF HANGER VOID - SIGNIFICANT DIFFICULTY BREAKING 35 YEAR OLD ADAPTER FLANGE OFF TUBING SPOOL. UTILIZE STEAMING INTERVALS, WEDGES, FLANGE SPLITTERS TO BREAK FREE - INSPECT HANGER THREADS (GOOD) AND CHECK XO MAKE UP (17-1/2 RIGHT HAND TURNS) '- INSTALL GRAY TEST DART IN GRAY 5" TYPE K BPV -CAMERON REPRESENTATIVE FUNCTIONED ALL LOCK DOWN SCREWS AND RE -TORQUE TO SPEC (NO ISSUES) SIMOPS: -CAMERON REP BLEED OFF CONTROLAND BALANCE LINES (NO PRESSURE)AND MONITOR FOR 1 HOUR TO CONFIRM STATIC (NO FLOW) -CAMERON REP TERMINATE CONTROLAND BALANCE LINES. INSTALL PLUGS IN TUBING SPOOL PORTS - PRESSURE TEST PLUGS & WELL BARRIER ENVELOPE BY PRESSURING UP DOWN IA WITH MUD PUMPS AND FRESH WATER, WELL PRESSURE APPLIED TO PLUGS THROUGH OPEN CONTROLAND BALANCE LINES; 250 PSI LOW AND 3500 PSI HIGH FOR 5 MIN EACH. -0.06 PRE NIPPLE UP HIGH PRESSURE RISERS AND 135/8" 5K NOV BOP STACK - ANNULAR PREVENTER, 41/2" X 7" UPPER VERS, BLIND -SHEAR RAMS, MUD CROSS, 2-7/8" X 5" LOWER VERS - INSTALL MOUSEHOLES - OBTAIN RKB MEASUREMENTS SIMOPS: - BEGIN BUILDING STANDS OF 5" DRILL PIPE -0.06 PRE RIG UP TO TEST BOPE - MAKE UP TEST JOINT AND XO - ATTEMPT TO MAKE UP TEST JOINT ASSEMBLY TO HANGER - UNABLE TO GET XO TO MAKE UP TO HANGER WITH DART VALVE INSTALLED IN BPV Printed 6/1512018 4:28:05PM 'All dephts reported in Drillers Depths' North America - ALASKA - BP Page 3 Operation Summary Report Common Well Name: 07-20 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date'. 5/20/2018 End Date. X3-01 BYQ-C: (7,639,602.00 ) Project: PBU Site: 07 Rig Name/No.: PARKER 272 Spud Date/time: 1/30/1983 12:00:OOAM Rig Contractor. PARKER DRILLING CO. Active datum. 07-20C Actual §74.24usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase _ (hr) - _(usft) - 22:00 00:00 2.00 BOPSUR N -0.06 PRE 5/22/2018 00:00 - 01:30 1.50 BOPSUR P 01:30 - 05:30 4.00 BOPSUR P -0.06 PRE -0.06 PRE Rig Release: 6/13/2018 BPUOI: USA00000900 Description or Operations RECONFIGURE HANGER CROSSOVER FOR TESTJOINT - DETERMINE THAT XO THREADS HAD BEEN RE -CUT BUT XO HAD NOT BEEN BORED OUT FURTHER TO COMPENSATE FOR MATERIAL CUT OFF. - LOCATE AND MOBILIZE ADDITIONAL CROSSOVERS TO MAKEUP TO HANGER CROSSOVER TO ALLOW FOR SUFFICIENT CLEARANCE OF TEST DART INSTALLED IN BPV; FINAL CONFIGURATION -5-7/8" MCAIACME PIN X 7-5/8" BTC BOX +7-5/8" BTC PIN X NC50 XO_ RIG UP TO TEST ROPE FILL STACK AND LINES AND PURGE AIR - MAKE UP TESTASSEMBLIES - PERFORM SHELL TEST 3500 PSI FOR 5 MIN: GOOD TEST - RE -TORQUE ALL BOLTS ON BOP STACK AFTER_ SHELL TEST TEST BOPE TO 250 PSI LOW 3500 PSI HIGH FOR 5 CHARTED MIN EACH - TEST GAS ALARMS, PVT AND FLOW SHOW - TEST ANNULAR WITH 7" TEST JOINT - TEST UPPER RAMS WITH T' TEST JOINT -TEST WITNESSED BY AOGCC INSPECTOR JEFF JONES TESTISSUES: - DAMAGE 5-7/8" MCA/ACME XO STARTER THREAD WHEN CHANGING OUT TEST JOINTS - CHOKE HCR FAILS PRESSURE TEST 05.30 - 17.30 1200.BOPSUR N -0.06 PRE WORK TO CONTINUE TESTING BOPE DESPITE DAMAGED TBG HANGER THREADS PREVENTING USE OF TYPICAL TEST JOINTS - CALL OUT DONUT TEST JOINTS. ONLY ABLE TO LOCATE 4" JOINT IN FIELD. UNABLE TO LOCATE 5' TEST JOINT OR NECESSARY CROSSOVERS FOR 4" TEST JOINT - DECISION TO BREAK STACK AT TUBING SPOOL. LIFTAND PULL TO SIDE -CLEAN HANGER THREADS AND MAKEUP NEW 5-7/8" MCA HANGER CROSSOVER WITH BLANKING PLUG TO PROVIDE HARD BOTTOM FOR BOP TESTING. - SET STACK BACK DOWN ON TUBING SPOOL, TORQUE UP FLANGE, RE -INSTALL MOUSEHOLE, BELL NIPPLEAND TURN BUCKLES - RIG UP TO TEST ROPE WITH 4" TEST JOINT. PERFORM SHELL TEST AND CALLAOGCC REP JEFF JONES BACK OUT TO LOCATION SIMOPS: - TEST BLIND -SHEAR RAMS + SEVERAL CHOKE MANIFOLD VALVES, AND PERFORM ACCUMULATOR DRAW DOWN TEST - CHANGE OUT CHOKE HCR VALVE. PASSING TEST ON NEW VALVE - BUILD STANDS 5" DRILLPIPE WITH OFFLINE Printed 6/15/2018 4:28:05PM •All dephts reported in Drillers Depths' North America - ALASKA - BP Operation Summary Report Page 4 Common Well Name. 07-20 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 5/20/2018 End Date: X3 -01870-C'. (7,639,602 00 ) Project:PBU Site: 07 Rig Name/No.: PARKER 272 Spud DateRme: 1/30/1983 12:00:OOAM Rig Release: 6/13/2018 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000900 Active datum: 07-20C Actual @74.24usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) - (usft) 1730 - 21:30 4.00 BOPSUR P -0.06 PRE RESUME BOPE TESTTO 250 PSI LOWAND 3500 PSI HIGH FOR 5 CHARTED MIN EACH - TEST ANNULAR WITH 4" AND 5" TEST JOINT - TEST UPPER VBRS WITH 5" TEST JOINT - TEST LOWER VBRS WITH 4" AND 5" TEST JOINTS -TEST WITNESSED BYAOGCC INSPECTOR JEFF JONES -SEE ATTACHED DOCUMENTATION - TWO FAIL/PASS ON TEST (CHOKE HCR & KILL HCR) PERFORM RIG EVACUATION DRILL WITH HUNDLEY CREW, AAR ,I TEST ISSUES: - SMALL LEAK WHEN TESTING AGAINST BOTH KILL& CHOKE HCR: CONTINUE WITH REMAINDER OF TESTSAND TROUBLESHOOT HCR LEAKAFTER ALL OTHER TEST COMPLETE. 21:30 - 00:00 2.50 BOPSUR N -0.06 PRE TROUBLESHOOT LEAK WITH HCR VALVES. WORK AND GREASE VALVES. ISOLATE AND IDENTIFY LEAK ON KILL HCR. _ -CHANGE OUT KILL HCR 5/23/2018 00:00 - 03:30 3.50 BOPSUR N -0of; PRE CONTINUE TO TROUBLESHOOT KILL HCR. - REPLACE KILL HCR AND TEST - REPLACEMENT HCR VALVE FAILED - REBUILD HCR VALVEAND MOBILIZE SECOND HCR FROM PARKER YARD - INSTALLAND FUNCTION TEST REBUILT HCR VALVE 03:30 - 04:00 0.50 BOPSUR P -0.06 PRE COMPLETE ROPE TEST TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 CHARTED MIN EACH - TEST KILL HCR: GOOD TEST -SEE ATTACHED DOCUMENTATION '- TWO FAIL/PASS ON TEST (CHOKE HCR & KILL HCR) 0400 - 0430 0.50 BOPSUB P -0.06 PRE RIG DOWN ROPE TEST MANIFOLD AND BLOW DOWN LINES _ _ 04:30 - 08:00 3.50 WHSUR P -0.06 PRE PULL 5" GRAY TYPE KBPV - RIG UP DUTCH RISER AND VALVE SHOP LUBRICATOR. TEST AGAINST BLANKING PLUG TO 250/3500 PSI FOR 5 MIN EACH (PASS PER LEAK TIGHT CRITERIA) - BREAK OFF LUBRICATOR AT QUICK TEST SUB. PULL BLANKING PLUG WITH 4" TEST JOINT. RE -MAKEUP LUBRICATOR TO QUICK TEST SUB - LUBRICATE BEV OUT. CONFIRM NO PRESSURE BELOW BPV - RIG DOWN LU BRICATOR AND DUTCH RISER Printed 6/15/2018 4:28:05PM *All dephts reported in Drillers Depths* North America - ALASKA - BP Operation Summary Report Page Common Well Name: 07-20 AFE No Event Type: RE-ENTER- ONSHORE(RON) Start Date: 5/2 012 01 8 End Date: X3-018YQ-Q(7,639,602.00) Project: PBU Site: 07 Rig Name/No.: PARKER 272 Spud Date/Time: 1/30/1983 12:00:00AM Rig Release: 6/13/2018 Active datum: 07-20C Actual 074.24usft (above Mean Sea L Date From - To Hrs Task (hr) 08:00 - 10:00 2.00 DHB Code NPT P 10:00 - 12:30 2.50 CASING P 12:30 13:30 1.00 CASING P 13:30 - 22:00 8.50 CASING P 2200 - 22:30 0.50 CASING 2230 - 23:30 1.00 CASING 2330 - 0000 0.50 - CASING P P P BPUOI: USA00000900 Total Depth Phase Description of Operations (usft) -0.06 DECOMP CIRCULATE OUT DIESEL FREEZE PROTECT FROM WELL WITH 8.3 PPG FRESH WATER AS FOLLOWS: LINE UP DOWN IA, TAKING RETURNS UP TUBING AND OUT TO FLOW BACK TANK PUMP -80 BBLS; 9 BPM, 1650 PSI - LINE UP DOWN TUBING, TAKING RETURNS UP THE IA TO FLOW BACK TANK. PUMP -250 BBLS; 10 BPM, 1825 PSI - FLOWCHECK WELL FOR 10 MIN AFTER PUMPS DOWN (STATIC) - SAVE -75 BBLS DIESEL TO USE FOR FREEZE PROTECT AT THE END OF THE WELL. -0.06 DECOMP PULL 5-1/2" TUBING HANGER TO RIG FLOOR -MAKEUP AND RUN IN HOLE WITH SLB 5-1/2" SPEAR - CAMERON REP BACK OUT LOCK DOWN SCREWS - UNSEAT HANGER WITH 175 KLBS AND PULL TO RIG FLOOR WITH 148 KLBS PICKUP 'WEIGHT (COMPARED TO 137 KLBS 'CALCULATED) - CONTROL LINES NOT PRESENT AT TUBING HANGER LAYDOWN SPEAR AND HANGER -0.06 DECOMP CIRCULATE SOAP PILL SURFACE TO SURFACE AS PART OF TOTAL 900 BBLS (3) BOTTOMS UP - 750 GPM, 640 PSI - MW IN/OUT = 8.3 PPG FRESH WATER, NO LOSSES -0.06 DECOMP LAYDOWN OLD 5-1/2", 17#, L-80, ABMOD-LTC 8RD TUBING FROM CUT AT -6873' MD TO SURFACE - LAY DOWN 159 FULL JOINTS, 1 CUT JOINT, 3 GLM, 1 SSSV, 25 CLAMPS AND 2 BANDS - BALANCE LINE AND CONTROL LINE RECOVERED FROM 80' MD TO SSSV - NO CLAMPS EXPECTED TO BE LEFT IN THE HOLE - CUT JOINT LENGTH = 37.56', FLARE OD = 6.55" SIMOPS: - BUILD STANDS OF 5" DP IN OFFLINE EQUIPMENT -0.06 DECOMP RIG DOWN CASING RUNNING TOOLSAND CLEAR RIG FLOOR -0.06 DECOMP INSTALL WEAR BUSHING (12-1/4" ID) -0.06 DECOMP SERVICE TOPDRIVE _ Printed 6/15/2018 4:28:05PM *All dephts reported in Drillers Depths' Common Well Name: 07-20 Event Type: RE-ENTER- ONSHORE(RON) Project: PBU Rig Name/No.: PARKER 272 North America - ALASKA - Blo Operation Summary Report Start Date. 5/20/2018 End Date. 1. Site: 07 AFE No K3-018YO-O. (7,639,602.00 ) Page 6 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000900 Active datum: 07-20C Actual @74.24usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 5/24/2018 00:00 - 02:00 2.00 STWHIP P 6,872.94 WEXIT MAKE UP 9-5/B" X 8-1/2" WHIPSTOCK ASSEMBLY TO BHA TOTAL LENGTH OF 109' MD - MAKE UP 8-1/2" TRI MILLASSEMBLY TO BAKER ONTRAKAND SCRIBE - MAKE UP WHIPSTOCKAND RUN IN THE HOLE - OBSERVE I K BOBBLEAT-44'MD INTO WELL (TOP OF CASING SPOOL @ 44.53' MD), OBSERVE OBSTRUCTION AT -49' MD (WHIPSTOCK SLIPS AT TOP OF CASING SPOOL), DISCUSS PLAN FORWARD WITH ODE, DECISION MADE TO PULL THE WHIPSTOCK TO THE RIG FLOOR, LAY DOWN AND WHIPSTOCK, WHILE WHIPSTOCK IS LAVED DOWN DRIFT WELLHEAD AND THE CASING ENTRY WITH MILL_ASSEMBLY 0200 - 0300 1.00 STWHIP N 6,872.94 WEXIT PULL WHIPSTOCK TO RIG FLOOR AND INSPECT, OBSERVE ANCHOR TRIPPED, SUSPECT ANCHOR TRIPPED ON TOP OF THE 9-5/8" CASING HANGER/PACKOFF '- LAY DOWN WHIPSTOCK AND PREPARE TO PICK UP BACKUP WHIPSTOCK - DRIFT WELLHEAD AND CASING ENTRY WITH MILLASSEMBLY, NO ISSUES RUNNING MILLS THOUGH TOP OF CASING - PULL WEAR BUSHING AND INSTALL WEAR BUSHING WITH SMALLER ID (8-718") TO KEEP THE WHIPSTOCK CENTRALIZED AS IT PASSES THROUGH THE WELLHEAD 0300 - 0500 2.00 STWHIP P 6,872.94 WEXIT MAKE UP AND RUN IN THE HOLE WITH SLB 9-5/8" X 8-1 /2" MECHANICAL ONE -RUN WHIPSTOCKASSEMBLY FROM SURFACE TO BHA OVERALL LENGTH OF 759' MD. - (3) STEEL COLLARS AND (18) HWDP 05:00 - 10:00 5.00 STWHIP P 6.872.94 WEXIT TRIP IN HOLE WITH WHIPSTOCK AND MILL ASSEMBLY FROM BHAAT 759' MD TO TAG TUBING STUB ON DEPTH AT 6873' MD. - SINGLE IN WITH ONLY (6) JOINTS OF 5" DP BECAUSE OF OFFLINE STAND BUILDING - PICKUP/SLACKK WEIGHTS AT 8800' MD = 205/185 KLBS - ORIENT TO 135° ROHS PER WP09 WITH MWD 1000 - 1030 0.50 STWHIP P 6,831.94 WEXIT SET WHIPSTOCKAS FOLLOWS: - RIH AND ACTIVATE ANCHOR ON TUBING STUB WITH 10 KLBS DOWN AT 6873' MD - PICKUP TO 205 KLBS UP WEIGHT + 18' TO SPACEOUT BETWEEN COLLARS, TOP COLLAR @ 6821' MD, BOTTOM COLLAR AT 6858' MO - SLACKOFF TO CONFIRM ANCHOR HOLDING - CONTINUE TO SLACKOFF TO 135 KLBS (50 KLBS DOWN VS 55 KLBS SHEAR BOLT) AND SHEER MILLS OFF SLIDE, NEW UP WEIGHT= 182 KLBS _ 10.30 - 11:30 1.00 STWHIP P 6,831.94 WEXIT DISPLACE WELL FROM 8.3 PPG FRESH WATER TO 10.1 PPG LSND - 740 GPM, FINAL CIRCULATING PRESSURE = 2250 PSI, NO PIPE MOVEMENT - RECORD SLOW PUMP RATES AT END OF Printed 6/15/2018 4:28:05PM *All dephts reported in Drillers Depths' Printed 6/152018 4:28:05PM *All dephts reported in Drillers Depths' North America - ALASKA - BP Page 7 orlif. Operation Summary Report Common Well Name: 07-20 AFF No Event Type: RE-ENTER-ONSHORE (RON) Start Date: 5/20/2018 End Date'. X3-018YQ-C'. (7,639,602.00) Project: Pau Site: 07 Rig Name/No.: PARKER 272 Spud Date/Time: 1/30/1983 12:00 OOAM Rig Release: 6/13/2018 Rig Contractor: PARKER DRILLING CO. BPUOI: USA00000900 Active datum: 07-20C Actual (JD74.24usft (above Mean Sea Level) Date From - To Hrs Task Code NPT I Total Depth Phase Description of Operations (hr) usft (�y�� 11:30 - 0000 12.50 STWHIP P 6,865.94 WEXIT KICK OFF "C" SIDETRACKAND M11-1-9-5/8"�I rCY/I WINDOW FROM 6832' MD TOP OF WINDOW TO 6846' BOTTOM OF WINDOW + 20' NEW FORMATION TO 6866' MD - 350-000 GPM, 750-900 PSI, 90 RPM, 10-13/9.5 KFT-LBS TRQ ON/OFF BTM - MW IN/OUT = 10.1 PPG 1-SND, NO LOSSES '- NO CEMENT OBSERVED BEHIND 9-5/8" CASING, NO PRESSURE OBSERVED ON OA -CLOSE MANUAL VALVES ON MUD CROSS - UPPER MILL EXITS CASING AT 6857' MD. HOLE CIRCULATED CLEAN WITH 2-1/2 BU DURING FINAL V OF FORMATION DRILLED, CIRCULATE AROUND 40 BBL HI-VIS SWEEP 'WITH NO INCREASE IN METAUFORMATION CUTTINGS BACKAT SHAKERS 5/25/2018 00:00 - 00:30 0.50 STWHIP P 6,865.94 WEXIT REAM THE WINDOW WITH THE TRI MILL li ASSEMBLY, 110 RPM, 400 GPM, 900 PSI - DRIFT WINDOWAFTER REAMING WITH PUMPS ON AND PUMPS OFF WITH NO ISSUES PULL TO THE TOP OF THE WINDOW AT 6832' MD AND FLOW CHECK WELL (STATIC) 0030 - 02'00 1.50 STWHIP P 8,865.94 1 WEXIT RIG UPAND PERFORM FIT/LOT - UNABLE TO REACH A TARGET FIT PRESSURE OF 748 PSI TOACHIEVEA 12.4 PPG EMW PRIOR TO PUMPING INTO THE FORMATION, PRESSURE BEGAN TO DEVIATE FROM LINEAR PATTERN AT 575 PSI EQUALING AN 11.8 PPG EMW 1 - MUD WEIGHT: 10.1 PPG, 6251' TVD, 6832' MD - PUMP 3.5 BBLS, BLEED BACK 2 BELS -LOT EMW =11.8 PPG - KICK TOLERANCE >25 BBL WITH 11.8 PPG EMW - SEE ATTACHED TEST CHART - LOT APPROVED BY ODE - NO PRESSURE OBSERVED ON THE OA DURING PRESSURE TEST 02.00 - 05'.00 3.00 STWHIP P 6,865.94 WEXIT PULL OUT OF THE HOLE WITH THE WINDOW MILLING ASSEMBLY FROM THE TOP OF THE WINDOW AT 6832' MD TO THE TOP OF THE BHAAT 735' MD - MONITOR THE WELL FOR 10 MIN PRIOR TO PULLING OUT OF THE HOLE (STATIC) 05:00 - 06:00 1.00 STWHIP P 6,865.94 WEXIT LAY DOWN MILLING ASSEMBLY FROM 735' MD TO SURFACE - MONITOR WELLAT THE TOP OF THE BHA FOR 10 MIN (STATIC) -RACK BACK HWDP - LEAD MILL 1/2" UNDER, FOLLOW MILL 1/8" U NDER, DRESS-OFF MILL 1/16" UNDER _ 06:00 - 07:00 1.00 STWHIP P 6,865.94 WEXIT FLUSH STACKAND FUNCTION RAMSAFTER MILLING WINDOW - RE-OPEN MANUAL VALVES ON MUD CROSS - HOLD ANNOUNCED RIG BLACKOUT DRILL WITH WELL CONTROL DISCUSSION +AAR WITH YEAROUT CREW Printed 6/152018 4:28:05PM *All dephts reported in Drillers Depths' TREP= FMC WELLHEAD - GREY AC�IWTOR= OKB. ELEV __ BAKERC REP ELEV = ----- 58. BF. ELEV ;--29 7T Max Angk=_ Datum MD= 2900 93• � 11444' 10269 Datum WD= 88W SS 91.5#, HdO, D =19.124' 1 80' 1 13-3/8• CSG, 72#, L-80 BTC, D = 12.34T I - Minimum ID = 2.30" @ 9335' MILLED OUT ALUMINUM BUSING IN DEPLOYMENT SLEEVE (2/26/01 JET CUT TBG (05/11/18) - SL TAGGED TOC (05/04/16) - 5-1/2" TBG PUNCH, 4 SPF (04/30/18) ) SL TAGGED TOC (04/28/ - 5-12• TBG-PC.17#. L-80..0232 bpf. D = 4.892• 8.41' rrOO SPEAR N REMAINING 9.15' OF KB PKR (01/19116) 07— O ^ SAFETY NOTES: W ELL ANGLE> -70° @ 10288'. 1 BALANCE & CONTROL LINE IN COMMUNICATION w/IA *** PREVIOUS W ELLBORES NOT SHOWN "" [:IcY0 w 4-6 /2• BKR PBR ASSY I i/8' X 5-1/2• BAKER SAB /2' X 4-1/2' XO, D = 3.95! CAMCO DB -6 NP D = h,._ .m ..................... .. _ BEHIND 1)=3.958• 9368• 9368• 4-1/2'WLEG.D=3.958• CT LINER 9362' E_MD TT LOGGED o9/OB/86 3-1/2' LNR, 9.29, L-80 STL, .0087 bpf, D = 2.992• 9379• w/ 2 RA PIP TAGS @ 8830' 7• LNR 29#. L-80. BTC. 0371 bpf. D = 6.184 PERFORATION SLI MARY REF LOG: MEM GRI CCL/TNAYTNF OF 02127/09 ANGLE AT TOP PERF: 93" G 11200' Note: Refer to Production DB for historical pert data SIZEI SPF I INTERVAL I Opn/Sgz SHOT SOZ 2' 6111200-117801 S 02128!09104/24118 3-3/16' LNR, 6.2#, L-80 TCI, 11013' .0076 bpf, D = 2.80' PBTD MLLOUT WINDOW (07-20B) 9820' - ?????' 11-�3-3/16• X 2-7/8• XO. D = 2.387' DATE REV BY COMMENTS I DATE REV BY COMMENTS 02/17183 PKR 176 INITIAL COMPLETION 05/09/18 BThVJMD TBG RAIDi(04/30/18) 09123195 NORDIC CTD SOTRCK(07-20A) 05/14/18 MRYJM0 ADDED& CORRCC'T®TOC DEPTHS 03/01108 NORDIC CTD SDTRCK (07-208) 05114/18 MS(JM) JET CUR TBG (05M 1/18) 03/29/18 ZV/JMD R1l.LEDEVO-TREVEPLL)G(0328/18) 0329118 ZVIJMD GLV C40(03/28118) 0426118 MRDfJMC RESERVOIR PEA (0424/18) PRUDHOE BAY IMT WELL: 07-20B PERMIT No: `1090130 API No: 50-029-20902-02-00 SEC 34, T11 N. R1 4F- 1596' RL & 633' FWL BP Exploration (Alaska) 411 • STATE OF ALASKA Reviewed liAn OIL AND GAS CONSERVATION COMMISSION P.I.Supry-j ,13i/• BOPE Test Report for: PRUDHOE BAY UNIT 07-20B - Comm 1 Contractor/Rig No.: Parker 272 . PTD#: 2090130 ' DATE: 5/23/2018 Inspector Jeff Jones Insp Sour* Operator: BP EXPLORATION(ALASKA)INC. Operator Rep: R.Cadenhead Rig Rep: D.Henderson Inspector Type Operation: WRKOV Sundry No: Test Pressures: Inspection No: bopJJ180523095933 Rams: Annular: Valves: MASP: 1 Type Test: INIT 318-088 250/3500 ` 250/3500 " 250/3500 - 2444 Related Insp No: TEST DATA MISC. INSPECTIONS: 1 ...... MUD SYSTEM: ' ACCUMULATOR SYSTEM: ii P/F Visual Alarm Time/Pressure P/F Location Gen.: P Trip Tank P - P ' E System Pressure 3050 - P Housekeeping: P - Pit Level Indicators P " P _ 1 Pressure After Closure 2100 - P i PTD On Location P f Flow Indicator P " P - 200 PSI Attained 19 - P . Standing Order Posted P Meth Gas Detector P P - 1 Full Pressure Attained 70 - P - Well Sign P ' H2S Gas Detector P P - Blind Switch Covers: All P - _ Drl. Rig P MS Misc NA NA Nitgn. Bottles(avg): 14 @2100 - P - Hazard Sec. P ACC Misc 0 NA Misc NA FLOOR SAFTY VALVES: BOP STACK: CHOKE MANIFOLD: r Quantity P/F Quantity Size P/F Quantity P/F Upper Kelly 1 P Stripper 0 NA No.Valves 15 - P Lower Kelly 1 - P Annular Preventer 1 - 13 5/8 P Manual Chokes 1 - P - Ball Type _ 4 " P - #1 Rams 1 _4 1/2x 7 _ _ P - Hydraulic Chokes 1 P Inside BOP ..___ 2 - P #2 Rams _ 1 " Blind/shear - P • CH Misc 0 NA FSV Misc 0 NA #3 Rams 1 -2 7/8 x 5 " P #4 Rams 0 I #5 Rams 0 NA = INSIDE REEL VALVES: #6 Rams 0 NA , (Valid for Coil Rigs Only) Choke Ln. Valves 1 - 31/8 P , Quantity P/F HCR Valves 2 '3 1/8Fp ,: Inside Reel Valves 0 NA Kill Line Valves 2 "3 1/8 2 1/16 - P I Check Valve 0 NA BOP Misc 0 NA 4 i Number of Failures: 3 Test Results Test Time 18 Remarks: I traveled to BPXA's PBF well 7-20B to witness a BOPE test on Parker Rig#272.Testing began at 0200 hrs.and concluded at nip_i .brs.The HCR kill failed the pressure test and was greased and passed a retest. later in the test the kill-HCR failed again and was replaced and_passed a retest.The HCR choke failed the pressure test and was replaced_and passed a retest.The extended test time was due in part to problems with the test equipment.The BOPE stack had to be nippled down and a blanking plug installed,then nippled back up to facilitate BOPE testing.i he gas detection and pit volume totalizer alarm systems were tested and operated properly. Parker Rig#272 and the surrounding location appeared clean,orderly and in good condition. SCANNED JUN 9 6202 • S MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Jim Regg f,I DATE: April 28, 2018 P.I. Supervisor I del I i' SUBJECT: Well Bore Plug &Abandonment PBU 07-20B FROM: Adam Earl BPXA Petroleum Inspector PTD 2090130; Sundry 318-008 Section: 34 Township: 11N Range: 14E Meridian: Umiat Drilling Rig: NA Rig Elevation: NA ' Total Depth: 11869 ft MD Lease No.: ADL00283I19 - Operator Rep: Zach Vick SCANNED Casing/Tubing Data: Casino Removal: Conductor: 20" O.D. Shoe@ 111 Feet Csg Cut@ NA - Feet Surface: 13 3/8" O.D. Shoe@ 2517 . Feet Csg Cut@ NA Feet Intermediate: 9 5/8" - O.D. Shoe@ 9627 Feet Csg Cut@ NA _ Feet Production: 7" O.D. Shoe@ 9820 - Feet Csg Cut@ NA _ Feet Liner: 3 1/2"x 2 7/8" O.D.- Shoe@ 11869 - Feet Csg Cut@ NA Feet Tubing: 5 1/2"x 4 1/2"-0.D. Tail@ 9358 - Feet Tbg Cut@ NA - Feet Plugging Data: Type Plug Founded on Depth (Btm) Depth (Top) MW Above Verified Fullbore ' Bottom -1 11869 ft MD, 8850 ft MD Wireline tag ✓ Test Data: Initial 15 min 30 min 45 min Result Tubing IA OA Remarks: Plug back for redrill. I traveled out to Drill Site 7 to witness a cement plug tag, with slick-line; no pressure test. The cement job was pumped by Full-bore, 72 hours prior to arriving on location. The operator rep Zach Vick said cement was displaced down t• 9,200 ft and that is the depth we should expect to tag. Top of cement was tagged several times 8,850 ft.After coming out of the ar, hole and checking the sample in the bailer, it reveled good dry cement. T Attachments: none rev. 05-02-18 2018-0427_Plug Verification_PBU_07-20B_ae • •yoF rti ,, ,,,, 6. THE STATE Alaska Oil and Gas ti ` s 'IfALAsKA Conservation Commission W,, a t 51 r 333 West Seventh Avenue ".L�" GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 o \*� Q. Main: 907.279.1433 A .SFax: 907.276.7542 www.aogcc.alaska.gov Kenneth W. Allen Engineering Team Lead SCANNE. BP Exploration P.O Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field,Prudhoe Oil Pool, PBU 07-20B Permit to Drill Number: 209-013 Sundry Number: 318-088 Dear Mr. Allen: 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 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, ll Hollis S. French .1l Chair i5 DATED this day of March, 2018. illtUL-iiitU 0 STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMIS.I APPLICATION FOR SUNDRY APPROVALS MAR 0 1 2fl 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well 0 Op Cy ter Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program Plug for Redrill El• Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 209-013 • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development p 99519-6612 Stratigraphic 0 Service 0 6. API Number 50-029-20902-02-00 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 0 No B PBU 07-20B • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028309 " PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 11869 • 9043 • 11829 9042 . 2444 None 11500 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 31-111 31 -111 1490 470 Surface 2487 13-3/8" 30-2517 30-2517 5380 2670 Intermediate 9599 9-5/8" 28-9627 28-8487 6870 4760 Production 506 7" 9314-9820 8259-8632 8160 7020 Liner 2550 3-1/2"x 3-3/16"x 2-7/8" 9319-11869 8263-9043 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11200-11780 9049-9042 5-1/2"17#x 4-1/2"12.6# L-80 26-9358 Packers and SSSV Type: 5-1/2"Baker SAB Packer Packers and SSSV MD(ft)and TVD(ft): 9272/8230 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary El Wellbore Schematic EL 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch 0 Exploratory 0 Stratigraphic 0 Development ® ' Service 0 14.Estimated Date for Commencing Operations: March 16,2018 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended IBJ • 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Raese,J.Kyle be deviated from without prior written approval. Contact Email: john.raesei bp.com Authorized Name: Allen,Kenneth W Contact Phone: +1 9075644629 Authorized Title: Engineering Team Lead Authorized Signature: , 1C„� Date ,�1 ' COMMISSION USE NL Conditions of approval:Notify Commission so that a representative may witness Sundry Number. Plug Integrity Ef/ BOP Test Er/ Mechanical Integrity Test 0 Location Clearance 0 Other: 13Dp 7z'54 -to 3JOUV ,l v,v�via r pr p-Ve -i f5 to 2SU� 6' SI� Post Initial Injection MIT Req'd? Yes 0 No di Spacing Exception Required? Yes 0 No IJ Subsequent Form Required: `®— 4 a - APPROVED BYTHE p Approved by: COMMISSIONER COMMISSION Date:3 jiS i vrL 3112/1 ' 4(, xt ORIGIN,AL RBDMS ,MAR222018 ,434* 49 3.2,/E Submit Form and Attachments in Duplicate Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. S GP /,,ffJQ9ff,,/ 0 bp 07-20B Sundry Application Well Type: Producer Current Status: Shut-in Request: P&A for rotary rig sidetrack Planned Pre-Rig Work Start Date: March 16, 2018 Planned Rig Start Date: May 20, 2018 MIT-IA Passed to 2633 psi (1/22/2018) MIT-OA Passed to 1132 psi (1/22/2018) PPPOT-T Passed to 5000 psi (12/23/2017) PPPOT-IC Passed to 3500 psi (12/23/2017) MASP: 2,444 psi (7.16 ppg EMW in Ivishak Zone 2 at 8,975' TVDss with 0.1 psi/ft gas gradient) Well History: 07-20B is a horizontal producer that was drilled in 2009. It is a high GOR well due to a leaking liner top packer and production liner. Multiple unsuccessful attempts have been made to pull and replace the LTP and there is currently an un-releasable spear in the LTP which prevents access to the previously logged GDWFI column. It is proposed to move the well to a more favorable location and has been released for rig sidetrack. ,�. Co" -J/. ��1 i Scope of Work: Prior to rig arrival, the 07-20B perforated liner will be abandoned via fullbore cement. Top of cement will be verified with a drift run and pressure tested. A —1300' cement plug will then be circulated into the tubing and IA with top of cement at—7972' MD. Final top of cement will be determined with a drift run followed by an integrity test of the tubing and IA. The 5-1/2" tubing will be cut at —6850' MD. Wellbore integrity will again be verified. The rig will then move over the well and pull the 5-1/2" tubing. A 9-5/8"whipstock will be used to mill a window out of the existing production casing at —6850' MD. This sidetrack is a horizontal producer targeting the lvishak (GDWFI) reservoir. The planned well is a two string, ultra-slimhole design using 7" intermediate casing and 4-1/2" production liner. The intermediate casing will be set at the top of the Sag River, and the production interval will be completed with a cemented and perforated liner. 07-20B Sundry 1 2/27/2018 i • '1--11 (° Pre-Rig Prep Work: ---' fi1' „v 1 F Injectivity Test A-u k CIA 2 F Fullbore P&A with 18 bbl cementr 3 S Brush BPV profile. D&T TOC- Pull GLV. MTT Log. -).k 4 F MIT-T to 2700 psi 5 F Circ 1300'Cement Plug with 88 bbl cement 6 S Brush BPV profile. D&T TOC. Drift for Jet Cut. 7 F CMIT-TxIA to 2700 psi. Inflow test. • 8 E Jet Cut TBG at—6850' MD 9 F CMIT-TxIA to 2700 psi 10 V Pre Rig Tree Work. Set BPV. Proposed Drilling Rig Operations: 1. MIRU Parker 272. 2. Test BPV from below to 2,700 psi. 3. Nipple down tree. Nipple up BOPE and test to 3,500 psi. 4. Pull BPV. _. 5. Circulate out freeze protection. 6. Pull 5-1/2"tubing from the pre-rig cut at—6850' MD. 7. Contingency: Run 8-1/2"cleanout assembly. 8. Run 9-5/8" whipstock and 8-1/2" window milling assembly. Set the whipstock on the tubing stub at 6850' MD. 9. Displace well to milling fluid. End of Sundry/Start of Permit to Drill Drilling Engineer: Kyle Raese (907) 564-4629 Production Engineer: Kirsty Schultz (907) 564-5105 Geologist: Josh Miller (907) 564-4523 07-20B Sundry 2 2/27/2018 TREE_ FMC • WELLHEAD= GREY .`lit NOTES: WELL ANGLE>—70°@i 10288'. ACTUATOR= BAKER Q 7"'?.,Q --BALANCE&CONTROL UNE IN COMMUNICATION OKB.ELEV= 58 wM•••PREVIOUS WEU BORES NOT SHOWN*** BF.ELEV= .r1I 2158' KOP= 2900' 20'CONDUCTOR — 80' }--5-1/2"CAMCO 8AL-O NP,D=4.562" Max Angle= 93"Q 11444' 915#,1.4_40, Datum MD= 10269' D=19.124' GAS LFT MANDRELS Datum ND= 8800'SS , ST MD ND DEV TYPE VLV LATCH PORT DATE r'13-3/8'CSG,72#,L-80 BTC,D ---I=12.347" � 2517' 1 1 2889 2887 9 MMG DMY RK 0 11/04/15 2 5028 4748 34 NAG DMY RK 0 11/04/15 Minimum ID =2.30" @ 9335' L ( 3 6559 6020 34 MMG DMY FF}( 0 02/15/83 I..� 4 7625 6926 30 MUG DMY R( 0 02/15/83 MILLED OUT ALUMINUM BUSING 5 8240 7455 31 MNG DMY RK 0 02/15/83 IN DEPLOYMENT SLEEVE (2/26/09) 6 8317 7524 32 MMIC DMY RK 0 02/15/83 7 8704 7831 41 MMIC DMY RK 0 02/15/83 8 8777 7885 43 MNG DMY RK 0 02/15/83 9 9107 8116 47 MMG DMY RK 0 08/06/05 10 9184 8168 46 MING DMY RK 0 08/06/05 � 9257' H5-1/2"BKR PER ASSY L 5-1/2"TBG-PC,17#, -80,.0232 bpf,b--;-4.89i3---1-1272;- I 9272' }—9-5/8"X 5-1/2"BAKER SAB PKR [1:OP OF 7"LNR I-1 9314' "-------I 9283' —{5-1/2"X4-1/2"XO,D=3.958 8.41'ITCO SPEAR N REMAINING 9.15' --1 9333'CTM 9319' —i KB LTP,13=2.36"(02/28/09) OF KB PKR(01/19!16) 9327' --I3.70"BTT DE TOY SLV,D=3.00" 9345' H4-1/2"CAMDD DB-6 NIP D=3.813" jil /' 9357' --{4-1/2"BAKER SHEAROUT SW BEHIND 4-1/2"TBG-FC,12.6#,L-80,.0152 bpf,ID=3.958" I— 9358' --I 9358' H4-1/2"WLEG,D=3.958" CT LINER 9352' 1ELM D TT LOGGED 09/08/86 3-1/2"LNR,9.2#,L-80 STL,.0087 bpf,D=2.992' H 9379' 9379' --13-1/2'X 3-3/16"XO,D=2.786' 9-5/8'CSG,47#,L-80 BTC,D=8.681' H 9627' , TOP OF CEMENT H 9825'? 441 11 FALLOUTWNDOw(07-20B) 9820'-9?7p7 7'WHIPSTOCK(XX/XX/XX) — 9825' 111.1 �'4 1 w/2RAPIP TAGS @9830' 14'111.1 7"LNR 29#,L-80,BTC,.0371 bpf,D=6.184" —9825 '14///1 11013' -i3-3/16"X 2-7/8"XO,D=2.387" 13 / PERFORATION SUMMARY REF LOG MEM GR/CCiJTTJ4tTTF OF 02/27/09 I1 ANGLE AT TOP PERF:93°@ 11200' V` i 11500 CTM —Fish AR LED Note:Refer to Production DB for historical pert data ��1� � CEP(09108!14) SIZE SPF INTERVAL Opn/Sgz SHOT SQZ 3-3/16"LNR,6.2#,L-80 TCI, — 11013' 2" 6 11200-11780 0 02/28/09 .0076 bpf,D=2.80" PBTD 11839' X411,1' • • '11.1 2-7/8"LNR,6.16#,L-80 STL,.0058 bpf,D=2.441" H 11869' DATE REV BY COMvENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/17/83 PKR 176 INITIAL COMPLETION 03/24/16 TTWTLH PULL FKR STRADDLE(11/10/15) WELL 07-208 09/23/95 NORDIC CTD SDTRCK(07-20A) 03/24/16 TTR/TLH SET SPEAR N FKR(01/17/16) FERMT No.'t090130 03/01/09 NORDIC i CTD SDTRCK(07-208) API No: 50-029-20902-02-00 08/25/14 TINYPJG SET FLOGARD FCR(7/19/14) V SEC 34,T11 N,R14E, 1596'FNL&633'nm_ 09/08/14 JGU PJC MLL&RECOVER CBP 03/24/16 TTRJILH RLL DSSSV &GLV GO(11/04/15) BP Exploration(Alaska) ---Tilik WaLHEAD= _GREY P&A PRO P O S A 1. NOTES: WELL ANGLE>—70"@ 10288'. ACTUATOR= BAKER C w/I O T�2 O B BALANCE&CONTROL LINE IN COMMUMCATION OKB ELEI/_ A***PREVIOUS WELLBORES NOT SHOWN*** BF.REV= j KOP= 2900' 20"CONDUCTOR, 80' ___L-2— 2158' I—5-1/2"CA MCO BAL-O NP,D=4.562" Max Angle= 93°@ 11444' 91.5#,H-40, O Datum MD= 10269' D=19.124" GAS LIFT MANDRELS Datum TVD= 8800'SS , ST MD TVD DEV TYPE VLV LATCH FORT DATE 1 2889 2887 9 WAG DMY FE 0 11/04/15 13-3/8"CSG,72#,L-80 BTC,ID=12.347" I— 2517' 2 5028 4748 34 MMIC DMY RK 0 11/04/15 3 6559 6020 34 IVMG DMY RK 0 02/15/83 TBG CUT H —6850` 4 7625 6926 30 NAG DMY RK 0 02/15/83 EST TOC I— —7972" 5 8240 7455 31 MMIC [MY RK 0 02/15/83 •041,••••41 6 8317 7520 32 MMIG DMY RK 0 02/15/83 EST TOC(30%WASHOUT) H —8297' k 1'• + 7 8704 7831 41 NAG DMY RK 0 02/15/83 8 8777 7885 43 MMIG DMY RK 0 02/15/83 Minimum ID =2.30" a 9335' 9 9107 8116 47 NAG DMY IRK 0 08/06/05 MILLED OUT ALUMINUM BUSING • it MG 9184 8168 46 G DMY FE 0 08/06/05 IN DEPLOYMENT SLEEVE (2/26/09) + ► • WV 0100 IP A•,..1 # „ 9257' H5-1/2"BKR PBR ASSY 5-1/2"TBG-FC,17#,L-80,.0232 bpf,ID=4.892" 9272' :40.7,40‘4,4417k41 A 4)11 " 9272' H9-5/8"X 5-1/2"BAKER SAB PKR • H TOP OF 7"LNR 9314' • # e� G 9283' H5-1/2"X 4-1/2"XO,ID=3.958 NE lit4t4 8.41'TTCO SPEAR N REMAINING 9.15' — 9333'CTM_ �. _��r V 9319' —IKB LTP,D=2.36"(02/28/09) OF KB PKR(01/19/16) . ::: 9327' H3.70"BTT DEPLOY SLV,ID=3.00" ‘171(?\: 1/2) i 'W-46,ii ♦ X r 9345' H4-1/2"CAMCO DB-6 NPD=3.813" •• F 9357' —i4 v2"BAKER SHEAROUT SUB - BEHIND 4-1/2"TBG-PC,12.6#,L-80,.0152bpf,D=3.958" I— 9358' 4 F4 9358• —14-1/2"WLEG.D=3-958" CT LINER • r 9362' HELMD TT LOGGED 09/08/86 •3-1/2"LNR,9.2#,L-80 STL,-0087 bpf,D=2.992" 9379' • 4w -+ 9379' H3-1/2"X 3-3/16"XO,ID=2.786" 1 • �• 9-5/8"CSG,47#,L-80 BTC,D=8-681" H 9627' — — 9628' —ITOP OF SAG RIVER(DPZ3) TOP OF CEMENT 9825' 4S1 '�'04- MLLOUT WNDOW(07-20B) 9820'-?????' 7"WHPSTOCK(XX/XX/XX) H 9825' 1'.'� /•.46L4. w/2 RA PIP TAGS @ 9830' '.*At'vA p 4,�4�'•.I 11013' —13-3/16"X 2-7/8"XO,D=2.387" 7"LNR 294,L-80,BTC,.0371 b ,D=6-184" —9825 441100 PERFORATION SUVIVARY REF LOG:MEM GR/CCUTMYTTF OF 02/27/09 1: ,4 V.,...1% ANGLE AT TOP PERF:930 011200' —11500 CTM FISH:MLLED A; IB (09/08/14) Note:Refer to Production DB for historical perf data4Ib 411, SIZE SPF INTERVAL Opn/Sqz SI-DT SOZ 3-3/16"LNR,6.2#,L-80 TCI, 11013' 2" 6 11200-11780 02/28/09 .0076 bpf,D=2.80" "4*4PBTD 11839' 4��,�''''.' 2-7/8"LNR,6.16/#,L-80 STL,.0058 bpf,D=2.441" —I 11869' DATE REV BY CONVENTS DATE REV BY CONVENTS PRUDHOE BAY UNIT 02/17/83 PKR 176 IMTIAL COMPLETION VV81: 07-20B 09/23/95 NORDIC CTD SDTRCK(07-20A) PERMIT No: `2090130 03/01/09 NORDIC i CTD SDTRCK(07-20B) AR No: 50-029-20902-02-00 01/17/18 KROMD P&A PROPOSAL SEC 34,T11N,R14E,1596'FIt&633'FWL 01/17/18 KR P&A PROPOSAL REV 1 BP Exploration(Alaska) TREE= 4-1/16"5M CNV • V'. L I-EAD= GREY PROPOSED SAFEiY NOTES: WELL ANGLE>-70°@ ACTUATOR= REV 2 O 7_�0EL ***CHROME TBG&LAIR*** OKB.ELEV= 58' BF.ELEV= 1 I KOP= 2900' 20"GOND, — 80' Max °@= 91.5#,H-40, 1 Angle —2000' —14-1/2"HES X NP,D=3.813" 9 — Datum luD= — ID=19.124" Datum TVD= 8800'SS GAS UFT MANDRELS 13-3/8"CSG,72#,L-80 BTC,ID=12.347" I— 2517' ST MD TVD DEV TYPE VLV LATCH FORT DATE 5 Minimum ID = " @ 4 3 2 9-5/8"SLB W-IPSTOCK(_/ / ) H 6847' 1 9-5/8"CSG,47#,L-80 BTC,D=8.681" —I —6847' MLLOUT WINDOW(07-20C) 6847'-6863' I H4-1/2"HES X NIP,D=3.813" Vii' l'', — 8239' r, 0 1 1 r 1 r 1 1 Q A 9444' —7"X 4-1/2"VIES TNT HCR,D= " 1 I:1,1 1 1 ' "IIii -�4-1/2"HES X MP,D=3.813" 1 1 1 1 1 1 1 i ifi .1i 1 1 1 H4-1/2"HES XN MP,D=3.725" 1 i 1 1 1 1 N 1 N 9589' 17"X 5"WFD LIP w TTEBK SLEEVE&WED TOPOF4-1/2"LIC —I 9589' IN " i HGR,D= 4-1/2"TBG,12.6#,13CR-85 VAM TOP, I 9594' ,iii , ` ii 9594' —I4-1/2"V4LEG.D=3.958" .0152 bpf,D %moi =3.958" ►� i --I ELMD TT NOT LOGGED Pi,PV NON Ili * ',iiiA. —15'X4-1/2"XO BUSHING,D= ' IP h. %1i 7"CSG,26#,L-80 VAM TOP HC,13=6276" 9739' % IlliriikIII PERFORATION SUMMARY 1 REF LOG: ON i i Z41trig ANGLE AT TOP PERF:_°@ %mitII Nbte:Refer to Rod uction DB for historical perf dataI SIZE SPF NT RVAL Opn/Sqz SHOT SQZ "f II V�Vtf#� mei II %) ;► PBTD H 14650' * tr- ,,' 40V 4-1/2"LM,12.6#,13CR-85 VAM HTTC,H 14730' •#si # .0152 bpf,13=3.958" DATE REV BY COMMENTS DATE REV BY COMVBNTS PRUDHOE BAY UN T 02/17/83 PKR 176 IMTIAL COMPLETION 02/27/18 JKR BOLT PROPOSED REV 2 WELL: 07-20" 09/23/95 NORDIC CTD SDTRCK(07-20A) PERMIT No: 03/01/09 NORDIC:CTD SDTRCK(07-20B) AH Nb: 50-029-20902-0:' i r SIDETRACK(07-20C) SEC 34,T11 N,R14E,1596'FIL&633'FAL 01/17/18 .AID BULT PROPOSED 01/17/18 KRIJMD BOLT PROPOS®REV 1 BP Exploration(Alaska) • • o U e Et m > r--- R o Jffits3� a m a; FM tel = o s 9 sa c" aK Sore ' ' .ZSiE r4°8 a i pp°pp° V m o m U D Nm S S N EO 7— 8:8 m 0 K 8 G G 31 " X"" • • SII E.n a g nna .2$w 1e CNNg d.s.N .. , N N z Z Er u''i' 20,45E.m .. �� ,,,.\ u\iuluin 2com.-. -..--. mm Nx S I I I, i��v =7777 \�\\ it\iNh gh IZi^i7Hmvv 2:2nnn; 2nn3t 1 1 1 nnn 00 R-m f �� Y +.® _ _-- ► a 1 1 U Y ii 1, . D I o oE '12, r CI z K m N� __--- W n 2 1 W m c 0 W m c 0 m m 2 U 3 3 U 3' W¢LL N N v\1 7 h VI y2 a N 22 N ' 1 I 1.1v,9_, Inn^ a n.- §n t- cZ�� cl . _____ __I- I 1 I i Ali" '�I' ' 1 _� .. ( J ` 1 I iii ; I 1 I I--- ri I 1 I _Imm. El 1L 155 2 II H ,- �wH �J� O MO■ 1 i\ �wo E :, _ __ �'M1 =____ Win 310 W 1 � e.,,=� U W C ce .Y.IZ Z n O r—,1/9 9-,9—, .11-,II 3 ,i/l Ol-,li O r oG ,Z/l S-,Zf / /1 $ (3dn,Ia1130) ,91'91 • • • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsib e 1 The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon"or J "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon"box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). P Instead, check the "Suspended"box and initial that change. Drilling Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the"Plug Stat Tech for Redrill"box, they will enter the Typ_Work code "IPBRD"into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill"code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill"comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. • V 0 X CO Thousand Cubic Feet of Gas ("MCF") per Month N o o , 0 co M 0 0 o c o O o O O O O O N (20 o O 0 0 O 0 0 o ."'1 .i .-1 .i .i .-1 ei N A M . i Oe o ?I ll 4E, m r 0_ 0 0 1 cm .. 0 O r 1 o N r, ; m AI .• o CO . ( 3 > O [ # v aI N .19 . o cui N -c, i,1 . • • • a O L.)I F— __. .41-4c o Z � 4 r V a d 1 -. ct of - St wi a J I I . • • LU m Q 4Pr x o i A�— §' LU a CL Q = L •k. __ •• v I1 ° 0 a _ _ q o 0. 3r d..—._. ,. ..• art-• a CL < 8a III CO t c 04� ° -1�----4 ' •• • UJ4.., iiik4 „ U Q C Z Q 2 �: SP — � •�. • •111 a v O Oj. V') p �4 z z1Pr • QN Ce M 7 Z Oa` w J CL ii X a. LLI Oo COet o 0 o O O O �tie O o O O O .-1 O 0 0 0 .-1 O O O .-1 O O .--1 glum .iad aale/N}o siaiie8 .io youow Jad Ho Jo siaaae8 2.d O\3 25°►15 WELL LOG TRANSMITTAL DATA LOGGED 1/ 11201 K BEND R To: Alaska Oil and Gas Conservation Comm. June 15, 2015 Attn.: Makana Bender 333 West 7th Avenue, Suite 100 ,4 Lr E o v- r,. Anchorage, Alaska 99501 JUN 18 2011, RE: Production Profile: 07-20B Run Date: 4/20/2015 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Fanny Sari, Halliburton Wireline &Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 07-20B Digital Log file, Interpretation Report 1 CD Rom 50-029-20902-02 Production Profile (Final Field Print) 1 Color Log 50-029-20902-02 SCANNED .H _ 4 ?0)`-‘• PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline &Perforating Attn: Fanny Sari 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907-275-2605 Fax: 907-273-3535 FRS_ANC@halliburton.com Date: Signed: M4L1-0-4a-,17) 6--eitzet