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Home My WebLink About213-109STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG "d k nrr ),7 en4n R404 DEC 3 01019 YL L la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned m Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero /� De a 65-9 a ry ❑ Service ❑ Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or Abend.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 11/29/2019 213-019 ' 319480 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 3/31/2013 50-029-20251-02-00 4a. Location of Well (Govemmontal Section): 8. Date TD Reached: 16. Well Name and Number: 4/11/2013 PBU J -09B ' Surface: 1248' FNL, 804' FEL, Sec. 09, T11N, R13E, UM g Rat Elevations KB 75.02 17. Field/Pool(s): Top of Productive Interval: 2425' FNL, 3027' FEL, Sec. 09, T11N, R13E, UM GL 40.55 BF 41.22 PRUDHOE BAY, PRUDHOE OIL Total Depth: 658' FNL, 2308' FEL, Sec. 09, T11N, R13E, UM 10. Plug Back Deplh(MD/TVD): 18. Property Designation: • 9455'18778' ADL 028281 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 643559 • y- 5970105 Zone - ASP 412133'/9035' 1 85-24 TPI: x- 641361 y- 5968887 Zone - ASP 4 12• SSSV Depth (MD/TVD): 20 Thickness of Permafrost MD/ VD Total Depth: x- 642042 y- 5970669 Zone - ASP 4 None 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 13. Water Depth, if Offshore: 21. Re-drilOLateral Top Window Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) MD/ND: 9600'/ 8881' 22. Lags 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/GR/RES, GR/CCL/ MCNL 23. CASING, LINER AND CEMENTING RECORD CASING WT. PER FT GRADE SETTING DEPTH MD SETTING DEPTH WD HOLE SIZEAMOUNT CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20" x 30" 35' 115' 35' 115' 36" 213 cu ft Cement 13-3/8" 72# N-eo 34' 2701' 34' 2701' 17-1/2" 4172 cu It Permafrost II, 97 cu ft Permafrost II 9-5/8" 47# N-80 33' 6100' 33' 5748' 12-1/4" 1177 cu ftHowcoLite, 250 cu ft Class'G', 135 cu ft PF 'C' 7-5/8" 29.7# L-80 5849' 9600' 5534' 8881' 8-112" 36 Bbls Class "G' 3-1/2"x3-1/4" 9.3#/6.6# L-80 9505' 12128' 8615' 9036' 4-i/4"x4-1/8" 132 sx Class'G' x2-7/8" /6.5# 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 Pedd): GRADE DEPTH SET (MD) PACKER SET (MD/TVD) 4-1/2" 12.6# L-80 9552' 9489' / 8806' 7-1 LY bn& 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during ormpletion? Yes ❑ No RI Per 20 AAC 25.283 (i)(2) attach electronic and printed information D kTE G{ Z 2t7( ` V Rj �(F�A FJ✓ �- 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 -0. Oil -Bbl: Gas -MCF: Water -Bbl: Choke Size: Gas -Oil Ratio' Flow Tubing Press Casing Press: Calculated 24 Hour Rate Oil -Bbl: Gas -MCF. Water -Bbl: Oil Gravity - API(com: Farm 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only R404 DEC 3 01019 28. CORE DATA Conventional Consist Yes ❑ No 0 Sidewall Cores Yes ❑ No 0 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 0 Permafrost- Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 9700' 8931' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. 21TS-Zone 2A 9700' 8931' Zone 1B 11920' 9028' Formation at total depth: Zone 1 B 11920' 9028' 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: Hartley, Josephine Authorized Title: SI S ialist Contact Email: Josephme.Hartley@bp.com Authorized Signature: Date: , 'f Contact Phone: +1 9075644570 INSTRUCTIONS General: This form is designe 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 Ia. 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-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 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. Form 10-407 Revised 5/2017 Submit ORIGINAL Only WELL NAME: J -09B 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 9493' Set CIBP 9480'- 9482' Punch Tubing 9474' Set Cement Retainer 9474' 180 Bbls IA Cement Squeeze 9455' Set Whipstock Daily Report of Well Operations PBU J -09B ***WELL S/I ON ARRIVAL*** (Pre CTD) PULL 4-1/2" NORTHERN SOLUTIONS IBP STOP FROM 2,074' SLM / 2,095' MD. SET 4-1/2" WHIDDON CATCHER SUB ON 45KB PATCH AT 5,191' SLM / 5,199' MD. MADE THREE ATTEMPTS TO PULL RK-LGLV FROM ST #2 (4,356' MD). 11/8/2019 ***JOB IN PROGRESS, CONTINUED ON 11/9/19 WSR*** ***CONTINUED FROM 11/8/19 WSR*** (Pre CTD) PULL RK-LGLV FROM ST #2 & SET RK-DGLV AT ST #2 (4,356' MD). PULL EMPTY 4-1/2" WHIDDON CATCHER SUB FROM 5,191' SLM / 5,199' MD. PULL COMPLETE BAKER 45KB STRADDLE PATCH FROM 5,191' SLM / 5,199' MD. DRIFT TO 45KB LTP AT 9,500' SLM / 9,505' MD W/ 3.70" CENT, S-BLR (No issues). 11/9/2019 ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** ***WELL SHUT IN ON ARRIVAL*** RIG UP HES ELINE UNIT 4863 11/11/2019 ***CONT ON 11/12/2019*** ***CONTINUE FROM 11/11/201 WSR***(cibp, tubing punch, cement retainer) SET BAKER 4.5" CIBP MID -ELEMENT AT 9494' CCL TO ME: 7.8', CCL STOP DEPTH: 9486.2'. (top of plug at 9493' MD) PULLED JEWELRY LOG PASS TO 5700'. PUNCHED TUBING 9480-9482 WITH 2" CIR-2106-4T381 CHARGES, 4 SPF, O DEG PHASE, CCL TO TOP SHOT 2.75', CCL STOP DEPTH 9477.5' ALL LOGS CORRELATED TO PDS COIL FLAG DATED 01 -AUG -2010. 11/12/2019 ***CONTINUE ON 11/13/2019 WSR*** T/I/0= 1994/1997/70 Temp= S/I (LRS Unit 72 - Assist Eline: Load & Test) Load IA w/ 5 bbls 60/40 bbls 340 bbls 110* Crude. Load Tubing w/2 bbls 60/40 Meoh and 210 bbis of 70* Crude. Eline sets CBP. Pumped 20.5 bbls crude down T/IA to pressure up to 2450/2493 psi, T/IA lost 95/99 psi in 28 min, Bleed T/IA pressure, Bled back 14 bbls, E -Line in control of well at departure- Hang AFE sign & tags, 11/12/2019 FWHP= 231/320/64 T/I/O - 283/388/67 Temp= S/I (LRS Unit 72 - Assist Eline: CMIT-TxIA) CMIT-TxIA PASSED with a Target pressure of 2250 psi. Pumped 16.3 bbls 50* Crude to achieve test pressure. First 15 minutes, TBG lost 38 psi and IA lost 40 psi. Second 15 minutes, TBG lost 14 psi and IA lost 16 psi. Bled back 16 bbls. Tags and AFE sign hung, E -Line in control of well upon departure. 11/13/2019 FWHPs - 288/385/65 ***CONTINUE FROM 11/12/2019 WSR***(cibp, tubing punch, cement retainer) SET BAKER 4.5" CAST IRON CEMENT RETAINER TOP OF RETAINER @ 9474' ELMD. LRS PERFORM MIT T X IA, SEE LRS AWGRS. RD ELINE. 11/13/2019 ***JOB COMPLETE*** CTU #9 - 1.75" Coil Job Objective: Pre-CTD/Cement IA MIRU. 11/13/2019 ***In Progress*** CTU #9 - 1.75" coil **Continued from 11/13/19 WSR** Job Objective: Pre CTD/Cement IA Test BOPS. Make up cement stinger BHA and RIH. At 2520' the levelwind became bound and needed to POOH to repair. 11/14/2019 ***In Progress*** Daily Report of Well Operations PBU J -09B CTU #9 - 1.75" Coil **Continued from 11/14/19** Job Objective: Pre CTD / Cement IA MU and RIH with Baker cement stinger. Circulate tubing to diesel. Sting into retainer and have reduced injectivity of -0.8 bpm at 5800 psi circ pressure. Circulate 50 bbls of SurfWash and then turn the IA over to Diesel. RU SLB cementers. 11/15/2019 ...Job in Progress... CTU #9 -1.75" coil **Continued from 11/15/19 WSR** Job Objective: Pre -CTD / IA Cement Pump 180 bbls of 15.8# cement down IA, taking returns up IA.Unsting and find that the retainer seal had failed at there is a large amount of cement in the tubing. PUH to get above tubing holes and begin contaminating and cleaning out cement from 5000' back down to the retainer at 9468' CTMD. Currently believe cement is in the IA from the punch holes at 9482 to -5640' and then comingled cement and diesel from the tubing holes at 5200' up to -4300. Chase cement out of hole jetting jewelry and tubing holes. FP down to 1000' with diesel and standby for cement to reach 500 psi compressive strength. 11/16/2019 ***In Progress*** CTU #9 - 1.75" coil **Continued from 11/16/19 WSR** Job Objective: IA cement squeeze Standby for cement UCA results. Once 500 psi compressive strength reach, Make up milling BHA with 3.80" bullnose junk mill and string reamer. Drift to cement retainer and dress cement down to the top at 9467 CTMD. Pump gel sweep and chase out of hole, dress tubing holes from 5100-5300'. FP tubing with 60/40 methanol. 11/17/2019 **Complete** T/I/0= 114/339/64.Temp=Sl, (LRS Unit 46 - MIT -T, MIT -IA Post CTU) Liquid Pack Tubing. 11/19/2019 Attempt MIT -T, IA tracking, roll into CMIT-TxIA Per Program. *** Job continued to ***WSR continued from 11/19/19*** T/I/0=1247/1339/57 Temp=Sl (LRS Unit 46 - MIT -T, MIT -IA Post CTU) CMIT-TxIA **PASSED** at 2333/2390 psi. Max applied pressure 2500 psi/Target pressure 2250 psi. Pumped 21.6 bbls Diesel down TBG/IA to reach test pressure 2403/2462. Test = 15 min TBG/IA lost 49/51 psi. 30 min TBG/IA lost 21/21 psi. Total loss of 70/72 psi in 30 mins. Bled back 10.2 bbls, SLB/SL in control of well at departure. Valve positions:SV/C WV/C SSV/C MV/0 IA/O AL/C OA/0 *** DSO notified of well status, 11/20/2019 FWHPs440/615/53 ****WELL S/I UPON ARRIVAL**** (ctd) DRIFTED W/ 20'x 3.70" DUMMY WHIPSTOCK TO 9,464' SLM (No issues) RAN 3.70" CENT, 3.50" LIB TO 9,464' SLM (No impression) RAN 3" SAMPLE BAILER TO 9,464' SLM (Sample of cement and metal shavings) RAN HES MEMORY SCMT LOG FROM PER SOR (Good data) 11/20/2019 ****WELL LEFT S/I & PAD -OP NOTIFIED OF STATUS UPON DEPARTURE**** T/I/0= 690/693/64. ( Circ out well w/2% KCL and U-tube DSL FP.) Pumped 295 bbls 80* 1 %KCL, followed by 295 bbls 110* 2%KCL down IA w/ returns up TBG. Pumped 173 bbls 120* Diesel down IA w/returns up TBG, U-tube Diesel Tx IA for 1.5 hrs. Pumped 3 bbls 11/22/2019 Diesel to FP surface lines. FWHP's =952/956/119. Well shut in upon departure. ***WELL SHUT IN ON ARRIVAL*** RIG UP ELINE AND RIH TO SET 4-1/2" BAKER WHIPSTOCK 11/23/2019 ***JOB CONTINUES ON 24-NOV-19 WSR**** ***CONTINUED FROM 23-NOV-19 WSR*** SET 4-1/2" WHIPSTOCK TOW AT 9455' ELMD, 178 DEGREES RIGHT OF HIGH SIDE 11/24/2019 ***WELL SHUT IN ON DEPARTURE*** Daily Report of Well Operations PBU J -09B T/1/0=0/0/0 Set 6" CIW "J" TWC #419 through tree. R/D upper production tree, installed CDR tree #1. Torqued to specs. Installed Kill line #1, torqued to specs. **made C/O with 11/25/2019 night crew**job in progress. TWC/50/50. Pre CDR2. Pulled 6" J TWC #419 @135". RD 6" tree bonnett. RU 6" test spool #1. Torqued to API spec. PT MV to low 300psi and high 3500psi for 5 min ea. Passed. PT 2nd MV and bottom SV on CDR2 tree #1 to low 300psi and high 3500psi for 5 min ea. Passed. PT top side SV on CDR2 tree #1 to low 300psi and high 3500psi for 5 min ea. 11/26/2019 Passed. Job Complete. See log. Final WHP's 10/50/50. MV=O. 2nd MV,WV and SV=C. TWO = MV2/50/70. Temp = SI. Bleed WHPs (Pre -rig). No AL, flowline or wellhead platform. Bled IAP to BT from 50 psi to 0 psi, all gas in 5 min. Bled OAP to BT from 70 psi to 0 psi in 1 hr 15 min, gas and fluid mix. Monitor for 30 min. Final WHPs = MV/0+/0+. 11/26/2019 MV2 = C. MV = O. IA, OA = OTG. 10:30 Common Well Name: J-09 Event Type. RE-ENTER- ONSHORE(RON) North America - ALASKA- BP Operation Summary Report Start Date: 11/27/2019 1 End Date: 12/11/2019 Site: J Page i of 25 AFE No - --- - IH-S4DW092438-EX-DI-RN (2,458,730.00) Rig Contractor. NABORS ALASKA DRILLING INC. j BPUOI: USA00000374 Active datum. KB @75.02usft (above Mean Sea Level) Date From - To HIM Task Code NPT Total Depth Phase Description of Operations 11/27/2019 10:00 - 18:00 8.00 RIGU P 1 PRE RIG MOVE -MOVE RIG FROM F PAD TO J PAD. -GET SUB CLOSE WITH TRUCK THEN USE STOMPER TO MOVE OVER WELL -MOVE PITS IN WITH TRUCK. ACCEPT RIG AT 18:00. 18 00 22:00 4.00 1 RIGU P PRE RIG UP -SAFE OUT RIG AND WORK ON RIG UP CHECKLIST 1 -SERVICE TREE VALVES AND TANGO VALVES li -LEAK TIGHT TEST SWAB AND MASTER VALVES TO 3500 PSI i RIG ACCEPT AT 1800 HRS" 12200 00:00 2.00 RIGU ISI P PRE RIG UP -CONTINUE WORK ON RIG UP CHECKLIST _' -INSTALL MPD LINE 11/28/2019 :0000 05:30 5.50 BOPSUR P I PRE NIPPLE UP - NIPPLE UP BOPS. ---- i- FLUID PACK REELAND SURFACE LINES - WITH FRESH WATER '.. j -CALIBRATE MICROMOTIONS -VALVE CREW TORQUE UP TREE �-PURGEAIR FROM LINES 1 -SHELLTEST BOPE 3500 PSI. NOTE: HOLD PRE SPUD MEETING WITH MICAH BUSH'S CREW NOTE: HOLD TABLE TOP FIRE DRILLAND j EVACUATION WITH MICAH BUSH'S CREW WITH SIMULATED FIRE COMING FROM Printed 12/26/2019 1:17:10PM "All depths reported in Drillers Deplhs" North Amenca - ALASKA - BP Page 2 of 25 Operation Summary Report ' Common Well Name: J-09 AFE No Event Type: RE-ENTER- ONSHORE(RON) IStart Date. 11/27/2019 End Date: 12/11/2019 HS4DW092438-EX-D1-RN(2,458,730.00) Project: PBU Site: J Rig Name/No.: CDR -2 Spud Date/Time: 7/18/1977 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000374 Active datum: KB @75.02usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations hr (usft) '05:30 - 13:00 7.50 BOPSUR P PRE TEST TOBP/AOGCC CRITERIA IINITIALBOPE ALL TESTS 250 PSI LOW/ 3500 PSI HIGH AOGCC WITNESS WAIVED BY LOU LAUBENSTEIN - 7-1116" ANNULAR, BLIND/ SHEAR, 2-3/8" PIPE / SLIP, MUD X, 2-3/8" x 34/2" VARIABLE, 2-3/8" PIPE / SLIP - ALL TESTS 250 PSI LOW/ 3500 PSI HIGH FOR 5 MIN EACH -TEST 1: IRV, PACKOFF, C9 BACKWARD, C10 'BACKWARD -PASS -TEST 2. MASTER, BLIND/ SHEAR, RI, BLIA, .81,84 -PASS - TEST 3: ANNULAR (2-3/8"), TIW#1, 33, B2, 'BL1-PASS - TEST 4: UPPER 2-3/8" PIPE/ SLIP, TIW#2, BL2, R2, T2, C15 - PASS - TEST 5: C16, T1, C11 - TI FAIL- CYCLE T1 AND RETEST - PASS j - TEST 6: VARIABLES (2-3/8 C7, C9, C10, TV2 -PASS - TEST 7: LOWER 2-3/8" PIPE/ SLIP, C5, C6, 'Ce, TV1-PASS i- TEST B: CHOKE A, CHOKE C - PASS - PERFORM ACCUMULATOR DRAW DOWN TEST- PASS ANNULAR & 61 USED FOR BLIND I SHEAR I- TEST 9: ANNULAR (3-1/2"), C1, C4 -PASS TEST 10: VARIABLE (3-1/2") C2, C3 - PASS 1300 - 14:30 1.50 BOPSUR P i PRE BOP TEST COMPLETED - RD TEST EQUIPMENT - SWAP OUT LUBRICATORS -STRAP STACK MEASUREMENTS 14.30 15:00 _ - INSTALL BHI FLOATS .— _—_ 0.50 BOPSUR P PRE UQC HAS BAD THREADS AND NEEDS TO BE REPLACED 15.00 - 16:00 1 T.00 BOPSUR , P ', PREERP SSURE TEST - PT LUBRICATOR AND BHI FLOATS _ '. -GOOD PT 2.00 BOPSUR P PRE WELL OPS ___..-. 16:00 - 18:00 - FLUID PACK MPL WITH METH TO OPEN UP TO THE WELLAND FILL THE WELL TO FLOW CHECK - PUMPED 8 BBLS AND METH PUP IS EMPTY li - SWAP METH PUPS AND FILL THE WELL. -FLOWCHECKGOOD -DISPLACE COIL WITH 10 BBLS OF METH AND j AND 45 BBLS OF HEATED 1% KCL -PURGE LUBRICATORS WHILE DISPLACING COIL -___ _ —ISI ,___�. _,_-FLOWCHECK FOR 10 MINUTES STATIC_ 18:00 - 20:00 2.00 STWHIP _ P 9,45600,. WEXIT MAKE UP 3.80' MILLING BHA#1 I'- HOLD PJSM WITH CREW I,I -MILL 3.80" GO / 3.79" NO GO - PRESSURE TEST QTS TO 3500 PSI HIGH FOR 5 MINUTES -INJECTOR ON: 0300 HRS NOTE HOLD KICK WHILE TRIPPING DRILL WHILE MAKING UP BHA WITH RICK ROY'S CREW. WELL SECURED IN 35 SECONDS. EXCELLENT RESPONSE BY CREW. AAR HELD WITH CREW Printed 12/26/2019 1:17:10PM **All depths reported in Drillers Depths** North America - ALASKA - BP Page 3 of 25 Operation Summary Report Common Well Name: J-09 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 11/27/2019 End Date: 12/11/2019 H-S4DW092438-EX-D7-RN (2,458,730.00 ) Project: PBU 1 Site: J Rig Name/No.: CDR -2 I Spud Date/Time: 7/18/1977 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. ! BPUOI: USA00000374 Active datum: KB (c@75.02usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr) _ i at) 120:0000:00 4.00 STWHIP P 9,456.00 WEXIT RIH WITH 3.80" MILLING BHA#2 I - RATE 0.50 BPM IN, 0.95 BPM OUT. CIRC PRESSURE: 795 PSI PUMPING HEATED SLICK 1% KCL MUD WEIGHT: 8.37 PPG IN, .8.26 PPG OUT TAKING RETURNS TO TIGER TANK - TIE IN FROM 9300' TO 9370' (CORRECTION -28) �-DISPLACE TO QUICK DRILL N WITH 6% KCL 8.8 PPG PUMPING AT 4.01 BPM IN 13.98 BPM OUTAT 2598 PSI WHILE RUNNING TO BOTTOM -WITH QUICK DRILL N ALL THE AROUND, STOP PUMPS AND CLOSE EDC - TAG WHIP STOCK (PINCH POINT) W/O I PUMPS AT 9456.98' 11/29/2019 00:00 - 12:00 12.00 STWHIP P 9463.00 WEXIT MILL WINDOW FROM 9456.9' 7O 9463 (1�iLi6 7i -RATE BPM IN 2.72 OUT 2.73 J ��V - FREE SPIN 2634 PSI oaG -PU52 SO 27 - MUD WEIGHT 8.78 PPG IN, 6.6 PPG OUT ECD 9.78 -TAG@ 9456.5 AND START MILLING WINDOW -WOB1-4 8.75 STWHIP P 9,470.50 WEXIT MILL WINDOW FROM 9463"709470.5' 12:00 - 20:45 -RATE BPM IN 2.92 OUT 2.99 - FREE SPIN 2634 PSI - CIRC PRESSURE 2854 PSI •.- MUD WEIGHT 8.72 PPG IN, 8.53 PPG OUT :ECD 9.83 -WOB 3.0-4.SK -AT 9470.5' BOTTOM OF WINDOW PICK UP TO TOP OF WHIPSTOCK CLEAN AND RUN BACK ITO BOTTOM j I . NOTE: SAMPLE FROM 9467.5 SHOWED 30% CHERT NOTE SAMPLE FROM 9470.5 SHOWED 50% -- CHERT 20:45 00:00 3.25 STWHIP P 9,472.80 WEXIT ! MILL RATHOLE FROM 9470.5' TO 9472.8 ;2.81 BPM IN/2.86 BPM OUT MUD WEIGHT 8.71 PPG IN / 8.72 PPG OUT j PUMP 10 BBLS LO / HI VIS SWEEPS AROUND. 9471 SAMPLE IS 60% FORMATION. PULL OFF BOTTOM THROUGH WINDOW j CLEAN AND GO BACK TO BOTTOM .-OBSERVE 50 PSI MOTOR WORKAT TOP OF I' WINDOW TRANSITION 11/30/2019 100:00 - 03:00 3.00 STWHIP P 9,473.00 WEXIT MILL RAT HOLE FROM 9472.8 TO 9473' -2.81 BPM IN /2.86 BPM OUT -MUD WEIGHT 8.71 PPG IN / 8.72 PPG OUT !-PUMP MULTIPLE SWEEPS I -PERFORM REAMING PASS FROM 9450'-9473' -CLEAN -PERFORM DRV DRIFT -CLEAN i -DYNAMIC FLOW CHECK -LOSING AT 6 BPH !-PIANT FLAG AT 9446.5' (9328.11'EOP) ! NOTE: ATTEMPT VARYING WOB AND PUMP RATES TO INCREASE ROP WITH NO SUCCESS Printed 12/26/2019 1:17:10PM **All depths reported in Drillers Depths** EZ VALLHEAD= McEVOY ACTUATOR= SH 3000 OKB. ELEV = 73.9T REF ELEV = 75.02 BF. ELEV = 4122 KOP= 2800' Max Angle = 94' (9D 12066' ❑aWm MD= 9587 Datum TVD= 88001SS FROM HOLES (11/16fl 9) ESTCMT IN IA (11116/19) –6640'-9482'— I Minimum 6640'-9482'— Minimum ID = 2.31" @ 9517' 2-71866 OTIS X NIP INSIDE KB LTP I9-5/8' CSG, 479, N-80, D = 9.681 • 6100' 4-12'BKR MONOBORE WHIPSTOCKw/2 RA PIP 9455' ELM ` TAGS 9463' (1124/19) ----------------- 4-12• BKR CAST IRON CMT RETAINER (1ill 3/19) 9474' TBG PUNCH (11112/19) 9480' - 9482' - 4-12-BKRCIBP(11/13A9) 9493' - 1 9662' 1 7-518' LNR, 29.7#, L-80, .0459 bpf, D = 6.875• –9600 PERFORATION SU lvWRY J -09B SAFETY NOTES: WELL ANGLE 700 @ 9725' *"• CHPRE J -09B WELLBORE'S Note: Refer to Production OB for historical pert data SIZE NOTSHOWNP`s*«* INTERVAL OpNSgz 2096' 4-12'0715 SSSVN, ID=3.813' SOZ ® 6 10439 - 10503 O 2183' s-518' FOG -3B'CSG, 2700' T 2887' 9-5/8• DV COLLAR 10539-10571 O 04/06(19 =12.347' T nse i ivruAcmoe FROM HOLES (11/16fl 9) ESTCMT IN IA (11116/19) –6640'-9482'— I Minimum 6640'-9482'— Minimum ID = 2.31" @ 9517' 2-71866 OTIS X NIP INSIDE KB LTP I9-5/8' CSG, 479, N-80, D = 9.681 • 6100' 4-12'BKR MONOBORE WHIPSTOCKw/2 RA PIP 9455' ELM ` TAGS 9463' (1124/19) ----------------- 4-12• BKR CAST IRON CMT RETAINER (1ill 3/19) 9474' TBG PUNCH (11112/19) 9480' - 9482' - 4-12-BKRCIBP(11/13A9) 9493' - 1 9662' 1 7-518' LNR, 29.7#, L-80, .0459 bpf, D = 6.875• –9600 PERFORATION SU lvWRY REF LOG: MCN./ GW OCL ON 04/15/13 ANGLEATTOPPERF 88'@ 10439 Note: Refer to Production OB for historical pert data SIZE SPF INTERVAL OpNSgz I SHDT SOZ T 6 10439 - 10503 O 04/06119 JCF/JMD CMT N 1A & CMT&DESEL IN T 6 10539-10571 O 04/06(19 JLS/JMD TREE CIO 0428/19 T 6 10899 - 10963 C 05/24/18 T 6 11260 - 11324 C 05/23/18 T 6 11670-11870 C 04/16/13 T 6 11970-12070 C 04/16/13 LNR 6.69, L-80 TG, .0079 bpf, D = ST MD ND I DEV I TWE I VLV LATCH PORT DA TE 2 1 56 434270 5760 5458 31 32 MMG DMY RK MMG DMY RK 16 11199/19 0 09/14/94 6849' –J9-518- X 7-5/8• BKR PKR D = 6.87 6860' 9-518• x 7-518• BKR HGR o= 6.B i 9-518' MLLOUT WNDOW (J -09A) 6100' - 6150' 2T 4-12.OTB X NP (9 -CRL D = 3813- 1) = 3.937' OTB X TIS X NP (9 -CR), D = 3.813' KB LNR TOP PNR N 1 DEPLOY SLV, D = 3.00' TIS XN NP (9 -CR), D = 3.725' LEG, D = 3.958' BEHIND LOGGED 08/13/97 1 CT LNR 7-5/8' MLLOUT WINDOW (J-098) 9600' - 9607- DATE REV BY COMMENTS DATE REV BY COMMENTS 08119177 RWN 26 INITIAL COMPLETION 12/02/19 GJB/JMD PULLED BP, PATCH, GLV C/O 09/09194 044 SIDETRACK (J -09A) 12/02/19 TJS/JMD TBG PUNCH, SET CIBP, CMi F 04114113 NORDIC 1 CTD SIDETRACK (J -09B) 12102/19 JCF/JMD CMT N 1A & CMT&DESEL IN 0420/19 DD/JMD+ PERF & ELEV UPDATES ( 12/02/19 BTN/JMD SET WS w/ PP TAGS (1124119 04/30/19 JLS/JMD TREE CIO 0428/19 06/18/19 GJB/JMD PULL XX PLUG✓SET BP STOP 6- X 2-7/8• XO, D BKR CIBP (0524/1 PRUDHOE BAY UNIT WELL: J -09B E PERMITNo:t130190 API No: 50-029-20251-02 SEC 9, T11 N, R13E, 1248' FNL & 804- 13P Exploration (Alaska)