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202-064
STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEIVED FEB J001w9c '` RDMS(-61' FEB 0 5 2020 Mg �(j% Vel 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned El 4 Suspended ❑ 1b. Well Class: 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero Develq®1 nt I to ❑ rA Service, 0 Stratigraphic Test ❑ 2. Operator Name: 6. Date Comp., Susp., or Abend.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 1/5/2020 202-064 . 319,504 3. Address: 7. Date Spudded: 15, API Number: P.O. Box 196612 Anchorage, AK 99519-0612 3/272002 50-029-2307740-00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16, Well Name and Number. 4/5/2002 PBU L-119 Surface: 2601' FSL, 3574' FEL Sec. 34, T12N, R11E, UM a 9, Ref Elevations KB 78.90 ' 17. Field/Pool(s): Top of Productive Interval: 1575' FSL, 183' FEL, Sec. 27, T12N, RI E. UM 0 GL 50.40 r BF 50.54 r PRUDHOE BAY, BOREALIS OILS Total Depth: 1694' FSL, 69 FEL, Sec. 27, T1 2N, R11 E. UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 9060'16658' ADL 028239 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27)' Surface: x- 583340' y- 5978324' Zone - ASP 4 11. Total Depth (MD/TVD): 9624'/ 7197' 1 19, DNR Approval Number: 00-001 TPI: x- 586875 y- 5982615 Zone - ASP 4 Total Depth: x- 586787 y- 5982736 - Zone - ASP 4 12. SSSV Depth (MD/TVD): None 20Thickness of Permafrost MDfrVD: 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13. Water Depth, if Offshore: 21. Re-drill/Lateral Top Vvndm Submit electronic and printed information per 20 AAC 25.050 WA (ft MSL) MD/TVD: N/A 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, LIND, CCL, CBL / VOL. OR, DIR, RES, DEN, NEU, USIT 23. CASING, LINER AND CEMENTING RECORD CASING Wr. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H-40 32' 112' 1 32' 112' 42" 260 sx Arctic Set (Approx.) 9-5/8" 40# L8o 32' 1 2919' 32' 2621' 12-1/4" 525 sx AS III Lite, 290 sx Class'G' 7" 26# L -so 28' 9609' 28' 7182' 8-3/4" 606 sx Clan 'G' 24. Open to Production or injection? Yes ❑ No ® 25. TUBING RECORD If Yes, list each interval open (MD/iVD of Top and Bottom; Perforation Size and Number; Date Perfd) GRADE DEPTH SET (MD) PACKER SET (MD/TVD) 4-12" 12.6# L-80 8995' 8834'16445,8958'16562' AIS -_ �,s71 , 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. adw l 2i Was hydraulic fracturing used during completion? Yes ❑ No VI Per 20 AAC 25.283 (i)(2) attach electronic and printed information information DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED IfDA VE 9060' Set Whipstock --�1�—�— 27.PRODUCTION TEST Dale First Production: Not on Injection Method of Operation (Flovdng, an lift, etc.): WA Data of Test: Hours Tested Pmdudion for Test Period y Oil -Bbl: Gas -MCF: Vdawr-Bbl: Choke Size: Gas -Oil Ratio: Flax Tubing Casing Press:Calculated Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity- API(wrl: Press 24 Hour Rate y Form 10-407 Revised 52017 CONTINUED ON PAGE 2 Submit ORIGINAL only J001w9c '` RDMS(-61' FEB 0 5 2020 Mg �(j% Vel 28. CORE DATA Conventional Corefs) Yes ❑ No a Sidewall Cores Yes ❑ No O 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 torte, 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 9055' 6653' separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Ugnu 3336' 2852' Schrader Bluff M 5370' 4000' Schrader Bluff N 5899' 4291' Schrader Bluff O 6185' 4461' Base of OBf / Colville 6598' 4716' Kalubik 8920' 6526' Kuparuk D 9055' 6653' Kuparuk C 9057' 6655' Kuparuk 8 9210' 6800' r KuparukA 9379' 6961' Miluveach 9470' 7048' Formation at total depth: Miluveach 9470' 7048' 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: Hyatt, Trevor Contact Name: Lastufka, Joseph N Contact Email: Joseph.Lastufkaabp.com Authorized Title: rilk Engine 4 Authorized Signature: Date:,,,'JIM Contact Phone: +1 907 564 4091 INSTRUCTIONS General: This form is designed for submitb 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 1 a. 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 Flrst. Item 23. Attached supplemental remms 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 toren 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 farm: 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 512017 Submit ORIGINAL Only .WELL SHUT IN ON ARRIVAL*** (hes eline - mill xn,set whipstock pre rig) MIRU HES ELINE AND WELLTEC MILLING TOOL. MILL OD 3.806" 12/18/2019 ***JOB CONTINUES ON 19-DEC-19 WSW" TWO = 514/55/11. Temp = SI. TBG FL (pre RIG). TBG FL @ surface. 12/19/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 23:00 ***JOB CONTINUES FROM 18-DEC-19*** MILL XN NIPPLE AT 8,982' AND DRIFT THROUGH NIPPLE DOWN TO 8,991' WITH WELLTEC MILLING/STROKER TOOL. FINAL MILL OD 3.805". SET BAKER 4-1/2" x 7" DELTA WHIPSTOCK AT 9,060' TOWS, ZERO DEG 12/19/2019 ORIENTATION. T/1/0=500/0/0. Pre CDR2. Set 4" H TWC #444 @ 125". RD 4" Cameron upper tree. RU 12/27/2019 CDR2 tree #3 and kill line #5. Torqued to API spec. Job in progress. See log. Final WHP's T/I/O =7 WC/0/0. Pre-CDR2 Job continued. Install 4x7 X-Over and TS #07. Torque to API specs. RU CIW lubricator #68-839 and PT against TWC to 350/5000psi (PASS). Run down and pull 4" 'H' TWC #444 at 130". RD lubricator and install tapped blind flange on TS. Torque to API specs. PT against MV1 gate to 350/3500psi (PASS) PT against Topside MV2 Gate x Bottom side SV Gate to 350/3500 (PASS). PT top side SV gate to 12/29/2019 350/3500psi (PASS). RDMO ***Job Complete*** SEE LOG FOR DETAILS Final T/I/0= TWO = 550/50/10. Temp = SI. Bleed WHPs to 0 psi (pre-RIG). TBG FL @ surface. IA FL @ surface. OA FL @ cemented to surface. Bled IAP to BT from 50 psi to 0 psi in 1 minute. Hold open bleed for 30 minutes. All fluid (<10 gals). Bled OAP to BT from 10 psi to 0 psi in 15 seconds. All gas. Hold open bleed for 30 minutes. Bled TP to BT from 550 psi to 200 psi in 5 minutes. All fluid (.75 bbis). SI bleed. Monitor for 15 minutes. TP increased to 520 psi during 15 minute monitor. Bled TP to BT from 550 psi to 200 psi in 5 minutes. All fluid (.75 bbls). SI bleed. Monitor for 15 minutes. TP increased to 520 psi during 30 minute monitor WHPs unchanged. Final WHPs = 520/0/VAC. 12/29/2019 2nd MV, WV = C. MV = 0. IA, OA = OTG. 23:00 TWO = 530/10/0. Temp = SI. WHPs (Pre Rig). No flowline. No wellhouse. CDR2 wellhead configuration rigged up. TP increased 10 psi, IAP increased 10 psi, OAP 12/30/2019 unchanged overnight. North America - ALASKA - BP Operation Summary Report Page 1 ab/9 Common Well Name: L-119 Event Type. RE-ENTER- ONSHORE(RON) Start Date. 1/3/2020 End Date. Project: PBU Site: L Rig Name/No.: CDR -2 Spud Date/Time: 3/27/2002 12:00 OOAM Rig Release: Rig Contractor. NABORSALASKA DRILLING INC. BPUOI: USA00001695 Active datum: KB §78.90usR (above Mean Sea Level) Date From - To Him Task Code NPT I Total Depth Phase Description of Operations (hr) (usR) 1/3/2020 13:00 - 19:30 6.50 MOB P _ PRE RELEASED RIG OFF J-17 - PJSM FOR PULLING OFF WELL - RU STOMPER AND MOVE PIT MODULE. - RU STOMPER TO SUB. GET ASSIST FROM CAT TO PULL SUB OFF -INSTALLJEEPS 19:30 - 00:00 4.50 MOB P PRE MOVE RIG FROM J -PAD TO L -PAD (CURRENTLY AT MOBILE PAD LETTING _ _ _; _ - TRAFFIC BY) 1/4/2020 00:00 - 02:00 2.00 MOB P RE CONTINUE MOVING RIG TO L -PAD ARRIVE L -PAD 02:00 - 06:00 4.00 MOB _ P _0N PRE REMOVE JEEPS SPOT 12 X 12 _ _ _ PJSM FOR SPOTTING SUB 06:00 - 17:00 11.00 RIGU P PRE MIRU OPS - MAIN AND PIT SUBS SPOTTED - ACCEPT RIG AT 08: 00 -SECURE CELLAR - CLOSE MV #1 AND OPEN MV #2 FOR THERMAL EXPANSION - LTT MV #1 TO 3500 PSI, GOOD PT - LTT MV #2 TO 3500 PSI, GOOD PT MU MPL - NO TREE CAP AND NU BOPE -SET INJECTOR ON WELLAND CHECK TREE BOLTS - TREE BOLTS ARE GOOD - FLUID PACK COILAND SURFACE LINES -TEST GAS ALARMS - HOLD PRE -SPUD & EVAC DRILL WITH CREW - SHELLTEST, GOOD TEST 1T.00 - 00:00 TOO BOPSUR I P _ PRE TESTBOPEASPER BPANDAOGCC STANDARD. WITNESS WAIVED BY AOGCC BY MATT HERRERA - 7-1/16" ANNULAR, BLIND/ SHEAR, 2-518" PIPE / SLIP, MUD X, 2-3/6" x 3-1/2" VARIABLE, 2-5/8" PIPE / SLIP - ALL TESTS 250 PSI LOW /3500 PSI HIGH FOR 5 MIN EACH - TEST 1: IRV, PACKOFF, C9 & C10 BACKWARD - PASS - TEST 2: BLIND / SHEAR, R1, BLiA, B1, B4 - PASS - TEST 3: ANNULAR (2-5/8"), TIW#2, B3, B2, BL1-PASS - TEST 4: UPPER 2-5/8" PIPE / SLIP, TIW#1, BL2, R2, T2, C15 - TIW#1 FAIL CYCLE - TEST 5: C16, Ti, C11, TIW#1 RE -TEST- PASS (TIW#1 FAIL/ PASS) - TEST 6: VARIABLES (2-5/8"), C7, C9, C10, TV2 -TROUBLESHOOT. C9 LEAKING. BLEED DOWN. GREASE/CYCLE RETEST PASS. C9 WILL BE FAIL / PASS - TEST 7: LOWER 2-5/6" PIPE/ SLIP, C5, C6, CO, TV1-PASS - TEST 8: CHOKE A, CHOKE C - PASS -ACCUMULATOR DRAW DOWN TEST Printed 2/3/2020 3:19:14PM **All depths reported in Drillers Depths•' North America - ALASKA - BP Operation Summary Report Common Well Name: L-119 Event Type: RE-ENTER- ONSHORE (RON) Stan Date: 1!312020 Eno Date: Project: PBU Site: L 12:00:OOAM Page 264 Rig Contractor: NABORSALASKA DRILLING INC. BPUOI: USA00001695 Active datum: KB @78.90us8 (above Mean Sea Level) Date Fmm - To HisTask Code NPT Total Depth Phase Description of Operations ..—_— (hr) (usft) 1/5/2020 00:00 - 01:00 1.00 BOPSUR P PRE CONTINUED TEST BOPE AS PER BPAND AOGCC STANDARD. WITNESS WAIVED BYAOGCC BY MATT HERRERA - 7-1/16" ANNULAR, BLIND/ SHEAR, 2-5/8" PIPE / SLIP, MUD X, 2-3/8"x 3-1/2" VARIABLE, 2-5/8" PIPE / SLIP - ALL TESTS 250 PSI LOW/ 3500 PSI HIGH FOR 5 MIN EACH - TEST 9: ANNULAR (3-1/2"), C1, C4. PASS _ -TEST 10: VARIABLE (3-1/2') C2, C3 - PASS 01:00 - 07:00 6.00 RIGU P PRE RIG DOWN TEST EQUIPMENT INSTALL SOMBREO INSTALL FLOATS IN UQC PRESSURE TEST UQC BODY TEST FLOAT TO 4000#, PASSED STAB INJECTOR. TEST DRILLING RISERS / IPACKOFFS MAKE UP NOZZLE ASSEMBLY - STAB ON TO WELL AND PT THE OTS - GIVE PRE -SPUD AND RIG EVAC DRILL TO _ _ _ _ __ NIGHT CREW 07.00 - 11:00 4.00 KILLW P _ PRE .WELL KI LL OPS '- LOAD NEAT METH INTO COIL - LOAD COIL WITH 9.8 BRINE - GOOD METH IN TT LINE, SHUT DOWN PUMP AND BLOW DOWN TT LINE - CLOSE CHOKE, REMOVE LOTO FROM MVS, OPEN SWAB AND MV #2, PRESSURE UP TO 700 PSI AND OPEN UP TO THE WELL - WHP = 554 PSI IAP = 67 PSI OAP = 0 PSI - ONLINE WITH PUMP DOWN THE COILAT 1 BPM HOLDING 575 PSI ON CHOKE AND RIH - GETTING A LITTLE GAS CUT FLUID, NOTIFY PAD OPAND BP RADIO FOR VENTING GAS TO THE TT - 9000', PU WT = 56K, RIHWT = 23K - TAG AT 9080.44', PU WT = 59K, RETAG SAME DEPTH - PU TO 9050', ZERO THE OUT MM AND START OUR BOTTOMS UP KILL WITH 9.8 PPG BRINE - 3.0 BPM AJUST WHP BASED ON IN & OUT RATES, WHP = 554 PSI IAP = 161 PSI OAP = 133 PSI - 2ND WORLEY VAC TRUCK HAS A MECHANICAL ISSUE WITH THE VALVE, GO TO _ MIN RATE 60 B_BLS LEFT ON FIRST TRUCK 11:00 - 13:00 2.00 KILLW N PRE SUSPEND OPERATIONS, FIELD WIDE EMERGENCY FOR A GAS LEAKAT GCI - SHUT DOWN BOTTOMS UP KILL OPS - SHUT IN WELL, BLOW BACK VAC TRUCK LINES & TT LINE AND STBY Printed 2/3/2020 3:19:14PM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 3111 Operation Summary Report Common W ell Name: L-119 Event Type: RE-ENTER- ONSHORE IRON) Start Date'. 1/3/2020 End Date. Project: PBU Site: L - -- Rig Name/No.: CDR -2 Spud Date/Time: 3/27/2002 12.00:OOAM Rig Release: Rig Contractor: NABORSALASKA DRILLING INC. _ BPUOI: USA00001695 Active datum: KB @78.90usft (above Mean Sea Level Date From - To Him Task Code NPT Total Depth Phase Description of Operations (hr)__ lush) _ 13:00 - 18:00 5.00 KILLW P PRE CONTINUE WELL KILL OPS -CREW CHANGED OUT, REVIEW PRE -TOUR MEETING FOR PLAN FORWARD - VERIFY TT LINE IS CLEAR, VERIFY LINE UP, ONLINE WITH PUMP TAKING RETURNS TO THE TT - WHP = 114 PSI IAP = 127 PSI OAP = 0 PSI - BOTTOMS UP IS CLEAN, CONTINUE PUMPING, PURGE LUBRICATOR - IN 8 OUT DENSITIESARE STABLEAT 9-8PPG, IN RATE = 1.97 BPM, OUT RATE = 1.92 BPM - WHP =66 PSI IAP =256 PSI CAP =100 PSI - BRING RETURNS INSIDE, REDUCE RATE, FOAMED UP FLUID THROWING OFF DENSITY, GET MUD WT - 14:20 SHUT DOWN AND FLOW CHECK THE WELL - 14:40 GOOD NO FLOW CHECK, ONLINE, 0.15 BBLS TO GET RETURNS WE IS STATIC -SWAP TO 9.8 MUD, 20 BBLS OF MUD OUT, j POOH HOLDING 50 PSI WHP - STOP 50' FROM SURFACE, FLOW CHECK WELL -- GOOD NO FLOW, PU THE INJECTOR AND LD THE BHA 18:00 - 21:30 3.50 STWHIP P 9,066.00 WEXIT RIH WITH 3.80" MILLING BHA #2 - RATE: 0.59 BPM IN, 1.05 BPM OUT. CIRC PRESSURE: 726 PSI li - MUD WEIGHT: 9.79 PPG IN, 9.98 PPG OUT - LOG DOWN FOR TIE-IN FROM 8880' TO 8947.58' MD (FORMATION) WITH -12.5' CORRECTION - RIH TO ABOVE WHIPSTOCK. PUW: 63K RW` 21.7K - DRY TAG AT 9066' MD _ - PICKUP AND BREAK CIRCULATION (Y _ 21:30 - 00:00 2.50 DRILL P 9,069.60 WEXIT MILL 3.80" WINDOW IN 7.0" LINER PER BAKER J✓ REP - RATE: 2.73 BPM IN, 2.70 BPM OUT MUD WEIGHT: 9.87 PPG IN, 9.97 PPG OUT ECD: 11.5 PPG - ROP DROPPING AT 9130' DRILLING SHALE, POSSIBLY BALLED UP 1/6/2020 00:00 - 04:00 4.00 STWHIP P 9,075.50 WEXIT MILL 3.80° WINDOW IN 7.0" LINER PER BAKER REP - RATE: 2.72 BPM IN, 2.70 BPM OUT - MUD WEIGHT: 9.86 PPG IN, 9.96 PPG OUT ECD: 11.5 PPG - MILL AHEAD TO 9072' MD (MID POINT) MOTOR WORKAND WOB STEADILY WENT CONTINUE TO TIME MILL TO STRING (AWAY. REAMER EXIT DEPTH OF 9075.5' Printed 2/3/2020 3:19:14PM **All depths reported in Drillers Depths" TTEE= 4-1/16'SMOW VVELU-EAD= 11' FNC ACTUATOR= WA OKB. E" = 78.9 BF. AB/ = 50.54' KOP= 949 M1x Angle = 58@5507 Datun MD= 9082 Datum TVD = 6804 SS 9-5/8' CSG, 40#, L-80, D = 8.835' 2919' Minimum ID = 3.805" @ 8982' 4-1/2" MILLED HES XN LANDING NIPPLE PERFORATION SL21A14ARY REF LOG SM DENSRY/rRJTTM 03127/02 ANGL E AT TOP FH7F: 26" Q 8850 Note: Pefer to Production DB for historical perf data 4-12"4 8850 - 8852 S 4-12" 4 8947-8949 S 33/8" 6 9058-9084 O 3318" 6 9092-9106 O 4-1/2' 5 9160-9161 C IIE 4-12' BKR DELTA WHIPSTOCK ad 2 RA PP TAGS AT 9051' (12/19/19) PBTD �. 7' CSG, 266, L -S0, BTGMOD, D = 6.276' �. L 119 MD I ND SAFETY NOTES: 1-12S READINGS AVERAGE 125 ppm SON MI. WELL REQUIRES A SSSV WHEN ON IAAI T I LAA— DS/JMD OA CEMENTED SURFACE TO SHOE GAR 1 FT MA MRP Q STI MD I ND I DLV I TYPE I VLv I LATCH PORT I DATE 3 DS/JMD OA CEMENTED SURFACE TO SHOE rD6/25/15 54KBG2DMY BK -s =2 o 0720/02 2 14:5013487 7 5303 43 DMt' BK -5 0 0720/02 1 8754 6373 24 K8G2 OW BK -5 0 0720/02 BOREALIS UNIT WELL: L-119 PERMR No: x2020640 API No: 50-029-23077-00 SP Exploration (Alaska) REV BY COMMENTS DATE REV BY COMMENTS JLMIKK ORIGINAL COMPLETION 11/13/18 DS/JMD OA CEMENTED SURFACE TO SHOE rD6/25/15 7MWJMD ADDED H2S SAFETY NOTE MD ADDED 3-12' TBG NFO 1126118 12/30/19 JMG/JMD PULLED PXN PLUG 1124/18) BTN/JMD MILLED XN NP & SET WB & PP TAGS JNL/JMD ADDED BF ELEV 0726/18 BO/JMD CORRECTED 9-5/8' CSG D 07!!0/18 CJN/JMD SET PXN PLUG (0712811 BOREALIS UNIT WELL: L-119 PERMR No: x2020640 API No: 50-029-23077-00 SP Exploration (Alaska) FP-ik L—I N Regg, James B (CED) FM From: Murphy, Jay <Jay.Murphy@bp.com> �e I�ZZI Z.c Sent: Tuesday, January 21, 2020 1:53 PM J ZO To: DOA AOGCC Prudhoe Bay Subject: AOGCC BOPE Usage Report Form Attachments: Nabors CDR2 BOP Usage Form for Well L119Ai 1-20-2020.doc Thank You and Best Regards, Jay Murphy GWO-Alaska Well Operations Specialist Office: (907) 659-4618 Cell: (907) 715-9211 Harmony: 2156 Alternate: Dave Newlon GVV Giobalt^1e!i Organ rano, AOGCC BOPE USAGE REPORT FORM (Well Control event only) Field Superintendent Name: Jay Murphy Wellsite Leader Name: Tom Kavanaugh/ Chuck VanRay Contact Number: 659-4618/ H# 2156 Contact Number: 685-4886/ H44542 BP Traction Number: TBD Rig Name & Well Pad or Drill Site & Well Name: CDR2 L-119Ai Permit To Drill (PTD) Number: 202-064 Date and Time of Incident: 1/20/2020 @ 22:45 Original Scope of Work: Drill sidetrack for Injector well L-119Ai Operational Description Leading up to Well Control Event: Drill String became detained with inability to pull free, crude had been pumped to try and free the coil without success and subsequently pumped out of the well. Coiled Tubing string was terminated and is currently at 66 foot below wellhead inside the 4-1/2" tubing string. Current operations were fishing E - Line from the coiled tubing string and recover string. The well was kept full with — lbph while fishing. The well had not been circulated the since 1/17/2020. BOPE Used and Reason: Observe well bore fluids rising due to small gas bubbles percolating. Shut in the Blind/ Shear rams against the Kill HCR and the Well Control Choke (A). Current BOPE test time/date: 1/20/2020 @ 00:30 witnessed by Adam Earle Is a BOPE re -test required after use: Yes/No and reason: Yes (BOPE components that have been used for routine purpose, or purposes other than WC need not be re -tested beyond current routine 7/14 day schedule. Breaking the stack for maintenance or other operations, or opening ram bonnet doors to change casing rams etc. would trigger a retest but a WC usage report is not requiredj BOPE Retest time/date and result (WSL to complete as applicable): 1/21/2020 @ 02:00 ✓ As much notice as possible is requested to NS AOGCC Inspectors email address prior to re -testing any BOPS components (following WC event usage) State witness may or may not be waived but prompt AOGCC notification must be made.) Plan Forward: Well was bullheaded with 2X annulus volumes and monitored before well was opened back up and was monitored again before continuing is ing operations. ✓ Additional Comments: When the well was shut in pressure built to 20psi and returned to Opsi after 30 minutes. Due to crude being pumped previously and no free gas in the Kuparuk, it is thought that this is residual breakout from the crude. The Blind/ Shear rams, Kill HCR and Well Control Choke (A) was tested immediately. ACTIONS REQUIRED: 1) Well Site Leader: Timely email notification of BOPE re -test time estimate to AOGCC North Slope Inspectors is required following any WC incident to allow the State to witness re -test as required. (This is a judgment call given WC is an unplanned event during rig operations and factors such as wellbore condition and trip timing will influence timing of any retest) 2) Superintendents: Email the completed BOPE Usage Report form to AOGCC North Slope Inspectors within 24 hours of a WC incident: doa.aoscc.prudhoe.bav@alaska.Pov 3) Well Site Leader: Complete AOGCC BOPE Test report form 10-424 and send to three AOGCC addresses (noted in form) within 5 days following the test/retest. This is applicable to Well Control events Only. THE STATE °fALASKA GOVERNOR MIKE DUNLEAVY Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Borealis Oil Pool, PBU L-119 Permit to Drill Number: 202-064 Sundry Number: 319-504 Dear Mr. Mclaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.oIaska.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, ti Jeremytee rice Chair DATED this�� day of November, 2019. 3BDMS ! Nov 141019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 .. r ORIGINAL ABDMS ±� NOV 14 2019 PC 111130�1V//7 1tnn�1a'eas ti9 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate C=t�A. a 1 t /2/i0 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ ChanAngeElPlug �J �,/� ❑ for Redrill El • Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing 11 Other 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number. 202-064 ' 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service D 6. API Number: 50-029-23077-00-00 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 m 1 PBU L-119 9. Property Designation (Lease Number): 10. Field/Pools- ield/PoolsADL ADL028239 4 PRUDHOE BAY. BOREALIS 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): 9624 7197 9150 6743 2720 9150 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 32-112 32-112 1490 470 Surface 2887 9-5/8" 32-2919 32-2621 5750 3090 Intermediate Production 9581 7" 28-9509 28-7182 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (it): Tubing Size: Tubing Grade: Tubing MD (ft): 1 9058 - 9161 6658 - 6753 4-1/2" 12.6# 26-8995 Packers and SSSV Type: 4-1/2" Baker Premier Packer Packers and SSSV MD (ft) and TVD (ft): 8834 / 6446 4-1/2" Baker S-3 Packer 8958/6562 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic p 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service RI 14. Estimated Date for Commencing Operations: 12/1/2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended RI 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ I Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hyatt, Trevor be deviated from without priorwntten approval. Contact Email: Trevof.Hyatt0tiocom Authorized Name: Mclaughlin, Sean M Contact Phone: +1 907 564 4627 Authorized Title: En K eenng Tem ead - CTD Authorized Signature: , Date: V COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: �3iq-�b1/ Plug Integrity 11/• BOP Test D1' Mechanical Integrity Test ❑ Location Clearance ❑ Other: B, cop b` 'i ers' 'T'e L4 ©eno �� N l•4ev.a.vdc a � Idce,,,,,�,,,,}, tra�ta.r�t r +-�u� ��n�j � r Z' � � C" Z-5• I fZ JPost Initial Injection MIT Req'd? Yes ❑ No ❑ / Spacing Exception Required? Yes 0L9� Subsequent Form Required: 10 `9 0`7(((yyy APPROVED BYTHE Q Approved by: COMMISSIONER COMMISSION Date. 1 it I 1 ORIGINAL ABDMS ±� NOV 14 2019 PC 111130�1V//7 1tnn�1a'eas ti9 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate C=t�A. a 1 t /2/i0 To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt by CTD Engineer Date: November 4, 2019 Re: L-119 Sundry Approval Request Sundry approval is requested to plug off the L-119 production as part of the preparation, drilling and completing the proposed L -119A coiled tubing sidetrack. History of L-119: Well is a Kuparuk injector originally drilled and completed in 2002. L-119 was shut in and not operable due to a surface casing leak. An OA down squeeze with cement has been completed to fix the surface casing leak. The well is back to being operable. Proposed plan for L-119: A 4,359' coil tubing drilling sidetrack will be drilled with the Nabors CDR2 rig. The whipstock will be set pre -rig, in the 7" liner. A 3.80" window+ 10' of rathole will be milled pre -rig with service coil. Then the rig will move in, test BOPE and kill the well. The well will kick off in the Kuparuk and drill the lateral in the C4 and C3 sands. The proposed sidetrack will be completed with a 3-1/4" x 2-7/8" 13Cr solid liner, cemented in place and selectively perforated. This completion will completely isolate and abandon the parent Kuparuk perfs. The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Pre -Rig Work (scheduled to begin December 1, 2019) 1. Drift for WS 2. Set Whipstock 3. Mill XN & Mill window (24 hr notice to AOGCC to witness BOP test of 4000 psi) 4. Pre -CTD Tree work. 1. MIRU and test BOPE 250 psi low and 3,500 psi hil 2. Drill build section: 4.25" OH, ^317' (35 deg DLS pl 3. Drill lateral section: 4.25" OH, -4,022' (8 deg DLS 4. Run 2-7/8" x 3-1/4" 13Cr liner to TD. 5. Pump primary cement job: 56 bbls, 15.3 ppg Clas 6. Close in tree, RDMO. * Approved alternate plug placement Der 20 AA1 Post -Rig Work: 1. V: tree work as necessary 2. S: install LGLVs. Install LTP if necessary 3. F: PT LTP if set. 4. C: Perforate 200' at toe. 2" MaxForce. 5. Special Projects: Pump N2 down IA if field ops cannot rig up clean pbgl in a timely manner 6. T: Pre -produce well via portable test separator for 5 days. 7. S: Dummy GLV's. Regulatory compliance SBHPS (prior to regular injection). Set MCX 8. F: Pre-AOGCC MIT -IA and AOGCC MIT -IA (to MI pressures) 7 "o%'Rtl 319 --ty The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: • A min EMW of 8.4 ppg KCI (103 psi under -balance to current parent pressure of 8.7 ppg). KCI will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. • The well will be freeze protected with a non -freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil's departure. • Additionally, all BHA's will be lubricated and there is no plan to "openhole" a BHA. Disposal: • All Class I & II non -hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3. Fluids >1% hydrocarbons or flammables must go to Pad 3. Fluids >15% solids by volume must go to GNI. Hole Size: • The window and 10' of formation will be drilled with a 3.80" OD mill. Well Control: • BOP diagram is attached. • AOGCC will be given at least 24 hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. • Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and 4,000 psi. • BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. • BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. • 10 AAC 25.036 c.4.0 requires that a BOPE assembly must include "a firewall to shield accumulators and primary controls". A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: Maximum H2S reading on L-116: 250 ppm (01/25/2009). Most recent H2S sample on L-119: NA (injector). Expected L-119 H2S: 10 ppm. Reservoir Pressure: • The reservoir pressure on L -119A is expected to be 3391 psi at 6716' TVDSS (9.71 ppg equivalent). • Current parent pressure: 2993 psi at 6600' TVDSS (8.7 ppg equivalent) taken on 6/18/2019. • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2720 psi. Trevor Hyatt CC: Well File CTD Engineer Joe Lastufka 564-4627 TTM= 4-1/16"5MCIW WELLHEAD= 11 -FMC ACTl1ATOR = NA OKS. B" - 78.9 L-119 SAFETY NOTES_ 112S READINGS AVERAGE 125 ppm WHEN ON ML WELL REQUIRES A SSSV WHEN ON Ml. DATE REV BY COMAEN S DATE I RLa7 BY I COMMENTS 0411602 JLMIKK ORIGINALCOMPLEfION 11/13118 DS/JM) OACEWNTEDSLIWACETOSHOE 01/1612 TMWJM) ADDED WS SAFETY NOTE 112618 J"JMD PULLB)FXNPLUG(1124/18) 0625115 JM) ADDED 31/2" T13G WO 07126/18 JNJJM) ADDEDBF9" 07/26/18 BOMM) 0OIWECTED9-5/8"CSGD 07/30/18 CJWJMD SETFIXN PLUG (07128/18) WELL: L-119 PETIT No: s1020640 API W: 50-029-23077-00 SEC 34, T12K R11 E 2601' FSL & 17W P1NL BP Exploration (Alaska) --- ._.--- ._._._. J._._., I � i I - i I i ! choke MaN(old I � I I jcoo=i I I I � i I f=� � I I jsoume Water Tank Farm_ 1 - j i._. Coiled Tobi�Unit ,_. 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." The initial reviewer will check to ensure that the "Plug for Redrill" box G ologi t tble in the upper left corner of Form 10-403 is checked. If the "Abandon" or "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form d 0-403 (AOGCC's and operator's �6+w I l q copies). I'f"I 12 the "Abandon" box is checked in Box 15 (Well Status after proposed work) the initial reviewer will cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. The drilling engineers will serve as quality control for steps 1 and 2. 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug 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." When the Stat Tech receives any Form 10-407, they will check the 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. Geologist , $'B Drilling Engineer (QC) Stat Tech When the Form 10-407 for the redrill is received, the Stat Tech willStat Tech change the original well's status from SUSPENDED to ABANDONED. The first week of every January and July, the Stat Tech and one of theT at Tech Geologists will check the "Well by Type Work Outstanding" user queologist 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 accuracv. STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Pull Tubing ❑ Operations shutdown El Suspend ❑ Perforate ❑ Other Stimulate ❑ Aller Casing ❑ Change Approved Program Plug for Rednll ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. OA Cement Squeeze 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work Development El Exploratory [3 5. Permit to Drill Number: 202-064 3. Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stratigraphic ❑ Service (Z 1 6. API Number: 50-029-23077-00-00 7. Property Designation (Lease Number): ADL 028239 8. Well Name and Number: PBU L-119 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY. BOREALIS OIL 11. Present Well Condition Summary: Total Depth: measured 9624 feet Plugs measured 9150 feet true vertical 7197 feet Junk measured None feet Effective Depth: measured 9150 feet Packer measured 8834, 8958 feel true vertical 6743 feet Packer true vertical 6446 6562 feet Casing: Length: Size: MD: TVD: Buret: Collapse: Structural Conductor 80 20" 32-112 32-112 1490 470 Surface 2887 9-5/8" 32-2919 32-2621 5750 3090 Intermediate Production 9580 9-5/8" 28-9609 28-7183 7240 5410 Liner Perforation Depth: Measured depth: 9058-9161 feet True vertical depth: 6656-6753 feet Tubing (size, grace, measured and true vertical depth) 4-1/2" 12.6# L-80 26-8995 26-6596 4-1/2" Baker S-3 Premier Packer 8834 6446 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Packer 8958 6562 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary: Pumped 10 bats of meth and 76 tools of 140 deg F Surfactant/Musol wash down OA swap to SLB pump and pump 10 bbl mud push2, 20 bbls of neat class G cement, 50 tools class G w/15 ppb loading of aggregate, 43 bats of neat clan G cement. Slowed pump rate to min at last 10 bbls M check on OA pressure; want on slight vac. Bmught pump rate back up until positive pressure was seen and rolled aggregate until "clogging" was an at shoe. Continued until and of required cement was pumped. Intervals treated (measured): Surface -2919' Treatment descriptions including volumes used and final pressure: 10 bbls Meth, 76 bbls 140 DegF SudactantlMusol, 10 bbls Mud Push2, 63 bbls neat Class G Cement, 50 sols Class G w/15 ppb aggregate. Final Pressures: OA = 50 psi, IA = 500 psi, TBG = 1750 psi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation: 0 0 2116 400 2000 Subsequent to operation: 0 0 3022 500 1750 14. Attachments aecuirea per 20 AAC 25.70 25 m1,& 25.283) 15. Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development ❑ Service (Z 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 ❑ 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: 318,321 Authorized Name: Obrigewitch, Beau Contac Name: Obdgewitch, Beau Authonzed Title: Well Integrity Engineer Contac Email: BEAU. OBRIGEWITCHAbp.com Authorized Signature: Date:''( VV 6 I Contact Phone: .1 907 564 4854 Form ID -4D4 Revised 04/2017 �•'/OW11f MArO'RJTAi>1�V9 RRnm.g9gJAN n 3 i01G Submit Original Only T/I/O = SSV/240/0. Temp = SI. Backfill cellar and install containment (Pre OA squeeze). Backfilled cellar with gravel to 47". Installed secondary containment around conductor (below flutes). Installed inner tube around casing spool and top of conductor. 9/10/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 1605 hrs. Job Scope: Pre OA Sqz injectivity test. Pumped 2.5 bbls of diesel into OA @.5 bpm w/ SLB cementers. Pressure increased steadily from 0 to 1250 psi. At 2.5 bbls away pressure dropped to zero and sudden release into containment in cellar. SD pump. Recover returned diesel w/ vac truck (appx 2 bbls) Also noted significant amount of cement fines in returns. Pushed rod to 4.8' through flutes. No tag or hard bottom. 9/25/2018 1 '*'Job Complete' T/I/O = SSV/240/0. Temp = SI. Steam clean conductor. Cleaned out blueGoo using hot water and steam to a hard bottom @ 5 feet deep RD for the night will be back in AM to finish steaming. 10/2/2018 SV, WV, SSV = C. IA, OA = OTG. T/1/0 = SSV/240/0. Temp = SI. Steam clean conductor. Steam clean for 8 hrs to a hard bottom @ 5 feet and rinse with hot water from steam unit. Conductor looks nice and clean. 10/3/2018 SV, WV, SSV = C. IA, OA = OTG. TWO = SSV/260/0. Temp = SI. Job Scope: Conductor Top Job. Mix 38 gallons of HES product LockCem. 80% ultra fine cement @ 14.1 ppg and 20% WellLock resin. Load conductor to 6" under 10/12/2018 flutes on landing collar. Wait 72 hours to set up. Sample left on wellhead. '**Job Complete' T/I/O = SSV/220/3. Temp = SI. WHPs (post Wellock). WH temp = 88°. Sample is mostly set up. 10/14/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 21:00 T/I/O = SSV/200/3. Temp = Sl. WHPs (post conductor top job). WH temp = 22*. Sample is set hard. 10/17/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:30 T/I/O = SSV/200/4. Temp = SI. WHPs (post conductor top job). WH temp = 22'. Sample is set hard. 10/18/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:00 T/I/O = SSV/200/4. Temp = SI. WHPs (post conductor top job). WH temp = 22°. Sample is set hard. 10/19/2018 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 14:30 T/I/O = SSV/200/4. Temp = SI. WHPs (post conductor top job). WH temp = 22*. Sample is set hard. WHPs unchanged since monitor overnight. 10/20/2018 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 10:00 T/I/O = SSV/190/4. Temp = SI. WHPs. (Post Conductor top job). IAP decreased 10 psi in 2 days. Cement sample is set up hard. 10/22/2018 ISV, WV, SSV = C. MV = O. IA, OA = OTG. 01:18. T/I/O = SSV/190/4. Temp = SI. WHP's. (Post Conductor top job). No change in IAP or OAP from previous day. Cement sample is set up hard. 10/23/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 13:00. T/I/O = SSV/190/4. Temp = SI. WHPs. (Post conductor top job). NO change in IAP, OAP from previous day. Cement sample is set up hard. 10/24/2018 SV, SSV, WV = C. MV = 0. IA, OA = OTG. 12:00 T/I/O = SSV/190/5. Temp = SI. WHPs (post conductor top job). IAP unchanged, OAP increased 1 psi since 10/24/18. Cement sample is setup. 10/27/2018 1 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 14:30 SSV/190/5. Temp = Sl. WHPs (Post conductor top job). No change in the WHPs overnight. Cement sample is set up. Installed containment around OA spool for injectivity test. 10/28/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 1045 hrs. Daily Report of Well Operations PBU L-119 T/1/0= 614/180/vac. (LRS Unit 72 - Assist Special Projects: OA Injectivity, Test Post Cement Top Job) Pumped 1.46 bbls of diesel into the OA to pressure up to 1375 psi. Stop pumping when a thump was heard. OA pressure dropped to a vac in 2 minutes. - Small drip (<tquart total) from conductor side ports. No other signs of surface leaking. Continue pumping a total of 40 bbls of diesel into the OA. Slowly stepped the rate up to 3 bpm at a max pressure of 1215 psi. OAP slowly dropped to 980 psi over the last 22 bbls. - Shutdown and inspect nearbywells and outside area for leaks - none found. WFO notified of well status upon departure. SV, SSV, WV closed. WV open. IA/OA OTG. 10/29/2018 lFinal T/I/0= 613/181/20. T/I/I = SSV/180/10. Temp = SI. WHPs (Post conductor top job). Secondary containment installed around well head with inner tube installed around SH. OAP decreased 10 psi since LRS blew out OA show, 10-29-2018. Cement sample is set up. 10/30/2018 SV, WV, SSV = C. MV = 0. IA, OA = OTG. 13:30 11/12/2018 LRS unit 42 heat fluids Heat and circulated Vac truck with F103 surfactant to 180* f. RDMO. T/1/0=641/159/187. Assist SLB cement crew. Pumped 2 bbls neat meth through hardline to ensure communication Pumped 10 bbls neat meth followed by 76 bbls of 140*F surfactant down OA. Freeze protect surface lines with 1 bbl neat methanol. SwV, WV, SSV -closed, MV -open, IA-OTG. SLB cement 11/12/2018 Icrew DHD still on IDA at LRS departure. FWHP-703/224/136. SLB Fullbore Pumping Services. Job Scope: OA down squeeze placing cement from shoe to surface. MIRU LRS hot oil unit. see LRS Roll and heat surfactant/musol solvent mixture (2gal/1m) in vac unit until temp reached 180 done before SLB showed up on locatoin. SLB arrived on lotion two hours later WSR from SLB. LRS pumped 10 bbls of meth and 76 bbls of 140 deg F Surfactant/Musol wash down OA swap to SLB pump and pump 10 bbl mud push2, 20 bbls of neat class G cement, 50 bbls class G w/15 ppb .l1 11 S np loading of aggregate, 43 bbls of neat class G cement. Slowed pump rate to min at last 10 bbls to check on OA pressure; went on slight vac. Brought pump rate back up until positive pressure was seen and rolled aggregate until "clogging" was seen at shoe. Continued until end of required cement was pumped. 136 psi holding on OA and shut in casing valve ASAPump was shut down. Grease OA CSG vlave and 11/12/2018 Ileave heat in wellhouse and secure well. ***Job Complete*** TWO = SSV/210/10. Temp = SI. WHPs (post squeeze). Heater in wellhouse blowing cold air, reset to fire up burner. Cement sample set up. 11/13/2018 SV, WV, SSV = C. MV = O. IA, OA = OTG. 15:00 T/I/O = SSV/210/10. Temp = Sl. Check Heater (Post OA cement job). No change in the WHPs overnight. Heater tripped on arrival. Could not get burner to light. Rigged down an replaced heater. 11/14/2018 SV, WV, SSV = C. MV=O. IA, OA = OTG. 1130 hrs. **"WELL S/I ON ARRIVAL` (post cement job) PULLED PXN PLUG @ 8982' MD 11/24/2018 *** JOB COMPLETE / DSO NOTIFIED` TWO = 1530/270/60. Temp = 124°. WHP's (Eval SC Repair). On PWI. PO on location putting well B01. 11/25/2018 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 14:00 T/I/O = 1530/250/50. Temp = 124*. WHPs level SC repair). Temporary containment and inner tube installed around conductor. 11/27/2018 SV = C. WV, SSV, MV = O. IA, OA = OTG. 21:00 T/I/O = 1660/270/60. Temp = 124°. WHPs level SC repair). Temporary containment and inner tube installed around conductor. TP increased 130 psi, IAP increased 20 psi, OAP increased 10 psi overnight. 11/28/2018 ISV = C. WV, SSV, MV = O. IA, OA = OTG. 21:00 T/I/O = 1600/240/50. Temp = 125*. WHPs (eval SC repair). On PWI. Temporary containment and inner tube installed around conductor. TP decreased 60 psi, IAP decreased 30 psi, OAP decreased 10 psi since 11/28/18. 11/30/2018 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 01:30 T/1/0 = 1720/320/80. Temp = 125*. WHPs level SC repair). On PWI. Temporary containment and inner tube installed around conductor. TP increased 120 psi, IAP increased 80 psi, OAP increased 30 psi since 11/30/18. 12/1/2018 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 14:30 Daily Report of Well Operations PBU L-119 TWO = 1720/440/60. Temp = 125. WHPs (eval SC repair). Temporary containment and inner tube installed around conductor. TP unchanged, IAP increased 120 psi, OAP decreased 20 psi from 12/1/18. SV = C. WV, SSV, MV = O. IA, OA = OTG. 14:30 12/3/2018 T/I/O = 1720/440/50. Temp = 125*. WHPs level SC repair). On PWI. Temporary containment and inner tube installed around conductor. TP, & IAP unchanged. OAP decreased 10 psi overnight 12/5/2018 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 05:30 T/I/O = 1670/460/40. Temp = 126°. WHPs level SC repair). On PWI. Temporary containment and inner tube installed around conductor. TP decreased 50 psi, IAP increased 20 psi. OAP decreased 10 psi ISV overnight 12/6/2018 = C. WV, SSV, MV = 0. IA, OA = OTG. 14:00. TWO = 1700/270/30. Temp = 126°. WHPs level SC repair). On PWI. TP increased 30 psi, IAP decreased 190 psi. OAP decreased 10 psi from 12/6/18. 12/8/2018 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 10:00. T/I/O = 1700/160/30. Temp = 126°. WHPs (eval SC repair). Temporary containment and inner tube installed around conductor. TP unchanged, IAP decreased 110 psi. OAP unchanged overnight. 12/9/2018 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 22:00 TWO = 1650/190/40. Temp = 126°. WHPs (eval SC repair). On PWI. Temporary containment and inner tube installed around conductor. TP decreased 50 psi, IAP increased 30 psi, & OAP increased 10 psi since 12/09/2018. 12/11/2018 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 20:00 TWO = 1710/210/40. Temp = 126°. WHPs (Eval SC repair). On PWI. Temporary containment and inner tube installed around conductor. TP increased 60 psi, IAP increased 20 psi & OAP unchanged since monitor overnight. 12/12/2018 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 11:40 T/I/O = 1630/170/40. Temp = 126°. WHPs (eval SC repair). On PWI. Temporary containment and inner tube installed around conductor. TP decreased 80 psi, IAP decreased 40 psi, and OAP unchanged overnight. 12/13/2018 ISV = C. WV, SSV, MV = 0. IA, OA = OTG. 14:00 T/I/O = 1650/210/50. Temp = 126*. WHPs (Eval SC repair). On PWI. Temporary containment and inner tube installed around conductor. TP increased 20 psi, IAP increased 60 psi, and the OAP increased 10 psi overnight. 12/14/2018 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 13:20. T/I/O = 1600/120/40. Temp = 126*. WHPs (Eval SC repair). On PWI. OA cemented to surface. Temporary containment installed around conductor. TP decreased 50 psi, IAP decreased 90 psi, OAP decreased 10 psi since 12/14/18. Pulled inner tube from around conductor. 12/15/2018 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 13:00. T/I/O = 1650/130/40. Temp = 126*. WHPs (Eval SC repair). On PWI. TP increased 50 psi, IAP increased 10 psi overnight. 12/16/2018 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 09:45. TWO = 1570/260/60. Temp = 126°. WHPs (Eval SC repair). On PWI. TP decreased 80 psi, IAP increased 130 psi, OAP increased 20 psi overnight. Measured depth to solid bottom in conductor = 16" from conductor lip with 7" of standing fluid present in conductor void. 12/17/2018 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 10:20. T/I/O = 1700/460/30. Temp = 126* WHPs (Eval SC repair). On PWI. TP increased 130 psi, IAP increased 200 psi and the OAP decreased 30 psi overnight. 12/18/2018 SV = C. WV, SSV, MV = 0. IA, OA = OTG. 14:30. T/I/O = 1210/40/10. Temp = SI. WHPs (Eval SC repair). Well shut in and freeze protected. TBG FL @ surface, IA FL @ near surface, OA FL @ near surface. TP decreased 490 psi, IAP decreased 420 psi and the OAP decreased 20 psi overnight. No LEL's in conductor/flutes taken 1' above flutes. Secondary containment still installed on well. No visible leaks noted at this time in cellar. 12/19/2018 ISV = C. WV, SSV, MV = 0. IA, OA = OTG. 14:00 TREE=" 41/16'5MCIW V1B_LFEAD= 1l'FMC ACTUATOR= WA OKB. ELEV = 78.9 L-119 SAFETY NOTES: 112S READINGS AVERAGE 125 ppm WHEN ON MI. WELL REQUIRES A SSSV WHEN ON ML DATE REV BY COWAHM DATE REV BY I COMMENTS 04116102 JLM1W ORIGRNALCOMPL90N 11/13/18 DS/JMD OACRENTEDSLWACETOSNOE 01118112 TMWJMD ADDED 112S SAFETY NOTE 11/26/18 JMG/JMD RAim FxNpLUG(1124/18) 06/25/15 JMD ADDED 3-12' TBG W-0 07/26/18 JNUJMD ADDED BF AEV 0726/18 DOWD CORRECT® 9-518" CSG D 07!30/18 CJWJMD SET PXN PLUG (0728118) T.70 WELL: L-119 PBRNIT No: `2020640 AH No: 50.029-23077-00 SEC 34, T12K R11E 2601' FSL 8 1706' FWL 8P Exploration (Alaska) Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Wednesday, December 19, 2018 9:05 AM To: AK, GWO Well Integrity Engineer, AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad LV; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS Pipeline Compl Specialist; AKOpsProdEOCTL, Draughon, Austin; Duong, Lea; Nottingham, Derek; Peru, Cale; Thompson, Ryan; Wellman, Julie; Youngmun, Alex; Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity, AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity, AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; AK, GWO Well Integrity Well Information; Regg, James B (DOA) Subject: OPERABLE: Injector L-119 (PTD# 2020640) Surface casing leak repaired with remedial OA down squeeze All, Injector L-119 (PTD# 2020640) was made under evaluation on 11/24/18 to assess a surface casing leak post remedial OA downsqueeze. The well was brought online 11/25/18 and has shown no signs of OA repressurization or a surface casing leak during the 25 day injection period indicating a successful repair. At this time the well is reclassified as Operable. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCANW JAN 0 3 2019 From: AK, GWO Well Integrity Engineer Sent: Saturday, November 24, 2018 1:09 PM To: AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; Ak, OPS GC2 Facility PTL <AKOPSGC2FacilityOTL@bp.com>; Ak, OPS GC2 Field PTL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2Wellpad Lead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad DFT N2 <AKOPSWellPadDFTN2@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRESGPBEastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AK, OPS Pipeline Compl Specialist <AKOPSPipelineComplSpecialist@bp.com>; AKOpsProdEOCTL <AKOPSPCCEOCTL@bp.com>; Draughon, Austin Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, November 24, 2018 1:09 PM To: AK, OPS EOC Specialists; Ak, OPS GC2 Facility PTL; Ak, OPS GC2 Field PTL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad DFT N2; AK, OPS Well Pad LV; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AK, OPS Pipeline Compl Specialist; AKOpsProdEOCTL; Draughon, Austin; Duong, Lea; Nottingham, Derek; Peru, Cale; Thompson, Ryan; Wellman, Julie; Youngmun, Alex; Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity, AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis 1; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; Regg, James B (DOA) Subject: UNDER EVALUATION: Injector L-119 (PTD# 2020640) Surface casing leak repaired with remedial OA down squeeze All, Injector L-119 (PTD# 2020640) was made not operable on 7/31/2018 for having a confirmed surface casing leak. On 11/12/2018 fullbore performed a remedial OA downsqueeze under AOGCC sundry #318-321. The well is now ready to be brought online so and is hereby reclassified as Under Evaluation. DHD will monitor the well daily to evaluate the success of the repair. Please respond with any questions, Joshua Stephens $CANKV A i Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 wo. Fromm• K, GWO Well Integrity Engineer Sent: Tues a , 31, 2018 10:21 AM To: AK, GWO Well Integra ineer <AKGWOWellSiteEnginee@bp.com>; AK, OPS EOC Specialists <AKOPSEOCSpecialists@bp.com>; S GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPS GC2 Field O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, 0 2 OS <AKOPSGC20SM@bp.com>; AK, OPS GC2 Wellpad Lead <AKOPSGC2Wellpad Lead @bp.com>; AK, OPS PCC Opstead<AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsprodcontrollersl@bp.com>; AK, OPS Well Pad LV <AK0 IIPadLV@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@bp.com>; AK, RES GPB East Wells Opt Engr <AKRE EastWellsOptEngr@bp.com>; AK, RES GPB West Wells Opt Engr <AKRESGPBWestWellsOpt2@bp.com>; AKO psP rod EOCTI ZAXWSPCCEOCTL@bp.com>; Frankenburg, Amy <Amy.Fra nkenburg@bp.com>; Peru, Cale <Cale.Peru@bp.com>; Rupe Ryan <Ryan.Rupert@BP.com>; Youngmun, Alex <younak@BP.com>; 'ch ris.waIlace @alaska.gov' <chris. lace@alaska.gov> Cc: AK, GWO Completions Well Integrity <AKDCWLCompletionsSupt@bp.com>; AK, GWO DHD Well Inte <AKD&CDHDWelllntegri@bp.com>; AK, GWO Projects Well Integrity<AKDCProjectsWelllntegrityEngineer@bp. >; AK, GWO SUPT Well Integrity <AKDCWelllntegrityCoordinator@bp.com>; AK, OPS FF Well Ops Comp Rep i THE sn* TT�C1 OJALASI� GOVERNOR BILL WALKER Beau Obrigewitch Well Integrity Engineer BP Exploration (Alaska), Inc. P -O Box 196612 Anchorage, AK 99519-6612 • Alaska Gil and Gas Conservation Commission SGANNM AUG 15 2018 Re: Prudhoe Bay Field, Borealis Oil Pool, PBU L-119 Permit to Drill Number: 202-064 Sundry Number: 318-321 Dear Mr. Obrigewitch: 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 www.aogcc.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, Hollis S. French Chair DATED this 1� day of August, 2018. r1BDM9��'p�6 0 9 2018 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COM ION APPLICATION FOR SUNDRY APPRS 20 AAC 25.280 ORIGINAL BDMS�_Inub 0 9 Zoo Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. ��3i ttach ent Duplicate 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ era '98M Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change Plug for Redrill ❑ Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other OA Cement Squeeze 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: Exploratory ❑ Development ❑ 5. Permit to Drill Number: 202-064 3. Address: P.O. Box 196612 Anchorage, AK 6. API Number: 50-029-23077-00-00 - 99519-6612 Stratigraphic ❑ Service 0• 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 L-119 9. Property Designation (Lease Number): 1 10. Field/Pools: ADL 0028239 PRUDHOE BAY, BOREALIS OIL / - -3; 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): 9624 7197 9150 6743 9150 None Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 32-112 32-112 1490 470 Surface 2887 9-5/8" 32-2919 32-2621 5750 3090 Intermediate Production 9580 7 28-9609 28-7183 7240 5410 Liner Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9058 - 9161 6656-6753 4-1/7' 12.6# L-80 26-8995 Packers and SSSV Type: 4-1/2" Baker S-3 Prem Packer Packers and SSSV MD (ft) and TVD (ft): 8834/6446 4-1/2" Baker S-3 Packer 8958/6562 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development ❑ Service 0 14. Estimated Date for Commencing Operations: Auqust 5, 2018 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended ❑ 16. Verbal Approval: Date: GAS ❑ WAG 0 GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. 1 hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Obrigewitch, Beau be deviated from without prior written approval. Contact Email: BEAU.OBRIGEWITCH@bp.com Authorized Name: Obrigewitch, Beau Contact Phone: +1 907 564 4854 Authorized Title: Well Integrity Engineer Authorized Signature: Date: 'V -Z COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number318-32[ 18'L {I n �f / C�Ji Plug Integrity ❑ BOP Test 11 Mechanical Integrity Test ❑ Location Clearance ❑ Other: Post Initial Injection MIT Req'd? Yes ❑ No IJ Spacing Exception Required? Yes [I No M Subsequent Form Required: APPROVED BYTHE I Approved by: - COMMISSIONER COMMISSION Date:�� (� ORIGINAL BDMS�_Inub 0 9 Zoo Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. ��3i ttach ent Duplicate by • • L-119 OA Cement Squeeze Well Interventions Engineer: Beau Obrigewitch (907) 564-4854 Pad Engineer: Joleen Oshiro (907) 564-4606 History As part of CST Screening work on 07/06/2018, an MIT -OA failed with fluid to surface and Blue Goo coming out of the conductor. Follow up work on 07/08/2018 confirmed a shallow Surface Casing leak to surface. Current Status The well is currently classified as Not Operable by BP due to the confirmed Surface Casing leak and secured with a mechanical plug in the tubing. Objective In order to return this well to Operable and continue with the planned Coiled Tubing Drilling sidetrack, the OA will be downsqueezed to repair the Surface Casing leak. If the leak is not repaired by downsqueezing, or if the downsqueeze cannot successfully be placed (insufficient injectivity), further work to repair the Surface Casing leak will be initiated. Job Stens 1 D OA fluid level 2 F OA Injectivity Test 3 J Cement OA 4 O POI Under Eval 5 D Monitor OA 6 VP Drop OA gate valve and install integral 7 JP Top Job OA Squeeze 8 VP Drop OA integral and install OA gate valve Procedural steps DHD 1. Shoot fluid level on OA to determine fill -up volume for fullbore injectivity test. Fullbore 2. Establish injectivity rate and pressure with diesel or crude down the OA and into formation. Max OA pressure 2500 psi. Note: During an MIT -OA attempt on 7/6/18, and during a subsequent Leak Depth Determination on 7/8/18, fluid was returned to surface through the Surface Casing leak. Ensure a vac truck is on location and spotted to take returns from the conductor and/or cellar prior to pumping the injectivity test. Fullbore/Special Projects 3. RU Cementers to the OA. RU in such a way that the OA can be closed in and wash up water diverted upstream of the OA. Mix cement on the fly (or batch mix at WSL discretion). Pump the following schedule at maximum rate below 2500 psi treating pressure. 10-bbls of 60/40 or 10 bbls neat MEOH 80 bbls hot surfactant wash (180 °F freshwater + 2 gal/mgal F103 and 2 gal/mgal UO67) ➢ 10 bbls of 13.5 ppg MUDPUSH II Spacer ➢ 20 bbls of neat cement ➢ 50 bbls of cement with 15 -ppb aggregate ➢ 43 bbls of neat cement Note: During an MIT -OA attempt on 7/6/18, and during a subsequent Leak Depth Determination on 7/8/18, fluid was returned to surface through the Surface Casing leak. Ensure a vac truck is on location with the appropriate cement contamination pill and spotted to take returns from the conductor and/or cellar prior to pumping the cement job. The injectivity test may provide an estimate of the volume of fluids that may be returned. 4. No displacement behind cement. Slow rate to -1 of cement away/10 bbls left to pump). Swap tc cement (S/D pumping as needed), and as the bpm as aggregate gets to the casing shoe (-103 bbls take returns from upstream of the OA while still on last couple of barrels are pumped (3-5 bbls left to pump). Ensure that returns are swapped to taking cement returns to surface before the last of the cement is pumped downhole to ensure only cement goes down the OA. SI the OA and flush lines through a different route than down the OA. Note that the OA may be on a vacuum and may suck any wash water that is pumped across the OA down into the OA if allowed to do so. Note: Good success on OA downsqueezes has been realized by the hesitation squeeze method; i.e. shutting down pump entirely as the last -10 bbls of cement are pumped, watching to see if pressure is maintained or drops right off then pumping a couple more barrels until catching fluid and repeating this to give the aggregate every opportunity to bridge off either in the OA or at the shoe. See WSRs from X-34, Y-39, and L1-13 for reference. 5. After washing up surface lines, hold open bleed on OA for 1 hour, sniff for LEL's, remove OA gate valve and manually clean any residual cement from the valve and VR profile. (See MOC #10083 for specific deviation details allowing for this operation). Cement Calculations - Fullbore OA Downsqueeze 9-5/8" x 7" volume from 2,919' MD to surface (0.0282 bpD 83 bbls Total Cement to Pump (10 bbl excess) 113 bbls Cement Type / Weight Class G 15.8 ppg mixed on the fly Field blend to by equal to lab +/- 0.1 ppg Slurry Temperature 80° to 110° F Fluid Loss 40-200cc 20-100 cc / 30 min Compressive Strength 2000 psi in 48 hrs Thickening Time Minimum 4 hours Cement thickening time: Mix on the fl Activit Time hours) Shearing time, quality control, PJSM 0 Cement displacement 2 Cement contamination 0 Safety 2 • Minimum required thickening time: I 4 Cement Ramp for Blend Time Volume Pumped bbls Temperature °F(psi) Pressure 0.00 0 100 0 0:30 113 90 1000 1:00 113 80 2150 2:00 113 70 2150 3:00 113 60 2150 4:00 113 50 2150 Operations 6. POI Under Evaluation DHD 7. Monitor for fluid to surface The following steps to remain on pending until end of monitor period Valve Shop 8. Drop OA gate valve and install integral Special Projects 9. Top -off OA with Squeeze of either Microfine Cement or Well Lock (at WSL discretion, after discussion with Well Integrity Engineer). Follow appropriate RP: "Small Volume Cement Squeeze" or "Well Lock Treatment for Cemented OAs". Detailed steps can be added to this program as needed. Note: Ensure that Halliburton formulates the Well Lock to allow as long of curing time as reasonable. In a recent job the Well Lock at surface cured too quickly and the job had to be cut short as a result. Plan to keep squeezing for -12 hours to get as much Well Lock into the OA as possible. Note: Mix Well Lock batches in quantities no larger than -1 gallon to minimize the volume of Well Lock that needs to be disposed of. 10. Prep OA, Fill and squeeze the remaining void in the OA. Squeeze to 2500 psi per appropriate RP. Note: The following are the well -specific equipment ratings that support squeezing to 2500 psi. a. Burst of 9-5/8" 40# L-80: 5,750 psi, 80% is 4,600 psi b. Collapse of 7" 26# L-80: 5,410 psi, 80% is 4,328 psi Valve Shop 11. After 2 -week cure, ND OA Integrals, NU OA gate valves. 3 rrent WBS: TFdT- = 4-1116'5MCW VALLHEAD= 11* F%C ACTUATOR = WA OKB. FLFV = 78 9' Br ELry 4 KOP= S Kbx Angke = 58" Q 5502" Dahen W = 9082' DatLsn TVD = 6St%3' SS 21"l Minimum ID = 3.725" @ 89824 4-112" HES XN LANDING NIPPLE FIEF LOG: SMCENSITY443ARONOT2702 ANGLEATTOPPEW. 26'@8850' Note: Hafer to Pfoduction C6 for tntarical Dorf data SIZE SFF t(MRVAL Cpni$qz SICT SQZ 4,112" 4 885(3 - 8852 S 0411= WlTi� 4112" 4 8047-8949 s 0412102 04113M 3-16" 6 WW - 9084 0 0509M I DKVY 3-31W 6 9092-9106 0 05107/02 6373 4-V2* 5 1 9160 - 9161 1 C 1 04t10102 1 1 1 I PBTD alro-MOD, 9) - 8,21W SAFETY NOTES: H2S READINGS AVERAGE 126 ppm L-1 19 WHE14 ON Mi. WELL REQUIRES A SSSV WHEN ON UL —T 9-51W TAM PORT OOLLAR Zrl —11-1 5w ST MD TVD DEV TYPE VLV LATCH i fX)RT DAM 3 4460 54 - KBG-2 JAY BK 5 00720102 07/201 2 7445 13487 5303 43 � KBG-2 I DKVY BK -5 0 � 0712=2 _1 _8754 6373 24 KJrv-2 OW 8K-5 0 0712=2 14-1t2" X LAMM HP. C.1= 1813* 1 881d' 7" MARIdBt JT 1'1B Fb4 TAC, $958' Hrx4-112"sm 15 8971' F442• X LAP"C —W. 1) = 3 813" m4q 8996' 1--i4-112'WLECD73.950 F78v (04113=) 80FEAJ5 L"T VVEL: L-119 FFRW Pb- %20CAO AFIND: 50-029-2307I-00 SET;" 34, Y12hk RI IE, MT FSL & 1706- t M HP Explorshon (ALaka) 4 MIMA1,09ill F78v (04113=) 80FEAJ5 L"T VVEL: L-119 FFRW Pb- %20CAO AFIND: 50-029-2307I-00 SET;" 34, Y12hk RI IE, MT FSL & 1706- t M HP Explorshon (ALaka) 4 TREE = 4-1/16" 5M CNV WELLHEAD = 11" FMC ACTUATOR = N/A OKB. ELEV = 78.9' BF- ELEV = 50.54' KOP SQZ Max Angle = _._---__-___---9082' 58" @ 5502' Datum MD = S Datum TV D = 6600' SS 9-5/8" CSG, 40#, L-80, ID = 8.681" 2919 Minimum ID = 3.725" @ 8982' — 4-1/2" HES XN LANDING NIPPLE 14-1/2" TBG, 12.6#, L-80 TC11, .0152 bpf, D = 3.958" I PERFORATION SUMMARY REF LOG: SWS DENSITY/NEUTRON 03/27/02 ANGLE AT TOP PERF: 26" @ 8850' Note: Refer to Production DB for historical pert data SEE SPF INTERVAL Opn/Sgz SHOT SQZ 4-1/2" 4 8850-8852 S 04/12/02 04/13/02 4-1/2" 4 8947-8949 S 04/12/02 04/13/02 3-3/8" 6 9058-9084 O 05/09/02 1 3-3/8" 6 9092-9106 O 05/07/02 BK -5 4-1/2" 5 9160-9161 C 04/10/02 PBTD —j 9556' 7" CSG, 26#, L-80, BTC -MOD, ID = 6-276" 9609' GE 125 ppm L-1 19 `M1. WELL REQUIRES A SSSSV WHEN ON TAM PORT COLLAR 2287' 4-1/2" X LANDING NIP, ID = 3-813" GAS LIFT MANDRELS ST MD TV D DEV TY PE V LV LATCH PORT DATE 3 4460 3487 54 KBG-2 DMY BK -5 0 07/20/02 2 7445 5303 43 KBG-2 DMY BK -5 0 07/20/02 1 8754 6373 24 KBG-2 DMY BK -5 0 07/20/02 8823' —'4-1/2" X LANDING NIP, ID = 3.813" DATE REV BY COMMENTS 04/16/02 JLM/KK ORIGINAL COMPLETION 01/18/12 TMN/JMD ADDED H2S SAFETY NOTE 8834' 7" X 4-1/2" BKR PREMIER PKR, ID = 06/25/15 JMD ADDED 3-1/2" TBG INFO 06/20/02 JWM GLV UPDATE 07/26/18 JNL/JMD ADDED BF ELEV 891 7" MARKER JT W/ RA TAG X 4-1/2" BKR S-3 PKR, ID = 3.875" 1/2" X LANDING NIP, ID = 3.813" I 8982' 1—{4-1/2" HES XN LANDING NIP, ID= 8995' 1-14-1/2" WLEG, ID = 3.958" 9150' 1-1EZSV (04/13/02) 9384' H7- MARKER JT W/ RA DATE REV BY COMMENTS DATE REV BY COMMENTS 04/16/02 JLM/KK ORIGINAL COMPLETION 01/18/12 TMN/JMD ADDED H2S SAFETY NOTE 5/7-9/02 CVVS/KK ADPERFS 06/25/15 JMD ADDED 3-1/2" TBG INFO 06/20/02 JWM GLV UPDATE 07/26/18 JNL/JMD ADDED BF ELEV 07/20/02 JB/tIh GLV UPDATE 104/08/031 DRS/TP TV D/MD CORRECTIONS 102/15/111 MB/JMD JADDEDSSSV SAFETY NOTE BOREALIS UNIT WELL: L-119 PERMIT No: 2020640 API No: 50-029-23077-00 SEC 34, T12N, R11 E, 2601' FSL & 1706' FVVL BP Exploration (Alaska) Loepp, Victoria T (DOA) From: Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com> Sent: Tuesday, August 07, 201812:17 PM To: Loepp, Victoria T (DOA) Subject: RE: PBU L-119(PTD 202-064, Sundry 318-321) OA Cement Squeeze Victoria, Regarding the repair options we have available, OA downsqueeze has proven to be a successful repair option many times in the recent past. While we have pursued the excavation route on some of our wells to repair Surface Casing leaks, our preference is to do that on wells that we cannot downsqueeze. Cementing the OA also brings the well closer to compliance with the P&A this well will undergo at some point in the future. Please let me know if I may be of further assistance. Kind regards, Beau From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Tuesday, August 7, 2018 9:49 AM To: Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com> Subject: RE: PBU L-119(PTD 202-064, Sundry 318-321) OA Cement Squeeze Beau, Did you consider excavation, cutting windows and patching? Victoria From: Obrigewitch, Beau <BEAU,OBRIGEWITCH@bp.com> Sent: Monday, August 06, 2018 7:47 AM To: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Subject: RE: PBU L-119(PTD 202-064, Sundry 318-321) OA Cement Squeeze Victoria, 1. The drilling records indicate the surface casing shoe is not cemented. Our desire is to confirm OA injectivity prior to attempting to pump cement. 2. The Surface Casing leak depth is estimated to be 102" below the OA casing valve. 3. The plug is set in the nipple at 8,982. Please let me know if you need further information. Regards, Beau • From: Loepp, Victoria T (DOA) <victoria.loepp@alaska.gov> Sent: Friday, August 3, 2018 2:57 PM To: Obrigewitch, Beau <BEAU.OBRIGEWITCH@bp.com> Subject: PBU L-119(PTD 202-064, Sundry 318-321) OA Cement Squeeze Beau, 1. Is there a cemented surface casing shoe in this well? 2. Do you know the depth of the surface casing leak? 3. Where is the mechanical plug set in the tubing(not on schematic)? Thanx, Victoria Victoria Loepp Senior Petroleum Engineer State of Alaska Oil & Gas Conservation Commission 333 W. 7th Ave Anchorage, AK 99501 Work: (907)793-1247 Victoria. LoeppOalaska.gov • CONFIDEMIALIIY NOTICE: This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information. The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it, without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Victoria Loepp at (907)793-1247 or Victoria.Loepp@alaska.aov Wallace, Chris D (DOA) From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Tuesday, July 31, 2018 10:21 AM To: AK, GWO Well Integrity Engineer, AK, OPS EOC Specialists; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad LV; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Frankenburg, Amy; Peru, Cale; Rupert, C. Ryan; Youngmun, Alex; Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity, AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity, AK, OPS FF Well Ops Comp Rep; AKIMS App User; Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; Regg, James B (DOA); AK, GWO Well Integrity Well Information Subject: NOT OPERABLE: Injector L-119 (PTD# 2020640) Confirmed surface casing leak, well secured with TTP All, Injector L-119 (PTD# 2020640) was made under evaluation on 7/7/2018 for having bubbling in the cellar during a failed MIT -OA. On 07/08/18 DHD confirmed a surface casing leak at 102" below the casing valve. Slickline secured the well with a tubing tail plug on 7/28/18 and the well passed a CMIT-TxIA to 2361psi on 7/29/18. At this time the well is reclassified as Not Operable and will remain shut in and secured. The production engineer will evaluate for a repair plan forward. Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 From: AK, GWO WeItfategrity Engineer SE00% ,AUG 0 3,1101b Sent: Saturday, July 7, 2018 . AM To: AK, OPS EOC Specialists <AKOPStOGSPecialists@bp.com>; AK, OPS GC2 Facility OTL <AKOPSGC2FacilityOTL@bp.com>; AK, OPS G d O&M TL <AKOPSGC2FieldOMTL1@bp.com>; AK, OPS GC2 OSM <AKOPSGC20SM@bp.com>; AK, OPS GC2 Wellpad Lea PSGC2WeIIpadLead@bp.com>; AK, OPS PCC Ops Lead <AKOPSPCCOpsLead@bp.com>; AK, OPS Prod Controllers <akopsp ntrollersl@bp.com>; AK, OPS Well Pad LV <AKOPSWellPadLV@bp.com>; Ak, Ops West Area TL <AkOpsWestAreaTL@ >; AK, RES GPB East Wells Opt Engr • Wallace, Chris D (DOA) � aoa- oc-0y From: AK, GWO Well Integrity Engineer <AKGWOWellSiteEnginee@bp.com> Sent: Saturday, July 7, 2018 7:26 AM To: AK, OPS EOC Specialists; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 OSM; AK, OPS GC2 Wellpad Lead; AK, OPS PCC Ops Lead; AK, OPS Prod Controllers; AK, OPS Well Pad LV; Ak, Ops West Area TL; AK, RES GPB East Wells Opt Engr; AK, RES GPB West Wells Opt Engr; AKOpsProdEOCTL; Frankenburg, Amy; Peru, Cale; Rupert, C. Ryan; Youngmun, Alex; Wallace, Chris D (DOA) Cc: AK, GWO Completions Well Integrity; AK, GWO DHD Well Integrity; AK, GWO Projects Well Integrity; AK, GWO SUPT Well Integrity; AK, GWO Well Integrity Well Information; AK, OPS FF Well Ops Comp Rep; AKIMS App User, Cismoski, Doug A; Daniel, Ryan; Dempsey, David G; Dickerman, Eric; Hibbert, Michael; Janowski, Carrie; Montgomery, Travis J; Munk, Corey; Obrigewitch, Beau; O'connor, Katherine; Romo, Louis A; Sternicki, Oliver R; Tempel, Joshua; Worthington, Aras J; Regg, James B (DOA) Subject: UNDER EVALUATION: Injector L-119 (PTD# 2020640) Anomalous bubbling in the cellar during MIT -OA Attachments: L-119.pdf All, Injector L-119 (PTD# 2020640) was reported to have bubbling in the cellar during a failed drilling screen MIT -OA on 7/6/2018. The bubbling is indication of a potential surface casing leak. At this time the well is reclassified as Under Evaluation and is on the 28 day clock for diagnostics and repair. Plan forward: 1. DHD — OA integrity test 2. Well Integrity Engineer—Additional diagnostics as needed Please respond with any questions, Joshua Stephens Well Integrity Engineer Office: 907-659-8110 Cell: 907-341-9068 SCAtAIJEa JUL 19 10118 MEMORANDUM • TO: Jim Regg P.I. Supervisor FROM: Jeff Jones Petroleum Inspector NON -CONFIDENTIAL • State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 05, 2018 SUBJECT: Mechanical Integrity Tests BP EXPLORATION (ALASKA) INC. L-119 PRUDHOE BAY UN BORE L-119 Src: Inspector Reviewed By: P.I. Supry Comm Well Name PRUDHOE BAY UN BORE L-119 API Well Number 50-029-23077-00-00 Inspector Name: Jeff Jones Permit Number: 202-064-0 Inspection Date: 6/9/2018 . Insp Num: mi[JJ180703140218 Rel Insp Num: Packer Depth - _- - - Well L-119 Type Inj JTVD 6562 PTD 2020640 .1 Type Test SPT Test psi 1 1640 BBL Pumped: 2BBL Returned: i 2 Interval 4YRTST P/F P Notes: 1 well inspected, no exceptions noted. Pretest Initial 15 Min 30 Min 45 Min 60 Min Tubing 1997 1995 1998 1998 IA 261 2753 2711 2704- O,k 109 205 204 - 203 " SCANNED AUG U 9tu� Thursday, July 05, 2018 Page 1 of 1 Image . )oject Well History File Cover F. ;,e XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Well History File Identifier Organizing (oow,�) ❑ Two -Sided Rescan Needed RESCAN DIG TAL DATA OVERSIZED (Scannable) ❑ Color items: Diskettes, No. ❑ Maps: Grayscale items: ❑ ❑ Poor Quality Originals: ❑ Other: NOTES: BY: BEVERLY ROBIN VINCENT SI Project Proofing Other, No/Type ❑ Other items scannable by large scanner OVERSIZED (Non -Scannable) ❑ Logs of various kinds ❑ Other MARIA WINDY DATE:. I BY: BEVERLY ROBIN VINCENT SHERY MARIA INDY Scanning Preparation x 30 = + BY: BEVERLY ROBIN VINCENT SHER MARIA INDY f DATE: .�.�i( 0/ ` TOTAL PAGES ,I DATE:6146�lsl MP Production Scanning Stage 1 PAGE COUNT FROM SCANNED FILE: LJck�J�� ad v PAGE COUNT MATCHES NUMBER IN SCANNING PREPARATION V YES NO BY: BEVERLY ROBIN VINCENT SHERYL ARIA WINDY DATE: 11 0AP�/ Stage 2 IF NO IN STAGE 1, PAGE(S) DISCREPANCIES WERE FOUND: YES NO BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /S/ (SCANNING IS COMPLETE AT THIS POINT UNLESS SPECIAL ATTENTION IS REQUIRED ON AN INDIVIDUAL PAGE BASIS DUE TO QUALITY, GRAYSCALE OR COLOR IMAGES) ReScanned (l11f/Il �(!t':)1 /)1{J l ;f? ;J,TJ vt)�r)tiCltl� .S r, r)!111tCJ i:Ol11r)!t`;t?d� RESCANNED BY: BEVERLY ROBIN VINCENT SHERYL MARIA WINDY DATE: /s/ General Notes or Comments about this file: Quality Checked i(in lc) 12110102Rev3N0TScanned.wpd MEMORANDUM TO: Jim Reggl}- P.I. Supervisor FROM: Lou Grimaldi Petroleum Inspector State of Alaska Alaska Oil and Gas Conservation Commission DATE: Thursday, July 17, 2014 SUBJECT: Mechanical Integrity Tests BP EXPLORATION(ALASKA)INC L -I 19 PRUDHOE BAY UN BORE L -I 19 Src: Inspector Reviewed By: P.I. Supry XZ— NON-CONFIDENTIAL — NON -CONFIDENTIAL Comm Well Name PRUDHOE BAY UN BORE L-119 API Well Number 50-029-23077-00-00 Inspector Name: Lou Grimaldi Permit Number: 202-064-0 Inspection Date: 6/7/2014 Insp Num: mitLG140607173936 Rel Insp Num: Packer Depth Pretest Initial 15 Min 30 Min 45 Min 60 Min ell — La 19 Type Inj I W TVD 6562 IA 773 2495 2461 - 2453 TD 2020640 Type Test SPT Test psi 1640 OA 138 280 272 263 . Interval 4YRTST P/F P Tubing 1647 1647 164s 1644 - — Notes' 1.2 bbl's MeoH pumped 2.0 bbl's returned, IA pressure bled below pretest pressure. Good test, all supporting documentation on hand. mak) `� t.t�A s� C tt,, SCA%j4FQ OCT $ 7 2014. Thursday, July 17, 2014 Page I of 1 4.000 3,000 2000 i i 1.000 Well: L -lis 03101{14 03108114 03W14 =14 032" 04106,14 OV12/14 "IW14 04x&14 06103/14 W10114 06111114 W24114 05131,14 t Tbg —A-- OA GOA • OOOA Dry TREE = 4-1/16" 5M CNV WELLHEAD = 11" FMC ACTUATOR = WA KB ELEV = 78 9' BF ELEV = Opn/Sqz KOP = 948' Max Angle = 58'@ 5502' Datum MD = 9082' Datum TVD = 1 6600'SSI 9.5!8" CSG, 40U, L-80, ID = 8 681" 1-1 2919' Minimum ID = 3.725" @ 8982' 4-112" HES XN LANDING NIPPLE PERFORATION SUMMARY REF LOG SWS DENSITY /NEUTRON 03127/02 ANGLEAT TOP PERF 26'@8850' Note Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 4.1/2' 4 8850.8852 S 04/13102 4-1/2' 4 8947- 8949 S 04/13/02 3-3/8' 6 9058-9084 O 05109/02 3-3/8" 6 9092-9106 O 05/07/02 4-1/7' 5 9160-9161 S 04/13/02 PBTD 7" CSG, 26A, L-80, BTC -MOD, ID = 6 276" 9556' 9609' L-119 SAFETY NOTES: H2S READINGS AVERAGE 125 ppm WHEN ON MI. WELL REQUIRES A SSSV WHEN ON MI - 1014' 9-5/8" TAM PORT COLLA R 2287' 4-112" X LANDING NIP, ID = 3 813' GAS LIFT MANDRELS ST ND TVD DEV TYPE VLV LATCH PORT DATE 3 4460 3487 54 KBG-2 DMY BK -5 0 07!20!02 2 7445 5303 43 KBG-2 DMY BK -5 0 07/20/02 1 8754 6373 24 KBG-2 DMY BK -5 0 07/20/02 4.112" X LANDING NIP, ID = 3 813" 7" X 4-112" BKR PREMIER PKR, ID = 7" MARKER JT W/ RA TAG 7" X 4-1 8971' 1--i4-1/7' X LANDING NIP, ID = 14-112" HES XN LANDING NIP. ID= 3.725" 1 8995' 1--14-1/2" WLEG, D = 3.958" 9150' 1—JEZSV (04/13102) 9384' H7" MARKER JT W/ RA TAG DATE REV BY COMMENTS DATE REV BY COMMENTS 04/16102 JLWKK ORIGINAL COMPLETION 01/18/12 TMWJMD ADDED H2S SAFETY NOTE 517-9102 CWS/KK ADPERFS 0620/02 JNYIIh GLV UPDATE 0720/02 JB/tlh GLV UPDATE 04/08103 DRSITP TVDIMD CORRECTIONS 122/15/11 MB/JMD ADDED SSSV SAFETY NOTE BOREALIS UNIT WELL L-119 PERMIT No '2020640 API No. 50.029-23077.00 SEC 34, TI 2N, R11 E, 2601' NSL 6 3574' WEL BP Exploration (Alaska) L-119 AOGCC MIT -IA TO 2500 PSI e Elapsed Time hh:mm:ss Irjl Monthly Injection Report for GP134MA, Northstar, Milne Point & Endicwr August... Page 1 of 1 Maunder, Thomas E (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator@bp.com] Sent: Saturday, September 03, 2011 4:20 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); AK, D&C Well Integrity Coordinator Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O&M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for August 2011 Attachments: AOGCC Inj Report 09-11.zip Tom, Jim, Phoebe, and Guy, Attached is the August 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. <<AOGCC Inj Report 09-11.zip>> Notes on wells: Added to Report: None „±. S F P °; Z 01.4 Taken off Report: 09-36C (PTD #1951140): Reclassified as Not Operable and added to Quarterly Not Operable Report after LDL identified patch leaking. R-02 C TD #1781000): Reclassified as Not Operable and added to Quarterly Not Operable Report after MIT -IA failed. L-119 (PTD #2020640 Finished monitoring for 2 additional months after being Under Evaluation in May, 2011 No L-210 (PTD #2031990): Finished monitoring for 2 additional months after being Under Evaluation in May, 2011 No repressurization noted. W-03 (PTD #1971390): Monitored for IA re pressurization reported February, 2011. No repressurization noted. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 9/6/2011 Monthly Injection Report for GP13MA, Northstar, Milne Point & Endico for April 2... Page 1 of 1 6 Maunder, Thomas E (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWelllntegrityCoordinator@bp.com] Sent: Thursday, May 19, 2011 2:49 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); Brooks, Phoebe L (DOA); AK, D&C Well Integrity Coordinator Cc: AK, OPS GC1 OSM; AK, OPS FS1 OSM; AK, OPS Area Mgr North (Gas Plants GPMA); AK, OPS GC2 OSM; AK, OPS FS1 DS Ops Lead; AK, OPS FS1 Facility OTL; AK, OPS FS2 DS Ops Lead; AK, OPS FS2 Facility OTL; AK, OPS FS3 DS Ops Lead; AK, OPS FS3 Facility OTL; AK, OPS GC1 Facility OTL; AK, OPS GC1 Wellpad Lead; AK, OPS GC2 Facility OTL; AK, OPS GC2 Wellpad Lead; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; AK, OPS GPMA Facility OTL; AK, OPS LPC DS Ops Lead; AK, OPS Ops Supt; Kurz, John; AK, OPS MPU OSM; AK, OPS MPU Field Lead Tech; AK, OPS MPU Field Ops TL; AK, OPS MPU Well Ops Coord; AK, OPS MPU Wells Ops Coord 2; AK, OPS Nstar Lead Tech; AK, OPS Nstar OIM; AK, OPS Nstar O&M TL; Nash, Justin; Daniel, Ryan; AK, RES END Production Optimization Engineer; Daniel, Ryan Subject: Monthly Injection Report for GPB, GPMA, Northstar, Milne Point & Endicott for April 2011 Attachments: AOGCC Inj Report 05-11.zip Tom, Jim, Phoebe, and Guy, Attached is the April 2011 Injection Report for GPB, GPMA, Northstar, Milne Point and Endicott injectors operating under a Sundry or Administrative Approval. <<AOGCC Inj Report 05-11.zip>> Notes on wells: Add to Report: _L-119: Added for being Under Evaluation for potential TxIA communication. L-210: Added for being Under Evaluation for potential TxIA communication. S-217: Added for evaluation of TxIA communication diagnostics. The Well Integrity Coordinator will apply for an administrative approval pending IA repressurization. W-44: Added for being Under Evaluation for potential TxIA communication. Taken off Report: X -24A: Removed after showing no signs of IA repressurization since December, 2010. Please call with any questions or concerns. Thank you, Gerald Murphy (alt. Mehreen Vazir) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 5/31/2011 Well L-119 Injection Plot o Pressure vs. Rate 0 0 It 0 0 Tubing Pressure CO ♦ ♦ ♦ : Tbg Press IA Press OA Press a o (BWPD / MCFPD) CL o WHP Date = N (psi) 00 ♦ �� 05/01/11 O ♦Last 90 days � Last Month 1,586 0 0 1,000 2,000 3,000 4,000 5,000 6,000 7,000 Injection Rate, MCFPD TIO Plot 0 0 0 v - Tbg IA o OA 0 0 CO CL o a o , C) O 0 0 11/29/10 2/19/11 5/12/11 Under Evaluation for IA repressurization �J Volume Injected Tubing Pressure Tbg Press IA Press OA Press Date (BWPD / MCFPD) (psi) WHP Date (psi) (psi) (psi) 05/01/11 1,925 1,586 05/01/11 1,600 560 180 04/30/11 1,687 1,583 04/30/11 1,600 560 180 04/29/11 1,617 1,565 04/29/11 1,600 560 180 04/28/11 1,635 1,568 04/28/11 1,600 560 180 04/27/11 1,681 1,551 04/27/11 1,600 560 180 04/26/11 1,676 1,542 04/26/11 1,600 560 200 04/25/11 1,737 1,536 04/25/11 1,600 500 140 04/24/11 1,702 1,527 04/24/11 1,600 1,540 280 04/23/11 1,579 1,500 04/23/11 1,500 1,420 320 04/22/11 1,737 1,518 04/22/11 1,550 1,460 320 04/21/11 1,741 1,493 04/21/11 1,550 1,460 320 04/20/11 1,740 1,449 04/20/11 1,450 1,140 80 04/19/11 1,580 1,410 04/19/11 1,450 1,060 80 04/18/11 1,591 1,416 04/18/11 1,450 1,140 120 04/17/11 1,556 1,407 04/17/11 1,450 1,180 160 04/16/11 1,281 1,342 04/16/11 1,420 1,180 160 04/15/11 1,296 1,348 04/15/11 1,400 1,040 160 04/14/11 1,094 1,301 04/14/11 1,320 960 140 04/13/11 1,030 1,241 04/13/11 1,350 960 160 04/12/11 1,160 1,315 04/12/11 1,350 960 160 04/11/11 1,171 1,321 04/11/11 1,350 960 160 04/10/11 1,204 1,322 04/10/11 1,350 960 160 04/09/11 1,202 1,313 04/09/11 1,350 960 160 04/08/11 1,228 1,307 04/08/11 1,350 860 160 04/07/11 1,142 1,281 04/07/11 1,350 860 160 04/06/11 1,159 1,291 04/06/11 1,350 860 160 04/05/11 1,120 1,289 04/05/11 1,350 1,000 160 04/04/11 1,211 1,314 04/04/11 1,350 1,000 160 04/03/11 1,175 1,302 04/03/11 1,350 1,000 160 04/02/11 1,187 1,296 04/02/11 1,350 1,000 160 04/01/11 1,753 1,394 04/01/11 1,350 1,000 160 Under Evaluation for IA repressurization �J RE: OPERABLE: Injector L-119 (PTD #2020640) No Indication of IA Repressurization -... Page 1 of 2 • Maunder, Thomas E (DOA) 0 From: AK, D&C Well Integrity Coordinator[AKDCWellintegrityCoordinator@bp.com] Sent: Sunday, May 08, 2011 9:29 PM To: AK, D&C Well Integrity Coordinator; Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad LV; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: King, Whitney; AK, D&C Well Integrity Coordinator Subject: RE: OPERABLE: Injector L-119 (PTD #2020640) No Indication of IA Repressurization - Corrected name in e-mail body All, The correct well name is L-119 (PTD #2020640), not L-219 as listed in the previous body of the e-mail. Thank you, Gerald Murphy BPXA Well Integrity Coordinator From: AK, D&C Well Integrity Coordinator Sent: Sunday, May 08, 20119:22 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field 0&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad LV; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: King, Whitney; AK, D&C Well Integrity Coordinator Subject: OPERABLE: Injector L-119 (PTD #2020640) No Indication of IA Repressurization /ON Injector L-219 (PTD #2020640) has not shown any signs of IA repressurization during the last 10 days of monitoring while on water injection. A copy of the TIO and Injection plots are included for reference. The well is reclassified as Operable. << File: Injector L-119 (PTD #2020640) TIO and Injection Plot.doc >> Thank you, Gerald Murphy (alt. Torin Roschinger) Well Integrity Coordinator Office (907) 659-5102 Cell (907) 752-0755 Pager (907) 659-5100 Ext. 1154 5/31/2011 Injector L-119 (PTD #2020640) TIO Plot Well: L-119 4,000 3,000 2,000 1,000 • 02/12/11 02/26/11 03112111 03/26/11 04/09/11 04/23/11 05/07/11 Injector L-119 (PTD #2020640) Injection Plot WeB_ L-119 3,200 3.000 2.000 2.600 2.400 2,200 2.000 d 1.800 3 1.680 1.400 1,200 1.080 800 680 400 200 —0 Tbg f IA — A OA OOA OOOA On s.o6o 5,50D 5,OG0 4,500 4,000 3,500 - WHIP 5y/ ✓--'� 3,800 -PW - MI 2,500 - Olhei 2,000 On 1300 1,000 500 1 UNDER EVALUATION: Injector L-210 (PTD #2031990) Signs of slow IA repressurizat... Page 1 of 2 0 0 Maunder, Thomas E (DOA) From: AK, D&C Well Integrity Coordinator[AKDCWellintegrityCoordinator@bp.com] Sent: Tuesday, April 26, 2011 7:11 PM To: Maunder, Thomas E (DOA) Cc: Regg, James B (DOA); Schwartz, Guy L (DOA) Subject: RE: UNDER EVALUATION: Injector L-210 (PTD #2031990) Signs of slow IA repressurization Attachments: L-119 TIO 4-26-11.doc; L-210 TIO 4-26-11.doc Tom, I agree with your assessment, a very definite thermal response is observed as a result of swapping these injectors to PWI from MI. L-119 was swapped to PWI on 3/21 and the IA showed an immediate increasing pressure response but then appeared to stabilize. The IA began an increasing trend again on 4/12 which could be attributed to the increase in injection rate. However, the IA also appeared to be equalizing with the tubing pressure. The IA was bled down on 4/25 to 400 psi. During the monitor period the IA pressure increased 90 psi with no correlating increase in injection pressure. L-210 was swapped to PWI on 4/3 and the thermal response on the IA was immediately evident but the IA equalized with the tubing pressure. The IA was bled down on 4/25 to 350 psi. During the monitor period an increase in IA pressure of 60 psi was seen. Given the fluid packed environment in the annuli of these injectors, it is to be expected that temperature shifts could result in substantial pressure effects. However, my concern was that after the bleeds, the IAs continued to exhibit an increasing pressure trend. Please let me know if you have further questions. Thanks, Mehreen From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, April 26, 20113:40 PM To: Vazir, Mehreen; Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad LV; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: Walker, Greg (D&C); Clingingsmith, Mike J (Swift); Greaves, Damien C Subject: RE: UNDER EVALUATION: Injector L-210 (PTD #2031990) Signs of slow IA repressurization Mehreen, It is interesting that L-210 and L-119 both exhibit similar responses when it appears they are changed from MI to water. Is the initial IA pressure response to both wells attributed to the change in temperature due to the warmer water? It doesn't seem that the magnitude of the pressure changes was very great. Your comments will be appreciated. Tom Maunder, PE AOGCC From: Vazir, Mehreen [mailto:Mehreen.Vazir@bp.com] Sent: Tuesday, April 26, 2011 12:53 PM 5/31/2011 UNDER EVALUATION: Injector L-210 (PTD #2031990) Signs of slow IArepressurizat... Page 2 of 2 To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC2 OSM; AK, OPS GC2 Facility OTL; AK, OPS GC2 Field O&M TL; AK, OPS GC2 Wellpad Lead; AK, OPS Well Pad LV; AK, OPS Prod Controllers; Cismoski, Doug A; AK, D&C Wireline Operations Team Lead; AK, D&C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; Daniel, Ryan Cc: Walker, Greg (D&C); Clingingsmith, Mike J (Swift); Greaves, Damien C Subject: UNDER EVALUATION: Injector L-210 (PTD #2031990) Signs of slow IA repressurization All, Injector L-210 (PTD #2031990) is exhibiting signs of slow IA repressurization. The IA was bled from 1150 psi down to 350 psi on 4/25/2011 and has built up 60 psi during the monitor. The well has been reclassified as Under Evaluation. The well will remain on injection and the IA pressure will be monitored for the next 10-14 days. If the well continues to exhibit IA repressurization, an AA will be submitted for continued injection. A TWO and wellbore schematic are attached for reference. <<L-210.pdf>> <<L-210 TIO 4-26-11.doc>> Thank you, Mehreen Vazir (Alternate: Gerald Murphy) Well Integrity Coordinator BP Alaska Drilling & Wells Well Integrity Office: 907.659.5102 Email: AKDCWellintegrityCoordinator@BP.com 5/31/2011 0 0 Wd L-119 3.300 32M 3100 3.000 2969 2,w 2 2.600 2500 Z4W 2,3W 2200 2100 2,000 900 � 1,800 31®0 1500 1,400 300 1,210 1100 1,000 9W 410 700 600 500 400 210 100 WeF.L-119 n.000 10,007 9,000 8,000 7,000 -WHIP 6,000 'w pm - MI -- GI 5,W0 -09w On 4 000 3m 2.067 1,070 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission DATE: Wednesday, July 14, 2010 TO: 71m Regg , �'Zr;CID SUBJECT: Mechanical Integrity Tests P.I. Supervisor BP EXPLORATION (ALASKA) INC L-119 FROM: Chuck Scheve PRUDHOE BAY UN BORE L-119 Petroleum Inspector Src: Inspector NON -CONFIDENTIAL Reviewed By: �� P.I. Supry Comm Well Name: PRUDHOE BAY UN BORE L-119 Insp Num: mitCS100711170157 Rel Insp Num: API Well Number: 50-029-23077-00-00 Permit Number: 202-064-0 Inspector Name: Chuck Scheve Inspection Date: 7/8/2010 Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. L-119 ' Type Inj. CT TVD 6446 IA 100 4000 3940 3940 FWell P.T.D 2020640' TypeTest SPT Test psi 1611 OA 20 40 40 40 Interval4YRTST P/F P " Tubing 2550 2550 2550 2550 Notes: Pre-test pressures observed and found stable. cir x Wednesday, July 14, 2010 Page I of I i • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Email to:jim.regg@alaska.gov; phoebe.brooks@alaska.gov; tom.maunder@alaska"gov; doa.aogcc.prudhoe.bay@alaska.gov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT I PAD: Prudhoe Bay / PBU / L Pad DATE: WWI0 OPERATOR REP: Tiffany Quy AOGCC REP: Chuck Scheve Packer Pretest Initial 15 Min. 30 Min. Well I L-111 Type In'. I W TVD I 4,015 Tubiing 1,300 1,300 1,300 1,300 Interval V P.T.D.2020300 I Typetest I P Test psil 1500 Casing 520 2,500 2,4201 2,410 P/Fj P Notes: AOGCC MIT -IA to 25W psi for AA compkance OA 160 160 16DI 160 Well L-119 I Type In'" T G I TVD I 6,44V Tubingj 2,5501 2,5501 2,5501 2,5501 intervall 4 IP P.T.D.2020640 I Typetest I P I Test 1611.5 Casingi 1001 4,0001 3,M1 3,940 P/Fj P Notes: AOGCC MIT -IA to 4000 psi for 4 year UIC OAJ 201 401 401 40 Well I L-123 Type In'. G TVD 1 6,3461 Tubing 3,060 3,060 3,060 3,060 Interval 4 P.T.D.2051940 T test P Test 1587 820 3,980 3,940 3,930 P/F P Notes: AOGCC MIT -IA to 4000 psi for 4 year UIC OA 270 680 6401 610 Weill I Type In'. I I TVD I Interval P.T.D. T test Test i MOA P/F Notes: Well Type In'. TVD Interval P.T.D. T test Test EMOA P/F Notes: TYPE INJ Codes D = Drilling Waste G = Gas I = Industrial Wastewater N = Not Injecting W = Water MIT Report Form BFL 11/27/07 TYPE TEST Codes M = Annulus Monitoring P = Standard Pressure Test R = Internal Radioactive Tracer Survey A = Temperature Anomaly Survey D = Differential Temperature Test MIT PBU L-111, 119 8 123 07-08-10 .xis INTERVAL Codes I = Initial Test 4 = Four Year Cycle V = Required by Variance T = Test during Workover O = Other (describe in notes) BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB-20 Post Office Box 196612 Anchorage, Alaska 99519-6612 r .,N r� ZOO, August 14, 2009 Mr. Tom Maunder Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB L -Pad Dear Mr. Maunder, rol OCT 0 5 2009 Alaska Gil & Gas Cons. Commission Anchorage Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB L - Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10-404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Anna Dube, at 659-5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) L pad Barg 8/13/2009 Well Name PTD # API # Initial top of cement Vol. of cement pumped Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date It bbis ft na gal L-01 2010720 50029230110000 NA 6 NA 61.2 6/25/2009 L -02A 2041490 50029230480100 NA 1.4 NA 14.5 6/27/2009 L-03 2051030 50029232690000 NA 2.8 NA 24.7 6/25/2009 L-04 2061200 50029233190000 NA 1.7 NA 15.3 6/25/2009 L-100 1980550 50029228580100 NA 6.2 NA 57.8 6/29/2009 L-101 1980320 50029228650000 NA 3.3 NA 30.6 6/29/2009 L-102 2020360 50029230710000 37' NA Need Top Job? NA L-103 2021390 50029231010000 NA 1.6 NA 10.2 6/26/2009 L-104 2012380 50029230600000 NA 3.5 NA 47.6 5/6/2009 L-105 2020580 50029230750000 NA 1.75 NA 24.65 5/6/2009 L-106 2012230 50029230550000 NA 2.75 NA 28.05 5/6/2009 L-107 2011510 50029230360000 NA 4.8 NA 57.8 5/6/2009 L-108 2021090 150029230900000 NA 1.2 NA 13.8 6/25/2009 L-109 2012010 50029230460000 NA 2.9 NA 32.3 6/27/2009 L-110 2011230 50029230280000 NA 27 NA 316.2 6/29/2009 L-111 2020300 50029230690000 NA 4.7 NA 54.4 6/29/2009 L-112 2022290 50029231290000 NA 5.5 NA 51 6/27/2009 L-1 14A 2051120 50029230320100 NA 2.5 NA 25.5 6/29/2009 L-115 2011400 50029230350000 NA 0.5 NA 3.4 6/27/2009 L-116 2011160 50029230250000 NA 5 NA 54.4 6/28/2009 L-117 2011670 50029230390100 NA 2.9 NA 28.9 6/27/2009 L-118 2011870 50029230430000 NA 1.4 NA 15.3 6/27/2009 L-119 2020640 50029230770000 NA 2.25 NA 28.9 5/6/2009 L-120 2020060 50029230640000 NA 0.75 NA 6.8 5/5/2009 L -121A 2030390 50029231380100 NA 2.2 NA 25.5 6/27/2009 L-122 2030510 50029231470000 NA 2 NA 20.4 6/27/2009 L-123 2051940 50029232900000 NA 2 NA 18.7 6/27/2009 L-124 2050430 50029232550000 NA 1.8 NA 17 6/27/2009 L-200 2040010 50029231910000 NA 1.8 NA 13.5 612612009 L-201 2040460 50029232020000 NA 1.75 NA 15.3 5/6/2009 L-202 2041960 50029232290000 NA 2 NA 17 6/26/2009 L-204 2060920 50029233140000 NA 1.5 NA 5.95 5/6/2009 L-205 2080530 50029233880000 NA 1 NA 12.75 1/10/2009 L-210 2031990 50029231870000 NA 3.25 NA 31.4 5/5/2009 L-211 2040290 50029231970000 NA 1.8 NA 17 6/27/2009 L-212 2050300 50029232520000 NA 1.8 NA 17 6/26/2009 L-213 2060530 50029233080000 NA 2 NA 17 6/25/2009 L -214A 2060270 50029232580100 NA 0.25 NA 10.2 5/6/2009 L-215 2051270 50029232740000 NA 1.5 NA 30.6 5/6/2009 L-216 2040650 50029232060000 NA 1.3 NA 11.9 6/26/2009 L-217 2060750 50029233120000 plate blocking conductor NA NA L-218 2051190 50029232720000 NA 1.7 NA 15.3 6/27/2009 L-219 2071480 150029233760000 surface NA NA L-220 2080470 50029233870000 NA 2 NA 20.4 6/28/2009 L-221 2080310 50029233850000 NA 1.7 NA 16.2 6/25/2009 L-250 2051520 50029232810000 NA 3.4 NA 34 6/26/2009 L-50 2051360 50029232770000 NA 1.8 NA 20.4 6/27/2009 L-51 2060590 500292330900001 NA 1.8 NA 17 6/27/2009 MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFicheNCwPgsLInsetts\Microfilm—Marker.doc 01 FRANK H. MURKOWSKI, GOVERNOR AI4ASKA 011L AND GALS 333 W. 7- AVENUE, SUITE 100 CONSERVATION COMMSSI011N ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bruce Smith Petroleum Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay L-119 Sundry Number: 304-404 Dear Mr. Smith: 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 rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested,,. BY ORDER OF TH Y OMMISSION DATED this ,' da of November, 2004 Encl. S-"GANNEr Nov -1 6 2004 STATE OF ALASKA RECEI\ ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVAL s U 90 AAc; PI 9An _ 1. Type of Request: Abandon El Suspend Operation ShutdownPerforated WaiveeE 6 Ar'" lar Disposal Alter Casing E] Repair Well Plug Perforations StimulateE] Time Extension OtheroX Change Approved Program Pull Tubing Perforate New Pool Re-enter Suspended Well Convert to WAG Inj 2. Operator 4. Current Well Class: 5. Permit to Drill Number: Name: BP Exploration (Alaska), Inc. 202-0640 Development Exploratory 3. Address: P.O. Box 196612 6. API Number Anchorage, Alk 99519-6612 StratigraphicService 50-029-23077-00-00 7. KB Elevation (ft): 9. Well Name and Number: 78.90 KB L-119 8. Property Designation: 10. Field/Pool(s): ADL -0028238 Prudhoe Bay Field / Borealis Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (md): Junk (md): 9624 7197.5 9556 7052.6 9150 None Casing Length Size MD TVD Burst Collapse top bottom top bottom Conductor 80 20" 91.5# H-40 28 - 108 28.0 - 108.0 1490 470 Production 1 9583 171 26# L-80 1 26 - 96091 26.0 - 7182.9 7240 5410 Surface 1 2890 9-5/8" 40# L-80 29 - 29191 29.0 - 2620.9 5750 3090 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 9058 - 9084 6656.01 - 6680.6 4.5 " 12.6 # L-80 24 - 8995 9092 - 9106 6688.15 - 6701.4 Packers and SSSV Type: Packers and SSSV MD (ft): 4-1/2" Baker Premier Packer 8834 4-1/2" Baker S-3 Perm Packer 8958 12. Attachments: Description Summary of Proposal 13. Well Class after proposed work: Detailed Operations Program BOP Sketch Exploratory[] Development ServiceoX 14. Estimated Date for November 17, 2004 15. Well Status after proposed work: CommencingOperation: Oil Gas[] Plugged Abandoned WAG �X GINJ[] WINJ[j WDSPL[j 16. Verbal Approval: Date: Commission Representative: Prepared by Garry Catron 564-4657. 17. t hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Bruce Smith Printed Name Bruce Smith Title Petroleum Engineer Signature t`.�-, _. \� Phone 564-5093 11/3/04 Commission Use Only Sundry Number: Conditions of approval: Notify Commission so that a representative may witness I 2d'(- L/O Plug Integrity BOP Test Mechancial Integrity Test Location Clearance El Other: Subsequen For Re d.' I Approved by; BY ORDER OF !� THE COMMISSION Date: /s/0 RBDMS 15H. OR�GNAL / / f Form 10-403 Revised 06/2004 SUBMIT IN DUPLICATE TRI= = d -1/'I R" RM l:M/ 1 L-1 19 SAFETY NOTES: S 4- 4- 3- 3- 4 - DATE REV BY COMMENTS DATE REV BY COMMENTS 04/16/02 JLM/KK ORIGINAL COMPLETION 5/7-9/02 CWS/KK ADPERFS 06/20/02 JM/tlh GLV UPDATE 07/20/02 JBAIh GLV UPDATE 04/08/03 DRS/TP TVD/MD CORRECTIONS DATE rrz0ro2 x/20/02 T/20/02 BOREALIS UNIT WELL: L-119 PERMIT No: 2020640 API No: 50-029-23077-00 SEC 34, T12K R11 E, 2601' NSL & 3574' WEL BP Exploration (Alaska) DATA SUBMITTAL COMPLIANCE REPORT 6/1/2004 Permit to Drill 2020640 Well Name/No. PRUDHOE BAY UN BORE L-119 Operator BP EXPLORATION (ALASKA) INC MD 9624 TVD 7197 Completion Date 5/7/2002 Completion Status 1-011- REQUIRED -OILREQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name Samples No Current Status 1WINJ 5p, J- -� 2 M --,L h qa- API No. 50-029-23077-00-00 Directional Survey Yes ✓` (data taken from Logs Portion of Master Well Data Maint) Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments ADDITIONAL INFORMATION Well Cored? Y /tN) Chips Received? Analysis Received? Comments: tYJ Daily History Received? N Formation Tops Q)IN Compliance Reviewed By: Date: Induction/Resistivity 25 BS 1 2900 9569 Open 6/4/2002 j' Log Density j� p .� 25 BS 1 2900 9569 Open 6/4/2002 Log Neutron �J 25 BS 1 2900 9569 Open 6/4/2002 Log C Density - �v)j 25 BS 1 2900 9569 Open 6/4/2002 g Induction/Resistivity` 25 BS 1 2900 9569 Open 6/4/2002 f�FO- C cjoq�i See Notes ; 1 126 9623 Open 6/4/2002 PP ADN ARC Data Log Neutron 25 BS 1 2900 9569 Oen 6/4/2002 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y /tN) Chips Received? Analysis Received? Comments: tYJ Daily History Received? N Formation Tops Q)IN Compliance Reviewed By: Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ Pre -Prod Converted to Water In' Pull tubing _ Alter casing _ Repair well _ Other _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development _ Exploratory_ RKB 79 feet 3. Address 7. Unit or Property name P. O. BOX 196612 Stratigraphic_ Anchora e, AK 99519-6612 Service_X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2678' FNL, 3573' FEL, Sec. 34, T1 2N, R11 E, UM (asp's 583340, 5978325) L-119 9. Permit number / approval number At top of productive interval 3705' FNL, 183' FEL, Sec. 27, T1 2N, R11 E, UM (asp's 586675, 5982615) 202-064 / 302-208 10. API number At effective depth 3684' FNL, 165' FEL, Sec. 27, T1 2N, R11 E, UM (asp's 586693, 5982636) 50-029-23077-00 At total depth 11. Field / Pool 3585' FNL, 69' FEL, Sec. 27, T1 2N, R11 E, UM (asp's 586787, 5982736) 1 Prudhoe Bay Field / Borealis Pool 12. Present well condition summary Total depth: measured 9624 feet Plugs (measured) true vertical 7197 feet Effective depth: measured 9140 feet Junk (measured) true vertical 6734 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 107' 20" 260 sx Arctic Set (Aprox) 136' 136' Surface 2890' 9-5/8" 525 sx AS III Lite, 290 sx 2919' 2621' Class 'G' Production 9582' 7" 606 sx Class 'G' 9608' 7182' Perforation depth: measured Open Perfs 9092'-9106', 9058'-9084', Sqzd Perfs 8850'-8852', 8947'-8949', 9160'-9161' true vertical Open Perfs 6656'-6680', 6688'-6701', Sqzd Perfs 6461'-6463', 6552'-6554', 6752'-6753' Tubing (size, grade, and measured depth) 4-1/2" 12.6# L-80 TBG @ 8958'. 4-1/2" 12.6# L-80 TBG @ 8995'. NO I ENe P. Packers & SSSv (type & measured depth) 7" x 4-1/2" Baker Premier Packer @ 8 34' MD. 7" x 4-1/2" Baker s-3 5 ( YP p ) 8 8 4-1/2" HES 'X' Landing Nipple @ 2287'. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Ahab 01M Gas GOnS. Commission Treatment description including volumes used and final pressure Anchamlge 14. Representative Daily Average Production or Infection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing Pressure Prior to well operation Shut -In Subsequent to operation 10/18/2002 1364 1922 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run , Daily Report of Well Operations _ Oil _ Gas _ Suspended _ Service WATER Infector 17. 1 hereby certify that the foregoing is tru and correct to the best of my knowledge. !�'✓ Title: Technical Assistant Date October 21, 2002 DeWa ne R. Schnorr Prepared by DeWa ne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 • I SUBMIT IN DUPLICATE L-109 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 07/20/2002 PBU TEST: GAS LIFT --TO DUMMY VALVES; PRESSURE BUILD-UP TEST 07/21/2002 PBU TEST: GAS LIFT --TO DUMMY VALVES; MIT -IA 07/21/2002 PBU TEST: MIT -IA 09/11/2002 PBU TEST: STATIC BOTTOM HOLE PRESSURE SURVEY 10/02/2002 PBU TEST: TUBING TAIL PLUG 10/16/2002 PRODUCED WATER INJECTION STARTED 10/18/2002 ANN -COMM (UIC PROGRAM): AC -MONITOR 10/19/2002 ANN -COMM (UIC PROGRAM): AC-MITIA 10/20/2002 TESTEVENT --- INJECTION PRESSURE, PSI: 1,923 TYPE: PW VOL: 1,254 BWPD. 10/20/2002 ANN -COMM (UIC PROGRAM): AC -MONITOR EVENT SUMMARY 07/20/02 RUN 3.8 GR TO 8952' WLMD. RUN 3.7 CENT. 3'1-1/2" STEM & 3-1/2" EQ DEVICE. RUN 4-1/2" GS TO DHSIT, LATCH AND POOH. 07/21/02 PULL DHSIT ( PETREDAT ). AVG BHP = 3000 psi, TEMP = 150 degrees F. SET CATCHER @ 8966' WLMD. PULL VALVES FROM GLM'S 1, 2 & 3. SET DGLV'S IN 3 & 2. LOAD IA W/ 50/50 INHIBITED METHANOL SET DGLV IN GLM # 1 (DUMMIES ALL HAVE "BK"LATCHES). MIT IA TO 3000#. NOTIFIED PAD OP. OF WELL STATUS. HUNG TAG ON IA. RDMO. 07/21/02 PUMP 170 BBLS OF 50/50 DOWN IA. TO 2650 PSI. SLICK LINE SETS PLUG. PUMP 2 BBLS 50/50 TO 3000 PSI. MIT FOR 30 MIN. DROPS TO 2970 PSI. GOOD 09/11/02 SET 4-1/2" XN- LOCKED FLOW THRU SUB W/ PETREDAT GAUGES @ 8,974' WLM(OAL=91" LOCK OPEN) 10/02/02 PULL PETREDAT GAUGE FROM XN-NIPPLE. <<< TURN WELL OVER TO PAD OPERATOR >>> 10/18/02 ANNCOMM --- T/I/O = 1860/1290/140 TEMP = 122 IA FL @ SURFACE (PREP FOR AOGCC MITIA). 10/19/02 MITIA PASSED TO 1850 PSI. (WITNESSED BY CHUCK SCHEVE FOR THE AOGCC). PRESSURED UP ON IA FROM AN INITIAL 1100 PSI TO 1850 PSI. STARTED TEST. AFTER 15 MINUTES THE IA PRESSURE WAS AT 1850 PSI AND AFTER 30 MINUTES THE PRESSURE WAS AT 1850 PSI. 10/1 /02 PRODUCED WATER INJECTION STARTED. 10/20/02 TESTEVENT --- INJECTION PRESSURE, PSI: 1,923 TYPE PW VOL: 11254 BWPD. Page 1 L-109 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 07/20/2002 PBU TEST: GAS LIFT --TO DUMMY VALVES; PRESSURE BUILD-UP TEST 10/20/02 ANNCOMM --- T/I/O/= 1840/830/50 MONITOR WHP's . POST MITIA . FLUIDS PUMPED BBLS 2 DIESEL FOR PRESSURE TEST OF SURFACE EQUIPMENT 2 TESTS 1 60/40 METHANOL WATER. 172 INHIBITED 50/50 METHANOL WATER. 175 TOTAL Page 2 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Cammy O Taylor,DATE: October 19, 2002 Chairman SUBJECT: Mechanical Integrity Tests THRU: Tom Maunder BPX P.I. Supervisor L Pad L-109 & L-119 FROM: Chuck Scheve PBU Petroleum Inspector NOW CONFIDENTIAL Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs L Pad and witnessed the initial MIT on wells L-109 and L-119. The pretest tubing and casing pressures were observed and found to be stable. The casing was then pressured up and observed for 30 minutes with the well demonstrating good mechanical integrity. tQ,�A WC�.S �►�'1����' M.I.T.'s performed: 2 Number of Failures: 0 Total Time during tests: 2 hour Attachments: cc: MIT report form 5/12/00 L.G. MIT PBU L 10-19-02 CS.xls 10/25/2002 Packer Depth Pretest Initial 15 Min. 30 Min. Well L-109 Type Inj. S T.V.D. 4596 Tubing 1750 1580 1700 1750 Interval P.T.D. 201-201 ITypetestj P Test psi 1149 Casing 590 1720 1660 1690 P/F P Notes: New Well Well L-119 TType Inj. S T.V.D. 66447 Tubing 1700 1700 1700 1700 Interval P.T.D. 202-064 Type test P Test psi 16612 Casing 1100 1850 1850 1850 P/F P Notes: New Well Well I Type Inj. T.V.D. I I Tubing I lintervall P.T.D. Type test Test psi Casing P/F Notes: Well Type Inj. T.V.D. I Tubing I I lintervall P.T.D. I Type test Test psi Casing I P/F Notes: Well Type Inj. T.V.D. I I Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS INJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval 1= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs L Pad and witnessed the initial MIT on wells L-109 and L-119. The pretest tubing and casing pressures were observed and found to be stable. The casing was then pressured up and observed for 30 minutes with the well demonstrating good mechanical integrity. tQ,�A WC�.S �►�'1����' M.I.T.'s performed: 2 Number of Failures: 0 Total Time during tests: 2 hour Attachments: cc: MIT report form 5/12/00 L.G. MIT PBU L 10-19-02 CS.xls 10/25/2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 1. Type of request: Abandon_ Suspend_ Operational shutdown _ Re-enter suspended well _ Pre -Producer Converted Pre -Producer Alter casing _ Repair well _ Plugging _ Time extension _ Stimulate —to Injector Converted to Inject Change approved program _ Pull tubing _ Variance _ Perforate _ Other _X 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development_ Exploratory_ RKB 78.9 feet 3. Address 7. Unit or Property name P. O. Box 196612 Stratigraphic _ Anchorage, AK 99519-6612 Service_X Prudhoe Bay Unit 4. Location of well at surface 8. Well number 2678' FNL, 3573' FEL, Sec. 34, T1 2N, R11 E, UM (asp's 583340, 5978325) L-119 At top of productive interval 9. Permit number / approval number 3705' FNL, 183' FEL, SEC 27, T1 2N, R11 E, UM (asp's 586675, 5982615) 202-064 At effective depth 10. API number 3684' FNL, 165' FEL, Sec. 27, T1 2N, R11 E, UM (asp's 586693, 5982636) 50-029-23077-00 At total depth 11. Field / Pool 3585' FNL, 69' FEL, Sec 27 T1 2N, R11 E, UM (asp's 586787, 5982736) Prudhoe Bay Field/ Borealis,?obl , 12. Present well condition summary Total depth: measured 9624 feet Plugs (measured) true vertical 7197 feet JUL 5 �_-02 J UL Effective depth: measured 9140 feet Junk (measured) true vertical 6734 feet ouaslia U11 & Lias Colliis. G.o.w . Casing Length Size Cemented Measured Depth True VD21Tilpth Conductor 107' 20" 260 sx ArcticSet (Approx) 136' 136' Surface 2890' 9-5/8" 525 sx AS III Lite, 290 sx 2919' 2621' Class 'G' Production 9582' 7" 606 sx Class 'G' 9608' 7182' Perforation depth: measured Open Perfs 9092'-9106', 9058'-9084', Sqzd Perfs 8850'-8852', 8947'-8949', 9160'-9161' true vertical Open Perfs 6656'-6680', 6688'-6701', Sqzd Perls 6461'-6463', 6552'-6554', 6752'-6753' Tubing (size, grade, and measured depth 4-1/2" 12.6# L-80 TBG @ 8958'. 4-1/2" 12.6# L-80 Tubing Tail @ 8995'. Packers & SSSV (type & measured depth) 7" x 4-1/2" Baker Premier Packer @ 8834' MD. 7" x 4-1/2" Baker S-3 Packer @ 8958' MD. 4-1/2" 'X' Landing Nipple @ 2287'. 13. Attachments Description summary of proposal _X Detailed operations program _ BOP sketch 14. Estimated date for commencing operation 15. Status of well classification as: July 9, 2002 Oil _ Gas _ Suspended 16. If proposal was verbally approved Name of approver Date approved Service WAG INJECTOR 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Questions? Call Bruce W. Smith @ 564-5093. Signed �� / Title: Borealis Development Petroleum Engineer Date July 03, 2002 Bruce W. Smith f-�' Prepared by DeWa ne R. Schnorr 564-5174 FOR COMMISSION USE ONLY Conditions of approval: Notify Commission so representative may witness Approval no3() a ao Plug integrity _ Test Location clearance _Mechanical Integrity TesZP ubequent form required 10- 9L TrS wi Ungmal S+gneo by Approved by order of the Commission QIMMX OeOsli Taylor Commissioner Date Form 10-403 Rev 06/15/88 • ORIGINAL SUBMIT IN TRIPLICATE by � BP Exploration (Alaska) Inc. 900 East Benson Boulevard P. O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 July 03, 2002 Winton Aubert Alaska Oil & Gas Conservation Commission 333 West 7t" Avenue Suite 100 Anchorage, AK 99501 Dear Tom: Re: Sundry Notice for L-119 Conversion from Pre -Produced Injector to WAG Injector BP Exploration Alaska, Inc. proposes to convert well L-119 from a pre -produced injection well to an active injector (both water and MI (WAG flood)) as part of the Borealis Pool Flood Development project. The procedure includes the following major steps: S D/T, Dummy off GL Design, Run Static Survey. MITIA to 4000 psig. Slickline Work: 1. Drift and tag to at least 9100' MD, to verify access to perfs. 2. Run DHSIT w/ dual gauges. Recover DHSIT w/ gauges after + 72 hours. 3. DGLVs MITIA to 4000 psig. Last test: 06/26/02 1000 BO P D Max Deviation: 580 @ 5502' MD Top Perf deviation: 19° @ 9144' MD Min. ID: 3.725" XN nipple @ 8982' MD Last TD tag: 8980' MD 06/19/2002 Last Downhole Ops: Static survey 06/19/2002 Latest H2S value: 0 ppm 06/26/2002. Wellbore Fluids: Tubing Oil, IA Gas Lift. BHT & BHP: L-1 19i 159.4°F & 3219.4 psia @ 6700' TVDSS Reference Log: Schlumberger Vision Log 04/06/2002 Note: Simops on -going Construction, drilling. If you have any questions concerning this Sundry Application, please don't hesitate to call me at 564-5093, hm: 345-2948, cell: 440-8008 or e-mail me at SmithBW @ BP.com Sincerely, J 0Bruce W. Smith GPB Borealis Development Engineer TREE = 4-1/16" 5M CIW WELLHEAD = - 11" FMC ACTUATOR= N/A KB. ELEV = 78.9' BF. ELEV = PORT KOP = 948' Max Angle = 58 @ 5502' Datum MD = KBG-2 Datum TV D = 8800' SS 9-5/8" CSG, 40#, L-80, ID = 8.681" H 2919' Minimum D = 3.725" @ 8982' 4-1/2" HES XN LANDING NIPPLE PERFORATION SUMMARY REF LOG: SWS DENSITY/NEUTRON 03/27/02 ANGLEATTOP PERF: 26@8850' Note: Refer to Production DB for historical rf data SIZE SPF INTERVAL Opn/Sgz DATE 4-1/2" 4 8850-8852 S 04/13/02 4-1/2" 4 8947-8949 S 04/13/02 3-3/8" 6 9092-9106 O 05/07/02 3-3/8" 6 9058-9084 O 5/9/2002 4-112" 5 9160-9161 S 04/13/02 I PBTD 9556' 7" CSG, 26#, L-80, BTC -MOD, ID = 6.276"9609' I SAFETY NOTES: — -----------------------I L-1 19 1014' 9-5/8" TAMPORT COLLAR 2287' 4-1/2" X LA NDING NIP, ID = 3.813" GAS LFT MANDRFLS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 4460 3487 54 KBG-2 DMY BK -5 0 04/15/02 2 7445 5303 43 KBG-2 DMY BK -5 0 04/15/02 1 8754 6373 24 KBG-2 RP I BK -5 16 04/15/02 8823 H 4-1 /2" X LA NDING NIP, ID =3.813" 8834' 7" X 4-1/2" BKR PREMIER PKR, ID = 8914' 7' MA RKER JT W/ RA TAG 8958' H 7' X 4-1/2" BKR S-3 PKR. ID = 3.875" 8971' —�4-1 /2" X LANDING NIP, ID= 3.813" 4-12" HES XN LANDING NIP, ID = 3.725" 8995' H4-12" WLEG, ID = 3.958" 9150' H EZSV (04/13/02) 9384' H 7" MARKER JT W/ RA TAG DATE REV BY COMMENTS DATE REV BY COMMENTS 04/16/02 JLMXK ORIGINAL COMPLETION 5(7-9/02 CWS/KK ADPERFS PRUDHOE BAY UNIT WELL: L-119 PERMIT No: 2020640 API No: 50-029-23077-00 SEC 34, T1 2N, R11 E, 2601' NSL, 3574' WEL BP Exploration (Alaska) i MECHANICAL INTEGRITY REPORT H P U D D A.T OPER & FIELD .1 1 -e -j F G. E I j S-7 I 7W -ELL DATA TD TIVD; :?BTD: -MD 60 7 TVD Casing: Shoe: %0 MD 19L TVD; DV-. 1-M -TVD 7 S h o e T D T COP HD T �1 D _Uoinz: /1"Packer "Vr f TVD ; S e t a t Q o 1e S e mr and Perfs to ,.Alq-C A T TNTEGRITY - PART I I -2- �., -I r-.Ld I .t, -A - , nnu.,,-us'Pr-ess Test:�, -P ,,.1-5 min I 50 min 4,4 C o=eT.i t s m oII V,'A ' T CF, -A N 7 CrAL TETE GRITY PART 12 Cement Volumes:- Amt. DV Cunt 7ol to cover per -;:_:s 12& b/o/c, 3 7. I -D i.-%eoret--Lcal TOC Cement Bond Log (Yes or No) In AOGCC File zone above per:Es CBL Evaluation Produation, Log: T- y -.D e Evaluation CON(LUS70jqS 7 al f2: 1II .4ni 4-1 .1 1 -e -j 4-1 Date: July 2, 2002 c Oct -O -70 RECEIVED Attn: Tom Maunder, AOOCC JUL 2 2002 FAN: 907-276-7542 Ak*a4il&GacCon CO*WM Re: BOP Test A� Well: Susan Dionne #3 Rig - Glacier Drilling #1 Marathon had planned to request an extension for the weekly scheduled BOP test:until final TD was reached at +/-10200 ft MD and the bit pulled. However, while drilling at 9797' MD, a wash out has occurred somewhere in the drill:;string and the pipe is being tripped to surface looking for the washed out pipe, Therefore, this is notice that Marathon will test BOP's today, Tuesday, 71212002. Estimated start time for the test is 11:00 am, 71212002. This note is in response to a conversation with Tom Maunder, A0GGG at 08:43 am,: 7/2/2002. It is understood that AOGCC witness for the test is waived. Gene Anderson Marothon Oil Company Drilling Supervisor Se6ior Drilling Engineer If there are any questions about this fax, please call 907-252-1913. _._... (IAI%4M+.-C 7n_P_inr `OOL9 Z9`OSR$ 13r38V-1 dH :A8 INN STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well ® Oil ❑ Gas ❑ Suspended ❑ Abandoned ❑ Service Pre -Produced Injector - Water & MI 2. Name of Operator BP Exploration (Alaska) Inc. 7. Permit Number 202-064 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 8. API Number 50-029-23077-00 4. Location of well at surface9. 2601' NSL, 3574' WEL, SEC. 34, T1 2N, R11E, UM At top of productive Interval } V 1575' NSL, 183' WEL, SEC. 27, T12N, R11E, UM At total depthSi; _ , 1694' NSL, 69' WEL, SEC. 27, T12N, R11 E, UM--.._�-� _ _ �- `' " 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation'and Serial No. RKB = 78.9' ADL 028239 Unit or Lease Name Prudhoe Bay Unit 10. Well Number L-1 19i 11. Field and Pool Prudhoe Bay Field /Borealis Pool (Undefined) 12. Date Spudded 03/27/2002 13. Date T.D. Reached 1 4/5/2002 14. Date Comp., Susp., or Aband. 5/7/2002 15. Water depth, if offshore N/A MSL 16. No. of Completions I One 17. Total Depth (MD+TVD) 9624 7197 FT 18. Plug Back Depth (MD+TVD) 9140 6734 FT 19. Directional Survey ® Yes ❑ No 20. Depth where SSSV set (Nipple) 2287' MD 21. Thickness of Permafrost 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, LWD , CCL, CBL / VDL , GR, DIR , RES, DEN, NEU , USIT 23. CASING LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BOTTOM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 107' 42" 260 sx Arctic Set (Approx.) 9-5/8" 40# L-80 29' 2919' 12-1/4" 525 sx AS I I I Lite 290 sx Class 'G' 7" 26# L-80 26' 9608' 8-3/4" 606 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom and interval, size and number) 3-3/8" Gun Diameter, 6 SPF MD TVD MD TVD 9058'-9084' 6656'-6681' 9092'- 9106' 6688'-6701' 25. TUBING RECORD SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2", 12.6#, L-80 8995' 8834'& 8958' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED See Attached. 27. PRODUCTION TEST Date First Production May 26, 2002 Method of Operation (Flowing, gas lift, etc.) Flowing Date of Test 5/24/2002 Hours Tested 4 PRODUCTION FOR TEST PERIOD OIL -BBL 707 GAS -MCF WATER 137 -BBL 268.75 CHOKE SIZE 0 GAS -OIL RATIO 194 Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY -API (CORR) 2. Brief description of lithology, porosity, fractures, apparen a n • as or. water. Submit core chips. No core samples were taken. J ! � U \1 2_7 '2002 State of Alaska Alaska Oil and Gas Conservation Commission Kaska Uj9 & Gas Cora. COi'd1i17I8Sr00 333 West 7th Ave., Suite 100 Anchorage Anchorage, Alaska 99501 .� Form 10-407 Rev. 07-01-80 U r y:� 1`,"'� K d M5 F �. Submit In Duplicate 29. Geologic Markers 30. Formation Tests Marker Name Measured True Vertical Include interval tested, pressure data, all fluids recovered and Depth Depth gravity, GOR, and time of each phase. Top of Ugnu 3336' 2852' Schrader Bluff 'M' 5370' 4000' Schrader Bluff'N' 5899' 4291' Schrader Bluff '0' 6185' 4461' Base of OBf / Top of Colville 6598' 4716' Top of Kalubik 8920' 6526' Top of Kuparuk'D' 9055' 6653' Top of Kuparuk 'C' 9057' 6655' Top of Kuparuk'B' 9210' 6800' Top of Kuparuk 'A' 9379' 6961' State of Alaska Alaska Oil and Cas Conservation Commission A4 9404' 6985' 333 West 7th Ave., Suite 100 Anchorage, Alaska 99501 Top of Miluveach 9470' 7048' 31. List of Attachments: Sec. 25 Detail Information, Summary of Daily Drilling Reports, Surveys, Post Rig Summary and a Leak -Off Integrity Summary. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble Title Technical Assistant Date 0(0_;Z7-0:2� L-1191 202-064 Prepared By Name/Number: Sondra Stewman, 564-4750 Well Number Permit No. / Approval No. 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 cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -In, Other -explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 WELL NAME: 25. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) 9160'- 9161' Amount & Kind of Material Used Perf for Remedial Cement for 7" Casing (04/10/02) 9150' 8947'- 8949' 9150' 8935' Set EZSV (04/11/02) Perf for Remedial Cement for 7" Casing (04/11/02) Pump 20 Bbls Gasbloc Cement (04/11/02) Set EZSV (04/12/02) (Pushed down to 9140' on 04/13/02) 8850'- 8852' 8935' Perf for Remedial Cement for 7" Casing (04/12/02) Pump 20 Bbls Gasbloc Cement (04/13/02) Freeze Protected with 60 Bbis of McOH BP EXPLORATION': page 1. f 10 ` ..Re oOperations;Summa�rt Legal Well Name: L-119 Common Well Name: L-119 Spud Date: 3/27/2002 Event Name: DRILL+COMPLETE Start: 3/26/2002 End: 4/16/2002 Contractor Name: NABORS Rig Release: 4/16/2002 Rig Name: NABORS 9ES Rig Number: 9-ES Date From - To: Hours Activity Code NPT Phase : - De"scription of 4per6t'ions 3/26/2002 00:00 - 10:30 10.50 MOB P PRE Wait on removal test equip L-120. Cut drlg line, service rig, 02:30 - 03:30 1.00 DRILL P SURF clean beneath rotary, misc 0.50 DRILL P SURF 04:00 - 14:00 maintenance during standby. Rig dn, prepare for move this DRILL P SURF 3/29/2002 00:00 - 03:00 3.00 time period. P 10:30 - 20:30 10.00 MOB P 0.50 PRE PJSM (Rig move), disconnect pit complex, ready shop for SURF move. Move pits to side. Move sub away from well. Top drive maintenance. Rig do diverter line. Lay matting boards over L-119. Spot sub over well. Spot pit complex to sub base. 20:30 - 21:30 1.00 RIGU P PRE Make all connections plumbing / electrical - steam, mud, fuel. 21:30 - 00:00 2.50 DRILL P SURF Take water to pits, begin build spud mud. Nipple up riser, wash pipe maintenance during mud mixing. NABORS RIG 9-ES ACCEPTED 2130 HRS THIS DATE 03/26/2002 WELL L-1191 3/27/2002 00:00 - 02:00 2.00 DRILL P SURF Install diverter valves, prepare for spud. 02:00 - 05:30 3.50 DRILL P SURF PJSM (Handling bha), make up bha #1, 12 1/4 spud assy. Stand back DCs, make up dretnl assy, motor, mwd, orient same. 05:30 - 06:30 1.00 DRILL P SURF Pre-spud meeting, all personnel. 06:30 - 07:30 1.00 DRILL P SURF Fill lines, test, shallow test mwd, circ spud mud at 20" shoe 107 ft. 07:30 - 10:30 3.00 DRILL P SURF Spud in, commence drill ahead 12 1/4 hole dretnl, 107 - 358 ft. 10:30 - 12:00 1.50 DRILL P SURF Poh, install jars, wash to btm 358 ft. No fill. 12:00 - 00:00 12.00 DRILL P SURF Resume drill ahead 358 - 1476 ft. WOB 25, RPM 70, SPP 2320, GPM 650, SPM 110 Up 77, Dn 70, Rot 76 AST = 5.1 hrs ART = 4 hrs 3/28/2002 00:00 - 02:00 2.00 DRILL P SURF 02:00 - 02:30 0.50 DRILL P SURF 02:30 - 03:30 1.00 DRILL P SURF 03:30 - 04:00 0.50 DRILL P SURF 04:00 - 14:00 10.00 DRILL P SURF 14:00 - 14:30 0.50 DRILL P SURF 14:30 - 16:30 2.00 DRILL P SURF 03:30 - 05:00 1 1.501 CASE IP I I SURF SPUD WELL L-119 THIS DATE 0730 HRS NABORS RIG 9 -ES Cont drill ahead 12 1/4 hole dretnl, 1476 - 1756 ft. Circ for wiper trip. Flow check, poh wiper trip to hwdp. Wellbore good cond, intermittent drag to 15K. No swabbing / losses. Rih, wash 90 ft to btm, no fill. Resume drill ahead 1756 - 2944 td as confirmed on site geologist. Circ / cond at td. Flow check, poh for 9 5/8 csg. Intermittent overpull to 25K. No losses / swabbing. Handle bha #1, lay do dretnl assy. Clear / clean floor all unneeded tools. Place csg tools on rig floor, rig up same. Make up shoe track, rih, test float equip. Floats holding. Follow shoe track with 9 5/8 L-80, 40#, BTC csg to 1450 ft. Cont rih 9 5/8 csg to td 2922 ft. No sticking, no losses. MU Idg jt to mandrel csg hgr, lay out Franks tool, make up cmt hd. Circ / cond mud for cmt. Full returns. No packoff, no losses. Recip csg during circ. Printed: 4/22/2002 11:37:06 AM 16:30 - 18:30 2.00 DRILL P SURF 18:30 - 19:00 0.50 DRILL P SURF 19:00 - 21:00 2.00 CASE P SURF 21:00 - 21:30 0.50 CASE P SURF 21:30 - 00:00 2.50 CASE P SURF 3/29/2002 00:00 - 03:00 3.00 CASE P SURF 03:00 - 03:30 0.50 CASE P SURF 03:30 - 05:00 1 1.501 CASE IP I I SURF SPUD WELL L-119 THIS DATE 0730 HRS NABORS RIG 9 -ES Cont drill ahead 12 1/4 hole dretnl, 1476 - 1756 ft. Circ for wiper trip. Flow check, poh wiper trip to hwdp. Wellbore good cond, intermittent drag to 15K. No swabbing / losses. Rih, wash 90 ft to btm, no fill. Resume drill ahead 1756 - 2944 td as confirmed on site geologist. Circ / cond at td. Flow check, poh for 9 5/8 csg. Intermittent overpull to 25K. No losses / swabbing. Handle bha #1, lay do dretnl assy. Clear / clean floor all unneeded tools. Place csg tools on rig floor, rig up same. Make up shoe track, rih, test float equip. Floats holding. Follow shoe track with 9 5/8 L-80, 40#, BTC csg to 1450 ft. Cont rih 9 5/8 csg to td 2922 ft. No sticking, no losses. MU Idg jt to mandrel csg hgr, lay out Franks tool, make up cmt hd. Circ / cond mud for cmt. Full returns. No packoff, no losses. Recip csg during circ. Printed: 4/22/2002 11:37:06 AM • EPLC7F�T1'C1N Page 2 of 1.0. BP pera ions urnrnary epo Legal Well Name: L-119 Common Well Name: L-119 Spud Date: 3/27/2002 Event Name: DRILL+COMPLETE Start: 3/26/2002 End: 4/16/2002 Contractor Name: NABORS Rig Release: 4/16/2002 Rig Name: NABORS 9ES Rig Number: 9 -ES ate on of Operations D : ` From - To Hours Activity Code : NPT ::Phase . Descripti 3/29/2002 03:30 - 05:00 1.50 CASE P SURF Up 140 do 111 05:00 - 08:00 3.00 CASE P SURF PJSM (Cmt Procedure) Pump 5 bbl CW100, test lines to 3500 psi. Pump remaining 5 bbl CW100, drop btm plug, (verified), pump 75 bbls Mudpush XL 10.2# Mix / pump 404 bbls 10.7 ppg, ASIII Lite lead slurry. Mix / pump 62.5 bbls 15.8 ppg class G tail slurry. Drop top plug (verified), chase with 10 bbl 1-12o. Displace with rig pumps 204 bbls mud at 9 bpm. Bump at correct stroke count. FCP = 800 psi, Build to 1350, hold 5 min, bleed and check floats holding. Okay. Note: Pipe reciprocation until cmt 50% annulus. 08:00 - 08:30 0.50 CASE P SURF Attempt remove Idg jt. Can not back out with 30000 torque. 08:30 - 11:30 3.00 CASE N SFAL SURF PJSM, Loosen riser, dresser sleeve, PU to cut Idg jt. Cut Idg jt above Hydril, remove riser. 11:30 - 13:30 2.00 CASE P SURF ND and lay out Hydril. 13:30 - 16:00 2.50 CASE N SFAL SURF Cut Idg jt from csg hgr. Remove Idg jt. Cut running tool off mandrel hanger. 16:00 - 17:30 1.50 WHSUR P SURF Install FMC casing head. Test to 1000 psi -OK. 17:30 - 18:30 1.00 CASE P SURF Clear rig floor all csg related equip, change bails. 18:30 - 21:30 3.00 DRILL P SURF Nipple up bope, DSA, tbg hd. 21:30 - 00:00 2.50 DRILL P SURF Set test plug, prepare for test bope. Commence test bope. Witness waived by Lou Grimaldi AOGCC. Approx 50% test complete at end of tour. 3/30/2002 00:00 - 02:00 2.00 BOPSU P PROD1 Complete test bope, accumulator volume / press / test as per BP specs. All tests successful, no re -tests. Witness waived by Lou Grimaldi AOGCC 02:00 - 03:00 1.00 DRILL P PROD1 Service top drive, blocks. 03:00 - 03:30 0.50 DRILL P PROD1 Re -locate bha / hwdp to drlr side mast. 03:30 - 10:00 6.50 DRILL P PROD1 Pick up 4" dp from shed, stand back in mast. 10:00 - 14:30 4.50 DRILL P PROD1 PJSM (bha), make up bha #2 / bit #2, orient motor / mwd, rih, shallow test dretnl assy. 14:30 - 16:00 1.50 DRILL P PROD1 Follow bha with 4" dp to 2693 ft. 16:00 - 17:00 1.00 DRILL P PROD1 Prepare and test 9 5/8 csg to to 4000 psi. / 30 min. Chart and document. Test good. 17:00 - 19:30 2.50 DRILL P PROD1 Wash to cmt at 2826 ft, cont drill out cmt, float collar, cmt, guide shoe, and 20 ft new frmtn. to 2965 ft. 19:30 - 20:30 1.00 DRILL P PROD1 Flow check. Displace well with new 9.3 ppg LSND drlg fluid. 20:30 - 21:30 1.00 DRILL P PROD1 Pull inside 9 5/8 csg. Perform LOT. 650 psi surface press = 14 ppg EMW 21:30 - 00:00 2.50 DRILL P PROD1 Flow check, Resume drill ahead 8 3/4 hole dretnl 2965 - 3626 ft. WOB 16, RPM 55, GPM 550, PRESS 1800 Up 96, Dn 75, Rot 86 AST = 0 hrs, ART = 1.5 hrs 3/31/2002 00:00 - 02:30 2.50 DRILL P PROD1 Drill ahead 8 3/4 hole dretnl, 3626 - 4280 ft. 02:30 - 03:30 1.00 DRILL P PROD1 Circ sweep for wiper trip. Blow do top drive. 03:30 - 04:00 0.50 DRILL P PROD1 Flow check, poh to 4009 ft. 20 - 25K overpull. 04:00 - 05:30 1.50 DRILL P PROD1 Begin backream tight hole 4009 - 3450 ft. 80 rpm, 460 gpm, Printed: 4/22/2002 11:37:06 AM ::BP EXPLORATION Pgge.3 of 1:0` tJ aerations Summa Re ort p rY , p Legal Well Name: L-119 Common Well Name: L-119 Spud Date: 3/27/2002 Event Name: DRILL+COMPLETE Start: 3/26/2002 End: 4/16/2002 Contractor Name: NABORS Rig Release: 4/16/2002 Rig Name: NABORS 9ES Rig Number: 9 -ES Date From - To 'Hours Activity Code NPT Phase Description of Operations 3/31/2002 04:00 - 05:30 1.50 DRILL P PROD1 780 psi. 05:30 - 08:00 2.50 DRILL N STUC PROD1 Work upward through tight hole to 3138 ft. No further progress. Multiple attempts at regaining circ, and rotation. No upward or downward movement possible. 08:00 - 12:00 4.00 DRILL N STUC PROD1 Jar on string, attempt work free. Continued attempts rotation / circulation. 12:00 - 13:00 1.00 DRILL N STUC PROD1 Inspect mast / top drive. 13:00 - 13:30 0.50 DRILL N STUC PROD1 Make up XOs and surface jars. 13:30 - 15:30 2.00 DRILL N STUC PROD1 PJSM (Jarring procedure), Commence surface jarring. Inspect mast one hour intervals. 15:30 - 16:00 0.50 DRILL N STUC PROD1 Lay do surface jars. 16:00 - 18:30 2.50 FISH N STUC PROD1 Mobilize Schlum, wait on arrival wireline unit. 18:30 - 00:00 5.50 FISH N STUC PROD1 Place Schlum equip on floor, rig up same for wireline work. PJSM (Pulling source, Shot back off), Pull Nuc source, contain and lay out. Rig up single shot for string backoff. Work reverse torque do to backoff point (Top of Jars). Rih wireline with single shot. 1500 ft depth at end of tour. 4/1/2002 00:00 - 01:30 1.50 FISH N STUC PROD1 Rih wireline single shot, CCL, shoot and back off at top of jars, 2890 ft. flow check. 01:30 - 03:00 1.50 FISH N STUC PROD1 Lay do top sgl 4" dp, lay out all Schlum equip, release unit. 03:00 - 04:30 1.50 FISH N STUC PROD1 Pump wt pill, poh with dp / hwdp. 04:30 - 05:30 1.00 FISH N STUC PROD1 Place fishing tools on rig floor, strap / record dimensions. 05:30 - 07:00 1.50 FISH P PROD1 Service top drive, crown, blocks, slip / cut drlg line. 07:00 - 09:00 2.00 FISH N STUC PROD1 PU DCs from shed, MU jar / fish assy. RIH same. 09:00 - 10:00 1.00 FISH N STUC PROD1 Follow bha with 25 stds 4" dp. 10:00 - 10:30 0.50 FISH N STUC PROW Circ btms up. 10:30 - 16:30 6.00 FISH N STUC PROD1 Wash to fish, engage at 2895 ft. Screw in with 20000 torque. Commence jarring down on fish, multiple methods, with pump, no pump, with torque, no torque. Inspect mast at two hr intervals during jarring. Work torque into fish with upward movement. Note progress, fish moving, cont poh slowly, swabbing but filling through drill pipe. Regain circ at 2300 ft. Note: fish free at 1500 hrs. 16:30 - 17:00 0.50 FISH N STUC PROD1 Circ btms up. 17:00 - 17:30 0.50 FISH N STUC PROD1 Resume poh with fish. 17:30 - 21:30 4.00 FISH N STUC PROD1 Stand bk 3 stds DCs, lay do remainder, lay out all fishing tools, clear floor. Fish retrieved 100 % 21:30 - 00:00 2.50 FISH N STUC PROD1 Break out saver sub, XOs, top drive quill, begin inspection with Tuboscope. 4/2/2002 00:00 - 01:30 1.50 FISH N STUC PROD1 Finish inspecting TD quill. MU tapered sub & lower saver sub. 01:30 - 03:00 1.50 FISH N STUC PROD1 PU & MU 8.75" clean out assembly. 03:00 - 05:00 2.00 FISH N STUC PROD1 RIH to 2565'. Breaking, doping, & making all connections. Continue in hole to 2665'. Started pushing down @ 10-15k. 05:00 - 06:30 1.50 FISH N STUC PROW Circ casing clean. Stage pumps up to 650 gpm w/ 120 rpm. Wash to shoe. 06:30 - 07:00 0.50 FISH N STUC PROD1 CBU w/ above parameters. Recovered quite a bit of sand & clay. 07:00 - 10:30 3.50 FISH N STUC PROD1 Wash to 4280'. Circulate bottoms up every five stands. 10:30 - 11:00 0.50 FISH N STUC PROD1 Circulate hole clean @ TD - 650 GPM @ 1850 psi. 11:00 - 12:30 1.50 FISH N STUC PROD1 Monitor well, pump slug, POH 12:30 - 14:00 1.50 FISH N STUC PROW Stand back HWDP, UD BHA> 14:00 - 17:30 3.50 FISH N STUC PROD1 Clear floor, M/U BHA # 5. Shallow test MWD. Printed: 4/22/2002 11:37:06 AM BP EXPLORATION Page 4 of 10 peratioh umrnary Report Legal Well Name: L-119 Common Well Name: L-119 Spud Date: 3/27/2002 Event Name: DRILL+COMPLETE Start: 3/26/2002 End: 4/16/2002 Contractor Name: NABORS Rig Release: 4/16/2002 Rig Name: NABORS 9ES Rig Number: 9 -ES Date From - To Hours Activity Code ;NPT ; . Phase Description o . OperatIons 4/2/2002 17:30 - 19:00 1.50 DRILL P PROD1 RIH to 4268' 1 OK. 19:00 - 19:30 0.50 DRILL P P PROD1 Wash to 4280'- No Fill. CHANGE OUT LINERS ON BOTH PUMPS TO 5". SERVICE 19:30 - 00:00 4.50 DRILL P PROD1 Drill from 4280' to 5117'. 600 GPM @ 2900 psi. TQ 4800 - off, TOP DRIVE, BLOCKS & CROWN. 6000 on. 80 RPM CUT & SLIP DRILLING LINE 58'. 08:00 - 11:00 3.00 DRILL P WOB 5- 18K. AST = 0.46 Hrs. ART = 1.79 Hrs. 4/3/2002 00:00 - 01:00 1.00 DRILL P PROD1 DRILL FROM 5117' TO 5398'. 600 GPM @ 2920 PSI. WOB = BOTTOM. TAKE SPR's. 11:00 - 00:00 13.00 DRILL P 5 - 15K. TQ = 6000 DRILL FROM 6985' TO 8104'. LOST RETURNS P/U = 123K, S/O = 87K, ROT = 105K. AST = 0.25 HRS. ART BACKREAMING. ABLE TO ROTATE AND RECIPROCATE. = 0.60 HRS. BHA BALLED. SLOWED RATE, PUMPED NUT PLUG 01:00 - 01:30 0.50 DRILL P PROD1 CIRCULATE HI - VIS WIEGHTED SWEEP. SWEEP. STARTED CLEANING UP BEFORE SWEEP WAS 01:30 - 03:30 2.00 DRILL P PROD1 BACK REAM TO 5021' WHILE CIRC. 2 nd WIEGHTED AT BIT. CLEANED BHA AND REGAINED FULL RETURNS. SWEEP. PULL DRY TO 4777'. =50K OVER PULL. BACK CONTINUED DRILLING TO 8198' WOB = 1 OK TO 25K REAM TO 4550'. LOSS OF PARTIAL RETURNS. TQ ON = 9500 TO 12,000. 600 GPM @ 4100 PSI. P/U = 188K, 03:30 - 04:30 1.00 DRILL P PROD1 CIRCULATE BAROFIBER AT REDUCED RATE - REGAINED S/O = 102K, ROT = 133K FULL RETURNS. ALL ROTATATION - 8.2 HRS. 04:30 - 08:30 4.00 DRILL P P PROD1 CONTINUE BACKREAMING OUT OF HOLE TO SHOE. NO DRILL FROM 8198' TO 8478'. 600 GPM @ 4000 PSI. WOB = REAL CUTTINGS OVER SHAKERS. CLAY AND SOME SAND 10 - 25K. TQ. = 10 K. ONLY. 08:30 - 09:00 0.50 DRILL P PROD1 CIRC. HI - VIS SWEEP @ SHOE. CLAY AND VERY LITTLE SAND OVER SHAKERS. 09:00 - 09:30 0.50 DRILL P PROD1 SERVICE TOP DRIVE, BLOCKS. 09:30 - 10:30 1.00 DRILL P PROD1 RIH - HOLE VERY SLICK. ONLY 1 TO 2K DRAG THROUGHOUT. 10:30 -11:30 1.00 DRILL P PROD1 CIRC. HI - VIS SWEEP @ 600 GPM & 120 RPM. CLAY AND LITTLE SAND BACK. 11:30 - 23:00 11.50 DRILL P PROD1 DRILL FROM 5398' TO 6985'. HAD TO REDUCE CIRC RATE TO 575 GPM ( 348OPSI ) FOR LAST 400'- 5.5" LINERS REACHING PRESSURE LIMITATION. CIRC RATE 600 GPM PRIOR AST = . 58 ART = 6.97 23:00 - 00:00 1.00 DRILL P PROD1 CIRCULAT WIEGHTED HI - VIS SWEEP. CLAY AND SOME SAND OVER SHAKERS. 4/4/2002 00:00 - 03:30 3.50 DRILL P PROD1 POH TO 6580'- TIGHT & SWABBING. BACKREAM FROM 6580' TO OLD HOLE @ 5304. Printed: 4/22/2002 11:37:06 AM 03:30 - 05:00 1.50 DRILL P PROD1 PUMP SLUG, POH TO SHOE. NO PROBLEMS - MAX DRAG 1 OK. 05:00 - 08:00 3.00 DRILL P PROD1 CHANGE OUT LINERS ON BOTH PUMPS TO 5". SERVICE TOP DRIVE, BLOCKS & CROWN. CUT & SLIP DRILLING LINE 58'. 08:00 - 11:00 3.00 DRILL P PROD1 RIH WITH NO PROBLEMS. WASH LAST STAND TO BOTTOM. TAKE SPR's. 11:00 - 00:00 13.00 DRILL P PROD1 DRILL FROM 6985' TO 8104'. LOST RETURNS BACKREAMING. ABLE TO ROTATE AND RECIPROCATE. BHA BALLED. SLOWED RATE, PUMPED NUT PLUG SWEEP. STARTED CLEANING UP BEFORE SWEEP WAS AT BIT. CLEANED BHA AND REGAINED FULL RETURNS. CONTINUED DRILLING TO 8198' WOB = 1 OK TO 25K TQ ON = 9500 TO 12,000. 600 GPM @ 4100 PSI. P/U = 188K, S/O = 102K, ROT = 133K ALL ROTATATION - 8.2 HRS. 4/5/2002 00:00 - 04:30 4.50 DRILL P PROD1 DRILL FROM 8198' TO 8478'. 600 GPM @ 4000 PSI. WOB = 10 - 25K. TQ. = 10 K. Printed: 4/22/2002 11:37:06 AM BP EXPLORATIONPage 5`of 10 O`peratior s: SU Report: Legal Well Name: L-119 Common Well Name: L-119 Spud Date: 3/27/2002 Event Name: DRILL+COMPLETE Start: 3/26/2002 End: 4/16/2002 Contractor Name: NABORS Rig Release: 4/16/2002 Rig Name: NABORS 9ES Rig Number: 9 -ES Date From -To Hours Activity CodeNPT Phase Description of. Opera#ions 4/5/2002 00:00 - 04:30 4.50 DRILL P PROD1 P/U = 193K, S/O = 114K, ROT = 142K. AST = 1.5 HRS. ART = 1.56 HRS. WEIGHT MUD UP TO 10 PPG WHILE DRILLING LAST TWO STANDS. 04:30 - 06:00 1.50 DRILL P PROD1 CIRCULATE WEIGHTED HI -VIS SWEEP. 06:00 - 10:00 4.00 DRILL P PROD1 POH TO 7815'. 50 K OVERPULL & SWABBING. BACKREAM TO 6985' (OLD HOLE). 10:00 -11:00 1.00 DRILL P PROD1 RIH TO 8384'- NO PROBLEMS. 11:00 -11:30 0.50 DRILL P PROD1 WASH LAST STAND TO BOTTOM @ 8478' 11:30 - 22:00 10.50 DRILL P PROD1 DRILL FROM 8478' TO 9624'- TD PER GEOLOGIST. WOB = 5-15K. TQ = 10.5K 535 GPM @ 4100 PSI. P/U = 198K, S/O = 128K, ROT = 158K. ART = 6.2 HRS. AST = 0.6 HRS. 22:00 - 23:30 1.50 DRILL P PROD1 CIRCULATE WEIGHTED HI -VIS SWEEP. 23:30 - 00:00 0.50 DRILL P PROD1 POH FOR WIPER TRIP TO SHOE. 4/6/2002 00:00 - 06:30 6.50 DRILL P PROD1 CONTINUUE POH TO 8550'. PULLING 50K OVER & SWABBING. BACKREAM FROM 8550' TO 6224'. PUMP WEIGHTED HI -VIS SWEEP STARTING AT 7451'. POH DRY FROM 5400' TO SHOE @ 2920'. 06:30 - 07:00 0.50 DRILL P PROD1 CIRCULATE SWEEP AT SHOE. NEGLIGIBLE RETURNS. 07:00 - 08:30 1.50 DRILL P PROD1 CUT & SLIP DRILLING LINE 45'. SERVICE TOP DRIVE, BRAKES & CROWN. 08:30 - 12:00 3.50 DRILL P PROD1 RIH TO 9537'. NO PROBLEMS. WASH LAST STAND TO BOTTOM @ 9624'. NO FILL. 12:00 - 15:30 3.50 DRILL P PROD1 CIRCULATE TWO CONSECUTIVE LO - HI VIS SWEEPS - 565 GPM, 4060 PSI. RECIPROCATING WITH 120 RPM. HAD SOME CUTTINGS RETURNED W/ FIRST SWEEP. SECOND SWEEP CLEAN. SPOT CASING RUNNING PILL. 15:30 -19:30 4.00 DRILL P PROD1 POH WITH DP. OPEN HOLE SLICK. 19:30 - 22:30 3.00 DRILL P PROD1 STAND BACK HWDP. L/D BHA. UNLOAD SOURCE. CLEAR & CLEAN FLOOR. 22:30 - 00:00 1.50 CASE P PROD1 PULL WEAR BUSHING. INSTALL TEST PLUG. CLOSE BLIND RAMS AND CHANGE OUT TOP PIPE RAMS TO 7". 4/7/2002 00:00 - 00:30 0.50 CASE P PROD1 TEST RAM DOOR SEALS TO 3500 PSI. R/D TEST EQUIP. 00:30 - 02:30 2.00 CASE P PROD1 MAKE DUMMY RUN W/ HGR. & LDG. JT., C/O TO LONG BAILS. R/U CSG. EQUIP. 02:30 - 05:30 3.00 CASE P PROD1 PJSM. M/U FLOAT JTS. R/U FRANKS TOOL. RUN 7 " PRODUCTION CASING. 05:30 - 06:00 0.50 CASE N SFAL PROD1 MAKING UP PUP JT WITH R/A PIP TAG, SCHLUMBERGER INSTALLED SELF TAPPING SCREW POPPED OUT OF COLLAR. NOT IN SEAL AREA - BAKER LOCKED SAME. NOTIFIED SCHLUMBERGER. 06:00 - 08:00 2.00 CASE P PROD1 CONTINUED RIH W/ 7" CASING TO 2322'. RCVD CALL FROM SWS. NRC REQUIRES PHYSICAL VERIFICATION OF PIP TAG MATERIAL. 08:00 - 13:30 5.50 CASE N SFAL PROD1 WAIT ON SWS. SWS ARRIVED AND CHECKED ALL CREW AND RIG AREA WITH GEIGER COUNTER. NO TAG DISCOVERED. NOW ASSUMED TO BE IN STRING. 13:30 - 17:00 3.50 CASE N SFAL PROD1 POH TO R/A MARKER JT. VERIFIED THAT MARKER WAS IN COLLAR. REMOVED JT FROM STRING AND REPLACED WITH ANOTHER PUP JT WITH PIP TAGS PROPERLY INSTALLED. RIG UP TO RUN IN HOLE W/ CASING. Printed: 4/22/2002 11:37:06 AM BR EXPLORATION Page 6 of 10 Operations : Su M110 Report Legal Well Name: L-119 Common Well Name: L-119 Spud Date: 3/27/2002 Event Name: DRILL+COMPLETE Start: 3/26/2002 End: 4/16/2002 Contractor Name: NABORS Rig Release: 4/16/2002 Rig Name: NABORS 9ES Rig Number: 9 -ES Date;' From - To Hours Activity' Code :'NPT Phase "Description of Operations 4/7/2002 17:00 - 19:00 2.00 CASE N SFAL PROD1 RIH TO 2322'. 19:00 - 20:00 1.00 CASE P PROD1 CONTINUE RUNNING 7" CASING AS PER PROGRAM TO 9 PJSM W/ DOWELL, HES & ALL HANDS. 1 st. STAGE: DROP BOTTOM PLUG. PUMP 5 BBLS CW -100. LOAD TOP PLUG. TEST LINES TO 4500 PSI. PUMP 25 BBLS CW -100 FOLLOWED BY 40 BBLS MUDPUSH XL SPACER @ 11.5 PPG. PUMP 46 BBLS, 15.8 PPG LATEX DESIGN, CLASS G SLURRY. DROP TOP PLUG & CHASE WITH 5 BBLS WATER. SWITCH TO RIG PUMPS AND DISPLACE WITH 361 BBLS 10.2 PPG MUD. BUMP PLUG W/ 1500 PSI. RECIPROCATED CSG THROUGHOUT - 2% TO 3% RETURNS. CHECK FLOATS - OK. 2 nd. STAGE: LOAD CLOSING PLUG. OPEN ES CEMENTER WITH 3250 PSI. ATTEMPT TO ESTABLISH RETURNS - NO SUCCESS. PUMP 50 BBLS CW -100 FOLLOWED BY 40 BBLS 11.5 PPG MUDPUSH XL. PUMP 80 BBLS LATEX DESIGN, 15.8 PPG, CLASS G CEMENT SLURRY. DROP CLOSING PLUG AND CHASE WITH 5 BBLS WATER. CONT. DISPLACING WITH 263 BBLS MUD. BUMP PLUG AND CLOSE ES -CEMENTER WITH 2300 PSI. BLEED OFF PRESSURE - NO BACKFLOW - TOOL CLOSED. PRESSURE CHARTS INDICATED GOOD LIFT WITH CEMENT IN ANNULUS ON BOTH STAGES. R/D CEMENT HEAD. BACK OUT LANDING JT. R/D CASING EQUIP., C/O BAILS. INSTALL PACK -OFF, R.I.L.D.S., TEST TO 5000 PSI. INSTALL TEST PLUG, CLOSE BLINDS, C/O TOP RAMS BACK TO VARIABLES. TEST BOPE. ALL RAMS, MANIFOLDS AND VALVES TO 250 / 4000 PSI. ANNULAR TO 3500 PSI. WITNESS WAIVED BY JEFF JONES, AOGCC. INSTALL WEAR BUSHING. R/D TEST EQUIP. SERVICE TOP DRIVE Printed: 4/22/2002 11:37:06 AM 12:00 - 17:30 5.50 CEMT P PROD1 5/8" SHOE @ 2920'. 17:30 - 18:30 20:00 - 20:30 0.50 CASE P PROD1 PROD1 CIRCULATE 150% CASING VOLUME. 1.00 20:30 - 22:30 2.00 CASE P PROD1 CONT. RIH W/ CSG. UP AND DOWN WEIGHTS OK. START BOPSU P PROD1 20:30 - 00:00 3.50 TO LOSE DISPLACEMENT. SLOWED DOWN TO 20 - 30 FT P PROD1 4/9/2002 00:00 - 00:30 0.50 BOPSUP PER MIN. STILL NOT GETTING PROPER DISPLACEMENT. PROD1 00:30 - 01:00 0.50 CASE P NO DISPLACEMENT @ 4360'. PROD1 22:30 - 23:00 0.50 CASE P PROD1 CIRC. BOTTOMS UP @ 4360. INITIAL RTNS 60 %. 100% RETURNS W/ BOTTOMS UP. TOTAL 60 BBLS. LOST WHILE CIRCULATING. 23:00 - 00:00 1.00 CASE P PROD1 CONTINUE RUNNING 7" PROD. CSG. 4/8/2002 00:00 - 09:00 9.00 CASE P PROD1 CONTINUE RIH W/ 7" CASING. CIRCULATE @ 6000'. ACHIEVED ONLY 50% RETURNS. CONT. RIH TO 9580', BREAKING CIRC. EVERY 10 JTS. MINIMAL RETURNS - 2% TO 3% 09:00 - 09:30 0.50 CASE P PROD1 L/D FRANKS TOOL, M/U HANGER & LANDING JT, LAND CASING W/ SHOE @ 9609. 09:30 - 12:00 2.50 CEMT P PROD1 M/U CEMENT HEAD. STAGE UP PUMPS ATTEMPTING TO ESTABLISH CIRCULATION WHILE RECIPROCATING CASING. 2% TO 3% RETURNS ONLY. PJSM W/ DOWELL, HES & ALL HANDS. 1 st. STAGE: DROP BOTTOM PLUG. PUMP 5 BBLS CW -100. LOAD TOP PLUG. TEST LINES TO 4500 PSI. PUMP 25 BBLS CW -100 FOLLOWED BY 40 BBLS MUDPUSH XL SPACER @ 11.5 PPG. PUMP 46 BBLS, 15.8 PPG LATEX DESIGN, CLASS G SLURRY. DROP TOP PLUG & CHASE WITH 5 BBLS WATER. SWITCH TO RIG PUMPS AND DISPLACE WITH 361 BBLS 10.2 PPG MUD. BUMP PLUG W/ 1500 PSI. RECIPROCATED CSG THROUGHOUT - 2% TO 3% RETURNS. CHECK FLOATS - OK. 2 nd. STAGE: LOAD CLOSING PLUG. OPEN ES CEMENTER WITH 3250 PSI. ATTEMPT TO ESTABLISH RETURNS - NO SUCCESS. PUMP 50 BBLS CW -100 FOLLOWED BY 40 BBLS 11.5 PPG MUDPUSH XL. PUMP 80 BBLS LATEX DESIGN, 15.8 PPG, CLASS G CEMENT SLURRY. DROP CLOSING PLUG AND CHASE WITH 5 BBLS WATER. CONT. DISPLACING WITH 263 BBLS MUD. BUMP PLUG AND CLOSE ES -CEMENTER WITH 2300 PSI. BLEED OFF PRESSURE - NO BACKFLOW - TOOL CLOSED. PRESSURE CHARTS INDICATED GOOD LIFT WITH CEMENT IN ANNULUS ON BOTH STAGES. R/D CEMENT HEAD. BACK OUT LANDING JT. R/D CASING EQUIP., C/O BAILS. INSTALL PACK -OFF, R.I.L.D.S., TEST TO 5000 PSI. INSTALL TEST PLUG, CLOSE BLINDS, C/O TOP RAMS BACK TO VARIABLES. TEST BOPE. ALL RAMS, MANIFOLDS AND VALVES TO 250 / 4000 PSI. ANNULAR TO 3500 PSI. WITNESS WAIVED BY JEFF JONES, AOGCC. INSTALL WEAR BUSHING. R/D TEST EQUIP. SERVICE TOP DRIVE Printed: 4/22/2002 11:37:06 AM 12:00 - 17:30 5.50 CEMT P PROD1 17:30 - 18:30 1.00 CEMT P PROD1 18:30 - 19:30 1.00 WHSUR P PROD1 19:30 - 20:30 1.00 BOPSU P PROD1 20:30 - 00:00 3.50 BOPSU P PROD1 4/9/2002 00:00 - 00:30 0.50 BOPSUP PROD1 00:30 - 01:00 0.50 CASE P PROD1 PJSM W/ DOWELL, HES & ALL HANDS. 1 st. STAGE: DROP BOTTOM PLUG. PUMP 5 BBLS CW -100. LOAD TOP PLUG. TEST LINES TO 4500 PSI. PUMP 25 BBLS CW -100 FOLLOWED BY 40 BBLS MUDPUSH XL SPACER @ 11.5 PPG. PUMP 46 BBLS, 15.8 PPG LATEX DESIGN, CLASS G SLURRY. DROP TOP PLUG & CHASE WITH 5 BBLS WATER. SWITCH TO RIG PUMPS AND DISPLACE WITH 361 BBLS 10.2 PPG MUD. BUMP PLUG W/ 1500 PSI. RECIPROCATED CSG THROUGHOUT - 2% TO 3% RETURNS. CHECK FLOATS - OK. 2 nd. STAGE: LOAD CLOSING PLUG. OPEN ES CEMENTER WITH 3250 PSI. ATTEMPT TO ESTABLISH RETURNS - NO SUCCESS. PUMP 50 BBLS CW -100 FOLLOWED BY 40 BBLS 11.5 PPG MUDPUSH XL. PUMP 80 BBLS LATEX DESIGN, 15.8 PPG, CLASS G CEMENT SLURRY. DROP CLOSING PLUG AND CHASE WITH 5 BBLS WATER. CONT. DISPLACING WITH 263 BBLS MUD. BUMP PLUG AND CLOSE ES -CEMENTER WITH 2300 PSI. BLEED OFF PRESSURE - NO BACKFLOW - TOOL CLOSED. PRESSURE CHARTS INDICATED GOOD LIFT WITH CEMENT IN ANNULUS ON BOTH STAGES. R/D CEMENT HEAD. BACK OUT LANDING JT. R/D CASING EQUIP., C/O BAILS. INSTALL PACK -OFF, R.I.L.D.S., TEST TO 5000 PSI. INSTALL TEST PLUG, CLOSE BLINDS, C/O TOP RAMS BACK TO VARIABLES. TEST BOPE. ALL RAMS, MANIFOLDS AND VALVES TO 250 / 4000 PSI. ANNULAR TO 3500 PSI. WITNESS WAIVED BY JEFF JONES, AOGCC. INSTALL WEAR BUSHING. R/D TEST EQUIP. SERVICE TOP DRIVE Printed: 4/22/2002 11:37:06 AM 4/9/2002 01:00 - 02:30 1.50 CASE P PROD1 M/U CLEAN - OUT BHA. 02:30 - 05:00 2.50 CASE P PROW RIH TO 6898'. 05:00 - 07:30 2.50 CASE P PROW WASH DOWN & TAG PLUG @ 6999'. DRILL OUT PLUG & ES -CEMENTER. 07:30 - 09:00 1.50 CASE P PROD1 CONTINUE RIH TO 9418'. 09:00 - 09:30 0.50 CASE P PROD1 WASH DOWN TO LANDING COLLAR @ 9523'. 09:30 - 13:30 4.00 CASE P PROD1 CIRCULATE CLEAN & DISPLACE MUD WITH 8.8 PPG BRINE. 13:30 - 14:30 1.00 CASE P PROW POH TO 6527'. 14:30 - 15:30 1.00 CASE P PROD1 SPOT PERF PILL ACROSS SCHRADER 15:30 - 18:30 3.00 CASE P PROD1 POH. STAND BACK DP, HWDP & 1 STAND DC. L/D REMAINDER BHA. 18:30 - 19:30 1.00 CASE P PROD1 LOT AND INJECTIVITY TEST ON 9 5/8" x 7" ANNULUS. LOT = 13.8 PPG. EMW. INJECTIVITY: 1 BPM @ 500 PSI, 2 BPM @ 700 PSI, 3 BPM @ 900 PSI. INITIALLY, THE DOWN TO 750 PSI. 19:30 - 20:00 0.50 CASE P PROD1 SERVICE BRAKES, CROWN & IRON ROUGHNECK. 20:00 - 00:00 4.00 CASE P PROD1 PJSM. R/U SWS E -LINE. RIH & LOG USIT. NO CEMENT IN KUPARUK ( LOWER SECTION - 1st STAGE). VERY POOR CEMENT IN SCHRADER ( UPPER SECTION - 2nd. STAGE). NOTIFIED BRUCE SMITH & ROBERT ODENTHAL. FREEZE PROTECTED 9 5/8" x 7" ANNULUS TO 2200' WITH 68 BBLS. OF DEAD CRUDE WHILE LOGGING. 4/10/2002 00:00 - 01:30 1.50 CASE P PROD1 POH W/ E -LINE. L/D USIT TOOL R/D SWS. 01:30 - 02:30 1.00 CASE P PROD1 TEST 7" CASING TO 4000 PSI. CHART FOR 30 MINUTES. 02:30 - 03:30 1.00 REMCM N CEMT PROD1 M/U 6 1/8" BIT & BHA. 03:30 - 06:30 3.00 REMCM N CEMT PROD1 RIH W/ 4" DP TO 9450'. 06:30 - 08:00 1.50 REMCM P PROD1 CUT & SLIP DRILLING LINE, INSPECT & ADJUST BRAKES, SERVICE TOP DRIVE & DRAWORKS. 08:00 - 10:00 2.00 REMCM N CEMT PROD1 TAG LANDING COLLAR @ 9523'. CBU AND DISPLACE BRINE W/ 10.0 PPG MUD. 10:00 - 14:00 4.00 REMCM N CEMT PROW POH. STAND BACK ALL. 14:00 - 00:00 10.00 REMCM N CEMT PROD1 R/U SWS E -LINE, SHOOTING NIPPLE & PRESSURE EQUIPMENT. M/U GUN # 1- 4.5" HSD, LOADED WITH 5 SPF ( 0.83" DIAM.HOLE). RIH AND CORRELATE ON STATION @ 9160'-9161'. FIRE & POH. MISFIRE. L/D ASSY. DIAGNOSTIC SHOWED BAD GAMMA RAY. L/D G/R & RIH W GUN & CCL. CORRELATE ON STATION & FIRE. POH ALL 5 SHOTS FIRED. L/D GUN. M/U SETTING TOOL AND 7" EZSV. 4/11/2002 00:00 - 07:00 7.00 REMCM N CEMT PROD1 RIH W/ HES EZSV PACKER, SET AT 9150'. RIH W SWS HSD 4.5" PERF GUN - 4 SPF. PERFORATE 8947' TO 8949'. TOTAL 9 - 0.83" HOLES. POH R/D SWS. 07:00 - 18:00 11.00 REMCM N CEMT PROD1 M/U HES STAR GUIDE STINGER ON DP & RIH. SPACE OUT INTO EZSV. P/U AND CIRCULATE DP VOLUME. STING INTO EZSV AND ATTEMPT CIRCULATION THROUGH PERFS. UNABLE TO ESTABLISH CIRC. BROKE DOWN @ 2520 PSI. @ 2 BPM. CONFERENCED WITH ANCHORAGE TEAM & DETERMINED PLAN FORWARD. RE-ESTABLISHED INJECTION RATE OF 1 BPM @ 1680 PSI. UN -STING FROM EZSV. PJSM W/ DOWELL.PUMP 5 BBLS CW -100. TEST LINES TO 4500 PSI. PUMP 5 BBLS CW -100. PUMP 20 BBLS 15.8 PPG LATEX GASBLOC CEMENT TAKING RETURNS THROUGH CHOKE - HOLDING Printed: 4/22/2002 11:37:06 AM B.P; EXPLORATION Page 8 of 10 R pe. -Cation epo`rt Legal Well Name: L-119 Common Well Name: L-119 Spud Date: 3/27/2002 Event Name: DRILL+COMPLETE Start: 3/26/2002 End: 4/16/2002 Contractor Name: NABORS Rig Release: 4/16/2002 Rig Name: NABORS 9ES Rig Number: 9 -ES Date From -"To:. Hours Activity:`Code NPT Phase Description of Operations 4/11/2002 07:00 - 18:00 11.00 REMCM N CEMT PROD1 600 PSI ON ANNULUS. FLUSH CEMENT LINES. DISPLACE W/ RIG PUMP @ 3 BPM @ 970 PSI, HOLDING 650 PSI BACK -PRESSURE. STING INTO EZSV AND INJECT CEMENT BEHIND CASING - 3 BPM @ 1700 PSI DOWN TO 2 BPM @ 1550 PSI. UN -STING FROM EZSV AND CIRCULATE BOTTOMS UP @ 550 GPM & 3187 PSI. DISPLACE 18:00 - 21:00 3.00 REMCM N CEMT PROD1 POH W/ DP. B/O STINGER. 21:00 - 22:00 1.00 REMCM N CEMT PROD1 M/U 6 1/8" C/O BHA WITH 7" SCRAPER AND BOOT BASKETS. 22:00 - 00:00 2.00 REMCM N CEMT PROD1 RIH W/ C/O ASSSY ON 4" DP. 4/12/2002 00:00 - 00:30 0.50 REMCM N CEMT PROD1 RIH W/ SCRAPER & BOOT BASKETS TO 9055'. 00:30 - 01:30 1.00 REMCM N CEMT PROD1 BREAK CIRCULATION, TAG EZSV, CBU, ROTAE & RECIPROCATE - 550 GPM. 01:30 - 04:30 3.00 REMCM N CEMT PROD1 POH W/ DP 04:30 - 05:30 1.00 REMCM N CEMT PROD1 STAND BACK HWDP, JARS & DC's. L/D SCRAPER & BOOT BASKETS - NO RECOVERY. 05:30 - 12:00 6.50 REMCM N CEMT PROD1 PJSM. R/U SWS E -LINE. RUN CBL/VDL FROM 9150' TO 5000'. NO CEMENT. POH. L/D LOGGING TOOLS. 12:00 - 01:00 13.00 REMCM N CEMT PROD1 RE - HEAD SWS LINE FOR GR & EZSV SETTING TOOL. 01:00 - 14:30 13.50 REMCM P PROD1 SERVICE TOP DRIVE, DRAWORKS & QUARTERLY P.M. 14:30 - 21:00 6.50 REMCM N CEMT PROD1 PJSM. M/U FAST DRILL EZSV ON SWS E -LINE. RIH SET EZSV @ 8935'. POH M/U SWS HSD 4.5" PERF GUN, 4 SPF- 2 FT. LOADED. RIH & FIRE @ 8850' TO 8852'. POH - ALL 9 SHOTS FIRED. R/D SWS 21:00 - 00:00 3.00 REMCM N CEMT PROD1 M/U STAR GUIDE STINGER ON DP & RIH. 4/13/2002 00:00 - 02:30 2.50 REMCM N CEMT PROD1 PJSM W/ RIG CREW, HES & DOWELL. ESTABLISH CIRC RATES AND PRESSURES ABOVE EZSV. STING IN AND ESTABLISH CIRCULATION THROUGH PERFORATIONS. RECORD RATES & PRESSURES. SWITCH TO DOWELL. PUMP 5 BBLS. 8.3 PPG CW -100. TEST LINES TO 4000 PSI. PUMP 5 BBLS CW -100, FOLLOWED BY 20 BBLS 15.8 LATEX, GASBLOC SLURRY. PUMP 10 BBLS WATER TO CLEAR LINES. SWITCH BACK TO RIG PUMPS AND DISPLACE WITH 77 BBLS 10.1 PPG. MUD, LEAVING 2 BBLS CEMENT IN DP. 100% RETURNS THROUGHOUT JOB. PRES.CHARTS INDICATED GOOD CEMENT LIFT. 02:30 - 04:30 2.00 REMCM N CEMT PROD1 UN -STING RROM EZSV. CIRC. OUT CEMENT. APPROX 15 BBLS CEMENT TO SURFACE. B/O CEMENT LINES, SCREW IN TOP DRIVE. CBU ROTATING & RECIPROCATING. PUMP @ 600 GPM - 2980 PSI. 04:30 - 08:00 3.50 REMCM N CEMT PROW POH. L/D STINGER. 08:00 - 09:00 1.00 REMCM N CEMT PROD1 M/U 6 1/8" DRILL OUT BHA. 09:00 - 11:30 2.50 REMCM N CEMT PROD1 RIH W/ 4" DP TO 8774'. 11:30 -13:30 2.00 REMCM N CEMT PROD1 REAM THROUGH PERFS @ 8850' - 8852'. REAM DOWN TO FAS DRILL EZSV @ 8935'. DRILL EZSV. CONT. REAM - PUSH JUNK DOWN TO 9140' SOME GREEN CEMENT BELOW EZSV. 13:30 - 15:00 1.50 REMCM N CEMT PROD1 CIRC., WORK JUNK BASKETS, CIRC SWEEP. Printed: 4/22/2002 11:37:06 AM BP EXPLORATION Page9of 10 .0berations. Summary Report. Legal Well Name: L-119 Common Well Name: L-119 Spud Date: 3/27/2002 Event Name: DRILL+COMPLETE Start: 3/26/2002 End: 4/16/2002 Contractor Name: NABORS Rig Release: 4/16/2002 Rig Name: NABORS 9ES Rig Number: 9 -ES Date From = To' Hours. Activity Code NPT Phase Description of Operations 4/13/2002 15:00 - 18:00 3.00 REMCM N CEMT PROD1 POH 18:00 - 19:00 1.00 REMCM N CEMT PROD1 STAND BACK BHA. BREAK OUT BIT, BOOT BASKETS - LITTLE RECOVERY. 19:00 - 00:00 5.00 REMCM N CEMT PROD1 PJSM. R/U SWS E -LINE. RUN USIT. 4/14/2002 00:00 - 00:30 0.50 REMCM N CEMT PROD1 R/D SWS. 00:30 - 01:30 1.00 REMCM N CEMT PROD1 M/U CLEAN OUT / SCRAPER BHA - RIH. 01:30 - 03:00 1.50 REMCM N CEMT PROD1 RIH W/ 4" DP TO 5600'. 03:00 - 04:00 1.00 REMCM P PROD1 CUT & SLIP 163' OF DRILLING LINE. SERVICE BRAKES. 04:00 - 05:30 1.50 REMCM N CEMT PROD1 CONTINUE RIH TO 9057'. 05:30 - 08:00 2.50 REMCM N CEMT PROD1 M/U TD. WASH DOWN TO 9140' CIRC. HI -VIS SWEEP. DISPLACE MUD W/ 8.8 PPG BRINE. 08:00 - 14:00 6.00 RUNCOMP COMP POH, LAYING DOWN ALL 4" DRILL PIPE. 14:00 - 15:30 1.50 RUNCOMP COMP UD HWDP & BHA. 15:30 -17:00 1.50 RUNCOMP COMP CLEAR FLOOR. PULL WEAR BUSHING. MAKE DUMMY RUN W/ 4.5" HANGER & LANDING JT. RIG TO RUN 4.5" TUBING COMPLETION STRING. 17:00 - 00:00 7.00 RUNCOMP COMP PJSM. RUN 4.5' COMPLETION STRING AS PER PROGRAM. 4/15/2002 00:00 - 04:00 4.00 RUNCOMP COMP RUN TOTAL 213 JTS, 4.5" TBG W/ JEWELRY AS PER PROGRAM. M/U HANGER, LANDING JT. AND CIRC. EGUIP. 04:00 - 06:00 2.00 RUNCOMP COMP REVERSE CIRCULATE TO SPOT CORROSION INIBITED BRINE. 06:00 - 06:30 0.50 RUNCOMP COMP LAND TBG, R.I.L.D.S., DROP BALUROD, UD LDNG. JT., TEST SFC. EQUIP. 06:30 - 09:00 2.50 RUNCOMP COMP PRESSURE TBG. TO 2800 PSI. TO SET LOWER S-3 PKR. BLEED OFF AND RE- PRESSURE TO 4200 PSI TO SET UPPER PREMIUM PKR. HOLD PRESSURE FOR 30 MIN. TEST - OK. BLEED TBG TO 2000 PSI. AND HOLD. PRESSURE ANNULUS TO 4000 PSI. PRESSURE BLEEDING OFF - TUBING PRESSURE INCREASING - SUSPECT COMMUNICATION. C/O ALL SURFACE EQUIP. - OK. TORQUE L.D.S TO 500 FT/ LBS.. BLEED PRESSURE FROM ANNULUS THEN TUBING TO "0". RE -PRESSURE TUBING TO 4000 PSI. 700 PSI LOSS IN 30 MINUTES - DEFINITE COMMUMICATION. SUSPECT "RP" SHEAR VALVE. BLEED TO "0". 09:00 - 10:00 1.00 RUNCOMN DFAL COMP PRESSURE ANNULUS TO 2200 PSI. - SHEARED RP. CIRC THROUGH RP - ONLY 118 GPM @ 2600 PSI. - BAD SHEAR/ PARTIALY OBSTRUCTED. 10:00 - 12:00 2.00 RUNCOMN DFAL COMP WAIT ON SLICK LINE. WHILE WAITING: BLOW DOWN ALL LINES & R/D TUBING RUNNING EQUIP. 12:00 - 00:00 12.00 RUNCOW4 DFAL COMP PJSM, R/U HES SLICK LINE. RUN CATCHER IN "X" NIP. BELOW GLM W/ RP. RIH & RETRIEVE RP @ 8754'. RIH W/ DUMMY, ATTEMPT TO SET IN GLM. POH - DAMAGED DUMMY. CIRC THROUGH RP POCKET WHILE M/U NEW DUMMY. RIH W/ DUMMY #2 SET IN POCKET, POH W/ SLICK LINE. 4/16/2002 00:00 - 01:00 1.00 RUNCOMP COMP TEST TBG TO 4000 PSI / 30 MIN, TEST ANN TO 4000 PSI / 30 MIN. TEST SUCCESSFUL. 01:00 - 03:30 2.50 RUNCOMP COMP RIG UP SLICKLINE, RETRIEVE DUMMY VALVE, RIG DN SLICKLINE EQUIP 03:30 - 04:00 0.50 BOPSUF P COMP INSTALL TWC, TEST BELOW CHECK TO 2800 PSI 04:00 - 05:00 1.00 BOPSUF P COMP NIPPLE DN BOPE, STAND BACK AND SECURE 05:00 - 07:30 2.50 WHSUR P COMP NIPPLE UP ADPTR FLANGE, TREE, TEST ALL Printed: 4/22/2002 11:37:06 AM Printed: 4/22/2002 11:37:06 AM BP`EXPLORATION Page 10 of 1`0 Opera! ions S M.Mary Repot Legal Well Name: L-119 Common Well Name: L-119 Spud Date: 3/27/2002 Event Name: DRILL+COMPLETE Start: 3/26/2002 End: 4/16/2002 Contractor Name: NABORS Rig Release: 4/16/2002 Rig Name: NABORS 9ES Rig Number: 9 -ES Date From - To Hours' Activit Code y NPT Phase: Description of Operations ": 4/16/2002 05:00 - 07:30 2.50 WHSUR P COMP COMPONENTS TO 5000 PSI. TEST SUCCESSFUL, NO RE -TESTS. 07:30 - 08:30 1.00 WHSUR P COMP RIG UP DSM, REMOVE TWC WITH LUBRICATOR. 08:30 - 11:00 2.50 WHSUR P COMP PJSM, PUMP 159 BBLS DIESEL DN 4.5 X 7 ANN. (4700 FT) ALLOW "U" TUBING PRESS CHECK, "0" PSI. 11:00 -12:00 1.00 WHSUR P COMP iNSTALL BPV, TEST TO 1000 PSI RELEASE NABORS RIG 9 -ES THIS DATE 1200 HRS Printed: 4/22/2002 11:37:06 AM Well: L-1 19i Rig Accept: 03/26/02 Field: Prudhoe Bay Field / Borealis Pool Rig Spud: 03/27/02 API: 50-029-23077-00 Rig Release: 04/16/02 Permit: 202-064 Drilling Rig: Nabors 9ES POST RIG WORK 05/07/02 RAN GR/CCL/TEMP JEWELRY LOG FROM PBTD (9141') TO 8700. PERFORATED INTERVAL 9092-9106'. 3-3/8" GUNS, POWERJET, 6 SPF. SHOTS WERE ORIENTED 20 DEG OFF BOTTOM OF LINER USING AN ECCENTRIC WEIGHT BAR. WHP INCREASED FROM 600 PSI TO 650 PSI AFTER PERFORATING. RD 05/09/02 PERFORATED 26' INTERVAL (9058'-9084') IN THREE RUNS USING 3 3/8" POWERJET HSD GUNS LOADED 6 SPF, 60 DEG PHASING AND ORIENTED 10 DEG OFF BOTTOM. WELL SHUT IN WHILE PERFORATING. SURFACE PRESSURES AND TEMPS RECORDED AFTER FIRING EACH GUN.WELL WAS SHOT BALANCED. 05/24/02 HYDRATE THAW; PUMP MEOH DOWN TBG AND HOT DSL DOWN IA 05/26/02 PUMPED 90 BBLS OF 180* DSL AT1.1 BPM AT1900 TO 2475 PSI DOWN IA 06/09/02 D/T W/ 3.5 CENT TEL SB TAG ICE PLUG @ 1318' SLM, HB&R PUMPED 19 BBLS DWN TUBING, PRESS. UP TO 3000# RDMO. ATTEMPT TO THAW ICE PLUG; PUMP 22 BLS MEOH DOWN TBG,61 BBLS HOT DIESEL DOWN I.A., UNABLE TO THAW 06/16/02 MIRU CTU #3. RIH W/ 2.25" DJN PUMPING 50/50 MW TO DISPLACE WTR OUT OF COIL. TAG UP ON HYDRATE/ICE PLUG AT 1613' CTMD. CONTINUE JETTING DOWN AT 1.5 BPM. BROKE THROUGH TO POCKET OF GAS AND 1885' CTMD. CONTINUE JETTING DOWN, BROKE THROUGH BTM OF PLUG AT 2280' CTMD. PUMPED MIN RATE AND DRIFTED DOWN TO BTM GLM. POOH & FP WELL W/ 60 BBLS NEAT METH. BP EXPLORATION Page 1 of.1 Leak -Off, Test Summary Legal Name: L-119 Common Name: L-119 Test Date Test Type Test Depth (TMD) Test Depth (TVD) AMW Surface Pressure Leak"off Pressure (BHP) EMW 3/30/2002 LOT 2,919.0 (ft) 2,621.0 (ft) 9.30 (ppg) 650 (psi) 1,916 (psi) 14.07( ppg) Printed: 4/22/2002 11:36:59 AM ANADRILL SCHLUMBERGER Survey report Client .................... BP Exploration (Alaska) Inc. Field ..................... Prudhoe Bay / Borealis Well ...................... L -119i API number ................ 50-029-23077-00 Engineer .................. Franco COUNTY :................... Nabors 9ES STATE: ................... : Alaksa ----- Survey calculation methods ------------- Method for positions.....: Minimum curvature Method for DLS........... . Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference..........: Drill Floor GL above permanent.......: 50.40 ft KB above permanent.......: n/a DF above permanent.......: 78.90 ft ----- Vertical section origin ---------------- Latitude (+N/S-)......... . 0.00 ft Departure (+E/W-)........ . 0.00 ft ----- Platform reference point --------------- Latitude (+N/S-)......... . -999.25 ft Departure (+E/W-)........ . -999.25 ft Azimuth from rotary table to target: 38.98 degrees [(c)2002 Anadrill IDEAL ID6_1C_10] 6 -Apr -2002 01:52:15 Page 1 of 5 Spud date ................. 27 -Mar -02 Last survey date.......... 06 -Apr -02 Total accepted surveys.. 104 MD of first survey........ 0.00 ft MD of last survey......... 9624.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2001 Magnetic date ............. 02 -Apr -2002 Magnetic field strength..: 1149.47 HCNT Magnetic dec (+E/W-)..... : 26.07 degrees Magnetic dip .............. 80.76 degrees survey Reference Criteria Reference G ............... 1002.68 mGal Reference H ............... 1149.47 HCNT Reference Dip ............. 80.76 degrees Tolerance of G ........... . (+/-) 2.50 mGal Tolerance of H ........... . (+/-) 6.00 HCNT Tolerance of Dip.........: (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 26.07 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 26.07 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N)........ . No degree: 0.00 AA?ADRILL SCHLUMBERGER Survey Report 6 -Apr -2002 01:52:15 Page 2 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Sr -VY Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP - 2 204.92 0.58 47.15 204.92 204.92 1.03 0.71 0.76 1.04 47.15 0.28 MWD Inc. Only 3 295.52 0.56 24.34 90.60 295.51 1.91 1.42 1.28 1.91 42.00 0.25 MWD -IFR -MSA 4 393.32 0.71 27.46 97.80 393.31 2.97 2.39 1.76 2.97 36.25 0.16 MWD_IFR_MSA 5 485.22 1.26 16.74 91.90 485.19 4.46 3.87 2.31 4.50 30.84 0.63 MWD_IFR_MSA 6 577.56 2.53 32.94 92.34 577.48 7.42 6.55 3.71 7.53 29.53 1.48 MWD_IFR_MSA 7 669.57 3.86 39.48 92.01 669.35 12.54 10.64 6.78 12.62 32.51 1.50 MWD_IFR_MSA 8 761.87 5.34 38.34 92.30 761.35 19.94 16.41 11.42 20.00 34.84 1.61 MWD_IFR_MSA 9 854.16 6.51 40.51 92.29 853.14 29.47 23.76 17.49 29.50 36.35 1.29 MWD_IFR_MSA 10 948.11 7.35 43.17 93.95 946.40 40.79 32.19 25.06 40.79 37.90 0.96 MWD_IFR_MSA 11 1041.85 8.49 40.08 93.74 1039.25 53.68 41.86 33.61 53.68 38.77 1.30 MWD_IFRRMSA 12 1135.28 10.86 40.18 93.43 1131.34 69.38 53.86 43.74 69.38 39.08 2.54 MWD -IFR -MSA 13 1228.35 12.15 38.83 93.07 1222.54 87.94 68.19 55.53 87.94 39.16 1.42 MWD_IFR_MSA 14 1321.07 14.10 39.19 92.72 1312.84 109.00 84.55 68.79 109.00 39.13 2.10 MWD_IFR_MSA 15 1415.19 16.61 38.02 94.12 1403.59 133.92 104.03 84.32 133.92 39.03 2.69 MWD_IFR_MSA 16 1507.60 19.76 38.19 92.41 1491.37 162.75 126.72 102.12 162.75 38.86 3.41 MWD_IFR_MSA 17 1600.76 20.00 37.31 93.16 1578.98 194.42 151.77 121.51 194.42 38.68 0.41 MWD -IFR -MSA 18 1695.48 22.73 37.99 94.72 1667.18 228.91 179.08 142.60 228.92 38.53 2.89 MWD_IFR_MSA 19 1788.55 23.30 37.84 93.07 1752.84 265.29 207.79 164.96 265.31 38.45 0.62 MWD -IFR -MSA 20 1881.84 23.56 39.15 93.29 1838.44 302.39 236.82 188.05 302.40 38.45 0.62 MWD_IFR_MSA 21 1975.69 24.16 39.17 93.85 1924.27 340.35 266.25 212.02 340.36 38.53 0.64 MWD_IFR_MSA 22 2068.89 28.76 38.26 93.20 2007.69 381.86 298.66 237.97 381.87 38.55 4.95 MWD_IFR_MSA 23 2162.49 31.68 37.94 93.60 2088.56 428.96 335.74 267.03 428.98 38.50 3.12 MWD_IFR_MSA 24 2256.00 34.54 40.48 93.51 2166.88 480.03 375.27 299.34 480.04 38.58 3.40 MWD -IFR -MSA 25 2347.46 37.18 39.38 91.46 2241.00 533.59 416.37 333.71 533.60 38.71 2.97 MWD_IFR_MSA 26 2440.38 38.99 40.00 92.92 2314.13 590.90 460.46 370.32 590.90 38.81 1.99 MWD_IFR_MSA 27 2534.55 43.78 40.46 94.17 2384.77 653.12 507.97 410.53 653.12 38.94 5.10 MWD_IFR_MSA 28 2630.05 49.70 38.57 95.50 2450.19 722.63 561.63 454.71 722.63 38.99 6.36 MWD_IFR_MSA 29 2720.16 53.09 39.16 90.11 2506.40 793.04 616.45 498.90 793.04 38.98 3.80 MWD_IFR_MSA 30 2815.71 54.83 39.06 95.55 2562.62 870.30 676.40 547.63 870.30 38.99 1.82 MWD_IFR_MSA ANADRILL SCHLUMBERGER Survey Report 6 -Apr -2002 01:52:15 Page 3 of 5 ----------- -- ----------- ----------------------------------------------------- ----- ----- ------ ----------- ------------- ----------------------------------------------------- ----- ----- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type type ----------- -- ----------- ----------------------------------------------------- ----- ----- ------ ----------- ------------- ----------------------------------------------------- ----- ----- ------ 31 2885.55 56.08 39.55 69.84 2602.22 927.82 720.91 584.07 927.82 39.01 1.88 MWD IFR MSA 32 2985.96 56.30 39.86 100.41 2658.09 1011.24 785.09 637.37 1011.24 39.07 0.34 MWD_IFR_MSA 33 3077.55 56.13 39.63 91.59 2709.02 1087.36 843.62 686.04 1087.36 39.12 0.28 MWD_IFR_MSA 34 3170.36 56.65 40.05 92.81 2760.40 1164.64 902.97 735.56 1164.65 39.17 0.68 MWD_IFR_MSA 35 3264.95 56.34 39.76 94.59 2812.61 1243.51 963.48 786.16 1243.52 39.21 0.42 MWD -IFR -MSA 36 3358.91 56.11 40.01 93.96 2864.85 1321.60 1023.41 836.24 1321.61 39.25 0.33 MWD -IFR -MSA 37 3452.55 55.85 40.06 93.64 2917.24 1399.20 1082.83 886.17 1399.22 39.30 0.28 MWD_IFR_MSA 38 3544.21 56.00 40.19 91.66 2968.59 1475.11 1140.88 935.10 1475.13 39.34 0.20 MWD -IFR -MSA 39 3637.95 55.24 40.03 93.74 3021.52 1552.45 1200.05 984.94 1552.49 39.38 0.82 MWD_IFR_MSA 40 3731.21 54.99 39.88 93.26 3074.86 1628.94 1258.69 1034.07 1628.99 39.40 0.30 MWD -IFR -MSA 41 3824.24 55.21 39.72 93.03 3128.09 1705.24 1317.31 1082.91 1705.29 39.42 0.28 MWD -IFR -MSA 42 3918.09 56.04 39.30 93.85 3181.08 1782.69 1377.08 1132.19 1782.75 39.43 0.96 MWD -IFR -MSA 43 4011.88 56.76 39.59 93.79 3232.98 1860.81 1437.40 1181.82 1860.86 39.43 0.81 MWD_IFR_MSA 44 4104.54 56.38 39.84 92.66 3284.03 1938.13 1496.89 1231.23 1938.19 39.44 0.47 MWD_IFR_MSA 45 4197.94 55.56 40.54 93.40 3336.30 2015.52 1556.02 1281.18 2015.59 39.47 1.08 MWD_IFR_MSA 46 4289.99 54.90 39.72 92.05 3388.79 2091.12 1613.83 1329.91 2091.20 39.49 1.02 MWD_IFR_MSA 47 4383.20 54.75 39.76 93.21 3442.49 2167.30 1672.41 1378.62 2167.39 39.50 0.16 MWD -IFR -MSA 48 4475.89 54.37 40.32 92.69 3496.23 2242.80 1730.23 1427.20 2242.90 39.52 0.64 MWD_IFR_MSA 49 4569.59 53.57 41.20 93.70 3551.35 2318.54 1787.63 1476.67 2318.66 39.56 1.14 MWD_IFR_MSA 50 4663.49 53.95 40.73 93.90 3606.86 2394.23 1844.81 1526.32 2394.37 39.60 0.57 MWD IFR MSA 51 4756.82 55.33 40.26 93.33 3660.87 2470.31 1902.70 1575.75 2470.47 39.63 1.53 MWD_IFR_MSA 52 4847.78 54.63 40.13 90.96 3713.07 2544.79 1959.60 1623.82 2544.96 39.65 0.78 MWD_IFR_MSA 53 4942.29 55.74 39.58 94.51 3767.03 2622.37 2019.16 1673.55 2622.55 39.65 1.27 MWD -IFR -MSA 54 5036.17 57.72 39.66 93.88 3818.53 2700.85 2079.62 1723.60 2701.04 39.65 2.11 MWD_IFR_MSA 55 5129.13 57.59 39.57 92.96 3868.26 2779.38 2140.12 1773.67 2779.58 39.65 0.16 MWD -IFR -MSA 56 5223.38 57.11 38.36 94.25 3919.11 2858.74 2201.82 1823.58 2858.92 39.63 1.19 MWD_IFR_MSA 57 5316.76 56.36 38.42 93.38 3970.33 2936.81 2263.02 1872.07 2936.98 39.60 0.80 MWD_IFR_MSA 58 5410.85 57.18 38.50 94.09 4021.89 3015.51 2324.65 1921.02 3015.67 39.57 0.87 MWD_IFR_MSA 59 5502.24 57.82 37.94 91.39 4070.99 3092.58 2385.20 1968.70 3092.73 39.54 0.87 MWD _ IFR _MSA 60 5596.50 57.45 38.52 94.26 4121.45 3172.19 2447.74 2017.97 3172.33 39.50 0.65 MWD IFR MSA ANADRILL SCHLUMBERGER Survey Report 6 -Apr -2002 01:52:15 Page 4 of 5 --- --- Seq -------- -------- Measured ------ ------ Incl ------- ------- Azimuth ------ ------ Course -------- -------- TVD ---------- -------- Vertical ---------------- ---------------- Displ Displ --------------- --------------- Total At ----- ----- DLS ---- - ----- Srvy ------ ------ Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ---------------- (ft) (ft) --------------- (deg) 100f) ----- type ---- - type ------ --- 61 ----- --- 5689.28 ----- - 56.35 ------- 38.69 ------ 92.78 -------- 4172.12 -------- 3249.91 ---------------- 2508.48 2066.46 --------------- 3250.04 39.48 ----- 1.20 ----- MWD_IFR_MSA ------ 62 5782.95 55.49 38.73 93.67 4224.61 3327.50 2569.02 2114.98 3327.61 39.46 0.92 MWD_IFR_MSA 63 5876.95 54.63 38.97 94.00 4278.44 3404.55 2629.03 2163.32 3404.67 39.45 0.94 MWD_IFR_MSA 64 5969.11 54.10 39.85 92.16 4332.14 3479.45 2686.90 2210.87 3479.57 39.45 0.97 MWD_IFR_MSA 65 6062.95 53.54 39.95 93.84 4387.53 3555.18 2745.01 2259.45 3555.31 39.46 0.60 MWD_IFR_MSA 66 6155.57 52.92 38.48 92.62 4442.98 3629.37 2802.49 2306.36 3629.50 39.45 1.44 MWD_IFR_MSA 67 6249.74 53.19 37.91 94.17 4499.58 3704.63 2861.64 2352.90 3704.74 39.43 0.56 MWD_IFR_MSA 68 6342.56 52.39 38.09 92.82 4555.71 3778.54 2919.89 2398.41 3778.64 39.40 _0.88 MWD -IFR -MSA 69 6435.58 51.58 38.59 93.02 4613.00 3851.82 2977.37 2443.87 3851.91 39.38 0.97 MWD_IFR_MSA 70 6528.72 50.45 37.63 93.14 4671.59 3924.21 3034.33 2488.55 3924.29 39.36 1.45 MWD_IFR_MSA 71 6622.98 49.56 37.39 94.26 4732.18 3996.40 3091.61 2532.52 3996.47 39.32 0.96 MWD_IFR_MSA 72 6716.62 48.82 37.33 93.64 4793.37 4067.24 3147.95 2575.53 4067.30 39.29 0.79 MWD_IFR_MSA 73 6809.56 47.81 36.61 92.94 4855.18 4136.60 3203.40 2617.28 4136.65 39.25 1.23 MWD_IFR_MSA 74 6901.68 46.91 36.22 92.12 4917.58 4204.30 3257.93 2657.50 4204.33 39.20 1.03 MWD_IFR_MSA 75 6995.10 45.75 36.09 93.42 4982.09 4271.79 3312.49 2697.37 4271.81 39.16 1.25 MWD_IFR_MSA 76 7090.25 45.26 36.13 95.15 5048.77 4339.58 3367.32 2737.37 4339.59 39.11 0.52 MWD_IFR_MSA 77 7183.12 44.71 35.37 92.87 5114.46 4405.13 3420.60 2775.73 4405.13 39.06 0.83 MWD_IFR_MSA 78 7275.90 44.34 35.20 92.78 5180.61 4470.05 3473.71 2813.31 4470.05 39.00 0.42 MWD_IFR_MSA 79 7369.71 43.73 35.06 93.81 5248.05 4535.11 3527.03 2850.83 4535.11 38.95 0.66 MWD_IFR_MSA 80 7463.65 42.93 34.46 93.94 5316.38 4599.39 3579.99 2887.58 4599.40 38.89 0.96 MWD_IFR_MSA 81 7556.67 42.39 34.61 93.02 5384.79 4662.24 3631.92 2923.32 4662.25 38.83 0.59 MWD_IFR_MSA 82 7649.09 41.64 33.94 92.42 5453.45 4723.89 3683.03 2958.16 4723.92 38.77 0.95 MWD_IFR_MSA 83 7743.58 40.97 34.24 94.49 5524.43 4786.03 3734.68 2993.11 4786.08 38.71 0.74 MWD_IFR_MSA 84 7836.35 40.58 34.14 92.77 5594.69 4846.41 3784.80 3027.16 4846.48 38.65 0.43 MWD -IFR -MSA 85 7930.89 39.56 34.09 94.54 5667.03 4907.04 3835.18 3061.29 4907.15 38.60 1.08 MWD -IFR -MSA 86 8023.73 36.72 33.08 92.84 5740.05 4964.12 3882.93 3093.02 4964.27 38.54 3.13 MWD_IFR_MSA 87 8115.00 34.17 32.95 91.27 5814.40 5016.76 3927.31 3121.86 5016.95 38.48 2.80 MWD_IFR_MSA 88 8209.94 31.62 33.68 94.94 5894.11 5068.06 3970.40 3150.16 5068.30 38.43 2.72 MWD -IFR -MSA 89 8303.53 29.76 33.76 93.59 5974.58 5115.63 4010.13 3176.68 5115.90 38.38 1.99 MWD_IFR_MSA 90 8395.95 30.11 38.51 92.42 6054.69 5161.66 4047.35 3203.86 5161.95 38.37 2.59 MWD_IFR_MSA ANADRILL SCHLUMBERGER Survey Report 6 -Apr -2002 01:52:15 Page 5 of 5 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool qual - --- (ft) -------- (deg) ------ (deg) ------- (ft) ------ (ft) -------- (ft) -------- (ft) ---------------- (ft) (ft) --------------- (deg) 100f) ----- type ----- type ------ --- 91 -------- 8490.90 ------ 28.84 ------- 39.79 ------ 94.95 -------- 6137.35 -------- 5208.37 ---------------- 4083.58 3233.35 --------------- 5208.67 38.37 ----- 1.49 ----- MWD_IFR_MSA ------ 92 8584.60 27.56 41.97 93.70 6219.92 5252.62 4117.06 3262.31 5252.89 38.39 1.75 MWD_IFR_MSA 93 8679.40 25.11 41.48 94.80 6304.88 5294.62 4148.45 3290.31 5294.88 38.42 2.59 MWD_IFR_MSA 94 8772.71 23.52 41.12 93.31 6389.91 5333.01 4177.31 3315.66 5333.25 38.44 1.71 MWD_IFR_MSA 95 8865.43 21.50 41.09 92.72 6475.56 5368.48 4204.05 3339.00 5368.70 38.46 2.18 MWD_IFR_MSA 96 8958.47 20.61 41.25 93.04 6562.39 5401.88 4229.21 3361.00 5402.09 38.47 0.96 MWD_IFR_MSA 97 9051.99 19.15 42.09 93.52 6650.33 5433.65 4252.97 3382.14 5433.84 38.49 1.59 MWD -IFR -MSA 98 9144.12 18.79 42.82 92.13 6737.46 5463.54 4275.07 3402.35 5463.72 38.51 0.47 MWD_IFR_MSA 99 9237.29 18.31 42.52 93.17 6825.79 5493.12 4296.86 3422.44 5493.28 38.54 0.53 MWD_IFR_MSA 100 9330.32 17.24 43.19 93.03 6914.38 5521.45 4317.69 3441.76 5521.60 38.56 1.17 MWD_IFRRMSA 101 9424.04 16.06 44.26 93.72 7004.17 5548.21 4337.10 3460.31 5548.35 38.58 1.30 MWD_IFR_MSA 102 9516.89 14.78 45.43 92.85 7093.67 5572.77 4354.61 3477.71 5572.89 38.61 1.42 MWD_IFR_MSA 103 9542.63 14.53 45.67 25.74 7118.58 5579.24 4359.17 3482.36 5579.35 38.62 1.00 MWD_IFR_MSA 104 9624.00 13.74 46.47 81.37 7197.48 5598.96 4372.96 3496.67 5599.06 38.65 1.00 Projected to TD [(c)2002 Anadrill IDEAL ID6_1C_101 Sh bepgv Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Job # Log Description NO. 2098 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Date Color Sepia BL CD L-119 22173 PP ADN ARC DATA 04/06/02 1 L-119 22173 VISION RESISTIVITY MD 04/06/02 1 1 L-119 22173 VISION RESISTIVITY TVD 04/06/02 1 1 L-119 22173 VISION DEN/NEUTRONTVD 04/06/02 1 1 L-119 22173 VISION DEWNEUTRON MD 04/06/02 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 RECFIVPn 900 E Benson Blvd. Anchorage AK 99508-4254 L002 Date Delivered: Adaft00&ftC0pS wdm— Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATfN: Sherrie Received 5/23/2002 hhopgr Alaska Data and Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well Job # NO. 2078 Company: Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Borealis Log Description Date Color Sepia BL CD PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E Benson Blvd. Rm;EIVE Anchorage AK 99508-4254-D 2 Date Delivered: Mas IPM All pq mama LM(k L-68 Cft. . AOmp Schlumberger DCS 3940 Arctic Blvd Suite 300 Anchorage AK 99503-5789 ATfN: Sherrie Receiveby:--� 5/15/2002 MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No L-1191 Date Dispatched: 11 -Apr -02 Installation/Rig Nabors 9ES Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys 2 1 4ECEIV D r^� 7 Alaska UOSCM.0 Won Anchorage Received By: 'r - �. Please sign and return to: Anadrill LWD Division 3940 Arctic Blvd, Suite 300 Anchorage, Alaska 99503 nrosei @slb.com Fax: 907-561-8417 LWD Log Delivery V1.1, Dec'97 Prudhoe Bay Unit L -Pad Diverter Waiver Notes to File March 22, 2002 The intent of a diverter system on a drill rig is to allow an uncontrolled well flow to be directed away from the rig floor, thereby enhancing the safety of a drilling crew by permitting them additional escape time. Regulation 20 AAC 25.035 (c) provides specific requirements for a diverter system. Regulation 20 AAC 25.035 (h) permits the Commission to waive diverter requirements in certain circumstances. Variances may be granted if the operator provides an equally effective means of diverting flow away from the drill rig, or if drilling experience in the near vicinity indicates that a diverter system is not necessary. BP is currently seeking a variance from diverter requirements for further drilling on the Prudhoe Bay Unit L -Pad. Their argument is that a diverter should not be required based on past drilling experience on L -Pad. To date, 13 wells have been drilled from the pad without incident, which argues in favor of a diverter waiver. However, a confidential map provided by Robert Hunter of BP (dated Oct. 15, 2001) shows that L -Pad is situated near the middle of a world-class gas hydrate accumulation, and within an area interpreted by BP to contain free gas associated with the hydrate deposits. Hunter's information augments USGS and drilling experience that the immediate area is known to contain hydrates. The Commission's principle concern at L -Pad is free -gas possibly associated with the gas hydrate deposits. In fact, wireline logs from well L-106 indicate approximately 25' of free gas reservoir at the base of a thick gas hydrate zone. Free gas may constitute a drilling hazard when improper operating practices allow such gas to flow into the well bore. At present, the area and vertical distribution of this free -gas beneath the hydrate zone and its occurrence within the hydrate zone is poorly understood by the Commission and by industry. Gas hydrates are the topic of current research by the USGS and at least two industry teams: one headed by BP, and another involving Anadarko. BP has designed and constructed L -Pad as a small -footprint operation with closely spaced wells and tightly packed equipment. Many of the facilities and flow lines are currently in place. In its present configuration, use of a standard diverter line is not possible. In many places on the pad, a diverter of required length and configuration (75', as straight as possible) simply will not fit between the rig and the piping/facilities already in place. Where it will fit, the diverter will point toward the centerline of the pad, and it will be aimed directly at existing or planned piping and/or facilities. There are no other rigs available today on the North Slope that will permit the diverter line to be aimed in any other, less hazardous direction. If the Commission were to require a diverter line, it must be lifted over, threaded through, and built around existing, active, above -ground piping, greatly increasing the potential of construction -related accident and spill. Modification of the diverter line to include curves or targeted -T intersections could impair its effectiveness and would likely not ease its construction. In such a drilling situation where shallow -hazard uncertainty exists, the Commission would normally require a diverter. However, because of the design and existing infrastructure on L -Pad, the Commission is now forced to choose the lesser of two evils. While the hydrates and potentially associated free -gas are still sources of uncertainty, drilling standards and practices have been developed and implemented that have allowed BP to drill 13 wells from L -Pad without incident. Although the existence of hydrates in the intended drilling path is known and successful mitigation strategies have been employed in the drilling plans, there is still some potential for a drilling accident caused by free gas associated with the hydrates. The probability of that occurrence is very low. In contrast, a construction -related accident or spill caused by placement and assembly of the diverter line near existing infrastructure is considered by the Commission to be a greater risk. Therefore, a diverter waiver should be granted. To offset the lack of a diverter system, and to increase the safety of the drilling crew, the Commission should require a high-resolution system capable of quickly detecting any influx of gas or fluid into the mud system on all future wells drilled from Prudhoe Bay Unit L -Pad. In addition, a full suite of well logs should be required from surface to total depth on the well that reaches furthest from L-106 (which currently has a complete suite of well logs). The purpose of this additional logging is to provide the Commission with more data that will increase our confidence that no significant zones of free gas or other shallow drilling hazards exist above 2580 feet TVD in the L -Pad area. 3 -zz • o z-- L-106 Surface Hole Log/Free Gas Subject: L-106 Surface Hole Log/Free Gas Date: Thu, 21 Mar 2002 1.9:13:34 -0600 From: "Crane, Lowell R" <CraneL.R@BP.com> To: "Winton Aubert (E-mail)" <winton_aubert@admin. state. ak.us> CC: "Cerveny, Phillip F" <CervenP.F@BP.com>, "Tom Maunder (E-mail)" <tom maunder@admin.state.ak.us>, "Paskvan, Frank A" <PaskvaFA@BP.com>, "Odenthal, Robert S" <OdenthRS@BP.com>, "Magee, D Neil" <MageeDN@BP.com> Winton, Attached is Kip Cerveny's statement concerning interpretation of the L-106 surface hole logs and the presence of free gas. I will add that well behavior during drilling and cementing operations in this hole section on all L Pad wells to date are consistent with Kip's conclusion concerning the presence of free gas. If additional information is required, please call. Plans currently call for the rig moving to L -119i on Monday or Tuesday of next week. Thanks, Lowell Name: stategasletter.doc U stategasletter.doc Type: WINWORD File (application/msword)' Encoding: base64 1 of 1 3/22/2002 6:08 AM Upon thorough examination of the open hole log data from the L-106 well, it is my professional opinion that there is no free gas in the interval between the base of permafrost and the surface casing point just below the SV -1 sand at -2570 ft TVDSS. Gas hydrates, however, are prevalent throughout this interval. This is confirmed by the NW Eileen #2 well, located approximately 1.5 miles to the northwest, which also shows the presence of gas hydrates within the same interval, but does not show evidence of free gas. Sincerely, Philip F. Cerveny Senior Geologist BP Exploration Alaska State of Alaska Certified Geologist #488 SUAU E OCA a�A��a A14ASKAL OIL AND GALS CONSERVATION COMI►IISSION Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Unit L-1191 BP Exploration (Alaska) Inc Permit No: 202-064 TONY KNOWLES, GOVERNOR 333 W. T" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Sur. Loc. 2601' NSL, 3574' WEL, SEC 34, T12N, R1 1E UM Btmhole Loc. 2172' NSL, 4918 WEL, SEC 26, T 12N, R1 1 E, UM Dear Mr. Crane, Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Annular disposal has not been requested as part of the Permit to Drill application for Prudhoe Bay Unit L-1191. A diverter waiver has been requested for Well L-1191 for drilling the shallow section to a depth of approximately -2570' TVDss. The L -Pad in the western portion of the Prudhoe Bay Unit is located over a thick accumulation of sub -permafrost methane hydrates that are underlain by a significant accumulation of free hydrocarbon gas. The shallow section in the well would include the interval containing the methane hydrates, but not the underlying free gas accumulation. Fourteen wells have been drilled from L -Pad, which demonstrates the shallow section can be successfully drilled without a diverter by using specialized mud treatments and drilling procedures. Therefore, the diverter waiver for well PBU L-1191 is approved provided BPXA: 1) employs a high-resolution, early kick detection system in addition to the other hydrate mitigation procedures described in the permit to drill application for the subject well; and 2) obtains an additional surface hole log suite in future Well L-1091 consisting of Gamma Ray, SP, Resistivity, Neutron -Density, Dipole Sonic, and mud logs. Well L -109i is the most appropriate well in the current L -Pad drilling schedule for obtaining additional control. Commission approval of the diverter waiver for PBU L-1191 does not guarantee approval of future diverter waiver requests on this or any other drill site. Diverter waiver applications will continue to be carefully considered on a case-by-case basis. Permit No. 202-064 March 22, 2002 Page 2 of 2 The blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035; and the mechanical integrity (MI) of the injection wells must be demonstrated under 20 AAC 25.412 and 20 AAC 25.030(g)(3). Sufficient notice (approximately 24 hours) of the MI test before operation, and of the BOPE test performed before drilling below the surface casing shoe, must be given so that a representative of the Commission may witness the tests. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Sincerely, Daniel T. Seamount, Jr. Commissioner BY ORDER OF THE COMMISSION DATED this 22nd day of March, 2002 Je/Enclosures cc: Department of Fish & Game, I1abitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA W 6 A 311 S o L ALASKA O! )ND GAS CONSERVATION COMMIS )N -3 PERMIT TO DRILL 20 AAC 25.005 1 a. Type of work ® Drill ❑ Redrill 1 b. Type of well ❑ Exploratory ❑ Stratigraphic Test ❑ Development Oil ❑ Re -Entry ❑ Deepen ® Service ❑ Development Gas ❑ Single Zone ❑ Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. Plan RKB = 78.9' Prudhoe Bay Field / Borealis 3. Address 6. Property Designation Pool (Undefined) P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028238 4. Location of well at surface 7. Unit or Property Name 11. Type Bond (See 20 AAC 25.025) 2601' NSL, 3574' WEL, SEC. 34, T1 2N, R11 E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number 1806' NSL, 5215' WEL, SEC. 26, T1 2N, R11 E, UM L-1 19i Number 2S100302630-277 At total depth 9. Approximate spud date 2172' NSL, 4918' WEL, SEC. 26, T1 2N, R11E, UM 04/01/02 Amount $200,000.00 12. Distance to nearest property line 13. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028239, 361' MD I No Close Approach 2560 9973' MD / 7168' TVD 16. To be completed for deviated wells 117. Anticipated pressure {sere 20 AAC 25.035 (e) (2)) Kick Off Depth 300'MD Maximum Hole Angle 56oMaximum surface 3038 psig, At total depth (TVD) 6490'/ 3375 psig 18. Casing Program Specifications Setting Depth Size Ter) Bot t m Quantity of Cement Hole Casing Weight Grade Coupling Len th MD TVD MD TVD include stage data 42" 20" 91.5# H-40 Weld Surface Surface 110' 110' 260 sx Arctic Set (Approx.) 12-1/4" 9-5/8" 40# L-80 BTC 3024' Surface Surface 3024' 2679' 444 sx AS Lite 172 sx Class'G' 8-3/4" 7" 26# L-80 BTC -M 9973' Surface Surface 9973' 7168' sx Class 'G' SC' tc Ba.FG�- 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented MD TVD Structural Conductor Surface FD Intermediate �r Production Liner MAR 0 Alaska Oil & Gas Cons. Comlrtissior' Perforation depth: measured Anchorage true vertical 20. Attachments ® Filing Fee ❑ Property Plat ❑ BOP Sketch ❑ Diverter Sketch ® Drilling Program ® Drilling Fluid Program ❑ Time vs Depth Plot ❑ Refraction Analysis ❑ Seabed Report ❑ 20 AAC 25.050 Requirements Contact Engineer Name/Number. Robert Odenthal, 564-4387 Prepared By Nama Number. Terrie Hubble, 564-4628 21. 1 hereby certify that the forealbing is true arld correct to the best of my knowledge Signed Lowell Crane Title Senior Drilling Engineer Date ,_ 6_,a --L Commission Use Only. Permit Number API Number Ap rov I Date See cover letter 7 a'� O 4- 50- 4 z — Z -.30 7 -7d for other requirements Conditions of Approval: Samples Required []Yes Iff No Mud Log Required ❑ Yes IM No Hydrogen Sulfide Measures ❑ Yes ErNo Directional Survey Required jo Yes []No Required Working Pressure for BOPE ❑ 2K ❑ 3K ❑ 4K ❑ 5K P10K []15K, 3.5K psi for CTU Other: st F.CeE fo v+�a S i MTT' a," zwc unci �^j 10 � rx b or, of ORIGINAL SIGNED Sy y Approved B ommissi ner the commission Date�- Form 10-401 Rev. 12-01-851) TaY F101 Seamouru HI b I'N'L Sbbmit n Triplicate L-119 cement surface casing septh coordinates Subject: L-119 cement surface casing septh coordinates Date: Tue, 12 Mar 2002 18:21:49 -0600 From: "Odenthal, Robert S" <OdenthRS@BP.com> To: "'winton_aubert@admin.state.ak.us"' <winton_aubert@admin. state. ak.us> Mr. Aubert: Production Hole Section 1st stage ----44 bbls/ 214 s x/ 1.17 ft3/sx / 250 ft3 2nd stage -----80 bbls / 382 sx / 1.17 ft3/sx / 447 ft3 Surface casing setting depth coordinates: N---560.14 E---536.14 Any question or need additional information please call me. Robert S. Odenthal BP Exploration Alaska Drilling Engineer Work # 907-564-4387 Cell #: 907-440-0185 E-mail: odenthrs@bp.com 1 of 1 3/12/2002 3:48 PM L-119 permit Subject: L-119 permit Date: Mon, 11 Mar 2002 19:05:50 -0600 From: "Odenthal, Robert S" <OdenthRS@BP.com> To: "'bob_crandall@admin. state.ak.us"' <bob_crandall@admin. state.ak.us> CC: "Franks, James D" <FranksJD@BP.com>, "Magee, D Neil" <MageeDN@BP.com> Dear Mr. Crandall: As per our phone conversation of March 11, 2002,. L-119 is a dual injector for the Kuparuk and Schrader Bluff formations. The rig will perforate the Schrader bluff formation and then run the completion. The Kuparak will be perforated post rig operations. The Schrader Bluff formation will be isolated by the following ways: 1. Packers will bet set above and below the Schrader Bluff interval 2. Cement isolation across and with 500' above and below the Schrader Bluff. 3. Dummy valves will be placed in the waterflood mandrels between the upper and lower packers. Any questions or need for additional information please do not hesitate to contact me. Robert S. Odenthal BP Exploration Alaska Drilling Engineer Work # 907-564-4387 Cell #: 907-440-0185 E-mail: odenthrs@bp.com 1 of 1 3/11/2002 4:28 PM Well Name: I L-1191 Drill and Complete Plan Summary Type of Well service / producer / injector): Dual Injector Surface Location: X = 583,339' Y = 5,978,324' Yield Point Ib/100ft 2601 FSL, 3574' FEL of Sec. 34, T12N, R11 E Target Location: X = 586,920' Y = 5,982,850' 300 1806 FSL, 5215' FEL of Sec. 26, T1 2N, R11 E Bottom Hole Location: X = 587,212' Y = 5,983,219' below Permafrost 1 9.0-9.5 2172' FSL, 4918' FEL of Sec. 26, T1 2N, R11 E AFE Number: 15M4031 Estimated Start Date: 4/1/2002 Rig: Nabors 9ES Operating days to complete: 116.8 MD: 9973' 1 TVD: 7168' 1 1 BF/MS: 44.1' RKB: 78.9' Well Design conventional, slimhole, etc.: I Ultra Slimhole (Ion string) Objective: I Schrader/Ku aruk Formation Mud Program: 121/4" Surface Hole (0-3024'): Spud Mud Density Viscosity seconds Yield Point Ib/100ft API FL mis/30min PH Initial 8.5-8.6 300 1 50-70 15-20 8.5-9.5 below Permafrost 1 9.0-9.5 200-250 30-45 1 <10 1 8.5-9.5 interval TD 1 9.6 max 200 30-45 1 <10 1 8.5-9.5 83/4" Intermediate / Production Hole (3024'— 9973'): LSND Interval Density Tau o YP PV pH API HTHP TFA (int) (ppg) , 600 4" 17.5# 90 1800 Filtrate Filtrate Upper 9.3 4-7 20-25 8-12 8.5-9.5 4-6 1 10.3 Interval 1 18,18,18,13 .875 Top of HRZ 10.1 5-8 20-25 10-15 8.5-9.5 3-5 <10 by to TD I I HRZ Hydraulics: Surface Hole: 12-1/4" Interval Pump GPM Drill Pie AV (fpm) Pump PSI ECD ppg-emw Motor Jet ("/32) Nozzles TFA (int) 0-2,000 600 4" 17.5# 90 1800 9.7 N/A 18,18,18,13 .875 2,000'-3,002' 650 4" 17.5# 110 2400 1 10.3 1 N/A 1 18,18,18,13 .875 Intermediate/Production Hole: 83/4 " Interval Pump GPM Drill Pipe AV (fpm) Pump PSI ECD ppg-emw Motor Jet ('/32) Nozzles TFA (int) 3002'- 7700' 575 4" 17.5# 200 3400 11.3 N/A 6x15 1.03 L-1 19i Drilling Permit (LSND) Page 1 Directional: Ver. Anadrill P5 Slot NV Drilling: MWD/GR/Dir KOP: 300' Maximum Hole Angle: 55.90at 2769-6091' MD Close Approach Wells: All wells pass major risk criteria. Drilling: MWD/GR/Res/Den/Neu/Dir L-01 — 449' offset @ 500' Open Hole: Cuttings Evaluation L-104 — 399' offset @ 400' Cased Hole: USIT cement evaluation L-106 — 1373' offset @ 1400' 1885' L-107 — 499' offset @ 500' L-110 — 350' offset @ 350' 2079' L-114 — 641' offset @ 650' L-115 — 645' offset @ 650' 2280' L-116 — 975' offset @ 1000' L-117 — 549' offset @ 550' 2739' L-120 — 299 offset @ 300 IFR -MS corrected surveys will be used for survey 3389' validation. Gyro will be on standby for surface hole close 4058' approaches. Loaaina Proaram: Surface Hole Drilling: MWD/GR/Dir TVDss Open Hole: None SV5 Cased Hole: None Production Hole Drilling: MWD/GR/Res/Den/Neu/Dir SV4 Open Hole: Cuttings Evaluation 1689' Cased Hole: USIT cement evaluation Formation Markers: Formation Tops MDbkb TVDss Estimated pore pressure, PPG SV5 1554' 1544' SV4 1707' 1689' Base Permafrost 1885' 1854' SV3 2079' 2029' SV2 2280' 2199' SV1 2739' 2519' UG4A 3389' 2884' UG3 4058' 3259' UG1 5012' 3794' Ma 5592' 4119' Hydrocarbon Bearing, 1806 psi, 8.43 ppg EMW WS2 N sands 6091' 4399' Hydrocarbon Bearing WS1 O sands 6335' 4544' Hydrocarbon Bearing Obf Base 6883' 4924' Hydrocarbon Bearing CM2 Colville 7231' 5177' CM1 Colville 8202' 5882' THRZ 8845' 6349' L-1 19i Drilling Permit (LSND) Page 2 / BHRZ Kalubik 9100' 6534' K-1 9210' 6614' Ku aruk C 9287' 6490' Hy drocarbon Bearing, 3540 psi, 10.0 ppg EMW TMLV Miluveach 9823' 7059' TD Criteria 9973' 7168' 150' below Miluveach to Casing/Tubing Program: Hole Size Csg/ Wt/Ft Tbg O.D. Grade Conn Length Top MD/TVD Btm MD/TVD bkb 42" Insulated 20" 91.5# H-40 WLD 110' GL 110/110 121/4 9 5/8" 40# L-80 BTC 3024' G L 302472679' 83/4 7" 26# L-80 BTC -m 9973' G L 99739/7168' Tub in 31/2 9.2# L-80 NSCT 3745' 53929/4007' 997377168' Tub in 41/2" 12.6# L-80 NSCT 6228' GL 539274007' Integrity Testing: Test Point Depth Test Type EMW Surface Casing Shoe 20' min from LOT 13.1 ppg EMW Target surface shoe Cement Calculations: Note: The following surface cement calculations are based upon a single stage job. A port collar will be utilized if hole conditions indicate that cement may not circulated to surface in a single stage. Casina Size 19-5/8" Surface Basis: Lead: Based on 1885' of annulus in the permafrost @ 215% excess and 638' of open hole from top of tail slurry to base permafrost @ 30% excess. Lead TOC: To surface 1 Tail: Based on 500' MD open hole volume + 30% excess + 80' shoe track volume. Tail TOC: At 2523' MD Total Cement Volume: Lead 352 bbl / 1971 ft / 444 sks of Dowell ARTICSET Lite at 10.7 ppg and 4.44 cf/ . Tail 36 bbl / 202 ft/172 sks of Dowell Premium `G' at 15.8 ono and 1.17 cf/sk. Casing Size 17" Production Longstring Basis: Stage 1: Based on TOC 500' above top 9f Kuparuk formation + 30% excess + 80' shoe Cement Placement: From shoe to 8787' MD (estimated) Stage 2: Based on TOC 500' above top of Schrader formation + 305 -excess Cement Placement: From 500' below Schrader 7383' to 5091' MD estimated Total Cement Volume: Stage 1 26 bbls / 150 Y /_128 sks of Dowell Premium "G" at 15.8 Ippg and 1.17cf/sk L1`4 Stage 2 52 bbls / 290, t / sks of-156well Premium "G" at 15.8 and 1.17cf/sk. `Z L-1 19i Drilling Permit (LSND) Page 3 Well Control: Z' Surface hole will be drilled with diverter. The intermediate hole, well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Based on the requirement for MI service up to 4000 psi the BOP equipment will be tested to 4000 psi Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Production Interval- * Maximum anticipated BHP: 3375 �i @ 6490' TVDss — Kuparuk Sands • Maximum surface pressure: 3038 psi @ surface (based on BHP and a full column of gas from TD @ 0.10 psi/ft) • Planned BOP test pressure: 4000 psi (The casing and tubing will be tested to 4000 psi.) • Planned completion fluid: 8.8 ppg filtered seawater / 6.8 ppg Diesel Disposal: f, • No annular disposal in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS -04. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS - 04 for disposal. Haul all Class I wastes to Pad 3 for disposal. L-1 19i Drilling Permit (LSND) Page 4 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Riq Work: 1. Weld an FMC landing ring for the FMC Ultra slimhole wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. 3. Ensure any required plugs and / or well shut-ins have been accomplished in nearby wells for rig move and close approach concerns. Riq Operations: 1. MIRU Nabors 9ES on Slot NV. 2. Nipple up diverter spool and riser. A diverter waiver has been wed for. PU 4" DP as required anc ------------ stand back in derrick. f 3. MU 12 '/a" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3024 MD/2679' TVD. The intent is to drill the entire surface section with Smith FGXiCPS "Twist and Shout" The actual surface hole TD r'll be +/-100' TVD below the top of the SV1 sand. 4. Run and cement the 9-5/8", 40# surface casing back to surface. A Tam port collar may be run in the casing to allow for secondary cementing if hole conditions indicate that cement may not reach surfacE during primary cementing operations. j 5. ND diverter spool and NU casing / tubing head. NU BOPE and test to 4000 psi. 6. MU 8-3/4" drilling assembly with MWD/GR/RES/DEN/NEU and RIH to float collar. Test the 9-5/8' casing to 3000 psi for 30 minutes. Z 7. Drill out shoe joints and displace well to 9.3 ppg LSND drilling fluid. Drill new formation to 20' below 9. 5/8" shoe and perform Leak Off Test.' 8. Drill ahead and increase mud weight to 9.6 ppg prior to entering the Schrader Oa sand. 9. Drill to +/-100' above the HRZ, ensure mud is in condition to 10.1 ppg and perform short trip aE needed. Ensure Pre -Reservoir meeting is held highlighting kick tolerance and detection prior tc entering HRZ. ,r 10. Drill ahead to -150' of rat hole into the Miluveach formation. Condition hole for running 7" 26# long. string. 11. Run and cement the 7" production casing in two stages. This is expected to be a two stage job wO 15.8 ppg lead across the Kuparuk followed by a 15.8 ppg tail across the Schrader utilizing a Type I - External sleeve (ES) Cementer. Displace the primary and secondary job with 10.1 ppg mud. 12. Close the ES Cementer by dropping closing plug. When the closing plug is within 10 bbl of the stagE tool, adjust the rate to between 5 and 10 bbl/min to land the plug. Once the plug impacts the cementer, increase pressure to close the cementer based on the following formula: Final displacement pressure + Closing pressure of cementer * ± 250 psi = Pressure to close cementer See Attachments section for specfic information for closing pressures of the ES Cementer - Type H. Hold the closing pressure for 2 minutes, then release. If you get enough flowback to indicate the tool is still open, increase the pressure by 250 psi, and re -apply for 2 minutes more. 13. Lock rings in the external closing sleeve lock the cementer in the closed position. 14. RIH w/ bit to drill out closing plug and clean out to ETD. When doing the clean out RIH rotating 40-60 rpm. Circulate at 40 gal/min per inch of bit. While maintaining rotation and pump rate, pick up the bit every 2 in. of penetration to clear rubber debris from around the bit. After the bit is past the plug(s), increase bit weight to 3,000 to 5,000 Ib/in. of bit diameter to drill the aluminum se�ts. With the drill bit chase the remaining debris that is not drilled out to the bottom. 15. Displace the well to 8.9 ppg completion brine. 16. Spot a 9.4 ppg pert pill across Schrader interval when POOH. L-1 19i Drilling Permit (LSND) Page 5 17. Freeze protect the 7" x 9-5/8" annulus as required. Record formation breakdown pressure on Morning Report. 18. Test the casing to 4000 psi for 30 min. 19. RU Schlumberger and run USIT log on a -line from the 7" float collar to the 9 5/8" surface shoe. 20. Perforate Schrader interval on TCP. 21. Make bit/scraper run positioning scrapper 100' above ES Cementer when bit below tags float collar. Circulate to clean 8.9 ppg brine a�nAPOOH laying down excess drill -pipe. 22. Run the combination 3-1/2" 9.3#, L-80 TC -II / 4-1/2", 12.6#, L-80 TC -II straddle completion assembly. Set packers and test the tubing to 4000 psi and annulus to 4000 psi for 30 minutes on chart recorder. Shear RP valve and install TWC. Test below to 2700 psi. 23. Nipple down the BOPE. Nipple up and test the tree to 5000 psi. Remove TWC. 24. Freeze protect the well by pumping diesel to the lowermost 4-1/2" GLM. Allow diesel to U-tube from the annulus to tubing. 25. Rig down and move off. L-1 19i Drilling Permit (LSND) Page 6 L-1191 Hazards and Contingencies Job 1: MIRU Hazards and Contingencies ➢ L -Pad is not designated as an H2S site. Standard Operating Procedures for H2S precautions should be followed at all times. ➢ The closest surface location is L-120, 60 feet to the east. Surface shut-in will be required as this well is on production. If the well house is removed for rig access to L-1191, the SSSV will need to be closed as well. ➢ Check the landing ring height on L-119. The BOP nipple up may need review for space out. ➢ Based on pore pressure data and experienced gained on the Borealis L -pad wells the AOGCC has been asked for dispensation from the diverter requirement on the 12 1/a" surface hole. During the Surface Hole Planning Meeting and PJSM's the absence of a diverter on the surface hole on this is to be discussed. Monitoring the hole, checking connections, importance of maintaining mud properties (including pre -treating with DrillTreat for Hydrates), focus on avoiding swabbing situations, importance of not loading up the hole (hole cleaning), evacuation drills, muster areas, etc. should be topics for discussion and action. The waiver has been justified based on extensive penetrations below "L" pad with no shallow gas problems and L-106 open hole surface logging. The absence of the ability to divert requires even greater diligence while drilling the surface hole. Reference RPs Operational Specifics Job 2: Drilling Surface Hole ➢ One fault is expected near the base of the permafrost. Offset wells have no had lost circulation problems associated with this fault. ➢ There is one close approach issue in the surface hole. All wells pass major risk criteria. The closest existing well, L-1 20i is 299' center -center at surface to -300' MD. Gyro survey tools will be on standby while drilling the surface hole until clear of magnetic interference. ➢ Gas hydrates have been observed all wells drilled on L -Pad. These were encountered near the base of permafrost to TD in the SV1 sand. Hydrates will be treated at surface with appropriate mud products and adjustment of drilling parameters. Refer to Baroid mud recommendation ➢ Associated with the hydrates, the danger of deeper gravel beds below the Permafrost that will tend to slough in when aerated gas cut hydrate mud is being circulated out. Maintain adequate viscosity. Reference RPs Operational Specifics L-1 19i Drilling Permit (LSND) Page 7 Job 3: Install Surface Casing Hazards and Contingencies ➢ It is critical that cement is circulated to surface for well integrity. 215% excess cement through the permafrost zone (and 30% excess below the permafrost) is planned. If hole conditions indicate that cement to surface may be an issue, a 9-5/8" port collar will be positioned at ±1000'MD to allow a secondary circulation. ➢ "Annular Pumping Awad' criteria for future permitting approval for annular injection. 1. Pipe reciprocation during cement displacement 2. Cement - Top of tail >500' TVD above shoe using 30% excess. 3. Casing Shoe Set approximately 100'TVD below SV -1 sand. Reference RPs Operational Specifics Job 7: Drilling Production Hole Hazards and Contingencies ➢ L-1 19i will cross a fault in the Schrader at 4106' TVD (+/-150'). The estimated throw of the fault is approximately 80'. Loss circulation is considered to be a moderate risk. The second fault is at a depth of 4755' TVD (+/-150') near the base of the Schrader. The estimated throw is 100'. Consult the Lost Circulation Decision Tree regarding LCM treatments and procedures. ➢ KICK TOLERANCE: The reservoir pressure of the Kuparuk has been determined to be 10.0 ppg. In the worst case scenario of 10.1 ppg pore pressure at the Kuparuk target depth, gauge hole, a fracture gradient of 13.1 ppg at the surface casing shoe, 10.2 ppg mud in the hole the kick tolerance is 25.8 bbls. Contact Drilling Superintendent if LOT is less than 13.1 ppg. ➢ L -Pad development has had "kick tolerances" in the 35-45 bbl range. A heightened awareness of kick detection, pre -job planning and trip tank calibration will be essential while drilling/tripping the intermediate/production intervals. ➢ There are no "close approach" issues with the production hole interval of L-1 19i. ➢ A LSND mud system will be used in the production interval. Experience suggest that the first wiper trip be made after approximately 1500' of new hole has been drilled. Flow rates should be maintained in the 575 gpm range particularily while drilling with higher ROP's (300'/hr) through the SV and Ugnu intervals. Note: Baroid will prepare hydraulic and hole cleaning models for these hole intervals prior to spud. Reference RPs Operational Specifics Job 9: Case & Cement Production Hole L-1 19i Drilling Permit (LSND) Page 8 Hazards and Contingencies ➢ The 7" casing will be cemented to 500' above the Schrader sand if logs indicate that it is oil bearing otherwise the cement will be brought up to 1000' above the Kuparuk. The top of the hydrocarbon interval should be verified with LWD resistivity log. ➢ A 7" Halliburton ES stage cementer will be utilized in the production casing string. This will be positioned 400-500' below the Schrader formation to allow for a stage cement job utilizing 15.8 ppg G across the Schrader interval. The Kuparuk will be cemented in the first stage utilizing 15.8 ppg G from TD to 500' above the Kuparuk. ➢ Ensure the production cement has reached a compressive strength of 500 psi prior to freeze protecting. After freeze protecting the 7" x 9-5/8" casing outer annulus with 56 bbls of diesel (2000'), the hydrostatic pressure will be 10.0 ppg vs the 9.8 ppg EMW of the formation pressure. Ensure a double -barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude however the hydrostatic pressure of the mud and diesel should exert a 46 psi overbalance to the open hole. (A second LOT will be required prior to displacing freeze protect. This to satisfy AOGCC for future annular pumping permits.) A cement bond log (USIT) will be run to confirm cement quality and the TOC. This will be done with the rig prior to perforating the well. ➢ Ensure a minimum hydrostatic equivalent of 10.1 ppg on the Kuparuk formation during pumping of cement pre flushes/chemical washes. Losses of hole integrity and packing off has resulted from a reduction in hydrostatic pressure while pumping spacers and flushes Reference RPs ,., as Operational Specifics Job 10: Perforate Well Hazards and Contingencies ➢ The Schrader interval of the well will be TCP perforated prior to running the completion. After placing a brine perf pill weighted to 9.4 ppg the well will be perforated across a 8.9 ppg EMW reservoir for an overbalance of 125 psi. Be prepared for losses upon firing guns. Ensure all responsibilities are clearly communicated with respect to perforating guns safety. Watch hole fill closely while POH with pert guns. ➢ A USIT log will be required from the ETD to the top of cement. Send results of USIT log into Anchorage office as soon as practical for evaluation. Reference RPs Operational Specifics Job 12: Run Completion Hazards and Contingencies ➢ Watch hole fill closely and verify proper safety valves are on the rig floor while running this completion. The Schrader interval of the well will be perforated. ➢ Take care while passing through ES Cementer with packer and completion string. L-1 19i Drilling Permit (LSND) Page 9 Reference RPs Operational Specifics Job 13: ND/NU/Release Rig Hazards and Contingencies ➢ No hazards specific to this well have been identified for this phase of the well construction. Reference RPs Operational Specifics L-1 19i Drilling Permit (LSND) Page 10 Borealis L-1191 Proposed Completion TREE: 4-1/16 "- 5M CIW Carbon WELLHEAD: 11"- 5M FMC G5 9-5/8", 40 #/ft, L-80, BTI 3024' ::] 4-1/2"'X' Landing Nipple with 3 seal bore 7" x 4-1/2" Baker "Premium" Production Packer 50' above top Schrader perforation 3-1/2" MMGW Water Flood with Injection Valve with Nev Vam BxP 7" 'TAM port collar below Scl Plug Back 9893' 7", 26 #/ft, L-80, BTC - 9973' Cellar Elevation = t44.1' RKB-MSL = t78.9' 4-1/2" 'X' Landing Nipple with 3.813" seal bore. 2200' Gas Lift Mandrels with handling pups installed. GAS LIFT MANDRELS # MD Type Valve Type 1 TBD 3-1/2" MMGW Dummy 2 TBD 3-1/2" MMGW Dummy 3 TBD 4-1/2" KBG-2 RP 4 TBD 4-1/2" KBG-2 Dummy 4-1/2" 12.6# L-80, TC -II Connection Tubing /2" TC -II Tubing below top packer 2"X Landing Nipple with 2.813" seal bore. 4-1/2" Baker "S-3" Packer +/- 200' above Kuparuk 2"X Landing Nipple with 2.813" seal bore. 2"X Landing Nipple with 2.813" seal bore 2" Wireline Entry Guide set at +/-120' above the Kuparuk Formation Date Rev By Comments 3-4-02 RSO Proposed Completion (P5) Borealis WELL: L-1 19i API NO: 50-029-???? BP Alaska 6000 5000 4000 A A A N_ z3000 2000 O V v 1000 0 -1000 Schlumberger ..................................... ..................................................................... ..............................................................................,................................................................:.::.........:............................... :.::i:.. ........: ........................... � Target 9287 MD X670 TVD 43.43' 38� 93' az 4486 N 331 E I ............... L................................. i..................... j ............................................... � 'End Cry ....................... .............. :6715 MD 4802 TVD (10 QV j43.43' 38.93' az \ :3110 N 2520E \`. �r Target I Cry 2/100 .(� 6091 MD . 399 TVD ax 2741 29:21 2741 N 2221 E ................................................a.....:.............................................................................................................................................................................................................. i ........................... 9-5/8^ Csg Pt 3024 MD 2679 TVD 55.90' 39.02' az 768 N 622 E End Bid 2769 MD 236 TVD ..........55 90 39.02' az .................................................................. ,............................. 604 N 490 ....................................... ...:........................ ................. .....................................................�........ .... \ Bid 41100 Y 2013 MD 1970 TVD 25.62' 39.02' az 225 N 182 E Bid 21100 1913 MD 1879 TVD ........... ............................................ ........................ 1................................... \........................... 192 N....1.3.964E'...........; ................................. ..............i........... ................ ....... ......... .......................... End Bid \ / \ ` 1850 MD 1822 TVD 23.62' 39.02' az \ 173 N 140E Bid 2.51100 KOP Bid 11100 Bid 1.751100 1400 MD 1394 TVD 500 MD 500 TVD 950 MD 950 TVD 12.37• 39.02' az 0.00' 39.02' az 4.50' 39.02' az 65N 53E ON OE 14N 11E ...._............ ...... __..... ..... ...... .. ... ....... ........ .......... 0 1000 2000 3000 4000 <<< WEST EAST >>> 6000 5000 4000 3000 2000 1000 0 -1000 0 11-1 -j 2000 O Z> O O N N > II _p C 4000 CO o. ti 0 Y CU ry W 6000 8000 bp VERTICAL SECTION VIEW Client: BP Exploration Alaska Well: L-119 (P5) Field: Prudhoe Bay Unit - WOA Structure: L -Pad Section At: 38.98 deg Date: February 26, 2002 Schlumberger -4000 -2000 0 2000 4000 6000 8000 10000 Vertical Section Departure at 38.98 deg from (0.0, 0.0). (1 in = 2000 feet) by f- :it w L-119 ■ •am on w r■■ _ AI - AN - r% Schlumberger WC rroposea vveii rrome - veoaeut; Kepvrt Report Date: February 26, 2002 Survey I DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 38.980° Field: Structure I Slot: Prudhoe Bay Unit - WOA (Drill Pads) L -Pad / L-119 Vertical Section Origin: TO Reference Datum: N 0.000 ft, E 0.000 fl KB Incl ® ® t TO VSec Well: L-119 ® TO Reference Elevation: 78.9 ft relative to MSL Borehole: L -119P IF Sea Bed / Ground Level Elevation: 44.100 ft relative to MSL UWIIAPI#: 50029 F;u Magnetic Declination: 26.0580 Survey Name I Date: L-119 (P5) / February 26, 2002 Total Field Strength: 57472.984 nT Tort I AHD I DDI 1 ERD ratio: 68.364° / 6242.52 ft / 5.774 / 0.871 Magnetic Dip: 80.764° Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feel Declination Date: April 10, 2002 Location LatlLong: N 70.35074668, W 149.3233593E Magnetic Declination Model: BGGM 2001 Location Grid NIE YIX: N 5978324.480 ftUS, E 583339.580 ftUS North Reference: True North Grid Convergence Angle: +0.63724234° Total Corr Mag North -> True North: +26.058° Grid Scale Factor: 0.99990789 Local Coordinates Referenced To: Well Head L-119 (P5) report.xls Page 1 of 3 2/26/2002-10:05 AM Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TO VSec NI -S EI -W DLS :..1100ft Northing Easting Latitude Longitude ft ft ft ft ft ftuS ftUS KBE 0.00 0.00 39.02 0.00 0.00 0.00 0.00 0.00 5978324.48 583339.58 N 70.35074668 W 149.32335938 KOP Bid 1/100 500.00 0.00 39.02 500.00 0.00 0.00 0.00 0.00 5978324.48 583339.58 N 70.35074668 W 149.32335938 600.00 1.00 39.02 599.99 0.87 0.68 0.55 1.00 5978325.17 583340.12 N 70.35074854 W 149.32335492 700.00 2.00 39.02 699.96 3.49 2.71 2.20 1.00 5978327.21 583341.75 N 70.35075408 W 149.32334152 800.00 3.00 39.02 799.86 7.85 6.10 4.94 1.00 5978330.63 583344.45 N 70.35076335 W 149.32331928 900.00 4.00 39.02 899.68 13.96 10.84 8.79 1.00 5978335.42 583348.25 N 70.35077629 W 149.32328802 Bid 1.75/100 950.00 4.50 39.02 949.54 17.66 13.72 11.12 1.00 5978338.32 583350.55 N 70.35078416 W 149.32326911 1000.00 5.38 39.02 999.35 21.97 17.07 13.83 1.75 5978341.70 583353.22 N 70.35079331 W 149.32324711 1100.00 7.12 39.02 1098.75 32.85 25.52 20.68 1.75 5978350.23 583359.97 N 70.35081640 W 149.32319150 1200.00 8.88 39.02 1197.78 46.77 36.34 29.45 1.75 5978361.14 583368.62 N 70.35084596 W 149.32312030 1300.00 10.62 39.02 1296.33 63.70 49.49 40.11 1.75 5978374.41 583379.13 N 70.35088188 W 149.32303376 Bid 2.5/100 1400.00 12.37 39.02 1394.32 83.64 64.98 52.66 1.75 5978390.04 583391.51 N 70.35092420 W 149.32293188 1500.00 14.87 39.02 1491.49 107.19 83.28 67.49 2.50 5978408.50 583406.13 N 70.35097419 W 149.32281148 SV5 1554.40 16.23 39.02 1543.90 121.78 94.62 76.67 2.50 5978419.94 583415.19 N 70.35100517 W 149.32273696 1600.00 17.37 39.02 1587.55 134.97 104.86 84.97 2.50 5978430.27 583423.37 N 70.35103315 W 149.32266958 1700.00 19.87 39.02 1682.31 166.90 129.67 105.08 2.50 5978455.30 583443.20 N 70.35110093 W 149.32250632 SV4 1707.01 20.05 39.02 1688.90 169.29 131.53 106.59 2.50 5978457.17 583444.69 N 70.35110601 W 149.32249406 1800.00 22.37 39.02 1775.58 202.94 157.67 127.77 2.50 5978483.55 583465.58 N 70.35117742 W 149.32232211 L-119 (P5) report.xls Page 1 of 3 2/26/2002-10:05 AM Station ID \ft) (ft) Incl \O) Arrzim (0) TVD (ft) VrrSec (ft) N/ }} -S ('-) Err/{{ -}}W (ft) End Bid 1850.00 23.62 39.02 1821.60 222.47 172.85 140.07 Base Permafrost 1885.25 23.62 39.02 1853.90 236.60 183.82 148.96 Bid 2/100 1912.54 23.62 39.02 1878.90 247.53 192.32 155.85 N 70.35134903 W 149.32190879 2000.00 25.37 39.02 1958.49 283.80 220.49 178.68 Bid 4/100 2012.54 25.62 39.02 1969.80 289.20 224.69 182.08 SV3 2078.84 28.28 39.02 2028.90 319.25 248.03 201.00 N 70.35167762 W 149.32111754 2100.00 29.12 39.02 2047.46 329.41 255.93 207.39 N 70.35195656 W 149.32044570 2200.00 33.12 39.02 2133.05 381.09 296.08 239.93 SV2 2280.14 36.33 39.02 2198.90 426.73 331.54 268.67 N 70.35239709 W 149.31938476 2300.00 37.12 39.02 2214.82 438.61 340.77 276.14 N 70.35348636 W 149.31676124 2400.00 41.12 39.02 2292.38 501.70 389.78 315.86 N 70.35633853 W 149.30988988 2500.00 45.12 39.02 2365.36 570.04 442.88 358.89 N 70.35823456 W 149.30532052 2600.00 49.12 39.02 2433.39 643.31 499.81 405.02 N 70.35824999 W 149.30528331 2700.00 53.12 39.02 2496.14 721.14 560.28 454.02 SV 1 2738.63 54.67 39.02 2518.90 752.35 584.53 473.67 End Bld 2769.34 55.90 39.02 2536.39 777.60 604.14 489.56 9-5/8" Csg Pt _ 3023.52 55.90 39.02 2678.90 988.06 767.66 622.06 UG4A 3389.14 55.90 39.02 2883.90 1290.81 1002.89 812.66 UG3 4057.98 55.90 39.02 3258.90 1844.63 1433.17 1161.32 UG1 5012.18 55.90 39.02 3793.90 2634.74 2047.05 1658.74 Ma 5591.83 55.90 39.02 4118.90 3114.71 2419.96 1960.92 WS2 6091.21 55.90 39.02 4398.89 3528.21 2741.23 2221.24 Target / Cry 2/100 6091.23 55.90 39.02 4398.90 3528.23 2741.25 2221.25 6100.00 55.72 39.02 4403.83 3535.48 2746.88 2225.82 6200.00 53.72 39.00 4461.58 3617.12 2810.32 2277.20 6300.00 51.72 38.99 4522.15 3696.68 2872.15 2327.27 WS 1 6334.85 51.02 38.99 4543.90 3723.90 2893.31 2344.40 6400.00 49.72 38.98 4585.45 3774.09 2932.32 2375.97 6500.00 47.72 38.96 4651.42 3849.23 2990.74 2423.23 6600.00 45.72 38.95 4719.97 3922.03 3047.36 2469.00 6700.00 43.72 38.93 4791.02 3992.40 3102.09 2513.22 End Cry 6714.55 43.43 38.93 4801.56 4002.43 3109.89 2519.53 Obf Base 6883.01 43.43 38.93 4923.90 4118.24 3199.99 2592.30 CM2 7231.40 43.43 38.93 5176.90 4357.75 3386.31 2742.79 CM 1 8202.20 43.43 38.93 5881.90 5025.16 3905.51 3162.14 L-119 (P5) report.xis Page 2 of 3 2/26/2002-10:05 AM Geographic Coordinates Grid Coordinates :DL:SjNorthing Easting Latitude Longitude ftUS ftUS 2.50 5978498.86 583477.71 N 70.35121889 W 149.32222225 0.00 5978509.93 583486.47 N 70.35124886 W 149.32215008 0.00 5978518.50 583493.27 N 70.35127208 W 149.32209414 2.00 5978546.92 583515.78 N 70.35134903 W 149.32190879 2.00 5978551.16 583519.13 N 70.35136051 W 149.32188119 4.00 5978574.71 583537.79 N 70.35142427 W 149.32172759 4.00 5978582.68 583544.09 N 70.35144585 W 149.32167571 4.00 5978623.18 583576.18 N 70.35155553 W 149.32141153 4.00 5978658.96 583604.52 N 70.35165240 W 149.32117819 4.00 5978668.27 583611.89 N 70.35167762 W 149.32111754 4.00 5978717.71 583651.06 N 70.35181151 W 149.32079506 4.00 5978771.28 583693.49 N 70.35195656 W 149.32044570 4.00 5978828.72 583738.98 N 70.35211209 W 149.32007117 4.00 5978889.72 583787.30 N 70.35227728 W 149.31967332 4.00 5978914.19 583806.68 N 70.35234352 W 149.31951378 4.00 5978933.97 583822.35 N 70.35239709 W 149.31938476 0.00 5979098.94 583953.01 N 70.35284379 W 149.31830891 0.00 5979336.25 584140.96 N 70.35348636 W 149.31676124 0.00 5979770.34 584484.78 N 70.35466172 W 149.31392986 0.00 5980389.66 584975.30 N 70.35633853 W 149.30988988 0.00 5980765.87 585273.28 N 70.35735708 W 149.30743528 0.00 5981089.98 585529.99 N 70.35823456 W 149.30532052 0.00 5981090.00 585530.00 N 70.35823462 W 149.30532044 2.00 5981095.68 585534.51 N 70.35824999 W 149.30528331 2.00 5981159.69 585585.17 N 70.35842326 W 149.30486590 2.00 5981222.06 585634.55 N 70.35859213 W 149.30445911 2.00 5981243.41 585651.44 N 70.35864993 W 149.30431994 2.00 5981282.77 585682.57 N 70.35875647 W 149.30406346 2.00 5981341.70 585729.17 N 70.35891603 W 149.30367949 2.00 5981398.82 585774.31 N 70.35907067 W 149.30330762 2.00 5981454.03 585817.91 N 70.35922014 W 149.30294835 2.00 5981461.90 585824.13 N 70.35924145 W 149.30289708 0.00 5981552.80 585895.89 N 70.35948752 W 149.30230583 0.00 5981740.76 586044.28 N 70.35999639 W 149.30108306 0.00 5982264.55 586457.79 N 70.36141434 W 149.29767541 2/26/2002-10:05 AM Leaal Description: Surface : 2601 FSL 3574 FEL S34 Tl 2N R11 E UM Target/ Cry 2/100: 62 FSL 1348 FEL S27 T12N R11E UM Target: 1806 FSL 5215 FEL S26 T12N R11 E UM BHL : 2172 FSL 4918 FEL S26 T12N R11 E UM 5983219.94 Grid Coordinates Geographic Coordinates Station ID MD Incl Azim ND VSec NI-S EI-W DLS Northing Easting Latitude Longitude ft ft ft ft ft °1100ft ftUS ftUS Top H RZ 8845.27 43.43 38.93 6348.90 5467.25 4249.44 3439.93 0.00 5982611.51 586731.72 N 70.36235358 W 149.29541782 Base HRZ 9100.02 43.43 38.93 6533.90 5642.39 4385.68 3549.97 0.00 5982748.95 586840.22 N 70.36272564 W 149.29452347 K-1 9210.18 43.43 38.93 6613.90 5718.12 4444.60 3597.56 0.00 5982808.39 586887.15 N 70.36288654 W 149.29413668 Top Kuparuk / C 9287.28 43.43 38.93 6669.89 5771.13 4485.83 3630.87 0.00 5982849.99 586920.00 N 70.36299913 W 149.29386594 Target 9287.30 43.43 38.93 6669.90 5771.14 4485.84 3630.87 0.00 5982850.00 586920.00 N 70.36299916 W 149.29386594 Top Miluveach 9822.94 43.43 38.93 7058.89 6139.38 4772.32 3862.26 0.00 5983139.01 587148.17 N 70.36378148 W 149.29198517 TD / 7" Csg Pt 9972.96 43.43 38.93 7167.83 6242.51 4852.55 3927.06 0.00 5983219.94 587212.06 N 70.36400057 W 149.29145844 Leaal Description: Surface : 2601 FSL 3574 FEL S34 Tl 2N R11 E UM Target/ Cry 2/100: 62 FSL 1348 FEL S27 T12N R11E UM Target: 1806 FSL 5215 FEL S26 T12N R11 E UM BHL : 2172 FSL 4918 FEL S26 T12N R11 E UM Northing m fftUS1 Easting W MUST 5978324.48 583339.58 5981090.00 585530.00 5982850.00 586920.00 5983219.94 587212.06 L-119 (P5) report.xls Page 3 of 3 2/26/2002-10:05 AM W Schlumberger Anticollision Report Company: BP Amoco Date: 2/26/2002 Time: 10:32:11 Page: 1 Field: Prudhoe Bay Reference Site: PB L Pad Co-ordinate(NE) Reference: Well: L-119, True North Reference Well: L-119 ' Vertical (TVD) Reference: L-119 plan 78.9 Reference Wellpath: Plan L-119 Db: Sybase NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Interval: 50.00 ft Error Model: ISCWSA Ellipse Depth Range: 28.50 to 9972.96 ft Scan Method: Trav Cylinder North Maximum Radius: 1192.15 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 12/26/2000 Validated: No Version: 7 Planned From To Survey Toolcode Tool Name ft ft 28.50 600.00 Planned: Plan #5 V1 CB -GYRO -SS Camera based gyro single shots 600.00 9972.96 Planned: Plan #5 V1 MWD+IFR+MS MWD + IFR + Multi Station Casing Points MD :TVD.. Diami�ter ... ;Hole Size .. ;Name ::. . ft ft An ....:... :..:: . 3023.47 2678.90 9.625 12.250 95/81, 9972.96 7167.75 7.625 8.750 7 5/8" Summary <-=-----=--=---: Offset Well ath:_'�:: r path, .:.: , :..::: Reference Re � Offset - ^ :Ctr ;Ckr.. -Allowable No' Go I.. :.: .::. .. Site.::.:::: Well . Well ath .: :MD: MD ;Distance Area ::..: Deviation ... .:: War.nin ff ft ft ft EX NWE#1 NWE1-01 NWE1-01 V3 299.99 300.00 464.10 6.40 457.70 Pass: Major Risk EX NWE#1 NWE1-01 NWE1-01A VO 299.99 300.00 464.10 6.40 457.70 Pass: Major Risk EX NWE#1 NWE1-02 NWE1-02 V2 2007.92 2100.00 241.28 39.14 203.84 Pass: Major Risk PB L Pad L-01 L-01 V14 449.97 450.00 226.81 8.90 217.91 Pass: Major Risk PB L Pad L-104 L-104 V7 399.99 400.00 179.51 7.98 171.53 Pass: Major Risk PB L Pad L-106 L-106 V14 1373.25 1400.00 125.48 22.03 103.68 Pass: Major Risk PB L Pad L-107 L-107 V14 499.50 500.00 214.33 11.32 203.01 Pass: Major Risk PB L Pad L-110 L-110 V11 349.97 350.00 309.52 7.65 301.88 Pass: Major Risk PB L Pad L-111 L-111 V19 Plan: Plan # 350.00 350.00 398.13 7.64 390.49 Pass: Major Risk PB L Pad L-114 L-114 V14 640.98 650.00 369.54 11.22 358.32 Pass: Major Risk PB L Pad L-115 L-115 V7 644.81 650.00 230.72 11.93 218.80 Pass: Major Risk PB L Pad L-116 L-116 V10 974.91 1000.00 280.90 15.80 265.10 Pass: Major Risk PB L Pad L-117 L-117 V11 548.50 550.00 221.41 10.13 211.28 Pass: Major Risk PB L Pad L-120 L-120 V8 299.98 300.00 32.38 6.34 26.05 Pass: Major Risk Target: L-119 Kup Tgt +E/ -W ft -395.58 404.44 395.58 -404.44 �L-119,L-118 on: Planned Program Site: PB L Pad Vertical Depth: 6591.00 ft below Mean Sea Level Drilling Target Conf.: 99% ' Centre Location: 0 D D �0 } Map Northing: 5982850.00 ft ( CEJ M Map Easting : 586920.00 ft Easting ft Latitude: 70°21'46.797N Polygon +N/ -S ft 1 404.44 2 395.58 3 -404.44 4 -395.58 Target: L-119 Kup Tgt +E/ -W ft -395.58 404.44 395.58 -404.44 �L-119,L-118 on: Planned Program Vertical Depth: 6591.00 ft below Mean Sea Level Local +N/ -S: 4486.00 ft Local +E/ -W: 3630.66 ft 0 D D �0 } Longitude: 149'17'37.917W ( CEJ M Northing ft Easting ft 5983250.00 586520.00 5983250.00 587320.00 5982450.00 587320.00 5982450.00 586520.00 �200 =1 0 D D �0 } O ( CEJ M m LO m 00 m�- �200 =1 x Site: PB L Pad Drilling Target Conf.: 99% Centre Location: Map Northing: 5981090.00 ft Map Easting : 585530.00 ft Latitude: 70°21'29.645N Shape: Circle Target: L-119 SB Tgt �L-119 on: Planned Program Vertical Depth: 4320.00 ft below Mean Sea Level Local +N/ -S: 2741.34 ft Local +E/ -W: 2221.12 ft Longitude: 149°18' 19.154W Radius: 150 ft 0 0 0 0 0 0 0 0 0 0 m Ln C\j C\j 2,00 2600 2500 H 205537 DATE 1 CHECK NO. 02/15/02 1-00205537] VENDOR Ai Acm do T I A nn DATE INVOICE / CREDIT MEMO DESCRIPTION GROSS DISCOUNT NET 021302 CK021302 F 100-00 100-00 PYMTCOMMENTS: Permit to Drill Fee HANDLING INST: S/H — Sondra) Ste man X4750 E C E- I'k, F D Alaska Oil G"s 00 s. Aml,h,fuImoe THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. m to]100-00 100.00 BP EXPLORATION, (ALASKA) INC. RO. BOX 196612 ANCHORAGE, ALASKA 99519-6612 FIRST NATIONAL BANK OF ASHLAND AN AFFILIATE OF NATIONAL CITY BANK CLEVELAND, OHIO 56-389 412 No. H 205.537 CONSOLIDATED COMMERCIAL ACCOUNT 00205537 PAY ONE HUNDRED & 0011(]0########## tt## ## ### ########### ### US DOLLAR DATE' AMOUNT 52/15/02 $100.00 To The ALASKA OIL AND GAS NOT VALID AFTER 120 DAYS ORDER CONSERVATION COMMISSION Of 333 WEST 7TH AVEI+.IUE SUITE 100 # ANCHORAGE AK 99501�� y . u' 20 S S 3 7u' 1:0 4 L 20 38 9 SI: 008 4 4 it 9u' H TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSIMTTA.L LETTER WELL NAME - CHECK 1 CHECK WHAT APPLIES STANDARD LETTER ADD-ONS OPTIONS "CLUE" DEVELOPMENT MULTILATERAL The permit is for a new wellbore segment of existing well Permit No, API No. (If api number last two (2) Production should continue to be reported as a function of digits are between 6049) the original API number stated above. DEVELOPMENT PILOT HOLE (PH) In accordance with 20 AAC 25.005(f), all records, data and REDRILL logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 -70/80) from records, data and logs acquired for well (name on permit). EXPLORATION ANNULAR_ DEPOSAL Annular disposal has not been requested ... NO INJECTION WELL ANNULAR DISPOSAL Annular Disposal, of drilling wastes will not be approved ... U YES INJECTION WELL ANNULAR DISPOSAL Annular Disposal of drilling wastes will not be approved ... REDRILL THIS WELL DISPOSAL INTO OTHER Please note that an disposal of fluids generated... . ANNULUS (� YES + SPACING EXCEPTION Enclosed is the approved application for permit, to drill the above referenced well. The permit is approved. subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) will assume the liability of any protest to the spacing exception that may occur. Templates are located m drive\jody\templates WELL PERMIT CHECKLIST COMPANY eZ,.Y WELL NAME /'���,/ 2- /�9�' PROGRAM: Exp _ Dev _ Redrll _ Serv2< Wellbore seg _ Ann. disposal para req FIELD & POOL INIT CLASS/- w.,S9 GEOL AREA UNIT# 116 SO ON/OFF SHORE -,jj_ ADMINISTRATION 1. Permit fee attached . . . . . . . . . . . . . . . . . . . 2. Lease number appropriate . . . . . . . . . . . . . . . . . . . 3. Unique well name and number ... . . . . . . . . . . . . . . . 4. Well located in a defined pool .. . . . . . . . . . . . . . . . . 5. Well located proper distance from drilling unit boundary. . . . 6. Well located proper distance from other wells.. . . . . . . . . 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . 8. If deviated, is wellbore plat included .. . . . . . . . . . . . . . 9. Operator only affected party. . . . . . . . . . . . . . . . . . 10. Operator has appropriate bond in force. . 11. Permit can be issued without conservation order. . . . . . . . APPR D T 12. Permit can be issued without administrative approval.. . . . . /111 oZ 13. Can permit be approved before 15 -day wait.. . ENGINEERING 14. Conductor string proviaea . . . . . . . . . . . . . . . . . . . 15. Surface casing protects all known USDWs. N-,fw- 16. CMT vol adequate to circulate on conductor & surf csg. . . . . 4 w_,ww_ � 17. CMT vol adequate to tie-in long string to surf csg. . . . . . . . I 18. CMT will cover all known productive horizons. . . . . . . . . . 4 Y N v e -v 19. Casing designs adequate for C, T, B & permafrost. . . . . . . N 6� N 20. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . F0� 21. If a re -drill, has a 10-403 for abandonment been approved. . . Y Y N 22. Adequate wellbore separation proposed .. . . . . . . . . . . . Y /14104q 23. If diverter required, does it meet regulations . . . . . . . . . . N y1 Y N 24. Drilling fluid program schematic & equip list adequate . . . .. APPR. DATE i 3 OZ 25. BOPEs, do they meet regulation . . . . . . . . . . . . . . 26. BOPE press rating appropriate; test to 'VD0 o psig. 27. Choke manifold complies w/API RP -53 (May 84) . . . . . . . . L�28. 3_G rte- Work will occur without operation shutdown.......... . 29. Is presence of H2S gas probable.. . GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures. 31. Data presented on potential overpressure zones . . . . . . . 32. Seismic analysis of shallow gas zones . . . . . . . . . . . . . AP DATE ,gV� �Z" 33. Seabed condition survey (if off -shore) . . . . . . . . . . . . . 34. Contact name/phone for weekly progress reports (exploratory Y N Y N Y jl Y' Y Y Y Y Y Y Y Y �Amr:� Mon N-,fw- l �� A r / 4 w_,ww_ � � - .Wk I 7-22'E) 300" Mo , - -- 4 Y N v e -v 4,� V a v v -t 5; t,cp S U N 6� N , eloov �' k F0� Y Y N Y /14104q N y1 Y N N N l �� A r / Y a CQ N N � - .Wk --N-- / (� N 7-22'E) 300" Mo , - -- 4 Y N v e -v 4,� V a v v -t 5; t,cp S U N 6� N , eloov �' k (V N a N Y Y N Y /14104q N y1 Y N ANNULAR DISPOSAL 35. With proper cementing records, this plan (A) will contain waste in a suitable receiving zone; . . . . . APPR DATE (B) will not contaminate freshwater; or cause drilling waste. to surface; (C) will not impair mechanical integrity of the well used for disposal; (D) will not damage producing formation or impair recovery from a pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. Y N CV / ff Y N4 Pj J[�,I.��ar� Y N Y N Y N GEOLOGY: ENGINEERING: UIC/Annular: COMMISSION: / RPQ/ TEM COT SFD WGAVJ61 DTS U3 0 JMH G:\geology\templates\checklist.doc Comments/Instructions:
