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211-002
Image rroject Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. Q..1 JI - 00 a Well History File Identifier Organizing (done) wo-sided ❑ Rescan Needed RESCAN: OVERSIZED: NOTES: rZfor Items: ❑ Maps: ayscale Items: ❑ Logs: ❑ Poor Quality Originals: ❑ Other: ❑ Other: BY: Maria Date: 7109. /s/ r'if' Project Proofing BY: din Date: filgliii. /s/ rifs Scanning Preparation l x 30 = /a 0 + S = TOTAL PAGES !a (Count does not include cover sheet) BY: OM Date: • /s/ Production Scanning !,, Stage 1 Page Count from Scanned File: 1a1(0 (Count does include cover heet) Page Count Matches Number in Scanning Pr paration: YES NO BY: _ I Date: / g `4- /s/ IA4 f Stage 1 If NO in stage 1, page(s) discrepanc es were found: YES NO BY: Maria Date: /s/ Stage 2 Additional Well Reports: YES NO TOTAL PAGES: Digital version appended by: Meredith Michal Date: /s/ Final Page Count: Stage 1 + Stage 2: TOTAL PAGES: Scanning is complete at this point unless rescanning is required. 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Well Class • 20AAC 25.105 20AAC 25.110 0 Exploratory 0 Stratigraphic 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 Other No.of Completions Zero . ®Development 0 Service 2. Operator Name: 5. Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska) Inc. 3/15/2014 . ' 211-002•. 313-536 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 2/8/2012 50-029-20875-03-00 • 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 2/8/2012 PBU 18-04C• 1067' FNL, 191' FEL, Sec.24,T11N, R14E, UM • Top of Productive Horizon: 8. KB(ft above MSL): 45.1' • 15. Field/Pool(s) 3727' FNL,3714' FEL, Sec.24,T11N, R14E, UM GL(ft above MSL): 16.1' • Prudhoe Bay Field/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD) Oil Pool 3969' FNL,3152' FEL, Sec. 24,T11N, R14E, UM 3022' • 2934'• 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 691572 • y- 5960796 • Zone- ASP4 10675' - 8690'• ADL 028307 • TPI: x- 688117 y- 5958048 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Permit: Total Depth:x- 688686 y- 5957820 Zone- ASP4 None 18.Directional Surve Y: 19.Water depth,if offshore: 20. Thickness of Permafrost(TVD): ❑Yes 0 No (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900'(Approx.) 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: MWD/GR/RES 9983' 8413' 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND HOLE AMOUNT CASING WT.PER FT. GRADE Top BOTTOM Top BOTTOM SIZE CEMENTING RECORD PULLED 20" 91.5# H-40 Surface 80' Surface 80' 30" 1850#Poleset 13-3/8" 72# L-80 Surface 2629' Surface 2593' 17-1/2" 2240 sx Fondu,400 sx Permafrost'C' 9-5/8" 47# L-80 Surface 8718' Surface 7370' 12-1/4" 500 sx Class'G',300 sx Permafrost'C' 7" 26# L-80 8541' 9882' 7208' 8331' 8-1/2" 287 sx Class'G' 4-1/2" 12.6# L-80 9685' 9983' 8173' 8413' 6-1/8" 250 sx Class'G' 24. Open to production or injection? ❑Yes 0 No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ND (MD+TVD of Top&Bottom;Perforation Size and Number): ) ��yy 4-1/2", 12.6#, 13Cr80 9608' 9551'/8066' T. l.Si 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. A j WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes 0 No • WW! ED ; DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED I """ "�` -3100' 90 Bbls Class'G' II 3076' Cut&Pull Tubing 3044' Set EZSV 3022' Set Whipstock 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc Not on Production N/A Date of Test Hours Tested. Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 24-Hour Rate 28. CORE DATA Conventional Core(s)Acquired? 0 Yes ®No . Sidewall Core(s)Acquired? 0 Yes 0 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 250.071. None . RBOMS APR 18 2 Form 10-407 Revised 10/2012CONTINUED ON REVERSE Submit Original Only `r 4'11411 - ,fiA, . 6-Z../5 29. GEOLOGIC MARKERS(List all formations and rr ''rs encounter 30. FORMATION TESTS NAME A ND Well Tested? L s ®No Permafrost Top If yes,list intervals and formations tested,briefly summarizing test Permafrost Base results. Attach separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sadlerochit 9947' 8384' None Kicked off from Parent Well 9983' 8413' Formation at Total Depth: 31.List of Attachment Summary of Pre-Rig Work, Summary of Daily Drilling Reports,Well Schematic Diagram 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jesse Rose aum,564-51 Email: Jesse.Rosenbaum@bp.com Printed Name: Joe Lastu a Title: Drilling Technologist Signature: Phone 564-4091 Date: 4110114-- 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 1 a: 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 elevation 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 ND for the top and base of permafrost in Box 28. 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 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. Form 10-407 Revised 10/2012 Submit Original Only TREE= McEVOY VVELLNIEAD= McEVOY 1 0-0 4 C 4SAf` NROME NOTES: WEBGLL ANGLE>70 @ 10120'**" ACTUATOR= AXELSON OKB.ELEV= 56' BF.ELEV — 19.21' KOP= 2100' 3022' H9-5/8"WHIPSTOCK(03/15/14) Max Angle= 75°@ 10187' 20"CONDUCTOR— 120' 3044' —{9-5/8"EZSV(03/14/14) Datum MD= 11113' Datum TVD= 8800'SS 11111111111MIw 3100' —ESTIMATED TOC(02/01/14) 13-3/8"CSG,72#,L-80 BTRS,ID=12.347" — 2629' GAS LIFT MANDRELS JET CUT TBG(02/13/14) — 3076' VPIIST MD TVD DEV TYPE VLV LATCH FORT DATE TAGGED TOP OF COIL TUBIVG(02/13/14) — 3108' A 4 3168 3055 34 MMGM DMY RK 0 03/29/08 y " 3 5993 5193 40 MMGM DMY RK 0 03/29/08 iM 1 2 8112 6830 31 MMGM DMY RK 0 04/06/02 Minimum ID = 3.813" @ 2185' '*" ` c �g a 21 9514 8036 38 KBG-2 DMY BK 0 04/06/02 41, 4-1/2" CAMCO BAL-O SSSVLN tid ALL GLM COVERED BY CEMENT 8541' H9-5/8"X 7"BKR ZXP PKR111EBACK,ID=6.313" 8555' -19-5/8"X 7"BKR HMC LNR HGR ID=6.313" TOP OF WHIPSTOCK H 8741' \ 14 Pi 9-5/8"CSG,47#,L-80 BTRS,ID=8.681" I –8734 �— L ig 4 9-5/8"MLLOUT WINDOW(18-04B)8718' 8734' %Pi' _ 8855' —I TOP OF CEMENT INSIDE COIL . R'4 Al oitii.. _ L �d 9541' —{4-1/2"OTIS X NP,ID=3.813" Pi 9551' H 7"X 4-1/2"BKR S-3 PKR ID=3.875" OlitittIi l 9575' —14-1/2"OTIS X NP,ID=3.813" fl IS IP 9595' —I4-1/2"OTIS XN NIP,MILL TO 3.80"(02/05/11) 4-1/2"TBG, 12.6#,13CR-80 VAM ACE H 9608' —\ .0152 bpf,ID=3.958" 9608' --{4-1/2"WLEG,ID=3.958" TOP OF 4-1/2"LNR H 9685' 9685' 17"X5"BKR ZXP LTP w/7.40'TIEBACK 1 . A &HMC LNR HGR, ID=4.39" 9699' H5"X 4-1/2"XO,ID=3.90" 7"LNR,26#,L-80 BTC,.0383 bpf,ID=6.276" —I 9882' Ii ig 4-1/2"PKR WHIPSTOCK(02/22/11) — 9980' O 44 _ 3.80"MLLOUT WINDOW(18-04C)9983'-9990' PERFORATION SUMMARY REF LOG: SWS PERF ON 08/14/01 ' ANGLE AT TOP PERF: 66°@ 10383' Note:Refer to Production DB for historical perf data I 4P.44,1410. SIZE SPF I"JTERVAL Opn/Sqz SHOT SQZ44111:40iNt 3-3/8" 6 10383-10410 °C 01/22/02 4-1/2"OPEN HOLE — 10675' 3-3/8" 6 10410- 10450 *C 09/25/01 2-7/8" 4 10426-10456 *C 08/14/01 F- ..1 2478" 4 10465-10485 *C 08/14/01 *PERFORATIONS BELOW WHPSTOCK@ 9980' .--.4 4-1/2"LNR,12.6#,L-80 IBT-M,.0152 bpf,ID=3.958" — 10594' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/29/83 ROW 41 INITIAL COMPLETION 02/01/14 TTR/PJC P&A WELL: 18-04C 05/18/98 N4/3 ES CTD SIDETRACK(18-04A) 02/17/14 ATO/JMD JET CUT TBG/TAGGED TOP OF CT(02/ PERMIT No:'2110020 07/17/01 MES SIDETRACK(18-04B) AR No: 50-029-20875-03 03/02/11 NORDIC 1 CTD SUSPENDED(18-04B) SEC 24,T11 N,R14E, 1067'FNL&191'FEL 02/18/12 NORDIC 2 OPS SHUT DOWN(18-04C) 02/27/12 MV/PJC BORE B CID CORRECTION BP Exploration(Alaska) 18-04C, Well History (Pre-Rig Sidetrack) Date Summary 01/25/14 T/I/O=SSV/180/0+,Temp=Sl. PPPOT-T(PASS), PPPOT-IC (PASS). PPPOT-T: Stung into test port(100 psi), bled to 0 psi. Functioned LDS, all moved freely. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT-IC: Stung into test port(0+ psi), bled to 0 psi. Functioned LDS, all were tight but fully functioned. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 01/31/14 MU cementing BHA w/2" BDJSN and RIH.Tag 2-3/8"CT at 3084', PUH 10'and flag pipe. Pump 90bbls of 15.8 Class G Cement down coil. 02/01/14 Pumped 90bbls of 15.8ppg Class G Cement down coil. Cement hit formation at 68bbls away, pushed an additional 17bbls away at—150-200psi before opening choke and laying in final 5bbls. PUH to safety. Contaminate cement down to flag w/PowerVis, make down/up/down/up pass and chase OOH at 80%. Returned 1:1 returns during clean out. Est TOC—3074'. FP well w/38bbls of 60/40 methanol. Pressure WHP up to 500psi. RDMO. 02/05/14 TAGGED TOP OF COIL @ 3,090'SLM W/3.70"CENT, 2.50"S.BAILER (metal marks). TAGGED TOP OF COIL @ 3,090' SLM W/2.50"CENT, 2.50"S.BAILER (metal marks). TAGGED TOP OF COIL @ 3,090'SLM W/3.70"CENT, 3.50" LIB(impression of coil). 02/06/14 T/I/O= 110/1280/0. Temp=SI.T, IA, OA FL(Fullbore request). No AL& Flowline.T FL near surface, IA FL© surface, OA FL near surface. SV, WV, SSV=C. MV=0. IA, OA=OTG. NOVP. 1600. 02/08/14 T/I/0=76/1270/3 SI (SIDETRACK) MITxT to 2500 psi***PASSED***MITx IA to 3500 psi ***PASSED*** MITx OA to 2000 psi***PASSED***Pumped 2 bbls diesel down TBG to achieve a test press. of 2500 psi. (MITx T)TBG lost 28 psi in 1st 15 min and lost 18 psi in 2nd 15 min for a total loss of 46 psi in 30 min test. Bleed TBG pressure to 1000 psi. Pumped 5 bbls of diesel down IA to achieve a test pressure of 3500 psi. (MITx IA) IA lost 54 psi in the 1st 15 min and lost 23 psi in 2nd 15 min for a total loss of 77 psi in 30 min test. Pumped 2 bbls of diesel down OA to achieve a test pressure of 2000 psi (MITx OA)OA lost 72 in the 1st 15 min and lost 25 psi in the 2nd 15 min for a total of 97 psi in 30 min test. Bleed WHPs to 0 psi. Notify DSO/PE Valve positions=SV SSV closed MV open CVs OTG FWHP=0/1000/0. 02/13/14 RIH W/CCL/WEIGHTS/SHOCK MANDRALS/3.65" POWER JET CUTTER. TAG CT STUB©3108'. FIRST COLLAR ABOVE STUB @ 3078'. JET CUT TBG @ 3076'. CCL TO CUTTER=20.3'. CCL STOP DEPTH=3055.7'. PUMP DOWN TBG TO ESTABLISH COMMUNICATION. TBG PRESSURE INCREASED FROM 0 TO 250 PSI. IA PRESSURE INREASED FROM 250 TO 500PSI. FINAL T/I/O=0/250/0 PSI. 02/16/14 T/1/0=200/300/0. Circ well. CMIT TxIA FAILED on four attempts(see mit data)to 3500 psi. Pumped 5 bbls neat methanol,followed by 290 bbls of 1%kcl down tbg taking returns up IA and 18-05 flowline to production. Pumped 290 bbls of 9.8 brine,followed by 20 bbls diesel. U-tube TxIA. Freeze protect 18-05 flowline with 20 bbls neat,52 bbls crude, and 3 bbls diesel. CMIT TXIA to 3500 failed on four attempts (see mit data). 02/17/14 CMIT TXIA to 3500 psi PASSED (see mit data) Pumped 9 bbls dsl to reach test pressure good test on sixth try rig down(swab closed wing closed ssv closed master open annulus valves open to gauges) FWHP=94/85/0. 02/22/14 T/I/O=0/0/0 Temp=S/I Circ out(SIDETRACK) Drove to location, spot unit, start to preheat tanker of diesel to 90*. Page 1 of 2 • 18-04C, Well History (Pre-Rig Sidetrack) Date Summary 02/23/14 Circ Out(SIDETRACK) Preheat diesel to 90*. Pumped 5 bbls neat meth followed by 290 bbls of 130* 1% KCL down TBG up IA taking returns down 18-05 FL. Pumped 210 bbls of 90*diesel down TBG up IA to freeze protect. Pumped 10 bbls meth followed by 55 bbls crude tailed with 10 bbls meth and 3 bbls diesel to freeze protect FL on 18-05. SV WV SSV=closed, MV IA OA=open Tags hung. FWHPS=300/300/60. 02/25/14 T/I/0 =VacNacNac.Temp=SI. Bleed WHP's(Pre Rig). No flowcross, WV,flowline.or AL.Temporary scaffolding to the tree cap. SV, SSV= C. MV=0. IA, OA=OTG. NOVP. 1540. 02/26/14 T/I/O =VacNac/Vac.Temp=SI.WHPs(Pre RWO). No flowcross,WV,flowline, and AL.Temporary scaffolding to the treecap. SV, SSV=C. MV= 0. IA, OA=OTG. NOVP. 10:30 hrs. 03/04/14 T/I/O=VAC/ONAC. Set BPV#520. Removed upper tree. Installed Dryhole tree temp valve#37.Torqued to API specs. PT'd (PASSED). Installed Piggy Back valves on IA and OA. IA=#25. OA=Tagged#54. Torqued to API specs. PT'd (PASSED).Verified VR plugs where present in Pad side IA and OA.Torqued to API specs. PT'd (PASSED). RDMO. Final WHP's BPV/ONAC. Page 2 of 2 North America-ALASKA-BP Page 14 Operation Summary Report Common Well Name:18-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/9/2014 End Date: X3-014HQ-C:(10,840,400.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:PARKER 272 Spud Date/me:12/25/1982 12:00:00AM 'Rig Release: - Rig Contractor:PARKER DRILLING CO. UW:500292087500 Active datum:18-040©63.20usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) I (usft) 3/9/2014 12:00 - 14:00 2.00 MOB P PRE RIG DOWN -CHANGE OUT SAVER SUB ON TOP DRIVE -DISCONNECT MUD,CHOKE AND BLEEDER LINES TO RIG FLOOR •-PREP CUTTINGS BOX FOR REMOVAL 14:00 - 16:00 2.00 MOB P PRE RIG DOWN -BRIDLE UP -SECURE STABBING BOARD OPEN -TIE ALL LINES AND HOSES BACK IN DERRICK -UNHANG TONGS -PREP MOTORS FOR SEPARATION 16:00 - 18:00 2.00 MOB P PRE RIG DOWN -PREPARE FLOOR FOR SKIDDING -REMOVE WALKWAYS FROM ROOF -SECURE IRON DERRICK MAN AND FORUM CRANE IN PREPARATION TO LAY OVER DERRICK. 18:00 - 19:00 1.00 MOB P PRE RIG DOWN -COMPLETE CHECKLIST AND SKID FLOOR 19:00 - 20:30 1.50 MOB P PRE RIG DOWN -FINISH PREPARING RIG FLOOR • -WALK THROUGH CHECKLIST TO LAY DOWN •DERRICK _ -LAY DOWN DERRICK 20:30 - 00:00 3.50 MOB P PRE RIG DOWN -REMOVE PLATES ON ROOF '-SECURE PIPE SHED -WARM UP MOVING SYSTEM -UNPLUG MOTORS FROM SUB -PREPARE TO SEPARATE MOTORS FROM SUB 3/10/2014 00:00 - 02:00 2.00 MOB P PRE MOVE MOTORS -SEPARATE MOTORS FROM SUB -TURN MOTOR COMPLEX TO MOVE OFF DS-09 02:00 09:00 7.00 MOB P PRE MOVE MOTORS F/DS-9 ACROSS ICE ROAD -ROLL TIRES ON THE SUB -PREP TO SEPARATE SUB FROM PITS 09:00 = 15:00 6.00 MOB P PRE MOVE MOTORS F/ICE ROAD TO DS-18 -MOTORS ON DS-18 AT 15:00 HRS SIMOPS: MOVE SUB F DS-9 TO DS-18 AT 09:00 Printed 3/24/2014 10:43:31 AM • North America-ALASKA-BP Page 2.261 Operation Summary Report Common Well Name:18-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/9/2014 End Date: X3-014HQ-C:(10,840,400.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:PARKER 272 Spud Date/Time:12/25/1982 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292087500 Active datum:18-04D @63.20usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 15:00 - 23:30 8.50 MOB P PRE MOVE SUB FROM DS-9 T/DS-18 -SUB ON DS-18 AT 23:30 HRS SIMOPS: -MOVE PITS F/DS-9 TO DS-18 AT 19:30 HRS 0-RING ON HYDRAUIC DRIVE PUMP FAILED -INCIDENT OCCURRED AT 22:00 HRS WHILE ON DS-17 -3 GALLONS IN CONTAINMENT,2 GALLONS ON GROUND -NOTIFIED 5700,DS-17,DRLG SUPT.,BP HSE, PARKER HSE -FLUID CLEANED UP -RESUMED MOVE AT 23:30 HRS 23:30 - 00:00 0.50 MOB P PRE MOVE PITS FROM DS-17 OVER ICE ROAD SIMOPS: SPOT SUB OVER WELL 3/11/2014 00:00 - 01:00 1.00 RIGU P PRE MOVE PITS FROM DS-17 OVER ICE ROAD SIMOPS: -SUB SPOTTED OVER WELL AT 01:00 HRS 01:00 - 02:00 1.00 RIGU P PRE MOVE PITS FROM ICE ROAD TO SPINE ROAD SIMOPS SHIM SUB AND DROP SUPPORT COLUMNS 02:00 - 03:00 1.00 RIGU P PRE MOVE PITS F/CH2 YARD TO GUARD SHACK SIMOPS:SPOT MOTORS -ROLL TIRES TO WARM UP HYDRAULICS -PULL TIE RODS AND TURN TIRES 03:00 - 04:30 1.50 RIGU P PRE MOVE PITS F/GUARD SHACK TO WEST DOCK ROAD SIMOPS -SPOT MOTORS NEXT TO SUB -SHIM MOTORS AND DROP SUPPORT COLUMNS 04:30 - 09:30 5.00 RIGU P PRE MOVE PITS ON WEST DOCK ROAD TO DS-18 -PITS ON DS-18 AT 0830 HRS -SET PITS DOWN PULL TIE RODS,TURN TIRES SIMOPS -HOOK UP ELECTRICAL BETWEEN SUB AND MOTORS -HOOK UP UTILITY LINES BETWEEN SUB AND MOTORS 09:30 - 12:00 2.50 RIGU P PRE SPOT PITS NEXT TO SUB -SHIM PITS AND DROP SUPPORT COLUMNS -CONTINUE UTILITY LINE HOOK UP ON MOTORS TO SUB -CONTINUE ELECTRICAL HOOK UP MOTORS TO SUB 12:00 - 14:00 2.00 RIGU P PRE RIG UP -HOOK UP ELECTRICAL BETWEEN PITS AND SUB -HOOK UP UTILITY LINES BETWEEN PITS AND SUB Printed 3/24/2014 10:43:31AM North America-ALASKA-BP Page 344, Operation Summary Report Common Well Name:18-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/9/2014 End Date: 1X3-014HQ-C:(10,840,400.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:PARKER 272 Spud Date/Time:12/25/1982 12:00:00AM Rig Release: Rig Contractor PARKER DRILLING CO. UWI:500292087500 Active datum:18-04D©63.20usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 14:30 0.50 RIGU P PRE RIG UP -PJSM - -RAISE DERRICK,PU WT 527K 14:30 - 16:00 1.50 RIGU P PRE RIG UP -SKID RIG FLOOR -HOOK UP UTILITY LINES UNDER FLOOR -INSTALL MAN RIDER HOISTS ON FLOOR 16:00 - 23:00 7.00 RIGU P PRE RIG UP -BRIDLE DOWN -PIN STABBING BOARD -HANG RIG TONGS -M/U HIGH PRESSURE MUD LINES -SET WALKWAYS ON ROOF -TAKE 290 BBLS OF SEAWATER INTO PITS -R/U HARLINE TO IA VALVES FOR CIRCULATION NOTE:RIG ACCEPTED AT 22:30 HRS NOTE:CONTACTED AOGCC VIA PHONE AND INFORMED AOGCC THAT RIG DID NOT RECEIVE EMAIL CONFIRMATION, JOHN CRISP WAIVED WITNESS OF BOP TEST AT 1710 HRS 23:00 - 00:00 1.00 RIGU P PRE M/U SECONDARY KILL LINE TO IA FOR BPV TEST 3/12/2014 00:00 - 02:30 2.50 RIGU P PRE RIG UP TO PRESSURE TEST BPV -COMPLETE R/U HARDLINE TO TIGER TANK -PRESSURE TEST HARD LINE 250 PSI/4000 PSI,5 MIN/5 MIN -TEST GOOD -C/O SENSATOR LINE IN WELL HOUSE R/U SECONDARY KILL LINE TO IA 02:30 - 04:00 1.50 RIGU P PRE PRESSURE TEST BPV -PJSM -PUMP 4 BBLS TO FILL SECONDARY KILL -TAKE RETURNS TO TIGER TANK,B/D LINE -PRESSURE TEST KILL LINE 250 PSI/3500 PSI,5 MIN/5 MIN -TEST GOOD -TEST BPV FROM BELOW -250 PSI/3500 PSI,5 MIN/5MIN,TEST GOOD 04:00 - 05:30 1.50 RIGU P PRE R/D PRESSURE TEST -PJSM -B/D SECONDARY KILL LINE -VERIFY 0 PSI ON TREE -CAMERON BLEED PRESSURE OFF CONTROL LINE,VOID BACK OUT HANGER ALIGNMENT PIN 05:30 - 07:00 1.50 RIGU P PRE N/D TREE -VACUUM OUT TREE -N/D TREE AND ADAPTER FLANGE 07:00 - 08:00 1.00 RIGU P PRE INSTALL BLANKING PLUG -VERIFY THREADS ON HANGER GOOD -INSTALL HANGER XO 12-1/2 TURNS TO LEFT -INSTALL BLANKING PLUG 13-1/2 TURNS TO LEFT -VERIFY BLANKING PLUG RUNNING TOOL M/U -10 TURNS TO THE RIGHT,REMOVE RUNNING TOOL Printed 3/24/2014 10:43:31AM North America-ALASKA-BP Page 4.p$ Operation Summary Report Common Well Name:18-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/9/2014 End Date: X3-014HQ-C:(10,840,400.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:PARKER 272 Spud Date/Time:12/25/1982 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UW:500292087500 Active datum:18-04D @63.20usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:00 - 09:00 1.00 BOPSUR P PRE N/U BOPE -BRING HP RISER TO FLOOR,CLEAN RING GROOVE -STAB HP RISER ON WELL HEAD AND 4 BOLT -INSPECT BRIDGE CRANES 09:00 - 12:00 3.00 BOPSUR P PRE N/U BOPE -SET BOP STACK ON HP RISER -TORQUE BOLTS ON HP RISER AND BOP NOTE:IRON DERRICKMAN SERVICE REP INCREASING OPERATING SPEED 12:00 - 16:00 4.00 BOPSUR N SFAL PRE N/U BOPE -REPLACE AND RE-TORQUE BOLTS ON LOWER FLANGE -INSTALL TURN BUCKLES -INSTALL BELL NIPPLE —HOOK UP FLOW LINE AND HOLE FILL LINE -CONNECT DRAIN LINES -TIGHTEN TURN BUCKLES 16:00 - 16:30 0.50 BOPSUR P PRE SERVICE RIG 16:30 - 18:30 2.00 BOPSUR P PRE TEST BOPE -M/U 4-1/2"AND 5"TEST JOINT -M/U 4-1/2"TEST JOINT TO BLANKING PLUG -PJSM -FILL BOP STACK,TEST JT,CHOKE AND KILL LINE 18:30 - 00:00 5.50 BOPSUR P PRE TEST BOPE -TEST BOPE 250 PSI/4000 PSI,5 MIN/5 MIN, TEST GOOD -TEST ANNULAR 250 PSI/3500 PSI,5MIN/ 5MIN,TEST GOOD -PERFORM KOOMEY DRAWDOWN NOTE:JOHN CRISP WAIVED WITNESS OF BOP TEST 3/13/2014 00:00 - 00:30 0.50 BOPSUR P PRE TEST BOPE -COMPLETE BOP TEST -TEST BLIND RAMS -250 PSI/4000 PSI,TEST GOOD NOTE:JOHN CRISP WAIVED WITNESS OF BOP TEST 00:30 - 02:30 2.00 BOPSUR P PRE R/D BOP TEST EQUIPMENT -B/D CHOKE,KILL LINE,CHOKE MANIFOLD -R/U DUTCH RISER,FILL STACK -BUILD 4"LANDING JOINT TO RETREIVE BLANKING PLUG -R/U VALVE SHOP LUBRICATOR 02:30 - 03:00 0.50 BOPSUR P PRE PULL IS TYPE BLANKING PLUG -PRESSURE TEST LUBRICATOR -250 PSI/3500 PSI,TEST GOOD -BREAK LUBRICATOR AT QUICK TEST SUB -P/U LANDING JT W/BLANKING PLUG RETRIEVAL TOOL -RIH W/RETRIEVAL TOOL,MAKE 24 TURNS TO RIGHT -POOH W/BLANKING PLUG AND BREAK TOOL OF JT -HANG LANDING JT OFF TUGGER Printed 3/24/2014 10:43:31AM North America-ALASKA-BP Page 5 afg/ Operation Summary Report Common Well Name:18-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/9/2014 End Date: X3-014HQ-C:(10,840,400.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:PARKER 272 Spud Date/Time:12/25/1982 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292087500 Active datum:18-04D©63.20usft(above Mean Sea Level) Date From-To Hrs j Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 05:00 2.00 WHSUR P DECOMP PULL IS TYPE BPV -P/U LUBRICATOR AND MAKE UP TOOL STRING -M/U TWO STABILIZERS IN TOOL STRING -PRESSURE TEST QUICK TEST CONNECTION,GOOD -FIRST ATTEMPT UNSUCCESSFUL M/U LUBRICATOR SECOND TIME -PRESSURE TEST QUICK TEST CONNECTION,GOOD -RETRIEVE BPV L/D LUBRICATOR AND CLEAR FLOOR 05:00 - 06:00 1.00 WHSUR P DECOMP R/D VALVE SHOP LUBRICATOR -L/D LUBRICATOR TOOL STRING -UD LUBRICATOR AND QUICK TEST SUB -BOLDS ON DUTCH RISER AND UD SAME -UD LANDING JT FOR RETREIVING BLANKING PLUG 06:00 - 08:00 2.00 PULL P DECOMP CIRCULATE OUT FREEZE PROTECT PJSM 1--TAKE RETURNS TO 500 BBL TIGER TANK -140 BBL DIESEL ON BACK SIDE -35 BBLS DIESEL ON TUBING,175 TOTAL -210 GPM,340 PSI -MONITOR WELL FOR 10 MIN,STATIC SIMOPS: BUILD LANDING JOINT TO PULL HANGER OFFLINE WHILE CIRCULATE OUT DIESEL 08:00 - 09:30 1.50 PULL P DECOMP R/U TO PULL 4-1/2 COMPLETION -BLOW DOWN HARD LINES TO TIGER TANK -R/U DOYON CASING TONGS AND EQUIPMENT -R/U SCHLUMBERGER CONTROL LINE SPOOLER 09:30 - 10:00 0.50 PULL P DECOMP PULL HANGER -RIH W/LANDING JT AND MAKE UP TO HANGER -CAMERON REP ON FLOOR -M/U TOP DRIVE TO LANDING JT -BOLDS AS PER CAMERON REP 10:00 10:30 0.50 PULL P DECOMP CBU 1.5X'S -UNSEAT HANGER,PU WT 78K -380 GPM,140 PSI 10:30 - 11:30 1.00 PULL P DECOMP L/D HANGER -MONITOR WELL FOR 5 MIN.STATIC -PULL HANGER TO FLOOR -SLB REP REMOVE CONTROL LINES F/HANGER -B/O TUBING HANGER FROM BELOW -SET IN MOUSEHOLE.BIO LANDING JT F/ ABOVE _ -L/D HANGER 11 30 - 12:00 0.50 PULL P DECOMP !CHANGE ELEVATORS REMOVE BX ELEVATORS -INSTALL YT TUBING ELEVATORS BREAK DOWN LANDING JOINT AND UD Printed 3/24/2014 10:43:31AM North America-ALASKA-BP Page 6 Operation Summary Report Common Well Name: 18-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/9/2014 End Date: X3-014HQ-C:(10,840,400.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:PARKER 272 Spud Date/Time:12/25/1982 12:00:00AM Rig Release: Rig Contractor.PARKER DRILLING CO. UWI:500292087500 Active datum:18-040©63.20usft(above Mean Sea Level) Date j From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:00 17:00 5.00 PULL P DECOMP POOH L/D 4.5"TUBING -POOH FROM 3,076'MD TO SURFACE -PU WT 78K,SO WT 78K -SPOOL DUAL CONTROL LINES WBE RECOVERED -72 JOINTS 4-1/2"12.6#VAM ACE 1 CUT JOINT 4-1/2",12.6#VAM ACE,40.65' LONG -1 SSSV -55 STAINLESS STEEL BANDS 17:00 - 18:30 1.50 PULL P DECOMP CLEAN AND CLEAR FLOOR -L/D CASING EQUIPMENT -L/D CONTROL LINE SPOOLER -REMOVE YT ELEVATORS -INSTALL BX ELEVATORS -BRING BHA COMPONENTS TO RIG FLOOR 18:30 - 19:00 0.50 CLEAN P i DECOMP SERVICE RIG 19:00 - 19:30 0.50 WHSUR P DECOMP -M/U LANDING JT TO WEAR RING PULLER RIH W/WEAR RING INSTALL WEAR RING, ID 9-1/16",OD 13-9/16" 19:30 - 20:00 0.50 CLEAN P DECOMP RIG EVAC DRILL AND AAR AAR NOTES: EMPLOYEES EXITING RIG BY WALKING THROUGH RIG TO MINIMIZE EXPOSURE TO COLD INSTEAD OF CLEARING RIG AT NEAREST EXIT 20:00 - 23:00 3.00 CLEAN P DECOMP PICK UP 8.5 CLEANOUT BHA -PJSM -F/SURFACE T/778' PU WT 80K,SO WT 80K -DRIFT TO 2.40" 23:00 - 00:00 1.00 CLEAN P DECOMP RIH W/8.5 CLEANOUT ASSEMBLY -PICKING UP SINGLES FROM PIPE SHED -F/778'T/1284' -PU WT 85K SO WT 83K -DRIFT TO 2.40" 3/14/2014 00:00 - 04:30 4.50 CLEAN P DECOMP RIH W/8.5 CLEANOUT ASSEMBLY -PICKING UP SINGLES FROM PIPE SHED -F/1284'T/3058' -TAG FISH(d 3099' -PU WT 121K SO WT 121K -DRIFT TO 2.40" NOTE RIG EVAC DRILL AT 0130 HRS 0430 - 05'30 1.00 CLEAN P DECOMP WASH DOWN SINGLE -126 GPM,69 PSI -TAG TUBING STUMP(g3099' 05.30 - 06:00 0.50 CLEAN P DECOMP CIRCULATE 2X'S BUS j -POOH 9'ABOVE STUMP '-650 GPM, 1150 PSI -PUMP HIGH VIS SWEEP SURFACE TO SURFACE -NO INCREASE IN SOLIDS,HOLE CLEAN 06:00 - 08:30 2.50 CLEAN P DECOMP POOH -MONITOR WELL 10 MINUTES,STATIC -BRINE WEIGHT 8.5 PPG IN,8.5 PPG OUT -POOH ON ELEVATORS FROM 3090'TO 810' -PU WT 120K, SO WT 120K AT 3090' Printed 3/24/2014 10:43:31AM • North America-ALASKA-BP Page 7„p2 Operation Summary Report Common Well Name:18-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/9/2014 End Date: X3-014HQ-C:(10,840,400.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:PARKER 272 Spud Date/Time:12/25/1982 12:00:OOAM Rig Release: Rig Contractor PARKER DRILLING CO. UWI:500292087500 Active datum:18-04D @63.20usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 08:30 - 11:00 2.50 CLEAN P DECOMP UD BHA -MONITOR WELL FOR 10 MINUTES,STATIC -PJSM -STAND BACK HWDP AND DRILL COLLARS -LAY DOWN MILL,JARS,AND BIT 11:00 - 11:30 0.50 CLEAN P DECOMP CLEAN AND CLEAR RIG FLOOR SEND BAKER TOOLS OFF FLOOR 11:30 - 14:30 3.00 WHIP P WEXIT SET EZSV -R/U HALLIBURTON WIRELINE -RIG UP SHEAVE IN BLOCKS -INSTALL WIRELINE BEAM AT TOOL CRANE -INSTALL SHEAVE AT WIRELINE BEAM -M/U TOOL STRING AND EZSV PER HES REP 14:30 - 15:30 1.00 WHIP P WEXIT RIH WITH E-LINE -RIH TO 3050' -FAILED TO SET -FAULT IN E-LINE HEAD 15:30 - 18:30 3.00 WHIP N DFAL 3,042.00 WEXIT SET EZSV -POOH WITH WIRELINE -RE-HEAD E-LINE -RIH TO 3099'TAG STUMP -POOH LOCATE COLLAR AND SET EZSV -TOP OF EZSV AT 3042' 18:30 - 20:00 1.50 WHIP P WEXIT POOH WITH E-LINE -POOH AND STAND BACK E-LINE TOOLS 20:00 - 21:00 1.00 WHIP P WEXIT PRESSURE TEST -250 PSI/3500 PSI,5 MIN/30 MIN,GOOD TEST NOTE CONTACT WTL WITH TEST RESULTS, RECEIVE APPROVAL TO PROCEED 21:00 - 21:30 0.50 WHIP P WEXIT R/D E-LINE -SEND HES TOOLS OFF FLOOR 21:30 - 00:00 2.50 WHIP P WEXIT P/U BHA W/WHIPSTOCK -PJSM -RIH F/SURFACE T/110' -P/U STRING MILLS AND STARTER MILL IN MOUSEHOLE -SCRIBE WINDOW MILL -SET WHIPSTOCK IN ROTARY TABLE -VERIFY 3 EA SHEAR BOLTS IN ANCHOR -REMOVE SHEAR STOP BOLT FROM ANCHOR -VERIFY SHEAR PLANE ON WHIPSTOCK BOLT BOLT STARTER MILL TO WHIPSTOCK 3/15/2014 00:00 - 01:00 1.00 WHIP P WEXIT P/U BHA W/WHIPSTOCK -PJSM -RIH F/110'T/860' P/U DRILL COLLARS,HWDP 01:00 - 04:30 3.50 WHIP P WEXIT RIH W/WHIPSTOCK -RIH F/860'T/2950' -PU WT 124K,DN WT 124K -RIH ON ELEVATORS,5"DP FROM DERRICK -M/U TOP DRIVE -ORIENT WHIPSTOCK 50.91 DEGREES RIGHT -TAG EZSV AT 3044' -SET WHIPSTOCK ANCHOR -SET 46K DN WT,SHEAR RAMP OFF STARTER MILL Printed 3/24/2014 10:43:31AM • • North America-ALASKA-BP Page 8.01,4- • Operation Summary Report Common Well Name:18-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/9/2014 End Date: X3-014HQ-C:(10,840,400.00) Project:Prudhoe Bay Site:PB DS 18 • Rig Name/No.:PARKER 272 Spud Date/Time:12/25/1982 12:00:00AM Rig Release: Rig Contractor.PARKER DRILLING CO. UWI:500292087500 Active datum:18-04D @63.20usft(above Mean Sea Level) Date From-To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 04:30 - 06:00 1.50 STWHIP P WEXIT SET RTTS -POOH THREE STANDS -RIH 2 STANDS W/RTTS,AND SET t 198' -BACK OUT STINGER,21 TURNS TO LEFT -RACK BACK TWO STANDS • -PUWT121K,SOWT121K_ 06:00 - 06:30 0.50 STWHIP P WEXIT TEST RTTS -250 PSI LOW,2000 PSI HIGH;5 MINUTES EACH -GOOD TEST 06:30 - 07:30 1.00 STWHIP P WEXIT NIPPLE DOWN BOPE • -BLOW DOWN LINES -SUCK OUT STACK -PULL MOUSE HOLE -PULL WEAR RING 07:30 - 08:30 1.00 STWHIP P WEXIT NIPPLE DOWN BOPE -REMOVE HOLE FILL LINE, -REMOVE TURNBUCKLES AND FLOW RISER -BREAK BOLTS ON STACK -STORE BOP ON STUMP 08:30 - 09:30 1.00 STWHIPP WEXIT NIPPLE DOWN BOPE I CAMERON BLEED PRESSURE OFF PACKOFF VOID -RIG UP BRIDGE CRANE TO HIGH PRESSURE RISER '-BREAK BOLTS ON HIGH PRESSURE RISER -BREAK BOLTS BETWEEN TUBING AND CASING SPOOL -PULL TO VERIFY TUBING SPOOL BREAKS FREE 09:30 - 10:00 0.50 STWHIP P WEXIT PULL HIGH PRESSURE RISER -UN-BOLT RISER FROM TUBING SPOOL -PULL RISER TO RIG FLOOR AND UD 10.00 - 10:30 0.50 WHSUR P WEXIT PULL TUBING SPOOL -REMOVE SECONDARY ANNULUS VALVES PULL TUBING SPOOL,STORE IN BOP DECK 10.30 - 11 30 1.00 WHSUR P WEXIT PULL PACKOFF -M/U RUNNING TOOL TO LANDING JT -RIH AND M/U RUNNING TOOL INTO PACKOFF -BOLDS ON PACKOF -PULL PACKOFF,PU WT 8K -PREP NEW TUBING SPOOL 11 30 - 12 00 0.50 WHSUR P WEXIT INSTALL NEW PACKOFF -LUBRICATE AND WORK LDS -INSTALL NEW PACKOFF -RILDS 12:00 - 13:00 1.00 WHSUR P WEXIT N/U NEW TUBING SPOOL 13:00 - 15:30 2.50 WHSUR P WEXIT PRESSURE TEST -TEST PACK OFF -250 PSI/5000 PSI,5 MIN/15MIN 15:30 - 17:30 2.00 WHSUR P WEXIT N/U BOPE -SET HP RISER ON WELL,TORQUE BOLTS -SET BOP STACK ON HP RISER,TORQUE BOLTS INSTALL BELL NIPPLE -CONNECT TURN BUCKLES AND TIGHTEN -INSTALL FLOW LINE AND HOLE FILL LINE Printed 3/24/2014 10.43:31AM North America-ALASKA-BP Page 9•cfi?h Operation Summary Report Common Well Name:18-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/9/2014 End Date: X3-014HQ-C:(10,840,400.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:PARKER 272 Spud Date/Time:12/25/1982 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292087500 Active datum:18-04D @63.20usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 17:30 - 19:30 2.00 WHSUR P WEXIT PRESSURE TEST CONNECTIONS -RIH AND SET TEST PLUG,PULL JT -CLOSE BLINDS,FILL STACK -TEST HP RISER CONNECTIONS -250 PSI/4000 PSI,5 MIN/5 MIN,GOOD -PULL TEST PLUG -INSTALL WEAR RING 19:30 - 21:00 1.50 WHSUR P WEXIT PULL RTTS -RIH W/TWO STANDS -M/U TIW VALVE ON TOP OF STUMP -CLOSE TIW VALVE AND BAG -UN-SEAT RTTS,CHECK FOR PRESSURE, STATIC POOH W/RTTS AND UD 21:00 - 22:00 1.00 WHSUR P WEXIT RIH WITH 8-1/2 WINDOW MILL -CALIBRATE BAKER DEPTH COUNTER 22:00 - 23:00 1.00 WHSUR P WEXIT CIRCULATE 1.5X'S BUS -DISPLACE WELL TO 9.8 PPG LSND -700 GPM,1100 PSI 23:00 - 00:00 1.00 STWHIP P WEXIT MILL 8-1/2 WINDOW 5 Lm4 -F/3022'T/3028'MD,2942'TVD (J f -500 GPM,1050 PSI ON,1050 PSI OFF -100 RPM,7-9K TQ ON,5K TQ OFF i s- o41) -PU WT 122K,SO WT 122K,ROT 118K -WOB 1-3K -MW 9.8 PPG IN,9.8 PPG OUT -SPR'S 3022'MD(2937'TVD),MW 9.8 PPG -#1 20/30SPM,125/165 PSI -#2 20/30 SPM,125/165 PSI 3/16/2014 00:00 - 03:00 3.00 STWHIP P WEXIT MILL 8-1/2 WINDOW -F/3028'T/3039'MD,2951'TVD -500 GPM,1060 PSI ON,1000 PSI OFF -100 RPM,3-9K TQ ON,3-4K TQ OFF -PU WT 116K,SO WT 115K,ROT 119K -WOB 3-6K -MW 9.8 PPG IN,9.8 PPG OUT -PUMP HI-VIS SWEEP @ 3039' -15%INCREASE IN METAL CUTTINGS RETURNS -100%SAND -NO CEMENT PRESENT LOSS RATE 5 BBUHR TOP OF WINDOW 3022' BOTTOM OF WINDOW 3039' SIMOPS BUILD STANDS 5"DP OFFLINE Printed 3/24/2014 10:43:31AM • • • North America-ALASKA-BP Page 10 Operation Summary Report Common Well Name:18-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/9/2014 End Date: X3-014HQ-C:(10,840,400.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:PARKER 272 Spud Date/Time:12/25/1982 12:00:00AM Rig Release: Rig Contractor:PARKER DRILLING CO. UWI:500292087500 Active datum:18-04D @63.20usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 03:00 - 08:00 5.00 STWHIP P WEXIT DRILL 8-1/2 INTERMEDIATE -F/3039'T/3060'MD,2968'TVD -500 GPM,1100 PSI ON,1000 PSI OFF -100 RPM,3-9K TO ON,3-4K TQ OFF -PU WT 117K,SO WT 116K,ROT 119K -WOB 10K -MW 9.8 PPG IN,9.8 PPG OUT RETURNS -75%SAND -15%SHALE -10%CLAY/SILT -SPR'S 3060'MD(2968'TVD),MW 9.8 PPG -#1 20/30 SPM,120/160 PSI #220/30SPM,120/162 PSI LOSS RATE 5 BBL/HR SIMOPS BUILD STANDS 5"DP OFFLINE 08:00 - 08:30 0.50 STWHIP P WEXIT CBU 2X'S -PULL INTO WINDOW -800 GPM,2300 PSI -50 RPM,2-4K TQ -RECIPROCATE PIPE 30' -PUMP HI-VIS SWEEP NO INCREASE IN CUTTINGS 08:30 - 10:00 1.50 STWHIP P WEXIT LOT AT 3024'MD,2938'TVD -RACK ONE STAND BACK -MONITOR WELL FOR 10 MINUTES -FLUID LEVEL DROPPING SLIGHTLY -M/U TOP DRIVE -FILL KILL LINE AND CHOKE LINE -MW 9.8 PPG IN,9.8 PPG OUT -PUMP 27.4 BBL,PRESSURE TO 500 PSI -13.0 PPG EMW -MONITOR FOR 10 MINUTES -PRESSURE L/O TO 385 PSI -BLEED BACK 7.5 BBL -OBTAIN APPROVAL FROM WTL JIM WILLINGHAM TO PROCEED WITH OPERATIONS 10:00 - 10:30 0.50 STWHIP P WEXIT BLOW DOWN SHOKE AND KILL 10:30 - 11:00 0.50 STWHIP P WEXIT SERVICE RIG 11:00 - 13:30 2.50 STWHIP P WEXIT POOH -F/3024'T/860' -MONITOR WELL FOR 10 MIN -FLUID LEVEL DROPPING SLIGHTLY -MW 9.8 PPG IN,9.8 PPG OUT -POOH ON ELEVATORS PU WT 95K,SO WT 95KAT 1409'MD 13:30 - 16:30 3.00 STWHIP P WEXIT L/D BHA -STAND BACK 5 STDS HWDP -L/D DC'S AND MILLS -BOTH UPPER WATERMELLON MILLS IN GAUGE Printed 3/24/2014 10:43:31AM - BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB DS 18 18-04 500292087500 18-04C Survey: MWD Survey Report - Geographic 02 March, 2011 Qbp 1r• Z Mall BAKER HUGHES Survey Report-Geographic 0 bp LNTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 18-04 Project: Prudhoe Bay TVD Reference: 18-04B Rig:45.10 @ 45.10ft(18-04B Rig:45.10 Site: PB DS 18 MD Reference: 18-04B Rig:45.10 @ 45.10ft(18-04B Rig:45.10 Well: 18-04 North Reference: True Wellbore: 18-04C Survey Calculation Method: Minimum Curvature Design: 18-04C Database: EDM.16-ANC Prod-WH24P Project Prudhoe Bay,GPB,PRUDHOE BAY Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB DS 18,TR-11-14 Site Position: Northing: 5,959,213.15ft Latitude: 70°17'35.252 N From: Map Easting: 691,583.44ft Longitude: 148°26'55.555 W I Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 1.46 ° Well 18-04 API No 500292087500 Well Position +N/-S 0.00 ft Northing: 5,960,796.07 ft Latitude: 70°17'50.819 N +EI-W 0.00 ft Easting: 691,571.58 ft Longitude: 148°26'54.724 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 18-04C API No 500292087503 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (0) (nT) BGGM2010 2/1/2011 21.84 81.01 57,664 Design 18-04C Audit Notes: Version: Phase: ACTUAL Tie On Depth: 9,977.04 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (0) 29.00 0.00 0.00 225.57 Survey Program Date: 3/2/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 89.10 8,689.10 Survey#2(18-04) GYD-CT-CMS Gyrodata cont.casing m/s 8,718.00 9,804.14 18-04B PB1 (18-04BPB1) MWD MWD-Standard 9,882.00 9,977.04 18-04B(18-04B) MWD MWD-Standard 9,982.50 10,675.00 MWD(18-04C) MWD MWD-Standard 3/2/2011 4:36:39PM Page 2 COMPASS 2003.16 Build 73 BAKER HUGHES Survey Report-Geographic 0 bp LNTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 18-04 Project: Prudhoe Bay TVD Reference: 18-04B Rig:45.10 @ 45.10ft(18-04B Rig:45.10 Site: PB DS 18 MD Reference: 18-04B Rig:45.10 @ 45.10ft(18-04B Rig:45.10 Well: 18-04 North Reference: True Wellbore: 18-04C Survey Calculation Method: Minimum Curvature Design: 18-04C Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +NI-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 9,977.04 34.57 159.71 8,408.07 -2,676.39 -3,517.24 5,958,031.05 688,123.91 70° 17'24.489 N 148°28'37.213 W TIP 9,982.50 34.51 159.01 8,412.56 -2,679.28 -3,516.15 5,958,028.19 688,125.08 70° 17'24.460 N 148°28'37.181 W KOP 10,020.22 40.35 148.94 8,442.53 -2,699.76 -3,506.00 5,958,007.98 688,135.74 70° 17'24.259 N 148°28'36.885 W 10,052.66 48.24 142.76 8,465.74 -2,718.43 -3,493.23 5,957,989.64 688,148.98 70° 17'24.076 N 148°28'36.513 W 10,087.24 60.88 137.59 8,485.76 -2,739.94 -3,475.16 5,957,968.60 688,167.59 70° 17'23.864 N 148°28'35.986 W 10,114.50 69.44 134.13 8,497.21 -2,757.66 -3,457.93 5,957,951.33 688,185.27 70° 17'23.690 N 148°28'35.484 W 10,153.80 72.88 122.45 8,509.93 -2,780.62 -3,428.78 5,957,929.12 688,214.99 70°17'23.464 N 148°28'34.634 W 10,186.64 74.97 115.29 8,519.04 -2,795.84 -3,401.16 5,957,914.61 688,242.99 70°17'23.315 N 148°28'33.829 W 10,220.06 74.59 110.03 8,527.82 -2,808.26 -3,371.42 5,957,902.95 688,273.04 70°17'23.193 N 148°28'32.962 W 10,254.16 73.29 105.03 8,537.26 -2,818.13 -3,340.18 5,957,893.88 688,304.51 70°17'23.096 N 148°28'32.052 W 10,286.38 73.59 99.64 8,546.45 -2,824.72 -3,310.02 5,957,888.06 688,334.82 70°17'23.031 N 148°28'31.173 W 10,312.84 72.66 96.80 8,554.13 -2,828.34 -3,284.97 5,957,885.08 688,359.96 70°17'22.995 N 148°28'30.443 W 10,347.26 68.41 94.05 8,565.60 -2,831.42 -3,252.67 5,957,882.83 688,392.33 70°17'22.965 N 148°28'29.502 W 10,384.80 65.47 92.40 8,580.30 -2,833.37 -3,218.19 5,957,881.76 688,426.84 70°17'22.946 N 148°28'28.497 W 10,433.30 63.51 99.58 8,601.21 -2,837.91 -3,174.70 5,957,878.33 688,470.44 70°17'22.902 N 148°28'27.230 W 10,470.30 64.35 104.09 8,617.48 -2,844.73 -3,142.18 5,957,872.34 688,503.11 70°17'22.835 N 148°28'26.282 W 10,506.82 67.82 106.52 8,632.28 -2,853.55 -3,109.99 5,957,864.34 688,535.52 70° 17'22.748 N 148°28'25.344 W 10,562.70 71.75 105.88 8,651.59 -2,868.17 -3,059.65 5,957,851.01 688,586.22 70° 17'22.605 N 148°28'23.877 W 10,616.68 69.29 109.45 8,669.59 -2,883.60 -3,011.16 5,957,836.82 688,635.07 70° 17'22.453 N 148°28'22.464 W 10,675.00 69.29 109.45 8,690.22 -2,901.76 -2,959.73 5,957,819.98 688,686.95 70° 17'22.275 N 148°28'20.965 W TD 3/2/2011 4:36:39PM Page 3 COMPASS 2003.16 Build 73 I Irli it BAKER PRINT DISTRIBUTION LIST N I 0 zij,i HUGHES AOGCC COMPANY BP Exploration(Alaska)Inc. INTERMEDIATE FINAL Yes (mandatory) WELL NAME 1b -0'2N,C, RUN NUMBER Z\ \ — oC'O^2 (mandatory) 2-7_76J V FIELD Prudhoe Bay BH SALESMAN Okechukwu(Okey)Anyanwu (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: TODAYS DATE: 6/5/2013 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: BP Exploration(Alaska)Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY D FIELD FINAL (digital ' I/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Ur NHIN I S #OF COPIES #OF COPIES 4 4 .4 11 4 1 BP Exploration(Alaska)Inc. I 3 I 1 I I Petrotechnical Data Center LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. I I 1 I I I Attn Ricky Elgarico PO Box 100360 Anchorage,Alaska 99510 3 ExxonMobil,Alaska 1 1 I 1 I I 1 Attn Lynda M.Yaskell and/or Leonardo Elias 3700 Centerpointe Dr. Suite 600 Anchorage,Alaska 99503 4 State of Alaska-AOGCC 1 I 1 I I I Christine Shartzer 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas I I 1 1 I Attn:Sean Clifton 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501 TOTALS FOR THIS PAGE: 0 5 5 0 0 0 TOTALS FOR ALL PAGES: 0 5 5 0 0 0 w\�\�j/j�s9 THE STATE Alaska Oil and Gas +moi-� 0fALAs 1 C �o uservatiGn Co ‘missitri GOVERNOR SEAN PARNELL 333 West Seventh Avenue �g� Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 Mary Endacott Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-04C Sundry Number: 313-536 Dear Ms. Endacott: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, if,/1 /0 � Cathy '. Foerster Chair, Commissioner DATED this IG day of October, 2013. Encl. C - STATE OF ALASKA RECEIVED ` , ALASF.,,OIL AND GAS CONSERVATION COMMISoiON U 5,13 APPLICATION FOR SUNDRY APPROVAL j°A OCT 10 2013 20 AAC 25.280 OGCC A 1. Type of Request: AOGCC ❑Abandon ®Plug for Redrill • 0 Perforate New Pool 0 Repair Well 0 Change Approved Program ❑Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension ❑Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration(Alaska) Inc. ❑Exploratory 0 Stratigraphic 211-002 • 3. Address: 6. API Numbe e,Alaska 99519-6612 ®Development ❑Service P.O. Box 196612,Anchorage, 50.029-20875-03-00 • 7. If perforating: 8. Well Name and Number: 1 What Regulation or Conservation Order governs well spacing in this pool? PBU 18-04C Will planned perforations require a Spacing Exception? 0 Yes ® No 9. Property Designatior 10.Field/Pool(s): ADL 028307 • Prudhoe Bay Field/Prudhoe Bay 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): 10675' 8690' 8855' 7494' 2185'&8855'(TOC) 3100' Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' Surface 2629' 13-3/8" 2629' 2593' 4930 2670 Intermediate 8718' 9-5/8" 8718' 7370' 6870 4760 Production Liner 1341' 7" 8541'-9882' 7208'-8331' 7240 5410 Liner 909' 4-1/2" 9685'-9983' 8173'-8413' , 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): None None 4-1/2", 12.6# 13Cr-80 9608' Packers and SSSV Type: 7"x 4-1/2"Baker'S-3'Packer Packers and SSSV 9551'/7661' MD(ft)and TVD(ft): 12. Attachments: 13.Well Class after proposed work: ®Description Summary of Proposal ®BOP Sketch • 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic ® Development 0 Service 1 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation: March 15,2014 0 Oil 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG ®Suspended - 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Jesse Rosenbaum,564-5155 Printed Name: Mary Endacott Title: Engineering Team Leader Email: Jesse.Rosenbaum@bp.com Signature: 17)/--9 ✓ jig 1 If Phone: 564-4388 Date: /0//0/4 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness \'2. �� Sundry Number: .� ❑Plug Integrity BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: - -s± f-p .35 OC 5 1 �lfcv��G �� p ! v � lacrr )-, rv, approvrd pzv- A 25,112(t- Spacing Exception Required? 0 Yes ❑No Subsequent Form Required: /Q — 4-U .7 APPROVED BY Approved By: P )2Z-1/4"----- COMMISSIONER THE COMMISSION Date: !0-/6 " /3 Y{ Form 10-403 Revised 1 /2012 Approv a f i1 NIAtimonths Submit In Duplicat 'U1: 1bp/5/13i�y�� from the to of approval RBDMS OCT 16 2�I.\Q� Qbp GP1 i Well Name: 18-04C Well Type: Producer Current Status: Ops. Shut down. Request: P&A-Well Prep f/Rotary Sidetrack MIT-OA- passed to 2000 psi (8/26/13) MIT-IA- passed to 3000 psi (8/26/13) MIT-T-pass to 3000 psi w/SSSV plug at 2161' MD(3/11/12) Well History: 18-04 was originally drilled as a vertical Romeo graben well in January 1983. It produced until April of 1998, when it was sidetracked to 18-04A, a horizontal graben well. During drilling operations, TD was called 450 ft short due to shale issues. It was unclear at the time of completion whether the reservoir was of good enough quality. Post sidetrack, the well would not flow. Several attempts were made to get the well on production, all with no results (nitrogen lifts, high pressure breakdown, 13,000Ib frac). In • August 1999, a coiled tubing gas lift string was run in the well in hopes that artificial lift would help this well to flow. The well finally flowed, but production was sporadic and required frequent hot oil treatments. In March 2000, the well quit flowing altogether due to paraffin buildup inside and outside the coiled tubing gas lift . string. 18-04B was a July 2001 rotary sidetrack targeting a structurally low block within the Midfield Graben. It was completed as high angle well in Zone 1B/1A. The well struggled to flow at -800 bopd at 3100 GOR from Zone 1 and required frequent Hot Oil Treatments. The oil rate steadily declined until Jan 2002 when 27 ft of Zone 2A were perforated. The well tested strong at-3000 bopd but declined to 1000 bopd at 30,000 GOR in . a few months. From mid 2002 to 2007, it cycled with slowly declining recharge and on time. The well was shut-in for high GOR in Jan 2008 when it POP and tested at 89,000 GOR after a 4 month shut-in period. Subsequent attempts to POP the well were not successful. Handed over to CTD group for a sidetrack. • 18-04C was a CTD sidetrack drilled in February 2011, targeting the Zone 1B/1A in the Ivishak. While drilling the production hole, a fault/loss zone was encountered and the well went on total losses. The decision was made to move off the well and return after an engineering plan was formulated. Another attempt to finish drilling and complete the well with CTD was performed in February of 2012. While drilling, the well went on complete losses and encountered stuck pipe. After many attempts to remediate losses and free pipe, the decision was made to bullhead cement down the coil followed by cutting and fishing coil at 3,100' MD. Injectivity down the backside of the CT was established at 2 BPM, 1180 PSI. Injectivity was established on 10/8/2013 at 780 psi at1.5 bpm with crude. Reason for P&A/RST: 18-04C is non-operable producer that was never completed and has no remaining options for well work due . to -5000 ft of a-line wire and cement inside the coil. A RWO to fish the remaining coil would be uneconomic. The proposed RST would access reserves in the midfield graben in Romeo block. Other Requests: Request approval for down squeezing cement for 18-04C P&A. • 18-04C Sundry Application 1 co", 10/10/2013 Scope Planned Sundry Work: As currently planned, the P&A of the 18-04C well and the well work in preparation for the 18-04D rotary sidetrack will be as follows: P&A: 1. RU coil and establish injectivity rate. 2. Use service coil to down squeeze - 100 bbls of 15.8 PPG class "G" cement down backside of coil targeting TOC at 3,100' MD. 3. Circulate excess cement off the top of the coil fish at 3100' MD 4. Pressure test cement plug to 2500 psi. Pre-Rig: 1. Drift 4-1/2" tubing and tag CT fish at-3,100' MD. 2. Jet cut 4-1/2", L-80, 12.6#, tubing mid joint above fish. 3. Circulate jet cut with clean seawater. 4. CMIT-TxIA to 3500 psi. 5. PPPOT-T, PPPOT-IC, function LDS. 6. Set BPV and test. Rig Work: 1. MIRU/confirm barriers. 2. ND Tree. NU BOPE and test to 250 psi low/3,500 psi hi h. ch'`) 3. RU and pull 4-1r"tubing from -3050' MD. 313 -531,, 4. PU 9-5/8" clean-out BHA and RIH to the top of the 4-1/2"tubing stub. 5. Set a 9-5/8" bridge plug at as required to avoid milling a casing collar and test to 3,500 psi. 6. RIH with 9-5/8" Whipstock assembly and 8-1/2" window milling assembly above EZSV. Orient and set whipstock. /NI or)v ' M p 7. Hang milling BHA on a storm packer and change-out tubing spool and 9-5/8" pack-off.. 8. NU and retest BOPE break. 9. Kick-off welfan_ ri - 2 hole section to-12,350' MD 10. Run 7" liner. 11. Drill 6-1/8" production hole section to TD--13,100' MD 12. Run 4-1/2" liner and completion string, perforate well 13. Secure well, RDMO. Post-Rig Work: I v ✓PTS 1. Pull ball and rod and RHC profile 2. Re-install wellhouse and FL's. 3. Generic GLV's MPSP Res P; 3,35-cps MASP: 2501 psi @ 8490' TVDss(7.59 ppg pore pressure at TSGR with 0.1 psi/ft gas gradient) • Estimated Pre-Rig Start Date: March 15th, 2014 Attachments: Existing Well Schematic Proposed Pre Rig Well Schematic Drilling Engineer: Jesse Rosenbaum (907)564-5155 Production Engineer: Noelle McBride (907)564-4619 Geologist: Katherine Cunha (907)564-5574 18-04C Sundry Application 2 10/10/2013 TREE' Mc EV OY WELLHEAD= McEVOY 1 8-04C SAFETY/2'CHROME BG •" WELL ANGLE>70 @ 10120'" 4 —ACTUATOR= AXE/ OPS SHUT DOWN K8..ELEVELEV= 455.11' BF.ELEV= 19 21' KOP= 2100' Max Angle 5°@ 10187' 2185' —14-1/2"CAMCO BAL-O SSSVN,ID=3.813" Datum MD= 11113' Datum ND= 8800'SS 2185' —4-12"DSSSV PLUG(01/27/12) 20"CONDUCTOR 120' 13-3/8"CSG,72#, L-80 BTRS, ID=12.347" H 2629' ( GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE TOP OF COIL TUBING(03/02/11) —I 3100' ❑ 4 3168 3055 35 MMGM DMY RK 0 03/29/08 3 5993 5193 40 MMGM DMY RIC 0 03/29/08 1 2 8112 6830 31 MMGM DMY RK 0 04/06/02 1 9514 8116 38 KBG-2 DMY BK 0 04/06/02 Minimum ID = 3.80" 9595' 8541' H9-51&'x7"BKR ZXP PKR/TIEBACK ID=6313' 4-1/2" MILLED OTIS XN NIP 8555' —{9-5/8"x7"BKR HMC LNR PGR,ID=6.313" TOP OF WHIPSTOCK —{ 8741' \ 9-5/8"CSG,47#,L-80 BTRS, ID=8.681" ---1 —8734 — 9-5/8"FOLLOW'WINDOW(18-048)8718'-8734' PERFORATION SUMMARY 8855' --I TOP OF CEMENT INSIDE COIL REF LOG SWS PERF ON 08/14/01 ANGLE AT TOP PERF: 18 @ 10383' ilk r 9541' —14-1/2"OTIS X NIP, ID=3.813" Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10383- 10410 'C 0122/02p 9551' —{7"X 4.1/2"BKR S-3 PKR,ID=3.875" 3-3/8" 6 10410-10450 'C 09/25/01X 2-7/8" 4 10426- 10456 'C 08/14/01 2478" 4 10465-10485 'C 08/14/01 9575' H4-1/2"OTIS X NIP, ID=3.813" 4416 9595' H4-1/2"OTIS XN NIP,MILL TO 3.80"(02/05/11) "PERFORATIONS BELOW WHPSTOCK 9980' i 1 9608' —14-112"WLEG,ID=3 958" 4-1/2'TBG, 12.6#,13CR-80 VAM ACE, H 9606' t .0152 bpf, ID=3.958" 9685' I--7"X 4-1/2"BKR ZXP PKR w/7.40'TIEBACK &HMC LNR HGR ID=4 39" 7"LNR,26#,L-80 BTC, .0383 bpf,ID=6.276" —{ 9882' 3 80"MILLOUT WINDOW(18-04C)9983'-9990' 4-1/2"PKR WHIPSTOCK(02/22/11) — 9980' 4-1/2"LNR, 12.6#, L-80, 0152 bpf, ID=3 958" —I —9990' 4-12"OPEN HOLE — 10675' ' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/29/83 ROW 41 INITIAL COMPLETION 02/27/12 DAS/PJC SET DSSSV RUG WELL: 18-04C 05/18/98 N4/3 ES CTD SIDETRACK(18-04A) FERMI No '2110020 07/17/01 N7ES SIDETRACK(18-04B) API No: 50-029-20875-03 03/02/11 NORDIC 1 CTD SUSPENDS)(18-048) SEC 24,T11 N,R14E, 1067'FNL&191'FEL 02/18/12 NORDIC 2 OPS SHUT DOWN(18-04C) 02/26/12 PJC DRLG HO CORRECTIONS 02/27/12 W/PJC BORE B CTD CORRECTION BP Exploration(Alaska) • • TREE= M;EVOY WELLHEAD= M:EVOY 1 8-04C 41/1 CHROME TBG***NOTES: L ANGLE>70 @ 10120'*** ACTUATOR= AXELSON KB.ELEV= 45.1' PROPOSED Pie-RijP&A BF.ELEV= 19.21' r KOP= 2100' Max Angie= 5"©10187' 2185' �4 112"CAMCO BAL-O SSSVN D=3.813" Datum MD= 11113' 0 Datum ND= 8800'SS 20"CONDUCTOR H 120' 13-3/8"CSG,72#,L-80 BTRS,ID=12.347" H 2629' GAS LIFT MANDRELS ST MJ ND DEV TYPE VLV LATCH PORT DATE TOP OF COIL TUBING(03/02/11) —I 3100' ,r,' 4 3168 3055 35 MMGM DMY RK 0 03/29/08 3 5993 5193 40 MA/GM DMY RK 0 03/29/08 1 I 2 8112 6830 31 MMGM DMY RK 0 04/06/02 ' 1 9514 8116 38 KBG-2 DMY BK 0 04/06/02 8541' H9-5/8"X 7"BKR ZXP PKR/TIEBACK,D=6.313" 8555' —19-5/8"X 7"BKR HMC LNR HGR ID=6-313" 1 9-5/8"MLLOUT WNDOW(18-04B)8718'-8734' 9-5/8"CSG,47#,L-80 BTRS,ID=8.681" H -•8734 — 8855' -I TOP OF CEMENT WIDE COL ,,...,,:- 9541' —14-1/2"OTIS X NP,D=3.813" ►, ow NI9551' —17"X 4-1/2"BKR S-3 PKR,ID=3.875" ►, 1 i IN AO9575' H4-1/2"OTIS X NIP,ID=3.813" ►` IIK4 :` 9595' —14-1/2"OT1S XN NIP,MLL TO 3.80"(02/05/11) IN1 9608' —4-1/2"WLEG,ID=3.958" 4-1/2"TBG, 12.6#,13CR-80 VAM ACE, H 9606' 010 .0152 bpf,ID=3.958" OW 9685' —7"X 4-1/2"BKR ZXP PKR w/7.40'TIEBACK &HMC LNR HGR D=4.39" 26#,L-80 BTC,-0383 bpf,ID=6.276" H 9882' ►, 7"LNR � `. 3.80"MLLOUT WrIDOW(18-04C)9983'-9990' 4-1/2"PKR W-IPSTOCK(02/22/11) —I 9980' iiii,„... 4-1/2"LNR, 12.6#,L-80,.0152 bpf,D=3.958" — ^-9990' 111001.111041bpf, OE3 WC SWS IR1t4W1A41N01 ANOLEA 1 IOPPERF.18@ 1038:1' 10114 143te Relate R0Wchn O01a 1151u4W Pat Wa4-1/2"OPEN HOLE — 10675' SUE SPF 14I9NAL Om/34,4CATE � 118• 0 10383 10410 •C 01/71.02 \ 318' 8 10110 10050 , 0915.01 2-TI8• 0 10426 10456 •C 0811401 2-/!8' 0 10085.10485 •C 00/14/11 PERFORATN*18(4130WWHPSTOCNAl 998, .••• DATE REV BY CONSENTS DATE REV BY CONTENTS PRUDHOE BAY UNIT 01/29/83 ROW 41 INTIAL COMPLETION 02/27/12 DAS/PJC SET DSSSV PLUG WELL: 18-04C 05/18/98 N4/3 ES CTD SIDETRACK(18-04A) PERMT No:"2110020 07/17/01 N7ES SIDETRACK(18-04B) AR No: 50-029-20875-03 03/02/11 NORDIC 1 CTD SUSPENDED(18-04B) SEC 24,T11N,R14E, 1067'FNL&191'FEL 02/18/12 NORDIC 2 OPS SHUT DOWN(18-04C) 02/26/12 PJC DRLG HO CORRECTIONS 02/27/12 W/PJC BORE B CTD CORRECTION BP Exploration(Alaska) ' tK =TREEEVOY TREE= D= IvEVOY 1 8-04D SA.- n NOTES: WELL ANGLE>70 @ 10120'*** ACTUATOR= AXELSON 4-112"CHROME TBG*** KB.ELEV= 45.1' Proposed Pre-R ig- BF.REV= 19.21' I1 KOP_= 2100' 4 Max Angle= 5"@ 10187li ,,, 2185' -I4-1/2"CAMCO BAL-O SSSVN,ID=3.813" Datum MD= 11113' Datum TVD= 8800'SS p 20"CONDUCTOR H 120' /�,\ -3000'MD Tut JetCut 13-3/8"CSG,72#,L-80 BTRS,ID=12.347" - 2629' GAS LFT MANDRELS .111 � ,, -r- - . ST MD TVD DEV TYPE VLV LATCH PORT DATE TOP OF COIL TUBING(03/02/11) - 3100' " 4 3168 3055 35 MMGM DMY RK 0 03/29/08 • 3 5993 5193 40 MMGM DMY RK 0 03/29/08 2 8112 6830 31 MMGM DMY RK 0 04/06/02 L 1 9514 8116 38 KBG-2 DMY BK 0 04/06/02 (N S 'V 36 8541' -9-5/8"X 7"BKR ZXP R<RI11EBACK,ID=6.313" Corrosion Inhibited - 8741' 8555' -9-5/8"X 7"BKR HMC LNR HGR,ID=6.313" Brine II 9-5/8"MLLOUT WINDOW(18-048)8718'-8734' 9-5/8"CSG,47#,L-80 BTRS,ID=8.681" H 8734 — i 8855' H TOP OF CEMENT INSIDE COL - 1 9541' -4-1/2"OTIS X NIP,ID=3-813" = 9551' -7"X 4-1/2"BKR S-3 Rte,ID=3.875" 7. 1 : 9575' H4-1/2"OTISXNIP,ID=3.813" 4 9595' H 4-1/2"OTIS XN NP,MILL TO 3.80"(02/05/11) .c� 9608' -I4-112"WLEG,ID=3.958" 4-1/2"TBG, 12.6#,13CR-80 VAM ACES H 9606' ','.1• r .0152 bpf,ID=3-958" 4 9685' -7"X 4-1/2"BKR ZXP PKR w/7.40'TIEBACK Vii.. ; &HMC LNR HGR,ID=4.39" I. Ito 7"LNR,26#,L-80 BTC,.0383 bpf,ID=6.276" --i 9882' - '\ 3-80"MLLOUT WINDOW(18-04C)9983'-9990' 4-1/2"RKR WHPSTOCK(02/22/11) -I 9980' \ ''' .:'''"s 4-1/2"LNR,12.6#,L-80,.0152 bpf,D=3.958" - -9990' RR/O AS014a1404aur RFT WO SWSPII-SN0811001 • ..� SKR F RI IOP HIS 18(1)10383' Note Refer101tiwcsmuurot tislrt2alpert as/ ..,.\ 4-1/2"OFENHOLE - 10675' SPF SPFNIFAL 00/Pap CAM e IN \� 3 N 8 10383 10410 10 01172/02 1318" a 10410 10450 • 0945/01 . AV 2-fir < 10426 10456 10 0811401 z-lis- a 10185-lows •r.0 os1e/01 ,... 41 •4. # 'P6FQ0\110M8 BELOW WHIPSTOCK 1Mfi0CNe! . *: •� DATE REV BY COMME3VTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/29/83 ROW 41 INITIAL COMPLETION 02/27/12 DAS/PJC SET DSSSV PLUG WELL: 18-04C 05/18/98 N4/3 PS CTD SIDETRACK(18-04A) PERMIT No:'110020 07/17/01 N7ES SIDETRACK(18-04B) AR No: 50-029-20875-03 03/02/11 NORDIC 1 CTD SUSPI3')D(18-04B) SEC 24,T11 N,R14E, 1067'FNL&191'FEL 02/18/12 NORDIC 2 OPS SI-UT DOWN(18-04C) 02/26/12 PJC DRLG HO CORRECTIONS 02/27/12 W/PJC BORE B CTD CORRECTION BP Exploration(Alaska) .• TREE= Calico 1AELLFEAD= AtEVOY 18-04D F ACTUATOR= AXELSON KB.BEV= 45.1' Proposed BF.R.EV= 19.21' KOP= 2100' Max Angle= XXXX —2,200 H4-1/2"OTIS X NP,ID=3.813" Datum M20= XXXX' Datum TVD= 8800'SS 20"CONDUCTOR — 120' GAS LET MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 13-3/8"CSG,72#,L-80 BTRS,D=12.347" H I 2629' 1 3500 KBG-2 DCK 2 5400 KBG-2 DMY 3 6900 KBG-2 DMY 4 7900 KBG-2 DMY ,,,,, A l \ 2950' H 9-5/8"X 7"BKR ZXP PKIVREBACK,D=6-313" 2975' 9-5/8"X 7"BKR HMC LNR HGR,D=6.313" 9-5/8"CSG,47#,L-80 BTRS,D=8.681" H —3000' , ti Al 1" I 11,710' —14-1/2"OTIS X NIP,D=3.813" X ' 11,800' --17"X 4-1/2"HES TNT Rod.Packer 11 ' 11,900' H4-1/2"OTIS X NIP,D=3.813" I12,000'-4-1/2" OTIS XN NIP, ID= 3.725" 12,100' —14-1/2"WLEG,D=3.958" 4-1/2"TBG, 12.6#,13CR-80 VAMTOP. 12100' ! 12,100' 17"X 4-1/2"BKR_LIP PKR .0152 bpf,D=3.958" &HMC LNR HGR,D=4.39" IP m 7"LNR,26#,L-80 BTC,.0383 bpf,D=6.276" —I 12,350' e¢. 4-1/2"LNR,12.6#,13Cr-80,.0152 bpf,ID= 13,090' , 3.958" • DATE REV BY COMvU'TTS DATE REV BY COMENTS FRUDHOE BAY UNIT 01/29183 ROW 41 IMTIAL COMPLETION 02/27/12 CAS/PJC SET DSSSV PLUG WELL: 18-04D 05/18/98 N4/3 ES CTD SIDETRACK(18-04A) 09/07/13 JER PROPOSED COMPLETION PERMIT Nu:"2110020 07/17101 N7ES SIDETRACK(18-04B) AFI No: 50-029-20875-03 03/02/11 NORDIC 1 CTD SUSPEICED(18-04B) SEC 24,T11 N,R14E, 1067'FNL&191'FEL 02/18/12 NORDIC 2 OPS SHUT DOWN(18-04C) 02/26/12 PJC DRLG HO CORRECTIONS 02/27/12 MV/PJC BORE B CID CORRECTION BP Exploration(Alaska) s Parker 272 BOPE Schematic PARKER 272 BOP STACK RAM TYPE 90P: DUTCH LOCK DOWN FLANGE SHAFFER LXT DOUBLE BOP 13 5/8"-5M 13 5/8"-5M STUDDED TOP 13 5/8"-5M FLANGED BOTTOM W/(2) I4" UL2 OPERATOR. UPPER CAVITYXi 0 ANNULAR BOP: AND (2) 14" PSLK W/BSTR OPERATOR, PAMtn� SHAFFER LXT 13 5/8" 5M LOWER CAVITY 13-5/8" 5M STUDDED TOP 0 13--5/8" 5M FLANGED BOTTOM 0 1 r DRILLING CROSS: 13 5/8"-SM FLANGED TOP r� 47 �♦C 13 5/8"-5M FLANGED BOTTOM � - .4„..., • ��i� 3 W(2) 3 1/8"-5M SIDE OUTLETS I- e (tei -I Ii•• t.ta,'• •• it T I - KILL LINE: •�� a, II.� 2-1/16" 5M FLEX HOSE :�����5►�i�� 1.♦t !w •rmi t 1■ ' +t 2-1/16" 5M X 3-1/8" 5M D.S.A, �1W \ l`'� I IVAII i 3-1/8" SM FLANGED MANUAL LATE VALVE 3-1/8" 5M FLANGED HYDRAUUC GATE VALVE 11 1 CHOKE LINE: RAM TYPE BOP: 3-1/8" 5M FLANGED MANUAL GATE VALVE SHAFFER LXT s;NGLE 13 5/8' 5M J 3-1/8" 5M FLANGED HYDRAULIC GATE VALVE 13 5/8"-5M SFLANGE BOTTOM 13 5/8"- 5M FLANGED BO 3-1/8" 5M FLEX HOSE W/(2) 14° UL2 OPERATOR pT.b 2JI 2- Ferguson, Victoria L (DOA) From: Ferguson,Victoria L(DOA) Sent: Tuesday, October 08, 2013 9:44 AM To: 'Rosenbaum,Jesse E' Subject: RE: 18-04C Plug for Redrill(PTD 211-002) Jesse, Please submit a 10-403 for a plug-for-redrill approval. Thanx, Victoria Victoria Ferguson Senior Petroleum Engineer State of Alaska Oil&Gas Conservation Commission 333 W.7th Ave,Ste 100 Anchorage,AK 99501 Work: (907)793-1247 victoria.ferquson )alaska.gov From: Rosenbaum, Jesse E [mailto:Jesse.Rosenbaum(a)bp.com] Sent:Tuesday, October 08, 2013 8:33 AM To: Ferguson, Victoria L(DOA) Cc: Endacott, Mary S; Staudinger, Garret Subject: 18-04C P&A Verbal Approval Request Importance: High Hi Victoria, Garret Staudinger contacted you ^' 2 weeks ago regarding a plan for the P&A of 18-04C in preparation to drill a rotary sidetrack (18-04D).This well is currently under an "operations shutdown" status. I just wanted to confirm that we have verbal approval to go ahead with this plan so we can submit a sundry in a timely fashion. Thank you for discussing the options with us.The well schematic is attached for your reference. «18-04C.pdf» «18-04C Proposed P&A.pdf» Jesse Rosenbaum Drilling Engineer I BP Exploration Alaska 0:907-564-5155 I C:406.533.8984 Jesse.rosenbaum(a.bp.com 1 TREE= McEVOY WELLHEAD= NbEVOY 1 8-04C Ss NOTES: WELL ANGLE>70 @ 10120'•** ACTUATOR= AXELSON 4-1 fc'CHROME TBG*** KB.ELEV= 45.1' OPS SHUT DOWN BF.ELEV= 19.21' I KOP= 2100' Max Angle= 5' 1.•• 10187' 2185' _—14-12'CAMCO BAL-O SSSVN,ID=3.813" Datum MD= 11113' Datum TVD= 8800'SS l'!4.- __'"} 2185' H4-112"DSSSV PLUG(01/27/12) 20"CONDUCTOR H 120' �J�--' 4- )/y /' 13-318"CSG,72#,L-80 BTRS,ID=12.347" H 2629' I GAS LIFT MANDRELS ST MD IVO DEV TYPE VLV LATCH FORT DATE TOP OF COIL TUBING(03/02/11) —1 3100' 1----- 4 3168 3055 35 MMGM DMY RK 0 03/29/08 El3 5993 5193 40 MMGM DMY RK 0 03/29/08 t 1 28112 6830 31 MMGM DMY RK 0 0406102 I1 9514 8116_ 38 KBG-2 DMY BK 0 04/06/02 Minimum ID = 3.80" 9595' 8541' H9-5/8"X 7"BKR ZXP PKR/TIEBACK,ID=6.313" 4-112" MILLED OTIS XN NIP 8555' --19-518"x 7"BKR HNC LNR HGR,0=6.313" TOP OF WHIPSTOCK H 8741' IN 9-5/8"CSO,47#,L-80 BTRS, ID=8.681" H —8734 9-5/8"MLLOUT WINDOW(18-04B)8718'-8734' I PERFORATION SUMMARY I 8855' HTOP OF CEMENT INSIDE COIL REF LOG: SWS PERF ON 08/14/01 ANGLE AT TOP PERF: 18 '- 10383' 9541' ---r4-1/2"OTIS X NIP, ID=3.813" Note:Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sgz DATE 3-3/8" 6 10383-10410 "C 0122/02Skz 9551' —17"X 4-1/2"BKR S-3 PKR,ID=3.875" 3-3/8" 6 10410- 10450 'C 0925/01 2-7/8" 4 10426- 10456 'C 08/14/01 2-/78" 4 10465- 10485 'C 08/14/01 9575' --14-1/2"OTIS X NIP,ID=3.813" *PERFORATIONS BELOW WHIPSTOCK 9980' ► i 9595' H4-1/2"OTIS XN NIP,NALL TO 3.80"(02/05/11) i 9608' —{4-12'WLEG,ID=3.958" 4-12'TBG, 12.6#,13CR-80 VAM ACE, H 9606' .0152 bpf,ID=3.958" % lip 9685' I—7"X4-1 4-1/2"BKR ZXP PKR w/7.40'TIEBACK &HMC LNR HGR ID=4.39" T LNR,26#,L-80 BTC, .0383 bpf,ID=6.276" H 9882' 3.80"MILLOUT WINDOW(18-04C)9983'-9990' 4-1/2"PKR WFIPSTOCK(02/22/11) H 9980' VS 4-1/2"LNR,12.6#, L-80,.0152 bpf,ID=3.958" —j —9990' ir ` 4-12'OPEN HOLE 10675' 4 •.r•• .!i!i!i DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNT 01129183 ROW 41 INITIAL COMPLETION 02/27/12 DAS/PJC SET DSSSV PLUG WELL: 18-04C 05/18/98 N4/3 ES CTD SIDETRACK(18-04A) PERMIT No:'2110020 07117/01 N7ES SIDETRACK(18-04B) API No: 50-029-20875-03 03/02/11 NORDIC 1 CTD SUSPENDED(18-048) SEC 24,T11 N, R14E,1067°FNL&191°FEL 02/18112 NORDIC 2 OPS SKIT DOWN(18-04C) 0226/12 PJC DRLG HO CORRECTIONS 0227/12 MV/PJC BORE B CTD CORRECTION BP Exploration(Alaska) WaLFEAD= WEVOY 1 8-04C4-1r. CHRANGLE>70 10120'***OME BG'** ACTUATOR= AXELSON KB.ELEV= 45.1' PROPOSED Pry-Ri3P&A BF.REV= 19.21' � KOP= 2100' Max Angle= 5"Q 10187' 2185' -j4-1/2"CAM0)BAL O SSSVN,D=3.813" Datum MD= 11113' Datum ND= 8800'SS 2185' H4-1/2"DSSSV RUG(01/27/12) 20"CONDUCTOR H120' Zi Jt/2 13-3/8"CSG,72#,L-80 BTPS,13=12.347' — 2629' GAS LFT MANDRILS ST MD ND I DEV TYPE VLV LATCH PORT DATE TOP OF COL TUBNG(03/02/11) -I 3100' 4 3168 3055 35 MMGM DMY RK 0 03/29/08 3 5993 5193 40 MMGM DMY RK 0 03/29/08 .„ "17--"":, 1 2 8112 6830 31 NS/GM DMY RK 0 04/06/02 Proposed TOC 3,100'M D 1 9514 8116 38 _KBG-2 DMY BK 0 04/06/02 DPZ #1 Ugnu,C retaceous -7623'M D (6425'TVDss 8541' H9-5/8'X7"BKR ZXP PKRMB3ACK,D=6.313" Corrosion hhbited — 8741' 8555' H9-5/8"X 7"BKR HMC LMR HGR,13=6.313" Brune 9-5/8"MLLOUT WIDOW(18-048)8718'-8734' 9-5/8"CSG,47#,L-80 BTPS,D=8.681" H -8734 8855' -i TOP OF CEMB1T NSDE COL 9541' H4-1/2"OTIS X NP,D=3.813" � j �•i j'�� , 9561' H 7'X 4-1/2"BKR S-3 RCR ID=3.875" 9575' H 4-1/2'OTIS X NP,D=3.813" DPZ#2 PUtRi,er-9482'-9539'MD (8055-8111'TVD ss) i 9595' H4-1/2"OTIS XN ISP,MILL TO 3.80"(02/05/11) P ? ,. 96o8" --14-1/2"WLBG,13=1958" 4-1/2"TBG, 12.6#,13CR-80 VAM ACE, H 9606' 1 0152 bpf,13=3.958" 9685' 17"X 4-1/2"BKR ZXP PKR w/7.40'TEBACK &FMC LMR HGR,D=4.39" DPZ#3 Ivishak -9844'M D (8255'TVD ss) 7"LMR 26#,L-80 BTC .0383 bpf,ID=6.276" —I 9882' 3.80"FALLOUT WWOW(18-04C)9983'-9990' 4-1/2"Rat WFIPSTOCK(02/22/11) -1 9980' I,\ 4-1/2"LMR, 12.6#,L-80,.0152 bpf,D=3.958" —I -9990' ,\ Pe00RAT999 9RONM' Rif LOQ SwS PEW C010141401 ARRawows:tee 10313. 4-1/2"OR311 HOLE — 10675' Kole Werth rto Ra01dm M b 1r111td"e0 dale SUE SPF 1R0NAL OplS¢ MTC ? 330 10711-10110 C 01072/02 Sate 6 10410-10150 C 0905101 2-715 I 100-10466 C 0601401 2-75 4 10105-10146 C 0601401 •••••• P13•01111 DOM B1LONg/!'R701.'Ka9R15 ��•••• DATE REV BY CONSENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/29/83 ROW 41 INITIAL COMPLETION 02/27/12 DAS/PJC SET DSSSV PLUG WELL: 18-04C 05/18188 N4/3 BS CTD SIDETRACK(18-04A) PERMIT No:12110020 07/17/01 N7ES SIDETRACK(18-04B) AR No: 50-029-20875-03 03/02/11 NORDIC 1 CTD SUSPENDED(18-04B) SEC 24,T11 N,R14E 1067'FPL&191'Fa 02/18/12 NORDIC 2 OPS SI-LIT DOWN(18-04C) 02/26/12 PJC DRLG HO CORRECTIONS 02/27/12 PN/PJC BORE B CTD CORRECTION BP Exploration(Alaska) 4111 pro —00 2- Ferguson, Victoria L (DOA) From: Rosenbaum,Jesse E <Jesse.Rosenbaum@bp.com> Sent: Monday, September 23, 2013 8:24 AM To: Ferguson,Victoria L(DOA) Cc: Staudinger, Garret Subject: RE: 18-04(PTD 211-002) Plug for redrill Follow Up Flag: Follow up Flag Status: Flagged Victoria, Yes we plan on pressure testing the cement after the down squeeze. Thanks, Jesse From: Ferguson, Victoria L(DOA) [mailto:victoria.ferguson@alaska.gov] Sent:Thursday, September 19, 2013 4:20 PM To: Rosenbaum,Jesse E Subject: RE: 18-04(PTD 211-002) Plug for redrill Do you plan to pressure test after you pump cement down the annulus and before you set the bridge plug and whipstock? From: Rosenbaum,Jesse E [mailto:Jesse.Rosenbaum@)bp.com] Sent: Thursday, September 19, 2013 9:28 AM To: Ferguson, Victoria L(DOA) Subject: 18-04 Schematic «18-04C.pdf» Jesse Rosenbaum Drilling Engineer I BP Exploration Alaska 0:907-564-5155 I C:406.533.8984 jesse.rosenbaumalbp.com 1 C 7!' D • STATE OF ALASKA 0SKA OIL AND GAS CONSERVATION CL ..JIISSION I'. F REPORT OF SUNDRY WELL OPERATIONS AOGCC 1. Operations Performed: ❑Abandon 0 Repair Well 0 Plug Perforations 0 Perforate 0 Re-Enter Suspended Well ❑Alter Casing 0 Pull Tubing 0 Stimulate-Frac 0 Waiver ®Other ❑Change Approved Program ®Operation Shutdown 0 Stimulate-Other ®Time Extension Extension through 3/1/2014 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. 0 Exploratory 0 Stratigraphic 211-002 3. Address: ®Development 0 Service 6. API Numbe P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-20875-03-00 7. Property Designation(Lease Number): 8. Well Name and Number: ADL 028307 PBU 18-04C 9. Logs(list logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): Prudhoe Bay Field/Prudhoe Bay Oil Pool 11. Present well condition summary: Total depth: measured 10675' feet Plugs:(measured) 2185'&8855'(TOC) feet true vertical 8690' feet Junk:(measured) 3100' feet Effective depth: measured 8855' feet Packer: (measured) 9551' feet true vertical 7494' feet Packer: (true vertical) 8066' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' Surface 2629' 13-3/8" 2629' 2593' 4930 2670 Intermediate 8718' 9-5/8" 8718' 7370' 6870 4760 Production Liner 1341' 7" 8541'-9882' 7208'-8331' 7240 5410 Liner 909' 4-1/2" 9685'-9983' 8173'-8413' 8430 7500 Perforation Depth: Measured Depth: None feet True Vertical Depth: None feet Tubing(size,grade,measured and true vertical depth): 4-1/2", 12.6# 13Cr-80 9608' 8111' Packers and SSSV(type,measured and true vertical depth): 7"x 4-1/2"Baker'S-3'Packer 9551' 8066' 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description 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: 0 0 0 300 0 Subsequent to operation: 0 0 0 300 0 14.Attachments: ❑Copies of Logs and Surveys run 15.Well Class after work: 0 Exploratory 0 Stratigraphic ®Development 0 Service ®Daily Report of Well Operations 16. Well Status after work: ®Oil 0 Gas 0 WDSPL ®Well Schematic Diagram 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 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: Contact: Carl Lundgren;564-4334 Email: Carl.Lundgren@bp.com 313-107,, Printed '. -: Joe : 'k. Title: Drilling Technologist Signatur- L.. ,,11``I. Phone: 564-4091 Date:5/19 I Form 10-404 - ed 10/201 r MAR 1. 11 71 F 1/51 3 ���Submit Original Only f � �3 r/zai3 bAuM OPOWwNkl. TieraeA vk-\-ve. 1 1 mil loviS1,1 $3N Sfr M TREE= • McEVOY WELLHEAD= McEVOY 0 1 8-04C S, (NOTES: WELL ANGLE>70 @ 10120'*** ACTUATOR= AXELSON ( ] 4-1�� CHROME TBG*** KB.ELEV= 45.1' OPS SHUT DO N BF ELEV= 19.21' KOP= 2100' Max Angle= 5°@ 1018T 2185' -{4-1/2"CAMCO BAL-O SSSVNID=3.813" Datum ND= 11113' Datum 1VD= 8800'SS 2185' h—4-12 DSSSV PLUG(0127112,) 20"CONDUCTOR 120' 13-3/8"CSG,72#, L-80 BTRS, ID=12.347" H 2629' GAS LIFT MANDRELS ST MD IVO DEV TYPE VLV LATCH PORT DATE TOP OF COIL TUBING(03/02/11) --I 3100' i------ r 4 3168 3055 35 MMGM DMY RK 0 03/29/08 3 5993 5193 40 MMGM DMY RK 0 03/29/08 — 2 8112 6830 31 MMGM DMY RK 0 04/06/02 1 9514 8116 38 KBG-2 DMY BK 0 04/06/02 Minimum I D = 3,80" @ 9595' 8541' H9-5/8"X 7"BKR ZXP PKR/TIEBACK, ID=6.313" 4-1/2" MILLED OTIS XN NIP 8555' H9-5/8"X 7"BKR HMC LNR HGR,ID=6.313" TOP OF WHIPSTOCK -1 8741' IN 9-5/8"CSG,47#, L-80 BTRS, ID=8.681" --I -8734 — 9-5/8"MILLOU7 WINDOW(18-048)8718'-8734' PERFORATION SUMMARY <+. 8855' HTOP OF CEMENT INSIDE COIL REF LOG: SWS PERF ON 08/14/01 ANGLE AT TOP PERF: 18 10383' ill , , 1-4574i1-1---14-1/2"OTIS X NIP,ID=3.813" Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE '<x.'4 3-3/8" 6 10383-10410 *C 01/22/02 X � Z 9551' -17"X 4-1/2"BKR S-3 PKR,ID=3.875" 3-3/8" 6 10410- 10450 *C 0925/01 ` 2-7/8" 4 10426- 10456 *C 08/14/01 �,� 2-/78" 4 10465-10485 *C 08/14/01r 9575' -14-1/2"OTIS X NIP,ID=3.813".,i I *PERFORATIONS BELOW WHIPSTOCK @ 9980' r 9595' H 4-1/T OTIS XN NIP,MILL TO 3.80"(02/05/11) l I i S 9608' --{4-1/2'WLEG,ID=3.958" 4-1/7'TBG,12.6#,13CR-80 VAM ACE, H 9606' .0152 bpf, ID=3.958" ♦ 9685' 7"X 4-1/2"BKR ZXP PKR w/7.40'TIEBACK &HMC LNR HGR,ID=4.39" x. T'LNR,26#,L-80 BTC, .0383 bpf,ID=6.276" ---I 9882' 1'l 3.80"MILLOUT WINDOW(18-04C)9983'-9990' 4-1/2'PKR WHIPSTOCK(0222/11) -1 9980' 4-1/2"LNR,12.6#, L-80,.0152 bpf, ID=3.958" H -9990' I 4-12"OPEN HOLE 10675' , .... '4%1* • DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01129/83 ROW 41 INITIAL COMPLETION 02/27/12 DAS/PJC SET DSSSV PLUG WELL: 18-04C 05/18/98 N413 ES CTD SIDETRACK(18-04A) PERMIT No:"2110020 07/17101 N7ES SIDETRACK(18-04B) API No: 50-029-20875-03 03102/11 NORDIC 1 CTD SUSPENDED(18-04B) SEC 24,T11 N,R14E,1067'FNL&191'FEL 02118112 NORDIC 2 OPS SHUT DOWN(18-04C) 02/26/12 PJC DRLG HO CORRECTIONS 02/27/12 MV/PJC BORE B CTD CORRECTION BP Exploration(Alaska) w w��\W// s9 THE STATE Alaska Oil and Gas g� ��i�� ofl 1L1 S1( 1 Conservation Commission wet wh 'AV GOVERNOR SEAN PARNELL 333 West Seventh Avenue o = e. Anchorage, Alaska 99501-3572 ALAS- Main: 907.279.1433 Fax: 907.276.7542 Joe Lastufka Drilling Technologist BP Exploration (Alaska), Inc. c2//— CO L P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-04C Sundry Number: 313-107 Dear Mr. Lastufka: 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, P Cathy . Foerster Chair DATED this / day of March, 2013. Encl. 1I • STATE OF ALASKA 4 <12ALAS1.r,OIL AND GAS CONSERVATION COMMISSION RECEIVED APPLICATION FOR SUNDRY APPROVAL MAR 01 2013 20 AAC 25.280 1. Type of Request: AOGCC 0 Abandon 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Change Approved Program 0 Suspend , 0 Plug Perforations 0 Perforate 0 Pull Tubing ime Extension , ®Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casingther Extension through 3/1/2014 vlir 2. Operator Name 4. Current Well Class 31101 5. Permit To Drill Number BP Exploration(Alaska) Inc. ❑ Exploratory 0 Stratigraphic 211-002 • 3. Address: 6. API Numbe ®Development 0 Service P.O. Box 196612,Anchorage,Alaska 99519-6612 50.029-20875-03-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? PBU 18-04C • Will planned perforations require a Spacing Exception? 0 Yes-12,57- 9. es No9. Property Designatior 10. Field/Pool(s): ADL 028307 • Prudhoe Bay Field/Prudhoe Bay 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), 10675' 8690' 8855' 7494' 2185'&8855'(TOC) 3100' Casing Length Size MD TVD Burst Collapse Structural _Conductor 80' 20" 80' 80' Surface 2629' _ 13-3/8" 2629' 2593' 4930 2670 Intermediate 8718' 9-5/8" _ 8718' 7370' 6870 4760 Production Liner 1341' 7" 8541'-9882' 7208'-8331' 7240 5410 Liner 909' 4-1/2" 9685'-9983' 8173'-8413' 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): None None 4-1/2", 12.6# 13Cr-80 9608' Packers and SSSV Type: 7"x 4-1/2" Baker'S-3'Packer Packers and SSSV 9551' MD(ft)and TVD(ft): 12. Attachments: 13.Well Class after proposed work: • ®Description Summary of Proposal 0 BOP Sketch 0 Detailed Operations Program 0 Exploratory 0 Stratigraphic Development 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation • ®Oil ❑WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date ❑Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: 0 WAG 0 SPLUG 0 Suspended 17. I hereby c that the foregoing is true and correct to the best of my knowledge. Contact: Carl Lundgren;564-4334 Printed ame• Joe L toTitle: Drilling Technologist Email: Carl.Lundgren uebp.com Signature. rPhone: 564-4091 Date: 2fie/'`� Commission Use Only Conditions of approval: Notify Commission so that a representative may witness Sundry 31 3 Ji Sund Number: 01 ❑Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: RBDMS MAR 12 2013 Spacing Exception Required? 0 Yes 0 No Subsequent Form Required: I © — ® it APPROVED BY Approved By: COMMISSIONER THE COMMISSION Date:3�-/7,�/ 3 Form 10-403 R ep"� PI'S A 1 I. application is valid for 12 months from the date of approval Submit In Duplicate V 'v «..,,., VL-I,' %s� -'1-`3 317-/13 Sundry number 312-066 was approved on 2/29/2012 for Operation Shutdown for well 18-04C. BPXA requests an extension to the existing Operation Shutdown for well 18-04C for one year.The well is secured with cement in the lost BHA string,and SSSV plug in the tubing. Two potential sidetrack bottom hole locations have been identified which could potentially be accessed by the well.These locations are under review.Our intention is to determine the sidetrack viability and plan within the next year. For additional information, please contact Carl Lundgren,564-4334;Carl.Lundgren@bp.com ,TREE= McEVOY WELLHEAD= McEVOY "' 8-04C SA NOTES: WELL ANGLE>70 @ 10120'*** ACTUATOR AXELSON �ma�+yy 4-1/� CHROME TBG*** KB.ELEV .` 45.1' O DOWN BF.ELEV= 1921' I I KOP= 2100' 2185' -14-1/2"CAMCO BAL-O SSSVN,ID=3.813" Max Angle= 5"@ 10187' Datum MD= 11113' Datum 1VD= 8800'SS 2185' F-4-1/2"DSSSV PLUG(01127112) 20"CONDUCTOR 120' 13-318"CSG,72#, L-80 BTRS, ID=12.347" -I 2629' _Al L. GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE TOP OF COIL TUBING(03/02111) -1 3100' i-- 4 3168 3055 35 MMGM DMY RK 0 03/29/08 3 5993 5193 40 MMGM DMY RK 0 03/29/08 t - 1 2 8112 6830 31 MMGM DMY RK 0 04/06/02 1 9514 8116 38 KBG-2 DMY _ BK 0 04/06/02 Minimum ID = 3,80" @ 9595' 8541' H9-518"X 7"BKR ZXP PKR/TIEBACK,ID=6.313" 4-1/2" MILLED OTIS XN NIP 8555' -19-5/8"X7"BKR HMC LNR HGR,ID=6.313" TOP OF WHIPSTOCK - 8741' 1 9-518"CSG,47#, L-80 BTRS, ID=8,681" -{ -8734 — 9-5/8"MILLOUT WINDOW(18-04B)8718'-8734' PERFORATION SUMMARY �t 1 8855' - TOP OF CEMENT INSIDE COIL REF LOG: SWS PERF ON 08/14/01 ''.0 � 1 ANGLEAT TOP PERF: 18 @ 10383' 'r--' 9541' -14-1/2"OTIS X NIP,1D=3.813" Note:Refer to Production DB for historical pert'data SIZE SPF INTERVAL OpnlSgz DATE ' x 3-3/8" 6 10383- 10410 *C 01/22/02 z z 9551' -17"X 4-1/2"BKR S-3 PKR,ID=3.875" , 3-3/8" 6 10410- 10450 'C 09/25/01 2-7/8" 4 10426- 10456 *C 08/14/014 ii 2-/78" 4 10465-10485 'C 08/14/01 r 9575' H4-1/2''OTIS X NIP,ID=3.813" , *PERFORATIONS BELOW WHIPSTOCK @ 9980' lin 9595' H4-1/2'OTIS XN NIP,MILL TO 3.8G'(02/05/11) i ., j 9608' -14-1/2'WLEG,ID=3.958" 4-1/2'TBG, 12.6#,13CR-80 VAM ACE, H 9606' r .0152 bpf,ID=3.958" 9685' 1-7"X 4-1/2"BKR ZXP PKR w/7.40'TIEBACK &HMC LNR HGR,ID=4.39" 7'LNR,26#, L-80 BTC, .0383 bpf,ID=6.276" -{ 9882' 3.80"MILLOUT WINDOW 18-04C 9983'-9990' 4-1/2"PKR WHIPSTOCK(02/22/11) H 9980' r` 4-1/2"LNR, 12.6#, L-80,.0152 bpf, ID=3.958" -1 -9990' IV 11441%t, 41*Ilklk% 4-1/2"OPEN HOLE 10675' t N0.., DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/29/83 ROW 41 INITIAL COMPLETION 02/27/12 DAS/PJC SET DSSSV PLUG WELL: 18-04C 05/18/98 N4/3 ES CTD SIDETRACK(18-04A) PERMITNo:'2110020 07/17/01 N7ES SIDETRACK(18-04B) API No: 50-029-20875-03 03102/1/ NORDIC 1 CTD SUSPENDED(18-04B) SEC 24,T11 N,R14E,1067'FNL&191'FEL 02/18/12 NORDIC 2 OPS SHUT DOWN(18-04C) 02/26/12 PJC DRLG HO CORRECTIONS 02/27/12 WI PJC BORE B CTD CORRECTION BP Exploration(Alaska) STATE OF ALASKA ' AL, A OIL AND GAS CONSERVATION CON,. ..SION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed: ❑Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended Well ❑Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Other ❑Change Approved Program 0 Operation Shutdown 0 Perforate 0 Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska)Inc. 0 Development 0 Exploratory - 211-002 3. Address: 0 Service 0 Stratigraphic 6. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 - 50-029-20875-03-00 7. Property Designation: 8. Well Name and Number: ADL 028307 ., PBU 18-04C 9.Field/Pool(s): Prudhoe Bay Field/Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured 10675' feet Plugs(measured) 2185'&8855' feet true vertical 8690' feet Junk(measured) 3100' feet Effective depth: measured 8855' feet Packer: (measured) 9551' feet true vertical 7494' feet Packer: (true vertical) 8066' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' Surface 2629' 13-3/8" 2629' 2593' 4930 2670 Intermediate 8718' 9-5/8" 8718' 7370' 6870 4760 Production Liner 1341' 7" 8541'-9882' , 7266'-8331' - l240__' 5410 Liner 909' 4-1/2" 9685'-9983' 8173'-8tcEOtt 1 7500 Perforation Depth: Measured Depth: None 3 20 12 { True Vertical Depth: None i I Al �t�,j�&Gas Cons. Go imissior Tubing(size,grade,measured and true vertical depth): 4-1/2", 12.6# p -lSier- p608 I 8111' Anchorag JJ Packers and SSSV(type,measured and true vertical depth): -- - -�' 7"x 4-1/2"Baker'S-3'Packer 9551' 8066' 11.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment description including volumes used and final pressure: Operation Shutdown due to BHA becoming stuck and left in hole, pump 54 Bbls Class'G'Cement,TOC at 8855'.Jet cut coil tubing, leaving top at 3100'. 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: - Subsequent to operation: 13.Attachments: ❑ Copies of Logs and Surveys run 14.Well Class after work: 0 Exploratory ®Development 0 Service 0 Stratigraphic ® Daily Report of Well Operations ®Well Schematic Diagram 15. Well Status after work: 0 GINJ 0 Oil 0 SUSP 0 WDSPL 0 Gas 0 GSTOR 0 SPLUG 0 WAG 0 WINJ 16. 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: Contact Matthew Ross,564-5782 312-066 Printe. e J.lt., a Title Drilling Technologist Prepared By Name/Number: Signatu1101 '' Phone 564-4091 Date 3/15i�2 Joe Lastufka,564-4091 Form 10-404ised 10/ iz 7. • S MAR 15 2012 /(v"/ ./'"j�^7�Z Submit Original Only 18-04C, Well History (Pre Rig Sidetrack) Date Summary 01/02/12 T/I/0=300/420/0 Temp=SI MIT-IA to 3000 psi PASSED, MIT-OA to 2000 psi ( Pre CTD) MIT-IA: Pressured up IA with 9 bbls crude. IA lost 56 psi in 1st 15 mins and 14 psi in 2nd 15 mins for a total loss of 70 psi in 30 min test. MIT-OA: Pressured up OA with 3 bbls crude.OA lost 50 psi in 1st 15 mins and 20 psi in 2nd 15 mins for a total loss of 70 psi in 30 min test. Bled pressures back. Final WHPs 300/520/0 01/06/12 PULL P-PRONG FROM 9555' SLM. PULL 4-1/2" PX PLUG BODY FROM 9560'SLM(9575' MD). RAN 2.50" CENT., SLB SPARTEK TANDEM SBHPS GUAGES AS PER PROGRAM(good data). WELL LEFT SHUT IN ON DEPARTURE, DSO NOTIFIED. 01/10/12 T/I/0=SSV/400/200,Temp=Sl PPPOT-T(PASS) PRE CTD PPPOT-T: Stung into test port(500 psi), bled to 0 psi. pumped through void good returns. Pressured void to 5000 psi for 30 min.test, lost 100 psi in 15 min., lost 0 psi in second 15 min. (PASS). Bled void to 0 psi. Function LDS. 01/12/12 T/1/O=2450/500/150.Temp=SI.Tubing FL. (FB). No AL.Tubing FL @ 9650' (150 bbls). 01/15/12 T/I/0=430/440/260 Temp=SI Load TBG, Injectivity Test, Freeze Protect(CTD) Pumped 5 bbls neat meth & 175 bbls 2% KCL to load TBG. Pumped an additional 200 bbls 2% KCL&38 bbls crude down TBG to establish Injectivity rates of 1 bpm @ 0 psi,2 bpm Q 10 psi,3 bpm C© 20 psi,4 bpm C© 30 psi&5 bpm C�3 30 psi. Pumped an additional 225 bbls down Tbg to confirm Injectivity. Freeze protected Tbg with 38 bbls crude. FWHP's=SSV/1650/240. 02/02/12 T/I/O=2890/1140NAC. WHP's(Pre-CTD). No AL.Wellhouse removed,flow line removed. 02/03/12 T/I/O=2400/1060/20 Temp=SI Laod& Kill (Pre-CTD) Pumped down TBG with 5 bbls MEOH followed by 163 bbls crude&257 bbls 2%KCL&3 bbls MEOH then capped with 40 bbls diesel to FP TBG. Bled IAP down to 60 psi (DHD to finish bleeding IAP&OAP to 0). FWHP's=Vac/60/20. DSO notified upon departure. Tags hung. 02/04/12 T/I/O=SSV/165NAC.Temp=Sl. Bleed IA&OA to 0 psi (Pre CTD). Flowlines disconnected,wellhouse removed. Integral installed on IA. No access to tree cap. Bled IAP from 165 psi to 0 psi in 4 hrs(mostly gas). Monitored for 30 minutes. During monitor IAP increased to 8 psi.Job complete. FWHPs=SSV/8NAC. T/I/O=SSV/22NAC.Temp=SI.WHPs(Pre CTD). IAP increased 14 psi overnight. Page 1 of 1 North America -ALASKA- BP Page 1 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/6/2012 End Date: X3-00YGV-C: (1,289,721.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 2/6/2012 00:00 - 02:00 2.00 MOB P PRE BEGIN RON EVENT AT 00:00 ON 2/6/12. OPEN WELLWORK TRANSFER PERMIT WITH DRILLSITE OPERATOR. MOVE NORDIC 2 RIG OFF 18-15C AND STAGE ON PAD. MOVE RIG MATS FROM 18-15 TO 18-04. PRE-RIG NOTES: 5"ISA BPV SET BY WELLS SUPPORT ON 2/3/12. INITIAL MIRU T/I/O PRESSURES=2000(BELOW BPV)/0/0 PSI 02:00 - 03:30 1.50 MOB P PRE MOVE RIG FROM STAGING LOCATION ON PAD TO WELL 18-04. SPOT AND CENTER OVER TREE. 03:30 - 06:00 2.50 RIGU P PRE GENERAL RIG UP OPERATIONS. INSTALL COVERS OVER IA AND OA VALVES ON WELLHEAD. 06:00 - 10:30 4.50 RIGU P .- PRE ACCEPT RIG AT 06:00 ON 2/6/2012. LOAD PITS WITH 8.4 PPG 1%KCL. NIPPLE DOWN AND PULL TREE CAP. NIPPLE UP 7-1/16"X 5M TOT BOPE ON TOP OF 7-1/16"MCEVOY AND GRAY TREE,ARRANGED AS FOLLOWS: -HYDRIL GK ANNULAR PREVENTER -BLIND SHEAR RAMS -2-3/8"COMBI RAMS -FLOW CROSS,HCRS ON CHOKE&KILL LINES -2-3/8"X 3-1/2"VB RAMS -2-3/8"COMBI RAMS 10:30 - 16:00 5.50 BOPSUR P' PRE CONDUCT FULL BOPE TEST PER AOGCC AND ADWOP REQUIREMENTS. tj, -AOGCC REP BOB NOBLE GIVEN 24 HOUR NOTICE. -RIGHT TO WITNESS TEST WAIVED BY AOGCC REP BOB NOBLE. -NO FAILURES NOTED. SEE ATTACHED CHART AND REPORT. -FUNCTION TEST COMPONENTS FROM EACH REMOTE STATION. 16:00 - 17:00 1.00 BOPSUR P PRE .CONDUCT RIG EVACUATION DRILL,H2S ALARM SOUNDED. -ALL PERSONEL AT EVAC AREA,3 MINUTES. -CONDUCT AAR.OUTSIDE RIG ALARM DID NOT SOUND. -REINFORCED THAT SITE CONTROL SPECIALIST RESPONSIBLE FOR ALL PERSONEL,AND,SHOULD ALARM SOUND ENSURE ALL ARE AWARE. -NO RESPONSE FROM DRILL SITE OPERATOR. -DISCUSSED WHAT TO DO IF GAS RELEASE WAS REAL. -HOLD PRE-SPUD MEETING WITH CREW. 17:00 19:00 2.00 RIGU P PRE PICKUP INJECTOR AND FILL COIL. RIG UP HARDLINE AND FLOWBACK TANK. FREEZE PROTECT HARDLINE. 19:00 - 19:30 0.50 RIGU P PRE 'CONDUCT RIG EVAC DRILL AND AAR WITH ALL PERSONNEL ON LOCATION. Printed 3/12/2012 2:19:16PM North America -ALASKA- BP Page 2 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/6/2012 End Date: X3-00YGV-C: (1,289,721.00) Project:Prudhoe Bay I Site:PB DS 18 Rig Name/No.:NORDIC 2 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:30 - 00:00 4.50 RIGU P PRE PERFORM SLACK MANAGEMENT. CUT 265' COIL. INSTALL COIL CONNECTOR. PRESSURE TEST SAME TO 300 PSI LOW AND '4200 PSI HIGH FOR FIVE MIN EACH(PASS), AND PULL TEST TO 35 KLBS. TEST E-LINE CONDUCTIVITY(PASS). MAKEUP UPPER QUICK CONNECT. 2/7/2012 00:00 - 00:30 0.50 RIGU P PRE MAKEUP UPPER QUICK CONNECT. 00:30 - 01:00 0.50 RIGU P PRE PRESSURE TEST INNER REEL VALVE, INJECTOR PACKOFF AND LUBRICATOR TO 250 PSI LOW AND 3500 PSI HIGH(PASSING TESTS,SEE ATTACHED CHART). 01:00 - 02:30 1.50 RIGU P PRE MAKEUP LOWER QUICK CONNECT ON COIL. 02:30 - 05:00 2.50 WHSUR P PROD1 MIRU WELLS SUPPORT VALVE SHOP CREW I WITH LUBRICATOR. PRESSURE TEST LUBRICATOR TO 300 PSI LOW AND 3500 PSI HIGH FOR FIVE MIN EACH(PASSING TESTS). EQUALIZE PRESSURE ABOVE AND BELOW BPV. PULL 5"ISA BPV. CLOSE MASTER AND SURFACE SAFETY VALVES, RDMO LUBRICATOR CREW. INITIAL SHUT IN TUBING PRESSURE=2460 PSI. 05:00 - 06:00 1.00 KILLW ' P PROD1 RIG UP TO KILL WELL. 06:00 08:00 2.00 KILLW P PROD1 'EQUALIZE PRESSURE BETWEEN TREE AND WELLBORE. WITH CLOSED CHOKE, BULLHEAD 5 BBLS MEOH DOWN KILL LINE. STAGE UP PUMPS TO 6 BPM AND CONTINUE TO BULLHEAD TO KILL WELL. WELL DEAD AFTER 150 BBLS. PUMP ADDITIONAL 120 BBLS WITH WELL ON VACCUUM. 08:00 - 11:00 3.00 KILLW P PROD1 CONSULT WITH ANCHORAGE AND ATTEMPT TO MEASURE DYNAMIC LOSS RATE. OPEN CHOKE AND ATTEMPT TO GAIN RETURNS AT 7 BPM. UNABLE TO GET RETURNS. DYNAMIC LOSS RATE WHILE PUMPING AT 7 BPM=APPROXIMATELY 456 BBLS/HR.PUMP TOTAL 1600 BBLS 1 %KCL. SHUT MASTER AND SWAB VALVES. 11:00 - 11:50 0.83 KILLW P PROD1 WAIT ON DECISION FROM TOWN FOR PLAN FORWARD. DECISION MADE TO BULLHEAD 120 BBL LCM PILL- FOLLOWED WITH A FORM-A-BLOCK PILL 11:50 - 16:00 4.17 KILLW P PROD1 WAIT ON SLB CEMENTERS AND LCM PILL FROM MI- TO ARRIVE ON LOCATION. 16:00 - 19:45 3.75 KILLW P PROD1 PJSM-R/U SLB CEMENTERS. LCM PILL ON LOCATION AT 18:30 HRS. 19:45 - 20:00 0.25 KILLW P PROD1 PJSM FOR PUMPING FIRST STAGE OF BULLHEADING- WITH SLB CEMENT CREW AND DRILLING CREW. I/A=129 PSI. O/A= 10 PSI. PVT=500 BBLS. Printed 3/12/2012 2:19:16PM North America -ALASKA- BP Page 3 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/6/2012 End Date: X3-00YGV-C: (1,289,721.00) Project:Prudhoe Bay Site: PB DS 18 Rig Name/No.:NORDIC 2 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 20:30 0.50 KILLW I P ' PROD1 OPEN SWAB VALVE.AGAINST CLOSED MASTER VALVE AND CHOKE- SET MP TRIPS TO 3000 PSI. EQUALIZE PRESSURE WITH TREE TO WELLBORE WITH 2000 PSI. OPEN MASTER VALVE,1985 PSI ON WELLBORE. SLB START MIXING 40 BBL FORM-A-BLOCK PILL. BULLHEAD 5 BBLS METHONAL FOLLOWED WITH 150 BBLS 1%KCL. PUMPING 5 BPM 1700 PSI. 123 BBLS AWAY TAPERING OFF TO 1250 PSI- 150 BBLS AWAY-WELL ON STRONG VAC. CLOSE MASTER VALVE. 20:30 - 21:40 1.17 KILLW P PROD1 FILL PITS WITH 165 BBLS 1%KCL FROM VAC TRUCK. CONTINUE TO BATCH FORM-A-BLOCK PILL. PVT=516 BBLS.I/A=146 BBLS.O/A=10 PSI. 21:40 - 21:50 0.17 KILLW P PROD1 PJSM FOR BULLHEADING LCM AND FORM-A-BLOCK PILLS- ' WITH SLB PUMPERS. 21:50 - 23:15 1.42 KILLW P PROD1 AS PER OPS NOTE FROM TOWN- .. PUMP 5 BBLS 1%KCL TO WARM UP LINES. PT LINES TO 250/4500 PSI. TEST PUMP TRIP AT 3000 PSI EQUALIZE PRESSURE WITH TREE TO WELLBORE. OPEN MASTER VALVE. 300 PSI ON WELLBORE. PUMP 120 BBL LCM PILL,BULLHEADING 5 BPM.300 PSI.TO 0 PSI WHP. PUMP 40 BBL FORM-A-BLOCK PILL 4 BPM,60 PSI. FOLLOWED WITH 5 BBLS KCL. 23:15 - 00:00 . 0.75 KILLW P PROD1 SWAP TO RIG PUMPS BULLHEAD 135 BBLS 1%KCL PUMPING 2.8 BPM. 10 BBLS AWAY PRESSURE INCREASE TO 1200 PSI SLOW PUMP TO 2 BPM,1000 PSI.WHP CONTINUES TO INCREASE. 90 BBLS AWAY PRESSURE AT 1650 PSI. SLOW PUMP TO 1 BPM,1560 PSI. 2/8/2012 00:00 - 00:45 0.75 KILLW P PROD1 CONTINUE TO BULLHEAD 135 BBLS 8.4 PPG 1%KCL AND DISPLACE LCM AND FORM-A-BLOCK PILLS INTO LOSS ZONE AT 10,120'PUMPING 1 BPM. FINAL RATE AT 1990 PSI. SHUT DOWN PUMP. 00:00 - KILLW PROD1 00:45 - 01:30 0.75 KILLW P PROD? BLEED WHP TO 0 PSI. OPEN CHOKE, MONITOR WELL FOR 10 MIN. STATIC. CIRCULATE ACROSS TOP AT 1 BPM FOR 10 MIN.-NO LOSSES. PVT=240 BBLS.I/A=161 PSI.O/A=157 BBLS. 01:30 - 02:00 0.50 BOPSUR P PROD1 R/D CEMENTERS. CONTINUE TO MONITOR WELL. 02:00 - 03:50 1.83 BOPSUR P PROD1 PJSM, M/U CHECKS. FILL AND WARMUP COIL. PT CHECKS TO 250/3500 PSI. Printed 3/12/2012 2:19:16PM • North America -ALASKA- BP Page 4 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/6/2012 End Date: X3-00YGV-C: (1,289,721.00) Project:Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time: 12/25/1982 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase ' Description of Operations r1, (hr) (ft) / 1" 03:50 - 05:05 1.25 BOPSUR P PROD1 PJSM FOR BHA, M/U BHA#1 ✓ 3 3/4"FULL GUAGE PDC BIT,2 7/8"ULS MOTOR W/1.1 DEG AKO, HOT,USR, DGS, DPS, EDC, PC,SWP, LQC, UQC,XO, CTC. M/U INJECTOR.TEST QTS TO 250/3500 PSI. PVT=353 BBLS. I/A= 143 PSI.O/A= 18 PSI. 05:05 - 08:30 3.42 DRILL P PROD1 RIH WITH LATERAL BHA-LOG TIE IN-6' @9858'-TAG TOP OF WINDOW @ 9982' 08:30 - 10:00 1.50 DRILL P PROD1 DRY TAG W/5K,10K,12K-TRY VARIOUS ORIENTATIONS R AND L OF AS DRILLED- WILL NOT PASS THROUGH-TRY PUMPING @ .5 AND.75BPM-NO SUCCESS-CALL TOWN AND DECIDE TO POOH FOR WINDOW MILL AND STRING REAMER-WELL STAYING FULL 10:00 - 12:30 2.50 DRILL P PROD1 PJSM AND POOH FOR BHA SWAP-FLOW CHECK WELL-STATIC 12:30 - 13:00 0.50 DRILL P PROD1 POP OFF WELL-STAND BACK INJECTOR AND LAY DOWN 3 3/4"FULL GUAGE BIT - PICK UP 3.79"WINDOW MILL AND 3.77 STRING REAMER 13:00 - 16:00 3.00 DRILL P PROD1 STAB INJECTOR-TEST QTS-RIH W/BHA#2- TIE IN W/-6.5'CORRECTION @-TAG TOP OF WINDOW @ 9982.5'-FS 2400#@ 2.6 BPM- START MILLING W/250#MOTOR WORK AND 2400#WOB 16:00 - 16:45 0.75 DRILL P PROD1 MILL THROUGH WINDOW AND RAT HOI F TO 10001 -MAKE 2 PASSES THROUGH WINDOW WITH PUMPS ON AND 1 WITH PUMPS OFF- CLEAN 16:45 - 17:45 1.00 DRILL P , PROD1 STARTED LOSING FLUID Cgs 10600'WITH TOTAL RETURNS LOST AT 1 Q6.12-.START PUMPING ACROSS THE TOP CONTINUE IN HOLE AND TAG BOTTOM AT 10680'47- 17:45 0680'417:45 - 18:30 0.75 DRILL N DPRB 10,675.00 PROD1 PUMPING DOWN BACKSIDE 2.5 BPM �y PUMPING 2.5 BPM DOWN COIL. s� ATTEMPT TO P/U PULLING 90K. STUCK AT 10,675'. ECD 7.4 PPG APPEARS TO BE PACKED OFF ABOVE BHA. 18:30 - 20:30 2.00 DRILL N DPRB 10,675.00 PROD1 NOTIFY FIELD SUPERINTENDANT AND ODE. FLAG OFF RIG FLOOR.DEVELOPE PLAN FORWARD. PUMP 2.5 BPM DOWN BACKSIDE AND 2.5 BPM DOWN COIL. EVERYTHING PUMPED DOWN COIL-INTO LOSS ZONE AT 10,612' 5 BBLS IN/2.5 BBLS OUT. ATTEMPT TO PULL FREE PULLING 90K.- CALL FOR 150 BBLS MINERAL OIL.MIX 40 BBL HI VIS PILL. CONTINUE TO OFFLOAD 1%KCL INTO PITS, SENDING TRUCKS FOR MORE. FIELD SUPERINTENDANT ON LOCATION AT 20:30 20:30 - 22:00 1.50 DRILL N DPRB 10,675.00 PROD1 DISCUSS PLAN FORWARD WITH FIELD SUPERINTENDANT AND ODE. CONTINUE KEEPING BACKSIDE FULL AND PUMPING DOWN COIL. WAIT ON 150 BBLS MINERAL OIL. PJSM WITH CREW FOR PLAN FORWARD. Printed 3/12/2012 2:19:16PM North America -ALASKA- BP Page 5 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/6/2012 End Date: X3-00YGV-C: (1,289,721.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time:12/25/1982 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 22:00 - 22:30 0.50 DRILL N DPRB 10,675.00 PROD1 P/U TO 84K LINE UP AND PUMP DOWN BACKSIDE. .54 BBLS IN/OUT.54 BBLS. S/O-10K.WAIT 20 MIN. 22:30 - 22:35 0.08 DRILL N DPRB 10,675.00 PROD1 PUMPING DOWN BACKSIDE.54 BPM- PULL 90K, S/O TO 20K, P/U TO 93K,S/O TO -14K, P/U TO 93K. CONTINUE WITH 1/1 RETURNS ON BACKSIDE. 22:35 - 23:50 1.25 DRILL N DPRB 10,675.00 PROD1 PUMP 3 BPM DOWN COIL 2630 PSI, CONTINUE KEEPING BACKSIDE FULL PUMPING.52 BPM. PUMP 30 BBLS MINERAL OIL DOWN COIL. SPOT 10 BBLS IN OPEN HOLE, PULL 90K.5/0 TO 8K.PULL 93K.5/0-14K. SPOT 10 MORE BBLS OF MINERAL OIL IN OPEN HOLE. PULL 90K, S/O-7K, PULL 92K.S/O TO-15K LET MINERAL OIL SOAK FOR 10 MIN. PULL 90K.S/O-15K,PULL 90K,5/0-15K 23:50 - 00:00 0.17 DRILL _ N DPRB 10,675.00 PROD1 PUMP 40 BBL HI VIS PILL 2.95 BPM 1700 PSI DOWN COIL. PUMP.91 BPM DOWN BACKSIDE. PUMP HI VIS SWEEP ATTEMPTING TO SLOW DOWN LOSSES. CONTINUE ATTEMPTING TO PULL FREE PULLING 92K. 2/9/2012 00:00 - 00:40 0.67 DRILL N DPRB 10,675.00 PROD1 CONTINUE TO PUMP.91 BPM DOWN BACKSIDE. WORK PIPE PULLING UP TO 92K 00:40 - 03:25 2.75 DRILL N DPRB 10,675.00 PROD1 S/O TO 10K.OPEN EDC.PUMP DOWN COIL 4.7 BPM 4550 PSI. WITH NO RETURNS ATTEMPTING TO FREE PIPE. '03:25 - 03:50 0.42 DRILL N DPRB 10,675.00 PROD1 WORK PIPE-SHUT DOWN PUMP. PULL 86K.S/O TO-14K CLOSE EDC.PUMP DOWN COIL 2 BPM, 03:50 - 04:30 ' 0.67 DRILL N DPRB 10,675.00 PROD1 CLOSE CHOKE. PUMP DOWN KILL LINE- BULLHEAD 65 BBLS MINERAL OIL. PRESSURE UP TO 2300 PSI, PRESSURE DROPPING TO 800 PSI. PUMP 1.48 BPM.PRESSURE BUILDING TO 1700 PSI. 04:30 - 04:50 0.33 DRILL N DPRB 10,675.00 PROD1 PULL 90K,S/O TO-15K. 1700 PSI ON BACKSIDE PULL 90K. OPEN CHOKE AND BLEED PRESSURE- OFF BACKSIDE.S/O TO-15K. PRESSURE UP ON BACKSIDE PULL 90K. S/O TO NEUTRAL WT. 04:50 - 10:00 5.17 DRILL N DPRB 10,675.00 PROD1 LINE UP AND PUMP DOWN COIL.6 BPM PUMP DOWN BACKSIDE.5 BPM KEEPING HOLE FULL. 1/1 RETURNS ON BACKSIDE. WAIT ON ORDERS FROM TOWN FOR PLAN FORWARD. 10:00 - 10:30 0.50 DRILL N DPRB 10,675.00 PROD1 R/U TO PULL 8.6#DRILLING MUD DIRECTLY OFF TRUCK WHILE GOING ACROSS TOP WITH 1%KCL USING OTHER PUMP Printed 3/12/2012 2:19:16PM • North America -ALASKA- BP Page 6 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/6/2012 I End Date: X3-00YGV-C: (1,289,721.00) Project:Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI: 500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 10:30 11:00 0.50 DRILL N DPRB 10,675.00 PROD1 PUMP 50 BBLS OF 8.6#MUD DOWN COIL AT 3.13 BPM/1140#ICP FOLLOWED BY 8 BBLS OF 1%KCL TO SPOT MUD AT THE BIT. FCP= 1810# 11:00 - 11:10 0.17 DRILL N DPRB 10,675.00 PROD1 SLACK OFF ON COIL TO NEUTRAL WEIGHT AND ORIENT HOT TO HIGHSIDE OF WELL. SEND COMMAND TO DISCONNECT FROM BHI TOOLS PRIOR TO PULLING ON COIL- DISCONNECT ACKNOWLEDGED 11:10 - 11:30 0.33 DRILL N DPRB 10,675.00 PROD1 PICK UP ON COIL TO SEE IF FREE.STILL STUCK.WORK PIPE PULLING TO 90K AND HOLD IN ATTEMPT TO PULL FREE. NO SUCCESS. REPEAT SEQUENCE 4 MORE TIMES WITH SAME RESULT. NO MOVEMENT NOTED.SLACK OFF AND CALLL TOWN FOR INSTRUCTIONS. 11:30 - 11:45 ' 0.25 DRILL N DPRB 10,675.00 PROD1 STILL HADA SOLID ELECTRONIC CONNECTION WITH BHI TOOLS SO ATTEMPTED TO RE-ENGAGE EDC.ATTEMPT WAS SUCCESSFUL. 11:45 - 18:00 6.25 DRILL N DPRB 10,675.00 PROD1 WAIT ON ORDERS FROM TOWN WHILE CONTINUING TO PUMP 1%KCL @.5BPM _ DOWN COIL AND.62 BPM ACROSS TOP. 18:00 - 18:30 0.50 DRILL N DPRB 10,675.00 PROD1 CREW CHANGE,DISCUSS RIG OPS.CHECK EQUIPMENT. 18:30 - 19:30 1.00 DRILL N DPRB 10,675.00 PROD1 CONTINUE TO PUMP 1%KCL.62 BPM DOWN COIL. PUMP.44 BPM ON BACKSIDE. .44 BPM RETURNS. CALL OUT LRS TO HEAT KCL. ORDER 2 HEATERS AND 270'OF HEATER HOSE. 19:30 - 20:30 1.00 DRILL N DPRB 10,675.00 PROD1 PJSM,FILL PIT 4 WITH 45 BBLS 1%KCL. MIX 50 BBL 20 PPB FORM-A-BLOCK PILL. 20:30 - 21:00 0.50 DRILL N DPRB 10,675.00 PROD1 FIELD SUPERINTENDANT ON LOCATION. PJSM FOR PUMPING HEATED KCL AND 20 PPB FORM-A-BLOCK PILL. WITH FIELD SUPERINTENDANT,LRS,WSL, TP,TRUCK PUSHER,MI AND RIG CREWS. 21:00 - 23:35 2.58 LCR N DPRB 10,675.00 PROD1 CONTINUE MIXING FORM-A-BLOCK PILL. R/U LRS TO RIG CEMENT LINE. PT LINES TO 250/3500 PSI. R/U HEATER TRUNK ON COIL ABOVE PIPESHED. 23.35 - 00:00 0.42 LCR N DPRB 10,675.00 PROD1 START TO BULLHEAD 1%180 DEG KCL DOWN COIL. PUMP 1.78 BPM 100 PSI. CONTINUE PUMPING DOWN BACKSIDE.5 BPM. 14 BBLS AWAY LRS TRUCK HAS BURNER PROBLEM. OPERATER NOTIFIED HIS LEAD AND MECHANIC. 2/10/2012 00:00 - 00:45 0.75 LCR N DPRB 10,675.00 PROD1 LRS REPAIRING BURNER ON HOT OIL TRUCK. Printed 3/12/2012 2:19:16PM North America-ALASKA- BP Page 7 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/6/2012 End Date: X3-00YGV-C: (1,289,721.00) Project:Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 00:45 - 02:45 2.00 LCR N DPRB 10,675.00 PROD1 BULLHEAD 138 BBLS 1%140 DEG KCL DOWN COIL. PUMP 1.78 BPM 100 PSI. 1 BURNER FAILED ON TRUCK- CONTINUE PUMPING DOWN BACKSIDE.5 BPM. I/A 203 PSI.0/A 494 PSI. BLEED 0/A TO 117 PSI. R/D LRS. 02:45 - 05:30 2.75 LCR N DPRB 10,675.00 PROD1 FOLLOW OPS NOTE FROM TOWN. BYPASS HI PRESSURE SCREEN IN REELHOUSE. PUMP 5 BBLS 20 PPB FORM-A-BLOCK PILL DOWN COIL. CHASE TO BOTTOM WITH 1%KCL. PUMP 2.9 BPM 850 PSI. AT 55 BBLS SLOW PUMP TO 1 BPM 22 PSI. NO PRESSURE INCREASE. PUMP 15 BBL 20 PPB FORM-A-BLOCK PILL. 3 BPM 580 PSI. 55 BBLS SLOW PUMP TO 1 BPM 22 PSI. NO PRESSURE INCREASE. PUMP 3RD 25 BBL 20 PPB FORM-A-BLOCK PILL. PUMP 3 BPM 725 PSI. AT 55 BBLS SLOW PUMP TO 1 BPM 22 PSI. • NO PRESURE INCREASE. 05:30 - 09:00 3.50 LCR N DPRB 10,675.00 PROD1 PUMP AT MINIMUM RATE DOWN COIL AND ACROSS TOP WHILE WAIT ON ORDERS FROM TOWN.MIX 40 BBL PILL OF 3OPPB FORM-A-BLOK 09:00 - 09:40 0.67 LCR N DPRB 10,675.00 I PROD1 PJSM. R/U AND PUMP 20 BBL OF 30 PPB DOWN COIL AT 3BPM X 700PSI FOLLOWED BY 38 BBL OF 1%KCL AT 3 BPM X 700 PSI TO SPOT FORM-A-BLOK AT END OF COIL. PUMP ADDITIONAL 2 BBL OF KCL AT 5 BPM AND SHUT DOWN PUMPS.WELL CONTINUING TO PULL FLUID AT 1.13 BPM UNTIL VALVE WAS SHUT.SHUT DOWN 09:40 - 10:00 0.33 LCR N DPRB 10,675.00 PROD1 WAIT 20 MINUTES TO GIVE FORM-A-BLOK TIME TO SEAL 10:00 - 10:10 0.17 LCR N DPRB 10,675.00 PROD1 PUMP 5 BBL OF 1%KCL AT.5 BPM X 0 PSI TO SPOT ADDITIONAL FORM-A-BLOK IN WELL BORE 10:10 - 10:40 ' 0.50 LCR N DPRB 10,675.00 PROD1 WAIT 30 MINUTES TO GIVE FORM-A-BLOK J TIME TO SEAL 10:40 - 10:50 0.17 LCR N DPRB 10,675.00 PROD1 PUMP 5 BBL OF 1%KCL AT.5 BPM X 0 PSI TO SPOT ADDITIONAL FORM-A-BLOC. 10:50 - 11:20 0.50 LCR N DPRB 10,675.00 PROD1 WAIT 30 MINUTES 11:20 - 11:35 0.25 LCR N DPRB 10,675.00 PROD1 PUMP 5 BBL OF 1%KCL AT.5 BPM X 0 PSI 11:35 - 12:00 0.42 LCR N DPRB 10,675.00 PROD1 PUMP ACROSS TOP OF WELL TO VERIFY HOLE FILL.HAD IMMEDIATE RETURNS WHEN PUMP ENGAGED 12:00 - 12:20 0.33 LCR N DPRB 10,675.00 PROD1 DISPLACE REMAINING 2 BBLS OF 30 PPB FORM-A-BLOK INTO WELLBORE AT.5 BPM X 0 PSI.COIL NOT ON VACUUM WHEN PUMPS SHUT DOWN 12:20 - 12:50 0.50 LCR N DPRB 10,675.00 PROD1 MADE 3 ATTEMPTS TO PULL FREE AT 93K. NO LUCK. HOLD 70K ON PIPE.COIL LIFE AT 15% Printed 3/12/2012 2:19:16PM • North America -ALASKA- BP Page 8 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 2/6/2012 End Date: X3-00YGV-C: (1,289,721.00) Project: Prudhoe Bay I Site: PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:50 - 13:15 0.42 LCR N DPRB 10,675.00 PROD1 PUMP DOWN COIL W/1%KCL AT 3 BPM TO CHECK INJECTIVITY.CAUGHT FLUID AT 6 BBLS.INJECT 7 BBLS AT 570 PSI CONSTANT 13:15 - 13:45 0.50 LCR N DPRB 10,675.00 PROD1 WAIT 30 MINUTES TO ESTABLISH HOURLY LOSS RATE 13:45 - 13:55 0.17 LCR N DPRB 10,675.00 PROD1 PUMP DOWN COIL W/1%KCL AT 3 BPM TO VERIFY LOSS RATE.CAUGHT FLUID AT 6.8 BBLS X 690 PSI 13:55 - 15:50 1.92 LCR N DPRB 10,675.00 PROD1 WAIT ON LCM AND PUMP TRUCK 15:50 - 17:30 1.67 LCR N DPRB 10,675.00 PROD1 SPOT TRUCKS TO PUMP LCM 17:30 - 18:00 0.50 LCR N DPRB 10,675.00 PROD1 ---DO NOT PUMP LCM---CALL FROM TOWN. WAIT ON ORDERS TO POSSIBLY PUMP CEMENT 18:00 - 18:30 0.50 LCR N DPRB 10,675.00 PROD1 FIELD SUPERINTENDANT ON LOCATION. CREW CHANGE.DISCUSS CURRENT OPS. CHECK RIG EQUIPMENT AND VAC TRUCK STATUS. 18:30 - 21:15 2.75 LCR N DPRB 10,675.00 PROD1 WAIT ON ORDERS FROM TOWN. CIRCULATE DOWN COIL AND BACKSIDE AT MIN RATE. MONITOR RETURNS AT.5 BPM. 21:15 - 21:30 0.25 LCR N DPRB 10,675.00 ' PROD1 PJSM, REVIEW PLAN FORWARD AND PROCEEDURE FROM TOWN FOR PUMPING CEMENT PLUG WITH CREWS. 21:30 - 00:00 2.50 LCR N DPRB 10,675.00 PROD1 WAIT ON CEMENTERS TO ARRIVE ON LOCATION. 2/11/2012 00:00 - 02:35 2.58 LCR N DPRB 10,675.00 PROD1 WAIT ON CEMENTERS TO ARRIVE ON LOCATION. LOAD OUT CEMENT.ORDER 20 BBL CONTAMINATE PILL. CEMENTERS ON LOCATION AT 02:30 02:35 - 03:40 1.08 LCR N DPRB 10,675.00 PROD1 R/U CEMENTERS.SPOT TRUCKS. 03:40 - 04:00 0.33 LCR N DPRB 10,675.00 PROD1 PJSM WITH SLB PUMPERS, FIELD SUPERINTENDANT, RIG CREWS,WSL,SCS,TP AND TRUCK DRIVERS REVIEW CEMENT PLUG PROCEDURE AS PER OPS NOTE FROM TOWN. Printed 3/12/2012 2:19:16PM North America -ALASKA- BP Page 9 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/6/2012 End Date: X3-00YGV-C: (1,289,721.00) Project: Prudhoe Bay Site:PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 05:50 1.83 LCR N DPRB 10,675.00 PROD1 PUMP 3 BBLS WATER AND FLOOD LINES. PT LINES TO 250/6000 PSI.AT 1500 PSI CHECK PUMP TRIP. BATCH CEMENT.TAKE CEMENT SAMPLE, PUMP 2 BBLS 17 PPG NEET CEMENT FOLLOWED WITH 1 BBL 17 PPG CEMENT WITH 10 PPB AGGREGATE FOLLOWED WITH 2 BBLS 17 PPG NEET CEMENT FOLLOWED WITH 3 BBLS WATER. PUMPING 2BM 800 PSI. DISPLACE CEMENT 1%KCL. (•t Q CEMENT OVER THE GOOSENECK AT 18i. BBLS. PUMPING 2.2 BPM 150 PSI WITH CEMENT FALLING DOWN COIL. SLOW PUMP DOWN TO 1 BPM 30 PSI AT 55 BBLS. PUMP TOTAL 60 BBLS WITH 2 BBLS CEMENT OUT OF BHA. SHUT DOWN PUMP. WAIT 20 MINUTES. SLOWLY BRING UP PUMP TO 1 BPM 30 PSI. PUMP TOTAL 63.4 BBLS SHUT DOWN PUMP. PREPARE TO REPEAT PROCEEDURE. 05:50 - 07:20 1.50 LCR N DPRB PROD1 CEMENT IN PLACE-SHUT IN COIL-0 PSI 07:20 - 08:30 1.17 LCR N DPRB PROD1 PJSM W/DAY CREWS-TAKE ON MIX WATER FOR NEXT BATCH-PLAN TO PUMP 12 BBLS OF 17 PPG CEMENT-QUIT PUMPING ACROSS TOP AND OPEN CEMENT LINE TO GO DOWNHOLE 08:30 - 09:00 0.50 LCR N DPRB PROD1 PUMP 3 BBLS OF FRESH WATER -PUMP 2 BBLS OF 17 PPG CLASS G NEAT CEMENT FOLLOWED BY 10 BBLS OF 17 PPG OF CLASS G WITH 1OPPB AGGREGATE FOLLOWED BY 2 BBLS OF 17 PPG CLASS G NEAT-PUMPING CEMENT AT 2.5 BPM X 200-800 PSI- DISPLACE WITH 1 %KCL AT 3 BPM X 1070- 1240 PSI-SHUT DOWN AFTER 50 BBLS OF KCL-0 PSI-SHUT DOWN FOR 20 MINUTES 09:00 - 09:25 0.42 LCR N DPRB PROD1 WAIT ON CEMENT 09:25 - 09:30 0.08 LCR N DPRB PROD1 SQUEEZE 4 BBLS OF CEMENT INTO WELL LEAVING 1 BBL IN COIL AT 45PSI X.4 BPM 09:30 - 09:45 0.25 LCR N DPRB PROD1 WAIT ON CEMENT 09:45 - 10:00 0.25 LCR N DPRB PROD1 CALL TOWN AND DECIDE TO PUMP REMAINING CEMENT OUT OF COIL TO KEEP OPTIONS OPEN-PUMP 10 BBLS AT 1 BPM X 33 PSI FOLLOWED BY 5 BBLS AT 2 BPM X 120 PSI-SHUT DOWN -O PSI 10:00 - 12:05 2.08 LCR N DPRB PROD1 WAIT ON CEMENT 12:05 - 12:30 0.42 LCR N DPRB PROD1 CONDUCT INJECTIVITY TEST ON CEMENT JOB-PUMP 10 BBLS AT 1 BPM X 33 PSI INCREASE TO 2 BPM FOR 5 BBLS AT 120 PSI- SHUT DOWN-0 PSI-CLOSE COIL AND PUMP ACROSS TOP-WAIT ON ORDERS 12:30 - 18:00 5.50 LCR N DPRB PROD1 WAIT ON ORDERS 18:00 - 18:45 0.75 LCR N DPRB PROD1 SHUT DOWN FOR CREW CHANGE Printed 3/12/2012 2:19:16PM North America-ALASKA- BP Page 10 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/6/2012 End Date: X3-00YGV-C: (1,289,721.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:NORDIC 2 Spud Date/Time:12/25/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43©56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:45 - 19:15 0.50 LCR N DPRB PROD1 PJSM: PUMPING CEMENT `-SLB, PUMPERS,NORDIC,WSL, BP SUPT AND CH2MHILL PRESENT 19:15 - 19:35 0.33 LCR N DPRB PROD1 PREP FOR CEMENT JOB -SEND FRESH WATER TO CEMENTERS,MIX __. CHEMICALS 19:35 - 19:55 0.33 LCR N DPRB PROD1 CEMENTER'S VALVE FROZEN -VALVE THAWED WITH TIOGA HEATER 19:55 - 20:35 0.67 LCR N DPRB PROD1 CONTINUE PREP FOR CEMENT JOB —PRESSURE TEST LINES TO 250 PSI LOW& 6000 PSI HIGH -BATCH 10 BBLS 17 PPG CLASS G CEMENT 20:35 - 21:00 0.42 LCR N DPRB PROD1 PUMP THE FOLLOWING: 3 BBLS FRESH WATER @ 1BPM ,2 BBLS 17 PPG NEET CMT @ 1BPM 6 BBLS 17 PPG CMT WITH CEM NET FIBERS (2 PPB)@ 1BPM 2 BBLS 17 PPG NEET CMT @ 1 BPM 3 BBLS FRESH WATER @ 1BPM 50 BBLS KCL©3 BPM SLOW PUMP RATE DOWN TO 1 BPM AS CEMENT ENTERS BHA AND SHUT DOWN HOLE FILL TO MONITOR RETURNS 21:00 - 21:20 0.33 LCR N DPRB PROD1 DOWN ON PUMP,NO PRESSURE BUILDING WITH CEMENT IN BHA -WAIT 20 MIN FOR CEMENT WITH CEM NET TO BRIGDE OFF 21:20 - 21:25 0.08 LCR N DPRB PROD1 PUMP 4 BBLS KCL @ 1BPM TO DISPLACE A TOTAL OF 9 BBLS OF CEMENT FROM COIL -NO PRESSURE BUILD,FINAL INJECTIVITY 1 BPM@10 PSI 21:25 - 21:30 0.08 LCR N DPRB PROD1 SHUT DOWN PUMP DOWN COIL -ISOLATE CEMENTERS AND BLOW DOWN LINE -FILL ACROSS TOP OF THE HOLE 21:30 - 00:00 2.50 LCR N DPRB PROD1 WAIT ON CEMENT 2/12/2012 00:00 - 03:00 3.00 LCR N DPRB PROD1 WAIT ON CEMENT 03:00 - 03:40 0.67 LCR N DPRB PROD1 INJECTIVITY TEST DOWN COIL AT 1.7 BPM, CAUGHT FLUID 8 BBLS PUMPED WITH 380 PSI CIRCULATING PRESSURE BATCH 10 BBLS OF 17 PPG CLASS G CEMENT 03:40 - 04:00 0.33 LCR N DPRB PROD1 PJSM:CEMENT JOB WITH NORDIC,SLB, CEMENTERS,CH2MHILL,BHI,BP WSL, BP SUPT Printed 3/12/2012 2:19:16PM • North America-ALASKA- BP Page 11 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/6/2012 End Date: X3-00YGV-C: (1,289,721.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:NORDIC 2 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 04:45 0.75 LCR N DPRB PROD1 PUMP THE FOLLOWING DOWN COILED TUBING: '3 BBLS FRESH WATER @ 1BPM 2 BBLS 17 PPG NEET CMT @ 1BPM 6 BBLS 17 PPG CMT WITH CEM NET FIBERS (-3 PPB)@ 1BPM 2 BBLS 17 PPG NEET CMT @ 1BPM 5 BBLS FRESH WATER @ 1 BPM 20 BBLS MINERAL OIL 29 BBLS KCL @ 3 BPM ,SLOW PUMP TO 1 BPM AS CEMENT ENTERED BHA,CIRC PRESSURE INCREASED FROM 30 PSI TO 250 PSI PUMPING CEMENT [THROUGH BHA. ATTEMPT TO CLOSE EDC WITH 1 BBL LEFT TO PUMP, UNABLE TO CLOSE EDC. 04:45 - 06:00 1.25 LCR N DPRB PROD1 WAIT ON CEMENT 06:00 - 11:20 5.33 LCR N DPRB PROD1 'CONTINUE WOC TO REACH 1500 PSI COMPRESSIVE 08:30-CEMENT AT 500 PSI. INFORM AOGCC OF TOMORROW'S SCHEDULED FUNCTION TEST.WILL NOT BE ABLE TO FUNCTION THE BLIND/SHEAR RAMS. 10:15-CEMENT AT 1000 PSI. 11:20 - 12:15 0.92 LCR N DPRB PROD1 CEMENT IS AT 1500 PSI COMPRESSIVE. LINE.UP TO PT THE CEMENT PLUG INSIDE THE COIL. BUMP PRESSURE UP TO 500 PSI, BLEEDS OFF SLOWLY. REPEAT MULTIPLE TIMES,BLEEDING OFF EACH TIME. PRESSURE UP TO 700 PSI, BLEEDS OFF SLOWLY EACH TIME. PUMP 7 BBLS THIS WAY. NO CHANGE IN BHP READINGS FROM THE BHI TOOL 'THROUGHOUT THIS PUMPING. 12:15 - 12:40 0.42 LCR N DPRB PROD1 BUMP IT UP TO 1000 PSI WITH 0.4 BBLS, BLEEDS OFF TO 200 PSI IN 3-4 MINI. REPEAT 3 TIMES. 12:40 - 13:20 0.67 LCR N DPRB PROD1 GO TO 1500 PSI,NO SUSTAINED INJECTIVITY. INJECTIVITY ACHIEVED AT 0.32 BPM/1800 PSI. CONTINUE PUMPING,0.5 BPM/1550 PSI. INCREASE RATE SLOWLY TO ACHIEVE SUFFICIENT INJECTIVITY FOR NEXT BATCH 'OF CEMENT. GET TO 0.66 BPM/1960 PSI. 13:20 - 14:00 0.67 LCR N DPRB PROD1 EASE RATE UP TO 0.8 BPM/2180 PSI. 14:00 - 15:50 1.83 LCR N DPRB PROD1 INJECTION RATE 1.02 BPM/2760 PSI. HOLD PJSM WITH SLB CEMENT CREW AND NORDIC RIG CREW. MIX 5TH BATCH OF CEMENT,5 BBLS 17 PPG CLASS G WITH 3 LB/BBL CEMNET ADDED. Printed 3/12/2012 2:19:16PM North America -ALASKA- BP Page 12 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/6/2012 End Date: X3-00YGV-C: (1,289,721.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 15:50 - 17:10 1.33 LCR N DPRB PROD1 'CEMENT IS READY. PUMP 3 BBLS WATER AHEAD THEN PT LINE. PUMP CEMENT,THEN FRESH WATER THEN KCL DISPLACEMENT. DISPLACE AT 1.15 BPM/3500 PSI. SLOW PUMP AT 53.3 BBLS AWAY,PRESSURE FALLS OFF. PUMP CEMENT TO BIT AT 0.5 BPM, GET TO 900 PSI. SHUT DOWN SLB PUMP WITH 1 BBL CEMENT OUT THE BIT,WAIT AND USE RIG PUMP FOR HESITATION SQUEEZE. 17:10 - 17:50 0.67 LCR N DPRB PROD1 PUMP 2 BBL OUT BIT AND SHUT DOWN FOR 25 MIN. CEMENT IS FALLING OUT,ABOUT 0.5 BBLS. PUMP 1.5 BBLS OUT AND LEAVE 1 BBLS IN CT. 17:50 - 23:00 5.17 LCR N DPRB PROD1 WAIT ON CEMENT. -1710 PSI COMPRESSIVE STRENGTH @ 2300 23:00 - 23:30 0.50 LCR N DPRB PROD1 PJSM:PRESSURE TEST CEMENT WITH SLB, NORDIC,CEMENTERS,WSL, BP SUPT PRESENT -CEMENTERS DISCONNECT FROM CEMENT LINE TO ISOLATE SURFACE EQUIPMENT LEAK POTENTIAL -SHUT DOWN HOLE FILL TO MONITOR RETURNS -START PUMPING KCL DOWN COIL,CATCH FLUID AT 1 BBL AWAY -PUMP 1/4 BPM AT 225 PSI -PRESSURE UP TO 1000 PSI,SHUT DOWN PUMP AND PRESSURE DROPPED TO 0 PSI IN 30 SEC. -PRESSURE UP TO 1200 PSI ,SHUT IN PUMP AT 1200 PSI WHICH HELD TO VERIFY NO SURFACE LEAKS,PRESSURE IN COIL BLED TO 0 PSI IN 35 SEC 23:30 - 00:00 0.50 LCR N DPRB PROD1 ESTABLISH INJECTIVITY AT 1 BPM/2900 PSI CALL ODE AND WTL WITH RESULTS OF PRESSURE TEST,AGREE ON PLAN FORWARD TO PUMP ANOTHER 10 BBL CEMENT JOB FOLLOWED BY MINERAL OIL TO MAINTAIN A 100 PSI OVER-BALANCE, PERFORM SEVERAL HESITATION SQZS PUMPING 5 BBLS OF CEMENT THROUGH BHA AND LEAVING 5 BBLS CEMENT IN COIL WHEN JOB COMPLETE. 2/13/2012 00:00 - 00:30 0.50 LCR N DPRB PROD1 BATCH UP 10 BBLS OF 17 PPG CEMENT CONTINUE INJECTIVITY TEST AT 1BPM -PRESSURE DROPPED FROM 2850 TO 2180 PSI OVER ONE HOUR INTERVAL 00:30 - 00:45 0.25 LCR N DPRB PROD1 PJSM: 10 BBL 17 PPG CEMENT JOB DOWN COIL -SLM, NORDIC, CEMENTERS, CH2MHILL,WSL, TP,BP SUPT PRESENT TURN HOLE FILL ON DOWN BACKSIDE Printed 3/12/2012 2:19:16PM • North America -ALASKA- BP Page 13 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/6/2012 End Date: X3-00YGV-C: (1,289,721.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:NORDIC 2 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9: 04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase 1 Description of Operations (hr) (ft) 00:45 - 01:55 1.17 LCR N DPRB PROD1 'PRESSURE TEST CEMENT LINE TO 1500 PSI LOW/6000 PSI HIGH PUMP THE FOLLOWING: 3 BBLS FRESH WATER @ 1.1 BPM 1 BBLS 17 PPG NEET CMT @ 1 BPM/2300 PSI 8 BBLS 17 PPG CMT WITH CEM NET FIBERS (3 PPB)@ 1 BPM/2500 PSI 1 BBLS 17 PPG NEET CMT @ 1BPM/2670 PSI 5 BBLS FRESH WATER @ 1.1 BPM/2600 PSI 20 BBLS MINERAL OIL @ 1.3BPM/2500 PSI 24 BBLS KCL @ 1.3BPM/2800 PSI 10 BBLS STATIC LOSSES -CAUGHT FLUID AT 5 BBLS TOTAL PUMPED AFTER BEING DOWN 30 MIN SHUT DOWN HOLE FILL BEFORE CEMENT APPROACHES BHA AT 53 BBLS AWAY 01:55 - 02:15 0.33 LCR N DPRB ; PROD1 120 MIN HESITATION SQZ WITH 9 BBLS ICEMENT IN COIL -PUMP 2 MORE BBLS 02:15 - 02:35 0.33 LCR N DPRB 'i PROD1 20 MIN HESITATION SQZ WITH 7 BBLS CEMENT IN COIL 02:35 - 02:45 0.17 LCR N DPRB PROD1 ATTEMPT TO PUMP 2 MORE BBLS, PRESSURE UP TO 4000 PSI, HOLD 3900 PSI FOR 5 MIN,SLOWLY BLEED OFF PRESSURE -TOC IN COIL 8855' 02:45 - 03:15 0.50 LCR N DPRB PROD1 FLUSH AND BLOW DOWN CEMENT LINES 03:15 - 08:30 5.25 LCR N DPRB PROD1 WAIT ON CEMENT 08:30 - 09:30 1.00 LCR N DPRB' PROD1 CEMENT IS AT 1500 PSI COMPRESSIVE. PERFORM TEST OF CEMENT PUG TO 250/ 1000 PSI,GOOD. SEND RESULTS TO WTL FOR APPROVAL TO PROCEED WITH OPERATIONS. 09:30 - 13:00 3.50 LCR N DPRB PROD1 CONFERENCE CALL WITH ODE,WTL,CTD SUPT,WELL OPS MANAGER CONCERNING PLAN FORWARD FOR CUTTING AND RETRIEVING CT. 13:00 - 18:00 5.00 LCR N DPRB PROD1 WAIT ON REVISED PLAN FORWARD. SCAFFOLDERS ARRIVE,SET UP SCAFFOLDING ON RIG FLOOR FOR CHEM CUT. REVIEW OPS NOTE WITH RIG TEAM AND SEND COMMENTS BACK TO ODE. 18:00 - 19:00 1.00 LCR N DPRB PROD1 RECEIVE FINAL OPS NOTE FROM TOWN -REVIEW OPS NOTE -MOBELIZE PERSONAL NEEDED FOR PLAN FORWARD 19:00 - 19:30 0.50 LCR N DPRB PROD1 PJSM:NO FLOW TEST AND ROLLING TEST OF SLIPS ENGAGED -SLB, NORDIC,SLB FSM, BP WSLS,BP SUPT, TP,SCS PRESENT 19:30 - 20:15 0.75 LCR N DPRB PROD1 SHUT DOWN HOLE FILL -PERFORM NO FLOW CHECK FOR 15 MIN THROUGH THE CHOKE AMD CONFIRM WELL IS DEAD ,-TURN HOLE FILL BACK ON DOWN BACKSIDE AT 0.4 BPM Printed 3/12/2012 2:19:16PM North America -ALASKA- BP Page 14 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/6/2012 End Date: X3-00YGV-C: (1,289,721.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.: NORDIC 2 Spud DaterTime: 12/25/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 20:15 - 20:30 0.25 LCR N DPRB PROD1 PULL TO 35K LBS ON COIL -CLOSE ANNULAR TO CENTER COIL -CLOSE UPPER 2-3/8"COMBI RAMS PUSH/PULL TEST ON COIL TO ENSURE INJECTOR IS ENGAGED -DUMP PACKOFF AND OPEN ANNULAR -PERFORM ROLLING TEST DOWN ANNULUS TO 250 PSI TO CONFIRM PIPE SLIPS ARE CLOSED -CLOSE MANUAL LOCKDOWNS ON PIPE SLIPS 20:30 - 20:45 0.25 LCR N DPRB PROD1 PJSM:STRIP UP INJECTOR AND HOT TAP COIL -SLB, NORDIC,SLB FSM, BP WSLS,BP SUPT, TP PRESENT 20:45 - 21:00 0.25 LCR N DPRB PROD1 STRIP UP INJECTOR WHILE ROLLING CHAINS IN DOWNHOLE DIRECTION 21:00 - 22:20 1.33 LCR N DPRB PROD1 INSTALL HOT TAP AND PRESSURE TEST TO 250 PSI -BLEED OFF PRESSURE -DRILL THROUGH COIL WALL -DRAIN KCL FROM COIL ABOVE HOLE 22:20 - 22:35 0.25 LCR N DPRB PROD1 PJSM:SECURE AND CUT COIL AT SURFACE --SLB, NORDIC,SLB FSM, BP WSLS, BP SUPT, TP PRESENT 22:35 - 23:00 0.42 I LCR N DPRB PROD1 INSTALL STRAPS ON COIL BELOW PLANNED CUT HEIGHT TO SECURE -CUT COIL WITH MANUAL CUTTER AT 5' ABOVE RIG FLOOR 23:00 - 00:00 1.00 LCR N DPRB PROD1 PULL UP TO CHECK FOR SLACK, NO SLACK IN LINE -INSTALL CABLE CLAMP ON EXPOSED WIRE 2/14/2012 00:00 - 00:45 0.75 LCR N DPRB PROD1 STOP THE JOB SINCE CHAIN ON CABLE CLAMP ISN'T RATED TO PULL. -CONTACT PERF SHOP TO DELIVER 3-1/2 SINGLE JOINT ELEVATORS -INSTALL HORSE SHOE CABLE CLAMP ABOVE E-LINE CABLE CLAMP FOR SECONDARY RESTRAINT 00:45 - 01:00 0.25 LCR N DPRB PROD1 PJSM:GET SLACK IN E-LINE TO RIG UP FOR KINLEY CUTTER -NO SLACK CURRENTLY, PUMPING SLACK FORWARD WOULD BE DIFFICULT TO CONTAIN FLUID SO DETERMINED THAT WE WOULD CUT SECTIONS OF COIL OFF ABOVE THE 1ST CUT TO GET THE REQUIRED 10'OF E-LINE FOR KINLEY CUTTER 01:00 - 02:15 1.25 LCR N DPRB PROD1 CUT 1'SECTIONS OF COIL TUBING OFF ABOVE ORIGINAL COIL CUT LEAVING COIL SECTIONS AROUND THE E-LINE UNTIL 18'OF E-LINE FREE. -CUT E-LINE AT HIGHEST POSSIBLE POINT LEAVING 18'OF E-LINE FOR RIGGING UP TO DROP KINLEY CUTTER _ 02:15 - 02:20 0.08 LCR N DPRB PROD1 STAND BACK INJECTOR 02:20 - 03:00 0.67 LCR N DPRB PROD1 PJSM:SLICKLINE DRIFT AND KINLEY CUTTER -SLB,NORDIC, BP WSLS,BP SUPT,TP,SLB SLICKLINE,AND HES PRESENT Printed 3/12/2012 2:19:16PM • North America-ALASKA- BP Page 15 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 2/6/2012 End Date: X3-00YGV-C: (1,289,721.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase ! Description of Operations (hr) (ft) 03:00 - 05:00 2.00 LCR N DPRB PROD1 RIG UP SLICKLINE -MAKE UP DOUBLE ROPE SOCKET TO CONNECT 3/16"BRAIDED LINE TO 5/16" E-LINE -HANG SHEAVES 05:00 - 06:00 1.00 LCR N DPRB PROD1 PULL TEST ON E-LINE WITH SLICKLINE UNIT -400 LBS TO PULL SLACK OUT OF CABLE FROM DOWNHOLE -PULL TEST ROPE SOCKET -WORK ROPE SOCKET OVER SHEAVES 06:00 - 06:30 0.50 LCR N DPRB PROD1 SLICKLINE WORKING WIRE INSIDE COIL TO PULL AS MUCH SLACK AS POSSIBLE FOR DROPPING KINLEY CUTTER 06:30 - 07:50 1.33 LCR N DPRB PROD1 PJSM:SLICKLINE DRIFT AND DROP KINLEY WITH DAY CREW 07:50 - 14:00 6.17 LCR N DPRB PRODt WAIT ON ORDERS FOR DRIFT RUN -RECIEVE 1"HYDRIL PIPE FROM NORDIC 1 FOR DRIFT -DAY WSLS CHANGEOUT 14:00 - 14:50 0.83 LCR N DPRB PROD1 PJSM: DRIFT COIL PAST TUBING HANGER -SLB,NORDIC,SLICKLINE,WSL,BP SUPT AND TP PRESENT 14:50 - 15:00 0.17 LCR N DPRB PROD1 DRIFT COIL WITH 2 JOINTS OF OF 1"HYDRIL TO 47'BELOW TOP OF COIL 15:00 - 15:15 0.25 LCR N DPRB PROD1 PJSM:ARM AND DROP KINLEY CUTTER -SLB,NORDIC,BP WSL,BP SUPT,TP,SLB SLICKLINE,AND HES PRESENT 15:15 - 17:00 1.75 LCR N DPRB PROD1 ARM AND DROP KINLEY CUTTER -WAIT 100 MIN FOR CHARGE TO FIRE CUTTING THE WIRE 17:00 - 17:20 0.33 LCR N DPRB PROD1 PJSM: RECOVER WIRE AND CUTTER WITH DAY CREW —SLB,NORDIC,SLICKLINE,WSL,BP SUPT AND TP PRESENT 17:20 - 19:00 1.67 LCR N DPRB PROD1 PULL UP TO CHECK IF CABLE IS FREE -UP WEIGHT IS 400 LBS WITH CABLE FREE -CREW CHANGE 19:00 - 19:15 0.25 LCR N DPRB PROD1 PJSM: PULLING E-LINE OUT OF HOLE WITH SL UNIT WITH NIGHT CREW -SLB, NORDIC, BP WSLS,SLB SLICKLINE, SCS,TP, HES PRESENT -FLAG OFF RIG FLOOR AND AREA AROUND SHEAVES 19:15 - 22:35 3.33 LCR N DPRB PROD1 PULL E-LINE OUT OF HOLE WITH SLICKLINE -PULL AT 30FT/MIN -RECOVERED 3160'OF E-LINE AND KINLEY CUTTER -FILL COIL EVERY 1000'PULLED -CALL ODE WITH RECOVERED WIRE LENGTH 22:35 - 23:10 0.58 LCR N DPRB PROD1 RIG DOWN SLICKLINE'S BRAIDED LINE _EQUIPMENT 23:10 - 23:25 0.25 LCR N DPRB PROD1 PJSM:MU AND PULL TEST COIL CONNECTOR -SLB,NORDIC,BOT,WSLS AND TP PRESENT 23:25 - 00:00 0.58 LCR N DPRB PROD1 RIG UP 180"BAILS 2/15/2012 00:00 - 00:25 0.42 LCR N DPRB PROD1 DRESS COIL -MAKE UP EXTERNAL SLIP CONNECTOR Printed 3/12/2012 2:19:16PM North America -ALASKA- BP Page 16 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/6/2012 End Date: X3-00YGV-C: (1,289,721.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:NORDIC 2 Spud Date/Time:12/25/1982 12:00:OOAM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To F Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 00:25 - 01:00 0.58 LCR N DPRB PROD1 'PULL TEST COIL CONNECTOR TO 10K TO ENGAGE SLIPS -PULL TO 26K UNTIL COIL STARTED TO MOVE -MAKE UP TIW VALVE TO COIL CONNECTOR 01:00 - 01:30 0.50 LCR N DPRB PROD1 PJSM:RIG UP SL AND DRIFT COIL RIG UP SLICKLINE FOR ELINE DRIFT 01:30 - 02:30 1.00 LCR N DPRB PROD1 RIH WITH 1.7"DRIFT WITH LIB -TOOL STRING=28'TOTAL LENGTH -TAG AT 3160' -POH 02:30 - 03:00 0.50 LCR N DPRB PROD1 RIG DOWN SLICKLINE 03:00 - 03:30 0.50 LCR N DPRB PROD1 PJSM:RIG UP E-LINE -REVIEW PLAN TO BRING ALL OF E-LINE PCE UP TO RIG FLOOR 03:30 - 06:00 2.50 LCR N DPRB PROD1 BRING WIRELINE VALVES,LUBRICATOR, PUMP-IN SUB,10'RISER TO RIG FLOOR -REMOVE DOG COLLAR, HAND-SLIPS,SLIP BOWL,AND C-PLATE 06:00 06:30 0.50 LCR N DPRB PROD1 CREW CHANGE. DISCUSS OPS AND RIG STATUS. MAKE EQUIPMENT CHECKS AND OUTSIDE ROUNDS. HOLD PJSM WITH SLB E-LINE CREW TO DISCUSS RU OF LUBRICATOR. 06:30 - 10:30 4.00 LCR N DPRB PROD1 RU FULL SLB LUBRICATOR. ADD 10'7" LUBRICATOR EXTENSION TO COVER TIW VALVE AND SUUPORT COIL STUB. DISCUSS TESTING OPTIONS WITH TOWN TEAM. AGREE NO PRESSURE TEST REQUIRED 10:30 - 11:30 1.00 LCR N DPRB PROD1 DISCUSS AND REVISE PRESSURE TEST REQUIREMETS WITH TOWN TEAM. DECIDE 250/2400 PSI PT REQUIRED. DISCUSS EQUIPMENT NEEDS WITH SLOPE TEAM. 11:30 - 13:30 2.00 LCR N DPRB PROD1 LOCATE CROSS OVERS AND EQUIPMENT TO RU SLB LUBRICATOR ON TIW VALVE. RD SLB LUBRICATOR EQUIPMENT FROM 7" LUBRICATOR ASSEMBLY. 13:30 - 15:00 1.50 LCR N DPRB PROD1 MU CROSSOVERS,PUMP IN SUB,AND QUICK CONNECT TEST SUB. 15:00 - 15:45 0.75 LCR N PROD1 SLB E-LINE CREW CHANGE. HOLD DETAILED PJSM WITH SLB AND RIG CREW TO DISCUSS TESTING PROCEDURE. ALSO DISCUSS CUTTING PROCEDURE. 15:45 - 16:45 1.00 LCR N DPRB PROD1 FLUID PACK SLB LUBRICATOR. VERIFY GREASE PACKED. RECORD LOW PRESSURE TEST TO 300 PSI FOPR 5 MIN. NO LOSS. RECORD HIGH PRESSURE TEST TO 2400 PSI. LOSS LESS THAN 50 PSI IN 5 MIN. LOW AND HIGH PRESS TEST PASS. BLEED OFF. 16:45 - 18:20 1.58 LCR N DPRB PROD1 HOLD PJSM WITH SLB AND RIG CREWS. ARM CUTTING TOOL. GET ON WELL. TEST QUICK CONNECT SUB. 18:20 - 18:40 0.33 LCR N DPRB PROD1 PJSM:JET CUT COIL TUBING -RIG AND E-LINE CREWS,WSL,TP PRESENT 18:40 - 18:50 0.17 LCR N DPRB PROD1 SECURE AND STRAIGHTEN LUBRICATOR WITH COMALONG Printed 3/12/2012 2:19:16PM North America -ALASKA- BP Page 17 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/6/2012 End Date: X3-00YGV-C: (1,289,721.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA - UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs • Task , Code NPT NPT Depth Phase Description of Operations (hr) (ft) 18:50 - 19:30 0.67 LCR N DPRB PROD1 RIH WITH E-LINE TO 3100' 19:30 - 20:20 0.83 LCR N DPRB PROD1 FIRE JET CUT AT 310C -INDICATIONS THAT CUTTER FIRED -POH TO 250' 20:20 - 20:40 0.33 LCR N DPRB PROD1 PJSM: PULL TO SURFACE WITH ELINE,CIRC COIL 20:40 - 23:00 2.33 LCR N DPRB PROD1 POH FROM 250'TO 180'WHEN TENSION INCREASED -SLOWLY WORK E-LINE OUT OF THE HOLE WHILE MONITORING PRESSURE ON THE LUBRICATOR -CHECK WIRE COMING OUT OF GREASE HEAD, NO MISSING ARMORS -BUMP UP TOOL STRING TO HEAD CATCHER 23:00 - 00:00 1.00 LCR N DPRB PROD1 CLOSE TIW VALVE -BLEED PRESSURE OFF OF LUBRICATOR -UNSTAB LUBRICATOR AND CHECK JET CUTTER -CUTTER FIRED -STAB BACK ON AND TEST QUICK TEST SUB 2/16/2012 00:00 - 00:45 0.75 LCR N DPRB PROD1 CIRCULATE 100 BBLS KCL DOWN ANNULUS AND UP THE COIL TUBING TO PIT 1 AT 2.9 BPM/200 PSI -MINERAL OIL RETURNS INITIALLY,AFTER 10 BBLS PUMPED KCL RETURNS 00:45 - 01:55 1.17 LCR N DPRB PROD1 FLOW CHECK WELL -AAR FOR E-LINE JOB -PJSM FOR RIGGING DOWN E-LINE _ 01:55 - 02:45 0.83 LCR N DPRB PROD1 WELL SLIGHTLY OUT OF BALANCE WITH MINERAL OIL DRIPPING OUT OF ANNULUS SIDE. -CIRC ANOTHER 100 BBLS AT 2.9 BPM AND 140 PSI TO BALANCE WELL 02:45 - 03:30 0.75 LCR N DPRB PROD1 MONITOR WELL FOR FLOW -SLIGHT U-TUBE -NO FLOW FOR 30 MIN 03:30 06:00 2.50 LCR N DPRB PROD1 TRIG DOWN E-LINE EQUIPMENT 06:00 - 07:00 1.00 LCR N DPRB PROD1 CREW CHANGE. DISCUSS OPS AND RIG STATUS. MAKE ALL CHECKS AND ROUNDS. HOLD PJSM TO DISCUSS PLAN FORWARD FOR CHECKING COIL CUT. 07:00 - 09:30 2.50 LCR N DPRB PROD1 LATCH COIL STUB CONNECTOR WITH BLOCKS. PULL TO NEUTRAL WT-ESTIMATED AT 12K#. OPEN COMBIS. PU ON COIL. FREE. PU ABOVE ROTARY TABLE TO INSPECT WHERE COMBIS HAD ENGAGED PIPE. SLIP MARKS CLEAR AND PROPER. COIL DID NOT MOVE THROUGH SLIPS. SET COIL AT PROPER WORKING HEIGHT FOR CUT PROCEDURE. 09:30 - 12:00 2.50 RIGD N DPRB PROD1 HOLD PJSM. RU SCAFFOLDING ON FLOOR. CUT AND DRESS BOTH COIL ENDS. INSTALL SPOOLABLE CONNECTOR. PULL TEST SAME TO 20K# Printed 3/12/2012 2:19:16PM North America -ALASKA- BP Page 18 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) I Start Date:2/6/2012 End Date: X3-00YGV-C: (1,289,721.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date I From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 13:30 1.50 RIGD N DPRB PROD1 HOLD PJSM. REMOVE HEATER EQUIPMENT AND HOSE FROM COIL ON RIG ROOF. SPOOL COIL OUT OF HOLE. 2.67"OD ON JET-CUT END OF RECOVERED COIL GET OFF WELL AND PU INJECTOR TO MONITOR LAST 500'OF COIL. AT SURFACE. 13:30 - 14:30 1.00 RIGD P POST PREFORM INJECTIVITY TEST WITH KCL. 1180 PSI AT2.OBPMIN. 14:30 - 18:00 3.50 RIGD P POST RU SLB N2 PUMPER. HOLD PJSM TO DISCUSS BLOW DOWN. PUMP 10 BBLS MEOH. CORROSION INHIBITER. BLOW DOWN WITH N2. 18:00 - 18:30 0.50 RIGD P POST CREW CHANGE FOR NORDIC,SLB,LRS, WSLS 18:30 - 19:00 0.50 RIGD P I POST PJSM WITH LRS FOR DEISEL FREEZE PROTECT k 19:00 - 23:10 4.17 RIGD P POST RIG UP LRS TO BOP VALVES 17/18 -PRESSURE TEST LRS HOSE, NIGHT CAP AND VALVES 17/18 TO 250 PSI LOW,3500 PSI HIGH FOR 5 CHARTED MIN -NEEDED GREASE CREW TO COME OUT AND SERVICE MASTER TO GET A PASSING TEST -CLEAN AND EMPTY PITS 23:10 - 00:00 0.83 RIGD P POST BULLHEAD 40 BBLS DIESEL TO FREEZE PROTECT AT 1 BPM AND 1000 PSI 2/17/2012 00:00 - 00:20 0.33 RIGD P POST CONTINUE TO PUMP DIESEL FP 00:20 - 01:00 0.67 RIGD P POST RIG DOWN LRS -LET WELL STABILIZE WITH TUBING PRESSURE TO 0 PSI 01:00 - 01:30 0.50 RIGD P POST PJSM WITH VALVE SHOP FOR SETTING BPV -SET BPV 01:30 - 03:00 1.50 RIGD P POST GREASE TREE VALVES -TEST TREE CAP AGAINST MASTER VALVE TO 3500 PSI -BLOW DOWN LINES 03:00 - 04:00 1.00 RIGD P POST PJSM:UNSTAB COIL -INSTALL AND PULL TEST GRAPPLE -PULL COIL ACROSS THE TOP AND SECURE TO SHIPPING BAR 04:00 - 06:00 2.00 RIGD P POST OPEN BOP RAM DOORS AND INSPECT -CHANGE OUT SEALS LOWER REEL THROUGH BOMBAY DOOR TO TRUCK 06:00 - 06:30 0.50 RIGD P POST CREW CHANGE. DISCUSS CURRENT OPS AND RIG STATUS. MAKE EQUIPMENT CHECKS AND OUTSIDE ROUNDS. 06:30 - 08:00 1.50 RIGD P POST CONTINUE TO INSPECT BOP EQUIPMENT. 08:00 - 11:30 3.50 RIGD P POST ND BOPS. NU TREE CAP. TEST TREE CAP TO 250/3500 PSI. CONTINUE TO CLEAN PITS. INSPECT AND WARM UP MOVING SYSTEM. 11:30 - 12:00 0.50 RIGD P POST RELEASE RIG AT 1200 HRS ON 2-17-12. 12:00 - 13:30 1.50 RIGD P POST COMPLETE CHECK LIST ITEMS FOR BACKING OFF WELL. Printed 3/12/2012 2.19:16PM , North America-ALASKA-BP Page 19 of 19 A Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/6/2012 End Date: X3-00YGV-C:(1,289,721.00) Project: Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 2 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: Rig Contractor: NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:30 - 14:00 0.50 RIGD P POST HOLD PJSM TO DISCUSS COMMS,SPOTTERS POSITIONS,ESD,MOVE PLAN. BACK OF WELL. Printed 3/12/2012 2:19:16PM TREE= McEVOY NVELLHEAD= Mc EVOY 1 8-04 C 54111/2"CHROME NOTES BGLL ANGLE>70 @ 10120'*** ACTUATOR= AXELS OPS SHUT DOWN KB.ELEV= 45.11' BF.ELEV= 19.21' I ) 1 KOP= 2100' Max Angle= 5"©10187' 2185' -14-1/2"CAMCO BAL-O SSSVN,ID=3.813" Datum MD= 11113' �� Datum TVD= 8800'SS 2185' H4-1/2"DSSSV PLUG(01/27/12) 20"CONDUCTOR 120' 13-3/8"CSG,72#, L-80 BTRS, ID=12.347" H 2629' I ' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE TOP OF COIL TUBING(03/02/11) 3100' 4 3168 3055 35 MMGM DMY RK 0 03/29/08 IM 3 5993 5193 40 MMGM DMY RK 0 03/29/08 t 2 8112 6830 31 MMGM DMY RK 0 04/06/02 I1 9514 8116 38 KBG-2 DMY BK 0 04/06/02 Minimum ID = 3.80" @ 5595` 8541' H9-5/8"X7"BKRZXPPKR/TIEBACK, ID=6.313" 4-1/2" MILLED OTIS XN NIP \\\\ 8555' -19-5/8"X 7"BKR HMC LNR HGR,ID=6.313" TOP OF WHIPSTOCK - 8741' IN 9-5/8"CSG,47#, L-80 BTRS, ID=8.681" H -8734 I- 9-5/8"M4ILLOUT WINDOW(18-04B)8718'-8734' PERFORATION SUMMARY 8855' -TOP OF CEMENT INSIDE COIL `'�: REF LOG: SWS PERF ON 08/14/01 ANGLE AT TOP PERF 18 @ 10383' ilr-i,-- 9541' H4-1/2"OTIS X NIP,ID=3.813" Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10383-10410 'C 0122102 p Z 9551' -17"X4-1/2"BKR S-3 PKR,ID=3.875" 3-3/8" 6 10410-10450 `C 09/25/01 2-7/8" 4 10426-10456 'C 08/14/01 2-/78" 4 10465- 10485 'C 08/14/01I— 9575' H4-1/2"OTIS X NIP,ID=3.813" "ti •PERFORATIONS BELOW WHIPSTOCKQ 9980' 9595' -4-1/2 OTIS XN NIP,MILL TO 3.80 (02/05/11) I — " i N- 9608' -14-1/2"WLEG,ID=3.958" 4-1/2"TBG, 12.6#,13CR-80 VAM ACE, -I 9606' I x 0152 bpf,ID=3.958" 9685' 1--7"X 4-1/2 BKR ZXP PKRw/7.40'TIEBACK • &HMC LNR HGR,ID=4.39" y 11 T LNR,26#,L-80 BTC, .0383 bpf,ID=6.276" -{ 9882' X 3.80"MILLOUT WINDOW(18-04C)9983'-9990` IllibiNN.....,.. 4-1Q"PKR WHIPSTOCK(0222/11) -I 9980' 4-1/2"LNR,12.6#, L-80,.0152 bpf, ID=3.958" -1 -9990' + 4-1/2"OPEN HOLE 10675' v i!•..!i ( Ire -7A) DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/29/83 ROW 41 INITIAL COMPLETION 02/27/12 DAS/PJC SET DSSSV PLUG WELL: 18-04C 05118/98 N4/3 ES CTD SIDETRACK(18-04A) PERMIT No:'2110020 07/17/01 MES SIDETRACK(18-04B) API No: 50-029-20875-03 03/02/11 NORDIC 1 CTD SUSPENDED(18-04B) SEC 24,T11 N,R14E, 1067'FNL 8191'FEL 02118/12 NORDIC 2 OPS SHUT DOWN(18-04C) 0226/12 PJC DRLG HO CORRECTIONS 0227/12€ NN/PJC BORE B CTD CORRECTION I BP Exploration(Alaska) 1 rF, --7,1r" 2 � L, irii �' I YJ II "J SEAN PARNELL,GOVERNOR Lru ALASKA OIL AND GAS 333 W.7th AVENUE,SUITE 100 CONSERVATION COMMISSIONANCHORAGE,ALASKA 99501-3539 i PHONE (907)279-1433 FAX (907)276-7542 Joe Lastufka0 2- Drilling Technologist a l _ D BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, 18-04C Sundry Number: 312-066 Dear Mr. Lastufka: 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, a Daniel T. Seamount, Jr. Chair DATED this Cr day of February, 2012. Encl. ` vim` • STATE OF ALASKA q, i611Iv ECEIVE9 ALAors,A OIL AND GAS CONSERVATION COMMISSION FEB 2 1 2012-1-.7'2 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ,,at.,. ,;, ,Jas Cons.Commission 1. Type of Request: Antt fagr± ❑Abandon 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Change Approved Program ❑ Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension ® Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration(Alaska)Inc. - ® Development 0 Exploratory 211-002 3. Address: 0 Service 0 Stratigraphic 6. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-20875-03-00 7. If perforating,closest approach in pool(s)opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 18-04C Spacing Exception Required? 0 Yes ®No 9. Property Designation: 10.Field/Pool(s): ADL 028307 - Prudhoe Bay Field/Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10675' 8690'- 8855' 7494' None 8855' Casing Length Size MD ND Burst Collapse Structural Conductor 80' . 20" 80' 80' Surface 2629' 13-3/8" 2629' 2593' 4930 2670 Intermediate 8718' 9-5/8" 8718' 7370' 6870 4760 Production • Liner 1341' 7" , 8541'-9882' 7208'-8331' 7240 5410 Liner 909' 4-1/2" , 9685'-9983' 8173'-8413' 8430 7500 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): None None 4-1/2", 12.6# 13Cr-80 9608' Packers and SSSV Type: 7"x 4-1/2"Baker'S-3'Packer Packers and SSSV 9551' MD(ft)and ND(ft): 12. Attachments: 13.Well Class after proposed work: ® Description Summary of Proposal 0 BOP Sketch 0 Detailed Operations Program 0 Exploratory . ®Development 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: February 17,2012 ® Oil - 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date: 2/17/2012 0 Gas ❑GINJ ❑GSTOR ❑Abandoned Commission Representative: Guy Schwartz b asfN v 0 WAG 0 SPLUG 0 Suspended 17. I hereby certify that t - : g•ing is true and correct to the best df my knowledge. Contact Matthew Ross,564-5782 Printe. ie La.t . Title Drilling Technologist 11 Prepared By Name/Number: Signatu Phone 564-4091 Date2./Z I/12- Joe Lastufka,564-4091 Commission Use Only Conditions of approval: Notify Commission so that a representative may witness �i �,^ /^ Sundry Number: J VJ YJ ❑ Plug Integrity 0 BOP Test 0 Mechanical Integrity Test 0 Location Clearance Other: Subsequent Form Required: 6 _£10 Y 4\41f-- APPROVED BY �j��� 2 Approved By: COMMISSI SION Date G. Form 10-403 Revised 01/2010 / 0RIG1 tH )FMSTh,l; Submit In Duplicate Page 1of1 Lastufka, Joseph N (Northern Solutions) From: Hubble, Terrie L Sent: Monday, February 20, 2012 4:35 PM To: Lastufka, Joseph N (Northern Solutions) Subject: FW: 18-04C Operational Shutdown Attachments: 18-04 Operational Shutdown.pdf (Compressed); 18-04C_Ops shutdown.CNV (Compressed) From: Ross, Matthew Sent: Monday, February 20, 2012 3:55 PM To: Hubble, Terrie L Subject: 18-04C Operational Shutdown Guy; Here is the sequence of events that have unfolded on 18-04C after returning back to this well from our operational shut down. After pulling the BPV, we encountered losses in excess of 8bpm. Rig crew can safely maintain 6bpm. A full bore LCM treatment was performed which was successful. The first BHA into the well tagged up at the window. A window milling dressing run was made which successfully dressed the window. We decide to RIH to bottom to condition the hole. We tagged bottom & losses in excess of 8bpm were encountered. The LCM material that was cleaned out the open hole was sucked down hole & packed off the BHA. The BHA also became stuck & had continued to have excessive losses down the coil. 4 LCM treatments were pumped down the coil (65bbls) followed by 6 treatments of cement (52bbls). We successfully stopped the losses down the coil with the cement leaving the top of cement inside the coiled tubing at 8855' MD. We recovered 3160' of e-line inside the coiled tubing. We cut the coiled tubing at 3000'MD, leaving the rest of the coiled tubing inside the well. We have freeze protected the well down to 2500' MD. Our plan forward for this well will be as follows; 1) Load & kill well with 8.37ppg, 1% KCL, followed by diesel freeze protect to 2500' MD. 2) MIT IA to 3000psi. 3) Set tubing plug in the SSSV profile at 2185' MD. 4) MIT T to 3000psi. 2/21/2012 .., 1 8-04C SAFETY NOTES: 4-1/21'CHROME TEG QM, Sidetrack —,.. 2185 I—4-1/2*CAMCO BAL-0 SSSVN,ID=3 813" 0 3100' -1 Top,of Coiled Tubing A II GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE . 4 3168 3055 35 14.4GM DMY RK 0 03/29108 - 3 5993 5193 40 !MGM DMY RK 0 03129/08 2 8112 6830 32 ',MGM DMY RK 0 04/06/02 1 9514 8116 38 KBG-2 DMY BK 0 04106102 I 1 8541' h.0-5/8'X 7"BKR ZXP PKR/TI:::ACK,ID r.6 313' r8555' —9-5/8"X 7'BKR HMC LI44 HGR,ID tz 8313' I 8856 —iTop 0 Cement Inside':,3 -----.'-'"-- ------- Coiled tubing stuck at 10,666TOC-8855' Called cut at 3100' 9541. -14-11r OTIS X NIP,102 3613 1 9551' —7 X 4-1'2 BKR 6-3 PKR.10 z.3.875" r .,,,, 9575 —14 12 MS XNIP ID.3 13 " 4- 9595 —14-1.2"OTIS X N NP,ID t3 6" ill 4-112"TBG,12 6#,13-CR,.0152 bpf.ID=3.958" — 96064 I x %Of —4-112"VILEG,ID t-:3.958' I9685' —7'X 4-1,2"BKR Otv ZXP PKR ID t:439 'fi 4-:1 A 6 9882' 1-i 7*LNR,26#,L-80,0 0383bpf,ID rl 6 276' 1:! 41% r 4 112"pkr w tppstock --i 998T '4 NAM + NV 6\ rirliffNa -.... F14-1,4`Open fi3i —1 10675' To: Alaska Oil & Gas Conservation Commission From: Matthew Ross 0 b CTD Engineer Date: January 30, 2012 p-Tb z//- - - Re: 18-04C Permit to Drill request Approval is requested for a permit to drill a CTD sidetrack from well 18-04B. 18-04B was a July 2001 rotary sidetrack targeting a structurally low block within the Midfield Graben. It was completed as high angle well in Zone 1B/1A. The well struggled to flow at-800 bopd at 3100 GOR from Zone 1 and required frequent Hot Oil Treatments. The oil rate steadily declined until Jan 2002 when 27' of Zone 2A were perforated. The well tested strong at 3000 bopd but declined to 1000 bopd at 30,000 GOR in a few months. From mid 2002 to 2007, it cycled with slowly declining recharge and ontime. The well was shut-in for high GOR in Jan 2008 when it POP'ed and tested at 89,000 GOR after a 4 month shut-in period. There have been subsequent attempts to POP the well without success, and it remains SI. LAST WELLTEST(12/31/07): 0 bopd, 36 MMscfd, 0%WC at>100,000 GOR The proposed plan for well 18-04C is to sidetrack out of the 18-04B 4-1/2"production liner with a Coiled Tubing Drilling rig on or around January 25,2011. The existing perforations will be isolated by the primary cement job after drilling and running liner. The sidetrack will exit the 4-12" liner in the Zone 3 and drill a 4- 1/4"hole in the target zone IA sands. CTD Sidetrack Summary Pre-Rig Work: (scheduled to begin January 15, 2011). 1. S Dummy WS drift to 10,150' MD. 2. F Load&kill well prior to setting WS. Freeze protect well to 2000'MD. 3. E Concurrently set 4-1/2"Packer WS at 9980' MD. 4. F Pressure test packer WS to 2400psi. 5. V PT MV, SV, WV. 6. D Bleed gas lift and production flowlines down to zero and blind flange. 7. 0 Remove welihouse, level pad. 8. V Set TWC -24hr prior to rig arrival. Rig Work: (scheduled to begin on January 25, 2011) / 1. MIRU and test BOPE to 250 psi low and 3500 psi high. Pull TWC. 2. Mill XN profile at 9595' MD. 3. Mill 3.80" window at 9980' MD and 10' of rathole. apti 4. Drill Build: 4.25" OH, 421' (40°/100). 5. Drill Lateral: 4.25"OH, 704' (12°/100). 6. Run 3-1/4"x 2-7/8" solid cemented completion leaving TOL at 9950' MD. 7. Pump primary cement leaving TOC at 9950', 11 bbls of 15.8 ppg liner cmt planned. 8. Cleanout run. 9. Run MCNL/GR/CCL log. 10. Perforate 100'. 11. Freeze protect well, set BPV and RDMO. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Run 4-1/2" liner top packer and test liner lap to 2,400 psi. 3. Run generic GLV's. Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Power Pro for milling window and drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4.25" Casing Program: • 3-1/4" TCII, 6.6 pounds per foot, L-80 solid liner—9950' MD to 10,675' MD. • 2-7/8" STL, 6.4 pounds per foot, L-80 solid liner— 10,675' MD to 11,105' MD • A minimum of 14 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 9950' MD. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 70.9°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property—37,800'. • Distance to nearest well within pool—860' to 18-19. Logging • MWD directional, Gamma Ray and resistivity will be run over all of the open hole section. • Cased hole GR/CCL/MCNL logs will be run. Anti-Collision Failures • None. Hazards • One mapped fault crossings at 10,740' MD. • The maximum recorded H2S level on Drill Site 18 pad was 70 ppm on well 18-18B on 5/22/2010. • Lost circulation risk is considered high for this well due to the planned fault crossing. Reservoir Pressure • The reservoir pressure on 18-04B is expected to be 3306 psi at 8,800' TVDSS. (7.3 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2426 psi. Matthew Ross CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble 18-04C Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L(DOA) Sent: Tuesday, December 20, 2011 2:37 PM To: 'Ross, Matthew' Subject: R ,;18-04C (PTD 211-002) Mathew, This is sufficient notification. If there are any major changes to the drilling program such as mud weight, BHA etc. please email me the specifics. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Ross, Matthew [mailto:rossmo@BP.com] Sent: Tuesday, December 20, 2011 2:02 PM To: Schwartz, Guy L(DOA) Subject: 18-04C Guy; 18-04C drilling was operationally suspended in March due to lost circulation. We did receive an approved 10-403 (Operations Shutdown)from the State with a note in the comment section to notify the Commission when ready to restart operations by e-mail. We plan to go back to 18-04 by the end of January, continue drilling where we left off&finish the drilling program. The directional plan will be the same. The drilling program itself has been changed in to reflect our updated lost circulation practices in coiled tubing drilling. Does this e-mail satisfy the requirements to allow CTD to complete the drilling of 18-04C? Many thanks! 12/20/2011 Page 1 of 1 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Tuesday, August 09, 20112:01 PM To: 'Lastufka, Joseph N (Wipro)' Cc: McMains, Stephen E (DOA) Subject: DS 18-04B (PTD 201-09�nd DS 9-44 (PTD 190-126) Joe, We received "Suspended well inspection" forms 10-404s for DS 18-04B and DS 0944 recently. These wells are actually P & A `d already (we received the 407s too) and can't be classified as suspended. The sidetracks that were started and then operationally shut down with sundries are all the paperwork that is needed. Once the sidetrack is started (window cut) the motherbore is officially P & A'd. Please call me with any questions.... Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) AUG 15 2011- fB/y 11:7- j i 00ZC) P u -OL( C LUCti CL 6k)eC� 1 ��Ck" brl 67/10 111 ao C0OT 6�L'7f►�illil STATE OF ALASKA ALASKA C.._ AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS ^kim Other v REPORT OF 0F4` 1. 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate❑ ❑ Performed: Alter Casing ❑ Pull Tubing❑ Perforate New Pool ❑ waiver[] Time Extension ❑ INSPECTIO Change Approved Program ❑ Operat. Shutdown[:] Perforate ❑ Re-enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: S. Permit to Drill Number: Name: Development ❑r Exploratory ❑ Stratigraphic❑ Service ❑ „ 201-0900 3. Address: P.O. Box 196612 5. API Number: Anchorage, AK 99519-6612 " 50-029-20875-02-00 8. Property Designation (Lease Number) : _ 9. Well Name and Number: ADLO-028307 PBU 18-04B 4b--C)1AC N, 10. Field/Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL OL 11. Present Well Condition Summary: yd Total Depth measured 10607 feet N Plugs (measured) 9575 feet true vertical 9002.08 feet Q1 Junk (measured) None feet Effective Depth measured 9980 feet / Packer (measured) 8541 9551 9685 feet true vertical 8410.51 feet (true vertical) 7208 8066 8173 feet Casing Length Size MD `\ TVD Burst Collapse Structural V Conductor 80' 20" 91.5# H-40 107 �'( 27 - 107 1490 470 Surface 2603' 13-3/8" 72# L-80 - 2629 26 - 2593 4930 2670 1:b Production 8709' 9-5/8" 47# L-80 ,(\ 5 - 87t4V 25 - 7385 6870 4760 Liner 1341' 7" 26# L-80 / r ,/\ 8541 - 9882 7208 - 8331 7240 5410 Liner 909' 4-1/2" 12.6# L -8d, 968 10594 8173 8990 8430 7500 Liner \/ Perforation depth: Measured depth: SEE True Vertical depth: — — — Tubing: (size, grade, measured and true vertical d th) 4-1/2" 12.6# 13Cr80 24-9608 24-8111 Packers and SSSV (type, measured and true v nical depth) 7" Baker ZXP Packer 8541 7208 4-1/2" Baker S-3 Perm Packer 9551 8066 4-1/2" Baker ZXP Packer 968a5r� 8173 pppp������'cc "T "�VE d ' 12. Stimulation or cement squeeze summary: JULZOl1 v U Intervals treated (measured): Treatment descriptions including volumes used and final pressure: fila4a GN �& GAA C01'4. r$i-diillSStU11 a�D 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: SUSPENDED Subsequent to operation: 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development p ❑ Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil Gas WDSPL GSTOR ❑ WINJ ❑ WAG❑ GINJ ❑ .. SUSP❑� SPLUG ❑ 17. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: i 6 20�-2�'�a-� NA Contact Joe Lastufka `; Pa r1 AUG a � 6+ M� B I4 Jl - Printed Name Joe Lastufka Title Petrotechnical Data Technologist Signature Phone 564-4091 Date 7/28/2011 Form 10-404 Revised 10/2010 RSDMS JUL 2 9 2011 RSDMS JUL 2 9 2011 L,. 9 b , f (- y_� Submit Original Only ,7 w Ph 1Nlp d M L c d p a 6 O F. L p, p > w M w aD W Cl)h M W w ao MO m O r W W' v N M M w ao' w M w a0 ao Oa v N W w ao Ci N LO off W aD h M M r 00 0o m IT N a0 W O M h 00 ao D1�CN v O r, a0 W t0 r O fD W eo h M W W W t0 07 N 0 h ao' w c0 IfJ O O) N h '* W O ao w > O p N � U0 YY Z W o A w v w v a a Vvw W W W W U U m`rov00000 ZIXyQ ad L O r 0 r r r r r J U LL CL LU W WW d In LL W J M J a N LU p p m d WaopZz>j29 W WJQQOOFI– .2 O -Q: (q VJyyyyy J C M M �p N D1 h O r r h h N M M h h - 0 j~`t w K o"o 'Q v ocoo a v M 1f7 Di Cp %d I� 0: LL Wv1LLf.QQf��00 G.LL'iulL-jyfA(%1VJNy d a O p U W > cO O F LU CL p p H HO N W W J d J J 4 a w J g Qw J Y LL LL LL Q LL LL m jW F —00 W r r r r r r N r M CO y y 0 Cl) N Na C4 N 04 W 0 7 0 5 0 Q Q co '00 Orn N W 01r� a LLJJ UU W o Owaa W W W J ZZzO _UJ :+ p Q Q Q= `m Q G W J J U U U W O- O mpQ.'p'JJ Q Q m m LL M W W W0 2 0 0 Emco m m m m m m Z v 0 v 0 v 0 v 0 v 0 v 0 v 0 v 0 LL M y 0 a. y Y 3 0o co co co co 0o co 00 4 a a U J 2 U) r r r r r r r r m m I- LL 20 Prudhoe Bay Unit Well 18-04B / 18-04C, PTD 2010900 / 2110020 Suspended Well Inspection Report BP Exploration Alaska (BPXA) completed a suspended well inspection of PBU 18-04B / 18-04C on 7/10/11. The following attachments document the inspection and the current condition of the well (reference 20 AAC 25.110 (e) and (f). • Suspended Well Site Inspection form documenting the well pressures and site condition. AOGCC Inspector Bob Noble witnessed the inspection. • Wellbore Diagram illustrating the current configuration of the well. • Pad map showing the well location and other wells within'/4 mile radius of the surface location. • Photographs showing the condition of the wellhead and surrounding location. Supplemental Information: • Sidetrack operations in PBU 18-04C (PTD 2110020) were temporarily shutdown after encountering drilling problems. The Operations Shutdown was approved 3/30/11 (Sundry 311-069). • Since the sidetrack PBU 18-04C has not been completed, parent well 18-04B is still considered suspended with a date of 02/23/11. L— LL Ak4- +'u • PBU 18-04B / 18-04C is located on a pad with active producing wells and/or service wells. • The strata through which the well was drilled is neither abnormally geo-pressured or depleted. • The well is secured with a tubing tail plug. • The well is mechanically sound as proven by a pressure test to 2500#. AWO 7/13/2011 1.5 P - LA;,' Suspended Wel, Site Inspection Form Notify AOGCC Inspectors at least 10 days prior to inspection to allow witness Well Name: PRUDHOE BAY UNIT 18-04B / 18-04C Field/Pool: PRUDHOE BAY Permit # (PTD): 2010900 / 2110020 API Number: 500292087502 / 500292087503 Operator: BP EXPLORATION (ALASKA) INC Date Suspended: 2/23/2011 Surface Location: Section: 24 Twsp: 11N Range: 14E Nearest active pad or road: Prudhoe Bay Drillsite #18 Take to Location Digital camera Brief well history Latest Sundry or Completion report Past Site Visit documentation Pressure gauges, fittings, tools Map showing well location /Aerial photos Wellbore diagram showing downhole condition Site clearance documentation Sample containers for fluids on or near pad Condition of Surface Location AOGCC requires: 1) a description of the condition of the surface location, including discoloration, fluids or sheens visible on the ground or in any nearby water, 2) photographs showing the condition of the location surrounding the well General location condition: Good Pad or location surface: Location cleanup needed: Pits condition: Clean gravel Surrounding area condition: Clean Water/fluids on pad: No Discoloration, Sheens on pad, pits or water: No Samples taken: No Access road condition: Good Photographs taken (# and description): 2: front of wellhouse, back of wellhouse Condition of Wellhead AOGCC requires: 1) a description of the condition of the wellhead, 2) well pressure readings, where practicable, 3) photographs showing the wellhead condition Well description, condition: McEvoy wellhead, Grey master valve McEvoy tree. No flowline. Cellar description, condition, fluids: Clean gravel Rat Hole: No Wellhouse or protective barriers: no barriers Well identification sign: Tubing Pressure (or casing if no tubing): No scaffolding Annulus pressures: IA: 0 psi OA: 0 psi Wellhead Photos taken (# and description): 2: wellhead, tree Work Required: Remove integral on IA, intall well information sign outside of wellhouse Operator Rep (name and signature) AOGCC Inspector: Bob Noble Other Observers: Michael Clingingsmith Inspection Date: 7/10/2011 AOGCC Notice Date: Time of arrival: 1:00 AM Time of Departure: 1:35 AM Site access method: Truck TREE= WELLHEAD = ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TV D = M EVG 18-04C McEVOY SAFETY W 'S: WELL ANGLE> 70 @ 10120'*** ,XELS SUSPENDED 4-1/2"CHR..�dETBG *** 1. 45.1' INTERVAL 113-3/8" CSG, 72#, L-80 BTRS, ID = 12.347" 1 Minimum ID = 3.80" @ 9595' 4-1/2" MILLED OTIS XN NIP TOP OF WHIPSTOCK 9-5/8" CSG, 47#, L-80 BTRS, ID = 8.681" PERFORATION SUMMARY REF LOG: SWS PERF ON 08/14/01 ANGLE AT TOP PERF: 18@10383' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10383 - 10410 C 01/22/02 3-3/8" 6 10410 - 10450 C 09/25/01 2-7/8" 4 10426 - 10456 C 08/14/01 2-/78" 4 10465 - 10485 C 08/14/01 4-1/2" 4-1/2" TBG, 12.6#, 13CR-80 VAM ACE, .0152 bpf, ID = 3.958" ID = 6.276 I-1 9882 (02/22/11) 9980' ID = 3.958" - --9990 ❑r ID = 3.813" GAS LIFT MA NDRR S ST MD I TVD DEV I TYPE I VLV I LATCH PORT DATE 4 3168 3055 35 MMGMDMY RK 0 03/29/08 3 5993 5193 40 MMGM DMY RK 0 03/29/08 2 8112 6830 31 MMGM DMY RK 0 04/06/02 1 9514 8116 38 KBG-2 DMY BK 0 04/06/02 u� 8�-5. -1 ZXP PKIRMEBACK, ID = 6.: HMC LNR HGR, ID = 6.313" 9-5/8" MILLOUT WINDOW (18.046) 8718' - 8734' 14-1/2" OTIS X NIP, ID = 3.813" I 17" X 4-1/2" BKR S-3 PKR. ID = 3.875" 1 4-1/2" OTIS X NIP, ID = 3.813' 4-1/2" PX PLUG (04/02/11) 4-1/2" OTIS XN NIP, MILL TO 4-1/2" WLEG, ID=3.958" 7" X 4-1/2" BKR ZXP PKR w / & HMC LNR HGR ID = 4.39" 3.80" MILLOUT WINDOW (18.04C) 9983' - 9990' DATE REV BY COMMENTS i DATE REV BY COMMENTS 01/29/83 ROW 41 ORIGINAL COMPLETION 05/18/98 N413 ES RW0 07117/01 MES SIDETRACK (18.04B) 03/02111 NORDIC 1 CTD SUSPENDED (18-04C) 03/08/11 PJC CSG/ TBG CORRECTIONS 04/01/11 MR/PJC SUSPENDED FINAL 04/04/11 WEC/PJC SET PX PLUG (04/02/11) PRUDHOE BAY UNIT WELL: 18-04B PERMIT No: '2010900 AP Nb: 50-029-20875-02 T11 N. R14R 1067' FNL & 191' FEL BP Exploration (Alaska) r Enter/Exit ) 911'\\-- — ►' 234' i - —4 L 244'—P-- lo 44'—P--10 I I� 9• I ■ 18 a■ I I 23 ■ I I I' I 5 ■ 16 27 • I I I I •25 Eo 5. l I ( I ■15 CO ■ 25 i 4 b �— 4• T I k. I 9 1 ■ I 24 3• I [ I ,3— 17 0 I' I I 2' I I I ■12 � I I I — 19 : I I I: -- I ' 21 ' 11 29, 28 ..—o I I'.. I • 20 O I. I 22 31 (o33 h —■ — 34 30 • _i Enter/Exit rl Enter/Exit r 1 i WELL PRODUCER ■ or ❑ PBU - DS 18 WELL INJECTOR A, DATE : 12/2/2010 SCALE : 1" = 250' MAP DATE : 2010 WELL SLOT W/CONDUCTOR 9 bs14495..xd VC ion �770 r firr MPMMMR ad s f1 VA STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION CO p1 Lo` eunG\ 4IeA Suspended Well Inspection Report 7 M 11-�oZ � I� 5 IG o Date Inspected: 07/10/11 Inspector: Bob Noble Type of Inspection: Well Name: —2BW@-848- FgU 18-OLyI C PTD No.: 4910900— 7 (I —oD 2, Location Verified? Yes If Verified, How? Other (specify in comments) Onshore / Offshore: Onshore Suspension Date: 02/23/11 Sundry No.: Well Completion Rpt Well Pressures (psi): Tubing N/A IA 430 OA 0 of nq Surface Up Actions Photo (1) fuLLr� S i`� i� 0* -W e fi`Me �Y2Qo'rt • RSL Operator: gp j_ `,,((I)),, -/'� Oper. Rep: Mike Clingingsmith `v I V �) �C Oper. Phone: 659-5766 Oper. Email: L4 11 Dale AOGCC Notified: 07/09/11 Type of Inspection: Initial Wellbore Diagram Avail.? Yes Photos Taken? Yes is of spills. k?Wcd' 'W T)Fi 1 Er L��l" `�.(SCclM'YILT cook -d +0 Supry BY: PLB 08/2010 2011-0710 Suspend_PBU 18-04B—bn.als C Suspended Well Inspection - PBU 18-04XC PTD 4*e960 211 -M Z Photo by AOGCC Inspector B. Noble P4 A dVl 212-3111, W Iyop,-L" iS I13 -d C . PBU-I�Suspended Well Inspection 7-10-11 bn O-Oq c- STATE OF ALASKA RECEIVED ALA; OIL AND GAS CONSERVATION COME BION MAR 3 0 2011 REPORT OF SUNDRY WELL OPERATIONS Alaska Qd&4nas Cam-Commission 1. Operations Performed: , ❑Abandon 0 Repair Well 0 Plug Perforations 0 Stimulate 0 Re-Enter Suspended iS.Y10f'itoe 0 Alter Casing 0 Pull Tubing 0 Perforate New Pool 0 Waiver 0 Other 0 Change Approved Program ®Operation Shutdown 0 Perforate 0 Time Extension 2. Operator Name: 4_ Well Class Before Work: 5_ Permit To Drill Number: BP Exploration(Alaska)Inc. N Development 0 Exploratory - 211-002 3. Address: 0 Service 0 Stratigraphic 6. API Number: P.O.Box 196612,Anchorage,Alaska 99519-6612 • 50-029-20875-03-00 7_ Property Designation: 8. Well Name and Number: ADL 028307 • PBU 18-04C 9.Field/Pool(s): Prudhoe Bay Field/Prudhoe Bay Oil Pool 10. Present well condition summary Total depth: measured 10675' feet Plugs(measured) None feet true vertical 869(y feet Junk(measured) None Effective depth: measured 10675' feet Packer: (measured) 9551' feet true vertical 86g0' feet Packer: (true vertical) 8066' feet Casing Length Size MD TVD Burst Collapse Structural Conductor 80' 20" 80' 80' Surface 2629' 13-3/8" 2629' 2593' 4930 2670 Intermediate 8718' 9-5/8" 8718' 7370' 6870 4760 Production Uner 1341' T 8541'-9882' 7208'-8331' 7240 5410 Liner 909' 4-1/2" 9685-9983' 8173'-8413' 8430 7500 Perforation Depth: Measured Depth: None True Vertical Depth: None Tubing(size,grade,measured and true vertical depth): 4-12",12.6# 13Cr-80 9608' 8111' Packers and SSSV(type,measured and true vertical depth): T x 4-12"Baker'S-3'Packer 9551' 8066' 11_Stimulation or cement squeeze summary Intervals treated(measured): Treatment description including volumes used and final pressure: 12. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Md Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: Subsequent to operation: 13_Attachments: ❑Copies of Logs and Surveys run 14_Well Class after work: ®Daily Report of Well Operations 0 Exploratory ®Development 0 Service 0 Stratgraphic ®Well Schematic Diagram 15_ Well Status after work: 0 GINJ ®Oil 0 SUSP 0 WDSPL 0 Gas 0 GSTOR ❑SPLUG 0 WAG 0 WINJ 16. I hereby certify that the foregoing is true and correct to the best of my knowledge. ndry Number or WA if C.O.Exempt Contact Matthew Ross,564-5782 311-069 Printed Name Terrie Hubble Title Drilling Technologist Signature --' J(/) 4 4Lgere, Phone 564-4628 Date °3I n Terris Hd By Name/Number ubble,5sa�s28 Form 10-404 Revised 102010 RBDMS APR O4 2011'"Zr.).) y•/Z • // i� /2ubrnitorigamalonly North America -ALASKA- BP Page 1 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 2/14/2011 End Date: 3/2/2011 IX3-00Y24-C(1,484,621.00) X3-00YGV-C(757,473.00) Project:Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor:NORDIC CALISTA UWI: 500292087500 Active Datum: 9: 04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) _ _ Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) ---- --- ----- 2/14/2011 00:00 - 00:30 0.50 MOB P PRE PJSM TO PUMP 50 BBLS FRESH WATER,15 BBLS INHIBITED WATER,10 BBLS 60/40 METHANOL THROUGH REEL AND BLOW DOWN REEL WITH N2. 00:30 - 02:30 2.00 MOB P PRE PUMP 50 BBLS FRESH WATER,15 BBLS INHIBITED WATER,10 BBLS 60/40 METHANOL THROUGH REEL. 02:30 - 04:00 1.50 MOB P PRE BLOW DOWN REEL WITH N2 TO TIGER TANK. 04:00 - 04:10 0.17 MOB 1 P PRE 'POP INJECTOR OFF WELL AND STAND BACK. SUCK OUT TREE. 04:10 - 04:30 0.33 MOB P PRE PREP COIL FOR REEL SWAP. '04:30 - 07:00 2.50 MOB P PRE, CHANGE OUT BRASS AND PACKOFF. 07:00 - 08:00 1.00 MOB P - - PRE [PULL BACK COIL AND SECURE TO REEL. 08:00 - 21:20 13.33 MOB N I WAIT',, 1 PRE `PHASE 3 CONDITIONS,HALT OPERATIONS. 21:20 - 00:00 2.67 MOB N j WAIT' ` PRE PHASE 2 LEVEL 3 ON ALL ROADS AND PADS. i - CALLED IMT AT 659-5648 AND THIER I COMANDER SAID NO ONE COULD GO BACK TO WORK. I 2/15/2011 00:00 - 04:50 4.83 MOB N WAIT PRE PHASE 2 LEVEL 3 ON ALL ROADS AND PADS. I CALLED IMT AT 659-5648 AND THIER COMANDER SAID NO ONE COULD GO BACK TO WORK. '04:50 - MOB ' P f PRE 2/16/2011 00:00 - 02:00 2.00 MOB P F PRE ND BOP'S.NU TREE CAP. 02:00 - 03:00 1.00 MOB P 1 PRE PT TREE CAP,NO VISIBLE LEAKS. 'TEST BLEEDS OFF 200 PSI IN 15 MINUTES. I FAILED. CALLED GREASE CREW TO GREASE SWAB VALVE. 03:00 - 03:15 0.25 J MOB P ,....- PRE KICK WHILE TRIPPING DRILL. 03:15 - 03:45 0.50 MOB P PRE PT TREE CAP, NO VISIBLE LEAKS. TEST BLEEDS OFF 200 PSI IN 15 MINUTES. STILL FAILED. 103:45 - MOB P PRE STOP TEST TO GREASE SWAB VALVE. 2/17/2011 00:00 - 01:30 1.50 ! BOPSUR ' P PRE BOPE TEST. I i HYDRAULIC CHOKE FAILED. INSTANTLY _ _ BLED OFF PRESSURE. f 01:30 - 02:00 0.50 BOPSUR P PRE PJSM TO CHANGE OUT GOOSE NECK I _ ROLLERS AND ADJUST FOR 2-3/8"COIL. 02:00 - 03:30 I 1.50 BOPSUR P PRE CHANGED OUT GOOSE NECK ROLLERS AND ADJUSTED FOR 2-3/8"COIL. REBUILD HYDRAULIC CHOKE.C/O STEM AND SEAT. 03:30 - 05:00 1.50 1 BOPSUR P PRE TEST HYDRAULIC CHOKE PERFORM SEAT TEST. I BLED OFF 200 PSI IN 5 MINUTES DURING A G__ 3500 PSI TEST. 05:00 - 11:30 6.50 RIGU P PRE PULL CT ACROSS AND STAB. FILL CT. PERFORM SLACK MANAGEMENT(PUMPING SLACK BACK INTO NEW REEL). CUT 10'CT, REBOOT ELINE. REHEAD. PULL TEST TO 35K LB, PRESSURE TEST TO 3500 PSI. Printed 3/30/2011 11:13:01AM North America -ALASKA- BP Page 2 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/14/2011 End Date: 3/2/2011 X3-00Y24-C(1,484,621.00) X3-00YGV-C(757,473.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11:30 - 12:00 0.50 BOPSUB P PRE PT INNER REEL VALVE TO 250 PSI/3750 PSI AND CHART TESTS AS PART OF BOPE TEST. 12:00 - 18:00 6.00 RIGU P PRE MU BAKER UQC. TEST CHECKS TO 250 PSI/ 1500 PSI AND CHART-GOOD. SIMULTANEOUSLY,RESEAL EAL PUMP#2. 18:00 - 19:00 1.00 BOPSUB P PRE TEST PACKOFF. CALIBRATE BARTON CHART RECORDER. TEST PACKOFF TO 300 PSI AND 3500 PSI. CHART TEST. 19:00 - 19:15 0.25 RIGU P f PRE PJSM FOR PUMPING SLACK FOWARD. 19:15 - 20:30 1.25 RIGU P I PRE SPOT 5 BBLS METHONAL AT EOP. PUMP SLACK FOWARD AT 2.5 TO 3 BPM. PUMP 60 BBLS TOTAL. 20:30 - 21:15 0.75 BOPSUB N SFAL -- - PRE RESTRICTION ON HYDRAULIC CHOKE. PJSM.PULL APART CHOKE.PLUNGER ON STEM PULLED OFF. REPLACE STEM AND PLUNGER. 21:15 - 22:00 i 0.75 BOPSUB N SFAL PRE I PJSM,PERFOM BODY TEST ON HYDRAULIC CHOKE TO 250 PSI AND 3500 PSI.CHARTED. PERFORM SEAT TEST.BLED OFF I i - - I INSTANTLY.FAILED TEST. 22:00 - 00:00 2.00 BOPSUB N f SFAL PRE WORK ON HYDRAULIC CHOKE. 2/18/2011 i 00:00 - 01:30 1.50 BOPSUB N SFAL PRE REPAIR HYDRAULIC CHOKE. PJSM,TEST HYDRAULIC CHOKE BODY TO 250 PSI AND 3500 PSI,CHARTED, GOOD TEST. • PERFORM CHOKE SEAT TEST TO 2500 PSI, BLED OFF 100PSI IN 5 MINUTES,CHARTED 01:30 - 02:00 0.50 BOPSUR P PRE PJSM WITH NORDIC,SLB AND VALVE CREW. REVIEW LIFTING AND INSPECTION CERTS. REVIEW BOP SCHEMATIC,REVIEW UPDATED AND APPROVED PROCEEDURES FOR !PULLING BPV. SETTING TREE TEST PLUG AND PRESSURE TESTING TTP AND TREE FLANGE. 02:00 - 02:20 0.33 BOPSUR P PRE H2S RIG EVACUATION DRILL, MUSTER TO SAFE AREA AT SATTELITE OFFICE. GOOD RESPONSE BY ALL.ALL THIRD PARTY CONTRACTORS RESPONDED WELL. SIMOPS WERE BEING CONDUCTED,ALL WERE NOTIFIED AT THE TIME OF THE DRILL. AFTER ACTION REVIEW WAS HELD. 02:20 - 03:30 1.17 ' BOPSUR P PRE R/U LUBRICATOR, 03:30 - 05:00 1.50 BOPSUR P PRE SET PUMP 1 TRIP LIMIT TO 1500 PSI, PRESSURE TEST LUBRICATOR AGAINST CLOSED MASTER VALVE TO 250 PSI AND 3500 PSI,CHARTED FOR 5 MIN.OPEN MASTER VALVE AND PUMP AT.4 BPM, UP TO 250 PSI STABILIZED. OBSERVED NO LEAKS AT WELLHEAD. PUMP 1 BBL TOTAL,VERIFY 250 PSI UNDER BPV. INSTALL FUSEABLE CAP ON SSV. BLEED OFF 250 PSI WHP THROUGH CHOKE. I !PULL BPV. L/D BPV. M/U TREE TEST PLUG.TEST LUBRICATOR AGAINST MASTER VALVE TO 250 PSI AND 13500 PSI. CHART TEST. Printed 3/30/2011 11:13:01AM North America -ALASKA- BP Page 3 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 2/14/2011 End Date: 3/2/2011 X3-00Y24-C(1,484,621.00) X3-00YGV-C(757,473.00) Project: Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor: NORDIC CALISTA 'UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:00 - 09:00 4.00 BOPSUR P PRE SET TTP. TEST TREE AGAINST TTP TO 250 PSI LOW/3500 PSI HIGH. BOTH PASSED. NOTE: TTP DOES NOT HOLD PRESSURE FROM BELOW-WHP OF 250 PSI IS NOT ISOLATED BY TTP. CLOSE MASTER,BLEED DOWN LUBRICATOR (GAS)FROM 250 PSI TO ZERO,CLOSE SSV. UNSTAB, MU PULLING TOOL W/2 SHEAR PINS, STAB ON. TEST LUBRICATOR AGAINST MASTER VALVE AND OPEN TO WELL. LAND PULLING TOOL AND ATTEMPT TO PULL PLUG PULLING TOOL CAME BACK SHEARED(DID NOT GET PLUG). CALL TOWN TO DISCUSS. MASTER AND SSV ARE CLOSED,VALVE SHOP LUBRICATOR IS RIGGED UP. T 09:00 - 20:30 11.50 BOPSUR N WAIT ; PRE WAIT ON ORDERS FROM TOWN REGARDING PLAN FORWARD FOR PULLING TTP. REVIEW SITUATION WITH CREW AND DISCUSS CONTINGENCIES. 20:30 - 21:00 0.50 BOPSUR N SFAL PRE PJSM TO RIG DOWN MOVE OFF 18-04C AND PULL OUT OF THE WAY FOR SLICK LINE TO FISH THE TREE TEST PLUG OUT OF THE TUBING HANGER. 21:00 - 00:00 3.00 BOPSUR N SFAL PRE SET INJECTOR ON ITS LEGS FOR RIG MOVE. CALLED GREASE CREW TO GREASE SWAB VALVE AND MASTER VALVE. OFF LOADED XS 2%KCL WITH 0.6%CFS-520 ONTO VAC TRUCK AND SENT BOTH FULL ;VAC TRUCKS TO PAD 3 FOR DISPOSAL. 'CALLED THE SERVICE COIL BULL PEN AND I NO ONE IN SERVICE COIL COULD USE IT IN THE NEXT WEEK.THE MUD PLANT ONLY HAD ROOM FOR THE TWO FULL TRUCKS OF N-VIS SENT BACK TONIGHT. ! ;TALKED WITH NORDIC TOURPUSHER AND SLB SUPERVISOR ABOUT MOVING THE RIG WITH THE COIL FULL OF FLUID. OFF LOADED THE FRESH WATER AND SENT IT FOR DISPOSAL.DID NOT TAKE ON DIESEL TODAY, 110 LIGHTENING THE LOAD. 2/19/2011 00:00 01:30 1.50 BOPSUR N SFAL PRE TEST SV AND SSV WITH NEAT METHANOL TO 250 LOW AND 3500 PSI HIGH FOR 5 MINUTES EACH.CHARTED AND SIGNED BY DRILLER AND WSL,PLACED IN WELL FILE. 01:30 - 02:00 0.50 BOPSUR N SFAL PRE PUMP ALL FLUID OUT OF BOPE STACK. 02:00 - 04:15 2.25BOPSUR N SFAL PRE RIG DOWN THE BOPE. FILL TREE WITH NEAT METHANOL. NU THE TREE CAP. RIG HYDRAULIC SYSTEM WARMING UP. 04:15 - 05:00 0.75 BOPSUR N SFAL PRE PT TREE CAP WITH NEAT METHANOL TO 250 LOW AND 3500 PSI HIGH FOR 5 MIN. CHARTED AND SIGNED BY DRILLER AND WSL,PLACED IN WELL FILE.RIG RELEASE 1AT05:00AM. Printed 3/30/2011 11:13:01AM North America -ALASKA- BP Page 4 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 2/14/2011 End Date: 3/2/2011 X3-00Y24-C(1,484,621.00) X3-00YGV-C 757 473.00) Project:Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) 4 — -- — (ft) 05:00 - 05:30 0.50 I BOPSUR N SFAL PRE PJSM WITH DS 18 PAD OPERATOR, NORDIC SUPERINTENDENT, BP SUPERINTENDENT, TWO WSL'S,SLB AND NORDIC 1 CREW. READ THROUGH THE BP PLAN FORWARD AND COVERED EVERY POINT. READ THROUGH NORDICS PROCEDURE AND MADE SURE EVERYONE KNEW WHAT WE WERE DOING AND WHY.WE IDENTIFIED HAZARDS AND ASSIGNED SPECIFIC DUTIES.ONE HAND WILL HOLD THE RIG WHEEL CHOCKS AND BE READY TO THROW IN FRONT OF THE RIG WHEEL AS A POSITIVE STOP.THE PAD OPERATOR WAS TOLD THAT ALL VALVES ARE CLOSED AND ASKED IF WHERE WE PLANNED TO PUT THE RIG WAS GOOD WITH HIM.ALL PERSONNEL INVOLVED WITH THE POSITIONING OF THE RIG WILL CARRY HAND HELD RADIOS AND PERFORM RADIO CHECKS. IF LINE OF SIGHT OR RADIO CONTACT IS LOST OR BROKEN THEN THE RIG WILL STOP.THE REASON FOR STOPPAGE WILL BE INVESTIGATED BEFORE RESUMING RIG MOVEMENT.THE RIG WILL ONLY BE MOVED IN LOW SPEED RANGE.AN AAR WILL BE HELD AFTERWARD. 05:30 - 06:00 0.50 BOPSUR N SFAL PRE PULL RIG OFF WELL AND PARK ON EDGE OF PAD OUT OF THE WAY. 06:00 - 09:00 3.00 BOPSUR N SFAL PRE MET WITH PAD OPERATOR,CONDUCTED A PAD INSPECTION AND CLOSED OUT THE WELL WORK TRANSFER PERMIT.ALSO TOLD HIM THAT THE LOTO WAS TAKEN OFF OF 18-15 AND WE NO LONGER NEEDED IT SHUT IN. 09:00 - 17:30 8.50 ' BOPSUR N SFAL PRE WAIT ON SLICKLINE TO FISH THE TREE TEST I PLUG IN THF TURINC4 HANC;FR KII I THF 1 WFLL AND SET A TUBING TAIL PLUG IN THE 4 SUB SURFACE SAFETY VALVE PROFILE AT 2185' 17:30 - 18:00 0.50 BOPSUR N SFAL PRE CONDUCTED AN AAR WITH THE CREW FOR PULLING THE RIG OFF THE WELL AFTER THE ,PTM.THE DAY SPOC POINTED OUT THAT ITHE SPOTTERS SHOULD HAVE BEEN WEARING REFLECTIVE VESTS.THE FLOOR HAND POINTED OUT THAT WITH ALL THE EXTRA SUPERVISION THAT THE HANDS WERE ASSIGNED TO DIFFERENT POSITIONS AROUND THE RIG THAN THEY ARE USED TO. THERE WAS ALSO SOME CONCERN ABOUT GETTING IN A HURRY SINCE THE RIG MOVE HAPPENED DURING THE NORMAL CHANGE OUT TIME, BUT NO ONE FELT RUSHED AND DID NOT MIND WORKING OVER A LITTLE TO LFINISH THE MOVE. 18:00 - 21:00 3.00 BOPSUR N SFAL PRE CHANGE AND WALK AROUND CHECKING I OUR AREAS.TALKED WITH THE SLICK LINE CREW ON 18-04 AND LET THEM KNOW WHAT WE DID BEFORE THEY GOT HERE AND ASKED THEM TO CALL IT THEY NEED ANYTHING, LIKE A HEATER OR NEAT METHANOL. Printed 3/30/2011 11:13:01AM North America -ALASKA- BP Page 5 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 2/14/2011 End Date: 3/2/2011 X3-00Y24-C(1,484,621.00) X3-00YGV-C(757,473.00) Project: Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43©56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 21:00 - 00:00 3.00 BOPSUR N SFAL PRE CALLED GCI TO GET COMMUNICATION HOOKED BACK UP TO THE RIG. WAIT ON SLICKLINE TO FISH THE TREE TEST PLUG IN THE TUBING HANGER.KILL THE WELL AND SET A TUBING TAIL PLUG IN THE SUB SURFACE SAFETY VALVE PROFILE AT 2185'. 2/20/2011 00:00 - 05:00 5.00 BOPSUR N SFAL PRE WAIT ON SLICKLINE TO FISH THE TREE TEST PLUG IN THE TUBING HANGER. KILL THE WELL WITH 8.4 PPG KCL AND SET A 4 1/2" TUBING TAIL PLUG IN THE X NIPPLE AT 9575'. PRESSURE TEST TO 250 PSI AND 3500 PSI FOR 30 MINUTES. 05:00 - 22:00 17.00 BOPSUR N SFAL PRE SLICKLINE RECOVERED TREE TEST PLUG. KILL WELL WITH 8.4 PPG KCL. SECURE WELL WITH TUBING TAIL PLUG IN X • NIPPLE AT 9575'. PERFORM MIT ON TUBING TAIL PLUG FOR 30 MINUTES AT 3500 PSI. SLICKLINE RDMO. 22:00 - 00:00 2.00 BOPSUR N SFAL PRE WELLS GROUP IS OFF WELL 18-04.CALLED DSM TO COME REMOVE WORK PLATFORM. 2/21/2011 00:00 - 02:30 2.50 BOPSUR N SFAL PRE WELLS GROUP IS OFF WELL 18-04.CALLED DSM TO COME REMOVE WORK PLATFORM. CONDUCTED A PAD INSPECTION WITH PAD 'OPERATOR.A NEW WELL WORK TRANSFER • !PERMIT WAS FILLED OUT. DISCUSSED THE PRIMARY SAFE AREA AND THE SECONDARY SAFE AREA INCASE OF AN INCIDENT.ALSO DISCUSSED SIMOPS AND THE 5 MPH SPEED LIMIT AROUND THE RIG. .G 02:30 - 03:00 0.50 BOPSUR N SFAL PRE PJSM TO MOVE RIG OVER 18-04C. CONTENTS OF DISCUSSION I-ENSURE THAT ALL TREE VALVES ARE CLOSED AND PRESSURE HAS BEEN BLED OFF. -REVIEWED NORDIC'S RIG MOVE PROCEDURE. I-DISCUSSED NORDIC'S PREMOVE CHECKLIST. -THE RIG HYD SYSTEM WAS PROPERLY :WARMED UP. I-EVERYONE WAS WEARING THE PROPER PPE. IDENTIFIED THE HAZARDS. I-EVERYONE HAD A RADIO AND RADIO ICHECKS WERE PERFORMED. 1-NORDIC SUPERINTENDENT IN CELLAR MAINTAINS LINE OF SIGHT OR RADIO CONTACT. -IF LINE OF SIGHT OR RADIO CONTACT IS BROKEN THE RIG WILL STOP. -ALL RIG MOVEMENT WILL BE PERFORMED IN LOW RANGE. • -ONE SPOTTER WILL CARRY THE WHEEL CHOCKS AND BE READY TO USE THEM. 03:00 - 04:00 1.00 BOPSUR N SFAL PRE RIG MOVE. RIG ACCEPT AT 04:00. 04:00 05:00 1.00 BOPSUR N SFAL PRE SPOT CUTTINGS BOX.PULL TREE CAP. HARDLINE CREW RECONNECT TIGER TANK AND PT TO 4000PSI. Printed 3/30/2011 11:13:01AM North America-ALASKA- BP Page 6 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:2/14/2011 End Date: 3/2/2011 X3-00Y24-C(1,484,621.00) X3-00YGV-C(757,473.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.:NORDIC 1 Spud Date/Time: 12/25/1982 12:00:OOAM ,Rig Release:3/2/2011 Rig Contractor.NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 05:00 - 05:30 0.50 BOPSUR N SFAL PRE PJSM. NU BOPE. 05:30 - 22:30 17.00 BOPSUR N SFAL PRE BOPE TEST. WITNESS WAIVED BY J.CRISP W/AOGCC. FIGHTING TO GET TEST ON SWAB VALVE. GREASE TREE.GREASE CHOKE MANIFOLD. 22:30 - 00:00 1.50 BOPSUR N SFAL PRE STAND BY PHASE 2 WEATHER COULD BE PHASE 3 ANY MINUTE.ELECT TO WAIT TO • RU SLICKLINE. 2/22/2011 00:00 - 03:00 3.00 BOPSUR N SFAL PRE :STAND BY PHASE 2 WEATHER COULD BE PHASE 3 ANY MINUTE. ELECT TO WAIT TO RU SLICKLINE. 03:00 - 03:30 0.50 BOPSUR N SFAL PRE BACK TO PHASE 1 LEVEL 2 ON ACCESS ROADS AND PADS. CALL FOR SLICKLINE. 03:30 - 05:00 1.50 i BOPSUR N SFAL PRE FILL PITS WITH 290 BBLS OF XS 2%KCL WITH 0.6%CFS-520. EXTRA TRUCK ON LOCATION WITH 210 BBLS XS 2%KCL WITH 0.6%CFS-520 05:00 10:00 5.00 RIGU N SFAL FOR BULLHEAD KILL. _ - PRE PT TREE AGAINST MASTER TO 250 PSI LOW/ 3500 PSI HIGH FOR 5 MINUTES EACH W/KCL -PASS. PT TREE AGAINST TTP TO 250 PSI LOW/ 3500 PSI HIGH FOR 5 MINUTES EACH W/KCL -PASS. ( STAGE SLICKLINE,CONFIRM WEIGHTS OF THEIR EQUIPMENT,AGREE ON LIFTING PLAN. -. CONFIRM CERTIFICATION OF THEIR PCE. CONFIRM LENGTHS/ODS OF THEIR TOOLSTRING, CONFIRM THEIR PULLING SELECTION. PJSM WI ENTIRE CREW FOR RU AND RIH W/ SLICKLINE. RECOGNIZE PINCH POINTS OF WIRE AT DRUM AND SHEAVES, ACKNOWLEDGE THE POTENTIAL FOR THE WIRE TO PART,CONSIDER THE POTENTIAL FOR DROPPED OBJECTS WHILE UNSTABBING W/FISH,CROWNING OUT W/ THEIR TOOLS IF WE COME DOWN ON TUGGER,DROPPING EQUIPMENT WHILE LOADING ONTO RIG FLOOR, ETC. REVIEW NORDIC AND WELLS GROUP PROCEDURES _ FOR RU AND RUNNING SLICKLINE. 10:00 - 11:45 1.75 RIGU N SFAL r— PRE RU SLICKLINE(30'LUBRICATOR,WIRELINE RAMS,PUMP-IN SUB). 11:45 - 18:00 6.25 RIGU N SFAL PRE RIH W/SLICKLINE W/SHROUDED JDC TO PULL PRONG. (DETAILS OF SLICKLINE WORK MAY BE FOUND IN THEIR AWGRS REPORT). PULL AND RECOVER PRONG. RIH W/SLICKLINE W/GS TO PULL AND RECOVER PLUG. PULLED PLUG ON FIRST ATTEMPT. POH WITH PLUG. 18:00 - 19:00 1.00 RIGU N SFAL PRE 1PJSM ON RD SLICKLINE UNIT. RD UNIT. NOTE-SI WHP IS ZERO PSI. {19:00 - 20:00 1.00 RIGU P PRE PRE-SPUD MEETING WITH NEW CREW COMING ONTO HITCH,DISCUSS HIGH GOR SOP UPDATE. PJSM ON WELL KILL OPERATIONS. Printed 3/30/2011 11:13:01AM North America -ALASKA- BP Page 7 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 2/14/2011 End Date: 3/2/2011 !X3-00Y24-C(1,484,621.00) •X3-00YGV-C(757,473.00) Project:Prudhoe Bay Site: PB DS 18 I Rig Name/No.: NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor: NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code l NPT NPT Depth Phase Description of Operations (hr) (ft) 20:00 - 22:00 2.00 KILLW P WEXIT CONDUCT WALKAROUNDS TO INSPECT FLOW LINE TO TIGER TANK, INSPECT CELLAR,CHECK VALVE FUNCTIONS. RECORD FLUID VOLUMES ON LOCATION. BEGIN WELL KILL OPERATIONS. -PUMP 5 BBL METHANOL SPEAR FOLLOWED BY 8.4 PPG KCL i -CATCH FLUID AT 15 BBLS, INCREASE RATE TO 4.5 BPM AT 1480 PSI, ZERO COUNTERS -BEGIN WELL KILL AT 4.5 BPM; PRESSURE INCREASE TO 1605 PSI AT 100 BBLS AWAY -PRESSURE REDUCED TO 1420 PSI AT END ' OF PUMPING 252 BBLS AWAY(1.5 TIMES ' VOLUME CALCULATED AT 240 BBLS) 22:00 - 22:40 0.67 KILLW P WEXIT FLOW CHECK WELL FOR 30 MINUTES; STATIC. COME ON WITH PUMPS, CALCULATE 9 BPH LOSS RATE. 22:40 - 23:30 0.83 WHIP P WEXIT PJSM ON MU OF WHIPSTOCK BHA TO COILTRACK. MU 3.70"WHIPSTOCK BHA: -WHIPSTOCK PACKER,KB WHIPSTOCK TRAY,WIRELINE ADAPTER KIT,#10 J • HYDRAULIC SEAT,CROSSOVERS, HOT, DGS, DPS, EDC. POWERCOMMS,SUB WEAR PROTECTOR, LQC, UQC,XO, CTC -CONFIRM HIGHSIDE ORIENTATION OF WHIPSTOCK TO COILTRACK MWD 23:30 - 00:00 0.50 WHIP P ' WEXIT MU INJECTOR TO LUBRICATOR. RIH WITH „ WHIPSTOCK BHA ON COIL AT.45 BPM WITH 4_ _-_.. EDC OPEN. 2/23/2011 00:00 - 02 15 2.25 WHIP P _I I , WEXIT RIH WITH 3.70"WHIPSTOCK BHA AT.45 BPM 1 WITH OPEN EDC: -WHIPSTOCK PACKER,KB WHIPSTOCK ,TRAY,WIRELINE ADAPTER KIT,#10 J HYDRAULIC SEAT,CROSSOVERS, HOT, DGS, DPS, EDC.POWERCOMMS,SUB WEAR PROTECTOR, LOC, UQC,XO, CTC ' NO ISSUES WITH PREVIOUSLY NOTED TIGHT SPOTS FROM SLB DRIFT RUNS 02:15 - 03:15 1.00 WHIP P WEXIT CONDUCT TIE-IN LOG AT 9870'TO 10,100';-15' CORRECTION. CONDUCT CCL LOG ACROSS WHIPSTOCK SETTING AREA. -AVERAGE 24 BPH LOSSES WHILE RIH, LOGGING 03:15 - 03:40 0.42 • WHIP P WEXIT CONFIRM TOOL FACE ORIENTATION TO 30 DEG LEFT OF HIGH SIDF PnSITION . WHIPSTOCK TOP AT 9980'MD. CLOSE EDC, • , PRESSURE UP TO SET WHIPSTOCK. • I POSITIVE INDICATION OF SET AT 1960 PSI. SET DOWN 5K TO CONFIRM SET. PU OFF OF WHIPSTOCK. CONFIRM ONE-FOR-ONE RETURNS. 03:40 - 04:20 0.67 WHIP P • WEXIT CONDUCT ANNULAR ISOLATION TEST. PRESSURE TEST TO 250 PSI LOW FOR 5 • MINUTES AND 2400 PSI HIGH ON CHART FOR 10 MINUTES. GOOD TEST. 04:20 08:00 3.67 WHIP P r WEXIT FLOW CHECK WELL. STATIC. DISPLACE 8.4 __ ;PPG KCL TO 8.6 PPG QUICKDRILL MUD. 08:00 - 09:40 1.67 WHIP P WEXIT (WELL SWAPPED TO MUD. RETURNS STILL ' '1:1. POOH W/SETTING ASSEMBLY. Printed 3/30/2011 11:13:01AM North America -ALASKA- BP Page 8 of 19 Operation Summary Report Common Well Name: 18-044 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 2/14/2011 I End Date: 3/2/2011 IX3-00Y24-C(1,484,621 00) 'X3-00YGV-C(757,473.00) Project:Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM 'Rig Release: 3/2/2011 Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43©56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 09:40 - 12:30 2.83 STWHIP P WEXIT AT SURFACE. FLOWCHECK-GOOD. UNSTAB,LD WS SETTING ASSEMBLY. TOOL APPEARS TO HAVE FUNCTIONED PROPERLY. MU WINDOW MILLING ASSEMBLY: UQC, LQC, WEAR SUB, P&C, EDC,DPS, DGS, BLIND,XO, XO,2 JTS 2-3/8"PH6,XO,2-7/8"XTREME MOTOR(STRAIGHT), HCC DIAMOND STRING REAMER(3.80"GO,3.79"NO-GO)AND HCC DIAMOND WINDOW MILL(3.80"GO,3.79" NO-GO). 12:30 - 14:30 2.00 STWHIP P WEXIT RIH WLW_VINDOW MILLING ASSEMBLY. pID NOT SEE XN AS RIH. 14:30 - 15:45 1.25 STWHIP P WEXIT LOG TIE-IN, CORRECTION OF(-12') DRY TAG WHIPSTOCK(PINCH POINT SAME --- AS TOWS)AT 9983'MD. 15:45 - 17:10 1.42 STWHIP P WEXIT UP WEIGHT 38800 LB. RIH WEIGHT 16800 LB. FREESPIN 2850 PSI AT 2.80 BPM. BEGIN MILLING WINDOW. ENGAGE AT 9982.8'MD. 16:10-TIME MILLING AT 9983.2'MD W/600 LB DHWOB AND 2950 PSI AT 2.80 BPM. 16:20-TIME MILLING AT 9983.3'MD W/750 LB DHWOB AND 2950 PSI(100 PSI MOTOR WORK)AT 2.80 BPM. BHP/ECD/PVT:4205 PSV 9.76 PPG/342 BBLS. RETURNS 1:1. IAP:200 PSI. OAP:300 PSI. MILL AHEAD TO 9984.5' MD. 17:10 - 19:00 1.83 ! STWHIP I P WEXIT IMMINENT PHASE III CONDITIONS. TRAVEL PERMITTED BY CONVOY ONLY WITH SUPERVISOR PERMISSION. DECISION IS TO 1 POH WITH MILLING ASSEMBLY TO SECURE WELL AND GET NON-RIG PERSONNEL BACK TO THEIR CAMPS SAFELY. -POH WITH MILLING BHA -CONDUCT KICK WHILE TRIPPING DRILL WHILE POH 19:00 - 20:00 1.00 STWHIP P WEXIT PJSM ON LD MILLING BHA 1-LD BHA;MILL GAUGED AT 3.80"GO AND 3.79"NO-GO 1-FILL HOLE. FLOW CHECK,WELL STATIC INSTALL NIGHTCAP,CLOSE VALVES TO SECURE WELL 20:00 - 00:00 4.00 STWHIP N WAIT WEXIT WAIT ON WEATHER -WINDS STEADY AT 36-40 MPH, GUSTING TO 50+MPH -CALLS TO SECURITY DEFERRED TO HEAVY EQUIPMENT OPERATIONS MANAGER(WHO MAKES DECISION ON PHASE LEVELS); CONSIDERED"HEAVY PHASE II" I-OFFICIAL PHASE CONDITIONS PHASE II, I LEVEL II ON ACCESS ROADS AND PADS -HEAVY EQUIPMENT IS MOVING;ALL OTHER TRUCKS ARE TRAVELING IN CONVOY ONLY IF REALLY NEEDED Printed 3/30/2011 11:13:01AM , North America -ALASKA- BP Page 9 of 19 • Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 2/14/2011 End Date: 3/2/2011 IX3-00Y24-C(1,484,621.00) 'X3-00YGV-C(757,473.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor: NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs 1 Task Code NPT NPT Depth Phase Description of Operations I (hr) (ft) 2/24/2011 00:00 - 02:30 2.50 STWHIP N WAIT WEXIT WAIT ON WEATHER. FIELD IS IN PHASE II CONDITIONS WITH TRAVEL BY CONVOY UNDER SUPERVISOR APPROVAL ONLY. WEATHER CONDITIONS SEEM TO IMPROVE. VISIBILITY NOW OVER 3 MILES,WIND DOWN TO 20 MPH. CALL SECURITY FOR PHASE STATUS. PHASE II WITH IMPROVING CONDITIONS AND NO EXPECTATION TO GO TO PHASE III. CALL CH2MHILL TO SEE IF ' TRUCKING AVAILABLE IF NEEDED. TRUCKING AVAILABLE,NO RESTRICTION ' 1EXCEPT CONVOY. '02:30 - 03:30 1.00 STWHIP P 1 WEXIT PJSM ON MU MILLING BHA. OPEN UP WELL, MONITOR. STATIC, NO FLUID DROP IN HOLE. 1 I MU BHA: UQC, LOC,WEAR SUB, P&C, EDC, DPS, DGS, BLIND,XO,XO,2 JTS 2-3/8"PH6, XO,2-7/8"XTREME MOTOR(STRAIGHT), HCC DIAMOND STRING REAMER(3.80"GO,3.79" NO-GO)AND HCC DIAMOND WINDOW MILL (3.80"GO,3.79"NO-GO). MU TO COILTRACK,STAB ONTO INJECTOR eill'i 03:30 - 06:45 3.25 STWHIP P ! WEXIT RIH WITH MILLING BHA. SLOWLY RUN 1 THROUGH XN LOCATED AT 9595'. NO IISSUES. OBTAIN PU WEIGHT OF 35K. I , CONDUCT TIE-IN AT 9915'. ESTABLISH FREESPIN 2.8 BPM AT 2840 PSI. TIME MILL INTO WINDOW. 06:45 - 10:00 3.25 STWHIP P WEXIT I ENGAGE AT 9985.2'MD(WE LEFT BOTTOM !AT 9984.5'MD). MILL WINDOW. ' 108:00-MILLING AT 9986.2'MD AT 2.8 BPM AT 3050 PSI W/2550 LB DHWOB. 09:00-MILLING AT 9987.1'MD AT 2.8 BPM AT 3070 PSI W/2620 LB DHWOB. 10:00-MILLING AT 9988.4'MD AT 2.8 BPM AT Wildliiii , 2970 PSI W/1360 LB DHWOB. ) 'NO STALLS DURING MILLING OPERATIONS. W 10:00 - 15:30 5.50 STWHIP P WEXIT 11:00-MILLING AT 9989.8'MD AT 2.8 BPM AT 2955 PSI W/2110 LB DHWOB. RETURNS i7.61{-61{C. STILL 1:1. BHP/PVT/ECD: 4201 PSI/342 BBL/ 19.75 PPG. IAP:300 PSI. OAP: 800 PSI. BLEED OAP FROM 800 PSI TO ZERO PSI IN 5 IMINUTES,ALL LIQUID. 112:00-BELIEVE MILL HAS EXITED AT 9990.9' • MD. IAP: 300 PSI. OAP: 50 PSI. WOB FALLING READILY W/EACH BITE. HOLD 'ROP TO LESS THAN 2 FPH FOR FIRST 2', THEN INCREASE ROP AS DICTATED BY 1 WEIGHT&MOTOR WORK. AFTER—2'OUT OF CASING, BEGIN LOSING RETURNS AT—25 BPH WHILE PUMPING AT 2.8 BPM(ECD 9.76 PPG). MILL AHEAD TO 10001'MD. RETURN SAMPLE W/90%FORMATION FROM 10000' IMO. PERFORM 3 RECIPROCATIONS AT 1'/MIN. FIRST RECIPROCATION SAW SMALL WEIGHT BOBBLE AS ENTER WINDOW ON BACKREAMING PASS. REMAINING PASSES (CLEAN. DRY DRIFT WINDOW,CLEAN. DID NOT HAVE ANY STALLS DURING MILLING . OPERATIONS. Printed 3/30/2011 11:13:01AM North America-ALASKA- BP Page 10 of 19 Operation Summary Report Common Well Name: 18-04 I AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/14/2011 I End Date: 3/2/2011 X3-00Y24-C(1,484,621.00) X3-00YGV-C(757,473.00) Project:Prudhoe Bay Site: PB DS 18 Rig Name/No.:NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs ! Task 1 Code NPT NPT Depth Phase Description of Operations (hr) ,i (ft) 15:30 - 18:15 2.75 ' STWHIP P WEXIT 'BEGIN PULL OOH. WHEN PU OFF BOTTOM, WE HAD LOST A TOTAL OF-50 BBLS AT A RATE OF 25 BPH. WE DID NOT SEE XN AS POOH. 16:15-POOH AT 5700'MD AT 3.19 BPM AT 2850 PSI. RETURNS BACK TO NEARLY 1:1. 18:15 - 18:30 0.25 STWHIP P 1 WEXIT POP OFF INJECTOR. LD MILLING BHA. MILL r AND STRING REAMER BOTH IN GAUGE WITH 3.80"GO AND 3.79"NO-GO. INSPECTED TREE,ALL BOLTS TIGHT. 18:30 - 18:45 0.25 DRILL P I PROD1 MU 2 3/8"DRILLING BHA:3.75"BI-CENTER BIT,2 7/8"BHI EXTREME MOTOR WITf-I 3.4 DEGREE BEND, HOT, DGS, DPS SUB, EDC, POWERCOMMS,WEAR PROTECTION SUB, LQC, UQC,XO, CTC. 18:45 - 22:00 3.25 DRILL P PROD1 RIH WITH 2 3/8"DRILLING BHA. AVERAGING 6 BPH LOSSES WHILE RIH. CONDUCT TIE-IN ' AT 9870'. -7.5'CORRECTION. DID NOT HAVE I ISSUES PASSING THROUGH JEWELRY. 22:00 - 22:40 0.67 DRILL P ' PROD1 SLOWLY EXIT WINDOW WITH NO PROBLEMS. j STAGE UP PUMPS TO 2.6 BPM,3050 PSI FREE SPIN. LOST 18 BBLS IN INITIAL 20 • MINUTES FROM 10,000'-19,009'. 22:40 - 23:10 0.50 DRILL P . PROD1 SLACK OFF PUMPS TO PULL INTO WINDOW I AND RE-ORIENT MWD EQUIPMENT. PULL UP HOLE AT 1.5 BPM,1980 PSI WHILE TUN ! I T HE RIGHT)NO FOURTHER RIENT LOSSOES AT H SO IPOINT. RUN BACK IN HOLE WITH TOOL WORKING. 123:10 - 00:00 0.83 I DRILL P 1 PROD1 'DRILL AHEAD IN BUILD SECTION WITH 2870, 1 PSI FREE SPIN AT 2.5 BPM. 1-2.42 BPM IN,2.12 BPM OUT,2870-2950 PSI, MW IN 8.53 PPG,MW OUT 8.59 PPG,9.7 PPG j I ECD,WOB.3-2.4 K • j• ;-AVERAGE 24 BPH LOSSES FROM 10,009'TO 110,023' • I----- -' -r 2/25/2011 i 00:00 - 01:55 1.92 DRILL j P PROD1 !DRILL AHEAD IN BUILD SECTION WITH 2870 'PSI FREE SPIN AT 2.47 BPM FROM 10,023'TO 10,130' I-2.43-2.49 BPM IN,1.94-2.30 BPM OUT, '3000-3190 PSI, MW IN 8.53 PPG, MW OUT 8.59 !PPG,9.7 PPG ECD,WOB.3-2.4 K j PHASE II CALLED AT 0115 DUE TO HIGH , 1WIND AND LOSS OF VISIBILITY;460 BBLS j FLUID ON LOCATION IN PITS AND ON TRUCK -AVERAGE 20 BPH LOSSES FR DA- +023'TO .-SIGNIFICANT LOSS OF RETURNS AT 10,0127'TO 10,130', FROM 2.30 BPM TO 1.1 j BPM; LOST 10 BBLS FROM 10,127'TO 10,130' -MET CRITERIA FOR BUILD SECTION,WIPER TRIP TO WINDOW L.otf L'tic. Printed 3/30/2011 11:13:01AM North America -ALASKA- BP Page 11 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 2/14/2011 End Date: 3/2/2011 X3-00Y24-C(1,484,621.00) X3-00YGV-C(757,473.00) Project: Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor:NORDIC CALISTA UWI:500292087500 u 9 _... eae- Active Datum:9:04 7/29/1998 10:43 @56 OOft(above Mean Sea Level) L Date From-To Hrs Task I NPT NPT Depth Phase Description of Operations / d (hr) — (ft) Ij-ps 7-- P PROD1 WIPER TO WINDOW AT 2.5 BPM IN,.2 TO.5 01:55 03:30 1.58 DRILL � BPM OUT. PULL INTO WINDOW AT MIN PUMP RATE WITH NO TROUBLES. BRING PUMPS 0 BACK UP TO 2.4 BPM IN,.1 TO.2 BPM OUT. -CALL TOWN ENGINEER TO DISCUSS LOSSES AND PLAN FORWARD. PLAN IS TO POH FOR BHA CHANGE MONITORING FLUIDS CAREFULLY. i -ATTEMPT TO OPEN EDC,CANNOT OPEN. TAKE ON FLUIDS WHILE RECIPROCATING 50' IN CASED HOLE AND PUMPING ACROSS THE TOP TO KEEP HOLE FULL. LOSING 4 BPH WHILE TAKING ON FLUID. -LOSSES CALCULATED AT 55 BPH DURING WIPER TRIP. GOT VAC TRUCK OFF ' LOCATION WITH ESCORT. 03:30 06:00 2.50 DRILL P PROD1 FLOW CHECK,NO PRESSURES AT j WELLHEAD. PUMP DOWN COIL AND THEN SHUT DOWN TO SEE IF EDC WILL EQUALIZE. ABLE TO OPEN EDC. I -BRING ON PUMPS WHILE POH. LOSING FLUID AT 24 BPH ON TRIP OUT INITIALLY, DROPPED TO 18 BPH LOSS RATE. RETURNS I BRINGING BACK GOOD AMOUNTS OF SAND. -NOTIFIED THAT KUPARAK WENT TO PHASE III. 540 BBLS FLUID ARRIVED FROM BAROID BHA AT SURFACE. JOG DOWN,PICK BACK ( UP. LD BHA. -FIELD AT PHASE III 06:00 12:00 6.00 DRILL --f:N WAIT PROD1 PREPARE TO STOP OPERATIONS,FREEZE PROTECT COIL WITH METHANOL. CONDUCT FLOW CHECK. AVERAGE 9 BPH LOSSES. FILLING ACROSS TOP AT.54 BPM WITH i RETURNS OF.39 BPM. PIT VOLUME 284 l BBLS,540 BBLS ON TRUCKS. FUEL,BOILER L — ' WATER GOOD. 12:00 - 00:00 12.00 DRILL N WAIT PROD1 CREW ON STANDDOWN. CONDCUT TABLE TOP DRILLS WHILE WOW. FILL ACROSS F _ _ ,TOP,AVERAGING 2 BPH LOSSES. 2/26/2011 00:00 - 10:00 10.00 DRILL N I WAIT PROD1 'WAITING ON WEATHER AND CREWS TO CLEAR ACCESS TO PAD IN CASE OF AN EMERGENCY. FILLING HOLE ACROSS THE TOP. AVERAGING 1.5 TO 2 BPH LOSSES. RECEIVED PERMISSION FROM IMT TO ALLOW LOADER TO CLEAR AREA IMMEDIATELY AROUND RIG AND TO CLEAR PATH TO CAMP. 10:00 17:00 7.00 DRILL N WAIT PROD1 FIELD GOES TO PHASE 2 LEVEL 3. RIG CREW WORKING TO DIG OUT EQUIPMENT. CONTINUE FILLING HOLE ACROSS THE TOP, I I LOSSES CONTINUE TO BE BETWEEN 1.5 BPH AND 2 BPH. PVT TOTAL AT 14:30-236 BBL. I IAP: 110 PSI, OAP: 10 PSI. CREW DIGGING ! OUT VAC TRUCKS. PHASE 1 DECLARED AT 1630 HRS. 17:00 - 17:30 0.50 EVAL P PROD1 FUNCTION TEST BOP I Printed 3/30/2011 11:13:01AM North America -ALASKA- BP Page 12 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/14/2011 End Date: 3/2/2011 X3-00Y24-C(1,484,621.00) X3-00YGV-C(757,473.00) -I Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release:3/2/2011 Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft)_- - 17:30 - 20:15 2.75 DRILL P (— PROD1 PJSM ON MU OF DRILLING BHA. CREW CHANGE OUT, INSPECT ALL LINES AROUND RIG AFTER DIGGING OUT FROM BLOW. LINES ACCESSIBLE AND GOOD. CONDUCT PJSM ON MU OF BHA WITH NIGHT CREW. MU FLOATS TO COILTRAK,PRESSURE TEST TO 250 PSI LOW,1500 PSI HIGH. MU BHA: -3.75"BI-CENTER BIT,2 7/8"BHI EXTREME MOTOR WITH 1.2 DEGREE BEND, HOT, USMPR, DGS, DPS SUB, EDC, POWERCOMMS,WEAR PROTECTION SUB, LQC, UQC,XO, CTC -STAB ON WITH INJECTOR,FILL HOLE AND GET MANUAL STRAP ON PIT VOLUMES 120:15 22:50 2.58 DRILLP j PROD1 RIH WITH 3.75"DRILLING BHA. OBTAIN SLOW PUMP RATES. CONDUCT TIE-IN AT 10,010'. -11'CORRECTION. RIH TO 10,130'. LOST 9 1 l BBLS ON TRIP IN COMPARED TO CALCULATED DISPLACEMENT. 22:50 - 00:00 1.17 DRILL P PROD1 DRILL AHEAD. IMMEDIATE LOSSES AS SOON AS PUMPS ARE BROUGHT ON TO DRILLING RATE. -2.52 BPM IN,3070 PSI,2930 PSI FREE SPIN, MW IN 8.53 PPG, ECD 9.46 PPG . -CALL TOWN TO INFORM ENGINEER AND I IMPLEMENT PREVIOUSLY DISCUSSED PLAN TO CLOSE CHOKE WHILE CONTINUING TO DRILL AHEAD PER LOST CIRCULATION SOP; [NOTIFIED FIELD SUPERINTENDENT I-CHOKE CLOSED,SIWHP RANGING FROM 33 'TO 166 PSI -LOST 154 BBLS FROM 10,130'TO 10,216' I -540 BBLS 8.6 PPG QUICKDRILL ON LOCATION;ORDERED 580 BBLS KCL H 2/27/2011 100:00 - 01:40 1.67 t DRILL P PROD1 DRILL AHEAD FROM 10,216'TO 10,230'. j._ CONDUCT 100'WIPER TRIP WITH NO WEIGHT 1 ISSUES. RUN BACK IN HOLE TO 10,216'. CONTINUE TO DRILL AHEAD TO 10,300'WITH LOSSES AT 2.5 BPM,3740 PSI PUMP PRESSURE, MW IN 8.47 PPG, ECD 9.46 PPG. -TAKE ON 280 BBLS 8.6 PPG QUICKDRILL LOSSES AT 150 BPH -SIWHP RANGED FROM 37 PSI TO 166 PSI 01:40 - 03:15 1.58 DRILL P PROD1 WIPER TRIP WINDOW,LOGGING MADPASS OF BUILD SECTION. TAKE ON 280 BBLS 1QUICKDRILL. SIWHP DROPPED TO 0 PSI i DURING LOGGING. SWAP OVER TO KCL, RUN BACK IN HOLE. 03:15 - 06:00 2.75 DRILL P PROD1 DRILL AHEAD IN LATERAL SECTION FROM 110,300'TO 10,460'WITH CLOSED CHOKE AND 10 PSI SIWHP WITH FULL LOSSES. -2.5 BPM,2870-3025 PSI PUMP PRESSURE ON BOTTOM,2435 PSI FREE SPIN,9.46 PPG 1 ECD -620 BBLS QUICKDRILL LOST TO FORMATION 1-ROUND TRIPPING TRUCKS FOR KCL Printed 3/30/2011 11:13:01AM North America -ALASKA- BP Page 13 of 19 Operation Summary Report Common Well Name: 18-04 I AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 2/14/2011 End Date: 3/2/2011 II X3-00Y24-C(1,484,621.00) X3-00YGV-C(757,473.00) Project: Prudhoe Bay Site:PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor:NORDIC CALISTA UWI: 500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) — _ (ft) 06:00 - 07:30 1.50 DRILL P PROD1 j WIPER TRIP FROM 10,483'TO 10,400'TO CHASE 20 BBL PILL. INCREASE IN SIWHP. DRILL AHEAD TO 10520'MD(SEE SUDDEN DROP IN WHP,CIRC PRESSURE,ANNULAR BHP AS DRILL INTO 10520'MD AS IF THIS IS ALSO A LOST RETRUN ZONE). CO MAN CHANGEOUT. 07:30 - 13:00 5.50 DRILL P PROD1 CO MAN CHANGEOUT COMPLETE. BEGIN FULL WIPER INTO CASED HOLE FROM 10520' MD. PUH AT 2.8 BPM AT-2600 PSI CIRCULATING MUD. WHP SLOWLY AND LINEARLY INCREASES AS WE PUH FROM-0 PSI AT BOTTOM TO-400 PSI AT 10330'MD(WHP DECREASES AS WE RBIH. REPEAT THIS TREND SEVERAL TIMES). BEGIN TO OVERPULL AT 10330'MD. OVERPULL 4K, TURN AROUND, RBIH(HAVE TO STACK-5K BEYOND NORMAL RIH WEIGHT TO GET MOVING). TRY AGAIN TO PUH,OVERPULL AGAIN AT 10330'MD. AGAIN HAVE TO STACK -5K BEYOND NORMAL RIH WEIGHT TO GET MOVING. REPEAT SEVERAL TIMES,ALWAYS OVERPULLING AT 10330'MD. INCREMENTALLY INCREASE THE AMOUNT OF OVERPULL, STILL CANNOT PULL THROUGH. POSITION CT IMMEDIATELY BELOW 10330' MD AND TRY TO PUH WHILE DUMPING THE 400 PSI WHP(BEGINNING TO TAKE RETURNS). RETURN-1 OR-2 BBLS BEFORE WHP DROPS TO ZERO AND RETURNS CEASE, NO INCREMENTAL UP FOOTAGE GAINED. HAVE TO SWAP TO KCL DOWN CT AT THIS POINT,GETTING LOW ON MUD. iCONTINUE INCREASING OVERPULL INTO 10330'MD WHILE VARYING PUMP RATES. FINALLY START TO DRAG UPHOLE W/ ERRATIC 60K UP WEIGHT PUMPING AT 2.1 BPM W/NO RETURNS. DRAG UPHOLE-10', UP WEIGHT INCREASING. TURN AROUND, BOBBLE FREE AND RBIH. KCL IS AROUND THE HORN, NO LONGER ABLE TO ESTABLISH POSITIVE WHP W/CHOKE CLOSED. j ! INCREMENTALLY INCREASE OVERPULL INTO '10320'MD. GETTING STICKIER AND STICKIER IN DOWN DIRECTION, ULTIMATELY HAVING TO STACK TO MAX COMPRESSION TO BOBBLE FREE AND RBIH. CALL TOWN REGARDING BULLHEADING INTO WELL(TEMPORARY PHONE OUTAGE ON NORTH SLOPE DELAYS CALL). Printed 3/30/2011 11:13:01AM North America-ALASKA- BP Page 14 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/14/2011 End Date: 3/2/2011 X3-00Y24-C(1,484,621.00) X3-OOYGV-C(757,473.00) Project:Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor:NORDIC CALISTA UWI: 500292087500 Active Datum:9:04 7/29/1998 10:43 @56.0oft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 13:00 - 16:00 3.00 DRILL P PROD1 MIX UP HIGH VISCOSITY PILL(-150K LSRV). PUMP 15 BBL HIGH VIS PILL,5 BBL KCL,17 BBL HIGH VIS PILL. CIRCULATE PILLS TO BIT AT 2.8 BPM AT 2800 PSI, BHP/ECD:3656 PSI/ 8.28 PPG. WITH MUD EXITING BIT, PARAMETERS ARE 2.8 BPM AT 2571 PSI, BHP/ECD: 3850 PSI/8.73 PPG. IAP: 310 PSI, • OAP:400 PSI. POSITION CT AT 10340'MD AND CREEP UH AS PILL EXITS BHA. AFTER PILL IS OUT OF BHA,ATTEMPT TO PULL UP HOLE-OVERPULL AGAIN AT 10320'MD(NO CHANGE AFTER PUMPING PILL). BLEED OAP FROM 520 PSI TO ZERO PSI IN 5 MINUTES,ALL LIQUID. 16:00 - 19:00 3.00 DRILL P PROD1 ONLINE W/MUD DOWN CT AND SIMULTANEOUSLY DOWN BACKSIDE. INITIAL BHP/ECD: 3600 PSI/8.10 PPG. ONLINE DOWN CT AT-0.2 BPM AT-500 PSI, ONLINE DOWN BACKSIDE AT 0.5 BPM AT-440 PSI. CATCH PRESSURE AT 1 BBL AWAY ON BACKSIDE. INCREMENTALLY WORK UP TO 4.5 BPM DOWN BACKSIDE WHILE MAINTAINING-0.2 BPM DOWN CT. BHP AND ECD INCREASE TO 3950 PSI AND 8.9 PSI. WE HAVE PUMPED A FULL BACKSIDE VOLUME OF MUD. REPEATEDLY TRY TO WORK UPHOLE,CONTINUALLY TAG HARD AT 10320' !MD. INCREASE RATE DOWN CT TO 2.8 BPM !AND REPEAT TAG WHILE STILL PUMPING 4.5 • BPM DOWN BACKSIDE,SAME RESULTS,AND !CONFIRM THAT WE SEE NO MOTOR WORK !AND WE SEE NO DHWOB CHANGE. !CONTINUE TO HAVE TO APPLY-10K LB 'DOWN WEIGHT IN EXCESS OF RIH WEIGHT �TO GET MOVING SOUTH AFTER EACH TAG. !LINE UP BOTH PUMPS DOWN BACKSIDE. 'ONLINE AT 8.2 BPM DOWN BACKSIDE WITH MUD AT 940 PSI. REPEAT TAG AT SAME DEPTH WITH SAME RESULTS. STOP PUMPING DOWN BACKSIDE. ONLINE DOWN CT W/MUD AT 0.6 BPM AT 760 PSI W/ NO RETURNS(CHOKE CLOSED). !RECIPROCATE BETWEEN 10350'MD AND 10450'MD. FORMULATE NEW PLAN. !CHANGE OUT WITH COMPANY MAN. CALL TO TOWN TO DISCUSS ALTERNATIVES WITH TOWN ENGINEER. Printed 3/30/2011 11:13:01AM North America -ALASKA- BP Page 15 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 2/14/2011 End Date:3/2/2011 X3-00Y24-C(1,484,621.00) X3-OOYGV-C(757,473.00) Project:Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor:NORDIC CALISTA i UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 19:00 - 21:05 2.08 DRILL P PROD1 BRIEF PERSONNEL OF WHAT IS HAPPENING WHILE ENGINEER DEVELOPS FORWARD PLAN. PLAN IS TO STOP PUMPING AND RECIPROCATING TO ALLOW FORMATION TO RELAX. WITH WEATHER,DOWN TIME 23 MINUTES. -AFTER ALLOWING FORMATION TO RELAX, BEGAN JOG UP AT 60 FPM WITH NO PUMPS. PULLED INTO OBSTRUCTION AT 10,320'AND HAD OVERPULL IMMEDIATELY. ENCOUNTERED ERRATIC PUW OF 54K TO I 77K BUT BROKE THROUGH. • -ENCOUNTERED SEVERAL AREAS WITH SIGNIFICANT OVERPULLS;MAX PUW ENCOUNTERED 84K -PULLED THROUGH OBSTRUCTION AT 10,130'AND CONTINUED UP HOLE WITH STEADY CT PUW AND NO OVERPULLS 21:05 00:00 2.92 DRILL P PROD1 SWAP OVER TO KCL,PUMP DOWN COIL AND 1 BACKSIDE TO POH WITH BHA FOR INSPECTION. PJSM ON LD OF BHA. BEGIN TO LD BHA. 2/28/2011 00:00 - 00:20 0.33 DRILL P PROD1 LD BHA. BIT RUNG OUT ON NOSE,SEVERAL TEETH CHIPPED. BIT GRADE: 5-3-RO-N-X-I-WT-BHA. INSTALL NIGHT CAP, � PUMP ACROSS THE TOP TO KEEP HOLE a FULL. 03:15 00:20 - 2.92 DRILL-_ P I PROD1 PJSM ON CONDUCT COIL MANAGEMENT. j ._ CUT 100'OF COIL. CHANGE OUT HIGH PRESSURE FILTERS,TEST TO 4000 PSI. CONDUCT PULL TEST ON CTC. MAKE UP !UQC. REPLACE FLOATS IN STRING, I [PRESSURE TEST TO 250 PSI LOW AND 1500 PSI HIGH. I • -HOLE TAKING 90 BPH WHILE FILLING ACROSS THE TOP 03:15 - 04:00 0.75 DRILL P PROD1 PJSM ON MU OF BHA. MU BHA: -3.75"BY 4.25"BI-CENTER BIT,2 7/8"BHI !EXTREME MOTOR WITH 1.2 DEGREE BEND, I HOT, DGS, DPS SUB, EDC, POWERCOMMS, WEAR PROTECTION SUB, LQC, UQC,XO,CTC -STAB ON WITH INJECTOR -FUNCTION TEST MWD TOOLS 04:00 - 07:00 3.00 DRILL P 1 PROD1 OPEN EDC, RIH WITH DRILLING BHA AGAINST A CLOSED CHOKE. CLOSE EDC, OBTAIN SLOW PUMP RATES. 07:00 - 09:00 2.00 i DRILL P PROD1 RECIPROCATE IN CASED HOLE WHILE ' CONFIRMING PLAN FORWARD W/TOWN. 09:00 - 10:30 1.50 DRILL . P PROD1 PJSM W/ENTIRE CREW REGARDING FLUFF& STUFF. CONFIRM TRUCKING AVAILABILITY. 10:30 - 12:20 1.83 DRILL P i PROD1 WEIGHT CHECK ABOVE WINDOW. UP 1 WEIGHT CLEAN AT 36500 LB. BHP/ECD:3458 • I PSI/8.07 PPG. REBOOT BHI TOOL. RIH WEIGHT 19K LB. RIH THROUGH WINDOW CLEAN. RIH CLEANLY W/FREQUENT WEIGHT CHECKS TO 10110'MD. PUH AND PERFORM TIE-IN ' PASS,CORRECTION OF(-13'). IAP:80 PSI. OAP: 10 PSI. Printed 3/30/2011 11:13:01AM North America -ALASKA- BP Page 16 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/14/2011 End Date: 3/2/2011 X3-00Y24-C(1,484,621.00) X3-OOYGV-C(757,473.00) Project: Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor:NORDIC CALISTA 'UWI:500292087500 Active Datum:9:04 7/29/1998 10:43©56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) ft) 12:20 - 14:00 1.67 DRILL P PROD1 BEGIN FLUFF&STUFF INTO FILL. FS 2.6 BPM AT 2020 PSI W/NO RETURNS(CLOSED CHOKE)AND 20 PSI WHP. BHP/ECD: 3780 PSI /8.66 PPG. CIRCULATING KCL W/PERIODIC SWEEPS OF 150K LSRV MUD. START TAKING 5'BITES OF FILL FROM 10125'MD, FLUFFING UP 5'OF FILL AT A TIME AND CARRYING IT UP TO OUR SUSPECTED LOSS ZONE AT 10127'MD. TURNAROUND AT 10070'MD TO TAKE ANOTHER BITE. TRIP FREQUENTLY ABOVE OUR TURNAROUND DEPTH(10070' MD)TO MAKE SURE WE ARE NOT PILING FILL • AT THIS DEPTH-AFTER PULLING CLEANLY TO 10065'MD WE REDUCE OUR PUMP RATE AS WE PUH TO ALLOW ANYTHING TRAPPED IN THE TURBULENT AREA OF THE NEAR BIT • TO FALL AWAY. THEN WE PU TO-10030'MD, INCREASE OUR PUMP RATE BACK TO 2.6 BPM AND RBIH JETTING ANY DEBRIS INTO THE LOST CIRCULATION ZONE. TRIP FREQUENTLY ALL THE WAY TO THE I WINDOW TO MAKE SURE WE ARE CLEAN INTO THE CASED HOLE,AGAIN REDUCING OUR PUMP RATE AS WE PUH TO ENSURE THAT WE DONT CARRY ANY DEBRIS INTO ITHE CASED HOLE IN THE TURBULENT AREA IN THE NEAR BIT. THE SIWHP CYCLES WITH EACH HIGH VIS • PILL. AS EACH HIGH VIS PILL HITS THE LOSS ZONE,THE SIWHP INCREASES TO-50 PSI. WHEN KCL HITS LOSS ZONE,SIWHP FALLS TO ZERO PSI. • FLUFF&STUFF FCO TO 10185'MD, COMPLETELY CLEAN SO FAR. 14:00 - 18:00 4.00 DRILL P ; PROD1 CONTINUE FLUFF&STUFF FCO AS DESCRIBED ABOVE FROM 10185'MD. PUMPING DOWN CT AT 2.6 BPM AT 2000 PSI, BHP/ECD: 3832 PSI/8.73 PPG. 15:30-FCO AT 10240'MD. SIWHP IS NOT HOLDING STEADY AT-120 PSI. Printed 3/30/2011 11:13:01AM North America -ALASKA- BP Page 17 of 19 Operation Summary Report Common Well Name: 18-04 ,AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/14/2011 End Date: 3/2/2011 X3-00Y24-C(1,484,621.00) X3-00YGV-C(757,473.00) Project:Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) i (ft) 18:00 - 23:45 5.75 T DRILL P T PROD1 RIH FROM 9500'USING FLUFF AND STUFF METHOD, PUMP AT 2.5 BPM,1830 PSI. CONTINUE WITH PUMPING KCL ALTERNATING 40 BBLS KCL WITH 20 BBL SWEEPS OF 8.6 PPG QUICKDRILL. -DRILL AHEAD FROM 10,522'TO 10,530'AT 2.51 BPM,2000 PSI, BHP 3860 PSI,8.83 PPG ECD. POH FOR WIPER PUMPING AT FULL RATE,1850 PSI. PUW STAYING CONSISTENT I AT 36-37K. NO INDICATION OF CUTTINGS BED AT SUSPECTED FAULT ZONE AT 10,130' AS BHA IS PULLED BY. SLOW PUMP RATE • TO.6 BPM AT 10,060'AND CONTINUE UP HOLE TO 10,000'. BRING PUMPS BACK UP TO FULL RATE OF 2.5 BPM AND RIH. NO ISSUES WITH COIL WEIGHT,SIWHP AT 33 PSI. -DRILL AHEAD FROM 10,530'TO 10,540'AT 2.6 BPM,2280 PSI, BHP 3870 PSI,8.75 PPG ECD. CONTINUING TO ALTERNATE 40 BBLS KCL WITH 20 BBL SWEEPS OF 8.6 PPG MUD. POH AT FULL RATE WITH 1930 PSI PUMP PRESSURE. COIL PUW WEIGHT 36-37K. NO INDICATION OF CUTTINGS BED AGAIN AS BHA IS PULLED BY. REPEAT CYCLE OF COMING OFF PUMPS AT 10,060'TO 10,000'. COME ON WITH PUMPS TO 2.5 BPM,1900 PSI FOR TRIP IN. NO SIWHP UNTIL JUST ABOVE SUSPECTED FAULT. SIWHP AT 51 PSI TO 60 !PSI ON TRIP TO BOTTOM. NO BOBBLES ON DRILL AHEAD FROM 10,540'TO 10,550'AT 2.65 BPM,2205-2320 PSI PUMP PRESSURE, BHP 3970-4016 PSI,8.9 PPG ECD. STILL ALTERNATING KCL AND MUD SWEEPS. SIWHP INCREASES FROM 60-150 PSI. SIWHP AND PUMP PRESSURE DROPPED AS SWEEP AND KCL CYCLED THROUGH. POH AT 2.6 BPM,1910-2117 PSI PUMP PRESSURE,37K !CONSISTENT COIL PUW TO 10,300;PUW DOWN TO 35-36K FROM 10,300'TO 10,070'. DROP RATE DOWN TO.6 BPM TO 10,000'. BRING UP PUMPS TO 2.6 BPM, RIH WITH 1865-1920 PSI PUMP PRESSURE,18-19K COIL WEIGHT. SIWHP INCREASED FROM 0 PSI TO 18 PSI. -REACH BOTTOM WITH NO ISSUES WITH WEIGHTS. DRILL AHEAD FROM 10,550'TO 10,565'AT 2.6 BPM,1920 PSI, BHP,3740 PSI, 8.4 PSI ECD WHILE PUMPING THE KCL AND MUD SWEEP CYCLE. AT PICKUP, COIL PU WEIGHT CONSISTENT AT 38K,SIWHP 0 PSI. MADE WIPER TRIP UP WITH NO ISSUES, MAINTAINING—38K ON COIL UP WEIGHT. CONTINUED WITH LOWERING PUMPS AT 10,060'UP TO WINDOW. RUN BACK INTO HOLE WITH FULL PUMPS AT 2.6 BPM,1910 PSI PUMP PRESSURE,0 SIWHP,COIL WEIGHT VERY CONSISTENT AT 18-19K. NO ISSUES SO FAR PASSING BY THE SUSPECTED FAULT ZONE AT 10,127'. -DRILL AHEAD FROM 10,565'TO 10,570' LOSE SIGNAL AT MWD. CANNOT CONTROL TOOL FACE. TROUBLESHOOT PROBLEM. Printed 3/30/2011 11:13:01AM North America -ALASKA- BP Page 18 of 19 Operation Summary Report ....____-------- Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date: 2/14/2011 End Date: 3/2/2011 'X3-00Y24-C(1,484,621.00) X3-OOYGV-C(757,473.00) Project:Prudhoe Bay Site:PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release:3/2/2011 Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) UNABLE TO RECEIVE SIGNAL OR ORIENT HOT,POH FOR REPAIR. 23:45 - 00:00 0.25 DRILL N DFAL PROD1 POH TO REPLACE HOT PUMPING AT 2.56 BPM,1650 PSI,COIL UP WEIGHT CONSISTENT AT 38-39K,0 PSI SIWHP. NO BOBBLES ALL THE WAY UP TO WINDOW. 3/1/2011 00:00 - 02:30 2.50 DRILL N DFAL 10,570.00 PROD1 PULL UP THROUGH WINDOW AT REDUCED RATE. OPEN UP EDC, BRING PUMPS BACK UP AND CONTINUE TO POH TO SURFACE TO REPLACE HOT. 02:30 - 03:45 1.25 DRILL N DFAL • 10,570.00 PROD1 PJSM. BREAK OFF,STAND BACK INJECTOR. -L/D HOT, P/U NEW HOT, NEW DGS, M/U DRILLING BHA. -PERFORM HIGH SIDE ORIENTATION. 03:45 - 06:00 2.25 DRILL N DFAL 10,570.00 PROD1 RIH W/LATERAL DRILLING BHA. -CHOKE CLOSED, EDC OPEN, PUMPING @ 2.5 BPM/630 PSI W/RIH. 06:00 - 07:00 1.00 DRILL N DFAL 10,571.00 PROD1 LOG TIE-IN,CORRECTION OF(-10'). END NPT TIME. 07:00 - 08:15 1.25 DRILL F P PROD1 RECIPROCATE IN CASED HOLE AT LOW RATE ON KCL DURING MORNING CALL. 08:15 - 12:00 3.75 DRILL P • PROD1 RIH CLEANLY THROUGH OPEN HOLE. BHP/ECD/CIRC PRESSURE INDICATE BACKSIDE IS NOT FULL. PUH AND LIQUID PACK BACKSIDE, CATCHING PRESSURE AFTER 22 BBLS NORMAL VISCOSITY MUD PUMPED DOWN BACKSIDE. RBIH. WEIGHT CHECK AT 10560' MD-UP WEIGHT 38K LB, RIH WEIGHT 17K LB. FS 2.68 BPM AT 2100 PSI, BHP/ECD: 3800 PSI/8.2 PPG. ENGAGE BOTTOM AT 10583' MD. TAKE BITE WI-50 PSI MOTOR WORK AND 500 LB DHWOB AT ROP OF 2 FPM PUMPING 40 BBL • I KCL THEN 20 BBL 150K LSRV MUD IN ITERATIONS. AT 10589'MD OUR CIRC PRESSURE, BHP AND ECD FALL AWAY(2.68 BPM AT 1500 PSI,3456 PSI,7.76 PPG)AS IF WE JUST DRILLED INTO ANOTHER LOST 'CIRCULATION ZONE. PUH CLEANLY AT 40K LB. WIPER TO THIEF ZONE 12:00 - 14:30 2.50 DRILL P PROD1 DIRECTIONALLY DRILL AHEAD AGAINST A CLOSED CHOKE FROM 10,581'TO 10,675' CONDUCTING FREQUENT"FLUFF AND STUFF"TRIPS TO THE WINDOW. DID NOT OBSERVE ANY SIWHP UNTIL LAST 25'OF DRILLING. SIWHP ROSE TO 223 PSI: ON WIPER TRIP IT INCREASED TO 480 PSI. DURING DRILLING, PUMP PRESSURE AT 1550-1805 PSI, ECD 7.37-7.39 PPG. BHP 3280-3310 PSI. NO REAL WOB; HAD TO HOLD (BACK FROM DRILLING TOO FAST CONSISTENT PICK UP COIL WEIGHTS ON TRIP UP AT 41-42K, SLACK OFF WEIGHTS AT 18K. -DRILLED AHEAD FROM 10.650'TO 10,675' 'WITH BHP 3310, ECD 7.39 PPG,CIRCULATING PRESSURE 1710 PSI,SIWHP62 PSI. Printed 3/30/2011 11:13:01AM North America -ALASKA- BP Page 19 of 19 Operation Summary Report Common Well Name: 18-04 AFE No Event Type: RE-ENTER-ONSHORE(RON) Start Date:2/14/2011 End Date: 3/2/2011 X3-00Y24-C(1,484,621.00) X3-00YGV-C(757,473.00) Project: Prudhoe Bay Site:PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 14:30 - 15:00 0.50 DRILL N DPRB 10,675.00 PROD1 CONDUCT WIPER. PUW FROM 10,675' INITIALLY AT 42K AND REDUCING TO 38K AT WINDOW. SIWHP GRADUALLY INCREASED FROM 62 PSI AT 10,675'. AS STRING CAME UP, EXPECTED SOME SIWHP IN ACCORDANCE WITH THE FLUFF AND STUFF PROCEDURE BUT IT KEPT CLIMBING AS BHA CROSSED BOTH LOSS CIRCULATION ZONES. SIWHP AT 480 AT WINDOW. CRACK CHOKE, CONFIRM GAS. CALL TOWN ENGINEER. DEVELOP PLAN,NOTIFY FIELD SUPERINTENDANT AND AOGCC. 15:00 - 17:30 2.50 DRILL N DPRB 10,675.00 PROD1 BULLHEAD KILL WELL AT 4.8 BPM, ICP 980 PSI, FCP 580 PSI. SIWHP AT 0 PSI WITH 150 BBLS AWAY. VOLUME PUMPED 290 BBLS. RECEIVED CALL FROM TOWN, DIRECTED TO POH FOR FREEZE PROTECTING AND PREPARING TO MOVE OFF OF WELL. 17:30 - 19:00 1.50 DRILL N DPRB 10,675.00 PROD1 POH.AT SURFACE. 19:00 - 21:00 2.00 DRILL N DPRB 10,675.00 PROD1 TOWN PREPARING ADDENDUM TO PROGRAM. -DOWN TO LESS THAN 300 BBLS KCL,GET MORE COMING. -GO OVER THOROUGHLY PLAN FOR LAYING DOWN BHA AND OVERALL PLAN FORWARD. 21:00 - 22:00 'i, 1.00 1 DRILL N DPRB 10,675.00 PROD1 1 SHUT DOWN PUMP.CHECK WELLHEAD, STRONG VACUUM. -BREAK OFF/STAND BACK INJECTOR. -SHORT CHAIN OUT BHA,CLOSE SWAB AND MASTER VALVES. -BREAK DOWN BHA. 22:00 - 23:00 1.00 DRILL • N DPRB 10,675.00 PROD1 PJSM. FLUID PACK TREE AND BOPE. -PRESSURE TEST NITE CAP AGAINST SWAB VALVE -250/3500 PSI, CHARTED 5 MIN/EA,GOOD TEST. 23:00 - 00:00 1.00 DRILL N DPRB 10,675.00 j PROD1 PJSM W/LITTLE RED.PRESSURE TEST LINES TO 4000 PSI,GOOD TEST. -BULLHEAD DIESEL @ 4.5 BPM/200 PSI INITIAL CIRC PRESSURE. -FINAL BULLHEAD PRESSURE=0 PSI.40 BBLS DIESEL PUMPED. i-CLOSE MASTER AND SWAB VALVES,R/D LITTLE RED. Printed 3/30/2011 11:13:01AM North America -ALASKA- BP Page 1 of 1 Operation Summary Report Common Wet Name: 18-04 AFE No Event Type: COM-ONSHORE(CON) Start Date:2/24/2011 End Date: X3-00YGV-C(757,473.00) Project: Prudhoe Bay Site: PB DS 18 Rig Name/No.: NORDIC 1 Spud Date/Time: 12/25/1982 12:00:00AM Rig Release: 3/2/2011 Rig Contractor:NORDIC CALISTA UWI:500292087500 Active Datum:9:04 7/29/1998 10:43 @56.00ft(above Mean Sea Level) Date From-To Hrs Task I Code NPT NPT Depth Phase Description of Operations (hr) (ft) 3/2/2011 00:00 - 00:30 0.50 WHSUR P POST PJSM.PRESSURE TEST MASTER VALVE AGAINS NITE CAP -250/3500 PSI,5 MIN EACH,CHARTED,OK. 00:30 - 01:30 1.00 WHSUR P POST PJSM.REMOVE FUSEABLE AND CLOSE SSV. -CONDUCT PRESSURE TEST, NITE CAP AGAINST SSV. -250/3500 PSI,5 MIN EACH,CHARTED, OK. -R/D LITTLE RED. 01:30 - 06:30 5.00 WHSUR P POST PJSM W/ALL HANDS INVOLVED IN OPERATION. -VERIFIED RECENT LIFTING CERTIFICATIONS -GREASE ALL TREE VALVES -R/U TO SET BPV, USE NEW 0 RING, STAB LUBRICATOR ONTO WELL. -PRESSURE TEST LUBRICATOR AGAINST SSV&MASTER VALVES. -250/3500 PSI,5 MIN EACH, CHARTED, ' GOOD TEST. -OPEN MASTER VALVE, OPEN SSV, INSTALL FUSEABLE. -SET BPV,975 PSI BELOW BPV. -CLOSE MASTER VALVE, PRESSURE TEST MASTER VALVE AGAINST LUBRICATOR. -250/3500 PSI,5 MIN EACH, CHARTED. GOOD TEST. -REMOVE FUSEABLE AND CLOSE SSV. -PRESSURE TEST LUBRICATOR AGAINST SSV. 250/3500 PSI,5 MIN EACH,CHARTED. 06:30 - 07:00 0.50 WHSUR P POST RD LUBRICATOR 07:00 - 12:00 5.00 WHSUR P POST PJSM ON BLOWING DOWN COIL. PUMP FRESH WATER FOLLOWED BY CORROSION INHIBITOR,METHANOL,AND THEN BLOW DOWN REEL WITH NITROGEN. POP OFF INJECTOR,RD FOR RIG MOVE. __ 12:00 - 16:00 4.00 WHSUR P I POST RD BOP. RELEASE RIG AT 1600 HRS Printed 3/30/2011 11:13:48AM BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB DS 18 18-04 500292087500 18-04C Survey: MWD Survey Report - Geographic 02 March, 2011 Qbp Mill MAKER Survey Report-Geographic 0 bP L\TEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 18-04 Project: Prudhoe Bay TVD Reference: 18-04B Rig:45.10 @ 45.10ft(18-04B Rig:45.10 Site: PB DS 18 MD Reference: 18-046 Rig:45.10 @ 45.10ft(18-04B Rig:45.10 Well: 18-04 North Reference: True Wellbore: 18-04C Survey Calculation Method: Minimum Curvature Design: 18-04C Database: EDM.16-ANC Prod-WH24P Project Prudhoe Bay,GPB, PRUDHOE BAY Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB DS 18,TR-11-14 Site Position: Northing: 5,959,213.15ft Latitude: 70°17'35.252 N From: Map Easting: 691,583.44ft Longitude: 148°26'55.555 W Position Uncertainty: 0.00 ft Slot Radius: 0.000 in Grid Convergence: 1.46 ° Well 18-04 API No 500292087500 Well Position +N/-S 0.00 ft Northing: 5,960,796.07 ft Latitude: 70°17'50.819 N +E/-W 0.00 ft Easting: 691,571.58 ft Longitude: 148°26'54.724 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00 ft Wellbore 18-04C API No 500292087503 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2010 2/1/2011 21.84 81.01 57,664 Design 18-04C Audit Notes: Version: Phase: ACTUAL Tie On Depth: 9,977.04 Vertical Section: Depth From(TVD) +N/-S +EI-W Direction (ft) (ft) (ft) (1 29.00 0.00 0.00 225.57 Survey Program Date: 3/2/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 89.10 8,689.10 Survey#2(18-04) GYD-CT-CMS Gyrodata cont.casing m/s 8,718.00 9,804.14 18-048 PB1 (18-04BPB1) MWD MWD-Standard 9,882.00 9,977.04 18-04B(18-04B) MWD MWD-Standard 9,982.50 10,675.00 MWD(18-04C) MWD MWD-Standard 32/2011 4:36:39PM Page 2 COMPASS 2003.16 Buid 73 BAKER MOMS Survey Report-Geographic 0 bp L'VTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 18-04 Project: Prudhoe Bay TVD Reference: 18-04B Rig:45.10 @ 45.10ft(18-04B Rig:45.10, Site: PB DS 18 MD Reference: 18-04B Rig:45.10 @ 45.10ft(18-04B Rig:45.10: Well: 18-04 North Reference: True Wellbore: 18-04C Survey Calculation Method: Minimum Curvature Design: 18-04C Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 9,977.04 34.57 159.71 8,408.07 -2,676.39 -3,517.24 5,958,031.05 688,123.91 70°17'24.489 N 148°28'37.213 W TIP 9,982.50 34.51 159.01 8,412.56 -2,679.28 -3,516.15 5,958,028.19 688,125.08 70°17'24.460 N 148°28'37.181 W KOP 10,020.22 40.35 148.94 8,442.53 -2,699.76 -3,506.00 5,958,007.98 688,135.74 70°17'24.259 N 148°28'36.885 W 10,052.66 48.24 142.76 8,465.74 -2,718.43 -3,493.23 5,957,989.64 688,148.98 70°17'24.076 N 148°28'36.513 W 10,087.24 60.88 137.59 8,485.76 -2,739.94 -3,475.16 5,957,968.60 688,167.59 70°17'23.864 N 148°28'35.986 W 10,114.50 69.44 134.13 8,497.21 -2,757.66 -3,457.93 5,957,951.33 688,185.27 70°17'23.690 N 148°28'35.484 W 10,153.80 72.88 122.45 8,509.93 -2,780.62 -3,428.78 5,957,929.12 688,214.99 70°17'23.464 N 148°28'34.634 W 10,186.64 74.97 115.29 8,519.04 -2,795.84 -3,401.16 5,957,914.61 688,242.99 70°17'23.315 N 148°28'33.829 W 10,220.06 74.59 110.03 8,527.82 -2,808.26 -3,371.42 5,957,902.95 688,273.04 70°17'23.193 N 148°28'32.962 W 10,254.16 73.29 105.03 8,537.26 -2,818.13 -3,340.18 5,957,893.88 688,304.51 70°17'23.096 N 148°28'32.052 W 10,286.38 73.59 99.64 8,546.45 -2,824.72 -3,310.02 5,957,888.06 688,334.82 70°17'23.031 N 148°28'31.173 W 10,312.84 72.66 96.80 8,554.13 -2,828.34 -3,284.97 5,957,885.08 688,359.96 70°17'22.995 N 148°28'30.443 W 10,347.26 68.41 94.05 8,565.60 -2,831.42 -3,252.67 5,957,882.83 688,392.33 70°17'22.965 N 148°28'29.502 W 10,384.80 65.47 92.40 8,580.30 -2,833.37 -3,218.19 5,957,881.76 688,426.84 70°17'22.946 N 148°28'28.497 W 10,433.30 63.51 99.58 8,601.21 -2,837.91 -3,174.70 5,957,878.33 688,470.44 70°17'22.902 N 148°28'27.230 W 10,470.30 64.35 104.09 8,617.48 -2,844.73 -3,142.18 5,957,872.34 688,503.11 70°17'22.835 N 148°28'26.282 W 10,506.82 67.82 106.52 8,632.28 -2,853.55 -3,109.99 5,957,864.34 688,535.52 70°17'22.748 N 148°28'25.344 W 10,562.70 71.75 105.88 8,651.59 -2,868.17 -3,059.65 5,957,851.01 688,586.22 70°17'22.605 N 148°28'23.877 W 10,616.68 69.29 109.45 8,669.59 -2,883.60 -3,011.16 5,957,836.82 688,635.07 70°17'22.453 N 148°28'22.464 W 10,675.00 69.29 109.45 8,690.22 -2,901.76 -2,959.73 5,957,819.98 688,686.95 70°17'22.275 N 148°28'20.965 W TD 3!2°7011 4:36:39PM Page 3 COMPASS 2003.16 Build 73 NELLHEAD= McEVOY 1 5_040 SAFET"NOTES: WELL ANGLE>70@10120'*** >CTUATOR= AXELSON SUSPENDED 4-1/2 COME TBG*** CB. ELEV= 45.1' 3F. ELEV = 19.21' COP= 2100' ✓lax Angle= 75°@ 10187' RiC DRAFT 2185' —14-1/2"CA MCO BAL-O SSSVN, ID=3.813" datum MD= 11113' )atum TVD= 8800'SS GAS LIFT MANDRELS 13-3/8"CSG,72#, L-80, ID=12.347" H 2629' I ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3168 3055 35 MMGM DMY RK 0 03/29/C 3 5993 5193 40 MMGM DMY RK 0 03/29/C Minimum ID = 3.80" @ 9595' i. j 2 8112 6830 31 MMGM DMY RK 0 04/06/C 4-1/2" MILLED OTIS XN NIP 1 9514 8116 38 KBG-2 DMY BK 0 04/06/C 1111. 8541' d 9-5/8"X 7"BKR ZXP PKR/TIEBACK, ID=6.313" 8555' H 9-5/8"X 7"BKR HMC LNR HGR, ID=6.313" TOP OF WHIPSTOCK H 8741' IN 9-5/8"CSG,47#, L-80, ID=8.681" —I —8734 1— / 9-5/8"MILLOUT WINDOW(18-04B)8718'-8734' PERFORATION SUMMARY ' ' 9541' —14-1/2"OTIS X NIP, ID=3.813" REF LOG: SWS PERF ON 08/14/01 ANGLE AT TOP PERF: 18 @ 10383' Note: Refer to Production DB for historical perf data S Z 9551' H7"X 4-1/2"BKR S-3 PKR, ID=3.875" SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10383- 10410 C 01/22/02 3-3/8" 6 10410- 10450 C 09/25/01 ' , 9575' —14-1/2"OTIS X NIP, ID=3.813" 2-7/8" 4 10426- 10456 C 08/14/01 2-/78" 4 10465- 10485 C 08/14/01 • 9595' —14-1/2"OTIS XN NIP, MILL TO 3.80"(02/05/11) i • 9608' H4-1/2"WLEG, ID=3.958" 4-1/2"TBG, 12.6#, 13CR, .0152 bpf, ID=3.958" H 9606' I 9685' —7"X 4-1/2"BKR ZXP PKR w/7.40'TIEBACK &HMC LNR HGR, ID=4.39" 7"LNR,26#, L-80, .0383 bpf, ID=6.276" H 9882' / 3.80"MILLOUT WINDOW(18-04C)9983'-9990' 4-1/2"PKR WHIPSTOCK(02/22/11) H 9980' 4-1/2"LNR, 12.6#, L-80, .0152 bpf, ID=3.958" — —9990' �, L asr Ze Cit.- µ� C' r0 Ic3 6' .;.;. 4-1/2"OPEN HOLE —1 10675' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/27/83 ORIGINAL COMPLETION WELL: 18-04B 05/18/98 RWO PERMIT No: 2010900 07/17/01 N7ES SIDETRACK(18-04B) API No: 50-029-20875-02 03/02/11 NORDIC 1 CTD SUSPENDED(18-04C) SEC 24,T11 N, R14E, 1067'FNL&191'FEL 03/07/11 PJC DRLG DRAFT CORRECTIONS 4 BP Exploration(Alaska) e s Page 1 of 1 Regg, James B (DOA) fr 211 _co From: AK, D&C RWO&CTD Operations Superintendent[AKDCRWOCTDOperationsSuperintendent@BP.com] Sent: Wednesday, March 02, 2011 6:10 PM To: DOA AOGCC Prudhoe Bay "I Z�I It Subject: BOP usage on Nordic rig 1, Well 18-04, 3-1-2011 Attachments: BOP usage DS18-04C.doc All, Attached is a summary of a BOP usage that was made by Nordic 1 on 3-1-2011. Notification was made at the time of the incident to the AOGCC North Slope office. Please contact me if you have additional questions. Thanks, Greg Greg Sarber Operations Superintendent RWO/CTD +1 (907)659-5329(Office-slope) +1 (907)242-8000(Cell Phone) Harmony 2157 Alternate: Jim Willingham 3/25/2011 Blow Out Preventer Equipment ( BOPE ) Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of any BOPE use to prevent the flow of fluids from a well. Field Superintendent Name: Greg Sarber Wellsite Leader Name: Rich Burnett Contact Number: 907-242-8000 Contact Number: 907-659-4564 Traction Number: TBD Well Location & Name: DS 18-04C _ Permit To Drill (PTD) Number: 2110020 Date and Time of Incident: March 1, 2011 1545 hrs Original Scope of Work: Drill horizontal sidetrack in Zone 1A sands using a CTD rig. Operational Description Leading up to Well Control Event: When drilling a horizontal sidetrack, losses were encountered at 10,130' and 10,520'. Drilling continued with 100% losses into the formation. Drilling was conducted with no returns being taken at surface and with no WHP or fluid returns to Surface. During drilling, the HCR was open to a manual choke in the closed position. Drilling continued and a second suspected fault was encountered between 10,650' and 10,675'. BOPE Used and Reason: After encountering the second fault, WHP began to build. Well control was provided by the closed manual choke and the coiled tubing packoff. No BOPE was functioned. The observed WHP was suspected to be due to the formation cuttings plugging off the loss zones and the rig regaining the ability to circulate returns to surface. The manual choke was cycled to confirm that there were fluid returns to surface. The returns were determined to be gas instead of fluid. The manual choke was closed, and notifications made to the AOGCC field inspector and the BP Ops Superintendent. Is a BOPE Test Required after use ( Yes / No): If no, why? The rig will test manual choke when the BHA is out of the hole. 24 hour notice required to NS AOGCC Inspectors prior to testing BOPE components. Plan Forward: The gas was successfully removed from the wellbore by bullheading the well with KCL. Due to the number of thief zones in this lateral, the plan forward is to POH with BHA, freeze protect well and pull rig off of well. Additional engineering will be needed to replan the lateral. Additional Comments: Contacted Chuck Scheve from AOGCC on 3-1-2011. Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa.aogcc.prudhoe.bayalaska.gov Email CC List BP WSL Harry Engel Wells Team Leader Jeff Kilfoyle Engineering Team Leader Operations Drilling Engineer-Well File Wells Operations Manager Drilling & Completions Engineer Manager Wells Intervention Manager BOPE Usage Report for AOGCC August 2, 2010 HRE 1 Mill BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB DS 18 18-04 500292087500 18-04C Survey: MWD Survey Report - Geographic 02 March, 2011 Øbp air-voa /L111 - BAKER HUG1lS Survey Report-Geographic 0 bp IN rEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 18-04 Project: Prudhoe Bay TVD Reference: 18-04B Rig:45.10 @ 45.10ft(18-04B Rig:45.10; Site: PB DS 18 MD Reference: 18-04B Rig:45.10 @ 45.10ft(18-04B Rig:45.10; Well: 18-04 North Reference: True Wellbore: 18-04C Survey Calculation Method: Minimum Curvature Design: 18-04C Database: EDM.16-ANC Prod-WH24P Project Prudhoe Bay,GPB,PRUDHOE BAY Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB DS 18,TR-11-14 Site Position: Northing: 5,959,213.158 Latitude: 70°17'35.252 N From: Map Easting: 691,583.44ft Longitude: 148°26'55.555 W Position Uncertainty: 0.00 ft Slot Radius: 0.000in Grid Convergence: 1.46° Well 18-04 API No 500292087500 Well Position +N/-S 0.00 ft Northing: 5,960,796.07ft Latitude: 70°17'50.819 N +E/-W 0.00 ft Easting: 691,571.58 ft Longitude: 148°26'54.724 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: 0.00ft Wellbore 18-04C API No 500292087503 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (0) (°) (nT) BGGM2010 2/1/2011 21.84 81.01 57.664 Design 18-04C Audit Notes: 'Version: Phase: ACTUAL Tie On Depth: 9.977.04 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 29.00 0.00 0.00 225.57 Survey Program Date: 3/2/2011 From To (ft) (ft) Survey(Wellbore) Tool Name Description 89.10 8,689.10 Survey#2(18-04) GYD-CT-CMS Gyrodata cont.casing m/s 8,718.00 9,804.14 18-04B PB1 (18-04BPB1) MWD MWD-Standard 9,882.00 9,977.04 18-04B(18-04B) MWD MWD-Standard 9,982.50 10,675.00 MWD(18-04C) MWD MWD-Standard 3/2/2011 4:36:39PM Page 2 COMPASS 2003.16 Build 73 ri.. BAKER HUGHES Survey Report-Geographic 0 bp 1NTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well 18-04 Project: Prudhoe Bay TVD Reference: 18-04B Rig:45.10 @ 45.10ft(18-04B Rig:45.10; Site: PB DS 18 MD Reference: 18-04B Rig:45.10 @ 45.10ft(18-04B Rig:45.10; Well: 18-04 North Reference: True Wellbore: 18-04C Survey Calculation Method: Minimum Curvature Design: 18-04C Database: EDM.16-ANC Prod-WH24P Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (ft) (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude Longitude 9,977.04 34.57 159.71 8,408.07 -2,676.39 -3,517.24 5,958,031.05 688,123.91 70°17'24.489 N 148°28'37.213 W TIP 9,982.50 34.51 159.01 8,412.56 -2,679.28 -3,516.15 5,958,02819 688,125.08 70°17'24.460 N 148°28'37.181 W� KOP 10,020.22 40.35 148.94 8,442.53 -2,699.76 -3,506.00 5,958,007.98 688,135.74 70°17'24.259 N 148°28'36.885 W 10,052.66 48.24 142.76 8,465.74 -2,718.43 -3,493.23 5,957,989.64 688,148.98 70°17'24.076 N 148°28'36.513 W' 10,087.24 60.88 137.59 8,485.76 -2,739.94 -3,475.16 5,957,96860 688,167.59 70°17'23.864 N 148°28'35.986 W 10,114.50 69.44 134.13 8,497.21 -2,757.66 -3,457.93 5,957,951.33 688,185.27 70°17'23.690 N 148°28'35.484 W 10,153.80 72.88 122.45 8,509.93 -2,780.62 -3,428.78 5,957,929.12 688,214.99 70°17'23.464 N 148°28'34.634 W 10,186.64 74.97 115.29 8,519.04 -2,795.84 -3,401.16 5,957,914.61 688,242.99 70°17'23.315 N 148°28'33.829 W 10,220.06 74.59 110.03 8,527.82 -2,808.26 -3,371.42 5,957,90295 688,273.04 70°17'23.193 N 148°28'32.962 W 10,254.16 73.29 105.03 8,537.26 -2,818.13 -3,340.18 5,957,893.88 688,304.51 70°17'23.096 N 148°28'32.052 W 10,286.38 73.59 99.64 8,546.45 -2,824.72 -3,310.02 5,957,88806 688,334.82 70°17'23.031 N 148°28'31.173 W 10,312.84 72.66 96.80 8,554.13 -2,828.34 -3,284.97 5,957,885.08 688,359.96 70° 17'22.995 N 148°28'30.443 W 10,347.26 68.41 94.05 8,565.60 -2,831.42 -3,252.67 5,957,88283 688,392.33 70°17'22.965 N 148°28'29.502 W 10,384.80 65.47 92.40 8,580.30 -2,833.37 -3,218.19 5,957,881.76 688,426.84 70° 17'22.946 N 148°28'28.497 W 10,433.30 63.51 99.58 8,601.21 -2,837.91 -3,174.70 5,957,87833 688,470.44 70°17'22.902 N 148°28'27.230 W 10,470.30 64.35 104.09 8,617.48 -2,844.73 -3,142.18 5,957,87234 688,503.11 70°17'22.835 N 148°28'26.282 W 10,506.82 67.82 106.52 8,632.28 -2,853.55 -3,109.99 5,957,86434 688,535.52 70°17'22.748 N 148°28'25.344 W 10,562.70 71.75 105.88 8,651.59 -2,868.17 -3,059.65 5,957,851.01 688,586.22 70°17'22.605 N 148°28'23.877 W 10,616.68 69.29 109.45 8,669.59 -2,883.60 -3,011.16 5,957,836.82 688,635.07 70°17'22.453 N 148°28'22.464 W 10,675.00 69.29 109.45 8,690.22 -2,901.76 -2,959.73 5,957,819.98 688,686.95 70°17'22.275 N 148°28'20.965 W TD 3/2/2011 4:36:39PM Page 3 COMPASS 2003.16 Build 73 S7bilrr[ E 1111i IF: 0,- / A 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 John McMullen Engineering Team Leader jj �O BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-04C Sundry Number: 311-069 Dear Mr. McMullen: 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, Daniel T. Seamount, Jr. /"X-- Chair DATED this ! day of March, 2011. Encl. 41 ik STATE OF ALASKA ..P_ Z ]�'► �, ' ALASK/ _AND GAS CONSERVATION COMMIS, 1 RECEIVED' APPLICATION FOR SUNDRY APPROVAL LIAR 0 ; 20 AAC 25.280 1. Type of Request: Allska ciii& S ogr A c r6 ❑Suspend 0 Plug Perforations 0 Perforate 0 Pull Tubing 0 Time Extension AIIC-hC ,.. :,, -®Operations Shutdown 0 Re-Enter Suspended Well 0 Stimulate 0 Alter Casing 0 Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration(Alaska) Inc. -® Development 0 Exploratory 211-002 - 3. Address: 0 Service 0 Stratigraphic 6. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 50-029-20875-03-00- 7. If perforating,closest approach in pool(s)opened by this operation to nearest 8. Well Name and Number: property line where ownership or landownership changes: PBU 18-04C- Spacing Exception Required? 0 Yes ►= No 9. Property Designation: 10.Field/Pool(s): ADL 028307 Prudhoe Bay Field/Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth ND(ft): Effective Depth MD(ft): Effective Depth TVD(ft): Plugs(measured): Junk(measured): 10675' 8690' 10675' 8690' None None Casing Length Size MD ND Burst Collapse Structural Conductor 80' 20" 80' 80' Surface 2629' 13-3/8" 2629' 2593' 4930 2670 Intermediate 8718' 9-5/8" 8718' 7370' 6870 4760 Production Liner 1341' 7" 8541'-9882' 7208'-8331' 7240 5410 Liner 909' 4-1/2" 9685'-9980' 8173'-8411' 8430 7500 Perforation Depth MD(ft): Perforation Depth ND(ft): Tubing Size: Tubing Grade: Tubing MD(ft): None None 4-1/2", 12.6# 13Cr-80 9608' Packers and SSSV Type: 7"x 4-1/2"BKR S-3 Packer Packers and SSSV 9551'/8066' 7"x 4-1/2"BKR ZXP Packer MD(ft)and ND(ft): 9685'/8173' 12. Attachments: 13.Well Class after proposed work: IN Description Summary of Proposal 0 BOP Sketch 0 Detailed Operations Program 0 Exploratory -0 Development 0 Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: March 2,2011 0 Oil- 0 WINJ 0 WDSPL 0 Plugged 16. Verbal Approval: Date: 3/2/2011 0 Gas 0 GINJ 0 GSTOR 0 Abandoned Commission Representative: Guy Schwartz ❑WAG 0 SPLUG ❑Suspended 17. I hereby certify that the of - true and correct to the best of my knowledge. Contact Matthew Ross,564-5782 Printed Name Jo/ , en if Title Engineering Team Leader Prepared By Name/Number Signature Illir Phone 564-4711 Date?A- /( Terrie Hubble,564-4628 Commission Use Only Conditio • approval: Notify Commission so that a representative may witness 1 ' `J _ �•.(J/„t� ❑ Plug IntegritySundry Number 0 BOP Test 0 Mechanical Integrity Test 0Locationn Clearance Other: I`o'F:5 Ce os..r.F 3 3 i e 4 �a en.e,t%n6-t. fr....a ►� c T ier-di dK-�• Subsequent Form Required: l 0• — • APPROVED BY 3/1/6/1 I Approved By: 0 COMMISSIONER THE COMMISSIONcDate Form 10-403 --w :: ` ,:g MAR 11101144 0 RIGINA �. 74- 34." 3'd'" _ , SubmitInDuplicate - , Blow Out Preventer Equipment ( BOPt ) Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of any BOPE use to prevent the flow of fluids from a well. Field Superintendent Name: Greg Sarber Wellsite Leader Name: Rich Burnett Contact Number: 907-242-8000 Contact Number: 907-659-4564 Traction Number: TBD Well Location & Name: DS 18-04C Permit To Drill (PTD) Number: 2110020 Date and Time of Incident: March 1, 2011 1545 hrs Original Scope of Work: Drill horizontal sidetrack in Zone 1A sands using a CTD rig. Operational Description Leading up to Well Control Event: When drilling a horizontal sidetrack, losses were encountered at 10,130' and 10,520'. Drilling continued with 100% losses into the formation. Drilling was conducted with no returns being taken at surface and with no WHP or fluid returns to Surface. During drilling, the HCR was open to a manual choke in the closed position. Drilling continued and a second suspected fault was encountered between 10,650' and 10,675'. BOPE Used and Reason: After encountering the second fault, WHP began to build. Well control was provided by the closed manual choke and the coiled tubing packoff. No BOPE was functioned. The observed WHP was suspected to be due to the formation cuttings plugging off the loss zones and the rig regaining the ability to circulate returns to surface. The manual choke was cycled to confirm that there were fluid returns to surface. The returns were determined to be gas instead of fluid. The manual choke was closed, and notifications made to the AOGCC field inspector and the BP Ops Superintendent. Is a BOPE Test Required after use ( Yes / No): If no, why? The rig will test manual choke when the BHA is out of the hole. 24 hour notice required to NS AOGCC Inspectors prior to testing BOPE components. Plan Forward: The gas was successfully removed from the wellbore by bullheading the well with KCL. Due to the number of thief zones in this lateral, the plan forward is to POH with BHA, freeze protect well and pull rig off of well. Additional engineering will be needed to replan the lateral. Additional Comments: Contacted Chuck Scheve from AOGCC on 3-1-2011. Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa.aogcc.prudhoe.bayalaska.gov Email CC List BP WSL Harry Engel Wells Team Leader Jeff Kilfoyle Engineering Team Leader Operations Drilling Engineer-Well File Wells Operations Manager Drilling & Completions Engineer Manager Wells Intervention Manager BOPE Usage Report for AOGCC August 2, 2010 HRE 1 I TREE= Mc EV OY r WELLHEAD= McEVOY 1 8-04C I SAFETY ?S: 4-1/2"CHROME TBG ACTUATOR= AXELSON Proposed CTD Sidetrack KB.ELEV= 45.1' BF. ELEV= 19.21' - KOP= 2100' Max Angle= 43 @ 3900' 2185' H4-1/2"CA MCO BAL-O SSSVN,D=3.813" Datum MD= 10439' 0 [ Datum TVD= 8800'SS 13-3/8"CSG,72*,L-80,D=12.347" -- 2629' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 3.8" @ 9595' LU 4 3168 3055 35 MMGM DMY RK 0 03/29/08 3 5993 5193 40 MMGM DMY RK 0 03/29/08 t Milled XN profile _ 2 8112 6830 32 MMGM DMY RK 0 04/06/02 1 9514 8116 38 KBG-2 DMY BK 0 04/06/02 t /id 8541' —19-5/8"X 7"BKR ZXP FKR/TI:BACK,D=6.313" 8555' —19-5/8"X 7"BKR HMC LNR HGR, D=6.313" 9-5/8"CSG,47x,L-80, ID=8.681" —1 9729' 1 9-5/8"MILLOUT WINDOW 8718'-8734' 9541' —14-1/2"OTIS X NIP,D=3.813"1 I 9551' 1-17"X 4-1/2"BKR S-3 PKR,D=3.875" g 9575' H4-1/2"OTIS X NIP,D=3.813"I _________—" 9595' 1--14-'/7"OTIS XN MP, ID=3.8" 4-1/2"TBG,12.6*,13-CR, .0152 bpf, D=3.958" —{ 9606' 1 `-- 1, 9608' —14-1/2"WLEG,D=3.958"1 I /........____ t k _ 9685' 187"X 4-1/2"BKR ZXPPKR. D=4.39" 0 PERFORATION SUMMARY REF LOG: SWS PERF ON 08/14/01 9882' —{7"LNR,26*,L-80,0.0383bpf, D=6.276" ANGLE AT TOP PERF: 18 @ 10383' Note:Refer to Production D8 for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 10383-10410 01/22/02 3-3/8" 6 10410-10450 09/25/01 1EE2Pkrw5t0 ck H 9982' 1 2-7/8" 4 10426-10456 08/14/01 2-/78" 4 10465-10485 08/14/01 �PB� 10505' I 4-1/2"LNR 12.6*,L-80,.0152 bpf,D=3.958" —I 10594' 4-1/4"Open Hole —{ 10675' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/27/83 ORIGINAL COMPLETION 06/13/03 CMO/TLP KB ELEVATION CORRECTION WELL: 18-04 05/18/S8 LAST WORKOVER 09/13/03 CMO/TLP DATUM M D&PERF ANGLE PERMIT No: F. 01/17/01 RIG SIDETRACK 02/14/04 LWB/TLH GLV TVD CORRECTION API No: 50-029-20875-0 07/21/01 CH/TP CORRECTIONS 04/01/08 SWC/SV GLV C/O SEC 24,T11N,R14E, 1067'FNL&191'FEL 08/14/01 ?/KAK PERFS 11/05/10 MSE PROPOSED CTD SIDETRACK 09/25/01 JLM/KK PERFS&GLV CHANGES 01/22/02 CWS/KK ADPERFS BP Exploration(Alaska) 18-u4C CTD Operation Shutdown Program To: Clark Olsen / Jerry Bixby Date: March 03, 2011 GPB Well Ops Team Leaders reviewed by wells: no Revision: 1 From: Matthew Ross 564-5782 0/ 980-0552 M Subject: 18-04C Operation Shutdown AFE#: X3-00YGV-C:PREPOST Sundry#: Verbal authority from state,see attached e-mail. Objective: Secure well. Post Rig: 1. 0 Install well work platform around well head. 2. 0 Pull BPV. 3. S Drift tubing to - 9,650' MD with 3.75 GR in preparation to set PX plug, brush & flush tubing as needed. 4. S Set PX plug body in X profile at 9,575' MD. 5. F Load & kill well with 2% KCL, freeze protect well to 2500ft with diesel. 6. S Set Prong in PX plug body. 7. F MIT-T 2500psi. NOTES: • Max angle in 18-04B is 43 deg at 3789' MD. • Max DLS is 16.5 deg/100ft at 9,913' MD. • Whipstock /Window - 9,982' MD. • There is no completion in this well, don't go past the window with slickline tools. CH2MHILL: Place well work platform around well head. Slickline: Drift Tubing, Set PX plug body. 1. Run a 3.75" drift to 9,650' MD. • The purpose of this drift is for setting the PX TTP. 2. If drift can't get through tubing tail, perform brush and flush. Recent pumping achieved 8.5bbl/min at 450psi WHP. 3. Set PX plug body in X profile at 9,575' MD. Full Bore: Load & kill, freeze protect well. 1. Load & kill well with 228bb1s of 8.4ppg 1% KCL at min pump rate of 4.5bbl/min, freeze protect well to 2,500' with 40bbls, 6.8ppg diesel. Slickline: Set Prong in PX TTP. 1. Set prong in PX plug body at 9,575' MD. Full Bore: MIT Tubing. 1. MIT tubing to 2500psi. Page 1 of 1 • • 18-04C Temporary Abandonment Page 1 of 2 . Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, March 02, 2011 3:43 PM To: 'Ross, Matthew' Subject: RE: 18-04C Temporary Abandonment(PTD 211-002) Matt, You have verbal approval to proceed with the operational shutdown of drilling DS 18-04C as outlined below. Please submit the 10-403 sundry as soon as you can also. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Ross, Matthew [mailto:rossmo@BP.com] Sent: Wednesday, March 02, 2011 3:31 PM To: Schwartz, Guy L (DOA) �P S' -bQo4,ti ' :-11, - •or.. :..ndonment PTD 211-002) 1) Load & kill well with 2% 8.4ppg KCI. .1 9.0 2) Freeze protect well to 2500ft with 6.8ppg diesel. 3) Set tubing tail plug at 9575ft. 4) Evaluate all job data recorded for 18-04C & evaluate CTD options with regard to current available equipment & practices to see if CTD can drill & complete this well with the extreme losses. We will also discuss if rotary drilling can meet the targets also. Thanks Matt From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, March 02, 2011 2:49 PM To: Ross, Matthew Subject: RE: 18-04C Temporary Abandonment(PTD 211-002) Can you send a brief email with your outline of plan?Then I can talk to the commissioners .. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Ross, Matthew [mailto:rossmo@BP.com] Sent: Wednesday, March 02, 2011 2:47 PM To: Schwartz, Guy L (DOA) Subject: RE: 18-04C Temporary Abandonment (PTD 211-002) Guy; I am working on the wellbore schematic & 403 sundry requesting an operational shutdown with plan & 3/8/2011 ' 18-04C Temporary Abandonment Page 2 of 2 details. So, I will need your verbal approval. When do you require the paperwork? Thanks. Matt From: Schwartz, Guy L(DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, March 02, 2011 9:59 AM To: Ross, Matthew Cc: McMains, Stephen E (DOA) Subject: RE: 18-04C Temporary Abandonment(PTD 211-002) Matt, Please submit a 403 sundry requesting an operational shutdown. Outline your plan on how the well will be left and any other details that are pertinent. You may have to get verbal approval for the sundry if you are planning on stopping with CTD operations right away. If so just email me a request for verbal approval, with the operational plan outlined. A 10-404 should be submitted later detailing operations up to the point of Op shutdown.... (call me for details.. depends no when you restart operations) Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Ross, Matthew [mailto:rossmo@BP.com] Sent: Wednesday, March 02, 2011 9:13 AM To: Schwartz, Guy L (DOA) Subject: 18-04C Temporary Abandonment Guy; Drilling operations has been postponed on well 18-04C due to severe losses while drilling with CTD. It has been decided to temporarily abandon this well while we engineer a solution to deal with severe losses and at that time we will be able to safely drill &complete well 18-04C. I will be working on the formalized paperwork today. Many thanks. Matt Ross 564-5782 3/8/2011 Blow Out Preventer Equipment ( BOPE ) Usage Report to the AOGCC The purpose of this document is to ensure timely reporting to the AOGCC of any BOPE use to prevent the flow of fluids from a well. Field Superintendent Name: Greg Sarber Wellsite Leader Name: Rich Burnett Contact Number: 907-242-8000 Contact Number: 907-659-4564 Traction Number: TBD Well Location & Name: DS 18-04 Permit To Drill (PTD) Numbe : 2110020 Date and Time of Incident: March 1, 2011 1545 hrs Original Scope of Work: Drill horizontal sidetrack in Zone 1A sands using a CTD rig. Operational Description Leading up to Well Control Event: When drilling a horizontal sidetrack, losses were encountered at 10,130' and 10,520'. Drilling continued with 100% losses into the formation. Drilling was conducted with no returns being taken at surface and with no WHP or fluid returns to Surface. During drilling, the HCR was open to a manual choke in the closed position. Drilling continued and a second suspected fault was encountered between 10,650' and 10,675'. BOPE Used and Reason: After encountering the second fault, WHP began to build. Well control was provided by the closed manual choke and the coiled tubing packoff. No BOPE was functioned. The observed WHP was suspected to be due to the formation cuttings plugging off the loss zones and the rig regaining the ability to circulate returns to surface. The manual choke was cycled to confirm that there were fluid returns to surface. The returns were determined to be gas instead of fluid. The manual choke was closed, and notifications made to the AOGCC field inspector and the BP Ops Superintendent. Is a BOPE Test Required after use ( Yes / No): If no, why? The rig will test manual choke when the BHA is out of the hole. 24 hour notice required to NS AOGCC Inspectors prior to testing BOPE components. Plan Forward: The gas was successfully removed from the wellbore by bullheading the well with KCL. Due to the number of thief zones in this lateral, the plan forward is to POH with BHA, freeze protect well and pull rig off of well. Additional engineering will be needed to replan the lateral. Additional Comments: Contacted Chuck Scheve from AOGCC on 3-1-2011. Email to AOGCC North Slope Inspectors within 24 hours of the incident: doa.aogcc.prudhoe.bay(aalaska.gov Email CC List BP WSL Harry Engel Wells Team Leader Jeff Kilfoyle Engineering Team Leader Operations Drilling Engineer-Well File Wells Operations Manager Drilling & Completions Engineer Manager Wells Intervention Manager BOPE Usage Report for AOGCC August 2, 2010 HRE 1 18-04C Temporary Abandonment Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Wednesday, March 02, 2011 3:43 PM To: 'Ross, Matthew' Subject: RE: 18-04C Temporary Abandonment(PTD 211-002) Matt, You have verbal approval to proceed with the operational shutdown of drilling DS 18-04C as outlined below. Please submit the 10-403 sundry as soon as you can also. D; (� ea •...,,:s s:•�•� s «,sse0 �� Nar••. . Guy Schwartz 3.2_ 41 Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Ross, Matthew [mailto:rossmo@BP.com] Sent: Wednesday, March 02, 2011 3:31 PM To: Schwartz, Guy L (DOA) Subject: RE: 18-04C Temporary Abandonment(PTD 211-002) 1) Load & kill well with 2% 8.4ppg KCI. 2) Freeze protect well to 2500ft with 6.8ppg diesel. 3) Set tubing tail plug at 9575ft. 4) Evaluate all job data recorded for 18-04C &evaluate CTD options with regard to current available equipment & practices to see if CTD can drill & complete this well with the extreme losses. We will also discuss if rotary drilling can meet the targets also. Thanks Matt From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, March 02, 2011 2:49 PM To: Ross, Matthew Subject: RE: 18-04C Temporary Abandonment(PTD 211-002) Can you send a brief email with your outline of plan?Then I can talk to the commissioners .. Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Ross, Matthew [mailto:rossmo@BP.com] Sent: Wednesday, March 02, 2011 2:47 PM To: Schwartz, Guy L(DOA) Subject: RE: 18-04C Temporary Abandonment(PTD 211-002) Guy; I am working on the wellbore schematic & 403 sundry requesting an operational shutdown with plan & 3/2/2011 18-04C Temporary Abandonme-* Page 2 of 2 details. So, I will need your verbal approval. When do you require the paperwork? Thanks. Matt From: Schwartz, Guy L (DOA) [mailto:guy.schwartz@alaska.gov] Sent: Wednesday, March 02, 2011 9:59 AM To: Ross, Matthew Cc: McMains, Stephen E (DOA) Subject: RE: 18-04C Temporary Abandonment(PTD 211-002) Matt, Please submit a 403 sundry requesting an operational shutdown. Outline your plan on how the well will be left and any other details that are pertinent. You may have to get verbal approval for the sundry if you are planning on stopping with CTD operations right away. If so just email me a request for verbal approval, with the operational plan outlined. A 10-404 should be submitted later detailing operations up to the point of Op shutdown.... (call me for details.. depends no when you restart operations) Guy Schwartz Senior Petroleum Engineer AOGCC 793-1226 (office) 444-3433 (cell) From: Ross, Matthew [mailto:rossmo@BP.com] Sent: Wednesday, March 02, 2011 9:13 AM To: Schwartz, Guy L (DOA) Subject: 18-04C Temporary Abandonment Guy; Drilling operations has been postponed on well 18-04C due to severe losses while drilling with CTD. It has been decided to temporarily abandon this well while we engineer a solution to deal with severe losses and at that time we will be able to safely drill &complete well 18-04C. I will be working on the formalized paperwork today. Many thanks. Matt Ross 564-5782 3/2/2011 I . L �' F = 1U [F V k A SE A / � 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 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU 18-04C BP Exploration (Alaska), Inc. Permit No: 211-002 Surface Location: 1067' FNL, 191' FEL, SEC. 24, T11 N, R14E, UM Bottomhole Location: 4294' FNL, 2888' FEL, SEC. 24, T11N, R14E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, a ' Daniel T. Seamount, Jr. Chair DATED this/ t day of January, 2011. cc: Department of Fish & Game, Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) ret STATE OF ALASKA ' IVI.:4);ke ALAS!' )IL AND GAS CONSERVATION COMM!' )N JAN 0 4 2011 /-14"// PERMIT TO DRILL 20 AAC 25.005 I1 nc'2 lit 2 iOti COYri�pTIS3kW la.Type of work: lb.Proposed Well Class: ®Development Oil 0 Service-Winj 0 Single Zone 1 c. Specify if we is propose tor: ❑Drill 0 Redrill 0 Stratigraphic Test 0 Development Gas 0 Service-Supply 0 Multiple Zone 0 Coalbed GaiWCPOritakdrates ❑Re-Entry 0 Exploratory 0 Service-WAG 0 Service-Disp 0 Shale Gas 2. Operator Name: 5.Bond: 0 Blanket 0 Single Well 11. Well Name and Number: BP Exploration(Alaska) Inc. Bond No. 6194193 PBU 18-04C 3. Address: 6. Proposed Depth: 12.Field/Pool(s): P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 11105' TVD 8850'ss Prudhoe Bay Field/Prudhoe 4a. Location of Well(Governmental Section): 7. Property Designation(Lease Number): Bay Oil Pool Surface: ADL 028307 1067'FNL, 191'FEL, SEC.24,T11N, R14E, UM Top of Productive Horizon: 8. Land Use Permit: 13. Approximate Spud Date: 3792'FNL,3669'FEL, SEC.24,T11 N, R14E, UM January 25,2011 Total Depth: 9.Acres in Property: 14.Distance to Nearest Property: 4294'FNL, 2888'FEL, SEC.24,T11 N, R14E, UM 2560 37800' 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 45.10 feet 15.Distance to Nearest Well Open Surface: x- 691572 y-5960796 Zone- ASP4 GL Elevation above MSL: feet to Same Pool: 860' 16.Deviated Wells: Kickoff Depth: 10000 feet 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) Maximum Hole Angle: 70.98 degrees Downhole: 3306 Surface: 2426 18. Casing Program: Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight Grade Coupling Length. MD ND MD ND (including stage data) 4-1/4" 3-3/16" 6.2# L-80 TCII 1155' , 9950' , 8386' 11105' 8850'ss 53 sx 15.8 Dia Class'G' 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured): 10607' 9002' None 10506' _ 8908' _ None Casing Length Size Cement Volume MD TVD Conductor/Structural 80' 20" 1850#Poleset 80' 80' Surface 2629' 13-3/8" 2240 sx Fondu&400 sx PFC 2629' 2593' Intermediate 8718' 9-5/8" 500 sx Class'G'&300 sx PFC 8718' 7370' Production Liner 1341' 7" 287 sx 15.8 DDM Class'G' 8541'-9882' 7208'-8331' Liner 909' 4-1/2" 250 sx 15.6 DDe Class'G'with Latex 9685'- 10594' 8173'-8990' Perforation Depth MD(ft): 10383'-10485' Perforation Depth ND(ft): 8793'-8888' 20.Attachments: 0 Property Plat 0 BOP Sketch 0 Drilling Program 0 Time vs Depth Plot 0 Shallow Hazard Analysis 0 Diverter Sketch 0 Seabed Report 0 Drilling Fluid Program 0 20 AAC 25.050 Requirements IIN E 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the oregoing is true and correct. Contact Matthew Ross,564-5782 Printed Name J. A),.� Title Engineering Team Leader / Prepared By Name/Number: Signature �4111PPhone 564-4711 Date IZ ��> �� Elizabeth Barker,564-4628 Commission Use Only Permit To Drill API Number: cb20IRS- Permit Approval pate: See cover letter for Number: o2//D04.70 50-029-20077-03-00 \\\N \\\ other requirements Conditions of Approval: If box is checked,well may not be used to explore for,test,or produce coalbedmethane,gas hydrates,or gas contained shales: Eal Other: -IF Set) P 5 8oP GS -- amples Req'd: ❑Yes EiNo Mud Log Req'd: ❑ es QINo le 2 500 PS: Ant.wIW --7-27.. L'-')-IZS Measures: "Yes 0 No Directional Survey Req'd: 114 Yes 0 No !/ APPROVED BY THE COMMISSION /// Date ,COMMISSIONER Fo 10-401 Revised 07/2009 This permit is valid for 24 months from the date of approval(20 AAC 25.005(8)) Su mit In Duplicate ORIGINAL A. To: Alaska Oil & Gas Conservation Commission From: Matthew Ross 0 b CTD Engineer Date: December 28, 2010 Re: 18-04C Permit to Drill request Approval is requested for a permit to drill a CTD sidetrack from well 18-04B. 18-04B was a July 2001 rotary sidetrack targeting a structurally low block within the Midfield Graben. It was completed as high angle well in Zone 1B/1A. The well struggled to flow at-800 bopd at 3100 GOR from Zone 1 and required frequent Hot Oil Treatments. The oil rate steadily declined until Jan 2002 when 27' of Zone 2A were perforated. The well tested strong at-3000 bopd but declined to 1000 bopd at 30,000 GOR in a few months. From mid 2002 to 2007, it cycled with slowly declining recharge and ontime. The well was shut-in for high GOR in Jan 2008 when it POP'ed and tested at 89,000 GOR after a 4 month shut-in period. There have been subsequent attempts to POP the well without success, and it remains SI. LAST WELLTEST(12/31/07): 0 bopd, 36 MMscfd, 0% WC at>100,000 GOR The proposed plan for well 18-04C is to sidetrack out of the 18-04B 4-1/2"production liner with a Coiled Tubing Drilling rig on or around January 25, 2011. The existing perforations will be isolated by the primary cement job after drilling and running liner. The sidetrack will exit the 4-12" liner in the Zone 3 and drill a 4- 1/4"hole in the target zone lA sands. CTD Sidetrack Summary Pre-Rig Work: (scheduled to begin January 15, 2011). 1. S Dummy WS drift to 10,150' MD. 2. F Load&kill well prior to setting WS. Freeze protect)well to 2000'MD. 3. E Concurrently set 4-1/2" Packer WS at 9980' MD.V 4. F Pressure test packer WS to 2400psi. 5. V PT MV, SV, WV. 6. D Bleed gas lift and production flowlines down to zero and blind flange. 7. 0 Remove wellhouse, level pad. 8. V Set TWC-24hr prior to rig arrival. Rig Work: (scheduled to begin on January 25, 2011) 1. MIRU and test BOPE to 250 psi low and 3500 psi high. Pull TWC. 2. Mill XN profile at 9595' MD. 3. Mill 3.80"window at 9980' MD and 10' of rathole. I 4. Drill Build: 4.25" OH,421' (40°/100). 1V 5. Drill Lateral: 4.25" OH, 704' (12°/100). 6. Run 3-3/16" solid cemented completionleaving TOL at 9950' MD. ' 7. Pump primary cement leaving TOC at 9950', 11 bbls of 15.8 ppg liner cmt planned. 8. Cleanout run. 9. Run MCNL/GR/CCL log. 10. Perforate 100'. 11. Run 4-1/2" liner top packer and test liner lap to 2,400 psi. 12. Freeze protect well, set BPV and RDMO. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Run generic GLV's. Mud Program: • Well kill: 8.4 ppg brine. • Milling/drilling: 8.6 ppg Geo Vis for milling window and drilling. Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4.25" Casing Program: • 3-3/16"TCII, 6.2 pounds per foot, L-80 solid liner—9950' MD to 11,105' MD. . • A minimum of 11 bbls 15.8 ppg cement will be used for liner cementing. • TOC planned at 9950' MD. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan. Maximum planned hole angle is 70.9°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property—37,800'. • Distance to nearest well within pool—860' to 18-19./ Logging • MWD directional, Gamma Ray and resistivity will be run over all of the open hole section. • Cased hole GR/CCUMCNL logs will be run. Anti-Collision Failures • None. Hazards • One mapped fault crossings at 10,740' MD. • The maximum recorded H2S level on Drill Site 18 pad was 70 ppm on well 18-18B on 5/22/2010. • Lost circulation risk is considered high for this well due to the planned fault crossing. Reservoir Pressure • The reservoir pressure on 18-04C is expected to be 3306 psi at 8,800' TVDSS. (7.3 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2426 psi. Matthew Ross CTD Engineer CC: Well File Sondra Stewman/Terrie Hubble TREE= McEVOY WELLHEAD= McEVOY 8-04B SA. tNOTES: 4-1/2"CHROME TBG ACTUATOR= AXELSON KB. ELEV= 45.1' BF. ELEV= 19.21' KOP= 2100' Max Angle= 43 @ 3900' 2185' —14-1/2"CA MCO BAL-O SSSVN, ID=3.813" Datum MD= 10439' ,_.9..i Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80, ID=12.347" — 2629' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE Minimum ID = 3.725" @ 9595' IA4 3168 3055 35 MMGM DMY RK 0 03/29/08 3 5993 5193 40 MMGM DMY RK 0 03/29/08 4-1/2" OTIS XN NIPPLE 2 8112 6830 32 MMGM DMY RK 0 04/06/02 1 9514 8116 38 KBG-2 DMY BK 0 04/06/02 —I 8541' —9-5/8"X 7"BKR ZXP PKR/TIEBACK,ID=6.313" 8555' -9-5/8"X 7"BKR HMC LNR HGR, ID=6.313" 9-5/8"MILLOUT WINDOW 8718'-8734' TOP OF WHIPSTOCK —I 8741' PERFORATION SUMMARY REF LOG: SWS PERF ON 08/14/01 9541' —4-1/2"OTIS X NIP, ID=3.813" ANGLE AT TOP PERF: 18 @ 10383' 9551' —7"X 4-1/2"BKR S-3 PKR,ID=3.875" Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE N: 9575' H 4-1/2"OTIS X NIP, ID=3.813" 3-3/8" 6 10383- 10410 0 01/22/02 111119595' --I4-1/2"OTIS XN NIP,ID=3.725" 3-3/8" 6 10410- 10450 0 09/25/01 Ii 2-7/8" 4 10426- 10456 0 08/14/01 9608' —4-1/2"WLEG, ID=3.958" I 2-178" 4 10465- 10485 0 08/14/01 '�'�'1'�'�'�/�'�'V ;� 9685 —7"X 4-1/2"BKR .......... ZXP PKR,ID=4.39" /00004 AL. .0....... ` 9882' —7"LNR,26#,L-80, 9-5/8"CSG,47#,L-80,ID=8.681" — 9729' •.4•4.4•4•4•4�4441 .0383 bpf,ID=6.276" 41, 4-1/2"TBG, 12.6#,13-CR, .0152 bpf,ID=3.958" —I 9606' �.,\11,, \4 %x► Ni-0 PBTD — 10505' 4-1/2"LNR, 12.6#,L-80,.0152 bpf, ID=3.958" — 10594' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 01/27/83 ORIGINAL COMPLETION 06/13/03 CMO/TLP KB ELEVATION CORRECTION WELL: 18-04B 05/18/98 LAST WORKOVER 09/13/03 CMO/TLP DATUM M D&PERF ANGLE PERMIT No: 2010900 07/17/01 RIG SIDETRACK 02/14/04 LWB/TLH GLV 1VD CORRECTION API No: 50-029-20875-02 07/21/01 CH/TP CORRECTIONS 04/01/08 SWC/SV GLV C/O SEC 24,T11 N,R14E, 1067'FNL&191'FEL 08/14/01 ?/KAK PERFS 09/25/01 JLM/KK PERFS&GLV CHANGES 01/22/02 CWS/KK ADPERFS BP Exploration (Alaska) NEE _ VOY W�L18 04C HEAD= McEIVbEVOY � 12.,,... -NOTES: 4-112" CHROME TBG ACTUATOR= AXELSON KB.ELEV= 45.1' Proposed CTD Sidetrack BF.ELEV= 19.21' KOP= 2100' Max Angle= 43 3900' [I 2185' H4-1/2"CA MCO BAL-O SSSVN, ID=3.813" Datum MD= 10439' O Datum TVD= 8800'SS 13-3/8"CSG,72#, L-80, ID=12.347" H 2629' GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3168 3055 35 MMGM DMY RK 0 03/29/08 Minimum ID = 3.725" @ 9595' 3 5993 5193 40 MMGM DMY RK 0 03/29/08 4-1/2" OTIS XN NIPPLE 2 8112 6830 32 !MGM DMY RK 0 04/06/02 1 9514 8116 38 KBG-2 DMY it 0 04/06/02 8541' H9-5/8"X 7"BKR ZXP PKR/TIEBACK, ID=6.313" 8555' —19-5/8"X 7"BKR HMC LNR HGR, ID=6.313" 9-5/8"CSG,47#, L-80,ID=8.681" —I 9729' 9-5/8"MILLOUT WINDOW 8718'-8734' "*., ‘ A `s.1,,,, � •+" 9541' H4-1/2"OTIS X NIP,ID=3.813" - 9551' --{7"X 4-1/2"BKR S-3 PKR, ID=3.875" Zi. L 9575' —14-1/2"OTIS X NIP,ID=3.813" 9595' H4-1/2"OTIS XN NIP,ID=3.8" 4-1/2"TBG, 12.6#, 13-CR, .0152 bpf, ID=3.958" —I 9606' 9608' —14-1/2"WLEG, ID=3.958" 9685' 17"X 4-1/2"BKR ZXP PKR,ID=4.39" PERFORATION SUMMARY REF LOG: SWS PERF ON 08/14/01 4 ANGLE AT TOP PERF: 18 @ 10383' I 9882' 7" LNR,26#, L-80,0.0383bpf, ID=6.276" Note: Refer to Production DB for historical perf data 4.5 KB LTP -9940' SIZE SPF INTERVAL Opn/Sqz DATE { 3-3/8" 6 10383-10410 01!22/02 I 9950' TOP OF LINER 3-3/8" 6 10410-10450 09/25/01 2-7/8" 4 10426-10456 08/14/01 2"pkr w hipstock 2-/78" 4 10465-10485 08/14/01 I ice. 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BENSON BL ATTN: LAND MANAGER- ALASKA ANCHORAGE AK 995196612 Case Type: 784 OIL&GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Status: 35 ISSUED Status Date: 09/14/1965 Total Acres: 2560.000 Date Initiated:05/28/1965 Office of Primary Responsibility:DOG DIV OIL AND GAS Last Transaction Date: 12/04/2006 Case Subtype: NS NORTH SLOPE Last Transaction: AA-NRB ASSIGNMENT APPROVED Meridian: U Township: 011N Range: 014E Section: 13 Section Acres: 640 Search Plats Meridian: U Township: 011N Range: 014E Section: 14 Section Acres: 640 Meridian: U Township: 011N Range: 014E Section: 23 Section Acres: 640 Meridian: U Township: 011N Range: 014E Section: 24 Section Acres: 640 Legal Description 05-28-1965 *SALE NOTICE LEGAL DESCRIPTION* C14-12811N 14E UM 13,14,23,24 2560.00 U-3- 7 End of Case Summary Last updated on 01/06/2011. http://dnr.alaska.gov/projects/las/Case_Summary.cfm?FileType=ADL&FileNumber=28307... 1/6/2011 TRANSMITTAL LETTER CHECKLIST WELL NAME PTD# c=.21/00,,,,P O ✓ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: f.e!/d4 2;1/ POOL: f,G'!/40,�Gc' X 1/ O/G - Circle Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce / inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of weld until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name)must contact the Commission to obtain advance approval of such water well testing program. Rev: 1/11/2008 0 'a o r0- v co 0 v 3 0 PCf1 Co ° ( ° ( a 3 r- 0 3 G) coo rn r '9 3.O 7 m O m pN n) N n) N to = O z 0 n O N co N O N _ CD -• -• - W W W W W W W W W W N N) N N N N N N N N CO OD -I 0) 01 A W N 0 r CO 00 -I CA 01 A W N -, O CO Co v Co 01 A W N -4 O (O co 0) ()1 A W N -, O V O cncn0 -0 K * C7W W0 :~. D •. Dc) c) c) c) 0c) vDg0 -o -o00 =1, g * cr -oz ? C7 O o 0 o v o o S p p c n a co a v c o - v o o a n c o (o o T� v =Fi Es Q m m 3 0 (u - o m m <' a 0 T. _I _1 _1 v a . e = ' 3 3 0 0 < _ _ _ a (n 3 8 W r N 3. -0 = v (n CD m m (O Oc. c c (0 < < 0 C co 0 r. r. 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