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) Image Project 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. .::)O~ - 1 7- Q Well History File Identifier Organizing (done) 0 Two-sided 1111111111111111111 ~scan Needed 1111111111111111111 OVERSIZED (Scannable) HESCAN ~olor Items: 0 Greyscale Items: DIGITAL DATA ~skettes, No.1 0 Other, NolType: 0 Maps: 0 Other Items Scannable by a Large Scanner 0 Poor Quality Originals: OVERSIZED (Non,..Scannabie) [] Other: 0 Logs of various kinds: NOTES: Scanning Preparation , x 30 = 30 0 Other:: , ,n Date/':;)- òS- /s/ VVJT 1111111111111111111 Date [ Ia- 65 151 V1tf + it = TOTAL PAGES :=)4- (Count dŒ.S not'include cover ShrJ\t~JL) Date: / I:J- f!)S' /s/ V Vt , 11111111111 \ I11I1 \ I BY: Helen ~ Project Proofing BY: Helen ~ BY: Helen ~ Production Scanning Stage 1 Page Count from Scanned File: :"SS (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: t/ YES Date t I (~l oS , r~ YES NO Helen ~ NO 151 M tP Stage 1 BY: If NO in stage 1, page(s) discrepancies were found: BY: Helen Maria Date: /s/ 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1111111111111111111 BY: Helen Maria Date: /s/ Comments about this file: Quality Checked IIIIIII111111111111 8/24/2004 Well History File Cover Page.doc 02/03/11 Stan NO. 5688 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Shartzer ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD F -12 BMSA -00003 RST 1=1'17 /DTP 01/05/11 1 () /a/ 1 H -01A 10115/10 1 V^;I�` I J -20B B5JN -00073 CH EDIT PDC-GR (PLUG T) 44.),.g-'^ '` `i (l 11/05/10 0 `( 1 A -25A BCZ2 -00027 CH EDIT POC -GR (GRICCL) ,�) (1' -- � 14-1( BG4H -00025 CH EDIT (US 11!06/10 ,..26+1C) 1 W -220 IT ' � /( J -/ 12/27/10 Oa; .1 1 D -33 BD88 -00061 MCNL �f'i > 10/21/10 1 ; jO 9 1 13 -37 BBKA -00056 USIT AWJI -00117 MCNL J / /� 09/18/10 ;40 1 1 03 -20A 11503603 PRODUCTION LOG �4' E-/ 11/19/06 1 ACT-+ //G 1 • PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc Alaska Data & Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. / c} 1' Anchorage, AK 99503 -2838 • RECElvED FEB 0 7 2011 Alaska OS & Gas Cons. Commission And-image iq ,,.. • STATE OF ALASKA • ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other NI Abandoned ❑ Suspended 1b. Well Class: 20AAC 25.105 20AAC 25.110 ® Development ❑ Exploratory ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ❑ Service ❑ Stratigraphic 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 11/08/2010 " 202 - 170 310 - 278 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 10/10/2002 50 029 - 21716 - 02 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 10/13/2002 PBU J -20B 1215' FNL, 802' FEL, SEC 09, T11N, R13E, UM 8. KB (ft above MSL): 70.33' 15. Field / Pool(s): Top of Productive Horizon: 5257' FNL, 5106' FWL, SEC. 10, T11N, R13E, UM GL (ft above MSL): 39.50' Prudhoe Bay Field / Prudhoe Bay Total Depth: 9. Plug Back Depth (MD +TVD): Oil Pool 4130' FNL, 184' FWL, SEC. 11, T11N, R13E, UM 3152' 2869' 4b. Location of Well (State Base Plane Coordinates, NAD 27): 10. Total Depth (MD +TVD): 16. Property Designation: Surface: x- 643560 y - 5970139 Zone- ASP4 13230' 9010' ADL 028281, 028280 TPI: x- 649553 y- 5966213 Zone- ASP4 11. SSSV Depth (MD +TVD): 17. Land Use Permit: Total Depth: x- 649886 y 5967347 Zone- ASP4 N/A 18. Directional Survey: 0 Yes El No 19. Water depth, if offshore: 20. Thickness of Permafrost (TVD): (Submit electronic and printed information per 20 AAC 25.050) N/A ft MSL 1900' (Approx.) 21. Logs Obtained (List all Togs here and submit electronic and printed information per 20 AAC 25.071): 22. Re- Drill/Lateral Top Window MD/TVD: CCL, GR, MCNL, GR, RES 11678' 8756' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD ` PULLED 20" Conductor Surface 110' Surface, 110' 8 cu vds Concrete 13 -3/8" 72# L-80 / S - 95 Surface 2978' Surface 2746' 17 -1/2" 4127 cu ft Permafrost 9-5/8" 47# L -80 Surface 11150' Surface 8381' 12 -1/4" 2141 cu ft Class 'G'. 230 cu ft Class 'G' 7" 26# L - 80 10887' 11304' 8197' 8487' 8 - 1/2" 438 cu ft Class 'G' 4 -1/2" 12.6# L -80 10798' 11678' 8136' 8756' 6" 473 cu ft Class 'G' 31/2 x3- 3/16 "x2 -7/6" 9.39 /6.2616.169 L -80 11361' 13230' 8526' 9910' 3 -3/4" 90 cu ft Class 'G' 24. Open to production or injection? ❑ Yes ® 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): None 41/2 ", 12.6#, L -80 3306' - 10740' None MD TVD MD TVD (Kill String) 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. 5/4,4 WED FEB 0 4 ail DEPTH INTERVAL (MD)I AMOUNT AND KIND OF MATERIAL USED 9878' P&A with 34 Bbls Class 'G' ✓ 3173' Set EZSV with Whipstock on top ✓ 27. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): No 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? ❑ Yes No Sidewall Core(s) Acquired? ❑ Yes No If Yes to either question, list formations and intervals cored (MD +TVD of top and bottom of each), and summarize lith 1 and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and labors i ^ t '' C 250.071. None JAN 2 0 2011 FISCIVIS JAN 2 0 2011` ftic,i1te . GPI Cons. Gar r:nission Form 10-407 Revised 12/2009 CONTINUED ON REVERSE ' O YO( II8 Submit Original Only �� � f Y ,' & 29. GEOLOGIC MARKERS (List all formationsmarkers encountered): 30. • FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes 0 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. 25N 11732' 8967' None 25P 11738' 8801' 22N 11850' 8886' 22P 11852' 8888' 21N 11910' 8935' 21P 11914' 8938' Zone 1B 11959' 8964' 14N 11979' 8973' 14P 11994' 8979' Formation at Total Depth (Name): 31. List of Attachments: Well work Summary, Summary of Daily Drilling Reports and Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed: Sondraan Y Q i..± :._,-- , Title: Drilling Technologist Date: (Tr 1 - 1 PBU J - 20B 202 - 170 310 - 278 Prepared By Name/Number. Sondra Stewman, 564 -4750 Well Number Permit No. / Approval No. Drilling Engineer: John Rose, 564 - 5271 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 - Altemating - 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 TVD 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 12/2009 Submit Original Only • • J -20B, Well History (Pre Rig Sidetrack) Date Summary 07/15/10 T/I/O= 0/0/120 temp =S /I CMIT -TxIA PASSED to 3000 psi / MIT -OA PASSED to 2000 psi (RST Screen) CMIT TxIA to 3000 psi- Pumped 7.3 bbls DSL down IA to bring TxIA to test pressure. On 3rd test T /IA lost 20/0 psi in 15 min, 40/30 psi in 2nd 15 min & 20/30 psi in 3rd 15 min. Total loss of 80/60 psi in 45 min. Fail. Bled back to -1500 psi ( -3 bbls) per PE. Pressured TxIA to test pressure w/2.9 bbls DSL. T /IA lost 60/40 psi in 1st 15 min & 20/20 psi in 2nd 15 min, for a total loss of 80/60 psi in 30 min. Bled Tx IAP ( -5 bbls). MIT -OA to 2000 psi- Pumped 2.2 bbls DSL down OA to reach test pressure. OA lost 60 psi in 15 min's, 20 psi in 2nd 15 min's, for a total loss of 80 psi in 30 min's. bled back WHP's to initial's ( -3.5 bbls) * *Swab= closed, Master, IA, OA valves open on departure ** FW HP's= 0/0/120 07/17/10 T /I/O= 0/0/0, Temp =SI. PPPOT-T (PASS), PPPOT -IC (PASS), RST screen. Dry hole tree on well head. PPPOT -T: External check installed. Stung into test port (0 psi). Functioned LDS (2.5 "), all moved freely. Pumped through void, good returns. Pressured void to 5000 psi for 30 min test, lost 50 psi in 15 min, lost 0 psi in second 15 min (PASS). Bled void to 0 psi. PPPOT -IC: External check installed. Stung into test port (0+ psi), bled to 0 psi. Functioned LDS (2.75 "), all moved freely. Pumped through void, good returns. Pressured void to 3500 psi for 30 min test, lost 150 psi in 15 min, lost 50 psi in second 15 min (PASS). Bled void to 0 psi. 10/11/10 * * *SLB Fullbore Cement Crew * ** Job Scope: P & A w/ 15.8 ppq Class G Cement MIRU Pump 180 1% KCL sweeg down TBG u• IA Pum• cement schedule leaving the followin•: Vp umped 34 bbls of class G cement from 10879' MD to -9740' MD, 1% KCL from -9740 to 2500', Freeze rotect w/ diesel 2500' to surface on both the TBG & IA, Bleed T /IA/OA to zero. Released J -23 back to Pad Op & J -20 to be left shut in. ** *Job Complete * ** pt �- 10/12/10 ** *WELL S/I ON ARRIVAL ** *(Pre - SDTRK) RIG UP SLICKLINE UNIT 4516 ** *WSR CONTINUED ON 10/13/10 * ** 10/13/10 ** *WSR CONTINUED FROM 10/12/10 ** *(Pre - SDTRK) DRIFTED TBG W/ 3.70 CENT & 2.50" S- BAILER(no problems) TAGGED TOC © 9,878' MD. (sample of cement). CMIT -TxIA TO 2500 PSI PASSED ** *WELL S/I ON DEPARTURE, DSO NOTIFIED * ** 10/21/10 T /I /O 100/400/0 went to location to install a 4 1/8 actuated valve on dry hole tree,had equpment issues had to cancel job until issues are resolved 10/21/10 ** *WELL SHUT -IN ON ARRIVAL * * *(ELINE - TUBING CUT) SSV = CLOSED, INITIAL T /I /O = 0/450/50 POWER JET CUT 4 -1/2" 12.6 LB /FT TUBING AT 3306'. DEPTH REFERENCED TO TUBING TALLY DATED 5/30/2009. POSITIVE SURFACE INDICATION OF FIRE. SSV = C, FINIAL T /I /O = 400/400/0. WELL SHUT -IN ON DEPARTURE. ** *JOB COMPLETE * ** 10/22/10 T /I /O 100/400/0 obtain a leak tight barrier remove tree cap set new 4 1/8 ciw actuated valve reset tree cap torque all connections to spec, fill tree pt 500 psi 5 min 5000 psi 15 min passed ** *job Complete * ** 10/22/10 Load fluids, road to location 10/23/10 T /1 /0= 550/550/0 CMIT -TxIA PASSED to 2500 psi. (RWO Prep) Pumped into Tbg w/ 4.9 bbls diesel to pressure TxIA to test pressure. Loss of 20 Psi 1st 15 min. Loss of 0 psi 2nd 15 min for a total loss of 20 psi during 30 min test. FWHP =0/0/0 SV,WV,SSV,MV shut. IA,OA open. 10/26/10 T /1 /O= 0/175/0 Pressure tested against 4" CIW actuated valve to 3500 PSI /Pass. Attached lubricator and pressure tested to 300 PSI /Pass (Low) 3500 PSI /Pass (High). Set 4- 1/16" CIW "H" BPV# 709..tag C�3 102 ", 1 -1' ext. used. Removed lubricator attached tree cap pressure tested to 500 PSI /Pass...Pre- Doyon 141...no problems. Page 1 of 2 • J -20B, Well History (Pre Rig Sidetrack) Date Summary 10/27/10 T /I /O = BPV /180/60. Temp = SI. Bleed WHP's to 0 psi (Pre rig). Rig scaffold on well (well has dry hole tree w/ SSV on top). IA FL @ surface. OA FL near surface. Bled IAP from 180 psi to 0 psi (fluid, to BT) in 20 min. Bled OAP from 60 psi to 0 psi (gas, to BT) in 5 min. Monitor for 30 min. IAP unchanged. OAP increased to 0+ psi. FWHP's = BPV /0/0 +. Job Complete. SSV, MV,2nd MV = C. IA, OA = OTG. NOVP. 10/31/10 T /I /O= BPV /0/0 +. Temp= SI. WHPs (Pre -rig). WHPs unchanged. SSV, MV, 2nd MV= C. IA, OA= OTG. NOVP. 11/03/10 T/I/O= 0/0/0; Barriers tested (passed); Lubricator tested 300 low and 3500 high for 5 min. ea. (passed); Pulled 4- 1/16" CIW "H" BPV #709 thru dryhole tree with SSV & two MVs for Doyon 141 post move over well; 1 -2' ext. used, tagged @ 90 "; No Problems 11/04/10 T /I/O= 0/0/0; Barriers tested (passed); Tested lubricator 500 psi low and 3500 psi high for 5 min. ea. (passed); Pulled 4- 1/16" CIW "H" TWC #283 thru stack for Doyon 141; RKB= 26.40 2 -5', 1 -3' ext. & centralizer used, tagged @ 100 "; No Problems Page 2 of 2 TREE = CM/ • NOTES: WELL ANGLE> 70° @ 11189' * ** • WELLHEAD = MCEVOY J-20C 4- 112" CHROMETBG * ** ORIGWELLBORE, ACTUATOR = BAKER C SIDETRACK "A" & "B" NOT SHOWN BELOW KB. ELEV = 78.4' WHIPSTOCK@ 3152' * ** , 11) BF. ELEV 39.5 KOP = 3152 Max Angle = 97° 11544' ' ( 2189' I — i4 - 1/2" HES X NIP ID = 3.813" @ Datum MD = 10941' Datum TVD = 8800' SS 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2978' TOP OF 7" LNR H 3040' I 3040' I — 9 -5/8" X 7" BKR ZXP PKR w / 11' PBR & FLEX LOCK LNR HGR, ID = 6.18" 17" WHIPSTOCK (11/06/10) 1-1 3152' 19 -5/8" CSG, 47 #, L -80 NSCC, ID = 8.681" 1-1 — 3152' I — I 9 -5/8" MILLOUT WINDOW (J -20C) 3152' - 3169' GAS LIFT MANDRELS Minimum ID = 3.725" @ 10360' ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 4580 3911 43 KBG2 DOME BEK 16 01/05/11 4 -1 /2" HES XN NIPPLE 2 7594 6121 42 KBG2 SO SBK 20 01/05/11 1 10104 9134 23 KBG2 DMY SBK 0 12/02/10 u I 10221' I - - 1/2" HES X NIP, ID = 3.813" I X ■ ( 10251' H 7" X 4 -1/2" HES TNT PKR, ID = 3.856" I ' I 10286' I - 14 - 1/2" HES X NIP, ID = 3.813" I 1 10361' H 4 -1/2" HES XN NIP, ID = 3.725" I ITOP OF 4 -1/2" LNR I-1 10367' I-- I 10367' I — 7" X 5" BKR HRD -EZXPN PKR 4 -1/2" TBG, 12.6 #, 13CR -85 VAM TOP, — 10372' w / 11' PBR ID = 4.20" .0152 bpf, ID= 3.958" 10373' H 4-1/2" WEG, ID = 4.100" I 7" LNR, 26 #, L -80 VAM TOP HC XO TO L -80 BTC-M, H 10412' I-X I H ELMD TT NOT LOGGED 1 10383' I--17" X 5" BKR FLEX LOCK HGR, ID = 4.290" I 17" LNR, 26 #, L -80 BTC-M, .0383 bpf, ID = 6.276" 1-1 10536' Hi 10393' I X 4 -1/2" XO, ID = 3.958" I PERFORATION SUMMARY I REF LOG: MEMORY CCL/ GR/ CNL ON 10/17/02 ANGLE AT TOP PERF: 90° @ 12750' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqz DATE I 2 -7/8' 6 12750 - 12950 0 11/30/10 2 -7/8' 6 13000 - 13220 0 11/30/10 2 -7/8' 6 13270 - 13450 0 11/30/10 I 2 -7/8' 6 13500 - 13760 0 11/30/10 1 I PBTD I—I 14202' 4 -1/2" LNR, 12.6 #, L -80 IBT -M, .0152 bpf, ID = 3.958" I 14291' • i� %% DATE REV BY COMMENTS DATE REV BY COMMENTS 1 PRUDHOE BAY UNIT jt 05/09/87 AUDI 2 ORIGINAL COMPLETION 01/12/11 WRR/PJC GLV C/O (01/05/11) WELL: J -20C ;:; 10 " iZ4 06/58/90 D16 RWO 01/13/11 AK/PJC FINAL DRLG CORRECTIONS PERMIT No: 021240 08/11/96 N2ES SIDETRACK (J -20A) API No: 50- 029 - 21716 -03 I 10/19/02 N2ES CTD SIDETRACK (J -20B) SEC 9, T11 N, R13E, 1215' FNL & 802' FEL i 12/03/10 D -141 SIDETRACK(J -20C) 1 12/10/10 PJC DRLG DRAFT CORRECTIONS BP Exploration (Alaska) • ry F 4-44 ate) 66A tft.Rir -640 " Common Well Name: J -20 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/1/2010 End Date: 11/28/2010 X3- 00XCG -C (4,284,567.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: DOYON 141 Spud Date/Time: 8/1/1996 12:00:OOAM Rig Release: 12/3/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292171600 Active Datum: J -20C Actual @68.67ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 11/1/2010 00:00 - 03:00 3.00 MOB P PRE PREPARE RIG FOR MOVE. - BLOW DOWN HOSES - DISCONNECT SERVICE AND ELECTRICAL LINES 03:00 - 04:30 1.50 MOB P PRE MOVE PIPE SHED AND ROCK WASHER, STAGE BOTH COMPLEXES ON PAD. 04:30 - 05:00 0.50 MOB P PRE HOOK UP SOWS TO COMPLEXES FOR MOVE TO J -PAD. 05:00 - 07:30 2.50 MOB P PRE MOVE COMPLEXES TO J -PAD. RETURN SOWS TO B -PAD. 07:30 - 09:00 1.50 MOB P PRE HOLD PJSM, WITH DRIVERS AND RIG CREW. HOOK UP WEIGHTED SOWS TO SUB BASE. PULL SUB BASE OFF OF B-08A. HOOK UP SOWS TO PIPE SHEDS, STAGE SHEDS AT ENTRANCE OF PAD. 09:00 - 12:00 3.00 MOB P PRE MOVE SUB BASE AND PIPE SHEDS TO J -PAD. ALL MODULES ON J -PAD LOCATION AT 12:00. 12:00 - 18:00 6.00 MOB P PRE SPOTAND SHIM SUB BASE. LAY MATTS FOR COMPLEXES, SET AND SHIM SAME. SET ROCK WASHER AND PIPE SHEDS. 18:00 - 20:00 2.00 MOB P PRE HOOK UP SERVICE LINES - ELECTRICAL - WATER - STEAM GYLCOL RIG READY TO TAKE ON SEAWATER IN PITS. 20:00 - 00:00 4.00 MOB N WAIT PRE TAKE ON SEAWATER IN PITS. PERFORM HOUSE KEEPING AND GENERAL MAINTENANCE ON RIG. SLIP AND CUT DRILLING LINE. 11/2/2010 00:00 - 12:00 12.00 MOB N WAIT PRE CALIBRATE PVT SYSTEM IN PITS. BEGINNING WITH PIT EMPTY, FILL PIT IN 15 BBL INCREMENTS AND COMPARE PIT STRAP TO PVT SYSTEM. CONTINUE UNTIL PIT FULL. REPEAT FOR ALL PITS. - CALIBRATION WITNESSED BY QUADCO TECHNICIAN WHILE WORKING ON CALIBRATION OF PVT ALSO CHANGED OUT THE SAVER SUB, SERVICED THE TOP DRIVE, CHANGED OUT 1502 FITTINGS AND HALLIBURTON VALVES ON THE RIG FLOOR. LOADED THE PIPESHED WTIH 4" DRILLPIPE, INSPECT THE DERRICK, REPLACED THE 3" DISCHARGE LINE IN THE PITS, AND SERVICE THE MUD PUMPS. SPILL DRILL WITH TED KRUGER'S CREW, CRT 2 MIN O SEC. Printed 1/17/2011 11:01:40AM 'Lat r-;:-./VA-R. -� r � ' ' d "°.- t y f ja 3 �, � E y z • , n • 1: S.t. `' � .6-�s33r ' �" `� , � �*.. I " '4.1:;04.:t* '` Vti Common Well Name: J -20 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/1/2010 End Date: 11/28/2010 X3- 00XCG -C (4,284,567.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: DOYON 141 Spud Date/Time: 8/1/1996 12:00:OOAM Rig Release: 12/3/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292171600 Active Datum: J -20C Actual @68.67ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 12:00 - 00:00 12.00 MOB N WAIT PRE CHANGE OUT THE BLADDERS IN 4 ACCUMULATOR BOTTLES. REPLACE LOW PRESSURE MUD LINES IN THE PITS AND CENTRIFICAL ROOM, MOBILIZE ALL BOP TESTING EQUIPMENT TO THE RIG FLOOR, LAYDOWN ALL LIFT SUBS THAT ARE NOT NEEDED FOR UPCOMING OPERATIONS. PERFORM MAINTENANCE ON THE GAS DETECTORS. SPILL DRILL WITH ART MORGAN'S CREW, CRT 1 MIN 45 SEC. 11/3/2010 00:00 - 11:00 11.00 MOB N WAIT PRE WORK ON GENERAL RIG MAINTENANCE. FLOOD AND CHECK NEW LOW PRESSURE MUD LINES. GOOD TEST. CLEAN OUT SUCTION DAMPENER ON MUD PUMPS 1 AND 2. ORGANIZEALL OF -THE TOOLS IN THE CELLAR, AND CLEAN THE MEZZANINE. WELD A KEY STOP ONTO THE PIPE SKATE ELEVATOR AND TIGHTEN UP THE DRAG CHAIN. FIRE DRILL WITH TED KRUGER'S CREW, CRT 2 MIN 0 SEC. 11:00 - 14:00 3.00 WHSUR P WHDTRE RECEIVE AUTHORIZATION TO PROCEED _ WITH THE DECOMPLETE OF J-20C. INSTALL THE SECOND ANNULUS VALVES ONTO THE IA AND OA. RIG UP LINES AND HOSES. FIRE DRILL WITH ART MORGAN'S CREW, CRT 2 MIN 45 SEC. 14:00 - 17:00 3.00 WHSUR P WHDTRE RIG UP LITTLE RED SERVICES AND TEST THE OA TO 250 PSI LOW FOR 5 MINUTES, 2000 PSI HIGH FOR 10 MINUTES. CHARTED. TEST THE TUBING X IA TO 250 PSI LOW FOR 5 MINUTES AND 2500 HIGH FOR 10 MINUTES CHARTED. GOOD TEST. BLEED OFF PRESSURE AND RIG DOWN LRS. 17:00 - 18:45 1.75 WHSUR P WHDTRE RIG UP DSM LUBRICATOR AND TEST TO 250 PSI LOW / 3500 PSI HIGH FOR 5 MINUTES. GOOD TEST. PULL THE BPV AND RIG DOWN THE LUBRICATOR. 18:45 - 21:30 2.75 WHSUR P WHDTRE RIG UP TO REVERSE CIRCULATE OUT FREEZE PROTECT. TEST THE LINES TO 250 PSI LOW / 2500 PSI HIGH FOR 5 MINUTES. 21:30 - 22:45 1.25 WHSUR P WHDTRE REVERSE CIRCULATE 250 BBLS OF 8.5 PPG SEAWATER INTO THE WELLBORE. RECOVERED APPROX. 225 BBLS OF DIESEL MIXED WITH SEAWATER BACK BEFORE GETTING 25 BBLS OF CLEAN SEAWATER. PUMPED AT 8 BPM WITH 200 - 300 PSI AND 10 BPM WITH 350 -650 PSI. MONITOR WELL. STATIC. 22:45 - 00:00 1.25 WHSUR P WHDTRE RIG DOWN CIRCULATING LINES, REMOVE THE TREE CAP, INSTALL THE TWC AND TEST FROM BELOW TO 500 PSI LOW AND 2000 PSI FOR 5 MINUTES. BOTH GOOD TEST. PRESSURE TEST FROM ABOVE TO 250 PSI LOW AND 3500 PSI HIGH FOR 5 MINUTES. BOTH GOOD TEST. 11/4/2010 00:00 - 04:00 4.00 WHSUR P WHDTRE NIPPLE DOWN THE TREE AND REMOVE FROM THE CELLAR. TEST FIT THE TC-II CROSSOVER IN THE TUBING HANGER 8.25 TURNS AND LAY IT DOWN FOR FUTURE USE Printed 1/17/2011 11:01:40AM NQrfh Amenca ALASKA$ B� ' P ' '.� -� a:,a . ;41444' , to .,.'E P .. € i � "`� � `°" ` ` z .... ` ... ` s k141 Common Well Name: J -20 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/1/2010 End Date: 11/28/2010 X3- 00XCG -C (4,284,567.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: DOYON 141 Spud Date/Time: 8/1/1996 12:00:OOAM Rig Release: 12/3/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292171600 Active Datum: J -20C Actual @68.67ft (above Mean Sea Level) Date From - To Firs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 04:00 - 05:00 1.00 BOPSUR P WHDTRE NIPPLE UP THE BOP STACK. 05:00 - 05:30 0.50 BOPSUR P WHDTRE CLEAN UP TOOLS IN THE CELLAR. 05:30 - 06:00 0.50 BOPSUR P WHDTRE RIG UP TO TEST THE BOP EQUIPMENT. 06:00 - 10:30 4.50 BOPSUR P WHDTRE TEST BOPE WITH 4" AND 4.5" TEST JOINTS TO A LOW 250 PSI / HIGH 3500 PSI, EXCEPT FOR ANNULAR BAG. TEST ANNULAR BAG TO 2500 PSI. EACH TEST CHARTED AND HELD FOR 5 MINUTES. TEST WITNESSED BY WSL DAVID JOHNSTON, WSL RICHARD BORDES, AND TOOLPUSHER PAT KRUPA. AOGCC REP JOHN CRISP WAIVED WITNESS OF BOPE TESTING 10:30 - 11:30 1.00 BOPSUR P WHDTRE RIG DOWN TEST EQUIPMENT AND BLOW DOWN THE CHOKE MANIFOLD. 11:30 - 12:00 0.50 PULL P DECOMP MOBILIZE CASING EQUIPMENT TO THE RIG -, FLOOR. 12:00 - 15:00 3.00 PULL N WAIT DECOMP WAIT ON DRILL SITE MAINTENANCE. LAYDOWN EXCESS TOOLS, BLOW DOWN HARDLINE TO THE OPEN TOP TANK. RIG UP THE DUTCH RISER. -ART MORGAN'S CREW HELD TABLE TOP WELL CONTROL DRILL. 15:00 - 17:00 2.00 PULL P DECOMP RIG UP DRILL SITE MAINTENANCE LUBRICATOR AND TEST TO 350 PSI LOW / 3500 PSI HIGH FOR 5 MINUTES. GOOD TEST. PULL TWC AND RIG DOWN LUBRICATOR. 17:00 - 18:00 1.00 PULL P DECOMP PICK UP 1 JOINT OF DRILLPIPE, MAKE UP CROSSOVER FOR TUBING HANGER AND MAKE UP TIW VALVE. 18:00 - 18:15 0.25 PULL P DECOMP PULL HANGER FREE AT 68K AND PULL TO THE RIG FLOOR. 18:15 - 19:00 0.75 PULL P DECOMP CIRCULATE 40 BBL SAFE-SURF-0 PILL SURFACE TO SURFACE AT 495 GPM WITH 300 PSI. STROKE COUNTER FAILED TOWARDS THE END OF THE CIRCULATION. WENT OFF OF STROKE COUNTER ON SUPER CHOKE PANEL AND MANUAL STRAP TO VERIFY PROPER DISPLACEMENT DURING CIRCULATION. 19:00 - 20:15 1.25 PULL P DECOMP MONITOR THE WELL. LAYDOWN THE HANGER AND PUP JTS. BLOW DOWN THE TOP DRIVE. 20:15 - 00:00 3.75 PULL P DECOMP PULL AND LAYDOWN 91 JTS. OF 4.5" TUBING AND 2.89' CUT JT. 11/5/2010 00:00 - 01:00 1.00 PULL P DECOMP RIG DOWN CASING EQUIPMENT. 01:00 - 02:00 1.00 CLEAN P DECOMP MONITOR THE WELL AND INSTALL THE WEAR BUSHING. Printed 1/17/2011 11:01:40AM E . , O p Ir ion mm� t � t Common Well Name: J -20 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/1/2010 End Date: 11/28/2010 X3- 00XCG -C (4,284,567.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: DOYON 141 Spud Date/Time: 8/1/1996 12:00:OOAM Rig Release: 12/3/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292171600 Active Datum: J -20C Actual @68.67ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 02:00 - 05:00 3.00 CLEAN P DECOMP MAKE UP AND SINGLE IN 9 -5/8" SCRAPER BHA. BHA AS FOLLOWS: - 8.5" TRI -CONE BIT - BIT SUB - NON -MAG FLOAT SUB - 8.5" UPPER STRING MILL - (9) SPIRAL DRILL COLLARS - (15) 5" X 3" HWDP - CROSS OVER SUB 05:00 - 08:00 3.00 CLEAN P DECOMP SINGLE IN THE HOLE WITH 4" DRILL PIPE AND TAG THE 7" LINER TOP AT 3203'. UP WT. 95K / DOWN WT. 90K. -HELD KICK WHILE TRIPPING DRILL WITH GRANT NEUI-IARTH'S CREW, CRT 1 MIN 37 SEC. 08:00 - 09:00 1.00 CLEAN P DECOMP LAY DOWN A SINGLE AND RACK BACK 1 STAND OF 4 DRILL PIPE. CIRCULATE A HI-VIS SWEEP SURFACE TO SURFACE AT 610 GPM WITH 1700 PSI. 09:00 - 10:00 1.00 CLEAN P DECOMP PULL OUT OF THE HOLE RACKING BACK 4" DRILL PIPE TO 750'. CHANGE OUT HANDLING EQUIPMENT. 10:00 - 11:00 1.00 CLEAN P DECOMP PULL OUT OF THE HOLE RACKING BACK THE HWDP AND DRILL COLLARS AND LAY DOWN THE BHA. 11:00 - 12:00 1.00 EVAL P DECOMP PICK UP E -LINE TOOLS AND RIG UP E -LINE UNIT. 12:00 - 16:30 4.50 EVAL - P DECOMP PICK UP 9 -5/8" EZSV AND RUN IN THE HOLE ON E -LINE. TAGGED THE SCAB LINER TOP AT 3183' E -LINE DEPTH. CORRECTED DEPTH TO 3191' AND PICKED UP TO 3161' AND SET EZSV 5' ABOVE THE COLLAR LOCATED AT 3166'. GAMMA RAY LOG TO SURFACE. RIG DOWN E -LINE UNIT. 16:30 - 17:30 1.00 EVAL P DECOMP CLOSE THE BLINDS AND TEST THE EZSV AND 9 -5/8" CASING TO 350 PSI LOW AND 3500 PSI HIGH FOR 30 MINUTES. GOOD TEST. 17:30 - 00:00 6.50 CLEAN P DECOMP SINGLE IN THE HOLE WITH 4" DRILL PIPE OUT OF THE SHED TO —3100' AND PULL OUT OF THE HOLE RACKING BACK THE DRILL PIPE IN ORDER TO HAVE ENOUGH DRILLPIPE IN THE DERRICK TO DRILL OUT ENTIRE 8.5" INTERMEDIATE SECTION. 11/6/2010 00:00 - 00:30 0.50 CLEAN P DECOMP INSPECT EQUIPMENT AND PIPE SKATE. KEEPER PIN ON 4" DRILL PIPE ELEVATORS FOUND TO BE LOOSE. 00:30 - 02:30 2.00 CLEAN N SFAL DECOMP SERVICE RIG WHILE WAITING ON NEW 4" DRILL PIPE ELEVATORS TO BE DELIVERED FROM API. 02:30 - 03:30 1.00 CLEAN P DECOMP SINGLE IN WITH 4" DRILL PIPE IN ORDER TO HAVE ENOUGH DRILLPIPE IN THE DERRICK TO DRILL OUT ENTIRE 8.5" INTERMEDIATE SECTION. 03:30 - 04:30 1.00 CLEAN P DECOMP PULL OUT OF THE HOLE RACKING BACK 4" DRILL PIPE. 04:30 - 05:00 0.50 CLEAN P DECOMP CLEAN AND CLEAR THE RIG FLOOR OF ALL UN- NEEDED HANDLING EQUIPMENT AND PREPARE TO PICK UP WHIPSTOCK BHA. 05:00 - 07:30 2.50 STWHIP P DECOMP PICK UP WHIPSTOCK BHA. Printed 1/17/2011 11:01:40AM � k Av. ` ©rth�merlca AU��t� SP � � s � p a ,' t Tk _, - f �p @Pa' s ©'1 Fl �T+ � t 'A '� Common Well Name: J -20 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/1/2010 End Date: 11/28/2010 X3- 00XCG -C (4,284,567.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: DOYON 141 Spud Date/Time: 8/1/1996 12:00:OOAM Rig Release: 12/3/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292171600 Active Datum: J -20C Actual ©68.67ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 07:30 - 08:00 0.50 STWHIP P DECOMP SHALLOW PULSE TEST MWD AT 400 GPM WTIH 350 PSI. 08:00 - 09:00 1.00 STWHIP P DECOMP PICK UP AND MAKE UP COLLARS AND HWDP FROM THE DERRICK. 09:00 - 10:30 1.50 STWHIP P DECOMP RUN IN THE HOLE TO 3088' ON 4" DRILL PIPE. 10:30 - 11:30 1.00 STWHIP P DECOMP ORIENT THE WHIPSTOCK TO 60 DEG RIGHT OF HIGH SIDE, TAG THE EZSV AT 3173', SET DOWN AND SET THE BOTTOM TRIP ANCHOR 28K. PULL 12K OVER TO VERIFY THE SET. SHEAR OFF THE BOLT AT 40K DOWN. UP WT. 100K / DOWN WT. 95K 11:30 - 12:30 1.00 STWHIP P DECOMP . DISPLACE WELL TO 9.8 PPG LSND AT 500 GPM WITH 1300 PSI. MUD WT. IN AND OUT P� A 9.8 PPG. 12:30 - 13:00 0.50 STWHIP P DECOMP ESTABLISH SPR'S AT-3125' MD , 2860 TVD, WITH 9.8 PPG MUD, MUD PUMP #2 35 SPM AT .`2 160 PSI .45 SPM AT 770 PSI. 13:00 - 20:15 7.25 STWHIP P DECOMP MILL WINDOW FROM 3152' - 3169' AND NEW FORMATION FROM 3169' TO 3194' AT 500 GPM WITH 1400 PSI, 100 RPM WITH 2K -10K 1r TQ, TOW- 3152', MOW- 3161', BOW- 3169' WORKED MILL THROUGH THE WINDOW WITH AND WITHOUT ROTATION, NO DRAG. UP WT. w 98K, DOWN WT. 90K, ROT WT. 95K 20:15 - 21:00 0.75 STWHIP P DECOMP PUMP SUPER SWEEP SURFACE TO P1) SURFACE TO CLEAN OUT ANY METAL SHAVINGS AT 500 GPM WITH 1500 PSI. CIRCULATE 1.5 BOTTOMS UP TO CLEAN UP THE HOLE. 21:00 - 22:00 1.00 STWHIP P DECOMP RIG UP AND PERFORM FIT TEST TO 225 PSI TO ESTABLISH 11.3 PPG EMW AT 2865' TVD WITH 9.8 PPG MUD IN AND OUT OF THE HOLE. ATTEMPTED 3 TIMES WITH TEST THAT WOULD BLEED OFF TO 0 PSI WITHIN 3 MINUTES. VERIFIED ALL SURFACE EQUIPMENT WHICH WAS GOOD. ATTEMPTED TEST FOR THE 4TH TIME WITH THE SAME RESULTS. 22:00 - 23:00 1.00 STWHIP N WAIT DECOMP CALLED ODE TO CONSULT ABOUT FIT. WAIT ON DECISION FROM TOWN. 23:00 - 23:30 0.50 STWHIP P DECOMP RIG UP AND PERFORM LOT. 23:30 - 00:00 0.50 STWHIP N WAIT DECOMP SENT LOT RESULTS TO TOWN ODE, OTL, AND ETL. WAITING ON DECISION OF LOT RESULTS. 11/7/2010 00:00 - 02:00 3.00 STWHIP N WAIT DECOMP WAIT ON ORDERS FROM TOWN ODE FOR DECISION ON LOT RESULTS. LOT OF 200 PSI WITH 9.8 PPG MUD WT. AT 2865' TVD; WHICH EQUALS 11.14 PPG EMW AS PER TOWN ODE. 02:00 - 03:00 1.00 DRILL P INT1 SPOT 40 BBL LCM PILL AT 5BPM WITH 400 PSI. - G -SEAL PLUS 10 PPB - M -I -X II M 15 PPB - SAFECARB 40 10 PPB - NUT PLUG FINE 5 PPB - UNANNOUNCED LOST CIRCULATION DRILL WITH NEUHARTH'S CREW. CRT 1 MIN, 25 SEC Printed 1/17/2011 11:01:40AM s 3 � n ` � .� rt �. � eF�.� x •;� ��:, era �S � rq - 4fr # f11trCIC� /h +� �� rts � ,. • ra a Summ Red Common Well Name: J -20 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 11/1/2010 End Date: 11/28/2010 X3- 00XCG -C (4,284,567.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: DOYON 141 Spud Date/Time: 8/1/1996 12:00:OOAM Rig Release: 12/3/2010 Rig Contractor: DOYON DRILLING INC. UWI: 500292171600 Active Datum: J -20C Actual @68.67ft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (ft) 03:00 - 06:30 3.50 DRILL P INT1 PULL OUT OF THE HOLE RACKING BACK THE 4" DRILL PIPE AND LAY DOWN THE WINDOW MILL BHA. MILLS IN GAUGE. TOTAL METAL BACK TO SURFACE 236 LBS. 06:30 - 07:00 0.50 DRILL P INT1 CLEAN AND CLEAR THE RIG FLOOR. PREPARE TO PICK UP THE DRILLING BHA. 07:00 - 08:00 1.00 DRILL P INT1 PULL THE BUSHING AND FLUSH OUT THE STACK. SET THE WEAR BUSHING AND BLOW DOWN THE TOP DRIVE. 08:00 - 11:00 3.00 DRILL P INT1 PJSM MAKE UP 8.5" INTERMEDIATE DRILLING. BHA AS FOLLOWS: 8.5" HYCALOG PDC DTX619M -D6 BIT SERIAL # 130544 - 7 1.3 DEGREE BEND MUD MOTOR - NON -MAG FLOAT,SUB - NON-MAG INTEGRAL BLADE STAB. NON -MAG 6.75" DM COLLAR - NON- MAG6.75 "'DGR/EWR/PWD /DDS - NON -MAG 6.75" POS PULSER - NON-MAG FLEX COLLAR NON -MAG FLEX COLLAR - NON -MAG FLEX COLLAR - UNANNOUNCED KICK DRILL WHILE MAKING UP BHA WITH NEUHARTH'S CREW. CRT 2 MIN. 11:00 - 11:30 0.50 DRILL P INT1 UPLOAD MWD 11:30 - 12:30 1.00 DRILL P INT1 CONTINUE TO MAKE UP THE BHA AS FOLLOWS: - 3" X 5" HWDP (3) - JAR 3" X 5" HWDP (14) - X -OVER SUB - 8.5 GHOST REAMER (2) LOCATED AT 2425.71' AND 4972.57' BEHIND THE BIT 12:30 - 12:45 0.25 DRILL P INT1 SHALLOW PULSE TEST THE MWD AT 500 GPM WITH 900 PSI. 12:45 - 14:00 1.25 DRILL P INT1 TRIP IN THE HOLE ON 4" DRILL PIPE TO 3089'. 14:00 - 14:30 0.50 DRILL P INT1 ORIENT TO 60 DEG RIGHT OF HIGH SIDE AND SLIDE THROUGH THE WINDOW WITH NO PROBLEMS. 3 � j 14:30 - 00:00 9.50 DRILL P INT1 DIRECTIONALLY DRILL AHEAD FROM 31-94' -" l TO 3933'. TVD 3430'. - 600 GPM AT O RPM WI H 3-4K Q 98K - CALC. ECD 10.14 PPG EMW / ACT. ECD 10.51 PPG EMW - ADT- 3.93 / AST- 1.97 / ART -1.96 - MUD WT IN 9.8 PPG / OUT 9.8+ PPG 11/8/2010 00:00 - 06:30 6.50 DRILL P INT1 DIRECTIONALLY DRILL AHEAD FROM 3933' TO 4685'. TVD 3988'. - UP WT. 107K / DOWN WT. 95K / ROT WT. 103K - 600 GPM AT 120 RPM WITH 3-4K TQ - CALC. ECD 10.18 PPG EMW / ACT. ECD 10.65 PPG EMW - MUD WT IN 9.9 PPG / OUT 9.9 PPG -ADT 3.49 / AST .45 / ART 3.04 06:30 - 07:30 1.00 DRILL P INT1 CIRCULATE AND CONDITION MUD AT 400 GPM WITH 1450 PSI. Printed 1/17/2011 11:01:40AM • ~~Q~C~ 0o L~ p~Q~~{Q /,.,,~w~LL~~..,, John Egbejimbe Engineering Team Leader BP Exploration (Alaska), Inc. ~~x;, Y. ~` ~ '', ,~, ~ r , _~ `a ~ ~ ~~r P.O. Box 196612 ~ ~~ Anchorage, AK 99519-6612 ~, Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU J-20B Sundry Number: 310-278 Dear Mr. Egbejimba: 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. %~ Chair DATED this ~ day of September, 2010. Encl. STATE OF ALASKA ALASIC/~ AND GAS CONSERVATION COMMIS~1 APPLICATION FOR SUNDRY APPROVAL 20 AAC 25.280 ,~~ 9-a•lo ~~~' .~ D R~~' 1. Type of Request: ^ Abandon ' ®Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Program ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ Time Extension ^ Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ Alter Casing ®Other Resume Operations 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 202-170' 310-107 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21716-02-00- 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 .l-206 - ' Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): ADL 028281, 028284, 028280` Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (tt): Effective Depth ND (ft): Plugs (measured): Junk (measured): 13230' ~ 9010'- 13185' - 9012' - 10879' -10872' Casin Len th Size MD ND Burst Colla se Structural Conductor 11 2 11 1 ' Surface 2 78' 13-3/8" 2978' 2746' 4 0 2 7 Intermediate 11152' 9-5/8" 111 2' 8382' 687 476 Production Liner 471' 7" 1 87' - 11304' 8197' - 8487' 7240 541 Liner 880' 4-112" 10798' - 11678' 813 ' - 8756' 8430 7500 Liner 1 3-1/2" x 3-3116" x 2-7/8" 1 '- 1 2 S'- 10' 101 1 Liner 7601' 7" 3191' - 1 792' 289 ' - 8132' 7240 410 Perforation Depth MD (ft): Perforation Depth ND (tt): Tubing Size: Tubing Grade: Tubing MD (ft): Below Plug: 12100' - 13170' 8997' - 9013' 4-1/2", 12.6# (Kill String) L-80 10740' Packers and SSSV Type: None (Kill String) Packers and SSSV None MD (ft) and ND (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: September 9, 2010 ^ Oil ^ WINJ ^ WDSPL ^ Plugged 16. Verbal Approval: Date: ^ Gas ^ GINJ ^ GSTOR ^ Abandoned ^ WAG ^ SPLUG - ®Suspended Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact John Rose, 564-5271 Printed Name John Egbejimba Title Engineering Team Leader „~- Prepared By Name/Number: Signature ` Phone 564-5859 Date ~ 3 f j O Elizabeth Barker, 564-4628 Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness Sundry Number: ' Q~~~ ~ OP Test ^ Mechanical Integrity Test ^ Location Clearance ^ Plug Integrity .~ 35ov pS~ Q~P ~ ~~r+ Other: .,~-2~~() s` ~nn~ GS ~ C/m.Crh) ~~~~``~~'''`~'T ~fD ~ p SC'~~~~.. -~-~- Zv ~q.4c.. ZS.Z ~ ~ s ~. ~ e~~ P~~ ~k5 rn t ~ 20 f~'4~ 2S' ltZ Subsequent Form Required: /~ _ !~` I~~.kR ~<;; ,~; yo7 Z .:~.,~~~ ' ,~'rn:th~ta~IfY~~i APPROVED BY ~ /~ Approved By: COMMISSIONER THE COMMISSION Date Form 10~fElite~~i01/~6,1,po n ~~ ~ ~ ?_ /v ~7®tJ~~YY~J~~77 JJCCII'' ~Fl .:~ ~ ~ ~ I ~ A L ~° G Sub4nit In Duplicate ~~~ • Well Name: J-20B Well Type: Producer Current Status: Shut-In /Suspended Request: P&A -Well Prep f/Rotary Sidetrack MIT -TxIA Passed to 3500 psi 05/19/09 MIT - OA Passed to 2000 psi 04/16/09 Request: J-20B was a 2002 CTD sidetrack which targeted Zone 1 B reserves within the Southeastern gravity drainage block of J-pad. J-206 tested initially at 2,295 bopd, 2% wc, 2,383 GOR. At shut-in (8/19/06), J-20B was a competitive gravity drainage producer at 446 bopd, 36,680 GOR, 12% WC. J-206 was waivered for IAxOA communication post CTD sidetrack, per waiver policy annual MIT-OA's were conducted. The IAxOA waiver was canceled in early 2006, with OA re-pressurization (~50 psi/day) being manageable by bleeds. In August 2006, the field operator noted high IAP, a TIFL (tubing integrity fluid level) was performed and failed on overnight build-up rate. A caliper log was run through the tubing indicating 2 joints of 70% penetration and 43 joints with 40 - 70 % penetration. The well was then secured with a PX plug set at X nipple at 10,778' MD. A CMIT-TxIA was performed on the well in October, it failed with a leak rate of 0.13 bpm, suggesting that the well had one of the following; Packer Leak, Production Casing Leak, or Plug Leak. Due to the OT21 pipeline issues diagnostics and repairs were held until June 2008, when a TecWel leak detection log was run to identify the source of the failed CMIT-TxIA. The TecWel log identified a possible production packer leak at 10,754' MD and a definite production casing leak at 5,107'. A RWO was undertaken in April 2009 to mitigate a production packer and a production casing leak. Significant mishaps during the RWO operation led to the decision to ultimately "suspend" operations and leave the well in an unusable status. To repair the production casing leak at 5,107', the RWO operations cemented a 7" scab liner in place from 3,191' to 10,792'. Shortly after running and cementing the scab liner, amilling/clean out BHA was lost down hole, adress-off BHA was lost downhole while prepping the original milling BHA for recovery, the dress-off BHA was recovered, and while attempting to recover the original fish downhole the tools being used to fish sidetrack out of the 4-1/2" liner which prohibited additional tool runs from accessing the original fish. A 4-1/2" kill string, without a production packer, was run to 10,740'. Pre-rig diagnostics were conducted proving production casing and surface casing integrity with passing a CMIT-TxIA and MIT-OA on 7/15/10, respectively. Passing pack off testing of the tubing and inner casing ~' ', was performed on 7/17/2010. ~ GQA`~ J~~W Reason for Sidetrack: f During the RWO all options were exhausted to recover the fish without success, the asset and RWO team ~. got A~ at the time weighed the options and decided it was best to move the rig off of the well and suspend ~S (~~ , operations. In its current state, J-206 does not have access to the reservoir to allow for production. To n T~® return the well to production and access reserves a rotary sidetrack is required to be drilled by June 3, ' 2011 per AOGCC. ~~~t'~ „~t'~~ Other Requests: Given rig floor height limitations, a MASP < 3000 psi, and the fact that the three ram bRS~ .iiltn drilling BOP configuration is preferred to a two ram configuration with a spool, BPXA will execute the ~~ provisions of 20 AAC 25.285 (f) (1) regarding the initial testing of the BOPE as follows when existing ~ ~~ ~, wellhead or testing equipment prevents the testing of the lowest set of pipe rams: That lowest set of rams ~~~~ ~'l~ • • will be tested at the earliest opportunity during path-forward de-completion work, i.e., after the completion has been pulled from the well. Safety concerns and spacing limitations with the wellhead height and tubing spool preclude us from installing a spacer spool in the three-ram drilling BOP stack. Scope of Work: As currently planned, the P&A of the J-20B well and the well work in preparation for the J-20C rotary sidetrack will be as follows: 1. Perform full-bore cement job setting a cement plug from the top of the WRP at 10,879' MD back ~ up the well to 9792' MD and perform CMIT-TxIA to 2500 psi. 2. Make 4-1/2" tubing cut at 9600' MD. 3. MIRU Doyon 141. ~ 4. Pull the 4-1/2" kill-string from the pre-rig cut at 9600' MD. 5. Set and test an EZSV in the 9-5/8" casing at 3191' MD for a whipstock departure of the well from 3174' MD (mid-window in 9-5/8" casing). NOTE: This P&A plan was presented in a-mail format on 8/6/10 for early consideration on meeting all AOGCC P&A requirements for this well. MASP: 2966 (8.6 ppg pore pressure at TSAG) Estimated Pre-Rig Start Date: September 9, 2010 Proaosed Pre-riq prep work: F 1. Full-bore cement down the 4-1/2" kill string to the top of the junkNVRP at 10,879' MD and up the annulus leavin TOC in the kill strin and annulus at 9792' MD. F 2. CMIT-TxIA to 2500 si, MIT-OA to 2000 si. S 3. Drift the 4-1 /2" tubin to TOC to confirm the abilit to cut the tubin . E 4. Make tubing cut at 200' above TOC at 9600' MD (new TC-II kill string worth salvage efforts . F 5. Circ out well to seawater and freeze protect upper 2200' on both sides of the tubing with diesel. CMIT-TxIA to 2500 si. W 6. PPPOT-T, PPOT-IC and service LDS. V 7. Set BPV. Planned Rip Work: 1. MIRU. 2. MIT - OA 2000 psi for 10 minutes (expect to pass). CMIT TxIA to 2,500 psi for 10 minutes (expect to pass). 3. Pull BPV. Circulate out freeze protection and displace well to seawater. Set a TWC and test to 3500 psi from above and 2000 psi from below (10 minute tests). Nipple down tree. Nipple up and test BOPE to 3,500psi. Pull TWC. - 4. RU and pull the 4-1 /2" tubing/kill-string from the pre-rig jet cut at --9600' MD_ Test the lower set of pipe rams if necessary. 5. MU a 9-5/8" clean-out assembly on 4" drillpipe to include a casing scraper to 3191' MD in preparation to set a CIBP for the whipstock. (NOTE: With the tubing stub at 9600' MD, PU 4" drillpipe as required to drill to the 7" casing point.) 6. RU E-line, run a 9-5/8" EZSV w/ GR/CCL for 47# casing. Set the EZSV at -3191' MD. Rig Down E-line. 7. Pressure test the EZSV to 3,500 psi for 30 minutes and chart. 8. PU 9-5/8" whipstock, bottom trip anchor and 8.5" window milling assembly. RIH to the top of the ~ /o£~ EZSV. Orient and set the whipstock. Swap the well over to 9.8 ppg fresh water LSND milling fluid and mill a window in the 9-5/8" casing at -3174' MD (-mid-window) plus 20'-50' of new 9. Perform aLOT/FIT as required. POOH for drilling BHA. ~, 10. MU an 8-1 /2" drilling BHA with DIR/GR/RES/PWD and RIH. Kick off and drill 8-1/2" intermediate N interval to 7" casing point at the top of the Sag River CBU, wiper trip to shoe, run back to bottom °~`'~ and circulate well clean and POOH. ~ I ~ 11. Run and cement a 7", 26#, L-80 drilling liner (1000' tail cement job / -150' of liner lap). • • 12. M/U a 6-%:" DIR/GR/RES drilling assembly. P/U 4" drill pipe as required to TD the well and RIH to top of the float collar and test the casing to 3,500 psi for 30 minutes. 13. Displace the well to 8.5 ppg Flo-Pro SF fluid. 14. Drill out shoe and 20' of new formation and perform an FIT. 15. Drill build section and land well, per directional proposal. POOH to swap BHA. 16. MU a 6-1/8" BHA with PDC bit and DIR/GR/RES/NEU/DEN. RIH and drill ahead, per directional proposal and rig site geologist, to TD. 17. CBU at TD. Back ream to shoe, MAD passing as required by geologist. Circulate the well clean at the shoe and POOH. 18. Run and cement a solid 4-1/2", 12.6#, L-80, IBT-M liner from TD to 150' inside the 7" shoe and set the liner top packer and displace the well to seawater. 19. Test casing/liner to 3500 psi and perforate well on drillpipe (-1000' perfs). 20. Run the 4-1/2", 12.6#, 13Cr completion tying into the 4-1 /2" liner top. 21. Displace the well to clean fluids and drop ball & rod and set the production packer and individually test the tubing to 3,500 psi and annulus to 3,500 psi for 30 minutes each. 22. Shear valve in the upper GLM and confirm circulation. 23. Set and test a TWC to 5000 psi from above and 2000 psi from below. 24. ND BOPE. NU and test the tree to 5,000 psi. 25. Pull TWC. Freeze protect the well to 2000' TVD. 26. Set a BPV. 27. RDMO. Planned Post-Rip. Work: 1. Pull BPV. 2. Pull ball and rod / RHC plug. Set generic GLV design. 3. Install wellhouse, instrumentation, and flowlines. (flow-line fabrication WILL be required.) 4. ASRC well test Drilling Engineer: John Rose (907) 564-5271 Production Engineer: Alice Kaminski (907) 564-5676 Geologist: Alec Duncan (907) 564-4590 MCEVOY • OPS SHUTDOWN RWO J-206 13-3/8" CSG, 72#, L-80, ID = 12.347" I~ 2978' Minimum ID = 2.39" @ 11356' 4" BKR LNR TOP PKR GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 2 1 • µJ a~Ry ~pL 4-1/2" HES X NIP, ID = 3.813" 10 6`2~ 7" 26# L-80 scab liner cmt'd 3191 `-10792' 9-5/8" X 7" BAKER ZXP PKR I 10798' W/TIEBACK, ID = 7.5" TOP OF 7" LNR I~ 10887, 9-5/8" CSG, 47#, L-80, ID = 8.681" 11152' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 12250' 3-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" I~ 11628' PERFORATION SUMMARY REF LOG: MEMORY CCUGR/CNL ON 10/17/02 ANGLE AT TOPPERF: 88 @ 12100' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 12100 - 12400 O 10/18/02 2" 4 12600 - 12900 O 10/18/02 2" 4 13090 - 13170 O 10/18/02 14-1/2" LNR, 12.6#, L-80 NSCT, .0152 bpf, ID = 3.958" I-I 14140' G 4-1/2" WLEG 10 740` -FISH 10 872` -4-1/2" WRP 10.879` I MILLOUT WINDOW 11678 ' - 11685' 11353' 4" BKR LNR TOP PKR 11361' 4" BKR DEPLOYMENT SLV, ID = 3.0" 11628' 3-1/2" X 3-3/16" XO, ID = 2.800" 11666' TOP OF WHIPSTOCK W/ RA TAG 11754' I-13-3/16" X 2-7/8" MILLABLE XO, ID = 2.441" I 13185' I I 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" I 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.800" I-I 1 DATE REV BY COMMENTS DATE REV BY COMMENTS 06128/90 LGM ORIGINAL COMPLETION 08/11/96 SIDETRACK (J-20A) 10/19102 JDM/KK CTD SIDETRACK (J-20B) 05/30/09 N4ES RWO OPS SHUTDOWN (J-206) 06/01/09 PJC DRLG DRAFT UPDATES 03/19/10 SV DRAFT CORRECTION SAFETY N ES: CTD STRADDLE OF PERF INTERVA~ 10-13510 W/4-1 /2" X 2-7/8" BAKER PROD PKR TBG IN BET CTMD ON 2/ @ 13309' & 13575' W/2-7/8" 6.4# WEEN. 2-7/8" HES CIBP @ 13440' 14/01. PRUDHOE BAY UNff WELL: J-208 PERMfT No: 2021700 API No: 50-029-21716-02 SEC 9, T11 N, R13E, 1215' SNL & 802' WE1 BP Exploration (Alaska) MCEV OY WELLHEAD = ~ MCEVOY ACTUATOR = OTIS KB. E1EV = 70.3' BF. ELEV = 42.23' KOP = 800' Max Angle = 94 @ 13017' Datum MO = 11831' DatumTVD= 8800' SS I 13-3/8" CSG, 72#, L-80, ID = 12.347" I I 2978' I Minimum ID = 2.39" @ 11356' 4" BKR LNR TOP PKR 4-1/2" Kill String Cut -9600` MD 7" 26# L-80 scab liner cmt'd 3191 `-10792' 9-5/8" X 7" BAKER ZXP PKR I 10798' W/TIEBACK, ID = 7.5" TOP OF 7" LNR I--~ 10887' 9-5/8" CSG, 47#, L-80, ID = 8.681" 11152' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 12250' -FISH 10 872` ~4-1/2" WRP 10879` MILLOUT WINDOW 11678 ' - 11685' 11353' ~ 4" BKR LNR TOP PKR 11361' 4" BKR DEPLOYMENT SLV, ID = 3.0" 3-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" ~ 11628' PERFORATION SUMMARY REF LOG: MEMORY CCL/GR/CNL ON 10/17/02 ANGLE AT TOP PERF: 88 @ 12100' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 12100 - 12400 O 10/18/02 2" 4 12600 - 12900 O 10/18/02 2" 4 13090 - 13170 O 10/18/02 14-1/2" LNR, 12.6#, L-80 NSCT, .0152 bpf, ID = 3.958" I~ 14140' 11628' I-I3-1/2" X 3-3/16" XO, ID = 2.800" 11666' TOP OF WHIPSTOCK W/ RA TAG 11754' I~ 3-3/16" X 2-7/8" MILLABLE XO, ID = 2.441" PBTD I 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" I I 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.800" I DATE REV BY COMMENTS DATE REV BY COMMENTS 06/28190 LGM ORIGINAL COMPLETION 08/11/96 SIDETRACK()-20A) 10/19/02 JDM/KK CTDSIDETRACK(J-20B) 05/30/09 N4ES RWO OPS SHUTDOWN (J-20B) 06/01/09 PJC DRLG DRAFT UPDATES 03/19/10 SV DRAFT CORRECTION J-20B J-206 Poe-Rig Wells Work: Well left with Seawater and a 2200' of diesel on both sides of the kill string above the P&A cement plug. 13-3/8" Surface Casing cemented to Surface -Estimated TOC in OA -2256' MD GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 2 1 -Estimated TOC on 9-5/8" casing -5512` MD - Top P&A Cement Plug -9792` MD - 4-1/2" HES X NIP, ID = 3.813" 1'irb,626` PRUDHOE BAY UNfT WELL: J-20B PERMfr No: 1021700 API No: 50-029-21716-02 SEC 9, T11 N, R13E, 1215' SNL & 802' WEL BP Exploration (Alaska) Page 1 of 2 Schwartz, Guy L (DOA) From: Schwartz, Guy L (DOA) Sent: Friday, August 06, 2010 3:20 PM To: 'Rose, John G (ASRC)' Cc: Egbejimba, Uchenna J; Maunder, Thomas E (DOA) Subject: RE: J-206 P&A (PTD 202-170) John, After reviewing the well file and the information provided in your email the procedure you propose would meet the requirements stipulated by 20AAC25.110 section C. Since the open lateral (J-20B) is in the same pool as the target reservoir for the rig sidetrack there is no issue with crossflow of fluids between zones or pools. Additionally, even though the cement plug is almost 1700' and away from the open pert zone in J-20B the well will be properly contained from migrating to other strata or surface by the cement plug and confining 4.5" casing liner that was fully cemented. The commission has discretion regarding alternate methods of P & A wells and your cement plug above the fish would meet this requirement provided it passes a pressure test. Call me if there needs to be any further clarification or discussion. Regards, Guy Schwartz Senior Petroleum Engineer 793-1226 (office) 444-3433 (cell) From: Rose, John G (ASRC) [mailto:John.G.Rose@bp.com] Sent: Friday, August 06, 2010 12:17 PM To: Schwartz, Guy I_ (DOA) Cc: Egbejimba, Uchenna J Subject: FW: J-20B P&A Guy, As we consider the issues associated with the sidetracking of the J-206 welt to a new Ivishak Zone 2 target as the J-20C well, AOGCC approval of our P&A plan for the current J-20B well is a very critical issue which will have a significant impact on our moving forward with a sidetracking plans for this well. Therefore, given the following brief description of the well in its current condition and the proposed P&A, please provide some feedback as whether this plan meets AOGCC requirements: 1. J-206 is currently shut-in/suspended post the 4/09 RWO where "junk" was left in the well above a wireline retrievable plug (10,879' MD). 2. During the 4/09 RWO (which was designed to install a scab liner to resolve a PC/production packer leak), after cementing the scab liner and while trying to clean-out above 4.5" WRP, 3 fishing assemblies were broke off inside the 4-1/2" tubing and a significant effort was made to recover the junk and salvage the J-206 well. However, after the recovery of 2 of the fish, the current well was suspended with a partial boot basket and a 5' mill remaining in the well as un-recovered junk above the WRP. 3. J-20B is now being considered for a rotary sidetrack which will involve sidetracking the well from above the existing 7" scab liner out of the 9-5/8" casing at 3170' MD targeting new Ivishak Zone 2 reserves. 4. The proposed P&A for this well will be to pump cement down the existing 4-1l2" kill string placing a cement plug from the top of the WRP at 10,879' MD back up the well to 9792' MD on both sides of the kill string. Given our un-successful attempts to recover the existing junk in this well, the approval of this P&A plan will allow us to move forward with the our planning efforts for J-20C RST with a clear understanding of our P&A 8/6/2010 Page 2 of 2 requirements. I have attached a document to this a-mail which provides additional details of this well's history and RST plans as well as 2 well schematics detailing the well in its current condition as well as its planned post P&A condition, therefore, please advise as to your agreement/approval of this planned P&A. Thanks -jr Note: This planned P&A is based upon the AOGCC regulations as referenced below; http://www.legis.state. ak. us/basis/folioproxy.asp?u rl=http://wwwjnu01.leg is. state. ak. us/cgi- bin/folioisa.dll/aac/query=[JUMP;%2720+aac+25!2E112%27]/doc/{@1 }?firsthit (c) Plugging of cased portions of a wellbore must be performed in a manner that ensures that all hydrocarbons and freshwater are confined to their respective indigenous strata and are prevented from migrating into other strata or to the surface. The minimum requirements for plugging cased portions of a wellbore are as follows: (1) perforated intervals must be plugged by one of the following methods (A) by the displacement method, a cement plug placed from 100 feet below the base to 50 feet above the base of the perforated interval and from 50 feet below the top to 100 feet above the top of the perforated interval; (B) by the displacement method, a cement plug placed from the well's total depth to 100 feet above the top of the perforated interval; (C) by the displacement method, a cement plug placed from the well's plugged-back total depth to 100 feet above the top of the perforated interval, if all hydrocarbon-bearing, abnormally geo-pressured, and freshwater strata below are isolated; hc~-ever, the oomrnie~Ort wiH 8pprove pluggitp from tfte toP fi~ +dr' the toP ~ junk id of from the plugged-bac:k tom depth, ifi tfie ©orrxnission defiermines that the olbjees of this su till be met; John G. Rose BPa -Staff Engineer Once 907/564-.i 271 Cell 907/748-5223 FAX 9071564-4040 Home 907/243-8813 8/6/2010 Page 1 of 2 Schwartz, Guy L (DOA) From: Rose, John G (ASRC) [John.G.Rose@bp.com] Sent: Friday, August 06, 2010 12:17 PM To: Schwartz, Guy L (DOA} Cc: Egbejimba, Uchenna J Subject: FW: J-20B P&A Attachments: J-206 P&A PIan.ZIP Guy, As we consider the issues associated with the sidetracking of the J-20B well to a new Ivishak Zone 2 target as the J-20C well, AOGCC approval of our P&A plan for the current J-206 well is a very critical issue which will have a significant impact on our moving forward with a sidetracking plans for this well. Therefore, given the following brief description of the well in its current condition and the proposed P&A, please provide some feedback as whether this plan meets AOGCC requirements: 1. J-206 is currently shut-in/suspended post the 4/09 RWO where "junk" was left in the well above a wireline retrievable plug (10,879' MD}. 2. During the 4/09 RWO (which was designed to install a scab liner to resolve a PC/production packer leak), after cementing the scab liner and while trying to clean-out above 4.5" WRP, 3 fishing assemblies were broke off inside the 4-1/Z" tubing and a significant effort was made to recover the junk and salvage the J-20B well. However, after the recovery of 2 of the fish, the current well was suspended with a partial boot basket and a 5' mill remaining in the well as un-recovered junk above the WRP. 3. J-20B is now being considered for a rotary sidetrack which wilt involve sidetracking the well from above the existing 7" scab liner out of the 9-5/8" casing at 3170' MD targeting new Ivishak Zone 2 reserves. 4. The proposed P&A for this well will be to pump cement down the existing 4-1/2" kill string placing a cement plug from the top of the WRP at 10,879' MD back up the well to 9792' MD on both sides of the kill string. i Given our un-successful attempts to recover the existing junk in this well, the approval of this P&A plan will allow us to move forward with the our planning efforts for J-20C RST with a clear understanding of our P&A requirements. I have attached a document to this a-mail which provides additional details of this well's history and RST plans as well as 2 well schematics detailing the well in its current condition as well as its planned post P&A condition, therefore, please advise as to your agreement/approval of this planned P&A. Thanks - jr Note: This planned P&A is based upon the AOGCC regulations as referenced below: http://www. [egis.state.ak. us/basis/folioproxy.asp?url=http://wwwjnu01. legis. state. ak. us/cgi- bin/folioisa.dll/aac/query=[JUMP:%2720+aac+25!2E112%27]/doc/{@1 }?firsthit (c) Plugging of cased portions of a wellbore must be performed in a manner that ensures that all hydrocarbons and freshwater are confined to their respective indigenous strata and are prevented from migrating into other strata or to the surface. The minimum requirements for plugging cased portions of a wellbore are as follows: (1) perforated intervals must be plugged by one of the following methods: (A) by the displacement method, a cement plug placed from 100 feet below the base to 50 feet above the base of the perforated interval and from 50 feet below the top to 100 feet above the top of the perforated interval; (B) by the displacement method, a cement plug placed from the well's total depth to 100 feet above the top of the perforated interval; 8/6/2010 Page 2 of 2 (C) by the displacement method, a cement plug placed from the well's plugged-back total depth to 100 feet above the top of the perforated interval, if all hydrocarbon-bearing, abnormally geo-pressured, and freshwater strata below are isolated; however, the oomrrion w~l p >h~n the top of ~ or4he trop of p+mic iirtsr9~d +~t fart the plugged-back .depth, i~ the-cotr~rassiot>t determines that the obj~biv~a ' ~ Otis sub+an w~ be met; ,lohn G. Rose BPX - StafJ'Engineer Offzce 907/564-5211 Cell 907/748-5223 FAX 907/564-4040 Home 907/243-8813 8/6/2014 • J-20 History: • J-20B was a 2002 CTD sidetrack which targeted Zone 1 B reserves within the Southeastern gravity drainage block of J-pad. J-20B tested initially at 2,295 bopd, 2% wc, 2,383 GOR. At shut-in (8/19!06), J-20B was a competitive gravity drainage producer at 446 bopd, 36,680 GOR, 12% WC. J-20B was waivered for IAxOA communication post CTD sidetrack, per waiver policy annual MIT-OA's were conducted. The IAxOA waiver was canceled in early 2006, with OA repressurization (~50 psi/day) being manageable by bleeds. In August 2006, the field operator noted high IAP, a TIFL was performed and failed on overnight build-up rate. A caliper tog was run through the tubing indicating 2 joints of 70% penetration and 43 joints with 40 - 70 % penetration. The well was then secured with a PX plug set at X nipple at 10,778'. A CMIT- TxIAwas performed on the well in October, it failed with a leak rate of 0.13 bpm, suggesting that the well had one of the following; Packer Leak, Production Casing Leak, or Plug Leak. Due to the OT21 pipeline issues diagnostics and repairs were held until June 2008, when a TecWel leak detection log was run to identify the source of the failed CMIT-TxIA. The TecWel log identified a possible production packer leak at 10,754' and a definite production casing leak at 5,107'. A RWO was undertaken in April 2009 to mitigate a production packer and a production casing leak. Significant mishaps during the RWO operation led to the decision to ultimately "suspend" operations and leave the well in an unusable status. To repair the production casing leak at 5,107', the RWO operations cemented a 7" scab liner in place from 3,191' to 10,792'. Shortly after running and cementing the scab liner, amilling/clean out BHA was lost down hole, a dress-off BHA was lost downhole while prepping the original milling BHA for recovery, the dress-off BHA was recovered, and while attempting to recover the original fsh downhole the tools being used to fish sidetrack out of the 4-1/2" liner which prohibited additional tool runs from accessing the original fish. A 4-1/2" kill string, without a production packer, was run to 10,740'. Pre-rig diagnostics were conducted proving production casing and surface casing integrity with passing a GMIT-TxIA and MIT-OA on 7/15/1.0, respectively. Passing pack off testing of the tubing and inner casing was performed on 7/17J2010. Reason for Sidetrack: During the RWO all options were exhausted to recover the fish without success, the asset and RWO team at the time weighed the options and decided it was best to move the rig off of the well and suspend operations. In its current state, J-20B does not have access to the reservoir to allow for production. To return the well to production and access reserves a rotary sidetrack is required to be drilled. by June 3, 2011 per AOGCC. • • J-20B Current: TRE£- MCEVOY WELLHEAD- MCEVOY A CTLWTOR< OTtS KB. B_EV - 70.3' BF. ELEV = 42.23' ~xnngle- 94(S'il,360. OPS SHUTDOWN Datum MD = 1183 t' RW O Datum ND - 8800' SS ' 3-3/S" CSG. 72#. L-80. D - t2.34T 2978' Minimum ID = 2.39" @ 11356' 4" BKR LNR TOP PKR J ~2 O B SAFETY NOTES: CTD STRADDLE OF PERF INTERVAL 1 341 0-1 3 51 0 W14-1 t2" X 2-7;8" BAKER PROD PKRS ;6~ 13309' 8 13575' W2-778" 6.4# TBGIN BETW EEN. 2-78" HES CIBP @ 13440' cralD ON zr1 aro 1. 7" 26# L-80 scab liner cmt'd 3191 `-10792' 9-5.8' X T BAKERZXP PKR 10798' WTEBACK. D - 7.5' roP of 7' LNR 10887' -5,8' CSG. 47#. L-80. D - 8.681' 11152' 26#. L~ 60..0383 hpf. D - 6.276' 12250' ~-Z,O bpf. D= 2992' f"I 11628' FHZFORATION SlArf~MRY Rff LOG' Po6~10RY CCL/GRiCNL ON t0;t7l02 ANGLE %~.i TOP FERF~ 86~ t2t00' Note: Refer to F'roduclion DB for historcal pert data SeE SPF INTERVAL OpnrSgz GATE 2' 4 12100 - 12400 O tOr18~02 2' 4 12600 - 12900 O 10'18,92 2- 4 13090 - '.3170 O 10~t8~02 4-L2' LNR 12.6#. L-80 NSCT..0152 bof. D- 3.956' ~"-Z aA 6.2#. L-80..0076 bpf. D= 2.800' \ GA S LIFT MANDRELS ST MD ND DEV TYFE VLV LATCH PORT DATE 3 2 t -4-1/2" HES X NIP, ID = 3.813" ~ 10,626' 4-1/2" W LEG 10 740' -FISH 10,872' ---4-112` WRP 10878' MLLOIJT WPDOW 11678'- 11685' 11628' I--13-1!2'X3-3;i6'XO.D-2.800' 11666' TOP OF WHPSTOCK W+ RA TAG 11754' 3-3.16" X 2-L'8' MLLABLE XO. ID = 2441' S-zoB DAfE REV B~ CGIvA.1ET17S DATE REV BY COMMENTS 06/28/90 LGM ORIGINAL COMPLETION 08/11A6 SIDETRACK (J-20A) 10/19!02 JDMIKK CTD SIDETRACK J-20B) OSlJ0109 N4ES RWO OPS SHUTDOWN IJ-ZOB) 06,'0',b9 PJC DREG DRAFT UFUA tES 03+19!10 SV DRAFTCORREC7DN F'RUDFIOE BAY lJnfT WELL .F20B PffrMfr Ntr. a2021700 API No: 50-029-2'.716-02 SEC 9. T 1 t N. Rt 3E 12 t 5' SNL 8 802' WEL BP Exploratbn (Alaska) I • J-20B Proposed P8r,A: TREE- MCEVOY WELLHEAD- MCEVOY J 2O B AcruAroR= ons KB. EL EV - 70.3' BF. L1 EV - 42.23' KOP- 800' Max Angle = 94 @ 13017 Datum MD - 11831' Datum TVD- 8800' SS J-20B Post Pre-Rig Wells Work: Well left with Seawater and a 2200' of diesel on both sides of the kill string above the P8A cement plug. -13-3/8" Surface Casing cemented to Surface -Estimated TOC in OA -2256' MD 1 GAS LIFT MANDRELS Minimum ID = 2.39" @ 11356' 4" BKR LNR TOP PKR 41/2" Kill String Cut -9600' MD 7" 26# L-80 scab liner cmt'd 3191'-10792' W(TEBACK, ID = 7.5" I TOP OF 7" LNR ~--I 10887 9-518- CSG. 47#. L-80. ID - 8.681' 11152' 7' LNR 26#. L-80..0383 bpf. D - 6.276' 12250' 1z~ PERFORATION SUMMARY REF LOG: N1Bv1ORY CCLIGR/CNL ON 10/17/02 ANGLE AT TOP PERF: 88 @ 12100' Note: Refer to Produc5on DB for historical pert data SIZE SPF INTH7VAL Opn/Sqz DATE z" a 121oo-lzaoo 0 1a1aro2 2" a 126oo-lzsoo 0 1o/1s/o2 2" 4 13090 - 13170 O 10118'02 - J Zo ~ i`/ I t v' bpf. D - 2.800" 117 ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 2 1 -Estimated TOC on 9-5/8" casing -5512' MD -Top P8A Cement Plug -9792' MD -4-1/2" HES X NIP, ID = 3.813" 10,626' ~4-1/2" WLEG 10740` FISH 10872' ~4-1/2" WRP 10879' F ' MELOUT WINDOW 11678' - 11685' ~ ~ ~ ~ ~ I f I , 11353' 4"BKR LNR TOP R<R 11361' 4' BKR DEPLOY MENi SLV. D = 3.0" 11628' 3-1/2' X 3-3(16" XO, ID = 2.800" 11666' TOP OF WHIPSTOCK W/ RA TAG 11~ 7~ 3-3(16' X 2-718° MILLABLE XO. ID - 2.441" ZOB Zoz-(7a 13185' PBTD I 2-718' LNR. 6.16#. L-80, .0058 bpf. ID = 2.441" I DATE REV BY CONN 1L-7JTS DATE REV BY COMMENTS 06128/90 LGM OWGINAL COMPLETION 08111196 SIDETRACK (J-20A) 10119/02 JDM IKK CTD SIDEfRACK(J-208) 05130/09 N4t~ RWOOPS SHUTDOWN (J-208) O6i01rn9 PJC DREG DRAFT UFOA TES 03.~79i10 SV DRA FT CORRECTION PRUDHOE BAY UNR WELL: J-20B PERMR No: F2021700 API No: 50-029-21716-02 SEC 9. Tt t N, R13E 1215' SNL 8 802' WEL BP F~cploration (Alaska) SIZE SPF INTERVAL OPEN/SOZD 2 3/4° 4 12,630' - 12,720' OPEN 2 3/4" 4 12,780' - 12,870' OPEN 2 314" 4 OPEN y 2,830' - 13,090' 23/4" 4 OPEN 2 ~4" 4 13,150' - 13,200' OPEN 2 3/4" 4 13,410' - 13,510' OPEN GAS LIFT MANDRELS 4.5"x 1 S" Merle TPD' o. D(BKB) VDss Dev. 3 3,766' 3,215' 46° 2 7,408' 5,733' 48° 1 10,713' 8,001' 47° HES'X' HIGH PRESSURE Nipple (ID: 3.813") 41/2" Wireline Entry Guide (ID: 4.000°) 71W 4 t/2' MLAS-CV Sub (ID: 3.8827 Jul 25 1996 (16) Pulled out of hole to 0 ft. Made up~A no. 12 . Serviced Block line. R~ to 11210 ft. Held safety meeting. R.I.H. to 13022 ft. Drilled to 13326 ft. Circulated at 13326 ft. Held safety meeting. Circulated at 13326 ft. Pulled out of hole to 3705 ft. Pulled BHA. Jul 26 1996 (17) Pulled BHA. Tested BOP stack. Made up BHA no. 13 . Held safety meeting. R.I.H. to 11202 ft. Serviced Block line. R.I.H. to 13326 ft. Drilled to 13411 ft. Circulated at 13411 ft. Pulled out of hole to 11000 ft. Held safety meeting. Pulled out of hole to 3702 ft. Pulled BHA. Made up BHA no. 14 R.I.H. to 3702 ft. Jul 27 1996 (18) R.I.H. to 13411 ft. Drilled to 13440 ft. Held safety meeting. Drilled to 13750 ft. Held safety meeting. Drilled to 13950 ft. Jul 28 1996 (19) Drilled to 14140 ft. Circulated at 14140 ft. Held safety meeting. Pulled out of hole to 3705 ft. Pulled BHA. Made up BHA no. 15 . Held safety meeting. R.I.H. to 11254 ft. Circulated at 11254 ft. R.I.H. to 14140 ft. Jul 29 1996 (20) Circulated at 14140 ft. Pulled out of hole to 11200 ft. Held safety meeting. Serviced Block line. Pulled out of hole to 3303 ft. Pulled BHA. Held safety meeting. Rigged up Completion string handling equipment. Ran Casing on landing string to 7100 ft. Jul 30 1996 (21) ~ S_" L.~-~-- Ran Casing on landing string to 11020 ft. Circulated at 11020 ft. Ran Casing on landing string to 14140 ft. Circulated at 14140 ft. Held safety meeting. Batch mixed slurry - 87 bbl. Pumped spacers -volume 50 bbl. Displaced slurry - 240 bbl. Circulated at 10798 ft. Pulled Drillpipe in stands to 9260 ft. Circulated at 10760 ft. Pulled Drillpipe in stands to 3800 ft. Held safety meeting. Pulled Drillpipe in stands to 0 ft, Rigged up Drillstring handling equipment. Made up BHA no. 16 . Jul 31 1996 (22) Made up BHA no. 16 . Rigged down Drillstring handling equipment. R.I.H. to 10735 • • ~ SEAN PARNELL, GOVERNOR ~ __ t>•LC>•-7~~AT QII! ~ ~ 333 W. 7th AVENUE, SUITE 100 C~~S`ERQA-~01` C~r~IIS''SI~1~ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 May 4, 2010 Terrie Hubble Technical Assistant BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519 Dear Ms. Hubble, It has come to our attention that Operational Shut Down Code (OPSD) is being used against wells that don't require a sundry for this operation. Prudhoe Bay Unit J-20B, PTD 202-170-0 is one such well. Actually, the correct well status is a "shut in oil well" at this time. The following is the regulation for the OPSD code use: 20 AAC 25.072. Temporary shutdown of drilling or completion operations (a) If circumstances prevent the continuation of the program approved on a Permit to Drill (Form 10-401), or if an operator wishes to change drill rigs, the operator shall apply to the commission for approval to shut down drilling or completion operations temporarily. Based on the information received under this subsection, the commission will decide whether to approve the temporary shutdown of drilling or completion operations. The request for operation shutdown must be submitted on an Application for Sundry Approvals (Form 10-403), providing a full justification for the shutdown, a description of the proposed condition of the wellbore upon shutdown of drilling or completion operations, the approximate date when drilling or completion operations will resume, and a proposed program for securing the well during the period of shutdown. An Application for Sundry Approvals is not required for planned shutdowns of well operations, if those shutdowns are described in the approved Permit to Drill. (b) The operator shall file with the commission, within 30 days after operation shutdown, a complete well record on a Report of Sundry Well Operations (Form 10-404), including a summary of daily well operations as described in 20 AAC 25.070 3 and a copy of all logs run in the well as required by 20 AAC 25.071 b (6). The commission will, in its discretion, waive the requirements of this subsection if drilling or completion operations are to be resumed within 60 days after operation shutdown. (c) Shutdown of well operations does not establish a completion, suspension, or abandonment date for a well. (d} If well operations are not resumed within 12 months, the operator shall immediately proceed to abandon or suspend the well. Upon application of the operator, the commission will RBDMS MAY 07 SOq ~Oy1,~.~!? (a, ~1 O l Terrie Hubble Technical Assistant BP Exploration (Alaska), Inc. May 4, 2010 Page 2 of 2 extend the 12-month period, if the operator shows that operational circumstances beyond the operator's control prevent resumption within the 12-month period. History: Eff. 4/2/86, Register 97; am 11/7/99, Register 152 The PBU J-20B well was completed October 19, 2002 as an oil well and the above regulation doesn't apply to future well operations after the initial well completion date. To correct this error, the Commission requires that the three references to Operational Shut Down Well operations that are documented in the well history of well PTD # 202-170-0, PBU J-20B deleted, along with sundrys filed by BP Exploration with Commission approval dates and codes 5/30/2009 (ROPSD), 6/3/2009 (IOPSD) and 4/9/2010 (IOPSD). If you are aware of other wells in similar circumstances, please also make the necessary corrections for those wells. Sincerely, Daniel T. Seamount, Jr. Commissioner, Chair • • Chris Stone Production Engineer ~, ~ ~~~~ ~ BP Exploration (Alaska), Inc. f: -~~~~a;~s.% ~!`'' ~' P.O. Box 196612 ~ Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU J-20B Sundry Number: 310-107 Dear Mr. Hobbs: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Chair DATED this day of April, 2010. Encl. STATE OF ALASKA °t ~A'10 ALASK~L AND GAS CONSERVATION COMMtS~I APPLICATION FOR SUNDRY APPROVAL 20 AAC 2s.2so RECEIVE nPR o 7 20~0~ ~O 1. Type of Request: 4~8t~6~OtIS.~m~lOft ^ Abandon ^ Plug for Redrill ^ Perforate New Pool ^ Repair Well ^ Change Approved Prog~1(N3Q8 ^ Suspend ^ Plug Perforations ^ Perforate ^ Pull Tubing ^ Time Extension - ®Operations Shutdown ^ Re-Enter Suspended Well ^ Stimulate ^ Alter Casing _ ®Other Extend Ops Shutdown to 06/03/2011 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ®Development ^ Exploratory 202-170 - 309-184 8r 309-105) 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21716-02-00 - 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 J-20B - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. Field /Pool(s): ADL 028281, 028284, 028280 - Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (tt): Effective Depth MD (ft): Effective Depth ND (ft): Plugs (measured): Junk (measured): 13230' ` 9010' 1 13185' ~ 9012' - 10879' • _10872' Casin Len th Size MD ND Burst ~ Colla Structural Conductor 1 ' Surface 7 ' 1 - / " 7 ' 74 ' 4 70 Intermediate 111 - / " 111 7 47 Production Liner 471' 7" 1 7' - 113 1 7' - 4 7 4 5410 Liner 8 ' -1 / " 1 ' - 11 7 ' 1 ' - 7 84 7 Liner 3-1/2" x 3-3/16" x 2-7/8" Liner 7 1' 7" 1 1' - 1 7 - 1 4 1 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (tt): Below Plug: 12100' - 13170' 8997' - 9013' 4-1/2", 12.6# (Kill String) L-80 10740' Packers and SSSV Type: None (Kill String) Packers and SSSV MD (tt) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: June 03, 2010 ®Oil • ^ Gas ^ WDSPL ^ GSTOR ^ Abandoned 16. Verbal Approval: Date: ^ yyl~ ^ GINJ ^ WAG ^ Plugged ^ SPLUG Commission Representative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name Chris Stone Title Production Engineer Prepared By Name/Number: Signature ,~ Phone 564-5518 Date 1~ Terrie Hubble, 564-4628 Commission Use Onl Conditions of approval: Notify Commission so that a representative may witness - .O _ M Sundry Number: lJ ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance t S/A u~.,r~ ~ ~f 3f ~~ a p Other: Subsequent Form Required: NOS APPROVED BY /v ~ f Approved By: COMMISSIONER THE COMMISSION Date Form 10-403 F2ev1c~12//2009 ~ Submit In Duplicate 5' f'/o ~,~%'i ~~~'~. BRIG{DIAL ~~~~~ ~' b i:~ :~i Chris Stone ~~~j~;;~ Production Engineer BP Exploration (Alaska) Inc. GPB -Gravity Drainage 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (907) 561-5111 April 7, 2010 Alaska Oil & Gas Conservation Commission 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 Reference: API # 50-029-21716-02-00 Permit # 202-170, PBU J-20B Direct: (907) 564-5518 Christopher.Stone~bp.com To Whom It May Concern: During a RWO in May 2009 a partial BHA fishing assembly was lost in the well above a WRP. The BHA fishing assembly was never recovered after multiple fishing attempts and was ultimately left in the well blocking access to retrieving the WRP. This has prevented access to the existing perforations as the WRP is still in the well securing the perforated interval. An "Operations Shutdown" was approved on 6/3/2009. We would like to request an extension of the Operations Shutdown for one additional year on well J-20B, to ensure that there is sufficient time devoted to the reservoir studies for well placement, drilling package preparation and placing the package on the drilling schedule. We are requesting that the Operations Shutdown be extended to 06/03/2011. Si cerely, ti~~~ Chris Stone Distribution Well Files PDC `TREE'= ~ MCEV OY WELLHEAD= MCEVOY AZ;TUATOR = OTIS KB. ELEV - 70.3' BF. ELEV = 42.23' KOP = 800' Max Angle = 94 @ 13017' Datum MD = 11831' Datum TV D = 8800' SS ~ / 1.J YY® J -~ 0 ~ SAFETY N : CTD STRADDLE OF PERF INTERVAL 13410-13510 W/4-1 /2" X 2-7/8" BAKER PROD PKRS @ 13309' & 13575' W/2-7/8" 6.4# TBG IN BETWEEN. 2-7/8" HES CIBP @ 13440' CTMD ON 2/14/01. 13-318" CSG, 72#, L-80, ID = 12.347" I-{ 2978' Minimum ID = 2.39" @ 11356' 4" BKR LNR TOP PKR C;AS I IFT MANDRELS ST MD TV D DEV TYPE V LV LATCH PORT DATE 3 2 1 112" F-I~S X NIP, 1D = 3.813" 10,626` 7" 26# I_-80 scab liner cmt'd 3191 `-10792' 9-5/8" X 7" BAKER ZXP PKR I 10798' W/TIEBACK, ID = 7.5" TOP OF 7" LNR I-j 10887' 9-5/8" CSG, 47#, L-80, Ip = 8.681" 11152' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 12250' 3-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" ~-{ 11 PERFORATION SUMMARY REF LOG: MEMORY CCL/GR/CNL ON 10/17/02 ANGLE AT TOP PERF: 88 @ 12100' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 12100 - 12400 O 10/18/02 2" 4 12600 - 12900 O 10/18/02 2" 4 13090 - 13170 O 10/18/02 14-1/2" LNR, 12.6#, L-80 NSCT, .0152 bpf, ID = 3.958" I-I 14140' ® i s l-~I 1 p 872' ,.._a__~_...:: I MILLOUT WINDOW 11678 ' - 11685' 11353' 4" BKR LNR TOP PKR 11361' 4" BKR DEPLOYMENT SLV, ID = 3.0" 11628' 3-1/2" X 3-3/16" XO, ID = 2.800" 11666' TOP OF WHIPSTOCK W/ RA TAG • 11754' 3-3/16" X 2-7/8" MILLABLE XO, ID = 2.441" 1 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" I-I 13230' I 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.800" I I 11754' I DATE REV BY COMMENTS DATE REV BY COMMENTS 06/28/90 LGM ORIGINAL COMPLETION 08/11/96 SIDETRACK()-20A) 10/19/02 JDM/KK CTD SIDETRACK (J-206) 05/30/09 N4ES RWO OPS SHUTDOWN (J-20B) 06/01/09 PJC DRLG DRAFT UPDATES 03/19/10 SV DRAFT CORRECTION PRUDHOE BAY UNIT WELL: J-206 PERMrr No: 2021700 API No: 50-029-21716-02 SEC 9, T11 N, R13E, 1215' SNL & 802' WEL BP Exploration (Alaska) Schlum6erger Alaska Data & ConsWting Services 2525 Gam6e11 Sireet, Suile 400 Mchorage, AK 99503-2B3B ATTN: Beth weu ~~2~" ~ ~ ~v~ ~~ Job # Log Descripiion Date BL N0.5353 Company: State of Alaska Alaska Oil & Gas Cons Comm Atln: Christine Mahnken 333 West 7th Ave, Suite 10D Mchorage, AK 9950t Color CD 09/11/09 . ~a ~ ~f~ ~ _w a _. ~~ ~ "!P.^' V-02 W-26A H32 82WY-OQ078 B7 JJ-00033 ANHY-00102 MEM PRODUC770N PROFlLE ' MEM PRODUCTION PROFIIE ~ PRODUCTION PROFIIE ~ L- 07/27/09 07/26/09 07/25l09 1 / / 1 1 1 P2•29 12-11 L2-06 P2-28 L-213 V-221 L-220 AVTU-00052 ANHY•00106 B68K•00007 AYTU-00051 B2WV-00019 N(80.00037 B1JJ-00035 INJECTION PROFILE ~ ~~-~ LDL CROSS FLOW CHECK ~ INJECTION PROFILE C. - MEM INJECTION PROFI E' MEM INJECTION PROFILE" MEM INJECTION PROFILE ~ OB/04/09 08/0Y/09 07/31/09 08/01/09 07/29/09 07/28/09 07/30l09 1 1 1 1 7 1 1 1 1 1 ~ 1 1 7 07-22 AZCM-00036 PRODUCTION PROFILE ~ ~ ' 08/09/09 1 ~ 04-02A AYS4A0091 USIT ~ 08/11/09 1 1 J-11A Lt-09 X•2B L2-06 AWLB-00029 AYS4-00089 AXBD-00026 B3SU-00020 USIT PRODU TION PROPILE '_Qp (p MEM INJECTION PROFILE V PRODUCTION PROFILE - 08/OSl09 OB/OB/09 05/17/09 08/14/09 1 1 1 1 1 1 7 1 3-29/J-32 AP3~-00055 IBP SET RECORD W/CROS GLOW 08/08/09 1 1 06-04A BSJN-00009 RST 08/23l09 1~ 1 15-498 82NJ-00013 MCNL 07/15/09 1 1 03-328 09AKA0030 OH MWD/LWD EDIT 02/28/09 2 ~ G-146 AWJI-OOD43 MCNL 07/24/09 1 ~ L2-73A AWJI-00036 MCNL OW17/09 1 18•02B AWJI-00045 MCNL $~ OB/17/09 1 1 P1-05 AWLB-00032 RST 08/09/09 1 1 B-16A 62WY-00020 MCNL '~ (7 08/03/09 1 ~ J-20B AXBD-00020 MCNL (REVISED) . j~ i ;"L 04/12/09 ~ o~ cecc nrrunw~ cnr_e oen c~or ov c~...~..~ .. ..~....~.~. ~.,.~.........~ ........ _'_" __ BP Exploralion (Alaska) Inc. Petwtechnical Data Center LR2-1 900 E. Benson Blvd. r.~~ i~±', _ 'tili~~.. ... _... ,.. aax,t% ,,. . .. Alaska Data 8 Consulting Services 2525 Gambell Sirset, SuAe 400 Mchorage, AK 99503-2838 • ~ .~-/~ ~~ STATE OF ALASKA ~ ~ ~ ~ ~'~~ ~~.`~~ A~ OIL AND GAS CONSERVATION CO~SION REPORT OF SUNDRY WELL OPERATIONS JUN 1 8~QO~ APnnL.. {'l:l O_ I'+__ n__ _ 1. Operations Performed: ^ Abandon "~Repair Well ^ Plug Perforations ^ Stimulate n --` ^ Re-Ef~t~F~s~'nded Well ~ Alter Casing - ~ Pull Tubing ~ ^ Perforate New Pool ^ Waiver ^ Other ^ Change Approved Program ~ Operation Shutdown" ^ PerForate ^ Time Extension 2. Operator Name: 4. Well Class Before Work: 5. Permit To Drill Number: BP Exploration (Alaska) Inc. -~ Development ^ Exploratory 202-170 - 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21716-02-00- 7. KB Elevation (ft): 70 33' ~ 9. Well Name and Number: . PBU J-20B. 8. Property Designation: 10. Field / Pool(s): , ADL 028281, 028284, 028280 ~ Prudhoe Bay Field / Prudhoe Bay Oil Pool 11. Present well condition summary Total depth: measured 13230' ~ feet true vertical 9010' ' feet Plugs (measured) 10879' Effective depth: measured 13185' ~ feet Junk (measured) --10872' true vertical 9012' - feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" 110' 110' Surface 2978' 13-3/8" 2978' 2746' 4930 2670 Intermediate 11152' 9-5/8" 11152' 8382' 6870 4760 Production Liner 471' 7" 10887' - 11304' 8197' - 8487' 7240 5410 Liner 880' 4-1/2" 10798' - 11678' 8136' - 8756' 8430 7500 Liner 1869' 3-1i2" x 3-3/~6" x 2-7/8" 11361' - 13230' 8526' - 9010' 10160 10530 Liner 7601' 7" 3191' - 10792' 2896' - 8132' 7240 5410 Perforation Depth MD (ft): Below Plug: 12100' - 13170' Pertoration Depth ND (ft): 8997' - 9013' 4-1/2", 12.6# (Kill String) L-80 10740' Tubing Size (size, grade, and measured depth}: Packers and SSSV (type and measured depth): None (Kill String) 12. Stimulation or cement squeeze summary: Intervals treated (measured): ~J~b ~~f~iY~ f , ~~~ +t ~ 3, ~ L t 7 i ~Q ~ * p ~.. D ~~a ~ ~ t~ J ~ J~ , Treatment description including volumes used and final p ressure: Cut and pull tubing, mill packer. Run 7" (26#, L-80) scab liner from 3191' to 10792' and cemented w/ 195 Bbls Class 'G' (Yield 1.16). Partia! fishin assemb! !eft in hole above WRP. Ran kil l strin and tem oraril shutdown o erations. 13. Re resentative Dail Avera e Production or In'ection Data Oil-Bbl Gas-Mcf Water-Bbl Casin Pressure Tubin Pressure Prior to well operation: Subsequent to operation: 14. Attachments: ~ Copies of Logs and Surveys run 15. Well Class after work: , ^ Exploratory ~ Development ^ Service ~ Daily Report of Well Operations 16. Well Status after work: ~ Well Schematic Diagram ~ Oil ^ Gas ^ WAG ^ GINJ ^ WINJ ^ WDSPL 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O. Exempt: Contact Hank Baca, 564-5444 309-184 (8~ 309-105) Printed Name Terrie Hubble Title Drilling Technologist Prepared By Name/Number: ~7 ~ Signature Phone 564-4628 Date Terrie Hubble 564-4628 Form 10-404 Revised 04/2006 _,_ _.. `~~+ ~~ ~ U~ ~ 5 200S Submit Original Only ~ ~~~ ~ ~~~ y • • ~~ J-20B, Well History (Pre Rig Workover) Date Summary 4/11/2009 ARRIV ON LOC WELL S/I. PULLED P. PRONG & PX PLUG BODY FROM X-NIP~ 10786' SLM (10778' MD). DRIFT TO 12008' SLM (STOPPED DUE TO DEV~ W/ 2.25" CENT, S.BAILER. NO SAMPLE RECOVERED. RAN W/ NEUTRON LOGGING. 4/11/2009 T/I/0= 175/940/940 Assist SLB w/ Loq. Load and kill tubing with 210 bbls 120° 1% kcl C~ 5 bpm, pumped 50 bbls 1% kcl at 2 bpm to maintain hole fill. Pumped 30 bbls 1% kcl at .75 bpm during S/L logging. 4/12/2009 RAN SLB CNL MEMORY LOG. GOOD DATA RECORDED. MADE ATTEMPT TO DRIFT W/ 3.77 W RP DMY SAT C«~ 10816 SLM. RAN 3.625" CENT, 2' x 1-7/8" WB, 3.70" CENT ON 4" LNR TOP @ 11365' SLM (11353' MD). NO TIGHT SPOTS ENCOUNTERED. RAN 4 1/2" X-CATCHER TAGGED BTM X-NIP C«3 10808' SLM (10798' MD). SET WFD WRP (3 77'x 3 69 od) C~ 10861' SLM (10852~ I~L1MP 9- 50# SAG OF SLUGGITS ON TOP OF WRP @ 10850' MD TOP OF SLUGGETS C~ -10_..$~T_~D. JOB COMPLETED TURN WELL OVER PAD OPER. 4/12/2009 Pumped 70 bbls 120° - 1%kcl at .8 bpm to assist with log. Freeze arotect tubinq with 42 bbls neat~]1Pih.. Wing closed. Swab, SSV, Master, IA, OA valves open on departure. S/L in control of well. FWHP's = vac/1000/800. 4/13/2009 T/I/0= Vac/960/790, Temp= S/I, CMIT-TxIA to 500 psi; MIT-OA t0 2000 psi. ~aD sh~t a fluid IPy,~I on IAFL C~3 7100'. IA loaded with gas. Job postponed. FWHP's = Vac/960/790. SV, WV, SSV = SHUT / MV, IA, OA = OPEN. 4/13/2009 T/I/O=SSV/980/860. Temp=Sl. Bleed IAP to 500 psi. No A/L. IA FL C~ 7130'. Unable to bleed, will need UR tank to bleed. NOTE: No well house on well. Cellar boards are frozen into the ground, cannot cycle OA valve due to boards in the way. Installed plastic over top of cellar boards & cellar with a heater to thaw. No WV, SSV - Closed, MV = Open, IA, OA = OTG. NOVP. 4/14/2009 T/I/0= 0+/930/810. Temp= SI. Bleed IAP <300 psi, OAP to 0 psi (pre-Rig). No AL. Note: No welihouse or flowline. Contacted grease crew to open SSV, and service tree. Contacted subsidence Foreman to have snow/timbers removed around well head. Rapid bubblinq cominq from conductor @ the 11 o'clock position (3-4 bubbles per secondZ. IA FL C~ 7130'. OA FL @ 228'. Bled IAP from 930 psi to 200 psi in_ 3 5 hrs to DHD UR (all gas) While bleeding IAP bled OAP from 810 psi to 0 psi in 2 5 hrs to bleed tank (all gas). Bubbling in conductor stopped. SI, monitored for 30 mins. IA & OA FL unchan9~ci. IAP increased 1 psi to 210 psi, AP increased to 0+. FWHPs= 0+/210/0+. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 4/15/2009 T/I/0= 0/220/20. Temp= SI. Install spill containment pre-MIT-OA. Unable to install containment due to ,c~ravel covering conductor. SV, WV = Closed. SSV, MV = Open. IA, OA = OTG. NOVP. 4/16/2009 T/I/0= 0+/230/20. Temp- SI. Assist FB w/ MIT-OA. TBG FL C~ 36' (1 bbls). IA FL Q 7130' (382 bbls~. ~A FL Q 228' (14 bbls). Installed secondary containment around conductor. Removed -4" of cement from flutes. Increased OAP to 2000 psi w/ diesel, lost 80 psi ist 15 mins, 40 psi in 2nd 15 mins for a total loss of 120 psi. TP & IAP unchanged during MIT. No fluid returns from conduc~nc. No LEL's, 02 = 21.6%. Pumped 382 bbls to fill volume in IA for CMIT-TxIA. Bled aas cap off IA. Bled OAP from 40 psi to 0 psi in 15 mins to bleed tank. LRS on location conducting CMIT-TxIA. FWHPs= 480/80/0. LRS has control of well head. 4/16/2009 T/I/0=0/220/0 Temp=Sl MITOA PASSED to 2000 psi CMIT TxIA PASSED to 500 psi. Pumped into OA with 2 bbls meth, 12.9 bbls crude to reach test pressure for MITOA. OA lost 80 psi in the 1st 15 mins and 40 psi in the 2nd 15 mins for a total pressure loss of 120 psi in 30 mins. Bled OA to 100 psi. Rigged up to IA. Pumped into IA with 5 bbls meth, 413 bbls crude to reach test pressure for CMIT TxIA. T/IA lost 20/40 psi in the 1st 15 mins and 10/0 psi in the 2nd 15 mins for a total pressure loss of 30/40 psi in 30 min test. Bleed T/IA. FWHP's = 0/60/0. Swab, Wing = shut. SSV, Master, IA, OA = open. IA & OA tagged. 4/17/2009 T/I/0= 40/45/10. Temp= SI. Monitor WHPs. TP unchanged, IAP decreased 10 psi, OAP increased 10 psi overnight. SV, WV - C. SSV, MV = O. IA, OA = OTG. NOVP. Page 1 of 2 ~ • J-20B, Well History (Pre Rig Workover) Date Summary 4/17/2009 T/I/0= 40/55/10. MITOA W/N2. OA FL near surface. Increased OAP from 10 psi to 500 psi w/N2. OAP decreased 15 psi in the first 15 minutes, 5 psi in the second 15 minutes for a total of 20 psi loss in 30 minutes. OA FL unchanged Bled OAP from 500 psi to 0 psi in 2 minutes. 02=20.9, LEL's=0%. Final WHP's=40/55/0. SV, WV = C. SSV, MV = O. IA, OA = OTG. NOVP. 4/18/2009 WELL S/I ON ARRIVAL. DRIFT W/ 4-1/2" BLB, 3.805" G.RING, UNABLE TO PASS X-NIP C~ 10,775' SLM. DRIFT W/ 4-1/2" BLB, 3.625" G.RING, TAG TOP OF SLUGGITS C~1 10820' ~. DRIFT W/ 3.77" WFD DMY WRP, TAG SLUGGITS C~3 10820' SLM. DRIFT W/ 3.805" CENT, 3' STM, WFD DRIFT, UNABLE TO PASS X-NIP W/ CENT. 4/18/20Q9 T/I/0=0/0/0, Temp=Sl. PPPOT-T (PASS), PPPOT-IC (PASS). Pre RWO. PPPOT-T: Opened slotted bleeder screw to verify 0 psi in test void. Removed internal check and installed Afemite external check. Functioned LDS, all moved freely (2.5"). Pumped through void, clean returns. Pressured void to 5000 psi for 30 min test, lost 200 psi in 15 min, lost 50 psi in second 15 min. Bled void to 0 psi. PPPOT-IC: External Alemite check previously installed. Bled test void to 0 psi. Functioned LDS, all moved freely (2.5"). Pumped through void, clean returns. Pressured void to 3500 psi for 30 min test, lost 100 psi in 15 min, lost 0 psi in second 15 min. Bled void to 0 psi. 4/19/2009 MAKE MULTIPLE PASSES THRU HP X-NIP C~ 10,775' SLM W/ 3.79" B.BELL, BAIL -7 GAL. OF SLUGGITS W/ 10'x3.5" P.BAILER FROM 10,820' TO 10,828' SLM. ATTEMPT TO PULL W~P. UNABLE TO LATCH. RAN 3.75" L.I.B.TO 10,828' SLM, PIC OF WRP SHEAR BOLT. 2 RUNS W/ 2.5" HYDRO.BAILER W/ 3.5" BTM TO 10,828' SLM (- 2 CUPS). PULL 3.69" WRP FROM 10,829' SLM (ALL, I NTACT). 4/20/2009 T/I/0=100/20/20 CMIT TxIA PASSED to 500 psi. Pumped 55.7 bbls crude down IA to reach test pressure for CMlT TxIA. T/IA lost 10/10 psi in the 1 st 15 mins and 0 psi in the 2nd 15 mins for a total pressure of 10/10 psi in 30 min test. FWHP's=300/40/20. Slickline in control of well upon departure. 4/20/2009 BRUSH / DRIFT W/ 3.79" CENT, 4-1/2" BLB, 3.79" G.RING FROM 10,800' TO 10,900'. FLAG WIRE W/ 4-1/2" X-LINE (HP X-NIP) C~ 10,778' SLM (+20' CORR). SET 4-1/2" WRP MID ELEMENT Q 10,82~' SLM (+21' TOOL & SLM CORR= 10,850' MD). LRS PERFORMED CMIT-TxIA (PASS). DUMP (2) 50# BAGS OR 12.5' SLUGGITS ON WRP, TOP C~ 10,816' SLM (10,838' MD). WELL S/!, PAD-OP NOTIFIED OF ALL WELL & VLV CONDITIONS. 4/24/2009 WELL SHUT-IN ON ARRIVAL. INITIAL T/I/O = 250 / 100 / 0 PSI. RIH WITH 3.65" MAX OD POWER CUTTER. CUT 4-1/2" TUBING AT 10749'. TIED INTO TUBING TALLY DATED 08/10/96. WELL LEFT SHUT IN. PAD OP NOTIFIED OF VALVE POSITIONS ON DEPARTURE. FINAL T/I/O = 230/150/0. JOB COMPLETE. 4/25/2009 T/I/0-200/80/20 Circ-out Well. Hardline rigged up to take Circ returns down J-09 flowline. Pumped 10 bbls of 30°F meth down J-09 Tbg in attempt to shut master valve (valve only closed part way), thought it might be due to hydrates. IBP most likely stuck in tree. Hardline crew to RU hardline jumper to J-23 for returns. Started circ-out, Job in progress. 4/26/2009 Circ-out Well. Pumped a total of 5 bbls neat, 1050 bbls 1% KCL, 150 bbls diesel down Tbg taking returns to J-23 flowline. U-Tubed diesel from Tbg to IA. Pumped 1 bbi neat and 5 bbls diesel down jumper line to J-23. Brought J-23 back on line. Freeze protected J-09 flowline with 7 bbls neat and 45 bbls crude. Bled all wellhead pressures to 0 psi. Final WHP's = vac/vac/0. SV = C, MV = O, SSV = C, IAV - OTG, OAV = OTG. 4/26/2009 T/I/O=Vac/0/0. Set 6-3/8" CIW J BPV #403 thru tree, pre 4es. 1-2' ext used, tagged C~ 108". No problems. Page 2 of 2 , ~ • B P' E~ Qperations Legal Well Name: J-20 Common Well Name: J-20 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 4ES ~ Date From - To Hours Task Code NPT 4/26/2009 18:00 - 18:30 0.50 RIGD P 18:30 - 22:00 3.50 RIGD P 22:00 - 23:30 I 1.501 MOB I P 23:30 - 00:00 0.50 MOB N 4/27/2009 00:00 - 02:00 2.00 MOB N 02:00 - 06:00 4.00 MOB P 06:00 - 07:30 1.50 MOB P 07:30 - 10:00 2.50 RIGU P 10:00 - 12:00 2.00 RIGU P 12:00 - 14:00 2.00 KILL P 14:00 - 15:30 1.50 KILL P 15:30 - 16:30 1.00 KILL P 16:30 - 17:00 0.50 KILL P 17:00 - 19:30 2.50 KILL P 19:30 - 20:00 0.50 KILL P 20:00 - 22:30 2.50 WHSUR P 22:30 - 00:00 I 1.501 WHSUR I P 4/28/2009 I00:00 - 01:30 I 1.50 ~ WHSUR I P 01:30 - 03:00 1.50 BOPSU P 03:00 - 04:00 1.00 BOPSU P 04:00 - 13:30 9.50 BOPSU P 13:30 - 16:00 I 2.50 I W HSU R I P 16:00 - 17:00 I 1.001 PULL I P N Spud Date: 8/1 /1996 Start: 4/26/2009 End: 5/31 /2009 I Rig Release: 5/31/2009 Rig Number: Phase Description of Operations PRE Perform pre-tour checks. Inspect equipment & Service rig. Prepare to RDMO. PRE Raise Beaver slide. Scope derrick down. RD rig floor equipment. Bridle up and lay derrick over. Ready rig to begin move. PRE Hold weekly safety meeting with Brandenburg crew. Discuss recent incidents, upcoming EMS audit and current safety bulletins. Focus on driving safety. Waiting on trucks to be available to move rig. (Currently moving 3S) Wait on truck availability (currently moving 3S). Move rig and camp from M-pad to J-pad. Move pipe shed and pits first. Then move sub and rig camp. Finish moving Nabors 4es to J-Pad. Spot Sub Base on J-20 Well Slot. Spot and hook up Pits, Pipe Shed, and Camp. PRE Raise and scope up Derrick. Spot Tiger Tank. Rig up lines. Acceot Ria at 12:00 hrs. DECOMP Take on first load of hot Sea Water in Pits. Continue rigging up misc equipment. Start to load 3 1/2" Drill Pipe in Pipe Shed. DECOMP Pick-up Lubricator. Test to 500 psi. Pull BPV. Lav dn~n same. Tubing on sli ng t vacuum., Casing = 0 psi. Outter Annulus = 100 psi. DECOMP Hook up line to the Production Tree. Test line at 3,500 psi. good. DECOMP FJSM for Well Kill Operations. Perform final environmental walk to double check lines and Tiger Tank. DECOMP Displace well with 760-bbls of clean 8.5-ppg seawater at 5.3-BPM with 550-psi. DECOMP Monitor well for 30-minutes - Static. DECOMP Hold PJSM on setting TWC. Cameron rep t-bar in TWC. Test TWC below to 500- si for 10-charted minutes. Test TWC above to 3500- si for 10-charted minutes. Good tests. DECOMP Hold PJSM on ND tree. Blow down and RD circulating lines. ND production tree. 2 barriers for ND tree are 1) Tested TWC and 2) WRP at 10,850'. DECOMP Continue ND tree and adapter flange. Cameron tech terminate control lines. MU 7" IJ4S XO with 7-1/4 turns. Function~,l~ LDSs. Clean ring groove. DECOMP PJSM on NU BOP stack. NU BOP stack, choke & kill lines. Install riser. DECOMP RU to test BOPE. Fill lines. Function rams. DECOMP Perform initial BOPE test per BP procedures and AOGCC regs. Test 3-1/2" x 6" VBRs using 3-1/2" & 4-1/2" test jts. Test annular using 3-1/2" test jt. Test to 250-psi low and 3500-psi high. Hold and chart each test for 5-minutes. AOGCC rep Lou Grimaldi, BP WS~ and Nabors Toolpusher witnessed test. DECOMP Rig up Dutch lubricator lockdown mandrel. Pick up DSM lubricator and essure test to 500- si. Pull and la down TWC. Lay down DSM lubricator and Dutch lubricator lockdown mandrel. DECOMP Makeup 3-1/2" DP landing joint with closed TIW valve and XO to 7" IJ4S hanger top thread. Cameron welihead technician WAIT PRE WAIT PRE PRE PRE PRE Printed: 6/8/2009 11:38:45 AM ~ • # BP EXPLQRATION Page 2 c~f 25 Qperations Summary Report Legal Well Name: J-20 Common Well Name: J-20 Spud Date: 8/1/1996 Event Name: WORKOVER Start: 4/26/2009 End: 5/31/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/31/2009 Rig Name: NABORS 4ES Rig Number: Date' From - To Hours Task Code NPT Phase Deseription of Operations 4/28/2009 16:00 - 17:00 1.00 PULL P DECOMP BOLDS. Applied 123K upweight with no upward movement from tubing hanger. Slacked off and Cameron welihead technician reconfirmed all lockdown screws backed out the required distance. Applied 122K upweiqht and tubina hanaer came free. Hoisted tubing hanger to rig floor with traveling weight varying from 123K to 125K. 17:00 - 18:00 1.00 PULL P DECOMP Disconnect dual control lines. Lay down landing joint and tubing hanger. Hook up circulating lines to tubing. 18:00 - 19:30 1.50 PULL P DECOMP Circulate bottoms up at 5.5-BPM with 310-psi. RU control line spooler while circulating. Monitor well - Static. RD circulating equipment. 19:30 - 22:30 3.00 PULL P DECOMP Pull and LD 4-1/2" 12.6# L80 BTC tb~from surface to SSSV, Spool up dual 1/4" Stainless steel control lines while POH. Recover 53-jts of 4-1/2" tbg, 1-SSSV assembly and 56-SS bands of 56-SS bands reported. 22:30 - 23:30 1.00 PULL P DECOMP RD Schlumberger control line spooler. While rigging down Schlumberger, circulate at 5.5-BPM with 270-psi to clean up fluid and pipe. 23:30 - 00:00 0.50 PULL P DECOMP Pull and LD 4-1/2" 12.6# L80 BTC tubinq. Beqin seeinq mild internal and pin end corrosion at jt #70 (-2900'). 4/29/2009 00:00 - 06:00 6.00 PULL P DECOMP Pull and LD 4-1/2" 12.6# L80 BTC / NSCT completion. At 0330-hrs, LD 4-1/2" BTC x 4-1/2" NSCT XO (after Jt #166 OOH). Hold Kick while Tripping Drill and review drill with Brandenburg crew. Continue to pull and LD 4-1/2" completion. Light internal and pin end corrosion continues. 06:00 - 08:00 2.00 PULL P DECOMP Continue POH laying down 4-1/2" 12.6# L80 BTC / NSCT completion 1x1 through pipe shed. Recovered 260 jts. 4-1/2" tbg., 4-1/2" HES SSSV, 3 x 4-1/2" GLM's, 1 x 4-1/2" "X" nipple and cut pup jt. Pup jt. cut length = 5.92' and max. flare O.D. _ 5.20". 08:00 - 10:00 2.00 PULL P DECOMP Rigged down 4-1/2" tubing handling tools. Cleared and cleaned rig floor. 10:00 - 12:00 2.00 FISH P DECOMP Rigged up floor with 3-1/2" DP handling tools and loaded pipe shed with and strapped 9 x 6-1/4" drill collars for packer miiling BHA. 12:00 - 12:30 0.50 FISH P DECOMP PJSM - Tinsley crew review making up BHA procedure. 12:30 - 14:30 2.00 FISH P DECOMP PUMU BHA #1 as follows: 8-1/2" "QuikPik" Pac ~ I, 3 x 7" Boot Baskets, 6-3/8" Bit Sub, 6-1/4" LBS, 6-1/4" oil Jar, 6-1/4" Pump-Out Sub, XO, 9` 6-1/4" Drill Collars & XO = 316.00'. 14:30 - 18:00 3.50 FISH P DECOMP RIH w/BHA #1 on 3-1/2" 15.5#/ft. Grade E IF drillipe 1 x 1 from pipe shed. 18:00 - 18:30 0.50 FISH P DECOMP Perform pre-tour checks, environmental walk-around and derrick inspection. Check PVT alarms. Service Rig. 18:30 - 23:30 5.00 FISH P DECOMP Continue to RIH with BHA #1 on 3-1/2" DP from pipe shed. At 2000-hrs, 175-jts RIH. Run a total of 330-jts of DP. 23:30 - 00:00 0.50 FISH P DECOMP PJSM on Slipping and cutting drilling line. 4/30/2009 00:00 - 01:00 1.00 FISH P DECOMP Slip and cut drilling line. 01:00 - 01:30 0.50 FISH P DECOMP PU jts #330-335 and RIH. PU wt = 161 K-Ibs, SO wt = 110K-Ibs. 01:30 - 06:00 4.50 FISH P DECOMP PU & MU Kelly. Obtain milling parameters: PU wt = 165K-Ibs, SO wt = 115K-Ibs, Rot wt = 132K-Ibs. Rotate at 79-rpm with 210-amps free torque. RIH and taq stump at 10,740.5'. Confirm latch by PU with 10K-Ibs overpull. Stage pumps up to Printed: 6/8/2009 11:38:45 AM ~ ~ ~ BP EXPLORATION Page 3 Qf 25 Qperations Summary Report Legal Well Name: J-20 Common Well Name: J-20 Spud Date: 8/1/1996 Event Name: WORKOVER Start: 4/26/2009 End: 5/31/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/31/2009 Rig Name: NABORS 4ES Rig Number: Date' From - To Hours Task Code NPT Phase Description of dperations 4/30/2009 01:30 - 06:00 4.50 FISH P 06:00 - 18:30 I 12.50I FISH I P 18:30 - 22:00 I 3.501 FISH I P 22:00 - 22:30 ~ 0.50 ~ FISH ~ P 22:30 - 00:00 ~ 1.50I FISH ~ P 5/1/2009 I00:00 - 00:30 I 0.50I FISH I P 00:30 - 01:30 1.00 FISH P 01:30 - 02:00 0.50 FISH P 02:00 - 06:00 4.00 FISH P 06:00 - 07:00 1.00 FISH P DECOMP 3-BPM with 510-psi. Rotate at 80-RPM and 240-amps torque. Run 5K-Ibs WOB. Mill ahead. Pump 10-bbl Hi Vis sweeps as needed. Torque continues to climb to 270-rotating amps. Reduce rotation to 71-RPM. Pump 1-drum of EP Mud lube and increase pump rate to 4-BPM with 850-psi. When EP Mud Lube reaches mill, torque drops off to 240-amps. At 0330-hrs, ROP decreases indicating we are on the packer (length milled correlates with ta in acker as well . Increase WOB to 7K-Ibs and see torque increase. After milling on packer for 1/2-hr, torque has climbed to between 260 and 280-amps. Stop milling and increase pump rate to 5-BPM with 1300-psi to move EP Mud Lube uphole and attempt to reduce torque. Resume milling with above parameters, except increase WOB to 7-10K-Ibs. Torque continues to be 270-amps~ DECOMP Continue milling on packer. Torque dropped off to 240-260 amps (-6500 ft-Ibs.) after EP Mud Lube had time to circulate around. Increased WOB to 23-25K. RPM = 80, pump Rate = 3.5-bpm. Mill to a depth of 10,748'. At 1815-hrs, jar on packer twice. When icking up the third time the strin wei ht dropped off at -190K-Ibs. Continue to PU to confirm uo weiqht of 170K-Ibs. Slack off and tag up hiQh. PU again and PU wt = 165K-Ibs. Slack off and tag up high again. Appears that lower slips are still able to bite, but packer is able to move u hole. DECOMP Pump 46-6 i is sweep an circulate out of the hole. Pump at 4.5-BPM with 920-psi. Seeing very fine metal millings across shakers. Monitor well - Static. DECOMP Work i e u to 50K-Ibs over a r breaks free with, PU wt of 165K-Ibs. LD 2-single jts of drill pipe to pipe shed. Rack back 1-std of DP in derrick. Packer dragging up to 50K-Ibs overpull. DECOMP Attempt to pull second stand of DP and packer becomes stuck at 10 451' 1-'t lus 6' o DP . Work pipe, jarring up to 60K-Ibs over and straight pulling up to 100K-Ibs over PU wt. Unable to come free. Jar down and again unable to come free. DECOMP Continue to attem t to free acker b'arrin both u and down. Discuss situation with Day WSL, Nabors Tourpusher and Baker Fishermen. Decide to attempt to release arao~lP on "QuickPik" BHA and s ace out kell to resume millin acker. DECOMP Set slips and release "QuickPik" grapple by working torque into the string and then picking up. PU wt = 150K-Ibs. DECOMP Stand back 1-std of DP in derrick (#110). PU 1-jt of DP, 10' DP pup and Kelly to resume milling, DECOMP Obtain milling parameters: PU wt = 154K-Ibs, SO wt = 118K-Ibs, Rot wt = 135K-Ibs. Rotate at 65-rpm with 180-amps of free torque. Bring pumps on at 3.5-BPM with 410-psi. ~~ and taq packer at 10451'. Set down 15K-Ibs and PU to confirm catch - did not catch packer. Slack off again and stack 30K-Ibs down. PU and packer is caught. Begin milling at 10,451' with 70-rpm and 240 to 270-amps of torque. Initially run 3-5K-Ibs WOB and increase to 10-20K-Ibs. Torque continues to be between 240-270-amps. DECOMP Continue millina with oreviouslv established narameters. Milled about 9" to 10,452' and mill stalled out at 10K ft-Ibs. torque. Printed: 6/S/2009 11:38:45 AM .t • ~ BP EX` Operations ~ Legal Well Name: J-20 Common Well Name: J-20 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES 7RATIQN Page 4 ot 25 mmary Report Spud Date: 8/1 /1996 Start: 4/26/2009 End: 5/31 /2009 Rig Release: 5/31/2009 Rig Number: Date From - To Hours Task Code NPT Phase 5/1/2009 06:00 - 07:00 1.00 FISH P DECOMP 07:00 - 11:00 4.00 FISH P DECOMP 11:00 - 12:00 1.00 DECOMP 12:00 - 12:30 0.50 FISH P DECOMP 12:30 - 14:30 2.00 FISH P DECOMP 14:30 - 16:00 1.50 FISH P DECOMP 16:00 - 19:00 3.00 FISH P DECOMP 19:00 - 20:00 1.00 FISH P DECOMP 20:00 - 23:00 3.00 FISH P DECOMP 23:00 - 00:00 1.00 FISH P DECOMP 5/2/2009 00:00 - 04:30 4.50 FISH P DECOMP Description ot Uperations Attempted twice to reestablish rotation with mill stalling out both times at 10K ft-Ibs. torque. Picked up strinq and did not experience any drag or sticking. Blew down kelly and set back in shuck. Pulled 1 stand without any drag or sticking. Ran back in hole and tagged fish at 10,452'. Worked pipe and did not experience any drag or sticking. Decided to POH and inspect BHA. POH standing back 3-1/2" DP in derrick. PTSM - Crew change, check PVT's, service rig and perform environmental walkaround rig. Break out and lay down BHA #1. Grapple mandrel on Quik-Pik packer mill broken off and left in hole. Safety Meeting - new day crew returning for first day of new hitch. Discussed personal weight lifting limitations, status of Nabors Rig 3S and recent HSE incidents and events. Clear and clean floor. Discuss plan forward with engineering support. PUMU BHA #2 as follows: 3-5/8" Convex Mill, Bit Sub, Spear E~., 2-3/8" Bowen Itco Spear w/4.010" grapple, XO, XO, 6-1/4" LBS, 6-1/4" Oil Jar, XO, 9 x 6-1/4" Drill Collars and XO = 306.82'. RIH w/BHA #2 on 3-1/2" 15.5#/ft, Grade "E" IF Drillpipe from derrick. PU std #110 & RIH. PU wt = 148K-Ibs, SO wt = 118K-Ibs. LD to 2 jts of DP. PU 24' pup jt and Kelly. Obtain parameters with Kelly. PU wt = 153K-Ibs, SO wt = 117K-Ibs, Rot Wt = 132K-Ibs. Rotate at 20-rpm with 180-amps of free torque. Stage pumps up to 3.7-BPM with 1010-psi. RIH a tan packer at 10,540'. Mill lightly with 2K-Ibs WOB. Stop rotating and continue to RlN. Set down 15K-Ibs at 10,553'. PU, no catch. RIH again and set weight down at 10. 62'_ P and confirm latch with overpull. Work pipe, jarring several times and straight pulling up to 250K-Ibs. After third iar hit, slack off and able to RIH until Kelly at rip floor itho~~ cta kinqg~. PU through tight spot at 10,540 and continue to move packer uphole to 10,532'. Circulate bottoms up at 4-BPM with 1200-psi. Small amount of fine metal millings collected on magnets. Hold PTSM for crew change while circulating. Also perform pre-tour checks, Rig service, environmental walkaround and derrick inspection while circulating. Monitor well - Static. Blow down and stand back Kelly. Pull 1-jt of DP and LD. Pull 1-std of DP and rack back. PU wt = 150K-Ibs. Decide to PU pipe to RIH and chase_packer to bottom. PU 7-jts of DP and RIH. Tag packer at 10 758' (Std #112 all the wav down~. Set down 20K-Ibs. PU and see -8K-Ibs overpull. POH, laying down 7-singles to pipe shed. Seeing drag between 2-5K-Ibs. See isolated overpull up to 50K-Ibs. Drop dart to open pump out sub. Pump dart down at 3-BPM with 340-psi. Shear pump out sub open at 1500-psi. Continue POH. standinp back 3-1/2" DP in derrick. Continues to draq 04:30 - 06:00 I 1.50I FISH I P I ~ DECOMP I POH and LD BHA # 2. Got qra~ple and mill to the rip floor, but Printed: 6/8/2009 11:38:45 AM • ~ BP EXPLORATION ' Page 5 af 2~ ' Operations Summary R~port Legal Well Name: J-20 Common Well Name: J-20 Spud Date: 8/1/1996 Event Name: WORKOVER Start: 4/26/2009 End: 5/31/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/31/2009 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Qeseription of Operations 5/2/2009 04:30 - 06:00 1.50 FISH P DECOMP the fish/pk r is still downhole. Grapple had engaged but backed off. Conferred with town engineers and Baker fishing lead and decision was made to re-enter with a 2-ft extension above the grapple on the next run to ensure well down into the packer before POH after next run. 06:00 - 07:30 1.50 FISH P DECOMP Waiting on town engineer decision and Baker fishing lead to get to rig with BHA components; MU/PU BHA # 3: 2-3/8" Bowen Itco Spear w/4.010" grapple, Spear Extension, XO, XO, 6-1/4" LBS, 6-1/4" Oil Jar, Pump out sub, XO, 9 x 6-1/4" Drill Collars and XO = 30522'. 07:30 - 13:00 5.50 FISH P DECOMP RIH with BHA # 3. Taq up at 10,660'. P/U wt. = 148K, S/O wt. = 114K. Pushed fish downhole another 35'. Picked up ar~~ had 45K over ull. Let oil 'ar tri and fish came free. RIH and ush fish down to refusal at 10,761'. Worked pipe up to 40K downweight and spudded spear into fish three times. POH to lay down two joints DP. 13:00 - 20:00 7.00 FISH P DECOMP POH w/BHA #3 standing 3-1/2" DP in derrick. Fish draqqing up to 50K overpull for first 10 stands pulled. After crew change at 1800-hrs, saw 20K-Ib overpull on first stand pulled. 20:00 - 21:30 1.50 FISH P DECOMP Stand back 3-stds of 6-1/4" DCs. ,J~ang uo whPn up Ilinq BHA throuqh stack. Rotate to left and able to pull rest of BHA through BOP stack. Packer recovered. LD Bumper sub, Jars to pipe shed. 21:30 - 22:00 0.50 FISH P DECOMP Attempt to release spear from packe, but unable. Break out packer and LD to pipe shed. Grapple carrier and grapple from "QuickPik" packer mill are stuck in packer just below ITCO spear bullnose. LD all tubing tailpipe to pipe shed. Recover 1-packer, 5(ea) 10' pupjts, 2-X Nipples, and 1-WLEG. "QuickPik" internal mandrel and bullnose were not recovered: 22:00 - 23:30 1.50 FISH P DECOMP Clean and Clear rig floor. Discuss fishing options for recovering "QuickPik" mandrel with RWO engineer, WSL and fisherman. Decide to fish mandrel using Overshot dressed with 1.625" grapple. Mobilize BHA to rig floor. 23:30 - 00:00 0.50 FISH P DECOMP Hold PJSM with rig crew on making up overshot BHA. MS;_ BHA #4 to fish "QuickPik" mandrel. BHA consists of: 3-5/8" Overshot dressed with 1.625" grapp e, 3(ea) PAC DCs, Bumper Sub, Jar, Pump Out Sub, and 9(ea) 6-1/4" DCs. Total BHA length = 393.95'. 5/3/2009 00:00 - 01:00 1.00 FISH P DECOMP Continue to PU BHA #4 - Fishing "QuickPik" mandrel. BHA consists of: 3-5/8" Overshot dressed with 1.625" grapple, 3(ea) PAC DCs, Bumper Sub, Jar, Pump Out Sub, and 9(ea) 6-1/4" DCs. Total BHA length = 393.95'. 01:00 - 04:00 3.00 FISH P DECOMP RIH with BHA #4 on 100-stds of 3-1/2" DP from derrick. 04:00 - 06:00 2.00 FISH P DECOMP Slip & Cut drilling line. 06:00 - 09:00 3.00 FISH P DECOMP Continue RIH w/BHA #4. Taq 7" liner top at 10,800'. Kelly up and establish parameters: P/U wt. = 156K, S/O wt. = 116K, RPM = 24, Rot. wt. = 136K, Torque = 4500 ft-Ibs., 5.0-bpm @ 1100-psi. Work overshot down to 10,812' with no further gains. Varied pump rate and RPM's which provided no assistance in getting deeper. 09:00 - 14:00 5.00 FISH P DECOMP Blow down kelly and set back. POH standing 3-1/2" DP in derrick. 14:00 - 15:30 1.50 FISH P DECOMP Break out and lay down BHA #4. The cut lip guide on the Printed: 6/8/2009 11:38:45 AM ~ ~ BP EXPLORATEON Page 6 of 25 Qperations Summary Report Legal Well Name: J-20 Common Well Name: J-20 Spud Date: 8/1/1996 Event Name: WORKOVER Start: 4/26/2009 End: 5/31/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/31/2009 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase ' aescription of Operations 5/3/2009 14:00 - 15:30 1.50 FISH P DECOMP 3-5/8" overshot was bent over and folded up inside the overshot barrel and also flattened to 2/3 of iYs orginal diameter. No fish were recovered. 15:30 - 16:30 1.00 FISH P DECOMP Clear and clean floor. 16:30 - 17:30 1.00 FISH P DECOMP Day crew - Weekly HSE meeting. 17:30 - 18:00 0.50 FISH P DECOMP MU BHA #5. BHA consists of: 5-3/4" RCJB, Double pin sub, Boot Basket, Bumper sub, Jars, Pump out sub, and 9(ea) 6-1/4" DCs. Total BHA length = 307.06'. 18:00 - 18:30 0.50 FISH P DECOMP Perform pre-tour checks. Check PVTs. Inspect derrick. Service rig equipment. 18:30 - 19:30 1.00 FISH P DECOMP Night crew - Weekly HSE meeting. 19:30 - 20:00 0.50 FISH P DECOMP Finish MU BHA #5 on 3-stds of 6-1/4" DCs from derrick. 20:00 - 00:00 4.00 FISH P DECOMP RIH with BHA on 111-stds of 3-1/2" DP from derrick. PU 3-jts of DP from pipe shed. PU wt = 150K-Ibs, SO wt = 116K-Ibs. 5/4/2009 00:00 - 01:30 1.50 FISH P DECOMP PU Kelly. Obtain parameters: PU wt = 155K-Ibs, SO wt = 120K-Ibs, Rot wt = 136K-Ibs. Pump on at 5.5-BPM with 1990-psi. Rotate at 22-rpm with 150-amps free torque. Wash down and pump pressure increases to 2020-psi. Tag twice without rotation at 10,790'. Begin rotating and RIH with rest of Kelly. Pump pressure fluctuates between 2080 and 2020-psi. Stand back Kelly & PU single jt of DP. RIH with single and tag a ain at 10,790'. Turn pipe and pass through liner top. PU Kelly. Continue RIH, washing at 6-BPM with 2060-psi. Rotate down and taQ 10,812'. STorque comes up briefly and then smoothes out. PU and wash down without rotation. Tag at 10,812' again. Continue circulating at 10,812' for 5-minutes at 6-BPM with 2020-psi. 01:30 - 02:00 0.50 FISH P DECOMP POH with Kelly. Blow down and stand back Kelly. LD 2-jts of DP to pipe shed. 02:00 - 06:00 4.00 FISH P DECOMP POH with BHA #5, standing back 3-1/2" DP in derrick. 06:00 - 06:30 0.50 FISH P DECOMP Crew change: C ec PVT's, daily derrick inspection, enviro walkaround and service rig. 06:30 - 07:30 1.00 FISH P DECOMP Continue POH with BHA #5, standing back 3-1/2" DP in derrick. 07:30 - 09:00 1.50 FISH P DECOMP Breakout BHA #5. Did not recover an 'unk or forei n materiai other than a very small amount of inetal cuttin in RCJB. ' 09:00 - 10:00 1.00 FISH P DECOMP PUMU BHA #6 as follows: 3-5/8" RCJB, Bit Sub, 3 x 3-1/8" PAC DRill Collars, XO, XO, 6-1/4" LBS, 6-1/4" Oil Jar, POS, XO, 9 x 6-1/4" Drill Collars, XO = 398.86'. 10:00 - 15:00 5.00 FISH P DECOMP RIH w/BHA #6 in 3-1/2" DP from derrick. Stop and circulate every 20 stands to ensure RCJB clear. 15:00 - 15:30 0.50 FISH P DECOMP Kelly up and circulate 30-Bbl. viscosified EP Mud Lube pill and spot outside BHA. 15:30 - 19:00 3.50 FISH P DECOMP Dry tag at 10,812'. _ Break kelly off and drop ball. Pump ball in place at 3.0-BPM ~ 550-PSI. Establish milling parameters: P/U wt. = 151 K, S/O wt. = 118K, 5.0-BPM C~ 2300-PSI, Free Torque at 40-RPM = 4000 ft-Ibs., Set Torque limit at 8000 ft-Ibs. Ease down and tag at 10,812' and commence millinq with 5-20K WOM. Able to work ahead to 10 813'. PU and wash down multiple times, with and without rotation. Unable to make any further progress. Pump pressure had increased to 2400-psi by end of operation. 19:00 - 23:00 4.00 FISH P DECOMP Blow down and Stand back Kelly. POH, standing back 3-1/2" Printetl: 6/8/2009 11:38:45 AM ~ ~ ~ BP EXPLORATIQN Page 7 of 25' Operations Summary Report Legal Well Name: J-20 Common Well Name: J-20 Spud Date: 8/1/1996 Event Name: WORKOVER Start: 4/26/2009 End: 5/31/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/31/2009 Rig Name: NABORS 4ES Rig Number: Date Frc~m - To Hours Task Code NPT Phase : Descriptian of aperations 5/4/2009 19:00 - 23:00 4.00 FISH P DECOMP DP in derrick. 23:00 - 00:00 1.00 FISH P DECOMP Stand back 3-stds of 6-1/4" DCs. LD 3yts of 3-1/8" DCs. Break down BHA and inspect RCJB. Find 3-chunks of a 5/5/2009 ! 00:00 - 00:30 I 0.501 FISH I P 00:30 - 01:30 1.00 FISH P 01:30 - 05:00 3.50 FISH P 05:00 - 06:00 1.00 FISH P 06:00 - 08:00 2.00 FISH P 08:00 - 13:00 5.00 FISH P 13:OQ - 14:00 1.00 FISH P 14:00 - 16:00 2.00 BOPSUF~ P I 16:00 - 22:30 6.50 BOPSUd P 22:30 - 23:00 0.50 BOPSU P 23:00 - 00:00 1.00 BOPSU P 5/6/2009 00:00 - 01:00 1.00 FISH P 01:00 - 04:30 3.50 FISH P 04:30 - 09:30 5.00 FISH P 09:30 - 10:30 1.00 FISH P together to see where they were milled by the shoe on the RCJB. Shoe on RCJB was worn smooth and carbide was completely worn off of the bottom. One small piece of carbide was recovered in the RCJB, probably part of one of the teeth on the shoe. DECOMP Clean and clear rig floor. Discuss options for next run with RWO engineer, Baker fishing hand and Baker technical advisor. Decide to run 3-5/8" RCJB with new carbide tipped shoe on bottom. DECOMP MU new shoe on RCJB and install new finaer inserts. Hold PJSM on MU BHA and RIH on DP. MU BHA #7: BHA consists of 3-5/8" RCJB with carbide shoe and extension, Bit Sub, 3(ea) 3-1/8" PAC DCs, Bumper Sub, Jars, Pump Out Sub, and 9(ea) 6-1/4" DCs. BHA length = 400.72'. DECOMP RIH with BHA #7 on 3-1/2" DP from Derrick. DECOMP Be in millin and fishin ' t- -1 " XO at 10 8' DECOMP Mill on junk at 10,813'. Broke throuqh iunk at 10.814' and stopped rotating. Washed down to 10 825' and was unable to wash or rotate any dee er. Shut down pump, broke off kelly, blew down and set back same. DECOMP POH w/BHA #7 standing DP in derrick. DECOMP Break out and lay down 3-5/8" RCJB and 3 x 3-1/8" PAC drill collars. Recovered ap~rox. 2 cups of inetal debris consisting of pieces of packer slips 1" wide by 1-1/2' long, one piece of inetal approx. 3-1/2" long by 2" wide by 1/8" thick and various smaller pieces of inetal debris. DECOMP Pull wear ring. Rig up testing tools and equipment for weekly BOP test. DECOMP Perform weekl~BOP testing per BP/AOGCC requirgmentis. Tested pipe rams with 3-1/2" and 4-1/2" testjoints to 250-psi Lo/3500-psi Hi. Tested annular preventer with 3-1/2" test joint to 250-psi Lo/3500-psi Hi. Tested choke manifold, both manual and HCR kill and choke valves, floor safety valve, IBOP and upper and lower kelly valves. AOGCC witness of test was waived by John Crisp, test was witnessed by BP WSL and Nabors Toolpusher. DECOMP R/D BOP test assemblies. DECOMP Pull test plug and install wear bushing with 9-1/8" ID. DECOMP M/U BHA #8, BHA = 3-5/8" Bowen Series 150 Overshot w/ 1.625 Grapple and 1.750 Mill Control, XO, (3) 3-1/8" DC's, XO, XO, LBS, Oil Jar, Pump Out SUb, XO, (9) 6-1/4" DC's, XO. Total BHA Lenght = 394.21' DECOMP Slip on new spool of drilling line. DECOMP RIH with Overshot BHA #8 on 3-1/2" drill pipe from derrick. DECOMP Kelly up and establish parameters: P/U wt. = 155K, S/O wt. _ 120K, Rot. Wt. = 135K ~ 34-RPM. Start circulating at 3.0-BPM at 550--PSI. Slide down and enqaqe fish at 10825'. Swallow fish with overshot. Pump pressure increased to 2200-psi. Set 25K downweight on fish. Picked up off bottom Printed: 6/8/2009 11:38:45 AM ~ ~ ~ _ BP EXPLORATION Pag~ 8 of 25 Operations Summary Report Legal Well Name: J-20 Common Well Name: J-20 Spud Date: 8/1/1996 Event Name: WORKOVER Start: 4/26/2009 End: 5/31/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/31/2009 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/6/2009 09:30 - 10:30 1.00 FISH P 10:30 - 15:00 ~ 4.50 ~ FISH I P 15:00 - 16:00 I 1.00 ~ FISH ~ P 16:00 - 17:00 1.00 FISH P 17:00 - 18:00 1.00 FISH P 18:00 - 18:30 0.50 FISH P 18:30 - 22:30 4.00 FISH P 22:30 - 00:00 1.50 FISH P 5/7/2009 00:00 - 00:30 0.50 FISH P 00:30 - 05:00 4.50 FISH P 05:00 - 06:30 I 1.501 FISH I P 06:30 - 08:00 I 1.501 FISH I P 08:00 - 09:00 I 1.001 FISH I P 09:00 - 12:00 I 3.001 FISH I P 12:00 - 13:30 I 1.501 FISH I P DECOMP and pump pressure dropped suddenly back to 550-psi. Set back down on fish and pump pressure increased to 790-psi. Picked up off bottom and pump pressure dropped to 550-PSI. Started rotating at 20-RPM and set down on fish. Did not gain an depth with overshot but pump pressure increased to 800-PSI. Picked up off bottom and spudded overshot onto fish twice. Set 35K downweight on fish and pump pressure increased to 770-PSI. Consulted with Baker Fishing Technical Authority and agreed plan to POH. DECOMP Broke off and blew down kelly. Set kelly back. POH standing 3-1/2" DP in derrick. DECOMP Break out and la down BHA. vershot cont ined no i h. , 3-5/8" vvershot guide shoe face is mushroomed out to 4.125" and the carbide face of the shoe shows moderate wear. There is a circular gouge in the shoe continuing around the circumference -180 degrees and the makeup threads indicate overtorquing though torque values when overshot downhole never exceeded 6500 ft.-Ibs. The 1.625" grapple, control ring and packoff indicate no contact made with fish. DECOMP Clear and clean rig floor while plan forward developed. DECOMP Makeup BHA #9 as follows: 3-5/8" RCJB, XO, (3) 3-1/8" DC's, XO, XO, LBS, Oil Jar, Pump out Sub, XO, (9) 6-1/4" DC's, XO. Total BHA Lenght = 400.72' DECOMP Crew change, service rig, inspect derrick, set and test PVT's. DECOMP RIH with RCJB BHA on 3-1/2" drill i e from derrick to 10,811' DECOMP P/U Kelly and establish parameters, P/U 155K, SOW 121 K, Rotating weight 136K, 60 rpm at 3,250 ft/Ibs of torque, 2 bpm at 250 psi, 6 bpm at 2,270 psi. Taq top of fish at 10,825'. Rotate and work RCJB over top of fish to 10,828'. 2-3k WOM, 60 rpm with 3,250 -4,500 ft/Ibs of torque. Had 5K overpull several times when picking up off fish. DECOMP Circulate at 6 bpm at 2,270 psi to finish circulating bottoms up. DECOMP Stand back Kelly and POOH with 3-5/8" RCJB standing back 3-1/2" drilipipe. DECOMP Stand back drill collars and break down RCJB assembly. Recovered one larpe piece and one small of packer slips, but --s left a piece of the mill shoe approx. 2-1/2" tall by approx. 3-1/2" in length and all but one of the brass fingers in both junk baskets as well as 1/2 of the cage of the bottom junk basket in hole. DECOMP clear and clean rig floor and develop plan forward with RWO engineer. DECOMP PUMU BHA #10 as follows: 3-5/8" Overshot w/3-3/4" Shoe and 1-5/8" grapple, XO, 3 ea. 3-1/8" PAC Drill Collars, XO, XO, 6-1/4" LBS, 6-1/4" oil Jar, 6-1/8" Pumpout Sub, XO, 9 ea. 6-1/4" Drill Collars and XO = 394.39'. DECOMP RIH w/BHA #10 on 3-1/2" 15.5# Grade "E" IF drillpipe from derrick. DECOMP Tag 7" liner top of 10,791' DPM. Set DP in slips with -2K downweight on BHA. Rotate pipe and roll BHA into liner. Pull slips. Kelly up and break circulation at 3.0-BPM at 550-PSI. Established parameters: P/U wt. = 153K, S/O wt. = 121 K, Rot. wt. = 136K. Tagged top of fish at 10,825' and noted a pump Printed: 6/8/2009 11:38:45 AM ~ ~ . BP EXPLORATION Page 9 of 25' Qperations Summary Report Legal Well Name: J-20 Common Well Name: J-20 Spud Date: 8/1/1996 Event Name: WORKOVER Start: 4/26/2009 End: 5/31/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/31/2009 Rig Name: NABORS 4ES Rig Number: i Date From - Ta Hours Task Code NPT Phase Description of Operations 5/7/2009 12:00 - 13:30 1.50 FISH P DECOMP pressure increase to -770-PSI. Set 10K downweight and 13:30 - 18:00 4.50 FISH P 18:00 - 19:00 1.00 FISH P 19:00 - 20:00 1.00 FISH P 20:00 - 20:30 0.50 FISH P 20:30 - 22:00 1.50 FISH P 22:00 - 00:00 2.00 FISH P 5/8/2009 00:00 - 01:00 1.00 FISH P 01:00 - 02:30 1.50 FISH P 02:30 - 06:00 I 3.501 FISH I P 06:00 - 07:00 I 1.001 FISH I P 07:00 - 10:00 I 3.001 FISH I P 10:00 - 11:30 I 1.501 FISH I P 11:30 - 13:00 ~ 1.50 ~ FISH ~ P 13:00 - 14:30 1.50 FISH P 14:30 - 17:30 3.00 FISH P incr -P I.. Picked up of bottom and pump pressure decreased to 640-PSI. Set back down with 10K downweight and applied 10 rounds of torque to DP. Gained an additional 6" of swallow. Picked up and set 10K downweight once more on fish with pyump pressure remaining at 640-PSI. Picked up out of 7" liner top at 10,791, went back down and tagged 7" liner top 1 foot higher than previously when BHA ran through liner top. Broke 24' pup joint off in mousehole so we wouldn't have to reenter liner top and risk knocking fish loose and dropping it, blew down and set kelly back in shuck. layed down 24' pup to pipeshed. DECOMP POH w/ BHA #10 standing 3-1/2" DP in derrick. DECOMP Break out and UD Overshot BHA. Did not recover fish, no indication of grapple being over fish. Some indication on carbide of junk or fish being 1" inside shoe of overshot. DECOMP Clear rig floor, service rig. Discuss options with RWO engineers, decission made to R/U Slick line unit and run LIB and bailers. DECOMP R/U Dutch System lubricator. DECOMP Wait on Slick line unit. DECOMP Spot Slick line unit, bring slick line equipment to rig floor and R/U. DECOMP R/U Slick line unit, test pack-off and lubricator to 500 psi. DECOMP I'c 'n . T TOF at 10 830' SLD. POOH with LIB. Indication of mandrel on LIB. BP Slick line PE on location with slickline unit. DECOMP RIH with 3.5" Pump Bailer with 3.69" muleshoe and 10' of barrel. Unable to qet past TOL at -10,800' SLD, POOH, large dent in bottom of muleshoe. No recovery in bailer. UD 3.5" Bailer and M/U 3" pump bailer with center stablization and RIH. RIH w/3" bailer and got past liner top and tagged TOF at 10,830' SLMD. Stroke pump bailer. POH w/bailer and recovered 2 qallons of EP Mud Lube, a couple small pieces of DECOMP PTSM, crew change, service rig, check PVT's and steam out 3" pump bailer. DECOMP RIH w/3" pump bailer. Tag at 10,839'. Stroked bailer 6 times and POH. Recovered approx. 2 gallons EP Mud Lube, 2 cups packer mill cuttings and two pieces packer rubber, one piece 2" square by 1/2" thick and one piece approx. 3/4" square by 1/2" thick. DECOMP Reconfigure 3.5" pump bailer to a 5' barrel and RIH w/same. tagged up on 7" liner top at 10,802' and could get no deeper. Worked tools string for 30 minutes with no luck. POH. DECOMP RIH w/3" pump bailer. Set down at 10,839'. Stroke bailer 6 times and work down to 10,841'. POH w/ bailer. Recovered 1 cup of packer mill cuttings and 2 gallons of EP Mud Lube. DECOMP RIH w/3" pump bailer (run #4). Set down at 10,841'. Stroked bailer 6 times and POH. Recovered approx. 2 cups packer mill cuttings and 2 gallons EP Mud Lube. DECOMP RIH w/3" pump bailer (run #5). Set down at 10,842'. Stroked Printed: 6/8/2009 11:38:45 AM ~ • • BP EXPLORaTION' Page 10 of 25 ; Operatio'ns Summary R~port i Legal Well Name: J-20 Common Well Name: J-20 Spud Date: 8/1/1996 Event Name: WORKOVER Start: 4/26/2009 End: 5/31/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/31/2009 Rig Name: NABORS 4ES Rig Number: Date Frorn - To Hours Task Code NPT Phase Deseription of Qperations ~i 5/8/2009 14:30 - 17:30 3.00 FISH P DECOMP bailer 6 times and POH. Recovered approx. 1 cup packer mill cutiings and 2 gallons EP Mud Lube/seawater. Inside bore on muleshoe/fla er ass . shows indications of contact with somethinq circular and hard. Slickline crew cutting wire to re-tie rope socket and also redressing packoff/line wiper. 17:30 - 20:00 2.50 FISH P DECOMP RIH w/ 3.5" LIB (run #6) Set down at 10,837'. POOH and inspect LIB. 1-1/4" curved indentation in center of LIB. Change out slick line crews. 20:00 - 21:30 1.50 FISH P DECOMP RIH with Hydrostatic bailer (run #7). Set down at 10,837' work to 10,841'. POOH recovered -2 gallons of EP Mud Lube/seawater and 1/2 cup of inetal shavings. Discuss plan forward with RWO Engineer. 21:30 - 23:00 1.50 ~ISH P DECOMP RIH with 3-3/16" Overshot w/GS latch run #8 . Set down at 10,837', work Overshot to 10,841'. Unable to latch onto fish. POOH, Some marks on inside of muleshoe and on grapple control but none on grapple. 23:00 - 00:00 1.00 FISH P DECOMP RIH with 3.5" ma net run #9 . Set Down at 10,840', work to 10,841'. 5/9/2009 00:00 - 01:00 1.00 FISH P DECOMP POOH with 3.5" magnet. Recovered icup on metal shavings on magnet. 01:00,- 02:00 1.00 FISH P DECOMP R/D Schlumberger Slickline unit and remove equipment from rig floor. 02:00 - 02:30 0.50 FISH P DECOMP R/D Dutch System lubricator and service rig. 02:30 - 03:30 1.00 FISH P DECOMP P/U BHA #11 BHA consists of Muleshoe, (2) Joints of Fox Tbg, X0, XO, LBS, Oil Jar, Pump Out Sub, XO, (9) Drill Collars, XO. Total BHA Lenght = 367.03' 03:30 - 06:00 2.50 FISH P DECOMP RIH with BHA # 12 on 3-1/2" IF drillpipe from derrick. 06:00 - 12:30 6.50 FISH P DECOMP Ta u at 10 829' DPM. Layed down 1 joint 3-1/2" DP. Picked up 24' 3-1/2" DP pup w/circulating headpin and close annular. Start reverse circulating at 5.5-BPM at 1600-psi. Wash down to 10,830'. Could get no deeper than 10,829'. At first bottoms up, large amount of thick, viscous liquid with serious amount of suspended solids recovered across shaker screens. Mixed and reversed 30-Bbl. Hi-Vis pill at 6.0-BPM at 1650-PSI. recovered Hi-Vis pill with no further solids recovered. Shut down pump. Opened annular preventer, picked string up 5' and applied 10 rounds rotation to string. Went back down and ta ed at 10 830'. Reverse circulated bottoms up and attem ted to work i e dee er with no 'o . Break off and blow down kelly. Blow down same. 12:30 - 14:00 1.50 FISH P DECOMP Slip and cut drilling line. 14:00 - 18:00 4.00 FISH P DECOMP POH with BHA #11 standing 3-1/2" DP in derrick. 18:00 - 18:30 0.50 FISH P DECOMP Crew change, service rig, derrick inspection, set and test PVT's , 18:30 - 19:00 0.50 FISH P DECOMP POH with BHA #11 standing 3-1/2" DP in derrick. 19:00 - 21:00 2.00 FISH P DECOMP Stand back drill collars, break out and UD reversing assembly. 1" iece of ti of muleshoe was broken off. Clear rig floor 21:00 - 22:00 1.00 FISH P DECOMP M/U BHA #12 BHA consists of 3-b/8" RCJB, 3-1/2" Boot Basket, XO, (3) PAC DCs, XO, XO, LBS, Oil Jar, Pump Out Sub, XO, (9) 6-1/4" DC's, XO. Total BHA Lenght = 397.48' 22:00 - 00:00 2.00 FISH P DECOMP RIH with BHA #12 on 3-1/2" IF drillpipe from derrick. 5/10/2009 00:00 - 01:00 1.00 FISH P DECOMP RIH with BHA #12 on 3-1/2" IF drillpipe from derrick to 10,815' j 01:00 - 03:00 2.00 FISH P DECOMP M/U Kelly and establish parameters. P/U weight 154K, S/O I weight 120K, Rotating weight 136K, 35 rpm with 3,250 fUlbs of Printed: 6/8/2009 11:38:45 AM t • • BP EXPLC}RATION Pa~e 11 of 25 Operations Summary Report Legal Well Name: J-20 Common Well Name: J-20 Spud Date: 8/1/1996 Event Name: WORKOVER Start: 4/26/2009 End: 5/31/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/31/2009 Rig Name: NABORS 4ES Rig Number: 5/10/2009 01:00 - 03:00 Code NPT Phase : Description caf Operations 2.001 FISH I P DECOMP torque, pipe plugging off, 1 bpm at 2,700 psi. Line up and reverse drill string volume 3 bpm at 1,250 psi. Line up to pump long way 2.5 bpm at 2,000 psi. Tag TOF at 10,827'. Work over Fish with 2-4K WOM, 30 RPM with 3,250 - 4,000 fUlbs of torque. Work to 10.829', drill strinq plupqed off. Unable to pump through drill string at all. Unable to regain circulation. DECOMP Stand back Kelly and POOH standing back 3-1/2". Dropped dart and sheared open Pump Out Sub. Sheared at 2,100 psi. DECOMP Crew change PTSM, service rig, check PVT's, daily derrick inspection and enviro walkaround. DECOMP Resume POH standing 3-1/2" DP in derrick. Breakout rolling dog sub. no fish recovered. however, marks on three of the four rolling dogs indicate contact with a circular rod. The fourth dog was stuck in the up/open position and failed to contact anything. There were gouge marks on the I.D. of the dog sub extending into the rolling dog openings. A piece of rubber approx. 2" x 2" x 1/2" was recovered in the RCJB from above the dog sub. The circulating sub was also found to be solidly plugged with metal cuttings and scale like material. The 3-1/8" PAC collars were clear as was the oil jar and LBS. DECOMP Clear and clean rig floor. DECOMP Develop new plan forward from discussion with RWO engineering. DECOMP Day crew weekly HSE meeting. Reviewed previous weeks North Slope HSE events and IADC safety alerts. DECOMP RIH w/3-1/8" collars and ensure flow path clear through them. PUMU BHA #13. DECOMP RIH w/BHA #13 on 3-1/2" DP from derrick. DECOMP Held stripping drill with crew. DECOMP Resumed RIH w/3-1/2" DP from derrick to 1,963'. DECOMP R/U circulating head and break circulation. Attempting to plug off, 1.5 bpm at 2,000 psi going to 2,500 psi with less than 1 bpm, Line up and reverse 2 drill string volumes at 3.5 bpm at 1,000 psi. Line up and pump long way. 2,500 psi with 1/2 bpm. DECOMP Crew change, rig service, inspect derrick, set and test PVT's. DECOMP POOH from 1,963' standing back 3-1/2" drillpipe in derrick. DECOMP Stand back DC's, break down BHA. Found lets in RCJB plugged off. 2 were packed off with EP Mud Lube and metal shavings and 1 was packed off with a piece of brass. Clear jets and flush with water. DECOMP RIH with BHA #13, Pump through BHA to insure flow path, 2.5 bpm at 1,800 psi. DECOMP RIH with BHA #13 on 3-1/2" drillpipe to 1,963'. Break circulation. 2.5 bpm at 1,850 psi. DECOMP RIH with BHA #13 on 3-1/2" drillpipe to 5,058'. Break circulation. 2 bpm at 2,070 psi. DECOMP RIH with BHA #13 on 3-1/2" drillpipe to 7,856'. Break circulation. 2.5 bpm at 1,860 psi. RIH to 10,812'. DECOMP M/U Kelly and establish parameters. P/U weight 154K, S/O weight 120K. 3 bpm at 2,100 psi. S/O and tag TOF at 10,825'. Work over TOF and work down to , pump pressure increased to 2,850 psi at 1.5 bpm. Set 25-30K down. Worked string multiple times did not see TOF again. 03:00 - 06:00 I 3.001 FISH I P 06:00 - 06:30 I 0.501 FISH I P 06:30 - 10:00 I 3.501 FISH I P 10:00 - 11:00 1.00 FISH P 11:00 - 12:00 1.00 FISH P 12:00 - 13:00 I 1.001 FISH I P 13:00 - 15:00 I 2.00 I FISH I P 15:00 - 16:00 1.00 FISH P 16:00 - 16:30 0.50 FISH P 16:30 - 17:00 0.50 FISH P 17:00 - 18:00 1.00 FISH P 18:00 - 18:30 0.50 FISH P 18:30 - 19:30 1.00 FISH P 19:30 - 21:00 1.50 FISH P 21:00 - 21:30 0.50 FISH P 21:30 - 22:00 0.50 FISH P 22:00 - 00:00 I 2.001 FISH I P 5/11/2009 ~ 00:00 - 02:00 ~ 2.00 ~ FISH ~ P 02:00 - 03:30 I 1.50I FISH I P Printed: 6/8/2009 11:38:45 AM v • i -_ BP EXPLQR~4TIQN' Page ~2 of 25 ' Operations Surnmary Report Legal Well Name: J-20 Common Well Name: J-20 Spud Date: 8/1/1996 Event Name: WORKOVER Start: 4/26/2009 End: 5/31/2009 Contractor Name: NABORS ALASKA DRI LLING I Rig Release: 5/31/2009 Rig Name: NABORS 4ES Rig Number: Date FrQm - To Hours Task Code NPT Phase ' Description of Operations 5/11/2009 03:30 - 06:00 2.50 FISH P DECOMP Drop dart. Shear open pump out sub. Stand back Kelly and POOH standing back 3-1/2" IF drillpipe in derrick. 06:00 - 06:30 0.50 FISH P DECOMP Crew change, PTSM, service rig, check PVT's, daily derrick inspection and enviro walkaround. 06:30 - 09:30 3.00 FISH P DECOMP Resume POH w/BHA #13 standing 3-1/2" IF DP in derrick. Gave AOGCC 24-hr. notification of impending weekly BOPE test. Jeff Jones waived states right to witness BOPE testing. 09:30 - 10:00 0.50 FISH P DECOMP Break out and lay down BHA. Recovered Quik-Pik 1-5/8" x 10:00 - 11:30 1.50 FISH P DECOMP Clear and clean rig floor. Collaborate and develop plan forward with RWO engineers. 11:30 - 14:00 2.50 FISH P DECOMP Wait on arrival of fishing tools. 14:00 - 15:30 1.50 FISH P DECOMP PJSM - Review making up BHA procedure. PUMU BHA #14 as follows: 3-5/8" RCJB w/3.75" shoe, Bit Sub, 3 ea. 3-1/8" PAC Drill Collars, XO, XO, 6-1/4" LBS, 6-1/4" Oil Jar, 6-1/4" Pumpout Sub, XO, 9 ea. 6-1/4" Drill Collars, XO = 394.40'. Note: 3.75" shoe is dimpled and the dimpled I.D. is 3.00". 15:30 - 18:00 2.50 FISH P DECOMP RIH w/BHA #14 on 3-1/2" DP from derrick. 18:00 - 18:30 0.50 FISH P DECOMP Crew change, rig service, derrick inspection, set and test PVT's. 18:30 - 20:00 1.50 FISH P DECOMP RIH w/ BHA #14 on 3-1/2" DP from derrick to 10,812'. 20:00 - 21:00 1.00 FISH P DECOMP M/U Kelly, establish parameters, P/U weight 154K, S/O weight 120K, Rotating weight 136K, 35 rpm at 3,250 ft/Ibs of torque, 5.5 bpm at 1,720 psi. Wash and rotate down, tag TOF at 10 827 Work ver ' t 35 rpm with 3,250 to 3,500 ft/Ibs of torque, 2K WOM, 5.5 bpm at 1,720 to 1,750 psi pump pressure. Work down to 10,831'. P/U and work down multiple times. Set down 30K. 21:00 - 00:00 3.00 FISH P DECOMP POOH with BHA #14 standing back 3-1/2" drilipipe in derrick. 5/12/2009 00:00 - 01:00 1.00 FISH P DECOMP POOH with BHA #14 standing back 3-1/2" drillpipe in derrick to 394'. 01:00 - 03:00 2.00 FISH P DECOMP Stand back 6-1/4" DC's, Break out and UD BHA #14, 3-5/8" RCJB modified with Dimples and V-Notches. Recovered 3-1/8" X 7" Bottom Nut, pieces of slip segments, packer pieces, overshot and mule shoe pieces. Also recovered some jet cutter bris. 03:00 - 04:00 1.00 FISH P DECOMP Hold weekly safety meeting with crew. 04:00 - 06:00 2.00 CLEAN P DECOMP M/U 2-7/8" Muleshoe and 2 joints of Fox tubing and RIH on 3-1/2" drillpipe from derrick. 06:00 - 06:30 0.50 CLEAN P DECOMP Crew change - PTSM. Service rig, check PVT's, daily derrick inspection and enviro walkaround. 06:30 - 10:30 4.00 CLEAN P DECOMP Resume RIH w/BHA #15 on 3-1/2" DP from derrick. Tagged 7" liner top at 10,790'. Set 3K downweight and applied 5 rounds torque. Muleshoe flopped over and went in liner. 10:30 - 15:30 5.00 CLEAN P DECOMP Rig up joint with TIW valve and headpin and hook up cement line to reverse circulate. Tag bottom at 10,831' and wash down to 4-1/2" WRP at 10,841' reverse circulating. Reverse circulated 3 bottoms up to clean off top of WRP. 15:30 - 19:30 4.00 CLEAN P DECOMP Pump 30 bbls of hot diesel, followed by 100 bbls of Safe-Surf O sweep. Displace well to clean 8.5 ppg seawater. 5.5 bpm at 1,640 psi. 19:30 - 22:30 3.00 CLEAN P DECOMP POOH with Reversing Assembly, standing back 3-1/2" drill pipe Pnntetl: 6/8/2009 11:38:45 AM ~ • ~ BP EXPLORATIQN Page 73 of 25 ' Operations Summary R~port Legal Well Name: J-20 Common Well Name: J-20 Spud Date: 8/1/1996 Event Name: WORKOVER Start: 4/26/2009 End: 5/31/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/31/2009 Rig Name: NABORS 4ES Rig Number: Date' From - To Hours Task Code NPT Phase Description of aperatians 5/12/2009 19:30 - 22:30 3.00 CLEAN P DECOMP in derrick. 22:30 - 23:00 0.50 CLEAN P DECOMP B/O and L/D 2-7/8" Fox Reversing Assembly. 23:00 - 23:30 0.50 BOPSU P DECOMP Pull Wear Bushing and install Test Plug. 23:30 - 00:00 0.50 BOPSU P DECOMP Perform weekl BOP testing per BP/AOGCC requirements. Tested pipe rams with 3-1/2" and 4-1/2" testjoints to 250-psi Lo/3500-psi Hi. Tested annular preventer with 3-1/2" test joint to 250-psi Lo/3500-psi Hi. Tested choke manifold, both manual and HCR kill and choke valves, floor safety valve, IBOP and upper and lower kelly valves. AOGCC witness of test was waived by Jeff Jones, test was witnessed by BP WSL and Nabors Toolpusher. 5/13/2009 00:00 - 05:00 5.00 BOPSU P DECOMP Perform weekly BOP testing per BP/AOGCC requirements. Tested pipe rams with 3-1/2" and 4-1/2" test joints to 250-psi Lo/3500-psi Hi. Tested annular preventer with 3-1/2" test joint to 250-psi Lo/3500-psi Hi. Tested choke manifold, both manual and HCR kill and choke valves, floor safety vaive, IBOP and upper and lower kelly valves. AOGCC witness of test was waived by Jeff Jones, test was witnessed by BP WSL and Nabors Toolpusher. 05:00 - 06:00 1.00 BOPSU P DECOMP Break down test assemblies and install 9-1/8" Wear Bushing 06:00 - 06:30 0.50 CASE P TIEB1 Crew change. Service Rig. Inspect Derrick. Check PVT alarms. 06:30 - 08:30 2.00 CASE P TIEB1 Make-u Baker Polish Mill Assembl consisting of 7.42" OD fluted polish mill spaced out 5.90' below 8.36" OD top dressing mill w/brass indicator pads, xo to 9-5/8" casing scraper, xo, xo, pump out sub, xo to nine 6-1/4" drill collars, xo to drill pipe. OAL BHA = 296.53'. 08:30 - 22:00 13.50 CASE N RREP TIE61 Repair glycol brake coolant line leak. Procure and replace hose. 22:00 - 23:00 1.00 CASE P TIE61 RIH w/Polish mill BHA and ta to of 7" liner at 10791'. 23:00 - 00:00 1.00 CASE P TIEB1 Rotate off liner top and into liner top tieback sleeve to 10797'. SO 3K on liner top. PU 10'. Rotate 53 rpm, 4 Bpm, 720 psi, tq. 4.3K. PU 116, SO 101, ROT 107. Work ~p and down slowl several times dressin ti bac I 5/14/2009 00:00 - 05:00 5.00 CASE P TIE61 Dump six sacks sand w/table and hose and spot down drill pipe. PU and allow sand to fall out. Displace Drill Pipe volume with Sea Water. RIH and tag up w/Top Dress Mill at 10797'. Sleeve clear of sand. 05:00 - 06:00 1.00 CASE P TIEB1 POH w/tieback sleeve polish mill assembly. 06:00 - 09:00 3.00 CASE P TIEB1 PUmp small dry job. Start to trip out with 3 1/2" Drill Pipe and Polish Mill Assembly. 09:00 - 09:30 0.50 CASE P TIEB1 Crew change (long change day). Service Rig. Inspect Derrick. Check PVT alarms. 09:30 - 10:30 1.00 CASE P TIEB1 Continue to trip out t 3,300-ft. 10:30 - 11:30 1.00 CASE P TIEB1 Drop dart to drift Drill Pipe and Drill Collars. Open Circulation Sub with 1200 psi. Circulate remaining Drill Pipe and Drill collars clean to prep for cementing scab liner. 11:30 - 12:30 1.00 CASE P TIEB1 Finish trip out with 3 1/2" Drill Pipe. Stand back Drill Collars. 12:30 - 13:30 1.00 CASE P TIEB1 Break out and lay down Polish Mill assembly. Inspect and o serve normal expected wear on tattle-tail pads on Top Dress MIII. Saw small amount of wear on the Polish MIII blades. 13:30 - 14:00 0.50 CASE P TIEB1 Clear and clean floor. Printed: 6/8/2009 11:38:45 AM , ~ ~ BP EXPLORATION' Page 14 ofi 2~ Qperations Sumrnary Repart Legal Well Name: J-20 Common Well Name: J-20 Spud Date: 8/1/1996 Event Name: WORKOVER Start: 4/26/2009 End: 5/31/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/31/2009 Rig Name: NABORS 4ES Rig Number: i Date From - To Hours Task Code NPT Phase Description of Operations 5/14/2009 14:00 - 15:00 1.00 CASE P TIEB1 PU 9-5/8" RTTS. 15:00 - 19:30 4.50 CASE P TIEB1 RIH to 9624'. 19:30 - 21:30 2.00 CASE P TIEB1 RIH and 2 qal seawater over top of drillpipe, wind blew over windwalls onto roof of rig. Dripped down wall of rig and into duckpond secondary containment. 1 cup missed containment and was found on pad. Called 5700, called superintendent. Spill tech called back and directed us to pick up dirt and mop up from containment w/absorb. Perform cleanup as instructed. Place all in waste bag for spill tech to pick up 5-15-09. Meet w/tourpusher, WSL, crew to discuss avoidance of repeat situation. IR #3072200 created. Circulate to clear packer elements of possible viscous materials. 21:30 - 22:30 1.00 CASE P TIEB1 RIH to 10700. 22:30 - 00:00 1.50 CASE P TIEB1 Test casinq below RTTS to 1000 psi f/ten min. POH to 3500' f/casin test. 5/15/2009 00:00 - 03:00 3.00 CASE C TIEB1 POH f/10700 to 3500 for casing test. 5 gal grey water overflow due to malfunction of flushing system for boiler water softener system, 5700 notified. IR to follow. 03:00 - 04:00 1.00 CASE C TIEB1 Set RTTS. RU and test casing above RTTS to 3500 for 30 charted min. 04:00 - 06:00 2.00 CASE C TIEB1 POH w/RTTS. Prep to RIH w/7" 26# L-80 BTC tieback liner. 06:00 - 07:30 1.50 CASE C TIEB1 Rig down 3 1/2" handling equipment. Clear and clean rig floor. Rig up equipment to handle and run 7" Casing. 07:30 - 08:00 0.50 CASE C TIEB1 PJSM with All. Topic discussed: Running casing. Also discussed safety topics related to picking up and running casing. 08:00 - 12:00 4.00 CASE C TIE61 Pick up 7" Scab Liner shoe Track as follows: Baker Tie-Back Seal Assembly, 1 Joint of 7" 26 Ib/ft L-80 BTC-M Casing, HES Float collar, 1 Joint of 7" 26 Ib/ft L-80 BTC-M Casing, 1 Joint of 7" 26 Ib/ft L-80 BTC-M Casing w/Insert Landing Collar in the pin end. Continue to single in with 7" 26 Ib/ft L-80 BTC-M Casing from Pipe Shed. Baker-Loc'd all connections in Shoe Track. Install centralizers on every joint. Fill casing every 5 joint with Sea Water. 12:00 - 12:30 0.50 CASE C TIEB1 Crew change (Crew rotated in from days-off). PJSM and operations meeting with Crew that just rotated in. 12:30 - 21:00 8.50 CASE C TIEB1 Continue running 7" Llner. 21:00 - 00:00 3.00 CASE C TIEB1 PJSM 7" casing running prior to tour change w/Smith crew. Continue RIH w/7" casing. 5/16/2009 00:00 - 01:00 1.00 CASE P TIE61 Cont. RIH w/7" liner filling every 5 joints. 01:00 - 01:30 0.50 CASE P TIEB1 PJSM. MU liner hanger/liner top packer assembly to 7"liner. 01:30 - 02:30 1.00 CASE P TIEB1 Circulate one liner volume 312 bbls at 5 bpm 270 psi. PU 165K, SO 130K. 02:30 - 04:30 2.00 CASE P TIEB1 PU nine 6-1/4" drill collars to achieve packer setting weight requirements. RIH w/7" liner on drill pipe filling every 10 stands. Space out to floor. 04:30 - 06:00 1.50 CASE P TIEB1 RU Schlumberger. Spot trucks. RU cementing head and hoses. 06:00 - 06:30 0.50 CASE P TIEB1 Nabors and Schlumberger Crew changes. Service Rig. Inspect Derrick. Check PVT Alarms 06:30 - 07:45 1.25 CASE P TIEB1 Continue with rigging up lines. 07:45 - 08:15 0.50 CASE P TIEB1 PJSM and Operations meeting with Nabors, Schlumberger, CH2M Hill, Baker, Mudman. Printed: 6/8/2009 11:38:45 AM t ~ ~ Legal Well Name: J-20 Common Well Name: J-20 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES ^ata' I Frnm - Tn ! Hnr.irc I Ta_ck f f`.nr~a I N'PT Start: 4/26/2009 Rig Release: 5/31/2009 Rig Number: ~ Spud Date: 8/1/1996 End: 5/31 /2009 5/16/2009 08:15 - 09:00 0.75 CEMT P T IEB1 Prime up and pressure lest lines at 550 psi/4500 psi. Good test. 09:00 - 11:30 2.50 CEMT P T IEB1 Batch mix Cement. Start cement at 4.8 bpm/700 psi/15.6 ppg. 50 bbls Cmt away = 5.5 bpm/575 psi/15.7 ppg. 100 bbls Cmt away = 4.2 bpm/370 psi/15.9 ppg. 150 bbls Cmt away = 4.1 bpm/340 psi/15.9 ppg. 200 bbls Cmt away = 4.2 bpm/300 psi/15.8 ppg. Final Cmt volume pumped 228 bbls (calculated volume behind Scab Llner = 195 bbls . Final Cmt away = 4.2 bpm/330 psi 15.7 ppg. Pump 5 bbls fresh water to flush line. Drop Pump Down Dart (flipper-dog tripped in Cement head). Start displacing Cement with 9.8 Ib/gal Brine at 5.2 bpm/225 psi. Watch for any pressure sign of a pressure bump when Dart hit Liner Wiper Plug in Running Tool. Saw nothing ( well on vacuum due to falling cement). Continue displacing Cement with Brine. Increase rate to 7.2 bpm to catch up to Cement. Caught up to cement with 150 bbps pumped at 6.2 b m/1150 si. W ith 250 bbls away, reduce rate to 4.2 bpm/1650 psi. W ith 290 bbls away, reduce rate to 3.0 bpm/1850 psi. With 300 bbls away reduce rate to 2.0 bpm and start looking fo W iper Plug to bump ~caculated displacemant to bump Plug = 312 bbls). Did not see plug bump at 312 bbls. Continue to displace. Called Anch Eng and discuss "over-displacemenY' Stopped displacing cement at 332 bbis away (~20 bbis over-displace). Shut down pump at 11:20 Hrs. Land Tie-Back Seal Assembl to the No-Go collar. Check Float. No flow back Flo t holdin . 11:30 - 13:00 1.50 CEMT P T IE61 Pressure up to 3,000 psi to set Flex Lock Linger Hanger. Slack off Liner weight plus 50K. Rotate with righ-hand release. Pick-up out of Liner Hanger and slack of on ZXP Packer. Set max weight available of 48K down on packer. Repeated several times and confirmed with right-hand rotation to make sure all weight got down to the Packer. 13:00 - 14:30 1,50 CEMT P T IE61 Reverse circulate excess cement back to surtace. Estimate 30 to 40 bbis of strung-out thin cement recovered in Slop Tank (33 bbls was the volume of excess Cement um er ro ram). Continue to reverse Well and Drill Pipe clean. 14:30 - 16:00 1.50 CEMT P T IEB1 Lay down Cementing Head. Trip out with 3 1/2" Drill Pipe, 6 1/4" Drill Collars, and Baker Setting Tools. Inspect Setting Tools. Tool indicator sub was properly sheared and the Wiper Plug was gone. 16:00 - 18:00 2.00 CEMT P T IEB1 Lay down Baker Setting Tools. Run in with 6 1/4" Drill Collars and lay same. 18:00 - 00:00 6.00 CEMT P T IEB1 Waiting on cement for 1000 psi compressive strength. PU and stand back collars 4-3/4" collars and 6-1/8" cleanout BHA. Clean out pits. 5/17/2009 00:00 - 01:30 1.50 CEMT P T IE61 Wait on cement. RU to test casing. PU 4-3/4" collars. Prep 6-1/8" cleanout BHA. 01:30 - 03:00 1.50 CEMT N DPRB T IEB1 Test casin and 7" liner top. Pressure u to 3500 174 strokes and held ok f/10 minutes then be an ra id bleed off. Trouble shoot all surface equipment and attempt retest. Pressure up to 3500 si 173 strokes. Start um in in at 2700 si. Shut in and observe pressure bleed to 1700 and stabilize. Two more attempts to pressure up and test resulted in leakoff. Total of 35 Printed: 6/8/2009 11:35:45 AM a ~.. ~ • or ~n Operations Legal Well Name: J-20 Common Well Name: J-20 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES i i i i i i _ORATIUN Pag~ 16 ~ umrnary Report Spud Date: 8/1/1996 Start: 4/26/2009 End: 5/31/2009 Rig Release: 5/31/2009 Rig Number: ~se ~~~~~ Description of Operatit~ns 1 bbls lost to leak in four attempts to test. OA open to bucket and under observation during test no evidence of flow around acp koff• 1 Consult w/town team and mobilise a 7" RTfS test packer. 1 Crew change. Service Rig. Inspect Derrick. Check PVT Alarms. Continue to off-load clean Sea water in Rig Pits. Load Halco 7" RTTS Packer in Pipe Shed. 1 Make up 7" RTTS Packer. Install 3 1/2" IF Mule Shoe on bottom of Packer. 1 Trip in with 7" Packer, 4 3/4" Drill Collars, and 3 1/2" Drill Pipe from Derrick. 1 Set the RTTS Packer at 3,394' Pum down the Drill Pi e at got full returns up the Annulus.. Shut Pipe Rams and pump down the back side. Both the Annulus and the Drill Pipe recored pressure build pound for pound. Pressured up to 3000 psi. After 10 minutes both sides fell off 700 psi. Release Packer and moved up hole to 3,363'. RE-tested with the same results with the pressure falling off on both side by 600 psi in 12 minutes. Released Packer and re-set, getting a little more agressive think that the circulating valve was not closing all the way. Pump down the Drill Pipe and once again fluid is circulatinq up the back side. 1 Released RTTS Packer and Trip out with 3 1/2" Drill Pipe, 4 3/4" Drill Collars, and Packer. Lay down Packer. Halliburton will take back to their shop for inspection and pressure testing (Halliburton found no aroblems with the Packer after 5/17/2009 01:30 - 03:00 1.50 CEMT N DPRB TIEB 03:00 - 06:00 3.00 CEMT N DPRB TIEB 06:00 - 07:00 1.00 CEMT N DPRB TIEB 07:00 - 07:30 0.50 CEMT N DPRB TIEB 07:30 - 09:30 2.00 CEMT N DPRB TIEB 09:30 - 12:30 3.00 CEMT N DPRB TIEB 12:30 - 14:00 I 1.501 CEMT I N I DPRB I TIEB 14:00 - 15:30 1.50 CEMT P TIEB1 Lay down RTTS. Clear and clean rig floor. 15:30 - 16:30 1.00 CEMT P TIEB1 Weekly Sunday Safety Meeting Attemed by Day Crew, Baker Fishing Tool Serviceman, Tool Pusher, WSL, Allen Graff, anf the President of BP Alaska. 16:30 - 18:00 1.50 CEMT P TIEB1 Make u cement cleanout BHA #17 as follows: 6-1/8" bit, 2 boot baskets, 7" casing scraper, bit sub, oil jars, pumpout sub, 9 drill collars. OAL BHA 17 = 306.33'. 18:00 - 18:30 0.50 CEMT P TIEB1 Service rig. 18:30 - 19:30 1.00 CEMT P TIEB1 Continue PU BHA 17. 19:30 - 22:30 3.00 CEMT P TIEB1 RIH w/BHA. fy,o difficultv enterina liner to~ 3190'. Taa up on lu landin ' No cement stringers encountered. 22:30 - 23:30 1.00 CEMT P TIEB1 Weekly safety meeting w/Smith crew, tourpusher, WSL, roughneck trainer. Discuss incidents and performance. Discuss EMS and ISO 14001 awareness and each individuais environmental responsbility. 23:30 - 00:00 0.50 CEMT P TIE61 Circulate brine in hole to clean 8.5 ppg seawater. 1750 psi, 5.4 bpm. 5/18/2009 00:00 - 01:30 1.50 CEMT P TIEB1 Continue circulate brine out to clean 8.5 ppg seawater. 01:30 - 06:00 4.50 CEMT P TIEB1 Drill lu s and landin collar from 10718'. 493 psi, 3 bpm, tq off 3.5K, tq on 4.7K, rpm 75, 2-7K WOB, 153K up, 110fK dn, 137K rot. Spinning on plugs, vary WOB, rpms, fluid rates as required. 06:00 - 06:30 0.50 CEMT P TIEB1 Crew change. Service Rig. Inspect Derrick and check PVT Printed: 6/8/2009 11:38:45 AM 1 + ~ • BP' EXPLQRATION Page 17 of 25 Qperations Summary Report Legal Well Name: J-20 Common Well Name: J-20 Spud Date: 8/1/1996 Event Name: WORKOVER Start: 4/26/2009 End: 5/31/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/31/2009 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Coda NPT Phase Description of Operations 5/18/2009 06:00 - 06:30 0.50 CEMT P TIE61 06:30 - 10:30 4.00 CEMT P TIEB1 10:30 - 12:15 ~ 1.75 ~ CEMT ~ P 12:15 - 18:30 6.25 CEMT P 18:30 - 19:00 0.50 CEMT P 19:00 - 00:00 5.00 CEMT P 5/19/2009 00:00 - 01:30 1.50 CEMT P 01:30 - 02:00 0.50 CEMT P 02:00 - 03:30 1.50 CEMT P 03:30 - 06:00 2.50 CEMT P 06:00 - 06:30 0.50 CEMT P 06:30 - 08:00 1.50 CEMT P 08:00 - 09:30 1.50 CEMT P 09:30 - 11:30 2.00 CEMT P 11:30 - 12:30 1.00 CEMT P 12:30 - 14:30 2.00 CEMT P 14:30 - 15:30 1.00 CEMT P 15:30 - 17:00 I 1.50I CEMT I P 17:00 - 18:00 18:00 - 18:30 18:30 - 21:00 21:00 - 00:00 1.00 CEMT P 0.50 CEMT P 2.50 CEMT P 3.00 CEMT P 5/20/2009 00:00 - 00:30 00:30 - 02:30 0.50 CEMT P 2.00 CEMT N TIE61 TIEB1 7iEB1 TIEB1 TIEB1 TIE61 TIEB1 TIEB1 TIEB1 TIE61 TIE61 TIEB1 TIE61 TIEB1 TIE61 TIEBi TIE61 TIEB1 TI EB 1 TIEB1 TIEB1 DPRB TIEB1 alarms. Continue to drill through Landing Collar at 10, 718'. Drill through Float at 10,759'. Found mushVi cement under float. Contiue rotating and washing down to unknown top of sand and tagged the 7" x 5 1/2" XO at 10,813' dmd Mix and pump a 20 bbl Hi-Vis sweep. Circulate Well clean at 5.0 bpm/1400 psi. Returns Contaminated cement and 20/40 mesh sand. No fluid loss. Set back Kelly. Monitor Well dead. Trip out with 3 1/2" Drill Pipe and BHA #17. Clear and clean rig floor. RIH w/HallibuRon Champ packer for casing test above Champ qacker. Set at 10600. RU and test casing f/10600 to surface over 7" Halliburton Champ packer. First attempt no test due to surface leak. Bleed down and check all surface equipment. 2nd attempt qood test with chart to 3500 nsi for 30 minutes. RD test equipment and clear floor. Slip and cut drill line. Service rig. POH w/Halco Champ packer. Crew change. Service Rig. Inspect Derrick. Check PVT Alarms. Continue to Trip out with 3 1/2" Drill Pipe. Per conversation with Anch Eng. Stop at 5,966'. Set Halco 7" Champ Packer. Test 7" Casing, Liner Hanger Equipment and 9 5/8" Casing back to surface at 3,500 psi x 20 minutes. Good test. Lost -25 psi. Then tested the 7" Casing, Shoe Track against the cement, and the sand top above the W RP at 3500. psi x 10 minutes. Good test. _ Finish Trip out with Drill Pipe and Drill Collars. Stand back DCs & UD packer. Clear & clean rig floor. Pressure test casing one more time per Anch Eng. Close Blind Rams and pressure up on well bore to 3,500 psi (115 strokes = 6.76 bbls) x 15 minutes. Good test lost -30 psi. P/U & M/U BHA #18 as follows: 3.70" Bladed Mill 2 Boot Baskets, Bit sub, 2- 2 7/8" PAC DCs, XO, Oil Jars, Pump Out Sub, 9- 4 3/4" DCs. TL = 360.70'. RIH w/ BHA #18 to clean out 4 1/2" to WRP. Crew Change. Service rig. Check PVT alarms. Inspect derrick. Con't to RIH w/ total ot 111 stands of 3 1/2" DP & BHA. P/U 2 DP singles. (10777.66') P/U kelly establish circulation & clean out parameters. Tagged uo on fill C~3 10803' (25' in on kelly. Wash & drill from TQ863"~ 10828'. Maximum torque limit met le~ 10K ft-Ibs C~ 10828'. Still drilling hard bottom when quit. P/U Wt - 185K, S/O Wt = 94K, Rot Wt = 127K. Free Torq = 9k ft-Ibs. 50-60 RPMs, 3 BPM Q 550 psi. ( Washed soft fill from 10803 to 10817'. Entered X-over C~3 10818' Drill harder from 10818 to 10828'.) Notified town engineer of torque problems & hard drilling. Ok'd using EP Mud lube. Attempted to locate EP Mud lube (Baroid product.) None on Slope, next shipment due Friday. Located MI's eqivelant. Printed: 6/S/2009 11:38:45 AM t ~ ~ ~ __ BP EXPLORAT[UN Pag~ 18 of 25 ~~~~~ Operations Surnmary Report Legal Well Name: J-20 Common Well Name: J-20 Spud Date: 8/1/1996 Event Name: WORKOVER Start: 4/26/2009 End: 5/31/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/31/2009 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Deseription of Op~ratit~ns 5/20/2009 00:30 - 02:30 2.00 CEMT N DPRB TIEB1 Arrived on location & approx. 0230 hrs. 02:30 - 04:30 2.00 CEMT P TIE61 Mixed MI Mud Lube & circulated down hole. Reduced drag 25 amps. Attempt to drill ahead from 10828'. Strinq pressures up when tapqinp up & puttinp wt on mill. No progress in - 45 min of attempts. Notify Town engineer & plan to POOH & inspect string & boot basket samples. 04:30 - 06:00 1.50 CEMT P TIEB1 Hold PJSM. Set back kelly. & POOH w/ BHA #18. 06:00 - 06:30 0.50 CEMT P TIEB1 Crew change. Service Rig. Inspect Derrick. Check PVT Alarms. 06:30 - 10:30 4.00 CEMT P TIEB1 Trip out with 3 1/2" Drill Pipe. Stand back 4 3/4" Drill Collars. 10:30 - 12:00 1.50 CEMT P TIEB1 Lay down 2 ea 3 1/8" PAC Drill Collars. Lay down remaining BHA. However, the upper Boot Basket has parted. Left the Mill, lower Boot Basket, and the remains of the parted Boot Basket in the hole. Total lenght of Fish = 5.63'. Also the BHA was coated in places with a" gummy tar" from the use of Mls mud lube used to reduce torque. 12:00 - 13:00 1.00 CEMT TIEB1 Clear and clean Floor. 13:00 - 15:00 2.00 WHSUR P TIEB1 PJSM. Pull Wear Bushing. Make up Pulling tool and pull 9 5/8" Pack-Off. BOLDS. Pull 9 5/8" Pack-Off through BOP Stack at 33K with no problems. Install new Pack-Off. RILDS. Test Pack-Off at 5K x 30 minutes. Good test. 15:00 - 18:00 3.00 BOPSU P TIEB1 PJSM. Install Test Plug. Rig up test equipment. Test BOPE per BP/AOGCC requirements at 250/3500 psi. Test Pipe Rams with the 3 1/2" and the 4 1/2" Test Joints. Test Annular with the 3 1/2" Test Joint. The State's right to witness the test was waived by L. Grimaldi. 18:00 - 18:30 0.50 BOPSU P TIEB1 Crew change. Service rig. Inspect derrick. Check PVT alarms. 18:30 - 21:00 2.50 BOPSU P TIE61 Con't to test BOP as per BP/AOGCC requirements. LP 250 psi, HP 3500 psi. Used 3 1/2" & 4 1/2" testjts. No failures. L/D test jts & R/D test equipment. 21:00 - 22:00 1.00 WMSUR P TIEB1 Drain stack. P/U running tool. Pull Test plug. Install Wear Bushing & RI 4 LDS. L/D running tool. 22:00 - 23:30 1.50 FISH N DFAL TIEB1 P/U & M/U BHA #19 as follows to dress off fish. 3.8" x 1.875" FB Mill, Top Drive Bushing, XO, 2- 2 7/8" PAC DCs, XO, Bumper sub, Jars, Po Sub, 9- 4 3/4" DCs. TL = 364.48'. 23:30 - 00:00 0.50 FISH N DFAL TIEB1 RIH w/ BHA #19 on stands of 3 1/2" DP. 5/21/2009 00:00 - 02:30 2.50 FISH N DFAL TIEB1 Con't to RIH w/ BHA #19 on 111 stands of 3 1/2" DP. 02:30 - 03:00 0.50 FISH N DFAL TIEB1 P/U 2 DP singles + 24' DP pup & RIH. P/U kelly & break circulation. 03:00 - 06:00 3.00 FISH N DFAL TIE61 Taq up on fish C~ 10821'. Establish milling parameters. Begin dressing off fish C~ 10821'. P/U Wt = 165K, S/O Wt = 106K, Rot Wt = 130K. Free Torq = 5K ft- Ibs. Set torq limiter to 6K ft-Ibs. 50-55 RPMs, WOB = 1 K. 2 BPM C~3 260 psi. 06:00 - 06:30 0.50 FISH N DFAL TIEB1 Crew change. Service Rig. Inspect Derrick. Check PVT Alarms. 06:30 - 08:30 2.00 FISH N DFAL TIEB1 Parameters: Amps 180, RTW = 127K, RPMs = 56, Pump rate = 2 bpm/215 psi. Mllled a total of 7 inches. End milling. 08:30 - 10:15 1.75 FISH N DFAL TIE61 Pump a 20 bbl HI-Vis Sweep. circulate and clean up hole at 5.0 bpm/1075 psi. Returns clean, very little fines. No fluid losses. Monitor Well dead. 10:15 - 14:30 4.25 FISH N DFAL TIEB1 Set back Kelly. Trip out with 3 1/2" Drill Pip~. 14:30 - 15:30 1.00 FISH N DFAL TIEB1 Stand back 4 3/4" Drill Collars. Pull 3 1/8 PAC BHA. Pin snapped on the bottom PAC Drill Collar. Left a second fish in ' Printetl: 6/8/2009 11:38:4b AM ~ , ~ • \ Legal Well Name: J-20 Common Well Name: J-20 Spud Date: 8/1/1996 Event Name: WORKOVER Start: 4/26/2009 End: 5/31/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/31/2009 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/21/2009 14:30 - 15:30 1.00 FISH N DFAL TIEB1 hole. Notify Anch Eng and discuss plan forward. Fish left in hole 3.80" Flat Bottom shoe, Top Drive Sub, 3 1/8" OD Cross-Over Sub w/2 7/8" PAC pin dutchman. TOF = 10,817'. 15:30 - 18:00 2.50 FISH N DFAL TIEB1 Order out a new 3 1/2" IF box x 2 7/8" PAC pin. Load a new joint of 3 1/8" PAC Drill Collar in Pipe Shed. 18:00 - 18:30 0.50 FISH N DFAL TIE61 Crew change. Service rig. Check PVT alarms. Inspect derrick. 18:30 - 20:00 1.50 FISH N D~AL TIEB1 P/U & M/U BHA #20 to fish PAC drill collar as follows: O/S, XO, PAC DC, XO, XO, Bumper Sub, Jars, P/O Sub, 9- 4 3/4" DCs. TL = 335.82'. 20:00 - 22:00 2.00 FISH N DFAL TIEB1 RIH w/ BHA #20 on stands of 3 1/2" DP. Started to take wt (25k) on stand 71. Gummed up Steel Lube EP. 22:00 - 23:00 1.00 FISH N DFAL TIEB1 Circulate bottoms up. 5.4 BPM ~ 1060 psi. Pumped total of 324 bbls. 23:00 - 00:00 1.00 FISH N DFAL TIEB1 Con't to RIH w/ BHA #20 on stands of 3 1/2" DP. 5/22/2009 00:00 - 01:00 1.00 FISH N DFAL TIE61 Con't to RIH w/ BHA #20. RIH w/ total of 112 stands + 1- 10' DP pup. 01:00 - 02:00 1.00 FISH N DFAL TIEB1 PJSM. P/U kelly & break circulation. Establish fishing parameters. RIH & engage fish 10822' swallow to 10825 w/ 15K down wt. Pump pressure increased 200 psi while swallowing. P/U, retag w/ 10K down wt & verify fish on. P/U Wt = 157K, S/O Wt = 106K, Rot Wt = 126K. Pumped 3 BPM ~ 520 psi. 12 RPMs while going down to engage fish. Free Torq = 4K ft-Ibs. Blow down & Set back kelly. UD 10' DP pup. 02:00 - 06:00 4.00 FISH N DFAL TIEB1 PJSM. POOH w/ BHA #20 & stand back 3 1/2" DP. 06:00 - 08:00 2.00 FISH N DFAL TIEB1 Finish POOH with Drill Pi e. PUII BHA #20. Did not recover Fish. Inspect Overshot, saw indications that Overshot was over Fish (at least part way). Lower section of the BHA was covered with "gummy tar". Discuss plan forward with Anch Eng Team to clean-up liner with hot diesel on the re-run with same Overshot w/new Grapple and Control Arm. (Service Rig. Check Derrick, Check PVT alarms with talking to Town). Clean-up Overshot. 08:00 - 14:30 6.50 FISH N DFAL TIEB1 Install new Grapple and Control Arm in Overshot. RIH with BHA #21 (re-run of BHA #20). RIH with 4 3/4" Drill Collars from Derrick. Trip in with 3 1/2" Drill Pipe from Derrick. 14:30 - 16:00 1.50 FISH N DFAL TIEB1 Stop to cut and slip Drilling Llne while waiting on Vac Trucks. Also spot and rig up Lil' Red Hot Oil Unit. 16:00 - 18:00 2.00 FISH N DFAL TIEB1 Wait on Vac trucks. Mix & pump 30 bbl Surf-Safe-O pill. Chase w/ 100 bbls of hot seawater. 18:00 - 18:30 0.50 FISH N DFAL TIEB1 Crew change. Service rig. Check PVT alarms. inspect derrick. 18:30 - 19:30 1.00 FISH N DFAL TIEB1 R/U Hot Oilers. Heat diesel to 175 degrees & pump 175 bbls down tubin . Pump 1 1/2 BPM Q 800 psi increased to 1100 psi. 19:30 - 20:00 0.50 FISH N DFAL TIE61 R/D Hot oilers. Chase hot diesel & SSO pill w/ 75 bbls of hot seawater. Pump 3-3 1/2 BPM ~ 860 - 440 psi. 20:00 - 22:00 2.00 FISH N DFAL TIEB1 R/U & reverse out the diesel & SSO pill. Pumped 4-5 BPM @ 1170 - 1500 psi. Pumped total of 400 bbls until fluid clean. Monitor well. 22:00 - 22:30 0.50 FISH N DFAL TIEB1 Rotate slowl & circulate while oin down over fish ~ 10823'. String pressured up to 600 psi. when swallowing fish. Swallowed -1'. P/U & bump down w/ 15K, 3 additional times to insure fish on. P/U Wt = 157K, S/O Wt = 110K, Rot Wt = 118K. 3 BPM ~ 420 psi. 15 RPMs, Free torq 3K ft-Ibs. Printed: 6/8/2009 11:38:45 AM ~ ~ • • BP EXPLORATION ' Page 20 Qf 25 Operations Summary Report Legal Well Name: J-20 Common Well Name: J-20 Spud Date: 8/1/1996 Event Name: WORKOVER Start: 4/26/2009 End: 5/31/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/31/2009 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Opera#ions 5/22/2009 22:00 - 22:30 0.50 FISH N DFAL TIEB1 22:30 - 00:00 1.50 FISH N DFAL TIEB1 PJSM. Blow down & set back kelly. POOH & stand back 3 1/2" DP. 5/23/2009 00:00 - 03:30 3.50 FISH N DFAL TIEB1 POOH w/ BHA #21 & stand back 3 1/2" DP. 03:30 - 04:00 0.50 FISH N DFAL TIEB1 Break out BHA. Recovered X-Over sub & Top Drive Sub. TL = 3.88'. 3.8". Flat Bottom Shoe left in hole (2.02'). 04:00 - 05:00 1.00 FISH N DFAL TIEB1 Clear & clean rig floor. 05:00 - 06:00 1.00 FISH N DFAL TIE61 Wait on Spear to fish Flat Bottom Shoe. 06:00 - 06:30 0.50 FISH N DFAL TIE61 Crew change. Service Rig. Inspect Derrick. Check PVT alarms. Bring ITCO Spear to floor. 06:30 - 07:00 0.50 FISH N DFAL TIEB1 Make-up BHA #22 as follows: Itco 2 7/8" spear, XO, XO, 1 Jt of 3 1/8 PAC Drill Pipe, XO, XO, Bumper sub, Oil Jar, Pump-out Sub, 9 ea 4 3/4" Drill Collars. TOL = 338.06 07:00 - 10:30 3.50 FISH N DFAL TIEB1 Trip in with BHA #22 and 3 1/2" Drill Pipe from the Derrick. 10:30 - 11:30 1.00 FISH N DFAL TIEB1 Kelly up. PUW = 147K. SOW = 115K. Bring pump on line at 3.0 bom/900 psi. Tag top of fish at 10,822'. Set down 10K Saw ve little um ressure if an . Pick-up and repeat same. Shut down pump. Set back down 10K one more time before POOH. 11:30 - 16:30 5.00 FISH N DFAL TIE61 Set back Kelly. Trip out of hole with 3 1/2" Drill Pipe. Pull BHA #22 No recovery. Clean and inspect Spear. Marks on Grapple indicate that the Spear was inside the fish. However, it may have bottomed out on the bull nose before the catch wa made. 16:30 - 18:00 1.50 FISH N DFAL TIEB1 Wait on a modified Taper Tap for next BHA #23. BHA to tap into FB Shoe as follows: 3 1/8" Taper Tap, XO, 1- PAC Dc, XO, XO, Bumper Sub, Jars, PO Sub, 9- 4 3/4" DCs. TL = 335.04' 18:00 - 18:30 0.50 FISH N DFAL TIEB1 Crew change. Service rig. Inspect derrick. Check PVT alarms. 18:30 - 22:00 3.50 FISH N DFAL TIE61 M/U Taner ta~on BHA. RIH on 112 stands of 3 1/2" DP. 22:00 - 00:00 2.00 FISH N DFAL TIEB1 P/U 10' DP pup & kelly. Break circulation 3 BPM C~3 500 psi. R/U Hot Oilers & pressure test lines to 2500 psi, Ok. Heat 25 bbls of diesel to 175 degrees & pump down DP. Displace diesel ~ 4 BPM, 1020 psi. w/ rig pump down & out DP After tagging up on fish C~ 10824'. R/D Hot Oilers. Swap over lines & reverse out diesel. Slowly RIH ~ 15 RPMs & screw into fish. Torque increased from 2500 ft-Ibs to 4k ft-Ibs. S/O 10K & release trapped torq. P/U w/ 2-3K overpull initally after BS & jars opened. 5/24/2009 00:00 - 04:30 4.50 FISH N DFAL TIE61 Hold PJSM. Blow down & set back kelly. UD 10' DP pup. POOH & stand back 112 stands of 3 1/2" DP. 04:30 - 05:30 1.00 FISH N DFAL TIEB1 Stand back 4 3/4" DCs. Break out BHA. Inspect Taper Tap. No recovery. 05:30 - 06:00 0.50 FISH N DFAL TIEB1 Inspect Taper tap. Taper tap appears to indicate 2.75" ID on fish rather than 3" ID. Call for spear to fish 2.75". 06:00 - 06:30 0.50 FISH N DFAL TIE61 Service Rig. Inspect Derrick. Check PVT Alarms. 06:30 - 07:00 0.50 FISH N DFAL TIE61 Make up BHA #24 as follows: 2 5/16 Itco S ear...2.748" nom catch...range 2.700" - 2.813", XO, XO, 1 Jt 3 1/8" PAC Drill Pipe, XO, XO, Bumper Sub, Oil Jar, Pump-out-Sub, 9 ea 4 3/4" Drill Collars. 07:00 - 12:00 5.00 FISH N DFAL TIEB1 Trip in with BHA #24 and 3 1/2" Drill Pipe from Derrick. Kelly uP 12:00 - 12:30 0.50 FISH N DFAL TIEB1 Bring Pump on line at 2.0 bpm/950 psi. PUW = 148K. SOW = 115K. Tag TOF at 10,822' and set 5K. Saw a bobble and lost Printed: 6/8/2009 11:38:45 AM t • • BP EXPLORATlC7N Page 21 of 25 ; Operations Sumrnary R~port Legal Well Name: J-20 Common Well Name: J-20 Spud Date: 8/1/1996 Event Name: WORKOVER Start: 4/26/2009 End: 5/31/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/31/2009 Rig Name: NABORS 4ES Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/24/2009 12:00 - 12:30 0.50 FISH N DFAL TIEB1 weight. Then stack 10K. Pick up and repead with no bobble. Set 10K. Pick up and shut down Pump. Set back down with 12K. 12:30 - 17:00 4.50 FISH N DFAL TIE61 Set back Kelly. Trip out with 3 1/2" Drill Pipe and BHA #24. Pull BHA. Recovered MIII. Fish #2 recovered I Inspect Mill face for wear. Mill is new. Saw now indication that the Boot Basket was being dressed off for fishing it. Discuss plan forward with Anch Eng. 17:00 - 18:00 1.00 FISH N DFAL TIEB1 Make u BHA #25 as follows: Dress-off shoe 3.80" OD/1 1/2" ID w/3 1/8" by.82' fishing neck), 1 Jt 3 1/8" PAC Drill Pipe, XO, Bumper Sub, Oil Jar, Pump-out Sub, 9 ea 4 3/4" Drill Collars. 18:00 - 18:30 0.50 FISH N DFAL TIE61 Crew change. Service rig. Inspect derrick. Check PVT alarms. 18:30 - 19:00 0.50 FISH N DFAL TIE61 Finish M/U BHA #25 & RIH w/ 3 stands of 4 3/4" DCs. 19:00 - 22:00 3.00 FISH N DFAL TIE61 RIH w/ BHA #25 to dress off fish on 111 stands & 1 single of 3 1/2" DP. Install TIW valve & secure well. 22:00 - 23:30 1.50 FISH N DFAL TIEB1 PJSM. Cut & slip 84' of drilling line. Adjust brakes. 23:30 - 00:00 0.50 FISH N DFAL TIEB1 Begin holding weekly safety meeting w/ all hands. 5/25/2009 00:00 - 00:30 0.50 FISH N DFAL TIE61 Con't Weekly Safety meeting w/ all hands. Reviewed 2009 Expectations, recent incidents & spills. Discuss rig performance & goals. 00:30 - 03:30 3.00 FISH N DFAL TIE61 P/U 2 singles & 10' DP pup. P/U kelly & break circulation. Establish milling parameters. RIH & tag up on fish 26' in on kelly C~ 10822'. Begin to dress off fish. P/U Wt - 149K, S/O Wt = 113K, Rot Wt = 129K, 3 BPM C~ 450 psi, 45-50 RPMs, Free Torq = 3K ft-Ibs. Set torq limiter to 3800 ft-Ibs. WOB = 1-3K. Milled 12". String started to torque up. 03:30 - 04:00 0.50 FISH N DFAL TIEB1 P/U & strin ulled ti ht..Stuck. Pump 40 bbls Hi-Vis sweep & begin to work pipe & started to jar. Jarred 4 times w/ 40K. Pulled on i e& worked u to 225K & i e came free. P/U. Appear to have all wt. 04:00 - 06:00 2.00 FISH N DFAL TIEBi Circulate sweep around. Pump 5 BPM C~ 1160 psi. 06:00 - 06:30 0.50 FISH N DFAL TIEB1 Crew change. Service Rig. Inspect Derrick. Check PVT Alarms. Finish circulating. 06:30 - 08:00 1.50 FISH N DFAL TIEB1 Go back to milling. RTW = 129K. RPMs = 45. Amps = 150. Pump Rate = 3.0 bpm/440 psi. Tagged up again at -10,822', then fell throu h. Continue to make slow steady hole with little weight on Mill ( osibil washin sand out from under fish? , Stop at 10,829'. 08:00 - 11:30 3.50 FISH N DFAL TIEB1 Set back Kelly. Trip out with 3 1/2" Drill Pipe and BHA #25. 11:30 - 12:00 0.50 FISH N DFAL TIE61 Lay down BHA. Recovered a 14" L x 2" W x.271" T piece of what appears to be 4 1/2" Tubing (Liner). This piece was jammed up inside the MIII. Inspected Mill for wear. Face was worn down pretty good. Inside showed little wear. 12:00 - 13:30 1.50 FISH N DFAL TIEB1 Discuss findings and plan forward with Anch Eng. Make up BHA #26 as follows: 3.80" Box Tap, XO, 2 Jts of 2 7/8" PAC Drill Pipe, XO, Bumper Sub, Oil Jar, Pump-out Sub, 9 ea 4 3/4" Drill Collars. 13:30 - 18:00 4.50 FISH N DFAL TIEB1 Trip in with BHA #26 and 111 stands of 3 1/2" Drill Pipe from Derrick. 18:00 - 19:00 1.00 FISH N DFAL TIE61 P/U DP singles + 24' DP pup & RIH. P/U kelly & broked circulation; 3 BPM ~ 470 psi. RIH & tag 12' in on kell~@ 10820'. Attempt to screw in to fish. Slowly rotate @ 15 RPMs w/ 2-4K down wt. Rotary stalled C~? 3800 ft-Ibs. P/U w/o Printed: 6/8/2009 11:38:45 AM ~ 1 ~ ~ BP EXPLORaTION Operations Summary R~ Legal Well Name: J-20 Common Well Name: J-20 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES Spud Date: 8/1/1996 Start: 4/26/2009 End: 5/31 /2009 Rig Release: 5/31 /2009 Rig Number: Date From - To Htaurs Task Code NPT Phase Description af ~perations 5/25/2009 18:00 - 19:00 1.00 FISH N DFAL TIEB1 overpull. P/U Wt = 147k, S/O Wt = 117K, Rot Wt = 127K. Free Torq = 3000 ft-Ibs. Blow down & set back kelly. 19:00 - 22:30 3.50 FISH N TIEB1 UD DP pup & 2 singles. POOH & stand back 111 stands of 3 1/2" DP. 22:30 - 23:00 0.50 FISH N TIEB1 Stand back 3 stands of 4 3/4" DCs. Break out BHA. Inspect Screw in Box... No Recovery. Screw in Box was 1.77' when run in & 1.64' when OOH. Also bottom was belled out from 3.8" to 4.0". UD same. 23:00 - 23:30 0.50 FISH N TIEB1 Clear & clean rig floor. 23:30 - 00:00 0.50 FISH N TIEB1 P/U & M/U BHA #27 to clean u dama ed area & dress boot basket. 5/26/2009 00:00 - 00:30 0.50 FISH N DFAL TIE61 Con't to M/U BHA #27 as follows: Dress off shoe, 1 jt PAC DP, XO, Stabilizer, Bumper Sub, Jars, PO Sub, 9- 4 3/4" DCs. TL = 339.02'. 00:30 - 03:30 3.00 FISH N DFAL TIEB1 RIH w/ BHA #27 on 112 stands of 3 1/2" DP. 03:30 - 05:00 1.50 FISH N DFAL TIEB1 P/U 10' DP pup & kelly. Break circulation, 3 BPM ~ 450 psi. Begin rotating & RIH. Tag 22.5' in on kelly, 10820.25'. Con't to rotate & RIH. Hole was torquing from 10822 to 10825'. Took some wt again C~3 10827'. con't to rotate & RIH w/ remainder of kell to 10834.25'. P/U out of liner & UD 10' pup. P/U 24' DP pup. RIH. Bottom out @ 10846'. P/U & run in & out of liner w/o rotation. No problems. P/U Wt = 148K, S/O Wt = 114K, Rot Wt = 129K. Free Torq = 3000 ft-Ibs. 50-55 RPMs. 05:00 - 06:00 1.00 FISH N DFAL TIEB1 Circulate & Discuss plan forward. 06:00 - 06:30 0.50 FISH N DFAL TIEB1 Crew change. Service Rig. Inspect Derrick. Check PVT Alarms. 06:30 - 08:45 2.25 FISH N DFAL TIEB1 Mlx and pump a 30 bbl Hi-Vis Sweep. Circulate at 5.0 bpm/1225 psi to clean-up Well. 08:45 - 12:30 3.75 FISH N DFAL TIE61 Pass throu h sus ected dama ed Liner area several more time with no problems. Trip out with 3 1/2" Drill Pipe. 12:30 - 13:00 0.50 FISH N DFAL TIE61 Break out lay down BHA. #27. Dress off shoe indicates contact on bottom surface only. No contacUwear on inner bore of shoe. 13:00 - 14:00 1.00 FISH N DFAL TIEB1 Wait on slickline unit to arrive. 14:00 - 14:30 0.50 FISH N DFAL TIEB1 PJSM - Rigging up slickline procedure reviewed with rig crew and slickline crew. 14:30 - 16:00 1.50 FISH N DFAL TIEB1 Rig up slickline unit and toolstring to RIH w/2.50" LIB with "dumbell" centralizer. Bottom centralizer is 3.70" O.D. and top centralizer is 3.65" O.D. 16:00 - 18:00 2.00 FISH N DFAL TIEB1 RIH w/2.50" LIB on slickline toolstrin . 18:00 - 20:30 2.50 FISH N DFAL TIE61 Con't to RIH w/ 3.7" & 3.6" dumbell assy w/ 2.5" LIB. Tagged u~ 10829'. Pulled tight when coming off bottom w/ -300# overpull. POOH & inspect same. LIB showed some gouging on edges in 2 spots.. no impression on tool face. see photos. Discuss results w/ town & plan next runs. 20:30 - 23:00 2.50 FISH N DFAL TIEB1 Make 2nd run w/ 2.5" LIB using a single 3.5" centralizer. 23:00 - 00:00 5/27/2009 ~ 00:00 - 01:30 1.001 FISH I N I DFAL I TIEB 1.501 FISH I N I DFAL ITIEB Tagged up C~3 10829' POOH & inspect same. LIB showed 2 gouges on edge, nothing on face as before. See photos. 1 Make 3rd run w/ bull nose & 2.25" centralizer. Tagged up @ 10829'. Bump bottom 2 times & tool con't down hole & bottomed out C~ 10849' SLM. 1 Finish Run #3 w/ Slickline unit. POOH & UD tools. Printed: 6/8/2009 11:38:45 AM t- ~ ~ • • BP' EXPLORATfON Page 23 ~f 25 ;.., Operations Summary Report Legal Well Name: J-20 Common Well Name: J-20 Spud Date: 8/1/1996 Event Name: WORKOVER Start: 4/26/2009 End: 5/31/2009 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 5/31/2009 Rig Name: NABORS 4ES Rig Number: Date Frorn - To Hours Task Code NPT Phase Description of Operations 5/27/2009 01:30 - 02:30 1.00 FISH N DFAL TIE61 Hold PJSM w/ all hands & 3rd party. R/D slickline equipment and Dutch lockdown lubricator. Clear & clean rig floor. 02:30 - 03:00 0.50 FISH N DFAL TIE61 P/U & M/U BHA #28 as follows, to fish Boot baskets & mill. Taper-Box tap, PxP Sub, Stabilizer, 2- jts PAC DP, XO, Bumper Sub, Jars, PO Sub, 9- 4 3/4" DCs. TL = 366.84'. 03:00 - 07:30 4.50 FISH N DFAL TIEB1 RIH w/ BHA #28 on 3 1/2" DP from derrick to fish boot baskets & shoe. 07:30 - 08:30 1.00 FISH N DFAL TIEB1 Pick up 10' 3-1/2" DP pup. Kelly up. Establish parameters: P/U wt. = 149K, S/O wt. = 114K, Free torque = 3000 ft.-Ibs. at 30 RPM. Break circulation at 3.0-bpm at 450-psi. Tag 5-1/2" x 4-1/2" XO at 10 813' with ta er ta . No o. Work pipe and slide through XO. Taking additional 3K downweight to slide downhole. Work pipe down to 10,858' with no additional downweiqht and no pressure increase. Make connection and reestablish parameters same as before. Worked pipe down to 10,877' with no additional downweight or pressure increases noted. At 10,877' noted a 1500 ft-Ibs. gain in torque. This depth would place 4-3/4" x 2-7/8" XO at 5-1/2" x 4-1/2" XO at 10,813'. Set kelly back, layed down 10" DP pup and prepared to POH. 08:30 - 08:45 0.25 FISH N DFAL TIE61 PJSM - Review POH with DP procedure. 08:45 - 12:30 3.75 FISH N DFAL TIEB1 POH standing 3-1/2" DP in derrick. 12:30 - 13:00 0.50 FISH N DFAL TIE61 Break out BHA #28. No fish recovered. Taper tap e~ernal wickers rounded and circular drag marks above wickers extending upwards 5-6". No contact marks on internal wickers. Layed down taper tap tool. 13:00 - 14:30 1.50 BOPSU N DFAL TIEB1 Pull wear ring. Rig up test equipment to perform weekly BOPE test. 14:30 - 23:00 8.50 BOPSU N DFAL TIEB1 Perform weekly BOPE test er BP/AOGCC requirements. Test 3-1/2" x 6" VBRs using 3-1/2" & 4-1/2" test jts. Test annular using 3-1/2" test jt. Test choke manifold valves, HCR kill and choke valves, test spool valve 3-1/2" IF TIW floor valve, IBOP and upper and lower kelly valves. Test to 250-psi low and 3500-psi high. Hold and chart each test for 5-minutes. BP WSL and Nabors Toolpusher observed testing. John Crisp - AOGCC witnessed testing. 23:00 - 23:30 0.50 BOPSU N DFAL TIE61 Rig down BOPE test equipment, pull test plug, and install wear ring. 23:30 - 00:00 0.50 FISH N DFAL TIE61 P/U & M/U BHA #29 as follows to fish boot.baskets & mill: Box/Taper-tap catch (3 3/4" OD and 1" ID; 3 1/4" outer and 2 3/4" inner catch), 18 jts PAC DP, XO, Bumper Sub, Oil Jar, Pump-out Sub, 9- 4 3/4" Drill Collars. TL = 855.85'. 5/28/2009 00:00 - 01:30 1.50 FISH N DFAL TIEB1 P/U & M/U BHA #29 as follows to fish boot baskets & mill: Box/Taper-tap catch (3 3/4" OD and 1" ID; 3 1/4" outer and 2 3/4" inner catch), 18 jts PAC DP, XO, Bumper Sub, Oil Jar, Pump-out Sub, 9- 4 3/4" Drill Collars. TL = 855.85'. 01:30 - 07:00 5.50 FISH N DFAL TIEB1 RIH w/ BHA #29 to refusal on 3 1/2" DP from derrick to fish boot baskets & mill shoe. Taq at 10,872'. Kelly up and establish parameters: P/U wt. = 144K, S/O wt. = 114K, Free Torque at 10-RPM = 2700 ft.-Ibs. Set torque limit at 3500 ft.-Ibs., 3.0-bpm at 480-psi. 07:00 - 08:00 1.00 FISH N DFAL TIE61 Work pipe down to 10,879' and attempt to screw Taqer Tap/Box Tap into fish. Set down with 10K downweight. Pipe Printed: 6/8/2009 11:38:45 AM ~ a ~t : r BP EXPLORATI(~N ~' Operations Summ,ary Report Legal Well Name: J-20 Common Well Name: J-20 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING I Rig Name: NABORS 4ES ~ ~ Date From - To Hours Task Cc 5/28/2009 07:00 - 08:00 1.00 FISH N Start: 4/26/2009 Rig Release: 5/31/2009 Rig Number: I DFAL TIE61 08:00 - 13:30 5.50 FISH N DFAL TIE61 13:30 - 14:00 0.50 FISH N DFAL TIEB1 14:00 - 15:00 1.00 TA C ABAN 15:00 - 16:00 1.00 TA C ABAN 16:00 - 16:30 0.50 TA C ABAN 16:30 - 17:00 0.50 TA C ABAN 17:00 - 20:30 3.50 TA C ABAN 20:30 - 00:00 3.50 TA C ABAN 5/29/2009 00:00 - 05:30 5.50 TA C ABAN 05:30 - 11:30 6.00 TA C ABAN 11:30 - 22:00 10.50 TA C ABAN 22:00 - 22:30 0.50 TA C ABAN 22:30 - 00:00 1.50 TA C ABAN 5/30/2009 ~ 00:00 - 01:00 ~ 1.00 ~ TA ~ C ~ ~ ABAN ~ ~ 01:00 - 02:00 I 1.00 I TA I C I I ABAN 02:00 - 02:30 I 0.50 I TA I C I I ABAN Spud Date: 8/1/1996 End: 5/31 /2009 ve~c:i iyuut;i ui ~NGi a~i~i ia torqued up and noted a 30-psi pump pressure increase. Picked up string and had 15K overpull. Let jars bleed off and continued up with 2K-3K drag. Repeated attempt to screw into fish. Picked up string with 15K overpull. Let jars bleed off siowly and continued inching upwards. Broke off and set back kelly. Continued inching upward until BHA and possible fish on board were above 5-1/2" x 4-1/2" XO at 10,812' in 4-1/2" liner top with continued 2K-3K drag. Draq disappeared when BHA and nossible fish above 10,812'. POH w/BHA #29 standing 3-1/2" DP in derrick. Break out and lay down BHA #29. No fish on board and nor. visible evidence that Taper/Box Tap had engaged fish. Small amount of cement in external wickers and minor gouge in one side of external wickers. No evidence of contact with fish on internal wickers. Pictures of Tap/Box Tap sent to RWO engineers. RIH with 18 jts. of 2-7/8" PAC DP. POH lavina down 18 its. of 2-7/8" PAC DP 1 x 1 throuqh Close blind rams and pressure test wellbore casinq to 1000-psi for 10-minutes. Good test. Bled off pressure and reopened blind rams. PJSM - RIH with drillpipe from derrick. RIH with 4-3/4" DCs and 3-1/2" DP from derrick. POH laying down 3-1/2" DP and 4-3/4" DCs 1 x 1 through pipeshed. POH laying down 3-1/2" DP and 4-3/4" DCs 1 x 1 through pipeshed. Clear and clean rig floor. Rig down 3-1/2" DP handling tools. Final load ot kill string tubing arrived at 11:30-hrs. Rig up floor with 4-1/2" pipe handling equipment and tools. Load 4-1/2" kill string tubing in pipe shed, drift and strap same. PJSM for running 4-1/2" kill string. RIH with 4-1/2" WLEG assembly and first joint of 4-1/2" NSCT tubing would not MU. LD first joint and PU second joint. When trying to MU the second joint, the joint would not MU either. LD second joint and PU next joint. It, too, would not MU. LD and PU next joint and it would not MU either. Next joint did MU, but it was direct from the factory and had not been remachined. Stopped the job to discuss options for way ahead. Upon further inspection of 4-1/2" NSCT tubing with night WSL, WSLf, Nabors tourpusher, and Nabors casing hand, it appeared that only 20 of oriqinallv received 78 ioints of 4-1/2" NSCT were good to run in the hole (no rouqhly machined _ threads . Called drilling material coordinator to come to the rig to view tubing and give us a way ahead with what was on-hand for tubulars in the field. Woke up day WSL and discussed options to move forward. After reviewing tubing on-hand inventory in field, it was decided that going with 3-1/2" TC-II on bottom and 4-1/2" BTC-M on top was the only way we could proceed and get to necessary depth without usina new 4-1/2" tubinp. Printed: 6/8/2009 11:38:45 AM t~ , . ~ ~ BP EXPLORATIUN Page 25 ~~~~~~~~ Operati~~ns Summary Report Legal Well Name: J-20 Common Well Name: J-20 Event Name: WORKOVER Contractor Name: NABORS ALASKA DRILLING Rig Name: NABORS 4ES Date ° From - To Hours Task Gode NPT 5/30/2009 02:30 - 06:00 3.50 TA C ABA 06:00 - 07:00 1.00 TA C ABA 07:00 - 07:30 0.50 TA C ABA 07:30 - 08:00 0.50 TA C ABA 08:00 - 12:00 I 4.00 I TA I C I I ABA 12:00 - 12:30 0.50 TA C ABA 12:30 - 00:00 11.50 TA C ABA 5/31/2009 00:00 - 01:00 1.00 TA C ABA 01:00 - 02:30 I 1.50 I TA I C I I ABA 02:30 - 04:00 1.50 TA C ABA 04:00 - 06:30 2.50 TA C ABA 06:30 - 08:00 1.50 TA C ABA 08:00 - 08:45 0.75 TA C ABA 08:45 - 10:00 125 TA C ABA 10:00 - 10:30 0.50 TA C ABA 10:30 - 11:30 1.00 TA C ABA 11:30 - 12:00 0.50 TA C ABA 12:00 - 13:00 1.00 TA C ABA 13:00 - 15:30 2.50 TA C ABA 15:30 - 16:00 0.50 TA C ABA 16:00 - 16:15 0.25 TA C ABA 16:15 - 18:00 1.75 TA C ABA Spud Date: 8/1 /1996 Start: 4/26/2009 End: 5/31 /2009 Rig Release: 5/31/2009 Rig Number: ase Description of Operations N Swapped out bad 4-1/2" NSCT tubulars for 3-1/2" TC-II and 4-1/2" BTC-M; handled and strapped all new tubulars and redid running order. N RU to run 4-1/2" kill string and hold PJSM for running 4-1/2" kill string. N RIH with WLEG, first two joints of 3-1/2" TC-II, X nipple, and ne~ 6 joints of 3-1/2" TC-II. N Called back by town engineer and told to stop RIH with 3-1/2". Decision made to POH with all 3-1/2" tubulars and jewelry and get back with drilling material coordinator to make kill strinq all 4-1/2", even if it meant using some new tubulars. N Got with drilling material coordinator to deliver new 4-1/2" TC-fl tubulars. Tubulars delivered, downloaded, strapped, and readied to go downhole. N PJSM for running 4-1/2" kill string. N RIH with 4-1/2" kill string. 273 jts. N PU landing joint. MU into tubing hanger. Land tubing hanger. WSLf and Cameron hand visually verified proper seating in tubing spool. Recorded final PU wt 117K and SO wt 85K. RILDS. LD landing joint. N Set and test TWC. Test to 1 000- si above and below for 10 charted minutes each. Good tests. N ND BOPE. Drain stack. Hold PJSM. N NU adapter flange and temporary abandonment tree and pressure test to 5,000-psi for 5 minutes to verify not leaking. N Clean and clear rig floor and get ready for move to D-13 as we wait on DSM to pull the TWC. N RU and pressure DSM lubricator to 500-asi. Pressure tested ood. Pull TWC. N Waiting on 290 bbls of corrosion-inhibited seawater. N RU CH2M Hill to corrosion inhibit well and conducted PJSM. N Pumped 290 bbls of corrosion-inhibited seawater down IA C~3 6 BPM and 680-psi. N RU LRS to freeze protect and conduct PJSM. N Waitin on 185 bbl of diesel to freeze rot ct. N LRS pumped 185 bbls of 80 deg F diesel down IA C~ 2.5 BPM and 250 psi. N Allow diesel to U-tube IA x T. N Cameron wellhead tech d r d set N LRS pressure tested TWC to 1000-psi for 10-charted minutes from above an~c below. Bled off pressure. RDMO LRS *'RELEASE RIG AT 18:00-hrs.*' ~ ~ Printed: 6/8/2009 11:38:45 AM /ELLHEAD ` CTUATOR~= MCEVOY OTIS J~Z O B SAFETY NOTES: CTD STRADDLE OF PERF INTE 1 341 0-1 351 0 W/4-1/2" X 2-7/8" BAKER ~ B. ELE~= 70.3~ S U S P E~E ~ PRO S @ 13309' 8~ 13575' W/2-7/8" 6.4# F. EIEV = 42.23' TBG IN BETWEEN. 2-7/8" HES CIBP @ 13440' OP = 800' RW ~ CTMD ON 2/14/01. lax Angle = atum MD = 94 @ 13017' 11831' atum ND = 8800' SS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~~ 2J7$' Minimum ID = 2.39" @ 11356' 4" BKR LNR TOP PKR 7" 26# L-80 scab liner cmYd 3191 `-10792' 9-5/8" X 7" BAKER ZXP PKR I 10798' W(TIEBACK, ID = 7.5" I TOP OF 7" LNR ~ 10887~ 9-5/8" CSG, 47#, L-80, ID = 8.681" 11152~ 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 12250~ GAS LIFT MANDRELS ST MD TVD DEV NPE VLV LATCH PORT DATE 3 z i 4-1/2" HES X NIP, ID = 3.813" 10 626` 4-1 /2" W L E G 10 740` -FISH 10 872` -4-1/2" WRP 10 879` MILLOUT WINDOW 11678 ' - 11685' 11353, ~~ a" BKR LNR TOP PKR ~ 11361~ 4" BKR DEPLOYMENT SLV, ID = 3.0" 3-1/2" LNR, 9.3#, ~-80, .0087 bpf, ID = 2.992" 11628' 11628~ ~-~ 3-1/2" X 3-3/16" XO, ID = 2.800" PERFORATION SUMMARY REF LOG: MEMORY CCL/GWCNL ON 10/17/02 ANGLE AT TOP PERF: 88 @ 12100' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 12100 - 12400 O 10/18/02 2" 4 12600 - 12900 O 10/18/02 2" 4 13090 - 13170 O 10/18/02 •1/2" LNR, 12.6#, L-80 NSCT, .0152 bpf, ID = 3.958" ~ 11666~ TOP OF WHIPSTOCK W! RA TAG 3-3/16" X 2-7/8" MILLABLE XO, ID = 2.44 13185~ I'~ ~TD 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" ~~ 13230~ I 3-3/16" INR, 6.2#, L-80, .0076 bpf, ID = 2.800" ~~ 11754~ ~ DATE REV BY CONIMENTS DATE REV BY COMMENTS PRUDHOE BAY UNff O6/28190 ~GM ORIGINAL COM PLETION WELL: J-208 08/11/96 SIDETRACK (J-20A) PERMff No: ~2021700 10/19102 JDMIKK CTD SIDETRACK (J-206) API No: 50-029-21716-02 05/30/09 N4ES RWO SUSPENDm (J-206) SEC 9, T11 N, R13E, 1215' SNL & 802' WEL 06/01l09 PJC DR~G DRAFT UPDATES BP Exploration (Alaska) • • ~ ~ . ~ ~ I ~ ri ~ ~ ~ ~ "~ ~ ~ ~ ~ `~ SARAH PALIN, GOVERNOR Lsi1[~-7~A OII< ~ ~ 333 W. 7th AVENUE, SUITE 100 COI~TSER~A7`IO1Q COMl-II551O1~T ~ ANCHORAGE, ALASKA 99501-3539 PHONE (907j 279-1433 FAX (907) 276-7542 David Reem Engineering Team Leader BP Exploration (Alaska) Inc. P.O. box 196612 Anchorage, Alaska 99519-6612 ~~ ~- ~ ~' Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, J-20B Sundry Number: 309-184 ;, ~'~!j[ } ~4 qj/'fit l,{ "'..t X.1~M! r Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. DATED this ~ day of June, 2009 Encl. Sincerely, STATE OF ALASKA ~ ~ E ~~~ A~ OIL AND GAS CONSERVATION COM~ION ~ ~Y ~ APPLICATION FOR SUNDRY APPROVAL ~~ ~2 9 2009 20 AAC 25.280 ~ ~~~~~ 1. Type of Request: ^ Abandon ^ Suspend ®Operation Shutdown - ^ Perforate ^ Time Extensio rAllGht)CB E Q ^ Alter Casing ^ Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program ^ Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. ,® Development ^ Exploratory 202-170'/ 309-105 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21716-02-00 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 J-20B i Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): , ADL 028281, 028284, 028280 70.33" Prudhoe Bay Field / Prudhoe Bay Oil Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13230' - 9010' - 13185' - 9012' ~ 10850' -10846' C in n Si a MD TV t II Sr rl n r 11 2 11 11 ' Surface 2 7 ' 13-3/ " 2978' 274 ' 4930 2 7 Interme iat 111 0' 9-5/8" 11150' 83 1' 6870 476 Pr Liner 471' 7" 10 87' - 11 04' 197' - 8487' 724 5410 Liner 880' 4-1/2" 107 8' - 11678' 81 6' - 7 6' 8430 7500 'n 1 6' 3-1/2" x 3-3/16" x 2-7/8" 1 '- 1 '- 9 1 1 1 Lin r 760 8' 7" 3190' - 10798' 2895' - 81 724 541 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): Below Plug: 12100' - 13170' 8997' - 9013' 4-1/2", 12.6# (Kill String) L-80 10000' Packers and SSSV Type: None (Kill String) Packers and SSSV MD (ft): 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ~ ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: May 30, 2009 ~® Oil ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: 5/29/2009 ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: Winton Aubert 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca, 564-5444 Printed Name vid Reem Title Engineering Team Leader / Prepared By Name/Number. Signature -~/Yn._ Phone 564-5743 Date 5-!Z 9r0 Terrie Hubble,~64-4628 Commission Use Onl Sundry Number: ~ Conditions of approval: Notify Commission so that a representative may witness ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Other: l.kb"~ ~ t~S v m~ ®~C'~-~~ ~ . Subsequent Form Required: APPROVED BY ~ ~~~ A roved B COMMISSIONER THE COMMISSION Date ~ Form 10-403 Revised 06/2006 l~ ~~' ,fl.~~ ~ ~ ?~~a ~.~~r_~~IAL Sub t In Duplicate ~~~~6~s n • We plan to move Nabors 4ES off J-20B due to multiple fishing problems. We successfully cemented the 7" scab to seal off a production casing leak. While trying to clean out above a Weatherford 4.5" WRP we broke off 3 fishing assemblies inside 4.5" tubing. Two of the fish have been recovered, but a partial boot basket and mill (~5' long) remain above the WRP. The plan forward is to run a kill string and develop a slickline and/or coil fishing plan. If the fish and WRP are recovered we will move a rig back on to pull the kill string and run completion. If that fails, another plan will be developed and paperwork submitted. TREE = MCEVOY WELLH D = MCEVOY ACTUATOR = OTIS KB: BEN = 70.3' BF. ELEV = 42.23' KOP = 800' Max Angle = 94 @ 13017' Datum MD = 11831' Datum TV D = 8800' SS ~ 13-318" CSG, 72#, L-80, ID = 12.347" ~ i J-20B CURRENT Minimum ID = 2.39" @ 11356' 4" BKR LNR TOP PKR 7" 26# L-80 scab liner cmt'd 3190`-10798' 9-5/8" X 7" BAKER ZXP PKR 10798' W(TIEBACK, ID = 7.5" I TOP OF 7" LNR I-1 10887' 9-5/8" CSG, 47#, L-80, ID = 8.681" 11152' 7" LNR, 26#, L-80, .0383 bpf, ID = 6.276" 12250' STES: CTD STRADDLE OF PERF INTER 13410-13510 W/4-1/Z" X 2-7/8" BAI~R PROD PKRS @ 13309' 813575' W/2-7/8" 6.4# TBG IN BETWEEN. 2-7/8" HES CIBP @ 13440' CTMD ON 2/14/01. ~ 4-1/2" 12.6#/ft, L-80 tbg kill string _10,000' -'6` fish, partial boot basket & mill, -10,846 4.5" WFD WRP @10,850` ^ MILLOUT WIbIDOW 11678 ' - 11685' 11353' 4" BKR LNR TOP PKR 11361' 4" BKR DEPLOYMENT SLV, ID = 3.0" 3-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" 11628' 11628' 3-1/2" X 3-3116" XO, ID = 2.800" P6~FORATION SUMMARY R~ LOG: MEMORY CCUGR/CNL ON 10/17/02 ANGLE AT TOP PERF: 88 @ 12100' Note: Refer to Production DB for historical pert data S¢E SPF INTERVAL Opn/Sqz DATE 2" 4 12100 - 12400 O 10/18/02 2" 4 12600 - 12900 O 10/18/02 2" 4 13090 - 13170 O 10/18/02 ~ ~ 4-1/2" LNR, 12.6#, L-80 NSCT, .0152 bpf, ID = 3.958" ~ 11666' TOP OF WHIPSTOCK W/ RA TAG 11754' ~--~ 3-3/16" X 2-7/8" MILLABLE XO, ID = 2.441" ~ 2-7/8" LNR 6.16#, L-80, .0058 bpf, ID = 2.441" ~ 13230' ~ 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.800" ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 06/28/90 LGM ORIGINAL COMPLETION 09/15/06 CJN/TLH PX TTP SET 08/11/96 SIDETRACK (J-20A) 01/07!09 DTRlPJC PULL PX TTP @ 10778' 10/19/02 JDM/KK CTDSIDETRACK(J-20B) 05/29/06 CO/DTM TREE CORRECTIONS (6/13/04) 08/30/06 GJF/PAG GLV GO 09/06/06 RCT/PJC GLV GO PRUDHOE BAY UNfT WELL: J-206 PERMIT No: 2021700 AR No: 50-029-21716-02 SEC 9, T11 N, R13E, 1215' SNL 8 802' WEL BP Exploration (Alaska) J-20 kill string o Maunder, thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, May 28, 2009 8:22 PM To: Baca, Hank Cc: Regg, James B (DOA); Aubert, Winton G (DOA) Subject: RE: J-20 kill string ~C~a ~- L~C7 Page 1 of 1 Hank, Could you please provide some information as to what has occurred to get BP to the position that it is necessary to SD operations or suspend? You are likely including such information with the paperwork that Terrie will be preparing. It also appears that you/BP is pretty far down the road with operations to implement the decision. While it is entirely appropriate for BP as operator to make this decision, it is also appropriate to advise the Commission as soon as possible with supporting documentation so that the Commission may concur with the path forward. I will try to call you on your cell. Tom Maunder, PE AOGCC From: Baca, Hank [mailto:hank.baca@bp.com] Seat: Thu 5/28/2009 4:19 PM To: Maunder, Thomas E (DOA) Subject: 7-20 kill string Tom, per our conversation earlier we're planning to set a kill string and move Nabors 4ES off J-20B. I will get with Terrie in the morning to file the paperwork. The asset is going to look at slickline and coil options after we move off. We'll be running the kill string as follows: 4.5" WLEG 2 joints 4.5" tbg 4.5" X nipple s~~:':~ °4~~'~~-t ',.i~' ,, G ~~;~ 4.5" tubing to surface Tubing hanger We'll freeze protect and RDMO as normal. Thanks, please holler with questions. Hank Baca Drilling Engineer 907-564-5444 office 907-748-0997 cell 6/25/2009 • ~~~/~~~ `~G~l~'~II~~SS~~~,l ALASSA OIL Ai~D GAS COI~TSERQATIOIIT COAIIrIISSIOr1T David Reem SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (9p7) 279-1433 FAX (907)276-7542 Engineering Team Leader BP Exploration Alaska Inc. PO Box 196612 Anchorage AK 99519-6612 ,~ ,~ ~,'' Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU J-20B Sundry Number: 309-105 ~~t~~~~7 ~iA~ ~~ ~ ~~C~ Dear Mr. Reem: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, ~~ Daniel T. Seamount, Jr. Chair 7~'~. DATED this 2 Sday of March, 2009 Encl. STATE OF ALASKA ~~~ ~~~ ~ ~ / b ` ~~,~'~ ALA OIL AND GAS CONSERVATION COM~I ~ q~ ~ ~~~~~f ~ti~ APPLICATION FOR SUNDRY APPROV~ ~ ~/9~ ~~ 20 AAC 25.280 h_ A'.: ; 1. Type of Request: ^ Abandon ^ Suspend ^ Operation Shutdown ^ Perforate ^ Time Extensio~ -® After Casing - ®Repair Well ^ Plug Perforations ^ Stimulate ^ Re-Enter Suspended Well ^ Change Approved Program '® Pull Tubing ^ Perforate New Pool ^ Waiver ^ Other 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. _ ® Development ^ Exploratory 202-170 3. Address: ^ Service ^ Stratigraphic 6. API Number: P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-21716-02-00 - 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 J-20B - Spacing Exception Required? ^ Yes ®No 9. Property Designation: 10. KB Elevation (ft): 11. Field /Pool(s): ADL 028281, 028284, 028280 " 70.33' - Prudhoe Bay Field / Prudhoe Bay Oil Pool 12. PRESENT WELL CONDITION SUM MARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 13230' 9010' - 13185' - 9012' - None None in n i M B' 1 S ru r I r 1 11 ' rfa 2978' 1 -3/8" 2978' 274 ' 4930 2670 Interm di a 111 9- / " 111 8381' 70 47 0 r in in r 471' 7" 1 8 T - 11304' 81 T - 4 T 7240 5410 Liner 4-1/2" 1 7 ' - 1167 ' 8136' - 87 8430 7 0 i 1 3-1@" x 3-3/16" x 2-7/8" 1' - 1 1 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 12100' - 13170' 8997' - 9013' 4-1/2", 12.6# L-80 10811' Packers and SSSV Type: 9-5/8" x 4-1/2" TIW 'HBBP-T' packer Packers and SSSV MD (ft): 10754' 13. Attachments: 14. Well Class after proposed work: ® Description Summary of Proposal ^ BOP Sketch ^ Exploratory ®Development ^ Service ^ Detailed Operations Program 15. Estimated Date for 16. Well Status after proposed work: Commencin O erations: May 1, 2009 ®Oil - ^ Gas ^ Plugged ^ Abandoned 17. Verbal Approval: Date: ^ WAG ^ GINJ ^ WINJ ^ WDSPL Commission Representative: 18. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Hank Baca, 564-5444 Printed Name vid Reem Title Engineering Team Leader j Prepared By Name/Number: Signature Phone 564-5743 Date 3! I91®~ Terrie Hubble, 564-4628 Commission Use Onl Sundry Number: Conditions of approval: Notify Commission so that a representative may witness ~,~ ~ i ~ ^ Plug Integrity ^ BOP Test ^ Mechanical Integrity Test ^ Location Clearance Q -- Other: ~ ~l W QS`a ~~~~5~ ~ a 5~ 5~ e"~\ c~~v`~V v~ ~U'n°l~~ `U~''~S~ Y Subsequent Form Required: ~~y APPROVED BY ~ /~ i J A roved B COMMISSIONER THE COMMISSION Date 666 Form 10-403 Reed 06/2006 ~ t ~ ~ it~nit In Duplicate !~ M~~ ~ t~tuQ~ by cr,~,y J-20B Rig Workover (Repair PC leak) • Scope of Work: Pull 4.5" L-80 completion, mill packer C~3 10,754'. Run & cement 7" 26# L-80 scab liner from 3000'-10,798. Replace 9.625" packoff and hanger. Run 4.5" 13Cr-80 completion. Engineer: Hank Baca MASP: 2420 psi Well Type: Producer Estimated Start Date: May 1st, 2009 S 1 Drift tubing to 10,900' for RBP & jet cutter. Set RBP in 4.5" liner ~ -10,844'. Reference liner tall 7/25/96. Dum 25' of sand on to of RBP. F 2 MIT-OA to 2000 psi, CMIT-TxIA to 500 psi for 10 minutes. Well has known cret & packer leaks, 'ust ho in to avoid sin le barrier dis ensation. E 3 If CMIT to 500 psi fails, run LDL w/ cold fluid down tubing to verify RBP & lower packer are holdin . E 4 Jet cut tubing at 10749'. Reference tubing tally dated 8/10/96, cut desired to be '/z way down u 'oint above acker. Packer will be milled F 5 Circulate well with 9.8 brine if CMIT fails ,diesel FP ca as needed. Bleed WHPs to 0 si. W 6 Check the tubing hanger lock down screws for free movement. Completely back out and check each lock down screw for breaka a check one at a time . PPPOT-T & IC. V 7 Set a BPV in the tubin han er. O 8 Remove the well house & flow line. Level the ad as needed for the ri . Proposed Procedure 1. MIRU. ND tree. NU and test BOPE to 250 psi low/ 3500 psi high. Circulate out freeze protection and circulate 9.8 ppg brine. 2. Pull and LD tubing string to the cut. 3. Mill up packer C~ 10,754'. Recover packer and tail pipe. 4. PU 9.625" RTTS &RIH to 3500'. Test above RTTS to 3500 psi for 30 minutes to determine top of leak and scab liner top. Continue to RIH w/ RTTS to 10700' and test RBP/packer to 3500 psi for 10 minutes to verify they're holding 5. Run 7", 26#, L-80 scab from 10798' - 3000'. Note: VBR's will not be changed to 7" pipe rams as the well has a tested barrier (RBP) to the reservoir ~ ~~) ~ 3 6. Cement 7" liner, set liner hanger and packer ~ ~~,1 7. Drill out 7" float equipment. 8. Test 7" scab liner to 3500 psi for 30 charted minutes. 9. Recover 4.5" RBP C~3 10844' 10. Run 4-~/z" 13Cr-80 completion 11. Displace the IA to packer fluid and set the. packer. 12. Test tubing and IA to 3500 psi. Freeze protect to 2,000' MD. 13. Set TWC. ND BOPE. NU and test tree. Pull TWC and set BPV. RDMO. MCEVOY WELLHEAD = MCEVOY ACTUATOR = OTIS KB„ ELEV = 70.3' BF. ELEV.- 42.23' KOP = 800' Max Angle = 94 @ 1301 T Datum MD = 11831' Datum TV D = 8800' SS • J-20B I ~ 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ Minimum ID = 2.39" @ 11356' 4" BKR LNR TOP PKR 9-5/8" CSG, 47#, L-80 NSCC X BTC XO ~ 5575' 4-1/2" TBG, 12.6#, L-80, X NSCT XO 6768' S TES: CTD STRADDLE OF PERF 1 13410-13510 W/4-112" X 2-7/8" BAKER PROD S @ 13309' 8~ 13575' W/2-7/8" 6.4# TBGIN BETWEEN. 2-7/8" HES CIBP @ 13440' CTMD ON 2/14/01. 2200' ~--~ 4-1 /2" HES HXO SSSV NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 3766 3215 35 MERLA DMY RM 0 09/06/06 2 7408 5733 42 MERLA DMY RM 0 09/06/06 1 10713 8001 36 MERLA DMY RM 0 08/15/96 10743' - -+4-1/2" HES X NIP, ID = 3.813" 10754' 9-5/8" X 4-1/2" TNV HBBP-T PKR, ID = 3.917" 10778' 4-1 /2" HES X NIP, ID = 3.813" TOP OF 4-1/2" LNR 9-5/8" X 4-1/2" BAKER ZXP PKR 10798' W/TIEBACK, O = 6.375" 1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 10811' TOP OF 7" LNR 10887' 9-5/8" CSG, 47#, L-80, ID = 8.681" 11152' 7" LNR 26#, L-80, .0383 bpf, ID = 6.276" 12250' 10798' 4-1/2" HES X HIGH PRESSURE N~, ID = 3.813" 10811' a-1/2" wEG, ID = a.ooo" MILLOUT WINDOW 11678 ' - 11685' 11353' 4" BKR LNR TOP PKR 11361' H 4" BKR DEPLOYMENT SLV, ID = 3.0" 3-1/2" LNR, 9.3#, L-80, .0087 bpf, ID = 2.992" i-~ 11628' PERFORATION SUMMARY REF LOG: MEMORY CCUGR/CNL ON 10/17/02 ANGLE AT TOP PERF: 88 @ 12100' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 12100 - 12400 O 10/18/02 2" 4 12600 - 12900 O 10/18/02 2" 4 13090 - 13170 O 10/18/02 ~ 4-1/2" LNR 12.6#, L-80 NSCT, .0152 bpf, ID = 3.958" ~--~ 14140' 11628' I--13-1 /2" X 3-3/16" XO, ID = 2.800" 11666' TOP OF WHIPSTOCK W/ RA TAG 11754' 3-3/16" X 2-7/8" MILLABLE XO, ID = 2.441" 13185' 1-1PBTD 2-7/8" LNR, 6.16#, L-80, .0058 bpf, ID = 2.441" i~ .13230' ~ 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.800" ~ DATE REV BY COMMENTS DATE REV BY COMMENTS 06/28/90 LGM ORIGINAL COMPLETION 09/15/06 CJN/TLH PX TTP SET 08/11/96 SIDETRACK (J-20A) 01/07/09 DTR/PJC PULL PX TTP @ 10778' 10/19/02 JDM/KK CTD SIDETRACK (J-206) 05/29/06 CO/DTM TREE CORRECTIONS (6/13/04) 08/30!06 GJF/PAG GLV GO 09/06/06 RCT/PJC GLV GO PRUDHOE BAY UNIT WELL: J-206 PERMfT No: 2021700 API No: 50-029-21716-02 SEC 9, T11 N, R13E, 1215' SNL ~ 802' WEL BP Exploration (Alaska) TREE = MCEV OY WELLHEAD = MCEVOY ACTUATOR = OTIS KB.,~EV = 70.3' BF. ELEV = 42.23' KOP = 800' Max Angle = 94 @ 13017' Datum MD = 11831' Datum TVD = 8800' SS J -20 PROPOS 13-3/8" CSG, 72#, L-80, ID = 12.347" ~ 2978' Minimum ID = 2.39" @ 11356' 4" BKR LNR TOP PKR 7" 26# L-80 scab liner cmt'd --3000'-10798' 9-5/8" X 7" BAKER ZXP PKR I 10798' W/TIEBACK, ID = 7.5" TOP OF 7" LNR ~ 10887' 9-5/8" CSG, 47#, L-80, ID = 8.681" 11152' 7" LNR 26#, L-80, .0383 bpf, ID = 6.276" 12250' 3-1/2" LNR, 9.3#, L-80, .0087 bpf, 10 = 2.992" ~-{ 11628' PERFORATION SUMMARY REF LOG: MEMORY CCUGR/CNL ON 10/17/02 ANGLE AT TOP PERF: 88 @ 12100' Note: Refer to Roduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 2" 4 12100 - 12400 O 10/18/02 2" 4 12600 - 12900 O 10/18/02 2" 4 13090 - 13170 O 10/18/02 4-1/2" LNR, 12.6#, L-80 NSCT, .0152 bpf, ID = 3.958" 14140' PBTD 2-7/8" LNR 6.16#, L-80, .0058 bpf, ID = 2.441" I--I 13230' 3-3/16" LNR, 6.2#, L-80, .0076 bpf, ID = 2.800" ~~ DATE REV BY COMMENTS DATE REV BY COMMENTS 06/28/90 LGM ORIGINAL COMPLETION 09/15/06 CJNITLH PX TTP SET 08/11/96 SIDETRACK()-20A) 01/07/09 DTR/PJC PULLPXTTP@10778' 10/19/02 JDM/KK CTDSIDETRACK(J-20B) 05/29/06 CO/DTM TREE CORRECTIONS (6/13/04) 08/30/06 GJF/PAG GLV GO 09/06/06 RCT/PJC GLV GO B S OTES: CTD STRADDLE OF PERF INTE 13410-13510 W/4-1/2" X 2-7/8" BAKER ED PROD PKRS @ 13309' 8 13575' W/2-7/8" 6.4# TBG IN BETWEEN. 2-7/8" HES CIBP @ 13440' CTMD ON 2/14/01. 2000` 4-1/2" HES X NIP, ID = 3.813" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 3 4351 3700 2 7982 6200 1 10599 8000 -4-1/2" HES X NIP, ID = 3.813" -7" x 4.5" Baker S-3 packer ~4-1/2" HES X NIP, ID = 3.813" -4-1/2" HES XN NIP, ID = 3.725" 4-1/2" 12.6#/ft, 13Cr-80 tbg MILLOUT WINDOW 11678 ' - 11685' 11353 4" BKR LNR TOP PKR 11361' 4" BKR DEPLOYMENT SLV, ID = 3.0" 11628' 3-1/2" X 3-3/16" XO, ID = 2.800" 11666' TOP OF WHIPSTOCK W/ RA TAG 11754' 3-3116" X 2-7/8" MILLABLE XO, ID = 2.441" PRUDHOE BAY UNfr WELL: J-206 PERMfT No: 82021700 API No: 50-029-21716-02 SEC 9, T11N, R13E, 1215' SNL & 802' WEL BP Exploration (Alaska) • llV~~~ >~f.~ ,. ~~, ~ -- --. ProActive Diagnostic Services, Inc. To: AOGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTV The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter tci the following BP Explowation (Alaska), Inc. Petrotechnical Data Center Attn:.loe Lastufka LR2-1 900 E Benson Blvd. Anchorage, Alaska 99508 and ~-- ~3rC'_ Zvi - `~~ ~3 ProActive Diagnostic Services,Jnc. ~~ f ~~ ~ J~O~ ~ ~ Attn: Robert A. "Richey ~~ 130 West International Airport Roa~~~~(VE~ ~ll~ ~ ~ 20~$ Suite C Anchorage, AK 99518 Fax (907) 245-8952 1 j Leak Detection -WLD 22,Jun-08 J-20B 2j LeakDetection -WLD 20,Jun-08 DS 13~2A t /~'y ~i ~~ (( ; Signed : _ l ~- ~~ Print Name: t"~` ; . ~ ` ~n ~ r~.~, A.i ~.o., 1 BL / EDE 50-029-21716.02 1 BL / EDE 50-029-20798-01 Date . PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88952 E-MAIL '' ~ ~ ~ `3. ~t~~ ~ ,~ WEBSITE +~ ~ .:; C:\Documents and Settings\Owner\Desktop\Trmismit_BP.doc • ~~~ ~~ ~~~~~~~~ - - - ~~ ProActive Diagnostic Services, Inc. To: ACC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 • ~~~dNE~ JUN ~ 200 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection[Caliper/ MTT) The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration {Alaska), Inc. Petratechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn: Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 ~~~_ ~~ ~ _ Fa~c (907j 245-8952 ~ ~ ~ f ~ 1) Leak Detection - WLD 22,Jun-08 J-20B 2] t } 1 ~ jj~~~ ~ ~ ~ Signed : ~ d / -~ Print Name: t ~,I,t~ ,A n ~~I ,r~aAA~~ 1 BL / EDE 50-029-21716-02 Date PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 Fax: (907)245-88952 E-IUU-I~ ~ ~.~. __. ~' ?-, a WEBS °9.,~.. ._LS - - C:1Documents and Settings\Owner\Desktop\Transmit_BP.doc Well J-20B (PTD 2021700) Reclassified from Waiver to Normal e e Sub.iect: Well J-20B (PTD 2(21700) Reclassified from Waiver to NOIl11al slD1 From: "NSU, ADW Well Integrity Engineer" <NSU^DWWellIntegrityEngincer@BP.com> ?c!ft' '1/')b Date: Mon, 06 Mar 2006 15:28: 18 -0900 To: "Rossberg, R Steven" <Steven.Rossberg@BP.com>, "Engel, Harry R" <Harry.EngcI@BP.com>, "NSU, ADW Well Operations Supervisor" <NSUADWWe110pcrationsSupervisor@BP.com>, "Zamora, Chris A" <Chris.Zamora@BP.com>, "GPB, Wclls Opt Eng" <GPBWel1s0ptEng@BP.com>, "GPB, Optimization Engr" <GPBOptimizationEngr@BP.com>, jim_regg(q)admin.state.ak.lIs, winton_aubcrt@admin.statc.ak.L1s, "Kurz, John" <john.kurz@BP.com>, "GPB, GC2 Area Mgr" <GPBGC2TL@BP.com>, "GPB, GC2 Wcllpad Lead" <GPBGC2WclIpadLead(~_YBP.com>, "GPB, GC2 OTL" <gpbgc2otl@BP.com>, "GPB, Wcll Pad R./Q" <gpbwp~jq@BP.com> CC: "NSU, ADW Wel1 Intcgrity Engineer" <NSUADWWelUntegrityEngincer@BP.com>, "NSU, ADW WI Tech" <NSLJADWWITech@BP.com>, "Hughes, And.rea (VECO)" <hllgha4@BP.com> Hello all. v" Well J-20B (PTD 2021700) has been classified as a Normal well. An OA repressure test indicated no IAxOA communication. No OA bleeds are currently being conducted. There is currently a 500 psi / pressure differential between the IA and OA Lead Operator: would you please ensure waiver related signage and forms are removed from the wellhouse. Please call with any questions. Joe 659-5102 From: NSU, ADW WI Tech Sent: Monday, March 06, 20069:10 AM To: NSU, ADW Well Integrity Engineer; Hughes, Andrea (VECO) -Subjeæ J-20 RA proj IAxOA NF Hello, I suggest we cancel the waiver and return to normal. The well has recently passed an OART @ -50psi per day with the IA FL below the OA casing shoe. MIT-OA to 3000 psi has also passed 7/4/05. TIFL has passed 10/20/05. I want your input as to the need to waiver this well, it is in compliance with the managable IAxOA comm requirement of less than 2 bleeds per week. Cody 1 of I 3/8/2006 I :04 PM e e MICROFILMED 07/25/06 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\CvrPgs _ Inserts\Microfilm _ Marker.doc Permit to Drill 2021700 MD 13230 .../ J q ~J~\Î )~JQt.f DATA SUBMITTAL COMPLIANCE REPORT 10/29/2004 Well Name/No. PRUDHOE BAY UNIT J-20B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21716-02-00 TVD 9010"/ /" Completion Date 1 0/19/2002 Completion Status 1-01L .,~--,. ~ N). ">...,._.:~;~~'" Current Status 1-01L REQUIRED INFORMATION Samples No DATA INFORMATION Types Electric or Other Logs Run: Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name L-6Q' Rpt ~ C ED ~"-CÖ/ ~---..~')" Æ-o C Tf !ill C Pds ~ Mud Log No Directional Survey (y~~2., CCU GR / MCNL, MWD/ GR / RES (data taken from Logs Portion of Master Well Data Maint) Log Log Run Scale Media No Interval OH / Start Stop CH ~ Received Comments An H2S Measurement is required to be submitted. This record automatically created from Permit to Drill Module on: 8/15/2002. ~utron Directional Survey ~79 Neutron 25 Blu 11224 12170 Case 2/7/2003 11663 13230 Open 1 0/30/2002 11224 12170 Case 2/7/2003 A Directional Survey Log is required to be submitted. This record automatically created from Permit to Drill Module on: 8/15/2002. " /'Ó¡rectional Survey '~128 LIS Verification 4128 Induction/Resistivity 12128 Induction/Resistivity 11663 13230 Open 10/30/2002 11696 13230 Case 9/28/2003 LDWG edit of MWD Slimpulse and ARC data Vision Resistivity Vision Resistivity 25 25 Blu 11696 12920 Case 9/28/2003 11696 12920 Case 9/28/2003 Well Cores/Samples Information: Name Interval Start Stop Sample Set Number Comments Sent Received Permit to Drill 2021700 MD 13230 TVD 9010 ADDITIONAL INFORMATION ~ Well Cored? Chips Received? ..-XJ..N---' .::L!.bL-'~-'~' Analysis Received? Comments: Compliance Reviewed By: DATA SUBMITTAL COMPLIANCE REPORT 10/29/2004 Well Name/No. PRUDHOE BAY UNIT J-20B Operator BP EXPLORATION (ALASKA) INC Completion Date 10/19/2002 Completion Status 1-01L Current Status 1-01L UIC N Daily History Received? ~N FiJN Formation Tops I " ~ Date: API No. 50-029-21716-02-00 .~ ;;:g J~~ '1 '--.....-I ScblUIDbepgep No. 2963 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: 09/18/03 State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Well Job# Log Description Date Blueline Prints H.17A I ~~ 6(9.. MEM PROD PROFILE 08/13/07 1 E-27A' -C")~") MEM PROD PROFILE 08/09/03 1 D.S. 13~A ~ ~~1~ GLS 09/04/03 1 E-25 ~7-J~~ LDL 09/05/03 1 D.S. 3-09 I Cf "-ê) . ... PSP PROD PROFILE 08/05/03 1 D.S. 1-11 . :t ,(". c; 1 INJECTION PROFILE 09/16/03 1 K~7C . li ~1 SBHP 09/16/03 1 A-23 ~ RST-C GRAVEL PACK 09/07/03 1 D.S.15-48A 'Ecr=3-..m PSP LDL 08/30/03 1 MPS-06 ~o~-W~ TEMPERATURE LOG 08/30/03 1 1-35/0-25 -, g (0'" ( L.I PROD PROFILE/DEFT/GHOST 09/14/03 1 ~.20B 23076 OH EDIT MWD SLlMPULSE & ARC DATA 10/14/02 Drtt-f1 J-20B 23076 MD VISION RESISTIVITY 10/14/02 1 '-20B 23076 TVD VISION RESISTIVITY 10/14/02 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Jnc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 CD .~ 1 J(~ 60' '~ Schlumberger GeoQuest 3940 Arctio Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Date Delivered: RECEIVED SEj:) ~g 2003 Received ~\ ~ ~~"IYV] Aiaska Œ¡ & Gas Cons. Commi8tlion Anchorage ~~~~~ Scblumbel'gep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well J-20B A-28 ~{):;J-/7n I ~é1- J!í D Job# Log Description Date 22480 MCNL 23020 RST 10/17/02 11/21/02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: REceiVED FEB 0 7 2003 Alaâaœ & G8s Cons. (;o~. Anchonige Blueline 01/23/03 NO. 2823 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Sepia Color Prints "-/ CD 1 1 "~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Re~ '-rYì 6. Ck(1J ) ) STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well aa Oil 0 Gas D Suspended D Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1215' SNL, 802' WEL, SEC. 09, T11N, R13E :~~r.°~f~~~~~r~ ~~~~~~, T11N, R13E ;1{).!'L't~~.1-.- At total depth )T,. ¡~W .. ~ 4130' SNL, 184' EWL, SEC. 11, T11N, R13E ',:'~:,::~~~) 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. KBE = 70.33' ADL 028280 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 10/10/2002 . 10/13/2002 ... 10/19/2002 . 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 13230 9010 FT 13185 9012 FT aa Yes DNa 22. Type Electric or Other Logs Run CCL / GR / MCNL, MWD / GR / RES 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE 20" Conductor Surface 110' 13-3/8" 72# L-80 / S-95 Surface 2978' 9-5/8" 47# L-80 Surface 11150' 7" 26# IJ4S 10887' 11304' 4-1/2" 12.6# L-80 10798' 11678' * 9.3#/6.2#/6.16# L-80 11361' 13230' 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 spf MD TVD '12100' - 12400' 8997' - 8995' 12600' - 12900' 9010' - 9016' 13090' - 13170\ 9017' . 9013' ~i~, '11 .DJ...' . ~,~ þ'C!«. ~. ~~g .., ¡~ ~\öi;,. ,., ..., , ,,"- "..: Classification of Service Well 7. Permit Number 202-170 8. API Number 50- 029-21716-02 9. Unit or Lease Name Prudhoe Bay Unit 1 O. Well Number J-20B 11. Field and Pool Prudhoe Bay Field / Prudhoe Bay Pool 15. Water depth, if offshore 16. No. of Completions N/A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2200' MD 1900' (Approx.) -r/~ü..J~ 1/67S " AI" ttt-~ ' ~ CEMENTING RECORD 8 cu yds Concrete 17-1/2" 4127 cu ft Permafrost 12-1/4" 2141 cu ft Class 'G', 230 cu ft Class 'G' 8-1/2" 438 cu ft Class 'G' 6" 473 cu ft Class 'G' 3-3/4"90 cu ft Class 'G' 25. SIZE 4-1/2", L-80, 12.6# MD TVD AMOUNT PUllED * 3-1/2" x 3-3/16" x 2-7/8" TUBING RECORD DEPTH SET (MD) 10811' PACKER SET (MD) 10754' ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protect with MeOH 26. 27. Date First Production November 3, 2002 Date of Test Hours Tested 11/3/2002 4 Flow Tubing Casing Pressure CALCULATED Press. 24-HoUR RATE PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR Oll-BBl TEST PERIOD 2,295 Oll-BBl GAs-McF 5,468 GAs-McF WATER-BBl 48 WATER-BBl CHOKE SIZE 96° GAs-all RATIO 2,383 all GRAVITY-API (CORR) 25.8 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. NO\! I 8 2O~!€E'VED NOV 0 8 2002 Na.s1<a Oil & Gas Cons. Comm\ss\on Aoc.t .OY8QC Submit In Duplicate No core samples were taken. RBDMS BFL Form 10-407 Rev. 07-01-80 ,; ~y ) ') 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 25N 11732' 8796' 25P 11738' 8801' 22N 11850' 8886' 22P 11852' 8888' 21N 11910' 8934' 21P 11914' 8937' Zone 1 B 11959' 8963' 14N 11979' 8973' 14P 11994' 8978' R!t!~IVEÐ NOV 0 8 2002 Alaska Oil & Gas Cons. Commission Anchorage 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I ~erebY certify that the foyOi~9 is true and correct to the best of my knowledge Signed Terrie Hubble /'f4AfuJl. ~ Title Technical Assistant Date [ ~ 0(0 .O~ J-20B 202-170 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / Approval No. Drilling Engineer: Dan Kara, 564-5667 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), 50 state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ) ) BP EXPLORATION Operations Summary Report Page 1 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-20 J-20 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/5/2002 Rig Release: 10/19/2002 Rig Number: N2 Spud Date: 8/1/1996 End: 10/19/2002 Date From - To Hours Task Code NPT Phase Description of Operations 10/5/2002 13:00 - 00:00 11.00 RIGU P PRE Complete move from Deadhorse to J-Pad at 13:00 hrs. Raise and pin derrick. Prepare to move over well. (tree valves and flowline valve tested to 4800 psi-okay) 1 0/6/2002 00:00 - 01 :15 1.25 RIGU P PRE Continue RIU to move over well. 01 :15 - 01 :35 0.33 RIGU P PRE PJSM w/ crews. Review BP/SLB procedures for pulling over well. 01 :35 - 02:30 0.92 RIGU P PRE Position rig over well and level rig. 02:30 - 06:00 3.50 BOPSUR P PRE Remove swab flange and nipple up BOPE. Install CT lubricator riser. 06:00 - 07:00 1.00 BOPSURP PRE Crew change and tech limits meeting (on critical path until meeting room is located) 07:00 - 11 :30 4.50 BOPSUR P PRE RU for BOPE test. Fill stack. 11 :30 - 13:00 1.50 BOPSUR P PRE Hook-up Burton chart recorder, high pressure hose and valve assembly for test joint. 13:00 - 00:00 11.00 BOPSURP PRE Start pressure test BOPE. Witnessed by AOGCC's John Crisp. Full body test - upper 2 3/8" PIS, VBR, inside stack valves to 250 psi /3500 psi 5 min ea - okay. Several problems encountered while testing lower 2 3/8" pipe/slip rams. Changed out torn seals and dressed pipe guides on ram block. Retest with continued small leak-off. Suspected swab valve. Grease-locked same w/ 4800 psi. Switched to testing manifold valve while pulling and inspecting lower rams again. 10/7/2002 00:00 - 06:00 6.00 BOPSUR P PRE Continue testing BOPE. Lower 2 3/8" PS, inner/outer stack valves, HCR's, blinds rams, manifold valves to 250 psi / 3500 psi. Annular 250 /2500 psi. All but choke line HCR tested okay. Hydraulic oil leaking from actuator and will need replacing. 06:00 - 06:45 0.75 BOPSURP PRE Safety and tech limits meeting. 06:45 - 11 :00 4.25 BOPSUR P PRE Replace HCR valve and finish BOP test 11 :00 - 11 :45 0.75 BOPSURP PRE Accept rig 11 :00. Safety meeting -- stab coil in injector. 11:45 -15:30 3.75 RIGU P PRE Pull coil to floor. Stab injector. 15:30 - 18:00 2.50 RIGU P WEXIT Dress coil end. Install CTC. Pull test to 35k 18:00 - 18:50 0.83 RIGU P WEXIT Crew change out. Safety and technical limit meeting. 18:50 - 21:40 2.83 RIGU P WEXIT Make adjustments to injector hang-off point. (Currently injector does not hang directly over the well resulting in difficulty stabbing the injector on well.) Prep to pump ball through coil. 21 :40 - 23:00 1.33 RIGU P WEXIT Stab on injector to well. Pump 2% KCL w/ 2# Bio and fill coil. Make adjustments to Micro Motion. 23:00 - 23:10 0.17 RIGU P WEXIT PJSM discuss PT inner reel valve and pumping 1" ball. 23: 10 - 00:00 0.83 RIGU P WEXIT PT inner reel valve to 3500 psi. Trace down problems with pressure transducers. 10/8/2002 00:00 - 00:20 0.33 RIGU P WEXIT Continue with PT of inner reel valve. 00:20 - 01 :00 0.67 STWHIP P WEXIT Launch and pump 1" ball through coil. 01 :00 - 01 :45 0.75 STWHIP P WEXIT Stab off well recover ball. 01 :45 - 02:30 0.75 STWHIP N MISC WEXIT Setback injector. Still having problems with correct alignment and finding neutral position for Otis thread connection. 02:30 - 03: 15 0.75 STWHIP P WEXIT P/U mousehole and install. Clearance problems with derrick windwall rubber sealing area. 03:15 - 04:15 1.00 STWHIP N MISC WEXIT Re-position injector on rig floor to clear area for handling BHA. 04: 15 - 04:30 0.25 STWHIP P WEXIT Open well and check for pressure. On vacuum. 04:30 - 06:00 1.50 STWHIP P WEXIT P/U BHA #1 and MHA 06:00 - 07:00 1.00 STWHIP P WEXIT Crew change safety and Technical Limits Do meeting. 07:00 - 08:00 1.00 STWHIP P WEXIT Stab inj. Printed: 10/21/2002 9:04:47 AM ) ') BP EXPLORATION Operations Summary Report Page 2 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-20 J-20 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/5/2002 Rig Release: 10/19/2002 Rig Number: N2 Spud Date: 8/1/1996 End: 10/19/2002 Date From - To Hours Task Code NPT Phase Description of Operations 10/8/2002 08:00 - 09:00 1.00 STWHIP N MISC WEXIT Stab inj NPT 09:00 - 09:30 0.50 STWHIP P WEXIT Fill hole. 12 bbls. 09:30 - 11 :30 2.00 STWHIP N MISC WEXIT Wait on power pak hose work. 11 :30 - 12:30 1.00 STWHIP P WEXIT Gooseneck adjustments 12:30 - 15:20 2.83 STWHIP P WEXIT RIH in 500' increments and pulling back 100' checking equipment integrity and looking for any hydraulic leaks. Displacing freeze protection to cuttings tank at the same time. RIH to 4100'. 15:20 -18:00 2.67 STWHIP N MISC WEXIT Repair hydraulic hose on wind wall. 18:00 - 18:25 0.42 STWHIP P WEXIT Continue RIH to 5250'. 18:25 - 18:55 0.50 STWHIP P WEXIT Crew change and Technical Limits Do meeting 18:55 - 21 :30 2.58 STWHIP P WEXIT Continue RIH stopping every 1000' and pulling back 50' checking equipment. With pump on tag pinch point at 11729' coil depth. 21 :30 - 22:00 0.50 STWHIP P WEXIT Pick-up l' and correct bit depth to 11665' (top of WS at 11666'). Flag pipe. 22:00 - 00:00 2.00 STWHIP P WEXIT Start milling window from 11666' @ 2.5 bpm 1620 psi off-btm 1700-1800 on btm. Frequent stalls. Mill to 11666.5' 10/9/2002 00:00 - 06:00 6.00 STWHIP P WEXIT Continue milling 3.80" window 2.8 bpm 2k wob 200-300 psi motor work from 11666.5' to 11669' appeared to have crossed casing center line. Continue milling ahead. 06:00 - 06: 15 0.25 STWHIP P WEXIT Continue milling ahead. Having to increase WOB to make footage. 06: 15 - 06:45 0.50 STWHIP P WEXIT Hold morning safety and Tech Limits Do mtg in ops cab. Discuss annular pressure monitoring proc & plan for the day. Continue milling during mtg. 06:45 - 08:45 2.00 STWHIP P WEXIT Milling ahead at 11671.7'. Appear to be through. Got a lot of . weight back. 200 psi motor work. Continue to mill ahead at 1 fph. 08:45 - 10:30 1.75 STWHIP P WEXIT Mill formation ahead to 11681'. Get sand back in returns. WINDOW: 11666' to 11672' 10:30 - 11 :45 1.25 STWHIP P WEXIT Back ream through window slowly three times. RIH dry. Very smooth. Left original pipe flag at 11665'. 11 :45 - 16:30 4.75 STWHIP P WEXIT POOH slowly to monitor injector. Stop several times to make minor adjustments. Pilot valve not adjusted for full hydraulic control in"out of hole" direction. (cannot adjust while in hole) POOH at 60 fpm max. 16:30 - 17:00 0.50 STWHIP P WEXIT Hold PJSM regarding getting injector off well and laying down milling BHA. 17:00 -18:15 1.25 STWHIP P WEXIT Set back injector. Difficult to maneuver due to wind wall design / gooseneck proximity. 18:15 -18:50 0.58 STWHIP P WEXIT Hold Tech limits Do mtg with night crew. Discuss UD of BHA. Plans to work on SLB Power Pack and make adjustments to hydraulic control. 18:50 - 20:15 1.42 STWHIP P WEXIT UD BHA #1 20:15 - 00:00 3.75 STWHIP N RREP WEXIT Diagnosis the problem of reduced charged hydraulic fluid supplied to the injector. Currently unable to POH faster than 60' fpm. 10/10/2002 00:00 - 05:00 5.00 STWHIP N RREP WEXIT Continue to diagnosis the problem of reduced charged hydraulic fluid supplied to the injector. Narrowed the problem to the Power Pack's gear ratio from traction motor to splitter gear box (hyd pump attached behind). Ratio now is 1.41 (motor) to 1 (gearbox). Should be the other way around (as spec'd). Printed: 10/21/2002 9:04:47 AM ) ) BP EXPLORATION Operations Summary Report Page 3 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-20 J-20 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/5/2002 Rig Release: 10/19/2002 Rig Number: N2 Spud Date: 8/1/1996 End: 10/19/2002 Date From - To Hours Task Code NPT Phase Description of Operations 10/10/2002 00:00 - 05:00 5.00 STWHIP N RREP WEXIT Maximum gpm obtainable is 72 gpm with traction motor running at close to high-end of recommended normal rpm range. Installation of correct gearbox may require removal of Power Pack and work performed in SLB Deadhorse shop. Options: Run as is until end of this well at reduced POH rates (lifting power not affected) then make swap (est. 24 hrs) or wait on new gearbox and make swap out before drilling ahead (2-3 days min) Confererred with town and decision made to go ahead with drilling this well as is. 05:00 - 06:00 1.00 DRILL P PROD1 PJSM cover p/u of BHA #2 procedures. (Earlier this morning discussed "fire drill" and "spill drill" procedures with crews) 06:00 - 07:00 1.00 DRILL P PROD1 MU BHA #2 (2.8 deg mtr w/ M09), Anadrill BHA w/ Torque orienter. 07:00 - 07:30 0.50 DRILL P PROD1 Hold on tour Tech Limit / Do mtg. Discuss plan forward & lessons learned. Also served as pre-job for stabbing injector on to well. 07:30 - 08:45 1.25 DRILL P PROD1 Stab injector on to well. Document each step of process. Note "unsolved" problems. Big improvement over first time on window mill run. Still room for improvement. 08:45 - 09:45 1.00 DRILL P PROD1 Test power pack hydraulics at surface. 09:45 - 10:15 0.50 DRILL P PROD1 RIH to mwd test depth at 1500'. 10:15-11:15 1.00 DRILL P PROD1 Test torque orienter. Minor problems with software. Rest of tools check ok. 11:15-13:15 2.00 DRILL P PROD1 Continue to RIH. Dry tag bottom at 11689 (uncorrected) 13:15 - 15:30 2.25 DRILL P PROD1 Log GR tie in from 11500 to 11650'. Add 16' correction. This corrects top of window to 11678' and bottom at 11685'. 15:30 -16:30 1.00 DRILL P PROD1 Begin displacement to flo-pro once through window. Re-Ioad orienter software. 16:30 - 20:45 4.25 DRILL P PROD1 Directionally drill ahead from 11695' (corrected TD) to 11800' .,; 2.7 bpm in/out, wob+/-2k, on btm 2875 psi, off btm 2680 (Hold Tech Limit / Do meeting with night crews) 20:45 - 21 :00 0.25 DRILL P PROD1 Wiper trip to window. 21 :00 - 00:00 3.00 DRILL P PROD1 Directionally drill ahead from 11800' to 11930' 2.7 bpm in/out, wob+/-2k, on btm 2850 psi, off btm 2670 psi 1 0/11/2002 00:00 - 06:00 6.00 DRILL P PROD1 Continue directionally drilling build section fl 11930' 2.6 bpm inlout 2400 psi off btm, 2700-2900 on btm, 3-4k wob. ROP slow while drilling the 14N shale. 0600 hrs at 12012' Bled down IA & OA 250 psi. 06:00 - 06:30 0.50 DRILL P PROD1 Drill ahead to 12030'. 06:30 - 06:45 0.25 DRILL P PROD1 Hold on tour Technical Limit Do mtg to discuss plan forward. Continue drilling ahead during mtg. 06:45 - 07:30 0.75 DRILL P PROD1 Drill to 12035'. Pump up survey to verify if landed. Projection to bit looks good. 07:30 - 11 :00 3.50 DRILL P PROD1 POOH. Max rate 80 FPM in high gear. Normal trip time would be 2.5 hrs. 11 :00 - 11 :45 0.75 DRILL P PROD1 Unstab injector from well. Update procedure documentation. 11 :45 - 12:30 0.75 DRILL P PROD1 Stand back/LD build assembly. 12:30 - 14:00 1.50 DRILL P PROD1 Download MWD data from tools. 14:00 - 15:00 1.00 DRILL P PROD1 MU BHA #3 (1.3 deg mtr with DS49). PU Anadril ARC resistivity tool. 15:00 -15:30 0.50 DRILL P PROD1 Stab on well with injector. 15:30 - 16:15 0.75 DRILL P PROD1 Replace pressure fitting on power pack. Printed: 10/21/2002 9:04:47 AM ") BP EXPLORATION Operations Summary Report Page 4 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-20 J-20 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/5/2002 Rig Release: 10/19/2002 Rig Number: N2 Spud Date: 8/1/1996 End: 10/19/2002 Date From - To Hours Task Code NPT Phase Description of Operations 1 0/11 12002 16:15 - 16:45 0.50 DRILL P PROD1 RIH to 1500'. Test mwd systems. Good 16:45 - 19:15 2.50 DRILL P PROD1 Run in hole with lateral assembly 19:15 - 20:20 1.08 DRILL P PROD1 Log tie-in f/11520' down log to 11579' coil depth. +47' correction. Distance: Bit>Res 17.57', Bit>D&144.03', Bit>Gr 47.03' 20:20 - 20:40 0.33 DRILL P PROD1 20:40 - 21 :00 0.33 DRILL P PROD1 Orient TF work down through 14N shale. Stalled motor to 4k blew o-ring seal on 1502 union at coil reel (no spill). Pull in csg. 21:00 - 21:15 0.25 DRILL N SFAL PROD1 Repair 1502 union. 21 :15 - 21 :50 0.58 DRILL P PROD1 Orient and wash back to bottom. Tag at 12035'. 21 :50 - 22:15 0.42 DRILL P PROD1 Orient TF 22:15 - 00:00 1.75 DRILL P PROD1 Directionally drill build section f/12035'. 2.6 bpm in/out on btm 3050 psi off btm 2700 psi. 2-5k wob. Drilled to 12109'. Cum drlg time on DS-49 bit/sliding = 1.33 hrs 10/12/2002 00:00 - 02:30 2.50 DRILL P PROD1 Continue directionally drilling build section from 12109'. 2.6 in/out. 3000 psi / 2690 psi fs. 4-5K wob. Landed at 8927' tvd (12,140 MD). Drilled to 12206'. Slide time 1.75 hrs. 02:30 - 03:00 0.50 DRILL P PROD1 Wiper trip to window. Hole smooth. 03:00 - 03:50 0.83 DRILL P PROD1 Drill ahead f/12206'. 39k up, 12.5k dn wt. Drill to 12255'. 03:50 - 04:00 0.17 DRILL N STUC PROD1 Stuck at 12255'. Work pipe. Rest hole for 10 min. Pull free. 04:00 - 04: 1 0 0.17 DRILL P PROD1 Wiper trip 100' up hole. 04:10 - 06:30 2.33 DRILL P PROD1 Continue to drill f/12255'. 3100-3200 psi on btm. 5-6k wob. 100' fph. 2.6 in/out. 06:30 - 07:15 0.75 DRILL P PROD1 Wiper trip to window. 07:15 - 11 :45 4.50 DRILL P PROD1 Drill f/12316'. 3000 psi. 4-5k wob. 2.6 in/out. Begin drop at 12390' to position for crossing projected fault. Having weight transfer problems. 11 :45 - 12:30 0.75 DRILL P PROD1 Wiper trip to window. Order new mud to be built (800' /48 hrrs on this system) 12:30 - 14:15 1.75 DRILL P PROD1 Drilling f/12445'. 2.6 in/out bpm 2900/3100 psi. 6-8K wob. Hard spot. Several short wiper trips. Work our way through. Drilling ahead 50-100 fph. Continue to drop angle approaching fault. 14:15 -14:45 0.50 DRILL P PROD1 Pump up two surveys. 14:45 - 15:45 1.00 DRILL P PROD1 Drilling ahead. Continue to hold angle at 83-84 deg inc. 2.5 in/out. Drill to 12560'. 15:45 - 16:00 0.25 DRILL P PROD1 Switch torque tool from rotary to highside to arrest drop. 16:00 - 18:45 2.75 DRILL P PROD1 Drill f/ 12560' to 12622'. 18:45 - 20:35 1.83 DRILL P PROD1 Wiper trip to window. Up wt 37.5k dwn wt 13-14k 20:35 - 21 :20 0.75 DRILL N MiSe PROD1 Re-boot SLB computer. PVT system down unable to acquire pit levels. 21 :20 - 00:00 2.67 DRILL P PROD1 Directionally drill f/12622' to 12750'. 2.6 bpm in/out 2970 psi free-spin, 3400 psi on btm. Cum totals on DS-49 bit: footage 715' sliding 366' / 6.5 hrs rotate 349' /6.25 hrs 1 0/13/2002 00:00 - 01 :30 1.50 DRILL P PROD1 Directionally drilllaterial section (slide) f/12750' to 12820'. 2.6 bpm 3400 psi on btm 2800 free-spin. 01 :30 - 02:40 1.17 DRILL P PROD1 Wiper trip to window. Pick-up 38.2k put TORC in rotation mode. Orient on the fly going down. 02:40 - 04:45 2.08 DRILL P PROD1 Directionally drill f/12820' (slide) to 12860' (80fph). Put in Printed: 10/21/2002 9:04:47 AM ) ) BP EXPLORATION Operations Summary Report Page 5 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-20 J-20 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 1 0/5/2002 Rig Release: 10/19/2002 Rig Number: N2 Spud Date: 8/1/1996 End: 10/19/2002 Date From - To Hours Task Code NPT Phase Description of Operations 10/13/2002 02:40 - 04:45 2.08 DRILL P PROD1 rotation mode 12860' to 12922'. Need to swap mud. 04:45 - 06:00 1.25 DRILL P PROD1 Wiper trip top window. Plan to tie-in. New mud ETA 0700 hrs. 06:00 - 07:15 1.25 DRILL P PROD1 Log grtie in fl 11550'. Add 12' correction. 07: 15 - 07:45 0.50 DRILL P PROD1 Run in hole. Smooth. Orient while RIH. 07:45 - 10:30 2.75 DRILL P PROD1 Drilling fl 12922'. 2.6 inlout 3100 psi fs 3-4k wob. Weight transfer problems. Begin mud swap. 10:30 - 12:50 2.33 DRILL P PROD1 Drilling f/13029' 2.6 inlout 3100 psi fs 3-5 k wob. Still having weight x-fer problems. New mud in OH. Send 285 bbls mud to plant for re-use. 12:50 - 14:00 1.17 DRILL P PROD1 Short trip to window. 14:00 - 15:30 1.50 DRILL P PROD1 Drilling f/13093 2.5 inlout 3100 psi fs 3-5k wob. Drilling much improved after wiper trip. 15:30 - 16:45 1.25 DRILL P PROD1 Drilling f/13174 Drilling definitely much improved after new mud. ROP up to 120 fpm. Rock looks good too. Drilled to 13223'. Stacking wt. Unable to drill ahead Cum totals fl DS49 footage 1185' slide 712' > 11.08 hrs rotate 471' > 9.17 hrs 16:45 - 19:00 2.25 DRILL P PROD1 Wiper trip. Orient different TF and in rotation to clean up hole. (Tech. Limit meeting during this time) 19:00 - 20:20 1.33 DRILL P PROD1 Ream and backream, try to drill, no motor work on bottom. Try in rotary mode no motor work. Need to TOH and inspect BHA. 20:20 - 23: 1 0 2.83 DRILL P PROD1 MAD pass from TO to 11,900'. (Talked with town group about pending TOH. Call TO or p/u another bha and finish last 250-300' of hole? Town agreed to call this TO.) Lost 450 psi pump pressure while at 12003' while logging. No surface leaks. MWD still giving data. RIH 30' could not tag anything. Continue MAD pass to 11900'. 23:10 - 00:00 0.83 DRILL P PROD1 POH to 11540'. Log tie-in down. 1 0/14/2002 00:00 - 00:45 0.75 DRILL P PROD1 Continue to log gr tie-in. +7' correction, changed TO to 13230'. Will not TIH to confirm TD. TOH to inspect BHA for pressure drop seen earlier. 00:45 - 04:05 3.33 DRILL P PROD1 TOH. 32'/min, coil wt 38.6k Stop and flag EOP at 9400'. Put in high gear at 8400' pulling 80'/min PJSM with crews about lId of bha. 04:05 - 05:00 0.92 DRILL P PROD1 Unstab from well and setback injector. 05:00 - 06:00 1.00 DRILL P PROD1 UD BHA. Bit, motor and xo sub left in hole. Clean back-off not a break. 2 3/8" SL H-90 pin will be looking up on fish. 06:00 - 06:30 0.50 DRILL N DFAL PROD1 LD BHA 06:30 - 07:15 0.75 DRILL N DFAL PROD1 Hold on Tour Tech limits Do mtg. Discuss plan, action items. lessons learned. 07:15 - 08:15 1.00 FISH N DFAL PROD1 Discuss plan with town. Decide to run H-90 box sub on motor. Take Anadrill cross over to Baker to verify thread compatibility. Not the same. Machine SL HT H-90 crossover to run on fishing assembly. 08:15 - 13:30 5.25 FISH N DFAL PROD1 Machine SL HT H-90 x PH-6 crossover to run on fishing assembly. 13:30 - 15:30 2.00 FISH N DFAL PROD1 PU fishing tools. Install and test Baker coil connector 15:30 - 15:45 0.25 FISH N DFAL PROD1 Hold PJSM to review fishing BHA make-up. 15:45 -18:15 2.50 FISH N DFAL PROD1 MU fishing BHA. Have trouble with hydraulic floor tugger which back spooled & jammed. M/U injector to well. Printed: 10/21/2002 9:04:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: ) BP EXPLORATION Operations Summary Report J-20 J-20 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/5/2002 Rig Release: 10/19/2002 Rig Number: N2 ') Page 6 of 9 Spud Date: 8/1/1996 End: 10/19/2002 Date From - To Hours Task Code NPT Phase Description of Operations 10/14/2002 18:15 - 21 :10 2.92 FISH N DFAL PROD1 RIH. Correct depth to flag at 9400'. Weight check at window 38.1 k continue RIH through window slight pump in weight. 21 :10 - 22:00 0.83 FISH N DFAL PROD1 RIH. Pumping at.7 bpm and pp @ 1350 psi. No problems through build section. Tag fish at 11984', pp increased to 1540 psi. Push another 100' and gained 100 psi (1640) Continue RIH pushing fish to bottom no further increase in pp other than possibly friction pressure which increased to 1730 psi. No problems going to bottom, never took weight. Tagged bottom 13213' + fish would be 13226'. Pressure increased to 1760 psi. Set down with 10k no increase in pp. Shut down pump. 22:00 - 00:00 2.00 FISH N DFAL PROD1 TOH filling hole across top with charge pump. P/U wt through laterial section 47-48k. Small bump at window coming up through. Flag pipe at 9240' EOP. Shift into high gear at 8300' speed 80'/min. 10/15/2002 00:00 - 02:10 2.17 FISH N DFAL PROD1 Continue TOH. 02:10 - 03:00 0.83 FISH N DFAL PROD1 Stab off well and set back injector. 03:00 - 03:30 0.50 FISH N DFAL PROD1 P/U BHA from well. Fish recovered. LID BHA and fish. BHl's motor bit box freespins, failed transmission between bit box and rotor. DS-49 bit green. No washout on SL H-90 pin that was looking up on fish. 03:30 - 17:30 14.00 BOPSURP PROD1 Grease master, swab, flowline valves. Test BOPE. AOGCC rep. Jeff Jones wavied witnessing test. 17:30 - 18:30 1.00 DRILL P PROD1 Pump dart to determine CT volume. CT Vol.= 53.8bbls 18:30 - 19:15 0.75 CASE P PROD1 Tech limits meeting, sharing lessons learned and reviewing forward plan to run liner. Good input from the crews. 19:15 - 20:00 0.75 CASE P PROD1 Stand back injector, RU tongs, elevators. Postition blocks, unable to position blocks directly above wellhead, get them as close as possible. 20:00 - 00:00 4.00 CASE P PROD1 PU and run 46 Joints 2-7/8",4 joints 3-3/16" and 9 joints of 3-1/2". 1 0/16/2002 00:00 - 02:00 2.00 CASE P COMP Continue making up liner. 02:00 - 03:00 1.00 CASE P COMP Position injector over wellhead. Stab injector. Still learning, need to capture a procedure to make this easier in the future. Difficult to maneuver due to wind wall design I gooseneck proximity. 03:00 - 07:30 4.50 CASE P COMP RIH with liner, unable to go any faster than 53fpm inside tubing due to power pack gear ratio problem. RIH to 11650' Coil wt 42000' RIH with 14000#. 07:30 - 08:00 0.50 CASE P COMP RIH to TD 13230. Drop 5/8" ball and disconnect. Weight on bottom 46000#. 08:00 - 08: 15 0.25 CASE P COMP Ball on seat. Shear with 4300 psi. 46.6 bbl away. PU 34000#. 08: 15 - 11 :20 3.08 CASE P COMP Change well over to KCL. 11 :20 - 11 :45 0.42 CEMT P COMP PJSM on pumping cement. 11 :45 - 11 :55 0.17 CEMT P COMP Batch mix 16 bbl, Class G, 15.8ppg cement 11 :55 - 12:45 0.83 CEMT P COMP Pump 5bbl H2O, PT lines to 4000 psi. pump. 12:45 - 13:15 0.50 CEMT P COMP Displaced dart with 35bbls biozan, followed with KCL. 13:15 - 13:30 0.25 CEMT P COMP PU liner wiper plug, sheared at 3300 psi. Displaced to landing collar. Bumped at 66.1 bbl, applied 2700 psi. Floats held. Flushed top of liner. Full return thru cement job. 13:30 - 16:40 3.17 CEMT P COMP POH with CTLRT. 16:40 -19:00 2.33 CEMT P COMP At surface, LD CTLRT. RU Swizzle stick and blow down stack. 19:00 - 20:00 1.00 CEMT P COMP PJSM, tech limits meeting Printed: 10/21/2002 9:04:47 AM ) ) BP EXPLORATION Operations Summary Report Page 7 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-20 J-20 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 1 0/5/2002 Rig Release: 10/19/2002 Rig Number: N2 Spud Date: 8/1/1996 End: 10/19/2002 Date From - To Hours Task Code NPT Phase Description of Operations 10/16/2002 20:00 - 21 :00 1.00 CEMT P COMP Stand back injector 21 :00 - 21 :45 0.75 EVAL P COMP RU to run MCNL and 1-1/4" CS Hydril. 21 :45 - 22:00 0.25 EVAL P COMP PJSM. Discuss CS Hydril running procedure, Radio Active Source issues with MCNL: Clear floor ( except one person on tugger + logging expert) when source is being placed in tool & when running thru stack. Take special care of pinch points in this new environment. 22:00 - 23:00 1.00 EVAL P COMP Strap pipe, continue RU to run MCNL 23:00 - 00:00 1.00 EVAL P COMP MU 2.3" parabolic mill, Navidrill motor, MCNL carrier, 63Joints 1-1/4" CS Hydril in singles, MHA. Disconnect above and below CS hydril, ciirc sub just above MCNL. 10/17/2002 00:00 - 02:00 2.00 EVAL P COMP Continue.. MU 2.3" parabolic mill, Navidrill motor, MCNL carrier, 63Joints 1-1/4" CS Hydril in singles, MHA. Disconnect above and below CS hydril, ciirc sub just above MCNL. 02:00 - 03: 15 1.25 EVAL P COMP Postion injector. Stab injector. 03: 15 - 05:30 2.25 EVAL P COMP RIH with MCNL and cleanout motor/mill at 60fpm. PBTD 13188' LC 13,193. 05:30 - 06:30 1.00 EVAL COMP Start logging down at 30fpm from 11,250'. 06:30 - 06:45 0.25 EVAL COMP Tech limits meeting. PJSM 06:45 - 07:05 0.33 EVAL COMP Continue logging down at 30fpm 07:05 - 07:30 0.42 EVAL COMP Tag up shallow, mill cement stringers with very little work down to 13,185'md. 07:30 - 08:30 1.00 EVAL P COMP Log OOH at 30 ftImin to 11240'. 08:30 - 09:30 1.00 EVAL P COMP RIH to TD to spot perf pill. 09:30 - 14:15 4.75 EVAL P COMP Start POH while laying in 20bbl, 150k LSRV flopro perf pill. perf pill. 14:15 -17:30 3.25 EVAL P COMP At surface. Unstab, set back injector. Pull and stand back CS hydril. 17:30 - 17:45 0.25 EVAL P COMP PJSM on removing RA source from MCNL 17:45 - 18:00 0.25 EVAL P COMP Remove source and LD MCNL tools. 18:00 - 18:20 0.33 PERF P COMP Load guns into pipe shed. 18:20 - 18:40 0.33 PERF P COMP Tech limits and PJSM prior to running guns. Discuss job responsibilities. - Flag cellar and place signs on rig that perforating is in progress. 18:40 -19:00 0.33 PERF P COMP Continue loading guns into pipe shed. Prepare safety joint and TIW valve. 19:00 - 19:40 0.67 PERF P COMP PT liner lap. Failed test, lost 913psi over 30minutes. Start press= 2000psi, end press=1087psi. 19:40 - 20:00 0.33 PERF P COMP Review MCNL output with Schlumberger logging rep. Fax log to Roger Sels. Discuss tie in to Ref. Log, tie in looks good. 20:00 - 22:00 2.00 PERF P COMP Waiting on orders, GEO and pad engineer taking a closer look at the MCNL results. 22:00 - 00:00 2.00 PERF P COMP PU guns. 3 intervals, 12100-12400, 12600-12900, 13090-13170. PBTD= 13185 10/18/2002 00:00 - 00: 15 0.25 PERF P COMP PU guns, MU firing head. MU one joint of running string, set in slips. Practice installing TIW valve in case of well control incident. 00:15 - 00:30 0.25 PERF P COMP PJSM on handling RTS work string stood back in derrick. Discuss job responsibilities. Watch toes when using slip type elevators, the string can drop as it is picked up. 00:30 - 01 :00 0.50 PERF P COMP RU for running work string. No breakout harness in derrick, install same. 01 :00 - 02:00 1.00 PERF P COMP PU, 12 stands of RTS 1-1/4" work string. Printed: 10/21/2002 9:04:47 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ) ) Page 8 of 9 BP EXPLORATION Operations Summary Report J-20 J-20 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/5/2002 Rig Release: 10/19/2002 Rig Number: N2 Spud Date: 8/1/1996 End: 10/19/2002 Description of Operations From - To Hours Task Code NPT Phase RIH with Perf guns. Wt check above window= 42000. 10/18/2002 02:00 - 04:15 04:15 - 05:10 05:10 - 06:30 06:30 - 06:45 06:45 - 09:30 09:30 - 10:00 10:00 - 11 :00 11 :00 - 11 :30 11 :30 - 16:00 16:00 - 17:00 17:00 - 18:00 18:00 - 20:00 20:00 - 20:20 20:20 - 21 :00 21:00 - 21:10 21:10 - 21:45 2.25 PERF P 0.92 PERF P 1.33 PERF P 0.25 PERF P 2.75 PERF P 0.50 PERF P 1.00 PERF P 0.50 PERF P 4.50 PERF P 1.00 RUNCOI'vP 1.00 RUNCOI'vP 2.00 RUNCOI'vP 0.33 RUNCOI'vP 0.67 RUNCOI'vP 0.17 RUNCOI'vP 0.58 RUNCOI'vP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP COMP Leak: <1 gal of hydraulic oil on pad after hydraulic pump failed on Loader. Spoke with environmental. Tag bottom, PU, tag bottom a second time. PU until weight breaks over. Call this PBTD. Correct depth, add 12'. Corrected to PBTD on MCNL, 13,185'. Drop 5/8" ball. Launch ball with Flo-Pro. Position bottom shot at 13170'md. Displace ball at 2.5bpm, 450psi. slow to 0.8bpm 10bbls before pumping CT volume. Ball on seat at 51 bbls away, CT volume is 56bbls. Positive indication that guns fired. POH to above liner. Monitor well. POH to 1-1/4" RTS tubing. Set back injector. Standback 12 stands of 1-1/4" RTS tubing. PJSM Lay down 51 guns ave lenght 21'. Pu liner top packer and two joints of 2-7/8" PH-6 tubing. Stab injector RIH with liner top packer assembly. Tech limits meeting from 18:25 to 18:45 while RIH. . " Leak: While transferring guns from rig to pick-up via forks on loader, spent guns leaked crude on pad. Less than a gallon. Spoke with environmental. Discussed mitiagting this type of leak in future with crew. Need to insure guns are bundled prior to transporting from rig if residual fluid is trapped in spent guns. Schlumberger has revised procedure for LD guns. Cont RIH. Slow down to 30fpm at 11 ,200'md. CT RIH weight= 19000-20000Lbs. Start losing wt at 11 ,364'md. Set down at 11368.8. Sit down on liner top, WOB=10000Ibs, CT wt=8950. Shut down pumps. PU, to 11364.0 CT wt=41500. Prepare to drop ball. PU to 11328' out of PBR to drop 5/8" ball. Baker hand is concerned that when we pump ball down we could hydraulic the seals out of the liner top if the formation is tight. Zero MMin. Drop ball. 2.5bpm/2.3bpm/1080psi. At 20bbls out, slow down pumps to 0.3bpm/0.3/50psi , CT vol.=53.4bbl. Ball on seat at 30.2bbls see CT circ pressure come up to 200psi. Shut down pumps. RIH at 15fpm without pumps. RIH CT wt= 20300Lbs. WOB=O. Set down at 11368.8, CT wt=9300, Wob=-10000. PU to 11364. Bring pumps up slowly, target pressure to set slips with ball on seat is 2500psi. Level out at 2500psi. Slack off, set down 1000Owob. PU to 11363.8 CT wt= 39000Lbs. WOB=O. Still holding 2500psi. Line up to pump down backside. Accidentally bleed off CT pressure, to 1500psi. Isolate CT, proceed. IA=110, OA=95psi. Ramp WHP up to 2000psi while pumping down backside to test seal. Once we were blocked in press= 1900, leaked off to 1870psi. GOOD test for 30min. Printed: 10/21/2002 9:04:47 AM ) ) BP EXPLORATION Operations Summary Report Page 9 of 9 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: J-20 J-20 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 10/5/2002 Rig Release: 10/19/2002 Rig Number: N2 Spud Date: 8/1/1996 End: 10/19/2002 Date From - To Hours Task Code NPT Phase Description of Operations 10/18/2002 21 :45 - 21 :50 0.08 RUNCOI\JP COMP Bleed pressure off backside and CT. Set down, CT wt=17000Lbs. WOB=3500. Pressure up to 3700psi to shear off of liner top packer. Shut down pumps. Let press bleed off. PU, CT wt=43000, getting a bit of overpull. Previous PU wt was 41500Lbs. 21 :50 - 00:00 2.17 RUNCOI\JP COMP POH at 75fpm. 10/19/2002 00:00 - 01 :00 1.00 RUNCOI\JP COMP POH at 75fpm. Freeze protect with MeOH to 2000'. 01 :00 - 02:00 1.00 RUNCOI\JP COMP LD Baker running tools. 02:00 - 06:15 4.25 RIGD P COMP Start rig down, stand back injector, blow back CT reel, pull CT back to reel, RD riser. 06: 15 - 07:00 0.75 RIGD P COMP Safety / Tech Limits meeting 07:00 - 08:00 1.00 RIGD P COMP Remove IA & OA transducers, Vac out cutting box, ND BOP. 08:00 - 08:30 0.50 RIGD P COMP Nu tree cap and test to 4000 psi. 08:30 - 10:00 1.50 RIGD P COMP Clean pits & move out side equipment. Release rig. Printed: 10/21/2002 9:04:47 AM Client...................: BP (Alaska) Inc Field....................: Prudhoe Bay Well. . . . . . . . . . . . . . . . . . . . .: J 20b API number...............: 50-029-21716-01 Engineer.................: Harmer RIG: . . . . . . . . . . . . . . . . . . . . .: Nordic 2 CTD STATE: . . . . . . . . . . . . . . . . . . .: Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ----------------------- Permanent datum..........: Mean Sea Level Depth reference. . . . . . . . . .: Correlation Marker GL above permanent.......: -50000.00 ft KB above permanent.......: -50000.00 ft DF above permanent.......: -50000.00 ft ----- Vertical section origin---------------- Lati tude (+N/S -) . . . . . . . . . : 0 . 00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft SCHLUMBERGER Survey report Azimuth from rotary table to target: 22.00 degrees [(c)2002 IDEAL ID8_0C_06] 14-0ct-2002 10:21:58 Spud date. . . . . . . . . . . . . . . . : Last survey date.........: Total accepted surveys...: MD of first survey.......: MD of last survey........: Page 1 of 3 09-0ct-02 14-0ct-02 43 11663.39 ft 13230.00 ft '-~ ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2002 Magnetic date............: 09-0ct-2002 Magnetic field strength..: 1150.55 HCNT Magnetic dec (+E/W-).....: 26.01 degrees Magnetic dip.. ...........: 80.81 degrees ----- MWD Reference Reference Reference Tolerance Tolerance Tolerance survey Reference G. . . . . . . . . . . . . . : H. . . . . . . . . . . . . . : Dip. . . . . . . . . . . . : of G........... : of H........... : of Dip......... : Criteria --------- 1002.68 mGal 1150.55 HCNT 80.81 degrees (+/-) 2.50 mGal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-).....: 26.02 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 26.02 degrees (Total az corr = magnetic dec - grid conv) Survey Correction Type. . . : I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction ~» SCHLUMBERGER Survey Report 14-0ct-2002 10:21:58 Page 2 of 3 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 1 11663.39 40.57 107.30 0.00 8674.52 -1707.22 -4178.82 5785.57 7136.90 125.84 0.00 TIP None 2 11678.00 40.46 107.34 14.61 8685.63 -1706.45 -4181.65 5794.63 7145.90 125.82 0.77 SP None 3 11722.85 42.50 82.96 44.85 8719.45 -1697.85 -4184.14 5823.75 7170.99 125.70 36.13 SP None 4 11765.17 44.20 68.86 42.32 8750.29 -1680.79 -4177.05 5851.77 7189.64 125.52 23.19 SP None 5 11802.46 41.45 53.17 37.29 8777.72 -1661.28 -4164.93 5873.84 7200.60 125.34 29.48 SP None 6 11833.67 35.58 42.00 31.21 8802.16 -1643.87 -4151.96 5888.21 7204.85 125.19 29.10 SP None 7 11872.77 30.70 21.72 39.10 8834.99 -1623.12 -4134.17 5899.56 7203.90 125.02 30.82 SP None 8 11914.40 46.35 13.85 41.63 8867.48 -1597.41 -4109.51 5907.15 7196.00 124.83 39.33 SP None ~' 9 11937.62 54.95 9.67 23.22 8882.19 -1579.77 -4091.94 5910.76 7188.96 124.69 39.55 SP None 10 11972.81 64.48 3.92 35.19 8899.93 -1550.52 -4061.82 5914.28 7174.75 124.48 30.52 SP None 11 12007.75 72.60 350.00 34.94 8912.75 -1521.22 -4029.48 5912.45 7154.98 124.28 43.71 SP None 12 12040.79 79.28 343.97 33.04 8920.78 -1495.02 -3998.29 5905.22 7131.47 124.10 26.87 SP None 13 12072.38 84.43 347.77 31.59 8925.26 -1469.77 -3967.98 5897.59 7108.20 123.93 20.19 SP None 14 12103.94 88.38 350.85 31.56 8927.24 -1443.27 -3937.04 5891.75 7086.11 123.75 15.86 SP None 15 12143.81 90.83 355.92 39.87 8927.52 -1408.28 -3897.45 5887.16 7060.37 123.51 14.11 SP None 16 12186.32 91.08 1.95 42.51 8926.82 -1369.19 -3854.97 5886.37 7036.35 123.22 14.19 SP None 17 12224.18 90.98 6.30 37.86 8926.14 -1333.18 -3817.23 5889.10 7018.02 122.95 11.49 SP None 18 12266.25 90.55 11.25 42.07 8925.58 -1292.24 -3775.66 5895.51 7000.91 122.64 11.81 SP None 19 12303.19 90.63 13.70 36.94 8925.20 -1255.81 -3739.60 5903.49 6988.26 122.35 6.64 SP None 20 12334.89 92.85 14.47 31.70 8924.24 -1224.43 -3708.87 5911.20 6978.40 122.11 7.41 SP None 21 12365.56 90.33 15.57 30.67 8923.39 -1194.00 -3679.26 5919.14 6969.45 121.86 8.99 SP None 22 12395.82 87.68 16.00 30.26 8923.92 -1163.93 -3650.15 5927.37 6961.13 121.63 8.84 SP None 23 12427.16 84.40 13.97 31.34 8926.08 -1132.90 -3619.95 5935.46 6952.25 121.38 12.30 SP None ~ 24 12458.66 84.03 12.77 31.50 8929.26 -1101.92 -3589.47 5942.70 6942.62 121.13 3.97 SP None 25 12488.89 83.58 12.62 30.23 8932.52 -1072.26 -3560.15 5949.31 6933.18 120.90 1.60 SP None 26 12520.89 84.13 12.02 32.00 8935.95 -1040.90 -3529.06 5956.10 6923.11 120.65 2.56 SP None 27 12576.29 87.88 9.22 55.40 8939.81 -986.73 -3474.76 5966.28 6904.38 120.22 8.44 SP None 28 12614.88 90.83 9.82 38.59 8940.25 -949.06 -3436.71 5972.66 6890.83 119.92 7.78 SP None 29 12653.92 90.63 9.05 39.04 8939.75 -910.96 -3398.20 5979.06 6877.27 119.61 2.03 SP None 30 12695.67 90.78 13.45 41.75 8939.24 -869.96 -3357.27 5987.20 6864.24 119.28 10.54 SP None [(c)2002 IDEAL ID8_0C_06] SCHLUMBERGER Survey Report 14-0ct-2002 10:21:58 Page 3 of 3 -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) ( deg) 100f) type (deg) -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ -------- ------ ------- ------ -------- -------- ---------------- --------------- ------ 31 12733.87 91.20 17.67 38.20 8938.58 -832.01 -3320.48 5997.44 6855.28 118.97 11.10 SP None 32 12774.03 90.88 22.47 40.16 8937.85 -791.89 -3282.77 6011.22 6849.19 118.64 11.98 SP None 33 12813.97 87.50 25.92 39.94 8938.42 -752.00 -3246.36 6027.58 6846.21 118.31 12.09 SP None 34 12853.75 83.63 30.00 39.78 8941.49 -712.57 -3211.34 6046.17 6846.08 117.97 14.11 SP None 35 12895.42 84.60 30.35 41.67 8945.76 -671.54 -3175.51 6067.00 6847.80 117.63 2.47 SP None 36 12935.58 85.53 30.22 40.16 8949.22 -631.95 -3140.96 6087.18 6849.77 117.29 2.34 SP None 37 12979.41 91.00 27.85 43.83 8950.55 -588.49 -3102.67 6108.43 6851.24 116.93 13.60 SP None 38 13016.98 94.30 28.12 37.57 8948.81 -551.17 -3069.53 6126.04 6852.03 116.61 8.81 SP None ~" 39 13054.75 90.33 33.57 37.77 8947.29 -513.90 -3037.15 6145.38 6854.92 116.30 17.86 SP None 40 13096.01 93.05 39.70 41.26 8946.07 -474.02 -3004.07 6169.97 6862.43 115.96 16.26 SP None 41 13135.08 93.05 46.02 39.07 8943.99 -437.58 -2975.49 6196.50 6873.87 115.65 16.15 SP None 42 13172.16 92.73 51.87 37.08 8942.12 -404.58 -2951.18 6224.41 6888.59 115.37 15.78 SP None Projected to TD: 43 13230.00 92.72 51.87 57.84 8939.38 -354.48 -2915.50 6269.86 6914.57 114.94 0.00 proj None [(c)2002 IDEAL ID8_0C_06] ---' bp J-20B Survey Report - Geodetic Schlumberger Report Date: 14-0ct-02 Survey I DLS Computation Method: Minimum Curvature 1 Lubinski Client: Shared Services Drilling Vertical Section Azimuth: 22.000° Field: Prudhoe Bay Unit - WOA (Drill Pads) Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: J-PAD 1 J-20 TVD Reference Datum: MSL Well: J-20 TVD Reference Elevation: 0.000 ft relative to MSL Borehole: J-20B Sea Bed I Ground Level Elevation: 0.000 ft relative to MSL UWI/API#: 500292171602 Magnetic Declination: -+D.OOO° Survey Name I Date: J-20BI October 14, 2002 Total Field Strength: 0.000 nT Tort I AHD I DOlI ERD ratio: 352.636° 18613.96 ft 16.652/ 0.962 Magnetic Dip: 0.000° ~ Grid Coordinate System: NAD27 Alaska State Planes, Zone 4, US Feet Declination Date: October 21,2002 Location LatlLong: N 70 1933.230, W 148508.881 Magnetic Declination Model: BGGM 2002 Location Grid N/E YIX: N 5970139.360 ftUS, E 643559.600 ftUS North Reference: True North Grid Convergence Angle: +1.09625426° Total Corr Mag North.) True North: -+D.OOO° Grid Scale Factor: 0.99992341 Local Coordinates Referenced To: Well Head Grid Coordinates Geographic Coordinates Station ID MD Incl Azim TVD VSec N/.S EI.W DLS Northing Easting Latitude Longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (°/1 OOft) (ftUS) (ftUS) 11663.39 40.57 107.30 8674.52 -1707.25 -4178.85 5785.57 5966072.28 649423.60 N 70 1852.109 W 1484720.095 11678.00 40.46 107.34 8685.63 -1706.48 -4181 .68 5794.63 0.77 5966069.63 649432.71 N 70 18 52.082 W 148 47 19.831 11722.85 42.50 82.96 8719.45 -1697.88 -4184.17 5823.75 36.13 5966067.69 649461.87 N 70 18 52.057 W 148 47 18.982 11765.17 44.20 68.86 8750.30 -1680.81 -4177.08 5851.77 23.19 5966075.32 649489.75 N 70 18 52.126 W 1484718.164 11802.46 41.45 53.17 8777.72 -1661.31 -4164.96 5873.84 29.48 5966087.86 649511 .58 N 70 18 52.245 W 148 47 17.520 11833.67 35.58 42.00 8802.16 -1643.90 -4151.99 5888.21 29.10 5966101.10 649525.70 N 70 1852.373 W 1484717.100 11872.77 30.70 21.72 8834.99 -1623.15 -4134.20 5899.56 30.82 5966119.10 649536.71 N 70 18 52.548 W 148 47 16.769 11914.40 46.35 13.85 8867.48 -1597.44 -4109.54 5907.15 39.33 5966143.90 649543.82 N 70 18 52.790 W 1484716.547 11937.62 54.95 9.67 8882.19 -1579.80 -4091.98 5910.76 39.55 5966161.53 649547.10 N 701852.963 W 1484716.441 ~. 11972.81 64.48 3.92 8899.93 -1550.55 -4061.85 5914.28 30.52 5966191.72 649550.04 N 70 18 53.259 W 148 47 16.338 12007.75 72.60 350.00 8912.76 -1521.25 -4029.51 5912.45 43.71 5966224.01 649547.59 N 70 18 53.577 W 148 47 16.390 12040.79 79.28 343.97 8920.78 -1495.05 -3998.32 5905.22 26.87 5966255.06 649539.76 N 70 18 53.884 W 148 4716.601 12072.38 84.43 347.77 8925.26 -1469.80 -3968.01 5897.59 20.19 5966285.21 649531 .56 N 701854.182 W 1484716.822 12103.94 88.38 350.85 8927.24 -1443.30 -3937.07 5891.75 15.86 5966316.03 649525.13 N 70 18 54.487 W 148 47 16.992 12143.81 90.83 355.92 8927.51 -1408.31 -3897.48 5887.16 14.12 5966355.52 649519.79 N 701854.876 W 148 4717.125 12186.32 91.08 1.95 8926.80 -1369.22 -3855.00 5886.37 14.20 5966397.97 649518.18 N 70 1855.294 W 1484717.147 12224.18 90.98 6.30 8926.12 -1333.20 -3817.26 5889.10 11.49 5966435.76 649520.18 N 701855.665 W 1484717.067 12266.25 90.55 11.25 8925.56 -1292.27 -3775.70 5895.51 11.81 5966477.44 649525.80 N 70 1856.074 W 1484716.879 J-20B ASP Final Survey.xls Page 1 of 2 10/28/2002-11 :00 AM Grid Coordinates Geographic Coordinates Station ID MD IncJ Azim TVD VSec N/.S EI.W DlS Northing Easting latitude longitude (ft) (°) (°) (ft) (ft) (ft) (ft) (°/1 DOft) (ftUS) (ftUS) 12303.19 90.63 13.70 8925.18 -1255.84 -3739.63 5903.49 6.64 5966513.64 649533.09 N 70 18 56.428 W 148 47 16.645 12334.89 92.85 14.47 8924.22 -1224.46 -3708.90 5911.20 7.41 5966544.51 649540.21 N 701856.730 W 1484716.419 12365.56 90.33 15.57 8923.37 -1194.03 -3679.29 5919.15 8.96 5966574.27 649547.58 N701857.021 W1484716.187 12395.82 87.68 16.00 8923.89 -1163.96 -3650.18 5927.38 8.87 5966603.53 649555.25 N 70 18 57.308 W 1484715.946 12427.16 84.40 13.97 8926.06 -1132.93 -3619.99 5935.46 12.30 5966633.87 649562.76 N 70 1857.605 W 1484715.710 12458.66 84.03 12.77 8929.23 -1101.95 -3589.50 5942.71 3.97 5966664.49 649569.42 N 701857.904 W 1484715.498 12488.89 83.58 12.62 8932.50 -1 072.29 -3560.18 5949.31 1.57 5966693.93 649575.46 N 701858.193 W 1484715.304 12520.89 84.13 12.02 8935.92 -1040.93 -3529.09 5956.10 2.54 5966725.13 649581.65 N 701858.498 W 1484715.105 12576.29 87.88 9.22 8939.78 -986.76 -3474.79 5966.28 8.44 5966779.62 649590.79 N 70 18 59.032 W 148 47 14.807 12614.88 90.83 9.82 8940.21 -949.09 -3436.74 5972.66 7.80 5966817.78 649596.44 N 70 18 59.407 W 1484714.620 "-'/ 12653.92 90.63 9.05 8939.72 -910.99 -3398.23 5979.06 2.04 5966856.40 649602.10 N 701859.785 W 1484714.433 12695.67 90.78 13.45 8939.20 -869.99 -3357.30 5987.20 10.54 5966897.48 649609.46 N 70190.188 W 1484714.194 12733.87 91.20 17.67 8938.54 -832.04 -3320.51 5997.44 11.10 5966934.45 649619.00 N 70190.549 W 1484713.894 12774.03 90.88 22.47 8937.81 -791.92 -3282.81 6011.22 11.98 5966972.41 649632.05 N 70 19 0.920 W 1484713.491 12813.97 87.50 25.92 8938.38 -752.03 -3246.39 6027.58 12.09 5967009.13 649647.71 N70191.278 W1484713.013 12853.75 83.63 30.00 8941.46 -712.60 -3211.37 6046.17 14.11 5967044.50 649665.62 N 70 191.622 W 1484712.470 12895.42 84.60 30.35 8945.73 -671.57 -3175.54 6067.00 2.47 5967080.72 649685.76 N 70 19 1.975 W 148 47 11.861 12935.58 85.53 30.22 8949.18 -631.97 -3140.99 6087.18 2.34 5967115.65 649705.27 N70192.314 W1484711.272 12979.41 91.00 27.85 8950.51 -588.51 -3102.70 6108.43 13.60 5967154.33 649725.79 N 70192.691 W 1484710.651 13016.98 94.30 28.12 8948.77 -551.19 -3069.56 6126.04 8.81 5967187.80 649742.76 N 70 19 3.017 W 1484710.136 13054.75 90.33 33.57 8947.25 -513.93 -3037.18 6145.38 17.84 5967220.54 649761.47 N 70 193.335 W 148 47 9.571 13096.01 93.05 39.70 8946.03 -474.04 -3004.1 0 6169.97 16.25 5967254.08 649785.43 N 70 19 3.660 W 148 47 8.853 13135.08 93.05 46.02 8943.95 -437.61 -2975.52 6196.50 16.15 5967283.16 649811.40 N 70 193.941 W 148 478.078 13172.16 92.73 51.87 8942.08 -404.61 -2951.21 6224.41 15.78 5967308.00 649838.84 N 70 194.180 W 148477.263 13230.00 92.72 51.87 8939.33 -354.51 -2915.54 6269.86 0.02 5967344.53 649883.59 N 70 194.530 W 148475.936 .~ J-20B ASP Final Survey.xls Page 2 of 2 10/28/2002-11 :00 AM ) ~Od.-JÎO MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Lisa Weepie Well No J-20b Date Dispatched: 21-0ct -02 Installation/Rig Nordic 2 Dispatched By: Nate Rose Data No Of Prints No of Floppies Surveys Field Copy ASP (Alaska State Plane) 2 2 1 on floppy on floppy RECEI.VED OCT ~~ C 2002 Ala8Ú! O~ !it G&S Com~. CommiUion Anch'Cfafrò Received By: ~ (, 000/'... ) Please sign and return to: James H. Johnson BP Exploration (Alaska) Inc. Petrotechnical Data Center (LR2-1) 900 E. Benson Blvd. Anchorage, Alaska 99508 Fax: 907-564-4005 e-mail address:johnsojh@bp.com LWD Log Delivery V1.1, Dec '97 ') (ill TONY KNOWLES, GOVERNOR AI¿ASIiA OIL AND GAS CONSERVAnONCO~SSION 333 W. ? AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Thomas McCarty CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe Bay Unit J-20B BP Exploration (Alaska), Inc. Permit No: 202-170 Surface Location: 1215' SNL, 802' WEL, Sec. 09, TIIN, R13E Bottomhole Location: 3909' SNL, 294' EWL, Sec. 11, TIIN, R13E Dear Mr. McCarty: Enclosed is the approved application for permit to redrill the above development well. The permit to redrill does not exempt you from obtaining additional permits or approvals 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. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~ ()uJV£' 'MJ Camm~echsli T;ylG;' Chair BY ORDER OF THE COMMISSION DATED this~~ay of August, 2002 cc: Department ofFish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ALASKA , STATE OF ALASKA'\ t AND GAS CONSERVATION COMM'v510N PERMIT TO DRILL 20 AAC 25.005 /' 1b. Type of well [] Exploratory [] Stratigraphic Test II Development Oil [] Service [] Development Gas [] Single Zone [] Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool KBE = 70.88' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028280 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number /' J.20B 9. Approximate spud date 09/15/02 /' Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 13500' MD / 8960' TVDss 17. Anticipated pressure {see 20 MC 25.035 (e) (2)} 0 - 90 Maximum surface 2135 psig, Attotal depth (TVD) 88001/3190 psig Setting Depth TQP Bo\;oJ)1 Ouantity of Cement enath Mn TVn Mn TVn (include stQQe data.) 2000' 11500' 8555' 13500' 8960' 84 cu ft Class 'GI \tJ GA- -{ Ils/ D 1.- ~ ~1~/- 1 a. Type of work [] . Drill II Redrill [] Re-Entry [] Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1215' SNL, 802' WEL, SEC. 09, T11N, R13E At top of productive interval 167' SNL, 5122' EWL, SEC. 15, T11N, R13E At total depth 3909' SNL, 294' EWL, SEC. 11, T11 N, R13E 12. Distance to nearest property line 13. Distance to nearest well / ADL 028281,294' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 11675' MD Maximum Hole Angle 18. Casin~ Program Specifications Sll~ Hole CasinQ WeiQht Grade CpuDlinÇJ 3-3/4" 3-3I16"x2-7/S" 6.2#/6.16# L-80 TCII/ST-L 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 r' 19. ~~::e~i~~:~~~~~~~o~e:~~'m~~entry, and Deepen Operations. F! ~::,: ('" ~::.~ ~ Total depth: measured 14140 feet Plugs (measured) CIBP milled / pushed to 1Š5~5"¡'(î2tOh true vertical 8989 feet ., Effective depth: measured 14053 feet Junk (measured) true vertical 8990 feet Length Size Casing Structural Conductor Surface Intermediate Production Liner Liner Straddle Packer Assy Cemented 110' 20" 2978' 13-3/8" 11150' 9-5/8" 417' 7" 3342' 4-1/2" 266' 2-7/8" 8 cu yds Concrete 4127 cu ft Permafrost 2371 cu ft Class 'G' 110' 2978' 11150' 110' 2746' 8381' 438 cu ft Class 'G' 473 cu ft Class 'G' N/A 1088T - 11304' 819T - 848T 10798' - 14140' 8136' - 8989' 13309' - 13575' 8977' - 8990' 20. Attachments Open: 11990' - 13200' (seven intervals); Perf's Behind Straddled Isolation: 13410' - 13510' Perf's Below CIBP: 13650' - 13850', 13920' - 14040' true vertical Open: 8953' - 8984' (seven intervals); Perf's Behind Straddled Isolation: 8982' - 8988' Perf's Below CIBP: 8989' - 8989', 8989' - 89891 II Filing Fee 0 Property Plat II BOP Sketch [] Diverter Sketch II Drilling Program II Drilling Fluid Program 0 Time vs Depth Plot [] Refraction Analysis [] Seabed Report [] 20 AAC 25.050 Requirements Contact Engineer NameINumber: Prepared By NameINumber: Terrie Hubble, 564-4628 21. Is~:~:Y :::~ ~~~ ~~d ?ct to the ~:eOf~; ;::n~i~r... ... Date 8 /It¡ /ð < : ':' ..~... :-'" ;:,'~ .-~/>~&":'.;:(~:\.::~,~,,~j.~.:~,,::~:::t~(~,:\.\_:~¡:j;.:»Ji~)[~::~:::">;:~;~:~'::~;'~ -." , Permit Number API Number A~roval Date See cover letter Zo.2..- /?c) 50- 029-21716-02 i 1&\81 I 0 ~ for other reauirements Conditions of Approval: Samples Required 0 Yes 8 No Mud Log Áequired 0 Yes mI No Hydrogen Sulfide Measures ~ Yes 0 No Directional Survey Required EYes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: ~~t- ~oPE þo ~ÇDO f! ¡ . ..J/igmðl SIgned By :~mmy OechSli T~ylnr Commissioner by order of the commission L Date ~ þ(~ D~ Sub~;/I\n Triplicate Perforation depth: measured Approved By Form 10-401 Rev. 12-01-85 ) ) BP J-20b CTD Sidetrack Summary of Operations: A CTD through tubing sidetrack is planned for J-20a. The coil sidetrack, J-20b, will exit the 4 1/2" liner in the Ivishak Zone 2 formation and target Zone 1 B. / / A cast iron bridge plug will be set at approx. 11,700' to isolate the open perfs below. The sidetr~ whipstock will be set at approximately 11 ,675' (8683ss). Drilling coil will likely mill the window. Three faults are prognosed along the planned well path. Drilling experience in this area shows that losl circulation is likely. J-20b will be completed with a fully cemented 3 3/16" x 2 7/8" line and perforated. The '7 top of the cemented liner will be placed at approx. 11,500' MD (8555ss)./A liner top packer will be run if the { well fails a liner lap test. Phase 1: Prep work. Planned to commence Aug 20, 2002. 1. Eline will kill set a CIBP at 11 ,700'md and a mechanical whipstock at 11,675' MD (8683ss). ,/ Phase 2: Mill window, Drill and Complete sidetrack: Planned for Sept 15, 2002. Drilling coil will be used to mill the window then drill and complete the directional hole as per attached plan. Maximum hole angle is planned for 92 degrees. A cased hole Memory CNL will be run prior to perforating. Mud Program: . Phase 1 &2: Seawater / . Phase 3: Mill and drill with Flo-Pro (8.6 - 8.7 ppg) 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. Casing Program: / The production liner will be a 33/16" TC II x 2 7/8" ST-L solid liner from TD to approx. 11,500' MD (8555ss). ~ The X-O between 3 3/16" x 2 7/8" will be approx. 11,775' MD. Liner cement will be a minimum of 15 bbls of 15.8 ppg latex cement. Well Control: . BOP diagram is attached. / . Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. . The annular preventer will be tested to 400 psi and 2500 psi. Directional . See attached directional plan. Max. planned hole angle is 92 deg. . Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging . An MWD Gamma Ray will be run over all of the open hole section. Memory CNL will be run inside the liner. Hazards . / J pad is not considered an H2S pad and has no production with H2S in excess of 100 ppm. Pad offsets <10ppm H2S. If Kavik or too much HOT is penetrated while drilling Z1 then a plug back may be required. / If loss circulation becomes unmanageable a plug back may be required. . . ') ) Reservoir Pressure Res. press. is estimated to be 3190 psi at 8800'ss (7.0 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2135 psi. / TREE = MCEVOY W8.LHEAD= MCEVOY . ... .., "..... .......' ... ........ .... .... ACTUA TOR= OTIS KB~wEIe..T;.._wm.,^.m..m.m'67~1'6; . ~ 'on, <~.'.W"""^"".'..'..."..~ ,.. ",. n " BF. 8.EV = 42.23' 'KÕpN;'~"'M".W",w,w'.."W'M_8ÕO' ~:~-!\~'~'I~'~"w,~~w~,~~~~~~~~,; Datum MD = 11835' Öãtùñí-iŸ-õ~mm..".. .mSSÕÕ;'wSS J-20A / ') <8 13-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2978' r---J " Minimum ID = 2.441" @ 13309' 2-7/8" TBG CTD GAS PERF STRADDLE 1 9-5/8" CSG, 47#, L-80 NSCC X BTC XO 1-1 5575' ~' 1 4-1/2" TBG, 12.6#, L-80,BTC-MOD. X NSCTXO 1-1 6768' 1 , L' ~ ") ~ '¡~ I TOP OF 4-1/2" LNR I 9-5/8" X 4-1/2" BAKERZXPPKR -1 10798' ~ WITIEBACK, ID = 6.375" . ~ r 4-1I2"TBG, 12.6#,L-80. 0.0152 bpf,ID = 3.958" I-{ 10811' I \ 'Z I I TOP OF 7" LNR 1-1 10887' 1 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 11152' 1 I ~ I .. ÆRFORA TION SUMMARY REF LOG: BHCS 02/04/87 ANGLEATTOPÆRF: 67 @ 11990' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 11990 - 12000 0 04/14/02 2-7/8" 6 12115 - 12130 0 04/05/01 2-7/8" 6 12238 - 12288 0 04/05/01 2-3/4" 4 12630 - 12720 0 08/11/96 2-3/4" 4 12780 -12870 0 08/11/96 2-3/4" 4 12930 - 13090 0 08/11/96 2-3/4" 4 13150 -13200 0 08/11/96 2-3/4" 4 13410 - 13510 STRADLE 03/03/00 2-3/4" 4 13650 - 13850 C 08/11/96 2-3/4" 4 13920 -14040 C 08/11/96 SAr .) :JOTES: CTD STRADDLE OF ÆRF INTERNVAL 134. - .... .:>510 W/4-1/2" X 2-7/8" BAKER PROD PKRS @ 13309' & 13575' W/2-7/8" 6.4# TBG IN BETWEEN. 2-7/8" HES CIBP@ 13440' CTMD ON 2/14/01. 2200' H4-1/2" HES HXO SSSV NIP, ID = 3.813" 1 ~ ST MD 1VD 3 3766 3215 2 7408 5733 1 10713 8001 GAS LIFT MANDRELS DEV lYÆ VLV LATCH 35 MERLA GL V RA 42 MERLA SO RA 36 MERLA DV RA PORT DATE 08/15/96 08/15/96 08/15/96 1 10743' 1-14-112" HES X NIP, ID = 3.813" 1 1 10754' 1-19-5/8" x 4-1/2" TrN HBBP-T PKR, ID = 3.917" r 10778' 1-14-1/2" HES X NIP, ID = 3.813" 1 I 10798' 1- 4-1/2" HES X HIGH PRESSURE NIP, ID = 3.813" I 10811' 1-{4-1/2" WIR8.INE ENTRY GUIDE, ID = 4.000" MILLOUT WINDOW - 11304' - 11319' 1 13309' 1-{4-1/2" X 2-7/8" FA PRODUCTION PKR. I 11~TMDI-{2-7/8" HES CIBP I - 1 13575' 1-14-1/2" X 2-7/8" FA PROD PKR 1 PBTD I-{ 14053' 1 7" LNR, 26#, L-80, 0.0383 bpf, ID = 6.276" 1-1 12250' I TOP OF 2-7/8" TBG 1-1 13309' 1 1 2-7/8" TBG, 6.4#, L-80, 0.00579 bpf, ID = 2.441" 1-1 13575' I I 4-1/2" LNR, 12.6#, L-80 NSCT, 0.0152 bpf, ID = 3.958" DATE REV BY COMMENTS 06/28/90 LGM ORIGINAL COMA..ETION 08/11/96 SIDETRACK COMPlE1lON 04/02101 CHIKAK CORRECTIONS 04/09/01 JDMfKAK ADÆRFS 11/01/01 WBfTP SURF LOG CORRECTION DATE REV BY COMMENTS 12/13/01 JLJ/KAK MILLS) CIBP DEPTH a-tANGE 04/14/02 CWS/tlh ADD ÆRFS I-{ 14140' I PRUDHOE BAY UNIT WELL: J-20A ÆRMIT No: 196-1060 API No: 50-029-21716-01 SEC9, T11N, R13E BP Exploration (Alaska) TREE = MCEVOY WaLHEAD= MCEVOY ACTUAToR;u, . u.. ... . oTiS 'Kã:-ËLêr;-"~-'__"N_ä7~1'6ì BF:"ELEV";';"..N.W ..'" -"'4'2:23' Kõp~M_.__'nN_uNw_W'"N^,"_NU8ÕÕ" MãXÃ"ôgÎëw;;;NNWg-ä-@1"31SEr DaiUmMÖ;';"' .u... .... "'1'1'83'5' '5âTùm-iV[);'''-~~-äáõ(Ÿsš' ) Proposed CrD Sidetrack SAFr'j 3: CTD STRADDLE OF ÆRF INTERNVAL 1341, ,51u W/4-1/2" X 2-7/8" BAKER PROD PKRS @ 13309' & 13575' W/2-7/8" 6.4# TBG IN BETWES\J. 2-7/8" HES CIBP@ 13440' CTMD ON 2/14/01. 13-3/8" CSG, 72#, L-80, ID = 12.347" I.., 2978' J-20B ~ Minimum ID = 2.441" @ 13309' 2-7/8" TBG CTD GAS PERF STRADDLE 1 9-5/8" CSG, 47#, L-80 NSCC X BTC XO I.., 5575' ~' 1 4-1/2" TBG, 12.6#, L-80,BTG-MOD. X NSCTXO I.., 6768' J , 8 L' ~ \. \ / ~ ¡~ 1 TOP OF 4-1/2" LNR 1 9-5/8" X 4-1/2" BAKERZXPPKR.., 10798' ~ W/TIEBACK, ID = 6.375" . ~ r 4-1/2"TBG,12.6#,L-80, 0.0152 bpf,ID = 3.958" H 10811' 1 \ 1 TOP OF 7" LNR I.., 10887' 1 9-5/8"CSG,47#,L-80,ID=8.681" I.., 11152' 7" LNR, 26#, L-80, 0.0383 bpf, ID = 6.276" I.., 12250' ÆRFORA TION SUMMARY REF LOG: BHCS 02/04/87 ANGLEATTOPÆRF: 67 @ 11990' Note: Refer to A"oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-7/8" 6 11990 - 12000 isolated proposed 2-7/8" 6 12115 - 12130 isolated proposed 2-7/8" 6 12238 - 12288 isolated proposed 2-3/4" 4 12630 - 12720 isolated proposed 2-3/4" 4 12780 -12870 isolated proposed 2-3/4" 4 12930 - 13090 isolated proposed 2-3/4" 4 13150 - 13200 isolated proposed 2-3/4" 4 13410 - 13510 STRADLE proposed 2-3/4" 4 13650 - 13850 isolated proposed 2-3/4" 4 13920 -14040 isolated proposed ~ / 'Z I I ~ // -~.-~, 2200' I.., 4-1 /2" HES HXO SSSV NIP, ID = 3.813" I ~ ST MD lVD 3 3766 3215 2 7408 5733 1 10713 8001 GAS LIFT MANDRELS DEV TYPE VLV LATCH 35 MERLA GL V RA 42 MERLA SO RA 36 MERLA DV RA PORT DA TE 08/15/96 08/15/96 08/15/96 1 10743' 1"'4-1/2" HES X NIP, ID = 3.813" 1 1 10754' 1"'9-5/8" x 4-1/2" TIVV HBBP-T PKR, ID = 3.917" I 1 10778' 1"'4-1/2" HES X NIP, ID = 3.813" 1 1 10798' 1- 4-1/2" HES X HIGH PRESSURE NIP, ID = 3.813" 1 10811' I.., 4-1 /2" WIRalNE ENTRY GUIDE, ID = 4.000" ' MILLOUTWINDOW-11304'-11319' 11500' I..,Top of 3-3/16" liner 11500' I.., Top of Cement 3-3/16" X 2-7/8" cmled & perfed 1m I.., 13500' J ':::::J . 't:::J t:::J c:::::J , 1) .,) , 11775' I.., 3-3/16" X 2-7/8" X-over 1 11675' I.., Mechanical Whipstock w /A<r 1 H 12430' I.., MLAS MJlti-lat access sub 1 8q ~ 13309' H4-1/2" X 2-718" FA PRODUCTION PKR I / i 13575' 1"'4-1/2" X 2-7/8" FA PROD PKR 1 ~ 13585' CTMDH2-7/8" HES ClBP(rrilled out) I ~ PBTD H 14053' I 1 2-7/8" TBG, 6.4#, L-80, 0.00579 bpf, ID = 2.441" H 13575' 1 4-1/2" LNR, 12.6#, L-80 NSCT, 0.0152 bpf, ID = 3.958" H 14140' IT PRUDHOE BAY UNIT W8.L: J-20A PERMIT No: 196-1060 API No: 50-029-21716-01 SEC9, T11N, R13E BP Exploration (Alaska) DATE REV BY COMMENTS . 12/13/01 JLJ/KAK MILLED Cl3P DEPTH ŒlANGE 04/14/02 CWS/tlh ADD PERFS I DATE REV BY COMMENTS 06/28190 LGM ORIGINAL COMA-ETION 08/11/96 SIDETRACK COMA-ETION 04/02/01 Ct-VKAK CORRECTIONS 04/09/01 JDM/KAK ADPERFS 11/01/01 WBfTP SURF LOC CORRECTION BP Amoco WlLLI'ATH DIITAlL8 "..", J.208 '002121"'02 PaN"t W.HP!'thl Tie 0" MDI .l-20A U..3.3t Nordic 1 31.20 7/111... 12100 70.33ft Itle' Ref. D8tum; VA_tIOft ""I" 22.00' =:::'~D ~1t: ~~ 0.00 0.00 REFERENCE INFORMATION Co-ordinate (NlE¡ Reference: Well Centre: J-20, True North V~~¿,IT&g~ ~:;:;:~~: ~r~t~~ó ~~g8N~~~)el Measured Depth Reference: 31 : 20 7}811996 12:00 70.33 Calculation Method: Minimum Curvature MO Inc .. 11881.11 .eo.17 '107.30 2 it.71000 .to.48 tOT.34 3 1t88LOO 4".7' 101.43 4 1f13I.00 43.8. ...,.. I 11eol.00 32.80 ".7' . 1118&00 D.'" 7.10 7 1""12 80.00 7.10 . 12188.12 80.00 348.10 . tlu.t.J2 eo.oo 18.'10 10 1212"''' "."8 U8 tt tacH"'2 ".88 18.70 11 nULU ..... "8"3 fa tlloo.OO 80.14 ".80 8SCT1ON DITA.... TVI) +Hf-8 +KI-W DL8. T'H8 V"c Yar..t "'''S2 -4178.82 1785.87 0.00 0.00 -1707.22 8883.308 -4tI1.07 '782.77 0.72 ..82.02 ..t101.'" ""'41 ........,. ..os.,eo 8.00 315.00 -nOI.12 "27.84 "-'8".11 N12.12 38.00 270.00 -1087.41 5=:5 :5ii iL~;:.1::= c~= :~5:* "20.80 ..aau:.ea "M.'" 12.00 270.00.. .12 ..18.80 -3117.417 ....... 12.00 10.00.. IU "KU -aNI'" 8QCH."8 12.00 281.00 ..11.'" ..3078.18 8..08.S8 12.00 .a.oo 88".74 -2811.30 8101.18 '12.00 210.00 7..88 .....n -288'1". 8382.18 '11000 18.00 .104.84 ANNOTATION. TVD MD A'uloutloa "7...2 11003.38 TIP ..83.34 1117..00 KOI' 10"A1 110...00 1 8727... 11731.00 2 .783..0 1100'.00 2 .831... 1180'.00 . ..20..0 12_.32 0 0021..0 12100.32 0 0021..0 12128.32 7 002"'3 12728.32 0 .083.10 13018.32 I .0.0.7. 131...32 10 '''0.72 13100.00 TO +E1.:w Shape 9000 8350-' 8400-= 8450 - 850o-j .... C , ~ 8550-~ II) 8600 -'1 - ~ i 8650 J Do ' G) 8700-3 a .. ¡ 8750 i 8800 > 8850- G) - ! 8900 8950 - 9050 9100 Otm -ZbUlr- IN't6Q ""-3100 ~ -,)¿UlF ~T=:T C ~~. ... -330o-::r:::~ "..... _c.-.:.-. -:.' u. +_'M~ - r 1: -,):Juu 0 ~ -3600- - . - i -3700- -,)::IUlF en -,)OUlF ......-.... JU - 4Z00-3: 1300-} 4700 4800 4900 52'00 LEGEND - ~:~g ¡j:~gl) - Q-06A (Q-06A) - Q-06 (Q-06) - -- Plan#5 J-20B - Plan #5 T ^M é .. Azimuths to True North Magnetic North: 26.06" Magnetic Field Strength: 57525nT Dip Angle: 80.81" Date: 8/1312002 Model: BGGM2002 -- Plan: Plan #5 (J-20/Plan#5 J-20B) Created By: Brij Potnis Date: 8/13/2002 Contact Information: Direct: (907) 267-6613 E-mail: brij.potnis@inteq.com Baker Hughes INTEQ: (907) 267-6600 1"'iJU - -- ---+-~ ...... Vertical Section at 22.000 [50ft/in] 5400 5500 5600 5700 5800 West(-)/East( +) [100ftlin] , \\ --- . . i .... . ::t=:::::-:: - ~+. ,-- '.n ,- ,.. ---- ,.,.... --- ! ¡ , in ,.- -I ... n.- -., 'n f,. - i.. I - . , '; . "" ,::::. . . \~ ~_. "-;tV I, ',-;tV"!! : ! . . . '" -, .n..'.F '=-....-:~! - """ --- .. 'u....... - ,. - - '-- f- ~,-- \ .~- - , -. -li}-- . liJ < \ -~ -.::0 '~M' , ! . ~] ÌJQJ . . ... .... --, ' i '\ ! ,'-. n'. f- . ... ...,. ... . .m. ...- .- nn'- .... .,.n.' \, . ... '...¡ , .. .'.. ~' , '.nnn ...,..C..-=::. . . -8)0 -7)0 . -350 '-31)0 -2)0 ' -1 jQ i. 4501400 ,3GO ,^^ A^~n An"" A A en A. nn . nen ,n -550 -450 ~,~ j =r-y-rrri"""c- n ~=-~--";=:'~~- +=;--=- 6700 6800 6900 7000 7100 7200 8/13/2002 3:511 PM ~' ~' Co~pa~y: Fi~b:l: $lte: WeJf~ - W~lPath: Field: Site: J-20 J-20 Well Position: Well: BP Baker Hughes INTEQ Planning Report ') ') . J$;tßQ- 1b\~:>;;811312002, ' - TilD~:<:15:54:46 - Ç~fO~d¡n~~~~)Jl~~#~çe~ " Y¥~IJ;O~20,LTr4~~~rth- :V~(TVD)Rereren~: System;"MesnSeaLevël- . ~~ti911(VS) Reference: Well (0.OON,O.00E,22.00Azi) . SJjryeyç~lcul!i~onMe~Ø: :Min~J'{IuJ'{lÇ~ryatlJr~ Db: Map Zone: Coordinate System: Geomagnetic Model: 5968224.22 ft 641155.79 ft Latitude: Longitude: North Reference: Grid Convergence: BPArriôcQ f?Ï"9dlJ()~~ay PB,JPad J'"20 ", . Plan#5J;.20B Prudhoe Bay North Slope UNITED STATES 'I Map System:US State Plane Coordinate System 1927 Goo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level PB J Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Slot Name: +N/-S 1869.74 ft Northing: 5970139.36 ft +E/-W 2439.59 ft Easting: 643559.60 ft Position Uncertainty: 0.00 ft Latitude: Longitude: Wellpath: Plan#5 J-20B 500292171602 Current Datum: 31 : 207/8/1996 12:00 Magnetic Data: 8/13/2002 Field Strength: 57525 nT Vertical Section: Depth From (TVD) ft 0.00 Targets Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 Height 70.33 ft +N/-S ft 0.00 Annotation l\1D ft 11663.39 11675.00 11695.00 11735.00 11805.00 11865.00 12049.32 12199.32 12524.32 12724.32 13019.32 13189.32 13500.00 P;1g~; .. I Oracle Alaska, Zone 4 Well Centre BGGM2002 70 19 14.845 N 148 51 20.092 W True 1.08 deg 20 70 19 33.230 N 148 50 8.881 W J-20A 11663.39 ft Mean Sea Level 26.06 deg 80.81 deg Direction deg 22.00 :l\t:a,p. <:~Låtitu4e:.~ ~...J,..9ngit04e:.~. ~~tijag - J)e,gl\finS~ . J)egl\fin,~ee TVD ft 8674.52 8683.34 8698.41 8727.94 8783.60 8836.55 8929.80 8929.80 8929.80 8934.83 8953.16 8959.74 8959.73 TIP KOP 1 2 3 4 5 6 7 8 9 10 TD I Plan: Plan #5 I' Identical to Plan #5 from Thomas Principal: Yes Date Composed: Version: Tied-to: Plan Section Information MD ft ; 11663.39 i 11675.00 i 11695.00 : 11735.00 Ind d~ 40.57 40.49 41.78 43.65 8/13/2002 3 From: Definitive Path Azim dfð9 107.30 107.34 105.43 84.91 bp çolJip~D.Y: BP\A.moco Field: Pr~dhpøBay . Sitê: PBJ: Pad w~n: J,.2Q . . . wellpath: Plån#5J,;20B Plan Section Information MD ft 11805.00 11865.00 12049.32 12199.32 12524.32 12724.32 13019.32 13189.32 13500.00 lild- deg 32.60 25.49 90.00 90.00 90.00 87.16 85.95 89.66 90.34 Survey MD ft 11663.39 11675.00 11695.00 11700.00 11725.00 11)(;1 d~g 40.57 40.49 41.78 41.81 42.84 11735.00 43.65 11750.00 40.44 11775.00 35.96 11800.00 32.98 11805.00 32.60 11825.00 28.88 11850.00 26.00 11865.00 25.49 11875.00 28.99 11900.00 37.74 11925.00 46.49 11950.00 55.24 11975.00 63.99 12000.00 72.74 12025.00 81.49 ) ") BP Baker Hughes INTEQ Planning Report m'tlo . Dåte:';.áf1312OP2 . . 'Tbn~:t5;54:4ô . ':p:~~: .èQ;.or; ~)R~~: .. .\Mêlt:'J;;2P.JTllêNQrth . . .,y~ )'R~~~" $Y§t~i'n::M@.ë~:~VØ! . ... ~jq":N~)'Rêcf~Ø.,.çe:-' . .' .w~"'(Q~.QC>N,i(16QE:í22;QO~O 'SuiveYJ~~lcJlI~tiQ.Í\{etþ9~;. . Mioirnüm.CÙ:rvatÜfe' " Db: ,Oracle Aiim ~~9 48.79 7.10 7.10 349.10 28.10 4.26 39.70 19.63 56.90 +N/~S )t -4172.32 -4148.59 -4001.95 -3852.65 -3537.47 -3346.86 -3078.15 -2931.30 -2691.64 ',TFØ ~E!9 , 230.00 233.00 0.00 270.00 90.00 263.00 93.00 280.00 89.00 . +E/,;,W.. , It- 5870.97 5884.88 5903.14 5898.18 5945.84 6001.16 6109.55 6193.15 6382.18 DLS'JmiJd .. Turn. . ~egl1(lPft'qegl~0Qft:dew1'0Qft . 35.00 -15.78 -51.61 35.00 -11.86 -69.48 35.00 35.00 0.00 12.00 0.00 -12.00 12.00 0.00 12.00 12.00 -1.42 -11.92 12.00 -0.41 12.02 12.00 2.19 -11.81 12.00 0.22 12.00 TVD ft, 8783.60 8836.55 8929.80 8929.80 8929.80 8934.83 8953.16 8959.74 8959.73 'I'.,g~t ' AZÛIl deg 107.30 107.34 105.43 102.80 89.88 ÐLS' . ,qågttQott 0.00 0.72 9.00 35.00 35.00 TOO' qßQ, 0.00 TIP 162.02 KOP 315.00 1 270.00 MWD 271.96 MWD . SSTVD ft 8674.52 8683.34 8698.41 8702.14 8720.65 -4178.82 5785.57 5966072.31 649423.61 -1707.22 -4181.07 5792.77 5966070.20 649430.85 -1706.61 -4184.78 5805.40 5966066.73 649443.54 -1705.32 -4185.59 5808.63 5966065.98 649446.79 -1704.86 -4187.42 5825.29 5966064.47 649463.48 -1700.32 84.91 8727.94 -4187.11 5832.12 5966064.91 649470.31 -1697.47 ...15.00 281.53 2 78.71 8739.08 -4185.70 5842.065966066.51 649480.21 -1692.44 /35.00 230.00 MWD 66.52 8758.75 -4181.18 5856.77 5966071.31 649494.83 -1682.74 35.00 234.61 MWD 51.94 8779.40 -4174.04 5868.88 5966078.68 649506.81 -1671.58 35.00 244.21 MWD 48.79 8783.60 -4172.32 5870.97 5966080.44 649508.86 -1669.20 35.00 256.25 3 37.16 8800.80 -4164.91 5877.95 5966087.98 649515.70 -1659.72 35.00 233.00 MWD 19.15 8823.03 -4154.90 5883.40 5966098.09 649520.96 -1648.40 35.00 243.01 MWD 7.10 8836.55 -4148.59 5884.88 5966104.43 649522.31 -1641.99 35.00 259.03 4 7.10 8845.44 -4144.05 5885.45 5966108.98 649522.79 -1637.57 35.00 0.00 MWD 7.10 8866.30 -4130.42 5887.14 5966122.64 649524.23 -1624.29 35.00 360.00 MWD 7.10 8884.82 -4113.80 5889.21 5966139.30 649525.98 -1608.11 35.00 0.00 MWD 7.10 8900.59 -4094.57 5891.61 5966158.56 649528.01 -1589.39 35.00 360.00 MWD 7.10 8913.22 -4073.19 5894.27 5966179.99 649530.26 -1568.57 35.00 360.00 MWD 7.10 8922.43 -4050.16 5897.14 5966203.07 649532.68 -1546.13 35.00 0.00 MWD 7.10 8928.00 -4026.00 5900.15 5966227.29649535.23 -1522.60 35.00 360.00 MWD 12049.32 90.00 7.10 8929.80 -4001.95 5903.14 5966251.38 649537.76 -1499.19 35.00 0.00 5 12050.00 90.00 7.02 8929.80 -4001.28 5903.22 5966252.06 649537.83 -1498.53 12.02 270.00 MWD 12075.00 90.00 4.02 8929.80 -3976.39 5905.63 5966276.98 649539.76 -1474.56 12.00 270.00 MWD 12100.00 90.00 1.02 8929.80 -3951.42 5906.72 5966301.97 649540.38 -1451.00 12.00 270.00 MWD 12125.00 90.00 358.02 8929.80 -3926.43 5906.51 5966326.95 649539.69 -1427.90 12.00 270.00 MWD 12150.00 90.00 355.02 8929.80 -3901.47 5904.99 5966351.87 649537.69 -1405.33 12.00 270.00 MWD 12175.00 90.00 352.02 8929.80 -3876.64 5902.17 5966376.64 649534.40 -1383.36 12.00 270.00 MWD 12199.32 90.00 349.10 8929.80 -3852.65 5898.18 5966400.55 649529.95 -1362.62 12.00 270.00 6 12200.00 90.00 349.18 8929.80 -3851.98 5898.05 5966401.21 649529.81 -1362.05 12.02 90.00 MWD 12225.00 90.00 352.18 8929.80 -3827.31 5894.01 5966425.80 649525.29 -1340.69 12.00 90.00 MWD 12250.00 90.00 355.18 8929.80 -3802.47 5891.25 5966450.58 649522.06 -1318.69 12.00 12275.00 90.00 358.18 8929.80 -3777.51 5889.81 5966475.51 649520.14 -1296.09 12.00 12300.00 90.00 1.18 8929.80 -3752.52 5889.67 5966500.49 649519.52 -1272.97 12.00 12325.00 90.00 4.18 8929.80 -3727.55 5890.83 5966525.48 649520.21 -1249.38 12.00 12350.00 90.00 7.18 8929.80 -3702.67 5893.31 5966550.39 649522.21 -1225.39 12.00 12375.00 90.00 12400.00 90.00 12425.00 90.00 12450.00 90.00 12475.00 90.00 12500.00 90.00 10.18 8929.80 -3677.96 5897.08 5966575.17 649525.51 -1201.06 12.00 13.18 8929.80 -3653.48 5902.14 5966599.74 649530.10 -1176.47 12.00 16.18 8929.80 -3629.30 5908.48 5966624.04 649535.97 -1151.68 12.00 19.18 8929.80 -3605.48 5916.07 5966647.99 649543.10 -1126.75 12.00 22.18 8929.80 -3582.10 5924.90 5966671.54 649551.48 -1101.76 12.00 25.18 8929.80 -3559.21 5934.93 5966694.62 649561.08 -1076.77 12.00 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD ") BP ) .-: !þp Baker Hughes INTEQ Planning Report IN'TEQ <:;o~pa..y: BPA,moCó - -:J)åiet ;ß/13120Q2 T~~~...'.1S:54~4~ r~gè:- 3 Flêld; Pn-rclhÇleB~Y - - ç~~4"~~t~':I~~~~~: -W~Jl;'+~,:.rru~NQrth Site: PBJPad X~~~;9(';tv¡~):~~~~~; . -~~;~~~p1:\~~~1~~;4~VEl!.,. Wen: J~20 . ~~..(VS)~~f~~n~: . . ..VVf:}tt{?~99N~9fQ.O~,2-2~OPA?i) Wtllpath; Plán#5J;.20B . S~rveyPálc:uh¡t¡91lM:~~4:. MinimumCurvatufEl -Db: Oracfe Survey MD Incl AziJn . SSYVD 1\1..1,11£ VS DLS- - TFO Tool ft d~ d~ ft oft ft <i~gIJOOft. cI~ 12524.32 90.00 28.10 8929.80 -3537.47 5945.84 5966716.56 649571.56 -1052.53 12.00 90.00 7 12525.00 89.99 28.02 8929.80 -3536.87 5946.16 5966717.16 649571.87 -1051.86 12.02 263.00 MWD 12550.00 89.62 25.04 8929.89 -3514.50 5957.32 5966739.74 649582.61 -1026.94 12.00 263.00 MWD 12575.00 89.26 22.06 8930.13 -3491.59 5967.31 5966762.84 649592.15 -1001.95 12.00 263.01 MWD 12600.00 88.90 19.08 8930.53 -3468.19 5976.09 5966786.40 649600.48 -976.97 12.00 263.04 MWD 12625.00 88.54 16.10 8931.09 -3444.37 5983.65 5966810.36 649607.58 -952.05 12.00 263.09 MWD 12650.00 88.18 13.12 8931.81 -3420.19 5989.95 5966834.65 649613.42 -927.27 12.00 263.15 MWD 12675.00 87.83 10.14 8932.68 -3395.72 5994.99 5966859.21 649617.99 -902.70 12.00 263.24 MWD 12700.00 87.49 7.16 8933.70 -3371.03 5998.74 5966883.97 649621.27 -878.39 12.00 263.34 MWD 12724.32 87.16 4.26 8934.83 -3346.86 6001.16 5966908.18 649623.23 -855.08 12.00 263.46 8 12725.00 87.15 4.34 8934.87 -3346.18 6001.21 5966908.86 649623.26 -854.43 12.02 93.00 MWD 12750.00 87.00 7.34 8936.14 -3321.35 6003.75 5966933.73 649625.33 -830.45 12.00 93.00 MWD 12775.00 86.86 10.34 8937.48 -3296.68 6007.59 5966958.47 649628.69 -806.15 12.00 92.84 MWD 12800.00 86.72 13.34 8938.88 -3272.25 6012.71 5966982.98 649633.34 -781.58 12.00 92.68 MWD 12825.00 86.59 16.34 8940.34 -3248.13 6019.10 5967007.22 649639.27 -756.82 12.00 92.51 MWD 12850.00 86.48 19.35 8941.85 -3224.38 6026.75 5967031.11 649646.46 -731.94 12.00 92.34 MWD 12875.00 86.37 22.35 8943.41 -3201.07 6035.62 5967054.59 649654.89 -706.99 12.00 92.16 MWD 12900.00 86.27 25.36 8945.02 -3178.25 6045.71 5967077.59 649664.54 -682.06 12.00 91.97 MWD 12925.00 86.18 28.36 8946.66 -3156.00 6056.98 5967100.06 649675.38 -657.21 12.00 91.78 MWD 12950.00 86.10 31.37 8948.35 -3134.37 6069.40 5967121.92 649687.38 -632.50 12.00 91.58 MWD 12975.00 86.04 34.37 8950.06 -3113.42 6082.93 5967143.12 649700.51 -608.01 12.00 91.38 MWD 13000.00 85.98 37.38 8951.80 -3093.22 6097.55 5967163.60 649714.74 -583.80 12.00 91.17 MWD 13019.32 85.95 39.70 8953.16 -3078.15 6109.55 5967178.89 649726.45 -565.33 12.00 90.96 9 13025.00 86.07 39.03 8953.55 -3073.77 6113.15 5967183.34 649729.96 -559.92 12.00 280.00 MWD 13050.00 86.59 36.07 8955.16 -3053.99 6128.35 5967203.41 649744.78 -535.89 12.00 280.05 MWD 13075.00 87.13 33.11 8956.52 -3033.44 6142.52 5967224.22 649758.56 -511.53 12.00 280.24 MWD 13100.00 87.68 30.16 8957.66 -3012.18 6155.62 5967245.73 649771.24 -486.91 12.00 280.40 MWD 13125.00 88.23 27.21 8958.55 -2990.27 6167.61 5967267.86 649782.81 -462.10 12.00 280.53 MWD 13150.00 88.78 24.26 8959.20 -2967.76 6178.46 5967290.58 649793.23 -437.16 12.00 280.64 MWD 13175.00 89.34 21.31 8959.61 -2944.71 6188.14 5967313.80 649802.47 -412.17 12.00 280.71 MWD 13189.32 89.66 19.63 8959.74 -2931.30 6193.15 5967327.30 649807.22 -397.86 12.00 280.76 10 13200.00 89.69 20.91 8959.80 -2921.28 6196.85 5967337.39 649810.72 -387.18 12.00 89.00 MWD 13225.00 89.74 23.91 8959.92 -2898.17 6206.38 5967360.68 649819.81 -362.19 12.00 88.99 MWD 13250.00 89.79 26.91 8960.02 -2875.59 6217.10 5967383.46 649830.10 -337.23 12.00 88.98 MWD 13275.00 89.85 29.91 8960.10 -2853.60 6229.00 5967405.66 649841.57 -312.39 12.00 88.97 MWD 13300.00 89.90 32.91 8960.16 -2832.27 6242.02 5967427.24 649854.18 -287.73 12.00 88.96 MWD 13325.00 89.96 35.91 8960.19 -2811.64 6256.15 5967448.13 649867.91 -263.32 12.00 88.95 MWD 13350.00 90.01 38.90 8960.19 -2791.79 6271.33 5967468.27 649882.71 -239.22 12.00 88.95 MWD 13375.00 90.07 41.90 8960.18 -2772.75 6287.53 5967487.61 649898.54 -215.50 12.00 88.94 MWD 13400.00 90.12 44.90 8960.14 -2754.59 6304.71 5967506.10 649915.37 -192.23 12.00 88.95 MWD 13425.00 90.18 47.90 8960.07 -2737.35 6322.81 5967523.68 649933.14 -169.46 12.00 88.95 MWD 13450.00 90.23 50.90 8959.98 -2721.09 6341.79 5967540.30 649951.80 -147.27 12.00 88.96 MWD 13475.00 90.29 53.90 8959.87 -2705.84 6361.60 5967555.93 649971.31 -125.71 12.00 88.97 MWD 13500.00 90.34 56.90 8959.73 -2691.64 6382.18 5967570.51 649991.61 -104.84 12.00 88.98 TD H 207033 DATE 8/01/02 INVOICE f CREDIT MEMO CK073102 THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. P.O. BOX 196612 ANCHORAGE, ALASKA 99519-6612 PAY TO THE ORDER OF DESCRIPTION Perrnitto Drill Fee GROSS -:r:-~oß PIs contact So~dra Stewman X4750 for check pick.lp TOTAL ~ DATE CHECK NO. 8/01/02 H207033 VENDOR DISCOUNT NET H $100.00 $100.00 No,.,H207033 I=IRST NATIONAL BANK OF ASHLAND ANAFFIUAtt OF NATIONAL CITY BANK CLEVELAND, OHIO fj..........'.... ...f?'..... i,....,...",..:....,...,............:..r:'. :.':1"'".,..:1""...,.."'..,... (""'1. .."W. t¡ .¡". '. 'J'J~......... .".,1, ... . ... ,;;:W-f - ,..>:.:: . - - - -l --f. ,,!fur-.. - '''''-''('. . ... . ....~...... fll' 'Uti ,'u'" .,..... 'Un 56-389 "412 CONSOLIDATED COMMERCIAL ACCOUNT ()ATE **"Aug~d1, . 2002*~jr Alaska Oil & GasCqnServat:iþn . 333 W 7th Ave, Ste 100 Anchorage, AI< '99501 III 2010 3 3111 1:0... ~ 2038 q 51: 008...... ~ qll8 NQ1':VALlD AFTER 12(1 DAYS' ¡~;:::0L.:::I!¡¡~~~!5Iî '-."P '-' Rev: 07/10/02 C\j ody\templates , :) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELLNAME/ßa V-2ðß PTD# ::2c>z. - J 7ð CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (If API number last two (2) digits are between 60-69) PILOT (PH) HOLE SPACING EXCEPTION DRY DITCH SAMPLE "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function. of the original API number stated above. In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and. API number (50 70/80) from records, data and logs acquired for well (name on permit). The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY Ny WELL NAME f>~à ¡:"2.ö,-~ PROGRAM: Exp - Dev';z£ Redrll L Re-Enter - Serv - Wellbore seg- FIELD & POOL h )16) . )"" ð INIT CLASS LJ.(V¿,/) .... 1::)1 tJ GEOL AREA f?7 r'"i UNIT# // .c. (0 ON/OFF SHORE ~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . fr~ N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N APPR DATE 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N ,. ;J2,) ~~'? 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N f)í~ ()..fþ £/ L- 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . \XJ N (Service Well Only) 13. Well located w/in area & strata authorized by injection order#- Y / /u.. ¡C) \ (Service Well Only) 14. All wells wlin X mile area of review identified. . . . . . . . .. ~ N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . tVN 16. Surface casing protects all known USDWs. . . . . . . . . . . @ N 17. CMT vol adequate to circulate on conductor & surf csg. . . . . ¥-N-N/k 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . .¥-N- 19. CMT will cover all known productive horizons. . . . . . . . . . gp N 20. Casing designs adequate for C: T, B & permafrost. . . . . . . &2... N -Ì\ II 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . (¿ N Q ~ V\.. ' 22. If a re-drill, has a 10-403 for abandonment been approved. .. '/; 'h. N 23. Adequate wellbore separation proposed.. . . . . . . . . . . . ~. N 24. If diverter required, does it meet regulations. . . . . . . . . . y-.. N NIl\- 25. Drilling fluid program schematic & equip list adequate. . . . . (;¡¿¡ N ¡11/LK 111. /tJ ~,7 ¡J pc¡ 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N ') i 27. BOPE press rating appropriate; test to 3500 psig. N m ~ I 1.1 '55 P ~ it ' 1 I 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N \JJf:A- ~ J ~ () L 29. Work will occur without operation shutdown. . . . . . . . . . . N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y l1?- 31. Mechanical condition of wells within AOR verified. . . . . . . . -¥-N- All It- 32. Permit can be issued wlo hydrogen sulfide measures. . . . . Y @ 33. Data presented on potential overpressure zones. . . . . . . . ßy N ¿ J /J 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . Y / v oj ,...-.t \ 35. Seabed condition survey (if off-shore). . . . . . . . . . . . . . N 36. Contact name/phone for weekly progress reports. . . . . . . . Y N GEO~)Y: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER Rpff~~ TEM JDH f JBR APPR DATE (Service Well Only) GEOLOGY ÄPPR DATE ~ ~jd?~ , (É~ploratory °nTY) SFD WGA )tJ t; f!r MJW Rev: 07/12/02 G:\geology\perm its\checklist.doc COMMISSIONER: COT DTS oy ¡>~.o 2--. ) ) Commentsllnstructions:
