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Home My WebLink About209-107 ' • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPL TION REPORT AND LOG 1a. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Plugged ❑ Abandoned Ilig Suspended 1b. Well Class: 2OAAC 25.105 0s.k�OAAC 25.110 Development ❑ Exploratory ❑ GINJ El WINJ ❑ WAG El WDSPL ❑ Other El No. ofCompletio s: Service 111 Stratigraphic Test ❑ 2. Operator Name: 5. Date Comp., Susp., 12. Permit to Drill Number: ConocoPhillips Alaska, Inc. or Aband.: December 8, 2012 209 - 107 / 312 - 294 - 3. Address: 6. Date Spudded: 13. API Number: P. O. Box 100360, Anchorage, AK 99510 - 0360 October 26, 2009 50 - 103 - 20604 - 00 • 4a. Location of Well (Governmental Section): 7. Date TD Reached: 14. Well Name and Number: Surface: 476' FSL, 227' FWL, Sec. 13, T11 N, R8E, UM December 3, 2009 2A Top of Productive Horizon: 8. KB (ft above MSL): 125' RKB pise 15. Field /Pool(s): na GL (ft above MSL): 3y 9 -AMSL Kuparuk River Field ■ Total Depth: 9. Plug Back Depth (MD + TVD): 1227' FNL, 1531' FWL, Sec. 23, T11 N, R8E, UM 5476' MD / 4353' TVD• Kupuruk River Oil Pool' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD + TVD): 16. Property Designation: Surface: x 498621 y 5959898 Zone 4 7271' MD / 5434' TVD . ADL 25570 - TPI: x - na y- na Zone 4 11. SSSV Depth (MD + TVD): 17. Land Use Permit: Total Depth: x 494646 y - 5958196 Zone 4 landing nipple @ 453' MD / 453' TVD 2668 18. Directional Survey: Yes ❑ No 0 19. Water Depth, if Offshore: 20. Thickness of Permafrost MD/TVD: (Submit electronic and printed information per 20 AAC 25.050) N/A (ft MSL) 1524' MD / 1500' TVD 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re drill /Lateral Top Window MD/TVD none not applicable 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CEMENTING RECORD CASING SIZE WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE PULLED 20" 62.5# H -40 34' 154' 34' 154' 42" 12 cu yds AS 1 13.375" 68# L -80 34.6' 3374' 34.6' 2930' 16" 530 sx AS Lite, 390 sx LiteCRETE 9.625" 40# L -80 33' 6849' 33' 5172' 12.25" 678 sx Class G 7" 26# L -80 6695' 7248' 5077' 5433' 8.5" 26 bbls15.8 ppg Class G , 24. Open to production or injection? Yes ❑ No 0 If Yes, list each 25. TUBING RECORD Interval open (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET (MD) PACKER SET ( MD/TVD) none none 6695' MD / 5077' TVD perfs cemented 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Was hydraulic fracturing used during completion? Yes ❑ No EI DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED % ED APR 2 4 2013 cement retainer @ 5483' RECEIVED JAN 1'2 27. PRODUCTION TEST mei Date First Production Method of Operation (Flowing, gas lift, etc.) AO <.e1 C V V plugged Date of Test Hours Tested Production for OIL -BBL GAS -MCF WATER -BBL CHOKE SIZE GAS - OIL RATIO Test Period -> Flow Tubing Casing Pressure Calculated OIL -BBL GAS -MCF WATER -BBL OIL GRAVITY - API (corr) Press. 24 -Hour Rate -> 28. CORE DATA Conventional,Core(s) Acquired? Yes ❑ No El Sidewall Cores Acquired? Yes ❑ No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (Submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 25.071. NONE RB vv� JAN 2 8 2013 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE (S (� Submit original only "0:10 \ � t r741,- ,,'.\. G 29. GEOLOGIC MARKERS (List all formations and •rs encountered): 30. • FORMATION TESTS NAME MD TVD Well tested? ❑ Yes 0 No If yes, list intervals and formations tested, Permafrost - Top ground surface ground surface briefly summarizing test results. Attach separate sheets to this form, if Permafrost - Bottom 1524' 1500' needed, and submit detailed test information per 20 AAC 25.071. not applicable N/A Formation at total depth: na 31. LIST OF ATTACHMENTS Summary of Daily Operations, schematic 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Haibin Guo @ 265 -1487 Email: Haibin.Guoeconocoohillips.com Printed Name G. Alvord Title: Alaska Drilling Manager Signature - A _ 4 L( Phone 265 -6120 Date 1061 r 3 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. Item la: Classification of Service wells: Gas injection, water injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. 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 4b: TPI (Top of Producing Interval). Item 8: 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 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. Item 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 23: 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 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut -in, or Other (explain). Item 27: 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 29: Provide a list of intervals tested and the corresponding formation, and a brief summary of this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 N.,, KU ID 2A -27 COCIOCOPFI��pS , Well Attributes M ax Angle & MD TD r `k Wellbore API/DWI Field Name Well Status Inc! ( °) MD (ftKB) Act Btm (ftKB) Alaska, inc. urc:curtxiups 501032060400 KUPARUK RIVER UNIT SVC 56.40 6,980.00 7,250.0 ;. Comment H2S (ppm) Date Annotation End Date KB-Grd (ft) Rig Release Date ' SSSV: NONE Last WO: 34.00 12/11/2009 Conk: Con. DEVIATED • 24-27, 10/7/2012 9:08:35 AM _ - Schematic - Actual Annotation Depth (ftKB) End Date Annotation _ Last Mod ... End Date Last Tag: WLM 6,602.0 9/18/2012 Rev Reason: TAG ninam 10/7/2012 _ Casing Strings r Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) .. String Wt... String String Top Thrd HANGER, 31 c r SURFACE 133/8 12.412 34.6 3,374.0 2,930.6 68.00 L - 80 TC - I I Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd � , ! INTERMEDIATE 95/8 8.835 33.3 6,849.0 5,171.7 40.00 L - 80 BTCM "" Casing Description String 0... String ID ... Top (ftKB) Set Depth (f... Set Depth (TVD) ... String Wt... String ... String Top Thrd filt LINER 7 6.276 6,694.5 7,248.0 5,417.3 26.40 L -80 Liner Details Cli :t Top Depth (TVD) Top In d Nom . ,.. _ Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 6,694.5 5,076.8 53.18 PACKER BAKER C -2 ZXP LINER TOP PACKER 6.280 $ ,. 6,714.1 5,088.7 52.12 HANGER LINER HANGER 6.210 3 - 7,164.8 5,359.3 48.13 CEMENT Halliburton ES Cementer 6.375 7,177.6 5,367.8 47.39 ECP Baker Payzone ECP 6.260 7,245.0 5,415.2 44.45 COLLAR Halliburton Baffle Collar 6.188 Tubing Strings Tubing Description String 0... String ID ...Top (ftKB) Set Depth (1... Set Depth (TVD) ... String Wt... String ... String Top Thrd KILL STRING 1 4 1/2 I 3.958 I 30.7 I 2068.0 1,963.7 12.60 I L -80 I IBTM Completion Details Top Depth NIPPLE, 2,059 - - (TVD) Top Inc! N ooml... ` `. Top (ftKB) (ftKB) ( °) Item Description Comment ID (in) 30.7 30.7 -0.01 HANGER FMC TUBING HANGER 4.500 2,059.4 1,956.8 37.14 NIPPLE - CAMCO DB NIPPLE NO GO PROFILE 3.875 2,066.7 1,962.6 37.29 WLEG WIRELINE ENTRY GUIDE 3.958 WLEG, 2,067 Y • Perforations & Slots Shot Top (TVD) 8tm (TVD) Dens Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Zone Date (s Type Comment 7,241 7,256 5,412.3 5,423.0 Camp_SST, 12/6/2009 5.0 RPERF All PERFS intended to shoot holes in 2A -27 2A-06 for cementing; 120 orient, 0 degree phase 7,244 7,259 5,414.4 5,425.1 Camp_SST, 12/4/2009 12.0 IPERF All PERFS intended to shoot holes in 2A -27 2A -06 for cementing; .34" gun, 45 degree phase SURFACE. _° 35 -3074 Cement Squeezes Top Depth Btm Depth (TVD) (TVD) Top (ftKB) Btm (ftKB) (ftKB) (ftKB) Description Start Date Comment 4,392.0 6,292.0 3,638.6 4,837.8 Cement Squeeze 11/27/2009 Open by -pass on pkr. Shut -in 2A -06. Close annular F.'"! li preventer. Tested cement lines to 2000 psi. 50 Cement bbls l 12.0 ppg fo by 10 bbl 12.0 ppg Squeeze a3sz % mud push. Held 150 psi back pressure on choke '0 while 2A -06 annulu th 35 bbls 13.0 ppg OBe cement and a dd 118 bbls 11.8 ppg OBM. Shut -in both wells. (SIP on 2A -27 = 250 psi. 2A -06 = 150 psi. / 6,692.0 7,271.0 5,075.4 Cement Plug 12/8/2009 Help PJSM on laying cmt plug with Dowell and all I 1'. hands, Batch mix cement & Spacer (Cement batched j at 19:40 hrs), Switch over to Dowell, Pump 2 bbls 13.5 ppg MudPUSH, Test lines to 2000 psi - OK, Continue to Total of 9 bbls 13.5 ppg MudPUSH at 6 rate of 2.4 bpm @ 160 psi, followed by 25 bbls (121 ,0 }I sxs) 15.8 ppg Cement at rate of 4.0 bpm @ 225 psi, fi ! Followed cmt w/ 1 bbl 13.5 ppg MudPUSH at rate of 2.2 bpm @ 160 psi, Switch over to rig & displace . cement w/ 110 bbls 11.8 ppg OBM at rate of 9 bpm n @ 1150 psi - CIP @ 20:25 hrs. NTERM -6,8 9 Notes: General & Safe ety End Date Annotation 12/11/2009 NOTE: Well drilled to cement off 2A -06 with perforations cement squeezed kill string in hole • LINER, _ 6.694-7,248 ..... RPERF, - 7,241- 7,256 TO. 7.250 IPERF, 7,244 -7,259 Cement Plug. 6,692 • • • ConocoPhilli s Time Log & Summary p We1Mew Web Reporting Report Well Name: 2A - 27 Rig Name: DOYON 141 Job Type: DRILLING SIDETRACK Rig Accept: 12/2/2012 9:00:00 PM Rig Release: 12/22/2012 3:00 :00 PM Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/01/2012 24 hr Summary Move Rig & Camp f/ 3C -11 t/ 2A -27, spot rig and R /U, rig accepted @ 2100 hrs. R/U t/ displace freeze protect. 00:00 02:30 2.50 MIRU MOVE MOB P Move pipe sheds & rock washer, move & stage complexes on pad. 02:30 08:30 6.00 MIRU MOVE MOB P Move complexes f/ 3C -11 t/ 2A pad 08:30 09:00 0.50 MIRU MOVE MOB P Pull sub off of 3C -11 09:00 12:00 3.00 MIRU MOVE MOB P Move sub & pipe sheds f/ 3c pad t/ 2A pad 12:00 16:00 4.00 MIRU MOVE MOB P Spot sub over 2A -27A, spot pipe sheds, power pack & rockwasher 16:00 21:00 5.00 MI RU MOVE MOB P Work on rig acceptance, simops move camp f/ 3C pad U 2A pad. Rig accepted @ 2100 hrs 21:00 00:00 3.00 SLOT WHDBO RURD P Install secondary IA valve, R/U circ lines in cellar, simops spot tiger tank & hook up hard lines. 12/02/2012 Pull BPV, R/U cellar lines attempt t/ Displace freeze protect, VR plugs in IA, Pull VR plugs displace freeze protect, OWFF f/ 30 min well static, Set TWC N/D tree & adaptor flange, N/U BOP & riser, Change rams, & saver sub, Rig up and test BOPE 00:00 03:30 3.50 0 0 SLOT WELCTL RURD P Continue R/U hardlines t/ choke house & tiger tank, Simops take on sea water to pits, test lines t/ tiger tank t/ 2500 psi, test Mud pumps t/ 3500 psi, Pull BPV 03:30 05:30 2.00 0 0 SLOT WELCTL CIRC P Attempt t/ displace freeze protect unable t/ pump, VR plugs still in Both IA valves. 05:30 07:15 1.75 0 0 SLOT WELCTL OTHR P R/U & pull VR plugs 07:15 08:30 1.25 0 0 SLOT WELCTL CIRC P Displace freeze protect @ 210 gpm 450 psi, to tiger tank, pump 220 bbls 8.5 ppg sea water. 08:30 09:30 1.00 0 0 SLOT WELCTL OWFF P Blow down lines observe well for flow f/ 30 min, well static. 09:30 10:30 1.00 0 0 SLOT WELCTL OTHR P Set TWC test t/ 1000 psi in direction of flow & f/ top down. 10:30 12:00 1.50 0 0 SLOT WHDBO NUND P Nipple down tree & adaptor flange. 12:00 12:15 0.25 0 0 SLOT WHDBO OTHR P Inspect threads on hanger & prep 9 5/8 casing spool 12:15 14:15 2.00 0 0 SLOT WHDBO NUND P Nipple up adaptor flange & BOP, Riser & flow lines. 14:15 17:45 3.50 0 0 SLOT WHDBO NUND P Change rams in upper and lower cavities t/ 3.5 x 6 in upper and 2 7/8 x 5 in lower rams. Simops C/O saver sub. Page 1 of 22 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 17:45 20:30 2.75 0 0 SLOT WHDBO RURD P Clear Floor R/U t/ test BOP's, R/U test equipment. (OA Pressure was 280 psi and bled down to zero) 20:30 00:00 3.50 0 0 SLOT WHDBO BOPE P Test BOPE with 4.5" test joint to 250 / 3500 psi and record on chart. Test # 1: Upper 3.5 x 6" VBR, Choke valves 1, 12, 13, 14 & manual kill valve. Test # 2: Upper IBOP, HCR kill, choke valves 9 & 11. Test # 3: Choke valves 5, 8 & 10. Test # 4: Choke valves 4, 6 & 10. Test # 5: Choke valve 2 (Lower IBOP failed several attempts) Test # 6: HCR choke & 4" kill line demco valve. (Test witness waived by AOGCC John Crisp) 12/03/2012 Continue testing BOP's, M/U landing jt pull hanger t/ rig floor, Pull Kill string out of hole total recovered 2068', bullhead 60 bbls 9.6 ppg brine down OA, OWFF , flowing, Bullhead 35 bbls 8.6 ppg sea water down OA, OWFF 00:00 03:30 3.50 0 0 SLOT WHDBO BOPE P Continue testing BOP's test all rams ann. & choke valves 1 -14 t/ 250/3500 accumulator test, (Test witness waived by John Crisp) 03:30 04:00 0.50 0 0 SLOT WHDBO OTHR P Blow down lines choke & kill R/D test equip. 04:00 04:45 0.75 0 0 SLOT RPCOM OTHR P Drain stack pull TWC 04:45 06:00 1.25 0 0 SLOT RPCOM RURD P R/U t/ pull kill string, M/U landing jt. BOLDS 06:00 06:45 0.75 0 2,318 SLOT RPCOM PULL P Pull hanger t/ rig floor monitor well static 06:45 10:30 3.75 2,318 0 SLOT RPCOM PULL P L/D 4.5 kill string 66jts. X nipple mule shoe total length pulled 2068'. 10:30 12:00 1.50 0 0 SLOT RPCOM RURD P R/D tubing equipment, clear floor. 12:00 13:00 1.00 0 0 SLOT RPEQP1OTHR P Mix 60 bbls of 9.6 ppg brine. 13:00 13:45 0.75 0 0 SLOT RPEQP1CIRC P Bullhead 60 bbls of 9.6 ppg brine down OA 126 gpm 1200 psi broke over @ 1100 psi 13:45 15:00 1.25 0 0 SLOT RPEQP1 OWFF P Bleed off and Monitor well, 13.7 bbls back. 15:00 16:30 1.50 0 0 SLOT RPEQP1 OWFF P Observe well for flow well folwing back @ 1.15 bph slowed t/.7 bph no change 16:30 17:00 0.50 0 0 SLOT RPEQP1CIRC P Bullhead 35 bbls 8.6 sea water down OA @ 84 gpm 1050 psi broke over @ 1050 psi. 17:00 00:00 7.00 0 0 SLOT RPEQP1OWFF P Observe well for flow, 20.4 bbls back in 7 hours, flow decreased to .29 BPH, SIMOPS work on MP2's clean and organize rig. 12/04/2012 Monitor OA till 14:00 hrs (flow down to .14 bph) R/U to lubricate and bleed as per - schedule, R/U and test BOPE with 5" test Jt., Set wear ring, Cont. lube & bleed, M/U scraper BHA with upper mill 8 -3/4" OD, would not past pack -off inner lip, call town, L/D upper mill and RIH with scraper and P/U 5" dp from shed. Page 2 of 22 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 00:00 12:00 12.00 0 0 SLOT RPCOM OWFF P PJSM, Monitor OA flowing back ,@ .27 bph, SIMOPS scrub rig, work on MP2's, Flow rate slowed to .14 bph in 12 hrs. 12:00 14:00 2.00 0 0 SLOT RPCOM KLWL P MONITOR WELL, FLOW DN TO 0.15 BHP 14:00 16:30 2.50 0 0 SLOT RPCOM KLWL P R/U LINES F/ LUBRICATE & BLEED W/ 10 BBL WEIGHTED SEA H2O @ 2 BPM DN OA. 1150 PSI BROKE OVER, SHUT IN & WAIT 30 MIN PRESSURE HELD @ 600 PSI, BLEED OFF F/ 15 MIN, SHUT IN & MONITOR PRESSURE F/ 15 MIN, GAINED 15 PSI, BULL HEAD ADDITIONAL 10 BBL. BROKE OVER W/ 950 PSI. SIMPOPS P/U & RACK BACK 3 STDS OF 6 3/4 DC & 1 STD HWDP. 16:30 17:15 0.75 0 0 SLOT RPCOM BOPE P R/U TEST EQUIP. & 5" TEST JT 17:15 18:30 1.25 0 0 SLOT RPCOM BOPE P BOPE TEST: LWR 2 7/8x5" VBR, UPPER 3.5x6" VBR & ANNULAR W/ 5" TEST JT TO 250/3500 PSI F/ 5 MIN EA. 18:30 18:45 0.25 0 0 SLOT RPCOM BOPE P R/D TEST EQUIP. 18:45 19:00 0.25 0 0 SLOT RPCOM OTHR P SET WEAR BUSHING, ID 12 7/16" 19:00 19:30 0.50 0 0 SLOT RPEQP1OWFF P CONT. LUBE & BLEED SCHEDULE 19:30 21:15 1.75 0 0 SLOT RPEQP1PULD P PJSM, M/U SCRAPER ASSY. 8.75" OD STRING MILL TAGGED UP ON PACKOFF INNER LIP (8.77 ID), P/U AND RACK BACK STAND OF DC's, REGAUGE STRING MILL (GOOD) 21:15 22:45 1.50 0 0 SLOT RPEQP1PULD T P/U SINGLE HWT AND M/U TOP DRIVE WAIT ON ORDERS. 22:45 00:00 1.25 0 125 SLOT RPEQP1PULD T UD SINGLE AND STRING MILL & RIH WITH SCRAPER bha # 2 TO 125 and 12/05/2012 Cont. RIH P/U singles with scraper BHA T/ 6687' MD, swap well over to 8.5 ppg sea water, spot 95 bbls 9.0 corrosion inhibitor brine, POOH, L/D scraper, R/U & pull 9 5/8 pack -off found seals damaged, M/U Baker swedge and drift top of stub no issues, attempt setting new pack -off, no go, wait on new pack -off, wash around stub & vac out around stub. 00:00 00:30 0.50 125 769 SLOT RPCOM OWFF P PJSM - CONT. M/U BHA T/ 769' MD. PUMP 9.6 PPG KWF DOWN OA EVERY 1.5 HRS @ 2BPM, 900 PSI, SHUT IN F/ 0.5 HR BLEED OFF F/ 15 MIN, TAKE READINGS X3. OPEND OA T/ TRIP TANK AND MONITORED 6.7 BBL GAIN. 00:30 06:30 6.00 769 5,500 SLOT RPCOM TRIP P CONT. SINGLE IN HOLE W/ SCRAPER ASSEMBLY T/ 5500'MD, P /U =150K, S/0 =100K 06:30 07:30 1.00 5,500 5,400 SLOT RPCOM CIRC P BREAK CIRC@ 5500'MD, ROT /RECIP T/ 5400' X 3, PUMP 550 GPM, 1800 PSI, ROT 30 RPM, TQ =5 -6K, ROT WGHT =126K. Page 3 of 22 • 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 07:30 09:00 1.50 5,400 6,604 SLOT RPCOM TRIP P BD TD, CONT RIH T/ 6604'MD, P /U =150K, S/O =100K . CAL DISP =70.1 BBL, ACTUAL =70.6 BBL 09:00 10:00 1.00 6,604 6,687 SLOT RPCOM WASH P BREAK CIRC. WASH T/ 6661'MD @ 2BPM, 150 PSI HIT FILL © 6661' MD. INCREASE PUMP T/ 500 GPM, WASH T/ 6687' MD TAG TOC.WOB 2 -10K, TAG CMT 3 TIMES. P /U =170K, S/O =115K 10:00 10:45 0.75 6,687 6,687 SLOT RPCOM CIRC P CBU @500 GPM, 1700 PSI. RECIP PIPE. 10:45 12:00 1.25 6,687 6,687 SLOT RPCOM CIRC P PJSM - DISPLACE WELL OVER T/ CLEAN 8.5 SEA H2O @ 6 BPM, 900 PSI, RECIP PIPE. 12:00 13:00 1.00 6,687 6,687 SLOT RPCOM CIRC P CONT. DISP. WELL W/ CLEAN 8.5PPG SEA H20@ 14 BPM 2000 PSI, PUMP 90 BBL 9.0 PPG CORROSION INHIB. PILL @ 4.5 BPM 200 PSI & SPOT W/ 92 BBL OF CLEAN SEA H20. 13:00 13:15 0.25 6,687 6,657 SLOT RPCOM OWFF P PULL STD & OBSERVE FLUID DROP IN HOLE, BLOW DN T/D & MONITOR WELL (STATIC). 13:15 16:45 3.50 6,657 57 SLOT RPCOM TRIP P POOH F/ 6600' & L/D SCRAPER ASSY. FILL F/ TRIP = ACT 68.15 BBL, CALC 66.79 BBL 16:45 17:15 0.50 57 _ 0 SLOT RPCOM OTHR P PULL WEAR BUSHING 17:15 18:30 1.25 0 0 SLOT RPCOM OTHR P M/U PACKOFF RETRIVAL TOOL & PULL PACKOFF W/ 25K O /P, PULL TO FLOOR & INSP. SIGNIFICANT SEAL DAMAGE. 18:30 20:30 2.00 0 0 SLOT RPCOM OTHR P WAIT ON BOT SWEDGE, SIMOPS CLEAN FLOOR, SERVICE RIG 20:30 21:00 0.50 0 0 SLOT RPCOM PULD P P/U BOT SUBS 21:00 21:15 0.25 0 0 SLOT RPCOM OTHR P M/U 8 3/4" SWEDGE ON SINGLE & DRIFT TOP OF CSG STUB (GOOD). 21:15 21:45 0.50 0 0 SLOT RPCOM PULD P L/D BOT SUBS. 21:45 22:15 0.50 0 0 SLOT RPCOM OTHR T PJSM, ATTEMPT TO SET NEW PACK -OFF W /30K X 2 WITH NO SUCCESS, PULL TO FLOOR & INSPECT AND FOUND DAMAGE SEALS. 22:15 00:00 1.75 0 0 SLOT RPCOM OTHR T PJSM, ATTEMPT TO SET NEW PACKOFF NO GO, ELVAUATE OPTIONS, WAIT ON NEW PACK -OFF, OBSERVED SLUDGE AND SAND AROUND OUTSIDE OF STUB CLEAN OUT WITH VAC & RINSE, FILL STACK WITH SEA WATER, OBSERVED CASING SPOOL PLUGGED OFF BETWEEN IA & OA, CONT. ATTEMPT TO ESTABLISH COMMUNICATIONS BETWEEN ANNULUS WITH PACK -OFF OUT. Page 4 of 22 • 1 Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 12/06/2012 24 hr Summary Continue flush & clean casing stub. Install new 9 5/8" packoff, RILDS and test same to 2470 PSI. Install Wear bushing - ID = 12 7/16". Test casing to 1500 PSI - 30 minutes on chart. Good test. Pump 10 BBLS of 8.6 PPG seawater down OA at 2 BPM - 880 PSI. Continue freeze protect OA with diesel with LRS pumping 90 BBLS diesel at 1.25 BPM - 950 PSI. FCP = 800 PSI. Make dummy run with 8.75" OD string mill. Slip & cut Drilling line. RU HES wireline crew and wireline in hole with 9 5/8" K -1 Cement retainer. Correlate & set retainer 6' from collar at 5483' WLM. WLOH, RD HES. Test casing & Plu9 to 2500 PSI, 30 min on chart. Good test. Held PJSM. Make up 9 5/8" whipstock assembly, orient whipstock face to high side at 45° R, MU BHA, and TIH. Pulse test MWD. Continue trip in hole at 2 minutes / stand. 00:00 02:15 2.25 0 0 MIRU RPCOM SEQP P Continue flush and clean 9 5/8" casing stub. Make a dummy run with 9 Y old packoff. Observed when running new packoff, damaged seals. Install new packoff as per FMC rep. Set down 30K to verify set and located. 02:15 03:00 0.75 0 0 MIRU RPCOM SEQP P RILDS. Rig up and test 9 5/8" packoff to 2470 PSI, 10 minute test witnessed by Co. Rep. Good test. 03:00 03:30 0.50 0 0 MIRU RPCOM OTHR P Install wear bushing. ID = 12 7/16". RILDS. 03:30 04:30 1.00 0 0 MIRU RPCOM PRTS P Rig up, and test casing to 1500 PSI. 30 minutes on chart - good test. 04:30 05:00 0.50 0 0 MIRU RPCOM OTHR P Rig up and pump 10 BBLS of 8.5 PPG seawater down OA at 2 BPM - 880 PSI. 05:00 05:30 0.50 0 0 SLOT RPCOM OTHR P Make up 8 4/4" OD string mill. RIH to 35' with no issues through packoff and casing stub. POOH lay down mill. 05:30 05:45 0.25 0 0 SLOT RPCOM SVRG P Held PJSM. Dicuss safety & hazard recognition issues. Discuss procedure to slip & cut drilling line. 05:45 07:30 1.75 0 0 SLOT RPCOM SVRG P Slip & cut 42' of drilling line. Service top drive and drawworks. Inspect brakes. 07:30 08:00 0.50 0 0 SLOT RPCOM FRZP P Spot Little Red services. Held PJSM. Rig up lines. 08:00 09:00 1.00 0 0 SLOT RPCOM FRZP P Load and test lines to 2500 PSI. Pump 90 BBLS of diesel down OA at 1.25 BPM. ICP = 950 PSI. FCP - 800 PSI. Shut in PSI on OA - 660 PSI. Held PJSM - SIMOPS mtg with HES wireline crew and BOT rep. Spot HES E -line unit. 09:00 10:45 1.75 0 0 SLOT RPCOM PACK P Hang sheaves, and rig up e- liners. Make up BOT K -1 Wireline set cement retainer on wireline. 10:45 11:15 0.50 0 0 SLOT RPCOM PACK P WLIH with retainer to 500'. Observed CCL not working. POOH. 11:15 12:00 0.75 0 0 SLOT RPCOM PACK T Trouble shoot tool string. Could not fiind any issues with the tool. Crew change 12:00 13:15 1.25 0 0 SLOT RPCOM PACK P WLIH with tools string to correlate. Observed CCL working good. Log to correlate casing collar depths. Locate & set cement retainer at 5483' WLM, 6' above collar. Page 5 of 22 • • Time Logs Date From To Dur S. Depth E. Depth Phase _Code Subcode T Comment 13:15 14:00 0.75 0 0 SLOT RPCOM PACK P WLOH, and rig down HES wireline crew and equipment. 14:00 14:45 0.75 0 0 SLOT RPCOM PRTS P Rig up lines, and pressure test casing and plug to 2500 PSI. 30 Minutes on chart - good test. 14:45 15:15 0.50 0 0 SLOT RPCOM SFTY P Held PJSM with crew, Sperry Sun and BOT reps. Discuss safety and hazard recognition issues. Discuss procedure to make up 9 5/8" whipstock assembly. 15:15 17:00 1.75 0 0 SLOT RPCOM PULD T Make up 9 5/8" whipstock assembly with flex joint as per BOT and Sperry reps. Orient MWD to whipstock face with offset at 238.96 Deg. 17:00 18:15 1.25 0 950 SLOT RPCOM PULD P Make up remaining BHA with Drill collars and HWDP. Total BHA length with whipstock - 832.35'. Makeup one stand of 5" drill pipe. 18:15 18:30 0.25 950 950 SLOT RPCOM TRIP P Screw into top drive and perform pulse test on MWD assembly. Pumps at 350 GPM - 500 PSI. Good test. 18:30 21:45 3.25 950 5,450 SLOT RPCOM TRIP P Continue trip in hole with whipstock assembly at 2 minutes / stand as per BOT rep. Observed proper displacement. 21:45 22:15 0.50 5,450 5,476 SLOT RPCOM WPST P Screw into top drive. Pumps at 350 GPM's- 650 PSI. Orient whipstock face to 45 deg right of high side as • per plan. Slack off to tag wireline set plug at 5476'. Set down to shear bolt at 35K. Work string to verify free of whipstock. Top of whipstock - 5454' 22:15 23:30 1.25 5,454 5,454 SLOT RPCOM CIRC P Position window mill above whipstock. Held PJSM with crew - discuss safety & hazard recognition issues. Discuss procedure to complete displacement and mill window, and displace well with 9.5 PPG milling fluid with 1.25% tube. p Pumps at 400 GPM's - 780 PSI. t �� Obtain SRPs @ 5454' MD, TVD _ _4335'MD MWT 9.5 ppg. _ 23:30 00:00 0.50 5,454 5,454 SLOT RPC • M WPST P Begin milling window at 5454' MD, Mill with 9ORPM's, WOB - 2 K Torque = 5/10 K GPM= 420, Pressure= 900. Observed good metal �� cuttings in returns. Pump super sweeps as needed. 12/07/2012 Finish milling window, mill new hole to 5480' circ & cond due to air in mud, take on another 100 bbls new milling mud and blend in system, cont milling new hole to 5493' MD, pull back to 5440' MD and perform leak off test broke over @ 1250 psi, POOH & L/D mills, Mills in gage, M/U stack washer and flush out BOP's 00:00 06:00 6.00 5,454 5,471 SLOT RPCOM OTHR P PJSM, Mill window F/ 5454' T/ 5471' MD, 120 SPM, 490 GPM, 1000 psi, RPM =100, TQ= 2 -14K, WOB= 4 -8K, pump 20 bbl super sweep @ 5459' MD, Recovered 400 lbs of metal Page 6 of 22 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:00 09:45 3.75 5,471 5,480 SLOT RPCOM OTHR P Cont. milling through window with upper mil and drill new hole T/ 5480' MD, @ 400 gpm, 800 psi, 100 RPM, TQ= 6K, WOB= 10 -25K, attempt different drilling parameters due to slow ROP. 09:45 11:00 1.25 5,480 5,450 SLOT RPCOM CIRC P Pulled back to 5450' MD, circ & cond mud, aired up mud, 6.5 bpm 270 gpm, 350 psi. 11:00 12:00 1.00 5,450 5,450 SLOT RPCOM OTHR P Take on 100 bbl of new 9.5 ppg mill fluid & blend in system. 12:00 16:30 4.50 5,450 5,493 SLOT RPCOM OTHR P Cont. milling new hole F/ 5480' T/5493' MD, RPM =120, 450 gpm, 1125 psi, WOB= 25K, Tq= 8K, pumped 20 bbl super sweep, P/U & ream through window x 4, x 2 with no rotation or pump. 16:30 17:00 0.50 5,493 5,440 SLOT RPCOM TRIP P Rack back stand to 5440' MD & blow down Top Drive, R/U head pin and cement line for FIT. 17:00 17:30 0.50 5,440 5,440 SLOT RPCOM LOT P Preform leak -off test with 1 bpm, broke over @ 1250 psi, pumped 6 bbl total, shut in & held for 10 min 1100 psi final pressure. 17:30 18:00 0.50 5,440 5,440 SLOT RPCOM OWFF P R/D lines and monitor well. (Static) 18:00 23:00 5.00 5,440 0 SLOT RPCOM TRIP P PJSM, POOH with milling BHA F/5440' MD T/4050' MD, pumped dry job, cont POOH to suface and L/D BHA. Act= 60.94 bbl, Calc= 56.97 bbl. 23:00 23:15 0.25 0 0 SLOT RPCOM OTHR P Clean and clear rig floor. 23:15 00:00 0.75 0 0 SLOT RPCOM OTHR P M/U stack washer and flush out BOP's with 20 bpm 100 psi. 12/08/2012 P/U and run magnet BHA to 5493' MD. Displace 9.5ppg milling fluid with 9.6ppg LSND mud; monitored static well. POOH. P/U and run drilling BHA T/ 2425' Service Top Drive, Continue TIH T/ 5389' Oreint 45R and slide through window, No issues, Establish PWD baseline. 00:00 00:15 0.25 0 0 SLOT RPCOM SFTY P PJSM ON M/U MAGNET BHA. (BLOW DOWN T.D.) 00:15 01:45 1.50 0 832 SLOT RPCOM PULD P M/U MAGNET BHA AS PER BAKER REP. 01:45 03:15 1.50 832 2,869 SLOT RPCOM TRIP P SINGLE IN HOLE F/ 832' MDT/ 2869' MD, (66 JTS) 03:15 05:00 1.75 2,869 5,454 SLOT RPCOM TRIP P RIH F/ 2869' MDT/ 5454' MD, FILL EVERY 25 STDS. CALC DISP = 60.29, ACT DISP = 54.83. 05:00 06:00 1.00 5,454 5,493 SLOT RPCOM TRIP P CONT RIH T/ 5475' MD, WOB = 10K, REAM F/ 5475' MD T/ 5493' MD W/ 80 RPM, TQ = 7K, WOB = 5 -10K, 420 GPM, 1700 PSI. INCREASED TO 100 RPM, TQ = 9.5K, WASH AND REAM F/ 5475' - 5493' MD SEVERAL TIMES, P/U T/ 5465' MD AND SLIDE BACK DOWN T/ 5493' MD (NO ROT). 06:00 06:15 0.25 5,493 5,493 SLOT RPCOM SFTY P PJSM ON DISPLACING THE WELL Page 7 of 22 • • Time Logs Date From To Dur S. Depth E. Depth Phase Code Subcode T Comment 06:15 07:15 1.00 5,493 5,493 SLOT RPCOM CIRC P TREAT NEW LSND MUD IN PIT #5 AS PER MI REP. 07:15 08:45 1.50 5,493 5,493 SLOT RPCOM CIRC P DISPLACE 9.5PPG MILLING FLUID W/ 9.6 PPG LSND MUD @ 6 BPM, 700 PSI, 40 RPM, TQ =5K 08:45 09:30 0.75 5,493 5,454 SLOT RPCOM OWFF P SET BACK STD, MONITOR WELL, (STATIC) BLOW DOWN T.D., CLEAN UNDER SHAKERS, EMPTY OUT T.T., AND FILL W/ 9.6 PPG LSND MUD. 09:30 12:00 2.50 5,454 832 SLOT RPCOM TRIP P POOH F/ 5454' MD, T/ 832' MD. CALC FILL = 39, ACT FILL = 40.63. 12:00 14:00 2.00 832 0 SLOT RPCOM PULD P RACK BACK HWT. UD DRILL COLLARS AND CLEAN OUT BHA. 14:00 14:30 0.50 0 0 SLOT RPCOM OTHR P CLEAR AND CLEAN RIG FLOOR. 14:30 17:00 2.50 0 141 PROD1 DRILL PULD P PJSM, M/U DRILLING BHA.106' 17:00 17:45 0.75 141 141 PROD1 DRILL PULD P UPLOAD MWD DATA 17:45 18:30 0.75 141 141 PROD1 DRILL CIRC P SHALLOW PULSE MWD W/ 450 GPM 100 PSI, BLOW DOWN TOP DRIVE. 18:30 19:00 0.50 141 141 PROD1 DRILL PULD P PJSM, P/U AND LOAD NUCLEAR SOURCES. 19:00 20:45 1.75 141 2,425 PROD1 DRILL TRIP P TIW WITH DRILLING BHA F/ 141' T/2425' 20:45 21:15 0.50 2,425 2,425 PROD1 DRILL SVRG P SERVICE TOP DRIVE SWIVEL AND ROLLERS. 21:15 23:00 1.75 2,425 5,389 PROD1 DRILL TRIP P TIH F/ 2425' T/ 5389' MD, ACT= 52.8 BBL, CALC= 53.58 BBL. 23:00 23:30 0.50 5,389 5,493 PROD1 DRILL CIRC P M/U TOP DRIVE, P /U= 140K, S /0= 115K, 450 GPM= 1600 PSI, ORIENT TOOLFACE 45° R AND SLIDE THROUGH WINDOW T/ 5493' 23:30 00:00 0.50 5,493 5,493 PROD1 DRILL CIRC P ESTABLISH PWD BASELINE W/ 450 GPM, 1450 PSI, 500 GPM, 1700 PSI, 550 GPM, 2000 PSI. 12/09/2012 Drill f/ 5493' MD - 6930' MD. TVD - 5405' 00:00 06:00 6.00 5,493 5,849 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 5493' - 5849'. TVD = 4589'. Pumps at 550 GPM's PSI= 1950, WOB - 5/10K . PU Wt = 143K, SO WT = 120K, ROT WT - 131 K. TQ ON - 5 -8 Ft LBS, TQ OFF - 4 Ft LBS. RPM's - 60. Jar HRS - 4.75. BIT HRS - 4.75. ECD - 10.39 PPG. ART= 2.86, AST= 1.71, ADT= 4.57 06:00 12:00 6.00 5,849 6,218 PROD1 DRILL DDRL P Directional drill 8 3/4" hole from 5849' - 6218.0. TVD = 4854'. Pumps at 550 GPM's PSI= 2100, WOB - 3/7K. PU Wt = 146K, SO WT = 122K, ROT WT - 135K. TQ ON - 8 Ft LBS, TQ OFF - 4.5 Ft LBS. RPM's - 100. Jar HRS - 7.53. BIT HRS - 7.53. ECD - 10.48 PPG. ART= 1.90, AST= 1.06, ADT= 2.96 Page 8 of 22 110 • Z 2- 0 5 -VD7 1 93o WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. September 28, 2012 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: Temperature / Pressure Survey: 2A -27 Run Date: 9/18/2012 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 2A -27 Digital Data in LAS format, Digital Log Image file 1 CD Rom 50 -103- 20604 -00 Temperature / Pressure Survey Log 1 Color Log 50- 103 - 20604 -00 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 201'4, 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907-273-3535 • klinton.wood @halliburton.com Date: .0 k2( 12- L k) Sied: • • [I5 ALASKA SEAN PARNELL, GOVERNOR ALASKA OIL AND GAS 333 W. 7th AVENUE, SUITE 100 CONSERVATION COMMISSION ANCHORAGE, ALASKA 99501 -3539 PHONE (907) 279 -1433 FAX (907) 276 -7542 Haibin Guo Drilling Engineer ConocoPhillips Alaska, Inc. ; a 0 P.O. Box 100360 a0 Anchorage, AK 99510 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2A -2�7 Sundry Number: 312 -294 �� L'� Dear Mr. Guo: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy . Foerster h� Chair DATED this 2 day of August, 2012. Encl. f i 1 STATE OF ALASKA MI j a S g l �' ),� AKA OIL AND GAS CONSERVATION COMMI ION APPLICATION FOR SUNDRY APPROVALS 20 AAC 25.280 1. Type of Request: Abandon r Plug for Redrill F7 • Perforate New Pool r Repair w ell r Change Approved Program r Suspend r Plug Perforations r Perforate r Pull Tubing r Time Extension r Operational Shutdow n r Re -enter Susp. Well 1't'''' Stimulate r Alter casing r Other: r 2. Operator Name: 2A -27 4. Current Well Class: 5. Permit to Drill Number: ConocoPhillips Alaska, Inc. Developrnent r Exploratory r 209 - 107 • 3. Address: Stratigraphic r Service 6. API Number: P. O. Box 100360, Anchorage, Alaska 99510 50 103 - 20604 - 00 7. If perforating, closest approach in pool(s) opened by this operation to nearest property line 8. Well Name and Number: where ownership or landownership changes: Spacing Exception Required? Yes r No P/ 2A -27 . 9. Property Designation (Lease Number): 10. Field /Pool(s): ! " ° �C 7$70 KuparukRiverField /KuparukRiverOilPool - 11. ,,LP . (, rL PRESENT WELL CONDITION SUMMARY Total depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 7271. 5434 . Casing Length Size MD TVD Burst Collapse SURFACE 3339 13.375 3374' 2931' 5020 2260 INTERMEDIATE 6816 9.625 6849' 5171' 5750 3090 LINER 554 7 7248' 5417' 7240 5410 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 7241 - 7259 5412 - 5425 4.5 L - 2067 Packers and SSSV Type: Packers and SSSV MD (ft) and TVD (ft) HANGER - FMC TUBING HANGER MD= 31 TVD= 31 NIPPLE - CAMCO DB NIPPLE NO GO PROFILE MD= 2059 TVD= 1957 RECEIVED WLEG - WIRELINE ENTRY GUIDE MD= 2067 TVD= 1963 1 12. Attachments: Description Summary of Proposal r 13. Well Class after proposed work: AUG 0 1 2012 Detailed Operations Program P' BOP Sketch r Exploratory r Dgreor ((�� o Senrice 14. Estimated Date for Commencing Operations: 15. Well Status after proposed work: //�� . September 27th, 2012 Oil r Gas r WDSPL r Suspended /Q I ,ty 16. Verbal Approval: Date: WINJ r GINJ r WAG r Abandoned ' Commission Representative: GSTOR r SPLUG r 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Haibin Guo Printed Name Haibin Guo Title: Drilling Engineer Signature fr-j j. . Phone: 265 -1487 Date: 08/01/2012 Commission Use Only Sundry Number: : 3 1 2 , 2g q Conditions of approval: Notify Commission so that a representative may witness �� Plug Integrity r BOP Test Mechanical Integrity Test r Location Clearance r Other: p l Subsequent Form Required: /0. Li 6 7- il / L._. — APPROVED MM Approved by P S S P -2 _ 1 / COMMISSIONER THE COMMISSION Date: L_ I/ DIMS AUG 0 3 1312 8-/ V Form 10 -403 Revised 1/2010 °�'y, I G I I Y A L , ubmi in Duplicate . , • • 2A -27 Plug Back for Redrill The objective of the proposed 2A -27 Plug Back is to prepare the well for the rotary side track planned for September 2012, which will include drill through C&A sands, run liner, perforate liner and run selective water injection string. This will provide water flood support to 2A -10, 2A -05, 2M- 21, 2A -24, 2A -17, 2A -12, 2A -11 and 2A -19, in an area with limited to no active water flood. 2A - 27 Plug back Program (to mill window plus 20' of new formation) 1. Move Doyon 141 on 2A -27and rig up. 2. Pull BPV. Record tubing, IA, and OA pressures. Circulate out freeze protect through tubing cut and monitor well for pressure. 3. Set BPV and nipple down tree. M/U blanking plug in tubing hanger and nipple up BOPE. • Notify AOGCC field inspector 24 hours prior to BOPE test. • Test BOPE to 250 psi low /�,,3 si high as per drilling permit. • BOP test cycle is one week until mill window to 20' new formation. • Upper pipe ram will be 3 -1/2" X 7" VBR. • Lower pipe ram will be 2 -7/8" X 6" VBR. • A FOSV is to be kept on the floor at all times with pertinent X/Os for DP or casing thread in rotary table. 4. Pull blanking plug and BPV. Pull tubing hanger and lay down 4 -1/2" tubing. 5. Run 9 -5/8" casing scraper to tag the top of cement plug. Pressure test 9 -5/8" casing / cement plug to 1,500 psi. c= k„)-130 St-cs , , a /. • Spot a weighted pill with corrosion inhibitor between cement plug and cement retainer. 6. Rig up E -line, run guns to perforate 9 -5/8" casing at +/- 5,480' MD ( +/- 8' below casing collar) for cement squeeze. f� 7. Set 9 -5/8" cement retainer bottom at +1- 5,464' MD ( +/- 8' above casing collar). 8. Squeeze 25 bbls cement into perforations. 9. Pick up 9 -5/8" whipstock/milling assembly. Run in hole and displace casing to milling fluid. Orient whipstock. 10. Set whipstock and mill window in 9 -5/8" plus 20' of new formation for FIT /LOT. Attached are the current well schematic and the proposed sidetrack schematic. e n s c i f fed 2xclrr,Vel ro i ow. s e •�, rh j / 70 �q j ((Qs 'p Gi 1 G rd 14, 44f7r tuAgy, 40a - -01 fve Ckrt of f 1 O c ,rtmdo► T4' lCptioir f re'a OP 1'0 f in ;ri 4/ fw,oCe 4-t -e'/ n a 4 omic i - re t o ,- , S fl eCessVt 7//2 HG - 0 • N o- r a Well 2A -27 ConocoPhilli s 1 � 4.4 Final Suspension Schematic Alaska 20" conductor @ 120' MD s t,4 f i 13 3/8" 68 ppf L -80 BTC / TC II surface casing @ ' 3374' MD / 2931' TVD 1 1 '; 5 '; (Cemented to Surface) ¢ i 41/2" 12.6 ppf L -80 IBTM kill string @ 2068' MD / 1964' TVD (Diesel circulated around for freeze protection) 7 � a ^. �'�i 9 5/8" 40 ppf L -80 BTCM / TC II intermediate G �o ,. casing @ 6849' MD / 5171' TVD �� (Est Top of Cement @ 4400' MD) 1` v 1 15.8 ppg Balanced Cement plug set @ ,' ' 7271' MD with top of plug @ 6692' MD. i , Abandoned Perforations Tagged & pressure tested plug s o • } Perforation Information ' i: ' ► `'' Perf #1: Top 7244' MD Bottom: 7259' MD ..;'r`' Perf #2 Top: 7241' MD Bottom 7256' MD '�.... . " ` ` 26 ppf L -80 BTCM liner @ All perforations intended to establish '° , o communication with 2A-06 � ' -Al-- 7248' MD / 5418' TVD Dave Reimer 12/15/09 6 -1/8" Hole TD @ 7271' MD 1 5434' TVD Schematic not to scale HG s • • 2A -27A Rotary Sidetrack Proposed J 20" conductor casing 120' MD ESI • 13 -3/8" 68# L -80 BTC / TC II surface casing 3374' MD / 2931' TVD TOC on 9 -5/8" casing @ 4,400' MD 7" TOL @ • ,.;:. 3-1/2" Selective Upper Completion String 5,250' MD / 4,211' Sidetrack KOP • 2.875" Nipple at 500' MD TVD thru window in 9 -5/8" a • Tubing: 3-Y2", 9.3 ppf, L 80, 8rd EUE 5,450' MD / 4,337' TVD • CMU Sliding Sleeve, 2.813" X Profile • Baker 20' PBR 9 -5/8" Whipstock n 3 -'2" 9.3# L -80 EUE Tubing • Baker FHL Packer 5,450' MD • Injection Mandrel #1, #2 • CMU Sliding Sleeve, 2.813" Profile \ • Baker 'F1' Packer with SBE Cement Retainer • Shear out sub @5,480' MD :. 4 k I Squeeze Perfs @5,464' MD • "FHL" packer +1- 7,425' MD / 5,763' TVD • , SLB Injection Mandrels +1.7,540' MD and 7,470' t MD. Tagged & Pressure Baker Sliding Sleeve, CMU w/ 2.183" X tested plug @ 6,692' '� //' S profile +/- 7,610' MD MD. Top of plug a 6,692' MDR "F profile +/- 7,645' MD / 5,918' TVD 7" TOL @ C sand Perfs: 7,574' 7,633' MD /�� 6,694' MD / 5,07. r,; - %" 15.5# BTCM tail TVD ` : N �% Baker Casing � - 813" X Profile Nipple Packer 9 -5/8" 40# L -80 BTC TC A sand Perfs: 7,672' - 7,755' MD `, @ 7,177' MD r 11 intermediate casing HES Stage Collar 6849' MD / 5171' TVD @7,164' MD " 7" 26# L -80 cemented liner @ Perfs @ ;� 8,018' MD / 6,184' TVD 7,241' - 7,256' .1 it. -41 : is ►- Perfs @ 7" 26.4# L -80 Liner Revised by: 7,244' - 7,259' 7,248' M.D / 5417' TVD Haibin Guo July 30, 2012 HG Page l of l • Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS (IPBRD) Type Work Code in RBDMS 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 f form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and r / operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_Document_ Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Suspended Well Inspection Report Date Inspected: 08/28/10 - Inspector: Bob Noble Operator: CPA Well Name: KRU 2A-27 Oper.Rep: Ian Ives PTD No.: 209-107 - Oper.Phone: 659-7043 Location Verified? Yes Oper.Email: If Verified,How? ier(specify in commet Onshore/Offshore: Onshore Suspension Date: 12/10/09 Date AOGCC Notified: 08/27/10 Sundry No.: 309-408 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Well Pressures(psi): Tubing 0 Photos Taken? Yes IA 0 " OA 350 SCANNED AUG 1 4 2015 Condition of Wellhead: Location verified with plot plan.All line blinded,Gauges were installed to abtain pressures. Guard around wellhead.. 1'8"of rain water inside of sealed steel cellar - Condition of Surrounding Surface The pad looked to be in good condition. Location: Follow Up Actions None Needed: Attachments: Photos(3) REVIEWED BY: Insp.Supry Comm PLB 08/2010 2010-0828_Suspend_KRU_2A-27_bn.xlsx iii,.11,41-1' moi ./ ,tIllij rvv C !'',3 j 1,1i }�� ` erlT yY • E r V #19 ,y., ,i, . . .„„ ,“ . ..,, . .. ,4 . .. i. c., 0 , ...„ . , aq I) I y ¢'a h s NON4 p v 1:1 co 0 US . A I : . ...009: ." , . . , . ... ; " • • , — -ViFf . 4 - , . 0,k, .. •• .•-,I il . ',v.,. „It :),:::iii•-•,,,,ii Nr. _. . - ' -. , ...• • - 41100 *- . —. ,, . . ..4 . •4110.y. .1.. .iniper' .. ' T.4„ -. of', • ' „ I= , .. . irl'".-..- e „ P'''' ..-Adipte ..",..,7,47dp,„ '- -,Ire7 '.•. - .ik..=--??';:r747.SP``-ft -)."' 1 'Z".7:40F,ad-'' - '* „ . , .ir ''''-k-'4'PEX,'• '... .- ir..., ,. , - , -.4" ' ...t., , .., • ". ,,, .•.., ._ .-,,, ''ig,tr 3•..,:l.:70,-,74,67:07.r.'. A ;-'...-4- -.r,.... 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