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205-082
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. 02 ~S - ~,g~, Well History File Identifier Organizing (done) ^ Two-sided III II'lII II III II III ^ Rescan Needed III (I'lll II II III III RESCAN DIGITAL DATA OVERSIZED (Scannable) [~'C for Items: Diskettes, No.~, ^ Maps: v Greyscale Items: ~ ~~~ ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ /s/ Protect Proofing III IIIIIIIIIII II III BY: Maria Date:' I ~ Ol ~0 /sf Scanning Preparation ~ x 30 = 3Q + ~_ =TOTAL PAGES__c~ 3 © lJ ~ (Count does not include cover sheet) BY: Maria Date: /s/ T Production Scanning III IIII1111111 IIIII Stage 1 Page Count from Scanned File: __G~ (Count does include ever sheet) Page Count Matches Number in Scanning Preparation: ~/ YES NO BY: Maria Date: ~ /3 ~ ~ ~ g /s/ i/~ ~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO ~ 6 BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. III II'I II I II II IIIII ReScanned III IIIIIIIIIII IIIII BY: Maria ___ Date: /s/ Comments about this file: Quality Checked 1.0/6/2005 Well History File Cover Page.doc . �: • f:.: `� • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: ❑ Oil ❑ Gas ❑ SPLUG ❑ Other ® Abandoned ❑ Suspended 1b. Well Class . 20AAC 25105 20AAC 25 110 ❑ Exploratory ❑ Stratigraphic ❑ GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ Other No. of Completions Zero ' • 4 Development ❑ Service 2. Operator Name: 5. Date Comp., Susp., or Aband.: 12. Permit to Drill Number: BP Exploration (Alaska) Inc. 3/14/2013 r 205 - 082 ' 313 - 046 3. Address: 6. Date Spudded: 13. API Number: P.O. Box 196612, Anchorage, Alaska 99519 - 6612 9/28/2005 50 029 - 20969 - 03 - 00 4a. Location of Well (Governmental Section): 7. Date T.D. Reached: 14. Well Name and Number: Surface: 10/6/2005 PBU J -17C • 801' FNL, 1806' FEL, Sec. 09, T11 N, R13E, UM . 8. KB (ft above MSL): 69 .8' 15. Field / Pool(s) Top of Productive Horizon: Prudhoe Bay Field / Ba 1775' FNL, 3407' FWL, Sec. 10, T11 N, R13E, UM GL (ft above MSL): 39.78' Y Bay Total Depth: 9. Plug Back Depth (MD +TVD) Oil Pool , 2204' FNL, 4573' FWL, Sec. 10, T11 N, R13E, UM 11735' 9032' 4b. Location of Well (State Base Plane Coordinates, NAD ; 10. Total Depth (MD +TVD) 16. Property Designation: Surface: x- 642547 • y- 5970534' Zone- ASP4 •12387' 9023' • ADL 028281 • TPI: x- 647779 y- 5969661 Zone- ASP4 11. SSSV Depth (MD +TVD) 17. Land Use Permit: Total Depth: x- 648955 y - 5969255 Zone- ASP4 None 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 logs here and submit electronic and printed information per 20 AAC 25.071): 22. Re -Drill /Lateral Top Window MD/TVD: DIR / GR / RES, DIR / GR / RES / NEU / ABI 8931' 7551' 23. CASING, LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT CASING WT. PER FT. GRADE To BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surface 110' Surface 110' 36" 8 cu vds Concrete 13 -3/8" 72# L -80 Surface 2685' Surface 2685' 17 -1/2" 3856 cu ft Arcticset III & II 9 -5/8" 47# L -80 Surface 8931' Surface 7551' 12 -1/4" 2360 cu ft Class 'G', 132 cu ft Permafrost 7" 26# L -80 8774' _ 10234' 7429' 8435' 8 -1/2" 348 cu ft Class 'G' 4 -1/2" 12.6# L -80 10067' 12387' 8326' 9023' 6 -1/8" 337 cu ft Class 'G' 24. Open to production or injection? ❑ Yes ® No 25. TUBING RECORD If Yes, list each interval open S D SET (MD +TVD of Top & Bottom; Perforation Size and Number): SIZE (MD) PACKER SET ( MD / TVD) 4 - 1/2 ", 12.6#, 13Cr80 10083' 10027' / 8300' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. F` 2 q q WAS HYDRAULIC FRACTURING USED DURING COMPLETION ?❑ Yes ® No SCANN APR 2 ZO 3 3 DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED �"� 11735' Set Whipstock - 10979' 24.5 Bbls Class 'G' 10971' 4 -1/2" KB Liner Top Packer 27. PRODUCTION TEST Date First Production Method of Operation (Flowing, Gas Lift, etc Not on Production N/A Date of Test Hours Tested Production For OIL -BBL: GAS -MCF: WATER -BBL: CHOKE SIZE: GAS -OIL RATIO: Test Period Flow Tubing Casing Press: Calculated OIL -BBL: GAS -MCF: WATER -BBL: OIL GRAVITY -API (CORR): Press. 24 -Hour Rate 28. CORE DATA Conventional Core(s) Acquired? ❑ Yes IS 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 lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None FI BDMS APR 1 01p13 Form 10-407 Revised 10/2012 CONTINUED ON REVERSE r e., Y.l 7 . s/3 bynit Original Only r i 3 V--13 29. GEOLOGIC MARKERS (List all formations allirkers encounter 30. • FORMATION TESTS NAME MD TVD Well Tested? ❑ Yes ® 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. Sag River 10232' 8434' None Shublik 10289' 8471' Sadlerochit 10419' 8556' CGL / Zone 3 10693' 8735' Base of CGL / Zone 2 10805' 8811' 25N 10893' 8870' 23N 10987' 8922' 22N 11034' 8944' 21N 11116' 8977' Formation at Total Depth: 31. List of Attachment: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Well Schematic Diagram 32. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Trevor Hyatt, 564-4627 Email: Trevor.Hyatt @bp.com Title: Drilling Technologist Printed Name: . - tufk 4/q I 1 • Signature: Phone 564 -4091 Date: 1 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10 -404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection, Water Injection, Water - Alternating -Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI (Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits (ex: 50- 029 - 20123- 00 -00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and 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 10/2012 Submit Original Only • • J e -17C Well History (Pre Rig Sidetrack) Date Summary 03/05/13 CTU #8 w/ 1.75" CT (CTV= 31.8). Objective -Mill XN and run dummy WS drift for CTD. Finish RIH w/ LH milling assy and mill out XN nipple to 3.80" taking returns to formation 2.3/750. Continue reaming in hole to remove any possible production deposits to 11830' CTM. Backream OOH thru XN. POH. LD milling BHA. Mill gauged 3.80" Go, 3.79" No Go. MU and RIH w/ dummy WS drift. Drifted to 11,830' and POOH. Pumped 60/40 FP. Blow down reel w/ N2 for pipe swap. RDMO. 03/09/13 T /I /O= 70/0/0 Conducted PJSM Barriers = SV & SSV Start barriers list. Verified LTT by bleeding tubing off SV & SSV independently ( PASS ). RU CIW Lubricator W /4" H TWC #258. PT Lubricator aginst SV 300 PSI low and 3500 PSI high for 5 min Both ( PASS) Set TWC # 258 tagging at 128" Torqued all flanges to API specs 726 FT /LBS No Movement. RU CIW Lubricator and installed Pulling Tool. PT Lubricator aginst SV 300 PSI low and 3500 PSI high for 5 min Both ( PASS) Pulled TWC # 258 RD lubricator and installed Tree cap. RDMO. 03/11/13 T /I /0= 5/27/0 Temp =SI (Obj: Pre RWO) Load and Kill Tbg. Spear in Tbg with 5 bbls of meth followed by 265 bbls of 140*f 1% KCL to kill then 3 bbl meth spacer followed by 40 bbls of 0 *f diesel to FP Tbg Bleed tbg, IA, & OA pressures dwon to 0 psi. FWHP= 0 /0 /0. Swab, SSV, & wing closed. Master, IA, & OA open. 03/11/13 T /I /0= Vac/0 /0; Conduct PJSM; Start barriers list, barriers = SSV & SV, verified by independently bleeding tubing pressure of each. LTT passed; Remove tree cap and R/U lubricator and TWC; Test lubricator to 300 and 3500 psi for 5 min. LTT passed; Set 4- 1/16" CIW "H" TWC #259 through tree for Nordic 1 24 hr prior move on, 1 -1' ext used, tagged @ 114 "; S/I barriers, R/D lubricator and install tree cap with new 0 -ring; Torque untapped companion flange to API specs using 32 -023 truck and equipment, calibrated 3 -11 -2013. (NO MOVEMENT) Open valves and shell test tree to 300 and 5000 psi for 5 min. LTT passed and charted; bleed to 0 psi and drain 2 -3 gallons of diesel out of wing needle valve to drop fluid column; S/I SSV, WV and SV, close needle valves and ensure caps are replaced; Notify operator of departure. 03/12/13 T /I /0= TWC /0 /0 Conduct PJSM. Pressure test from TWC to bottom of swab through wing valve to low pressure of200 -300 psi for 5 mins; Passed. Test to high pressure of 3000 psi for 5 mins; Passed. Closed wing and pressure tested TWC through tree cap to low pressure of 200 -300 psi for 5 mins. Passed. Conducted high pressure test to 3500 psi for 5 mins; Passed. All tests charted and downloaded into field charted tests in TRP folder. All tree valves closed upon departure. Page 1 of 1 i • 151 -':';::Tete:iaiWtafwhikk'etiomCitititti.y,viecAftAiklgti;iz:a=t;d..LLzoAti-4:.r..:Q:K-gittotg,,p Common Well Name: J -17 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 3/11/2013 I End Date: 3/19/2013 X3- 0135K- C:DRILL (2,121,298.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °19'37.030 "0 Long: 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/11/2013 22:00 - 00:00 2.00 MOB P PRE PJSM FOR PULLING RIG OFF WELL. TOOL PUSHER AND WSL AND NORDIC FIELD SUPERINTENDANT PRESENT. JACK UP RIG. PULL OFF WELL. REMOVE T MATS FROM AROUND WELL. STAGE RIG AT ENTRANCE OF K PAD. CLOSE OUT WELL WORK TRANSFER PERMIT FOR K -06C WITH DSO. 3/12/2013 00:00 - 00:30 0.50 MOB P PRE STAGE RIG AT ENTRANCE OF K PAD. TOOL SERVICE SETTING MATS ON FLOWLINE AT PAD ENTRANCE. 00:30 - 01:00 0.50 MOB P PRE PJSM FOR RIG MOVE TO J -PAD. IN ATTENDANCE WSL, TOOL PUSHER, NORDIC FIELD SUPERINTENDANT, TOOL SERVICE, SECURITY, RIG CREWAND SLD. 01:00 - 06:30 5.50 MOB P PRE MOVE FROM K -PAD TO J -PAD. OPEN WELL WORK TRANSFER PERMIT FOR J -17D WITH DSO. 06:30 - 07:00 0.50 MOB _ P PRE RIG ON J -PAD AND CREWS ARE CHANGING OUT 07:00 - 07:20 0.33 MOB P PRE HOLD PJSM WITH CREWS & DSO TO SPOT RIG OVER WELL 07:20 - 08:00 0.67 MOB P PRE 1 SPOT RIG OVER WELL 08:00 - 11:00 3.00 RIGU P PRE RIG SPOTTED AND ACCEPTED "ACCEPT RIG AT 0800 -HRS" 11:00 - 13:00 2.00 BOPSUR P PRE !BOP'S ARE NU, GREASE MUD CROSS VALVES _ THEN PREP TO FILL STACK FOR SHELL TEST 13:00 - 13:30 0.50 BOPSUR P PRE 1 PJSM FOR FUNCTIONING AND TESTING BOPE. FUNCTION TEST ALL BOPE COMPONENTS EACH FROM RIG FLOOR REMOTE, OPSCAB REMOTE AND AT ACCUMULATOR. 13:30 - 14:00 0.50 BOPSUR P PRE FILL STACK WITH FRESH WATER. FLUID PACK CHOKE MANIFOLD AND LINES. R/U SENSOR ON WING VALVE TO MONITOR PRESSURE IN VOID BETWEEN SWAB AND MASTER. Printed 4/2/2013 7:29:28AM • • - r ijaistafANNifitit,44,10.1_,44.-' 4 WAUVVAVOLVIOrf k• OWA; 1 . Common Well Name: J -17 AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 3/11/2013 End Date: 3/19/2013 X3- 0135K- C:DRILL (2,121,298.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °19'37.030"0 Long: 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) Date I From - To Hrs Task Code I NPT 1 NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 22:00 8.00 BOPSUR P PRE PERFORM INITIAL BOPE TEST USING 2 3/8" TEST JOINT. AOGCC REP BOB NOBLE WAIVED WITNESS FOR BOP TEST ON 03/12/2013 8:11 AM. TEST BOP RAMS TO 250 / 3500 PSI 5 MIN EA. TEST CHOKE MANIFOLD, MUD CROSS VALVES TO 250 / 3500 PSI 5 MIN EA. 2 WAY CHECK VALVE FAILED, REBUILD AND RE -TEST GOOD. CHOKE MANIFOLD VALVE # 2 FAILED LO Q PRESSURE TEST. ��ll SERVICE VALVE AND RE -TEST GOOD. PRESSURE TEST ANNULAR TO 250 / 3500 PSI 5 MIN EA. TEST 2 FOSV TO 250 / 3500 PSI 5 MIN EA. CHART RECORD ALL PRESSURE TESTS. TEST LEL ALARMS. PERFORM ACCUMULATOR DRAWDOWN TEST. ALL TESTS WITNESSED BY BP WSL & NORDIC TOOLPUSHER. 22:00 - 23:00 1.00 BOPSUR P PRE M/U INJECTOR. PRESSURE TEST INNER REEL VALVE AND BULKHEAD TO 250 / 3500 PSI EA. CHART RECORD TESTS. LOTO Q -06 PER WELLPLAN WITH DSO AND WSL. 23:00 - 00:00 1.00 BOPSUR P PRE PJSM. PUMP E -LINE SLACH BACK 4 BPM 2200 PSI. UNSTAB INJECTOR. R/U AND BLOW COIL BACK WITH AIR. R/U HYDRAULIC COIL CUTTER. CUT 255' 2 3/8" COIL. 3/13/2013 00:00 - 02:00 2.00 BOPSUR P PRE FINISH CUTTING COIL. M/U CTS CTB CONNECTOR. PULL TEST TO 40K. PRESSURE TEST TO 3900 PSI. 02:00 - 02 :15 0.25 BOPSUR P PRE M/U INJECTOR. PRESSURE TEST OTIS CONNECTION AND BAKER CHECKS. PRESSURE TO 250 / 3700 PSI 5 MIN EACH. CHARTED. 02:15 - 02:35 0.33 BOPSUR P ■- PRE OPERATE REMOTE PPG DRILLING MUD. OPERATE E REMOTT E FOR SSV. SET BACK INJECTOR. CIRC COIL. Printed 4/2/2013 7:29:28AM Common Well Name: J -17 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 3/11/2013 End Date: 3/19/2013 X3- 0135K- C:DRILL (2,121,298.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name/No.: NORDIC 1 Spud Date/Time: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA i UWI: / Lat: 070 19'37.030"0 Long: 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 02:35 - 03:05 0.50 BOPSUR P PRE RIG EVAC DRILL. FIRE ON RIG UNKOWN SOURCE AND LOCATION ON RIG. WELL IS SECURE WITH TWC AND TREE VALVES CLOSED. RIG EVACUATION ALARM ACTIVATED. REPORT TO PRIMARY MUSTER AREA. 100 PERCENT HEAD COUNT. SIMULATE EMT AND BP HSE NOTIFICATIONS. DSO NOTIFIED. MR: USING RIG FLOOR OUT SIDE EXIT, STAIRS TO 2ND LEVEL WERE NOT INSTALLED DUE TO NOT HAVING ENOUGH ROOM TO GET TO BEAVER SLIDE TO BRING LUBRICATOR TO RIG FLOOR. MAKING YOU HAVE TO RE -ENTER RIG TO GET TO LOWER EXIT. SET STAIRS AS SOON AS POSSIBLE. VALVE CREW AND CH2MHILL PERSONEL RESPONDED QUICKLY. TRUCK DRIVER HAD BP RADIO MONITORING NORDIC HUB. WHEN ANNOUNCEMENT WAS MADE .SOMEONE ELSE CALLED ON RADIO AND HE • MISSED THE ANNOUNCEMENT, BUT HEARD SIREN CLEARLY. 03:05 - 03:15 0.17 BOPSUR P PRE PJSM FOR PULLING TWC WITH VALVE CREW. VERIFY EQUIPMENT CERTIFICATIONS. VALID. REVIEW SOP FOR PULLING TWC. 03:15 - 05:10 1.92 BOPSUR P PRE LOAD LUBRICATOR TO RIG FLOOR. R/U AND PRESSURE LUBRICATOR TO 250 / 3500 PSI 5 MIN EA. CHARTED. WITH LTT ON LUBRICATOR. OPEN SSV, MASTER AND SWAB VALVES. PULL TWC. 0 PSI ON WELL. CLOSE SSVAND SWAB VALVES. LTT LUBRICATOR TO 250 / 3500 PSI 5 MIN EA. CHARTED. BLEED OFF PRESSURE. L/D AND LOAD OUT LUBRICATOR. 05:10 - 05:35 0.42 BOPSUR P PRE I PRE SPUD MEETING WITH DD, RIG CREW, WSL, TP AND SLB. 05:35 - 06:00 0.42 BOPSUR P PRE R/U NIGHT CAP. PRESSURE TEST TO 250 / 3500 PSI AGAINST CLOSED SWAB AND MASTER VALVES 5 MIN EA. CHART RECORD TEST 06:00 - 07:00 1.00 BOPSUR P PRE FREEZE PROTECT COIL BY PUMPING 5-BBLS FRESH WATER, 5-BBLS MEOH, 5 -BBLS FRESH WATER & SPOTTING MEOH AT DH END OF COIL. PERFORM PRE TOUR CHECKS 07:00 - 07:30 0.50 BOPSUR P PRE RIG EVAC DRILL & AAR. SIMULATE H2S RELEASE IN PITS. WIND DIRECTION & PRIMARY MUSTER AREA CHANGED SINCE PRE -TOUR MEETING. RIG CREW RESPONDED APPROPRIATELY WITH ALL PARTIES ACCOUNTED FOR IN SAFE LOCATIONS. DISCUSSED THE ADVANTAGE TO EVACUATING WITH 5 -MIN ESCAPE PACKS. ONLY REEL HOUSE EVAC ALARM SOUNDED BUT SIREN WAS HEARD BY ALL. Printed 4/2/2013 7:29:28AM , „tot .AViitoortA014101-.<ixitsi4=1--r xtigiviit= a e 34 f Common Well Name: J -17 1 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 3/11/2013 1 End Date: 3/19/2013 f X3- 0135K- C:DRILL (2,121,298.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name/No.: NORDIC 1 Spud Date/Time: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °19'37.030 "0 Long: 0148 °50'38.023 "W I Active datum: Kelly Bushing / Rotary Table ©77.00usft (above Mean Sea Level) Date From - To Hrs 1 Task Code NPT NPT Depth Phase Description of Operations (hr) I (usft) 07:30 - 08:00 0.50 BOPSUR P PRE PJSM ON WELL KILL WITH RIG CREW, WSL, TRUCK DRIVERS. DISCUSS ORDER OF OPERATIONS, FLUIDS PUMPED, COMMUNICATION BETWEEN TRUCKS & RIG CREW. 08:00 - 10:00 2.00 BOPSUR P PRE ENSURE BOTH PUMPS ARE FLUID PACKED. LINE UP TO BULLHEAD DOWN TUBING - WELL ONAVAC. PUMP 5-BBLS MEOH SPEAR AT 1 -BPM / 0 -PSI. CHASE MEOH WITH 290 -BBLS 8.4 -PPG 1% KCL. PUMP AT 5 -BPM / 1850 -PSI. TOOK —17 -BBLS TO CATCH FLUID LEVEL. WITH 1- WELLBORE VOLUME KCL BULLHEADED PRESSURE STABILIZES AT 5.7 -BPM / 2540 -PSI. CHASE KCL WITH 200 -BBLS 8.6 -PPG USED POWERPRO DRILLING MUD. BULLHEAD AT 5.7 -BPM / 2000 -PSI WITH FINAL BH PRESSURE OF 2330 -PSI. IA / OA = 16 -PSI / 0 -PSI. 10:00 - 10:30 0.50 BOPSUR P PRE FLOW CHECK WELL FOR 30 -MIN - NO FLOW OBSERVED. ESTABLISH CIRCULATION ACROSS THE TOP I f OF THE WELL WITH 8.6 -PPG MUD. 10:30 - 11:00 0.50 STWHIP P WEXIT HOLD PJSM ON MU WHIPSTOCK BHA. DISCUSS POSITIONS OF PEOPLE, BHA HANDLING, WELL CONTROL CONSIDERATIONS. CIRCULATE ACROSS THE TOP OF THE WELL ./ AT 1 -BPM DURING MEETING - NO LOSSES SEEN OVER 1 /2 -HR CIRCULATING. 11:00 - 11:30 0.50 STWHIP P WEXIT MU WHIPSTOCK BHA. BHA CONSISTS OF 4 -1/2" KB PACKER WHIPSTOCK, J RUNNING TOOL, XO, HOT, DGS, DPS, EDC, P &C, WEAR SUB, LQC, UQC, XO & CTC. OAL = 78.71'. MU BHA TO COIL & STAB INJECTOR ON WELL. 11:30 - 12:15 0.75 STWHIP P � WEXIT TEST QTS TO 250 -PSI / 3500 -PSI FOR 5 -MIN PER TEST. GOOD TESTS. OPEN EDC & CIRCULATE FRESH WATER / MEOH OUT OF COIL TO CUTTINGS BOX. FILL MGS WITH MUD IN PREP FOR RIH. 12:15 - 14:30 2.25 STWHIP P WEXIT RIH WITH WHIPSTOCK, CIRCULATING THROUGH OPEN EDC AT .82 -BPM / 900 -PSI, TAKING ALL RETURNS THROUGH MGS. 14:30 - 15:30 1.00 STWHIP P WEXIT LOG TIE IN TO TSAD PER GEO FROM 10,390' TO 10,480' (UNCORRECTED DEPTHS). CIRCULATE AT .88 -BPM / 1200 -PSI WHILE LOGGING DOWN. APPLY MINUS 8' CORRECTION. SIM OPS - FILL PIT #4 WITH 8.6 -PPG MUD TO TOP OF PITS. 15:30 - 16:00 0.50 STWHIP P WEXIT RIH TO 11,640'. CIRCULATE AT .88 -BPM / 1315 -PSI. Printed 4/2/2013 7:29:28AM . • ! e ' � . s e - *� g 7 y am^' - 3' r ** r ° . itv: t-x ,a- a 3 4 -.� } .�`s s .. A `$� 't�Cr.. '� tO� ,� �`�� �� t w� p"a .'� ��£s r �.,� �. � �' i e tt . : .'� r.. ' :-.r° AVIA , r.n. ij; `x `„:,, e , ;K ,zY .rt "? m . ...t E, , *. s r. T F r Common Well Name: J -17 AFE No Event Type: RE- ENTER- ONSHORE (RON) I Start Date: 3/11/2013 End Date: 3/19/2013 X3- 0135K- C:DRILL (2,121,298.00 ) 1 1 Project: Prudhoe Bay j Site: PB J Pad Rig Name /No.: NORDIC 1 1 Spud Date/Time: 1/3/2002 12:00:00AM (Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA ! UWI: / Lat: 070 °19'37.030"0 Long: 10148°50'38.023"W Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) Date 1 From - To Hrs Task I Code 1 NPT I NPT Depth 11 Phase 1 Description of Operations (hr) j (usft) 1 16:00 - 16:30 0.50 I STWHIP , P WEXIT LOG CCL DOWN FROM 11,640 TO 11,800' i (SHOE DEPTHS) AT 1000 -FPH. I CIRCULATE AT .88 -BPM / 1270 -PSI. PU TO 11,750' AND ASSESS CCL. COLLAR AT j 11,728'. DISCUSS WITH ENGINEERING TEAM 1 AND DECIDE TO SET TOWS AT 11,733' FOR 1 j COLLAR AVOIDANCE. 16:30 17:00 0.50 1 STWHIP P WEXIT POSITION WHIPSTOCK WITH TOP AT 11 ,733' (BOTTOM 11,748.7') 1 I SHUT DOWN PUMP & CLOSE EDC. PRESSURE UP TO SET WHIPSTOCK SEE 1 SET AT 2800 -PSI. SET DOWN 4K -LBS TO I CONFIRM SET. ! PU TO 11,700' AND FLOW CHECK WELL- NO I FLOW. IA / OA / PVT = 20 -PSI / 0-PSI / 308 -BBLS. 17:00 - 18:15 1.25 STWHIP P WEXIT 1 W CBU THROUGH MGS FROM 11,700'. CIRCULATE AT 2.24-BPM / 2060 -PSI, MOVING 1 UPHOLE SLOWLY. I AT BOTTOMS UP CLEAN. 1 I ISOLATE MGS. CONTINUE TO CIRCULATE. 18:15 20:10 SETTING POH WITH WS WEXIT 1 PUMPING 2 BPM 1860 PSI. to 200' -- 120:10 - 20:25 0.25 STWHIP 1 P WEXIT I FLOWCHECK WELL. NO FLOW. PJSM FOR BHA. 1 ! 20:25 - 22:20 1.92 STWHIP P ! WEXIT SET BACK INJECTOR. CIRC COIL. UD BHA# 1 WS SETTING TOOL. M/U BHA# 2, 3.8" WINDOW MILL, 3.80" STRING MILL, 2 7/8" X -TREME MM, XO, 2 JTS 2 3/8" PH6, XO XO, BLIND SUB, DGS, DPS, EDC, P & C, WEAR SUB, LQC, UQC, XO. OAL = 120.37, M/U INJECTOR. TEST QTS. PVT= 254 BBLS. i I ORDER MORE MUD FOR CONTINGENCY. 122:20 - 00:00 1.67 1 STWHIP P , WEXIT RIH PUMPING MIN. RATE. 1 I — 1 3/14/2013 P I WEXIT CONTINUE RIH WITH 3.80" WINDOW MILL BHA 00:00 01:15 1.25 —_ - -_ . STWHIP I I I # 2 FROM 8200'. ! PUMPING MIN RATE. I LOG TIE AT 10490'. - 7' CORRECTION. CONTINUE RIH TO 11700' 1 P/U WT = 38K. S/O WT = 18K I OBTAIN SPR #1 & # 2 MP. # 1 MP 2.6 BPM = 2500 PSI. 1 BPM = 1580 PSI. I .5 BPM = 1230 PSI. 1 # 2 MP 2.6 BPM = 2500 PSI. 1 BPM = 1450 PSI. .5 BPM = 1230 PSI. !UPDATE KILL SHEET. SHUT PUMP OFF AND CONTINUE RIH. 1 I DRY TAG TOP WHIPSTOCKAT 11734.6' Printed 4/2/2013 7:29:28AM • Common Well Name: J -17 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 3/11/2013 End Date: 3/19/2013 'X3- 0135K- C:DRILL (2,121,298.00 ) Project: Prudhoe Bay Site: PB J Pad SAC Rig Name/No.: NORDIC 1 Spud Daterme: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 ' Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °19'37.030 "0 Long: 0148 °50'38.023 "W _ J� Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) , ` Date From - To j Hrs Task Code I NPT l NPT Depth Phase Description of Operations hr usft) 01:15 - 02:15 I 1.00 STWHIP P WEXIT P/U TO 11722'. F/S = 2540 PSI AT 2.68 BPM. RIH SLOWLY. LIGHTLY TAG PINCH POINT AT y 11733.8' \/ O 14-D i TIME MILL 1ST FT WINDOWAT 1 FPH PER BTT 1 ( ` REP. WOB = 1.5K - 1.6K. 150 TO 200 PSI MOTOR l WORK. N MM IN = 2.6 BPM. MM OUT = 2.62 BPM MW = 8.63 PPG IN. MW = 8.56 PPG OUT PVT = 311 BBLS. IA = 21 PSI. OA = 0 PSI. ECD = 10.02 PPG. 02:15 - 05:30 3.25 I STWHIP P ( WEXIT SLOWLY INCREASE WOB 1.8K- 3.21K 200 PSI MOTOR WORK. ROP = 1.4 FPH. MILL WINDOW TO 11739' FORMATION SEEN AT SHAKER. GEO CONFIRMS -5% FORMATION IN SAMPLE FROM 11,739'. 05:30 - 12:00 6.50 STWHIP P WEXIT TIME MILL FROM 11,739.5' TO 11,740.5' AT 1 -FPH. MAINTAIN .75 - 1K -LBS DHWOB AND 100 -PSI MOTOR WORK STRING REAMER APPEARS TO EXIT AT 11,741.3'. TIME MILL AT 2 -FPH FROM 11,741.5' TO 11,743.5'. MILL AHEAD IN FORMATION FROM 11,743.5' TO 12,750', MAINTAINING 2.5-3K -LBS DHWOB AND 200 - 300 -PSI MOTOR WORK. ROP SLOW AT 2- 3-FPH. AT START, IA / OA / PVT = 20-PSI / 4-PSI / 309 -BBLS. MW IN / OUT = 8.61 -PPG / 8.53 -PPG. ECD = 9.9 -PPG. AT END, IA / OA / PVT = 20 -PSI / 5-PSI / 306 -BBLS. MW IN / OUT = 8.61 -PPG / 8.53 -PPG. ECD = 9.9 -PPG. 12:00 - 14:00 2.00 STWHIP P WEXIT PU FROM 11,750' AND BACK -REAM THROUGH WINDOW TO 11,738' AT 1 -FPM WHILE CIRCULATING 2.57 -BPM / 2420 -PSI FREE SPIN. SEE VERY SLIGHT MOTOR WORK ( -30 -PSI) AT 11,741' & 11,740' ON UP PASS INDICATING STRING REAMER & MILL PASSING MINIMAL DEBRIS AT BOTTOM OF WINDOW. I REAM UP & DOWN THRU WINDOW 3X WITH SAME PARAMETERS AS ABOVE AND NO ISSUES NOTED ON ANY OF THE PASSES. PU TO 11,725' AND SHUT PUMP OFF. DRY DRIFT WINDOW- CLEAN. CATCH SAMPLE FROM 11,749' AND GEOLOGIST CONFIRMS ALMOST ALL SAND WITH SOME CHERT PRESENT. 14:00 - 16:00 2.00 STWHIP P WEXIT MILL AHEAD IN RATHOLE FROM 11,750' TO 11,752'. FREE SPIN = 2.65 -BPM / 2430 -PSI. MILL AHEAD WITH 2.5 - 3.2K -LBS DHWOB & 250 - 400 -PSI MOTOR WORK. ROP VERY SLOW BETWEEN 1 & 2 -FPH. DISCUSS SITUATION WITH ODE & DECIDE TO POH FOR DRILLING BHA. Printed 4/2/2013 7:29:28AM n ,gam Common Well Name: J -17 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 3/11/2013 End Date: 3/19/2013 X3 -0135K C:DRILL (2,121,298.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 1 1 Spud Date/Time: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA UWI: / Let: 070 °19'37.030"0 Long: 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table i77.00usft (above Mean Sea Level) Date From - To Hrs 1 Task Code NPT NPT Depth Phase Description of Operations (hr) 1 (usft) 16:00 - 16:30 0.50 STWHIP 1 P WEXIT POH ABOVE WINDOW- CLEAN THROUGH WINDOW. FLOW CHECK WELL AT 11,725' - NO FLOW. OPEN EDC. 16:30 - 18 :55 2.42 STWHIP P WEXIT ESTABLISH CIRCULATION THROUGH OPEN EDC AT 3-BPM / 2340 -PSI. PVT AT START = 304 -BBLS. IA / OA = 20 -PSI / 7 -PSI. POH PUMPING THROUGH EDC TO 200' PERFORM 300' TO 500' JOG. 18:55 - 19:10 0.25 STWHIP P WEXIT FLOWCHECKAT 200'. NO FLOW. CLOSE EDC. PJSM FOR UD WINDOW MILL BHA AND P/U LATERAL BHA # 3. I PVT = 247 BBLS. IA = 42 PSI. OA = 9 PSI 19:10 - 19:45 0.58 STWHIP P WEXIT SET BACK INJECTOR. CIRC COIL. U D WINDOW MILL BHA. MILL = 3.73" NOGG. 3.74" GO. GRADE = 8 -7. STRING MILL = 3.78" NOGO. 3.79" GO. 1 19:45 - 20:00 0.25 BOPSUR P WEXIT PJSM. CHECK TORQUE ON TREE BOLTS. ALL BOLTS PROPERLY TORQUED. 20:00 - 21:00 1.00 DRILL P PROD1 M/U LATERAL BHA# 3. 4.25" BI- CENTER BIT, 3 1/8" M1XL MM WITH AKO 1.41 DEG, HOT, DGS, USMPR, DPS, EDC, P &C, WEAR SUB, LQC, XO, CTC = 86.40'. M/U INJECTOR. PRESSURE TEST QTS. 21:00 - 23:00 2.00 DRILL P L PROD1 RIH PUMPING .24 BPM 730 PSI TO 10240'. 23:00 - 00:00 1.00 DRILL P PROD1 LOG TIE IN FROM 10240' TO 10350' AT 100 FPM. 3/15/2013 00:00 - 01:30 1.50 DRILL P PROD1 LOG TIE IN FROM 10350' TO 10470' AT 100 FPH. -6.5' CORRECTION. TOW = 11734.5', BOW = 11742.5', RA TAG = 11743.5' CORRECTED. 01:30 - 02:00 0.50 DRILL P PROD1 CONTINUE RIH. P/U WT 40K JUST ABOVE WINDOW. { PUMPS OFF PASSING THROUGH WINDOW 11733', CLEAN. TAG BOTTOM AT 11752' 02:00 - 03:00 1.00 DRILL P PROD1 GET PARAMETERS. ON BOTTOM DRILLING FROM 11752' F/S = 2535 PSI 2.66 BPM. 150 - 200 PSI MOTOOR WORK WOB= 1K -1.5K. ROP =70 FPH. MM IN = 2.55 BPM. MM OUT = 2.56 MW IN = 8.59 PPG. MW OUT = 8.53 PPG. PVT =301 BBLS. IA = 55 PSI. OA = 5 PSI OBTAIN SPR 1 & 2 MP AT 11800' #1 MP AT 2.77 BPM = 2538 PSI. AT 1.59 BPM = 1644 PSI. AT .55 BPM = 1179 PSI. #2 MPAT2.71 BPM =2465 PSI. AT 1.65 BPM= 1685 PSI. AT .6 BPM = 1205 PSI. UPDATE KILL SHEET. _ 03:00 - 03:30 0.50 DRILL P PROD1 LOG TIE IN AT 11765' NO CORRECTION. Printed 4/2/2013 7:29:28AM *'z 4 h p r Common Well Name: J -17 ! AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 3/11/2013 I End Date: 3/19/2013 IX3- 0135K- C:DRILL (2,121,298.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °19'37.030"0 Long: 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) Date From - To Hrs I Task I Code NPT NPT Depth I Phase Description of Operations (hr) (usft) ' 03:30 - 04:45 1.25 I DRILL P PROD1 CONTINUE DRILLING FROM 11800' TO 11900' WOB = 1K ROP = 100 FPH. 1 2650 PSI CIRCULATING PRESSURE MM IN = 2.62 BPM. MM OUT = 2.67 MW IN = 8.6 PPG. MW OUT = 8.58 PPG. PVT =298 BBLS. IA = 59 PSI. OA = 5 PSI. ECD = 10.3 P/U TO CIRCULATE UP SAMPLE. 04:45 - 05:55 1.17 DRILL P ( PROD1 PUH TO CIRCULATE UP SAMPLES. 05:55 - 06:30 0.58 DRILL P PROD1 CONTINUE DRILLING LATERAL FROM 11900' !TO 11,950' WOB = 1K. ROP = 88 FPH. ! 2629 PSI CIRCULATING PRESSURE 1 MM IN = 2.6 BPM. MM OUT = 2.55 MW IN = 8.61 PPG. MW OUT = 8.58 PPG. PVT =290 BBLS. IA = 60 PSI. OA = 6 PSI. ECD = 9.98 PPG. 06:30 - 07:00 0.50 DRILL I P PROD1 MAKE SHORT WIPER TRIP WHILE COMPLETING CHANGE OUT. INCREASE PUMP RATE TO 2.9 -BPM / 2780 -PSI. NO ISSUES NOTED ON WIPER. 07:00 - 08:50 1.83 DRILL P PROD1 DRILL AHEAD IN LATERAL SECTION FROM 11,950' TO 12,100' FREE SPIN = 2.9 -BPM / 2780 -PSI. DRILL AHEAD WITH 150- 350 -PSI MOTOR WORK AND 1 - 3.5K -LBS DHWOB. DD STEERING UP TO LAND ABOVE HOT PER GEO AT 8960' TVD. GOOD ROP ABOVE 75-FPH FOR INTERVAL. I AT START, IA / OA / PVT = 61 -PSI / 7 -PSI / 284 -BBLS. MW IN / OUT = 8.59 -PPG / 8.59 -PPG. ECD = 10.06 -PPG. AT END, IA / OA / PVT = 63-PSI / 10-PSI / 282 -BBLS. MW IN / OUT = 8.61 -PPG / 8.59 -PPG. ECD = 10.06 -PPG. 08:50 - 09:05 I 0.25 DRILL P ! PROD1 BHA WIPER FROM 12,100'. CIRCULATE AT 2.9 -BPM / 2780 -PSI. NO ISSUES ON TRIP. 09:05 - 13:10 I 4.08 DRILL P PROD1 DRILL AHEAD FROM 12,100' TO 12,294' FREE SPIN AT 2.9 -BPM / 2780 -PSI. DRILL AHEAD WITH 2 - 4K -LBS DHWOB AND 150 - 350 -PSI MOTOR WORK. GEO REPORTS UP TO 60% CHERT IN CUTTINGS SAMPLES. AT 12,140', PUMP 10 -BBLS NEW MUD SWEEP TO ASSESS MUD CONDITION. SEE - 10% INCREASE IN CUTTINGS WITH SWEEP BACK CONTINUE TO DRILL AHEAD WITH ABOVE PARAMETERS. PUMP 12 -BBL NEW MUD SWEEP TO TIME WITH WIPER TO WINDOW. AT START, IA / OA / PVT = 63-PSI / 9-PSI / 281 -BBLS. MW IN / OUT = 8.6 -PPG. ECD = 10.06 -PPG. AT END, IA / 0 A/ PVT = 66-PSI / 11 -PSI / 267 -BBLS. MW IN / OUT = 8.61 -PPG / 8.59 -PPG. ECD = 10.08 -PPG. Printed 4/2/2013 7:29:28AM Common Well Name: J -17 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 3/11/2013 End Date: 3/19/2013 X3- 0135K- C:DRILL (2,121,298.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °19'37.030"0 Long: 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) Date From - To Hrs Task Code ■ NPT NPT Depth Phase Description of Operations (hr) I (usft) 13:10 - 13:35 0.42 DRILL P PROD1 WIPER TO WINDOW FROM 12,294'. CIRCULATE AT 3.08 -BPM / 3020 -PSI. NO ISSUES ON TRIP TO WINDOW. HOLD KWT DRILL & AAR WITH RIG CREW. CREW RESPONDED ACCURATELY AND SAFELY PER STANDING ORDERS. DURING AAR, HIGHLIGHT DISTANCE COIL MUST BE PICKED UP OFF OF BOTTOM IN CASE BSRS WOULD NEED TO BE USED. 13:35 - 14:00 0.42 DRILL P PROD1 LOG TIE IN TO RA TAG. APPLY +2' CORRECTION. MINIMAL INCREASE IN CUTTINGS SEEN WITH SWEEP BACK. CHANGE OUT SHAKER SCREENS 14:00 - 14:30 0.50 DRILL P PROD1 WIPER FROM WINDOW TO 12,294'. CIRCULATE AT 2.94 -BPM / 2800 -PSI. 14:30 - 15:30 1.00 DRILL P PROD1 DRILL AHEAD FROM 12,294' TO 12,315. FREE SPIN = 2.98 -BPM / 2820 -PSI. DRILL WITH 4.5 - 6K -LBS DHWOB AND 200 -PSI MOTOR WORK. ROP AT STEADY 20 -FPH. TRY LOWERING PUMP RATE TO 2.7 -BPM AND NO CHANGE IN ROP. AT START, IA / OA / PVT = 66-PSI / 11 -PSI / 263 -BBLS. MW IN / OUT = 8.61 -PPG / 8.6 -PPG. ECD = 10.11 -PPG. AT END, IA / OA / PVT = 66- PSI / 11 -PSI / 262 -BBLS. MW IN / OUT = 8.59 -PPG / 8.56 -PPG. ECD = 10.11 -PPG. 15:30 - 16:00 0.50 DRILL P PROD1 FLOW CHECK WELL - NO FLOW POH, CIRCULATING AT 2.9 -BPM / 2800 -PSI. NO ISSUES SEEN ON WIPER TRIP. LOWER PUMP RATE AND PASS THRU WINDOW WITHOUT ISSUE. 16:00 - 16:10 0.17 DRILL P -_ PROD1 FLOW CHECK WELL - NO FLOW. OPEN EDC. 16:10 - 18:40 2.50 DRILL P PROD1 ESTABLISH CIRCULATION AT 3.85 -BPM / 3000 -PSI. POH WITH LATERAL BHA TO INSPECT BIT. POH TO 200'. PERFORM JOG TO 500'. 18:40 - 19:00 0.33 DRILL P ■- PROD1 FLOWCHECK WELL. NO FLOW. CLOSE CLOSE E ED EDC. PJSM FOR BHA. 19:00 - 20:30 1.50 DRILL P PROD1 TAG UP. SET INJECTOR BACK. CIRC COIL. L/D BHA. INSPECT MUD MOTOR AND BIT. BITGRADE= 2 /2 /WT /A /X /I /CT /PR. M/U NEW HYC 4.25" BI- CENTER BIT. M/U INJECTOR. PT QTS. 20:30 - 23:00 2.50 DRILL N RREP PROD1 TROUBLESHOOT BHI ADVANTAGE SOFTWARE. WELL TRACKING COMPUTOR SCREEN IN MWD OFFICE NOT READING. MWD TECH RE -IMAGE SOFTWARE ON SCREEN. _ 23:00 - 00:00 1.00 DRILL P ■- PROD1 RIH WITH LATERAL 0A S 4 TO 5400' PUMPING G .22 BPM 730 PSI. LOAD LINER INTO PIPESHED. Printed 4/2/2013 7:29:28AM • K; ry d .6 $ S° 'v im%^ f a ' V "f 1.f 1 9 � a4t _ #"'� Common Well Name: J -17 j AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 3/11/2013 End Date: 3/19/2013 X3 -0135K C:DRILL (2,121,298.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA I UWI: / Lat: 070 °19'37.03170 Long: 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) Date From - To Firs Task Code I NPT NPT Depth Phase Description of Operations (hr) (usft) 3/16/2013 00:00 - 02:25 2.42 DRILL P PROD1 RIH WITH LATERAL BHA # 4 FROM 5400' PUMPING .22 BPM 900 PSI. PASS THROUGH WINDOW WITH PUMPS OFF AT 11735' LOG TIE IN AT RA TAG. - 6.5' CORRECTION. ISOLATE 1 PIT FOR RETUNS. START MUD SWAP TO NEW 8.6 PPG POWERPRO MUD. P/U WT = 40K. TAG BOTTOM AT 12310' 02:25 - 03:30 1.08 DRILL P PROD1 GET PARAMETERS. DRILLING FROM 12310' F/S 2850 PSI AT 2.7 BPM. WOB = 1.8K. ROP = 24 FPH. 2985 PSI CIRCULATING PRESSURE MM IN = 2.7 BPM. MM OUT = 2.74 MW IN = 8.53 PPG. MW OUT = 8.6 PPG. !IA = 55 PSI. OA = 6 PSI. ECD = 10.1 PPG. ! NEW MUD ALL THE WAYAROUND 12326'. WIPER BHA 03:30 - 06:15 2.75 DRILL P PROD1 CONTINUE DRILLING FROM 12340' TO 12412' F/S 2600 PSI AT 2.6 BPM. WOB = 3.71K. ROP = 32 FPH. 2842 PSI CIRCULATING PRESSURE MM IN = 2.67 BPM. MM OUT = 2.65 MW IN = 8.54 PPG. MW OUT = 8.47 PPG. PVT = 316 BBLS. IA = 54 PSI. OA = 6 PSI. ECD = 9.95 PPG. OBTAIN SPR 1 & 2 MP AT 12350' #1 MP AT 2.9 BPM = 2600 PSI. AT 1.59 BPM = 1732 PSI. AT .56 BPM = 1311 PSI. #2 MP AT 2.98 BPM = 2600 PSI. AT1.71 BPM = 1835 PSI. AT .56 BPM = 1271 PSI. UPDATE KILL SHEET. 06:15 - 06:30 0.25 DRILL P PROD1 MAKE BHA WIPER TRIP FROM 12,412'. NO ISSUES. 06:30 - 10:00 3.50 DRILL P PROD1 DRILL AHEAD FROM 12,412' TO 12,500'. FREE SPIN = 2.95 -BPM / 2610 -PSI. DRILL WITH 3 - 4K -LBS DHWOB AND 150 - 350 -PSI MOTOR WORK. ADDED 4 -DRUMS LO -TORQ TO INCREASE LUBRICANT TO 5% HIGHER GR READINGS AND WHITE CLAY SEEN IN CUTTINGS. BUILDING ANGLE TO GET ABOVE CLAYSTONE. AT - 12,460', INCREASE PUMP RATE TO 3.3 -BPM WITH FREE SPIN AT 2960 -PSI. CONTINUE TO DRILL AHEAD WITH 3- 5.5K -LBS DHWOB AND 200 -400-PSI MOTOR WORK. ROP IMPROVES SLIGHTLY TO 30 - 50 -BPH. AT START, IA / OA / PVT = 59 -PSI / 7 -PSI / 320 -BBLS. MW IN / OUT = 8.51 -PPG / 8.48 -PPG. ECD = 9.95 -PPG. AT END, IA / OA / PVT = 65-PSI / 10-PSI / 320 -BBLS. MW IN / OUT = 8.52 -PPG / 1 8.47 -PPG. ECD = 10.08 -PPG. Printed 4/2/2013 7:29:28AM • ,, 4, 4 , .4„,,,, it ,.. v,,, 4i .-4.4-.:4,;Tv;,-w 11.310‘: .:'.0:471.1.4 ,, '.,.,,,,,, -* "'' '..:-A ;#......,., .!,,,,--, -,-;4474.wa.: ,... . i .e. %,,..0.14,,aket.t.:::*:14,140#00,5,44tafirWrt.. 214,4414V1410,4',4` Common Well Name: J -17 + AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 3/11/2013 ,End Date: 3/19/2013 X3- 0135K- C:DRILL 2121 298.00 I Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 I Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °19'37.03110 Long: 1 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) I II Date From - To I Hrs Task I Code NPT 1 NPT Depth 1 1 Phase 1 Description of Operations (hr) , (usft) 1 10:00 - 10:15 0.25 DRILL P I PROD1 MAKE WIPER TRIP FROM 12,500' TO 12,200' CIRCULATE AT 3.35 -BPM / 3050 -PSI. ECD AT START 10.08 -PPG. ECD AT END = 10.11 -PPG. I RETURNS FROM WIPER SHOW SLIGHT I INCREASE IN WHITE CLAY CUTTINGS. 10:15 - 13:00 I 2.75 DRILL I P PROD1 DRILL AHEAD FROM 12,500' FREE SPIN = 3.3 -BPM / 3000 -PSI. DRILL AHEAD WITH 3 - 5K -LBS DHWOB AND 1200 - 400 -PSI MOTOR WORK ROP STILL IMPROVED BUT CONTINUE TO SEE WHITE CLAY CUTTINGS & HIGH GR. , AT START, IA / OA / PVT = 65-PSI /11 -PSI / 320 -BBLS. MW IN / OUT = 8.53 -PPG / i 8.48 -PPG. ECD = 10.12 -PPG. AT END, IA / OA / PVT = 73-PSI / 15 -PSI / 317 -BBLS. MW IN / OUT = 8.56 -PPG / 8.48 -PPG. ECD = 10.16 -PPG. j 13:00 - 13:30 1 0.50 DRILL P PROD1 ,WIPER TRIP FROM 12,600'. I CIRCULATE AT 3.4 -BPM / 3240 -PSI. I SEE 10K -LB OVERPULLAT 12,580' (CTC AT 12,500'). ALSO SEE OVERPULLS WITH CTC AT 12,285' & OVERPULLS WITH MOTOR WORK FROM 12,350' TO 12,280'. 113:30 - 13:45 0.25 DRILL P I 1 PROD1 LOG TIE IN TO RA TAG. ! � APPLY +3' CORRECTION. _ IC I 13:45 - 15:00 1.25 DRILL P I PROD1 LOG MAD PASS FROM 11,778' TO 12,150' AT 5 -FPM. CIRCULATE AT 3.3 -BPM / 3060 -PSI. I NOTICE UNUSUAL NOISE COMING FROM SLB POWER PACK CTS OPERATOR DISCUSS WITH CTS MECHANIC & DISTRICT MANAGER. DECIDE TO PULL INSIDE CASING FOR I 1 MECHANICS TO INSPECT POWER PACK 1 15:00 - 15:55 0.92 DRILL N ' SFAL 1 PROD1 POH FROM 12,150'. CIRCULATE AT 3.3 -BPM / 3050 -PSI. NO I ISSUES ON TRIP TO WINDOW. LOWER PUMP TO MIN RATE & PULL THROUGH WINDOW - NO ISSUES. CONTINUE TO POH TO 11,700'. FLOW CHECK WELL- NO FLOW. OPEN EDC & ESTABLISH CIRCULATION. PUMP 20 -BBLS NEW 8.6 -PPG POWERPRO MUD SWEEP AND CHASE AT 3.4 -BPM / 1 2550 -PSI. 15:55 - 17:00 I 1.08 DRILL N SFAL PROD1 CTS MECHANIC ON LOCATION TO INSPECT POWER PACK CONTINUE TO CHASE NEW MUD SWEEP OOH 1 AT 3.33 -BPM / 2505 -PSI. MINIMAL INCREASE IN CUTTINGS WITH SWEEP RETURNING - SEEING MAINLY SAND WITH DIFFUSE WHITE CLAY. NO INCREASE IN CUTTINGS SEEN WITH SECOND BOTTOMS UP. Printed 4/2/2013 7:29:28AM • . Common Well Name: J -17 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 3/11/2013 1 End Date: 3/19/2013 X3 0135K- C:DRILL (2,121,298.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °19'37.030"0 Long: 10148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) Date 1 From - To I Hrs Task I Code 1 NPT NPT Depth I Phase Description of Operations (hr) (usft) 17:00 - 20:15 3.25 DRILL N SFAL PROD1 CTS MECHANIC CONTINUE TO INSPECT POWER PACK REDUCE PUMP RATE TO .5 -BPM / 1030 -PSI. INPUT SHAFT BEARING ON SPLITTER MAKING NOISE. CTS MECHANIC CHECK FOR PLAY ON MARCOS SPLITTER SHAFT. VERY LITTLE PLAY FOUND. RE -ALIGN COUPLER. CHECK TEMP WITH HEAT GUN. 120 DEG - NORMAL. ATTEMPT TO DUPLICATE BEARING NOISE. NOTIFY ODE, RWO FIELD SUPERINTENDANT, WTL, CTS DISTRICT MANAGER. DISCUSS PLAN FORWARD. MONITOR BEARING AND SHAFT TEMPS WITH HEAT GUN AT 15 MIN INTERVALS. MONITOR POWER PACK FOR ANY OR ADDITIONAL NOISES. 1500 RPM MAX. MONITOR HYDRAULIC. OIL TEMP ON POWER PACK. IF THERE ARE ANY CHANGES IN POWER .PACK PARAMETERS, POH TO WINDOW. IF POWER PACK SPLITTER FAILS IN OPEN HOLE - CONTINUE TO CIRCULATE. MONITOR WELL. SLB TO BRING OUT SPOOLER OR ANOTHER UNIT. R/U SPOOLER OR CTD UNIT HYDRAULICS TO POH TO WINDOW. OPEN EDC, CIRCULATE AND MONITOR WELL. MAKE REPAIRS IN CASED HOLE ABOVE WINDOW. RECIEVED APPROVAL FROM WTL, RWO FIELD SUPERINTENDANT TO CONTINUE OPS. 20:15 21:45 1.50 DRILL P PROD1 LOG TIE IN AT 11760' .5' CORRECTION. MAD PASS LOG FROM 12145' TO 12360' 1 21:45 - 22:15 0.50 DRILL P PROD1 RIH, WORK THROUGH AND CLEAN UP TIGHT AREAS AT 12513' TO 12519' AND AT 12526' TO 12533'. TAG BOTTOM 12600'. _ 22:15 - 00:00 1.75 DRILL P PROD1 GET PARAMETERS. DRILLING FROM 12600' TO 12660' PUMP 20 BBL LO VIS SWEEP. F/S 2950 PSI AT 3.1 BPM. WOB = 4.8K ROP = 22 FPH. 3160 PSI CIRCULATING PRESSURE MM IN = 3.13 BPM. MM OUT = 3.14 MW IN = 8.63 PPG. MW OUT = 8.54 PPG. PVT = 305 BBLS. IA = 55 PSI. OA = 6 PSI. ECD = 10.12 PPG. NO ISSUES WITH POWER PACK BEARING AND SHAFT TEMPS 112 DEG. Printed 4/2/2013 7:29:28AM • Atif*NicAtriviviNZ_. T .; Common Well Name: J -17 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 3/11/2013 End Date: 3/19/2013 `X3- 0135K- C:DRILL (2,121,298.00 ) --1 Project: Prudhoe Bay Site: PB J Pad Rig Name/No.: NORDIC 1 Spud Date/Time: 1/3/2002 12:00:00AM I Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °19'37.030"0 Long: 1 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) Date From - To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 3/17/2013 100:00 - 00:30 0.50 DRILL P PROD1 i DRILL FROM 12660' TO 12684' F/S 2950 PSI AT 3.1 BPM. WOB = 4.7K. ROP = 33 FPH. 3168 PSI CIRCULATING PRESSURE MM IN = 3.14 BPM. MM OUT = 3.15 BPM. MW IN = 8.64 PPG. MW OUT = 8.51 PPG. PVT = 309 BBLS. IA = 55 PSI. OA = 6 PSI. ECD 10.12 PPG. SWEEP RETURNS NO NOTABLE INCREASE IN CUTTINGS. 00:30 - 01:00 0.50 DRILL P PROD1 WIPER FROM 12684' TO 12515'. i CLEAN WIPER. OBTAIN SPR 1 & 2 MP AT 12650' #1 MP AT 3.18 BPM = 2800 PSI. AT 1.63 BPM = 1791 PSI. AT .67 BPM = 1370 PSI. #2 MP AT 3.28 BPM = 2878 PSI. AT 1.6 BPM = 1185 PSI. AT .66 BPM = 1381 PSI. UPDATE KILL SHEET. 01:00 - 02:30 1.50 DRILL P PROD1 I DRILL AHEAD FROM 12684'TO 12804' WOB = 2.3K CIRC PRESSURE 3145 PSI 02:30 - 04:15 1.75 DRILL P PROD1 WIPER TO WINDOW FROM 12804' TO11760' CLEAN WIPER. KICK WHILE TRIPPING DRILLAT 04:00 HRS. STOP POH FOR WIPER. SHUT DOWN PUMP. FLOWCHECK WELL. MR: NOTICE PIT GAIN. CREW AND SLB SUPERVISOR RESPONDED WELL. FOLLOWED STANDING ORDERS FOR KWT DRILL. 2 NEW HANDS ON RIG DID GOOD JOB REPORTING TO THIER STATION. 04:15 - 07:10 2.92 DRILL P PROD1 DRILLING FROM 12804' TO 13,000' F/S 2835 PSI AT 2.85 BPM. WOB = 2K. ROP = 33 FPH. 3140 PSI CIRCULATING PRESSURE MM IN = 2.87 BPM. MM OUT = 2.88 BPM. MW IN = 8.68 PPG. MW OUT = 8.61 PPG. PVT = 391 BBLS. IA = 74 PSI. OA = PSI. ECD = 10.25 PPG. 07:10 - 08:00 0.83 DRILL P PROD1 WIPER TRIP FROM 13,000'. CIRCULATE AT 3.15 -BPM / 3100 -PSI. SEE MOTORWORK AND ISOLATED OVERPULLS FROM 12,300' TO 12,270'. 108:00 - 08:10 0.17 DRILL P PROD1 TIE IN TO RA TAG, + 3.5' 08:10 - 08:30 0.33 DRILL P PROD1 POH 10,840 08:30 - 09:30 1.00 DRILL P PROD1 RIH, LOG CCL FROM 10,800' TO 11,200'. Printed 4/2/2013 7:29:28AM r1 0 AS . 14141, 4 ,11, 1 ;," b r a :✓. y Y is �� Y. Common Well Name: J -17 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 3/11/2013 End Date: 3/19/2013 X3 0135K- C:DRILL (2,121,298.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA UWI: / Let: 070 °19'37.030 "0 Long: 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) Date j From - To Hrs I Task I Code I NPT NPT Depth Phase Description of Operations (hr) (usft) 09:30 - 11:20 1.83 DRILL P PROD1 CONTINUE TO RIH. STOP ABOVE WINDOW, CLOSE EDC. PASS THROUGH WINDOW WITHOUT ISSUE. CONTINUE TO RIH CIRCULATING AT 3.27 -BPM / 3270 -PSI. SET DOWN X2 AT 12,285. WORK THROUGH TO 12,300' THEN WIPE BACK TO 12,270'. CLEAN PASS THRU. CONTINUE TO RIH. SLIGHT MOTOR WORK / PERIODIC SET DOWNS SEEN FROM 12,500' TO 12,700'. 1I OBTAIN SPRS. TOTAL LOSSES DURING WIPER TRIP = 6 -BBLS. 11:20 - 14:00 2.67 DRILL P PROD1 DRfLLAHEAD FROM 13,000' TO 13,150'. FREE SPIN = 3.1 -BPM / 3100 -PSI. DRILL WITH HIGHER ROP (60 - 100 -FPH), 1 - 2.5K -LBS DHWOB AND 150 - 350 -PSI MOTOR WORK. CHERT & SAND SEEN IN CUTTINGS. AT START, IA / OA / PVT = 52 -PSI / 20-PSI / 275 -BBLS. MW IN / OUT = 8.71 -PPG / 8.58 -PPG. ECD = 10.37 -PPG. AT END, IA / OA / PVT = 60-PSI / 20 -PSI / 268 -BBLS. MW IN / OUT = 8.73 -PPG / 8.62 -PPG. ECD = 10.45 -PPG 14:00 - 14:30 0.50 DRILL P PROD1 SHORT WIPER FROM 13,150' TO 12,850'. CIRCULATE AT 3.2 -BPM / 3230 -PSI. NO ISSUES NOTED ON WIPER TRIP. 14:30 - 18:00 3.50 DRILL P PROD1 DRILL AHEAD FROM 13,150' TO 13,325'. FREE SPIN = 3.2 -BPM / 3210 -PSI. DRILL AHEAD WITH 2 - 3.5K -LBS DHWOB AND 250 - 400 -PSI MOTOR WORK. ROP VERY GOOD ABOVE 70 -FPH. WEIGHT TRANSFER BECOMING MORE CHALLENGING SO MAKE WIPER FROM 13,272' & 13,300'. PUMP 10 -BBLS 8.6 -PPG LO VIS FOLLOWED BY 10 -BBLS 8.6 -PPG HI VIS SWEEP. ONCE SWEEPS ARE BOTH IN THE OH, BEGIN WIPER TRIP. AT START, IA / OA / PVT = 63-PSI / 20-PSI / 267 -BBLS. MW IN / OUT = 8.72 -PPG / 8.62 -PPG. ECD = 10.44 -PPG. AT END, IA / OA I PVT = 70 -PSI / 22 -PSI / 269 -BBLS (ADDED 10 -BBLS FROM LO VIS SWEEP BEING PUMPED). MW IN / OUT = 8.75 -PPG / 8.64-PPG. ECD = 10.5 -PPG. Printed 4/2/2013 7:29:28AM • • 4 4tf...444 44, 4 -,- 4.. ; , . . . f , 3 ': C to 0 ,7 rif. Common Well Name: J -17 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 3/11/2013 End Date: 3/19/2013 X3- 0135K- C:DRILL (2,121,298.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name/No.: NORDIC 1 Spud Date/Time: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 Rig Contractor NORDIC CALISTA UWI: / Lat: 070 °19'37.030 '0 Long: 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table ©77.00usft (above Mean Sea Level) Date From - To Hrs Task , Code NPT NPT Depth '', Phase Description of Operations (hr) I (usft) 18:00 - 21:50 3.83 DRILL P PROD1 WIPER FROM 13,325' CHASING LO & HI VIS SWEEPS. CIRCULATE AT 3.12 -BPM / 3150 -PSI. TIGHT SPOTS AT 12770', 12572' WITH 5K OVERPULLS. TIGHT SPOT AT 12272' WITH 10K OVERPULL CLEAN UP TIGHT SPOTS. LOG TIE IN AT RA TAG. + 4' CORRECTION. OBTAIN SPR 1 & 2 MP AT 13325' # 1 MP AT 3.28 BPM = 3052 PSI. AT 1.73 BPM = 1923 PSI. AT .63 BPM = 1458 PSI. #2 MP AT 3.28 BPM = 3029 PSI. AT 1.66 BPM = 1896 PSI. AT .63 BPM = 1447 PSI. UPDATE KILL SHEET. 21:50 - 00:00 2.17 DRILL P PROD1 ON BOTTOM DRILLING FROM 13325' TO 13375' START 20 BBL LO VIS SWEEP DOWN COIL. CONTINUE DRILLING FROM 13375' F/S 3050 PSI AT 2.96 BPM. WOB = 3K. ROP = 15 - 20 FPH. 3325 PSI CIRCULATING PRESSURE MM IN = 2.98 BPM. MM OUT = 3.3 BPM. MW IN = 8.75 PPG. MW OUT = 8.63 PPG. PVT = 287 BBLS. IA = 84 PSI. OA = 22 PSI. ECD = 10.49 PPG. 3/18/2013 00:00 - 00:15 0.25 DRILL P PROD1 ' CONTINUED DRILLING FROM 13391' TO 13393' STACKING UP TO 15K. DIFFICULT WT TRANSFER TO BIT. 3320 PSI CIRCULATING PRESSURE MM IN = 2.98 BPM. MM OUT = 3.3 BPM. MW IN = 8.75 PPG. MW OUT = 8.63 PPG. PVT = 301 BBLS. IA = 90 PSI. OA = 24 PSI. ECD = 10.49 PPG. SOME EXTRA CUTTINGS ON SHAKER AT I SWEEP RETURNS. 00:15 - 01:00 0.75 DRILL P PROD1 WIPER TO 12960'. CLEAN. PUMP 20 BBLS NEW 8.6 PPG MUD DOWN COIL. 01:00 - 05:00 4.00 DRILL P PROD1 CONTINUE DRILLING PER GEO AND DD. STACKING UP TO 13K. MAKING SLOW PROGRESS. ROP = 10 FPH. CONTINUE STACKING UP TO 15K. WT TRANSFER TO BIT GETTING MORE DIFFICULT. REDUCING TO 8 FPH. 05:00 - 05:30 0.50 DRILL P PROD1 ROP INCREASED AT 13425 TO 15 FPH. '3285 PSI CIRCULATING PRESSURE MM IN = 2.99 BPM. MM OUT = 3.02 BPM. MW IN = 8.75 PPG. MW OUT = 8.62 PPG. PVT = 311 BBLS. IA = 104 PSI. OA = 26 PSI. ECD = 10.46 PPG. Printed 4/2/2013 7:29:28AM S � sz •' • `�' � ,� ff � `.�� - a �" � � � r r � 5 -a' � r t s^ �`� . v * ' ' f c x sa£ '" r,7 as r� s= &, r;'E. s �, ' 4' ' r Common Well Name: J -17 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 3/11/2013 End Date: 3/19/2013 X3- 0135K- C:DRILL (2,121,298.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °19'37.030"0 Long: 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) Date From - To Hrs Task Code I NPT NPT Depth Phase j Description of Operations (hr) (usft) 05:30 - 09:15 3.75 DRILL P PROD1 DRILL AHEAD WITH IMPROVED ROP TO 13,500'. FREE SPIN = 3.2 -BPM / 3250 -PSI. DRILL WITH NEGATIVE COIL WEIGHT AND SOME CHALLENGING WEIGHT TRANSFER. DHWOB = 2 - 4K -LBS AND 300 - 400 -PSI -MOTOR WORK ROP DIMINISHING RAPIDLY AND WEIGHT TRANSFER POOR SO DECIDE WITH GEO TO CALL TD AT 13,500'. 09:15 - 09:45 0.50 DRILL P PROD1 PUMP 11 -BBLS 8.5 -PPG LO VIS & 10 -BBLS 8.6 -PPG HI VIS SWEEP. WIPER SLOWLY WHILE PUMPING SWEEPS TO BIT AT 3.3 -BPM / 3450 -PSI. 09:45 - 11:00 1.25 DRILL P PROD1 WITH BOTH SWEEPS IN OH, WIPER TO WINDOW WHILE PUMPING AT 3.3 -BPM / 3490 -PSI. MINIMAL INCREASE IN CUTTINGS AHEAD OF HI VIS SWEEP. HOLE APPEARS IN GOOD SHAPE. SEE CONNECTOR OVERPULLS ( -5K -LBS) AT 12,380' 11:00 - 11:10 0.17 DRILL P PROD1 'LOWER PUMP RATE AND LOG TIE INTO RA TAG. APPLY PLUS 4.5' DEPTH CORRECTION. IA / OA = 106 -PSI / 30 -PSI. 11:10 - 12:30 1.33 DRILL P PROD1 WIPER BACK TO TD, PUMPING AT 3.23 -BPM / 3450 -PSI. SEE SLIGHT MOTOR WORK SPIKE AT 12,290' AND AGAIN AT 12,315' BUT NO SUSTAINED MOTORWORK OR WEIGHT STACKING. SEE SAME AT 12,500' , 12,550'. SET DOWN, STALL THEN POP THRU AT 12,595' BUT TOOLFACE WAS 180 -DEG OUT. NO ADDITIONAL ISSUES RIH. TAG CORRECTED TD AT 13,498' X3 TO CONFIRM. 12:30 - 13:30 1.00 DRILL N SFAL PROD1 OPEN HIGH PRESSURE SCREEN BYPASS TO PUMP LRP WITH BEADS - ITS FROZEN. CHECK PUMPS - 1502 CONNECTION ON MP #2 IS LEAKING. TIGHTEN BUT NEED TO RETEST PUMP. FLOW CHECK WELL- NO FLOW. ESTABLISH CIRCULATION AT 3.15 -BPM / 3320 -PSI. POH TO WINDOW TO RE -TEST MP #2. SEE OVERPULLS AND MINIMAL MOTORWORK FROM 12,550' TO 12,500'. SEE SIMILAR ISSUES FROM 12,300' TO 12,245'. CLOSE REEL HOUSE DOORS & TURN HEATERS ON. MONITOR BYPASS LINE TEMPERATURE DURING POWER PACK MONITORING ROUNDS. PULL THROUGH WINDOW WITHOUT ISSUES. Printed 4/2/2013 7:29:28AM 1 ' • North America - ALASKA - BP *V * *„ **0*-- � 0 ' Operation Summary Report ` ' �� „, f Common Well Name: J -17 ; AFE No Event Type: RE- ENTER- ONSHORE (RON) j Start Date: 3/11/2013 1 End Date: 3/19/2013 X3- 0135K- C:DRILL (2,121,298.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 1 I Spud Date/Time: 1/3/2002 12:00:00AM I Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA , UWI: / Lat: 070 °19'37.030 "0 Long: 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) Date From - To Hrs' Task 1 Code NPT NPT Depth Phase Description of Operations 1 (hr) 1 (usft) 113:30 - 14:00 0.50 DRILL I N SFAL ! PROD1 ! TEST MUD PUMP #2 TO 4500 -PSI - NO LEAKS. I OPEN EDC & CIRCULATE COIL AT 1 -BPM / 1 I 1450 -PSI. LINE UP ON BYPASS WITH TRIPS SET AT 2000 -PSI. CIRCULATE AT 1 -BPM / 1450 -PSI. BYPASS IS CLEAR. CLOSE EDC. BREAK CIRCULATION AT MIN RATE AND PASS THROUGH WINDOW WITHOUT ISSUE. 14:00 - 14:45 I 0.75 DRILL P PROD1 WIPER BACK TO TD CIRCULATING AT 3.1-BPM I / 3370 -PSI. ! SEE PERIODIC MOTORWORK AND WEIGHT STACKING IN 12,500' CLAY SECTION. 14:45 - 16:00 1.25 DRILL P PROD1 i WIPER UP FROM 12,720' THROUGH ENTIRE 1 !WHITE CLAY SECTION TO CLEAN UP TO 12,200' - SEEING ISOLATED OVERPULLS & LIMITED MOTORWORK. I I TURN AROUND TRY TO WIPER DOWN - 1 STACKING OUT AT 12,282'. ATTEMPT TO WORK PAST BY VARYING PUMP RATE, RUNNING SPEED & ORIENTATION - NO 1 SUCCESS. 1 16:00 - 18:00 2.00 DRILL N DPRB � ; PROD1 DISCUSS SITUATION WITH ENGINEERING I TEAM AND FIELD SUPT. WIPERING TO WINDOW AND SEE PACKOFF AT 11,765'. ATTEMPT TO RIH AND UNABLE TO MOVE. 1 MAINTAIN CIRCULATION AT .5-BPM / .35 -BPM RETURNS. ORIENTING FREELY AND DHWOB !RESPONDING NORMALLY. SLACK OFF TO NEUTRAL WEIGHT ON . DHWOB SENSOR AND STAGE PUMPS UP TO 2.8 -BPM. SEE WEIGHT COME BACK, ESTABLISH FULL RETURNS AND ABLE TO ! RIH. i PUMP 20 -BBLS HI VIS SWEEP AND CHASE AT 2.8 -BPM / 3030 -PSI. 18:00 - 19:00 1.00 DRILL N DPRB 13,498.00 PROD1 I COMPLETE CREW CHANGE. CONTINUE TO RIH AT20 -FPM, CIRCULATING I AT 2.8 -BPM AND FULL RETURNS. ; INCREASE RATE TO 3 -BPM / 3230 -PSI. SOME SMALL WHITE CLAY BALLS AT SWEEP ,RETURNS. PUMP 3 BPM 3248 PSI. CLEANUP BELOW WINDOW FROM 11768'. BACKREAMING TO BELOW WINDOW. PUMP MIN RATE THROUGH WINDOW. _ I NO OVERPULLS. 19:00 - 20:15 1.25 DRILL N I DPRB I 13,498.00 PROD1 OPEN EDC. CIRCULATE MAX RATE. I PUMPING 4 BPM. 3.2 BPM 2900 PSI. I START 35 BBL HI VIS SWEEP DOWN COIL. CIRCULATE HOLE CLEAN ABOVE WINDOW. JET WHIPSTOCK TRAY CLEAN. I CLOSE EDC. Printed 4/2/2013 7:29:28AM . • • ' ii""Ji:Vfy , a�g `k " fir 111.11V,- Wyt..4.-.444449V6MPFV°44AV.4111,'": t Common Well Name: J -17 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 3/11/2013 j End Date: 3/19/2013 X3 -0135K C:DRILL (2,121,298.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 1/3/2002 12:00:00AM 1 Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA I UWI: / Let: 070 °19'37.030"0 Long: 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table ©77.00usft (above Mean Sea Level) Date From - To Hrs Task Code NPT ! NPT Depth I Phase Description of Operations (hr) (usft) 20:15 - 23:00 2.75 DRILL N DPRB 13,498.00 PROD1 P/U WT = 40K. S/O WT = 15K RIH, WORK THROUGH AND CLEANUP LEDGE FROM 12282' TO 12285' • ATTEMPT TO RUN PAST 1ST TIME PUMPING 2.8 BPM. P/U ATTEMPT TO RUN PAST 2 TIMES PUMPING MIN RATE TAGING AT 12284' WITH PUMPS ON REAM AND CLEANUP LEDGE WORKING PAST. RIH TO 12292' PUMPING 2.5 BPM 2850 PSI WITH LITTLE MOTOR WORK, 70 PSI. MAKE SEVERAL PASSES. PUH TO 12270'. WITH PUMPS OFF RIH PAST LEDGE PASSING THROUGH WITH OUT TAGGING. CONTINUE RIH PUMPING 2.8 BPM 3100 PSI. CLEANUP 12306' TO 12313', 12611' START 35 BBL HI VIS SWEEP DOWN COIL AT 13200' TAG TD 2 TIMES AT 13498'. SWEEP OUT OF BIT. 23:30 - 00:00 0.50 DRILL P PROD1 WIPER TO WINDOW, CHASING SWEEP OUT. PUMPING 3.18 BPM 3600 PSI. PVT = 275 BBLS. IA = 100 PSI. OA = 27 PSI. 3/19/2013 00:00 - 01:45 1.75 DRILL P PROD1 CONTINUE TO WIPER TO WINDOW FROM 12700' CHASING SWEEP OUT. PUMPING 3.18 BPM 3600 PSI. TIGHT AT 12685' 10K OVERPULL. WORK THROUGH TIGHT SPOT. TIGHT FROM 12620' TO 12531' WITH 10K OVERPULLS. WORK THROUGH AND CLEANUP TIGHT SPOT. OUT MM PLUGGING OFF. CLEAR MM. PLUGGING WITH SMALL BALLS WHITE CLAY WITH SAND. PULL THROUGH WINDOW WITH PUMP OFF. CLEAN PASSING THROUGH WINDOW 01:45 - 03:00 1.25 DRILL P PROD1 CIRCULATE WITH OPEN EDC ABOVE WINDOWAT 11719' PUMP 35 BBL HI VIS SWEEP DOWNHOLE. PUMP 3.5 BPM 3200 PSI. CLOSE EDC. PVT= 257 BBLS. IA = 104 PSI. OA = 29 PSI. 03:00 - 04:15 1.25 DRILL P PROD1 I RIH PUMPING 2.5 BPM 2950 PSI. WITH BOBBLE AT 12525' AND 12616'. BYPASS REEL SCREENS. PUMP 8.6 PPG LINER PILL WITH ALPINE BEADS. TAG TD AT 13498' WITH LINER PILL AT BIT, 04:15 - 05:00 0.75 DRILL P PROD1 I POH. TIGHT P/U OFF BOTTOM WITH 10K OVERPULL. LAYING IN LINER PILL. LINE BACK ON REEL SCREENS. SEEN SHALE AT 12550' POP THROUGH WITH 5K OVERPULL. 1 PUMP OFF PASSING THROUGH WINDOW. • Printed 4/2/2013 7:29:28AM � ° � � "� F y n „ V � fr �k X 'k `:� o pera n S u re. 4 Common Well Name: J -17 AFE No Event Type: RE- ENTER- ONSHORE (RON) Start Date: 3/11/2013 I End Date: 3/19/2013 X3 0135K- C:DRILL (2,121,298.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °19'37.030 "0 Long: 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table ©77.O0usft (above Mean Sea Level) Date From - To Hrs Task Code I NPT ! NPT Depth Phase Description of Operations (hr) (usft) 05:00 09:30 4.50 DRILL P PROD1 OPEN EDC. DISPLACE WELL TO 1% KCL WITH 2% LO -TORQ AND 2% 776 WITH .25 PPB FLOVIS. PAINT EOP FLAG AT 10,700' EOP DEPTH (WHITE) AND AT 8900' EOP DEPTH (YELLOW). CONTINUE TO POH CIRCULATING THROUGH OPEN EDC AT 2.78 -BPM / 1180 -PSI. MAKE 200' JOG AT SURFACE. IA/ OA = 62 -PSI / 13 -PSI. 09:30 - 10:00 0.50 DRILL P PROD1 FLOW CHECK WELL- NO FLOW. HOLD PJSM ON LD BHA. DISCUSS POSITIONS OF PEOPLE, ORDER OF OPERATIONS, WELL CONTROL 1 CONSIDERATIONS. 10:00 - 10:30 0.50 DRILL P PROD1 UNSTAB INJECTOR AND SET BACK OVER CIRC HOLE. BLOW DOWN BHI TOOLSTRING. LD LATERAL DRILLING BHA. GRADE BIT 5- 4- RO- A- X- 1- BT -TD. ALSO BIT WAS BALLED UP WITH WHITE CLAY. 10:30 - 10:45 0.25 BOPSUR P PROD1 FUNCTION TEST BOPE FROM RIG FLOOR PANEL. NO ISSUES NOTED WITH FUNCTION TEST. 110:45 - 11:00 0.25 BOPSUR P PROD1 RD BHI UQC. Printed 4/2/2013 7:29:28AM • 0 #, - s , . :, , : kut . 1 e gy : '4- r ye , '- l" 45 a t ® ma & a , f i i iiii f s ms x r I 1. 4 � ' � ' .; : ZAl G ; ' '`.° , fi s = s s . e. Common Well Name: J -17 AFE No Event Type: COM- ONSHORE (CON) Start Date: 3/19/2013 End Date: 3/22/2013 X3 -0135K C:DRILL (1,176,312.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name/No.: NORDIC 1 ! Spud Date /me: 1/3/2002 12:00:00AM I Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °19'37.030"0 Long: 1 0148°50'38.023"W Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) Date From - To Hrs I Task Code NPT NPT Depth Phase Description of Operations 1 (hr) (usft) 3/19/2013 11:00 - 11:30 0.50 CASING P RUNPRD HOLD PJSM ON PUMPING OUT E -LINE SLACK BOOT E -LINE. 1 1 MU NOZZLE TO CTC. STAB INJECTOR ON WELL & ESTABLISH CIRCULATION AT .95 -BPM / 260 -PSI. INCREASE RATE TO 3.8 -BPM / 2000 -PSI AND HEAR WIRE MOVING. SURGE X2 AND NO 1 MORE MOVEMENT HEARD. i 1 UNSTAB INJECTOR. RECOVER 200' OF 1 1E-LINE (255' ANTICIPATED). 11:30 - 12:00 0.50 CASING P ! RUNPRD !CUT OFF CTC. 1 I RU HYDRAULIC COIL CUTTER. 1 ! !CUT 100' OF COIL FOR CHROME 1 MANAGEMENT. 1 RD HYDRAULIC COIL CUTTER. 12:00 - 13:00 1.00 1 CASING !i P RUNPRD MU BTT CTC. 1 PULL TEST TO 40K -LBS. 1 1 !PRESSURE TEST TO 3800 -PSI. GOOD TESTS. 113:00 - 14:00 1.00 BOPSUR P RUNPRD MU STINGER & SWIZZLE STICK. PU INJECTOR & STAB ON WELL. FLUID PACK COIL. CLOSE MASTER & SWAB VALVES. TEST LUBRICATOR TO 250 -PSI / 3500 -PSI FOR 5- CHARTED MIN PER TEST. GOOD TESTS. OPEN UP WELL TO CLOSED CHOKE & INNER REEL VALVE - NO PRESSURE. FILL WELL WITH 1.4 -BBLS. 14:00 - 14:30 0.50 [ CASING 1 N SFAL ! RUNPRD PREP TO PUMP 3/4" DRIFT BALL- BALL DROP LO TORQ ISOLATION VALVE HAS -1 -CUP CEMENT IN IT. CLOSE INNER REEL VALVE & CIRC ACROSS I TOP OF WELL TO MONITOR. 1 CHANGE OUT BALL DROP LO TORQ 1 i ISOLATION VALVE. ! 1 TEST BALL DROP LO TORQ ISOLATION VALVE TO 250 -PSI / 3500 -PSI. GOOD TEST. BRING ALL LINER COMPONENTS TO RIG FLOOR WHILE TESTING VALVE. 14:30 - 15:00 0.50 CASING 1 P RUNPRD PUMP 3/4" DRIFT BALL. , ; LAUNCH WITH 1000 -PSI AND CHASE AT 3.16 -BPM / 1420-PSI. HEAR BALL ROLLING IMMEDIATELY. BALL I APPEARS TO LAND AT 51.3 -BBLS PUMPED (BALL NO LONGER HEARD IN REEL HOUSE) VS COIL VOLUME OF 54.5 -BBLS. UNSTAB INJECTOR, LD SWIZZLE NOZZLE, I RECOVER BALL BELOW CTC. SET INJECTOR BACK OVER CIRC HOLE ON __ LEGS. 15:00 - 16:00 1.00 CASING P RUNPRD RU TO RUN 2 -7/8" X 3-1/4" X 3-1/2" LINER. RU ALL HANDLING EQUIPMENT, SET UP 1 SAFETY JOINT, RU FARR TONGS. WHILE RIGGING UP, SEAT VALVES IN MP #1. WSL, TOOLPUSHER, NORDIC DRILLER & BTT REP CONFIRM PIPE LAYOUT IN PIPE SHED & RUNNING ORDER. Printed 4/2/2013 7:30:04AM i • • � ' st z X'' Yt Common Well Name: J -17 AFE No Event Type: COM- ONSHORE (CON) Start Date: 3/19/2013 I End Date: 3/22/2013 X3 -0135K C:DRILL (1,176,312.00 ) Project: Prudhoe Bay 1 Site: PB J Pad Rig Name/No.: NORDIC 1 Spud Date /me: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 „ Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 ° 1937.030 , 0 Long: 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table ©77.00usft (above Mean Sea Level) Date From - To I Hrs Task I Code I NPT NPT Depth Phase I Description of Operations (hr) (usft) 16:00 - 16:30 0.50 CASING P RUNPRD HOLD PJSM WITH RIG CREW, WSL, TOOLPUSHER & BTT REP ON RUNNING 1 PRODUCTION LINER. DISCUSS RUNNING ORDER, PIPE COUNT, HAZARDS ASSOCIATED WITH WORKING IN THE PIPE SHED WITH A FILL IN HAND FROM RIG 2, PROPER MU TORQUE, WELL CONTROL CONSIDERATIONS (SAFETY JT), USING TEH 3-1/4" ELEVATORS FOR THE FIRST TIME AND HAZARDS ASSOCIATED WITH REPETITIVE ACTIVITY. 16:30 - 17:15 0.75 CASING P 1 RUNPRD RUN PRODUCTION LINER PER RUNNING ORDER. SHOE TRACT CONSISTS OF 2 -3/8" BULLNOSE, 2 -3/8 "STL PUP JT, 2 -3/8" 1 -DEG BENT SUB, 2 -7/8" STL B X 2 -3/8" STL P, R &R INDEXING TOOL, 2 -7/8" PUP JT, FLOAT COLLAR, 1 -JT OF 2 -7/8" L -80 STL LINER, FLOAT COLLAR, 2 -7/8" STL PUP JT, LANDING COLLAR, 2 -7/8" STL PUP JT AND 2 -7/8" STAGE COLLAR PINNED FOR 4K -PSI. CONTINUE TO RIH WITH 11 -JTS OF 2 -7/8" L -80 STL 6.40#/FT LINER. DRIFT EACH 2 -7/8" STL CONNECTION - NO ISSUES. USE JET LUBE SEAL GUARD ON ALL CONNECTIONS. 17:15 - 18:00 0.75 CASING P RUNPRD CHANGE OUT HANDLING EQUIPMENT FOR 3 -1/4 ". CONTINUE TO RUN 3- 3/16" TCII W/ 3-1/4" L80 STL 6.60 # /FT LINER JTS. DRIFT FIRST 5 -JTS OF 3 -1/4 ". NO ISSUES. ** *SIMOPS - CTS PERFORMING OIL FLUSH ON GEARBOX * ** 18:00 - 19:00 1.00 CASING P RUNPRD CONDUCT CREW CHANGE AND WSL HAVE QUALITY HANDOVER. WSL, NORDIC DRILLER AND TOOLPUSHER REVIEW LINER RUNNING ORDER, COUNT & VERIFY JOINTS LEFT IN PIPESHED AND CHECK SAFETY JOINT. 19:00 - 19:15 0.25 CASING P RUNPRD HOLD PJSM WITH ALL CREWS INVOVLED. SINCE CREW HAS NEW CREW MEMBERS, EMPHASIZE GOOD COMMUNICATION AND CLEAR ROLES & RESPONSIBILITIES. DISCUSS THE HAZARDS OF OVERHEAD I LOADS WHEN MU LINER AS WELL AS WELL CONTROL AND PERSONAL SAFETY. 19:15 - 20:30 1.25 CASING P RUNPRD CONTINUE MAKING UP 3-1/4" L80 STL 1 6.60# /FT LINER WITH 3- 3/16" TCII- CONNECTIONS FROM JOINT #30. AGAIN DRIFT FIRST FIVE LINER - JOINTS WITHOUT ISSUES. 20:30 - 20:45 0.25 CASING P RUNPRD STOP TO FILL LINER HALF WAY THROUGH WITH WATERHOSE. 20:45 - 22:30 1.75 CASING P RUNPRD COMPLETE MAKING UP 75 JOINTS OF 3-1/4" LINER. 22:30 - 00:00 1.50 CASING P I RUNPRD CHANGE LINER HANDLING EQUIPMENT FOR RUNNING 3.5" LINER AND MAKE UP 12 JOINTS OF 3-1/2" L80 STL 9.30# /FT LINER. Printed 4/2/2013 7:30:04AM • • ;: t 2 ,, , a f a(a" 4 `S O f 9 x+ F s :'; �� g :' ; ' ,' � L * :�� - , •¢ £ ^'' rei i E / q 1 0 d 1 6 j B 9 TtlS1 i -,r L. - } Common Well Name: J -17 AFE No Event Type: COM- ONSHORE (CON) Start Date: 3/19/2013 I End Date: 3/22/2013 X3- 0135K- C:DRILL (1,176,312.00 ) 1 Project Prudhoe Bay Site: PB J Pad Rig Name/No.: NORDIC 1 Spud Date/Time: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 Rig Contractor. NORDIC CALISTA UWI: / Lat: 070 °19'37.030 "0 Long: 014550'38.023 "W Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) Date I From - To I Hrs Task Code NPT I NPT Depth Phase Description of Operations (hr) (usft) I 3/20/2013 1 00:00 - 01:15 1.25 I CASING P ' RUNPRD I CONTINUE MU 12 JTS 3-1/2" STL L -80 LINER. I SWAP JOINT #87 WITH JOINT #98 DUE TO DAMAGED BOX END. MU 3.T' X 3.0" P110 !DEPLOYMENT SLEEVE W/ 4" GS PROFILE, I SELRT, DISCO, & 6 JTS 2 -3/8" PH6. RIG 1 DOWN LINER HANDLING EQUIPMENT. PU I !INJECTOR & STAB ON TO WELL. 01:15 - 01:30 I 0.25 I CASING P RUNPRD I PT QTS LOW TO 500 PSI & HIGH TO 3500 PSI. BOTH PT'S PASSED. SET PUMP TRIPS TO 1000 PSI. I MEANWHILE START FILLING LINER WITH I `COIL. ' 01:30 - 02:00 i 0.50 CASING P I RUNPRD FILL LINER W/ 14 BBLS OF 1% KCL BEFORE I RIH W/ BHA #5 (LINER RUNNING BHA). CIRC I I PRESSURE 300 PSI. 02:00 04:00 1 2.00 CASING I P I RUNPRD START RIH W/ BHA #5 (LINER RUNNING BHA) I @ 100 FPM. PVT = 122 BBLS / CIRC I , I PRESSURE 310 PSI @ 0.30 BPM 1 I MM IN 0.30 BPM / MM OUT 0.83 BPM / MM IN _ i DENSITY 8.4 PPG / MM OUT DENSITY 8.3 PPG 04:00 - 04:30 0.50 1 CASING P f RUNPRD I SEE WINDOW -FLAG AT 11,529.36'. APPLY ! I DEPTH CORRECTION TO 11,510.00' AND [CONTINUE RIH. I j ; MEANWHILE START TO GET SCHLUMBEGRER I CEMENTING TRUCKS SPOTTED AND RIGGED I i UP. 04:30 - 04:45 0.25 1 CASING P � RUNPRD I KEEP RIH WITH -14K LBS SOW. AT 12,635' STACK OUT COILED TUBING WEIGHT. PU UP TO 48K LBS AND MANAGE TO 1 RUN PAST RESTRICTION. 1 04:45 - 05:20 0.58 CASING 1 P RUNPRD ; KEEP RIH AND SEE TD -FLAG AT 13,310' JUST AS EXPECTED. CONTINUE RIH, HOWEVER S ISSUES ONWARDS FROM - 13, 385'. WORK TO SEE COIL DOWN TO 13,445'. PICK UP 100FT AND MANAGE TO GET DOWN TO 13,485' ' (ANTICIPATED TD = 13,498'). 05:20 - 06:00 0.67 CASING P RUNPRD CONTINUE WORKING COIL TO GET PAST 113,485'. PU MULTIPLE TIMES TO MANIPULATE THE R &R INDEXING TOOL. HOLE IS VERY TIGHT, SEE PUW MOSTLY AROUND 48K LBS I I BUT ALSO AS HIGH AS 60K LBS. I PU TO 13,312', RUN BACK IN HOLE AND DO NOT GET PAST 13,485'. 06:00 - 07:30 1.50 CASING P RUNPRD I PERFORM RIG CREW CHANGE& SLB CHANGEOUT. DISCUSS LINER POSITION WITH ODE & GET ASSET APPROVAL TO CONTINUE FORWARD I I WITH SHOE AT 13,485 / LINER TOP AT 10,979'. Printed 4/2/2013 7:30:04AM • S • q f a rts < '� --. -w onyx gati�F .. , w - ' Ze.T } � - -V43 4I 9 A Common Well Name: J -17 I AFE No Event Type: COM- ONSHORE (CON) I Start Date: 3/19/2013 End Date: 3/22/2013 X3 -0135K C:DRILL (1,176,312.00 ) Project: Prudhoe Bay I Site: PB J Pad Rig Name/No.: NORDIC 1 Spud Date/Time: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA UWI: / Let: 070 °19'37.03170 Long: 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table t77.00usft (above Mean Sea Level) Date From - To Hrs I Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 07:30 - 08:30 1.00 CEMT P RUNPRD HOLD PJSM WITH SLB CREW ON PRESSURE TESTING CEMENT LINE. DISCUSS FREEZE UP TIME (15 -MIN TO FIRST ICE) & MITIGATIONS, TEST PROCEDURE, CLEAR & CONCISE COMMUNICATION, HAZARDS OF HIGH PRESSURE TESTING. CEMENTERS PUMP 10 -BBLS KCL TO WARM LINES. TEST CEMENT LINE TO 250 -PSI / 6000 -PSI PER LEAK TIGHT TESTING CRITERIA IN WELL PLAN. GOOD TESTS. BLOW DOWN CEMENT LINE WITH AIR. * *MIX 20 -BBLS 1% KCL SPACER IN PIT 4 ** 08:30 - 09:00 0.50 CASING P RUNPRD BTT REP CHANGEOUT. CIRCULATE AT .41 -BPM / 220 -PSI. CONTINUE TO MIX 1% KCL SPACER. REPEAT BLOW DOWN CEMENT LINE WITH AIR. 09:00 - 10:30 1.50 CASING P RUNPRD CONFIRM BREAKOVER WEIGHT / DEPTH AT 44K -LBS / 13475' - REPEAT TWICE. POOR BALL DROP POSITION ON BOTTOM. PU TO 13,461'. LOAD 5/8" BALL. PRESSURE TO 1000 -PSI & LAUNCH BALL. PUMP 2 -BBLS AT 2 -BPM / 1250 -PSI. HEAR BALL ROLLING. REDUCE PUMP RATE TO MIN AND WORK LINER BACK TO BOTTOM & SET DOWN 10K -LBS ON LINER AT 13,485' TO MAINTAIN COMPRESSION. CHASE BALL AT 1 -BPM / 1700 -PSI, INCREASING TO 1.3 -BPM / 1890 -PSI AND THEN 1.75 -BP / 2830 -PSI AND THEN 2 -BPM / 2890 -PSI. SOME EVIDENCE OF SLIGHT PACKING OFF - SLOW RESPONSE IN OUT RATE WITH PUMP INCREASE. DO NOT HEAR BALL IN REEL HOUSE WITH 29 -BBLS AWAY. WITH 38 -BBLS AWAY (70% COIL VOLUME) REDUCE RATE TO .8 -BPM / 500 -PSI. I BALL LANDS AT 52.8 -BBLS AWAY. PRESSURE UP AND SEE BALL SEAT SHEAR AT 3940 -PSI. REDUCE RATE AND CIRC AT .5-BPM / 300 -PSI. PU AND SEE BREAKOVER AT 13,476' / PU WT = 37K -LBS. LINER IS RELEASED. STACK BACK DOWN 10K -LBS TO 13485'. 10:30 - 11:00 0.50 CASING P RUNPRD CONTINUE TO CIRCULATE AT .5 -BPM / 320 -PSI WITH FULL RETURNS. TOP OFF RIG WATER TANK. GET PUMP RATES / PRESSURES FOR CEMENT JOB. 1 -BPM / 890 -PSI. 1.5 -BPM / 1100 -PSI. 11:00 - 11:30 0.50 CEMT P RUNPRD HOLD PJSM WITH RIG CREW, SLB CMT, CH2MHILL ON PUMPING CEMENT JOB. HIGHLIGHT HIGH PRESSURE PUMPING HAZARDS, CLEAR & CONCISE COMMUNICATION, STOPPING THE JOB IF ANYTHING GOES DIFFERENTLY THAN PLANNED, CONTINGENCY PLANS FOR HIGH PRESSURES OR PLUGGED BYPASS, AND ORDER OF FLUIDS PUMPED. Printed 4/2/2013 7:30:04AM 0 . ` ny -,- v: :- %., - . 7'7 — -Gws- is ), 0` P#: s Common Well Name: J -17 I AFE No Event Type: COM- ONSHORE (CON) Start Date: 3/19/2013 1 End Date: 3/22/2013 IX3- 0135K- C:DRILL (1,176,312.00 ) 1 I I Project: Prudhoe Bay ' Site: PB J Pad Rig Name/No.: NORDIC 1 1 Spud Date/Time: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 Rig Contractor. NORDIC CALISTA 1 UWI: / Lat: 070°19'37.030"0 Long: 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) Date i From - To 1 Hrs I Task Code NPT I NPT Depth Phase 1 I1 Description of Operations I (hr) I : (usft) 1 11:30 - 12:30 1.00 CEMT P RUNPRD ' BATCH UP 36 -BBLS 15.8 -PPG CLASS G I 1 I CEMENT WITH YIELD = 1.17- FT3 /SK. 1 1A / OA / PVT = 50-PSI / 2 -PSI / 157 -BBLS. 112:30 - 14:36 2.10 CEMT P RUNPRD I PUMP 10 -BBLS 8.5 -PPG 1% KCL SPACER WITH RIG PUMP. FEED 5-BBLS OF 8.5 -PPG 1% KCL SPACER TO I i UNIT. LINE UP DOWN COIL. CEMENTERS PUMP KCL SPACER FOLLOWED BY 24.5 -BBLS 15.8 -PPG CLASS G CEMENT. DISPLACE CEMENT WITH 1.5 -PPB POWERVIS CONTAMINANT FLUID AT 1.5 -BPM. SLOW TO 1 -BPM WITH INTERFACE AT SELRT I FOR 2 -BBLS. RESUME DISPLACEMENT AT 1.5 -BPM. ZERO OUT MM WHEN CEMENT AT SHOE. 1 WITH 2 -BBLS CEMENT LEFT IN COIL- SHUT I DOWN PUMP, PU TO 13,464', THEN STACK 1 DOWN 10K -LBS AT 13,476'. PRESSURE UP TO 800 -PSI TO LAUNCH PEEWEE. PU AND SIDE 1 EXHAUST 2 -BBLS CEMENT & 3-BBLS I CONTAMINANT. SET BACK DOWN TO 13,476'. PRESSURE UP AND SHEAR LWP AT 3600 -PSI. CHASE WITH CEMENT CONTAMINANT AT 1.25 -BPM. SEE i PLUG BUMP AT 18.9 -BBLS PUMPED. CIP AT I 1436 -HRS. 1 14:36 - 15:00 0.40 CEMT P j RUNPRD OPEN BAKER CHOKE AND CHECK FLOATS - 1 FLOATS HOLDING. UNSTING FROM LINER BUT PRESSURE 1 ' DOESNT BLEED OFF - INDICATES CEMENT I ABOVE LINER TOP. STOP AT 13,460' AND I CIRCULATE 5-BBLS AT .6-BPM / 970 -PSI TO ' CONTAMINATE CEMENT NEAR LINER TOP. 1 , TOTAL CEMENT BEHIND PIPE = 21.8 -BBLS. TOC = TOL ,15:00 - 17:15 1 2.25 CASING P 1 RUNPRD POH WITH LINER RUNNING TOOL, 1 CONTAMINATING CEMENT WITH 1.5 -PPB 1 1 I I I POWERVIS MIXED IN 8.4 -PPG FRESH WATER. CIRCULATE AT .9 -BPM / 890 -PSI AND POH AT I j 85-FPM TO MAINTAIN .5-BPM RETURNS. 17:15 18:00 0.75 CEMT P RUNPRD FLOW CHECK WELL - NO FLOW. HOLD PJSM ON LD LINER RUNNING BHA. 1 DISCUSS POSITIONS OF PEOPLE, EQUIPMENT HANDLING, WELL CONTROL CONSIDERATIONS AND OFFLOADING OF I I TOOLS FROM RIG FLOOR. 1 UNSTAB INJECTOR, CUT OFF CTC & SET I BACK OVER CIRC HOLE ON LEGS. 18:00 - 18:45 0.75 CASING P i RUNPRD PERFORM CREW CHANGEOUT. CLEAN & CLEAR RIG FLOOR FOR CLEANOUT RUN. 18:45 - 19:30 0.75 EVAL P OTHCMP PICKUP INJECTOR AND MU BAKER CTC. INSTALL TEST -PLATE AND PULL -TEST CONNECTOR TO 40K LBS. PERFORM PRESSURE -TEST TO 3500 PSI. GOOD PT. Printed 4/2/2013 7:30:04AM • se -V IT . +r:.s.er ,�'t+'''�mu.,, s.- ... -3�a _,.- .'a,:�,�°..a =: r.'�. . , �."�.'�:_uroo- -:tt �,,,.��`r...•:,:.,a.. ° Common Well Name: J -17 1 AFE No 176 1 Event Type: COM- ONSHORE (CON) Start Date: 3/19/2013 1 End Date: 3/22/2013 X3- 0135K- C:DRILL (1,176,312.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 1 Spud Date /me: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA UWI: / Lat: 070 °19'37.030"0 Long: 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) Date 1 From - To Hrs Task Code NPT NPT Depth Phase j Description of Operations (hr) (usft) 119:30 - 20:15 0.75 EVAL P OTHCMP I MU NORTHERN SOLUTIONS SWIVEL. ENSURE 3/8 ", 1/2" & 5/8" BALLS DROP THROUGH APPROPRIATE SEATS & LAND ON APPROPRIATE SEATS. INSPECT 2 1/8" !MOTOR - LOOKS GOOD. LAY OUT SAFETY JOINT XO'S ON RIG FLOOR FOR IMMEDIATE USE IF NEED BE FOR 1 -1/4" & 2- 1/16" CSH. PU SLB LOGGING TOOLS TO RIG FLOOR. 20:15 - 20:30 0.25 EVAL P OTHCMP I HOLD PJSM & DISCUSS ASSOCIATED I HAZARDS WITH CLEANOUT /LOGGING RUN I INCLUDING: WORKING WITH SUSPENDED LOADS, HAND & BODY PLACEMENT, PINCH 1 POINTS & WORKING WITH SOURCE TOOLS ION THE FLOOR MAKING SURE TO BLOCK ENTRANCE TO RIG FLOOR & CELLAR AS WELL AS STAYING CLEAR OF SOURCE. ALSO DISCUSSED MAKING SURE TO KEEP A CLOSE EYE ON WEIGHT INDICATOR WHILE RUNNING LOGGING TOOLS. 20:30 - 22:30 2.00 EVAL P OTHCMP MU BHA #6 (CLEANOUT /LOGGING BHA). PU INJECTOR & STAB ON TO WELL. PT QTS LOW TO 500 PSI / 5 MIN & HIGH TO 3500 PSI / 5 MIN. BOTH TESTS PASSED. 22:30 - 00:00 1.50 EVAL P OTHCMP RIH W/ BHA #6 (CLEANOUT /LOGGING BHA) @ 75 FPM. PVT = 317 BBLS IAP = 46 PSI / OAP = 0 PSI CIRC P 350 PSI MM IN 0.30 BPM / MM OUT 0.70 BPM MM IN DENSITY 8.39 PPG / MM OUT DENSITY 8.44 PPG 3/21/2013 00:00 - 03:30 3.50 EVAL P OTHCMP CONTINUE RIH W/ BHA #6 & BEGIN LOGGING MCNL/GR /CCLAT 9,900' AT 30 FPM. AT 00:45 HRS SLB CEMENT LAB NOTIFIED US THAT UCA TEST RESULTS SHOW CEMENT WITH 816 PSI COMPRESSIVE STRENGTH - OK TO ENTER LINER. PVT = 175 BBLS (TOOK 206 BBLS CONTAMINATED CEMENT RETURNS TO CUTTINGS BOX) IAP =51 PSI /OAP =0 PSI CIRC P 1556 PSI MM IN 1.53BPM /MMOUT1.63BPM MM IN DENSITY 8.42 PPG / MM OUT DENSITY 8.46 PPG SWAP TO PIT 4 SO PERF PILL IS AT BIT WHEN START POOH. TAG UNCORRECTED PBTD @ 13,452.56'. 03:30 - 06:45 3.25 EVAL P I OTHCMP POOH W/ CLEANOUT /LOGGING BHA. LAY IN 33 BBL PERF PILL. SWAP BACK TO KCL. PAINT EOP PBTD FLAG @ 12,640' (13,339' BIT DEPTH) & EOP FLAG @ 9,379' (10,179' BIT DEPTH) . 06:45 - 07:00 0.25 EVAL P i OTHCMP FLOW CHECK WELL AT 200' - NO FLOW. HOLD PJSM ON LD LOGGING / CLEANOUT BHA. DISCUSS 1 -1 /4" CSH HANDLING, WELL CONTROL CONTINGENCIES, HAZARDS & MITIGATIONS WITH SOURCE HANDLING. Printed 4/2/2013 7:30:04AM • . te t < :, " C a r, �:gy - " ��3 r�° 7,r 1 .1,-,..-1,--, t 47; Y1 1 C ' ' r l ° 1 ,r r s , , s � ,, . ": Common Well Name: J -17 I AFE No Event Type: COM- ONSHORE (CON) Start Date: 3/19/2013 I End Date: 3/22/2013 X3 -0135K C:DRILL (1,176,312.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA , UWI: / Lat 070 °19'37.030 "0 Long: 1 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) Date I From - To Hrs Task ! Code I NPT NPT Depth Phase I Description of Operations I (hr) 1 (usft) 107:00 - 08:30 1.50 EVAL P I OTHCMP I UNSTAB INJECTOR & SET BACK OVER CIRC HOLE ON LEGS. j I LD 2 -JTS OF 2 -1/16" CSH TO PIPE SHED. I STAND BACK 9-STDS OF 1 -1/4" CSH. CLEAR RIG FLOOR AND UNLOAD SOURCE. LD ALL LOGGING TOOLS TO GROUND. 08:30 - 09:30 1.00 BOPSUR j P OTHCMP I PU INJECTOR & STAB ON. 1 1 JET BOP STACK AT 2 -BPM / 850 -PSI X3 PASSES. j ' UNSTAB INJECTOR AND SET BACK OVER I CIRC HOLE. I GREASE CREW SERVICE TREE VALVES. CONFIRM POST JOB UCA IS SHOWING >1500 -PSI COMPRESSIVE STRENGTH. 09:30 - 10:30 1.00 'j EVAL P OTHCMP j RU AND PERFORM LINER LAP TEST. 1 I TEST TO 250 -PSI / 5-MIN AND 2400 -PSI / '30 -MIN. j I PUMP .4 -BBLS TO ACHIEVE 250 -PSI. GOOD, !FLAT LINE LOW PRESSURE TEST. I PUMP 2.1 -BBLS TO ACHIEVE HIGH TEST ! I PRESSURE OF 2400 -PSI. HOLD HIGH PRESSURE TEST FOR 5-MIN WITH LOSS OF 428 -PSI. BUMP UP WITH .5 -BBLS TO ACHIEVE TEST PRESSURE OF 2400 -PSI AGAIN. 1 i � ;HIGH TE I HOLD HIGH PRESSURE TEST FOR 5- MINUTES ' WITH LOSS OF 370 -PSI. LINER LAP TEST FAILED. BLEED OFF PRESSURE AND RD TEST _ EQUIPMENT. 10:30 - 11:00 0.50 EVAL P . I OTHCMP I REVIEW MCNUGR /CCL DATA. CONFIRM THAT I DEPTH CORRELATION CAN BE MADE. VAC OUT CUTTINGS BOX WITH SUPER SUCKER. 11:00 - 12:00 1.00 PERFOB P i OTHCMP I HOLD PJSM AND LOAD GUNS INTO PIPE I SHED. I i I BRING IN ALL GUN HANDLING EQUIPMENT. j F RU RIG FLOOR FOR RUNNING PERF GUNS. 12:00 - 13:00 1.00 1 PERFOB P OTHCMP RUN 10-2" 6SPF 2006PJ PERF GUNS. MU FIRING HEAD. 113:00 - 14:00 1.00 PERFOB P OTHCMP FINISH MU PERFORATING BHA WITH HIGH LOAD DISCONNECT (1/2" BALL), XO, 5-STDS OF 1 -1/4" CSH, MARKER JT, 4-STDS OF 1 -1/4" 1 I CSH, XO, DISCONNECT (5/8" BALL), DPBV, XO, 2-JTS OF 2- 1/16" CSH, SLIMLINE SWIVEL, AND CTC. OAL = 855.51'. PU INJECTOR, MU COIL TO BHA & STAB ON WELL. ! TEST QTS TO 250 -PSI / 3500 -PSI. ESTABLISH I CIRCULATION AT .3-BPM / 110 -PSI. Printed 4/2/2013 7:30:04AM • gi p` s I f i t G ' ®rs -n"" "' -r' TNIO Common Well Name: J -17 AFE No Event Type: COM- ONSHORE (CON) Start Date: 3/19/2013 End Date: 3/22/2013 X3- 0135K- C:DRILL (1,176,312.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 1 1 Spud Date/Time: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 Rig Contractor: NORDIC CALISTA UWI: / Lat 070 °19'37.030"0 Long: 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table ©77.00usft (above Mean Sea Level) Date From - To Hrs ! Task I Code NPT NPT Depth Phase Description of Operations (hr) (usft) 14:00 - 17:30 3.50 PERFOB P OTHCMP RIH WITH PERFORATING BHA. CIRCULATE AT .25 -BPM / 130 -PSI. I HOLD KWT DRILL WITH RIG CREW WHILE RIH WITH PERF BHA. CREW PERFORMS STANDING ORDERS TO SECURE WELL FLAWLESSLY BUT IS THEN TOLD THAT THERE IS STILL FLOW FROM THE WELL EVEN WITH THE HCR SHUT. MOTORMAN CONFIRMS KOOMEY FUNCTION OK AND CELLAR CONFIRMS HCR HAS FUNCTIONED. GATHER CREW FOR AAR & DISCUSSION OF PATH FORWARD IF HCR IS LEAKING. ! DISCUSS OPTIONS FOR SECURING WELL - CLOSE MANUAL VALVE, VBRS TO SECURE j _ ! WELL FOR VALVE REPLACEMENT. LOTS OF LIVELY DISCUSSION AND CREW LEFT WITH A BETTER UNDERSTANDING OF A RESPONSE TO THIS SITUATION. CORRECT DEPTH AT 9480.75' CORRECTED EOP FLAG. SEE FLAG AT AT 10,336.49' ON CTDS DEPTH. CORRECT DEPTH TO 10,336.26'. .CONTINUE TO RIH WITH PERFORATION BHA. WT CHECK AT 13,375'. PU WT = 37K -LBS, RIH WT = 14K -LBS. TAG TD & PU TO NEUTRAL AT 13,447.18' ON CTDS. CORRECT DEPTH TO CORRECTED PBTD FROM MEMORY LOG OF 13,450.6' (PLUS 3.42' CORRECTION). 17:30 - 18:00 0.50 PERFOB P ! OTHCMP PU TO POSITIONS GUNS JUST BELOW PERF INTERVAL WITH BOTTOM AT 13,383'. MAKE PRACTICE FIRING SEQUENCE TO GET HI / LO PARAMETERS. .5 -BPM / 410 -PSI & 1.74 -BPM / 1880 -PSI. PERFORM TCP E -FIRE SEQUENCE AND PU TO DRIVE BY FIRE GUNS. GOOD INDICATION ON SHOT DETECTION, COIL WEIGHT JUMP AND LOSS OF RETURNS. 18:00 - 19:10 1.17 PERFOB P OTHCMP POH HOLDING 200 -PSI BACK PRESSURE. 19:10 - 22:15 3.08 PERFOB P OTHCMP PULL TO 10,880' AND CONDUCT 30 MIN FLOWCHECK - NO FLOW. START PUMPING & SEE IMMEDIATE RETURNS - NO LOSSES. CONTINUE POOH. 22:15 - 22:45 0.50 PERFOB P OTHCMP STOP POOH AT 1080' AND CONDUCT 30 MIN FLOW CHECK- NO FLOW. START PUMPING & SEE IMMEDIATE RETURNS - NO LOSSES. 22:45 - 23:00 0.25 PERFOB P OTHCMP HOLD PJSM FOR STANDING BACK CSH & DISCUSS HAZARDS INCLUDING: WORKING AT HEIGHTS - MITIGATE DROPPED OBJECTS & INSPECT HARNESS, HAND & BODY PLACEMENT & WELL CONTROL CONTINGENCIES. 23:00 - 00:00 1.00 PERFOB P OTHCMP UNSTAB & PU INJECTOR. UNSTAB COIL & STAND INJECTOR BACK LD 2 JTS OF 2 1/16" CSH & STAND BACK 18 JTS OF 1 -1/4" CSH. 3/22/2013 00:00 - 00:30 0.50 PERFOB P OTHCMP COMPLETE STANDING BACK 18 JTS OF 1 -1/4" CSH, THEN SLB TCP SPECIALISTS LAY DOWN FIRING HEAD. Printed 4/2/2013 7:30:04AM • • Common Well Name: J -17 I AFE No Event Type: COM- ONSHORE (CON) Start Date: 3/19/2013 End Date: 3/22/2013 X3- 0135K- C:DRILL (1,176,312.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name/No.: NORDIC 1 Spud Date/Time: 1/3/2002 12:00:00AM Rig Release: 3/23/2013 Rig Contractor. NORDIC CALISTA UWI: / Lat: 070 °19'37.030"0 Long: 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table ©77.00usft (above Mean Sea Level) Date II From - To Hrs I Task Code ! NPT NPT Depth Phase j Description of Operations (hr) _ (usft) 00:30 - 00:45 0.25 PERFOB P OTHCMP HOLD PJSM WITH ALL NORDIC CREWS BEFORE LAYING DOWN PERF GUNS. DISCUSS HAZARDS OF SHARP EDGES ON GUNS AND FLUIDS LEFT INSIDE GUNS. ALSO DISCUSS THE POTENTIAL OF FURTHER TRAPPED PRESSURE IN GUNS. 1 00:45 - 01:20 0.58 PERFOB P I OTHCMP I COMPLETE LAYING DOWN PERFORATING BHA (BHA #7). ALL GUNS HAVE FIRED, NO PROBLEMS IDENTIFIED. 1 01:20 - 02:15 0.92 PERFOB P 1 OTHCMP CLEAN RIGFLOOR AND DRAIN GUNS. BUNDLE UP SPENT GUNS AND LOAD OUT OF PIPESHED. 02:15 - 03:10 0.92 BOPSUR P I POST MU FREEZE - PROTECTING BHA(BHA #8) WITH BPV, 6' STINGER AND NOZZLE. 03:10 - 03:30 0.33 BOPSUR P POST STAB ON INJECTOR AND PRESSURE-TEST QTS TO 300PSI / 5MINS AND 3,500PSI / 5MINS. ACHIEVE GOOD TESTS. HOLE IS FULL - NO LOSSES. 03:30 - 04:00 0.50 BOPSUR P i POST RIH W/ BHA#8 (FREEZE PROTECT). SWAP FLUIDS TO DIESEL. 04:00 - 04:20 0.33 BOPSUR I P I POST POOH & LAY IN FREEZE PROTECT FROM .2500' TO SURFACE WITH 46 BBLS OF DIESEL. 04:20 - 04:45 0.42 BOPSUR P POST LD NOZZLE -BHA AND CLEAR RIGFLOOR. MEANWHILE HAVE GREASE CREW GREASE ALL TREE VALVES. SLB N2 CREW ARRIVES ON LOCATION, SPOTS TRUCK TO CEMENT STAND -PIPE AND RIGS UP HARDLINE. 04:45 - 05:15 0.50 BOPSUR P POST LIFT T -BAR ONTO RIGFLOOR AND PREPARE FOR SETTING BPV. VALVE CREW INSTALLS 4-1/16" CAMERON H -TYPE BPV, NO COMPLICATIONS. 05:15 - 05:30 0.25 BOPSUR P POST PERFORM PRESSURE -TEST ON N2 SURFACE LINES TO 300PSI / 5MINS AND 3,500PSI / 5MINS. CLOSE MASTER VAVLE AND SWAB VALVE WITH 23.5 TURNS, CLOSE SSV. 05:30 - 05:45 0.25 BOPSUR P POST FLUSH TREE WITH METHANOL. 05:45 - 06:00 0.25 BOPSUR P POST ESTABLISH TREE BARRIERS FOR BREAKING CONTAINMENT - APPLY 3,000PSI BELOW SWAB VALE AND VISUALLY CONFIRM NO LEAK ACROSS SWAB. BLEED OFF PRESSURE AND MONITOR TREE CAVITY. GIVE 24HRS NOTICE FOR INITIAL BOP -TEST TO AOGCC THROUGH http:// doa. alaska. gov /ogc/forms /TestWitnessNotif. html 06:00 - 07:00 1.00 RIGD P POST TEST N2 LINE TO 250 -PSI / 3500 -PSI FOR 5-MIN PER TEST. GOOD TESTS PER TEMPORARY PIPEWORK CRITERIA. CONFIRM N2 PUMP TRIPS Printed 4/2/2013 7:30•04AM • 4 w 'i, sue"` '. w r n +'. $'" ' . �?` r & r s . s� �.- ' '7" �y.. '" � � CrO �s� � 4�'ai t ' �--� �E�?.�` Common Well Name: J -17 AFE No Event Type: COM- ONSHORE (CON) Start Date: 3/19/2013 End Date: 3/22/2013 X3- 0135K- C:DRILL (1,176,312.00 ) Project: Prudhoe Bay Site: PB J Pad Rig Name /No.: NORDIC 1 Spud Date/Time: 1/3/2002 12:00:00AM I Rig Release: 3/23/2013 Rig Contractor. NORDIC CALISTA UWI: / Lat: 070 °19'37.030 "0 Long: 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) Date ! From - To Hrs T Task Code NPT j NPT Depth ! Phase Description of Operations (hr) (usft) 07:00 - 07:40 0.67 RIGD P POST HOLD PJSM ON BLOWING DOWN REEL WITH 1N2. DISCUSS HAZARDS OF N2 EXPOSURE, 'IMPORTANCE OF CLEAR & CONCISE COMMUNICATION, PROPER LINE UP & RESTRICTED AREAS. I PU INJECTOR AND MU TO WELL. POSITION NOZZLE JUST ABOVE SWAB VALVE. ;PUMP 50 -BBLS FRESH WATER. SCREEN I BYPASS LINE IS FROZEN - HEAT & ABLE TO PUMP THROUGH FREELY AT 3-BPM / 1860 -PSI. FOLLOW WITH 10 -BBLS MEOH AT 1.4 -BPM / i ! 380 -PSI. CONFIRM LINE TO TIGER TANK IS OPEN. 07:40 - 08:30 0.83 RIGD P ! POST BLOW DOWN REEL WITH N2. MAINTAIN 150 -PSI DOWNSTREAM OF CHOKE. BLEED OFF ALL PRESSURE. 08:30 - 09:30 1.00 BOPSUR P POST HOLD PJSM WITH RIG CREW & CTS ON CHANGING OUT PACKOFF BRASS. DISCUSS POTENTIAL PINCH POINT, HIGHLIGHT WAYS TO WORK SAFELY AND THE IMPORTANCE OF COMMUNICATION DURING THE JOB. CHANGE OUT PACKOFF BRASS. 09:30 - 10:00 0.50 RIGD P POST 1INSTALL GRAPPLE W /CABLE. PULL TEST - GOOD. 10:00 - 12:00 2.00 RIGD P POST HOLD PJSM ON PULLING COIL ACROSS FROM INJECTOR TO REEL HOUSE. DISCUSS EXCLUSION ZONES, POTENTIAL STORED ENERGY, CLEAR & CONCISE COMMUNICATION, SHIPPING BAR HANDLING, WORKING AT HEIGHTS AND PROPER BODY POSITIONS. PULL COIL BACK ACROSS FROM INJECTOR TO REEL HOUSE. SECURE COIL TO SHIPPING BAR WITH DUAL CLAMPS. RD GRAPPLE. _ 12:00 - 14:00 2.00 RIGD P I POST REMOVE INNER REEL IRON. SET INJECTOR BACK OVER CIRC HOLE ON LEGS. VAC OUT BOP STACK. 14:00 - 16:30 2.50 RIGD P POST HOLD PJSM FOR REEL SWAP WITH RIG CREW, CTS & CH2. DISCUSS RADIO COMMUNICATION, EXCLUSION ZONE, STOPPING THE JOB, AND ASSIGN PEOPLE TO POSITIONS. ATTEMPT TO LOWER REEL BUT SHIPPING BAR POSITION ON THE BACK OF THE REEL IS STICKING OUT TOO FAR TO FIT THROUGH BOMB BAY DOOR. REPOSITION REEL WITH SHIPPING BAR ON THE FRONT OF THE REEL & LOWER REEL OUT WITHOUT ISSUE. PU NEW REEL & SECURE IN REEL HOUSE. Printed 4/2/2013 7:30:04AM g a 4 1. _,. -,, i as T1 t .r.: v :Y, . -y.� tea. — .f - ,r ' Common Well Name: J -17 AFE No Event Type: COM- ONSHORE (CON) Start Date: 3/19/2013 1 End Date: 3/22/2013 ,X3 -0135K C:DRILL (1,176,312.00 ) 1 ! Project: Prudhoe Bay r Site: PB J Pad I Rig Name /No.: NORDIC 1 1 Spud Date/Time: 1/3/2002 12:00:00AM , Rig Release: 3/23/2013 Rig Contractor. NORDIC CALISTA I UWI: / Lat: 070 °19'37.030"0 Long: 1 0148 °50'38.023 "W Active datum: Kelly Bushing / Rotary Table @77.00usft (above Mean Sea Level) Date 1 From - To Hrs Task Code I NPT !, NPT Depth ! Phase 1 Description of Operations (hr) i (usft) 1 16:30 - 18:30 2.00 BOPSUR P POST 1 HOLD PJSM WITH SLB MECHANICS REGARDING GEARBOX SWAP. HIGHLIGHT JOB STEPS, LO/TO NECESSARY, GENERAL HSE POLICIES WHILE WORKING ON THE RIG. ! RIG CREW BEGIN INSPECTION OF BOPE. NO I DEFICIENCIES NOTED - CHANGE OUT BLADE ! I SEAL ON BSRS PER NORDIC INSPECTION (PROCEDURE. !BARRIERS FOR OPENING BOPE DOORS ARE I DUAL LEAK TIGHT BARRIERS TESTED PER 1 WELL PROGRAM -1) LEAKTIGHT SWAB & 2) i � I � LEAK TIGHT SSV. CONTINUALLY :MONITORING SSV X SWAB VOID USING SLB 1 PRESSURE TRANSDUCER - NO PRESSURE 1 BUILDUP SEEN. FINISH OFFLOADING ALL FLUIDS FROM PITS & CLEANING PITS. 1800 - HRS - CONTACT AOGCC JIM REGG PER DIRECTION ON "AOGCC INSPECTION FORM I CONFIRMATION EMAIL" IF WE HAVE NOT BEEN CONTACTED WITHIN 12 -HRS OF I PROVIDING NOTICE. HE INDICATED AN INSPECTOR WOULD BE CONTACTING US. I ', 18:30 - 21:30 3.00 BOPSUR j P POST 1 HOLD PJSM WITH NIGHTSHIFT SLB ! MECHANICS. REVIEW HARC AND 1 PROCEDURES AND DISCUSS LOTO FOR !GEARBOX. CONTINUE GEARBOX i I I, CHANGE -OUT. ' [ !NORDIC RIG CREW CONTINUE ND BOPE. 121:30 - 22:30 1.00 BOPSUR ' P POST 1 NU TREECAP AND ATTEMPT TO PRESSURE -TEST SAME. STRUGGLE TO ACHIEVE LP -TEST TO 300PSI. 22:30 - 22:40 0.17 BOPSUR P POST ! DECIDE TO OPEN UP TREE - VALVES TO CONFIRM TREE IS FLUSHED AND FILLED ! WITH METHANOL. OPEN MASTER VALVE 23.5 TURNS AND SSV, 1 READ -11 PSI ON FWV. OPEN SWAB WITH 23.5 I j I TURNS. PUMP 1 BBL METHANOL, THEN 1 !, 'CLOSE MASTER VALVE (23.5 TURNS), SSV 1 1 AND SWAB VALVE (23.5 TURNS). 122:40 - 23:20 0.67 1 BOPSUR P POST I RE- ATTEMPT PRESSURE- TESTING TREE CAP. 23:20 - 00:00 0.67 BOPSUR P POST ACHIEVE GOOD PRESSURE -TEST ON TREECAP TO 300PSI / 5MINS AND 3,500PSI / ! 5MINS. ! RIG DOWN TESTING EQUIPMENT AND IA/OA- PRESSURE TRANSDUCERS AS WELL 1 AS SSV CONTROL LINE. "' RIG RELEASED AT 24:00HRS "; Printed 4/2/2013 7:30:04AM • • J -17D, Well History (Post Rig Sidetrack) Date Summary 03/26/13 T /I /O = 0/0/0. Conducted PJSM. Barriers = WV & SSV. Verified by performing independent LTI tet (Passed). Removed blind flange from flow cross on companions side & installed tapped (4 ") with ball valve and needle valve. Torqued flange to API spec. T /I /O/ = 0/0/0. Conducted PJSM. Barriers = SSV & SV. Verified by performing independent LTI test (Passed). Rigged up Cameron lubricator with 4" CIW pulling tool to tree cap. PT'd lubricator 300 psi low & 3500 psi high for 5 minutes each (Passed). Tagged @ 127 ", pulled 4" CIW BPV # 140 thru tree. Bled TBG to 0 psi closed barriers & rigged off well. Changed out pulling tool to setting tool with 4" CIW TWC # 289. Rigged lubricator onto tree cap. PT'd lubricator 300 psi low & 3500 psi high for 5 minutes each (Passed). Set TWC @ 127 ", bled TBG to 0 psi, closed barriers & rigged off well. Changed setting tool to pulling tool. Rigged lubricator onto tree cap, PT'd tree thru lubricator 200 -300 psi low & 5000 psi high for 5 minutes each (Passed), charted and put into TRP folder. Tagged @ 127 ", pulled TWC # 289 thru tree, closed barriers & bled TBG to 0 psi. Rigged down off well, PT'd tree cap. Job complete. Final WHP's = VAC /0/0. 03/26/13 T /I /O = SSV /0 +/0 +. Temp = SI. IA FL (SL request). No AL. IA FL near surface. SV, WV, SSV = Closed. MV = Open. IA & OA = OTG. NOVP. 21:30. 03/26/13 IA FL (SL request). BPV in well. 01:00 hrs. 03/31/13 T /I /O =0/1/0 Temp =S /I Assist SLB (Post CTD) Pump 5 bbls meth, 177 bbls 180"f crude while slickline brushes. Pump an additional 92 bbls crude while slickline cleans LTP. Job continued on 4 -1 -13 WSR. 03/31/13 BRUSH AND FLUSH W/ 177bbIs OF CRUDE. DRIFT TO DEP SLV @ 10979' MD W/ 10' x 3.70 DMT WHIPSTOCK & 3.5" LIB. BRUSH TBG & DEP SLV WITH 4 -1/2" BLB, STEM FOR SPACE & 3 -1/2" BLB. RAN 2.25" PUMP BAILER TO DEVIATION @ 11232' SLM. DRIFT TO DEP SLV @ 10979' MD W/ 10' x 3.70 DMT WHIPSTOCK & 3.5" LIB. BRUSH 10977' SLM FOR 30min WITH LRS PUMPING lbbs MIN. 04/01/13 Pumped 13 bbls of crude for attempt of SLB to set LTP. 04/01/13 MIT -T to 2500 PSI PASSED Pumped 8 bbls crude down Tbg to achieve test pressure of 2500 psi for MIT- T. Tbg lost 85 psi in the 1st 15 min and 30 psi in the 2nd 15 min for a total presuure loss of 115 psi in 30 min test. Bled Tbg down to 115 psi ( -4 bbls). 250 total bbls crude pumped for job. SLB on well of departure. IA,OA =otg FWHP's= 200/0/5. 04/01/13 RAN 10' x 3.70" DUMMY WHIPSTOCK WITH LIB. RAN 2 DEPLOYMENT SLEEVE TEST TOOL. TEST ONE FAIL. MISS RUN WITH DPU AND LINER TOP PACKER. START NEXT LINER TOP PACKER RUN. 04/02/13 SET LINER TOP PACKER @ 10971' MD. SET LTTP IN LTP @ 10981' SLM, LRS MIT -T TO 2500 (PASS SEE LRS AWGRS FOR DETAILS). SET 4 -1/2" WHIDDON CS ON LTP @ 10976' SLM. PULL STA #3 DGLV @ 3235' MD & STA #4 DGLV @ 6368' MD. SET RK -LGLV (1500# TRO, 16/64" PORTS) IN STA# 3 @ 3235' MD & RK -OGLV (24/64" PORTS) IN STA# 4 @ 6368' MD PULL WCS FROM LTP @ 10976' SLM. Page 1 of 1 '4 TIC= 4-1/16" OW • WELLHEAD= McEVOY ■ SAF NOTES; WH L ANGLE t° 70 11144' *" 4-1/2" ACTUATOR = BAKER / CHROME TBG ""` INITIAL, "A ", "B "', & "C" WELLBORES INITIAL KB. ELE 77' NOT SHOWN"" BF. REV 39.78' I2f}" CONDUCTOR I 110' 1111 22'18` — 14 -1/2" FES X NIP, ID = 3.817 1 KOP = 3000' l Max Angle = 95" @ 11727' [ , Datum M � ii D = 10893' 2584' 1 9 - 518" DV PKR I Datum TVD= 8800' SS GAS LET" MANDRES 113 -3/8" CSG, 72#, L -80, 0 =12.347" I 2685 ST MD TVD 0EV TYPE VLV LATCH PORT DATE 4 3235 3227 15 WAG DOME RK 16 04/02/13 9-5/8" X 7" BKR C-2 ZXP LTP —I 8774' 111 3 6368 5608 45 MMG SO I2K 20 04 /02/13 w 1 11.6' TEBK SLV, 0 = 6.30" L 2 8620 7308 37 AIftG EMY I2K 0 10/10/05 ►mot 0 1 9936 8240 41 KBG2 DI IY BK 0 10/10/05 I9 -5 /8" X 7" BKR HMC LNR HGR, 13 = 6.32" 1 8791' .11 IN VVFIPSTOCK (09/2705) 8952' A IP A 9-5/8" CSG, 47 #, L -80, 0 = 8.681" — 8931 NI MLLOUT WIdDOW (J -17C) 8931' - 8947" Minimum ID = 2.37" @ 10971' 10006' I I 4 -112' KB LTP I 10027' 1-- 7" X 4 -1/2" BKR S-3 PKR, 13 = 3875" I 10050' H4-1/2" I-ES X NIP, ID = 3.813 I 10067' —17 X 5" BKR ZXP LTP w /11' TIEBACK, ID =4A0" I 4-1/7 TBG, 12.6 #, 13GR -80 VAM TOP, —) 10083' !T� ' ►:1 10070• H4 -1/2" FES XN NP, MLLED TO 3.80" (03/05/13) 1 .0152 bpf, 0 = 3.958" ) ) 10083' —I 4-1/2" VVLEG, 13= 3.958" 1 10084' —17" X 5" BKR LNR HGR, D = 4.40" I 10091' —15" X 4 -1/2 X0, 0 = 3.958" 7" LNR, 26#, 1 -80 STC-M, .0383 bpf, IO = 6.276" —J 10234' 10417' 1-14- 112" MARKER JOINT, 13= 4.00" I CI IC . 10971' —14 -1/2" KB LIP, 13= 2.37" (04/03/13) [ MEM 10979' H3.70 DEPLOYMff SLV, I3 =300 "I ( 11001' - 3 -1/2" HES X NP, 13= 2.813" ( 14 -1/2' LNR, 12.6#, L -80 BT-M, .0152 bpf, 13= 3.958" 1 14 -1/2" BKR WHPSTOCK (03 /13/13) 1-f 11735 I I MLLOtlT WIVIX31i+V (J - 170) 11735' - 11743` 3 LNR, 9.3#, L - 80 SM., .0087 bpf, ID = 2.992 H 11382' PERFORATION SLIMvAARY REF LOG: SLB MCNJ GR/ CCL. ON 03171/13 1 11382' —13-1/2" X 3-3/16" X0, I3 =2.786" 1 ANGLE AT TOP FR F: 89" @ 13190' i; Note: Refer to Production DB for historical pert data I SIZE SPF INTERVAL Opn /Sqz DATE SQZ 2 -7/8" 4 1 1350 - 11500 S 1 0/09/05 03/20/13 2" 6 13190 -13380 0 03/21/13 I 13082' --13-3/16" X 2 -7 /8" XO, I7 = 2.377" 1 I 3 LNR, 6.64t, L -80 TCI, .0079 bpf, ID = 2.850" H 13082' I FBTD 13439' 2 -7/8" LNR, 6.4#, L -80 STL, .0058 bpf, D = 2.441" I - 1 134$5' I 13480' ---12 -718" X 2 -3/8" X0 FIN, rJ = 1.992" DATE REV BY ` COMMENTS DATE REV BY 1 COMMENTS FRL *- )E BAY uirr 07/18/83 A1t1 INITIAL COMPLETION 03/26 /13 MW PJC DRLG DRAFT CORRECTIONS' WELL: 3-170 , 10/26/99 JLH CTD SIDETRACK (J -17A) 04/08/13 JNLJJMD REVISED LIM12 TD PERIvIT No: 2130120 01/21/02 NORDIC 1 CTD SIDETRACK (J - 17/3) 04/09/13 BSE/JMD GLV C/O (04/02113) API No_ 50-029-20969-04 10!11/05 N2E5 SIDETRACK() -17C) 04/09/13 NXWV /JMD ADD LTP (04103/13} SEC 9, T11N, R13E, 801' FNL& 1806` FEL 06/22113 NORDIC 1 CTD SIDETRACK (J -17D) 03/22/13 PJC DRLG I-10 CORRECTIONS 1 , BP Exploration (Alaska) OF T�� • • w� \ \I % % s v THE STATE Alaska it and Gas ALAsKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue Anchorage, Alaska 99501 -3572 A ALAS y 5 'tt13 Main: 907.279.1433 ,CAt 1 Fax: 907.276.7542 John McMullen Engineering Team Leader BP Exploration (Alaska), Inc. o 5 ' _ o g c�- P.O. Box 199612 V� Anchorage, AK 99519 -6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU J -17C Sundry Number: 313 -046 Dear Mr. McMullen: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Cathy P. oerster Chair DATED this 1 d ay of February, 2013. Encl. STATE OF ALASKA 4 RECEIVED ALA* OIL AND GAS CONSERVATION COM•ION APPLICATION FOR SUNDRY APPROVAL JAN 29 2013 20 AAC 25.280 '27" z ` i / O 1. Type of Request: AOGCC ❑ 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 2. Operator Name 4. Current Well Class 5. Permit To Drill Number BP Exploration (Alaska) Inc. ❑ Exploratory ❑ Stratigraphic 205 -082 - 3. Address: 6. API Numbe ® Development ❑Service P.O. Box 196612, Anchorage, Alaska 99519 -6612 50.029- 20969 -03 -00 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a Spacing Exception? ❑ Yes No PBU J -77C . 9. Property Designatior 10. Field / Pool(s): ADL 028281 • Prudhoe Bay Field / Prudhoe Bay Oil Pool • 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): Total Depth TVD (ft): Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured) 12387' . 9023' ' 12302' 9023' 11950' None Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" x 30" 110' 110' Surface 2685' 13 -3/8" 2685' 2685' 4930 2670 Intermediate 8931' 9 -5/8" 8931' 7551' 6870 4760 Production Liner 1460' 7" 8774' - 10234' 7429' - 8435' 7240 5410 Liner 2320' 4 -1/2" 10067' - 12387' 8325' - 9023' 8430 7500 Perforation Depth MD (ft): Perforation Depth TVD (ft): Tubing Size: Tubing Grade: Tubing MD (ft): 11350' - 12285' 9024' - 9023' 4 -1/2 ", 12.6# 13Cr80 10083' Packers and SSSV Type: 7" x 4 -1/2" BKR S -3 Packer Packers and SSSV 10027' / 8300' MD (ft) and TVD (ft): 12. Attachments: 13. Well Class after proposed work: ® Description Summary of Proposal ® BOP Sketch ' ❑ Detailed Operations Program ❑ Exploratory ❑ Stratigraphic ® Development ❑ Service 14. Estimated Date for 15. Well Status after proposed work: Commencing Operation February 10, 2013 ❑ Oil ❑ WINJ ❑ WDSPL ❑ Plugged 16. Verbal Approval: Date ❑ Gas ❑ GINJ ❑ GSTOR ❑ Abandoned Commission Representative: ❑ WAG ❑ SPLUG Suspended ' 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Trevor Hyatt, 564 -4627 Printed Name: J`• r ulle Title: Engineering Team Leader ail: Trevor.Hyatt @bp.com Signature: Phone: 564 - 4711 Date: 1 7 7/7 O PY( Commission Use Only Conditions of approval: Notify Commission so that a representative may witness 3/5...._0 C Sundry Number: ( C ❑ Plug Integrity ti BOP Test ❑ Mechanical Integrity Test ❑ Location Clearance ,O Other: d ✓ 7 ! ..-z to 35 psi RSDMS FEB 0 4 2013 Spacing Exception Required? ❑ Yes ❑ No Subsequent Form Required: - APPROVED BY Approved By: /J _4_4/ _ COMMISSIONER THE COMMISSION Date: 2. ' 1 " / 3 For Iv 1- - 1 fili Approved application is valid for 12 months from the date of approval Submit In Duplicate r`( / i • • To: Alaska Oil & Gas Conservation Commission From: Trevor Hyatt b p CTD Engineer Date: January 21, 2013 Re: J -17C Sundry Approval WELL HISTORY: J -17 was drilled in 1983. Perforations were primarily in lower Z2. J -17a was a CT sidetrack drilled NE of the parent wellbore in 1999. Initial perfs in the 22P struggled due to low PI. Perforations were gradually added uphole, but the well quickly reached the MGOR of the time. J -17b was a CT sidetrack drilled SW of the parent in 2002. The initial attempt (PB1) drilled to 11,616' MD, but were unable to run a liner due to trouble with shales. A cement plug was layed between 10,915 and 10,480' MD. J- 17b sidetracked from PB1 at 10,690', and drilled to TD at 11,721' MD. J -17b was completed with 350' of Z2 perfs. J -17b started cycling in 2003, and annular communication was discovered in 2004. J- 17C is a Zone 2A well drilled in 2005. The sidetrack in 2005 with Nabors 2ES replaced the 4 -1/2" tubing with 13 -Cr, well is a 4 -1/2" monobore completion. Ran PPROF 2/2011 which indicated the toe perforations to be at HGOR. A CIBP was set at 11,950' to isolate the HGOR perfs. Initial results post ' plug set were strong but within 2 months well has approached MGOR. REASON FOR SIDETRACK: J -17C is not a competitive producer due to high GOR. The well does not recharge effectively from • cycling. The proposed sidetrack will access reserves in a 31 acre Z2A target. The plan is to shut -off the parentbore perforations due to their low remaining value. The proposed plan for J -17D is to drill a through tubing sidetrack with the SLB/Nordic 2 Coiled Tubing Drilling rig on or around March 25, 2013. The existing perforations will be isolated by the primary liner cement job. The sidetrack, J -17D, will exit the existing 4.5" liner, kick off and land in the Ivishak Zone 2A. The following describes work planned and is submitted as an attachment to Form 10 -403. A schematic diagram of the proposed sidetrack is attached for reference. vX / uci r / i 6 T r 00 cu r, l e �� rc f �- l r �p �/ 7-4 c / kre 1° f er rqic ,) l fir (�� (✓P �� Cce 4e f JeKtAcked jZj ,^TGrr t ront. 1‘11`c ?Of 01 ' 1 12° /,407 • • Pre -Rig Work: (scheduled to begin on February 10, 2013) 1. C Injectivity Test 2. C Mill out XN Nipple at 10,070' MD, to 3.80" ID. 3. C Remove Restriction at 11,000 MD. 4. C Dummy WS drift. 5. W Torque LDS. l �G 6. V PT MV, SV, WV. 7 / J 7. V Double Valve IA p7 D 2 ° 5 _ 8. 0 Blind and bleed lines, remove well house, level pad. S c, ctvy 9. V Set TWC —24 hrs prior to rig arrival. 3 J I ` Rig Work: (scheduled to begin on March 25, 2013) 1. MIRU and test BOPE to 25 and 3500 psi high. No h 5 41 ° « G 2. Set top of 4 -1/2" KB Packer Whipstock at 11,730'. • 3. Mill 3.80" window at . 11,730' and 10' of rathole. Swap the well to PowerPro. M 4. Drill Build: 4.125 OH, (12 deg/100 planned) with resistivit 5. Drill Lateral: 4.125" OH, (12 deg/100 planned) with resistivity 6. Run 3 -1/2" x 3 -1/4" x 2 -7/8" solid L-80 liner leaving TOL at 11,000' 7. Pump primary cement leaving TOC at 11,000', 22 bbls of 15.8 ppg liner cmt planned 8. Cleanout liner and MCNL /GR/CCL log n/c w / rD 9. Test liner lap to 2000 psi. 10. Perforate liner per asset instructions ( -250') T ?D 11. Freeze protect well, RDMO p r0 21 3 0 /2.` f Post Rig: 1. Re- install well house and attach production lines. 2. Pull BPV. 3. Run generic GLVs. 4. Set LTP 5. Possible Test separator (-250' - 500' of perfs). Trevor Hyatt CTD Engineer 564 -4627 CC: Well File Joseph Lastufka 114:h = 4-1/16" CM' III . WELLJ-EAD = ItEVOY J -1 7C SAFETY NOTES: ORIG WEL_130RE & SIDETRACK ACTUATOR= BAKER "A" NOT SHOWN ON DIAGRAM. "WELL ANGLE > NTIAL KB. ELE T7 .0 70° @ 11154'. ***4-1/2" CHROME 7BM" BF. B_EV = 39.78' I KOP 30MY Max Angie = 95° © 1172T I 2218' H4-1/2" FES X NP, 0=3.813" I Datum ND = 10893' I Datum TVD = 8800' SS. .—. 2584' 119 DV PKR 1 120" CONJUCTOR 1 110' r GAS LFT PJAWIRES 113-3/8" CSG, 72#, L-80, D = 12.347" H 2685' Ilk ST PAD ND DEV 1Y FE VLV LATCH FORT DA1E 4 3235 3227 15 LIAG MY FE 0 11/30/12 Minimum ID = 3.725" @ 10070' 3 6368 5608 45 WAG DMY RK 0 11/30/12 4-112" HES XN NIPPLE I 2 8620 7308 37 WAG OW IRK 0 10/10/05 1 9936 8240 49 KBG2 DAN 13K 0 10/10/05 I TOP OF 7" LM 1 8774' 8774' F- 9-5/8" X r BKR C-2 ZXP LTP w / 11.6' TEBK SLV, D = 6.30" 41 : Nd 41 8792' H 9- X 7" BKR1-MC LM HGR, 0 = 8.32" I V V V V I wiPs (0912705) H 8952' V '4 19-5/8" CSG, 47#, L-80, 0 = 8881" --I — 8931 .4 N V MLLOUT VVNJOW(J-17C) 8931' - 8947' A24 ' "P...1 f e,,e PERFORATION SUMMARY REF LOG: MAID ON 10/4/05 I I 10006' H4-1/2 FES X NP, D = 3_813' I A NSLE AT TOP PERF: 87° ,,, 11350' 1 Ffefer to Production DB for historical pert data SEE SPF NIERVAL - Opn/Sqz DATE SOZ E ■- I 10027' Hr X 4-1/2' BKR S-3 PKR, D = 3.875' I 2-7/8" 4 11350 - 11500 0 10/09/05 2-7/8" 4 11750 - 11920 0 10/09/05 2-7/8" 4 12000- 12285 C 10/09/05 I 1 10050' H4-1/2" FES X kr, 0 = 3.813' I 1006T 1 — 7' X 5' BKR ZXP LTP, FMC LNR FIGR & TEBACK SLV, D = 4440* . I 10070' H4-1/2. FES XN NIP, 0 = 3.725 I 4-1/2" TBG, 12.6#, 13CR-80 VAM TOP, — 1 10083 .0152 bpf, 0 = 3.958" 1 10083' —j4-1/2' WIG, ID = 3.958' I i -------- -1 10091' _I-15' X 4-1/2' X0, 0= 3.958' T LNR, 26#, L BTC .0383 bpf, 0 = 6276' H 10234' I- I 10417' H4-1/2" MARKER JOINT, ID =400" I I I -. 11950' 1--13.66' CIBP (02/10/11) 1 14-1/2" LNR 12.6#, L-80 LUC, XO TO BT-M I—I 12262' 1—,‹ I PBTD 12302' I ' 14-1/2" LNR, 12.6#, L-80 £T-M, .0152 bpi, ID = 3.958" H 1238T • %I DATE REV BY COMENTS - DATE REV BY COL&IENTS FRUDHOE BAY MIT 07118183 AID 3 IMTIAL COMPLETION 12/02/12 LEF/ PJC GLV C/0 (11/30/12) wat: J-17C 10126/99 JLH CTD SIDETRACK "A" 12/02/12 PJC REFORWATING PERMIT ND: ' 01/21/02 NOROC 1 CM SIDETRACK13 AR Pb: 50-029-20969-03 10111/05 ICES SIDETRACK "C' SEC 9, T11N, RI3E, 801' St/ & 1806' VVEL 03/19/10 JLW/SV CSG CORRECTION 02/11/11 RI&-VPJC SET CEP (02/10/11) - BP Exploration (Alas k a) TREE= 4 -1/16" CNV _ S Y NO I LS: UKICi VV I LLti(Ntt & Slut I KA(A. WELD= Mc EVOY ACTUATOR= BAKE? • J 17 D T SHOWN ON DIAGRAM. **WELL ANGLE> ' K8 REV = 77.0' 70° af 11154'. * * *4 -112" CHROME TBG* ** proposed CTD sidetrack BF. ELEV = 39.78' 1 - 1 KOP = 3000' Max Angle = 5° @ 11727' Datum ND = 10893' 2218' I-14-1/2" HES X NP, D = 3.813" Datum TVD= 8800' SS 1 am 2584' H9-5/8" DV PKR 20" CONDUCTOR --I 110' GAS LIFT MANDRELS 13 -3/8" CSG, 7211, L -80, D = 12.347" H 2685' ST ND TVD DEV TYPE VLV LATCH FORT DATE 4 3235 3227 15 NAG DOW RK 16 10/24/05 3 6368 5608 45 WAG SO RK 20 10/24/05 In 2 8620 7308 37 WAG DMY RK 0 10/10/05 1 9936 8240 49 KBG2 DIM' BK 0 10/10/05 TOP OF 7" LNR —{ 8774' . I 8774' I- 9 -5/8" X 7" BKR C-2 ZXP LW 1;1 I: WI11.6. SLV, D = 6.30" Minimum ID = 3.725" @ 10070' • � ► ∎ .. 8792' — I 9 -5/8" X 7" BKR HMG LNR HGR, D = 6.32" 4-1/2" HES XN NIPPLE • • ►' •' • ►• .• ►i 1 MLLOUT WINDOW (J -17C) 8931' - 8947' �4 WHPSTOCK (09/2705) H 8952' ►i % ∎ � •∎ , 10006' I - - 1/2" HES X NP, D = 3.813" I • • *** 10027' H 7" X 4 -1/2" BKR S -3 PKR, D = 3.875" EZSV (09/26/05) I—I 8962' _ =� �► 10050' H4 - 1/2" HES X NP, D = 3.813" I 0,v-. 4 - 1/2" TBG STUB 9110' _.„ _ ♦ ,_ 3 ,1 4 1 4 1 ! 1006T 1 7" X 5" BKR ZXP LTP, HMC LNR • � HGR &TIEBACK SLV, D = 4.440" ... ! 10070' -4 4-1/2" F-ES XN NP, � M atp 3.80" D = 3.725" • ♦ . ` 10083' 14-1/2" WLEG, 04 4 -1 "TBG, 12.6#, — 10083' 9 -5/8" CSG, 47 #, L -80, D = 8.681 " —I 9963' �% 13CR 80 VAM TOP, V ID = 3.958" i•l .0152 bpf, D = 3.958' 10091' — 5" X 4- 112" XO, • . ID = 3.958" •ii 7" LNR, 26 #, L -80 BTGM —I 10234' Iv .0383 bpf, D= 6.276" 10417' 4-1/2" MARKER •• JOINT, D = 4.00" � ••� e Notei2estiilim 11,348'MD PF7RFORATION StItiNIARY • 1 0 of4 12 "W S @ - 11,730'M D REF LOG: MVVD ON 1014/05 : Top of3-1/2" li�erand cement@ - 11,000' p 94 6 11950' 1166" CBP ANGLE ATTOPFERF: 87° @ 11350' 2-7/8" L -80 liner/PD @ - 13,520' 3-1/4"x 2 7i8 "x0 , (02/10/11) Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz ATE (I...._ 2 -7/8" 4 11350 - 11500 0 10/09/05 2 -7/8" 4 11750 - 11920 0 10/09/05 2 -7/8" 4 12000 - 12285 C 10/09/05 4-1/2" LNR, 12.6#, L -80 LT &C, XO TO BT -M H 12262' PBTD H 12302' � o � 4 -1/2" LNR, 12.6#, L -80 IBT -M, .0152 bpf, ID = 3.958" —I 12387' DATE REV BY COMvENTS DATE REV BY COMMENTS PRUDHOE BAY I.1MT 07/18/83 AUDI 3 IMTIAL COMPLETION 05/29/06 OD /DTM PERE/TREE CORRECT (6/13/04) WELL: J-17C 10/26/99 JLH CTD SIDETRACK "A" 11/17/07 CAZ/PJC DRLG DRAFT CORRECTIONS FERMT No: "'2050820 01/21/02 NORDIC 1 CTD SIDETRACK "B" 03/19/10 JLW /SV CSG CORRECTION AR No: 50- 029 - 20969 -03 10/11 /05 •2ES SIDETRACK "C" 02/11/11 RM-VPJC SET CBP (02/10/11) SEC 9, T11 N, R13E, 801' S■L & 1806' VVEL 11/05/05 KSBITLH GLV GO (10/24/05) 02/22/06 SVVITLH FERF CORRECTION BP Exploration (Alaska) NORDIC CTD UNIT # 2 CHOKE / REEL / CIRCULATION MANIFOLD DIAGRAM w - Cho a Panel Standpipe 2" Circulation Line I Driller Gauge •M. • M 10 •.• M 11 Manual Choke -CAIISrB •• CIRCULATING MANIFOLD — MM; MM 9 MM 16 tO • e a • MM 15 : ` 10/62012 I SLB Transducer _ _ • .MMB _ • • Pvrsenaqr 0 1 MM •14• Baker Choke ae.a sh.,a I MM 13 MM 4 111111 0 MM 17 KILL SIDE MANUAL VALVE 6 O . CHOKE SIDE I MANUAL VALVE -�: �� KILL HCR an I Rev Clr Line II /CHOKE HCR I . , fAir Blow down - �. MM74 �y r I I a, ,�, s s " • Chok. une I Coiled Tubing — i = I .M61/MN} 1111•18•8111111111118011111111 001011111. 1811•104•101 I Baler Choke Klt Line - -- • ! , ■ I MP2 •. MP1 .*. • - I , :s I .1 I „ s KIII Line - - R V - ••1 \ BOP 16 HP 11 HP 10,.. Tranducers _ COILED TUBING I , / 170P17 p CIRCULATING SYSTEM 1L HP 18 AP MP 14 ( I P19 •' To Inner Reel I Valve HP 15_ HP7 HP HP4 HP3 i HP 17 -I - I El ■ • _ __ -I I HP 12 HP2 HP1 - HP 16 / J cement line N2 SLB /. CHOKE MANIFOLD / / _ I Si HP 17 N2 Talow .„/ CM 85 CON 7 Gauge \ . I ��� I - I CM 29 - '• M CRONE LINE OAS BUS - r — I y - - Test Pump Inlet —CM 70 / •� -' I J H'Gauge PB7 Flow I/ HCR // t .;,, 01 I 4Wav Block CM14 CM7/ CMS I • ' �. = CM24 PB2 quid I CM5 CM6 C . .k� • • leg is Baker Choke Line " ^^` — • 10, from wal — _ high I M17 • ' , *_ 0,EAS I CM1 . . u.. POSSUM BELLY CM28, CM21 C ono C ". • • Mlcro M4 N _ V' c "I— _ Tlger Tank I ai l • - , , - - lir I CM76 CM79 CM27 TIGER TANK ® / -.. - I I - I I _ _ _ 4.1 • • Page 1 of 1 Subject: FW: INTENT PLUG for RE -DRILL WELLS: Corrected From: Davies, Stephen F (DOA) Sent: Monday, February 08, 2010 10:52 AM To: Foerster, Catherine P (DOA); McMains, Stephen E (DOA); Schwartz, Guy L (DOA); Saltmarsh, Arthur C (DOA); Aubert, Winton G (DOA) Subject: RE: INTENT PLUG for RE -DRILL WELLS: Corrected Revised procedure with an additional step per Cathy's comment: INTENT PLUG for RE -DRILL WELLS ( IPBRD) Type Work Code in RBDMS ✓ 1. When a Form 10 -403 is submitted requesting approval to plug a well for redrill, the initial reviewer (Art or Steve D.) will check to make sure that the "Plug for Redrill" box in the upper left corner of the 403 form is checked. If the "Abandon" box is checked, we will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). 2. On the Form 10 -403 if "Abandon" is checked in Box 15 (Well Status after proposed work), Art or Steve D. will cross that erroneous entry out and initial it on both copies of the Form 10 -403 (AOGCC's and operator's copies). Instead, we will check the "Suspended" box. Guy and Winton will serve as quality control for steps 1 and 2. 3. When Steve McMains receives the Form 10 -403 with a check in the "Plug for Redrill" box, he will enter the existing code "IBPRD" into RBDMS. This code automatically generates a comment under the History tab stating "Intent: Plug for Redrill." 4. When Steve McMains receives any Form 10 -407, he will check the History tab in RBDMS for this comment. If he sees the "Intent: Plug for Redrill" code, and cannot find any evidence that a subsequent re -drill has been COMPLETED, he will assign a status of SUSPENDED to the well bore in RBDMS, no matter what status is listed on the 10 -407. Steve will also change the status on the 10 -407 form to SUSPENDED, and will date and initial his change. If Steve does not see the "Intent: Plug for Redrill" comment or code, he will enter the status listed on the Form 10 -407 into RBDMS. 5. When the Form 10 -407 for the redrill is received, Steve M. will change the original well's status from suspended to abandoned. 6. The first week of every January and July, Steve M. and Steve D. will check the "Well by Type Work Outstanding" user query in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, Steve M. and Steve D. will also review the list of suspended wells for accuracy. Thanks, Steve D. file: //F: \Daily_Document Record \Procedures_Instructions \FW INTENT PLUG for RE- DRI... 4/6/2012 04/18/11 $chki merger NO. 5719 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 S Log Description Date BL Color CD 01 -16 BCRD -00092 PRODUCTION PROFILE (7—') V 03/11/11 1 /y. 1 14 -12 BBKA -00091 PRODUCTION PROFILE ( / n 03/05/11 1 J 1 Z -02A BJOH -00013 INJECTION PROFILE L) 74... f. - n /3 03/14/11 1 / 1 13 -09 BDAD -00038 LDL U IC /V— 03/19/11 1 / 1 L5 -36 BJOH -00014 PRODUCTION PROFILE C - ( 03/16/11 1 / 1 L4 -15 BBSK -00059 PRODUCTION PROFILE n 03/16/11 1 ' •" J 1 03 -25A BG4H -00042 PRODUCTION PROFILE / . I 03/18/11 1 e . : '3 1 Z -112 BL65 -00021 MEM PROD PROFILE O 03/01/11 1 1 F -35 �, � , { t�� BG4H -00037 RST 'S Q/ 02/23/11 1 0' l 1 J -17C BAUJ -00061 MCNL 1 ?^-� 02/09!11 1 _ ♦r A.' 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. Anchorage, AK 99503 -2838 • RECEIVED APR 19 2011 =... .= Co oote kodierw 03/08/11 Schlumberger NO. 5701 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil 8 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 W -202 BMSA -00004 MDT J (().- /g 01/22/11 aO ' - ic3 1 1 W -202 BMSA -00005 ISOLATION SCANNER (USIT ,..9.0— i 33 01/30/11 1 1 1 V -02 BL85 -00018 SCMT Ong- (? A -39A BL65 -00018 MEM DEPTH CORRELATION O — 'I _ 02/01/11 1 1 02/03/11 1 � - 1 J -17C BAUJ -00061 MEM PROD PROFILE 4 O �r{ 02/09/11 1 1. a -�-c a, 1 18-13C AWJI -00128 MEMORY CBL /O _ / 02/10/11 a 1 1 R -12 BBKA -00087 PRIMARY DEPTH CONTROL LOG /* -' 17:3, j' 02/18/11 1 1 D -21 BG4H -00036 PRODUCTION PROFILE , a 02/20/11 1 1 W -18 BJOH -00010 PRODUCTION PROFILE fraffillel 02/13/11 1 1 H -20 BBSK -00051 PRODUCTION PROFILE 4. , — a , `.¢ 02/11/11 1 Q $ ?- 1 • P2 -52 BCRD -00082 SCMT ( q 9- — ,,WII ( I 02/10/11 00. A 1 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data 8 Consulting Services Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 ' MA . ) • MAR 1 4 f D! 1 C......g C~ WELL LOG TRANSMITTAL To: State of Alaska February 26, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs : J-17C AK-MW-3959209 J-17C: 2" x 5" MD TC Logs: 50-029-20969-03-00 2" x 5" TVD TC Logs: 50-029-20969-03-00 Digital Log Images: SO-029-20969-03-00 1 Color Log . ~, -` ~ ~ .~ ,~ 1 Color Log c ~, ~I,~ ~ CAN d +,~ ~~~ ~ ~~ ~' ~ G~~ 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 ~~~ ~~~ ~ 2D0~ ~~~~ Date °' ~' " J,/,~ Signed: 1 h.........._...,._. _.~..,~.__.. ,,.~.. ~~ ova ~ ~s~5-~ • i WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: J-17C February 26, 2008 '~~ AK-MW-3959209 1 LDWG formatted CD rom with verification listing. API#:50-029-2096903-00 ~. ~, ~ 3 ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anch<arag~ , -Alaska--9~5~18 L ~ ~ ~ ~r Date: BP Exploration (Alaska) Inc. Petrotechnical Data Center MB33 900 E. Benson Blvd. Anchorage, Alaska 99508 ti Signed: ~C~~ SCAR ~ ~ Z00~ ~oS-a'~a ~' ls~~ ll M~~ ~rJ~? DATA SUBMITTAL COMPLIANCE REPORT 11 /23/2007 Permit to Drill 2050820 Well Name/No. PRUDHOE BAY UNIT J-17C Operator BP EXPLORATION (ALASKA) INC MD 12387 TVD 9023 Completion Date 10/11/2005 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION Mud Log No Samples No API No. 50-029-20969-03-00 UIC N Directional DATA INFORMATION Types Electric or Other Log s Run: DIR / GR /RES, DIR / GR /RES / NEU / ABI Well Log Information: Log/ Electr Data Digital Dataset yp Med/Frmt Number Name D D Asc Directional Survey ~D D Asc Directional Survey y~D C Las 15437 See Notes Well Cores/Samples Information: Interval Name Start Stop ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? ~ Y ! N Analysis Y !r-_N___ Received? (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 8892 12387 Open 11/17/2005 Definitive 8892 12387 Open 11/17/2005 MWD 8800 12388 Open 9/17/2007 Field Data, LAS - FNC, GR, NCN, NPHI, PEF, ROP w/EMF Graphics Sample Set Sent Received Number Comments Daily History Received? ~ N Formation Tops ~N Comments: Compliance Reviewed By: __. _ _ ____ Date: Date 09-14-2007 Transmittal Number:92903 BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) have any questions, please contact llouglas L)ortcn at the rli~ at ~o4-4y i ~ v~C- slivery Contents CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 06-06B ~ rSY2b Oti-Ot3BPB1 ~ ~~-~~ ~ ~ yam 13-31 A -uzC9o5 1(00 ~ t5'-/2~ 14-11 A `~ aos !a6 ~S~a 14-11 APB1 14-21 A vi~ao~ -rod ~ +5 ~i31 15-39A ao(o-o~~r ~ ibry3a 16-06Baac.-opt '+ os~133 16-14Bao(o-o~3 "~sv3y C-036 905- i5`6 '~ X6;135 C-10A aoS t3~ • 45Ya~ J-17C ~ O~f2 ~ +5`-~3~' NGI-07A uz~acX.-,aV ~' t5~1c3~ /11 J ~' Please ign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 7 ~` a J S '~ 3 ~ n~-~ ~~ ~~ 3 .~~ ~.. -- `~~:~ ;,,~t:~rissicp3 i~vlf $ '~4 ~'-. J wl- s'i1C~;C~~isi Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 1.96612 Anchorage, AK 99519-6612 STATE OF ALASKA ~~~~'~~~ ALASKA OIL AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG N~V ~' ~ ~~~~ Alaska Oil & Gas Cons. Corrxnission Ancherana ia. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG 20AAC 25.105 20AAC 25.110 ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 10/11/2005 12. Permit to Drill Number 205-082 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 9/28/2005 13. API Number 50-029-20969-03-00 4a. Location of Well (Governmental Section): Surtace: ' ' 7. Date T.D. Reached 10/6/2005 14. Well Name and Number: PBU J-17C 801 SNL, 1806 WEL, SEC. 09, T11N, R13E, UM Top of Productive Horizon: 1775' SNL, 3407' EWL, SEC. 10, T11 N, R13E, UM g, KB Elevation (ft): 69.8' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 2204' SNL, 4573' EWL, SEC. 10, T11N, R13E, UM 9. Plug Back Depth (MD+TVD) 12302 + 9023 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 642547 y- 5970534 Zone- ASP4 10. Total Depth (MD+TVD) 12387 + 9023 Ft 16. Property Designation: ADL 028281 TPI: x- 647779 y- 5969661 Zone- ASP4 Total Depth: x- 8955 Y- 5969255 Zone- ASP4 64 11 • Depth where SSSV set None MD 17. Land Use Permit: _ _ 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900 (Approx.) 21. Logs Run: DIR / GR /RES, DIR /GR /RES / NEU / ABI 2. CASING, LINER AND CEMENTING RECORD CASING ETTINCi EPTH MD ETTIN(i EPTH TVD HOLE , AMOUNT SIZE. WT. PER FT. GRADE OP TTOM OP TTOM 'SIZE' CEMENTING RECORD PULLED 20" x 30" Insulated Conductor Surtace 110' Surtace 110' 36" 8 cu ds Concrete 13-3/8" 72# L-80 Surface 2685' Surtace 2685' 17-1/2" 3856 cu ft Arcticset III & II 9-5/8" 47# L-80 Surtace 8931' Surface 7551' 12-1/4" 360 cu ft'G', 132 cu ft Permafrost 7" 26# L-80 8774' 10234' 7429' 8435' 8-1/2" 348 cu ft Class'G' 4-1/2" 12.6# L-80 10067' 12387' 8325' 9023' 6-1/8" 37 cu ft Class'G' 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2-7/8" Gun Diameter, 4 spf 4-1/2", 12.6#, 13Cr80 10083' 10027' MD TVD MD TVD 11350' - 11500' 9024' - 9031' 11750' - 11920' 9031' - 9028' 25. Aclo, FRACTURE, CEMENT SQUEEZE, ETC. 12000' - 12285' 9026' - 9023' DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED Freeze Protect w/ 153 bbls of Diesel 26. PRODUCTION TEST Date First Production: October 28, 2005 Method of Operation (Flowing, Gas Lift, etc.): Flowing Date of Test 11/7/2005 Hours Tested 4 PRODUCTION FOR TEST PERIOD OIL-BBL 758 GAS-MCF 4,151 WATER-BBL 65 CHOKE SIZE 82.75° GAS-OIL RATIO 5,474 Flow Tubing Press. 94 Casing Pressure 1,200 CALCULATED 24-HOUR RATE OIL-BBL 4,550 GAS-MCF 24,907 WATER-BBL 390 OIL GRAVITY-API (CORK) 25.4 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none' . t None jj ~ ~ ~~. ~~V ~ ~ Z~QrJ !~~/" a r~/L.e_ FOrm 10-407 Revised 12/2003~~~ ~ ~ ~ ~~ INUED ON REVERSE SIDE „~' 28. GEOLOGIC MARKERS 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Sag River 10232' 8272' None Shublik 10289' 8471' Sadlerochit 10419' 8556' Top CGL /Zone 3 10693' 8735' Base CGL /Zone 2 10805' 8811' 25N 10893' 8870' 23N 10987' 8921' 22N 11034' 8944' 21N 11116' 8977 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. / t Signed Terrie Hubble Title Technical Assistant Date ` ! t ~ (QS PBU J-17C 205-082 Prepared By Name/Number• Terrie Hubble, 564-4628 Well Number Permit No. / A rOVal NO. Drilling Engineer: Phil Sm/th, 564-4897 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 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. 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: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). YrEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only Printed: 10/14/2005 3:56:44 PM I-~J BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date ~; From - To 9/22/2005 16:00 - 00:00 9/23/2005 100:00 - 09:30 09:30 - 12:00 12:00 - 17:30 17:30 - 22:00 22:00 - 22:30 22:30 - 23:30 23:30 - 00:00 9/24/2005 100:00 - 03:00 Page 1 of 7 J-17 J-17B Spud Date: 1/3/2002 REENTER+COMPLETE Start: 9/22/2005 End: NABORS ALASKA DRILLING I Rig Release: 10/11/2005 NABORS 2ES Rig Number: 2ES Hours Task ,Code NPT 8.00 MOB P 9.50 MOB P 2.50 MOB P 5.50 MOB P 4.50 MOB P 0.50 MOB P 1.00 MOB P 0.50 KILL P 3.00 KILL P 03:00 - 04:00 1.00 WHSUR P 04:00 - 08:00 4.00 WHSUR P 08:00 - 10:30 2.50 BOPSU P 10:30 - 18:30 8.00 BOPSU P 18:30 - 19:30 1.00 WHSUR P 19:30 -20:30 1.00 PULL P 20:30 - 21:30 I 1.001 PULL I P 21:30 - 22:00 22:00 - 00:00 9/25/2005 00:00 - 01:30 0.50 PULL P 2.00 PULL P 1.50 PULL P 01:30 - 09:30 09:30 - 12:00 8.00 PULL P 2.50 BOPSU P 12:00 - 22:00 I 10.001 CLEAN I P 22:00 - 00:00 I 2.001 DHB I P Phase Description of Operations PRE Exception rig move from DS14 to J Pad.Substructure module on K- Pad road Q 0000 hrs - no problems. Pit module, camp, and truckshop on DS14. PRE Continue exception rig move with substructure module. Lay matting boards /move rig fromG pad road to J Pad. PRE Spot sub on J-17C. Raise Derrick. PRE Move camp, pits, and shop from DS14 to J-pad. Raise cattle chute. RU floor. Bridlel down derrick. RU top drive. Close cellar door and install second annular valve. PRE Spot shop, pits, camp, cuttings pit, and out buildings. Berm cellar, pits, and cuttings tank. RU pits. PRE RU DSM. Pulled BPV. Tubing /Csg press - 0 psi. Continue rigging up. PRE Test gas alarms, take on water, adjust suction valves in pits, RU circ lines. Accept rig C~ 2330 hrs 9-23-05. DECOMP Pre spud meeting with crew, tool pusher, DS leader, mud enginner. DECOMP Test lines to 1,000 psi. Tubing /Csg press 0 psi. Rev circ 50 bbls diesel out tubing. Pump down tubing -circ out 100 bbls diesel out csg. Pump soap pill and circ hole with clean 8.4 ppg sea water - 9 BPM Q 1,100 psi. Observe well -static. RD circ lines. DECOMP Dry rod TWCV. Test from below to 1,000 psi. DECOMP ND Tree and adaptor flange. Clean up hanger and inspect hanger threads. Break down tree and remove from cellar. DECOMP NU BOP's. Install mouse hole. DECOMP Fill stack. Rig up to test. Repair test pump. Test BOPE to 250 psi low and 3,500 psi high as per BP policy.Test witness waived by Chuck Scheve w/ AOGCC. Test witnessed by Bill Decker - Wellsite leader, and Charlie Henley -Tool pusher. RD test equip /blow down. DECOMP RU DSM lubricator /extension. Pulled TWCV. DECOMP M.U. landing joint. Back out lock down screws. RU handling tools for 5.5" tubing. PJSM. DECOMP Pull tbg hanger to rig floor. No over pull. String wt. 180K. Monitor well -stable. L.D. hanger and landing joint. DECOMP RU spooling unit. DECOMP POOH L.D. 34 jts 5 1/2" tubing and spooling up control line. DECOMP POOH laying down 5 1/2" tubing and spooling control line. LD SSSV. RD spooling unit. Clean and clear floor. Rec 26 clamps and 4 ss bands. DECOMP POOH laying down 5 1/2" tubing and GLM's. Recovered total 209 jts and cut off piece (19.70'), 11 GLM's, SSSV. Hang tongs and change elevators. Clear floor. DECOMP MU 4" test joint. Install test plug. Test upper and lower rams, annular, and floor valves to 250 psi low and 3,500 psi high. Test witnessed by Charlie Henley -tool pusher and Bill Decker - DS leader. RD test equip. Install wear ring. DECOMP PJSM. RU SWS. Ran 8.5" Gauge ring/ JB/ CCU GR. Tagged up @ 9,110'. Ran GR/ CCL correlation log. POOH. Junk basket full of contol line plastic coating. Made 3 more runs w/ GR / JB. No recovery in JB on last run to 9,050'. DECOMP MU 9 5/8" EZSV plug w/ GR /CCL. RIH and spot plug Printed: 10/14/2005 3:56:51 PM • BP EXPLORATION Operations Summary Report Page 2 of 7 Legal Well Name: J-17 Common Well Name: J-17B Spud Date: 1/3/2002 Event Name: REENTER+COMPLETE Start: 9/22/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/11/2005 Rig Name: NABOBS 2ES Rig Number: 2ES Date I~, From - To Hours Task I; Code NPT ' Phase ~'~ Description of Operations 9/25/2005 22:00 - 00:00 2.00 DHB P DECOMP 8,962'. Setting tool would not fire. 9/26/2005 00:00 - 00:30 0.50 DHB N DFAL DECOMP Attempt to set 9 5/8" EZSV plug C~ 8 962'. Unable to fire ignitor. 00:30 - 01:30 1.00 DHB N DFAL DECOMP POOH w/ wire line and 9 5/8" EZSV plug. 01:30 - 03:00 1.50 DHB N DFAL DECOMP L.D. EZSV plug and setting tool. Behead line. Change out CCL and ignitor. Check out tools at surface. MU setting tool and EZSV plug. 03:00 - 04:00 1.00 DHB N DFAL DECOMP RIH w/ 9 5/8" EZSV plug and CCL. Set EZSV plug @ 8,962'. 04:00 - 05:00 1.00 DHB P DECOMP POOH with W.L. and setting tool. UD same. 05:00 - 06:00 1.00 CASE P DECOMP R/U & test 9 5/8" Casing to 3500 psi. Chart test for 30 minutes. Bleed pressure & rig down test equip. Test witnessed by Mike Whiteley - BP WSL. 06:00 - 13:00 7.00 EVAL P DECOMP SWS ran USIT log from 8,932' to surface. Log showed max 20% metal loss perdominately in high dogleg interval f/ 7,800' - 7,950. RD SWS. 13:00 - 14:00 1.00 STWHIP P WEXIT PJSM. RU handling tools. Prep W.S. BHA. 14:00 - 18:30 4.50 STWHIP P WEXIT MU whipstock / 8 1/2" window milling BHA. Orient. Upload MWD. Surface test tools. PU DC's and HWDP. Change out handling tools. 18:30 - 19:00 0.50 STWHIP N RREP WEXIT Work on iron roughneck. 19:00 - 00:00 5.00 STWHIP P WEXIT RIH w/ whipstock /window mills picking up 140 jts 4" DP to 5,239'. (make up DP w/ spinning chain). 9/27/2005 00:00 - 04:00 4.00 STWHIP P WEXIT RIH w/ whipstock & window mills picking up 4" DP to 8,910'. Fill pipe @ 2000' intervals. 04:00 - 04:30 0.50 STWHIP P WEXIT Lubricate rig .Service top drive. Connect blower hose. 04:30 - 05:00 0.50 STWHIP P WEXIT Orient whipstock 76 deg LHS - 500 gpm - 2200 psi. Up 210K, DN 155K. Tagged plug @ 8,952' -sheared and set BT anchor w/ 22k down. Pull 10K over on anchor 2X. Sheared off whipstock w/ 39k down. Mill hung up -pulled 25K over w/ 8K torque and mill came free. 05:00 - 06:00 1.00 STWHIP P WEXIT Displace well to 11.2 ppg LSND mud -pumped 50 bbl high vis spacer, 600 bbls 11.2 ppg mud - 500 gpm - 2200 psi. Torque = 7/8K off bottom. Rotate and reciprocate. 06:00 - 13:00 7.00 STWHIP P WEXIT Mill window in 9 5/8" casing from 8931' to 8947'. Drill 20' of new hole to 8959'. Pump C~ 400 gpm Q 1940 psi. Torque while milling = 11 K. WOB = 5K, RPM = 105. Recovered 50 pounds metal cuttings. 13:00 - 16:00 3.00 STWHIP P WEXIT Circ super sweep around, small amount of metal back. Pump super sweep # 2 @ 500 gpm @ 2400 psi. Work mills through window. Rack back 1 stand DP. 16:00 - 17:00 1.00 STWHIP P WEXIT Slip and cut 112' of drill line. Service crown, inspect desks. 17:00 - 18:00 1.00 STWHIP P WEXIT Service top drive. 18:00 - 18:30 0.50 STWHIP P WEXIT Perform F.I.T. to 12.4 EMW @ 475 psi. TVD = 7551'. Pressure up to 510 psi, pressure dropped slowly and stabalized C~J 475 psi. Pumped 1.4 bbl C~ .5 bpm. 18:30 - 22:00 3.50 STWHIP P WEXIT Pump dry job, blow down surface equip. POH for drilling BHA. 22:00 - 00:00 2.00 STWHIP P WEXIT POH with BHA from 1018', UD drill collars and mills. Clear rig floor. 9/28/2005 00:00 - 01:30 1.50 STWHIP P WEXIT Change elevators, pull wear ring. P/U Johnny Wacker & flush BOP stack, function rams. Blow down kill line, choke line and top drive. 01:30 - 05:00 3.50 STWHIP P WEXIT P/U BHA. M/U Hughes HCM605 bit & 1.5 degree mud motor and MWD, orient. Upload MWD, P/U flex collars, jars &HWDP Printed: 10/14/2005 3:56:51 PM • BP EXPLORATION Operations Summary Report Page 3 of 7 Legal Well Name: J-17 Common Well Name: J-176 Spud Date: 1/3/2002 Event Name: REENTER+COMPLETE Start: 9/22/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/11/2005 Rig Name: NABOBS 2ES Rig Number: 2ES Date ~ From - To - -Hours Task Code NPT Phase ~~ Description of Operations 9128!2005 05:00 - 08:30 3.50 STWHIP P WEXIT RIH P/U drill pipe from 812' to 5108'. Fill pipe @ 2700' intervals. 08:30 - 10:30 2.00 STWHIP P WEXIT RIH with stands from 5108' to 8838', RIH @ 90 fpm. Fill. pipe @ 2800' intervals. Install top drive blower hose. Orient BHA to pass through window. Take SPRs. Tag bottom @ 8959'. 10:30 - 00:00 13.50 DRILL P INT1 Drill from 8959' to 9470'. UWT = i80K, DWT = 140K, RWT = 160K. Torque off bottom = 7K, on = SK @ 70 rpm. WOB = 11 K. Pump @ 480 gpm @ 2830/3100 psi. ART = 3.61, AST 4.49 hrs. TVD = 7936'. 9/29/2005 00:00 - 17:00 17.00 DRILL P INT1 Drill ahead from 9470' to casing point TD @ 10234'. AST total = 6.37, ART total = 11.65 hrs. HWT = 190K, DWT = i40K, RWT = 160K. Torque off bottom = 7K, on = 10K @ 70 rpm. WOB = 11 K. Pump @ 485 gpm @ 3250/3500 psi. 17:00 - 18:30 1.50 DRILL P INTi Pump high vis sweep @ 480 gpm @ 3300 psi. Rotate & reciprocate. 18:30 - 19:30 1.00 DRILL P INT1 Monitor well. Short trip, POH from 10234' to window in 9 5/8" casing @ 8931'. Limit pulling speed to 60 fpm. 19;30 - 20:00 0.50 DRILL P INT1 Service top drive. 20:00 - 20:30 0.50 DRILL P INTi RIH from 8931' to bottom @ 10234'. Hole in good shape. Limit running speed to 60 fpm. 20:30 - 22:30 2.00 DRILL P INT1 Pump high vis sweep. Spot liner running pill and pump dry job. 22:30 - 23:30 1.00 DRILL P INTi POH from bottom @ 10234' to 8960'. Limit pulling speed to 60 fpm. 23:30 - 00:00 0.50 DRILL P INT1 MAD pass from 8960' to 8830' @ 300 fph. Drop drill pipe drift @ window. 9/30/2005 00:00 - 03:30 3.50 DRILL P INT1 POH from 8830' to 812'. 03:30 - 07:30 4.00 DRILL P INT1 UD BHA, Retreive drill pipe drift. Flush MWD tools, down load MWD, UD 20 HWDP, jars, 3 flex collars, MWD, bit & motor. 07:30 - 08:30 1.00 CASE P LNR1 R/U 7" casing equipment, PJSM. 08:30 - 11:00 2.50 CASE P LNR1 M/U 7" float equip, check floats are holding. RIH with 7" 26# L-80 BTC-M liner to 1436'. 11:00 - 11:30 0.50 CASE P LNRi M/U liner hanger, change out handling equip. M/U 1 stand of drill pipe . 11:30 - 12:00 0.50 CASE P LNR1 Circ liner volume @ 3 bpm @ 160 psi. Clear rig floor. HWT = 65K, DWT = 60K. 12:00 - 16:30 4.50 CASE P LNR1 RIH with liner on 4" drill pipe from 1566' to 8909'. Running speed = 90 fpm. Fill pipe @ 930' intervals. 16:30 - 17:00 0.50 CASE P LNR1 UD single of drill pipe, circ 1.5 times liner and drill pipe volume @ 7 bpm @ 1060 psi. HWT = 180K, DWT = 125K. 17:00 - 18:00 1.00 CASE P LNR1 RIH from 8909' to 10202' @ 60 fpm. 18:00 - 18:30 0.50 CEMT P LNR1 M/U cement head and joint of drill pipe, break circ and tag bottom @ 10234'. 18:30 - 19:00 0.50 CEMT P LNR1 Circ, stage pump up to 6 bpm @ 1330 psi. PJSM with drill crew, cementers, Baker tools Rep. & WSL. 19:00 - 20:30 1.50 CEMT P LNR1 Line up cementers, pump 3 bbl water & pressure test lines to 4500 psi. Pump 30 bbl of 12.2 ppg MudPush spacer followed by 62 bbls (324 sx) of 15.8 ppg class "G" cement @ 5 bpm. Drop plug, displace with mud @ 6 bpm. Observe liner wiper latch up, bump plug with 4000 psi & set liner hanger. Slack off 50K to confirm hanger is set. Bleed off pressure. Rotate 15 turns to the right to release from hanger. Pressure up to 1000 psi and unsting from liner. Pump 30 bbl @ 12 bpm to circ cement off {finer top. PJU to expose dog sub, slack off 70K to Printed: 10/14/2005 3:56:51 PM C, BP EXPLORATION Operations Summary Report Page 4 of 7 Legal Well Name: J-17 Common Well Name: J-17B Spud Date: 1/3/2002 Event Name: REENTER+COMPLETE Start: 9/22/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/11/2005 Rig Name: NABOBS 2ES Rig Number: 2ES Date From - To Hours Task ~~ Code NPT 9/30/2005 19:00 - 20:30 ~ 1.50 (CEMT I P 20:30 - 22:30 I 2.001 CEMT I P 22:30 - 23:30 1.00 CASE P 23:30 - 00:00 0.50 CASE P 10/1/2005 00:00 - 03:30 3.50 CASE P 03:30 - 05:30 I 2.001 DRILL I P 05:30 - 09:30 4.00 DRILL P 09:30 - 10:00 0.50 DRILL P 10:00 - 11:00 1.00 DRILL P 11:00 - 13:00 2.00 DRILL P 13:00 - 16:00 1 3.001 DRILL I P 16:00 - 17:00 1.00 DRILL P 17:00 - 17:30 0.50 DRILL P 17:30 - 00:00 6.50 DRILL P 10/2/2005 100:00 - i 1:30 I 11.501 DRILL i P 11:30 - 12:00 0.50 DRILL P 12:00 - 12:30 0.50 DRILL P 12:30 - 16:30 4.00 DRILL P 16:30 - 17:30 1.00 DRILL P 17:30 - 19:00 I 1.501 DRILL I P 19:00 - 21:30 I 2.501 DRILL I P 21:30 - 00:00 I 2.501 DRILL I P 10/3/2005 00:00 - 01:00 1.00 DRILL P 01:00 - 01:30 0.50 DRILL P 01:30 - 02:00 0.50 DRILL P 02:00 - 02:30 0.50 DRILL P 02:30 - 00:00 21.50 DRILL P Phase Description of Operations LNR1 set liner top packer. Rotate down 2 times to confirm packer is set. CIP @ 20:20 hrs. LNR1 Circ out excess cement ~ 12 bpm C~3 3500 psi. Trace of cement to surface. Pump dry job, UD cement head. Clear and clean rig floor. Clean shaker beds, possum bellies and troughs. LNR1 Slip and cut 76' of drill line. LNR1 POH with 4" drill pipe from 8737' to 7845'. LNR1 POH from 7845', UD 7" liner running tool. Clear and clean rig floor. PROD1 P/U 6 1/8" drilling assy, Hughes MX-18DX bit & 1.5 degree mud motor & Dir/GR/Res. Upload, P/U DCs, HWDP & jars. RIH to 446' & shallow hole test. PRODi RIH, tag cement Q 10131'. PROD1 Clean out to landing collar C~ 10147'. PROD1 Test 9 5/8" casing and liner to 3500 psi for 30 min. OK. PRODi Clean out liner and drill float equip to 10230'. Pump @ 240 gpm @ 2100 psi, torque C~ 50 rpm = 9/11 K. PRODi Pump high vis spacer & displace well to 8.4 ppg FloPro mud. Pump @ 273 gpm C~ 1400 psi. Clean possum bellies, shaker beds and troughs. Change shaker screens and take slow pump rates. PROD1 Drill shoe and new formation to 10259'. PROD1 Pull bit into liner. Perform FIT to 9.9 ppg EMW. (700 psi with 8.4 ppg mud @ 8435' TVD.) PROD1 Drill from 10259' to 10410'. AST = .14 ART = 6.01 hrs. UWT = 185K, DWT = 135K, RWT = 163K. Torque = 9/10K on and off bottom Q 55 rpm. WOB = 12K. pump Q 272 gpm @ 1365 psi off bottom and 1470 psi on. PRODi Drill 6 1/8" hole to from 10410' to 10896'. UWT = 190K, DWT = 145K, RWT = 165K. Torque off bottom = 6, on = 7K @ 55 rpm. Pump @ 274 gpm @ 1630 psi. AST = 1.47 ART = 7.42. PROD1 POH to shoe @ 10234', hole in good shape. PROD1 Ope circ sub and pump dry job. PROD1 POH from 10234' to BHA @ 353' PROD1 Stand back HWDP, jars & flex collars. Break bit, down load MWD. L/D mud motor. PROD1 M/U test joint, drain stack, pull wear ring, install test plug and test upper pipe rams to 250 psi low and 3500 psi high test as per AOGCC regulation. Install wear ring & UD test joint. PRODi M/U BHA. P/U HTC HCM406 bit, service float, M/U MWD & up load. Surface test. PJSM. Load nukes, RIH with flex collars, HWDP & jars to 378'. PROD1 RIH from 378' to 8777'. Fill pipe and test MWD @ 3000' intervals. PROD1 RIH from 8777' to 10179'. PROD1 Service top drive & crown. PROD1 RIH to 10831'. Hole in good shape. PROD1 Ream from 10831' to 10896'. PROD1 Drill from 10896' to 11288'. AST = 6.01 hrs, ART = .66 hrs. HWT = 195K, DWT = 145K, RWT = 172K. Pump Q 275 gpm 1725 psi. WOB = 1 to 5K. Torque off bottom = 6K, on = 7K 50 rpm. Printed: 10/14/2005 3:56:51 PM ~1 L_J BP EXPLORATION Operations Summary Report Page 5 of 7 Legal Well Name: J -17 Common W ell Name: J -176 Spud Date: 1/3/2002 Event Nam e: REENTE R+COM PLET E Start : 9/22/2005 End: Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 10/11/2005 Rig Name: NABOB S 2ES Rig Number: 2ES Date ~ From - To Hours Task Code I, NPT Phase i Description of Operations 10/4/2005 00:00 - 04:30 4.50 DRILL P PROD1 Drill from 11288' to 11374'. AST = 1.35 hrs, ART = 1.64 hrs. Prepare to POH, ROP dropped to 19 fph. 04:30 - 05:30 1.00 DRILL P PROD1 POH to 7" shoe @ 10234'. Drop dart on pump out sub and shear, pump dry job. 05:30 - 08:30 3.00 DRILL P PROD1 POH to 387'. 08:30 - 10:30 2.00 DRILL P PROD1 BHA: Down load nukes and MWD. Break bit. 10:30 - 14:30 4.00 DRILL P PROD1 P/U bit # 4, remove stb on mud motor, change directional modul and pulsar on MWD, upload. Upload unsuccessful. Break & UD directional module, plug into, reprogram and upload. M/U DM &MWD tools. Scribe & pulse test. PJSM. Load nukes. M/U BHA to 378'. 14:30 - 18:00 3.50 DRILL P PROD1 RIH from 378' to 10180'. Fill pipe and test MWD @ 2700' intervals. 18:00 - 19:30 1.50 DRILL P PROD1 Slip & cut 65' of drill line, adjust brakes, install top drive blower hose. Set crown savers. 19:30 - 20:00 0.50 DRILL P PROD1 RIH from 10180' to 11297'. 20:00 - 00:00 4.00 DRILL P PROD1 Wash & ream from11297' to 11374'. Drill from 11374' to 11495'. AST = .26 hrs, ART = 1.93 hrs. UWT = 195K, DWT = 140K, RWT = 172K. Torque off bottom = 6K, on = 6/7K @ 50 rpm. WOB = 5K. Pump @ 274 gpm @ 1650 psi. 1015!2005 00:00 - 13:30 13.50 DRILL P PROD1 Drill from 11495' to 11949'. AST = 3.78 hrs, ART = 7.73 hrs. UWT = 190K, DWT = 135K, RWT = 170K. Torque on bottom = 6/7K, off = 6K @ 40 rpm. WOB = 5/10K. Pump @ 250 gpm @ 1625 psi. 13:30 - 15:30 2.00 DRILL P PROD1 Pump high vis sweep, CBU. Pump dry job, monitor well. 15:30 - 16:00 0.50 DRILL P PROD1 POH from 11949' to 10900'. UWT = 205K. Hole in good shape. 16:00 - 19:00 3.00 DRILL P PROD1 Log MADD pass up from 10900' to 10300' @ 300 fph & rotating @ 10 rpm. Hole in good shape. 19:00 - 23:00 4.00 DRILL P PROD1 POH from 10300' to BHA @ 378'. 23:00 - 00:00 1.00 DRILL P PROD1 Handle BHA, stand back HWDP,jars & flex collars. PJSM. Remove nuke tools and down load MWD. 10/6/2005 00:00 - 01:30 1.50 DRILL P PROD1 BHA, Down load MWD. Break & UD directional module tool, break bit & stab blade. UD failed mud motor. 01:30 - 03:00 1.50 DRILL P PROD1 P/U new mud motor. M/U stab & Hughes MX18-HDX bit. P/U directional module tool, orient, upload MWD & pulse check. Load nukes, RIH with BHA to 378'. 03:00 - 06:30 3.50 DRILL P PROD1 RIH to 10180'. 06:30 - 07:00 0.50 DRILL P PROD1 Service top drive. 07:00 - 07:30 0.50 DRILL P PROD1 RIH to bottom @ 11949'. Hole in good shape. 07:30 - 13:30 6.00 DRILL P PROD1 Drilling from 11949' to 12042'. 13:30 - 14:30 1.00 DRILL P PROD1 Directional work, Casandra surveys and check shots. 14:30 - 23:00 8.50 DRILL P PROD1 Drill from 12042' to TD @ 12387'. AST = 1.87 hrs, ART = 5.26 hrs. UWT = 200K, DWT = 135K, RWT = 168K. Torque on and off bottom = 7/8, 50 rpm. WOB = 5/10K. Pump @ 274 gpm @ 1650 psi. 23:00 - 00:00 1.00 DRILL P PROD1 Pump sweep, rotate and reciprocate. 10/7/2005 00:00 - 02:00 2.00 DRILL P PROD1 Circ, pump high vis sweep. Spot liner pill. 02:00 - 03:00 1.00 DRILL P PROD1 POH to 7" shoe @ 10234'• 03:00 -04:00 1.00 DRILL P PROD1 Monitor well. Drop dart and open pump out sub. CBU @ 522 Printed: 10/14/2005 3:56:51 PM r1 U BP EXPLORATION Page 6 of 7 Operations Summary Report Legal Well Name: J -17 Common W ell Name: J -176 Spud Date: 1/3/2002 Event Nam e: REENTE R+COM PLET E Start : 9/22/2005 End: Contractor Name: NABOB S ALASK A DRI LLING I Rig Release: 10!1112005 Rig Name: NABOB S 2ES Rig Number: 2ES Date '; From - To Hours ' Task Code I! NPT ', Phase I~, Description of Operations 10/7/2005 03:00 - 04:00 1.00 DRILL P PROD1 gpm @ 1540 psi. Pump dry job. 04:00 - 07:30 3.50 DRILL P PROD1 POH from 10234' to BHA @ 378'. 07:30 - 10:30 3.00 DRILL P PROD1 UD BHA. PJSM. Remove nukes from MWD tool. Down load MWD. UD MWD, bit and mud motor. Clear & clean rig floor. 10:30 - 11:30 1.00 CASE P RUNPRD PJSM. R/U to run 4.5" liner. 11:30 - 12:00 0.50 CASE P RUNPRD Service top drive and drawworks. 12:00 - 16:30 4.50 CASE P RUNPRD PJSM. M/U shoe track & check floats. RIH with 4 1/2" 11.6# L-80 LT & C liner. 16:30 - 17:00 0.50 CASE P RUNPRD Circulate liner volume. 17:00 - 21:00 4.00 CASE P RUNPRD RIH with liner on drill pipe to 7" shoe @ 10234'. 21:00 - 21:30 0.50 CASE P RUNPRD Circulate liner and drill pipe volume, blow down lines. 21:30 - 22:30 1.00 CASE P RUNPRD RIH to 12364'. Hole in good shape. 22:30 - 23:00 0.50 CASE P RUNPRD M/U cement head and circ lines. Tag bottom @ 12387'. 23:00 - 00:00 1.00 CASE P RUNPRD Circ and cond mud. HWT = 190K, DWT = 140K. Pump @ 6 bpm @ 1000 psi. 10/8/2005 00:00 - 01:00 1.00 CASE P RUNPRD CBU @ 12387', pump @ 6 bpm @ 1000 psi. UWT = 185K, DWT = 140K. 01:00 - 02:30 1.50 CEMT P RUNPRD PJSM with Drill crew, Schlumberger cement crew, $aker`& WSL. Pump 5 bbl water, test lines to 4500 psi. Pump 20 bbl CW100 pre flush followed by 25 bbl of 9.5 ppg mud push. Pump 60 bbl of 15.8 ppg class G cement @ 6 BPM. Wash lines up with pert pill to "T" on rig floor. Drop wiper plug. Displace with 30 bbls of pert pill and 102 bbls of mud @ 6 bpm. Bump plug with w/4000 psi. Slack off 80K to set liner hanger, check floats, held OK. CIP @ 02:30. 02:30 - 03:30 1.00 CEMT P RUNPRD Rotate 15 turns to the right & release from liner. Pressure up to 1000 psi & unsting. Pump 500 stks. Rotate down with 65K 3 times to set Liner Top Packer. Good surface indication. CBU @ 10006' @ 13 bpm @ 2350 psi. Approx 15 bbl cement returns. 03:30 - 05:00 1.50 CEMT P RUNPRD Displace well to 8.4 ppg seawater. Pump @ 10 bpm @ 2050 psi. 05:00 - 05:30 0.50 CEMT P RUNPRD UD cement head, manifold and hoses. 05:30 - 06:30 1.00 CEMT P RUNPRD Slip and cut drill line. Adjust brakes. 06:30 - 08:00 1.50 CEMT P RUNPRD POH from 10006' to 7842'. 08:00 - 08:30 0.50 CEMT P RUNPRD Service top drive, lubricate rig. 08:30 - 09:30 1.00 CEMT N RREP RUNPRD Replace quick release valve on low drum clutch. 09:30 - 13:00 3.50 CEMT P RUNPRD POH from 7842', UD drill pipe pups and XOs. Clear rig floor. 13:00 - 14:00 1.00 CEMT P RUNPRD Test casing to 3500 psi for 30 min. OK. 14:00 - 17:00 3.00 CEMT P RUNPRD Pull wear ring. Set test plug, test BOPE to 250 psi low test and 3500 psi high test. Test all choke manifold valves & top drive valves. Test top & bottom rams, blind rams, choke & kill lines. Test annular to 250 low & 3500 high. Test witnessed by AOGCC Rep Jeff Jones &WSL John Rall. 17:00 - 17:30 0.50 CEMT P RUNPRD Pull test plug, set wear bushing & blow down lines. 17:30 - 18:00 0.50 PERFO P OTHCMP R/U to run pert guns. 18:00 - 20:00 2.00 PERFO P OTHCMP PJSM with drill crew, Schlumberger pert crew &WSL. P/U 2 7/8" pert guns to 985'. 20:00 - 22:30 2.50 PERFO P OTHCMP Change handling tools & P/U 42 jts of 2 7/8" PAC drill pipe. RIH to 2295'. Change handling tools. 22:30 - 00:00 1.50 PERFO P OTHCMP RIH with pert guns on drill pipe to 8645'. 10/9/2005 00:00 - 02:30 2.50 PERFO P OTHCMP RIH with pert guns from 8645' to 4.5" landing collar @ 12301'. Tag landing collar & put guns on depth. UWT = 185K, DWT = 145K. PJSM with drill crew, Schlumberger pert crew &WSL. Printed: 10/14/2005 3:56:51 PM • BP EXPLORATION Operations Summary Report Page 7 of 7 Legal Well Name: J-17 Common Well Name: J-176 Spud Date: 1/3/2002 Event Name: REENTER+COMPLETE Start: 9/22/2005 End: Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 10/11!2005 Rig Name: NABOBS 2ES Rig Number: 2ES Date ~I From - To 'Hours Task Code' NPT i Phase ' Description of Operations 10/9/2005 02:30 - 03:30 1.00 PERFO P OTHCMP Fire pert guns, perf intervals = 12285' to 12000' 11920' to 11750' 11500' to 11350', 605" total perfs, 4 spf. POH from 12285' to 11258'. Monitor well, stable. Pump dry job, blow down lines. 03:30 - 10:00 6.50 PERFO P OTHCMP POH for 4.5" tubing LDDP from 11285' to 2294'. 10:00 - 15:30 5.50 PERFO P OTHCMP Change handling equipment to 2 7!8", POH UD 2 7!8" pipe to 995'. UD perf guns. Clear & clean rig floor. 15:30 - 16:30 1.00 PERFO P OTHCMP M/U mule shoe and RIH with drill pipe from derrick to 3290'. 16:30 - 18:30 I 2.00 PERFO P OTHCMP POH LDDP. 18:30 - 19:00 0.50 PERFO P OTHCMP Pull wear bushing. Make up landing jt. Clear rig floor. 19:00 - 20:00 1.00 BUNCO RUNCMP R/U to run 4.5" tubing. 20:00 - 00:00 4.00 BUNCO RUNCMP PJSM with drill crew, Baker Tech Rep, Toolpusher & WSL. RIH with 4.5" 12.6# 13Cr-80 Vam Top tubing to 3006'. 10/10/2005 00:00 - 05:30 5.50 BUNCO RUNCMP RIH with 4.5" 12.6# 13Cr-80 Vam Top tubing to 7591'. 05:30 - 06:00 0.50 BUNCO RUNCMP Service top drive, lubricate rig. 06:00 - 09:00 3.00 BUNCO RUNCMP RIH with 4.5" tubing from 7591' to top of 4.5" tie-back. 09:00- 10:00 1.00 BUNCO RUNCMP Space out tubing, M/U hanger. 10:00 - 10:30 0.501 BUNCO RUNCMP Land tubing on hanger & RILDS. 10:30- 15:00 4.50 BUNCO RUNCMP R/U to reverse circ. Test lines to 4000 psi. Displace annulus to inhibited seawater, pump 494 bbl @ 3 bpm @ 150 psi. 15:00 - 17:00 2.00 BUNCO RUNCMP Drop ball & rod, pressure up to 4000 psi with rig mud pump, isolate mud pump & pressure up to 4500 psi with rig test pump to set packer. Hold test for 1/2 hr, OK. Bleed pressure to 1500 psi, pressure up to 3500 psi and test annulus for 1/2 hr, OK. Bleed off tubing and shear DCR. 17:00 - 17:30 0.50 WHSUR P RUNCMP Set TWC valve and test from below to 1000 psi. 17:30 - 18:30 1.00 WHSUR P RUNCMP N/D BOPE. 18:30 - 21:00 2.50 WHSUR P RUNCMP Clean & prep well head, N/U adaptor flange & test to 5000 psi. 21:00 - 22:30 1.50 WHSUR P RUNCMP N/U 4 1/16" 5000 psi tree. Test tree to 5000 psi. 22:30 - 23:00 0.50 WHSUR P RUNCMP R/U DSM lubricator and pull TWC valve, R/D lubricator. 23:00 - 00:00 1.00 WHSUR P RUNCMP R/U circ lines and LRHOS. Test lines to 3000 psi, reverse circ 153 bbl of 6.8 ppg diesel freeze protect. 10/11/2005 00:00 - 02:30 2.50 WHSUR P RUNCMP Reverse circ 153 bbls of diesel freeze protect, U-tube same. 02:30 - 03:00 0.50 WHSUR P RUNCMP Install BPV & test from below to 1000 psi. 03:00 - 04:00 1.00 WHSUR P RUNCMP Remove secondary annulus valve & secure well. Rig released @ 04:00 hrs 10/11/2005 Printed: 10/14/2005 3:56:51 PM Halliburton Sperry-Sun North Slope Alaska BPXA J-17C Job No. AKMW0003959206, Surveyed: 6 October, 2005 Survey Report 17 October, 2005 Your Ref: API 500292096903 Surface Coordinates: 5970534.00 N, 642547.00E (70° 19' 37.3006" N, 148° 50' 38.2163" W) Grid Coordinate System: NAD27Alaska State Planes, Zone 4 Kelly Bushing Elevation: 69.80ft above Mean Sea Level s~c~rr-sun 17FR1t_L_tNG SERVICES A Halliburton Company Survey Ref: svy4676 • • Hal/iburton Sperry-Sun Survey Report for J-17C Your Ref: API 500292096903 Job No. AKMW0003959206, Surveyed: 6 October, 2005 North Slope Alaska BPXA Measured True Sub-Sea Vertical Local Coordinates Glo bal Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 8892.80 38 .720 114 .700 7451.55 7521. 35 957. 24 S 3554. 65E 5969644. 46 N 646119. 19E 3676 .66 Tie On Point MW D+I I FR+MS 8931.00 38 .640 114 .580 7481.37 7551. 17 967. 19 S 3576. 35E 5969634. 93 N 646141. 08E 0.287 3699 .97 Window Point 8964.38 40 .450 111 .520 7507.11 7576. 91 975. 50 S 3595. 90E 5969626. 99 N 646160. 78E 7.965 3720 .84 8995.99 41 .820 108 .630 7530.92 7600. 72 982. 63 S 3615. 43E 5969620. 23 N 646180. 44E 7.412 3741 .43 9026.82 42 .700 105 .800 7553.74 7623. 54 988. 76 S 3635. 23E 5969614. 48 N 646200. 36E 6.800 3762 .08 9056.54 43 .560 103 .080 7575.43 7645. 23 993. 82 S 3654. 90E 5969609. 79 N 646220. 12E 6.893 3782 .38 9088.98 44 .480 100 .100 7598.76 7668. 56 998. 35 S 3676. 98E 5969605. 69 N 646242. 28E 6.985 3804 .92 9119.47 45 .080 97 .310 7620.40 7690. 20 1001. 59 S 3698. 21E 5969602. 85 N 646263. 57E 6.739 3826 .35 9151.23 45 .830 94 .400 7642.68 7712. 48 1003. 90 S 3720. 72E 5969600. 97 N 646286. 12E 6.943 3848 .84 9185.86 46 .280 91 .890 7666.72 7736. 52 1005. 26 S 3745. 61E 5969600. 08 N 646311. 03E 5.378 3873 .46 9213.84 46 .980 89 .880 7685.93 7755. 73 1005. 58 S 3765. 95E 5969600. 15 N 646331. 37E 5.790 3893 .40 9245.04 47 .260 88 .900 7707.16 7776. 96 1005. 33 S 3788. 81E 5969600. 83 N 646354. 22E 2.470 3915 .69 9291.65 47 .590 88 .620 7738.70 7808. 50 1004. 59 S 3823. 12E 5969602. 22 N 646388. 52E 0.835 3949 .08 9338.99 47 .610 89 .370 7770.62 7840. 42 1003. 98 S 3858. 08E 5969603. 50 N 646423. 45E 1.171 3983 .11 9432.73 48 .700 87 .800 7833.16 7902. 96 1002. 24 S 3927. 88E 5969606. 56 N 646493. 21E 1.705 4050 .97 9481.79 48 .460 87 .720 7865.61 7935. 41 1000. 81 S 3964. 64E 5969608. 70 N 646529. 94E 0.504 4086 .60 9526.54 48 .000 87 .450 7895.42 7965. 22 999. 40 S 3997. 99E 5969610. 74 N 646563. 25E 1.122 4118 .89 9573.70 48 .250 85 .750 7926.90 7996. 70 997. 32 S 4033. 04E 5969613. 48 N 646598. 26E 2.736 4152 .71 9619:51 47 .660 85 .260 7957.58 8027. 38 994. 65 S 4066. 95E 5969616. 79 N 646632. 12E 1.513 4185 .30 9670.37 47 .180 85 .560 7992.00 8061. 80 991. 65 S 4104. 28E 5969620. 50 N 646669. 38E 1.039 4221 .15 9713.21 48 .000 87 .470 8020.89 8090. 69 989. 74 S 4135. 85E 5969623. 02 N 646700. 91E 3.808 4251 .60 9806.22 47 .500 88 .250 8083.43 8153. 23 987. 16 S 4204. 65E 5969626. 90 N 646769. 65E 0.821 4318 .30 9899.59 48 .100 87 .280 8146.15 8215. 95 984. 46 S 4273. 76E 5969630. 91 N 646838. 70E 1.003 4385 .29 9992.94 49 .410 89 .330 8207.69 8277. 49 982. 40 S 4343. 92E 5969634. 31 N 646908. 80E 2.167 4453 .42 10086.86 49 .090 89 .430 8269.00 8338. 80 981. 63 S 4415. 06E 5969636. 43 N 646979. 91E 0.350 4522 .79 10174.20 48 :730 88 .950 8326.40 8396. 20 980. 70 S 4480. 88E 5969638. 61 N 647045. 70E 0.584 4586 .93 10271.53 49 .620 88 .490 8390.03 8459. 83 979. 05 S 4554. 51E 5969641. 65 N 647119. 29E 0.982 4658 .55 10305.60 49 .770 87 .910 8412.07 8481. 87 978. 24 S 4580. 48E 5969642. 96 N 647145. 24E 1.371 4683 .76 10398.31 49 .000 88 .100 8472.42 8542. 22 975. 79 S 4650. 81E 5969646. 75 N 647215. 51E 0.845 4751 .99 10491.64 49 .390 86 .340 8533.41 8603. 21 972. 36 S 4721. 37E 5969651. 52 N 647285. 99E 1.487 4820 .23 10585.53 49 .280 86 .220 8594.60 8664. 40 967. 74 S 4792. 44E 5969657. 49 N 647356. 96E 0.152 4888 .71 10679.89 48 .260 85 .060 8656.79 8726. 59 962. 35 S 4863. 20E 5969664. 22 N 647427. 60E 1.422 4956 .73 10770.68 46 .780 87 .810 8718.11 8787. 91 958. 16 S 4930. 01E 5969669. 67 N 647494. 32E 2.765 5021 .15 10802.99 46 .750 88 .480 8740.24 8810. 04 957. 40 S 4953. 54E 5969670. 88 N 647517. 83E 1.514 5043 .99 10833.57 46 .690 89 .270 8761.20 8831. 00 956. 97 S 4975. 80E 5969671. 74 N 647540. 08E 1.891 5065 .65 • 17 October, 2005 - 15:18 Page 2 of 5 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Reporf for J-17C Your Ref: APl 500292096903 Job No. AKMW0003959206, Surveyed: 6 October, 2005 North Slope Alaska Measu red True Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Dept h Incl. Az im. Depth Dept h Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (°/100ft) 10859. 75 48. 820 90. 880 8778. 80 8848. 60 957. 00 S 4995 .17E 5969672.08 N 647559. 45E 9.323 5084.60 10890. 24 50. 720 91. 260 8798. 49 8868. 29 957. 43 S 5018 .45E 5969672.08 N 647582. 73E 6.304 5107.44 10919. 92 54. 320 93. 080 8816. 55 8886. 35 958. 33 S 5041 .98E 5969671.63 N 647606. 27E 13.068 5130.63 10952. 02 58. 200 94. 170 8834. 38 8904. 18 960. 02 S 5068 .61E 5969670.44 N 647632. 93E 12.412 5157.02 10983. 08 60. 510 94. 750 8850. 21 8920. 01 962. 10 S 5095 .25E 5969668.87 N 647659. 61E 7.609 5183.49 11015. 02 62. 670 95. 640 8865. 40 8935. 20 964. 65 S 5123 .22E 5969666.86 N 647687. 63E 7.193 5211.38 11045. 73 64. 530 96. 040 8879. 06 8948. 86 967. 45 S 5150 .59E 5969664.58 N 647715. 04E 6.168 5238.71 11076. 09 66. 160 95. 830 8891. 72 8961. 52 970. 30 S 5178 .03E 5969662.25" N 647742. 53E 5.406 5266.14 11107. 84 67. 560 96. 990 8904. 20 8974. 00 973. 56 S 5207 .04E 5969659.54 N 647771. 60E 5.543 5295.18 11138. 55 69. 340 97. 240 8915. 48 8985. 28 977. 10 S 5235 .38E 5969656.54 N 647800. 00E 5.845 5323.63 11169. 10 71. 760 98. 270 8925. 65 8995. 45 980. 99 S 5263 .93E 5969653.19 N 647828. 61E 8.535 5352.35 11199. 92 75. 670 99. 430 8934. 29 9004. 09 985. 54 S 5293 .15E 5969649.20 N 647857. 92E 13.191 5381.88 11230. 96 79. 470 98. 980 8940. 97 9010. 77 990. 39 S 5323 .07E 5969644.92 N 647887. 92E 12.324 5412.14 11261. 60 82. 260 96. 880 8945. 84 9015. 64 994. 56 S 5353 .02E 5969641.32 N 647917. 95E 11.344 5442.31 11293. 85 84. 630 97. 950 8949. 52 9019. 32 998. 70 S 5384. 79E 5969637.79 N 647949. 79E 8.054 5474.23 11324. 95 85. 740 99. 230 8952. 13 9021. 93 1003. 32 S 5415 .43E 5969633.74 N 647980. 52E 5.437 5505.16 11356. 64 86. 910 97. 430 8954. 16 9023. 96 1007. 91 S 5446 .72E 5969629.75 N 648011. 89E 6.765 5536.71 11388. 26 87. 410 97. 650 8955. 73 9025. 53 1012. 05 S 5478 .03E 5969626.21 N 648043. 27E 1.727 5568.19 11419. 14 87. 960 98. 180 8956. 98 9026. 78 1016. 30 S 5508 .59E 5969622.54 N 648073. 91E 2.472 5598.95 11449. 66 87. 410 97. 800 8958. 21 9028. 01 1020. 54 S 5538 .79E 5969618.87 N 648104. 18E 2.190 5629.37 11481. 06 86. 970 97. 590 8959. 75 9029. 55 1024. 74 S 5569 .87E 5969615.27 N 648135. 33E 1.552 5660.63 11510. 06 86. 170 97. 470 8961. 48 9031. 28 1028. 53 S 5598 .57E 5969612.02 N 648164. 10E 2.789 5689.48 11541. 35 86. 480 97. 360 8963. 49 9033. 29 1032. 56 S 5629 .53E 5969608.58 N 648195. 13E 1.051 5720.60 11573. 02 86. 730 99. 800 8965. 36 9035. 16 1037. 28 S 5660 .79E 5969604.46 N 648226. 48E 7.731 5752.15 11604. 30 88. 330 102. 170 8966. 71 9036. 51 1043. 23 S 5691 .47E 5969599.09 N 648257. 26E 9.136 5783.39 11634. 78 90. 620 105. 060 8966. 99 9036. 79 1050. 40 S 5721 .08E 5969592.48 N 648287. 01E 12.097 5813.85 11665. 84 91. 850 107. 770 8966. 32 9036. 12 1059. 18 S 5750 .87E 5969584.27 N 648316. 95E 9.580 5844.82 11696. 17 94. 080 110. 460 8964. 75 9034. 55 1069. 10 S 5779 .48E 5969574.90 N 648345. 75E 11.511 5874.88 11727. 47 94. 570 112. 600 8962. 39 9032. 19 1080. 55 S 5808 .51E 5969564.00 N 648374. 99E 6.995 5905.68 11758. 21 93. 770 113 .740 8960. 16 9029. 96 1092. 61 S 5836 .70E 5969552.47 N 648403. 40E 4.523 5935.78 11788. 83 91. 230 115. 340 8958. 82 9028. 62 1105. 32 S 5864 .52E 5969540.30 N 648431. 46E 9.801 5965.66 11821. 86 89. 880 117. 260 8958. 50 9028. 30 1119. 95 S 5894 .13E 5969526.23 N 648461. 34E 7.106 5997.69 11852. 80 90. 120 118. 240 8958. 50 9028. 30 1134. 35 S 5921 .51E 5969512.35 N 648488. 99E 3.261 6027.50 11916. 42 90. 930 116. 530 8957. 92 9027. 72 1163. 62 S 5978 .00E 5969484.17 N 648546. 03E 2.974 6088.89 11945. 77 90. 060 119. 150 8957. 66 9027. 46 1177. 32 S 6003 .95E 5969470.96 N 648572. 23E 9.406 6117.15 BPXA • • 17 October, 2005 - 15:1 B Page 3 of 5 DrillOuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for J-17C Your Ref: API 500292096903 Job No. AKMW0003959206, Surveyed: 6 October, 2005 North Slope Alaska Measured True Sub-Sea Vertical Local Coordi nates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 11978.96 91.170 116.660 8957.31 9027.11 1192.85 S 6033.27E 5969455.99 N 648601.85 E 12008.15 93.020 116.850 8956.24 9026.04 1205.98 S 6059.32E 5969443.35 N 648628.14 E 12053.81 92.710 117.250 8953.96 9023.76 1226.72 S 6099.93E 5969423.39 N 648669.14 E 12101.09 91.420 .117.510 8952.26 9022.06 1248.45 S 6141.89E 5969402.46 N 648711.50 E 12147.04 90.190 119.360 8951.61 9021.41 1270.33 S 6182.29E 5969381.36 N 648752.31 E 12195.32 88.640 123.550 8952.10 9021.90 1295.51 S 6223.46E 5969356.96 N 648793.95 E 12243.07 89.440 124.890 8952.90 9022.70 1322.36 S 6262.94E 5969330.86 N 648833.93 E 12287.99 89.440 124.630 8953.34 9023.14 1347.97 S 6299.84E 5969305.96 N 648871.31 E 12354.36 90.490 123.750 8953.38 9023.18 1385.27 S 6354.74E 5969269.71 N 648926.91 E 12387.00 90.490 123.750 8953.10 9022.90 1403.40 S 6381.88E 5969252.10 N 648954.39 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference . Northings and Eastings are relative to Well Reference . Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 102.200° (T rue). Based upon Minimum Curvature type calculations, at a Measured Depth of 12387.OOft., The Bottom Hole Displacement is 6534.36ft., in the Direction of 102.402° (True). Comments Measured Station Coordinates Depth TVD Northings Eastings (ft) (ft) (ft) (ft) 8892.80 7521.35 957.24 S 3554.65 E 8931.00 7551.17 967.19 S 3576.35 E 12387.00 9022.90 1403.40 S 6381.88 E Comment Tie On Point Window Point Projected Survey Dogleg Vertical Rate Section Comment (°/100ft) 8.213 6149.10 6.371 6177.33 1.107 6221.41 2.783 6267.01 4.834 6311.12 9.253 6356.68 3.268 6400.94 0.579 6442.42 2.064 6503.96 0.000 6534.32 Projected Survey BPXA ~J 17 October, 2005 - 15:18 Page 4 of 5 DrillQuesf 3.03.06.008 Halliburton Sperry-Sun Survey Report for J-17C Your Ref: API 500292096903 Job No. AKMW0003959206, Surveyed: 6 October, 2005 North Slope Alaska BPXA Survev tool Karam for J-17C From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 8892.80 7521.35 BP High Accuracy Gyro - GYD-CT-CMS (J-17) 8892.80 7521.35 12387.00 9022.90 MWD+IIFR+MS (J-17C) • 17 October, 2005 - 15:18 Page 5 of 5 DriilQuest 3.03.06.008 FREE _ 6" Mc EV OY WELLHEAD = McEVOY ACTUATOR= OTIS KB. ELEV = 77.0' BF. ELEV = 39.78' KOP = 3000' Max Angle = Datum MD = Datum TV D = 8900' SS J-17 roposed w/out Ti~ack D~. ~~~ C~~A,FT 5~~: 2118' (~ 4-1/2" X Nipple, ID = 9-5/8" DV PKR 25$4' 13-3/8" CSG, 72#, ID = 12.347" 2685' Minimum ID = 3.725 @ 10070' HES XN Nipple GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3235 3228 15 MMG DOME RK 16 10/24/05 3 6368 5608 45 MMG SO RK 20 10!24/05 2 8620 7308 37 MMG DMY RK 0 1 9963 8240 49 KBG2 DMY RK 0 8774` -Top of 7" LNRI 8900' 9 5/8" Window TBG, 12.6#, 13Cr-80, iD = 3.958" ~-~ 1 Top Cement (J-178 Abandonment) -9,600 A ~" s 10,006' -14 1/2" HES X Nipple (3.813" ID) 10,027' 7" x 4 1/2" Baker S3 Packer (3.875" ID) 10,050' 4 1/2" HES X Nipple (3.813" ID} 10,070' 4 1/2" HES XN Nipple (3.725" ID) 10,066' 4 1/2" Hanger! liner top packer 10,083' 4 1/2" WLEG, ID=3.958" 10,234' 7" 26# L-80 (6.276" ID) 4 1/2" 12.6# (3.958" ID) 0.0152 bpf 12,387' 9-5/8" CSG, 47#, L-80, ID = 8.671" ~-{ 9963' PERFORATION SUMMARY REF L WS MCNL/GR /20/02 ANGLEATTO : 90 @ 11300' Note: Refer to Pro on DB storical pert data SIZE SPF VAL Opn/ DATE 11300 - 11650 I S 7" LNR, 26#, L-80, BTRS, ID = 6.276" 7" LNR MILLOIJT WINDOW (J-176) I 10023' - 10031' 'RA TAG @ 10031' 10068' 3-1/2" LNR, 9.2#, L-80, ID = 2.992" 2-3/8" LNR, 4.7#, L-80, .0039 bpf, ID = 1.92" ~~ 11731' DATE REV BY COMMENTS DATE REV BY COMMENTS 07118/83 INITIAL COMPLETION 07/29/04 MDGTLP IBP WfrH FISH NECK 10/26/99 JLH CTD SIDETRACK (J-17A) 04!15/05 PGS Proposed Sidetrack 01/21!02 CTD SIDETRACK (J-17B) 10/21/05 PJC HAND WRITTEN CORRECTIONS 02/03/02 CH/TP CORRECTIONS 11/05/05 KSB/TLH GLV GO (10/24/05) C7,'15/03 CMO/TLP KB ELEVATION CORRECTION t ~ ~ J~+ ~ ~ ~ _",,, PRUDHOE BAY UNrf WELL: J-17C PERMff No: 82012240 API No: 50-029-20969-02 SEC 9, T11 N, R13E, 801' SNL & 1806' WEL BP Exploration (Alaska) • • 26-Oct-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well J-17C Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,892.80' MD Window /Kickoff Survey: 8,931.00' MD (if applicable) Projected Survey: 12,387.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date ~ ( PUQYa~.() v ~ Signed CJ Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) • 26-Oct-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well J-17C MWD Dear Dear Sir/Madam: Enclosed is one disk with the *.PTT and *.PDF files. Tie-on Survey: 8,892.80' MD Window /Kickoff Survey: 8,931.00' MD (if applicable) Projected Survey: 12,387.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sinn Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. AnchorageN, AK 99518 Date ~) 1@e~ ~.bU~ Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) .Z a y-, a 8~ r` ~~. ~ ~gq ;~ ~ ~~ ~ ~ -~ ~ ~~ ~I ~ a,~~, ~~ ~ ~ ~ ~ ~ ~ ~°° p~ ~ FRANK H. MURKOWSKI, GOVERNOR ~ I~, ~T 4a~[1a7~ 0~ ~ a]r~~ ;~~ 333 W. 7T" AVENUE, SUITE 100 COl`S~Rs~ii~1` C~~IISSIO~ err ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay J-17C BP Exploration (Alaska) Inc. Permit No: 205-082 Surface Location: 801' FNL, 1806' FEL, SEC. 09, T11N, R13E, UM Bottomhole Location: 2178' FNL, 4519' FWL, SEC. 10, T11N, R13E, UM Dear Mr. Isaacson: Enclosed is the approved application for permit to redrill the above development well. This 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. Ple e provide at least twenty-four (24) hours notice for a representative of the Commission t ness any required test. Contact the Commission's petroleum field inspector at (907659- 607 ager). DATED thi~~ day of May, 2005 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS A OIL AND GAS CONSERVATIO OMMISSION PERMIT TO DRILL ~ 20 AAC 25.005 ~IGq- sCi1 ft~"~~ `~,, s,... f~~. MAY ~ z> 2(~U5 ~! ~a~ ~~rt~. ~of~lr~i~s~ 1a. Type of work ^ Drill ®Redrill ^ Re-Entry ib. Current Well Class ^ Exploratory ®Development Oil fi~~Zone ^ Stratigraphic Test ^ Service ^Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 2S100302630-277 11. Well Name and Number: PBU J-17C 5~z7/d~ 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12361 TVD 9034 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surtace: 801' SNL 1806' WEL T11N SEC 09 R13E UM 7. Property Designation: ADL 028281 Pool , , . , , , Top of Productive Horizon: 1803' SNL, 3669' EWL, SEC. 10, T11N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: June 1, 2005 ~ Total Depth: 2178' SNL, 4519' EWL, SEC. 10, T11N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 16,400' 4b. Location of Well (State Base Plane Coordinates): Surface: x-642547 y-5970534 Zone- ASP4 10. KB Elevation (Height above GL):plan 69.8 feet 15. Distance to Nearest Well Within Pool -100' to J-17A 16. Deviated Wells: Kickoff Depth: 8900 feet Maximum Hole Angle: 90 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3160 Surface: 2280 ~ 18. asing rogram: Size Specifications Setting Depth To Bottom- uant~ty o ement " c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 8-1/2" 7" 26# L-80 BTC-M 1500' 8750' 7400' 10250' 8430' 196 cu ft Class'G' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 2261' 10100' 8332' 12361' 9034' 26 cu ft Class'G' 19. PRESENT W ELL CONDITION SUMMARY (To be completed for Redrill AND Re-e ntry Operations) Total Depth MD (ft): 11731 Total Depth TVD (ft): 8999 Plugs (measured): 9668 Effective Depth MD (ft): 11664 Effective Depth TVD (ft): 8998 Junk (measured): None Casin Len th Size Cement Volume MD TVD r on u r 110' 20" x 30" 8 cu ds Concrete 110' 110' 2685' 13-3/8" 3856 cu ft Arcticset III & II 2685' 2685' 9963' 9-5/8" 360 cu ft Class 'G', 132 cu ft Permafrost 9963' 8364' Pr uc i n 311' 7" 92 cu ft Class 'G' 9713' - 10024' 8172' - 8410' Liner 336' 3-1/2" 2 cu ft Class'G' 9732' - 10068' 8187' - 8443' Liner 2024' 2-3/8" 70 cu ft Class 'G' 9707' - 11731' 8167' - 8999' Perforation Depth MD (ft): 11300' - 11650' Perforation Depth TVD (ft): 8996' - 8999' 20. Attachments ®Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Phil Smith, 564-4897 Printed Name Bill Isaacson Title Senior Drilling Engineer Prepared By Name/Number: Si nature Phone 564-5521 Date `S 2~ QS Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: „ Q API Number: 50- 029-20969-03-00 Permit Approval Date: 3~3i o~ See cover letter for other requirements Conditions of Approval: Sampl equired '~ Yes ~No Mud Log Required ~ 'Yes ;~ No Hy gen ulfide Measures Yes ~~=; No Directional Survey Required 1$Yes '~ No Other: ~ pS~' v ~ laC r~-:. , Per a ~ ~ s c~~ c-~ , ~-1{~,-il~ ~~~~ ~ s ~pp,~ ~~~. APPROVED BY ~/~, A rove a THE COMMISSION Date J Form 10-401 Revised os~ ~+---~~ ~ ~ E°m ~ubmif In Duplicate • • Well Name: J-17C Drill and Complete Plan Summary T e of Well service / roducer / in'ector : Horizontal Sidetrack Producer 1- Surface Location: - 2,5~,4~ ''"` = 5,970,534 ~ Estimated 801 ' ~ 06' - Sec. 9, T11 N, R13E Umiat . Target Location: = 648,0 ~ Y = 5,969,638.3 TVDss 8960' Ivishak Zone 2A 1803' FNL 3669' FW L Sec. 10, T11 N, R13E Umiat Bottom Hole Location: X = 648,900.0 Y = 5,969,280.0 TVDss 8964' 2178' FNL 761' FEL Sec. 10, T11N, R13E Umiat ~ AFE Number: PBD4P2369 Ri Nabors 2ES Estimated Start Date: 06/01/05 O eratin da s to com lete: 18.2 MD: 12,361' TVD: 9,034' GL: 41.3' KB: 28.5' KBE: 69.8' Well Desi n conventional, slimhole, etc.: Two String Horizontal Sidetrack Ob'ective: Ivishak Zone 2A r\~_ _1• vlrectlonal -Sperrywp0 2 KOP: 8900' MD Maximum Hole Angle: -50° in the 8-1/2" intermediate section -90° in the 6-1/8" horizontal section Close Approach Wells: Due to the large ellipse of uncertainty, F-08A fails major risk criteria in the reservoir section by 50 feet, though center to center is 718'. All other wells (except the original F-08 and J-17A abandoned wellbores) pass major risk criteria. To reduce the ellipse of uncertainty to a reasonable size and eliminate the major risk, a ro surve will be erformed on J-17B rior to drillin . Surve Pro ram: Pre-Rig Gyro + MWD Standard + IIFR /Cassandra Nearest Pro ert Line: 16,400' to the nearest PBU property line Nearest Well within Pool: ±100' to P&A'd J-17A wellbore Casin /Tubin Pro ram Hole Size Csgl1'bg O.D. / WUFt Grade l Conn/ Length Top MDlTVD Btm MD/TVD 8-1/2" 7" 26# L-80 BTC-M 1500' 8,750'/7,400' 10,250'/8,430' 6-1/8" 4-1/2" 12.6# L-80 IBT-M 2261' 10,100'/8332' 12,361'/9034' Tubin 4-1/2" 12.6# 13Cr-80 VAM To --10,070' GL 10,100'/8332' J-17C Permit to Drill Page 1 • • Formation Markers Formation Tops (wp02) MD TVD TVDss Comments CM1 7846 6665 6595 ABOVE KOP THRZ 8189 6946 6876 " LCU 8431 7145 7075 " KINGAK 8449 7160 7090 " TJF 8866 7491 7421 " KOP 8900 7524 7454 TJE 9075 7650 7580 TJD 9421 7890 7820 TJC 9774 8120 8050 TJB 10,005 8270 8200 TSGR 10,273 8445 8375 SHUBLIK 10,315 8480 8410 TSAD / TZ4B 10,480 8575 8505 TCGL / TZ3 10,743 8750 8680 BCGL / TZ2C 10,858 8825 8755 25N 11,000 8912 8842 3160 psi Q 8800 PGOC 11,095 8955 8885 22N 11,087 8991 8921 MHO/HOT 11,429 9028 8958 INITIAL LANDING 21 N 11, 500 9030 8960 TZ1 B 9080 9010 Not penetrated BSAD 9182 9112 " TD Criteria: Plan for 500` of perforations. The minimum of 200'. of perfable sand includes 150' standoff from faults/fractures. Drill to end of of on to maxmize the amount of horizontal well bore available for erforation: Mud Pro ram Section Millin Mud Pro erties• LSND Whip Stock Window 9-5/8" 47# Densit Viscosit PV YP TauO MBT PH 11.2 45-55 15-22 28-35 3-5 <20 9.0-9.5 Intermediate Mud Properties: LSND ~ 8-1/2" hole section Dens' Viscosit PV YP TauO MBT PH 11. 38-45 15-22 22-30 2-4 <20 9.0-9.5 L~~', Production Mud Properties: FloPro Densit Viscosit PV YP LSVR H API FI 8.4 - 8.5 45-55 <10 25-35 >35,000 8.5 - 9.0 9-9.5 Logging Program 8-1/2" Intermediate: Sample Catchers -None Drilling: Dir/GR/Res Open Hole: None Cased Hole: None 6-1/8" Production: Sample Catchers -over entire interval, samples described Drilling: Dir/GR/Res/Neu/ABI Open Hole: None Cased Hole: None ll, z ~,S' J-17C Permit to Drill Page 2 • • Cement Program -Based on 206°F @8800' TVD Casing Size 7" 26#, L-801ntermediate Liner Basis: Lead: None Tail: Based 80'shoe track, 1000' of 7" X 8-1/2" open hole with 40% excess. Tail TOC• 25 ' D 1000' above shoe Total Cement Volu Spacer 25 bbls Mudpush 12.2 ppg Tail 35 bbls, 196 ft3, 16 acks Class G @ 15.8 ppq, .1 3/sack Casin Size 4.5" 12.6#, L-80 Production Liner Basis: Tail: Based on 80' shoe track, 2111' of 4-1/2" X 6-1/8" open hole with 40% excess, 150' 4-1/2" X 7" Liner Lap, an ' of 7" X 4" DP excess. Tail TOC: ,1 ' MD To of Liner Total Cement Volu PreFlush 15 bbls CW-100 Spacer 25 bbls Mudpush 12.2 ppg Tail 58 bbls. 326 ft3. 8 sacks Class G @ 15.8 Dp . 1.1 ft3/sack Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC Intermediate Interval Maximum antici ated BHP 3160 si @ 8800' TVDss 6.9 EMW) Maximum surface ressure 22 i .10 si/ft as radient to surface) Kick tolerance fi ~ e with an 12.5 FIT - Planned BOP test pressure ms test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin Test 3500 si surface ressure Inte rit Test - 8-1/2" hole 12.5 FIT after drillin 20' from middle of window 7" Drilling Liner The VBRs will not be changed to accommodate the 1700-ft 7"drilling liner. Instead, the current and best practice of picking up a joint of drillpipe, with crossover to the casing thread, will be employed in the event of a kick. This practice provides two rams capable of closing on the i e across the BOP stack instead of ~ust a sin le 7" ram. Production Interval Maximum antici ated BHP 3150 si @ 8800' TVDss 6.9 EMW Maximum surface ressure 22 - si .10 si/ft as radient to surface Kick tolerance l i e with a 10.0 p FIT Planned BOP test pressure R ms test to 3,500 psi/250 psi. Annular test to 2,500 si/250 si 9-5/8" Casin "Liner Test 3500 si surface ressure Inte ri Test - 6-1/8" hole 10.0 FIT after drillin 20' of new hole Planned com letion fluids 8.5 Seawater / 7.2 Diesel Disposal • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. J-17C Permit to Drill Page 3 • • Sidetrack and Complete Procedure Summary Current Condition: / IBP set in packer bore at 9966' 7/29/04. / CMIT x IA failed at 0.26 bpm Q 2500 psi 8/1/04 / Cycled LDS on Tubing spool: Two frozen, one left backed out. Tested tubing hanger to 5000 PSI. Test on 9-5/8 IC hanger cycle all LDS on casing spool, all LDS okay. Purged old packing from Y seal and re- energized YB seal and test to 3500 PSI. 4/15/05 Scope Pre-Riq Work: 1. Run Gyrodata survey from planned KOP at 890 ' urface. 2. R/U slick-line. Puii the IBP from the packer 966'-f 3. Drift the 2 3/8" liner to as deep as possible ( anon > 70° C~ 10,800'). 4. Fluid pack the well as necessary. RU coiled tubing and P&A the 2 3/8" liner from PBTD to ±10,000' MD. Liner volume = 6.5 bbls. 5. R/U E-line. RIH with chemical cutter and seve~the 5'/i" tubing in the center of a full joint of tubing at 9,100' md. 6. Displace the well to clean seawater by circulating down the tubing through the tubing cut. Continue to circulate until clean seawater returns to surface. Freeze protect to 2,100' MD with diesel. 7. Combo pressure test the tubing /casing to 3500 psi f/ 30 minutes. 8. Bleed casing and annulus. pressures to zero, 9. Cycle the tubing hanger LDS and test the 9 5/8" mandrel packoff to 5000 psi: 10. Set a BPV and test to 1000 psi from tubing annulus. Secure the well. Level the pad as necessary. Riq Operations: 1. MI / RU Nabors rig 2ES 2. Circulate out diesel freeze protection and displace the well to seawater. Set BPVlTWC. 3. Nipple down tree. Nipple up and test BOPE to 3,500psi. Pull BPVlTWC. 4. R/U. Pull 5'h" tubing from the cut at --9,100' MD and above. 5. RIH w/ 8'/z" gauge ring /junk basket to top of tubing stub. 6. RIH with HES EZSV and set bridge plug as required to avoid cutting casing collar and place top of whip stock at -8900. 7. Pressure-test the 9 5/8" casing to 3,500psi for 30 minutes. Record test. 8. Run USIT in 9 5/8" casing from CIBP to surface. POOH. R/D E-line. a. Pick-up RTTS and isolate leak if necessary C~and RIH with 9 5/8" Baker bottom-trip anchor whip stock assembly. Orient whip stock, as desired, and set on bridge plug. Shear off of whip stock. 10. Displace the well to 11.2 ppg LSND based milling fluid. Completely displace the well prior to beginning milling operations. ~ t~-tS 1~ -, ~o[ 1. Mill window in 9 5/8" casing at ± 8,900' MD, plus approximately 20' beyond middle of window. Circulate well bore clean. r~~~ 1'~~`-~~ ~ 12. Pull up into 9 5/8" casing and conduct an FIT to 12.5 ppg EMW. POOH. 13. M/U 8 Y2" Dir/GR/Res assembly. RIH, kick off and drill the 8 1/2" intermediate section to the top of the Sag River, per directional proposal. Circulate well clean, short trip to window. POOH. 14. Run and cement a 7", 26.0#, L-80 intermediate drilling liner. 15. Run and cement a 7" liner tieback from TOL at 100' below the surface casing shoe. ~ 16. Test the 9 5/8" casing X 7" liner to 3,500psi for 30 minutes. Record the test. 17. M/U 6 1/8" Dir/GR/Res/ABI assembly. RIH to the landing collar. 18. Drill out the 7" liner float equipment and cement to die shoe. 19. Displace the well to 8.4 ppg Flo-Pro drilling fluid. l J-17C Permit to Drill Page 4 • • 20. Drill out the 7" shoe plus drill ~20' new formation; pull up into the shoe and conduct an FIT to 10.0 ppg EMW. Drill ahead to horizontal landing point. POOH for bit / BHA change. PU Neu/Den. 21. RIH, drill horizontal section to planned TD, short trip as necessary. ~ 22. Circulate, short trip, spot liner running pill, POOH. 23. Run and cement a 4'/z", 12.6#, L-80 solid production liner. POOH UD all drill pipe. 24. RIH with 2 7/8" perf guns and perforate ±500'. 25. R/U and run 4 1/2", 12.6#, 13Cr-80 completion tubing. Land the tubing RILDS. ` 26. Set a TWC and test to 1000 psi 27. Nipple down the BOPE. Nipple up the tree and test to 5,OOOpsi. 28. Reverse circulate inhibited seawater to the packer depth. Set packer and individually test the tubing and annulus to 3,500psi 30 minutes. Record each test. 29. Shear the DCK valve and freeze protect the well to --2,100'. Secure the well. 30. Rig down and move off. Post-Rig Work: 1. Install well house and instrumentation 2. MI / RU slick-line. Pull the ball and rod / RHC plug from landing nipple below the production packer. Install gas lift valves. 3. POP well to test unit until cleaned up. J-17C Drilling Program Job 1: MIRU Hazards and Contingencies - J-17B is toward the western (entrance) end of the pad between. J-26 and J-27 on 35' centers. No well houses will require removal or shut-in for the rig move onto J=17B. - J La /s not designated a an H~~ sif. Recent H2S data from the pad is as follows: ._--- Well Name H2S Readin Date #1 Closest SHL J-26 30 m 12/12/2000 #2 Closest SHL J-27 5 m 03/05/2002 #1 Closest BHL F-40 10 m 02/27/2004 #2 Closest BHL F-08A 10 m 05/23/2004 - Post Permit to Drill in the dog house and camp prior to spud Reference RP • "DrillingNVork-over Close Proximity Surface and Subsurface Wells Procedure" SOP Job 2: De-complete Well Hazards and Contingencies - A July 2004 caliper log indicates good to poor tubing with a maximum penetration of 77%. Sixty-five percent of the tubing has penetrations greater than 20% of wall thickness. The majority of the damage is in the form of line corrosion below 3000'. There are no areas of significant cross sectional wall foss, therefore the maximum overpull can remain at the standard 80% of tensile strength for the 5 '/2" tubing. - NORM test all retrieved well head and completion equipment. - Verify the hanger type and connection. Be prepared with necessary equipment to remove. J-17C Permit to Drill Page 5 • • Reference RP • "De-completions" RP Job 4: Window Mill Hazards and Contingencies - Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. - The 9 518" casing was cemented with 1785 ft3 (-318 bbls) of class G at 13.2 ppg followed by 575 ft3 (100 bbls) class G at 15.8 ppg. The 20-bbl second stage was placed through the DV packer following the Artic Pack job. Expect ample cement at the window depth. Reference RP • "Whipstock Sidetracks" RP Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies - The intermediate section will kick off near the top of the Kingak F and TD at the top of Sag River. With relatively high inclination, 11.2 ppg mud weight will be required through the whole section.. Follow all shale drilling practices to minimize potential problems. - Must tie MWD - GR back to GR log of parent well J-17 (copy provided in wellsite geologist's package}. CAUTION: KB for J-17 and J-17C are different. MD values reported in this SOR are referenced to the J-17C KB. - Lost circulation events from J-17 and.2 .nearby wells are summarized below: • The parent well, J-17, crossed a E-W trending fault, southwest of the polygon at zone 2 section and did not lose any fluid. J-17C does not cross any faults and maintains a safe distance from the fault (>250ft) as mention above • The J-25A well lost 200 barrels of fluid at -8929 TVDSS in Zone 2. These losses occur at a fault tip of E-W trending fault. • The F-08 well lost 535 barrels of fluid at -8124 TVDSS, which is not fault related. - KICK TOLERANCE: In the worst-case scenario of 8.4 ppg pore pressure at the Sag River depth, a fracture gradient of 12.5 ppg at the 9-5/8" casing window, and 11.2 ppg mud in the hole, the kick. tolerance is infinite. Reference RP • "Shale Drilling, Kingak and HRZ" RP • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management" RP • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" Job 6: Install 7" Intermediate Liner Hazards and Contingencies - Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. J-17C Permit to Drill Page 6 • • - Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. - The planned 7" liner tieback may be eliminated depending on the results of the RTTS run. Reference RP • "Intermediate Casing Cementing Guidelines" RP • "Running and Cementing a Drilling Liner" RP Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies - Polygon hardlines are defined as follows: • To the southwest side, 300 feet away from NE-SW trending fault (30ft throw) • To the west side, 300 feet away from J-17A • To the north, > 600 feet away from future add pref location of F-08A • To the east >850 feet away from F-40 • To the southeast side, >600 feet away from O-06A well - KICK TOLERANCE: In the worst-case scenario of 8.3 ppg pore pressure in the Ivishak, a fracture gradient of 9.5 ppg at the 7" casing shoe, and 8.5 ppg mud in the hole, the kick tolerance is Infinite. j Reference RP • "Standard Operating Procedure:. Leak-off and Formation Integrity Tests" - • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management" RP Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies - Differential sticking is a concern. The 8.5 ppg mud will be -750psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. - Reduce losses as much as feasible prior to cement job and pump excess cement as per loss rate.. Evaluate alternative cement options based upon conditions. Hydraulic set packer may be required if losses exist prior to running liner. - Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. - Sufficient 4-1/2" liner will need to be run to extend -150' back up into the 7" intermediate liner. - Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. Reference RPs • "Production Liner/Casing and Cementing Guidelines" • Schlumberger Cement Program Job 10: DPC Perforate Production Casing J-17C Permit to Drill Page 7 • • Hazards and Contingencies - Observe Schlumberger's safety procedures while running in and out of hole with perf guns. Confirm all parties understand their responsibilities during pre-job safety meetings. Reference RPs • Follow Schlumberger perforating practices and recommendations. • "DPC Perforating" RP Job 12: Run Completion Hazards and Contingencies - Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is -- 0.1 psia at 100° F. Reference RP • "Completion Design and Running" RP • "Tubing connections" RP Job 13: ND/NU/Release Rig Hazards and Contingencies - No wells will require well house removal or shut-in for the rig move off of J-17C. See MIRU section for nearest wells. Reference RP • "Freeze Protecting an Inner Annulus" RP J-17C Permit to Drill Page 8 TREE= 6" McEVOY WELLHEAD= McEVOY ACTUATOR = OTIS KB. ELEV = 77.0' BF. ELEV = 39.78' KOP = 3000' Max Angle = 94 @ 11009' Datum MD = 10830' Datum TV D = 8900' SS 9-5/8" DV PKR ~ 2584' 13-3/8" CSG, 72#, ID = 12.347" 2685' Minimum ID =1.92" @ 9715' TOP OF 2-3/8" LINER (STL) 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" ~~ 9644' 13.70" BKR DEPLOYMENT SLV, ID = 3.00" I 9707' 2-5/8" X 2-3/8" XO, ID = 1.92" 9715' 3.70".BKR DEPLOY SLV, ID _ 3.00" (BEHIND LNR) .9732' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" 9784' 9-5/8" CSG, 47#, L-80, ID = 8.671" 9963' TOP OF 7" BAKER WHIPSTOCK ~ 10021' TOP OF OLD 2-7/8" CUT LNR 10058' PERFORATION SUMMARY REF LOG: SWS MCNL/GR ON 1/20/02 ANGLE AT TOP PERF: 90 @ 11300' Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 1.56" 4 11300 - 11650 O 01/20/02 7" LNR, 26#, L-80, BTRS, {D = 6.276" ~ 11040' ^ ^ 5-1 /2" CA MCO SSSV N, ID = 4.562" GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 13 3149 3067 12 OTIS LBD DMY RM 0 07/11/04 12 5074 4610 43 OTIS LBD DMY RM 0 07/11/04 11 6476 5603 45 OTIS LBD DMY RA 0 10 7171 6094 44 OTIS LBD DMY RA 0 9 7322 6204 43 OTIS LBD DMY RA 0 8 7806 6564 40 OTIS LBD DMY RA 0 7 7962 6689 35 OTIS LBD DMY RA 0 6 8276 6947 34 OTIS LBD DMY RA 0 5 8434 7077 34 OTIS LBD DMY RA 0 4 8751 7332 38 OTIS LBD DMY RA 0 3 8907 7453 38 OTIS LBD DMY RA 0 2 9353 7805 38 OTIS LBD DMY RA 0 1 9509 7931 38 OTIS LBD DMY RA 0 -~ 9582' ~- i 5-1/2" BKR L SLIDING SLV, ID = 4.313" 9644' BOT SBR W/ 3.813" X PROFILE 66 SET WFD IBP 07/29!04 W/ FISH NECK 0" @ 66' OD = 1 9668' , . 9-5/8" BOT 3H PKR ID = 3.958" 9713' 7" BOT LNR HGRTIEBACK SLEEVE 9716' 4-1/2" OTIS X NIP, ID = 3.813" 9752' 4-1/2°' OTIS XN NIP, ID = 3.80" 97$5' 4-1/2" WLEG 7" LNR MILLOUT WINDOW (J-17B) 10023' - 10031' 'RA TAG @ 10031' 10068' 3-1/2" LNR, 9.2#, L-80, ID = 2.992" `/ PBTD 11663' 2-7/8" LNR (J-17A) NOT SHOWN. CIBP SET @ 10100' ON 12/12/01. 2-3/8" LNR, 4.7#, L-80, .0039 bpf, ID = 1.92" 11731' DATE REV BY COMMENTS DATE REV BY COMMENTS 07/18/83 INITIAL COMPLETION 07/29/04 MDC/TLP IBP WfTH FISH NECK 10/26/99 JLH CTD SIDETRACK (J-17A) 01/21/02 CTD SIDETRACK (J-17B) 02/03/02 CH/TP CORRECTIONS 07/15/03 CMO/TLP KB ELEVATION CORRECTION 07/11/04 RWLiKA C/O GLV PRUDHOE BAY UNIT WELL: J-176 PERMIT No: 2012240 API No: 50-029-20969-02 SEC 9, T11N, R13E, 801' SNL & 1806' WEL BP Exploration (Alaska) TREE = 6" Mc EV OY WELLHEAD= McEVOY ACTUATOR = OTIS KB. ELEV = 77.0' BF. ELEV = 39.78' KOP = 3000' Max Angle = Datum MD = Datum TVD = 8900' SS • ~ -17 C Pro O Se~ SAFETY NOTES: p 2100' I--I 4-1/2" X Nipple, ID = 3.813" 9-5/8" DV PKR 13-3/8" CSG, 72#, ID = 12.347" Liner I 2800' I Minimum ID = 3.725 @ XN Nipple GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 DCK 3 DMY 2 DMY 1 DMY 8750` -Top of Liner 4-1/2" TBG, 12.6#, 13Cr-80, ID = 3.958" ~-i 10,100' ~~~ 1~OCI~ 8900' 9 5/8" Window /r 10,040' 4 1/2" X Nipple (3.813" ID) 10,050' 7" x 4 1/2" Baker S3 Packer 10,070' 4 1/2" X Nipple (3.813" ID) 10,090' 4 1/2" XN Nipple (3.725" ID) 10,100' 4 1/2" Hanger /liner top packer 10100' 4 1/2" WLEG 10,250' 7" 26# L-80 (6.276" ID} 4 1/2" 12.6# L-80 Liner PBTD 12,280' 4 1/2" 12.6# (3.958" ID) 0.0152 bpf 12,361' I9-5/8" CSG, 47#, L-80, ID = 8.671" ~~ 9963' f Top Cement (J-17B Abandonment) -10,000 PERFORATION SUMMARY REF LOG: SWS MCNL/GR ON 1/20/02 ANGLE AT TOP PERF: 90 @ 11300' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 1.56" 4 11300 - 11650 S 01/20!02 7" LNR, 26#, L-80, BTRS, ID = 6.276" 11040' 7" LNR MILLOUT WINDOW (J-176) I 10023' - 10031' *RA TAG @ 10031' 10068' 3-1/2" LNR, 9.2#, L-80, ID=2.992" ^ 2-3/8" LNR, 4.7#, L-80, .0039 bpf, ID = 1.92" I-I 11731' DATE REV BY COMMENTS DATE REV BY COMMENTS 07!18/83 INITIAL COMPLETION 07/29/04 MDC/TLP IBP WITH FISH NECK 10/26/99 JLH CTD SIDETRACK (J-17A) 04/18/05 PGS Proposed Sidetrack 01/21/02 CTD SIDETRACK (J-176) 02/03/02 CH/TP CORRECTIONS 07/15/03 CMOITLP KB ELEVATION CORRECTION 07/11/04 RWL/KA C/O GLV PRUDHOE BAY UNff WELL: J-17C PERMfT No: 2012240 API No: 50-029-20969-02 SEC 9, T11 N, R13E, 801' SNL & 1806' WEL BP Exploration (Alaska) C'OMPAKY DEfA1LS REFEREKCE IKFORMATIOK SL'RVF.Y PROGRAM Plan: J-I7C wp02 (J-17/Plan 1-I7C) IiP Amoco II~' CahvbtienMAhuA:MinimumCUnamrc Error Syznn: ISC'WS.4 Scan Melhal Tnv Cylirrhr KoM F Surbce: EllipiW *Caeing Coadivw IK'E) Rcf c: Well Crn°c: 1-1], True KoM VertinIITVDI Ref :2R.5 +41.1 69.X0 Section!\'SIRe( e:Sbl-171000K,OODE1 Messurtd Depth Ref :2X.5+11.7 69.Ap Calculatiun Mnhad: Mmimvn Curvanve Depth Fm Dryth To SurveyrPlan Tool N900.Iq 1.381.15 pWmnf:J-DCw3A12VIA MWD+IFR+h1S Ctpted B Di tal Butiiness Clicm Usm Date: 4/14/2005 Y~ $i Checked: Date' Reviewed: Date: Wamin Mnhod: RWes Baxd WELL DETAIIS ' i t I ~ i ~ i ~ ~ I ~~ Kamc +tuS +Fi-W K°Nung Eating lwteude Wngimdc Slol . }} ~ I I i ~ - i I ~ ' '~ ~ 1-I] 22A7.1A 1434.51 59'!0534.00 61'_54]00 ]0°19'7].301N I4X°NP7A.21M1W' I] ~ t ~ - I ~ ~ ~ f t I 1 I TARGET DETAIIS I ~ ~~ ~ i I Kama TVD +NIS +FJ-W Nathmg Eating Shape i ~ ~ I /1 .8 5 3.~1 I tt I ;1 J-I7C T1 9029.811 -1000.00 5177.41 596963831 64801207 Point 1-I7C PdY 9029.80 -1541.71 6175.10 5969110.00 64X75000 Polygon 750 $ f I~ I D 7$38 ~~ 2 I J-I]C T2 9011.80 -1374.58 fiJ28.52 59692N(100 64X900.00 Poinl '; ~ I ~ ~ , ~ I . ~ ~ ~. ~ I I i i I I SECTION DETAILS Sec MD Inc Azi TVD +N/-S +E/-W DLeg TFace VSec Target ' ' I 1 I I, 1 ~ ~ I - ~ 1 ! ! I -- I 8900.00 38.71 114.68 7523.31 -1117.62 3516.22 0.00 0.00 3673.32 I I ; ~ 2 8920.00 39.54 111.11 7538.82 -1122.53 3527.84 12.00 -71.00 3685.72 3 9293.62 49.45 82.12 7807.76 -1146.20 3782.66 6.00 -75.01 3939.76 r ~ 92 ~~ 43 63 M ~ '~ s0 b.7 ~"$ V 4 10886.21 49.45 82.12 8843.06 -980.19 4981.39 0.00 0.00 5075.93 I I I I I 5 11429.56 89.77 100.00 9029.80 -1000.00 5477.44 8.00 26.51 5564.89 J-I7C TI 780 ~ 6 11621.12 89.75 115.32 9030.60 -1057.95 5659.43 8.00 90.10 5755.03 '~ '~ i I 7 12361.35 89.75 115.32 9033.80 -1374.58 6328.52 0.00 0.00 6476.08 J-I7C T2 I _ CASING DETAILS ~ 7 -j- I _ _ -- -- , • -- -- - - -- -- ~ ~ - No. TVD MD Name Srze I ~ ; ; I I -- _ I I 8429.80 10250.50 7" 7.000 I -~- ~ ' i 2 9033.80 12361.00 4 I/2" 4.500 . I ~ 810 ~ I I ~ I ~ f I I I ~ - -- ~ -- I - FORMATION TOP DETAILS ~ I ;I I I I I f l ~ i I ~ $ -t_ _ - ~ ~ { I ~ I i i ~ _ _ I 1 ~ . ! No. TVDPath MDPath Formation r ~ l ~~ 1 1 i l I ~ ~ f I ~ I - i ~ I ' - ~ i I 8429.80 10250.50 TSGR ._ _ 1 ~L ""~, "" S ~ i ~ ' ~ i I ~ I I ~ 2 8689.80 10650.45 TCGL p _ _ _ 1 I yDy rJ i i ~ C t I ~ ~ ~ I I ~ ~ - _ ~ ~ 3 8789.80 10804.28 BCGL ~~ --i- T- - - -- - ~ i I ! ~ ' ~ ~. `_ I I 1 I- I i I I ~ I I I I I. . ~ 840 1 .. . ~ : 1 - - I - _ 1 .SG R I - -- - -- - - - - -- 1 1 ~ - ~ - ~ St ar! Di r 8 %100' :1 101 ; .28 b{ D 3. 06 I j _ 1 ~ _... .. ` _ _ i I I I I ~ ' ' ~ { 1 + I ~ - -__ -! - _.. - - - .... - -_ - - - f I I 1 1 I I I 870 , _- _. __- -- . 1 I I - ~ I - _ I ~, _ _ _ I _ f ~ }j G + ' f - - _ - _ : . , 1 I 1 1. B ~ h ._j . _. . l _ 1 - f ~. . 1-I7C wp02 . - _ - I t 0 0 a II ~ i 1 ~. .. .. _ - - - __. -- - _,-_ - - -_ _. ._ - - _ ~ 1 I - - - - - - - - - - ~~ _..t_, ~.~-_T._T. r -; --kfiP2° 900 ~ 1 1-17 I 1 B + J 7 I - . ... .- - - - - - -- - - -- --. .. - _. .. I 1 ~ - _ - - -- - - - 12000 i - ~ - - -~ -. ~ ; _ I - --. ._ - _ j _- . -- I Depth: 12361.34' MD, 903 .R' TVD . . i - I i 1 , I , 1 11 ip _1 ; i 4 1 ~ ~ I I { ' ~ I i ;- I I - ; r, 1--- ,_` ~ I } - 1- . i ~ , t ~ ~ r I , ~ ~ - 1 I r - 1 1 930 5700 6000 6300 3600 3900 4200 4500 4800 5100 5400 Vertical Section at 102.25° [3001t/in] • Sperry-Sun BP Planning Report • Company: ,BP Amoco Dater 4/14/2005 Time: 15:51:23 Page: " I Fields Prudhoe Bay Co-ordinste(NE) Reference: W eIL J-17, True North Site: PB J Pad Vertical (TVD) Reference: 28.5 + 41.3 69.8 Well: J-17 Section (VS)lteference: Well (O.OON,O.OOE,102.25Azi) Wellpath: > Plan J-17C Survey Calculation Method: Minimum Curvature Db; Oracle Plan: J-17C wp02 Date Composed: 4/6/2005 Version: 18 Principal: Yes Tied-to: From: Definitive Path Field: Prudhoe Bay North Slope UNITED STATES Map System: US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea level Geomagnetic Model: bggm2004 Site: PB J Pad TR-11-13 UNITED STATES :North Slope Site Position: Northing: 5968224.22 ft Latitude: 70 19 .14.845 N From: Map Easting: 641155.79 ft Longitude: 148 51 20.092 W Position Uncertainty: 0.00 ft North Reference: True Ground LeveL• 0.00 ft Grid Convergence: 1.08 deg Well: J-17 Slot Name: 17 J-17 Well Position: +N/-S 2283.38 ft Northing: 5970534.00 ft Latitude: 70 19 37.301 N +E/-W 1434.51 ft EasNng : 642547.00 ft Longitude: 148 50 _38.216 W Position Uncertainty: 0.00 ft Casing Points MD TVD: Diameter Hole Size Name"" ft ft in in 10250.50 8429.80 7.000 8.500 7" 12361.00 9033.80 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg ~9 10250.50 8429.80 TSGR 0.00 0.00 10650.45 8689.80 TCGL 0.00 0.00 10804.28 8789.80 BCGL 0.00 0.00 Targets Map Map ' <-- Ls6tude ---> ~--- Longitude Name Description TVD +N/-S +EI.W Northing Fasting Deg Min Sec Deg Min Sec Dip... Dir. ft ft; ft ft ft: J-17C T1 9029.80 -1000.00 5477.44 5969638.31 648042.03 70 19 27.446 N 148 47 58.343 W J-17C Poly 9029.80 -1541.71 6175.30 5969110.00 648750.00 70 19 22.113 N 148 47 37.988 W -Polygon 1 9029.80 -1541.71 6175.30 5969110.00 648750.00 70 19 22.113 N 148 47 37.988 W -Polygon 2 9029.80 -1255.45 6375.79 5969400.00 648945.00 70 19 24.927 N 148 47 32.129 W -Polygon 3 9029.80 -770.20 5579.81 5969870.00 648140.00 70 19 29.705 N 148 47 55.351 W -Polygon 4 9029.80 -1056.09 5359.32 5969580.00 647925.00 70 99 26.895 N 148 48 1.792 W J-17C T2 9033.80 -1374.58 6328.52 5969280.00 648900.00 70 19 23.756 N 148 47 33.512 W Plan Section Information MD ' Intl Azim TVD +NJ-S +EJ-W: DLS Build Turn TFO 'Target ft deg deg ft ft ft degl100ft degJ100ft degi100ft deg 8900.00 38.71 114.68 7523.31 -1117.62 3516.22 0.00 0.00 0.00 0.00 8920.00 39.54 111.11 7538.82 -1122.53 3527.84 12.00 4.18 -17.83 -71.00 9293.62 49.45 82.12 7807.76 -1146.20 3782.66 6.00 2.65 -7.76 -75.01 10886.21 49.45 82.12 8843.06 -980.19 4981.39 0.00 0.00 0.00 0.00 11429.56 89.77 100.00 9029.80 -1000.00 5477.44 8.00 7.42 3.29 26.51 J-17C T1 11621.12 89.75 115.32 9030.60 -1057.95 5659.43 8.00 -0.01 8.00 90.10 12361.35 89.75 115.32 9033.80 -1374.58 6328.52 0.00 0.00 0.00 0.00 J-17C T2 Sperry-Sun BP Planning Report Company: ` BP Amoco Date: 4/14/2005 Time: 15:51:23 Page: 2 :Field: Prudhoe Bay Co-ordinate(NE) Reference: Wetl: J-17, True North Site: PB J Pad Vertical (1'VD) Reference: 28.5 +:41.3 69.8 .Well: J-17 Section (VS) Reference: Well (t)OON,O.OOE,102.25Azi) Wellpath: Plan J-17C Snrvey Calculation Method: "Minimum Curvature Db: Oracle Survey MD Incl Azim TVD Sys TVD N/S E!W DLS MapN MapE' TooUCorpme t ft deg deg ft ft ft ft deg/100ft ft ft 8900.00 38.71 114.68 7523.31 7453.51 -1117.62 3516.22 0.00 5969483.47 646083.54 Start Dir 12/10 8920.00 39.54 111.11 7538.82 7469.02 -1122.53 3527.84 12.00 5969478.78 646095.26 Start Dir 6/100 9000.00 41.00 104.04 7599.89 7530.09 -1138.07 3577.09 6.00 5969464.18 646144.79 MWD+IFR+MS 9100.00 43.40 95.84 7674.03 7604.23 -1149.53 3643.15 6.00 5969453.97 646211.05 MWD+IFR+MS 9200.00 46.32 88.40 7744.95 7675.15 -1152.02 3713.53 6.00 5969452.82 646281.46 MWD+IFR+MS 9293.62 49.45 82.12 7807.76 7737.96 -1146.20 3782.66 6.00 5969459.96 646350.46 MWD+IFR+MS 9293.63 49.45 82.12 7807.77 7737.97 -1146.19 3782.67 0.00 5969459.96 646350.47 End Dir :9293 9300.00 49.45 82.12 7811.91 7742.11 -1145.53 3787.46 0.00 5969460.72 646355.25 MWD+IFR+MS 9400.00 49.45 82.12 7876.92 7807.12 -1135.11 3862.73 0.00 5969472.57 646430.30 MWD+IFR+MS 9500.00 49.45 82.12 7941.92 7872.12 -1124.68 3938.00 0.00 5969484.42 646505.35 MWD+IFR+MS 9600.00 49.45 82.12 8006.93 7937.13 -1114.26 4013.27 0.00 5969496.27 646580.40 MWD+IFR+MS 9700.00 49.45 82.12 8071.94 8002.14 -1103.83 4088.54 0.00 5969508.12 646655.45 MWD+IFR+MS 9800.00 49.45 82.12 8136.95 8067.15 -1093.41 4163.81 0.00 5969519.97 646730.51 MWD+IFR+MS 9900.00 49.45 82.12 8201.95 8132.15 -1082.99 4239.08 0.00 5969531.82 646805.56 MWD+IFR+MS 10000.00 49.45 82.12 8266.96 8197.16 -1072.56 4314.35 0.00 5969543.67 646880.61 MWD+IFR+MS 10100.00 49.45 82.12 8331.97 8262.17 -1062.14 4389.61 0.00 5969555.53 646955.66 MWD+IFR+MS 10200.00 49.45 82.12 8396.97 8327.17 -1051.71 4464.88 0.00 5969567.38 647030.71 MWD+IFR+MS 10250.50 49.45 82.12 8429.80 8360.00 -1046.45 4502.89 0.00 5969573.36 647068.61 7" 10300.00 49.45 82.12 8461.98 8392.18 -1041.29 4540.15 0.00 5969579.23 647105.76 MWD+IFR+MS 10400.00 49.45 82.12 8526.99 8457.19 -1030.87 4615.42 0.00 5969591.08 647180.82 MWD+IFR+MS 10500.00 49.45 82.12 8591.99 8522.19 -1020.44 4690.69 0.00 5969602.93 647255.87 MWD+IFR+MS 10600.00 49.45 82.12 8657.00 8587.20 -1010.02 4765.96 0.00 5969614.78 647330.92 MWD+IFR+MS 10650.45 49.45 82.12 8689.80 8620.00 -1004.76 4803.94 0.00 5969620.76 647368.79 TCGL 10700.00 49.45 82.12 8722.01 8652.21 -999.60 4841.23 0.00 5969626.63 647405.97 MWD+IFR+MS 10800.00 49.45 82.12 8787.02 8717.22 -989.17 4916.50 0.00 5969638.48 647481.02 MWD+IFR+MS 10804.28 49.45 82.12 8789.80 8720.00 -988.72 4919.72 0.00 5969638.99 647484.24 BCGL 10886.21 49.45 82.12 8843.06 8773.26 -980.19 4981.39 0.00 5969648.70 647545.72 MWD+IFR+MS 10886.26 49.45 82.12 8843.09 8773.29 -980.18 4981.42 0.00 5969648.71 647545.76 Start Dir 8/100 10900.00 50.44 82.75 8651.93 8782.13 -978.80 4991.85 8.03 5969650.29 647556.16 MWD+IFR+MS 11000.00 57.70 86.91 8910.59 8840.79 -971.64 5072.43 8.00 5969658.97 647636.58 MWD+IFR+MS 11100.00 65.08 90.44 8958.45 8888.65 -969.71 5160.12 8.00 5969662.57 647724.21 MWD+IFR+MS 11200.00 72.53 93.57 8994.58 8924.78 -973.03 5253.21 8.00 5969661.02 647817.34 MWD+IFR+MS 11300.00 80.03 96.45 9018.29 8948.49 -981.54 5349.90 8.00 5969654.35 647914.17 MWD+IFR+MS 11400.00 87.55 99.20 9029.11 8959.31 -995.07 5448.31 8.00 5969642.69 648012.81 MWD+IFR+MS 11429.56 89.77 100.00 9029.80 8960.00 -1000.00 5477.44 8.00 5969638.31 648042.03 J-17C T1 11500.00 89.76 105.64 9030.09 8960.29 -1015.62 5546.10 8.00 5969624.00 648110.97 MWD+IFR+MS 11600.00 89.75 113.64 9030.51 8960.71 -1049.20 5640.21 8.00 5969592.22 648205.69 MWD+IFR+MS 11621.10 89.75 115.32 9030.60 8960.80 -1057.94 5659.41 8.00 5969583.85 648225.05 End Dir :1162 11621.12 89.75 115.32 9030.60 8960.80 -1057.95 5659.43 8.00 5969583.84 648225.07 MWD+IFR+MS 11700.00 89.75 115.32 9030.94 8961.14 -1091.69 5730.73 0.00 5969551.46 648296.99 MWD+IFR+MS 11800.00 89.75 115.32 9031.38 8961.58 -1134.46 5821.12 0.00 5969510.41 648388.17 MWD+IFR+MS 11900.00 89.75 115.32 9031.81 8962.01 -1177.24 5911.51 0.00 5969469.37 648479.35 MWD+IFR+MS 12000.00 89.75 115.32 9032.24 8962.44 -1220.01 6001.89 0.00 5969428.32 648570.53 MWD+IFR+MS 12100.00 89.75 115.32 9032.67 8962.87 -1262.79 6092.28 0.00 5969387.27 648661.70 MWD+IFR+MS 12200.00 89.75 115.32 9033.10 8963.30 -1305.56 6182.67 0.00 5969346.23 648752.88 MWD+IFR+MS 12300.00 89.75 115.32 9033.54 8963.74 -1348.34 6273.06 0.00 5969305.18 648844.06 MWD+IFR+MS 12361.00 89.75 115.32 9033.80 8964.00 -1374.43 6328.20 0.00 5969280.14 648899.68 41/2" 12361.35 89.75 115.32 9033.80 8964.00 -1374.58 6328.52 0.00 5969280.00 648900.00 J-17C T2 - TERRIE L HUBBL€ ss-sii252 202 $P' EXPLORATION AK INC''Mastercard Check" PO BOX 196612 MB 7-5 t~ ANCHORAGE, AK 99519-6612 DATE ~s'2`t'(.~,,~. PAY TO THE C~ `~ ' ~[ ORDER OF First N tionaF Bank Alaska Anchorage, AK 99501- . ~J 'MEMO ~~ ~ / ~ ~ ~: 25 200060:99 L4~~~6 2 2?~~~ i 556~~' 0'.20`:2. r1 ~J • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~,(4!'i/ (T'' ~ ~ C CHECK WHAT ADD-ONS "CLUE" APPLIES (OPTIONS) MULTI The permit is for a new wellbore segment of LATERAL existing well , Permit No, API No. (If API number Production should continue to be reported as last two (2) digits a function of the original API number stated are between 60-69) above. PILOT HOLE In accordance with 20 AAC 25.005(f), all (PIT) 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). SPACING The permit is approved subject to full EXCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce/infect 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. DRY DITCH All dry ditch sample sets submitted to the SAMPLE 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. Rev: 04/01/05 C\jody\transmittal_checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT J-17C Program DEV Well bore seg ^ PTD#:205D820 Company BP EXPLORATION (ALASKA) INC Initial ClasslType DEV 11-OIL GeoArea 890 Unit 11650 ONOff Shore On Annular Disposal ^ Administration 1 Permit feeattached,___.__-_-_-__________________ ______--__-Yes__,_ _.___-_-___-__.--_----__- - - - - - 2 Lease numkerappropriate. - - - - - - - - - Yes . - - - - - - - - - 3 Uniquewell_nameandnumbe[_________________________ _____________Yes-__-_ ___-_-_ 4 WelUocatedin_a-defimedpool-- --------------------- -----_----Yes------ --------------_-- -- - - - - - - 5 WeNlocatedP[operdistan4efromdrillingunitboundary__-------- -------------Yes---- -------------------- -------------,------------.----------------- - 6 Well located properdistance_f[o_motherwells-.__.-__.._-____ _____________Yes-____ -_,._ - - - - 7 Sufficient acreageavailakleindnllingunit__.-__-__-.__-_.. _;-_--_._-_Yes_-_-_- _-____-_.-__-_- -_--_-_-_____,-,_-_ 8 If deviated,js_wellboreplat_included______________________ ____--____ Yes_-___. __-_-__-_.-,__--_- - - - 9 Ope[atoronlyaffectedparty___-_-____._--._ Yes_.__. - _._._._-_. - - - - 10 Ope[atofhas-appropriate.kondinforre--------- ----- -- - -------- --Yes - - - - - ---------- - -- -- -- -- ---------- -- ---------- --- -- 11 Permit_cankeissuedwithoutconservationorder___-_-_-_-___ ____---_----Yes______ ___________ - - - - - Appr Date 12 Permit_can ke issued wjthout administrative_approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ .Yes _ _ , - _ _ _ - _ _ - - _ _ - - - _ - - - _ - - - - RPC 5/25/2005 13 Can permit be approved before 15-day wait Yes 14 Well)ocated within area and strata authorized ky_ Injection Order # (put10# [n_comments)_(For NA- - . - - - - - _ . , - - - - - - - - - - - - - - - --------------------- 15 All wells within 114_mile--area of review jdentified (For service well only)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ - . _ _ _ - 16 Pre-produced injector; duration of pre production less than_ 3 months_(For service well only) _ . NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - 17 ACMP_Finding of Consisteney_has keen issued_forthis project- , _ _ _ _ - - . - - NA_ _ _ Engineering 18 Canductorstring.provided__-.__,-__-_____-,-_,-_,_ -------------NA_____- _-__,--,_--_---_---. ------------------------------------------------- 19 Su_rfacecasing-protects all known_USDWs_____._--_._ -------------NA____ -__--__-_-_-____--_______--_--____---_----- --- 20 CMT-voladequate-tocirculate_onconductor_&surf_csg___________ _____________NA_-.__-_ --____-___-_._,-__,-_ ------------------------------------------- 21 CMT_voladequate_totie-in longstringtosurfcsg_,__-__-__,.. _,__-_-_..--NA____- _,-_--__-_---_ - - 22 GMT_willcaver_aliknown_productivehorizons____-__---_. _____---_---Yes.____ -___-_.,_- --__. --------------------------------------------------- 23 Casing designsadequaleforG,T,B&-permafrost------------ ------- - ---Yes- --- ------------------------------------------------ - -- 24 Adequate tankage.or reserve pit _ - - - - - Yes - Nabo[s_2ES: - - - - - - - - - - - - - - 25 Ifa_re-drill,has_a10.403forakand4nment keen approved_________ _____________ Yes_,._- _512712005._.-__..-_-,-__,__ - - - - - 26 Adequate wellkore separationproposed- _ _ _ _ _ _ _ -Yes _ _ _ _ _ _ _ _ _ _ _ _ _ 27 Ifdjve[terrequired,doesitmeetregulations__________________ _____-_-_-_- NA___.-_ -$idetrack.____-__.-._--_- -------------------------------------------- Appr Date 28 Dlillingfluid-prQgramschematic&equiplistadequate____________ ___________-Yes-__-_ _MaxMW_11,2_ppg._-__,..__-___-__-___-_-_---_-,_---_- -,--_- WGA 5/3112005 29 BOPEs,-do they meet_ regulation _ . _ - _ - .. - - Yes - - - - - - - - - - - 30 60_PE_pressratingappropriate;testto-(putpsigincomments)_______ _____________ Yes_.-__ -Testto 3500_psi.-MSP22.8Qpsi._.-__-_-___-,- -_---_----_-_---_-__-_-_ 31 Choke.manifoldcomplieswlAPI_RP-53(May84)______________ _____--_._Yes____- ______--_ 32 Work will occur without operation shutdown_________________ ____---_--Yes--__-- -__-_--___-___- ---------------------------------------------------- 33 Is presence°f H2S gas prokakle - - - - - - NO - Not ao H2S pad. - - - - - - 34 Mechanical condition of wells within AOR verified (.Forservice well only) . , _ - _ . - _ - - NA- - ----- --------------------------------------------------------------------- Geology 35 Permit can be issued w!o hydrogen-sulfide measu(es _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No- _ - - - - _ . _ - .. _ 36 Data_presentedonpotentialoverpressurezones_.__._-_-__-_- ___-_,--_-_ NA._..__ -___--__________ ___ ____ Appr Date 37 Seismicanalysisofshaliowgas,zones___._-___-__---- -------------NA_-_-_. _ -_--_-_-________ - - RPC 512512005 38 Beaked condjtioo survey-('rf_ off-shore) - _ _ _ - - _ - - - _ - - - - - _ _ _ - - - - - NA_ - _ - -------------------------------------------- 39 -Contact namerphone for weekly progress reports [exploratory onlyJ_ - - _ _ _ . - _ - - NA. _ - Geologic Engineering Commissioner: ~T~ ~ Date: Commissioner: Date o mis ~ S ~ 3~ I ~ ~ ner Date i~/ ~ s ' 31-05 ~ ~ • • Pages in th ~~ ~D S- e appendix have not ~~~ been microfilmed. • Well History File APPENDIX • Information of detailed nature that is not pariiculariy germane to the Well Permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically organize this category of information. ~~~ MAR ~. $ 2D0$ • • j-17c.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Fri Feb 22 17:24:49 2008 Reel Header Service name .............LISTPE Date . ...................08/02/22 Origin ...................STS Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing Library. scientific Technical services Tape Header Service name .............LISTPE Date . ...................08/02/22 Origin ...................STS Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. Scientific Technical Services Physical EOF TAPEeHEADER rd ~~~~ ~iA~ ~'- ~ ~~~~ Prudhoe Bay MWD/MAD LOGS WELL NAME: J-17C API NUMBER: 50029209690300 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 22-FEB-08 JOB DATA MWD RUN 1 MWD RUN 2 MWD RUN 3 JOB NUMBER: w-0003959209 w-0003959209 W-0003959209 LOGGING ENGINEER: N. WHITE N. WHITE D. RICHARDSO OPERATOR WITNESS: B. DECKER D. MASKELL D. MASKELL MWD RUN 4 MWD RUN 5 MWD RUN 6 JOB NUMBER: W-0003959209 W-0003959209 W-0003959209 LOGGING ENGINEER: D. RICHARDSO D. RICHARDSO D. RICHARDSO OPERATOR WITNESS: D. MASKELL J. RALL J. RALL SURFACE LOCATION SECTION: 9 TOWNSHIP: 11N RANGE: 13E FNL: 801 FSL: FEL: 1806 FWL: Page 1 dos -ova ~ ~59~ ~ • • j-17c.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: 69.80 DERRICK FLOOR: GROUND LEVEL: 41.30 WELL CASING RECORD OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 8.500 9.625 8930.0 2ND STRING 6.125 7.000 10234.0 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. J-17C WAS DRILLED FROM A WHIPSTOCK IN THE J-17 WELLBORE. THE TOP OF THE WHIPSTOCK WAS POSITIONED AT 8930'MD/7550'TVD. 4. MWD RUN 1 WAS DIRECTIONAL ONLY. THE PURPOSE OF THIS RUN WAS TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. SROP DATA ARE PRESENTED. 5. MWD RUNS 2-6 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (DGR) UTILIZING GEIGER-MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE- 4 (EWR4). MWD RUNS 4-6 ALSO INCLUDED AZIMUTHAL LITHO-DENSITY (ALD) AND COMPENSATED THERMAL NEUTRON (CTN). UPHOLE MAD CTN AND ALD DATA ACQUIRED WHILE POOH AFTER RUN 5 WERE MERGED WITH RUN 4 MWD DATA. NO SEPARATE MAD PRESENTATION IS INCLUDED. 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A GEARHART GAMMA RAY RUN IN J-17 ON 14 JULY 1983. THESE PDC DATA WERE PROVIDED BY D.DORTCH (SAIC/BP) ON 27 NOVEMBER 2007, QUOTING AUTHORIZATION FROM ROGER SELS (BP). LOG HEADER DATA RETAIN ORIGINAL DRILLERS' DEPTH REFERENCES. 7. MWD RUNS 1-6 REPRESENT WELL J-17C WITH API#: 50-029-20969-03. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12387'MD/9022'TVD. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM Page 2 • • j-17c.tapx SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED HOLE SIZE). CTFA = SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA = SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 = SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN). SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN). SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN). SLIDE = NON-ROTATED INTERVALS. DENSLIDE = NON-ROTATED INTERVALS REFLECTING SENSOR-TO-BIT DISTANCE. PARAMETERS UTILIZED FOR POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.4 PPG MUD SALINITY: 1000-2000 PPM CHLORIDES FORMATION WATER SALINITY: 10000 PPM CHLORIDES FLUID DENSITY: 1.0 G/CC MATRIX DENSITY: 2.65 G/CC LITHOLOGY: SANDSTONE File Header Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/22 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.000 comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR RPD RPS R PX FET RPM ROP FCNT NCNT NPHI RHOB DRHO PEF and clipped curves; all bit runs merged. .5000 START DEPTH 8792.5 8922.0 8922.0 8922.0 8922.0 8922.0 8934.0 10218.0 10218.0 10218.0 10226.5 10226.5 10226.5 BASELINE CURVE FOR SHIFTS: STOP DEPTH 12338.5 12345.5 12345.5 12345.5 12345.5 12345.5 12390.5 12310.0 12310.0 12310.0 12325.5 12325.5 12325.5 Page 3 j-17c.tapx CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH GR 8797.0 8794.5 8802.0 8797.0 8808.0 8804.5 8810.0 8809.0 8816.5 8815.0 8832.5 8829.5 8840.0 8836.5 8852.0 8849.0 8870.0 8868.0 8878.5 8875.5 8891.0 8888.0 8896.5 8893.5 8909.5 8906.5 8923.5 8919.0 8925.5 8921.0 8930.0 8925.0 $8932.0 8926.5 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MWD 1 8930.5 8959.0 MWD 2 8959.0 10234.0 MWD 3 10234.0 10896.0 MWD 4 10896.0 11374.0 MWD 5 11374.0 11950.0 MWD 6 11950.0 12387.0 REMARKS: MERGED MAIN PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 FCNT MWD CNTS 4 1 68 4 2 NCNT MWD CNTS 4 1 68 8 3 RHOB MWD G/CM 4 1 68 12 4 DRHO MWD G/CM 4 1 68 16 5 RPD MWD OHMM 4 1 68 20 6 RPM MWD OHMM 4 1 68 24 7 RPS MWD OHMM 4 1 68 28 8 RPX MWD OHMM 4 1 68 32 9 FET MWD HOUR 4 1 68 36 10 GR MWD API 4 1 68 40 11 PEF MWD BARN 4 1 6$ 44 12 ROP MWD FT/H 4 1 68 48 13 NPHI MWD PU-S 4 1 68 52 14 Page 4 • j-17c.tapx First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8792.5 12390.5 10591.5 7197 8792.5 12390.5 FCNT MWD CNTS 138.12 4163.91 694.446 4185 10218 12310 NCNT MWD CNTS 15936.3 53442.5 28746.1 4185 10218 12310 RHOB MWD G/CM 0.904 3.22 2.33982 4199 10226.5 12325.5 DRHO MWD G/CM -3.114 0.903 0.0982986 4199 10226.5 12325.5 RPD MWD OHMM 0.41 2000 46.5308 6848 8922 12345.5 RPM MWD OHMM 0.17 2000 36.5455 6848 8922 12345.5 RPS MWD OHMM 0.52 1331.43 16.5693 6848 8922 12345.5 RPX MWD OHMM 0.52 1330.75 15.3049 6848 8922 12345.5 FET MWD HOUR 0.41 49.11 2.94901 6848 8922 12345.5 GR MWD API 5.23 232.93 56.9618 7093 8792.5 12338.5 PEF MWD BARN 1.07 15.28 2.27659 4199 10226.5 12325.5 ROP MWD FT/H 0.24 726.97 60.6182 6914 8934 12390.5 NPHI MwD PU-S 3.96 52.27 22.8114 4185 10218 12310 First Reading For Entire File..........8792.5 Last Reading For Entire File...........12390.5 File Trailer Service name... .......STSLIB.001 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/22 Maximum Physical Record..65535 File TyL~e ................LO Next File Name...........STSLIB.002 Physical EOF File Header Service name... .......STSLI6.002 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/22 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY header data for each bit run in separate files. 1 .5000 VENDOR TOOL CODE START DEPTH ROP 8930.5 S LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: STOP DEPTH 8959.0 27-SEP-05 Insite Page 5 • DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): j-17c.tapx 66.37 Memory 8959.0 8930.0 8959.0 38.7 38.7 TOOL NUMBER 8.500 8930.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Polymer 11.20 49.0 .0 0 .0 .000 .0 .000 162.8 .000 .0 .000 .0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 ROP MWDO10 FT/H 4 1 68 4 2 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 8930.5 8959 8944.75 58 8930.5 8959 Page 6 • j-17c.tapx ROP MWDO10 FT/H 0.66 11.33 5.61655 58 8930.5 First Reading For Entire File..........8930.5 Last Reading For Entire File...........8959 File Trailer Service name... .......STSLI6.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/22 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.003 Physical EOF File Header service name... .......sTSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/22 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 8792.0 10202.0 FET 8919.5 10194.5 RPx 8919.5 10194.5 RPS 8919.5 10194.5 RPD 8919.5 10194.5 RPM 8919.5 10194.5 ROP $959.5 10234.0 LOG HEADER DATA DATE LOGGED: 30-SEP-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10234.0 TOP LOG INTERVAL (FT): 8959.0 BOTTOM LOG INTERVAL (FT): 10234.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 38.7 MAXIMUM ANGLE: 49.4 TOOL STRING (TOP TO BOTTOM) Page 7 8959 • • j-17c.tapx VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 132477 EWR4 ELECTROMAG. RESIS. 4 10505932 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 8.500 DRILLER'S CASING DEPTH (FT): 8930.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 11.20 MUD VISCOSITY (S): 47.0 MUD PH: 9,6 MUD CHLORIDES (PPM): 900 FLUID LOSS (C3): 4.4 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .750 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .380 147.2 MUD FILTRATE AT MT: .920 70.0 MUD CAKE AT MT: 3.250 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing ........ ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units Size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MWD020 OHMM 4 1 68 16 5 FET MWD020 HOUR 4 1 68 20 6 GR MWD020 API 4 1 68 24 7 ROP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8792 10234 9513 2885 8792 10234 RPD MWD020 OHMM 1 2000 16.557 2551 8919.5 10194.5 RPM MWD020 OHMM 0.97 2000 12.3071 2551 8919.5 10194.5 RPS MWD020 OHMM 0.98 1331.43 2.94246 2551 8919.5 10194.5 Page 8 • • j-17c.tapx RPX MWD020 OHMM 1 1330.75 2.92069 2551 8919.5 10194.5 FET MWD020 HOUR 0.41 31.46 1.87978 2551 $919.5 10194.5 GR MWD020 API 39.7 160.84 110.9 2821 8792 10202 ROP MWD020 FT/H 1.85 118.05 65.6417 2550 8959.5 10234 First Reading For Entire File..........8792 Last Reading For Entire File...........10234 File Trailer Service name... .......STSLIB.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/22 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/22 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: FILE SUMMARY .5000 VENDOR TOOL CODE START DEPTH STOP DEPTH FET 10195.0 10851.0 RPX 10195.0 10851.0 RPS 10195.0 10851.0 RPD 10195.0 10851.0 RPM 10195.0 10851.0 GR 10202.5 10844.0 OP 10234.5 10896.0 $ LOG HEADER DATA DATE LOGGED: 02-OCT-05 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 10896.0 TOP LOG INTERVAL (FT): 10234.0 BOTTOM LOG INTERVAL (FT): 10896.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 46.7 Page 9 header data for each bit run in separate files. 3 • j-17c.tapx MAXIMUM ANGLE: 49,8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 EWR4 Electromag Resis. 4 159436 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLER'S CASING DEPTH (FT): 10234.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.40 MUD VISCOSITY (S): 53.0 MUD PH: g,g MUD CHLORIDES (PPM): 1000 FLUID LOSS (C3): $,6 RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): 1.250 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .750 122.0 MUD FILTRATE AT MT: 1.500 70.0 MUD CAKE AT MT: .880 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Loging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 Name Service Order units size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MWD030 OHMM 4 1 68 16 5 FET MWD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 ROP MWD030 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10195 10896 10545.5 1403 10195 10896 Page 10 • • j-17c.tapx RPD MWD030 OHMM 0.41 2000 178.08 1313 10195 10851 RPM MwD030 OHMM 0.17 2000 139.716 1313 10195 10851 RPS MWD030 OHMM 0.52 1271.49 57.5307 1313 10195 10851 RPX MWD030 OHMM 0.52 1183.57 51.8301 1313 10195 10851 FET MWD030 HOUR 0.48 49.11 4.12038 1313 10195 10851 GR MWD030 API 5.43 232.93 25.0769 1284 10202.5 10844 ROP MWD030 FT/H 0.77 726.97 63.2205 1324 10234.5 10896 First Reading For Entire File..........10195 Last Reading For Entire File...........10896 File Trailer Service name... .......STSLIB.004 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/22 Maximum Physical Record..65535 File Type ................LO Next File Name...........STSLIB.005 Physical EOF File Header Service name... .......STSLI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/22 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.004 Comment Record FILE HEADER FILE NUMBER: 5 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 10214.5 11294.0 FCNT 10214.5 11294.0 NPHI 10214.5 11294.0 PEF 10223.0 11309.5 RHOB 10223.0 11309.5 DRHO 10223.0 11309.5 GR 10844.5 11322.0 RPx 10851.5 11329.0 RPD 10851.5 11329.0 RPS 10851.5 11329.0 RPM 10851.5 11329.0 FET 10851.5 11329.0 ROP 10896.5 11374.0 LOG HEADER DATA DATE LOGGED: SOFTWARE Page 11 03-oCT-05 C SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: TOOL STRING (TOP TO VENDOR TOOL CODE DGR CTN EWR4 ALD • j-17c.tapx Insite 66.37 Memory 11374.0 10896.0 11374.0 BOTTOM) TOOL TYPE DUAL GAMMA RAY COMP THERMAL NEUTRON Electromag Resis. 4 Azimuthal Litho-Dens BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Di rection .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 50.7 85.7 TOOL NUMBER 203301 1844674407370955 159436 1050894 6.125 10234.0 Polymer 8.50 46.0 9.5 2400 .0 1.250 70.0 .710 129.0 1.500 70.0 .880 70.0 Name Service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 FCNT MWD040 CNTS 4 1 68 4 2 NCNT MWD040 CNTS 4 1 68 8 3 Page 12 • j-17c.tapx RHOS MWD040 G/CM 4 1 68 12 4 DRHO MWD040 G/CM 4 1 68 16 5 RPD MWD040 OHMM 4 1 68 20 6 RPM MWD040 OHMM 4 1 68 24 7 RPS MWD040 OHMM 4 1 68 28 8 RPX MwD040 OHMM 4 1 68 32 9 FET MWD040 HOUR 4 1 68 36 10 GR MWD040 API 4 1 68 40 11 PEF MWD040 BARN 4 1 68 44 12 ROP MWD040 FT/H 4 1 68 48 13 NPHI MWD040 PU-S 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 10214.5 11374 10794.3 2320 10214.5 11374 FCNT MWD040 CNTS 138.12 4163.91 804.786 2160 10214.5 11294 NCNT MWD040 CNTS 15936.3 53442.5 29734.4 2160 10214.5 11294 RHOB MWD040 G/CM 0.904 3.22 2.35464 2174 10223 11309.5 DRHO MWD040 G/CM -3.114 0.903 0.0951417 2174 10223 11309.5 RPD MwD040 OHMM 4.89 70.62 23.2129 956 10851.5 11329 RPM MWD040 OHMM 4.27 71.54 19.8351 956 10851.5 11329 RPS MWD040 OHMM 4.17 67.68 16.2347 956 10851.5 11329 RPX MWD040 OHMM 4.12 60.46 14.045 956 10851.5 11329 FET MwD040 HOUR 0.94 18.3 3.92106 956 10851.5 11329 GR MWD040 API 5.23 42.99 11.7138 956 10844.5 11322 PEF MWD040 BARN 1.07 15.28 2.46533 2174 10223 11309.5 ROP MWD040 FT/H 0.24 133.71 41.3621 956 10896.5 11374 NPHI MwD040 PU-S 3.96 52.27 20.8789 2160 10214.5 11294 First Reading For Entire File..........10214 Last Reading For Entire File...........11374 File Trailer Service name... .......sT5LI6.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/22 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......sTSLI6.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/22 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSL26.005 Comment Record FILE HEADER FILE NUMBER: 6 RAW MWD curves and log header data for each bit run in separate files. Page 13 • j-17c.tapx BIT RUN NUMBER: 5 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH FCNT 11294.5 11869.5 NCNT 11294.5 11869.5 NPHI 11294.5 11869.5 PEF 11310.0 11884.5 RHOB 11310.0 11884.5 DRHO 11310.0 11884.5 GR 11322.5 11897.5 RPD 11329.5 11904.5 RPM 11329.5 11904.5 FET 11329.5 11904.5 RPX 11329.5 11904.5 RPS 11329.5 11904.5 ROP 11374.5 11950.0 LOG HEADER DATA DATE LOGGED: 05-oCT-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 11950.0 TOP LOG INTERVAL (FT): 11374.0 BOTTOM LOG INTERVAL (FT): 11950.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.4 MAXIMUM ANGLE: 94.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 CTN COMP THERMAL NEUTRON 1844674407370955 EWR4 Electromag Resis. 4 159436 ALD Azimuthal Litho-Dens 1050894 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 6.125 DRILLERS CASING DEPTH (FT): 10234.0 BOREHOLE CONDITIONS MUD TYPE: Polymer MUD DENSITY (LB/G): 8.50 MUD VISCOSITY (5): 46.0 MUD PH: 9.7 MUD CHLORIDES (PPM): 2000 FLUID LOSS (C3): .O RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): 1.600 70.0 MUD AT MAX CIRCULATING TERMPERATURE: .650 183.2 MUD FILTRATE AT MT: 1.700 70.0 MUD CAKE AT MT: 2.300 70.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): Page 14 • TOOL STANDOFF (IN): EWR FREQUENCY (HZ): j-17c.tapx REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................Down optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 • Name service order units size Nsam Rep Code offset channel DEPT FT 4 1 68 0 1 FCNT MWD050 CNTS 4 1 68 4 2 NCNT MWD050 CNTS 4 1 68 8 3 RHOB MWD050 G/CM 4 1 68 12 4 DRHO MWD050 G/CM 4 1 68 16 5 RPD MWD050 OHMM 4 1 68 20 6 RPM MWD050 OHMM 4 1 68 24 7 RPS MWD050 OHMM 4 1 68 28 8 RPx MWD050 OHMM 4 1 68 32 9 FET MWD050 HOUR 4 1 68 36 10 GR MWD050 API 4 1 68 40 11 PEF MWD050 BARN 4 1 68 44 12 ROP MWD050 FT/H 4 1 68 48 13 NPHI MwD050 PU-S 4 1 68 52 14 First Last Name Service unit Min Max Mean Nsam Reading Reading DEPT FT 11294.5 11950 11622.3 1312 11294.5 11950 FCNT MWD050 CNTS 388.5 745.22 535.66 1151 11294.5 11869.5 NCNT MWD050 CNTS 22120 32077.6 26986 1151 11294.5 11869.5 RHOB MWD050 G/cM 2.024 2.465 2.30473 1150 11310 11884.5 DRHO MWD050 G/CM 0 0.59 0.12756 1150 11310 11884.5 RPD MWD050 OHMM 4.01 13.01 7.43089 1151 11329.5 11904.5 RPM MWD050 OHMM 3.62 12.71 6.96582 1151 11329.5 11904.5 RPS MWD050 OHMM 3.44 12.64 6.69527 1151 11329.5 11904.5 RPx MWD050 OHMM 3.47 14.23 6.83968 1151 11329.5 11904.5 FET MWD050 HOUR 0.73 18.97 2.62003 1151 11329.5 11904.5 GR MWD050 API 11.07 34.56 19.1201 1151 11322.5 11897.5 PEF MWD050 BARN 1.63 3.05 2.09212 1150 11310 11884.5 ROP MWD050 FT/H 0.78 182.82 58.9504 1152 11374.5 11950 NPHI MWD050 PU-S 21.79 31.5 25.9092 1151 11294.5 11869.5 First Reading For Entire File..........11294 Last Reading For Entire File...........11950 File Trailer Service name... .......STSLIB.006 Service Sub Level Name... version Number...........1.0.0 Page 15 • • j-17c.tapx Date of Generation.......08/02/22 Maximum Physical Record..65535 File Type ................Lo Next File Name...........STSLIB.007 Physical EOF File Header Service name.... .......STSLIB.007 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/22 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.006 Comment Record FILE HEADER FILE NUMBER: 7 RAW MWD Curves and log he ader data for each bit run in separate files. BIT RUN NUMBER: 6 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH NCNT 11870.0 12306.5 NPHI 11870.0 12306.5 FONT 11870.0 12306.5 PEF 11885.0 12322.0 DRHO 11885.0 12322.0 RHOB 11885.0 12322.0 GR 11898.0 12335.0 RPS 11905.0 12342.0 FET 11905.0 12342.0 RPM 11905.0 12342.0 RPD 11905.0 12342.0 RPX 11905.0 12342.0 ROP 11950.5 12387.0 LOG HEADER DATA DATE LOGGED: 06-OCT-05 SOFTWARE SURFACE SOFTWA RE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 66.37 DATA TYPE (MEMORY OR REAL-TIME) : Memory TD DRILLER (FT): 12387.0 TOP LOG INTERVAL (FT): 11950.0 BOTTOM LOG INTERVAL (FT): 12387.0 BIT ROTATING SPEE D (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 88.6 MAXIMUM ANGLE: 93.0 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER DGR DUAL GAMMA RAY 203301 CTN COMP THERMAL NEUTRON 1844674407370955 EwR4 Electromag Resis. 4 159436 ALD Azimuthal Litho-Dens 1050894 Page 16 r~ u j-17c.tapx BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 6.125 10234.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Polymer 8.50 47.0 9.6 1900 .0 2.100 70.0 1.130 136.0 2.200 70.0 1.700 70.0 Name Service order units size Nsam Rep Code Offset channel DEPT FT 4 1 68 0 1 FCNT MWD060 CNTS 4 1 68 4 2 NCNT MWD060 CNTS 4 1 68 8 3 RHOB MWD060 G/CM 4 1 68 12 4 DRHO MWD060 G/CM 4 1 68 16 5 RPD MWD060 OHMM 4 1 68 20 6 RPM MWD060 OHMM 4 1 68 24 7 RPS MWD060 OHMM 4 1 68 28 8 RPX MWD060 OHMM 4 1 68 32 9 FET MWD060 HOUR 4 1 68 36 10 GR MWD060 API 4 1 68 40 11 PEF MWD060 BARN 4 1 68 44 12 ROP MWD060 FT/H 4 1 68 48 13 NPHI MWD060 PU-S 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11870 12387 12128.5 1035 11870 12387 Page 17 • j-17c.tapx FCNT MWD060 CNTS 466.06 927.82 630.862 874 11870 12306.5 NCNT MWD060 CNTS 24478.9 33453.9 28621.6 $74 11870 12306.5 RHOB MwD060 G/CM 2.168 2.737 2.34912 875 11885 12322 DRHO MWD060 G/CM -0.023 0.373 0.0676846 875 11885 12322 RPD MWD060 OHMM 5.63 93.13 9.15779 875 11905 12342 RPM MWD060 OHMM 4.91 402.42 9.38203 875 11905 12342 RPS MWD060 OHMM 4.61 16.43 8.21331 875 11905 12342 RPX MWD060 OHMM 4.68 368.13 9.14019 875 11905 12342 FET MwD060 HOUR 0.51 24.27 3.61598 875 11905 12342 GR MWD060 API 9.72 97.6 29.0466 875 11898 12335 PEF MWD060 BARN 1.44 3.51 2.05011 875 11885 12322 ROP MWD060 FT/H 0.67 410.28 68.9301 874 11950.5 12387 NPHI MwD060 Pu-s 18.24 27.19 23.5079 874 11870 12306.5 First Reading For Entire File..........11870 Last Reading For Entire File...........12387 File Trailer Service name... .......STSLIB.007 service Sub Level Name... version Number. ........1.0.0 Date of ~eneration.......08/02/22 Maximum Physical Record..65535 File TyPe ................L0 Next File Name...........STSLIB.008 Physical EOF Tape Trailer Service name .............LISTPE Date . ...................08/02/22 Origin ...................STS Tape Name. .... ........UNKNOWN Continuation Number......01 Next Tape Name...........UNKNOWN Comments .................STS LIS Reel Trailer Service name .............LISTPE Date . ...................08/02/22 o n 9in ...................STs Reel Name. .... ........UNKNOWN continuation Number......01 Next Reel Name...........UNKNOWN ~omments .................STS LIS Physical EOF Physical EOF writing Library. Scientific Technical services writing Library. Scientific Technical services End Of LIS File Page 18
