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Home My WebLink About199-012STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil 0 Gas 0 SPLUG 0 Other 0 Abandoned 0 Suspended 0I 20AAC 25.105 20AAC GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero lb Well Class: , Developmenlp Exploratory:-' 0 Service 0 Stratlgraphic Test 0 2. Operator Name: 6. Date Comp., Susp., o bantl 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 9/3/2019 199-012 • 319-274 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 3/16/1999 50-029-20885-01-00 4a. Location of Well (Governmental Section): 8. Date TO Reached: 16. Well Name and Number: 3/17/1999 PBU 01-26A 4 Surface: 990' FNL, 616' FVVL, Sec. 08,TION, R15E, UM 9 Ref Elevations KB 67.85 17. Field/Pool(s): Top Of Productive Interval: 2243' FNL, 5039' FWL, Sec. 08, T10N, R1 5E, UM GL 39.95 • BF 41.40 PRUDHOE BAY, PRUDHOE OIL ' Total Depth: 2203' FNL, 5063' FWL, Sec. 08, TION, R15E, UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 10365'/ 8654' ADL 028329 . 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 697955 ' y- 5939913 Zone - ASP 4 ' . 10970'/9232' • 79-179 TPI: x- 702414 y- 5938778 Zone - ASP 4 Total Depth: x- 702437 y- 5938819 Zone - ASP 4 12. SSSV Depth (MD/TVD): None 20Thickness of Permafrost MD/ND: 1900' (Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13. Water Depth, if Offshore: 21. Re-arill/Lateral Top VMndow Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) MD/TVD: • 10298'/ 8602' 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, GR, RES, RES / AIT, DT / BHC, CNL, LDL, GR, Caliper, SP, MIRES 23, CASING, LINER AND CEMENTING RECORD CASING WT. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZEAMOUNT CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20" 91.5# H -4o 29' 109' 29' 109' 30" 1910#Poleset 13-3/8" 72# L-ao 29' 2604' 29' 2604' 17-1/2" 1800 sx CS III, 400 sx CS II 9-5/8" 47# L-80 27' 10258' 27' 8570' 12-1/4" 500 sx Class 'G', 50 Bbls CS I 7" 29# L-80 9938' 10298' 8309' 8602' 8-1/2" 370 as Class'G' 3-1/2" 9.3 13cr00 10385' 10783' 8670' 9047' Scab Liner 11.5 Bbl. Class'G' 456' 4-1/2" 12.6# L-ap 10197 10965' 8521' 9227 6" 97 sz Class'G' 24. Open to production or injection? Yes 0 No 0 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): GRADE DEPTH SET (MD) PACKER SET (MD/TVD) 5-1/2" 17# 13Cr80 9974' 9916'/ 8291' x4-1/2" 12.6# 13Cr80 /,4Jg4 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Q�117N Was hydraulicfractunng used during completion? Yes ❑ No Per 20 AAC 25.283 (i)(2) attach electronic and printed information .?D&T Z�� 1 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED VERIFIED I1c 10385' Cut &Pull 3-1/2" Scab Liner 10365' Set Whipstock 10365' 10 B01s Cement 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, gas lift, etc.): N/A Date 0Test: Hours Tested: Production for Test Period _► Oil-Bhl: Gas -MCF: Water -Bbl: Choke Size Gas -Oil Ratio: FlowTubing Press Casing Press: I Calculated 24 Hour Rate �► Oil -Bbl: Gas -MCF: Water Bbl: Oil GraviN- APIIcon): Form 10-007 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only "IfOcv % RBDMS& OCT 10 2019 01g!/,� A4,,,/6 28_ CORE DATA Conventional Corals) yes ❑ No 0 Sidewall Cores Yes ❑ No 21 ° If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): - 30. FORMATION TESTS NAME WD DPermafrost-Top Permafrost - Top Well Tested? Yes ❑ No m , Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 10691' 8957' separate sheets to this farm, if needed, and submit detailed test information per 20 AAC 25.071. Sag River 10295' 8599' Shublik 10334' 8630' Sadlerochil-Zone 4 10424' 8703' CGL - Zone 3 10622' 8889' Base of CGL - Zone 2 10691' 8957' Formation at total depth: Zane 2 10691' 8957' 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Hartley, Josephine Authorized Title: SLU Specialist Contact Email: Josephine. Hartley@bp.com Authorized Signature: Date: Contact Phone: +1 9075644570 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item 1a. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 1b. Well Class Service wells: Gas Injection, Water Injection, Water-Altemaling-Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Tap 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 ND for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other ( explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 512017 Submit ORIGINAL Only ***WELL S/I ON ARRIVAL*** (Pre ctd) PULL EQUALIZING PRONG & 5-1/2" PX PLUG BODY FROM 2,163' SLM / 2,182' MD. TAG DEPLOYMENT SLEEVE W/ 3.80" CENT, 3.50" L.I.B. AT 9,935' SLM / 9,929' MD. DRIFT TO 10,460' SLM W/ 2.70" CENT, 2-1/2" S-BLR (No issues, Target = 10,383' elm). LATCH 3.70" DEPLOYMENT SLV AT 9,935' SLM W/ NO ISSUE (Fish neck appears good). 5/29/2019 ***WELL S/I ON DEPARTURE, NOTIFIED DSO OF WELL STATUS*** T/I/O = SSV/340/30. Temp = SI. Assist Ops bleed FL. No AL. FLP = 33 psi. Bled FLP from 33 psi to 0 psi in 1.5 hrs. Monitored for 30 minutes. During monitor flow line pressure increased to 5 psi. Job complete. 6/21/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 11:00 ***JOB STARTED ON 29 -JUNE -2019*** (SLB ELINE JET CUT TBG) WELL S/I ON ARRIVAL. INITIAL TWO = 2470/350/0. CUT 3.5" LINER AT 10383'W/ 2.5" POWER JET CUTTER. RDMO. WELL LEFT S/I ON DEPARTURE. FINAL TWO = 2470/350/0. 6/29/2019 ***JOB COMPLETE ON 29 -JUNE -2019*** CTU #9 2" 0.156WT CV=45.1 bbl Objective: pull/confirm liner is cut MIRU. Make up fishing BHA and RIH. Load well with 290 bbls of 1% KCI at 5.0 bpm. Able to inject at this rate and 0 psi WHP. RIH and latch top of liner. After 8k overpull able to pick up jet cut section of liner. Unable to RIH and set top of line back inside 4" tubing. Pump to release GS spear and leave top of 3 1/2" liner at 9908' CTMD (-9892' MD). POOH. 7/2/2019 ...Continued on WSR 7-3-19... CTU #9 - 2" Coil, 0.156WT CV=45.1 bbl Objective: pull/confirm liner is cut POOH. FP Well. RDMO. 7/3/2019 ***Job Complete*** T/1/0=2288/345/32 Temp=S1 Assist Stine (CTD) Pumped 5 bbls 50/50 meth, 285 bbls 1% KCL and 60 bbls DSL down Tbg for load. Pumped 14 bbls DSL to pressure up on Tbg 7/8/2019 for MIT -T ***Job Continued to 07-09-2019 WSR*** ***WELL S/I ON ARRIVAL***(pre ctd) BRUSHED SSSV NIPPLE W/ 5 1/2" BRUSH, 4.50" GAUGE RING @ 2,182' MD LRS LOADED TUBING W/ 285bbls 1 % KCL, 60bbls DIESEL F/P SET 5 1/2" PX -PLUG IN SSSV NIPPLE @ 2,182' MD 7/8/2019 ***CONT WSR ON 7/9/19*** ***Job Cont from 07-08-2019 WSR*** MIT -T, ***PASS*** @ 2605. Max applied 2750, target 2500.. Pumped 1.95 bbls Diesel down TBG to achieve test pressure. 1st 15 min lost 21 Tpsi, 2nd 15 min lost 19 Tpsi, total 30 min loss of 40 psi. Bled clack -0.9 bbls. Hang 7/9/2019 caution and FP tags. FWHP's 299/356/44. SLB on well upon departure ***CONT WSR FROM 7/8/19*** (ctd) LRS PERFORMED PASSING MIT -T TO 2603psi (several attempts, see log) 7/9/2019 ***WELL S/I ON DEPARTURE*** T/I/O = SSV/350/20 TEMP = SI, PPPOT-T Eval TxIA comm (PASS) PPPOT-T: Stung into test void 200 psi on void (ALL GAS), bled to 0 psi. Monitored for 15 min, no change in pressure. R/U test equipment. Pressure test void to 5,000 psi for 30 min. Lost 100 psi i 15 min, Lost 0 psi in second 15 min (PASS). Bled test void to 0 psi. Monitored 7/10/2019 115 min, no change in pressure. R/D test equipment. Daily Report of Well Operations PBU 01-26A T/1/0=1000/400/100 R/U lubricator. Set 5" FMC IS -A BPV #520 R/D lubricator. Removed upper tree. Installed new Master valve and CDR Tree #10. Torqued to API specs. R/U CDR platform. R/U lubricator, PT'd 300/low against BPV and 3500/high against upper HWO valve. Pulled BPV, C/O tools, Set 5" ISA TTP #528. C/O tools. PT'd tree 5000/high against TTP. see "Field Charted Tests" Pulled TTP. Shut barriers, R/D lubricator, installed tree cap with 7/11/2019 new O-ring. PT'd 500 psi... pass. FWP's 1000/400/100 see log for details. ***WELL SHUT IN ON ARRIVAL*** (ctd) PULL 5 1/2" PX PRONG AND PLUG BODY FROM SVLN @ 2182' MD. 7/12/2019 ***WELL LEFT SHUT IN. DSO WALK THROUGH UPON DEPARTURE*** T/1/0=2000/300/0 Installed Kill line #1 on comp. side of tree. Torqued to API specs. Removed Tree cap bonnet, installed Test Spool #8 with tapped blind for clearance. Overall height is 16' to top of jewelry. PT'd 300/low..5000/high.. see "Field Charted Tests" FWP's 7/13/2019 2000/300/0 see Iof for details. TWO = 2470/370/40. Temp = SI. Bleed IAP & OAP to 0 psi (pre CTD). Wellhouse, scaffold, and flowline removed. IA FL @ 240' (6 bbls). OA FL @ near surface. Bled OAP to BT from 40 psi to 0 psi in 30 min (all gas). Currently bleeding IAP & holding open bleed on 8/21/2019 OA. Cont from WSR 8/21/19. Bleed IAP & OAP to 0 psi (pre CTD). IA FL @ 240'(6 bbls). OA FL @ near surface. Held open bleed on OA after bleeding to 0 psi for 3 hrs 30 min. Bled IAP from 370 psi to 0+ psi in 2 hrs. Held open bleed for 1 hr 30 min. Monitored for 30 min. IAP increased 4 psi, OAP unchanged. Final WHPs = 2470/4/0. 8/22/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:00 TWO = 2470/12/0. Temp = SI. WHPs (pre CTD). No wellhouse, flowline, or scaffolding. CDR tree configuration installed. IAP increased 8 psi overnight. OAP unchanged. 8/23/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 03:30 T/I/O = 2440/60/0. Temp = SI. Bleed IAP (pre CTD). No wellhouse, flowline, or scaffolding. CDR tree configuration installed. Bled IAP from 60 psi to 10 psi in 20 minutes to BT. (All gas). Monitored for 30 minutes, TP, OAP unchanged, IAP increased 5 psi. Final WHPs = 2440/15/0. 8/28/2019 SV, WV, SSV = C. MV = O. IA, OA = OTG. 20:30 North America - ALASKA- BP Page 1 dEx Operation Summary Report Common Well Name: 01-26 AFE No Event Type: RE-ENTER- ONSHORE(RON) Start Date: 8/28/2019 End Date: 9/7/2019 H-S4DW0019F5-EX-DI-RN-(1,997,619.00) Project: PBUSite: OT 1 1 Rig Name/No.. CDR -2 Spud Date/Time: 3/25/1983 12:00:OOAM 1 Rig Release: Rig Contractor. NABORS ALASKA DRILLING INC.jBPUO1: USA00001361 Active datum: KB @67.95usft (above Mean Sea Level) Date From - To Hrs 7 1 Task Code 1 NPT Total Depth I Phase Description of Operations 8/29/2019 :04:00 - 05:00 1.00 i RIGU P—t PRE I PRE JOB SAFETY MEETING WITH CREWAND (TRUCK DRIVERS. i- EMPHASIS ON GOOD COMMUNICATION, VERIFY STOP COMMAND. -STOP BLOCK IN PLACE TO PREVENT RIG FROM ROLLING BACKWARDS INTO WELL. - TREE & CASING VALVES ON TREE SHUT IN. - IA, OA AND ODA PRESSURES = 0/20/0 PSI - DRILL SITE OPERATOR NOTIFIED AND DECLINED WITNESSING RIG MOVE OFF OF WELL. 1 - ANYONE CAN STOP THE JOB ATANYTIME. 1 BE WATCHFUL �. 'MOVE PITS AND RIG MODULE OFF WELL 05:00 - 14:00 1 9.00 RIGU P PRE MOVE RIG MODULES OVER TO DS -01. ROUTE IS DS -11 ACCESS ROAD, RIGHT ON 1,. WEST DOCK ROAD, LEFT ONTO SPINE RD, RIGHT ONTO DS -01 ACCESS ROAD. CONDUCT PJSM WITH PEAKAND NABORS CREW FOR SPOTTING OVER WELL. SPOT SUB OVER WELL USING WALKING FOOT. SPOT PIT MODULE NEXT TO SUB. RIG ACCEPTED AT 14:00. 14:00 - 00:00 10.00 RIGU P PRE RIG UP -WORK THROUGH R/U CHECKLISTS. 1 -LEAK TIGHT TEST MASTER AND SWAB TO i 3500 PSI -GOOD TEST. –MAKE UP MPD LINE -REMOVE TREE CAP FLANGE :-REMOVE TEST SPOOL FROM TOP OF TREE -MAKE UP BOPS f CHANGE OUT PACK OFFS Ij— NOTE: HELD PRE SPUD MEETING WITH JEFF T _WARD'S CREW 8/30/2019 '20:30 - 00.00 3.50 BOPSUR P PRE WELL KILL -CUTOFF SLIM HOLE CTC -INSTALL 2 3/8" CTC AND PULL TEST SAME TO i i 50K -GOOD TEST I -INSTALL FLOATS TEST AND TEST CTC TO 3500 PSI -GOOD TEST -TEST FLOATS TO 25013500 PSI -GOOD TEST -INSTALL NOZZLE AND MAKE UP INJECTOR -TEST DRILLING RISER TO 250/3500 PSI FOR 5 MINUTES EACH -PASS -DISPLACE COIL TO KCL -HOLD RIG EVACUATION DRILL WITH MICAH BUSH'S CREW. RIG EVACUATED IN 3 Printed 9/2412019 10:50:46AM **All depths reported in Drillers Depths" North America -ALASKA - BP Operation Summary Report Common Well Name: 01-26 AFE No Event -Type: RE-ENTER- ONSHORE (RON) Start Date: 8/28/2019 End Date. 9/7/2019 H-S4DW0019F5-EX-D1-RN- (1,997,619,00) Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00001361 Active datum: KB @67.95usft (above Mean Sea Level) Date iFrom - To Hrs Task Code NPT Total Depth Phase Description of Operations 0000 - 04:30— 4.50 RIGU i P PRE RIG UP - -REPLACE PACK OFFS -HELD H2S / RIG EVACUATION DRILL WITH JEFF WARD'S CREW (_GREASE TREE ABOVE LOWEST MASTER VALVE -TORQUE TREE BOLTS ABOVE LOWEST 'MASTER VALVE -FILL COILAND SURFACE LINES WITH FRESH WATER. -CALIBRATE MICROMOTIONS. -- — - _ _-SHELL TEST BOPS 70250/3500 -- PSI 04:30 - 12:00 7.50 IL BOPSUR P �— I PRE TEST BOPE AS PER AOGCC AND BP (GUIDELINES. ALL TESTS TO 250/3500 PSI. TEST WITNESS BY WSLAND TOOLPUSHER. WAIVED BY AOGCC REP GUY COOK TEST 1: IRV, STRIPPER, C9, C10 BACKWARDS -. C9 AND C10 FAILED, SERVICE, FUNCTION AND RETEST GOOD. iTEST 2: BLIND/ SHEARS, R1, BL1A, B1, B4 R1 -PASS li ITEST 3: ANNULAR (2-3/8"), TIW#1, B3, B2, BL1-FAILONTIW#1. FUNCTION TIW#i AND RE -TEST, GOOD. FAIL/PASS ON TIW#1. iTEST 4: UPPER 2-3/e"PIPE /SLIP. TIW#2, BL2, R2, T2, Cis- FAIL R2. GREASEAND RE -TEST. FAIL TIW#2, ISOLATE AND CONTINUE TESTING OTHER COMPONENTS. WILL REMOVE BOTH TIWS#1, 2AND REBUILD. FAIL T2, CALL GREASE OUT TO SERVICE THESE VALVES. TEST 5: C16, T1, C11 - FAIL C16, GREASE AND ! RE -TEST. C16 FAILAGAIN WILL REPLACE. T2 'FAILSAGAIN, WILL REPLACE. TEST 6: VARIABLES (2-3/8"),. C7, C9, C10, TV2 - PASS TEST 7: LOWER 2-3/8"PIPE / SLIP, C5, C6, C8, TV1-PASS iTEST B: CHOKE A, CHOKE C - PASS PERFORM ACCUMULATOR DRAW DOWN I I (TEST INSTALL SAVER SUB - TEST 9: ANNULAR (3-1/2")CI, C4 -PASS TEST 10: VARIABLES (3-1/2") C2, C3- PASS .1200 - 13:30 1.50 BOPSUR P-�-- - -- '. PRE CHANGE OUT C16 AND RE -TEST, GOOD. TEST C9, C10 BACKWARDS, GOOD. .. 13:30 - 19:30, 6.00 BOPSUR P i PRE PJSM FOR SERVICING MASTER VALVES AND CHANGING OUT T2. DOA VALVE CHECKLIST. • INSTALL NIGHT CAP TEST TO 3500 PSI, GOOD. SERVICE MVI, MV2 AND LEAK TIGHT TEST INDEPENDENTLY FROM THE RESERVOIR SIDE BOTH HOLDING. li PURGE STACK OUT TO TIGER TANK PURGE MPD LINE WITH AIR TO BREAK FLANGE. � I I REMOVE AND REPLACE VALVE T2. — — TEST 70250/3500 PSI FOR 5 MINUTES EACH -PASS minted 9/24/2019 10:50:46AM **All depths reported in Drillers Depths" North America - ALASKA - BP Page 3 qfk Operation Summary Report Common Well Name: 01-26 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 8/28/2019 End Date: 9/7/2019 H-S4DW0019F5-EX-DI-RN- (1,997,519,00) Project: PBU --Site: 01 Rig Name/No.: CDR-2 Spud Date/Time: 3/25/1983 12:0O:OOAM Rig Release: Rig Contractor: NABORSALASKA DRILLING INC. BPUOI: USA00001361 Active datum: KB @67.95usft (above Mean Sea Level) Date From -To H. Task Cade NPT Total Depth Phase Description of Operations (110 (usft) 19:30 - 20:30 1.00 Y BOPSUR P PRE RD TEST EQUIPMENT/PREP FOR WELL KILL -SWAP TO DRILLING RISERS AND GET RKBS -GREASE SO PS AND CHOKE VALVES 8/31/2019 100:00 - 03:45 3.75 1 BOPSUR P DECOMP WELL KILL OPS HOLD PJSM WITH CREW '- LINE UP TO BULLHEAD KILL WELL - ON LI NE WITH METHANOL TO THE TT - CLOSE SWAB, IEQUALIZE PRESSURE BETWEEN MPD LINE ANDWELL - WHP =2407 PSI, ONLINE WITH 10 BELS OF METH, 200 BBLS OF KCL, 50 BELS HVP, 198 BBLS OF MUD -MAX PRESSURE @ 5.5 BPM 2500 PSI (5 BBLS OF KCL PUMPED) IA 30 1I OBSERVE PRESSURE BUILDING SLOWLY WHEN WELL BORE IS FULL OF KCL FROM 130 PSI - FINAL INJECTION PRESSURE @ 5.5 BPM AT X11448 BBLS PUMPED 440 PSI _ i- PURGE INJECTOR AND BOP TO TIGER TANK WITH KCL 'i -OPEN SWAB TO ACLOSED CHOKE - PUMP 4 BPM UNTIL CATCHING RETURNS, REDUCE PUMP RATE TO 2.5 BPM IN / 0.32 1, BPM OUT TAKING RETURNS TO THE THE TIGER TANK (10 BBLS) BRING RETURNS INSIDE PUMP RATEAT 2.55 BPM IN/ 0.21 BPM OUT DISCUSS LOSSES WITH ODE AND SUPERINTENDENT-CONTINUE OPERATIONS KEEPING HOLE FULL. 03:45 05:30 1.75 FISH P DECOMP MAKE UP FISHING BHA 1 -CONTINUE CIRCULATING THROUGH COIL WHILE MAKING UP BHAON PDL WINCH 1 -HOLD PJSM WITH CREW 1-MAKE UP FISHING BHA -REMOVE INJECTOR FROM WELLAND CONITNUE FILLING WELL DOWN BACKSIDE i-SET BHA IN HOLEAND MAKE UP INJECTOR -- _ _ ,_+__- _ _ ' -TEST QTS TO 3500 PSI-GOOD TEST 05:30 - 07:45 ! 2.25 FISH P DECOMP RIH. CIRC THROUGH THE CTAT2.50/0.3 BPM OUTTO TIGER TANK. 3VAC TRUCKS ROUND TRIPPING FLUIDS LATER GET MORE FROM WORLEY. R TO 9500'. UP WT HERE IS 45K. 07:45 - 11:00 5 FISH P DECOMP STOPAT 8500'AND GET CAUGHT UP ON FLUIDS. I CONTINUE PUMPING DOWN THE CT 2.4/0.3 I I ------ _ BPM. i— .11:00 - 11:30 0.50 FISH P DECOMP SAFETY ENGAGEMENT DISCUSSION WITH JEFF WARD CREWAND REST OF RIG TEAM. I I I I DISCUSS AVOIDING DISTRACTIONS WHILE !WORKING. CONDUCT DISCUSSION WITH ONCOMING I CREW ALSO (MICAH BUSH CREW), ALONG _.. WITH PRE-SPUD SLIDES. 11 30 72'30 1.00 FISH P + - DECOMP CONTINUE CIRCULATING. T� Printed 9/242019 10:50:46AM **All depths reported in Drillers Depths** North America - ALASKA -BP - Operation Summary Report Common Well Name: 07-26 - - AFE No Page vem type- no-Mry I LK- VIVJn UKt (KUN) Jtart Late. 8/28/2019 End Date: 9/7/2019 i H-J4UW0019F5-EX-DI-RN- (1,997,619.00 ) Project: Pau Site: Ot - Rig Name/No.. CDR -2 Spud Date/Time: 3/25/1983 12:00 OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00001361 Active datum: KB @67.95usft (above Mean Sea Level) -- Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations _- (hr) _ usft) 1230- 14:00 1.50 FISH P i, DECOMP CAUGHT UP ON FLUIDS, LINE UP TO PUMP DOWN THE WELLAND THE CT. RIH TO LATCH LINER. PUMP 1.25 BPM EACH DOWN THE CTAND THE WELL. UP WEIGHTAT 9800'IS 45K. -ICONTINUE RIH, LATCH AT 9938' PUT 10K DOWN, PICK UP 20 FT, NEW UP WEIGHT IS 51 K. SHUT IN WELL, PUMP 2.5 BPM EACH DOWN � I CT AND WELL. PUMP 100 BBLS DOWN EACH —..__.__TI ....—_. 74:00 - 163i�2.50 FISH P DECOMP WAY. SHUTOFF CT PUMP,CONTINUE PUMPING - 'DOWN WELL. , RIH TO 9974' AND STACK 10K, UP WT IS 65K. I PICK UP HOLE, ABOUT 4K HEAVIER. PUMP 1,3 BPM DOWN BOTH THE CTAND DOWN THE ANNULUS WHILE POOH, GET 0.90 BPM BACK TO TIGER TANK. IPULL PULL HEAVYAT 9550' AND POP FREE. 70K AT -9950' END OF FISH (X NIPPLE). 16:30 - 17:00 0.50 FISH. p ll� DECOMP ! CONTINUE POOH. AT SURFACE, SHUT DOWN CT PUMP. PUMP DOWN CT X TBG ANNULUSAT2 BPM WITH 0.48 BPM RETURNS BACK TO TIGER TANK j PURGE RISER. j I ESTABLISH 10 MIN STABLE LOSS RATE. LOSS OF 16 BBLS IN 10 MIN PUMPING __ _ _ 1700 7—FISH ACROSS THE TOP. - 19:30 250 P-� DECOMP BHA HANDLE -LD FISHING BHA -LD DOWN FISH ( DEPLOYMENT SLEEVE, FLUTED NO GO SUB, PUP, PUP, X NIPPLE, PUP, PUP, PUP, 13 FULL JOINTS AND 1 CUT j JOINT WITH A3 13/16" FLARE AT CUT). -REMOVE BAKER SWIVELAND MAKE UP FLOATAND NOZZLE NOTE: SIMOPS START MIXING DIAMOND SEAL PILL NOTE: LOSS RATE AT RATE AT 115 BBLS PER HOUR I i NOTE: LINER FROM WELL WAS NORM TESTEDAND CAM BACKAT OR BELOW I TWICE OF BACKGROUND LEVELS Printed 9/24/2019 10:50:46AM **All depths reported in Drillers Depths- North America -ALASKA - BP Page 5 OGR Operation Summary Report Common Well Name: 01-26 AFE No _ Event Type. RE-ENTER- ONSHORE(RON) Start Date. 8/28/2019 End Date: 9/7/2019 H-S4DW0019F5-EX-D1-RN-(1,997,619.00) Project: PBU Site: 01 Rig Name/No.: CDR -2 Spud Date/Time: 3/25/1983 12:00:0 AAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00001367 _ Active datum: KB @67.95usft (above Mean Sea Level) Date From - To Him Task Code NPT Total Depth Phase Description of Operations _ (hr) I (usft) 19:30 - 23:15 3.75 FISH P !i DECOMP PUMP DIAMOND SEAL PILL ! -HOLD PJSM WITH CREW -MAKE UP INJECTOR -CLOSE SWAB -LINE UP TO PUMP DOWN MPD LINE -BULLHEAD 45 BELS OF DIAMOND SEALAT 2,5 BP MAT 118 PSI 'I -BULLHEAD 20 BBLS OF FRESH WATER AT 2,5 BPM AT 138 PSI BULLHEAD 206 BBLS OF SLICK 1% KCLAT 5.1 BPM AT 560 PSI -FINAL PRESSURE 1730 PSI f WITH 22 BELS OF DIAMOND SEAL IN PERFS. -OPEN SWAB -SOAK FOR 1 HOUR CIRCULATING ACROSS TOP TO MAINTAIN HOLE FILL STARTING AT 2115 HRS -BULLHEAD DOWN MPD LINE AGAINSTA CLOSED CHOKEAT BRINGING RATE UP TO 1 II, BPM AND REACH 1000 PSI WELL HEAD PRESSUREAT 4.5 BBLSAWAYAND REDUCE PUMP RATE TO HOLD AT 1000 PSI STOP PUMPING AT 8.2 BBLS AWAY AND BLEED OFF I- PRESSURE. -PUMPACROSS TOP TO MONITOR WELL STATIC. -OPEN UP BLEEDER ON LUBRICATORAND ;MONITOR NO FLOW BREAK OFF INJECTOR. T 1DECOMP SLACK MANAGEMENT 23:15 - 00:00 0.75 , FISH I P I i — � REMOVE FLOAT VALVE AND NOZZLE —I -PUMP SLACK BACK AT 4.5 BBLS PER MINUTE 9/1/2019 00:00 - 02:00-2.00 1 FISH I P j DECOMP SLACK MANAGEMENT " -PUMP SLACK BACKAT 4.5 BBLS PER MINUTE -RIG UP CUTTER -CUT 28'OF COILAND FIND WIRE j !i -RIG DOWN CUTTER -PUMP SLACK BACK WITH FRESH WATER -RIG UP CUTTER -CUT 118'OF COIL NOTE: HAD A BLACKOUT ON RIG FOR 30 I SECONDS. ;0 00 - 02:30 0.50 FISH Nom— DECOMP BLACK OUT ON RIG -POWER OFF FOR 30 SECONDS DUE TO ! TRIPPED TIE BREAKER -UNDER - ! INVESTIGATION -KOOMEY STILL POWERED AND FLUID LEVEL IN WELL STATIC �__ -RESET BREAKERS AND CHECK EQUIPMENT ' - 05:30 3.00 FISH PP� DECOMP SLACKMANAGEMENT I�02.30 -CUT COIL 210' FOR A TOTAL OF 328' OF COIL AND 300'OF SLACK :-RIG DOWN CUTTER -INSTALL CTC AND PULL TEST TO 50K FT/LBS PUMP SLACK !INSTALL FOR FORWARD FOR REHEAD HE + -REHEAD BHI UQC 05:30 06:30 1.00 FISH P DECOMP - 1 —� TEST UQC CONNECTION TO 3500 PSI, GOOD. MONITOR WELL WHILE DOING SURFACE j WORK, FLUID IS STATIC. j MAKE UP RISER TO WELLAND TEST RISER CONNECTION AND BHI FLOATS TO 3500 PSI, — iGODD. Printed 9/24/2019 10:50:46AM "All depths reported in Drillers Depths" Printed 9/24/2019 10:50:46AM ""All depths reported in Drillers Depths" North America - ALASKA - BP Page 6 dxi� Operation Summary Report Common Well Name: 01-26 AFE No Event Type: RE-ENTER- ONSHORE (RON) Start Date: 8/28/2019 End Date: W712019 'H-S4DW0019F5-EX-D1-RN- (1,997,619,00) Project: PBU Site: 0� j - - Rig Name/No.: CDR -2 Spud Date/Time: 3/25/1983 12:00:OOAM Rig Release: Rig Contractor: NABORS ALASKA DRILLING INC. ,BPUOI: USA00001361 _ Active datum: KB @67.95usft (above Mean Sea Level) Date j From - To Hire as j Code NPT Total Depth Phase I Description of Operations (h r) x06:30 - 0890 1.50 (usft) j FISH P DECOMP PJSM FOR M/U BHA. WU BHA#2 (CLEANOUT). MILL IS 3.78" NO-GO, REAMER IS 3.79" NO-GO. M/U INJECTOR. INJECTOR ON WELLAT 07: 20. OPEN EDC AND DISPLACE FRESH WATER OUT TO TIGER TANK. AFTER KCLALL THE WAYAROUND OUT MM READING 8.25 PPG, 8.4 PPG IN/OUT ON MUD BALANCE. ZERO OUT MM HEAD, ADJUST OUT MM SIGNAL ON HMI SCREEN TO 1 _ _ MATCH MUD BALANCE READINGS. 0800 - 11:30 3.50 FISH p� �— DECOMP _� 3.8"CLEANOUT BHA#2 FRIHITH E: 1.04 BPM IN, 1.49 BPM OUT. CIRC SURE: 280 PSI i- MUD WEIGHT: 8.40 PPG IN, 8.41 PPG OUT j- AT 9000'GO TO 3 BPM. I - AT 9500' STOP AND CLOSE EDC. '- CONTINUE CLEANOUT AT 2.9 BPM, RIH 40 ,FT/MIN '- AFTER 9700'GO TO 2.7 BPM TO REDUCE VIBRATION. - LOG DOWN FOR TIE-IN FROM 10150'. OR IS - + . MAX VALUE WHEN STARTING LOGGING. 11:30 - 13:30 2.00 FISH P DECOMP NOTABLE TO LOG THE INTERVAL VROM j11 10150' DOWN DUE TO HIGH GR READINGS. PICKUP TO 9400' AND TRY FROM THERE. NO I USEABLE GR THE VALUES ARE SPIKING . PERIODICALLY. LOG CCL FROM 9850' DOWN TO 10000'. LOG DATA IS INCONCLUSIVE. 13.30 - 15:00 1.50 FISH P DECOMP DISCUSS WITH ODE, DECISION IS MADE TO CLEANOUT TO TUBING STUB THEN DOA LONG CCL DOWN TO TUBING STUB. PUMP 10 BELS HI -VIS SWEEP AROUND. RIH, LIGHT TAG AND STALLAT 10415' (UNCORRECTED). PICK UPAND DO CLEANOUT PASSES FROM 1035G'- 10410' j PICK UP TO 9450'AND OPEN EDC. SEND B/U FROM TAGGING TUBING STUB OUT TOTIGERTANK. NOTHING UNUSUALSEEN. 15.00 - 17'.30 2.50 FISH P DECOMP LOG CCL DOWN FROM 9447' TO 10410'. PUMP 3.1 BPM WHILE LOGGING THROUGH OPEN EDC. REVIEW LOGS, CORRECT -30'. RIH AND TAG TUBING STUDAT 10385'. POOH, FLAG PIPE AT 10330' BIT DEPTH (10275.6' EOP) POOH. j I LOG FROM 9100' 70 9176' TO CONFIRM DEPTH. 17:30 - 20:00 2.50 FISH P DECOMP _ ''I POOH ------— -PUMP 3.1 BPM IN / 2.6 BPM OUT -HOLD KICK WHILE TRIPPING DRILL WITH j JEFF WARD'S CREW WITH AAR-WELL j SIMULATED SHUT IN 100 SECONDS. -MONITOR WELL PRIOR TO PULLING BHA — — THROUGH BOPS FOR 10 MINUTES -NO FLOW Printed 9/24/2019 10:50:46AM ""All depths reported in Drillers Depths" Printed 9/24/2019 10:50:46AM **All depths reported in Drillers Depths** North America - ALASKA - SP Page 7 Operation Summary Report Common Well Name: 01-26 - - - - - - --- - AFE Na Event Type: RE-ENTER- ONSHORE(RON) Start Date: W28/2019 End Date: 9/7/2019 '.H-S4DWO019F5-EX-DI-RN-(1,997,619.00) Project: PBU Site: 01 Rig Name/No.: CDR -2 Spud Date/Time. 3/25/1983 12:00:OOAM Rig Releaser Rig Contractor NABORS ALASKA DRILLING INC. BPUO1: USA00001361 Active datum: KB @67.95usft (above Mean Sea Level) -- Date From - To Hrs Task Code NPT Total Depth I Phase Description of Operations (hr) ~20:00 SII (usft) - 2t75 1.25 FISH P DECOMP BHA HANDLE !-HOLD PJSM WITH CREW �-INJECTOR OFFAT 20:05 HRS I -INSPECT LAST 50' OF COIL I -LD CLEANOUT BHA -INJECTOR SERVICE .-MAKE UP WHIPSTOCK SETTING BHA I- INJECTOR ON AT 2100HRS _ __TEST OTS T03500 PSI -GOOD TEST 21:15 - 00:00 1 2.75 WHIP P j WEXIT _ 'RIHWITH WHIPSTOCK SETTING BHA -RATE: 0.49 BPM IN, 0.93 BPM OUT. CIRC !PRESSURE 90 PSI I- MUD WEIGHT: 8.41 PPG IN, 8.41PPG OUT I —` - TIE IN FROM 9100' TO 9231' CORRECTION -31' 9/2/2019 00:00 - 00:15 0.25 WHIP P WEXIT RIH WITH WHIPSTOCK SETTING BHA43 I- RATE: 0:49 BPM IN, 0.93 BPM OUT. CIRC PRESSURE: 90 PSI - FLAG ON DEPTH I WT CHECKAT FLAG 48K UP 26K DOWN. I'RIH - TO WHIPSTOCK SETTING DEPTH OF 0015 - 0045 0.50 1 WHIP P 10,365.00 WEXIT 10379.52 _ `.SET WHIPSTOCK 1 -PICKUP TO45K WITH PUMP -SHUT OFF PUMP CLOSE EDC WITH ORIENTATION AT 30° R - 10376.11' BOTTOM OF WS, PLACING TOWS j AT 10365' (WS LENGTH 11.11 TRAY LENGTH li 9.1') I- WS SETAT 2800 PSI, SET DOWN ''ADDITIONAL SK - WS IS SET NO MOVEMENT 1 - PU OFF WS, WE ARE FREE - PERFORM 10 MINUTE DYNAMIC FLOW ' CHECK,LOSING 15-18 6BLS PER HOUR 1100:45 - 03:00 1 225 WHIP P 11 1 10,365.00 WEXIT POOH -PUMP AT 1.49 BPM IN/0.85 BPM OUT NOTE: AT 9025' LOSSES INCREASE TO 1.49 BPM IN / 0.25 BPM OUT OR 52 BPH. DISCUSS 1 WITH ODE AND SUPERINTENDENT AND AGREE TO CONTINUE OUT OF THE HOLE AND PLAN TO PUMP A DIAMOND SEAL PILL WHEN OOH WITH WHIPSTOCK SETTING J TOOL. 'NOTE: LOSSES REDUCED TO 40 BPH AT 1'1 'SURFACE '. 03:00 - 04:00 I 1.170 WHIP P '1 i 10,365.00 WEXIT BHA HANDLE -HOLD PJSM WITH CREW �-INJECTOR OFFAT 03:25 HRS -LAY DOWN WHIPSTOCK SETTING TOOL -STAND BACK COIL TRACK TOOLS -MAKE UP NOZZLE AND STAB INJECTOR - 'INJECTOR ON AT 03: 45 HRS NOTE: MIXING BASE PILL FOR DIAMOND SEAL PILL Printed 9/24/2019 10:50:46AM **All depths reported in Drillers Depths** NorthAmenca - ALASKA- BP Page 82o 1% Operation Summary Report Common Well Name: 01-26 _ - - _ - - _ - - - - - -- - - - - - - -- - - - - AFE No Event Type: RE-ENTER- ONSHORE (RON) i Start Date: 8/28/2019 End Date: 9/7/2019 H-S4DW0019F5-EX-D1-RN- (l,997,619.00 ) Project PBU W---te: 01 - -- I Rig Name/No.: CDR -2 Spud Date/Time. 3/25/1983 12:00:00AM Rig Release' Rig Contractor. NABORS ALASKA DRILLING INC. BPUOI: USA00001381 Active datum: KB @67.95usft (above Mean Sea Level) --- — Date From - To Hrs Task Code NPT Total Depth j Phase Description of Operations .(hr)_i (usft) 04:00 - 07:00 3.00 �r WHIP ! P 10,365.00 WEXIT I PUMP DIAMOND SEAL PILL _ !-CLOSE SWAB j -LINE UP TO PUMP DOWN MPD LINE -TEST INJECTION RATE AT 2.5 BPM AT 510 PSI ,/ 4.5 BPM AT 1000 PSI MIX DIAMOND SEAL IN TO PILL -BULLHEAD 45 BBLS OF DIAMOND SEALAT -12.5 BPM AT 622 PSI !i -BULLHEAD 20 BBLS OF FRESH WATER AT 2.5 BPM AT 640 PSI -BULLHEAD 206 BBLS OF SLICK 1% KCLAT 5 BPM. - WHEN DIAMOND SEAL HITS PERFS START ITO I PRESSURE UP, REDUCE RATE TO 1.2 BPM ! �11350PSI. CONTINUE BULLHEADINGAT ! LOWER RATE KEEPING WHPAROUND 1500 ' PSI. -AFTER 15 BBLS SQUEEZED INTO PERFS INJECTION RATE IS 0.1 BPM / 1500 PSI. SHUT '. DOWN PUMP. -OPEN SWAB -SOAK FOR 1 HOUR HOLDING 145 PSI WHP. WHP SLOWLY CLIMBS TO 190 PSI WHILE - .-- — — .SOAKING. —i 07:00 - 08:00 1.00 WHIP P 10,365.00 WEXIT AFTER 1 HR SOAK WHP IS 188 P51, SLOWLY ! BLEEDING OFF. PUMP 0.5 BPM INCREASE WHP TO SQUEEZE PRESSURE OF 1400 PSI WITH 2.6 BBLS. SHUT DOWN PUMP, AFTER 5 MIN PRESSURE BLEEDS OFF TO 1110 PSI. li BLEED OFF PRESSURE SLOWLY. BLEED OFF 2.1 BBLS FLOW OUT GOES TO 0. ! FLOW CHECKAT RIG FLOOR, NO FLOW. LIFT OFF INJECTOR. .. __ __, _. 09:30 'i— t .WELL IS STATIC. .08:00 - 1.50 WHIP 10,365.00 WEXIT. PJSM FOR MAKING UP CEMENTING BHA. M/U BHA 94, M/U INJECTOR, LIFT INJECTOR BACK OFF, REMOVE FLOATS FROM UQC. '.; PT UQC CONNECTION, GOOD. M/U UQC, M/U INJECTOR, PT QTS TO 3500 PSI, GOOD. I .' 0990 INJECTOR ONAT09:30. - 12:30 3.00 i WHIP P� 10,365.00 WEXIT 'RIH BHA#4. PUMP 0.55/1.03 BPM UNTIL 4000'. PAST4000' !I ! GO TO 3.5 / 4 BPM TO CLEANOUT DIAMOND SEAL. l 8.40 / 8.43 PPG IN / OUT. ' SLOW RIH SPEED TO 50 FT/MIN PAST 9500'. AT 9970' PULL 300' WIPER TRIP TO CLEAR TUBING. GOT04.05BPM/2270PSI, RUN PAST FLAG FROM YESTERDAY, ABOUT -35' CORRECTION. !. TAG WHIPSTOCKAT 10400' UNCORRECTED. PICK UP la' AND CORRECT -35' TO WHIPSTOCK DEPTH. FLAG PIPE 10' OFF BOTTOM (WHITE). 12:30 - 1330 1.00 WHIP, P 10,365.00 WEXIT _ PUMP 10 BBLS HI -VIS SWEEP AROUND. .--. PUMP 4.24 BPM / 2700 PSI Printed aQ41zu1 V IU bU 46AM **All depths reported in Drillers Depths** Common Well Name: 01-26 Event Type: RE-ENTER- ONSHORE (RON) Rig Name/No.: North America - ALASKA - BP Operation Summary Report Start Date: 8/28/2019 Site: 01 Spud Date(Time: 3/25 End Date: 9/7/2019 Rig Contractor: NABORS ALASKA DRILLING INC. Active datum: KB @67.95usft (above Mean Sea Level) Date From - To Hire Task Code NPT Total Depth Phase (hr) I (usft) Page ARE No H-S4DW0019F5-EX-DI-RN- (1,997,619.00) 1 Rig Release: BPUOI: USA00001361 Description or Operations 13:30 - 14:301.00 !^WHIP P 10,365.00 WEXIT 'AFTER B/U DIAMOND SEAL CLEANS UP. RIH TO FLAG DEPTH. SHUT IN CHOKE AND -RIH TO 5'ABOVE WHIPSTOCK AND PERFORM INJECTIVITY TEST. CLEANOUT WITH EXHAUST PILL. .TRY TO INJECT 0.5 BPM, GET INJECTIVITY OF -POOH PUMP RATE 4 BPM IN / 3.63 OUT 10.5 BPM AT 1180 PSI. -JOG THROUGH ALL JEWELRY SEND SLB CEMENT VAN KCL WATER, PT ! -PERFORM A 10 MINUTE FLOW CHECKAT CEMENT LINES TO 3500 PSI, GOOD. 1430 - 1630 2.00 i WHIP P 10,365.00 WEXIT PJSM WITH SLB AND RIG CREW FOR _•_-_. _. -0000._- --L—_ PUMPING CEMENT. .BOPS BATCH UP 10 BBLS PUMPABLE CEMENT. WHIP P LOAD 10 BBLS CEMENT INTO CT. _.. 1 10,365.00 ___—_ WEXIT CLEAN UP LINES BACK TO CEMENT VAN. j PUMP CEMENT DOWN TO NOZZLE RIGHTAT TOP WHIPSTOCK. I -HOLD PJSM WITH CREW WITH 1 BBL OUT PICK UP LAY IN CEMENT 1:1 LEAVE CEMENT TOPAT 9995' PICK UP TO -REMOVE INJECTOR AT 2000 HRS 9700'. I i SQUEEZE 8.1 BBLS CEMENT PAST -LAY DOWN CEMENTING BHA WHIPSTOCK SQUEEZE PRESSURE BUILDS TO 1200 PSI, BREAKS BACK TO 550 PSI THEN T ' BACK TO 1100 PSI. WELLHEAD _ _ BLEED OFF SQUEEZE PRESSURE SLOWLY. 16:30 - 19:45 3.25 T WHIP r P 1036500 . WEXIT POOH 9/3/2019 -RIH TO 5'ABOVE WHIPSTOCK AND CLEANOUT WITH EXHAUST PILL. -POOH PUMP RATE 4 BPM IN / 3.63 OUT -JOG THROUGH ALL JEWELRY ! -PERFORM A 10 MINUTE FLOW CHECKAT - j SURFACE PRIOR TO THE BHA ENTERING THE _•_-_. _. -0000._- --L—_ .BOPS 1945 - 21:00 1.25 WHIP P _ _.. 1 10,365.00 ___—_ WEXIT BHA HANDLE I -HOLD PJSM WITH CREW -REMOVE INJECTOR AT 2000 HRS I i -LAY DOWN CEMENTING BHA -INSTALL JET NOZZLE AND JET BOPAND T WELLHEAD 2100 - 23:00 2.00 STWHIP P 10,365.00 WEXIT BHA HANDLE -INSTALL AND TEST CHECK VALVES TO 3500 PSI -GOOD TEST -MAKE UP WINDOW MILLING BHA -MAKE UP INJECTOR AT 2245 HRS 000.0..__.. }— _ t --t.. _ -- '..__. !-TEST -0,365_ .. QTS TO 3500 PSI- GOOD TEST 2300 - 00:00 1.00 STWHIP P 10,365.00 WEXIT ',RIH -PUMPAT 0.5 BPM IN/ 1.03 BPM OUTAT 103 PSI 00:00 - 01:45 1.75 STWHIP P 10,365.00 WEXIT RIH -PUMPAT0.5 BPM IN/ 1.03 BPM OUTAT 103' PSI -TIE LOG FROM 9165' TO 9220' CORRECTION -30' -CLOSE EDC AT 10350' UP WT 52K DOWN AT 25K -TAG AT 10365' WITH NO INDICATION OF 'CEMENT IIS -PICK UP AND OPEN EDC AT 10350' Printed 9/24/2019 10:50:46AM **All depths reported in Drillers Depths** Printed 9/24/2019 10:50:46AM **All depths reported in Drillers Depths" North America - ALASKA- BP Page ion Operation Summary Report Common Well Name: 01-26 _ ---- -- - '- "-- AFE No Event Type: RE-ENTER- ONSHORE(RON) Start Date: 8/28/2019 End Date. 9/7/2019 IH-S4DW0019F5-EX-DI-RN-(1,997,619.00) Project: PBU 01 Rig Name/No.: CDR -2 Spud Date/Time: 3/25/1983 12:00:OOAM Rig Release: Rig Contractor NABORS ALASKA DRILLING INC. I BPUOI: USA00001361 Active datum: KB @67.95usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Description of Operations 10145 - 0215 (hr) 0.50 STWHIP P (usR) 10,365.00 WEXIT DISPLACE DRI LL PIPE TO QUICKDRILL-N, 6% KCL. 8.9 PPG i -PUMP AT BPM UNTIL DRILLING FLUIDAT IBIT -CLOSE EDCAND CONTINUE TO DISPLACE WELLTO QUICK DRILL -N WHILE STARTING TO MILL WINDOW. (�� 02:15 - 09:30 7.25 STWHIP P 10,372.10 j WEXIT MILL WINDOW FROM 10365.6' TO 10372.1' J LIKELY WINDOW EXIT AT THAT DEPTH BASED 6 f-Zcou ON MILLING PARAMETERS. I -RATE BPM IN 2.53 OUT - FREE SPIN 2130 PSI j -PU 48K SO 24K - MUD WEIGHT 8.9 PPG IN,8.9 PPG OUT ECD 9.66 AND START MILLING WINDOW –WOB 1-2.5 ' 09:30 - 12:30 i 3.00 STWHIP P it 10,363.00 WEXIT �.. MILL RATHOLE FROM 10372.1 TO 70363'. RATE 2.47/2:51 BPM IN/OUT j MUD WEIGHT 8.88 / 8.82 PPG IN / OUT CONTINUE TIME MILLING UNTIL REAMER EXITS. PAST 11375' START PUSHING ON MILL. MILL RATHOLEAROUND 5-10 FT/HR WITH 3K DWOB. _ _ i —r SAMPLE FROM 10376' IS 95% FORMATION. 12:30 - 14:00 I 7.50 STWHIP P 10,383.00 WEXIT CONDUCT FIRST REAMING PASS UP AT 1 FT/MIN, 30R j DOWN PASS AT 1 FT/MIN, 30R UP PASS AT 45R, 1 FT/MIN DOWN PASS AT 30R, 1 FT/MIN UP PASSAT 15R, 1 FT/MIN. PUMP 10 BELS HI -VIS SWEEP AROUND. NOTHING SEEN ON ANY OF THE PASSES. DRY DRIFT IS CLEAN, TAG AT 10383'. SAMPLE FROM END OF RATHOLE IS 95% FORMATION. 14 DO - 1800 4.00 STWHIP P 10,383.00 WEXIT PICKUP ABOVE WINDOW AND OPEN EDC. I FLAG PIPE AT 9718 FT BIT DEPTH (9585.9' EDP) YELLOW PUMP 4 BPM / 3300 PSI. TIE IN DEPTH AT 9190', CORRECT +2' RIH FOR CCLACROSS LINER TOPAREA 9800'- 10050'. (FROM POOH PUMP 4 BPM. _ 18:00 - 19:15 1.25 STWHIP P 10,383.00', WEXIT BHA HANDLE '- HOLD PJSM WITH CREW - BREAK INJECTOR AT 1815 HRS - INSPECT LAST 50' OF COIL - LAY DOWN WINDOW MILLING BHA CALIBRATE IN MICROMOTION NOTE: MILLAND STRING REAMER 3.79" NO-GO / 3.80" GO 19:75 - 19:45 0.50STWHIP P 10,383.00 WEXIT FUNCTION TEST BOPE FUNCTION TESTANNULAR, UPPER AND LOWER PIPE SLIP RAMS, BLINDS AND HORS � II FROM DRILLERS STATION -GOOD Printed 9/24/2019 10:50:46AM **All depths reported in Drillers Depths" I TRIE= FMC VYaLHEAD= FMC ACTUATOR= AXE -SON OKB. E -EV = 74' RE= ELBE = 67.95' BE R = 41.4' KOP= 3364' Max Angle = 54" @ 7900' Datum MD= 10600' Datum ND= 8800' SS 20"COND, 91.5#, H40 . =D 110' 13-3/8" CSG, 72#, L-80, D = 12.347'2607- Minimum ID = 2.813" @ 9949' 3-1/2" OTIS X NIPPLE 01 -26A SAFETY NOTES: —CHROME TBG & LNR •'• 2• HES X NP, D = 4.562' GAS LFT MANORR S ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3745 3727 20 LB DMT RM 0 04/24/18 2 6396 5735 43 LB DMY RM 0 04/24/18 3 8296 6993 49 LB OMY T-2 0 11/19/05 4 9072 7586 35 LB DMY T-2 0 03/20/99 5 9558 7991 32 LB DMY T-2 0 11/19/05 9976' �9-5/8' X 5-1/2' BKR S3 PKR D = 5-1/2• TBG, 17#, 13 -CR NSCC, 9921• 9921' 5-1/2' X 4-1/2" XO, D = 3.937• .0232 bpf, D = 4.892" :1 TOP OF 7" LNR 9944' 9944• 4-1/2• TBG, 12.6#, 13CR NSCC, � 9973• .0152 bpf, D = 3.958" TOP OF 4-1/2•LNR 10197• 9-5/8" CSG, 47#, L-80 BUTT, D = 8.681 • 10264• VYHPSTOCK (03/15/99)10296' .NR 299. L-60 BTC, .0371 bpf, ID = 6.184• –10298 7• FZSV (03/141991I–f-13� 3-1/2" STL, .0087 bpf, D 4-1/2" LNR 12.6#. D =? 3.813' � n97a- Iia-1rz-WLLii,D=a.DD• I 9966' BMD Ti LOG XX00[00C? 10197- 7"X8"BKR ZXP LTPw/HMC HGR D=4.; ' 10218• 5 X 4-1/2" XO, D = 3.937• 7- MLLOUT VVNDOW (01-26A) 10298' - 10310' 10365' WHIPSTOCK (09/02/19) 10365' ToC (osrovl9) 10383• JET CUT LNR (06/29/19) L]3 DATE PERFORATDN SUMAARY DATE REV BY 11 COMMENTS REF LOG: BRCS ON 03/14/99 RWN 35 INITIAL COMPLETION ANGLEATTOPPf ?P. 10"@10767' NDte: Refer to Production DB for historical perf data SIZE SPF ME2VAL Opn/Sgz SHOT I SQZ 2-7/8" 4 )750-107,% S 12/03/00 10/16/08 2" 6 10767 - 10777 O 06/01/11 2-7/8" 4 10769- 10783 S 04/12/99 10/16/08 2-7/8• 4 10793 - 10803 S 04/12/99 10/16/08 2-7/8" 4 10824 - 10830 C 04/12/99 3-1/2" STL, .0087 bpf, D 4-1/2" LNR 12.6#. D =? 3.813' � n97a- Iia-1rz-WLLii,D=a.DD• I 9966' BMD Ti LOG XX00[00C? 10197- 7"X8"BKR ZXP LTPw/HMC HGR D=4.; ' 10218• 5 X 4-1/2" XO, D = 3.937• 7- MLLOUT VVNDOW (01-26A) 10298' - 10310' 10365' WHIPSTOCK (09/02/19) 10365' ToC (osrovl9) 10383• JET CUT LNR (06/29/19) L]3 DATE REV BY COMMENTS DATE REV BY 11 COMMENTS 04/12183 RWN 35 INITIAL COMPLETION 12/13/18 MTWJMD PULLED PX PLUG & SET PX PLUG 03/21/99 NSES SIDETRACK (01-26A) 02/06/19 CJNJMD PULLED PX FLOG & SET PX RUG 10/16112 WIMP 3-12" SCAB LNR (10116108) 05/30/19 R7jJ MD ADDED REF & BF E -EV 12/01/13 PJC PERFORATION UPDATE 05/30/19 TJS/JMD PULLED PLUG (0529/19) 0327/18 EDWD CORRECTED MIN D 07/15/19 -PiKV16—jw jEr CUT LNR (06/29/19) 04/30/18 EFD/JMD GLV C/O (0424/18) 07/15/19 JCF/JMD RILL LNR LP (07/03/19) P RUDHOE BAY UNIT WELL: 01-26A PE2MfT No: 91990120 AR No: 50-029-2088501 TI ON, RI 5F- 616' FWL & 990' FN - BP Exploration (Alaska) 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, Prudhoe Oil Pool, PBU 01-26A Permit to Drill Number: 199-012 Sundry Number: 319-274 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 v .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. Daniel T. Seamount, Jr. Commissioner J ' DATED this day of June, 2019. RBOMSE' JUN 0 5 2019 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 RECENED MAY 3 A mo 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other Stimulate ❑ Pull Tubing ❑ Change APl ker'W Plug for Rednll 0 Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other ❑ 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: • Exploratory ❑ Development 0 5. Permit to Drill Number: 199-012 3, Address: P.O. Box 196612 Anchorage, AK 99519-6612 Stretigrephic ❑ Service 1-16. API Number. 50-029-20865-01-00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU 01-26A ' 9. Property Designation (Lease Number): 1 10. Field/Pools: ADL 028329 PRUDHOE BAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD(ft): Effective Depth NO Effective Depth TVD: MPSP (psi): Plugs (MD): Junk (MD): 10970 9232 10801 9065 2385 10814 None Casing Length Size MD TVD Buret Collapse Conductor 80 20" 29-109 29-109 1490 470 Surface 2576 13-3/8" 29-2604 29-2604 5380 2670 Intermediate 10232 9-5/8" 27-10258 27-8570 6870 4760 Liner 1 360 1 7" 9938-10298 8309 - 8602 8160 7020 Scab Liner 854 3-1/2" 9929-10783 8302 - 9047 10160 10530 Liner 768 4-1/2" 1101197-110965 8521 -9227 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 10767 - 10830 9032 - 9094 5-1/2" 17# x 4-1/2" 12.6# 13Cr80 25-9974 Packers and SSSV Type: 5-1/2" Baker S-3 Packer Packers and SSSV MD (ft) and TVD (ft): 9916/8291 No SSSV Installed No SSSV Installed 12. Attachments. Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch 0 Exploratory ❑ StreSgrephic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: July 1, 2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended 0 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Hartley, Josephine be deviated from without prior written approval. Contact Email: Josephine.Hartley0bp.com Authorized Name: Mdaughlin, Sean M Contact Phone: +1 9075644570 Authorized Title: Eng eering Team Lead - CTD Authorized Signature: �._ I Date: 57b"I 9 COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: n I �r ,1 14 I Plug Integrity BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ❑/.-lh(/i n C❑ Other.Nv Post Initial Injection MIT Req'd? Yes ❑ No ❑ Spacing Exception equired? Yes ❑ No 13?" Subsequent Form Required: v?M Y' APPROVEDBYTHE Approved COMMISSIONER COMMISSION Date: ('�1ci kf�- Form 10-403 Revised 04/2017 ORIGINAL '1RDM1,;ttrL/jlltil n 5 ?n1q /•��'��7"� Submit Form and Approved application is valid for 12 months from the date of approval. �k7 AttaChmepif In Duplicate r Bs/�/Iq To: Alaska Oil &Gas Conservation Commission Obp From: Josi Hartley CTD Engineer Date: May 29, 2019 Re: 01-26A Sundry Approval Request Sundry approval is requested to plug off the 01-26A production as part of the drilling and completing the proposed 03-26B coiled tubing sidetrack. History of 01-26A: 01-26 was originally drilled and completed in 1983, and in 1999 the sidetrack 03-26A was drilled. In 2008 a 3-1/2" scab liner was run and cemented to 10,750' MD (TOC confirmed with logs). The 3-1/2" scab liner has extensive holes and damage. The parent well has no remaining value in its current condition, with no economic well work options available. Proposed plan for 01-266: The coil sidetrack 01-26B will be a 1470' U-shaped well targeting the Zone 4 GDWFI oil pad where DS -01 meets DS -03. Drilling in 2017 identified a thick oil column in the Southeast DS -01 area, which will be the target of this well. The CST will be drilled on or around September 1", 2019. During pre -rig work it is proposed to cut and pull the 3-1/2" scab liner from the cut at 10,380' MD above the top of cement at —10,700' MD, then drift and set a 4-1/4" monobore whipstock with TOWS at -10,365' MD in the 4-1/2" production liner. The rig will move in, test BOPE and kill the well. A 3.80" window + 10' of rathole will be milled. The well will kick off in the Shublik, land in Zone 3 to locate the OWC and toe up into Zone 4. 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 Sundry covers plugging the existing 01-26A production via the liner cement Fob or liner top packer, if the liner lap oressure test fails (alternate plug placement per 20 AAC 25.1120)). 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 July 1", 2019) GI 1 pun Dx Dh,n n,;fr I in.r Svnr0�'2� Post -Rig Work: 1. V: Tree work as needed 2. SL/FB: PT Liner Lap, Set KO GLD and Set LTP if needed. 3. C: Drift. RPM. Perforate 50-100'. Josi Hartley CC: Well File CTD Engineer Joe Lastufka 564-4570 WaLGo=I W- U rF. = 10P=W9YNe= 0 D=#8.12I9 13-3/8' CSG, 72#, L-80, ID =12.347 Minimum ID = 2.813" @ 9949' 3-1@" OTIS X NIPPLE 5-12- TBG, 17#, 13 -CR NSOC, .0232 bpf, ID = 4.892' LNR TBG, 12.6#, 13CR NSCC,1--1 9973- bpf. D = 3.958' TOPOF4-1/2'LNZ 10197 1, L-80 BUTT, D = B.681102W I bpf, D=6.184' --L_2110298 ¢SV (03/14/99) 10330' 01-26A D = 2.992' R.S#, L-80 II SAFETY NOTES: "'CHROME TBG & LNR "' C- EIE.'S A NIP, IU = 4.5E GAS LIFT MANDRELS ST MD PERFORATION SUMLIARY DEVI TYPEI VLVj REF LOG: BHCS ON 03/14/99 PORT ANGLEATTOP R3tF. 10' @ 10767' Nobe: Refer to Production DB for hstork al pert data SIZE SPF INTERVAL OpWft SHOT SOZ 2-7/8' 4 10750-10756 S 12/03/00 10/16/08 2- 6 10767 - 10777 O 06/01/11 6993 2-79' 4 10769-10783 S 04/129910/16/08 4 2-7/8' 4 10793 - 10803 S 04/12/99 10/16/08 2-7/8' 4 10824 - 10830 C 04/1299 LB DMY 01-26A D = 2.992' R.S#, L-80 II SAFETY NOTES: "'CHROME TBG & LNR "' C- EIE.'S A NIP, IU = 4.5E GAS LIFT MANDRELS ST MD I WDI DEVI TYPEI VLVj LATCH PORT I DATE 1 3745 3727 20 LB DMV RM 0 0424/18 2 6396 5735 43 LB OW RM 0 0424118 3 8296 6993 49 LB OM1' T-2 0 11/19/05 4 9072 7586 35 LB DMY T-2 0 0320/99 5 9558 7991 32 LB DMY T-2 0 11/19/05 ID = 4.75' 9921' 70' DEPLOY SLV, D= 12' XO PN. ID = 2 992 X 7' BOT LNR HGR 9952' X14-12' HES X NP, ID = 3.813" 8874' 4-12'WLEG,ID=4.00' 9966' B -MD Tr LOG UJXXIXX? 10197' 7-X5-BKRZXPLTPW/HMi 7- MILLOUT WNDOW (01-26A) 10298'-10310' 1074W SLM TOPOFCE34ENT(0827/10 TA( .0152 bpf, D = 3.958' DATE REV BY COMMENTS DATE REV BY COWENTS 04M2183 RWN 35 INTIAL COMPLETION 12/13/18 MTiIJMD PILLED PX RUG & SET PX RUG 0321/99 NIPS SIDETRACK (01-26A) 0296/19 CJNJMD PULLED PX RUG & SET P% PLUG 10MV12 W WP 3.12- SCAB LNR (1011698) 05/30/19 JNJJMD ADDED RTP & BF E LLV 1291/13 PJC PERFORATION UPDATE 05/30/19 TJS/JMD PULLEDPLUG(05/29/19) 0327/18 ED/JMD CORREUTED MIN D 04/30/18 EPD/JMD GLV C/O (0424/18) 1 PRUDHOE BAY UNTT WELL: 01-26A PERMIT No: 1990120 AR No: 50-029-20685-01 SECB, T10N, R15E, 616' FWL & 990' FNL BP Bipbrat-an (Alaska) ,RM= WELLHEAD = FRC ACRl4TOR= DEV Nf1AL KB. ELE 74' BF. ELBI = PORT KOP= 3364 Max Angle 3727 Datum RD= 10600 Datum TVD= 8800'SS PROPOSED REV 1 20•COWXICTOR 110' 91.5#, H-40, D =19.124" 13-3/8" CSG, 72#, L-80, D =12.347 260 Minimum ID = " 5-12NSCC, 992 - TBG, 17#,13 -CR .0232 bpf, D = 4.892' 7" LN2 H 9944' 4-1/2• TBG, 12.6#, 13CR NSCC, .0152 bpf, D = 3.958" /2'LNR H 10197' 9-58" CSG, 47#, L-80 BUTT, D = 8.681 —L_102" VWIPSTOCK(03/15/99) 10288' LWT, 29#, L-80 BTC, .0371 bpf, D= 6.184• ^10288 4-1/2•WHPSTOCK(=—) 10: LNR. 12.6#. L-80 ET/IBC..0152 bof. D = 3.958' PEFFORKTDN SUuM TTY REF LOG: _ ON _!_/ ANGLEATTOP PHiF: —*@—' We Refer to Production DS for historical oerf data PBTD 11835' www SAFETY NOTES: W ELL ANGLE> 70' @ _'. 01-26B B MAX DLS: _' @ "CHROME TBG & LNR `•` 2182' 5-12" HES X NP, D = 4.562• GAS LFT WNUR LS ST RV TVD DEV TYPE VLV LATCH PORT DATE 1 3745 3727 20 LB DW RM 0 04124/18 2 6396 5735 43 LB DW RM 0 0424118 3 8296 6993 49 LB DW T-2 0 11119/05 4 9072 7586 35 LB DW T-2 0 03/20/99 5 9558 7991 32 LB DMY T-2 0 11/19/05 9921' H 5-12" X 4-12" XO, D = 3.937" 13.70• DEPLOY SLV, D= 3.00" 9-5/8" X 7" TIEBACK SLV, D =? 9962' 1-14-12" HES X PP, D= 3.813" (BEHIND LNR) { 9974' H4-12• WLEG, D=4.00• 9866' E -MD TT LOG XXIIOOXX? 7" MLLOIfr WINDOW (01-26A) 10298'-10310- FMLLOIJT WINDOW (01-268) 10365'-10375- i 13 -1/4 -X2 -7/8-X0, ID=2377- 1 DATE REV BY CORNBJIS DATE RET/ BY CORM94I5 04112!83 RWN 35 INITIAL COMPLETION 03/2V99 NOTE SIDETRACK(01-26A) 10/16/12 WWP 3-112" SCAB LNR(10/16/08) CTD ST (01-268) 08122J18 JMD BLLT PROPOSED 08122/18 GS/JM BLIT PROPOSED REV 1 PRUGHOE BAY LNr WH.L 01-26B PEMAT No, AR No. 50-029-20885-02 SEC 8, T1 OR R15E, 616' FWL & 990 FTL BP Exploration (Alaska) Well Bi9hoie CDR2-AC 4 Ram BOP Schematic Date 21 -Nov -17 Quick Test Sub to Otis -L1 tt Top of 7" Otis 0.0 ft . 4 CDR2 Rig's Drip Pan Distances from top of riser Excluding quick -test sub -- 7-1116. 6k Flange x 7. Otis Boa Top of Annular F 6.0 ft i- ydril 7 1 M Top of Annular Element 6.7ft Annular Bottom Annular 8.0 ft 2-L8" Pipe/Slips CL 2�318" Pipe/Slips 0 11111 Kill LineA6 I Ala- aA 7-1/16 as I . �16� tra e;q sMudr'aa1��4 ns } -1 rAi�f cru III 2-110" v 1-112" VBRs III 4. , 2318"PlpelSlips � � �I CL 2-3/8" PipelSlips CL of Top Swab 16.0 ft • t Test Pump Hose CL of Flow Cross CL of Master 18.8 ft LDS O OA LDS O Ground Level • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 11,2012 t< OA ,'C 7 2.Ui Mr. Jim Regg Alaska Oil and Gas Conservation Commission Q ta-d 333 West 7 Avenue 61 i p t Anchorage, Alaska 99501 0‘1 Subject: Corrosion Inhibitor Treatments of GPB DS -01 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB DS- 01 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, Gerald Murphy, at 659 -5102. Sincerely, I , Mehreen Vazir BPXA, Well Integrity Coordinator • • BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10-404) DS-01 01/20/12 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft NA qal 01 -01C 2070920 50029210070200 0.8 NA 0.8 NA 8.5 10/22/2011 01 -02 1691190 50029200530000 4.8 NA 4.8 NA 78.2 9/17/2010 01 -03A 1952040 50029200630100 2.3 NA 2.3 NA 22.2 10/10/2010 01 -04A 2011520 50029200700100 Dust Cover NA NA NA NA NA 01 -05B 2070480 50029200760200 1.5 NA 1.5 NA 5.1 1/20/2012 01 -06A 1950080 50029201120100 Sealed conductor _ NA NA NA NA NA 01 -07A 1940820 50029201570100 Sealed conductor NA NA NA NA NA 01-08A 2051950 50029201600100 Sealed conductor NA NA NA NA NA 01 -09A 1940330 50029201640100 Dust Cover NA NA NA NA NA 01 -10 1750430 50029201690000 Sealed conductor NA NA NA NA NA 01 -11 1770570 50029202680000 Sealed conductor NA NA NA NA NA 01 -12A 2021920 50029202690100 Sealed conductor NA NA NA NA NA 01 -13 1770590 50029202700000 Sealed conductor NA NA NA NA NA 01 -14A 2091290 50029202810100 Sealed conductor NA NA NA NA NA 01 -15A 1952100 50029202870100 Sealed conductor NA NA NA NA NA 01 -16 1780080 50029202880000 Sealed conductor NA NA NA NA NA 01 -176 2040120 50029202890200 Sealed conductor NA NA NA NA NA 01 -18A 2090720 50029203030100 Sealed conductor NA NA NA NA NA 01 -196 2081770 50029208000200 0.1 NA 0.1 NA 0.9 9/16/2010 01 -20 1821460 50029208210000 0.1 NA 0.1 NA 9.4 10/22/2011 01 -21A 2081310 50029208270100 41.0 2.0 0.4 7/8/2011 9.4 10/22/2011 01 -22B 2100340 50029208480200 0.2 NA 0.2 NA 1.7 10/11/2010 01 -23 1821800 50029208540000 0.2 NA 0.2 NA 11.1 10/21/2011 01 -24A 1921320 50029208600100 0.3 NA 0.3 NA 3.4 10/10/2010 01 -25 1822030 50029208740000 0.0 NA 0 NA 10.2 10/25/2011 ,..--, 01 -26A 1990120 50029208850100 0.0 NA 0 NA 7.3 10/21/2011 01 -28A 2091250 50029215970100 0.0 NA 0 NA 8.5 10/22/2011 01 -29 1861050 50029216040000 Dust Cover NA NA NA NA NA 01 -30 1861110 50029216060000 1.9 NA 1.9 NA 11.9 10/11/2010 01 -31 1861320 50029216260000 0.0 NA 0 NA 9.4 10/21/2011 01 -32 2021850 50029216220100 15.0 NA 15 NA 15.3 10/11/2010 01 -33 1861220 50029216170000 3.0 NA 3 NA 34.0 10/11/2010 01 -34A 2081250 50029216090100 Sealed conductor NA NA NA NA NA STATE OF ALASKA ALASKAOAND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate ❑ Otherf LINER TOP PACKER Performed: Alter Casing ❑ Pull Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate s Re -enter Suspended We 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ ` 199 -0120 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 20885 -01 -00 8. Property Designation (Lease Number) : - 9. Well Name and Number: ADLO- 028329 , PBU 01 -26A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10970 feet Plugs (measured) 10801TOC, 10814 feet true vertical 9231.67 feet Junk (measured) None feet Effective Depth measured 10879 feet Packer (measured) 9916 9929 10197 feet true vertical 9141.97 feet (true vertical) 8291 8302 8521 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 91.5# H -40 27 - 107 27 - 107 1490 470 Surface 2581' 13 -3/8" 72# L -80 26 - 2607 26 - 2607 4930 2670 Production 10239' 9 -5/8" 47# L -80 25 - 10264 25 - 8575 6870 4760 Liner 366' 7" 29# L -80 9944 - 10310 8314 - 8611 8160 7020 Liner 768' 4 -1/2" 12.6# L -80 10197 - 10965 8521 - 9227 8430 7500 Liner 854' 3 -1/2" 9.3# L -80 9929 - 10783 8302 - 9047 10160 10530 Perforation depth: Measured depth: SEE ATTACHED - - NN JUN 24 ZU True Vertical depth: _ - _ _ Tubing: (size, grade, measured and true vertical depth) 5 -1/2" 17# 13Cr80 24 - 9921 24 - 8295 4 -1/2" 12.6# 13Cr80 9921 - 9974 8295 - 8339 Packers and SSSV (type, measured and true vertical depth) 5 -1/2" Baker S -3 Packer 9916 8291 4 -1/2" Baker KB LT Packer f.r 8302 � q,F_ 5" Baker ZXP To Packer d 1 8521 12. Stimulation or cement squeeze summary: Intervals treated (measured): 114 **flaw °41 Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 182 22,510 1,464 656 Subsequent to operation: 473 14,184 5,738 563 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory0 Development 0 - Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil - 151 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ SUSP❑ SPLUG ❑ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Joe Lastufka Printed N. - •e Lastuf , ' Title Petrotechnical Data Technologist Signa - MIR Phone 564 -4091 Date 6/24/2011 RBDMS JUN 213 NU : 716.z g 1( Form 10-404 Revised 10/2010 Submit Original Only 01 -26A 199 -012 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 01 -26A 4/12/99 PER 10,769. 10,783. 9,033.51 9,047.31 01 -26A 4/12/99 PER 10,793. 10,803. 9,057.17 9,067.03 01 -26A 4/12/99 PER 10,824. 10,830. 9,087.74 9,093.66 01 -26A 12/3/00 APF 10,750. 10,756. 9,014.77 9,020.68 01 -26A 11/24/05 BPS 10,720. 10,725. 8,985.2 8,990.13 01 -26A 6/2/08 BPS 10,814. 10,830. 9,077.88 9,093.66 01 -26A 6/3/08 BPP 10,720. 10,793. 8,985.2 9,057.17 01 -26A 10/15/08 STC 9,929. 10,781. 8,301.97 9,045.34 01 -26A 10/16/08 SQZ 9,929. 10,814. 8,301.97 9,077.88 01 -26A 9/7/10 MLK 9,929. 9,930. 8,301.97 8,302.8 01 -26A 6/1/11 APF 10,767. 10,777. 9,031.53 9,041.39 AB ABANDONED PER PERF • APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE • 1 1 1 i • • 01 -26A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY A Y; D,4' E 99.& 4X # 7 "' 5/23/2011 ** *WELL S/I ON ARRIVAL ** *(pre adperf) LRS PUMPS 250 BBLS CRUDE DOWN TBG RAN 3.75" CENT, 4 -1/2" BLB, 3 -1/2" BLB, TAG/ BRUSH DEPLOY SLV @ 9932' SLM/ 9929' MD SET 4 -1/2" KB LT PKR (oal= 13.76' min i.d 2.36, 4 -1/2" G -fn) IN LT DEPLOY SLV (cr) I 9932' SLM/ 9929' MD LRS PERFORMS PASSING MIT -T TO 2500# ** *WELL LEFT S/I ON DEPARTURE * ** 5/23/2011 T /I /0= 2300/280/400 Temp= SI MIT -T PASSED to 2500 psi (Add Perf) Loaded Tbg with 5 bbls meth, 250 bbls crude. MIT -T: Pressured up Tbg with 7 bbls crude. Tbg lost 20 psi in 1st 15 mins and 0 psi in 2nd 15 mins for a total loss of 20 psi in 30 min test. Bled pressure back. Slickline on well upon departure. FWHP's= 60/200/400 6/1/2011 ** *WELL SHUT -IN ON ARRIVAL * ** E -LINE PERF SSV CLOSED, INITIAL T /I /O = 100/350/200 `LOGGED JEWELRY FROM 9350'- 10777', TAGGED TD AT 10777'. DEPTH REFERENCED TO SLB SCMT LOG DATE 9- JUNE -10. CHANGED GR SCALE TO 0 -300 WITH x10 BACK -UP. HEAVY SCALE CAUSED GR TO READ UP TO 3000 GAPI. PERFORATED 10767'- 10777' WITH 2" HSD 6 SPF 60 DEGREE PHASED PJ OMEGA GUN. ALL SHOTS FIRED. CORRELATED TO JEWELRY LOG MADE ON PREVIOUS RUN. WHP DROPPED FROM 150 PSI TO 50 PSI AFTER SHOOTING. MOVED PERF INTERVAL UP 3 FEET DUE TO HIGH TAG DEPTH. DOUBLE CONFIRMED WITH PAD ENGINEER PRIOR TO SHOOTING. FINAL T /I /O 50/300/200. SSV LEFT CLOSED AS ON ARRIVAL. HAND OVER WITH DSO PRIOR TO DEPARTURE. ** *JOB COMPLETE * ** FLUIDS PUMPED BBLS 1 DIESEL 6 METH 267 CRUDE 274 TOTAL TREE _ FMC WELLHEAD - _ FMC • SAFETY PeS: ** *CHROME TBG & LNR*** ACTUATOR = AXELSON O 1 -2 KB. ELEV = 74' BF.ELEV= ( - KOP = 3364' 20" CONDUCTOR, -I 110' V Max Angle = 54° @ 7900' Datum MD = 10600' 91.5 # , H-40, I 2182' 1-15 -1/2" HES X NIP, ID = 4.562" I Datum - TV - 6'z . atum TVD = 8800' _ SS ID = 19.124" GAS LIFT MANDRELS 113 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2607' ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3745 3727 20 LB DOME T -2 16 04/09/09 Minimum ID = 2.36" @ 9832 2 6396 5735 43 LB SO T -2 20 04/09/09 4.1'2" KB LNR TOP PKR 3 8296 6339 49 LB DMY T -2 0 11/19/05 4 9072 7586 35 LB DMY T -2 0 03/20/99 5 9558 7991 32 LB DMY T -2 _ 0 11/19/05 4 -112" KB LTF'K, ID = 2.36" (05/23/11) I 9532' `� �� .�,� iii V 9916' --I9 5/8" X 5 -112" BKR S -3 PKR, ID = 4.75" 1 5 -1/2" TBG, 17 #, 13 -CR NSCC, 9921' 9921' -I5 1/2" X 4 -1/2" XO, ID = 3.937" .0232 bpf, ID = 4.892" III 9929' 1 DEPLOY SLV, ID = 3.00" I TOP OF 3-1/2" CTU LNR 1-) 9929' 9936' --I 3-1/2" XO PIN, ID = 2.992" I 9944' H9 -5/8" X 7" TIEBACK SLV, ID =? 9949' I - I3 - 1/2" OTIS X NIP, ID = 2.813" I TOP OF 7" LNR H 9944' I 9949' H9 -5/8" X 7" BOT LNR HGR (SHORTY), ID =? 1 9952' I- I4 -1/2" HES X NIP, ID = 3.813" (BEHIND LNR) 3 4 -1/2" TBG, 12.6 #, 13CR NSCT, - I 9974' 9974' I - 14 - 1/2" WLEG, ID = 3.958" I .0152 bpf, ID = 3.958" 9966' I - 1 ELMD TT LOG XX/XX/XX? 1 !TOP OF4- 1 /2 "LNRH 10197' 10197' 1 -37 " X5 "BKRZXPLTPw /HMC HGR, ID= 4.375" 1 10218' I X 4 -1/2" XO, ID = 3.937" I 1 9-5/8" CSG, 47 #, L -80 BUTT, ID = 8.681" H 10264' I !WHIPSTOCK (03/15/99) I--I 10298' I I 7" MILLOUT WINDOW (01 -26A) 10298' - 10310' 10749' SLM - ITOP CEMENT (08/27/10 TAGGED) 1 17" EZSV (03/14/99)1 10330' 17" LNR, 29 #, L -80 BTC, .0371 bpf, ID = 6.184" I - 1 11075' •1•• , �i /` X +, PERFORATION SUMMARY 0 4#••••• 0004 1111111 ��s. 10801' CTMD H Pam (06/03!10) REF LOG: BHCS ON 03/14/99 1 1 +. ��1��1 \ s ANGLE AT TOP PERF: 10° @ 10767' +11 Note: Refer to Production DB for historical perf data , * ' . + .'. ' .' + ' � s�45, is SIZE SPF INTERVAL Opn /Sqz DATE 10814' I-{ CIBP I 3 -1/2" CTU LNR, 9.3 #, - 10783' iiik 2 -7/8" 4 10750 - 10756 S 10/15/08 / \ �; li,; 2" 6 10767 - 10777 0 06/01 /11 f/ 13CR -80 STL, tisti 2 -7/8" 4 10769 - 10783 S 10/15/08 .0087 bpf, ID = 2.992" 2 -7/8" 4 10793 - 10803 S 10/15/08 2 -7/8" 4 10824 - 10830 C 04/21/99 1 4-1/2" LNR, 12.6 #, L -80 IBT /IBC, .0152 bpf, ID = 3.958" H 10965' I DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 04/21/83 RWN 35 ORIGINAL COMPLETION 06/04/10 KEY /PJC FISH MILLED (06/03/10) WELL: 01 -26A 03/21/99 N9ES SIDETRACK (01 -26A) 03/09/11 BS /PJC GMT CORRECTION PERMIT No: ° 1990120 06/26/08 ?/ PJC DRAWING CORRECTIONS 05/31/11 MSS/ PJC SET LNR TOP PKR (05/23/11) API No: 50- 029 - 20885 -01 10/28/08 JKC /PJC 3 -1/2" CTU LNR (10/16/08) 06/02/11 JCM/ PJC PERFORATE (06/01/11) SEC 8, T1 ON, R15E, 616' FWL & 990' FNL 04/12/09 CJN/SV GLV C/0 (04/09/09) 06/04/10 JKD /PJC MILL CEMENT (06/03/10) BP Exploration (Alaska) osn>3r1o J I 1 /~ l Scttt~unherger Alaska Data & Consulting Services 2525 Gembell Street, Buae 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # N0.5545 Company: State of Alaska Alaska Oil & Gas Cons Comm Ann: Christine Mahnken 333 West 7th Ave, Sufte 100 Anchorage, AK 99501 Log Description Date BL Color CD E-198 BBUO-00015 STATIC BOTTOM & TEMP SURVEY 04/03/10 1 1 H-30 BCR0.00020 PRODUCTION PROFILE 05/10/10 1 1 P2-34 B3S0-00071 STATIC PRESSURE SURVEY 05/15/10 1 1 P2.34 B3S0.00073 (PROF WITH STATIC SURVEY 05/19/10 1 1 V-OS AWJt-00090 MEM CBL .. ? 05/24/10 1 1 P2-17 BCRC-00017 PRODUCTION PRO ICE .06/01/10 1 1 i6-O6B BBUO-00023 PRODUCTION PROFILE 06/08/10 1 1 S•21 Z-46A BBSK-D0019 BAUJ-00027 PRODUCTION PROFILE MEM CBL 06/03/10 06/01/10 1 1 1 t V-OS 01-26A BD88-00018 8148-00106 MEM LDL SCMT ..06/08/10 06/10/10 / 1 1 1 B-13A 1-27/P-20 BBUO-00019 AYKP-00085 USIT RST & FL RECOR 05/28/10 06/06/10 1 / 1 1 1-27/P-20 AYKP-00005 PRODUCTION PROFILE 06/06/10 1 1 MPF-82A BAUJ-00010 MCNL 04/06/10 1 1 Z-16A E-15D BCUE-00005 AWJI.00081 CH EDIT PDC MEM CORR CATION MCNL 04/06/10 04/03/10 1 1 1 05-19 BBKA-00013 RST - 03/14/10 1 1 F-27A AYKP-00078 RST 03/17/10 1 1 J-18A BD88-00010 MCNL 04/18/10 1 1 BP Exploration (Alaska)Inc. __--- . _. V'V.-.,-V ^~•V „"V,""„MV~•~vVr ~ ~~V~~ ~V~ Petrotechnicai Data Cenler LR2-1 900 E. Benson Blvd. Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ,7 ~.11, k6 '.' ~ l.1 ~'.1 ,~ °.~. ~~ STATE OF ALASKA ALASKA AND GAS CONSERVATION COMMIS REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ^ Repair Well ^ Plug Perforations ^ Stimulate^ Other 0 MILL Performed: Alter Casing ^ Pull Tubing ^ Perforate New Pool ^ Waiver^ Time Extension ^ CEMENT Change Approved Program ^ Operat. Shutdown ^ Perforate ^ Re-enter Suspended Well ^ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: .Permit to Drill Number: Name: Development ~ Exploratory ^ 199-0120 3. Address: P.O. Box 196612 Stratigraphic^ Service ^ 6. API Number: Anchorage, AK 99519-6612 ~ 50-029-20885-01-00 8. Property Designation (Lease Number) : ~ 9. Well Name and Number: ADLO-028329 ~ PBU 01-26A 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10970 feet Plugs (measured) 10814' feet true vertical 9231.67 feet .Junk (measured) None feet Effective Depth measured 10879 feet Packer (measured) 9916 10197 true vertical 9142 feet (true vertical) 8291 8521 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20" 91.5# H-40 27 - 107 27 - 107 1490 470 Surface 2581 13-3/8"72# L-80 26 - 2607 26 - 2607 5380 2670 Production 10239 9-5/8" 47# L-80 25 - 10264 25 - 8587 6870 4760 Liner 377 7"29# L-80 9921 - 10298 8295 - 8602 8160 7020 Liner 754 4-1/2"12.6# L-80 10211 - 10965 8532 - 9227 8440 7500 Liner 854 3-1/2" 9.3# 13CR-80 9929 - 10783 8302 - 9047 10160 10530 Perforation depth: Measured depth: SEE ATTACHED - _ _ _ True Vertical depth: Tubing: (size, grade, measured and true vertical depth) 5-1/2" 17# 13-CR SURFACE - 9921 SURFACE - 8295 4-1/2" 12.6# 13CR 9291 - 9974 8295 - 8339 Packers and SSSV (type, measured and true vertical depth) 9-5/8"X5-1 /2" BKR S-3 PKR ~ 9916 8291 7"X5" BKR ZXP LTP 10197 8521 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~, ~ ;a~~~~, ` ' ~~° ~ ~ (~ N ~~~~ ~; %~ ~ moo.. ~s :. ~ ~ .~., Treatment descriptions including volumes used and final pressure: tl ~ gas ~"~'~~. ~ptilttllR~w4l~ Alaska Q 13. Representative Daily Average Production or Injection Data - ft Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: 666 22444 2365 246 14. Attachments: 1YZ Well Class after work: Copies of Logs and Surveys Run Exploratory^ Development ^~ Service ^ Daily Report of Well Operations X .Well Status after work: Oil ~ Gas WDSPL GSTOR ^ WAG ^ GINJ ^ WINJ ^ SPLUG ^ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: NA Contact Gary Preble Printed Name Gary Pre Title Data Management Engineer Signature Phone 564-4944 Date 6/24/2010 ' ~ '7> 7-tv %~fa 01-26A 199-012 PPFRF ATTA[_I-IMFIUT r~ LJ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 01-26A 4/12/99 PER 10,769. 10,783. 9,033.51 9,047.31 01-26A 4/12/99 PER 10,793. 10,803. 9,057.17 9,067.03 01-26A 4/12/99 PER 10,824. 10,830. 9,087.74 9,093.66 01-26A 12/3/00 APF 10,750. 10,756. 9,014.77 9,020.68 01-26A 11/24/05 BPS 10,720. 10,725. 8,985.2 8,990.13 01-26A 11/24/05 BPS 10,814. 10,830. 9,077.88 9,093.66 01-26A 6/5/08 BPP 10,720. 10,793. 8,985.2 9,057.17 01-26A 10/15/08 STC 9,929. 10,781. 8,301.97 9,045.34 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE C~ • i 01-26A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 6/2/2010 CTU #9 w/ 1.75" CT: Job Scope: Mill Cement: MIRU coiled tubing unit. MU and RIH with SLB memory GR/CCL. ***Job Continued on 03 June 10"** 6/3/2010 CTU #9 w/ 1.75" CT: Job Scope: Mill Cement: Continued from 02 June 10. Continued RIH with memory GR/CCL. Log from 10742' to 9500' uncorrected depth. OOH with good data, correction = +14'. MU motor and 2.78" diamond parabolic mill. POP well through ASRC test separator and RIH. Correct depth at flag and mill liner jewelry. Mill from 10750' to 10801' corr. FP well 3 with 58 Bbls 50/50 McOH. Cannot rig down due to high winds. Go to weather ticket at midnight ***Job Continued on 04 June 10*'`* 6/3/20103 ASRC Test Unit #1, Assist CTU w/milling operations, CTU standing by to rig down due to high winds, Stand by , **"Job in Progress"** , Inlet 01-26, Outlet 01-22 ~~ 6/4/2010 CTU #9 w/ 1.75" CT: Job Scope: Mill Cement: Continued from 03 June 10. I f Off weather standby. Rig down coiled tubing unit. ***Job Complete*"" .~~ 6/4/2010 ASRC Test Unit #1, CTU Rigged down, POP well, Stabilize for well test, ***Job in Progress*** Inlet 01-26, Outlet 01-22 1 6/5/2010 ASRC Test Unit #1, End 8 hour test, Begin rig down, ***Job in Progress*** j Inlet 01-26, Outlet 01-22 6/6/2010 ~ASRC Test Unit #1, Complete Rig Down, ""*Job Complete*** Inlet 01-26, Outlet 01-22 FLUIDS PUMPED BBLS 486 1 % XS KCL W/.6% SAFELUBE 34 GEOVIS 148 50/50 METH 668 Total Ea= _, . FMC 'WELLHEAD = FMC 'ACTUATOR= AXELSON I KB. ELEV = 74' BF. ELEV = KOP = 3364' 20" CONDUCTOR, 110' Max Angle = 54° @ 7900' Datum MD = 10600' 91.5#, H-40, Datum TV D = 8800' SS ID = 19.124" 13-3/8" CSG, 72#, L-80, ID = 12.347" 2607' Minimum ID = 2.813" @ 9949' 3-1/2" OTIS X NIPPLE 5-112" TBG, 17#, 13-CR NSCC, 9921' .0232 bpf, ID = 4.892" TOP OF 3-1/2" CTU LNR --I-9929' TOP OF 7" LNR ~-~ 9944' 4-1/2" TBG, 12.6#, 13CR NSCT, 9974' .0152 bpf, ID = 3.958" TOP OF 4-1/2" LNR 10197' 9-5/8" CSG, 47#, L-80 BUTT, ID = 8.681" 10264' WHIPSTOCK (03/15!99) 10298' 17" EZSV (03/14/99) ~ 7" LNR, 29#, L-80 BTC, .0371 bpf, ID = 6.184" ~ PERFORATION SUMMARY REF LOG: BRCS ON 03/14/99 ANGLE AT TOP PERF: 10° @ 10750' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-718" 4 10750 - 10756 S 10/15/08 2-718" 4 10769 - 10783 S 10/15/08 2-7/8" 4 10793 - 10803 S 10/15/08 2-7/8" 4 10824-10830 C 04/21/99 O ~ -~ ~~ SAF~TY~ES: ***CHROMETBG&LNR*** 2182' ~ 5-1 /2" HES X NIP, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 1 3745 3727 20 LB DOM T-2 16 04/09/09 2 6396 5735 43 LB SO T-2 20 04/09/09 3 8296 6339 49 LB DMY T-2 0 11/19!05 4 9072 7586 35 LB DMY T-2 0 03/20!99 5 9558 7991 32 LB DMY T-2 0 11/19/05 9916, I-j 9-518" X 5-1/2" BKR S-3 PKR, ID = 4.75" 9921' 5-1/2" X 4-1/2" XO, ~ = 3.937 9929' 3.70" DEPLOY SLV, ID = 3.00", 9936' 3-1/2" XO PIN, ID = 2.992" 9944' 9-5/8" X 7" TIEBACK SLV, ID =? 99~ 3-1/2" OTIS X NIP, ID = 2.813" 9949' ~ 9-5/8" X 7" BOT LNR HGR (SHORN), ID =? 9952' 4-1/2" HES X NIP, ID = 3.813" (BiJi1ND LNR} 9974' 4-1/2" WLEG, ID = 3.958' 9966' ELMD TT LOG XX/XX/XX? 10197' 7" X 5" BKR ZXP LTP w / HMC HGR, ID = 4.375" 108' ~ 5 X 4-112" XO, ID = 3.937" 7" MILLOUT WINDOW (01-26A} 10298' - 10310' CTMD I-I PBTD (06103110) 3-1/2" CTU LNR, 9.3#, 10783' ~ 10814' ~ CIBP 13CR-80 STL, .0087 bpf, ID = 2.992" 4-1/2" LNR, 12.6#, L-80 IBT/IBC, .0152 bpf, ID = 3.958" 10965' DATE REV BY COMMENTS DATE REV BY COMMENTS 04/21/83 RWN 35 ORIGINAL COMPLETION 06/04/10 KEY/PJC FISH MILLED (06103110) 03!21199 N9ES SIDETRACK (01-26A) 06!26/08 ?! PJC DRAWING CORRECTIONS 10!28/08 JKC/PJC 3-112" CTU LNR (10/16/08) 04!12/09 CJN/SV GLV C/O {04/09/09) 06/04/10 JKDIPJC MILL CEMENT (06/03/10) PRUDHOE BAY UNff WELL: 01-26A PERMIT No: "1990120 API No: 50-029-20885-01 SEC 8, T10N, R15E, 616' FWL & 990' FNL BP Exploration (Alaska} 12/08/08 ~~ ~~ill~~m~er~~ih Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: BetFi Wall _InF. fk ~ n.. NO.4995 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 R-03A 4994 INJECTION PROFILE (REVISED) 10/08/08 1 1 13-23A 4994 INJECTION PROFILE 10/21/08 1 1 01-26A 4994 SCMT 11/13/08 1 1 D-29 4994 USIT 10/19/08 1 1 15-02B 4994 MEM PROD PROFILE - 11/25/08 1 1 H-05A 4994 MEM PROD & INJ PROFILE 11/20/08 1 1 E-32A 4994 SCMT ( 11/04/08 1 1 12-17 4994 PRODUCTION LOG - p L/ 11/04/08 1 1 P2-41 4994 PRODUCTION LOG - 11/07/08 1 1 1••29/M-25 4994 PRODUCTION LOG (p - 11/04/08 1 1 NIPC-05A 4994 MEM LDL ~ 11/15/08 1 1 L-114A 4994 _ USIT .- (( J`_ 11/03/08 1 1 A-07 4994 PRODUCTION PROFILE ~• - ( ~} 11/27/08 1 1 07-18 4994 INJECTION PROFILE ~- - 12/02/08 1 1 15-12B 4994 MEM PROD PROFILE eo .- 1•~ ~e ~ 11/27/08 1 1 4-40/P-43 4994 MEM LDL l~j `~' .f.X 11/26/08 1 1 N-14B 4994 MCNL --~ C~ ~ 09/20/08 1 1 01-21A 4994 MCNL 09/29/08 1 1 E-29A 4994 MCNL - 09/01/08 1 1 PI FOSF ACKNAWI Fil(]C GC !`CIDT cv c~~w uw~r_ nw~n ~GTI Illw --- -_----_. __.. _. _._~.~. -..~.. .v. BP Exploration (Alaska) Ina Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 , `7 Date Delivered: Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503 8 8 ATTN: Beth Received by: • Page 1 of 1 ~ • AAaunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Monday, November 10, 2008 4:36 PM To: 'Preble, Gary B (SAIC)' Subject: RE: DS 01-26A (199-012) Gary, I received the updated 404 and operations summary. A couple of questions ... 1. According to the rig schedule this work is being "supported" with the Klondike, correct? 2. Is there a report with greater detail? I would think that some greater detail report is being provided. I don't know if it is as extensive as what the rigs provide, but the work is classified as RWO on the drilling schedule. If there is a greater detailed report, I'd appreciate if you could send. This should be the case for any of the operations done with Klondike. Thanks in advance. Call ar message with any questions. Tom Maunder, PE AOGCC From: Preble, Gary B (SAIC) [mailto:Gary.Prehle@bp.com] Sent: Monday, November 10, 2008 11:05 AM _~~ r~~~e: To. Maunder Thomas E (DOA) - `_ < > ~ ~~ w; ~ ~ -~ , "~ ` ' i ~ .; ~, ~.~ .. ::~~ Subject; RE: DS 01-26A (199-012) Tom, I have added the 3-1/2" liner to the 10-404 and also included the specs on the work summary attachment and have resubmitted the 10-404 for 01-26A. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, November 10, 2008 8:48 AM To: Preble, Gary B (SAIC) Subjecfi: DS 01-26A (199-Oi2) Gary, I have reviewed the 404 recently submitted for the setting of a scab liner apparentty by coil in this well and noted the following: 1. I don't find any detail regarding any small liner on the 404 sheet. 2. Although there are comments regarding the liner in the operations report, there are no specific details on size, weight, length, top depth, bottom depth, etc. Could you look in#o this and get back to me. Tom Maunder, PE A4GCC 11/10/2008 , ~ . STATE OF ALASKA ALA~OIL AND GAS CONSERVATION COMM~~JN , ~' r .,'~at1 REPORT OF SUIVDRY WELL OPERATION~~' ~~'~~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ $timul~t~ + Qtt~er:~ $GAB LINER Performed: Alter Casing ~/ Pull Tubing ~ Perforate New Pool ~ Waiver ~ Time Extension ~ Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: rvame: De~elopment ~ Exploratory ~ 199-0120 3. Address: P.O. Box 196612 Stratigraphic ~ Se1'VICG ~ 6. API Number: Anchorage, AK 99519-6612 50-029-20885-01-00 7. KB Elevation (ft): 9. Well Name and Number: 67.95 KB PBU 01-26A 8. Property Designation: 10. Field/Pool(s): ADLO-028329 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10970 feet Plugs (measured) 10814' CIBP true vertical 9231.67 feet Junk (measured) 10793' 6/5/08 Effective Depth measured 10879 feet true vertical 9142 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 91.5# H-40 27' - 107' 27' - 107' 1490 470 Surface 2581' 13-3/8" 72# L-80 26' - 2607' 26' - 2607' 5380 2670 Production 10239' 9-5/8" 47# L-80 25' - 10264' 25' - 8587' 6870 4760 Liner 377' 7" 29# L-80 9921' - 10298' 8295' - 8602' 8160 7020 Liner 754' 4-1/2" 12.6# L-80 10211' - 10965' 8532' - 9227' 8440 7500 Liner 854' 3-1/2" 9.3# 13CR-80 9929' - 10783' 8302' - 9047' 10160 10530 Perforation depth: Measured depth: SEE ATTACHED = _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 5-1/2" 17# 13CR Surface - 9921' 4-1/2" 12.63 13CR 9921' - 997~,' Packers and SSSV (type and measured depth) 9-5/8"X5-1/2" BKR S-3 PKR 9916' 7"X5" BKR ZXP L TP 10197' 0 0 0 0 12. Stimulation or cement squeeze summary: lntervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: SI Subsequent to operation: SI 14. Attachments: 15. Well Class after oroposed work~ Copies of Logs and Surveys Run Exploratory ~ De~lopment ~' Service ~' Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~~ Gas l' WAG ~' GINJ ~! WINJ ~ WDSPL ~~` 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-101 Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 11/10/2008 Form 10-404 ReNised 04/2006 '; t '~ ~#~~~, y~~ ,~, ~4 -~~ubmit Original Only ~~ ~ y i 'ti 1 ~ ?`~. ,~m*_??wtk~'' .. ~ r :~'i's ~ €. 7~~~u ~~ W ~ Y~ • STATE OF ALASKA ' ~~~~ , ,~,, ALA~ OIL AND GAS CONSERVATION C~Il~1N~ .:r REPORT OF SUNDRY WE L OPERATIO~~`' 1. Operations Abandon ~ Repair Well ~ Plug Perforations ""' ~irrrufate~ ; ~t~~ SCAB LINER ~ Performed: Alter Casing ~- Pull Tubing~ Perforate New Pool ~ WaWe~O -, Time Extension~ ~hange Appro d Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well ~ 2. Operator BP Expl ation (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: De~lopment ~ ~ Exploratory ~ 199-0120 ~ 3. Address: P.O. Box 19 12 Stratigraphic ~ Service ~ 6. API Number: Anchorage,AK 9519-6612 50-029-20885-01-00~ 7. KB Elevation (ft): 9. Well Name and Number: .95 KB PBU Ot-26A ~ - 8. Property Designation: 10. Field/Pool(s): _ ADLO- 8329 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 109 - feet Plugs (measured) 10814' CIBP true vertical 9231.6 feet Junk (measured) 10793' 6/5/08 Effective Depth measured 10879 eet true vertical 9142 f t Casing Length Size MD ND Burst Collapse Conductor 80' 20" 9t.b# H-40 7' - 107' 27' - 107' 1490 470 Surface 2581' 13-3/8" 72# L-80 26' - 2607' 26' - 2607' 5380 2670 Production ~ 10239' 9-5/8" 47# L-80 25' - 10264' 25' - 8587' 6870 4760 Liner 377' 7" 29# L-SO 9921' - 0298' 8295' - 8602' 8160 7020 Liner 754' 4-1/2" 12.6# L-80 10211' - 1 65' 8532' - 9227' , 8440 7500 Perforation depth: Measured depth: SEE ATTACHED = - _ _ True Vertical depth: _ _ _ _ Tubing: (size, grade, and measured-depth) 5-1/2" 17# 13CR Surface - 9921' 4-1/2" 12.63 1 CR 9921' - 9974' Packers and SSSV (type and measured depth) 9-5/8"X5-1/2" BKR S-3 PKR 9916' 7"X5" BKR ZXP L TP 10197' 0 0 0 0 ~ 12. Stimulation or cement squeeze summary: ~ Intervals treated (measured): t ` ~ ~~~ 0 ~ ~ Treatment descriptions including volumes used and final pressure: ~~~~Y R~'~~~~~~_ 13• Representative Daily Average Production or Injectio ata Oil-Bbl Gas-Mcf Water-Bbl Casing Pr sure Tubing pressure Prior to well operation: SI Subsequent to operation: SI 14. Attachments: 15. Well Class after oroposed work: Copies of Logs and Surveys Run Exploratory ~"' Dev~elopment ~V ~ Se ~ce ~ Daily Report of Well Operations X i 6. Well Status after proposed work: Oil ~~ Gas ~ WAG ~` GINJ ~ WINJ ~ DSPL ~ 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exem : 307-101 Contact Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 10/24/2008 Form 10-404 Revi~ed 0+3/2006 '' ` ' Submit Original Only 01-26A 199-0120 PFRF QTTO[`HMFNT C~ Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 01-26A 4h2/99 PER 10,769. 10,783. 9,033.51 9,047.31 01-26A 4/12/99 PER 10,793. 10,803. 9,057.17 9,067.03 01-26A 4h2/99 PER 10,824. 10,830. 9,087.74 9,093.66 01-26A 12/3/00 APF 10,750. 10,756. 9,014.77 9,020.68 01-26A 11/24/05 BPS 10,720. 10,814. 8,985.2 9,077.88 01-26A 11/24/05 BPS 10,814. 10,830. 9,077.88 9,093.66 01-26A 6/5/08 BPP 10,750. 10,793. 9,014.77 9,057.17 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMO VED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED M!R MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE C~ V j~ ~ ~ ~ 01-26A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY CTU #9 on WWP w/ 2.375" CT Rig Up in Progress Continued on 10/1 WSR. 10/13/2008' CTU #9 on WWP w/ 2.375" Job Scope: Scab Liner «InterAct publishing» Called state to witness the test Chuck Sheve waived the BOP test. RIH w. PDS `Gama/CCL in 2.375" carrier and 3.6" JSN POOH from logging run. Continued ion 10/14/08 WSR. ~. ~._...._ ...~. _ __ _ r........_. .~_._ „___. __ ....., . .. 10/14/2008' CTU #9 on WWP w/ 2.375" Job Scope: Scab Liner «InterAct publishing»Continued from *""'10/13/08*""* POOH from logging run. Wasn't ' able to use BHCS reference log due to being hot across the section had to use ! Cement Bond Log from 4/3/1999 for reference. Pump dart thru coil to get volume. Pump well kill. Perform no flow test well looks good run liner. Continue to run liner. **""* Job Continued on 10/15/08 WSR *`***" _ _ ____-------.__ _ __ _ 10/15/2008 CTU #9 on WWP w/ 2.375" Job Scope: Scab Liner 3.5" 9.3# 13CR-80. «InterAct publishing»Continued from *"""10/14/08""`" Continue to Run liner. RIH with liner to 10788' tagged TD. Release from liner confirm that we are released. Liner top at 9929'ctm Liner bottom at ~uiti~'ctm. c;irc out tne gas trom the weii. °°----- ~on c;ontinuea on 10/16/08 W SR """`""'" _ _ _ __ _ _ _ _ __ . - ------_ _ __ _ _ __- 10/16/2008 CTU #9 on WWP w/ 2.375" Job Scope: Scab Liner «InterAct publishing»Continued from """10/15/08"""` Circulate well to get gas out. Cement crew on location. Batch mix and load 11.5 bbls 15.8ppg liner cement slurry in coil. Load 2.375" "pee wee" dart at tail of cement. Pump cement stage 0 o~wedby 2# biozan. Noted first bump at 54.9 bbls away(54.7 coil volume). i Sheared at - 2900 psi. Noted liner wiper plug seat at 7.1 bbls from top of liner. 9 bbls returned to 40 bbls tank during cementing operations(2.5bbls behind pipe)., Shut down pump and test float for 5 minutes(good). POOH contaminating with biozan at 1.5 bpm. 1/1 returns noted at tiger tank. During returns check ~ 6000' noted that we had approximately 60% losses. Continue ++out of hole. Notify coil coordinator and town engineer. Freeze protect coil and 'well to 2500' with 60/40 methanol. OOH. Secure well and make up nozzle to 'wash BOP stack and tree valves. Notify DSO of well status. RDMO. *"'Job FLUIDS PUMPED BBLS 75 KCL W/SAFELUBE 278 KCL 137 METH 183 DIESEL 11.5 15.8 CEMENT 50 BIO 735.5 Total _ LL LAG ~~ ~ T~~~1/511~/T~~L ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken ~ ~ ~; . r,r~ 333 W. 7th Ave %,;;,v ~~~~ ;\~ w' `, (;.. ~ ~, L;,_ Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax. (907) 245-8952 X94-6<a ~(~Cj 1) Coil Flag 2) Signed Print Name: 13~0ct-08 01-26A ESE 50-029-20885-01 PROACTNE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)2458952 E-MAIL : s~~san~~a®r~g~Ca~~;tara~sr?~3ar~.~~s~ WEBSITE : wwv~~.r~~raa®r~l®~ c~sa;~ C:\Documents and Settings\OwnerlDesktop\Trensmit_BP.doc ^~ • Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, July 08, 2008 10:20 AM To: 'Preble, Gary B (SAIC)' Cc; Quy, Tiffany ~~~ _ ~ ~~ Subject: RE:Emailing: 01-26AAOGCC Scope of Work1.doc Gary, I don't believe another 403 is necessary. When I compared what you just mailed with what is in the file, I did not find a significant difference. The work platform is now planned to be employed, but the actual work looks similar. One thing I did note was that we had communicated about a month ago regarding the 404 submitted that detailed milling the BP. I am going to move that document to the file. When you submit the 404 reporting the information regarding the scab-liner work, please be sure to reference 307-101. Call or message with any questions. Tom Maunder, PE AOGCC ~IN~~ JUL ~ $ Z00$ -----Original Message----- From: Preble, Gary B (SAIC) [mailto:Gary.Preble@bp.com] Sent: Tuesday, July 08, 2008 9:58 AM To: Maunder, Thomas E (DOA} Cc: Quy, Tiffany Subject: Emailing: 01-26A AOGCC Scope of Workl.doc Hi Tom, A 10-403 (307-101} was created and approved but the Scope of work has changed slightly. Can the new Scope be added to the existing Sundry or do we need to create a new 10-403? Thanks The message is ready to be sent with the following file or link attachments: Ol-26A AOGCC Scope of Workl.doc Note: To protect against computer viruses, e-mail programs may prevent sending or receiving certain types of file attachments. Check your e-mail security settings to determine how attachments are handled. «01-26A AOGCC-Scope of Workl.ZIP» 1 • by G~~~ Wel I: 01-26A PTD: 199-0120 Scope of Work: Scab Liner Scope of Work: Run and cement 863' of 3.5" chrome liner from TD to 9930'. This will cover the existing perfs and deteriorated liner to shut off excess gas production. The liner will be set on bottom. Following a test of the tubing and liner, the well will be re- perforated from 10770'-10780'. PLEASE NOTE: This work is scheduled for the Wellwork Platform with CTU #5. MAASP: 2400 psi Est. BHP: 3279 psi EMW: 7.2 pp9 Well Type: Ivishak Producer Estimated Start Date: July 25, 2008 Wells Engineer: Tiffany Quy This procedure includes the followin~t main steps: 1. RU SL. D&T to TD with 3.72" Centralizer. SBHPS. 2. RU2-3/8" CT with CTU and Wellwork Platform. Run 850' of 3.5" Chrome liner from TD to 9945' and fully cement. Liner will sit on bottom (a CIBP @ 10814') with fluted/centralized sub on top. 3. WOC 10 days. MIT-T and scab liner. (Will need a LTP if PT fails.} 4. RU SL. Drift with 2.5"dummy gun. Install generic GL design. 5. RU EL. Perforate from .10,770 -10,780' and with 2.5" power jet omega - HMX. Due to scab liner TD may vary. Please perforate 10' up from TD to no higher than 10,763' md. Please tie in with GR and use "01-26A BHCS logged 1999- 03-14" for reference. Proposed WWP Procedure MIRU CTU with WWP. Perform BOP tests. Well control equipment will include (top to bottom): 7-1/16" annular Preventer, 7-1/16" TOT dual-ram preventer with blind/shear rams (top) and pipelslip rams for 3.5" liner (bottom), 7-1/16" mud cross, and 7-1/16" TOT Dual-Ram preventer with pipe/slip rams dressed for 2- 3/8" CT (top) and 2-3/8" x 3-1/2" variable rams (bottom). The mud cross will be rigged up with 2 flanged connections (one manually and one hydraulically • • controlled) rigged to hard line out to the coil pump and choke. See attached Schematic of Klondike Well Control Equipment. 2. Bullhead kill well as follows: 125 bbls filtered KCI followed by 16 bbls of 150,000 LSRV flo-pro, 165 bbls of KCI and 70 bbls of diesel. Discontinue pumping if a significant pressure increase is observed. Avoid pumping an excess amount of flo-pro behind pipe if possible. If well does not appear to be dead, RIH to 10' off bottom, circulate bottoms up, and lay in the following (1:1): 15 bbls flo pro, 108 bbls filtered 1 % KCL, and 126 bbls diesel while POOH. 3. RIH with 3.5" liner and release on bottom (CIBP set at 10814'). 4. Fully cement liner in place. 5. WOC. PT liner to 2000 psi. Lubicator Ext. Lubricator RIG FLOOR Top of Mnular _~ ~~ Lubricator ID = s.375" with s" Otis unions ' ~ Hydnl Annular 7 1/16" Annular x 5000 psi Bottom of Mnular ~ 7 1/1s" 5000 psi, RX-4s Blind/Shears Blind/Shears -~ 1/4 Tum LT Valve 3.5" Pi a/Sli s Liner P P ( ) _• 3.5" Combi 7 vis~ soon psi wc-As / flanged connections - ` manual and hydraulic Choke /Kill Lines Mud cross control Hard line connections to coil and choke 2-318" Pipe/Slips (Coil) _~ ` z~i8 combi 2-3/8" x 3-1l2" Variables -• 2.375" - 3 5" variables Test & Monitor Line X-over -- Tree (XO wilt attach to Swab or SSSV depending on tree and mast heights) SSSV Master Valve Base Flange -Ground • Maunder, Thomas E (DOA) • Page 1 of 1 From: Maunder, Thomas E (DOA) Sent: Friday, June 13, 2008 3:23 PM To: 'Preble, Gary B (SAIC)' Subject: RE: DS 01-26A (199-012} m be fine,. I will holaan~t~ this 404 awaiting the operations reports~_, From: Preble, Gary B (SAIC) [mailto:Gary.Preble@bp.com] Sent: Friday, June 13, 2008 3:18 PM To: Maunder, Thomas E (DOA) Subject: RE: DS 01-26A (199-012) Tom, The scab liner work has not been completed yet. It is scheduled for sometime this summer. I will forward you the operations report for the scab liner when the work is completed. The Sundry number assigned to this work is 307- 101.Thanks for you assistance. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, June 13, 2008 11:49 AM To: Preble, Gary B (SAIC) Subject: DS 01-26A (199-012) Gary, I am reviewing the 404 recently submitted for this well. The operations reports only detail milling the BP. I believe there should be more work. Please check and if so, send the additional reports via email. Call or message with any questions. Tom Maunder, PE AOGCC 6/13/2008 1 .~~ STATE OF ALASKA 6'~'~'~ AL~ OIL AND GAS CONSERVAT~~IFlI C~t~ON REPORT OF SUNDRY E ~F ~6. ; ~,~,~ 1. O erations Abandon Re air Well Plu Pe ions rr~~ "~ (~ ti SC INER ~ ~~ Performed: Alter Casing ~ P pll Tubing ~ Perfo ate New Pool ~ ~~ Waiv~r ~ Time Extens on Q ` ° ~ Q ~ ~t l Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4 Current Well Class: 5. Permit to Drill Number: 1~ g.p Name: [development :~~ ~ Exploratory 199-0120 " 3. Address: P.O. Box 196612 StratlgraphlC Servioe 6. API Number: Anchora e, AK 99519-6612 9 50-029-20885-01-00 7. KB Elevation (ft): 9. Well Name and Number: 67.95 KB ~ PBU01-26A~ 8. Property Designation: 10. Field/Pool(s): ADLO-028329 ~ PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 10970 ~ feet Plugs (measured) 10814' true vertical 9231.67 feet Junk (measured) None Effective Depth measured 10879 feet true vertical 9142 feet Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 91.5# H-40 27' - 107' 27' - 107' 1490 470 Surface 2581' 13-3/8" 72# L-80 26' - 2607' 26' - 2607' 5380 2670 Production 10239' 9-5/8" 47# L-80 25' - 10264' 25' - 8587' 6870 4760 Liner 377' 7" 29# L-80 9921' - 10298' 8295' - 8602' 8160 7020 Liner 754' 4-1/2" 12.6# L-80 10211' - 10965' 8532' - 9227' 8440 7500 Perforation depth: Measured depth: SEE ATTACHMENT True Vertical depth: Tubing: (size, grade, and measured depth) 5-1/2" 17# 13CR80 Surface - 9921' 4-1/2" 12.6# L-80 9921' - 9974' Packers and SSSV (type and measured depth) 9-5/8"X5-1/2" BAKER S-3 9916' 7"X5" XZP LNR TOP PKR 10197' 0 0 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 1685 84462 1721 0 697 Subsequent to operation: SI 0 0 0 0 14. Attachments: 15. Well Class after proposed work' Copies of Logs and Surveys Run Exploratory ~ Development Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil Gas WAG ~' GINJ ~' WINJ ' WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: 307-101 Contact Gary Preble Printed Name Gary Preb Title Data Management Engineer Signature Phone 564-4944 Date 6/10/2008 Form 10-404 Revised 04/20 - `~~~- ~ ~ 2D0S Submit Ori al Only 01-26A 199-0120 PERF ATTACHMENT Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base 4/12/99 __ PER ~ 10,769. 10,783. 9,033.51 9,047.31 4/12/99 PER 10,793. 10,803. 9,057.17 9,067.03 4/12/99 PER 10,824. 10,830. _ 9,087.74 9,093.66 12/3/00 APF 10,750. 10,756. 9,014.77 9,020.68 11/24/05 BPS 10,720. 10,814. 8,985.2 9,077.88 11/24/05 BPS 10,814. 10,830. 9,077.88 __ 9,093.66 6/5/08 BPP 10,750. 10,793. 9,014.77 9,057.17 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER ___ BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG S ET FIL FILL SOF _ SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SOZ __ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ___ • . ~ • 01-26A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY CCTIVITYDATE SUMMARY 6/2/2008 "x'`WELL FLOWING ON ARRIVAL""" (pre cibp mill /scab liner) ', RAN 3.70" CENT, TEL, 3.25" LIB, LOC EOT @ 9955' SLM + 11' cor. = 9966' ELMD 'TAGED CIBP @ 10715' SLM + 11' cor. = 10726' ELMD (IMPRESSION OF corn '***WELL SHUT IN ON DEPARTURE"** 6/3/2008'CTU #9 w/ 1.75" OD CT. Mill CIBP. MIRU CTU #9. MU and RIH w/2-7/8" 'Baker Extreme PDM with 3.70" OD 5-bladed flat-bottomed junk mill. Tag CIBP 10749'. Mill w/ 5 stalls. Then no motor work/stacking weight. POOH. 'Inspect BHA. Continued on 06/04/08 WSR. 6/4/2008 Continued from 06/03/08 WSR. Broadcasting=yes. Inspect BHA at surface. . No apparent problems. MU/RIH w/ 3 1/8" venturi. Tag CIBP @ 10725' up. :Venturi at tag. POOH. Venturi empty. RIH with mill and stabilizer. Mill CIBP and 'push to bottom 10803' ctm. POOH. MU/RIH w/ 3 1/8" venturi. Continued on 6/5/2008',Continued from 06/04/08 WSR. Publishing =yes. RIH w/ 3 1/8" venturi. ',Venturi from 10700' to tag @ 10800'. POOH. Gravel-metal pieces- in junk ';basket. Run PDS memory GR/CCL for depth reference. Gamma ray failed, good ';collar log. Tied into Schlumberger CBL dated 4-3-99. Corrected TD @ 10793' md. Freeze protect wellbore to 2000' with 50/50 meth. RD °*~~*JOB COMPLETE'`***" FLUIDS PUMPED BBLS 30 METHM/ATER 61 XS 1 % KCL 91 Total • °~~~ - - - - ~,_ ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska], Inc. Petrotechnical Data Center Attn: Joe Lastufka I.R2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ~~ANNE~ JUN ~ ~ 2008 ProActive Diagnostic Services, Inc. Attn: Robert A. Richey ~/ ~Ll~ ~ 130 West International Airport Road (~~ -pl a Suite C Anchorage, AK 99518 Fax: (907j 2458952 1) Coil Flag 2) Siyne~ Print Name: 06,Jun-08 DS 01,26A V / ~7~~ I c~ / U (~,~it~v~f.~~~ EDE 50-029-20885-01 Date `~~ PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)245$8952 E-MAIL ~5 ~ _ ~~ ~~ ~ t7, ~+_ ~~~ ~ WEBSITE : An, - 9~~ ~, C:\Docivnents and Battings\Owner\Desktop\Transmit_BP.doc . . SARAH PALIN, GOVERNOR A1tASIiA OIL AND GAS CONSERVATION COMMISSION 333 W 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ana Seltenright P.E. BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 01-26A Sundry Number: 307-101 t:~~NED MAR 2 ß 2007 \o..q-O {V Dear Ms. Seltenright: 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. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). 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. DATED this t1'day of March, 2007 Encl. 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 O¡-'S 3/2..7/7 G¡:t 3/v1/o1 ~ R· 'e.. CEIVED A~~!~~~~~~~~~~~~~~~ ~~~~t£~;¡<, MAR 2 0 Z007 20 AAC 25.280 Operational shutdown Plug Perforations 0 Perforate New Pool 0 4. Current Well Class: Development ø Suspend Repair well 0 Pull Tubing ::J 5. Permit to Drill Number: .' 1. Type of Request: Abandon Alter casing 0 Change approved program 0 2. Operator Name: Exploratory 0 199-0120 r Anchorage, AK 99519-6612 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line where ownership or landownership changes: Spacing Exception Required? Yes 0 9. Property Designation: Stratigraphic 0 Service 0 6. API Number: 50-029-20885-01-00 / 8. Well Name and Number: PBU 01-26A / ADLO-028329 / No 0 10. KB Elevation (ft): 11. Field/Pools(s): { / 67.95 KB PRUDHOE BAY Field / PRUDHOE OIL Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 10970 I 9231.67 , 10879' 9142' 10720' 10814' None Casing Length Size MD TVD Burst Collapse Conductor 80' 20" 91.5# H-40 27' 107' 27' 107' 1490 470 Surface 2581' 13-3/8" 72# L-80 26' 2607' 26' 2607' 5380 2670 Production 10239' 9-5/8" 47# L-80 25' 10264' 25' 8575' 6870 4760 Liner 377' 7" 29# L-80 9921' 10298' 8295' 8602' 8160 7020 Liner 754' 4-1/2" 12.6# L-80 10211' 10965' 8532' 9227' 8440 7500 Perforation Depth MD (ft): 10750' - 10830' Perforation Depth TVD (ft): 9015' - 9094' Tubing Size: 5-1/2" 17# 4-1/2" 12.6# Tubing Grade: 13CR80 L-BO Tubing MD (ft): 24' - 9921' 9921' - 9974' Packers and SSSV Type: 5-1/2" Baker S-3 Packer 5" ZXP Liner Top Packer Packers and SSSV MD (ft): 9916' 10197' o 0 o 0 13. Well Class after proposed work: Exploratory 0 Development ø Service 0 12. Attachments: Descriptive Summary of Prcposal ø Detailed Operations Program 0 BOP Sketch 0 14. Estimated Date for Date: 15. Well Status after proposed work: Oil ø Gas 0 Plugged 0 Abandoned 0 WAG 0 GINJ 0 WINJ 0 WDSPL 0 Prepared by \.:>étry ..-'I:Oule 564-4944 Commencing Operations: 16. Verbal Approval: Commission Representative: 3/30/2007 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Ana Maria Seltenright Printed Name Maria Seltenright Title P.E. Signature Phone 564-4418 Date 3/16/2007 / COMMISSION USE ONLY Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ~ Plug Integrity 0 BOP Test ~ Mechanical Integrity Test 0 Location Clearance 0 Other: ')'500 \,Y5.'\ M." :\' 'ºo 1-> \ " " '" ~ U ""'..~ ' _ -S ""\ RBDMS 8Ft MAR .2 8 2007 Subsequent Form Required: L\ () Approved by: APPROVED BY THE COMMISSION Date: Form 10-403 Revised 06/Ð RIG I N A L Submit in Duplicate If . . . bp .,. ,\'f.'lI. _...~ ~..- ~--~ ---:......~ ...~ ~...... "I~'·~'\'" ". Memorandum To: C. Olsen/J. Bixby G PB Well Ops Team Leaders Date: March 16, 2007 AFE: PBD01WL26-N NRWO_Scab Liner From: Jennifer Julian - Wells Engineer Ana Seltenright - Production Engineer Jim Fagnant - North Slope 01-26A Scab Liner Est. lOR Est. Cost: 400 $350,000 Subject: ~ob Seo e Perform MIT-IA to 3000 Mill CISP MIRU 1.75" CTU · MU a stabilized motor and milling BHA assembly (3.70"-3.75" mill) with up-jars- · The 4-1/2" liner is in very poor condition with multiple holes. A stabilized BHA may prevent milling out of the liner and target the CIBP. · RIH and mill CIBP set at 10,720' · Push milled CIBP down as far as possible to the lower CIBP which is set at 10,814' · Make venturi run s as necessa to clean u left debris Run Scabl"'iner Run scab liner from deployment sleeve -9,946' to -10,780' (assuming CIBP at -10,785') RU cementers and pump 11 bbls of class G latex cement POOH while um in at a maximum rate Drift and Ta RU slickline and install eneric GL desi n Get a corrected ta of TOC Drift to TOC with 2.5" dumm Pet"'forate RU E-line and perforate interval 1 0,770 - 1 0,780' md (2.5" power jet omega - HMX). Please tie in with GR and use "01-26A 2006-05 Reperf.pdf" for reference. from TO to no hi her than 1 0,763' md. Baekqround Information and Historv An STP from Nov-02 indicated that 98% of production is coming from Zn 2C perfs - only 6' open. Well makes 70+ mmscfpd. Oil rate is declining and GOR is skyrocketing. A CIBP was set at 10,720' md to shut off all the perfs. After setting the CIBP the tubing pressure would not bleed down. A Caliper was run on 12/03/05 and indicated that the interval of 7" logged is in poor condition and the 4 W' liner is in very poor condition with multiple holes confirmed by a PPROF - LDL (1/13/06) with indications of leaks at 10,456',10,500',10,538',10,550' 10,574', 10,592', 10,614', and 10,628'. It is necessary to mill the CIBP at 10,720' and worked downhole to the top of the second CIBP which is set at 10,814'. A scab liner will then be run and cemented to cover the existing perfs and deteriorated liners. New perforations will be shot in the liner. Hopefully this will shut off the gas and make it a more competitive well. The scab liner will be an attached procedure. For questions or comments please call Ana Seltenright x 4418, 349-1969 (home) or Jennifer Julian x 5663, 274-0929 (home), 240-8037 (cell). 3/16/2007 1 FW: 0 1-26A (199-012) . . Gary Preble Petroleum Data Management Engineer SAIC 907-564-4944 E:r::""_Þ~_~9Þ,~?ÞP,,:,,c:;?S -----Original Message----- From: Seltenright, Ana Maria Sent: Monday, March 26, 2007 9:38 AM To: Preble, Gary B (SAIC) Subject: RE: 01-26A (199-012) Gary, Here the 01-26 details: Proposed scab liner 3-1/2" and cement 11 bbls Also, please find attached current well bore schematics. Thanks, Ana Maria Seltenright Production Engineer Prudhoe Bay - Gravity Drainage BP Exploration Alaska Inc. (907) 564-4418 -----Original Message----- From: Preble, Gary B (SAIC) Sent: Monday, March 26, 2007 8:17 AM To: Seltenright, Ana Maria Subject: FW: 01-26A (199-012) Ana, Please let me know what size of the proposed scab liner and the cement volume will be on this job. I will forward it on to the AOGCC (Tom Maunder) Gary Preble Petroleum Data Management Engineer SAIC 907-564-4944 preblegb@bp.com engineer on this well. o lof2 3/26/2007 10:02 AM 01-26A (199-012) . . Gary, I do not have the eddress of the engineer on this well. I need a couple of items 01-26A 1. What is the size of the proposed scab liner and the cement volume? 2. Please provide a current wellbore drawing. Thanks in advance. Tom Maunder, PE AOGCC 1 of 1 3/23/20074: 15 PM TREE = FMC 1'v1ODEL 75 WELLHEAD = FMC _ __.'."____._ . . .'_mm"___··~.n··___ ACTUA TOR = AXELSON ... ..,." nmmmm.··..__ ~1<3xi\~ÇJle= Datum MD = Datum rvD = ~~(Çg7900' 10600' 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" H 2607' Minimum ID = 3.813" @ 9952' 4-1/2" X NIPPLE TOPOF7" LNR H 15-1/2" TBG, 17#, 13-CR .0232 bpf, ID = 4.892" H 9921' 9921' 4-1/2" TBG, 13-CT, L-80, .0149 bpf, ID = 3.920" -1 9974' 7" LNR, 29#, L-80, ,0371 bpf, ID = 6.184" H 9-5/B" CSG, 47#, L-BO, ID = B.681" I 1 TOP OF WHIPSTOCK 1 14-1/2" TBG, 13-CT, L-80, .0149 bpf, ID = 3.920" H I EZSvl 10197' I 10264' 10330' 9974' 10330' ÆRFORA TION SUMMARY REF LOG: SHCS ON 03/14/99 ANGLE AT TOP ÆRF: 10 @ 10750' Note: Refer to Production DB for historical perf data SIZE SPF INTERV AL Opn/Sqz DA TE 2-7/8" 4 10750 - 10756 C 12/03/00 2-7/8" 4 10769 - 10783 C 04/12/99 2-7IB" 4 10793 - 10803 C 04112/99 2-7/8" 4 10824 - 10830 C 04/21/99 17" LNR, 29#, L-80, .0371 bpf, ID=6.1B4" I DATE 04121/83 03/21/99 05106/01 11112/02 08117103 11119105 REV BY COMMENTS ORIGINAL COM PLETION RWO RN/KAK CORRECTIONS fTLH DELETE WAIVER SAFETY NOTE CMOfTLP DATUM MD CORRECTION KSBIPJC GL V C/O 11075' 01-26A NOTES: 5-1/2" CHROMETBG 2182' -i 5-1/2" HES X NIP, ID = 4.562" I GAS LIFT MANDRELS ST MD rvD DEV TYPE VLV LATCH PORT DATE 1 3745 3727 19 LB Drv1Y T-2 0 11119105 2 6396 5735 43 LB DMY T-2 0 11/19/05 3 8296 6992 49 LB DMY T-2 0 11119/05 4 9072 75B6 34 LB DMY T-2 0 03/20199 5 9558 7991 32 LB DMY T-2 0 11/19/05 9916' 9-518" X 5-1/2" BAKER S-3 PKR, ID = 4.75" 5-112" X 4-1/2" XO I 9921' 9952' 4-112" HES X NIP, ID = 3.813" I 9974' 9966' 4-1/2" TUBING TAIL I ELMD TT LOG NOT A V AILABLE I -1 7" X 5" XZP LNR TOP PKR, ID = 4.375" -1 5 X 4-1/2" XO, ID = 3.937" I MILLOUT WINDOW 1029B' - 10310' 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID= 3.953" -1 10965' I DA TE REV BY COMMENTS 12/02/05 RIJI/LfTLH IBP SET (11124/05) 05/30/06 DTM WELLHEAD CORRECTION PRUDHOE BAY UNIT WELL: 01-26A PERMIT No: "1990120 API No: 50-029-20885-01 SEC 8, T10N, R15E, 214.56' FEL & 2200.28' FNL BP Exploration (Alaska) Sc~luInbel'ger NO. 4058 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ¡qq-Óld Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 ~ /¿/¡)C,C, Field: Prudhoe Bay Well Job# Loa Description Date BL Color CD H-34 11477963 LDURST 11/07/06 1 Y-01B 11485468 MPPROF W/DEFT & GHOST 11/07/06 1 2-08/K-16 11487771 LDL 11/12/06 1 X-03A 11485772 MPPROF W/DEFT & GHOST 11/09/06 1 DS 09-51 11477933 INJECTION PROFILE 11/06/06 1 15-45A 11485469 MPPROF & INJECTION PROF 11/09/06 1 N-OT A 11296715 PROD PROFILE W/GHOST 09/10/06 1 DS 09-31C 11483691 INJECTION PROFILE 11/20/06 1 G-06A 11422979 SCMT 11/01/06 1 P2-59A 11414775 SCMT 11/05/06 1 NGI-06 11414773 USIT 11/01/06 1 A-43 11414774 US IT 11/03/06 1 01-26A 11001225 RST-SIGMA OS/24/05 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consulting Services "" G.m"'" 81"', ',ile t A~h"",., AK ""1 ATTN: Beth Q Received by: I / '----- Date Delivered: NO\! 2, 9 7nmì I~ 11/28/06 . . Schlumbergel' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth Well YDS 01-26A ~ ~9-ðl.?- V11-12 1<24 - Iq!J Job# 11087213 11087220 BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: D~J ~9' ¡Of.¡; "-- /~~.;f2;"",o·;t' J, :'=. ~ t-...... 4 'f '=~ T- . ~. ,- ~ FEB 222006 .........-- ..... - ~ VVJltiUi~JUI. Log Description LEAK DETECTION LOG RST -SIGMA ";--. /?'<L h ~' ~ § -- r~ ðLð4.n~B~t;~ FEE ~ þ'¡ 2"ùO' ~ ,;¿ w t..; Date 01/13/06 01/19/06 01/26/06 NO. 3671 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Helen Warman 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay, Milne Pt. BL 1 1 Color CD .-- ~ Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth ~J J Received by: (J ~ -(1 ) _ STATE OF ALASKA _ ALA~ OIL AND GAS CONSERVATION COM~ION REPORT OF SUNDRY WELL OPERATIONS ,~ 1. Operations Abandon D Repair Well D Performed: Alter Casing D Pull Tubing D Change Approved Program D Operat. Shutdown D 2. Operator BP Exploration (Alaska), Inc. Name: P.O. Box 196612 Anchorage, AK 99519-6612 7. KB Elevation (ft): 3. Address: 67.95 KB 8. Property Designation: ADL-028329 11. Present Well Condition Summary: Total Depth measured 10970 true vertical 9231.67 Effective Depth measured 10879 true vertical 9141.97 Casing Conductor Surface Production Liner Liner Length 80 2581 10239 377 754 Size 20" 91.5# H-40 13-3/8" 72# L-80 9-5/8" 47# L-80 7" 29# L-80 4-1/2" 12.6# L-80 Perforation depth: Measured depth: 10750 - 10756 True Vertical depth: 9014.77 - 9020.68 Tubing: (size, grade, and measured depth) Packers and SSSV (type and measured depth) 12. Stimulation or cement squeeze summary: Intervals treated (measured): Plug Perforations [2] Perforate New Pool D Perforate D 4. Current Well Class: Development Ri Stratigraphic 0 feet feet feet feet MD 27 - 107 26 - 2607 25 - 10264 9921 - 10298 10211 - 10965 10769 - 10783 9033.51 - 9047.31 5-1/2" 17# 4-1/2" 13-CT 5-1/2" Baker S-3 Packer 5" ZXP Liner Top Pkr Treatment descriptions including volumes used and final pressure:~j<CA,b~~i'~~L) 13. Prior to well operation: Subsequent to operation: 14. Attachments: Copies of Logs and Surveys Run Daily Report of Well Operations Oil-Bbl 1162 1082 x Representative Daily Average Production or Injection Data Gas-Mcf Water-Bbl Casing Pressure 60286 1895 0 54379 1806 0 15. Well Class after proposed work: Exploratory Development I;?' 16. Well Status after proposed work: Oil .Ri Gas 0 WAG 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Sharmaine Vestal P'oted N'me Sh'''''~oe ves"'. -k Signat~ Co" REC·EIVE DE 2005 Stimulate D Other D WaiverD TimeAhisk~c0i[& Gas Cons. Lumrn¡;·:sì " Re-enter Suspended Well D n hora a 5. Permit to Drill Number: Exploratory 0 199-0120 Service 0 6. API Number: 50-029-20885-01-00 9. Well Name and Number: 01-26A 10. Field/Pool(s): PRUDHOE BAY Field/ PRUDHOE OIL Pool Plugs (measured) Junk (measured) 10720, 10814 None TVD 27 - 107 26 - 2606.95 25 - 8574.77 8295.37 - 8601.71 8532.39 - 9226.75 Burst 1490 5380 6870 8160 8440 Collapse 470 2670 4760 7020 7500 10793 - 10803 10824 - 10830 9087.74 - 9093.66 9057.17 - 9067.03 13CR80 L-80 24 - 9921 9921 - 9974 9916 10197 ?~ RBDMS 8Ft OEC2 2 2005 Tubing pressure 1816 1862 Service WDSPL Title Data Mgmt Engr Phone 564-4424 Form 10-404 Revised 04/2004 Date 12/20/2005 Submit Original Only · If e e 01-26A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACTIVITYDATE SUMMARY 11/24/2005 CORRELATED TO SWS BHC SONIC DATED 14-MAR-1999 (SET CIBP/PERF) SET CIBP AT 10,720' FT **NOTIFY DSO OF WELL STATUS-WILL BE BACK IN AM TO CONT.** 11/25/2005 T/I/0=2370/660/540. SI. Bleed TBG to CLP (post-CIBP set). TBG FL @ 9908'. !,!\ FL @ 9405'. OA FL @ 102. Bled TBG down flowline for 45 minutes. TOG pressure never dropped below 1800 psi with a 50 degree choke. Shut in well and TBG pressure increased to 2300 psi in 5 minutes. Monitored 30 minutes. TBG pressure remained at 2300 psi. Final WHPs=2300/660/540. FLUIDS PUMPED BBLS 1 I Diesel TOTAL 1 199-012-0 PRUDHOE BAY UNIT 01-26A 50- 029-20885-01 BP EXPLORATION ,/~0 (ALASKA) tnt Roll #1: Start: Stop Roll #2: Start p MD 10970 ~' TVD 09230 ,Completion Date: /~4¢~9 Completed Status: 1-OIL Current: T Name Interval c 9166 {,,/" 1 SCHLUM PEX-HALS/BHC C 9167 ~ I SCHLUM GR/TAB-IMP L BHCS ~'"'" FINAL 10318-10920 L CN t" FINAL 9840-10936 _ L HALS ' FINAL 10322-10962 L IMP-GR-MD ~ FINAL 10295-10922 L IMP-GR-TVD -/'"-' FINAL 10295-10922 L MCFL~/''''~ FINAL 10318-10954 L PROD-DEFTJ FINAL 9500-10824 L SCMT e.--"" FINAL BL(C) 9900-10805 4/3/99 L SSTVDJ FINAL 9900-10954 L TLD DENS/CN ~""/' FINAL 10290-10950 L VPWD/ FINAL 10295-10922 R SRVY RPT / SCHLUM 10293.70-10970. Sent Received T/C/D · . . OH OH OH OH OH OH OH OH CH 5 CH 5 OH OH OH 2 OH 5/6/99 5/13/99 5/5/99 5/13/99 5/6/99 5/13/99 5/6/99 5/13/99 5/6/99 5/13/99 5/5/99 5/13/99 5/5/99 5/13/99 5/6/99 5/13/99 4/7/00 4/10/00 6/9/99 6/16/99 5/6/99 5/13/99 5/6/99 5/13/99 5/5/99 5/13/99 3/29/99 4/2/99 Wednesday, March 28, 2001 Page 1 of 1 ~ ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging _ Pedorate _X Pull tubing _ Alter casing _ Repair well_ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development~X RKB 74 feet 3. Address Exploratow__ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 988' FNL, 4662' FEL, Sec. 8, T10N, R15E, UM (asp's 697955, 5939913) 01-26A At top of productive interval 9. Permit number / approval number 2243' FNL, 232' FEL, Sec. 08, T1 ON, R15E, UM (asp's 702422, 5938778) 199-012 At effective depth 10. APl number 50-029-20885-01 At total depth 11. Field / Pool 2200' FNL, 215' FEL, Sec. 8, T10N, R15E, UM (asp's 702437, 5938818) Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 10970 feet Plugs (measured) true vertical 9232 feet CIBP @ 10814' MD (4/21/2000) Effective depth: measured 10804 feet Junk (measured) true vertical 9068 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 79' 20" 191 o# Poleset 79' 79' Surface 2533' 13-3/8" 1800 Sx CS ~H & 4oo Sx cs ~l 2610' 2610' Production 10190' 9-5/8" 500 Sx G & 50 bbls CS I 1 0264' 8575' Liner 272' 7" 370 Sx Class G 10298' 8602' Liner 660' 4-1/2" 97 sx C~ass G 1 0965' 9227' Perforation depth: measured 10750' - 10756'; 10769' - 10783'; 10793' - 10803' (Isolated below CIBP are 10824' - 10830'). ._~ true vertical 9015' - 9068'; 9032' - 9046'; 9056' - 9066'; (Isolated below CIBP are 9086' - 9092'). Ell Tubing (size, grade, and measured depth) 5-1/2", 17#, 13CR Tbg @ 9740' MD. '"'"' Packers & SSSV (type & measured depth) 7" X 5" XZP LINER TOP PACKER @ 10198' MD; 9-5/8" X 5-1/2" BAKER S-3 PACKER @ 9917' MD. ~ 4-1/2" HES X @ 2183' MD. ~ 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Iniection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 718 1387 538 210 Subsequent to operation 5736 8195 2066 276 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ~ ~~~-,/~ Title: DS 1 Surveillance Engineer Date Deid re Taylor Prepared by Paul Rauf 564-5799 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 01-26A DESCRIPTION OF WORK COMPLETED PERFORATING OPERATIONS Date Event Summary 11/29/2000: 12/03/2000: RIH & tagged PBTD @ 10804' MD. MIRU ELU. PT'd equip. RIH w/perforating guns & shot 6' of add perforations located @: 10750' - 10756" MD (Zone 2C) Ref Log: BHCS 3/14/1999 Used 2-7/8" carriers & all shots @ 4 SPF, random orientation, & underbalanced press. POOH w/perf guns - all shots fired. RD ELU. Returned well to production & obtained a valid well test. - ' STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate_ Pull tubing _ Alter casing_ Repair well_ Olher_X(set ClBP for WSO) 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 68 feet 3. Address Explorato~ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 servia__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 988' FNL, 4662' FEL, Sec. 8, T10N, R15E, UM 01-26A At top of productive interval 9. Permit number / approval number 2243' FNL, 5047' FWL, Sec. 08, T10N, R15E, UM 99-12 At effective depth 10. APl humber 50-029-20885-01 At total depth 11. Field / Pool 2200' FNL, 215' FEL, Sec. 8, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summar Total depth: measured 10970 feet Plugs (measured) CIBP @ 10814' MD (4/21/2000) true vertical 9232 feet Effective depth: measured 10814 feet Junk (measured) true vertical 9078 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 79' 20" 191o# Poleset 79' 79' Surface 2533' 13-3/8" 18oo Sx cs m &4oo Sx cs U 2610' 2610' Production 10190' 9-5/8" 500 sx G & 50 bbls CS I 10264' 8575' Liner 272' 7" 370 Sx Class G 10298' 8602' Liner 660' 4-1/2" 97 sx C~ass G 10965' 9227' Perforation depth: measured (10769' - 10783' & 10793' - 10803"a~lisolated below ClBP); 10824' - 10830'. ~*% ~ ..... ~--~ ~-~: ~ ~ -?? ?-% true vertical (9032' - 9046' & 9056' - 9066'-~.~u,solated--'A[ below CIBP)' 0086'-'9~92'.- E~_ ' ---- 05 200( ' Tubing (size, grade, and measured depth)5-1/2", 17#, 13CR Tbg @ 9740' MD. ORIGINAL ~ i~;~ C;4! e~ ~$ Packers & SSSV (type & measured depth) 7" X 5" XZP LINER TOP PACKER @ 10198' MD; 9-5/8" X 5-1/2" BAKER S-3 PAOKER @ 9917' MD. 4-1/2" HES X @ 2183' MD. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 652 1541 4056 - 208 Subsequent to operation 1646 1736 181 - 205 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations ___X Oil __X Gas __ Suspended ~ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed ba'~. ~,.~,_ "~ ~ Title Arco Engineering Supervisor Date Erin 0 ~ Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 01-26A DESCRIPTION OF WORK COMPLETED CAST IRON BRIDGE PLUG INSTALLATION FOR WSO Date Event Summary 3/28/2000: 4/16/2000: 4/21/2000: Ran PPROF w/DEFT. PF splits 6% / 6%/ 88%. RIH & tagged PBTD @ 10842' MD. MIRU ELU. PT to 3000 psi. RIH & set CIBP for WSO @ 10814' MD to isolate the following perf interval: 10824' - 10830" MD (Zone 2B) Ref Log: BHCS 3/14/1999 Saw positive indication of set. RD. Returned well to production & obtained a valid well test. Schlumberger NO. 121354 4/7/00 Schlumberger Technology Corporation, by and through is Geoquest Division 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A'I-I'N: Sherrie Company: Alaska Oil & Gas Cons Comm Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Cased Hole) Well Job # Log Description Date BL Sepia CD D.S. 1-26A PRODUCTION PROFILE W/DEFT 000326 I 1 D.S. 4-24 ~ c~r 20045 RST 000109 I I 1 D.S. 4-26 ~--~H ~(~ 20044 CNTG 000108 I I 1 F-,~ ....... I;)F('FiVF ) ,:,,,.,-,=.. ooo Alaska 0il & Gas t~. Please sign and return one copy of this transmittal to Sherrie at the above address or fax to (907) 561-8317. Tha~g6 ....... STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate,~ Plugging _ Perforate_ Pull tubing _ Alter casing _ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) ARCO Alaska, Inc. Development__X RKB 68 feet 3. Address Explorato~___ 7. Unit or Property name P. O. Box 100360 Stratigraphic__ Anchorage, AK 99510-0360 Service__ Prudhoe Bay Unit 4. Location of well at surface 8. Well number 988' FNL, 4662' FEL, Sec. 8, T10N, R15E, UM 01-26A At top of productive interval 9. Permit number / approval number 2243' FNL, 5047' FWL, Sec. 08, T10N, R15E, UM 99-12 At effective depth 10. APl number 50-029-20885-01 At total depth 11. Field / Pool 2200' FNL, 215' FEL, Sec. 8, T10N, R15E, UM Prudhoe Bay Oil Pool 12. Present well condition summer Total depth: measured 10970 feet Plugs (measured) Tagged PBTD @ 10822' MD (8/09/1999) true vertical 9232 feet Effective depth: measured 10822 feet Junk (measured) true vertical 9086 feet Casing Length Size Cemented Measured Depth True vertical Depth Conductor 79' 20" 191 o# Poleset 79' 79' Surface 2533' 13-3/8" 18oo sx cs m &4co sx cs ~ 2610' 2610' Production 10190' 9-5/8" 500 Sx G & 50 bbls CS I 10264' 8575' Liner 272' 7" 370 SX Class G 10298' 8602' Liner 660' 4-1/2" 97 sx C~ass G 10965' 9227' Perforation depth: measured 10769'- 10783'; 10793'- 10803'; 10824'- 10830'. '~ .' ..... ' · :: ' ~: true vertical 9032'- 9046'; 9056'- 9066'; 9086'- 9092'. ~ ~'' ' ;'i' i.~' :~:;~ Tubing (size, grade, and measured depth) 5-1/2", 17#, 13CR Tbg @ 9740' MD. .~;';'?~¥::¥'i: =ackers & SSSV (type & measured depth) 7" X 5" XZP LINER TOP PACKER @ 10198' MD; 9-5/8" X 5-1/2" BAKER S-3 PACKER @ 9917' MD. 4-1/2" HES X @ 2183' MD. 13. Stimulation or cement squeeze summary 0RIGJNAL Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Average Production or Injection Data OiI-Bbl Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure Prior to well operation 1310 1207 8 206 Subsequent to operation 1576 903 167 193 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run _ Daily Report of Well Operations ._X Oil __X Gas __ Suspended __ Service 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed _~./.~r,,/!.,t...~~ ,~,,/p\..~,?-~.,;~.,,../~ Title Arco Engineering Supervisor Erin Oba Prepared by Paul Rauf 263-4990 Form 10-404 Rev 06/15/88 · SUBMIT IN DUPLICATE 01-26A DESCRIPTION OF WORK COMPLETED ACID STIMULATION W/DIVERTER Date Event Summary 6/12/1999: 8/09/1999: 8/21/1999: Placed 35 bbls 50/50 Diesel/Xylene and 25 bbls of 1% KCL Water w/10% Mutual Solvent & 4 GPT Surfactant through perfs. Injectivity decreased while Crude was going through perfs and saw no breakback w/Water w/Mutual Solvent at perfs. RIH & tagged PBTD @ 10822' MD. Performed a Fullbore Acid Stimulation Treatment w/diverter as follows: MIRU & PT'd equipment. Pumped stimulation fluid sequence fullbore to treat the open perforation interval located @: 10769'- 10783" MD (Zone 2B) Ref Log: BHCS 3/14/1999 10793' - 10803" MD (Zone 2B; 10824' - 10830" MD (Zone 2B', Pumped: (a) 25 bbls of 1% KCL Water w/Citric Acid @ 5 bpm, followed by (b) 48 bbls of 50% Diesel, 50% Xylene @ 5.29 bpm, followed by (c) 50 bbls of 1% KCL Water @ 5.3 bpm, followed by (d) 50 bbls of 12% HCL - 3% Acetic Acid @ 5.1 bpm, followed by (e) 11 bbls of OSR Diverter (J237A 10 gal/Mgal & F40 2 gal/Mgal in 1% KCL Water) @ 3.1 bpm, followed by (f) 48 bbls of 12% HCL - 3% Acetic Acid @ 4.02 bpm, followed by (g) 50 bbls of 1% KCL Water @ 5.2 bpm, followed by (h)50 bbls of Crude @ 5.02 bpm, followed by (i) 275 bbls of 1% KCL Water @ 5.0 - 4.1 bpm, followed by (k) shutdown RD. Returned well to production & obtained a valid well test. 6/9/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 Al'tN: Sherrie NO. 12637 Compan~ Alaska Oil & Gas Cons Corem Attn: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job # Log Description Date Print DiS. 1-26A 99238 CBL/SCMT 990403 1 D.S. 12-28A 99238 CBL W/PSP/SCMT 990522 1 D.S. Z4-0S~ 99238 SCM'~ 950221.8 1 ~.~'~i~ !~iZ ?' 'z.Z/~'!... , ,.'. SIGN .z,_ DATE: Please sign and return one copy of this transmiflal to Sherrie at the above address or fax to (907) 562-652]. 5/6/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrle NO. 12554 Compan~ Alaska Oil & Gas Cons Comm Attn: Lorl Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole) Well Job # Log Description Date BL Sepia CD-R D.S. 1-26A 99173 HALS/PEX/BHC ~t(~(e 990314 1 D.S. 1-26A 99173 HALS 990314 1 1 D.S. 1-26A 99173 MCFL 990314 1 1 D.S. 1-26A 99173 CNL 990314 1 D.S. 1-26A 99173 TDL DENSITY CNL 990314 1 1 D.S. 1-26A 99173 BHC L 990314 1 1 D.S. 1-26A 99173 SSTVD i 990314 1 1 . I Please sign and return one copy of this transmittal 1o Sherrie at the above address. Thank~y~('~l.01'agL~ ~,,laska Oil & Gas Cons. Comr~lissio~'~ 5/5/99 GeoQuest 3940 Arctic Blvd Anchorage, AK 99503 ATTN: Sherrie NO. 12543 Compan~ Alaska Oil & Gas Cons Comm Afln: Lori Taylor 3001 Porcupine Drive Anchorage, AK 99501 Field: Prudhoe Bay (Open Hole] Well Job # Log Description Date BL Sepia CD-R 01-26A 99174 GR/ROP5/I'AB ,l~r,,~l~ll~ 39031? 1 D.S. 01-26A 99174 IMPULSE/~R 990317 1 1 D.S. 01-26A 99174 I~PULSE/~R TVD 990317 1 1 D.S. 01-26A 99174 VPWD 990317 1 1 SIG DATE: :'b,Y 1 5 1¢99 Please sign and return one copy of this transmi~al to Shorrio et tho ~bo¥o address, lh~n~F~]~ 0it&Ga~n~. "' '" '" ALASKA 0IL AND GAS CONSERVATION CoM~MlsslON WELL COMPLETION OR RECOMPLETION REPORT AN .LOG 1. Status of Well Classification of S~'r~m~/ell "C,- ,70., [] Oil [] Gas [] Suspended [] Abandoned [] Service 2. Name of Operator 7. Permit Number ARCO Alaska Inc. 99-12 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-20885-01 4. Location of well at surface ................. '~ :',n:,~,,; ~.- 0;,! '. 9. Unit or Lease Name ~:~;.~,.~:~ Prudhoe Bay Unit 990' SNL, 616' EWL, SEC. 08, T10N, R15E, UM i ~}.~.'~?! ! ............ At top of productive interva, !~/.~.~/¢~._ ~~li 10. WellNumber 2243' SNL, 5047' EWL, SEC. 08, T10N, R15E, UMi ~:~', .... ~:,: ~ ~'! 01-26A At total depth !i: ~_'~:.: ~ ..... ~~! 11'.FieldanOPoo, 2204' SNL, 5071' EWL, SEC. 08, T10N, R15E, UM~-" ................ Prudhoe Bay Field / Prudhoe Bay 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Pool KBE = 67.95'I ADL 028329 3/16/99 3/17~99 4112~99 N/A MSLI One 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD)I19. Directional Survey 120. Depth where SSSV set 121. Thickness of Permafrost 10970 9230 FT 10879 9141 FTI [~Yes [~NoI (Nipple) 2182' MD] 1900' (Approx.) 22. Type Electric or Other Logs Run MWD, GR, RES, RES/AlT, DT/BHC, CNL, LDL, GR, Caliper, SP, MRES 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH I HOLE SIZE WT. PER FT. GRADE TOP BOTTOMI SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.5# H-40 Surface 79' 30" Instld w/1910# Poleset 13-3/8" 72# L-80 Surface 2610' 17-1/2" 1800 sx CS III, 400 sx CS II 9-5/8" 47# L-80 Surface 10264' 12-1/4" 500 sx Class 'G', 50 Bbls CS I 7" 29# L-80 9921' 10298' 8-1/2" 370 sx Class 'G' 4-1/2" 12.6# L-80 10211' 10965' 6" 97 sx Class 'G' 24. Perforations open to Production (MD+TVD of Top and 25. TUBING RECORD Bottom and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 4 spf 5-1/2", 17#, 13Cr 9923' 9916' MD TVD MD TVD 4-1/2" tailpipe 9923' - 9974' 10769' o 10783' 9032' - 9046' 10793' o 10803' 9056' - 9066' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 10824' o 10830' 9086' ° 9092' DEPTH INTERVAL (MD) AMOUNT & KiND OF MATERIAL USED Freeze Protect with 150 Bbls of Diesel 27. PRODUCTION TEST Date First Production I Method of Operation (Flowing, gas lift, etc.) April 13, 1999I Gas Lift Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I Flow Tubing Casing Pressure CALCULATED OIL-BBL GAS-MCF WATER-BBL O~L GRAVITY-APl (CORR) Press. 24-HOUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. ORIGINAL Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. Geologic Markers 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids Marker Name Depth Depth recovered and gravity, GOR, and time of each phase. Sag River 10295' 8598' Shublik 10334' 8628' Sadlerochit 10424' 8701' Zone 2 10691' 8955' 31. List of Attachments Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the for, cgoing is true and correct to the best of my knowledge SignedTerrieHubble "'~~)/ ,~ Title TechnicalAssistantlll Date 01-26A 99-12 Prepared By Name/Number: Terrie Hubble, 564-4628 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 Progress Report Facility PB DS O1 Well 01-26A Rig (~igI:) }q~~ q~7~ Page 1 Date 14 April 99 Date/Time 07 Mar99 17:30-18:00 18:00-01:00 08 Mar 99 01:00-05:00 05:00-06:00 06:00-16:30 16:30-20:00 20:00-21:00 21:00-23:00 23:00-00:15 09 Mar 99 00:15-04:30 04:30-06:00 06:00-12:00 12:00-14:00 14:00-15:00 15:00-17:30 17:30-18:30 18:30-19:30 19:30-20:00 20:00-22:30 22:30-06:00 10 Mar 99 06:00-12:00 12:00-13:30 13:30-15:30 15:30-18:00 18:00-06:00 11 Mar 99 06:00-07:00 07:00-11:00 11:00-13:30 13:30-14:00 14:00-18:00 18:00-19:30 19:30-20:30 20:30-21:30 21:30-01:30 12 Mar 99 01:30-02:30 02:30-06:00 06:00-08:30 08:30-10:00 10:00-12:00 12:00-18:00 18:00-20:30 20:30-23:30 23:30-00:00 13 Mar 99 00:00-01:30 01:30-06:00 06:00-06:30 06:30-07:00 07:00-08:00 08:00-13:00 13:00-13:30 13:30-19:00 19:00-22:30 22:30-23:00 23:00-00:00 Duration 1/2 hr 7 hr 4 hr lhr 10-1/2 hr 3-1/2 hr lhr 2hr 1-1/4 hr 4-1/4 hr 1-1/2 hr 6 hr 2hr 1 hr 2-1/2 hr 1 hr 1 hr 1/2 hr 2-1/2 hr 7-1/2 hr 6 hr 1-1/2 hr 2 hr 2-1/2 hr 12hr lhr 4hr 2-1/2 hr 1/2 hr 4 hr 1-1/2 hr lhr 1 hr 4 hr lhr 3-1/2 hr 2-1/2 hr 1-1/2 hr 2hr 6 hr 2-1/2 hr 3 hr 1/2 hr 1-1/2 hr 4-1/2 hr 1/2 hr 1/2 hr lhr 5 hr 1/2 hr 5-1/2 hr 3-1/2 hr 1/2 hr 1 hr Activity Held safety meeting Rigged down Drillfloor / Derrick Rig moved 90.00 % Rigged up Drillfloor / Derrick Rig moved 100.00 % Fill pits with Seawater Rigged down Hanger plug Investigated pressure change Cleared Standpipe manifold Circulated at 9850.0 ft Installed Hanger plug Installed BOP stack Tested Blind ram Rigged up Hanger plug Tested BOP stack Rigged down Hanger plug Made up BHA no. 1 Fished at 0.0 ft Circulated at 9850.0 ft Laid down 3200.0 ft of Tubing Laid down 9850.0 ft of Tubing Installed BOP stack Tested BOP stack Made up BHA no. 2 Singled in drill pipe to 9800.0 ft Fished at 9839.0 ft Pulled out of hole to 3500.0 ft Serviced kon roughneck Held safety meeting Pulled out of hole to 0.0 ft Made up BHA no. 3 Serviced Block line Serviced Top drive R.I.H. to 9800.0 ft Fished at 9866.0 ft Pulled out of hole to 6500.0 ft Pulled out of hole to 0.0 ft (cont...) Laid down fish Made up BHA no. 4 R.I.H. to 9882.0 ft Milled Permanent packer at 9882.0 ft Circulated at 9893.0 ft Flow check Circulated at 9893.0 ft Pulled out of hole to 0.0 ft Pulled BHA Made up BHA no. 5 Serviced Top drive R.I.H. to 9922.0 ft Fished at 9922.0 ft Pulled out of hole to 300.0 ft Pulled BHA Performed cement integrity test Installed Logging/braided cable equipment Facility DatedTime 14 Mar 99 15 Mar 99 16 Mar 99 17 Mar 99 18 Mar 99 19 Mar 99 20 Mar 99 PB DS 01 Progress Report Well 01-26A Rig (null) Duration Activity 00:00-03:30 03:30-06:00 06:00-07:00 07:00-10:00 10:00-20:30 20:30-21:00 21:00-22:00 22:00-06:00 06:00-12:00 12:00-13:30 13:30-14:00 14:00-15:00 15:00-16:00 16:00-21:30 21:30-23:30 23:30-00:00 00:00-04:00 04:00-05:00 05:00-06:00 06:00-09:30 09:30-15:30 15:30-06:00 06:00-11:30 11:30-14:00 14:00-14:30 14:30-15:00 15:00-16:30 16:30-21:30 21:30-00:00 00:00-01:30 01:30-05:00 05:00-06:00 06:00-08:00 08:00-09:00 09:00-10:00 10:00-10:30 10:30-14:00 14:00-15:30 15:30-16:00 16:00-01:30 01:30-03:00 03:00-03:30 03:30-03:45 03:45-04:00 04:00-06:00 06:00-07:30 07:30-12:00 12:00-18:00 18:00-20:00 20:00-20:30 20:30-23:00 23:00-00:00 00:00-00:30 00:30-02:00 3-1/2 hr 2-1/2 hr lhr 3 hr 10-1/2 hr 1/2 hr lhr 8 hr 6 hr 1-1/2 hr 1/2 hr lhr 1 hr 5-1/2 hr 2 hr 1/2 hr 4hr lhr lhr 3-1/2 hr 6 hr 14-1/2 hr 5-1/2 hr 2-1/2 hr 1/2 hr 1/2 hr 1-1/2 hr 5 hr 2-1/2 hr 1-1/2 hr 3-1/2 hr 1 hr 2 hr lhr 1 hr 1/2hr 3-1/2 hr 1-1/2 hr 1/2 hr 9-1/2 hr 1~1/2 hr 1/2 hr 1/4hr 1/4 hr 2 hr 1-1/2 hr 4-1/2 hr 6 hr 2 hr 1/2 hr 2-1/2 hr lhr 1/2 hr 1-1/2 hr Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations (cont...) Made up BHA no. 6 R.I.H. to 10273.0 ft Functioned M.W.D. tool Circulated at 10298.0 ft Milled Casing at 10315.0 ft Milled Casing at 10322.0 ft (cont...) Circulated at 10322.0 ft Pulled out of hole to 9410.0 ft Serviced Block line Serviced Top drive Pulled out of hole to 273.0 ft Pulled BI-IA Jet wellhead Tested Well control Installed Wear bushing Made up BHA no. 7 Made up BHA no. 7 (cont...) R.I.H. to 10322.0 ft Drilled to 10700.0 ft Drilled to 10970.0 ft (cont...) Circulated at 10970.0 ft Pulled out of hole to 10224.0 ft R.I.H. to 10970.0 ft Circulated at 10970.0 ft Pulled out of hole to 458.0 ft Pulled BHA Rigged up Logging/braided cable equipment Conducted electric cable operations Conducted electric cable operations Conducted electric cable operations (cont...) Rigged down Logging/braided cable equipment Installed Tubing handling equipment Held safety meeting Ran Tubing to 743.0 ft (4-1/2in OD) Ran Tubing to 657.0 ft (2-7/8in OD) Repaired Draw works Ran Liner on landing string to 10970.0 ft Circulated at 10970.0 ft Mixed and pumped slurry - 20.400 bbl Displaced slurry - 104.000 bbl Functioned Hanger assembly Circulated at 10870.0 ft Circulated at 10870.0 ft (cont...) Pulled Drillpipe in stands to 6370.0 ft Laid down 3800.0 ft of 4in OD drill pipe Laid down 628.0 ft of Tubing Tested Liner Rigged up Top ram Installed Tubing handling equipment Held safety meeting Installed Tubing handling equipment Page Date 2 14 April 99 Progress Report Facility PB DS O1 Well 01-26A Rig (null) Page 3 Date 14 April 99 Date/Time 21 Mar 99 02:00-06:00 06:00-21:30 21:30-22:00 22:00-01:30 01:30-02:15 02:15-02:45 02:45-04:00 04:00-04:30 04:30-06:00 06:00-07:00 07:00-08:30 08:30-10:00 10:00-11:00 11:00-11:30 11:30-12:30 12:30-13:00 13:00-14:00 14:00-15:00 15:00-15:30 15:30-16:30 Duration 4 hr 15-1/2 hr 1/2 hr 3-1/2 hr 3/4 hr 1/2 hr 1-1/4 hr 1/2 hr 1-1/2 hr lhr 1-1/2 hr 1-1/2 hr 1 hr 1/2 hr lhr 1/2 hr lhr lhr 1/2 hr 1 hr Activity Ran Tubing to 5-1/2in (2081.0 ft OD) Ran Tubing to 9974.0 ft (5-1/2in OD) (cont...) Installed Tubing hanger Reverse circulated at 9974.0 ft Functioned Production packer Tested Tubing Tested Permanent packer Installed Hanger plug Removed BOP stack Removed BOP stack Installed Adapter spool Installed Xmas tree Removed Hanger plug Installed Hanger plug Rigged up High pressure lines Tested Xmas tree Removed Hanger plug Freeze protect well - 150.000 bbl of Diesel Installed Hanger plug Freeze protect well - 0.000 bbl of Diesel 01-26A ~- DESCRIPTION OF WORK COMPLETED PERFORATIONS OPERATIONS Date Event Summary 4/12/1999: MIRU E-line unit. PT'd equipment to 3000 psi. RIH w/perforating guns & shot 30' of Initial Perforations at: 10769'- 10783' (Zone 2B) 10793'- 10803' (Zone 2B) 10824'- 10830' (Zone 2B) RefLog: BHCS 3-14-1999 POOH w/guns. ASF. RD. Used 2-7/8" carriers & shot all perfs @ 4 SPF, underbalanced press, 60°/120° phasing, & random orientation. Placed well 01-26A on initial production & obtained a valid well test. Anadrill MWD/LWD Log Product Delivery Customer Well No Installation/Rig LOG Surveys (Paper) Arco Alaska, inc. DS 01-26A Nabors 9Es Run No. Scale Original Film DS 01-26A End of Well Report AGOCC API# 50-029-20885- l0 By: Dispatched To: Date Dispatche Dispatched By: No Of Prints AOGCC, Lori Taylor 29-Mar-99 Joey LeBlanc No of Floppies No of Tapes D Please sign and return to: Anadrill LWD Division 4560 Arctic Blvd Anchorage, Alaska 99503 LWD Log Delivery V1.1, Dec '97 ANADRILL SCHLUMBERGER Survey report Client ................... : ARCO Alaska Inc. Field .................... : Prudhoe Bay Unit Well ..................... : DS 01-26A API number ............... : 50-029-20885-01 Engineer ................. : J. Rathert Rig: ..................... : Nabors 9ES TState: ................... : Alaska 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 ....... : 28.00 ft KB above permanent ....... : 67.95 ft DF above permanent ....... : 67.95 ft Vertical section origin- Latitude (+N/S-) ......... : Departure (+E/W-) ........ : 0.00 ft 0.00 ft Platform reference point Lat%tude (+N/S-) ......... : -999.25 ft Departure (+E/W-) ........ : -999.25 ft Azimuth from rotary table to target: 116.66 degrees 17-Mar-99 14:53:15 Page 1 of 2 Spud date ................ : 15-Mar-99 Last survey date ......... : 17-Mar-99 Total accepted surveys...: 20 MD of first survey ....... : 10293.70 ft MD of last survey ........ : 10970.00 ft ORIGINAL Geomagnetic data .... Magnetic model ........... : BGGM version 1999 Magnetic date ............ : 13-Apr-1999 Magnetic field strength..: 1146.83 HCNT Magnetic dec (+E/W-) ..... : 27.89 degrees Magnetic dip ............. : 80.71 degrees MWD survey Reference Criteria Reference G .............. : 1003 00 mGal Reference H .............. : 1146 00 HCNT Reference Dip ............ : 80 72 degrees Tolerance of G .......... ~: (+/-) 4 00 mGal Tolerance of H ........... : (+/-) 6 00 HCNT Tolerance of Dip ......... : (+/-) 0 30 degrees Corrections -- Magnetic dec (+E/W-) ..... : 27.89 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-) .... : 27.89 degrees (Total az corr = magnetic dec - grid conv) Sag applied (Y/N) ........ : No degree: 0.00 [ (c)1999 Anadrill IDEAL ID5 IA 12R] -- -- RECEIVED Alaska Oil & Gas Cons. Commission ANADRILL SCHLUMBERGER Survey Report 17-Mar-99 14:53:15 Page 2 of 2 Seq Measured Incl Azimuth Course % depth angle angle length - (ft) {deg) (deg) {ft) 1 10293.70 37.77 115.4 2 10312.00 39.19 117.7 3 10330.64 39.75 121.3 4 10362.03 37.76 127.3 5 10389.56 34.92 132.6 6 10423.38 30.85 139.1 7 10455.35 25.95 142.4 8 10482.41 21.98 143.4 9 10512.90 18.01 136.7 10 10544.45 15.52 123.7 11 10574.08 15.16 107.0 12 10606.96 13.81 89.1 13 10639.10 11.92 70.6 14 10670.41 10.23 53.0 15 10702.08 9.75 37.7 16 10734.34 9.75 36.3 17 10764.34 9.56 33.4 18 10856.15 9.59 30.3 19 10916.57 9.71 27.3 Survey Projected to TD: 20 10970.00 9.71 27.3 0.00 18.30 18.60 31.40 27.60 33.80 31.90 27.10 30.50 31.60 29.60 32.90 32.10 31.30 31.70 TVD depth Vertical Displ Displ section +N/S- +E/W- (ft) (ft) (£t) 8597.04 4378.09 -1175.20 4308.88 8611.37 4389.47 -1180.29 4319.06 8625.73 4401.28 -1186.11 4329.35 8650.22 4420.74 -1197.16 4345.58 8672.46 4436.65 -1207.63 4358.12 8700.84 4453.97 -1220.74 4370.93 8728.90 4467.83 -1232.46 4380.55 8753.66 4477.70 -1241.23 4387.19 8782.32 4487.24 -1249.25 4393.83 8812.58 4496.03 -1255.16 4400.70 8841.14 4503.78 -1258.49 4407.70 8873.01 4511.50 -1259.68 4415.75 8904.32 4517.20 -1258.52 4422.71 8935.04 4520.68 -1255.77 4427.98 8966.26 4522.44 -1251.96 4431.87 32.20 8998.00 4523.42 -1247.60 4435.15 30.00 9027.58 4524.14 -1243.47 4438.03 91.80 9118.10 4525.52 -1230.51 4446.08 60.50 9177.74 4525.90 -1221.62 4450.96 9230.38 53.40 4526.00 -1213.62 4455.09 Total At DLS Srvy Tool displ Azim {deg/ tool qual (ft) (deg) lOOf) type type 4466.27 105.26 0.00 TIP 4477.43 105.28 11.02 MWD M -- 4488.89 105.32 12.67 MWD M -- 4507.47 105.40 13.53 MWD M -- 4522.35 105.49 15.33 MWD M -- 4538.20 105.60 15.92 4550.62 105.71 16.12 4559.40 105.80 14.73 4567.98 105.87 15.01 4576.20 105.92 14.20 4583.85 105.94 14.93 4591.91 105.92 14.15 4598.29 105.88 14.04 4602.61 105.83 12.01 4605.31 105.77 8.48 4607.29 105.71 0.74 4608.94 105.65 1.74 4613.22 105.47 0.56 4615.56 105.35 0.85 4617.44 105.24 0.00 MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD MWD M -- 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis 6-axis [(c)1999 Anadrill IDEAL ID5 iA 12RI -- -- ~."~Ja mm~m~_,-[=]2 Anadrill 12-Oct-98 A summary of Anadrill's performance on DS 01-26A has been compiled. SERVICES PROVIDED: IMPulse Gamma Ray 10294 ft to 10970 ft AIM 10294 ft to 10970 ft OPERATING STATISTICS: MWD operating time (over 200 GPM) for the well was 207 hours. MWD footage of 675' was accomplished in 1 MWD run. LWD time below the rotary for this well was 38 hours. LWD pumping time was 23.4 hours. LWD footage of 624' was accomplished in 1 run. RECEIVED Ala 0il & C as 00 s. C0mmissi0n DIRECTIONAL A total of 18 MWD surveys were used by the Directional Driller. AIM (Inclination at bit) was also provided and was used to guide the well. LESSON S LEARNED: Anadrill's new 4 3/4 "VPWD (Vision Pressure While Drilling) tool was run for the first time in Alaska. While we were not able to display real-time ECD, we were able to get both an internal and annular pressure in real time. AIM (Inclination at bit) was also run and proved useful in guiding the well. ANADRILL appreciates the opportunity to provide ARCO Alaska / Shared Services Drilling with MWD/LWD services. John D. Rathert Jr. Cell Manager 9ES Joey LeBlanc Field Service Manager, AK ALASKA OIL AND GAS CONSERVATION COMMISSION TONY KNOWLES, GOVERNOR 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 FebruaD, 16, 1999 Dan Stone Senior Drilling Engineer ARCO Alaska. Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bav Unit 01-26A ARCO Alaska, Inc. Permit No: 99-012 Sur Loc: 990'SNL, 616'EWL. Sec. 08, T10N, R15E, UM Btmhole Loc. 3076'NSL, 227"vVEL, Sec. 08, TION, R15E, UM Dear Mr. Stone: Enclosed is the approved application for permit to redrill the above referenced well. The permit to redrill does not exempt you from obtaining additional permits required bv law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25 035. Sufficient notice (approximately 24 hours) must be given to allow a representative of the Commission to witness a tcst of BOPE installed prior to drilling new hole. Notice may be given by contacting the Commission petroleum field inspector on the North Slope pager at 659-3607. Robert N. Christenson, P. E. Chairman BY ORDER OF THE COMMISSION dlf/Enclosures CC: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o cncl. STATE OF ALASKA ALASKA t_ .:_ AND GAS CONSERVATION COM¥c,~SSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work l--I Drill I~Redrill Ilb. Typeofwell [--I Exploratory [] Stratigraphic Test I~ Development Oil [] Re-Entry [] Deepenl [] Service [] Development Gas [] Single Zone [] Multiple Zone 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool ARCO Alaska Inc. Plan KBE = 67.7' Prudhoe Bay Field / Prudhoe 3. Address 6. Property Designation Bay Pool P.O. Box 196612, Anchorage, Alaska 99519-6612 ADL 028329 4. Location of well at surface 7. Unit or Property Name il 1. Type Bond (See 20 AAC 25.025) 990' SNU 616' EWL, SEC. 08, T10N, R15E, UM Prudhoe Bay Unit At top of productive interval 8. Well Number Number U-630610 3046~[~_Z 220' WEL, SEC. 08, T10N, R15E, UM 01-26A At tole1 ~e"¢th i9. Approximate spud date Amount $200,000.00 3076' NSL, 227' WEL, SEC. 08, T10N, R15E, UM 02/17/99 12. Distance to nearest property line113. Distance to nearest well 14. Number of acres in property 15. Proposed depth (MD and TVD) ADL 028328, 227'I No Close Approach 2560 10963' MD / 9150' TVDss 16. To be completed for deviated wells 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} Kick Off Depth 10312' MD Maximum HoleAngle 42-6° Maximum surface 2470 psig, At total depth (TVD) 8800'/3350 psig 18. Casing Program Specifications Setting Depth Size Top Bottom Quantity of Cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 6" 4-1/2" 12.6# L-80 IBT-M 763' 10200' 8524' 10963' 9218' 100 sx Class 'G' 19. To be completed for Redri'll, Re-entry, and Deepen Operations. ~'~ Present well condition summary 0 '~ii~~"'' ~!'-/~ Total depth: measured 11080 feet Plugs (measured) ! I i true vertical 9235 feet ~' ~ ~ ! ~ ~'J f~ ~--~ Effective depth: measured 11035 feet Junk (measured) ;,,.!:::-~;~-~ true vertical 9198 feet Casing Length Size Cemented MD Structural Conductor 79' 20" 1910# Poleset 79' 79' Surface 2536' 13-3/8" 1800 sx CS III, 400 sx CS II 2610' 2610' Intermediate Production 10190' 9-5/8" 500 sx Class 'G' 10264' 8574' Liner 1154' 7" 370 sx Class 'G' 9921' - 11075' 8295' - 9231' Perforation depth: measured 10820' - 10830', 10833' - 10843', 10860' - 10878', 10891' - 10895' true vertical 9022' - 9030', 9033' - 9041 ', 9055' - 9070', 9080' - 9084' 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 C'ontact Engineer Name/Number: James Smith, 564-5026 Prepared By Name/Number: Terrie Hubble, 564-4628 21. I hereby certify that the foregoing is t~e and correct to the best of my knowledge ~i ~ Signed ~.._. --~-,. Dan Stone Title Senior Drilling Engineer Date Commission Use Only /G~/~::~- // 2.., 50-029-20885-01 ,,.~-~/'¢ ,¢"7 for other requirements Conditions of Approval: Samples Required []Yes []No Mud Log Required []Yes .~ No Hydrogen Sulfide Measures I~Yes I--INo Directional Survey Required ]~Yes []No Required Working Pressure for BOPE []2K; 1~3K; []4K; [] 5K; [] 10K; [] 15K Other: ORIGINAL SIGNED. BY by order of Approved By Robert N. IDhri~,.. .... Commissioner the commission Dat~:~'"/ Form 10-401 Rev. 12-01-85 Submit In Triplicate I Well Name: IDS 1-26A I Well Plan Summary I Type of Well (producer or injector): I Producer I Surface Location: 4290' FSL, 4664' FEL, Sec. 8, T10N, R15E Target #1 Start: 3046' FSL, 220' FEL, Sec. 8, T10N, R15E X = 702,435 Y= 5,938,788 Z = 8938' TVDss Total Depth: 3076' FSL, 227' FEL, Sec. 8, T10N, R15E X = 702,427 Y = 5,938,818 Z= 9,150' TVDss I AFE Number: 14J8083 Estimated Start Date: 12/17/99 Well Design (conventional, slim hole, etc.): ling: ] Nabors 9ES I ITVDss: 19,150' IConventional Sidetrack Operating days to } 16 complete: I IKBE: 1 67.7' Objective: Sidetrack out of existing 7" liner in the Sag River formation, directionally drill 6 "hole thru (1) Z2 target, TD at 10,963' MD. Run, cmt and test 4 1/2" solid liner, complete with 5 ~/-'' ~2 , 13CR tbg, (6) GLM's and EOA tail assy. Perf post-rig on wireline Formation Markers Formation Tops MD TVD(ss) Put River Sand 10,168' 8,424' Sag River Top 10,295' 8,525' Whipstock KOP 10,312' 8,544' Top Whipstock at 10,300'MD in 7" Shublik 10,335' 8,557' TSAD 10,423' 8,629' TZA 10,548' 8,740' TZ2C 10,694' 8,884' Target 1 10,749' 8,938' Total Depth 10,963' 9,150' Casing/Tubing Program: Hole Csg/ WttFt Grade Conn Length Top Btm Size Tbg ~' MD/TVD MD/TVD O.D. 6" 4 1/2" 12.6g L-80 IBT 763' 10200'/8,524' 10,963'/9,218' liner Mod Tubing 5 ¥2" 17.0# 13CR NSCC 9,970' 30'/30' 10,000'/8,300' Logging Program: I Open Hole Logs: I Cased Hole Logs Drilling section: MWD/GR from KOP (10,312') to TD. MADD pass as'per Geologist request. . Open Hole: Wireline Platform Express + Sonic will be run after reaching TD. Run log back up to 8,150'TVDss to ensure tie in. Sample catchers and rig site geologist on site before drill out. None, will perf post rig. Mud Program: ISpecial design considerations IDrill from KOP to TD with MI Flo-Pro Polymer system. I The formulation of the brine phase will be 6% KCL. I Density LSRV PV Gels Chlorides pH (ppg) (cps) 8.7 55 - 60,000 < 15 10 sec. >18 30,000 9.0-9.5 to to expect to to 8.9 55 - 60,000 8-12 10 min. >20 30,000 9.0-9.5 Record LSRV at 1,2,3 minutes: Make certain they are elevated and fiat. Plan to run 3 % Lubetex by volume. Start 6" section at 3 % Lubetex Sweeps (50 bbl min at 150,000 cp), Liner slugs and CBU w/60-80 rpm & reciprocation the full 90'. Ensure good stocks of LCM on location. Directional: KOP: 1) 10,312' MD, drill out of 7 "liner via whipstock window at 117° azimuth, 39° inclination, drop and turn angle to 8.3° inclination, 345° azimuth to target #1 at 10,749' MD, 8,938' TVDss', hold to TD at 10,963' MD, 9,150' TVDss. Maximum Hole 42.6°just off whipstock Angle: Surface Shut-in No wells will need to be shut-in and de-pressurized before rig move on and off of the well. Close Approach There are no close approach wells to this wellbore Well: identified by Anadrill Wp #5A. Point to point separation Cement Data: Casing/Liner Lead: Tail: Sxs/Wt/Yield Comments Sxs/Wt/Yield P&A of original well 208/15.8/1.15 Class "G", TOC pre-rig coil work in 875' + 10 bbl 10,200' 590' above top 7" production liner perfs. 4 lA", 12.6#, L-80 liner 100/15.8/1.15 Class "G", 30% excess Shoe at 10,963' MD OH + 200' above liner Liner top@ 10,200'MD top w/DP in hole Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter and BOPE system schematics on file with AOGCC. Bottom hole pressure is 3,350 psi at 8,800' TVDss (estimated) Maximum shut-in casing pressure is 2,470 psi (assumes 0.1 psi/ft gas gradient to surface). NO ANNULAR INJECTION IN THIS WELL. DS 1-26A Class II drilling wastes will be disposed at CC-2A grind and inject facility. If Class I wastes are generated, they will be taken to Pad 3 disposal site. Contacts Name Office Home Pager Jim Smith Drilling Eng. 564 5026 345 8660 275-4015 Tony Bunch Drilling Supt. 564 5219 348 6683 275-3703 Dick Owens Geologist 263 4982 Dwight Warner Pad Engr. 263 4681 Lowell Crane Asset Drilling Eng. 564 4089 868 7711 275 8644 Martin Olsen Geophysicist 265 6437 Drilling Discussion Well Obiective The primary reason that this twin sidetrack is needed is due to mechanical failure of the 7" production liner which appears to be parted at 10,819'MD in the Ivishak. Nabors 9ES will move to 1-26A on/about Feb. 20, 1999 after completing 14-05 RWO drilling objective of 1- 26A is to pull the existing 5 1/2" tubing, mill and retrieve the 9 5/8" x 5 ½' production packer, set a whipstock and mill through 7' liner casing into the Sag River formation, then directionally drill this standard sidetrack to a single Zone 2 target. Pre-Rig Operations: .1. RU Coil Tubing and P & A open perforations (open perfs 10,820' - 10,895, shallowest squeezed perf at 10,790'). Cement top MUST NOT be above 10,200' MD (minimum per AOGCC - 10,690' MD at 100' above uppermost squeezed perforation). Tag and test cement plugback. 2. Pressure test 9-5/8" against cement plug to 3,000 psi. Contact AOGCC representative to witness test. Report results to ODE in Anchorage. 3. RU electric line and make a chemical cut tubing in the first full joint above the 5 1,~,, x 9 5/8"production packer + 9,845' MD. Circulate well to seawater through the cut. Freeze protect to + 2,2OO' MD. Note: use 6 arm chemical cutter. 4. Pressure test the 9 5/8" packoff and tubing hanger packoff to 5,000 psi.. Carefully cycle Lock Down Screws. 5. Freeze protect the well to 2000'MD. 6. Set a BPV in preparation of the rig sidetrack. Rig Sidetrack Procedure o 2. 3. 4. 5. 6. 7. 8. 9. 10. MIRU. ND tree, NU and test BOPE. Circulate well clean. Pull the existing 5 1/2" tubing completion. Tubing cut at _+ 9,845' MD. Replace the leaking 9 5/8" packoff if necessary. RIH w/5 1/2" Overshot, retrieve PBR assy.. RIH retrieve K-anchor. Mill and retrieve 5 1/2" x 9 5/8" production packer. RIH with 6" cement drilling assy. Dress cement to 10,312' MD. Set 7"whipstock on cement top and mill window. Displace to Quickdriln. Kick-off and directionally drill the 6" hole to 10,954' TD. Run wireline log suite at TD. Run and cement 4 1/2", L-80 solid production liner. ! 1. Run 5 1/2", 13 Cr tubing comp)btion. 12. ND BOPE, NU and test tree. RDMO. Post rig perforations on wireline Sidetracking this well should take 16 days DRILLING HAZARDS AND CONTINGENCIES Always have two levels of tested isolation before NU/ND. SURFACE CLOSE APPROACH WELL SHUT-INS There is no well that will need to be shut-in during the rig move on and off of the well. Careful coordination with any ongoing pad or facility operations or activities will be initiated prior to commencing the rig move per ASH procedures. DRILLING CLOSE APPROACH WELL SHUT-INS No shut-ins identified on Anadrill directional well plan Wp #5A due to close approach requirements. PORE PRESSURE: The pore pressure in the Sag River (KOP) is expected to be near 7.3 ppg EMW and the Sadlerochit is expected to be near 7.3 ppg. 8.6 - 8.7 ppg mud will be used drilling the Sag River, Shublik and Sadlerochit formations and will provide sufficient overbalance to the reservoir pressure. HOLE PROBLEMS The well' s design cuts no faults but be prepared for the possibility of lost circulation by stocking LCM materials at the rigsite. No major hole problems are expected since the directional program is relatively simple and the target is drilled nearly vertical. H_a_S: DS 1 is not an H2S Pad There are reported incidents of H2S at DS 1 which involved circulation of annular fluids from the wellboroe. H2S precautions will be in effect at all times. These include (but are not limited to): · Regular H2S drills (minimum of two per week) Proper training of all permanent onsite personnel, unescorted visitors and temporary onsite personnel; H2S monitors with both audible and visual alarms; Access to 5-minute emergency escape air packs; Personal H2S monitors; Functional wind indicator; Posted evacuation routes (minimum of two); Muster points in designated safe areas;H__H~_S; Functional communications between rig camp and rig floor. Casing Shoe Kick Tolerance The smallest kick tolerance for the 9 5/8" casing shoe is calculated as infinite of influx assuming a swabbed gas influx at the Sag River formation along the planned directional path. Based on 8.7 ppg MW (TSAG 10,312' MD & 8,544' TVDss, 7.5 ppg reservoir pore pressure), and min. frac at shoe of 12.0 ppg. Anadrill Schlumberger Alaska District 39%0 Arctic B]vd Anchorage, AK 99503 (907) 273-1700 Fax 561-8537 DIRECTIONAL WELL PLAN for SHARED SERVICES DRILLING ~ell ......... : DS01-26A (D5A) Field ........ : Prudhoe Computation..: Minimum Curvature Units ........ : FEET Surface Lat..~ 7D.23996348 Surface Long.: 148.40t30269 W Legal De~cription Surface ...... : 4290 FSL 466{ FEL S08 T10N R15E l~4 Tie-in survey: 3113 FSL 360 PHL S88 T10N RZSE UM Target 1 ..... : 3046 FSL 220 FEL S08 T10N ~ISE UM ~}H~ .......... : 3076 FSL 227 FEL 8~8 TION R~SE UM LOCATIONS - Ak~SKA Zone: 4 X-Coord Y-Coord 697~55,09 59399~3,L4 702293.L0 5938851.46 702435.00 5938788.08 7~2426.6% 5938817.91 PROFILE Prepared ..... : 22 ~sn 1999 ver~ sect az.: 116.~2 KB elevation.: 67.70 Magnetic- Dcln: +27.894 (E) · gca~e Factor.: 0. 99994452 co~v~-~5%%1-.'?'~'.~~ {A~JADRJL/ AKA.DPC: , NOTA/ ROV¢.D FOR i ]' D',cCIJTION PLAN I STATXON M]~ASUR~ INCL~ DXREC~IO~ VERT]CAL-DEPT}tS SECTION COORDI~ATES-FR(IM ZD~IFI~TION DE~H ~E ~Z~ ~ S~-S~A DED~T ~LLH~ ~==~=~==~===~=== ~=~===~ ~=~ ~=~~ ~m=~=~ ~=====~ ====~ ===~====~ =====~= TIE-IN $~VEY 10293.7~ ~7.77 115,45 8597.04 8529.34 {378,74 1175.28 S 4308.88 E TOP WHIPS~K 10300.00 37.73 115,43 8~02.02 8534.32 {382.59 1176.94 S ~312.36 E B~ ~HIP~CK 103~9.80 39.51 1~7.03 86L[.40 85~3,70 {390.08 1~80,25 S 43~9.08 E ~ [2/~00 [0372.00 41.54 ~24.79 8656.28 8588.58 4499.78 12~O.34 S ALASKA Zone ~ TDOL D~/ X Y PACS ~00 702293.10 593885~.~6 163L <TIE 702296.63 $93~B~9.89 30R 0.67 702303.43 59388~6,76 30R 702321,0l 5938837,84 I~0R 12,00 4153.42 ~ 709338,28 5938827.58 173L TSAD TZ4A /O&O0.O0 37,79 f2{.O0 8677.83 8610.13 4447.49 1210.44 S 4368,16 E 702353.28 5938817.B7 172L 13.50 ~0423.40 34.67 ~23,23 8696.70 8629.00 {~61.21 1218.10 S {379.67 ~ 7~2364.99 59358Z0.52 Z7IL 13.50 30500.00 24,48 119,53 8763.24 8695,54 {{98,80 1237,91 $ ~411.79 E 702397,62 5938791,56 168L 13.50 10547.75 18.~2 115.31 8807.70 8740.00 4516.~? 1245,99 S 4427.16 E 702413.20 5938783.89 I6&L 13,SO 10600.00 11.58 105.75 885~.L7 S790,47 4529.50 1250.91 S 4439.63 E 702{25,77 5938779.30 155L 13.50 CURVE Z3,50/100 L0677.94 4.87 40.31 ~935,39 8867.69 4537.9~ 1250.51 S &6%],31 E 702435.46 5938779.95 9R 13.50 ]> m (Anadr/ll {c)99 0126APSA 3 '2C 11:25 A~4 P] CD DS0~-26A (PSA) 22 Jam 1999 Page PROPOSED WELL PROFILE STATION MEASURED INC~ IDENTI~ICATIO~ OEPTR AR~LE TZ2C L069(.31 5,35 10700.00 5,7] TZ3 ~0707.38 6.28 ~ND 12.50/100 CURVE L0728.11 8,34 TARGET L0748.77 8.34 C17~ 0 C L0754.83 8.34 ROT L0826.59 8.34 O0~C L0839.73 8.3¢ 4-1/2~ L.NR PT L0963.03 S.34 TD L0963.03 S.34 DIRECTION VERTICAL-DE~TH$ AZIMUTH TVD SUB-SEA 15.87 8951.70 ~84.00 8.82 8977,36 6889.66 1.02 8964.70 889~.00 345.88 8985.26 8917.$6 345.89 9005.70 893~.00 SECTION COORDINAT~S-PROM ALASKA Zone 4 TOOL DL/ DE~ART WBSLHF, AD X ¥ PACE 4538.~1 1249,24 S 4449.97 E 702{36.08 593878~.23 66L 13.5~ ~537.88 1245,7] S 4450.05 E 70~36.~8 593878~,77 S9L 13.50 ~537.$9 1147-94 $ ~450.15 ~ 702436,23 5938782.54 5~L 13-50 ~536.12 1245.35 $ 4449.80 E 70~43S.81 5938785,12 HS 13,50 653~.16 1249,45 S 4449.07 E 7~2435.~ ~3~788,0~ ~S 0.00 ~45.8S 901~.70 8944.00 3~5.88 90S2.70 9015.00 345.8~ 9095.70 9028.00 345.88 92~?.70 9150.00 3~5.88 92L7.70 9150.00 ~533.$9 124~.60 S 4448-$6 K 702434.77 5938788.85 HS 0,~0 ~526.80 123~.51 S 4446,32 E 70243~.97 5938798.87 HS 0-~0 t525.S6 1229-66 8 4445,S5 E 70243L.t5 593~800.70 HS 0.~0 ~513.89 1212.33 S 444L.49 R 702426.64 $9388L?.91 0-00 4513.89 12~2.33 8 444~,49 E 702~26.6~ $9388L7.91 0,~0 -El m (Anadrill (C]99 O126A~SA 3.2C 11:25 ....................... ~, ~H~iLL U~U PAGE 04 SHAREB SERVIC ii 'DRILLING DSOt-26A (P5A) VERTICAL SECTION VIEW ill - ii i i i ii ii Section at: t~6.62 TVD Scale.' ! inch = lO0 feet Der Scale' ! inch = ~00 feet OrNwn ..... : 22 Jan 1999 _. Narker Identification HO 8K8 SECTN INCLN A} TIE-IN SURVEY 10294 8597 4379' 37.77 B) TOP WHIPSTOCK 10300 8602 4383 37.73 ~_ C) BASE WHIPSTOCK ~0312 861! 4390 39.51 0) CURVE 12/~00 10342 8634 4410 42.66 E) CURVE 12/t00 10372 8658 4430 41.54 F) CURVE 13.50/~00 ~0678 8935 4538 4.87 ...... ~~ ..... Gl ENO 12.50/~00 CURVE~._, ~0728~ 8985 4536 8.34 )~ '~" ~' H) TARGET ~0749 9006 a534 8,34 I) 4-1/2" LNR PT 10963 92~8 45~4 8.34 J) TD ~0963 92~8 45i4 8.34 . ~ ~ ~-,r'.l, l::',!:'.' "~-.~ < i ,Zk~ ',, '-L.' ~.~ LL ' i I , · _:-.~ · - · '2 .... '" ~.- ........ ~ ' "' ]c~ ' ~ ............ I 1 ..... } ........ I _ I I 4200 4250 4300 4350 4400 4450 4500 4550 4600 4650 4700 4750 4800 4850 4900 Section Departure 1 123~ 126: SHARED SERVICES GRILLING ~nadPJl ] $chJumDerge£ DSO -26A (P5A) · DECLINATION.: +27.894 (E) ISCALE ....... : ~ inch: 25 feet I _ .................... I DRA¥1N ....... : 22 Jan 1999 ..... M~rker Identificatioa ND N/S E/~t A~ TIE-IN SUBVEY 1O294 1~75 S 4309 E B) TOP MHIPSIOCK 10300 1~77 S 43~2 E C} BASE ~HIPSTOCK 10312 I~80 S 43~9 E ........ ~, D) CURVE 12/100 10342 1390 S 4336 E ~ E~ CURVE ~2/100 10372 1200 S 4353 E ~ F} CURVE ~3.~/100 i0678 125i S 4449 E { G~ END 12.50/100 C~VE 10728 1245 S 4450 E . -.~ .,. HJ TARGET 10749 1242 S 4449 E ~ II 4-t/~" LNR PT t0963 12,2S 444tE ~ ~ O~ TD 10963 1212S 4441 E .... ..... ~71.7.~, ~ ...~-,. ;~ [... ' .... ~ .... F ~ "'~ "r..,4 ~.,¢ ~ .......... "' "-:- .%'~ ~ ': -' ~' ,:... .j -.~.k : ~ ~ ..... ',C' ' """'"' ......... ,'. ..... :.: ;'~!l' ::;;'.~f '.,~ :."; .; ~ ... ......... ' ~ :' , 4250 PLAN VIE~ CLOSURE ' 4604 feet at Azimuth t05.27 ,nac~;i][ Ic]99 01~PSA 3.~ :1:1:18 ~ P) 4263 4275 4288 4300 4313 4325 4338 4350 4363 4375 4366 4400 4413 4425 4438 4450 4463 4475 EAST -> L L DS 1-26 (Current i ' ~ 5-1/2' BAL-O SSSV @ -2,000' (Not required) 13 3/8', 72#/ft, ~ ~ L-80, BTC @ 2,607' , i , , ! ~ , I 5-112', 17#1fl, 180, Gomplotion I Packer @ .9,895' MD i __ 4~1/2' TaJlpipe ~1 (stung into 7' liner top) I R ~ 7' UnerTop _ _ @ ~9,947 9 5/8', 47#/ft, L-80, BTC @ 10 264' --,~ ~ ~i~ k at 10, 200'MD :i~ Top perf at 10790'MD - "'"- ~7" liner parted at 10,819'MD 7', 29#, L-80 11,075' MD ~ Date Revised by Comments pRUDHOE BAY UNIT 10-2-98 TAB Conventional Sidetrack APl NO: 50-029-20885-00 ARCO-BP SSD DS 1-26A Conventional ST (Proposed) 1 ! ,'-', L 5-1/2' BAL-O i SSSV @ -2,000' 13 3/8', 72#/ft, (Not required) L-80, BTC @ 2,607' ~ k I I 6 x 5-1/2' GLM'S ; i ~ I i 5-1/2', 17#/ft, 13Cr, Completion ~ ~ ~ 5-1/2" Production Packer @ .~J,800' MD 4-1/2' Tailpipe I I (stung into 7~ liner top) @ ~9,947' 9 5/8', 47#/ft, L-BO, BTC @ 10,264' ~ I KOP @ 10,300' Cement dressed to 10,312'MD ~ Then set whipstock for sidetrack Top original per[ 10,790'MD ~.~!~:!;~i!ii!i?.~ ~ 4-1/2', 12.6#, L-80, BTC-Mod 7", 29#, L-80 -10,150' - -10,953' MD 11,075' MD Date Revised by Comments PRUDHOE BAY UNIT 10-2-98 JES Conventional Sidetrack '~ELLLI~.6A- APl NO: 50-029-20885-01 ARCO-BP SSD H 145055 DATE 110691 HANDL INVOICE ! CREDff MEMO CK110698E INO INST: S/F DESCRIPTION KATHY CAMPO HE AI'rACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. GROSS 100.00 MOR X5122 DISCOUNT D^TE ] i C.ECKNO. [ 11~o6~va1 J 00145055J NET 100.00 PAY ',ii?:" r,;~ .... FirST: 'i~TI~: BANK!:bF ASi~I~AND ¥'iii ":i'[ ~::!~F~{LIATE,~ · ~j~J'~ :'3 ;?, , ;.',,.;?. ;:,,.:',' NATI&N~TYeA~K ~..;; :t.:,: ?; ':: :'(;"."::'.'] C~EVE[AND, O~lO ,'.'.'; j'. :: ,',' , ,:. ?:": ~. y:: ':':~:::.: ,~, ,,,'.. ,.:;::. :,: ~',. ). ~: :'::.. ':.?,' 412 Tb':;: T:h:&i', ??"ALASKA STATE ANCHORAOE NO., H ::~,,:~, 4 5..,0 5~ IS:: DOLLAR !ii,,,' ..... ":' I 1:1'/°6/~e II ' $100'00 AK 99501-31~0 ,'l, h50SS,, ~:0L~.P038qS,: 00,qhL&q,, WELL PERMIT CHECKLIST COMPANY r _,,~.~,~ WELL NAME/~z~ ,/- .~.~:~/'~' PROGRAM: exp ~ ~ wellbore seg ann. disposal para req ~ FIELD & POOL ADMINISTRATION 1. 2. 3. 4. 5. 6. 7. 8. 9. 10. 11. R D~T.F,_ 12. 15. 16. 17. 18. 19. 20. 21. 22. 23. 24. 25. APPR DATE 26. 27. 28. 20. INIT CLASS ,~,~__.z./ /'~:>,, ~/ Permit fee attached ....................... Lease number appropriate ................... Unique well name and number .................. Well located in a defined pool .................. Well located proper distance from ddlling unit boundary .... Well located proper distance from other wells .......... Sufficient acreage available in drilling unit ............ If deviated, is wellbore plat included ............... Operator only affected party ................... Operator has appropriate bond in force ............. Permit can be issued without conservation order ........ Permit can be issued without administrative approval ...... Can permit be approved before 15-day wait ........... GEOL AREA N Conductor string provided ................... Surface casing protects all known USDWs ........... CMT vol adequate to circulate on conductor & surf csg ..... CMT vol adequate to tie-in long string to surf csg ........ Y N CMT will cover all known productive horizons .......... ~) N Casing designs adequate for C, T, B & permafrost ....... Adequate tankage or reserve pit ................. If a re-drill, has a 10-403 for abandonment been approved... Adequate wellbore separation proposed ............. (~ N If diverter required, does it meet regulations .......... Drilling fluid program schematic & equip list adequate ..... BOPEs, do they meet regulation ................ ~) N BOPE press rating appropriate; test to ~J~O<~) psig. '~ N Choke manifold complies w/APl RP-53 (May 84) ........ ~ N Work will occur without operation shutdown ........... N Is presence of H2S gas probable ................. N UNIT# //oZ''.~'<:~ ON/OFF SHORE <:~,,,,._~ (~N p GEOLOGY ANNULAR DISPOSAL APPR DATE 30. Permit can be issued w/o hydrogen sulfide measures ..... Y N./' 31. Data presented on potential overpressure zones ....... Y,~ ~ ] 32. Seismic analysis of shallow gas zones ............. /,,x( N //_.~,"~, ,~ 33. Seabed condition survey (if off-shore) ............. /' Y N ' 34. Contact name/phone for weekly progress reports [explora~,/Ol/only] Y N 35. With proper cementing re~,ords, thiS ple/n (A) will contain waste in a ~itable re,~iving zone; ....... Y N (B) will not contaminate fres~l,water;/br cause drilling waste... Y N to surface; ~ / (C) will not impair mechanical i.~grity of the well used for disposal; Y N (D) will not damage producjl;~forn~ion er impair recovery from a Y N pool; and (E) will not circumvent 20 AAC 25.252 or 20 AAC 25.412. GEOL.O.~Y.: ENGINEERING: U IC/Arf~uyr JDH RNC co C~ ~./~ dev_./~ redrll _...',~ serv Y N COMMISSION: Comments/Instructions: 0 0 c:\msoffice\wordian\diana\checklist