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213-012
STATE OF ALASKAALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED WELL COMPTION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG ❑ Other ❑ Abandoned 0 Suspended ❑ 1b. Well Class: 8 2020 20AAC 25.105 20AAC 25.110 GINJ ❑ WINJ ❑ WAG ❑ WDSPL ❑ No. of Completions: Zero Developme(It ` 0Exploratory-, 0 , ! Service ❑ Stratigr'apfiic Test -0 2. Operator Name: 6, Date Comp., Susp., or Abend.: 14. Permit to Drill Number/Sundry BP Exploration (Alaska), Inc 12/18/2019 213-012 ' 319-505 3. Address: 7. Date Spudded: 15. API Number: P.O. Box 196612 Anchorage, AK 99519-6612 3/15/2013 50-029-20969-04-00 ' 4a. Location of Well (Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 3/18/2013 PBU J -17D ' Surface: 801' FNL, 1806' FEL, Sec. 09, T11 N, R13E, UM g Ref Elevations KB 69.80 ' 17. Field/Pool(s): Top of Productive Interval: 1779' FNL, 3438' FWL, Sec. 10, T11 N. R13E, UM GL 39.78 BE 39.75 PRUDHOE BAY, PRUDHOE OIL ' Total Depth: 1033' FNL, 106' FWL, Sec. 11, T11 N. R1 3E, UM 10. Plug Back Deplh(MD/ JD): 18. Property Designation: 10270-18459' ADL 028281 8 028280 ' 4b. 4b. Location of Well (State Base Plane Coordinates, NAD 27): 11. Total Depth (MD/TVD): 19. DNR Approval Number: Surface: x- 642547' y- 5970534 Zone - ASP 4 • 13498'/9016' ' 85-24 TPI: x- 647811 y- 5969657 Zone - ASP 4 12. SSSV Depth (MD/TVD): 20Thickness of Permafrost MD/fVD: Total Depth: x- 649742 y- 5970442 Zone - ASP 4 None 1 900'(Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No 0 13. Water Depth, if Offshore: 21. Re-dell/Lateral Top Window Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) MD/ND: 11735'/ 9032' 22. Logs Obtained List all logs run and, pursuant to AS 31.05.030 and 20 AAC 25.071, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Types of logs to be listed include, but are not limited to: mud log, spontaneous potential, gamma ray, caliper, resistivity, porosity, magnetic resonance, dipmeter, formation tester, temperature, cement evaluation, casing collar locator, jewelry, and perforation record. Acronyms may be used. Attach a separate page if necessary MWD/GR/RES, GR/CCL /MCNL 23. CASING, LINER AND CEMENTING RECORD CASING Wf. PER FT. GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZEAMOUNT CEMENTING RECORD PULLED TOP BOTTOM TOP BOTTOM 20" x 30" 33' 113' 33' 113' 36" 8 of yds Concrete 13-3/8" 72# Lbo 32' 2678' 32' 2678' 17-1/2" 3856 cu ft Arctic Set III 811 9-5/8" 47# L-80 30' 8931' 30' 7551' 12-1/4" 2360 cu It Class'G', 132 cu ft Permafrost 7" 26# L -s0 8774' 10234' 7429' 8435' 8-1/2" 348 cu H Class'G' 4-1/2" 1 12.6# L-80 10067' 11735' 8326' 9032' 6-1/8" 337 cu It Class'G' 3-1/2"x3-1/4" x2-7/8" 9.39(6./6.5# # L-80 10971' 13485' 8914' 9016' 4-1/4" 117 sx Class'G' 24. Open to production or injection? Yes ❑ No 0 25. TUBING RECORD If Yes, list each interval open (MD/TVD of Top and Bottom; Perforation Size and Number; Date Perfd): GRADE I DEPTH SET (MD) PACKER SET (MD/TVD) 4-1/2" 12.6# 13Cr80 1 10083' 10027'/ 8300' 4ban oA 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. ( � -"-e PATEEZO(I Was hydraulicfractuhng used during completion? Yes ❑ No 0 Per20 AAC 25.283 (i)(2) attach electronic and printedL2 nformation VD DEPTH INTERVAL (MD) AMOUNT AND KIND OF MATERIAL USED ---L�_ 10270' Set Whipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation (Flowing, gas lift, etc.): N/A Date of Test: Hours Tested: Production for Test Period -.11. Oil-Bhl: Gas -MCF: Water Bbl: Choke Size: Gas -Oil Ratio: Flow Tubing Press Casing Press: Calculated 24 Hour Rate �► Oil -Bbl: Gas -MCF: Water -Bbl: Oil Gravity-API(cor): Form 10-407 Revised 512017 CONTINUED ON PAGE 2 Submit ORIGINAL only RBDMS :`9 ,JEAN 10 2020 28. CORE DATA Conventional Corefs) Yes ❑ No R1 Sidewall Cores Yes ❑ No 0 If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presenceof oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, wre chips, photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS (List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost - Top Well Tested? Yes ❑ No D Permafrost - Base If yes, list intervals and formations tested, briefly summarizing test results. Attach Top of Productive Interval 11150' 8989, separate sheets to this form, if needed, and submit detailed test information per 20 AAC 25.071. Zone 2A 11150' 8989' Kicked off from Parent Well 11735' 9032' Formation at total depth: Zone 2A 11150' 9032' 31. List of Attachments: Summary of Pre -Rig Work, Summary of Daily Drilling Reports, Wellbore Schematic Diagram Information to be attached includes, but is not limited to: summary of daily operations, wellbore schematic, directional or inclination survey, core analysis, paleontological report, production or well test results, per 20 AAC 25.070. 32. 1 hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka, Joseph N Contact Name: Ciolkosz, Ryan R Authorized Title: pecial t Contact Email: Ryan.Ciolkosz@bp.com Authorized Signatu Date: Contact Phone: +1 907 564 5977 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC, no matter when the analyses are conducted. Item la. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each is segregated pool a completion. Item 1b. Well Class Service wells: Gas Injection, Water Injection, Water -Alternating -Gas Injection, Salt Water Disp, Water Supply for Injection, Observation or Other. Item 4b. TPI (Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15. The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). Item 20. Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 29. Item 22. Review the reporting requirements of 20 AAC 25.071 and, pursuant to AS 31.05.030, submit all electronic data and printed logs within 90 days of completion, suspension, or abandonment, whichever occurs first. Item 23. Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24. If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27. Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-in, or Other (explain). Item 28. Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30. Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31. Pursuant to 20 AAC 25.070, attach to this form: well schematic diagram, summary of daily well operations, directional or inclination survey, and other tests as required including, but not limited to: core analysis, paleontological report, production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only ****WELL S/I UPON ARRIVAL**** (ctd) R/U SLICKLINE UNIT SWCP #4522 FOR GLV C/O 11/20/2019 ****CONT JOB ON 11/21/19**** ****CONT. JOB FROM 11/20/19**** (ctd) SET 4-1/2" WHIDDON CATCHER ON IBP STOP @ 10,050' MD. PULLED RK-OGLV FROM ST#3 @ 6368' MD. PULLED RK-LGLV FROM ST#4 @ 3425' MD. SET RK-DGLV IN ST#4 @ 3425' MD. LRS LOADED IA W/ 410 BBLS OF CRUDE. SET RK-DGLV IN ST#3 @ 6368' MD. LRS PERFORMED PASSING MIT -IA. see Irs I PULLED WHIDDON & IBP STOP FROM 10,050' MD. DRIFTED WITH 20' OF 3.70" WS. SAT DOWN HIGH AT @ 10,073' SLM (POSSIBLY MILLED XN) 11/21/2019 ***CONT ON 11-22-19 WSR*** T/I/0= Temp=S/I (LRS unit 76 -Assist SL with Load and test) Loaded IA W/ 410 bbls Crude. S -line set DGLV, Pumped 7.1 bbls Crude down IA to reach test pressure. MIT -IA PASSED to 2648 psi (2750 MAX, 2500 Target) Loss of 59 psi 1st 15 min. Loss of 27 psi 2nd 15 min. for a total loss of 86 psi during 30 min test. Bled back 7 bbis Freeze protect FL w/ 5 bbls 60/40, 50 bbls Crude. FWHP=1900/300/60, Tags hung, Casing valves OTG, S- 11/21/2019 Line on location upon departure ***CONT FROM 11-21-19 WSR***(CTD) RAN 3.79" G -RING, 4 1/2" BL -BRUSH TO TIGHT SPOT @ 10,073' SLM, CLEANED AREA UP. 11/22/2019 DRIFTED TO 10,550' SLM WITH 20' OF 3.70" WS. ***WELL SHUT-IN ON ARRIVAL*** RIG UP HES ELINE UNIT 4863. 11/24/2019 ***JOB CONTINUES ON 25-NOV-19 WSR*** T/I/0= 1816/0/0 Temp= SI/ Assist E -line (Set packer Whipstock) Spotted equipment in. 11/24/2019 ***Job continued 11/25/19****** (Assist E -Line setting whip stock) ****Job continued fronm 11/24/19***** MIT TBG PASSED @ 2747 psi Target 2500 psi Max applied 2750 Pumped 5 bbls 60/40 meth spear followed by 290 bbls 120*f 1% KCL to load the well. Spear in to TBG with 2 bbls of 60/40 followed by 38 bbls DSL for TBG freeze protect. Pumped 8.7 bbls of 5* diesel down TBG to reach test psi 1 st test 1 st 15 min TP lost 0 2nd 15 min 0 for a total of 0 psi in 30 min Bleed TP down bleed back 2.2 bbls E -line on well on dep. Wing shut swab open ssv open master open casing valves 11/25/2019 open to gauges Final Whp's=295/vac/vac ***CONTINUED FROM 24-NOV-19 WSR*** SET 4-1/2" BAKER WHIPSTOCK, TOWS AT 10,271' ELMD, 149 DEGREES ROHS. MIT -T PASSED. 11/25/2019 ***JOB COMPLETE, WELL SHUT IN ON DEPARTURE*** T/I/O = 150/0/0. Set TWC/Pre CDR2 Tree conversion. RU CIW lubricator and PT to 35013500psi (PASS) Run down and set 4" CIW TWC #444 at 125". LTT (PASS) RD lubricator. Torque THA x MV to API specs. PT against TWC to 35015000psi (PASS) RDMO 11/29/2019 ***Job In Progress*** SEE LOG FOR DETAILS. Final T/I/0= TWC/0/0. T/1/0=150/0/0 Job in progress from night crew. PT'd top of Master x Bottom of Swab 300/low..3500/high.. to flat line criteria, pass. PT'd through blind flange on top of Swab, 11/30/2019 against top of Swab 300/low..3500/high.. pass. see "Field Charted Tests" Job complete. Daily Report of Well Operations PBU J -17D T/I/O. Pre CDR2. RD 4" Cameron upper tree. RU 4" CDR2 tree #9 kill line #3. Torqued to API spec. RU CIW lubrucator with 4" H pulling tool. PT 4" CDR2 tree #9 and kil line #3 through lubrucator to low 300psi and high 5000psi for 5 min ea. Passed. Pulled 4" H TWC #444 @130". RD 4" tree cap bonnett. RU 4" test spool #2. Torqued to API spec. PT topside MV 11/30/2019 low 300psi and high 3500psi for 5 min ea. Passed. Change out with day crew job in progress. TWO = VacNac/Vac. Temp = SI. Bleed WHPs (Pre rig). No wellhouse or flowline. 12/10/2019 SV, WV, MV(upper) = C. MV = O. IA, OA = OTG. 10:30. T/I/O = Vac/Vac/Vac. Temp = SI. Bleed WHPs (Pre rig). No wellhouse or flowline. WHP's unchanged from 12/10/19. 12/16/2019 1 SV, WV, MV(upper) = C. MV = O. IA, OA = OTG. 11:10. NorthAmerica- ALASKA - BP Pagel Operation Summary Report Common Well Name: J-17 - Event Type: RE-ENTER- ONSHORE (RON) Start Date: 12/16/2019 End Date: Project: PBUSite: J Rig Name/No.: CDR -2 Spud Daterrime: 1/3/2002 12:00:OOAM Rig Release: 1/3/2020 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000388 Active datum: J -17D @69.80usft (above Mean Sea Level) Date From - To Hrs Task Code NPT Total Depth Phase Descnption of Operations (hr) _ (usft) 12/16/2019 15:30 - 16:30 100 G RID P _ PRE RELEASE RIG FROM J -09C. 16:30 - 18:00 1.50 RIGD P PRE MOVE RIG OFF J -09C, MOVE AROUND PAD TO J-1 7E 118:00 - 22:30 4.50 RIGD P PRE _ PJSM, - VERIFY PRESSURES ON WELL. - VERIFYALL VALVES CLOSED. - SPOT SUB AS CLOSE AS WE CAN WITH TRUCKS, RU STOMPER AND MOVE SUB IN PLACE I- MOVE PITS IN PLACE. - _—ILRIG ACCEPTED AT 22: 30" 22:30 - 00:00 1.50 RIGU P PRE _ PJSM, BEGIN RU CHECKLISTS 12/17/2019 00:00 - 04:00 j 4.00 RIGU P PRE RIG UP CHECKLISTS. OPEN TREE UP FOR THERMAL EXPANSION. MONITOR LTT MASTER AND SWAB. GOOD TEST. NIPPLE DOWN TREE CAP. NIPPLE UP BOPE. IRU INNER REEL IRON. STAB INJECTOR, SERVICE VALVES, TORQUE 04:00 - 10:00 6.00 RIGU __ P _ TREE BOLTS PRE . FILL REEL FORWARD WITH FRESH WATER. LINE UP TO REVERSE CIRCULATE. REVERSE CIRCULATE, CABLE IS HEARD j 'MOVING, j CUTBACK 300' OF CT FOR 1.98% SLACK. INSTALL CT CONNECTOR, PULLTESTTO50K. MAKE UP INJECTOR TO WELL, PUMP FORWARD. 1000 - 13:30 3.50 RIGU P PRE INSTALL BHI CABLE HEAD WITH NO FLOATS. • ELECTRICAL TEST ON CABLE HEAD, GOOD. GREASE VALVES. FLUID PACK LINES. PREP Ir FOR BOP TEST. 13:30 - 21:45T8.255 BOPSUR P ! PRE _ SHELL TEST BOPS TO 4700 PSI, GOOD./ TEST BOPS AS PER BP AND AOGCC REG"S. TEST WITNESS IS WAIVED BYAOGCC - INSPECTOR LOU LAUBENSTEIN. TEST 1: PRESSURE BULKHEAD IS SEEN LEAKING, MOVE ON TO TEST 2 AND TIGHTEN PACKING. TEST 2: BLIND ISHEARS, RI,BOA, BI,B4- PASS TEST 3: ANNULAR (2-3/8"), TIW #1, B3, B2, BL1-PASS TEST 4: UPPER 2-3/6" PIPE / SLIPS, TIW #2, . BL2, I T2, C15 - PASS TEST 5: C16, T1, C11 - FAIL VALVE C3 IS LEAKING PAST THE STEM. CHANGE IT OUT. RE -TESTS: PASS TEST 6: VARIABLES (2 2/8"), C7, C9, C10, TV2 TEST 7: LOWER 2 3/8" PIPE SLIPS, C5, C6, C8, TVI -PASS TEST 8: CHOKEA, CHOKE C -PASS ACCUMULATOR DRAW DOWN TEST -PASS TEST 9:ANNULAR (3 1/2"), C1 , C4 - PASS TEST 10: VARIABLES (3 1/2") C2, C3 - PASS TEST 1 V C10 BACKWARDS) AND STRIPPER PASS Printed 1/7/2020 12:09:37PM **All dephts reported in Drillers Depths" Printed 117/2020 12:09:37PM **All dephts reported in Drillers Depths** North America - ALASKA - BP Page 2 Operation Summary Report Common Well Name: J-17 -- - - -- Event Type: RE-ENTER- ONSHORE(RON) Start Date: 12/16/2019 End Date: Project PBU Site: J Rig Name/No.: CDR -2 Spud DateTme: 1/3/2002 1200.00AM Rig Release: 1/3/2020 Rig Contractor: NABORS ALASKA DRILLING INC. BPUOI: USA00000388 Active datum: J -17D Q69.80usft (above Mean Sea Level) Date From -To His Task Code NPT Total Depth Phase I Description of Operations (hr) ! usft 121:45 - 23:30 1.75 BOPSUR P PRE BOP TEST COMPLETED - RD TEST EQUIPMENT - SWAP OUT LUBRICATORS 1 -- STRAP STACK MEASUREMENTS INSTALL BHI FLOATS 23:30 - 00:00 0.50 BOPSUR P PRE PRESSURE TEST - PT LUBRICATOR TO 4000 PSI *HOLD PRE SPUD MEETING WITH JEFF WARD'S CREW. *HOLD FIRE / EVACUATION DRILL WTH JEFF 1 WARD'S CREW. 12/18/2019 iI:08:00 - 10:00 2.00 STWHIP P 10,271.0 _ WEXIT LOG GR FROM 9050'. CORRECT -34'. RIH, LIGHT 'TAG .AT 10270'. 1 FINISH CIRCULATING MUD AROUND. 1 RETURNS CLEAN, PURGE CT RISER. AFTER MUD TO SURFACE BRING RETURNS TO PITS, SHUT DOWN FLOW CHECK WELL 10 MIN AND CLOSE EDC, GOOD. — 100:00 - 01:00 1.00 BOPSUR P PRE 1- PT UQC, COIL CONNECTOR AND BHI FLOATS ------ — GOOD PT 01:00 - 02:30 1.50 STWHIP - p ------- WEXIT FWELL OPS _ FLUID PACK MPL WITH METH TO OPEN UP TO THE WELLAND FILL THE WELL TO FLOW CHECK -1 BBLTO FILLWELL. i I 1 -FLOW CHECK GOOD . -DISPLACE COIL WITH 5 BBLS OF METH AND AND 50 BELS OF HEATED 1% KCL -PURGE LUBRICATORS WHILE DISPLACING COIL —_ 02:30 _ _ -FLOWCHECK FOR 10 MINUTES STATIC - 03:30 1.00 1 STWHIP P 10,271.00 WEXIT MAKE UP 3.80" MILLING BHA#1 - HOLD PJSM WITH CREW 1 -MILL 3.80" GO / 3.79" NO GO/STRING MILL 3.79" GO / 3.78" NO GO I' - PRESSURE TEST QTS TO 3500 PSI HIGH ! FOR 5 MINUTES 10,271.00 WEXIT INJECTOR ON: 0300 HRS RIH WITH 3.80" MILLING BHA#1 03.30 06:00 2.50 STWHIP P - RATE: 0.50 BPM IN, 0.95 BPM OUT. CIRC PRESSURE: 108 PSI PUMPING HEATED SLICK 1% KCLTAKING RETURNS TO TIGER TANK 1 *OBSERVE DROP IN FLUID DENSITYALONG ! WITHAOUT RATE INCREASE, DISCUSS WITH WELL SUPERINTENDENT AND HOLD I FOR RETURNS WITH THE CHOKE. 11 06:00 - 07:00 1.00 STWHIP P ! 10,27100 WEXIT TIE-IN DEPTH FROM 10040'. CORRECT+3' RIH, LIGHT TAG AT 10305'. WELLRECORDS INDICATE WHIPSTOCK WAS SETAT 10271', REVIEWTIE-IN WITH GEO. PICK UPAND REPEAT TIE-IN LOG. 1 CIRCULATE KCL WATER THEN DRILLING MUD. 07:00 08:00 1.00 _ _ _ STWHIP P�1 _ 827100 r WEXIT PICK UP TO 9050'TO VERIFY FIRST TIE-IN. _ PICK UP TO LOGGING DEPTH. SHUTDOWN PUMP AND SHUT IN WELL, VAC OUT TIGER TANK GETTING FULL. Printed 117/2020 12:09:37PM **All dephts reported in Drillers Depths** North America -ALASKA - BP Page 3 OK Operation Summary Report Common Well Name: J-17 ------------ Event Type: RE-ENTER- ONSHORE (RON)Start Date: 12/16/2019 End Date: Project: PBU Site: J -- Rig Nama/No.: CDR -2 Spud Date/Time: 1/3/2002 12:00 OOAM Rig Release: 1/3/2020 Rig Contractor: NABORSALASKA DRILLING INC. BPUOI: USA00000388 Active datum. J -17D @69.80usft (above Mean Sea Level) - Dale From - To Hrs Task ! Code NPT Total Depth Phase Description of Operations (hr) I (usft c , I10:00 - 18:15 8.25 STWHIP P 1 10,275.70 WEXITMILL WINDOW FROM 10268.7-10277 GO TO 2.86 BPM AND EASE DOWN TO START WINDOW I� ✓ :2 STALLS GETTING STARTED THEN TIME MILLING FROM 10268'. MILL 3.8" WINDOWAS PER BTT REP FROM 10268'. MW IN / OUT 9.00 / 8.98 PPG. FLOW IN / OUT 2.84 / 2.93 BPM. TOW 10268.7 BOW 10275.7 -- !_ STRING REAMER OUT OF WINDOW AT 10277 _ .18:15 - 20:30 2.25 STWHIP P 1 10,287.00 WEXIT MILL RATHOLE FROM 10277' TO 10287' -2.58 BPM IN /2.58 BPM OUT -MUD WEIGHT 8.99 PPG IN/ 8.87 PPG OUT -PUMP 5 BBLS LO / HI VIS SWEEPS AROUND. -AT TO OF RATHOLE PUMP 10 BBLS LO / HI VIS SWEEPS AROUND. -PERFORM REAMING PASS FROM li 10287' -10265' --CLEAN PERFORM DRY DRIFT -CLEAN - I- -PIANT FLAG AT 10287' (10168.92' EDP) -PULLABOVE WINDOW, OPEN EDC AND ! PERFORM FLOW CHECK -WELL IS STATIC ------ NOTE:1 028TSAMPLE IS 20% FORMATION. - �, 211:30 23:OD 2.50 : STWHIP P 10,287.00 WEXIT POOH -- -3.93 BPM IN 13,61 BPM OUT — - ! -HOLD PJSM FOR BHA OPERATONS AND FLOW CHECK WELL -STATIC. 23:00 - 00:00 1.00 ! STWHIP P 10,287.00 � WEXIT BHA HANDLE -INSPECT LAST 150' OF COIL -GOOD -INJECTOR OFF AT 2315 HRS -LAY DOWN WINDOW MILLING BHA#1 -BLOW DOWN CHOKE -REPLACE STRIPPER PACK OFF ON INJECTOR. - MILL IS 3.79" GO, 3.78" NO-GO. NOTE: DISCOVERED ELECTRICAL WET CONNECT IN UQC BROKEN -BROKEN PIECE RECOVEREDAND ELECTRICAL WET '. CONNECT REPLACED. �- NOTE: MONITORING HOLE WHILE OUT OF - 12/19/2019 100:00 - 01:15 1.25 __ HOLE DRILL P M287A0 PROD1 BHA OPERATIONS -TEST ELECTRICAL CONNECTION ON WET CONNECT -GOOD -TEST PACK OFFS TO 250 / 3500 PSI FOR 5 MINUTES EACH -GOOD -MADE UP LATERAL DRILLING BHA#2 -INJECTOR ON AT 0100 HRS -TESTED QTS TO 3500 PSI GOOD. 2.25 01:15 0330 _ DRILL P 10,287.00 ! PROD1 RUN IN HOLE -0.48 BPM IN/0.93 BPM OUT -TIE IN FROM 9120' TO 9167' CORRECTION -39' Printed 117/2020 12:09:37PM "All dephts reported in Drillers Depths'" ;ONOUCTOR 110- 13-3/8" CSG, 72#, L-80, D = 12.347" 2685 9-5/8' X T7 BKR G2 ZXP LTP 8774' w / 11.6 TFBK SLV, D = 6.30" X 7" IVl-1PSTOCK(09/2705) —t 895T CSG, 47#, L-80, D=8.681" Minimum ID = 2.377" @ 13082' 3-3/16" X 2-7/8" XO 14 0152 12.6#, 13CR-80 VAM TOP, .0152 bpf, D = 3.958" 7" LNR 26#, L-80 BTC -M, .0383 bpf, D = 6.276" 4-12" BKR PKR WHIPSTOCKw/2 RA PIP TAGS I4-1/2" LNR,2.6# 1, L-80 DT -M, .0152 bpf, D = 3.958"-11736 4-1/2' BKR WHPSTOCK (03/13/13) 11735'_ PERFORATION SII WRY FIEF LOG: SLB MILL/ GR CCL ON 03122!13 ANGLEATTOP P97F 93° Q 11990' Mte: Refer to Rodmtion DB for historical perf data SIZE SPFJ INTERVAL OprllSgz DATE ---SOZ 2" 6.11990--12020 0 - 86/16/14 2" 6 12070 - 12100 O 06/76/14 2" 6 12190 - 12220 O 11/02/13 2" 6 12220-12250 O 11/01/13 2" 6 12640-12670 C 11/01/13 2" 6 12800 - 12830 C 10/31/13 2" 6 12930 - 12960 C 10/31/13 2" 6 13180- 13380 C 03/21/13 PBTD GLE INITIAL, 4 -1/2- J -17D CHROME — W,B-,&--WELLBORE'S HO '8" DV J n_ee i icr ua unoo c ST MD ND DEV 71PE I VLV I LATCH I PORT I DATE 4 3235 3227 15 AMG DMY RK 0 1121!19 3 6368 5608 45 MMG DMY RK 0 1121/19 2 8620 7308 37 MMG DMY RK 0 10/10/05 1 9936 8240 41 KBG2 DMY BK 0 10/10/05 MLLOU! WBJDOW (J -17C) 8931' - 8947' I 10006' I 1 10091' 1 X 4-1/2" 17- X 5" BKR ZXP LTP w /I V TIEBACK, D = 4.40' 4-1/2" HES XN NP, MILLED TO 3.80' (03/05/13) 4-1/2"VILEG, D=3.958" MARKER JOINT, D=4.00" I KB LTP, D = 2.37" (04/03/13) EPLOYMENT SLV, D = 3.00' !"HES X NP, D=2.813" 2813- WK2 X 3-3/16' XO, D= 2786- 1 MLLOIff WNDOW (J-170) 11735' - 11743- 2-118" BKR IWFD 2.28" DCT RANGE C13P(08/31/17) 1 3-3/16' X 2-718' XO, D = FISH: CBP MILLED (06/1° 12-7/8" X 2-3/8" XO PN. D = 1.992" 1 PRUDHOE BAY UNIT WELL: J -17D PERMIT NO: F2130120 API No: 50-029-20969-04 SEC 9, T11N, R13E, 801' FNL & 1806' FEL DATE REV BY COMMENTS DATE REV BY COMMENTS 07/18/83 AU013 INITIAL COMPLETION 0327/19 MHIJMD SET IBP STOP (03/25/19) 1012689 JLH CTD SIDETRACK (J -17A) 04/10/19 DD/JMD+ ELEVATION CORRECTIONS (04/05/19 0112182 NORDIC 1 CTO SIDETRACK (J-1713) 12/02/19 MH/JMD PULLED IBP STOP 1121/19) 1011185 N2ES SIDETRACK (J -17C) 1282/19 MWJMD GLV CX) (11/21119) 03/22113 NORDIC SIDETRACK (J -17D) 1282119 BTWJMD SET PKR WHIPSTOCK(1125/19) BP Exploration (Alaska) 03/19/19 JMD CORRECTION TO XO ON WBS THE STATE ALASKA GOVERNOR MIKE DUNLEAVY Sean Mclaughlin Engineering Team Lead BP Exploration (Alaska), Inc. PO Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU J -17D Permit to Drill Number: 213-012 Sundry Number: 319-505 Dear Mr. Mclaughlin: Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, Alaska 99501-3572 Main: 907.279.1433 Fax: 907.276.7542 w .aogcc.alaska.gov Enclosed is the approved application for the sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown, a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Vc e Chair DATED this N3 day of November, 2019. RBDMSA;J Nov 14 2019 STATE OF ALASKA RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS NOV 6 ZQ19 20 AAC 25.280 1. Type of Request: Abandon ❑ Plug Perforations ❑ Fracture Stimulate ❑ Repair Well ❑ Operations shutdown ❑ Suspend ❑ Perforate ❑ Other -Stimulate ❑ Pull Tubing ❑ AGGod Qm ❑ Plug for Redrill 0 • Perforate New Pool ❑ Re-enter Susp Well ❑ Alter Casing ❑ Other /i �i�1 W -'K zLoW 2. Operator Name: BP Exploration (Alaska), Inc 4. Current Well Class: 5. Permit to Drill Number. 213-012 J 3. Address: P.O. Box 196612 Anchorage, AK Exploratory ❑ Development 0 99519-6612 6. qpl Number: 50-029-20969-04-00 Stratigraphic ❑ Service ❑ / 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes ❑ No 0 PBU J -17D J 9. Property Designation (Lease Number): ADL 028281 & 028280 10. Field/Pools: PRUDHOE SAY, PRUDHOE OIL 11. PRESENT WELL CONDITION SUMMARY Total Depth MD (ft): 13498 Total DepthTVD(ft): Effective Depth MD: 9016 12393 Effective Depth TVD: 9029 MPSP (psi): Plugs (MD): 2384 12393.12460 Junk (MD): 12670,13445 Casing Length Size MD TVD Bunt Collapse Conductor 80 20" x 30" 33-113 33-113 Surface 2646 13-3/8" 32-2678 32-2678 5380 2670 Intermediate 8901 9-5/8" 30-8931 30-7551 6870 4760 Liner 1460 7" 8774-10234 7429 - 8435 7240 5410 Liner 1668 4-1/2" 10067-11735 8325-9032 8430 7500 Liner 2506 3-1/2" x 3-114" x 2-7/8" 10979 - 13485 8918-9016 10160 10530 Perforation Depth MD (ft): 11990 - 13380 Perforation Depth TVD (ft): 9036 - 9020 Tubing Size: 4-1/2" 12.6# Tubing Grade: 13Cr80 Tubing MD (ft): 28-10083 Packers and SSSV Type: 4-1/2" Baker S-3 Perm Packer I Packers and SSSV MD (ft) and TVD (ft). 10027/8299 No SSSV Installed No SSSV Installed 12. Attachments: Proposal Summary 0 Wellbore Schematic 0 13. Well Class after proposed work: Detailed Operations Program ❑ BOP Sketch ❑ Exploratory ❑ Stratigraphic ❑ Development 0 Service ❑ 14. Estimated Date for Commencing Operations: 11/15/2019 15. Well Status after proposed work: Oil ❑ WINJ ❑ WDSPL ❑ Suspended 0 16. Verbal Approval: Date: GAS ❑ WAG ❑ GSTOR ❑ SPLUG ❑ Commission Representative: GINJ ❑ Op Shutdown ❑ Abandoned ❑ 17. I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Ciolkosz, Ryan R be deviated from without prior written approval. Contact Email: Ryan.CiolkoszObp.com Authorized Name: Mclaughlin, Sean M Contact Phone: +1 907 564 5977 Authorized Title: Engine 'ng Team L ad CTD r Authorized Signature: _,�./� Date: COMMISSION USE ONLY Conditions of approval: Notify Commission sothat a representative may witness I Sundry Number: ^ ,r -'5O67 Wat Plug Integnty ❑ BOP Test Mechanical Integrity Test ❑ Location Clearance ❑ 5 _q Other: 41f eC' PLe�ec,e,,,..�-�iJ" a.�+pe-ov'- � Z_OA4e Z�/f2- �[) Post Initial Injection M Req'd? JVes ❑ Zo ❑ �� ®C. -r RBDMSL64 NOV 14 2019 Spacing Exception Required? Yes 0\ No 0?'*� Subsequent Form Required: Approved by: Ci /i 11/1311 Form 10-403 Revised 04/2017 COMMISSIONER ORIGINAL APPROVED BYTHE COMMISSION Date: 14 Approved application is valid for 12 months from the date of approval. // t� ! Submit Form and I Attachments in Duplicate C;>arR of Iota To: Alaska Oil & Gas Conservation Commission From: Ryan Ciolkosz - CTD Engineer Date: November 4, 2019 Re: J -17D Sundry Approval Request Sundry approval is requested to plug off the J -17D production as part of the drilling and completing the proposed J -17E coiled tubing sidetrack. History of J -17D: J-17 was originally completed in 1983 and sidetracked several times. J -17D was sidetracked in 2013. The well is currently at marginal GOR. There are no more future perforation intervals remaini g. /✓ Q1� Ate' P� Ir/A90- Proposed /' k4�l �Pifs /A9 Proposed plan forJ-17E: fi� T Well �f r�Jr 4y of 6OR 6�� (� act-, /�/1 The sidetrack will be a ^3490' horizontal ST that will kick -out from the parent in t e Sag River. The CST will establish Y offtake in Zone 1B/2A. The sidetrack will be drilled on or around January 2020. During pre -rig work it is proposed to set a 4_-1/2" packer whipstock at a kickoff depth of `10268' MD. CT will mill a 3.80" window pre -rig The rig will move in, test BOPE and kill the well, and drill into Zone 16. The proposed sidetrack will be completed with a 3-1/4" x 2-7/8" L-80 solid liner and cemented in place. The rig will perforate 1000 ft. This Sundry covers plugging the existing J -17D production via the liner cement iob or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Pre -Rig Work (scheduled to begin Nov 15th, 2019) 1. 5 DMY GLVs, Pull IBP stop, Drift for whipstock 2. EL Set CIBP/ Whipstock T� c_(6 G- 3. F MIT -IA. A/EL: Displace well to brine/FP. Pressure test CIBP b 4. C Mill Window LTA- 5. V Pre -CTD Tree work. Rig Work (scheduled to begin January 2020) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2384 psi). 2. Drill production section: 4.25" OH 3. Run 3-1/4" x 2-7/8" L-80 liner to TD. 4. Pump primary cement job: 44.4 bbls, 15.3 ppg Class G, TOC at TOL (10120' MD)*. 6. RPM Log and perforate wellbore. 2" Maxforce guns planned (-1000', 6spf, planned). 7. Freeze protect well to a min 2,200' TVDss. 8. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post -Rig Work: 1. V: Valve & tree work 2. SL/FB: Set LTP if needed. PT LTP. Set KO GLD. 3. T: Portable test separator flowback Ryan Ciolkosz CC: CTD Engineer 564-5977 Well File Joe Lastufka Schwartz, Guy L (CED) From: Ciolkosz, Ryan R <Ryan.Ciolkosz@bp.com> Sent: Tuesday, November 12, 2019 2:47 PM To: Schwartz, Guy L (CED) Subject: PTD# 213-012 Sundry Pre -rig Steps Slickline Dummy GLVs. Pull IBP Stop. MIT- IA. Drift for WS I. Pull LGLVs and set Dummy GLVs in Sta 4 and 3. • Prior to setting last valve. Load IA with dead crude. IA fluid level assumed to be at the SO. Volume to SO is 340 bbls. Load volume (1.2x) is 410 bbls. 2. MIT -IA to a target pressure of 2500 psi with crude, max applied pressure of 2750 psi. • This is an assurance test and there is no requirement on TBG and OA pressures. • Integrity limits have been checked and verified. 3. Pull IBP Stop 4. Drift for whipstock with a 20'x 3.70" OD dummy whipstock drift down to top of packer at least 10300' MD. Eline Set CIBP. Set Whipstock 1. Set HES 4-1/2" CIBP at 10300' MD • Tie in log: SLB Coil Flag (GR/CCL) 30 -Oct -2013 • Prior to setting CIBP, load tubing with 235 bbls of 1% KCL followed by 38 bbls of diesel. • MIT -T to a tofget pressure of 2500 psi with diesel, max/ayp/plied pr ssure of 2750 psi. C 13 N"l t P'r i l..A++ /ry a 2. Set a Baker 4-1/2" Monobore Whipstock (3.63" OD) at 10271' ELMD TOWS. • Set with SLB WPP tool or HES Guardian. • Install 2 RA Tags in the whipstock — to be installed by Baker at their shop. • Tie in log: SLB Coil Flag (GR/CCL) 30 -Oct -2013 • 150 deg ROHS orientation, (setting range is +/- 5deg) • Inclination at setting depth is 48 deg. • Contact Drilling Engineer for any tie-in related ssues. Coiled Tubing E Ost (AOGCC Notification). Mill Window. 1. MU and RIH with 3.80" OD window milling assembly (see baker procedure). • If the XN nipple is tagged with the mill, do not mill on the XN as this risks backing off the tubing tail. 2. Mill window at 10,271' (WS pinch point) and 1Q' Qf formation per Baker procedure. • CIBP plug will be set covering the perforations. Geovis viscous sweeps should be used to keep the hole clean. This can be performed at WSL discretion. Ryan Ciolkosz Drilling Engineer BP Exploration Alaska Office: (907)564-5977 Cell: (907)244-4357 The sundry and permit to drill will be posted in the Operations Cabin of the unit during the window milling operation. Window Milling Fluids Program: • A min EMW of 8.4 ppg KCL (^'627 psi over -balance). KCI will be used as the primary working fluid and viscous gel sweeps will be used as necessary to keep the hole clean. • The well will be freeze protected with a non -freezable fluid (typically a 60/40 methanol/water mixture) prior to service coil's departure. • Additionally, all BHA's will be lubricated and there is no plan to "openhole" a BHA. Disposal: • All Class 1& II non -hazardous and RCRA-exempt drilling and completion fluids will go to GNI at DS 4 or Pad 3. • Fluids >1% hydrocarbons or flammables must go to Pad 3. • Fluids >15% solids by volume must go to GNI. Hole Size: • The window and 10' of formation will be drilled with a 3.80" OD mill. Well Control: • BOP diagram is attached. • AOGCC will be given at least 24 hour notice prior to performing a BOPE function pressure test so that a representative of the commission can witness the test. • Pipe rams, blind rams, CT pack off, and choke manifold will be pressure tested to 250 psi and 4,000 psi. • BOPE test results will be recorded in our daily reporting system (Alaska Wells Group Reporting System) and will provide the results to the commission in an approved format within five days of test completion. • BOPE tests will be performed upon arrival (prior to first entry into the well) and at 7 days intervals thereafter. • 10 AAC 25.036 c.4.0 requires that a BOPE assembly must include "a firewall to shield accumulators and primary controls". A variance is requested based on the result of the joint hazop with the AOGCC. For our operation, the primary controls for the BOPE are located in the Operations Cabin of the Coiled Tubing Unit, and the accumulators are located on the backside of the Operations Cabin (opposite side from the well). These are approximately 70' from the well. Hazards: • 1 pad is not an 112S pad. Max recorded H2S reading on J-17: 20 ppm on 4/26/2019. Max H2S recorded on the pad: <100 ppm. Reservoir Pressure: • The reservoir pressure on J -17E is expected to be 3278 psi at 8944' TVDSS (7.05 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2384 psi. • A min EMW of 8.4 ppg for this well will provide 627 psi over -balance to the reservoir. TREE= 4-1/16"CMVFLS I -I -FEAR= WEVOY ACTUATOR= CIWSH 3_000 63 ELEV= --76.98' _REFELEV= 69.80' i BF._ V ELE= .K_ - 39.75 20" CONDUCTOR — 110' 12070- 12100, 3000' MexArgle= 95"_@1'172T Daturn MD= 1.0893 13-3/8" CSG, 72#, L-80, D = 12.347" H 2685' I9-518" X 7" BKR G-2 ZXP LTP w / 11.6' TIEBK SLV, D = 6.30" 19-5/8" X 7" BKR HMC LNR HGR D = 6.32" 1 D=8.681" I—] - Minimum ID = 2.00" @ 10050' 4-1/2" IBP STOP TBG, 12.6#, 13CR-80 VAM TOP, h1008: bpf, D = 3.958" 'R 'r' s_ 7" LNR, 26#, L-80 BTC -M, .0383 bpf, ID = 6 276"-- 10234' I3-12" LNR 9.3#, L-80 STL, .0087 bpf, D = 2.992" -1__11382-_j 4-1/2" LNR 12.6#, L 80 IBT M, .0152 bpf, D = 3 958" — -11735 , 4-112 BKR WHPSTOCK (03/13/13) — 11735' PERFORATION SUMMARY REF LOG: SLB MIC NIJ GR/ CCL ON 03/22/13 ANGLEAT TOP PERF: 93" @ 11990' Note, Refer to Production DB for historical pert data SEE SPF_ INTERVAL Opn/Sgz DATE SOZ 2" 6 11990 - 12020 O 06/16/14 2" 6 12070- 12100, O 06/16/14 2" 6 12190 - 12220 O 11/02/13 2" 6 12220-12250: O 11/01/13 2" 6 12640- 12670 C 11/01/13 2" 6 '12800 - 12830 C 10/31/13 2" 6 12930 - 12960 C 10/31/13 2" 6 13180-13380 C 03/21/13 J -17 DSAFETY NOTES: CHROME TBG " NIT AL, "A-,GLE B"7g@ 11WELLBORE'S NOT SHOWN *`* 221$' 4-1/2"EDS X NIP, D=3.813" 8" DV PKR GAS LIFT MANDRELS ST ND ND DEV TYPE VLV LATCH PORT DATE -49 PBTD 3227 15 rvNK' DOME RK 16 02!03/19 3 6368 5608 45 MNG SO RK 20 02/03/19 2 8620 7308 37 MMM DMY RK 0 10/10/05 1 9936 8240 41 KBG2 DMY BK 0 10/10/05 MILLOUT WINDOW (J -17C) 8931'-8947 10006' 4-1/2" HES X NP, D = 3.613" 70027' 7" X 4-1/2" BKR S-3 PKR D = 3.875" 10050' - = 3.813" -- - --1/2"BTOP, 2. P SID=00"(0 1 0050' 4 I3/25/19)- 10067' 7" X 5" BKR ZXP LTP w /11' TACK, D = 4.40" 10070' 4-1/2" HES XN NIP, MILLED TO 3.80" (03/05/13) 10083' 4-12"WLEG, D=3.958" 10084' 7" X 5" BKR LNR HGR, ID = 4.40" 10091' � 10417' a-12"MARKH2 Jow-r, D=a.00^ (+1+ W I 10977' 4-1l2" KB LTP, D = 2.37" (04/03/13) 10979' 3.70DEPLOYMBJTSLV, D=3.00" 11001' —3 1/2' HES X NP, D = 2.813" MILLOUT WINDOW (J -17D) 11735'- 11743' z,(- 12393'—2-1/8"BKRIBP(03/16119) 112670' CMD I 187" 13082' — 3-3/16" X 2-7/8" XO, D = 2.377" 3-1/4" LNR 6.6#, L-80 TCII, .0079 bpf, ID = 2.850" 13082' 13445' FISH: CBP MILLED (06/15/14) PBTD 13439' 2-7/8" LNR 6.4#, L-80 STL, .0058 bpf, D = 2.441" 13485' 13480' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/18/83 AUD13 INITIAL COMPLETION 0529118 KP/JMD TREE C/O (05/26/18) WELL: J -17D 10116199 JLH CTD SIDETRACK (J -17A) 02/07/19 JPK/JMD GLV C/O (02/03/19) PERMIT No: 2130120 0121102 NORDIC 1 CTD SIDETRACK (J -17B) 03/19/19 JCF/JMD _ SET BKR IBP (03/16/19) API No: 50-029-20969-04 10/11/05 N2ES SIDETRACK (J -17C) 03/19/19 JMD CORRECTION TO XO ON WBS SEC 9, T11 N, Rl3E, 801' FNL & 1806' FEL 0322/13 NORDIC 1 CTD SIDETRACK (J-170) 03/27/19 MH/JMD - SET UP STOP (0325119) 09/05/17 CF/JMD MILLED CIBP/SETCIBP/SE. 04/10/19 DD/JMD+ ELEVATION CORRECTIONS (04105119) BP Exploration (Alaska) Well Bighole 16.0 H CDR2-AC 4 Ram BOP Schematic Date 21-NOV-17 Quick Test Sub to Otis -1.1 H — — — — — — —'— — —I....... Top of 7" Otis 0.0 ft —._._._._.—._._— ._._.—._. if Distances from top of riser T1 T2 --coR3 Rig's pop Pan Excluding quick -test sub Top of Annular 7 -IMS" Sk Flange X T' Otis Box 6.0 ft 78.8 ft dril 7 1/16" O Top of Annular Element 6.7H Annular Bottom Annular CL Blind/Shears 9.3ft IA CL 2-3/8" Pipe/Slips OA all B2 83 ea Choke Line LDS Kill Line - CL 2-3/8" x 3-1/2" VERS 12.6 ft CL 23/8" Pipe/Slips 13.4 H CL of Top Swab 16.0 H 1 all— Swab Test Pump Hose T1 T2 CL of Flow Cross 17.4 H t� Master 9 CL of Master 78.8 ft LDS O IA OA LDS Ground Level 0 6'{00 TT, 01 ,A,,- „. I � 4 i I I Choke Manifold I L, — —._._._._._._._.i dro®. wM*m �� oa�roo moms ops,rm wcs e.e, fu- tsoume-Water Tank Farm TREE= 4-1M6"CMVFLS VlELL1EAD = WcEVOY' ACTLATOR= CNVSH30W PROPOSED OCB ELEV= 76.98' r :REFELEV= 4 BF. ELEV = 39.75'-20' CONDUCTOR — 110' KOP= 3000'. _ _ _ _. _..... MvcAroe= 95'.§11727 Dahm MD = 10893'' 113-31W CSG, 72#, L-80, D=12347- I !8" X 7" BKR G2 ZXP LTP I -j 8774 11.6 TEBK SLV, D= 6.30" •- 8831 Minimum ID =2.00" @ 10060' 4-112" IBP STOP 1 .0152 bpf, D= 3.958' 7-LNR 26#. L -BO BTC -k .0383 bpf, D = 6.276' — 10234' 13 -IW LNR, 6.6C, L80 TCS .0079 bpf, D - 2.850' I J -17 ESAFETY NOTES: [_�cAROME BG— ItaTIAL, ANGLE, -B"7-&�"C- WELLBORE'S T NOT SHOWN GAS LIFT MANIIRR S ST MD I TVD I DIV I TYPE I VLV I LATCH PORT DATE 4 3235 3227 15 MPG DOME RK 16 02103/19 3 6366 5608 45 AMG SO RK 20 02/03/19 2 8620 7308 37 MNG DMY RK 0 10/10/05 1 9936 8240 41 KBG2 DW BK 0 10/10105 MLLOUf WIDOW (J -17C) 8931'-894T 10068• 4-1rr HES x NP, a = 3.813^ 10027' 7-X4-12'BKR S3 R(R 0=31 10060' 412'I$XNP,D=3.813' 10087- 10076' 7-XS"BKRZ)(P LTPw/IT TIEB, 4-12" HES XN NP, MLL®TO 3. 10083' 1 4-12'WLEG. a=3.958" 70084' i -j7- X5'BKR LNi HGR, ID=4.40' 10091' 5'X4-12' XO, D= 3.858• 10268' 3-12' X 3-3/16' XO, D = 2786' MlOtfiWfDOW (J -17E) -10418 "/16-X 2-I18" Xo. ID = 2.377" PERFORATION SUMMARY RITLOG RIGLE AT TOP PEA F. No%:Rakrb Pmdocbn DBb huh..W ddN 514: SPF WwRw DATE.. 902 0529!18 KP/JMD TREEC/O(0526/18) 1020/89 JLH CTD SIDETRACK (J -17A) 'NORDIC DATE REV BY , COMMENTS DATE ' REV BY COMMENTS 07/16183 AUDI3 OLITIALCOMPLETION 0529!18 KP/JMD TREEC/O(0526/18) 1020/89 JLH CTD SIDETRACK (J -17A) 'NORDIC 02N7l19 JPK/JMD GLV C10 (02x03/19) 81121102 ICTO SIDETRACK (J -17B) 'SIDETRACK(J-17C) 03/19119 JCF/JMD SETBKR BP(03li6t19) 10/71/05 N2ES 03/19119 JMD CORRECTDNTO XO ON WBS 0322113 NORDIC.ICTD SIDETRACK (J -14D) .032 7119 MWJMD _ B SET P STOP (0325/19) 09!05/17 CFlJMD MLLEDCBP/SETCBP/SE' 04110/19 DDIJMD+ ELEVATIONCORRECTIONS(04/05119) PRUDHOE BAY UNIT WELL J -17D PERMIT No: °!130120 API No: 50-029-20969-04 SEC 9, T71 N, R13E, 801' FNL & 1806' FEL SP Explom8on (Ala9ka) I i Choke Manifold I I ._..... TupcPJMP% SLB CT PUS'? 1 � I I �1II 1 111111'llll1111l'III 1 L,_._Coll ed Tubrg ort muupgn .N .mw�.upige. Sundry Application Plug for Re -drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re - drilled. Those wells that are not re -drilled immediately are identified every 6 months and assigned a current status Of "Suspended." 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Kes Geologist in the upper ]eft comer of Form 10-403 is checked. If the "Abandon" or� "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form .10-403 (AOGCCIs and operator's copies). If the "Abandon" No: is checked in Box I S (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial then it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended" box and initial that change. Drilling The drilling engineers will serve as quality control for steps 1 and 2. Engineer (QC) When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tec} for Redrill" box, they will enter the Typ_Work code "IPBRD" into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill" code (IPBRD). If present and there is no evidence that a subsequent re -drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill" comment or code, they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and ane of the Stat Tech Geologists will check the "Well by Type Work Outstanding" user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of sus ended wells for accuracv. EiIt_%.#I.a V " L.# STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS APR 10 2019 1. Operations Performed Size: MD: Abandon ❑ Plug Perforations 0 Fracture Stimulate ❑ Pull Tubing ❑ Operations sAG G Cj Suspend ❑ Perforate ❑ Other Stimulate ❑ Alter Casing ❑ Change Approved Program ❑ Plug for Redrill ❑ Perforate New Pool ❑ Repair Well ❑ Re-enter Susp Well ❑ Other. Set IBP 0 2. Operator Name: BP Exploration (Alaska), Inc 4. Well Class Before Work 31-2678 5. Permit to Drill Number: 213-012 3. Address: P.O. Box 196612 Anchorage, Development 0 Exploratory ❑ 30-8931 30-7551 AK 99519-6612 Stratigraphic ❑ Service ❑ 1 6. API Number: 50-029-20969-04-00 7. Property Designation (Lease Number). ADL 028281 & ADL 028280 8. Well Name and Number: PBU J-1 7D 9. Logs (List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: 10067 - 11735 8325-9032 10160 10530 PRUDHOE BAY, PRUDHOE OIL 3-1/2" x 3-1/4" x 11. Present Well Condition Summary: 10979 - 13485 8918-9016 Total Depth: measured 13498 feet Plugs measured 12393, 12460 feet true vertical 9016 feet Junk measured 12670, 13445 feet Effective Depth: measured 12393 feet Packer measured 10027 feet true vertical 9029 feet Packer true vertical 8299 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Conductor 80 20" x 30" 31983 32-112 32-112 Subsequent to operation: No Test Available Surface 2644 13-3/8" GSTOR ❑ WINJ 31- 2678 31-2678 4930 2670 Intermediate 8901 915/8" Sundry 30-8931 30-7551 6870 4760 Liner 1460 7" Authorized Name: Wellman, Julie 8774-10234 7429-8435 7240 5410 Liner 1668 4-1/2" JulasWellman0bp.00m 10067 - 11735 8325-9032 10160 10530 Liner 2506 3-1/2" x 3-1/4" x 2-7/8" 10979 - 13485 8918-9016 Perforation Depth: Measured depth: 11880 - 13380 feet True vertical depth: 9036-9020 feet Tubing (size, grade, measured and true vertical depth) 4-1/2" 12.6# 13Cr80 28-10063 28-8336 Packers and SSSV (type, measured and 4-1/2" Baker S-3 Perm Packer 10027 8299 true vertical depth) No SSSV Installed 12. Stimulation or cement squeeze summary Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Tubing Pressure 996 240 14. Attachments (.quied par 20 MC 25070,25,071, & 25.283) Oil -Bbl Gas-Mcf Water -Bbl Casing Pressure Prior to well operation: 353 Service 31983 58 0 Subsequent to operation: No Test Available Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ 0 Tubing Pressure 996 240 14. Attachments (.quied par 20 MC 25070,25,071, & 25.283) 15. Well Class after work: Daily Report of Well Operations 0 Exploratory ❑ Development 0 Service ❑ Streligraphic ❑ Copies of Logs and Surveys Run ❑ 16. Well Status after work: Oil 0 Gas ❑ WDSPL ❑ Printed and Electronic Fracture Stimulation Data ❑ 1 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG ❑ 17. I herebycert) that the foregoing certify regoing is true and coned to the best of my knowledge - Sundry Number or N/A if C.O. Exempt: N/A Authorized Name: Wellman, Julie Contact Name: Wellman, Julie Authorized Title: P duction Engineer Contact Email: JulasWellman0bp.00m Authorized Signature: Jf ILI - Date: q/q /I q Contact Phone: +1 9075644657 Form 10404 Revised 04/2017 v rvtCsAr tc.nrx, T4 V,fflDMS LW APR 1 1 2019 Submit Original Only Daily Report of Well Operations PBU J -17D ACTIVITYDATF SHMMARY CTU #9 - 1.75" Coil Job Objective: Set IBP MIRU CTU. Complete weekly BOP test. Make up 2.2" GR/CCL carrier with 2.25" JSN and RIH. Spear with 60/40 and L&K well with slick 1%KCL w/safelube while RIH with logging tools. 3/15/2019 ...Job In Progress... CTU #9 - 1.75" Coil Job Objective: Set IBP RIH w/ 2.25" drift/ HES memory GR/CCL to WFD ext range cibp at 12460'. Confirm +5.5' correction. Make up Baker 1/8" IBP, RIH. Tie in at flag and set IBP at 12400' ME (top of IBP 12393"'1 3/8" 3/16/2019 JDC FN). POOH. RDMO CTU. ***WELL S/I ON ARRIVAL*** (Profile Modification) RAN 3.80" GAUGE RING, 4-1/2" BRUSH TO 10,070' SLM. ATTEMPTED TO SET IBP STOP, UNABLE TO MAKE DEPTH. (tools covered in metal shavings/dust) PERFORMED BRUSH AND FLUSH W/ 3.50" GAUGE RING, 4-1/2" BRUSH TO 10,070' SLM. LRS PUMPED A TOTAL OF 150bbis CRUDE DOWN TBG. ATTEMPTED TO SET IBP STOP, UNABLE TO MAKE DEPTH. (Left in st# 1 @ 9,936' md) RIH TO RETRIEVE IBP STOP. 3/24/2019 ***WSR CONTINUED ON 3/25/19*** ***WSR CONTINUED FROM 3/24/19*** (Profile Modification) RAN 3.80" G -RING, 4-1/2" BRUSH TO 10,070 SLM. SET 4-1/2" IBP STOP IN X -NIP 0 10.050' MD. RAN CHECK SET TO IBP STOP @ 10,050' MD. 3/25/2019 ***JOB COMPLETED, WELL LEFT S/1*** TREE= 4-1/16"CNV FIS WB-LHEAD= McEVOY ACTUATOR= CNV SH 3000 INITIAL KB. ELE 7T BF. ELEV = 39.76 KOP= 3000' Max Angle = 95" @ 11727' Datum MD = 10893' Datum ND= Saw SS J-17 D SAFETY CHROMETOBG ""'VINITIAL, "A , ELL "W 78@ 11WELLBORE'S NOT SHOWN"' CONDUCTOR 110' I 2218' 4-11/2" FES X NP, D = 3.813" I9 -518"X7" BKR C-2 ZXP LTP w / 11.6' TE BK SLV, D = 6.30" D=6.32- 8791' (09/2705) 8952' n=AAAl- 2021 Minimum ID = 2.00" @ 10050' 4-112" IBP STOP GAS LIFT MANDRELS ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3235 3227 15 MMG DOME RK 16 02/03/19 3 6368 5608 45 MMG SO RK 20 02/03/19 2 8620 7308 37 MMG DMY RK 0 10/10/05 1 9936 8240 41 KBG2 DW BK 0 10/10/05 MLLOUT WINDOW (J -17C) 8931'-8947- X 4-1/2" BKR S-3 RSR D = 3.875- 1/2' .875"1/2" HES X NP. D = 3.813' 10067' -j7"X5"BKRZXPLTPw/11'TE3, 4-1/2" TBG, 12.6#, 13CR•80 VAM TOP, 10083' 10070'-]-14-112" HES XN NIP, MILLED TO 3. .0152 bpf, D = 3.958" 10083' 4-1/2" WLEG, D = 3.958" 10084' 7" X 5" BKR LNR HGR, D = 4.40" 1nn91'5" X 4-119" Xn 7" LNR, 26#, L-80 BTG -M, .0383 bpf, D = 6.276' — 10234' (3-12" LNR 9.3#, L-80 STL, .0087 bpf, D = 2.992" - 11382' 4-1/2" LNR 12.6#, L-80 BT -M, .0152 bpf, D = 3.958" - -11735' 4-1/2" BKR WHIPSTOCK (03/13/13) - 11735' PERFORATION SUNTMRY RTF LOG: SLB MCN/ GW OCL ON 03/22/13 ANGLE AT TOP PERF: 93" @ 11999 Note: Refer to Production DB for historical pert data SIZE SPF INTERVAL OpNSgz DATE SOZ 104 —j4-1/2- MARKER JOINT, D=4.00" 10971' 4-1/2" KB LTP, D = 2.37" (04/03113) 10979' 3.70 DEPLOYMENT SLV, D = 3.00" 11001' 11382' -3-1/2"HESXNIP,D=2.813" - 3-1/2" X 3-3/16" XO, D = 2.786" MLLOUT WINDOW (J -'17D) 11736-11743- 2" 1735'-11743' 2" 6 11990 - 12020 O 06/16/14 05/29/18 2" 6 12070-12100 O 06/16/14 GLV C10 (02(03/19) 2" 6 12190-12220 O 11/02/13 12393' !-2-1/8'BKRBP(03/16/19), 2" 6 12220 - 12250 O 11/01/13 12460' CMD WFD 2.28" EXT RANGE CBP (08/31/17) 2" 6 12640 - 12670 C 11/01/13 2" 6 12800-12830 C .10/31/13 12670'CMD MILLED WFD 2.187" EXT RANGE CBP(I 2" 6 12930-12960 C 10/31/13 2" 6 13180-13380 C 03121/13 13-1/4" LNR. 6.6#. L-80 TCII..0079 bnf. D = 2.850" I D--2.441" 13082' - 3-3/16" X 2-7/8" XO, D = 2.377" 13445' FBH CBP MLLED(06/15/14) DATE REV BY COKS13M DATE REV BY COMMENTS 07/18183 AUD13 IMTIALCOMPLETION 05/29/18 KP/Jw TREE CIO (05/26/18) 10/26/99 JLH CTD SIDETRACK (J -17A) 02/07/19 JPK/JND GLV C10 (02(03/19) 01/21/02 NORDIC I CTD SIDETRACK (J -17B) 03/19/19 JCF/JIVD SEr BKRBP(03/16/19) 10/11/05 N2ES SIDETRACK (J -17C) 03/19/19 JND CORRECTION TO XO ON WBS 0312213 NORDIC I CTD SIDETRACK (J -17D) 03127/19 M1JM) SET BP STOP (03/25119) 09/05/17 CF/JM) MLL87CBF1'SETCBRSEr FBH 12-7/8- X 2-3/8" XO PN, D= 1.992' 1 PRUDFDE BAY UNIT WELL: J -17D PERMIT No: 1130120 AR No: 50-029-20969-04 SEC 9, T11 N. R1 3F 801' FPL 8 1806' FEL BP Exploration (Alaska) BAN(ER PRINT DISTRIBUTION LIST h� UGHES a GE company COMPANY BP Exploration Alaska Inc. WELL NAME J -17D FIELD Prudhoe Bay Unit CD/DVD COUNTY PRUDHOE BAY PRELIM BHI DISTRICT Alaska SURVEY I AUTHORIZED BY Paul Canizares EMAIL Paul.Canizares@bhge.com 2130 ,2 30 42 1 Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 or AKGDMINTERNAL@bp.com to acknowledge receipt of this data. LOG TYPE RPM:PNC3D LOG DATE December 29. 2019 TODAYS DATE February 28, 2019 Revision STATUS Final Replacement: No Details: Rev. Requested by: --- COMPANY ADDRESS (FEDEX WILL NDT DELIVER TO P.O. BOX) PERSON ATTENTION V 1 BP North Slope. --- — EOA, PBOC, PRB-20 (OtOce 109) D&C Wells Project Aides Attn: Benda Glassmaker & Peggy O'Neil 900 E. Benson Blvd. Anchorage, Alaska 99508 2 ConocoPhillips Alaska Inc. Atm: Ricky Elgarico ATO 3-344 700 G Street Anchorage, AK 99501 3 Lynda M. Yaskell and/or Lisa Boggs C Street, Suite 505 orage, AK 99503 e of Alaska - AOGCC c Makana Bender W. 7th Ave, Suite 100 horage, Alaska 99501 5 DNR - Division ofOil & Gas *** Attn: Garret Brown 550 West 7th Avenue, Suite 1100 Anchorage, Alaska 99501 ** Stamp "confidential" on all material deliver to DNR BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 K Benson Blvd. Anchorage, Alaska 99508 Attn: Gerardo Cedillo FIELD I FINAL CD/DVD FINAL PRELIM LOGS (las, dlis, PDF, META, SURVEY I REPORT LOGS CGM, Final Surveys) (Compass) # OF PRiN Ur rMov # OF COPIES J#OFCOPIES # OF COPIES is V MAR 0 12019 i COGCC 111 TOTALS FORTHISPAGE: 0 1 4 0 0 RECEIVED STATE OF ASKA 0 •ALASKA OIL AND GAS CONSERVAT ON COMMISSION OCT 0 't 2017 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed �1j0 , { ,ru Abandon 0 Plug Perforations Il Fracture Stimulate 0 Pull Tubing 0 Operations hutd n �� 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other:Mill Plug /pet C/,9P Elf 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 213-012 3. Address: P.O.Box 196612 Anchorage, Development m Exploratory ❑ AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20969-04-00 7. Property Designation(Lease Number): ADL 0028281 8. Well Name and Number PBU J-17D 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth: measured 13498 feet Plugs measured 12460 feet true vertical 9016 feet Junk measured 12670/13445 feet Effective Depth: measured 12460 feet Packer measured 10029 feet true vertical 9027 feet Packer true vertical 8301 feet Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 32-112 32-112 Surface 2644 13-3/8"72#L-80 31-2675 31-2675 4930 2670 Intermediate 8903 9-5/8"47#L-80 30-8933 30-7553 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11990-12020 feet 12070-12100 feet 12190-12220 feet 12220-12250 feet 12640-12670 feet 12800-12830 feet 12930-12960 feet 13180-13380 feet True vertical depth: 9036-9034 feet feet 9034-9033 feet 9034-9034 feet 9034-9033 feet 9024-9023 feet 9020-9020 feet 9022-9022 feet 9017-9020 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 28-10085 28-8337 Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: g- NOV0 S 2017 SCANNC° IV V 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 648 29928 82 180 1066 Subsequent to operation: 493 7739 260 1440 188 14.Attachments:(required per 20 AAC 25.070.25.071,8 25.283) 15.Well Class after work: Daily Report of Well Operations H Exploratory 0 Development Q Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil Q Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ 0 SUSP 0 SPLUG 0 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Authorized Name: Shriver,Tyson Contact Name: Shriver,Tyson Authorized Title: Well Intervention Engineer Contact Email: Tyson.Shriver@bp.com _______ __JiAuthorized Signature: Date:/Q/3/40'7 Contact Phone: +1 9075644133 Form 10-404 Revised 04/2017 r 7- 1 0 /6 / I 9-itio *p p DAAi+ 1-L- pri - 5 2017 Submit Original Only • • Alaska Oil and Gas Conservation Commission 333 West Seventh Avenue Anchorage, AK 99501-3572 RE: BP Exploration (Alaska), Inc. Report of Sundry Well Operations Summary September 28, 2017 To Whom it May Concern: Attached please find the Report of Sundry Well Operations for Milling of a Cast-Iron Bridge Plug and Setting of a New Cast-Iron Bridge Plug for Well J-17D, PTD # 213-012. Sincerely, BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Attachment: Form 10-404 BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 • • ro N Q, 00 _00 O O Ln O - O N M Ln co ' ,NL C N LO CO O v r- U M cc .Nr 000 O N O M Lo M CO N LO CO CO N LO CO M N CO CO Lf) 't O O O O M N N- 00 O) C) O) O) 00 I-- O I,- 00 LO CO N O M N N Cr) MMMM7MO) OON I"- 000 O) O) Ln M CO Ln () N N LO L N O •- M M CCO O V i . . i I I I i CD CO O) N N M M CO O O) M M co CO N.-- e- 13 • W CL � O 0900000 C) J � Fo) • CU co N *k J �# *k *kv. i# • N X V *k r O•) CO CO LO e= N co O v' M M N - •:1- CO O I"- co Ca O O CO 0 M O M LCA co CO 000 r O J W =° w � ' U III U O u_ ce Q O D c D Z Z W W W W W W m QDZZZZZD 0cnZJJJJJI— • • Packers and SSV's Attachment PBU J-17D SW Name Type MD TVD Depscription J-17D PACKER 8787.1 7439.33 7" Baker ZXP Top Packer J-17D TBG PACKER 10028.52 8300.67 4-1/2" Baker S-3 Perm Packer J-17D PACKER 10079.88 8334.23 5" Baker ZXP Top Packer • 0 t = co q = t \ d % 22 § -0 ° $ $ - o 0 as b » 77/ 7k / O ƒ % 0_2co80_ 62 — o = mac Cu c c % E 2 @ e o o 3 ka)kkk / / E5 —IE2 £./ 2 \ do . -aN eLo_ 2e _0 / a) R E -02k � � k 2 � 2 co E b ' / k = e � oom@ co >- � � Ek / mak � c0) tal r: t. o 0 t- m __ .§ m a. 2 > = o (N � o - k E E @ I 0 3 - O n 2 t $ m > 0. _ § - a& _ 7a) \ m5 u) w 0 ® /co(NJ In 1 U / R m ƒ \ a) ,t- m � / 1— o o/ G Oc 3 & � oOx . a c � _ \ 0) 0-2 E n o CO § E & k CO k / tb OmE $ . - E 0- 0 a. � d � k � / - � c / k & 7 ƒ Ti/ k 7 \ a) eee = � � » CamP �R / / D - \_ / k k / / k § ai / - a = � � C kk / co / / k - 0k - Cu \ E co = e m m = » o % m o / . mnf0 Q k — § 0- c ¥ 5 » t z 7 \ a - t cc = E a . Q w t- a- c I ■ Q I ° a) co 2 U $ / c arc f ° 0 = 2 o M m 2 2 03 f \ § 7 2 k 2 % 2 / 0kIEJf a0/ O -,Oo to / L I— < 2 \ I- <V / co 2 Q co Lc) co \ co $ 4 •TREE= 4-1/16"CNV FLS SA NOTES; L ANGLE>°70 11140''"4-1/2" WELLHEAD= McEVOY J 17 D Wa. CHROME TBG""" IIOTIAL,"A","8",&"C"VVEt_LBORES ACTUATOR= BAKER INITIAL KB.ELE 77' �,1 ' NOT SHOWN*** 33 20"CON�TOR H 110'000' , , 2218' --{4-1/2"FES X MF D=3.813" KOP=Max Angle= 95" c@ 11727' Datum MD= 10893' ll 2584' -19-5/8"DV Rat Datum TVD= 8800'SS GAS LFT MANDRELS 13-3/8'CSG,72#,L-80,D=12.347' -I 2685' ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3235 3227 15 MNG DONE RK 16 04/02/13 9-5/8"X 7"BKR C-2 ZXP LIP -1 8774' 3 6368 5608 45 MNG SO RK 20 04/02/13 w 111.6'TRK SLV,D=6.30' ` 2 8620 7308 37 MNG 0M' FE 0 10/10/05 _4 HM1 9936 8240 41 KBG2 DMY BK 0 10/10/05 9-5/8"X 7"BKR C LNR HGR,D=6.32" -1 8791" / WHPSTOCK(09/2705) -1 8952' A • rie ME.LOUT 1MVDOW(J-17C) 8931'-8947' 9-5/8"(=SG,47#,L-80,0=8.681' -8931 c 2` i` rZ Minimum ID =2.37" @ 10971' I I 10006' H4-1/2"FES X NP,D=3.813" 4-1/2" KB LINER TOP PACKER 2.--1 10027' H7"X4-1/2'BKR S-3PKR,0=3.875" I , 10060' —14-1/2"FES X NP,D=3.813" 10067' -f 7'X 5"BKR ZXP LTPw/11'TEBACK,13=4.40" 4-1/2"TBG,12.6#,13CRt 80 VAM TOP, --1 10083' 10070' -14-1/2"FES XN NP,AAL!®TO 3.80"(03/05/13) .0152 bpf,D=3.958" r 10083' -I4-1/2"WLEG, D=3.958" 10084' -17"X 5"BKR LM HGR D=4.40" 10091' —15"X 4-1/2"XO, 0=3.958" r LNR 26#,L-80 BTC-M,.0383 bpf,D=6.276" —1 10234' • �l I. J 10417' —14-1/2"MB2 ARKJOWL D=4.00" 4-1/2'LW,12.6#,L-80 BT-M,.0152 bpf,D=3.958" —11735' � 10971' —I4-1/2"KB LIP,D=2.37"(04/03/13) 10979' --13.70 DEPLOYMENT SLV,D=3.00" 4-1/2"BKR WHPSTOCK(03/13/13) -1 11736' 3-1/2'LNR,9.3#,L-80 STL,.0087 bpf,D=2.992" —1 11382' a 11001' —I3-1/2"FES X NP,D=2.813" FM:ORATION� � WINDOWMMA & LOUT WDOW(J-17D)11735'-11743' FIEF LOG:SLB MCNU GR/OCL ON 03/22/13 ANGLE AT TOP F RF:93"@11990' Note:Refer to Production DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE SQZ 2" 6 11990-12020 0 06/16/14 11382' H3-1/7 X 3-3/16-XO,D=2.786" 2" 6 12070-12100 0 06/16/14 I 2" 6 12190-12220 0 11/02/13 2" 6 12220-12250 0 11/01/13 I _ 112460'CMD -MVFD 2.28"EXT RANGE CEP(08/31/17) 2" 6 12640-12670 C 11/01/13 2" 6 12800-12830 C 10/31/13 of I 12670'CMD H ML.LED WFD 2.187'EXT RANGE CEP(8/30117) 2' 6 12930-12960 C 10/31/13 2" 6 13180-13380 C 03/21/13 I 13082' --I 3-3/16"X 2-7/8"XO,D=2.377" 3-1/4"LNR 6.6#,L-80 TCA.0079 bpf,D=2.850" H 13082' I 13445' -1FIS t CN3P PALLED(06/15/14) PBTD - 13439' 13480' -12-7/8"X 2-3/8"XO PN,D=1.992" 2-7/8'LNR,6.4#,L-80 STI,.0058 bpf,D=2.441" -1 13485' -,t DATE REV BY COMFITS DATE REV BY CONVENTS I PRl1DFIDE BAY INT 07/18/83 AUDI 3 INITIAL COMPLETION 11/06/13 ALMJAiD SET WFD/ADPERFS(10/30-11/02/13) WELL: J-17D 10/26/99 JLH CTD SIDETRACK(J-17A) 06/18/14 RMWJAC1 MLUSET CBPADPERFS(6/15-16/14) P6EJIr No:"2130120 01/21/02 NORDIC 1 CTD SIDETRACK(J-178) 06/23/17 ZV/JM) SET PX PLUG(06/13/17) AR No: 50-029-20969-04 10/11/05 ICES SIDETRACK(J-17C) 07/25/17 RCB/JMD PULLED PX PLUG(07/21/17) SEC 9,T11N,R13E,801'FTE.&1806'FEL 03/22/13 NORDIC 1 CTD SIDETRACK(J-17D) 09/05/17 CF/JM) PALLED CBPISET CBR'SET FISH 11/06/13 DU/JMD TREE C/0(10/19/13) BP Exploration(Alaska) 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. j 3 - 01Q Well History File Identifier Organizing (done) ❑ Two-sided 1 ❑ Rescan Needed I 111111 1 111111 RE CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ❑ Diskettes, No. ❑ Maps: rreyscale Items: ❑ Other, No/Type: ❑ Other Items Scannable by {� a Large Scanner ❑ Poor Quality Originals: OVERSIZED (Non-Scannable) ❑ Other: ❑ Logs of various kinds: NOTES: ❑ Other:: 0 BY: Date: I /s/ I Pro"ect Proofing I 111111111II 11 111 g BY: aria Date: a topti. /s/ 1YLO Scanning Preparation x 30 = bo + .2 7 = TOTAL PAGES '13 (Count does not include cover sheet) BY: �- Date: a �� ` /s/ pi � Production Scannin g II 1 11111 Stage 1 Page Count from Scanned File: (g S (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: elk Date: ca/ `�Oti ` (fl4f Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II 1111111111111111 ReScanned I 1 1111111111 11111 BY: Maria Date: /s/ Comments about this file: Quality Checked 11111111111111111 O M Q Q 0) 0I o 01 N co o r. W m W w W O 0 y 2 Z C J W I I I 0 0 °3 E _1 _1 N 0 y . 0 W Z < a a 0 ¢ 9 j /ll m c (O O W W o 7 a O m a d I I -3 °- b N 0 5 vi - 0 0 I- 0 ) I- as C a) N Z _ d 0 �I �I Z LL ,, Z E- Z DUI M M 0 O 0 CT. CO `m L9 N c0 0 0 } O 0 } N J Q c i - il..co Q' Ce m W N m O LL Q Q 0 D °- n J ° ... I 2 0 N' N. O U W E0 8 co RI _rn _) 2 2 C U J p ' 0 c0a a - 0 ai0 ii u) 0 0 a� D Z 0 E p� Ur` �DIO UPI it(2 d� U cWi d� c 2 w E EZ + •c m 'E CC E EM NW c E NW E to f6 °) 0 0 1_ --� o f l o p 0) o p a 0 0 ° 0 E U'2 Z z IM u 1 I o< o °Q o I0z U NN.`-' N0= Nom= M W a) a) M W U Ce Q i t ■ EO 2I— 2 W N. W �m W�m N2 W W N2 O^ Q O c -0 co M co M co co M co co M co M Q.r+ d CL U Y > 0 co O O O O O E N E .N- •� N N N N N N N ld 7 WN y co N r r CO (O Cl) Z Ce OJ V (O (O CO to a X II - c c U W J Mm n m > 0 000 0 co Z 0 a) CL 0) 0) co 0 w N I O M M V 0 O Q N to 3 f6 in M r a J 0 w° m Om o* , Z1 � ` t'. . ° 0 0• 0 oc CO co rn rn o O N °_ti N a C) =' U I E 1 o N w CO � C - J a ce z°' r J 0.• S= z 20 J2 U — Cl)s Q N I N W CO co II /0 J y 1 N C r 0 N CO 2 O 0 / uj N Q a o 1.0 CC 1 N OI re Q ° E /Z I' �0 Z ° QE 0 J a c C al Co (I) Z 7 _ 2 Co co CO N Co CO N N a) m i c E l c CO 0 Co crii Co 0 ru c / 0 I o O o m m m I a :° 2 w 7 j •� a p) •a as O) la Z Z 0 0 0 J 0 0 J E a o 0 z C)o .+ N O W N O ` Y N O0 o V rV1• V V' CEO ((0 CO C NI- N j 0 0 r W O Z (0,1 N N IN IN N N N CO N d 0 0 1 Q .- Co a+ a N d' 3: co t o 2 c°i •E Co E Co E 0 m m ? cC y w a1 LL '° N Z P ° /� D O v O y a aNi Q U C re Z W O 0 0 0 0 0 0 o rG L) j a 0 -1 U 0 0 '' O ° - — 1 et o M O I O iZ >- > >- l N w on N O Ito fn o H Z L L o I a 0 O as Q N 2 2 I �J 0 0 J 0 p QZ /Z i llw Z a '' I • N ��} } > a I— g " l o cc < a o = O Z 0 0 rn m w a; Ce o J a) o. it E II a)w X W Cl) ui , Ca) J CI) m o E 3 E Z • Q r 0 0 0) o --I Q C I J d E -- ; O Om U U ;' M c N N a O N U /Z c w 00 a) o J > } >- 1 E N OA Q ° /' U a F-- `° E ~ Z _ M O N 0 ` Z co I W m M o 1- E w 7 0 a> c r i. Cl) � rq o< = Ce C H o ao N a o o co 0 -` Q0 Z o ° T E v o g U i ri A 1 MI z M M a) 1 l N N `�� O Z N s a) N N>- >- >- M I N ° J >• m al ce N � � N II. 91 a) N Y W f0 I' Q' rn c Fo) t6 U ° C A C = Z C o 0 t 0 0 o Q o ° :+ D c U a o a a m o E a 8 E E o o E a� E E Zr) 2 0 d C9 ca 1 0 0 C ' U U RECEIVED STATE OF ALASKA C AL,,oKA OIL AND GAS CONSERVATION COMMI__.ON DEC 0 5 2013 REPORT OF SUNDRY WELL OPERATIONS AOGCC 1.Operations Abandon ❑ Repair Well❑ Plug Perforations U Perforate U _ Other❑ Performed: Alter Casing ❑ Pull Tubing❑ Stimulate-Frac ❑ Waiver ❑ Time Extension❑ !, Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other ❑ Re-enter Suspended Well❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development El Exploratory ❑ 213-012-0 ' 3.Address: P.O.Box 196612 Stratigraphk❑ Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-20969-04-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028281I AOl-pO2462`16 PBU J-17D • 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): PRUDHOE BAY,PRUDHOE OIL• 11.Present Well Condition Summary: Total Depth measured 13498 feet Plugs measured 13139 feet true vertical 9015.96 feet Junk measured None feet Effective Depth measured 13139 feet Packer measured See Attachment feet true vertical 9016.83 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 88 20"x 30" 28-116 28-116 0 0 Surface 2646 13-3/8"72#L-80 32-2678 32-2677.9 4930 2670 Intermediate None None None None None None Production 8903 9-5/8"47#L-80 28-8931 28-7551.16 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12190-12220 feet 12220-12250 feet 12640-12670 feet 12800-12830 feet 12930-12960 feet 13180-13380 feet True Vertical depth 9033.67-9033.91 feet 9033.91-9032.82 feet 9024.15-9022.54 feet 9019.61-9020.28 feet 9021.95-9021.87 feet 9017.36-9019.62 feet Tubing(size,grade,measured and true vertical depth) 4-1/2"12.6#13Cr80 24-10083 24-8336.27 Packers and SSSV(type,measured and true vertical depth) See Attachment See Attachment See Attachment Packer None None None SSSV 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 33 16542 78 0 1056 Subsequent to operation: 1195 14300 187 0 238 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run ExploratorA❑ Development El ' Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil 0• Gas ❑ WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUG❑ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email Gar .Catron • BP.Com Printed Name Garry Catron Title PDC PE Signature ,g(l .Lt� , Phone 564-4424 Date 12/4/2013 'ilP7.,;‘,U,' DEC 1 3 era � Form 10-404 Revised 10/2012 / 1/4r* Submit Original Only I'I I- a) U as a O Y Y �a a , a d M oau) a 1 C13 a) m a) Y _ Y CU as— CO N CO LO ch E G CCOO CO M M CO C N ONO 00 N co O co 'C a as N 00 O O 0 cc a aYYY 1-000 aaa m E 0 0 0 as N.. 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E -a � a) o -0 I L 0 D _ o OV C 0 c0 C o N Cn 0 c 73 cO C) N 0 0 1° U Q= a ID= . `_flN aY EEti 'u) = ti E 00 3 � aU oo •� a) u_ cv CD 0 � Q az0 0 o t ° i ; b 0 - - 0 - C) Q' ° 4- Y N- 0 ce C O O M Q Q O N N .- 2 ° )N d U V N C N a_ IZ a) O 2' C N a U) N a O C 0_ O O - d � U cm-0 Q - O E CO 0 CO N o - �m o o - o 3 o 0 o N U o U 0 3 w Lo O M O U C a) O to O co O C 2 9 ✓ )J in ° 2 E ID a °' : _ E E a ,T) 13 Q� 2--° CO ao (O 2 Y � a � °O � 0) - Lc) m Q ° = mM 5 N � Clm � � � U _ - c E U a) 0O IT; N 0 = ate) a) Od 00 ° a) * ° _ m a) ° Cl) U) C Q a) M L U L 4-- Cl) C o ° N >, U .•C m CO - E L [l d 0_73 ° ` = d Cn a a) Q O_ m J um_ m _� U a) m ° E a°)) .u ^ a0^ +� L Q Q O 0) L 0 O .- C L y LL — TI- L LL }; LL L 0 70 Q- O N LO U CD 0)Y U (0 O U “ m - C CL C U 0 O 0 QII rn f° o o a) O r -aY 0_(I) CI0= a) O0 ° mpY Eo 0 a_ N +, Q 0- U) C U) E a 0 ' Q N m E N co C (6 L a) N a) co Uc °0 3o = C - m 3a) C° °) ° o N U .O d U') 0) C , O co d E :C 3 N U CV o �a- .L a) O 0 0 O U �T rn p i Q-o Q .7. 4- y U) D 2 2 Oa . . O -0 m • . 0 ECmv . . c , - ° o . v pp M ° N a) p a U co fl a U ° -0 - o a) E O < L � ° u) ~ • Na0 ° E 0 * o � -,--, EOU o Oa• O. N.c `- r�i o �-0 c i� o0 -nrX C °- ' � v= inE -0 U> 0 M U Q 67 U) U) M p N (6 M a O U co (U Q O ›+ II CN co U) a) II - U ,- 0 O H M - + II �'- co CIS (Ni C L OM V N �' t) CD O O 0 a) Up .1 E E Uo a o = -0 UaZNCO - OU � YU � ?,''' @ co .- 2_ � oN IZ f H pN N = aH .- a 0 Ua _ 'c co� rn H � M ' µ= p _ - rnC oc0 Ec Ern o § u) 0 Eo () Uao0 E a) N to 2 C N S N ° E . co N- 3 0 C 0 N 1,... m N 10 to c- H c O U .� u) co N C O U/) O a) U U •- D a.) ° a) M0 E o � a � C o � (Ow -- co E L, Eo .Eca� m Q t I O o_M D C _ `C N r Q C _ C 0 N Q C -o J E H Q E 0 a) O C O H ° Q Q a) C I- 0 -, "60 -'5N1- O 02 0 U) -ON -0 = 00 WO- CL ° � ° 002l0 00 CO o co M co co O O O O (NI N N N C) r c- N CO CO -c- O . TREE= 4-1/16"CM/FLS WEiLHEAD= McEVOY J -17D A CI-ROM NTIAL,"�A""E"B", &@"C1 _WELLBORE'S ACTUATOR= BAKER NOT SHOWN"' NTIAL KB. ELE 77' ',I i BF.ELEV= 39.78' 20"CONDUCTOR J-1 110' 2218' -{4-1/2"FES X NP,D=3.813" KOP= 3000' Max Angle= 95°@ 11727' Datum MD= 10893' ■ V 2584' H9-5/8"DV PKR Datum TVD= 8800'SS GAS LIFT MANDRELS 13-3/8"CSG,72#,L-80,D=12.347" H 2685' ST MD TVD DEV TY FE VLV LATCH PORT DATE 4 3235 3227 15 MMG DOME RK 16 04/02/13 9-5/8"X 7"BKR C-2 ZXP LTP -r 8774' 3 6368 5608 45 MMG SO RK 20 04/02/13 w!11.6'TEBK SLV,D=6.30"_ L 2 8620 7308 37 MMG DMY RK 0 10/10/05 CO 1 9936 8240 41 KBG2 DMY BK 0 10/10/05 [9-5/8'X 7"BKR HMC LNR HGR,D=6.32" ]- 8791' i 'WHIPSTOCK(09/2705)] 8952' .+ MILOUT WINDOW(J-17C) 8931'-8947' 9-5/8"CSG,47#,L-80,ID=8.681"J- - 8931 Minimum ID = 2.37" @ 10971' 10006' --14-1/2"HES X NP,D=3.813" 4-1/2" KB LINER TOP PACKER 0_1 = 10027' ---{7"X 4-1/2"BKR S-3 PKR,D=3.875" 10050' H4-1/2"FES X NP,ID=3.813" 1 , C 10067' -17"X 5"BKR ZXP LTP w/11'TRACK,D=4.40"1 4-1/2"TBG,12.6#,13CR-80 VAM TOP, - 10083' I,: 10070' -14-1/2"FES XN NP,MLLE)TO 3.80"(03/05/13) .0152 bpf,0=3.958" I I 10083' -14-1/2"VVLEG, D=3.958" 10084' -1 7"X 5"BKR LNR HGR D=4.40" 10091' H5"[7"LNR 26#,L-80 BTC-M,.0383 bpf,D=6.276" [-I 10234' L. X 4-1/2"XO, D=3.958' 1 —_-- , 10417' H 4-1/2"MARKER JOINT,D=4.00" 1 14-1/2"LNR, 12.6#,L-80 13T-M,.0152 bpf,D=3.958" H -11735' ili 10971' H4-112"KB LTP,D=2.37"(04/03/13) 10979' H 3.70 DEPLOYMENT SLV,D=3.00" 4-1/2"BKR WHPSTOCK(03/13/13) - 11735' 3-1/2"LNR 9.3#,L-80 STL,.0087 bpf,ID=2.99 " -{ 11382' \II i I 1 11001' -13-1/2"H E S X NP,D=2.813" PERFORATION SUMMARY MLLOUT WINDOW(J-170) 11735'-11743' F�LOG SLB MCNJ GR/CCL ON 0:3/22/13 ANGLE AT TOP FERE 89°@ 12190' Note:Refer to Roduction DB for historical perf data SIZE SFE INTERVAL Opn/Sqz DATE SOZ 11382' H3-1/2"X 3-3/16"XO,D=2.786" 2" 6 12190- 12220 0 11/02/13 I 2" 6 12220- 12250 0 11/01/13 2" 6 12640- 12670 0 11/01/13 I 2" 6 12800- 12830 0 10/31/13 2" 6 12930- 12960 0 10/31/13 2" 6 13180- 13380 C 03/21/13 13082' -3-3/16"X 2-7/8"XO,D=2.377" 1313W H2-7/8"WFD CEP(10/30/13) 3-1/4"LNR,6.6#,L-80 TCI, .0079 bpf,ID=2.850" -1 13082' /'''''I PBTO -1 13439' 2-7/8"LNR,6.4#,L-80 STL,.0058 bpf,D=2.441" - 13485' 13480' 2-7/8"X 2-3/8"XO PIN,D=1.992' nlit DATE REV BY COMMENTS DATE REV BY COMMENTS F1RUDHOE BAY IUT 07/18/83 AUDI 3 INTIAL COMPLETION 04/15/13 TW PJC FINAL APPROVAL ODE WELL J-17D 10/26/99 JLH CTD SIDETRACK(J-17A) 11/06/13 DU/JMD TREE CJO(10/19/13) PERMT No: 2130120 01/21/02 NORDIC 1 CTD SIDETRACK(J-17B) 11/06/13 ALICMD SET WFLYADPERFS(10/30-11/02/13 AR No: 50-029-20969-04 10/11/05 N2ES SIDETRACK(J-17C) SEC 9,T11N,R13E,801'FNL&1806'FEL 03/22/13 NORDIC 1 CTD SIDETRACK(J-17D) 04/08/13 JNJJMD REVISED LNR TD BP Exploration(Alaska) McMains, Stephen E (DOA) From: Lastufka, Joseph N <Joseph.Lastufka @bp.com> Sent: Tuesday, August 27, 2013 10:53 AM To: McMains, Stephen E (DOA) �� Q (2_Subject: RE: PBU Missing Well Data Steve, For 07-29E and J-17D,you have both the MD and TVDSS presentation in one log print. If you open the log print, you will see a TVDSS profile (right side) and the directional survey(bottom). These are horizontal wells and TVDSS plotting is not possible,thus why the TVDSS profile is combined with the MD depth track described above. Please let me know if you have any additional questions. From: McMains, Stephen E (DOA) [mailto:steve.mcmains(aalaska.gov] Sent: Tuesday, August 27, 2013 10:21 AM To: Lastufka, Joseph N Subject: PBU Missing Well Data Joe, Here is a complete list of well and log missing that I called you about the last few days. PTD: 213-001, PBU 07-29E Missing log GR/RES TVD. PTD: 213-012, PBU J-17D Missing log GR/RES TVD. PTD: 213-067, PBU Y-33A Missing log GR/CCL/MCNL. PTD: 212-026, PBU B-20A Missing log CCL/MCNL. Steve 793-1233 1 Mil BAKER PRINT DISTRIBUTION LIST:N 11;::()::';6•C z6 t; HUGHES AOGCC COMPANY BP Exploration(Alaska)Inc. INTERMEDIATE FINAL Yes (mandatory) 2 `/sv )� WELL NAME 4'.3 - 1—TD RUN NUMBER lJ (mandatory) 2 FIELD Prudhoe Bay BH SALESMAN Okechukwu(Okey)Anyanwu (mandatory) (mandatory) COUNTY North Slope Borough BH DISTRICT Alaska (mandatory) (mandatory) STATE Alaska PAGE OF (mandatory) LOG DATE: TODAYS DATE: 6/5/2013 (mandatory) DISTRIBUTION LIST AUTHORIZED BY: BP Exploration(Alaska)Inc. (mandatory) HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? COMPANY FIELD FINAL (digital/ ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) LOGS LOGS image) FILM PERSON ATTENTION #OF PRINTS #Or NHIN I S #OF COPIES #OF COPIES 4 II 4 11 4 1 BP Exploration(Alaska)Inc. I I 3 I 1 I I I I Petrotechnical Data Center LR2-1 900 E.Benson Blvd. Anchorage,Alaska 99508 2 ConocoPhillips Alaska Inc. I I 1 I I I I Attn Ricky Elgarico PO Box 100360 Anchorage,Alaska 99510 3 ExxonMobil,Alaska I 1 I 1 I I I I Attn Lynda M.Yaskell and/or Leonardo Elias 3700 Centerpointe Dr. Suite 600 Anchorage,Alaska 99503 4 State of Alaska-AOGCC I 1 I 1 I I I I Christine Shartzer 333 West 7th Ave,Suite 100 Anchorage,Alaska 99501 5 DNR-Division of Oil&Gas I I 1 I I I I Attn:Sean Clifton 550 W.7th Ave,Suite 800 Anchorage,Alaska 99501 TOTALS FOR THIS PAGE: 0 5 5 0 0 0 TOTALS FOR ALL PAGES: 0 5 5 0 0 0 RECEIVED MAY 16 2013 Letter of Transmittal Irdik 11 2..\-5-012 BAKER Date: May 10, 2013 HUGHES 3)..(v To: From: State of Alaska AOGCC Baker Hughes INTEQ 333 W. 7th Ave., Suite 100 795 East 94th Avenue Anchorage,Alaska 99501 Anchorage, Alaska 99515 Bill Michaelson Please find enclosed the directional survey data for the following well(s): K-06CPB 1, K-06C J-17D J-09BPB 1, J-09B 02-06C 06-08BPB 1, 06-08B E-25APB1,E-25A G-14CPB 1, G-14C Enclosed for each well(s): 2 hardcopy prints of directional survey reports 1 compact disk containing electronic survey files Please sign and return one copy of this transmittal form to: BP Exploration (Alaska) Inc. Petrotechnical Data Center, LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 to acknowledge receipt of this data. RECEIVED BY: , State of Alaska AOGCC DATE: Z\ -O( 2 2 501 t.0 i �!i ! 0' 0 0 0 0:0'0 ,,0 0,0.0 Ca 00 CI 0 0.0:0.0 i 0' O O UU O O ,O :O O O ,O O O O•`U O 0 0 U f !'� CJ e- r e- e- e- e- e- e- ,e- e- e- e- e- e-L T P e-Vie- '.� M _ G till �� r-+ 1-4 H '.., _--t._y ,) ,,..,c3 ..:?i, Rf r' cd'e/"111 , ij L °-- V i.t G O O cc 0 o v fa- 1 n> ,r,r N n 5 v - o rn N m �.•`z clo 1.11 I.1.4 is al m Fc' 7 l7 rn W 0 s t at C9 °� Y- .. , N N Q M M N t-+ , 0 e- e- e- e- e- - e- - e• r e-.e- e- �� OD _ _ _ _ _ _ m a) 0) ■ CU 0„, CL (1) - o Q m , o R t J . ." ,� - o M r e co co O o °D `t N 'e to a0 N w c CI) r-" e- N N N N N e- N e- N M N e- e- 0 0) X E. Q 4 2 - ypf 9 Z z O 9' 0 O 0 N _ p a. J O > m X LL W LL LL ,, LL W Nz Q 0 0.— i0, ,i 0 k _ t a 0c w .cc H .cc J W L "cc J F X �_ m 0 0 a � 'a � w aka IX W CL - 3 CC W 0}C WO CC C cn l cn Ce 3 2 co O O _1 O Y O Oaa O _1 J Z Z Z2 2 Z 2 Q 2 2 _ _ 2 Z,z H Z Z 00 U U W W O W W W W m m W U U (q U U 2 OC 2 2 2 2 2 '2 . 242 u) v) 2 2�2;m 2 2 G b-- cn r • n X X X 4X X X X X X X X X xXXxX F X , v, co CD CD a J CD : ty to W M CO 0 e" 0 0 0) e" e- t` ap O O N co co ct CC N Oe O f^ N u, ..:= i- O Cl) LL, O t0 h`O (O to t0 Z O e- O O N e- e" O O e- (Z O 0 0 O o 0 0 0 - O O O O O O O O O O WO 900c:300 0 LLi o o 0 0 0 o 0 0 (0 0 a CO o .Q -) X O o N o o O N 4 2 Li 6 4 4 Ki X 4 o °o D 2 X X -) X X T.K. to D 2 Q OC > > m cn 0 0 Q LL In to O to in to .a U Q LL OO 0 Q Q OO Q a co v o m CO U U U U U U U Q U CO U U 03 m CO U U m O ® CD N Lrl N N > Q1 co m Ql Y r Y U � to � Qt � e-i C a v C� v a O1 wu m Q O CO m U.1 J U co o M N cO co J CO Q m - N o0 a o N •of r n C O e- to p M o O r t!7 A K C d0 °E C W b0 U `/ O (7 l" e- r �. P (� o J QJ f6 R = z m 2 Z 6 Z 4 Oo 6 c 0i °ro to J ,_ & OL c W 6 u m o o �0 N a w s Q° ra S' N u v d o0 o v '' x a m rn Q L RECEIVED STATE OF ALASKA APR 1 ,2013 ALASKA OIL AND GAS CONSERVATION COMMISSION AOGCC WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ®Oil ❑Gas ❑SPLUG ❑Other ❑Abandoned ❑Suspended 1b. Well Class 20AAC 25.105 20AAC 25.110 ❑Exploratory ❑Stratigraphic ❑GINJ ❑WINJ ❑WAG ❑WDSPL ❑Other No.of Completions One ®Development ❑Service 2. Operator Name: 5.Date Comp.,Susp.,or Aband.: 12. Permit to Drill Number: BP Exploration(Alaska) Inc. 3/22/2013 213-012 3. Address: 6.Date Spudded: 13. API Number: P.O. Box 196612,Anchorage,Alaska 99519-6612 3/15/2013 50-029-20969-04-00 4a. Location of Well(Governmental Section): 7.Date T.D.Reached: 14. Well Name and Number: Surface: 3/18/2013 PBU J-17D 801' FNL, 1806'FEL, Sec.9,T11N, R13E, UM Top of Productive Horizon: 8. KB(ft above MSL): 69.8' 15.Field/Pool(s) 1779'FNL,3438' FWL, Sec. 10,T11N, R13E, UM GL(ft above MSL): 39.78' Prudhoe Bay/Prudhoe Bay Total Depth: 9.Plug Back Depth(MD+TVD) 1033'FNL, 106'FWL, Sec. 11,T11N, R13E, UM 13439' 9017' 4b. Location of Well(State Base Plane Coordinates,NAD: 10.Total Depth(MD+TVD) 16. Property Designation: Surface: x- 642547 y- 5970534 Zone- ASP4 13498' 9016' ADL 028281 &0.28280 TPI: x- 647811 y- 5969657 Zone- ASP4 11.SSSV Depth(MD+TVD) 17. Land Use Perrtiit: Total Depth:x- 649742 y- 5970442 Zone- ASP4 None 18.Directional Surve 19.Water depth,if offshore: 20. Thickness of Permafrost(ND): Y ®Yes ❑No N/A ft MSL 1900'(Approx.) (Submit electronic and printed information per 20 AAC 25.050) ( PP ) 21.Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): 22.Re-Drill/Lateral Top Window MD/TVD: MWD/GR/RES, GR/CCL/MCNL 11735' 9032' 23. CASING,LINER AND CEMENTING RECORD SETTING DEPTH MD SETTING DEPTH ND 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 yds 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' 11735' 8326' 9032' 6-1/8" 337 cu ft Class'G' 3-1/2"x3-1/4"x2-718" 9.3#/6.6#16.4# L-80 10971' 13485' 8914' 9016' 4-1/4" 117 sx Class'G' 24. Open to production or injection? ®Yes ❑No 25. TUBING RECORD If Yes,list each interval open SIZE DEPTH SET(MD) PACKER SET(MD/ND (MD+TVD of Top&Bottom;Perforation Size and Number): ( ) ( ) 2-7/8"/2"Gun Diameter,4/6 spf 4-1/2", 12.6#, 13Cr80 10083' 10027'/8300' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. 13180'-13380' 9017'-9020' WAS HYDRAULIC FRACTURING USED DURING COMPLETION?❑Yes ®No V` DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 2500' Freeze Protect w/46 Bbls Diesel • 27. PRODUCTION TEST Date First Production Method of Operation(Flowing,Gas Lift,etc April 4,2013 Flowing Date of Test Hours Tested. Production For OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: 4/7/2013 24 Test Period ♦ 543 4125 363 96 7600 Flow Tubing Casing Press: Calculated OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API(CORR): Press. 160 1020 24-Hour Rate ♦ 543 4125 363 23.9 28. CORE DATA Conventional Core(s)Acquired? ❑Yes ®No Sidewall Core(s)Acquired? ❑Yes ®No If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize 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 R8DMS APR 15 2013 -C*.tik Form 10-407 Revised 10/2012 17 f /J q//3ONTINUED ON REVERS •y/ /) Submit Original Only 29. GEOLOGIC MARKERS(List all formations and .ers encounter 30. FORMATION TESTS NAME MD ND 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. Zone 2A 11150' 8989' None Zone 2A 11735' 9032' (Kicked off from Parent Well) Formation at Total Depth: Zone 2A 11150' 8989' 31.List of Attachment: Summary of Daily Drilling Reports,Summary of Post-Rig Work,Well Schematic Diagram,Surveys 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 Printed Name: J._ Title: Drilling Technologist -tufka Signature: Phone 564-4091 Date: it/IH i3 INSTRUCTIONS General: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. Item 1 a: Classification of Service Wells: Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disposal,Water Supply for Injection, Observation,or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. Item 4b: TPI(Top of Producing Interval). Item 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 13: The API number reported to AOGCC must be 14 digits(ex: 50-029-20123-00-00). Item 20: Report true vertical thickness of permafrost in Box 20. Provide MD and ND for the top and base of permafrost in Box 28. Item 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Item 24: If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27: Method of Operation: Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-In,or Other(explain). Item 28: Provide a listing of intervals cored and the corresponding formations,and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30: Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 10/2012 Submit Original Only TREE= 4-1/16"CEW WELLI-EAD= McEVOY J DRAFT 7 D SAFE 3TES: WH L ANGLE<°70 @ 11140'"" 4 1/2" ACTUATOR= BAKER CHROME TBG"'*" INITIAL,"A","B",&"C"WELLBORES INITIAL KB.ELE 77' r I - I NOT SHOWN'"" BF.REV 3000 120"CONDUCTOR 110' 1 i 2218' H4-1/2"FES X NIP,ID=3.813" Max Angle= 95°@ 11727' Datum MD= 10893' ■ 2584' H9-5/8"DV PKR Datum ND= 8800'SS GAS LFT MANDRELS 13-3/8'CSG,72#,L-80,D=12.347" —I 2685' ® ND TV D DEV TYPE®LATCH FORT DATE 3235 3227 MMG DOME RK 16 04/02/13 9-5/8"X 7"BKR C-2 ZXP LTP —I 8774' 6368 5608 MMG SO RK 20 04/02113 w/11.6'TEBK SLV,D=6.30" L 8620 7308 MMG DMY RK 0 10/10/05 19-5/8"X 7"BKR HMG LNR HGR,D=6.32" — 8791' 1 9936 8240 KBG2 DMY BK 0 10/10/05 sr WHIPSTOCK(09/2705) H 8952' 0. 9-5/8"CSG,47#,L-80,D=8.681" —I —8931 r. ,a org it MLLOUT WNVDOW(J-17G) 8931'-8947' 6 Minimum ID =2.37" © 10971' 1 10006' --14-1/2"}-ES X NP,D=3.813" 1 4-1/2" KB LTP 0 10027' I X 4-1/2"BKR S-3 PKR,D=3.875" II 10050' H4-1/2"-ESX NP,D=3.813" 1 1006T H7"X 5"BKR ZXP LTP w/11'TIEBACK,D=4.40" 6 10070' IH4-1/2"FES XN NP,MLLE)TO 3.80"(03/05/13) 4 1/2"TBG,12.6#,13CR-80 VAM TOP, — 10083' I .0152 bpf,D=3.958" ' 10083' —!4-1/2"WLEG, D=3.958" 10084' —j 7"X 5"BKR LNR HGR,ID=4.40" 10091' —15"X 4-112"XO, D=3.958" 7"LNR,26#,L-80 BTC-M,.0383 bpf,D=6.276" —I 10234' I—, 10417' H4-1/2"MARKER JOINT,D=4.00" 1 ►0 ►0 10971' —14-112"KB LTP,D=2.37"(04/03/13) 10979' —13.70 DEPLOYMENT SLV,ED=3.00" I 1 I 11001' —13-1/2"HES X NP,D=2.813" 4-1/2"LNR,12.6#,L-80 BT-M,.0152 bpf,D=3.958" -11735' 4-1/2"BKR WHPSTOCK(03/13/13) —I 11735' MLLOUT WINDOW(J-17D)11735'-11743' 3-1/2"LNR,9.3#,L-80 STL,.0087 bpf,ID=2.992" 11382' li FERFORAT1ON SUMMARY REF LOG:SLB Mall GR!CCL ON 03/22/13 11382' H 3-1/2"X 3-3/16"XO,ID=2.786" I ANGLE AT TOP PERF:89°@ 13190' INote:Refer to Production DB for historical perf data SIZE SPF NTERVAL Opn/Sqz DATE SOZ 2-7/8" 4 11350-11500 S 10/09/05 03/20/13 2" 6 13180-13380 0 03/21/13 13082' H3-3/16"X 2-7/8"XO,ID=2.377" 1) 3-1/4"LNR,6.64,L-80 TCL_0079 bpf,ID=2.850" —I 13082' FBTD —I 13439' 2-7/8"LNR,6.4#,L-80 STL,.0058 bpf,D=2.441" — 13485' 1 13480' I�2 7/8"X 2318"XO PIN,D=1.992" DATE REV BY COMMENTS DATE REV BY COMMENTS PRUD HOE BAY K 07/18/83 AIn3 INITIAL COMPLETION 03/26/13 MW PJC DRLG DRAFT CORRECTIONS WELL: J-17D 10/26/99 JLH CTD SIDETRACK(J-17A) 04/08/13 JNL/JND REVISB)LNR TD FF32MT No:'2130120 01/21/02 NOFIDIC 1 CTD SIDETRACK(J-17B) 04/09/13 BSE3JMD GLV C/O(04/02/13) API No: 50-029-20969-04 10/11/05 N2E S SIDETRACK(J-17C) 04/09/13 NXW/JMD ADD LTP(04/03/13) SEC 9,T11 N,R13E,801'FM_8 1806'FEL 03/22/13 NORI C 1 CTD SIDETRACK(J-17D) 04/12/13 JNL/JND FDCED FERF TYPO 03/22/13 PJC DRLG HO CORRECTIONS BP Exploration(Alaska) North America-ALASKA-BP Page 1 of 19 Operation Summary Report 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 1 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 I 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 CREW AND 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-PADAND 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 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 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 North America-ALASKA-BP Page 2 of 19 Operation Summary Report 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 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 WWI:/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) 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 PRESSURE TEST. 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 FILL COIL WITH 8.6 PPG DRILLING MUD. OPERATE REMOTE FOR SSV. SET BACK INJECTOR.CIRC COIL. Printed 4/2/2013 7:29:28AM North America-ALASKA-BP Page 3 of 19 Operation Summary Report 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) (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. AAR: 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 SSV AND SWAB VALVES. l 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 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 North America-ALASKA-BP Page 4 of 19 Operation Summary Report 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) (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 ON A VAC. 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 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 North America-ALASKA-BP Page 5 of 19 Operation Summary Report 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 1 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 Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 16:00 - 16:30 0.50 STWHIP P ! WEXIT LOG CCL DOWN FROM 11,640 TO 11,800' (SHOE DEPTHS)AT 1000-FPH. CIRCULATE AT.88-BPM/1270-PSI. PU TO 11,750'AND ASSESS CCL. COLLAR AT 11,728'. DISCUSS WITH ENGINEERING TEAM AND DECIDE TO SET TOWS AT 11,733'FOR COLLAR AVOIDANCE. 16:30 - 17:00 0.50 STWHIP P WEXIT POSITION WHIPSTOCKW1TH TOP AT11,733' (BOTTOM 11,748.7') SHUT DOWN PUMP&CLOSE EDC. PRESSURE UP TO SET WHIPSTOCK SEE SET AT 2800-PSI. SET DOWN 4K-LBS TO CONFIRM SET. PU TO 11,700'AND FLOW CHECK WELL-NO FLOW. IA/OA/PVT=20-PSI/0-PSI/308-BBLS. 17:00 - 18:15 1.25 STWHIP P WEXIT CBU THROUGH MGS FROM 11,700'. CIRCULATE AT 2.24-BPM/2060-PSI,MOVING UPHOLE SLOWLY. AT BOTTOMS UP CLEAN. ISOLATE MGS.CONTINUE TO CIRCULATE. 18:15 - 20:10 1.92 STWHIP P WEXIT POH WITH WS SETTING BHA. PUMPING 2 BPM 1860 PSI.to 200' 20:10 - 20:25 0.25 STWHIP P WEXIT FLOWCHECK WELL.NO FLOW. PJSM FOR BHA. 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. ORDER MORE MUD FOR CONTINGENCY. 22:20 - 00:00 1.67 STWHIP P WEXIT RIH PUMPING MIN.RATE. 3/14/2013 00:00 - 01:15 1.25 STWHIP P WEXIT CONTINUE RIH WITH 3.80"WINDOW MILL BHA #2 FROM 8200'. PUMPING MIN RATE. LOG TIE AT 10490'.-7'CORRECTION. CONTINUE RIH TO 11700' P/U WT=38K.S/O WT=18K OBTAIN SPR#1 MP. #1 MP 2.6 BPM=2500 PSI.1 BPM=1580 PSI. .5 BPM=1230 PSI. #2 MP 2.6 BPM=2500 PSI.1 BPM=1450 PSI. ,.5 BPM=1230 PSI. UPDATE KILL SHEET. SHUT PUMP OFF AND CONTINUE RIH. DRY TAG TOP WHIPSTOCK AT 11734.6' Printed 4/2/2013 7 29 28AM ' North America-ALASKA-BP Page 6 of 19 Operation Summary Report 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) (usft) 01:15 - 02:15 1.00 STWHIP P WEXIT P/U TO 11722'. F/S=2540 PSI AT 2.68 BPM. RIH SLOWLY.LIGHTLY TAG PINCH POINT AT 11733.8' TIME MILL 1ST FT WINDOWAT 1 FPH PER BTT REP. WOB=1.5K-1.6K.150 TO 200 PSI MOTOR WORK. 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 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.75-1 K-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. 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 North America-ALASKA-BP Page 7 of 19 Operation Summary Report 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) (usft) 16:00 - 16:30 0.50 STWHIP 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. PVT=247 BBLS.IA=42 PSI.OA=9 PSI 19:10 - 19:45 0.58 STWHIP P WEXIT SET BACK INJECTOR.CIRC COIL. UD WINDOW MILL BHA. MILL=3.73"NOGO.3.74"GO.GRADE=8-7. ' STRING MILL=3.78"NOGO.3.79"GO. 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 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 MP AT 2.71 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 North America-ALASKA-BP Page 8 of 19 Operation Summary Report 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) (usft) 03:30 - 04:45 1.25 DRILL P PROD1 CONTINUE DRILLING FROM 11800'TO 11900' WOB=1K.ROP=100 FPH. 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 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 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. 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 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 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/O 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 Page 9 of 19 North America-ALASKA-BP Operation Summary Report 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©77.0Ousft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (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 PROW 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 EDC. PJSM FOR BHA. 19:00 - 20:30 1.50 DRILL P PROD1 TAG UP.SET INJECTOR BACK.CIRC COIL. UD BHA.INSPECT MUD MOTOR AND BIT. 1 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 BHA#4 TO 5400' PUMPING.22 BPM 730 PSI. LOAD LINER INTO PIPESHED. Printed 4/2/2013 7.29.28AM North America-ALASKA-BP Page 10 of 19 Operation Summary Report 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) (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 WAY AROUND 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.AT 1.71 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/ 8.47-PPG. ECD=10.08-PPG. Printed 4/2/2013 7:29:28AM North America-ALASKA-BP Page 11 of 19 Operation Summary Report 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 0OAM 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 1 NPT NPT Depth j Phase Description of Operations (hr) (usft) • 10:00 10:15 0.25 DRILL P 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. RETURNS FROM WIPER SHOW SLIGHT INCREASE IN WHITE CLAY CUTTINGS. 10:15 - 13:00 2.75 DRILL P PROD1 DRILL AHEAD FROM 12,500' FREE SPIN=3.3-BPM/3000-PSI. DRILL AHEAD WITH 3-5K-LBS DHWOB AND 200-400-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/ 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. 13:00 - 13:30 0.50 DRILL • P PROD1 WIPER TRIP FROM 12,600'. CIRCULATE AT 3.4-BPM/3240-PSI. 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'. 13:30 - 13:45 0.25 DRILL P PROW LOG TIE IN TO RA TAG. APPLY+3'CORRECTION. 13:45 - 15:00 1.25 DRILL P PROD1 LOG MAD PASS FROM 11,778'10 12,150'AT 5-FPM. CIRCULATE AT 3.3-BPM/3060-PSI. NOTICE UNUSUAL NOISE COMING FROM SLB POWER PACK. CTS OPERATOR DISCUSS WITH CTS MECHANIC&DISTRICT MANAGER. DECIDE TO PULL INSIDE CASING FOR MECHANICS TO INSPECT POWER PACK. 15.00 - 15:55 0.92 DRILL N SFAL PROD1 POH FROM 12,150'. CIRCULATE AT 3.3-BPM/3050-PSI. NO 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/ 2550-PSI. 15:55 - 17:00 1.08 DRILL N SFAL PROD1 CTS MECHANIC ON LOCATION TO INSPECT POWER PACK. CONTINUE TO CHASE NEW MUD SWEEP OOH 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 North America-ALASKA-BP Page 12 of 19 Operation Summary Report 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) (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 1 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' 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 North America-ALASKA-BP Page 13 of 19 Operation Summary Report 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) (usft) 3/17/2013 00:00 - 00:30 0.50 DRILL P PROD1 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'. 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 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 DRILL AT 04:00 HRS. STOP POH FOR WIPER.SHUT DOWN PUMP. FLOWCHECK WELL. AAR: NOTICE PIT GAIN.CREWAND 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'. 08:00 - 08:10 0.17 DRILL P j 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 North America-ALASKA-BP Page 14 of 19 Operation Summary Report 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:OOAM 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) 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'. OBTAIN SPRS. TOTAL LOSSES DURING WIPER TRIP= 6-BBLS. 11:20 - 14:00 2.67 DRILL P PROD1 DRILL AHEAD 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/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 North America-ALASKA-BP Page 15 of 19 Operation Summary Report Common Well Name:J-17 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:3/11/2013 End Date:3/19/2013 1X3-0135K-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°19'37.03170 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) 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 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=10FPH. 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 North America-ALASKA-BP Page 16 of 19 Operation Summary Report 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) (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 IN TO 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-IT'S FROZEN. CHECK PUMPS-1502 CONNECTION ON MP#2 IS LEAKING. TIGHTEN BUT NEED TO RETEST PUMP. FLOW CHECK WELL-NO FLOW. ESTABLISH CIRCULATION AT 3.15-8PM/ 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 North America-ALASKA-BP Page 17 of 19 Operation Summary Report 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:O0AM 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 NPT NPT Depth Phase Description of Operations (hr) (usft) 13:30 - 14:00 0.50 DRILL N SFAL PROD1 TEST MUD PUMP#2 TO 4500-PSI-NO LEAKS. OPEN EDC&CIRCULATE COIL AT 1-BPM/ 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 0.75 DRILL P PROD1 WIPER BACK TO TD CIRCULATING AT 3.1-BPM /3370-PSI. SEE PERIODIC MOTORWORK AND WEIGHT STACKING IN 12,500'CLAY SECTION. 14:45 - 16:00 1.25 DRILL P PROD1 WIPER UP FROM 12,720'THROUGH ENTIRE WHITE CLAY SECTION TO CLEAN UP TO 12,200'-SEEING ISOLATED OVERPULLS& LIMITED MOTORWORK. TURN AROUND TRY TO WIPER DOWN- STACKING OUT AT 12,282'. ATTEMPT TO WORK PAST BY VARYING PUMP RATE, RUNNING SPEED&ORIENTATION-NO SUCCESS. 16:00 - 18:00 2.00 DRILL N DPRB PROD1 'DISCUSS SITUATION WITH ENGINEERING TEAM AND FIELD SUPT. WIPERING TO WINDOWAND SEE PACKOFF AT 11,765'. ATTEMPT TO RIH AND UNABLE TO MOVE. 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. 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 COMPLETE CREW CHANGE. CONTINUE TO RIH AT 20-FPM,CIRCULATING 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. NO OVERPULLS. 19:00 - 20:15 1.25 DRILL N DPRB 13,498.00 PROD1 OPEN EDC.CIRCULATE MAX RATE. PUMPING 4 BPM.3.2 BPM 2900 PSI. START 35 BBL HI VIS SWEEP DOWN COIL. CIRCULATE HOLE CLEAN ABOVE WINDOW. JET WHIPSTOCK TRAY CLEAN. CLOSE EDC. Printed 4/2/2013 7:29:28AM North America-ALASKA-BP Page 18 of 19 Operation Summary Report 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:OO:OOAM 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 (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 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 PILLAT BIT, 04:15 - 05:00 0.75 DRILL P PROD1 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. PUMP OFF PASSING THROUGH WINDOW. Printed 4/2/2013 7:29:28AM North America-ALASKA-BP Page 19 of 19 Operation Summary Report 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) (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 PON 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 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 I _ TEST. 10:45 - 11:00 0.25 BOPSUR P PROD1 RD BHI UQC. Printed 4/2/2013 7:29:28AM North America-ALASKA-BP Page 1 of 11 Operation Summary Report 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 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 I Hrs Task Code NPT ! NPT Depth Phase Description of Operations _ I (hr) (usft) 3/19/2013 11:00 - 11:30 I 0.50 CASING P RUNPRD HOLD PJSM ON PUMPING OUT E-LINE SLACK. BOOT E-LINE. 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 MORE MOVEMENT HEARD. UNSTAB INJECTOR. RECOVER 200'OF E-LINE(255'ANTICIPATED). 11:30 - 12:00 0.50 CASING P RUNPRD !CUT OFF CTC. RU HYDRAULIC COIL CUTTER. CUT 100'OF COIL FOR CHROME IMANAGEMENT. RD HYDRAULIC COIL CUTTER. 12:00 - 13:00 1.00 CASING P RUNPRD MU BIT CTC. PULL TEST TO 40K-LBS. PRESSURE TEST TO 3800-PSI. GOOD TESTS. 13:00 - 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 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 TOP OF WELL TO MONITOR. CHANGE OUT BALL DROP LO TORQ ISOLATION VALVE. TEST BALL DROP LO TORO 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 P RUNPRD PUMP 3/4"DRIFT BALL. LAUNCH WITH 1000-PSI AND CHASE AT 3.16-BPM/1420-PSI. HEAR BALL ROLLING IMMEDIATELY. BALL 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, 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 SAFETY JOINT,RU FARR TONGS. WHILE RIGGING UP,SEAT VALVES IN MP#1. 1 WSL,TOOLPUSHER,NORDIC DRILLER&BTT REP CONFIRM PIPE LAYOUT IN PIPE SHED& RUNNING ORDER. Printed 4/2/2013 7:30:04AM North America-ALASKA-BP Page 2 of 11 Operation Summary Report Common Well Name:J-17 AFE No Event Type:COM-ONSHORE(CON) Start Date:3/19/2013 End Date:3/22/2013 IX3-0135K-C:DRILL(1,176,312.00) Project:Prudhoe Bay Site:PB J Pad Rig Name/No.:NORDIC 1 I Spud Date/Time:1/3/2002 12:00:00AM Rig Release:3/23/2013 Rig Contractor:NORDIC CALISTA UW:/Lat:07019'37.030"0 Long: 0148°50'38.023"W Active datum:Kelly Bushing/Rotary Table @77.00usft(above Mean Sea Level) Date From-To 1 Hrs Task I Code ! NPT NPT Depth Phase 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 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 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 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 6.60#/FT LINER WITH 3-3/16" TCII-CONNECTIONS FROM JOINT#30.AGAIN DRIFT FIRST FIVE LINER-JOINTS WITHOUT ISSUES. I 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 , 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 North America-ALASKA-BP Page 3 of 11 Operation Summary Report 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 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 NPT NPT Depth I Phase I Description of Operations (hr) (usft) 3/20/2013 00:00 - 01:15 1.25 CASING P RUNPRD CONTINUE MU 12 JTS 3-1/2"STL L-80 LINER. SWAP JOINT#87 WITH JOINT#98 DUE TO DAMAGED BOX END. MU 3.7"X 3.0"P110 DEPLOYMENT SLEEVE W/4"GS PROFILE, SELRT,DISCO,& 6 JTS 2-3/8"PH6. RIG DOWN LINER HANDLING EQUIPMENT. PU INJECTOR&STAB ON TO WELL. 01:15 - 01:30 0.25 CASING P RUNPRD PT QTS LOW TO 500 PSI&HIGH TO 3500 PSI. BOTH PT'S PASSED. SET PUMP TRIPS TO 1000 PSI. MEANWHILE START FILLING LINER WITH COIL. 01:30 - 02:00 0.50 CASING WA RUNPRD FILL LINER W/14 BBLS OF 1%KCL BEFORE RIH W/BHA#5(LINER RUNNING BHA). CIRC PRESSURE 300 PSI. 02:00 - 04:00 2.00 CASING P RUNPRD START RIH W/BHA#5(LINER RUNNING BHA) C@ 100 FPM.PVT=122 BBLS/CIRC PRESSURE 310 PSI©0.30 BPM MM IN 0.30 BPM/MM OUT 0.83 BPM/MM IN DENSITY 8.4 PPG/MM OUT DENSITY 8.3 PPG 04:00 - 04:30 0.50 CASING P RUNPRD SEE WINDOVIFFLAG AT 11,529.36'.APPLY DEPTH CORRECTION TO 11,510.00'AND CONTINUE RIH. MEANWHILE START TO GET SCHLUMBEGRER CEMENTING TRUCKS SPOTTED AND RIGGED UP. 04:30 - 04:45 0.25 CASING P RUNPRD KEEP RIH WITH-14K LBS SOW. AT 12,635'STACK OUT COILED TUBING WEIGHT.PU UP TO 48K LBS AND MANAGE TO RUN PAST RESTRICTION. 04:45 - 05:20 0.58 CASING P RUNPRD KEEP RIH AND SEE TD-FLAG AT 13,310'JUST AS EXPECTED. CONTINUE RIH,HOWEVER START TO SEE ISSUES ONWARDS FROM-13,385'.WORK 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 13,485'.PU MULTIPLE TIMES TO MANIPULATE THE R&R INDEXING TOOL.HOLE IS VERY TIGHT,SEE PUW MOSTLY AROUND 48K LBS BUT ALSO AS HIGH AS 60K LBS. PU TO 13,312',RUN BACK IN HOLE AND DO NOT GET PAST 13,485'. 06:00 - 07:30 1.50 CASING P RUNPRD PERFORM RIG CREW CHANGE& SLB CHANGEOUT. DISCUSS LINER POSITION WITH ODE&GET ASSET APPROVAL TO CONTINUE FORWARD WITH SHOE AT 13,485'/LINER TOP AT 10,979'. Printed 4/2/2013 7:30:04AM North America-ALASKA-BP Page 4 of 11 Operation Summary Report 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 I Hrs ' Task I Code I NPT NPT Depth Phase I 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 1BTT REP CHANGEOUT. CIRCULATE AT.41-BPM/220-PSI. I CONTINUE TO MIX 1%KCL SPACER. REPEAT BLOW DOWN CEMENT LINE WITH AIR. 09:00 - 10:30 1.50 CASING P RUNPRD I 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. I REDUCE PUMP RATE TO MIN AND WORK LINER BACK TO BOTTOM&SET DOWN I'r 10K-LBS ON LINER AT 13,485 TO MAINTAIN I 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. 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. I TOP OFF RIG WATER TANK I 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. j HIGHLIGHT HIGH PRESSURE PUMPING HAZARDS,CLEAR&CONCISE COMMUNICATION,STOPPING THE JOB IF IANYTHING GOES DIFFERENTLY THAN PLANNED,CONTINGENCY PLANS FOR HIGH PRESSURES OR PLUGGED BYPASS,AND ORDER OF FLUIDS PUMPED. Printed 4/2/2013 7:30:04AM North America ALASKA-BP Page 5 of 11 Operation Summary Report Common Well Name:J-17 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 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©77.0ousft(above Mean Sea Level) Date From-To I Hrs Task Code I NPT NPT Depth Phase I Description of Operations (hr) (usft) — - 11:30 - 12:30 1.00 CEMT P RUNPRD BATCH UP 36-BBLS 15.8-PPG CLASS G CEMENT WITH YIELD=1.17-FT3/SK. IA/OA/PVT=50-PSI/2-PSI/157-BBLS. 112:30 - 14:36 2.10 CEMT P RUNPRD PUMP 10-BBLS B.5-PPG 1%KCL SPACER WITH RIG PUMP. I FEED 5-BBLS OF 8.5-PPG 1%KCL SPACER TO CEMENT 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 I CONTAMINANT FLUID AT 1.5-BPM. SLOW TO 1-BPM WITH INTERFACE AT SELRT !FOR 2-BBLS. RESUME DISPLACEMENT AT 1.5-BPM. ZERO OUT MM WHEN CEMENT AT SHOE. WITH 2-BBLS CEMENT LEFT IN COIL-SHUT DOWN PUMP,PU TO 13,464',THEN STACK DOWN 10K-LBS AT 13,476'. PRESSURE UP TO 800-PSI TO LAUNCH PEEWEE. PU AND SIDE EXHAUST 2-BBLS CEMENT&3-BBLS CONTAMINANT. ISET BACK DOWN TO 13,476'. PRESSURE UP AND SHEAR LWP AT 3600-PSI. CHASE WITH CEMENT CONTAMINANT AT 1.25-BPM. SEE PLUG BUMP AT 18.9-BBLS PUMPED. CIP AT 1436-HRS. 14:36 - 15:00 0.40 CEMT P I RUNPRD OPEN BAKER CHOKE AND CHECK FLOATS- FLOATS HOLDING. UNSTING FROM LINER BUT PRESSURE DOESNT BLEED OFF-INDICATES CEMENT ABOVE LINER TOP. STOP AT 13,460'AND CIRCULATE 5-BBLS AT.6-BPM/970-PSI TO CONTAMINATE CEMENT NEAR LINER TOP. TOTAL CEMENT BEHIND PIPE=21.8-BBLS. TOC=TOL 15:00 - 17:15 2.25 CASING P RUNPRD POH WITH LINER RUNNING TOOL, CONTAMINATING CEMENT WITH 1.5-PPB POWERVIS MIXED IN 8.4-PPG FRESH WATER. CIRCULATE AT.9-BPM/890-PSI AND POH AT 85-FPM TO MAINTAIN.5-BPM RETURNS. 17:15 - 18:00 0.75 CEMT P RUNPRD FLOW CHECK WELL-NO FLOW. ON LU DISCUSS HOLD PJSM POSITIONS LD OF INER PEOPLER NNING BHA. EQUIPMENT HANDLING,WELL CONTROL CONSIDERATIONS AND OFFLOADING OF TOOLS FROM RIG FLOOR. UNSTAB INJECTOR,CUT OFF CTC&SET BACK OVER CIRC HOLE ON LEGS. 18:00 - 18:45 0.75 CASING P RUNPRD I PERFORM CREW CHANGEOUT. CLEAN& CLEAR RIG FLOOR FOR CLEANOUT RUN. 18:45 - 19:30 0.75 EVAL P OTHCMP PICK UP INJECTOR AND MU BAKER CTC. INSTALL TEST-PLATE AND PULL-TEST !CONNECTOR TO 40K LBS.PERFORM L 'PRESSURE-TEST TO 3500 PSI. GOOD PT. Printed 4/2/2013 7:30:04AM �. .b North America-ALASKA-BP Page 6 of 11 Operation Summary Report 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 Site:PB J Pad Rig Name/No.:NORDIC 1 Spud DateTme:1/3/2002 12:00:00AM 1 Rig Release:3/23/2013 Rig Contractor:NORDIC CALISTA j 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 I Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 19:30 - 20:15 0.75 EVAL P OTHCMP 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 HAZARDS WITH CLEANOUT/LOGGING RUN INCLUDING:WORKING WITH SUSPENDED LOADS,HAND&BODY PLACEMENT,PINCH 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 I MU BHA#6(CLEANOUT/LOGGING BHA). PU INJECTOR&STAB ON TO WELL. PT QTS LOW TO 500 PSI/5 MIN&HIGH TO 3500 PSI/ 15 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 I ENTER LINER. PVT=175 BBLS(TOOK 206 BBLS CONTAMINATED CEMENT RETURNS TO CUTTINGS BOX) IAP=51 PSI/OAP=OPSI CIRC P 1556 PSI MM IN 1.53 BPM/MM OUT 1.63 BPM 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 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 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 North America-ALASKA-BP Page 7 of 11'I. Operation Summary Report 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 I Site:PB J Pad Rig Name/No.:NORDIC 1 I 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 I From-To Hrs Task I Code I NPT I NPT Depth I Phase Description of Operations (hr) (usft) 07:00 - 08:30 1.50 1 EVAL P OTHCMP UNSTAB INJECTOR&SET BACK OVER CIRC 'HOLE ON LEGS. 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 P OTHCMP 'PU INJECTOR&STAB ON. JET BOP STACK AT 2-BPM/850-PSI X3 PASSES. 1 UNSTAB INJECTOR AND SET BACK OVER CIRC HOLE. GREASE CREW SERVICE TREE VALVES. CONFIRM POST JOB UCA IS SHOWING '>1500-PSI COMPRESSIVE STRENGTH. 09:30 - 10:30 1.00 EVAL P . OTHCMP 1 RU AND PERFORM LINER LAP TEST. TEST TO 250-PSI/5-MIN AND 2400-PSI/ 1 30-MIN. PUMP.4-BBLS TO ACHIEVE 250-PSI. GOOD, FLAT LINE LOW PRESSURE TEST. PUMP 2.1-BBLS TO ACHIEVE HIGH TEST PRESSURE OF 2400-PSI. HOLD HIGH • I PRESSURE TEST FOR 5-MIN WITH LOSS OF I 428-PSI. BUMP UP WITH.5-BBLS TO ACHIEVE HIGH TEST PRESSURE OF 2400-PSI AGAIN. HOLD HIGH PRESSURE TEST FOR 5-MINUTES WITH LOSS OF 370-PSI. LINER LAP TEST FAILED. BLEED OFF PRESSURE AND RD TEST I EQUIPMENT. 10:30 - 11:00 0.50 EVAL P OTHCMP !REVIEW MCNL/GR/CCL DATA. CONFIRM THAT DEPTH CORRELATION CAN BE MADE. VAC OUT CUTTINGS BOX WITH SUPER ' SUCKER. t 11:00 - 12:00 1.00 PERFOB P , OTHCMP HOLD PJSM AND LOAD GUNS INTO PIPE SHED. BRING IN ALL GUN HANDLING EQUIPMENT. . RU RIG FLOOR FOR RUNNING PERF GUNS. 12:00 - 13:00 1.00 PERFOB P OTHCMP I RUN 10-2"6SPF 2006PJ PERF GUNS. MU FIRING HEAD. 13:00 - 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" 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. 1- _, TEST QTS TO 250-PSI/3500-PSI. ESTABLISH CIRCULATION AT.3-BPM/110-PSI. Printed 4/2/2013 7:30:04AM North America-AtA$KA BPS ro Page 8 of 11 Operation Summary Report Common Well Name:J-17 AFE No Event Type:COM-ONSHORE(CON) Start Date:3/19/2013 End Date:3/22/2013 1X3-0135K-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 From-To Hrs Task 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. !HOLD KWT DRILL WITH RIG CREW WHILE RIH I 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 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 I CTDS DEPTH. CORRECT DEPTH TO 10,336.26'. 1 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 j PBTD FROM MEMORY LOG OF 13,450.6'(PLUS 13.42'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 North America-ALASKA-BP '' ` `Page' "iii Operation Summary Report Common Well Name:J-17 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 ' 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 1 Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) I 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 I DISCUSS THE POTENTIAL OF FURTHER 'TRAPPED PRESSURE IN GUNS. 1 00:45 - 01:20 0.58 PERFOB P OTHCMP COMPLETE LAYING DOWN PERFORATING I BHA(BHA#7).ALL GUNS HAVE FIRED,NO I PROBLEMS IDENTIFIED. 01:20 - 02:15 0.92 PERFOB P OTHCMP CLEAN RIGFLOOR AND DRAIN GUNS. BUNDLE UP SPENT GUNS AND LOAD OUT OF PIPESHED. 1 ode 02:15 - 03:10 0.92 i BOPSUR P POST MU FREEZE-PROTECTING BHA(BHA#8)WITH BPV,6'STINGER AND NOZZLE. 103:10 - 03:30 0.33 BOPSUR P POST STAB ON INJECTOR AND PRESSURE-TEST QTS TO 300PSI/5MINS AND 3,500PSI/5MINS. I ACHIEVE GOOD TESTS. HOLE IS FULL-NO ' _ LOSSES. 03:30 - 04:00 0.50 BOPSUR P POST RIH W/BHA#8(FREEZE PROTECT).SWAP FLUIDS TO DIESEL. 104:00 - 04:20 0.33 BOPSUR P POST POOH&LAY IN FREEZE PROTECT FROM .2500'TO SURFACE WITH 46 BBLS OF DIESEL. 104:20 - 04:45 0.42 BOPSUR P POST LD NOZZLE-BHA AND CLEAR RIGFLOOR. MEANWHILE HAVE GREASE CREW GREASE ALL TREE VALVES.SLB N2 CREWARRIVES 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 1 FOR SETTING BPV. VALVE CREW INSTALLS 4-1/16"CAMERON I 1H-TYPE BPV,NO COMPLICATIONS. 05:15 - 05:30 0.25 BOPSUR P POST PERFORM PRESSURE-TEST ON N2 SURFACE 1 LINES TO 300PSI/5MINS AND 3,500PSI/ I5MINS. 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/fomis/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 t TEMPORARY PIPEWORK CRITERIA. CONFIRM N2 PUMP TRIPS Printed 4/2/2013 7:30:04AM North America-ALASKA-BP Page 10 of 11 Operation Summary Report 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 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: i 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) 07:00 - 07:40 0.67 RIGD P POST !HOLD PJSM ON BLOWING DOWN REEL WITH N2. DISCUSS HAZARDS OF N2 EXPOSURE, IMPORTANCE OF CLEAR&CONCISE COMMUNICATION,PROPER LINE UP& RESTRICTED AREAS. PU INJECTOR AND MU TO WELL. POSITION NOZZLE JUST ABOVE SWAB VALVE. PUMP 50-BBLS FRESH WATER.SCREEN BYPASS LINE IS FROZEN-HEAT&ABLE TO PUMP THROUGH FREELY AT 3-BPM/ 1860-PSI. FOLLOW WITH 10-BBLS MEOH AT 1.4-BPM/ 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 INSTALL 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 I 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 POST I REMOVE INNER REEL IRON. I 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 I COMMUNICATION,EXCLUSION ZONE, I 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 I OUT WITHOUT ISSUE. • PU NEW REEL&SECURE IN REEL HOUSE. Printed 4/2/2013 7:30:04AM North America-ALASKA-BP Page 11 of 11 Operation Summary Report 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 r 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) 16:30 - 18:30 2.00 BOPSUR P POST 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 DEFICIENCIES NOTED-CHANGE OUT BLADE I SEAL ON BSRS PER NORDIC INSPECTION PROCEDURE. I BARRIERS FOR OPENING BOPE DOORS ARE !DUAL LEAK TIGHT BARRIERS TESTED PER WELL PROGRAM-1)LEAKTIGHT SWAB&2) !LEAK TIGHT SSV. CONTINUALLY i MONITORING SSV X SWAB VOID USING SLB 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 CONFIRMATION EMAIL"IF WE HAVE NOT BEEN CONTACTED WITHIN 12-HRS OF PROVIDING NOTICE. HE INDICATED AN INSPECTOR WOULD BE CONTACTING US. 118:30 - 21:30 3.00 BOPSUR P POST HOLD PJSM WITH NIGHTSHIFT SLB i MECHANICS.REVIEW HARC AND PROCEDURES AND DISCUSS LOTO FOR GEARBOX.CONTINUE GEARBOX CHANGE-OUT. NORDIC RIG CREW CONTINUE ND BOPE. 21:30 - 22:30 I 1.00 BOPSUR P POST I 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. I OPEN MASTER VALVE 23.5 TURNS AND SSV, I READ-11 PSI ON FWV.OPEN SWAB WITH 23.5 TURNS.PUMP 1BBL METHANOL,THEN CLOSE MASTER VALVE(23.5 TURNS),SSV AND SWAB VALVE(23.5 TURNS). 22:40 - 23:20 0.67 BOPSUR P POST 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 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/1/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/0/=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/0=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/177bbls 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 NMI BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB J Pad J-17 / Lat: 070 019'37.030"0 Long: 0148°50'38.023"W J-17D Survey: MWD Survey Report - Geographic 22 March, 2013 Øbp rr„a111 sHIUGHES Survey Report-Geographic bp INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well J-17 Project: Prudhoe Bay TVD Reference: J-17C:@ 69.80usft(J-17C:) Site: PB J Pad MD Reference: J-17C:@ 69.80usft(J-17C:) Well: J-17 North Reference: True Wellbore: J-17D Survey Calculation Method: Minimum Curvature Design: J-17D Database: EDM R5K-Alaska PROD-ANCP1 Project Prudhoe Bay,GPB,PRUDHOE BAY Map System: US State Plane 1927(Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927(NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site PB J Pad,TR-11-13 Site Position: Northing: 5,968,224.22 usft Latitude: 70°19'14.845 N From: Map Easting: 641,155.79usft Longitude: 148°51'20.09 W Position Uncertainty: 0.00 usft Slot Radius: 0.000 in Grid Convergence: 1.08 ° Well J-17 API No. 500292096900 Well Position +N/-S 0.00 usft Northing: 5,970,534.00 usft Latitude: 70°19'37.301 N +E/-W 0.00 usft Easting: 642,547.00 usft Longitude: 148°50'38.22 W Position Uncertainty 0.00 usft Wellhead Elevation: usft Ground Level: 39.78 usft Wellbore J-17D API no. 500292096904 Magnetics Model Name Sample Date Declination Dip Angle Field Strength (°) (°) (nT) BGGM2012 15/04/2013 20.41 81.03 57,624 Design J-17D Audit Notes: Version: Phase: ACTUAL Tie On Depth: 11,727.47 Vertical Section: Depth From(TVD) +N/-S +E/-W Direction (usft) (usft) (usft) (1 28.47 0.00 0.00 100.64 Survey Program Date: 18/03/2013 From To (usft) (usft) Survey(Wellbore) Tool Name Description 92.80 8,892.20 J-17 GyroData(J-17) GYD-CT-CMS Gyrodata cont.casing m/s 8,931.00 11,727.47 J-17C IIFR(J-17C) MWD+IFR+MS MWD+IFR+Multi Station 11,734.50 13,498.00 MWD(J-17D) MWD MWD-Standard 22/03/2013 14:51:04 Page 2 COMPASS 5000.1 Build 61 s BAKER HUGHES Survey Report-Geographic i INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well J-17 Project: Prudhoe Bay TVD Reference: J-17C:@ 69.80usft(J-17C:) Site: PB J Pad MD Reference: J-17C:@ 69.80usft(J-17C:) Well: J-17 North Reference: True Wellbore: J-17D Survey Calculation Method: Minimum Curvature Design: J-17D Database: EDM R5K-AlaskaPROD-ANCP1 Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 11,727.47 94.57 112.60 9,032.12 -1,080.20 5,808.77 5,969,564.43 648,374.79 70°19'26.655 N 148°47'48.67 W TIP 11,734.50 94.39 112.86 9,031.57 -1,082.91 5,815.23 5,969,561.85 648,381.31 70°19'26.628 N 148°47'48.49 W KOP 11,760.86 90.15 109.42 9,030.53 -1,092.40 5,839.79 5,969,552.82 648,406.04 70°19'26.535 N 148°47'47.77 W 11,792.52 85.66 105.31 9,031.68 -1,101.84 5,869.97 5,969,543.96 648,436.39 70°19'26.442 N 148°47'46.89 W 11,820.35 84.65 101.67 9,034.03 -1,108.31 5,896.93 5,969,538.00 648,463.47 70°19'26.378 N 148°47'46.10 W 11,850.49 85.39 97.83 9,036.65 -1,113.39 5,926.52 5,969,533.48 648,493.15 70°19'26.327 N 148°47'45.24 W 11,880.42 88.31 95.97 9,038.30 -1,116.98 5,956.18 5,969,530.46 648,522.87 70°19'26.292 N 148°47'44.37 W 11,910.35 90.37 92.84 9,038.64 -1,119.28 5,986.02 5,969,528.73 648,552.74 70°19'26.269 N 148°47'43.50 W 11,940.38 92.03 89.16 9,038.01 -1,119.80 6,016.03 5,969,528.77 648,582.75 70°19'26.264 N 148°47 42.63 W 11,971.03 93.05 85.99 9,036.65 -1,118.51 6,046.62 5,969,530.65 648,613.31 70°19'26.276 N 148°47'41.73 W 12,000.41 93.01 80.99 9,035.10 -1,115.18 6,075.76 5,969,534.53 648,642.38 70°19'26.309 N 148°47 40.88 W 12,031.03 91.32 78.07 9,033.94 -1,109.62 6,105.84 5,969,540.66 648,672.35 70°19'26.363 N 148°47'40.00 W 12,061.91 89.60 73.22 9,033.69 -1,101.97 6,135.75 5,969,548.88 648,702.10 70°19'26.438 N 148°47'39.13 W 12,092.88 91.57 71.01 9,033.38 -1,092.46 6,165.22 5,969,558.94 648,731.38 70°19'26.531 N 148°47'38.27 W 12,120.25 90.34 65.33 9,032.92 -1,082.29 6,190.61 5,969,569.60 648,756.58 70°19'26.631 N 148°47'37.53 W 12,150.25 89.17 60.58 9,033.05 -1,068.65 6,217.32 5,969,583.74 648,783.02 70°19'26.765 N 148°47'36.75 W 12,180.73 89.23 52.14 9,033.48 -1,051.78 6,242.67 5,969,601.08 648,808.04 70°19'26.931 N 148°47'36.01 W 12,212.31 89.48 49.96 9,033.83 -1,031.93 6,267.23 5,969,621.39 648,832.22 70°19'27.126 N 148°47'35.29 W 12,241.29 93.13 47.69 9,033.17 -1,012.86 6,289.03 5,969,640.87 648,853.65 70°19'27.313 N 148°47'34.66 W 12,270.40 90.92 40.70 9,032.14 -992.02 6,309.30 5,969,662.10 648,873.52 70°19'27.518 N 148°47'34.06 W 12,300.09 92.37 38.64 9,031.29 -969.18 6,328.24 5,969,685.29 648,892.02 70°19'27.743 N 148°47'33.51 W 12,330.17 92.00 42.27 9,030.14 -946.31 6,347.74 5,969,708.52 648,911.08 70°19'27.967 N 148°47'32.94 W 12,360.17 92.52 46.20 9,028.96 -924.84 6,368.65 5,969,730.39 648,931.58 70°19'28.178 N 148°47'32.33 W 12,390.06 89.05 49.49 9,028.55 -904.78 6,390.80 5,969,750.86 648,953.34 70°19'28.375 N 148°47'31.68 W 12,420.03 91.50 51.51 9,028.41 -885.72 6,413.92 5,969,770.35 648,976.09 70°19'28.563 N 148°47'31.01 W 12,450.04 92.30 54.57 9,027.41 -867.69 6,437.88 5,969,788.83 648,999.71 70°19'28.740 N 148°47'30.31 W I 12,480.22 93.01 58.84 9,026.01 -851.15 6,463.08 5,969,805.85 649,024.58 70°19'28.902 N 148°47'29.57 W 12,509.81 93.16 62.34 9,024.42 -836.64 6,488.81 5,969,820.85 649,050.03 70°19'29.045 N 148°47'28.82 W1 12,540.14 88.56 58.41 9,023.96 -821.65 6,515.16 5,969,836.33 649,076.09 70°19'29.192 N 148°47'28.05 W 12,570.11 87.73 54.40 9,024.93 -805.08 6,540.11 5,969,853.37 649,100.72 70°19'29.355 N 148°47'27.32 W 12,600.37 90.61 54.07 9,025.37 -787.40 6,564.66 5,969,871.51 649,124.92 70°19'29.528 N 148°47'26.61 W 12,634.47 92.82 50.45 9,024.35 -766.54 6,591.60 5,969,892.88 649,151.47 70°19'29.733 N 148°47'25.82 W 12,665.65 93.26 45.03 9,022.70 -745.61 6,614.64 5,969,914.24 649,174.10 70°19'29.939 N 148°47'25.15 W 12,695.26 90.31 40.97 9,021.77 -723.97 6,634.82 5,969,936.26 649,193.86 70°19'30.152 N 148°47'24.56 W 12,726.07 93.44 38.80 9,020.77 -700.35 6,654.56 5,969,960.25 649,213.15 70°19'30.384 N 148°47'23.98 W 12,763.07 90.80 33.17 9,019.40 -670.44 6,676.27 5,969,990.56 649,234.29 70°19'30.678 N 148°47'23.34 W 12,802.51 88.62 28.06 9,019.60 -636.52 6,696.35 5,970,024.86 649,253.72 70°19'31.011 N 148°47'22.76 W 12,832.49 88.83 25.18 9,020.26 -609.72 6,709.78 5,970,051.90 649,266.63 70°19'31.275 N 148°47'22.36 W 12,865.33 87.70 23.67 9,021.26 -579.84 6,723.35 5,970,082.04 649,279.64 70°19'31.568 N 148°47'21.97 W 12,903.69 90.34 29.49 9,021.91 -545.56 6,740.50 5,970,116.64 649,296.13 70°19'31.905 N 148°47'21.47 W 12,936.32 89.69 28.20 9,021.91 -516.97 6,756.25 5,970,145.51 649,311.33 70°19'32.186 N 148°47'21.01 W1 12,967.03 91.14 23.79 9,021.68 -489.38 6,769.70 5,970,173.35 649,324.26 70°19'32.458 N 148°47'20.61 W 12,995.59 91.69 27.30 9,020.98 -463.62 6,782.01 5,970,199.34 649,336.07 70°19'32.711 N 148°47'20.25 W 13,025.01 93.41 30.02 9,019.67 -437.84 6,796.11 5,970,225.38 649,349.67 70°19'32.964 N 148°47'19.84 W 13,054.85 92.83 33.70 9,018.04 -412.53 6,811.83 5,970,250.98 649,364.91 70°19'33.213 N 148°47'19.38 W 13,084.85 89.08 36.45 9,017.54 -387.99 6,829.06 5,970,275.84 649,381.68 70°19'33.454 N 148°47'18.88 W 13,115.63 92.09 41.21 9,017.23 -364.03 6,848.35 5,970,300.17 649,400.51 70°19'33.690 N 148°47 18.31 W 13,144.16 89.79 45.79 9,016.76 -343.34 6,867.98 5,970,321.22 649,419.74 70°19'33.893 N 148°47'17.74 W 13,174.87 88.68 50.54 9,017.17 -322.87 6,890.86 5,970,342.12 649,442.21 70°19'34.094 N 148°47'17.07 W 13,205.13 88.41 55.16 9,017.94 -304.60 6,914.96 5,970,360.84 649,465.97 70°19'34.274 N 148°47 16.37 W 13,235.23 88.80 58.93 9,018.67 -288.24 6,940.21 5,970,377.68 649,490.89 70°19'34.434 N 148°47'15.63 W 13,273.79 89.02 64.84 9,019.41 -270.08 6,974.19 5,970,396.48 649,524.53 70°19'34.613 N 148°47'14.64 W 13,300.12 90.21 67.58 9,019.58 -259.46 6,998.28 5,970,407.56 649,548.41 70°19'34.717 N 148°47'13.93 W 22/03/2013 14.51:04 Page 3 COMPASS 5000.1 Build 61 Mill BAKER DES Survey Report-Geographic 0 bp 1NTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well J-17 Project: Prudhoe Bay TVD Reference: J-17C:@ 69.80usft(J-17C) Site: PB J Pad MD Reference: J-17C:@ 69.80usft(J-17C) Well: J-17 North Reference: True Wellbore: J-17D Survey Calculation Method: Minimum Curvature Design: J-17D Database: EDMRSK-Alaska PROD-ANCP1 Survey Measured Vertical Map Map Depth Inclination Azimuth Depth +N/-S +E/-W Northing Easting (usft) (°) (°) (usft) (usft) (usft) (usft) (usft) Latitude Longitude 13,331.04 89.14 73.29 9,019.76 -249.11 7,027.41 5,970,418.46 649,577.33 70°19'34.818 N 148°47 13.08 W 13,365.69 90.80 77.67 9,019.78 -240.42 7,060.94 5,970,427.78 649,610.69 70°19'34.903 N 148°47'12.10 W 13,395.28 91.32 79.73 9,019.23 -234.63 7,089.95 5,970,434.12 649,639.58 70°19'34.960 N 148°47'11.26 W 13,424.89 93.13 87.20 9,018.08 -231.26 7,119.32 5,970,438.05 649,668.88 70°19'34.993 N 148°47'10.40 W 13,454.89 91.35 91.34 9,016.91 -230.88 7,149.29 5,970,439.00 649,698.83 70°19'34.996 N 148°47'9.53 W 13,498.00 91.35 91.34 9,015.89 -231.89 7,192.38 5,970,438.81 649,741.93 70°19'34.986 N 148°47'8.27 W TD 22/03/2013 14:51:04 Page 4 COMPASS 5000.1 Build 61 V OF Tit! yi).* I//j.. st THE STATE Alaska Oil and Gas oft LASKA Conservation Commission GOVERNOR SEAN PARNELL 333 West Seventh Avenue ti ,¢� Anchorage, Alaska 99501-3572 AL AS Main: 907.279.1433 Fax: 907.276.7542 John McMullen Engineering Team Leader BP Exploration(Alaska), Inc. P.O. Box 199612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU J-17D BP Exploration (Alaska), Inc. Permit No: 213-012 Surface Location: 801' FNL, 1806' FEL, SEC. 9, T11N, R13E, UM Bottomhole Location: 1000' FNL, 119' FWL, SEC. 11, T11N, R13E, UM Dear Mr. McMullen: Enclosed is the approved application for permit to re-drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Sincerely, Cathy P. oerster Chair 51 DATED this I day of February,2013. cc: Department of Fish& Game,Habitat Section w/o encl. (via e-mail) Department of Environmental Conservation w/o encl. (via e-mail) iC iCIVCLi ".. STATE OF ALASKA k ALAS 1IL AND GAS CONSERVATION COMMI N JAN 2 9 2013 PERMIT TO DRILL 1 20 AAC 25.005 AOGCC 1 a.Type of work: 1 b.Proposed Well Class: 0 Development Oil ❑Service-Winj ®Single Zone • 1 c.Specify if well is proposed for: ❑Drill ❑Lateral ❑Stratigraphic Test ❑Development Gas ❑Service-Supply ❑Multiple Zone ❑Coalbed Gas ❑Gas Hydrates 0 Redrill•❑Reentry ❑Exploratory ❑Service-WAG ❑Service-Disp ❑Geothermal ❑Shale Gas 2.Operator Name: 5.Bond 0 Blanket ❑Single Well " 11.Well Name and Number: BP Exploration(Alaska) Inc. Bond No 6194193 . PBU J-17D ` 3. Address 6.Proposed Depth: 12.Field/Pool(s) P.O. Box 196612,Anchorage,Alaska 99519-6612 MD 13520' • TVD 8980'ss • Prudhoe Bay/Prudhoe Bay . 4a.Location of Well(Governmental Section): 7.Property Designation(Lease Number): Surface: ADL 028281 &028280 . 801'FNL, 1806' FEL, Sec.9,T11 N, R13E, UM • Top of Productive Horizon: 8. Land Use Permit: 13.Approximate Spud Date: 1775'FNL,3407'FWL,Sec. 10,T11 N, R13E, UM March 25,2013 Total Depth 9.Acres in Property: 14.Distance to Nearest Property: 1000'FNL, 119' FWL, Sec. 11,T11N, R13E, UM 2560 16500' . 4b. Location of Well(State Base Plane Coordinates-NAD 27): 10.KB Elevation above MSL: 69.8' ' feet 15.Distance to Nearest Well Open Surface: x 642547 • y-5970534 Zone- ASP4 GL Elevation above MSL: 39.78' • feet to Same Pool: 71: 0' 16.Deviated Wells: Kickoff Depth: 11730' feet . 17.Maximum Anticipated Pressures in psig(see 20 AAC 25.035) %SP r' e=%5 Maximum Hole Angle: 93 degrees Downhole: 3180 . Surface: 2300 18. Casing Program Specifications Top-Setting Depth-Bottom Quantity of Cement,c.f.or sacks Hole Casing Weight r Grade Coupling Length MD ND MD TVD (including stage data) 4-1/8" 3-1/2"x 3-1/4" 9.2#/6.2# L-80 STL/TC-ii 2520' 11000' 8858'ss 13520' 8980'ss 106 sx Class'G' x 2-7/8" /6.4# /STL 19. PRESENT WELL CONDITION SUMMARY(To be completed for Redrill and Re-entry Operations) Total Depth MD(ft): Total Depth ND(ft): Plugs(measured): Effective Depth MD(ft): Effective Depth ND(ft): Junk(measured): 12387' 9023' 11950' 12302' 9023' None Casing Length Size Cement Volume MD ND Conductor/Structural 110' 20"x 30" 8 cu yds Concrete 110' 110' Surface 2685' 13-3/8" 3856 cu ft Arcticset III&II 2685' 2685' Intermediate 9963' 9-5/8" 2360 cu ft Class'G', 132 cu ft Permafrost 8931' 7551' Production Liner 1460' 7" 348 cu ft Class'G' 8774'- 10234' 7429'-8435' Liner 2320' 4-1/2" 337 cu ft Class'G' 10067'- 12387' 8325'-9023' Perforation Depth MD(ft): 11350'- 12285' Perforation Depth ND(ft): 9024'-9023' 20.Attachments: ❑Property Plat IN BOP Sketch ®Drilling Program ❑Time vs Depth Plot ❑Shallow Hazard Analysis ®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: Contact Trevor Hyatt,564-4627 Printed Name John Mulle i Title Engineering Team Leader mail Trevor.Hyatt @bp.com Signature Phone 564-4711 Date Z 9 7(3 / Commission Use Only Permit To Drill,l v, Z API Number: Permit Approval Da : See cover letter for Number: 50-029-20969-04-00 �`\\\e/"J other requirements: Conditions of Approval: If box is checked,well may not be used to explore for,test,or produce coalbed methane,gas hydrates,or gas Er contained shales: Other: t)p i--r5 f y 33-6 p p 5 / Samples Req'd ❑yes "No Mud Log Req'd: ❑Yes � U No HZS Measures: L Yes ,❑,/No Directional Survey Req'd: 'Yes ❑No Spacing exception req'd: ❑Yes Ly No inclination-only svy Req'd: ❑Yes 9/No APPROVED BY APPROVED BY -2 —/�Q�(�I��MISSIONER THE COMMISSION Date Form 04R+ i d LThis permit is valid for 24 months from the date of approval(20 AAC 25.005(g)) Sub F Duplicate riyj, To: Alaska Oil & Gas Conse1 vation Commission From: Trevor Hyatt Rig: Nordic 2 by CTD Engineer Target Reservoir: Ivishak Zone 2A Date: January 24, 2013 Re: J-17D Permit to Drill Request Approval is requested for a permit to drill a CTD sidetrack from well J-17. 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. CTD Drill and Complete J-17D program: Rig Start Date: March 25, 2013 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. perA 6. V PT MV, SV, WV. p 2e —�52 7. V Double Valve IA 8. 0 Blind and bleed lines, remove well house, level pad. d ry 9. V Set TWC -24 hrs prior to rig arrival. 313 - 0 +4, Rig Work: (scheduled to begin on March 25, 2013) 1. MIRU and test BOPE to 250 psi low and 3500 psi high 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. 4. Drill Build: 4.125" OH, (12 deg/100 planne• wit rests ivi y 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 MCNUGR/CCL log 9. Test liner lap to 2000 psi. 10. Perforate liner per asset instructions (-250') • 1■1 rk7- P7 11. Freeze protect well, RDMO _/ Post Rig: p j Re-install well house and attach production lines. D 1 l3 D l� 2. Pull BPV. 3. Run generic GLVs. 4. Set LTP 5. Possible Test separator (-250' - 500' of perfs). Mud Program: • Well kill: 8.4 p•• 'dine. • Milling/drillin•: 8.6 •pg PowerPro for milling window and drilling ( 748 psi over-balance ). Disposal: • All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. • All Class I wastes will go to Pad 3 for disposal. Hole size: 4.125" Liner Program: • 3-1/2", 9.2#, L-80, STL Solid Liner 11,000' MD— 11,720' MD • 3-1/4", 6.2#, L-80, TC-II Solid Liner 11,720' MD— 12,320' MD • 2-7/8", 6.4#, L-80, STL Solid Liner 12,320' MD— 13,520' MD • A minimum of 22 bbls of 15.8 ppg cement will be used for liner cementing. (TOC 11,000' MD) • The primary barrier for this operation: a minimum EMW of 8.4 ppg. • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Well Control: • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3,500 psi. • The annular preventer will be tested to 250 psi and 3,500 psi. Directional • See attached directional plan. Maximum planned hole angle is 93°. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • Distance to nearest property— 16,500' to the North. • • Distance to nearest well within pool —420' to F-08A (abandoned), 720' to F-40 (active). • Logging • MWD directional, Gamma Ray and Resistivity will be run over all of the open hole section. • Cased hole GR/CCL/MCNL logs will be run. Perforating: • 2", 6 spf, pert guns, 1.25" CSH work string, & 2-3/8" PH6 • The primary barrier for this operation: a minimum EMW of 8.4 ppg. . • A X-over shall be made up to a safety joint including a TIW valve for all tubulars ran in hole. Anti-Collision Failures • F-08A failed Major Risk -well is P&A'd. • Q-06A failed Major Risk -well has and will continue have a downhole plug in place. Hazards • The maximum recorded H2S level on J Pad was 100 ppm on well J-28 on 5/1/2011. - Reservoir Pressure • The reservoir pressure on J-17D is expected to be 3180 psi at 8800' ND. (7.0 ppg equivalent). • Maximum expected surface pressure with gas (0.10 psi/ft) to surface is 2300 psi. • • An EMW of 8.4 ppg for this well will provide 655 psi over-balance to the reservoir. Trevor Hyatt CC: Well File CTD Engineer Joseph Lastufka •TREE:= 4-1/16"CIW WELIFEAD= McEVOY J -1 7C SAFETY.../TES: ORIG WELLBORE&SIDETRACK ACTUATOR= BAKER "A"NOT SHOWN ON DIAGRAM.**WELL ANGLE> NTTAL KB.ELE 77.0' 70°@ 11154'."'4-1/2"CHROME TBG"' BF.ELEV= 39.78' I II- KOP= 3000' Max Angle= 95°@ 11727' Oaten MD= 10893' ' II 2218' 1-14-1/2"FES X MP,D=3.813' I Datum TVD= 8800'SS • 2584' —19-518* DV R� 20"CONDUCTOR 110' GAS LET MANDRELS 13-318"CSG,72#,L-80,D=12.34T H 2685' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3235 3227 15 MMG DMY RK 0 11/30/12 Minimum ID =3"725" ( 10070' 3 6368 5608 45 MMG OMY RK 0 11/30/12 4-1/2" H E S XN NIPPLE L 2 8620 7308 37 MMG DMY RK 0 10/10/05 [ 1 9936 8240 49 KBG2 DM( BK 0 10/10/05 TOP OF 7"LNR 8774' 1 8774' 9-5/8"X 7"BKR C-2 ZXP LW 'lll-, �w/11.6'TEBK SLV,D=6.30" 1 4 1 8792' H 9-5/8"X 7"BKR MAC LNR HGR,D=6.32" Ilit WF-IPSTOCK(09/2705) —1 8952' stiti'' N+ 9-5/8"CSG,47#,L-80,D=8.681" —8931 MLLOUT WINDOW(J-17C) 8931'-8947 cd r. PERFORATION SUMMARY REF LOG:IMM11D ON 10/4/05 I ' 10006' 1-14-112"ITS X MP D=3.813" I ANGLE AT TOP PEFRF:87°@ 11350' Note:Refer to Production D8 for historical pert data SEE SFF INTERVAL Opn/Sgz DATE SoZ C x 10027' H7"X 4-1/2"BKR S-3 PKR,D=1875" 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 I 10050' H 4-1/2"FES X NP,D=3.813" 1006T 17'X 5"BKR ZXP LIP,HMC LNR HGR&TRACK SLV,D=4.440" �I 10070' —14-1/2"HESXNNP,D=3.725" 4-1/2"TBG, 12.6#, 13CR 80 VA TOP, —{ 10083' I .0152 bpf,ID=3.958" 10083' -I4-1/2"WLEG, D=3.958" r LNR,26#,L-80 BTC-M,.0383 bpf,D=6.276" H 10234' IJ �\ 10091' —�5"X 4-1 rz"XO, D=3.958' • 10417' H4-1/2"MARKER JOINT,D=4.00" o 1 11950' H 3.66"CIBP(02/10/11) 4-1/2"LNR,12.6#,L-80 LT&C, XO TO IBT-M —1 12262' —.c O PBTD — 12302' I ly D 4-1/2"LNR,12.6#,L-80 IBT-M,.0152 bpf, =3.958" H 12387' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/18183 AUDI 3 INTIAL COMPLETION 12/02/12 LET=/PJC GLV CIO(11/30/12) WELL: J-17C 10/26199 JLH CTD SIDETRACK"A" 12/02/12 PJC REFORMATTING PEWIT No:'2050820 01/21/02 NORDIC 1 CTD SIDETRACK"B" AR ND: 50-029-20969-03 10/11/05 N2ES SIDETRACK"C" SEC 9,T11 N,R13E,801'SNL&1806'WEi, 03/19/10 JLW/SV CSG CORITION 02/11/11 RIMPJC SET CUP(02/10/11) BP Exploration(Alaska) TREE= 4-1/16"CIW iN�LFEAD= WtcEVOY 51U' IO 1 LS: UF'Ci VV H L to t<L g,SIUL I RACE( ACTUATOR= BAKER J 17 D "A" SHOWN ON DIAGRAM.*`WELL ANGLE> KB.F�EI/= 77.0' 70°0 11154'.***4-1/2"CHROME MG*** proposed C TD s detrack BF.ELEV= 39.78' 1 - I KOP= 3000' Max Angle= 5°@ 11727' Datum MD= 10893' 2218' I�4-1/2"HES X NP,D=3.813" Datum TVD= 8800 SS 2584' 1-19-5/8"DV PKR 20"CONDUCTOR —I 110' GAS UFT MANDRELS 13-3/8"CSG,72#,L-80,D=12.347" H 2685' ST MD TVD DEV TYPE VLV LATCH FORT [SATE 4 3235 3227 15 MUG DOME RK 16 10/24/05 3 6368 5608 45 M 1G SO RK 20 10/24/05 2 8620 7308 37 WIG DMY RK 0 10/10/05 1 9936 8240 49 KBG2 DMY BK 0 10/10/05 TOP OF 7'LNR H 8774' ■ F. 8774' 119-5/8"X 7"BKR C-2 ZXP LIP I � �� w/11.6'TEBK SLV,D=6.30" Minimum ID = 3.725" @ 10070' ■-■ . 8792' H 9-5/8"X 7"BKR HMC LNR HGR,D=6.32" I •4-1/2" HES XN NIPPLE ■ •:• ► •• ►� MLLOUT WINDOW(J-17C) 8931'-8947' ►∎t WHIPSTOCK(09/2705) H 8962' I ►•• I10006' —I4-112"HX NPD=3.813"44 64 •••�� 1002T -1 7"X 4-1/2"BKR S-3 PKR D=3.875' EZSV(09/26/05) 8962' iii .., �� N► 10050' -I4-1/2"HES X NP,D=3.813" a-1/2^TBG STUB 9110' !1:..4•.! •% 1006T 7"X 5"BKR ZXP LIP,HMC LNR :•i .•� HGR&TIEBACK SLV,D=4.440" ►•i ••i fi .•� 10070' —4-1/2"FES XN NP, �. D=3.725" • 4-1 "TBG,12.64, 10083' \`� 10083' 14-1/2"WLEG, 9-5/8"CSG,47#,L-80,D=8.681" H 9963' — �% 113CR 80 VAM TOP, '�� ID=3.958" t�� .0152 bpf,13=3.958" 10091' 15"X 4-1/2"XO, ••• ID=3.958" �� 7"LNR,26#,L-80 BTC-M —I 10234' 0383 bpf,11:1=6-276" 10417' —4-1/2"MARKER •. , NOM,D=4.00" FERFORATIONSLMAARY •i! No�itestr: n 11,348'MD ��i o of3 12"Inerand cem ent@ -11,000' F 'op off ' " s @ -11,730'M L . REF LOG:MM)ON 10/4/05 ,%•., p 04' 11950' —3.66"CBP ANGLE AT TOPPERF:87°@ 11350' 2-7/8" L-80 liner/TD @ -13,520' • 3-1/4"x 2--7/8"X0 , (02/10/11) Note:Defer to Production DB for historical pert data SIZE SPF INTERVAL _ Opn/Sgz DATE 6.- - 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,12.60,L-80 LT&C, XO TO BT-M H 12262' FBTD -I 12302' ��es&P, 4-1/2"LNR,12.64,L-80 1BT-M,.0152 bpf,ID=3.958" H 12387' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 07/18/83 AU]3 INTIAL COMPLETION 05/29/06 CO/DIM PERF/TREE CORRECT(6/13/04) WELL: J-17C 10/26/99 JLH CTD SIDETRACK"A" 11/17/07 CAZ/PJC DRLG DRAFT CORRECTIONS FF32MT No:'2050820 01/21/02 NORDIC 1 CID SIDETRACK"B" 03/19/10 JLW/SV CSG CORRECTION AR No: 50-029-20969-03 10/11/05 WES SIDETRACK"C" 02/11/11 RM-VPJC SET CBP(02/10/11) SEC 9,T11 N,R13E,801'SNL&1806'VVEL 11/05/05 KSB/TLH GLV C/O(10/24/05) 02/22/06 SVV/TLH FEW CORRECTION BP Exploration(Alaska) 0 0 0 03 1 0 Q a. 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LL$ ;; i i O V i i RPiin n n n n E sn�°nm=nu"a'&6mmb�6 oW t / 14 44 4 } 1 1 } ► 4 1 4 4 t / 1 i I 1 f 1 $ t f t i 1 1 f / t 1 f € ax u� ; 5558Rai8888559 .1Q E$ MI ' 0:8$888$$$8y3$$8$ hia 2. 2. +o °m o0 0 a 0 2 0" 6 I I ilion.0• , ti V a l API.IIIIIIIIIIW\ 0 O n$e o�da h //,---011111 \; A ,n f9 ILL y d y B,Ed / -, (n map 0 an" • i Q¢ C 060 c°al 0 W O! f� ,f1 M _ I ��tf:l�_ �L�,d/�, m U i.m" o°, O Iaau o� H N a YT) w1 O 8 3e Z w ' M N T Li- Q � �'a 0 s _ N N k m ^ 1 N n rik II BAKER HUGHES INTEQ North America - ALASKA - BP Prudhoe Bay PB J Pad J-17 / Lat: 070°19'37.030"0 Long: 0148°50'38.023"W J-17D Plan 2 Travelling Cylinder Report 25 January, 2013 Qbp BAKER HUGHES Travelling Cylinder Report 0 by INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well J-17 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB J Pad MD Reference: J-17C:@ 69.80ft(J-17C:) Site Error: 0.00ft North Reference: True Reference Well: J-17 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore J-17D Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 2 Offset TVD Reference: Offset Datum Reference Plan 2 Filter type: GLOBAL FILTER APPLIED:All wellpaths within 200'+100/1000 of refer( Interpolation Method: MD Interval 25.00ft Error Model: ISCWSA Depth Range: 11,727.47 to 13,520.00ft Scan Method: Tray.Cylinder North Results Limited by: Maximum center-center distance of 1,549.15ft Error Surface: Elliptical Conic Survey Tool Program Date 1/25/2013 From To (ft) (ft) Survey(Wellbore) Tool Name Description 92.80 8,892.20 J-17 GyroData(J-17) GYD-CT-CMS Gyrodata cont.casing m/s 8,931.00 11,727.47 J-17C IIFR(J-17C) MWD+IFR+MS MWD+IFR+Multi Station 11,727.47 13,520.00 Plan 2(J-17D) MWD MWD-Standard Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (in) (in) 13,520.00 8,979.86 2 7/8" 2.875 4.125 10,226.82 8,360.87 DRILLING LINER 1 7.000 8.500 Summary Reference Offset Centre to No-Go Allowable Measured Measured Centre Distance Deviation Warning Site Name Depth Depth Distance (ft) from Plan Offset Well-Wellbore-Design (ft) (ft) (ft) (ft) PB F Pad F-02-F-02A-F-02A 12,725.00 11,700.00 1,358.66 205.89 1,152.76 Pass-Major Risk F-08-F-08-F-08 12,375.00 11,100.00 692.59 499.61 212.06 Pass-Major Risk F-08-F-08A-F-08A 13,437.70 12,675.00 413.14 487.79 -72.23 FAIL-Major Risk F-08-F-08B-F-08B 12,609.74 11,050.00 685.44 496.53 215.96 Pass-Major Risk F-40-F-40-F-40 13,350.00 10,500.00 677.83 237.25 443.00 Pass-Major Risk PB J Pad J-02-J-02B-J-02B Out of range J-05-J-05A-J-05A Out of range J-05-J-05B-J-05B Out of range J-05-J-05C-J-05C Out of range J-08-J-08A-J-08A Out of range J-15-J-15A-J-15A Out of range J-15-J-15B-J-15B Out of range J-15-J-15B-Plan#4 Out of range J-17-J-17C-J-17C 11,749.99 11,750.00 0.31 1.12 -0.72 FAIL-Major Risk J-18-J-18-J-18 12,275.00 11,250.00 1,503.85 800.57 833.14 Pass-Major Risk J-18-J-18A-J-18A 12,275.00 11,250.00 1,503.85 800.57 833.14 Pass-Major Risk J-25-J-25A-Plan#6 Out of range PB Q Pad Q-06-Q-06A-Q-06A 12,208.29 12,518.90 836.92 1,047.83 -205.22 FAIL-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/25/2013 10:50..33AM Page 2 of 16 COMPASS 2003.16 Build 73 Wei MI BAKER HUGHES Travelling Cylinder Report ss :bp INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well J-17 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB J Pad MD Reference: J-17C.@ 69.80ft(J-17C:) Site Error: 0.00ft North Reference: True Reference Well: J-17 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore J-17D Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 2 Offset TVD Reference: Offset Datum Offset Design PB F Pad- F-02-F-02A-F-02A Offset Site Error: O.00ft Survey Program: 100-GYD-CT-CMS,8625-BOSS-GYRO,10400-MWD Rule Assigned:Major Risk Offset Well Error: 0.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) 1°) (f) (ft) (ft) (ft) (ft) (ft) 12,500.00 8,964.78 12,025.00 8,964.75 32.72 34.75 130.77 -1,813.82 7,623.62 0.29 1,473.72 207.28 1,26644 Pass-Major Risk 12,500.00 8,964.78 12,050.00 8,96525 32.72 34.86 130.79 -1,838.60 7,626.82 0.29 1,492.16 207.61 1,284.56 Pass-Major Risk 12,500.00 8,964.78 12,075.00 8,965.25 32.72 34.97 130.79 -1,863.20 7,631.32 0.29 1,511.65 207.92 1,303.73 Pass-Major Risk 12,500.00 8,964.78 12,100.00 8,965.29 32.72 35.07 130.80 -1,887.85 7,636.52 0.29 1,531.72 208.21 1,323.51 Pass-Major Risk 12,510.17 8,964.83 12,000.00 8,964.10 32.75 34.64 129.54 -1,788.87 7,622.24 0.29 1,456.64 206.28 1,250.35 Pass-Major Risk 12,515.06 8,964.87 11,975.00 8,963.80 32.77 34.52 128.94 -1,763.88 7,622.66 0.29 1,441.14 205.58 1,235.56 Pass-Major Risk 12,525.00 8,964.96 11,900.00 8,967.03 32.81 34.15 127.88 -1,689.36 7,630.12 0.29 1,401.15 203.71 1,197.45 Pass-Major Risk 12,525.00 8,964.96 11,925.00 8,965.50 32.81 34.28 127.82 -1,714.20 7,627.77 0.29 1,414.32 204.11 1,210.22 Pass-Major Risk 12,525.00 8,964.96 11,950.00 8,964.28 32.81 34.40 127.78 -1,738.97 7,624.61 0.29 1,427.13 204.49 1,222.63 Pass-Major Risk 12,536.71 8,965.11 11,875.00 8,968.08 32.85 34.02 126.53 -1,664.62 7,633.50 0.29 1,389.01 202.38 1,186.64 Pass-Major Risk 12,550.00 8,965.32 11,800.00 8,967.57 32.90 33.57 124.91 -1,594.00 7,657.86 0.29 1,368.11 199.92 1,168.20 Pass-Major Risk 12,550.00 8,965.32 11,825.00 8,968.33 32.90 33.73 124.96 -1,616.70 7,647.42 0.29 1,372.36 200.38 1,172.00 Pass-Major Risk 12,550.00 8,965.32 11,850.00 8,968.50 32.90 33.88 124.98 -1,640.29 7,639.19 0.29 1,379.37 200.83 1,178.55 Pass-Major Risk 12,710.14 8,969.51 11,775.00 8,966.55 33.44 33.42 129.53 -1,571.85 7,669.40 0.29 1,364.91 208.17 1,156.73 Pass-Major Risk 12,725.00 8,969.90 11,700.00 8,964.86 33.50 32.97 127.63 -1,509.50 7,710.94 0.29 1,358.66 205.89 1,152.76 Pass-Major Risk,CC,ES, 12,725.00 8,969.90 11,725.00 8,964.53 33.50 33.12 127.65 -1,529.97 7,696.61 0.29 1,359.83 206.31 1,153.50 Pass-Major Risk 12,725.00 8,969.90 11,750.00 8,965.39 33.50 33.27 127.71 -1,550.98 7,683.10 0.29 1,362.41 206.74 1,155.66 Pass-Major Risk 12,735.99 8,970.20 11,675.00 8,966.16 33.54 32.82 126.38 -1,490.22 7,726.79 0.29 1,359.72 204.67 1,155.04 Pass-Major Risk 12,750.00 8,970.57 11,625.00 8,968.65 33.60 32.51 124.79 -1,455.86 7,762.94 0.29 1,368.95 202.75 1,166.20 Pass-Major Risk 12,750.00 8,970.57 11,650.00 8,967.56 33.60 32.66 124.77 -1,472.26 7,744.11 0.29 1,363.18 203.16 1,160.01 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/25/2013 10:50:33AM Page 3 of 16 COMPASS 2003.16 Build 73 BM BAKER HUGHES Travelling Cylinder Report 0 bp INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well J-17 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB J Pad MD Reference: J-17C:@ 69.80ft(J-17C:) Site Error: 0.00ft North Reference: True Reference Well: J-17 Survey Calculation Method: Minimum Curvature Well Error: O.00ft Output errors are at 1.00 sigma Reference Wellbore J-17D Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 2 Offset TVD Reference: Offset Datum Offset Design PB F Pad- F-08-F-08-F-08 Offset Site Error: 0.00 ft Survey Program: 100-CB-MAG-MS Rule Assigned:Major Risk Offset Well Error: 0.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +NI-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) lit) (ft) (ft) (ft) (1 (ft) lit) (ft) (ft) (ft) (ft) 12,375.00 8,966.48 11,100.00 8,836.28 32.16 131.36 -25.83 -419.91 5,976.23 0.46 692.59 499.61 212.06 Pass-Major Risk,ES,SF 12,600.00 8,966.52 11,075.00 8,816.80 33.05 131.00 -44.96 -413.62 5,990.59 0.46 689.25 487.80 225.29 Pass-Major Risk 12,609.74 8,966.79 11,050.00 8,797.41 33.08 130.64 -42.06 -407.28 6,005.04 0.46 685.44 489.27 223.00 Pass-Major Risk 12,615.14 8,966.94 11,025.00 8,778.09 33.09 130.27 -39.65 -400.89 6,019.57 0.46 682.41 489.55 223.13 Pass-Major Risk 12,625.00 8,967.21 10,950.00 8,720.64 33.12 129.17 -33.15 -381.42 6,063.67 0.46 677.85 488.61 232.15 Pass-Major Risk 12,625.00 8,967.21 10,975.00 8,739.67 33.12 129.54 -34.93 -387.97 6,048.84 0.46 678.60 489.70 227.25 Pass-Major Risk 12,625.00 8,967.21 11,000.00 8,758.85 33.12 129.91 -36.71 -394.46 6,034.17 0.46 680.16 490.77 223.52 Pass-Major Risk 12,638.05 8,967.56 10,925.00 8,701.77 33.16 128.79 -29.86 -374.79 6,078.66 0.46 677.58 490.25 235.27 Pass-Major Risk,CC 12,650.00 8,967.89 10,850.00 8,646.08 33.20 127.65 -23.28 -354.31 6,124.53 0.46 681.19 489.09 256.64 Pass-Major Risk 12,650.00 8,967.89 10,875.00 8,664.52 33.20 128.04 -24.99 -361.29 6,109.17 0.46 679.16 490.25 247.73 Pass-Major Risk 12,650.00 8,967.89 10,900.00 8,683.06 33.20 128.42 -26.72 -368.09 6,093.83 0.46 678.10 491.39 240.05 Pass-Major Risk 12,663.49 8,968.25 10,825.00 8,627.71 33.25 127.26 -20.04 -347.11 6,139.88 0.46 683.93 490.15 264.49 Pass-Major Risk 12,675.00 8,968.56 10,800.00 8,609.41 33.29 126.87 -17.06 -339.67 6,155.21 0.46 687.63 490.61 274.06 Pass-Major Risk 12,875.00 8,973.79 10,750.00 8,573.08 33.99 126.08 -32.34 -324.47 6,186.01 0.46 692.54 458.43 317.94 Pass-Major Risk 12,875.00 8,973.79 10,775.00 8,591.20 33.99 126.48 -34.13 -332.05 6,170.55 0.46 691.42 459.44 309.37 Pass-Major Risk 12,886.64 8,974.07 10,725.00 8,555.06 34.01 125.68 -29.20 -316.98 6,201.64 0.46 694.14 461.53 324.15 Pass-Major Risk 12,892.68 8,974.21 10,700.00 8,537.13 34.02 125.29 -26.73 -309.60 6,217.43 0.46 696.38 462.55 332.85 Pass-Major Risk 12,900.00 8,974.37 10,650.00 8,501.61 34.04 124.49 -22.40 -295.12 6,249.49 0.46 702.55 462.88 353.84 Pass-Major Risk 12,900.00 8,974.37 10,675.00 8,519.31 34.04 124.89 -24.13 -302.31 6,233.37 0.46 699.18 463.92 342.13 Pass-Major Risk 12,911.63 8,974.63 10,625.00 8,484.03 34.07 124.09 -19.34 -288.03 6,265.79 0.46 706.36 465.50 363.71 Pass-Major Risk 12,918.26 8,974.77 10,600.00 8,466.57 34.09 123.69 -16.89 -281.05 6,282.26 0.46 710.72 466.43 375.42 Pass-Major Risk 12,925.00 8,974.91 10,575.00 8,449.22 34.11 123.28 -14.46 -274.10 6,298.87 0.46 715.63 467.29 387.83 Pass-Major Risk 12,931.97 8,975.05 10,550.00 8,431.96 34.13 122.88 -12.04 -267.06 6,315.53 0.46 721.18 468.14 400.90 Pass-Major Risk 12,939.08 8,975.19 10,525.00 8,414.77 34.15 122.47 -9.64 -259.91 6,332.22 0.46 727.37 468.94 414.64 Pass-Major Risk 12,950.00 8,975.42 10,475.00 8,380.63 34.18 121.66 -5.38 -245.30 6,365.70 0.46 741.61 469.42 444.42 Pass-Major Risk 12,950.00 8,975.42 10,500.00 8,397.67 34.18 122.07 -6.84 -252.65 6,348.95 0.46 734.19 470.58 428.56 Pass-Major Risk 12,961.73 8,975.66 10,450.00 8,363.61 34.22 121.25 -2.58 -237.87 6,382.43 0.46 749.63 471.02 459.40 Pass-Major Risk 12,975.00 8,975.92 10,400.00 8,329.63 34.27 120.43 1.66 -222.75 6,415.85 0.46 767.50 471.49 492.07 Pass-Major Risk 12,975.00 8,975.92 10,425.00 8,346.61 34.27 120.84 0.34 -230.35 6,399.15 0.46 758.30 472.68 474.98 Pass-Major Risk 12,986.36 8,976.15 10,375.00 8,312.63 34.31 120.01 4.22 -214.63 6,432.28 0.46 777.52 472.48 508.77 Pass-Major Risk 13,000.00 8,976.43 10,325.00 8,278.58 34.37 119.16 7.96 -195.58 6,463.53 0.46 800.61 472.29 544.41 Pass-Major Risk 13,000.00 8,976.43 10,350.00 8,295.61 34.37 119.58 6.95 -205.57 6,448.19 0.46 788.61 473.57 526.05 Pass-Major Risk 13,014.12 8,976.71 10,300.00 8,261.59 34.43 118.73 10.51 -184.69 6,478.28 0.46 813.45 473.16 562.34 Pass-Major Risk 13,025.00 8,976.93 10,275.00 8,244.62 34.48 118.29 12.59 -173.24 6,492.62 0.46 826.97 473.25 580.75 Pass-Major Risk 13,033.80 8,977.10 10,250.00 8,227.64 34.52 117.86 14.35 -161.40 6,506.64 0.46 841.05 472.92 599.40 Pass-Major Risk 13,043.80 8,977.30 10,225.00 8,210.66 34.57 117.42 16.18 -149.19 6,520.34 0.65 855.63 472.78 617.99 Pass-Major Risk 13,050.00 8,977.42 10,200.00 8,193.69 34.60 116.98 17.48 -136.62 6,533.72 0.65 870.69 471.92 636.91 Pass-Major Risk 13,064.05 8,977.70 10,175.00 8,176.86 34.67 116.52 19.65 -123.79 6,547.03 0.65 885.94 471.53 655.72 Pass-Major Risk 13,075.00 8,977.91 10,150.00 8,160.21 34.73 116.07 21.40 -110.75 6,560.36 0.65 901.34 470.71 674.45 Pass-Major Risk 13,084.69 8,978.10 10,125.00 8,143.75 34.79 115.62 22.96 -97.50 8,573.72 0.65 916.84 469.66 693.05 Pass-Major Risk 13,100.00 8,978.39 10,100.00 8,127.48 34.88 115.16 25.12 -84.03 6,587.09 0.65 932.47 468.51 711.69 Pass-Major Risk 13,105.63 8,978.50 10,075.00 8,111.39 34.91 114.71 26.10 -70.36 6,600.48 0.65 948.13 467.13 729.88 Pass-Major Risk 13,116.17 8,978.70 10,050.00 8,095.50 34.98 114.25 27.61 -56.48 6,613.89 0.65 963.90 465.60 748.11 Pass-Major Risk 13,125.00 8,978.86 10,025.00 8,079.80 35.03 113.80 28.88 -42.39 6,627.30 0.65 979.74 463.97 766.14 Pass-Major Risk 13,137.28 8,979.09 10,000.00 8,064.29 35.12 113.34 30.51 -28.10 6,640.73 0.65 995.64 462.04 784.18 Pass-Major Risk 13,150.00 8,979.32 9,975.00 8,048.98 35.20 112.87 32.15 -13.60 6,654.16 0.76 1,011.60 459.93 802.06 Pass-Major Risk 13,158.32 8,979.47 9,950.00 8,033.84 35.26 112.40 33.24 1.11 6,667.56 0.76 1,027.64 457.87 819.72 Pass-Major Risk 13,168.76 9979.66 9,925.00 8,018.89 35.34 111.93 34.53 16.03 6,680.93 0.76 1,043.74 455.49 837.41 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/25/2013 10:50:33AM Page 4 of 16 COMPASS 2003.16 Build 73 ' AI BAKER a",,°- HUGHES Travelling Cylinder Report ° ia, INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well J-17 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB J Pad MD Reference: J-17C:@ 69.80ft(J-17C:) Site Error: 0.00ft North Reference: True Reference Well: J-17 Survey Calculation Method: Minimum Curvature Well Error: O.00ft Output errors are at 1.00 sigma Reference Wellbore J-17D Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 2 Offset TVD Reference: Offset Datum Offset Design PB F Pad- F-08-F-08-F-08 Offset Site Error: 0.00ft Survey Program: 100-CB-MAG-MS Rule Assigned:Major Risk Offset Well Error: 0.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (6) (°) (ft) (ft) (n) (R) (ft) (ft) 13,175.00 8,979.77 9,900.00 8,004.13 35.38 111.45 35.30 31.15 6,694.28 0.76 1,059.93 453.45 854.76 Pass-Major Risk 13,189.22 8,980.02 9,875.00 7,989.49 35.49 110.97 36.98 46.39 6,707.65 0.76 1,076.16 450.33 872.60 Pass-Major Risk 13,200.00 8,980.21 9,850.00 7,974.95 35.58 110.49 38.23 61.68 6,721.05 0.76 1,092.48 447.45 890.25 Pass-Major Risk 13,209.18 8,980.37 9,825.00 7,960.50 35.65 110.01 39.27 77.02 6,734.51 0.76 1,108.89 444.68 907.78 Pass-Major Risk 13,218.97 8,980.54 9,800.00 7,946.15 35.73 109.53 40.36 92.42 6,748.00 0.76 1,125.37 441.68 925.38 Pass-Major Risk 13,225.00 8,980.65 9,775.00 7,931.89 35.78 109.04 40.99 107.92 6,761.46 0.76 1,141.97 439.27 942.70 Pass-Major Risk 13,238.08 8,980.88 9,750.00 7,917.72 35.89 108.55 42.43 123.55 6,774.87 0.76 1,158.66 435.44 960.68 Pass-Major Risk 13,250.00 8,981.09 9,725.00 7,903.66 36.00 108.07 43.71 139.31 6,788.24 0.76 1,175.49 431.63 978.67 Pass-Major Risk 13,256.51 8,981.20 9,700.00 7,889.67 36.05 107.58 44.33 155.20 6,801.55 0.76 1,192.43 428.92 996.15 Pass-Major Risk 13,265.42 8,981.36 9,675.00 7,875.71 36.13 107.09 45.21 171.18 6,814.77 0.76 1,209.54 425.60 1,014.01 Pass-Major Risk 13,381.79 8,981.53 9,650.00 7,861.78 37.20 106.61 37.66 187.28 6,827.88 0.76 1,225.40 442.87 1,017.64 Pass-Major Risk 13,391.17 8,981.42 9,625.00 7,847.88 37.28 106.12 38.70 203.47 6,840.89 0.76 1,241.24 440.11 1,034.41 Pass-Major Risk 13,400.00 8,981.31 9,600.00 7,833.97 37.36 105.63 39.67 219.72 6,853.84 0.76 1,257.27 437.33 1,051.29 Pass-Major Risk 13,409.40 8,981.19 9,575.00 7,820.02 37.45 105.14 40.69 235.92 6,866.80 0.76 1,273.47 434.37 1,068.38 Pass-Major Risk 13,418.27 8,981.08 9,550.00 7,806.02 37.53 104.65 41.65 252.06 6,879.78 0.76 1,289.85 431.40 1,085.61 Pass-Major Risk 13,425.00 8,981.00 9,525.00 7,791.98 37.60 104.17 42.33 268.15 6,892.78 0.76 1,306.39 428.78 1,102.79 Pass-Major Risk 13,435.47 8,980.87 9,500.00 7,777.83 37.70 103.69 43.46 284.20 6,905.72 0.76 1,323.16 425.34 1,120.57 Pass-Major Risk 13,450.00 8,980.70 9,450.00 7,749.12 37.84 102.72 44.92 316.24 6,931.18 0.76 1,357.56 419.62 1,156.33 Pass-Major Risk 13,450.00 8,980.70 9,475.00 7,763.55 37.84 103.20 45.08 300.23 6,918.52 0.76 1,340.25 420.83 1,139.20 Pass-Major Risk 13,459.63 8,980.58 9,425.00 7,734.55 37.94 102.24 45.93 332.24 6,943.71 0.76 1,375.17 416.11 1,174.91 Pass-Major Risk 13,467.25 8,980.49 9,400.00 7,719.86 38.02 101.77 46.70 348.20 6,956.14 0.76 1,393.03 413.05 1,193.50 Pass-Major Risk 13,475.00 8,980.39 9,350.00 7,690.13 38.09 100.82 47.30 380.00 6,980.72 0.76 1,429.45 408.75 1,230.48 Pass-Major Risk 13,475.00 8,980.39 9,375.00 7,705.05 38.09 101.30 47.47 364.12 6,968.48 0.76 1,411.11 409.90 1,212.36 Pass-Major Risk 13,488.92 8,980.23 9,325.00 7,675.09 38.24 100.35 48.82 395.84 6,992.89 0.76 1,447.94 403.89 1,250.59 Pass-Major Risk 13,500.00 8,980.10 9,275.00 7,644.73 38.36 99.42 49.81 427.44 7,016.97 0.76 1,485.58 398.59 1,289.29 Pass-Major Risk 13,500.00 8,980.10 9,300.00 7,659.96 38.36 99.89 49.99 411.66 7,004.97 0.76 1,466.67 399.67 1,270.66 Pass-Major Risk 13,508.90 8,979.99 9,250.00 7,629.42 38.45 98.96 50.72 443.20 7,028.89 0.76 1,504.68 394.93 1,309.44 Pass-Major Risk 13,520.00 8,979.86 9,225.00 7,614.01 38.57 98.49 51.89 458.92 7,040.74 0.76 1,523.98 390.53 1,330.20 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/25/2013 10:50:33AM Page 5 of 16 COMPASS 2003.16 Build 73 EnI BAKER HUGHES Travelling Cylinder Report INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well J-17 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB J Pad MD Reference: J-17C:@ 69.80ft(J-17C:) Site Error: 0.00ft North Reference: True Reference Well: J-17 Survey Calculation Method: Minimum Curvature Well Error: 0.O0ft Output errors are at 1.00 sigma Reference Wellbore J-17D Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 2 Offset TVD Reference: Offset Datum Offset Design PB F Pad- F-08-F-08A-F-08A Offset Site Error: 0.00ft Survey Program: 100-CB-MAG-MS,11112-MWD Rule Assigned:Major Risk Offset Well Error: 0.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Well bore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (k) (ft) (ft) (°) (ft) (ft) (ft) (ft) (ft) (ft) 12,600.00 8,966.52 11,075.00 8,817.36 33.05 131.29 -45-01 -412.62 5,990.99 0.29 689.34 488.47 224.66 Pass-Major Risk 12,600.00 8,966.52 11,100.00 8,838.64 33.05 131.49 -46.91 -415.30 5,978.16 0.29 694.12 489.03 226.04 Pass-Major Risk 12,609.74 8,966.79 11,050.00 8,797.41 33.08 131.06 -42.06 -407.28 6,005.04 0.29 685.44 490.34 221.96 Pass-Major Risk 12,615.14 8,966.94 11,025.00 8,778.09 33.09 130.70 -39.65 -400.89 6,019.57 0.29 682.41 490.62 222.11 Pass-Major Risk 12,625.00 8,967.21 10,950.00 8,720.64 33.12 129.58 -3115 -381.42 6,063.67 0.29 677.85 489.67 231.18 Pass-Major Risk 12,625.00 8,967.21 10,975.00 8,739.67 33.12 129.96 -34.93 -387.97 6,048.84 0.29 678.60 490.76 226.26 Pass-Major Risk 12,625.00 8,967.21 11,000.00 8,758.85 33.12 130.33 -36.71 -394.46 6,034.17 0.29 680.16 491.84 222.51 Pass-Major Risk 12,638.05 8,967.56 10,925.00 8,701.77 33.16 129.21 -29.86 -374.79 6,078.66 0.29 677.58 491.31 234.32 Pass-Major Risk 12,650.00 8,967.89 10,850.00 8,646.08 33.20 128.05 -23.28 -354.31 6,124.53 0.29 681.19 490.13 255.74 Pass-Major Risk 12,650.00 8,967.89 10,875.00 8,664.52 33.20 128.45 -24.99 -361.29 6,109.17 0.29 679.16 491.30 246.81 Pass-Major Risk 12,650.00 8,967.89 10,900.00 8,683.06 33.20 128.83 -26.72 -368.09 6,093.83 0.29 678.10 492.44 239.11 Pass-Major Risk 12,663.49 8,968.25 10,825.00 8,627.71 33.25 127.66 -20.04 -347.11 6,139.88 0.29 683.93 491.19 263.61 Pass-Major Risk 12,675.00 8,968.56 10,800.00 8,609.41 33.29 127.27 -17.06 -339.67 6,155.21 0.29 687.63 491.64 273.20 Pass-Major Risk 12,875.00 8,973.79 10,750.00 8,573.08 33.99 126.48 -32.34 -324.47 6,186.01 0.29 692.54 459.35 317.24 Pass-Major Risk 12,875.00 8,973.79 10,775.00 8,591.20 33.99 126.88 -34.13 -332.05 6,170.55 0.29 691.42 460.36 308.64 Pass-Major Risk 12,886.64 8,974.07 10,725.00 8,555.06 34.01 126.08 -29.20 -316.98 6,201.64 0.29 694.14 462.45 323.46 Pass-Major Risk 12,892.68 8,974.21 10,700.00 8,537.13 34.02 125.68 -26.73 -309.60 6,217.43 0.29 696.38 463.47 332.18 Pass-Major Risk 12,900.00 8,974.37 10,650.00 8,501.61 34.04 124.87 -22.40 -295.12 6,249.49 0.29 702.55 463.79 353.22 Pass-Major Risk 12,900.00 8,974.37 10,675.00 8,519.31 34.04 125.28 -24.13 -302.31 6,233.37 0.29 699.18 464.84 341.49 Pass-Major Risk 12,900.00 8,974.37 11,475.00 8,974.42 34.04 130.94 -64.76 -157.08 5,873.58 0.29 918.23 479.28 454.61 Pass-Major Risk 12,900.00 8,974.37 11,500.00 8,975.38 34.04 130.82 -64.79 -135.08 5,885.41 0.29 916.87 478.90 453.61 Pass-Major Risk 12,911.63 8,974.63 10,625.00 8,484.03 34.07 124.47 -19.34 -288.03 6,265.79 0.29 706.36 466.42 363.11 Pass-Major Risk 12,912.11 8,974.64 11,525.00 8,976.20 34.07 130.70 -63.39 -114.27 5,899.22 0.29 913.65 482.73 446.32 Pass-Major Risk 12,918.26 8,974.77 10,600.00 8,466.57 34.09 124.07 -16.89 -281.05 6,282.26 0.29 710.72 467.34 374.85 Pass-Major Risk 12,925.00 8,974.91 10,575.00 8,449.22 34.11 123.66 -14.46 -274.10 6,298.87 0.29 715.63 468.20 387.28 Pass-Major Risk 12,925.00 8,974.91 11,550.00 8,976.61 34.11 130.57 -61.87 -95.10 5,915.24 0.29 908.20 486.58 436.75 Pass-Major Risk 12,925.00 8,974.91 11,575.00 8,975.72 34.11 130.45 -61.78 -76.85 5,932.29 0.29 901.79 486.18 430.70 Pass-Major Risk 12,931.97 8,975.05 10,550.00 8,431.96 34.13 123.25 -12.04 -267.06 6,315.53 0.29 721.18 469.06 400.38 Pass-Major Risk 12,937.00 8,975.15 11,600.00 8,974.11 34.14 130.33 -60.24 -60.29 5,950.92 0.29 893.59 489.54 418.86 Pass-Major Risk 12,939.08 8,975.19 10,525.00 8,414.77 34.15 122.85 -9.64 -259.91 6,332.22 0.29 727.37 469.85 414.15 Pass-Major Risk 12,950.00 8,975.42 10,475.00 8,380.63 34.18 122.03 -5.38 -245.30 6,365.70 0.29 741.61 470.32 443.97 Pass-Major Risk 12,950.00 8,975.42 10,500.00 8,397.67 34.18 122.44 -6.84 -252.65 6,348.95 0.29 734.19 471.49 428.09 Pass-Major Risk 12,950.00 8,975.42 11,625.00 8,972.95 34.18 130.21 -58.60 -46.25 5,971.56 0.29 882.85 492.94 404.39 Pass-Major Risk 12,950.00 8,975.42 11,650.00 8,972.96 34.18 130.09 -58.57 -33.50 5,993.06 0.29 871.00 492.53 392.86 Pass-Major Risk 12,960.18 8,975.62 11,675.00 8,973.37 34.22 129.98 -57.37 -22.46 6,015.48 0.29 857.83 494.95 376.98 Pass-Major Risk 12,961.73 8,975.66 10,450.00 8,363.61 34.22 121.61 -2.58 -237.87 6,382.43 0.29 749.63 471.92 458.97 Pass-Major Risk 12,975.00 8,975.92 10,400.00 8,329.63 34.27 120.79 1.66 -222.75 6,415.85 0.29 767.50 472.38 491.69 Pass-Major Risk 12,975.00 8,975.92 10,425.00 8,346.61 34.27 121.20 0.34 -230.35 6,399.15 0.29 758.30 473.58 474.58 Pass-Major Risk 12,975.00 8,975.92 11,700.00 8,973.70 34.27 129.87 -55.62 -13.40 6,038.77 0.29 843.30 498.33 358.67 Pass-Major Risk 12,975.00 8,975.92 11,725.00 8,974.03 34.27 129.77 -55.61 -5.58 6,062.51 0.29 827.82 497.94 343.48 Pass-Major Risk 12,975.00 8,975.92 11,750.00 8,974.29 34.27 129.66 -55.60 3.66 6,085.73 0.29 814.07 497.54 330.04 Pass-Major Risk 12,986.36 8,976.15 10,375.00 8,312.63 34.31 120.36 4.22 -214.63 6,432.28 0.29 777.52 473.36 508.42 Pass-Major Risk 12,990.47 8,976.24 11,775.00 8,974.03 34.33 129.54 -53.73 14.74 6,108.14 0.29 802.22 500.72 314.60 Pass-Major Risk 13,000.00 8,976.43 10,325.00 8,278.58 34.37 119.51 7.96 -195.58 6,463.53 0.29 800.61 473.17 544.09 Pass-Major Risk 13,000.00 8,976.43 10,350.00 8,295.61 34.37 119.93 6.95 -205.57 6,448.19 0.29 788.61 474.44 525.72 Pass-Major Risk !I 13,000.00 8,976.43 11,800.00 8,973.28 34.37 129.44 -52.52 24.99 6,130.91 0.29 790.06 502.28 300.59 Pass-Major Risk 13,000.00 8,976.43 11,825.00 8,972.24 34.37 129.34 -52.41 32.57 6,154.70 0.29 775.90 501.89 286.73 Pass-Major Risk 13,013.67 8,976.70 11,850.00 8,971.46 34.43 129.24 -50.70 37.32 6,179.21 0.29 759.59 504.12 267.80 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/25/2013 10:50:33AM Page 6 of 16 COMPASS 2003.16 Build 73 Mill BAKER „h,�4"� HUGHES Travelling Cylinder Report " i> % INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well J-17 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB J Pad MD Reference: J-17C:@ 69.80ft(J-17C:) Site Error: 0.00ft North Reference: True Reference Well: J-17 Survey Calculation Method: Minimum Curvature Well Error: O.00ft Output errors are at 1.00 sigma Reference Wellbore J-17D Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 2 Offset TVD Reference: Offset Datum Offset Design PB F Pad- F-08-F-08A-F-08A Offset Site Error: 0.00 ft Survey Program: 100-CB-MAG-MS,11112-MWD Rule Assigned:Major Risk Offset Well Error: 0.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (1 (ft) (ft) (ft) (ft) (ft) (ft) 13,014.12 8,976.71 10,300.00 8,261.59 34.43 119.08 10.51 -184.69 6,478.28 0.29 813.45 474.03 562.05 Pass-Major Risk 13,025.00 8,976.93 10,275.00 8,244.62 34.48 118.64 12.59 -173.24 6,492.62 0.29 826.97 474.11 580.47 Pass-Major Risk 13,025.00 8,976.93 11,875.00 8,971.11 34.48 129.16 -49.31 39.40 6,204.11 0.29 741.69 505.65 248.01 Pass-Major Risk 13,025.00 8,976.93 11,900.00 8,971.28 34.48 129.08 -49.29 39.40 6,229.11 0.29 722.53 505.32 229.08 Pass-Major Risk 13,033.38 8,977.10 11,925.00 8,972.13 34.52 129.01 -48.33 39.55 6,254.09 0.29 703.73 506.21 209.08 Pass-Major Risk 13,033.80 8,977.10 10,250.00 8,227.64 34.52 118.20 14.35 -161.40 6,506.64 0.29 841.05 473.78 599.14 Pass-Major Risk 13,040.38 8,977.24 11,950.00 8,973.55 34.55 128.93 -47.59 40.29 6,279.04 0.29 685.58 506.80 190.05 Pass-Major Risk 13,043.80 8,977.30 10,225.00 8,210.66 34.57 117.76 16.18 -149.19 6,520.34 0.47 855.63 473.63 617.74 Pass-Major Risk 13,050.00 8,977.42 10,200.00 8,193.69 34.60 117.32 17.48 -136.62 6,533.72 0.47 870.69 472.76 636.67 Pass-Major Risk 13,050.00 8,977.42 11,975.00 8,975.04 34.60 128.85 -46.54 41.91 6,303.94 0.29 668.34 507.62 171.62 Pass-Major Risk 13,050.00 8,977.42 12,000.00 8,975.80 34.60 128.76 46.57 44.95 6,328.74 0.29 652.49 507.24 156.04 Pass-Major Risk 13,064.05 8,977.70 10,175.00 8,176.86 34.67 116.86 19.65 -123.79 6,547.03 0.47 885.94 472.36 655.49 Pass-Major Risk 13,064.64 8,977.71 12,025.00 8,976.07 34.68 128.67 -44.84 49.46 6,353.32 0.29 638.05 508.27 140.09 Pass-Major Risk 13,075.00 77.91 ,0 5.00 8,9 10,150.00 8,160.21 34.73 116.40 21.40 -110.75 6,560.36 0.47 901.34 471.54 674.23 Pass-Major Risk 13,075.00 8,977.91 12,050.00 8,976.52 34.73 128.58 -43.62 55.31 6,377.62 0.29 625.22 508.66 126.49 Pass-Major Risk 13,083.58 8,978.08 12,075.00 8,977.59 34.78 128.48 -42.66 62.41 6,401.56 0.29 613.97 508.74 114.81 Pass-Major Risk 13,084.69 8,978.10 10,125.00 8,143.75 34.79 115.95 22.96 -97.50 6,573.72 0.47 916.84 470.48 692.84 Pass-Major Risk 13,100.00 8,978.39 10,100.00 8,127.48 34.88 115.49 25.12 -84.03 6,587.09 0.47 932.47 469.31 711.48 Pass-Major Risk 13,100.00 8,978.39 12,100.00 8,978.86 34.88 128.39 -40.81 70.82 6,425.07 0.29 604.52 508.92 104.63 Pass-Major Risk 13,100.00 8,978.39 12,125.00 8,979.96 34.88 128.28 40.87 80.98 6,447.87 0.29 597.25 508.50 97.66 Pass-Major Risk 13,105.63 8,978.50 10,075.00 8,111.39 34.91 115.03 26.10 -70.36 6,600.48 0.47 948.13 467.93 729.69 Pass-Major Risk 13,115.27 8,978.68 12,150.00 8,980.65 34.97 128.18 -39.10 93.26 6,469.63 0.29 592.83 508.22 93.03 Pass-Major Risk 13,116.17 8,978.70 10,050.00 8,095.50 34.98 114.58 27.61 -56.48 6,613.89 0.47 963.90 466.39 747.92 Pass-Major Risk 13,125.00 8,978.86 10,025.00 8,079.80 35.03 114.12 28.88 -42.39 6,627.30 0.47 979.74 464.76 765.96 Pass-Major Risk 13,125.00 8,978.86 12,175.00 8,980.52 35.03 128.08 -37.89 105.69 6,491.32 0.29 589.17 507.68 89.58 Pass-Major Risk 13,137.28 8,979.09 10,000.00 8,064.29 35.12 113.66 30.51 -28.10 6,640.73 0.47 995.64 462.81 784.00 Pass-Major Risk 13,137.41 8,979.09 12,200.00 8,979.65 35.12 127.98 -36.30 117.85 6,513.15 0.29 585.77 506.85 86.61 Pass-Major Risk 13,150.00 8,979.32 9,975.00 8,048.98 35.20 113.19 32.15 -13.60 6,654.16 0.76 1,011.60 460.86 801.72 Pass-Major Risk 13,150.00 8,979.32 12,225.00 8,978.94 35.20 127.88 -34.71 129.33 6,535.34 0.29 582.20 505.75 83.74 Pass-Major Risk 13,158.32 8,979.47 9,950.00 8,033.84 35.26 112.72 33.24 1.11 6,667.56 0.76 1,027.64 458.79 819.39 Pass-Major Risk 13,159.66 8,979.50 12,250.00 8,978.90 35.27 127.78 -33.52 139.85 6,558.02 0.29 578.13 504.62 80.45 Pass-Major Risk 13,168.76 8,979.66 9,925.00 8,018.89 35.34 112.24 34.53 16.03 6,680.93 0.76 1,043.74 456.40 837.08 Pass-Major Risk 13,175.00 8,979.77 9,900.00 8,004.13 35.38 111.77 35.30 31.15 6,694.28 0.76 1,059.93 454.35 854.43 Pass-Major Risk 13,175.00 8,979.77 12,275.00 8,979.77 35.38 127.69 -31.75 149.44 6,581.08 0.29 573.68 502.72 77.37 Pass-Major Risk 13,181.95 8,979.89 12,300.00 8,981.38 35.44 127.60 -31.05 158.05 6,604.49 0.29 568.73 501.51 73.30 Pass-Major Risk 13,189.22 8,980.02 9,875.00 7,989.49 35.49 111.28 36.98 46.39 8,707.65 0.76 1,076.16 451.21 872.28 Pass-Major Risk 13,193.06 8,980.09 12,325.00 8,982.93 35.52 127.52 -29.86 165.22 6,628.39 0.29 562.89 499.64 68.88 Pass-Major Risk 13,200.00 8,980.21 9,850.00 7,974.95 35.58 110.80 38.23 61.68 6,721.05 0.76 1,092.48 448.32 889.93 Pass-Major Risk 13,200.00 8,980.21 12,350.00 8,984.23 35.58 127.44 -29.14 170.55 6,652.77 0.29 555.81 498.22 62.88 Pass-Major Risk 13,209.18 8,980.37 9,825.00 7,960.50 35.65 110.32 39.27 77.02 6,734.51 0.76 1,108.89 445.53 907.47 Pass-Major Risk 13,215.06 8,980.48 12,375.00 8,985.18 35.70 127.36 -27.42 174.31 6,677.47 0.29 547.68 495.30 57.11 Pass-Major Risk 13,218.97 8,980.54 9,800.00 7,946.15 35.73 109.83 40.36 92.42 6,748.00 0.76 1,125.37 442.53 925.07 Pass-Major Risk 13,225.00 8,980.65 9,775.00 7,931.89 35.78 109.34 40.99 107.92 6,761.46 0.76 1,141.97 440.11 942.39 Pass-Major Risk 13,225.00 8,980.65 12,400.00 8,985.85 35.78 127.30 -26.29 176.68 6,702.34 0.29 538.79 493.05 50.07 Pass-Major Risk 13,236.67 8,980.85 12,425.00 8,986.47 35.88 127.23 -24.95 176.60 6,727.32 0.29 528.18 490.26 41.78 Pass-Major Risk 13,238.08 8,980.88 9,750.00 7,917.72 35.89 108.85 42.43 123.55 6,774.87 0.76 1,158.66 436.25 960.38 Pass-Major Risk 13,250.00 8,981.09 9,725.00 7,903.66 36.00 108.37 43.71 139.31 6,788.24 0.76 1,175.49 432.43 978.37 Pass-Major Risk 13,250.00 8,981.09 12,450.00 8,986.82 36.00 127.18 -23.39 173.80 6,752.15 0.29 515.64 486.85 32.15 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/25/2013 10:50:33AM Page 7 of 16 COMPASS 2003.16 Build 73 ltal BAKER HUGHES Travelling Cylinder Report 0 bP. INTEQ 7414 E x= � Company: North America-ALASKA-BP Local Co-ordinate Reference: Well J-17 - �i t Project: Prudhoe Bay TVD Reference: Mean Sea Level �' 1 Reference Site: PB J Pad MD Reference: J-17C:@ 69.80ft(J-17C:) Site Error: 0.00ft North Reference: True Reference Well: J-17 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore J-17D Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 2 Offset TVD Reference: Offset Datum Offset Design PB F Pad- F-08-F-08A-F-08A Offset Site Error: 0 00f Survey Program: 100-CB-MAG-MS,11112-MWD Rule Assigned:Major Risk Offset Well Error: 0 00f Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +Nl-5 +El-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (°) (ft) (ft) (ft) (ft) (ft) (ft) 13,256.51 8,981.20 9,700.00 7,889.67 36.05 107.88 44.33 155.20 6,801 55 0.76 1,192 43 429.71 995.84 Pass-Major Risk 13,256.99 8,981.21 12,475.00 8,986.81 36.06 127.13 -22.54 168.68 6,776.61 0.29 501.53 484.79 19.78 Pass-Major Risk 13,265.42 8,981.36 9,675.00 7,875.71 36.13 107.39 45.21 171.18 6,814.77 0.76 1,209.54 426.37 1,013.71 Pass-Major Risk 13,267.25 8,981.39 12,500.00 8,986.68 36.15 127.09 -21.29 163.47 6,801.06 0.29 487.79 481.77 8.64 Pass-Major Risk 13,365.00 8,981 74 12,525.00 8,986.78 37.05 127.04 -31.02 158.81 6,825.63 0.29 474.08 504.36 -24.85 FAIL-Major Risk 13,375.00 8,981.62 12,550.00 8,986.84 37.14 126.99 -29.86 155.65 6,850.42 0.29 459.11 502.59 -38.48 FAIL-Major Risk 13,381.79 8,981.53 9,650.00 7,861.78 37.20 106.90 37.66 187.28 6,827.88 0.76 1,225.40 443.69 1,017.32 Pass-Major Risk 13,388.14 8,981.46 12,575.00 8,986.67 37.26 126.93 -28.29 154.43 6,875.38 0.29 446.19 500.08 -49.41 FAIL-Major Risk 13,391.17 8,981.42 9,625.00 7,847.88 37.28 106.41 38.70 203.47 6,840.89 0.76 1,241.24 440.92 1,034.09 Pass-Major Risk 13,400.00 8,981.31 9,600.00 7,833.97 37.36 105.92 39.67 219.72 6,853.84 0.76 1,257.27 438.13 1,050.97 Pass-Major Risk 13,400.00 8,981.31 12,600.00 8,986.51 37.36 126.87 -26.89 154.69 6,900.38 0.29 435.11 497.50 -58.42 FAIL-Major Risk 13,409.40 8,981.19 9,575.00 7,820.02 37.45 105.43 40.69 235.92 6,866.80 0.76 1,273.47 435.15 1,068.07 Pass-Major Risk 13,411.96 8,981 16 12,625.00 8,986.63 37.47 126.80 -25.50 156.10 6,925.33 0.29 425.65 494.67 -65.54 FAIL-Major Risk 13,418.27 8,981.08 9,550.00 7,806.02 37.53 104.94 41.65 252.06 6,879.78 0.76 1,289.85 432.17 1,085.29 Pass-Major Risk 13,425.00 8,981.00 9,525.00 7,791.98 37.60 104.45 42.33 268.15 6,892.78 0.76 1,306.39 429.55 1,102.48 Pass-Major Risk 13,425.00 8,981.00 12,650.00 8,986.90 37.60 126.73 -24.01 158.96 6,950.16 0.29 418.17 491.33 -70.22 FAIL-Major Risk 13,435.47 8,980.87 9,500.00 7,777.83 37.70 103.97 43.46 284.20 6,905.72 0.76 1,323.16 426.09 1,120.27 Pass-Major Risk 13,437.70 8,980.85 12,675.00 8,987.08 37.72 126.66 -22.54 163.66 6,974.71 0.29 413.14 487.79 -72.23 FAIL-Major Risk ES,SF 13,450.00 8,980.70 9,450.00 7,749.12 37.84 103.00 44.92 316.24 6,931.18 0.76 1,357.56 420.34 1,156.03 Pass-Major Risk 13,450.00 8,980.70 9,475.00 7,763.55 37.84 103.48 45.08 300.23 6,918.52 0.76 1,340.25 421.56 1,138.90 Pass-Major Risk 13,450.00 8,980.70 12,700.00 8,987.26 37.84 126.59 -21.12 169.99 6,998.89 0.29 410.44 484.12 -71.74 FAIL-Major Risk 13,459.63 8,980.58 9,425.00 7,734.55 37.94 102.52 45.93 332.24 6,943.71 0.76 1,375.17 416.82 1,174.61 Pass-Major Risk 13,464.48 8,980.52 12,725.00 8,987.51 37.99 126.51 -19.44 177.49 7,022.74 0.29 409.65 479.56 -68.51 FAIL-Major Risk,CC 13,467.25 8,980.49 9,400.00 7,719.86 38.02 102.04 46.70 348.20 6,956.14 0.76 1,393.03 413.75 1,193.21 Pass-Major Risk 13,475.00 8,980.39 9,350.00 7,690.13 38.09 101.09 47.30 380.00 6,980.72 0.76 1,429.45 409.44 1,230.19 Pass-Major Risk 13,475.00 8,980.39 9,375.00 7,705.05 38.09 101.57 47.47 364.12 6,968.48 0.76 1,411.11 410.59 1,212.07 Pass-Major Risk 13,475.00 8,980.39 12,750.00 8,987.79 38.09 126.43 -18.24 185.64 7,046.37 0.29 410.29 475.96 -64.70 FAIL-Major Risk 13,488.92 8,980.23 9,325.00 7,675.09 38.24 100.62 48.82 395.84 6,992.89 0.76 1,447.94 404.56 1,250.30 Pass-Major Risk 13,500.00 8,980.10 9,275.00 7,644.73 38.36 99.69 49.81 427.44 7,016.97 0.76 1,485.58 399.24 1,289.00 Pass-Major Risk 13,500.00 8,980.10 9,300.00 7,659.96 38.36 100.15 49.99 411.66 7,004.97 0.76 1,466.67 400.32 1,270.37 Pass-Major Risk 13,508.90 8,979.99 9,250.00 7,629.42 38.45 99.22 50.72 443.20 7,028.89 0.76 1,504.68 395.57 1,309.15 Pass-Major Risk 13,520.00 8,979.86 9,225.00 7,614.01 38.57 98.76 51.89 458.92 7,040.74 0.76 1,523.98 391.15 1,329.91 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/25/2013 10:50:33AM Page 8 of 16 COMPASS 2003.16 Build 73 Mil BAKER 0 HUGHES Travelling Cylinder Report by INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well J-17 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB J Pad MD Reference: J-17C:@ 69.80ft(J-17C:) Site Error: 0.00ft North Reference: True Reference Well: J-17 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore J-17D Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 2 Offset TVD Reference: Offset Datum Offset Design PB F Pad- F-08-F-08B-F-08B Offset Site Error: 0,00ft Survey Program: 100-CB-MAG-MS,11053-MWD,11086-MWD Rule Assigned:Major Risk Offset Well Error: O.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (1 (ft) (rt) (ft) (ft) (ft) (ft) 12,600.00 8,966.52 11,075.00 8,817.35 33.05 133.41 -45.01 -412.64 5,990.98 0.27 689.34 494.65 218.61 Pass-Major Risk 12,600.00 8,966.52 11,100.00 8,838.30 33.05 133.54 -46.89 -415.54 5,977.66 0.27 694.47 494.99 220.54 Pass-Major Risk 12,609.74 8,966.79 11,050.00 8,797.41 33.08 133.18 -42.06 -40728 6,005.04 0.27 685.44 496.53 215.96 Pass-Major Risk,ES,SF 12,615.14 8,966.94 11,025.00 8,778.09 33.09 132.80 -39.65 -400.89 6,019.57 0.27 682.41 496.79 216.16 Pass-Major Risk 12,625.00 8,967.21 10,950.00 8,720.64 33.12 131.66 -33.15 -381.42 6,063.67 0.27 677.85 495.79 225.48 Pass-Major Risk 12,625.00 8,967.21 10,975.00 8,739.67 33.12 132.05 -34.93 -387.97 6,048.84 0.27 678.60 496.91 220.46 Pass-Major Risk 12,625.00 8,967.21 11,000.00 8,758.85 33.12 132.43 -36.71 -394.46 6,034.17 0.27 680.16 498.01 216.63 Pass-Major Risk 12,638.05 8,967.56 10,925.00 8,701.77 33.16 131.27 -29.86 -374.79 6,078.66 0.27 677.58 497.43 228.68 Pass-Major Risk,CC 12,650.00 8,967.89 10,850.00 8,646.08 33.20 130.09 -23.28 -354.31 6,124.53 0.27 681.19 496.19 250.40 Pass-Major Risk 12,650.00 8,967.89 10,875.00 8,664.52 33.20 130.49 -24.99 -361.29 6,109.17 0.27 679.16 497.39 241.36 Pass-Major Risk 12,650.00 8,967.89 10,900.00 8,683.06 33.20 130.88 -26.72 -368.09 6,093.83 0.27 678.10 498.56 233.55 Pass-Major Risk 12,663.49 8,968.25 10,825.00 8,627.71 33.25 129.69 -20.04 -347.11 6,139.88 0.27 683.93 497.23 258.37 Pass-Major Risk 12,675.00 8,968.56 10,800.00 8,609.41 33.29 129.29 -17.06 -339.67 6,155.21 0.27 687.63 497.67 268.07 Pass-Major Risk 12,875.00 8,973.79 10,750.00 8,573.08 33.99 128.47 -32.34 -324.47 6,186.01 0.27 692.54 464.83 312.82 Pass-Major Risk 12,875.00 8,973.79 10,775.00 8,591.20 33.99 128.88 -34.13 -332.05 6,170.55 0.27 691.42 465.87 304.10 Pass-Major Risk 12,886.64 8,974.07 10,725.00 8,555.06 34.01 128.06 -29.20 -316.98 6,201.64 0.27 694.14 467.96 319.12 Pass-Major Risk 12,892.68 8,974.21 10,700.00 8,537.13 34.02 127.65 -26.73 -309.60 6,217.43 0.27 696.38 468.99 327.95 Pass-Major Risk 12,900.00 8,974.37 10,650.00 8,501.61 34.04 126.82 -22.40 -295.12 6,249.49 0.27 702.55 469.29 349.24 Pass-Major Risk 12,900.00 8,974.37 10,675.00 8,519.31 34.04 127.24 -24.13 -302.31 6,233.37 0.27 699.18 470.36 337.37 Pass-Major Risk 12,911.63 8,974.63 10,625.00 8,484.03 34.07 126.41 -19.34 -288.03 6,265.79 0.27 706.36 471.93 359.23 Pass-Major Risk 12,918.26 8,974.77 10,600.00 8,466.57 34.09 125.99 -16.89 -281.05 6,282.26 0.27 710.72 472.85 371.08 Pass-Major Risk 12,925.00 8,974.91 10,575.00 8,449.22 34.11 125.57 -14.46 -274.10 6,298.87 0.27 715.63 473.70 383.65 Pass-Major Risk 12,931.97 8,975.05 10,550.00 8,431.96 34.13 125.15 -12.04 -267.06 6,315.53 0.27 721.18 474.55 396.86 Pass-Major Risk 12,939.08 8,975.19 10,525.00 8,414.77 34.15 124.73 -9.64 -259.91 6,332.22 0.27 727.37 475.33 410.76 Pass-Major Risk 12,950.00 8,975.42 10,475.00 8,380.63 34.18 123.89 -5.38 -245.30 6,365.70 0.27 741.61 475.77 440.84 Pass-Major Risk 12,950.00 8,975.42 10,500.00 8,397.67 34.18 124.31 -6.84 -252.65 6,348.95 0.27 734.19 476.97 424.81 Pass-Major Risk 12,961.73 8,975.66 10,450.00 8,363.61 34.22 123.46 -2.58 -237.87 6,382.43 0.27 749.63 477.36 455.95 Pass-Major Risk 12,975.00 8,975.92 10,400.00 8,329.63 34.27 122.61 1.66 -222.75 6,415.85 0.27 767.50 477.77 488.92 Pass-Major Risk 12,975.00 8,975.92 10,425.00 8,346.61 34.27 123.04 0.34 -230.35 6,399.15 0.27 758.30 479.01 471.67 Pass-Major Risk 12,986.36 8,976.15 10,375.00 8,312.63 34.31 122.17 4.22 -214.63 6,432.28 0.27 777.52 478.74 505.75 Pass-Major Risk 13,000.00 8,976.43 10,325.00 8,278.58 34.37 121.29 7.96 -195.58 6,463.53 0.27 800.61 478.49 541.63 Pass-Major Risk 13,000.00 8,976.43 10,350.00 8,295.61 34.37 121.73 6.95 -205.57 6,448.19 0.27 788.61 479.81 523.15 Pass-Major Risk 13,014.12 8,976.71 10,300.00 8,261.59 34.43 120.85 10.51 -184.69 6,478.28 0.27 813.45 479.33 559.67 Pass-Major Risk 13,025.00 8,976.93 10,275.00 8,244.62 34.48 120.41 12.59 -173.24 6,492.62 0.27 826.97 479.40 578.17 Pass-Major Risk 13,033.80 8,977.10 10,250.00 8,227.64 34.52 119.96 14.35 -161.40 6,506.64 0.27 841.05 479.03 596.91 Pass-Major Risk 13,043.80 8,977.30 10,225.00 8,210.66 34.57 119.51 16.18 -149.19 6,520.34 0.45 855.63 478.85 615.57 Pass-Major Risk 13,050.00 8,977.42 10,200.00 8,193.69 34.60 119.05 17.48 -136.62 6,533.72 0.45 870.69 477.96 634.57 Pass-Major Risk 13,064.05 8,977.70 10,175.00 8,176.86 34.67 118.59 19.65 -123.79 6,547.03 0.45 885.94 477.52 653.44 Pass-Major Risk 13,075.00 8,977.91 10,150.00 8,160.21 34.73 118.12 21.40 -110.75 6,560.36 0.45 901.34 476.66 672.24 Pass-Major Risk 13,084.69 8,978.10 10,125.00 8,143.75 34.79 117.65 22.96 -97.50 6,573.72 0.45 916.84 475.56 690.90 Pass-Major Risk 13,100.00 8,978.39 10,100.00 8,127.48 34.88 117.19 2512 -84.03 6,587.09 0.45 932.47 474.35 709.58 Pass-Major Risk 13,105.63 8,978.50 10,075.00 8,111.39 34.91 116.72 26.10 -70.36 6,600.48 0.45 948.13 472.92 727.83 Pass-Major Risk 13,116.17 8,978.70 10,050.00 8,095.50 34.98 116.25 27.61 -56.48 6,613.89 0.45 963.90 471.34 746.10 Pass-Major Risk 13,125.00 8,978.86 10,025.00 8,079.80 35.03 115.79 28.88 -42.39 6,627.30 0.45 979.74 469.66 764.17 Pass-Major Risk 13,137.28 8,979.09 10,000.00 8,064.29 35.12 115.32 30.51 -28.10 6,640.73 0.45 995.64 467.66 782.25 Pass-Major Risk 13,150.00 8,979.32 9,975.00 8,048.98 35.20 114.84 32.15 -13.60 6,654.16 0.76 1,011.60 465.66 799.98 Pass-Major Risk 13,158.32 8,979.47 9,950.00 8,033.84 35.26 114.35 33.24 1.11 6,667.56 0.76 1,027.64 463.54 817.66 Pass-Major Risk 13,168.76 8,979.66 9,925.00 8,018.89 35.34 113.87 34.53 16.03 6,680.93 0.76 1,043.74 461.09 835.38 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/25/2013 10:50:33AM Page 9 of 16 COMPASS 2003.16 Build 73 Mid HUGHES Travelling Cylinder Report ' 1NTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well J-17 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB J Pad MD Reference: J-17C:@ 69.80ft(J-17C.) Site Error: 0.00ft North Reference: True Reference Well: J-17 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore J-17D Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 2 Offset TVD Reference: Offset Datum Offset Design PB F Pad- F-08-F-08B-F-08B Offset Site Error: 0.00 ft Survey Program: 100-CB-MAG-MS,11053-MWD,11086-MWD Rule Assigned:Major Risk Offset Well Error: 0.00 ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (1 (n) (n) (ft( (ft) (ft) (ft) 13,175.00 8,979.77 9,900.00 8,004.13 35.38 113.38 3530 31.15 6,694.28 0.76 1,059.93 458.99 852.75 Pass-Major Risk 13,189.22 8,980.02 9,875.00 7,989.49 35.49 112.89 36.98 46.39 6,707.65 0.76 1,076.16 455.77 870.62 Pass-Major Risk 13,200.00 8,980.21 9,850.00 7,974.95 35.58 112.39 38.23 61.68 6,721.05 0.76 1,092.48 452.81 888.29 Pass-Major Risk 13,209.18 8,980.37 9,825.00 7,960.50 35.65 111.90 39.27 77.02 6,734.51 0.76 1,108.89 449.96 905.84 Pass-Major Risk 13,218.97 8,980.54 9,800.00 7,946.15 35.73 111.40 40.36 92.42 6,748.00 0.76 1,125.37 446.89 923.47 Pass-Major Risk 13,225.00 8,980.65 9,775.00 7,931.89 35.78 110.91 4099 107.92 6,761.46 0.76 1,141.97 444.41 940.79 Pass-Major Risk 13,238.08 8,980.88 9,750.00 7,917.72 35.89 110.41 4243 123.55 6,774.87 0.76 1,158.66 440.47 958.80 Pass-Major Risk 13,250.00 8,981.09 9,725.00 7,903.66 36.00 109.91 43.71 139.31 6,788.24 0.76 1,175.49 436.57 976.81 Pass-Major Risk 13,256.51 8,981.20 9,700.00 7,889.67 36.05 109.41 44.33 155.20 6,801.55 0.76 1,192.43 433.79 99429 Pass-Major Risk 13,265.42 8,981.36 9,675.00 7,875.71 36.13 108.91 45.21 171.18 6,814.77 0.76 1,209.54 430.38 1,012.16 Pass-Major Risk 13,381.79 8,981.53 9,650.00 7,861.78 37.20 108.41 37.66 187.28 6,827.88 0.76 1,225.40 447.94 1,015.65 Pass-Major Risk 13,391.17 8,981.42 9,625.00 7,847.88 37.28 107.91 38.70 203.47 6,840.89 0.76 1,241.24 445.10 1,032.44 Pass-Major Risk 13,400.00 8,981.31 9,600.00 7,833.97 37.36 107.41 39.67 219.72 6,853.84 0.76 1,257.27 442.25 1,049.33 Pass-Major Risk 13,409.40 8,981.19 9,575.00 7,820.02 37.45 106.91 40.69 235.92 6,866.80 0.76 1,273.47 439.21 1,066.44 Pass-Major Risk 13,418.27 8,981.08 9,550.00 7,806.02 37.53 106.41 41.65 252.06 6,879.78 0.76 1,289.85 436.17 1,083.68 Pass-Major Risk 13,425.00 8,981.00 9,525.00 7,791.98 37.60 105.91 42.33 268.15 6,892.78 0.76 1,306.39 433.49 1,100.87 Pass-Major Risk 13,435.47 8,980.87 9,500.00 7,777.83 37.70 105.42 43.46 284.20 6,905.72 0.76 1,323.16 429.96 1,118.68 Pass-Major Risk 13,450.00 8,980.70 9,450.00 7,749.12 37.84 104.43 44.92 316.24 6,931.18 0.76 1,357.56 424.09 1,154.46 Pass-Major Risk 13,450.00 8,980.70 9,475.00 7,763.55 37.84 104.92 45.08 300.23 6,918.52 0.76 1,340.25 425.34 1,137.33 Pass-Major Risk 13,459.63 8,980.58 9,425.00 7,734.55 37.94 103.94 45.93 332.24 6,943.71 0.76 1,375.17 420.50 1,173.06 Pass-Major Risk 13,467.25 8,980.49 9,400.00 7,719.86 38.02 103.48 48.70 348.20 6,956.14 0.76 1,393.03 417.37 1,191.66 Pass-Major Risk 13,475.00 8,980.39 9,350.00 7,690.13 38.09 102.49 47.30 380.00 6,980.72 0.76 1,429.45 412.98 1,228.65 Pass-Major Risk 13,475.00 8,980.39 9,375.00 7,705.05 38.09 102.97 47.47 364.12 6,968.48 0.76 1,411.11 414.14 1,210.53 Pass-Major Risk 13,488.92 8,980.23 9,325.00 7,675.09 38.24 102.01 48.82 395.84 6,992.89 0.76 1,447.94 408.00 1,248.79 Pass-Major Risk 13,500.00 8,980.10 9,275.00 7,644.73 38.36 101.06 49.81 427.44 7,016.97 0.76 1,485.58 402.58 1,287.50 Pass-Major Risk 13,500.00 8,980.10 9,300.00 7,659.96 38.36 101.53 49.99 411.66 7,004.97 0.76 1,466.67 403.68 1,268.88 Pass-Major Risk 13,508.90 8,979.99 9,250.00 7,629.42 38.45 100.58 50.72 443.20 7,028.89 0.76 1,504.68 398.84 1,307.67 Pass-Major Risk 13,520.00 8,979.86 9,225.00 7,614.01 38.57 100.11 51.89 458.92 7,040.74 0.76 1,523.98 394.34 1,328.45 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/25/2013 10:50:33AM Page 10 of 16 COMPASS 2003.16 Build 73 ran BAKER HUGHES Travelling Cylinder Report 0 by INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well J-17 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB J Pad MD Reference: J-17C:@ 69.80ft(J-17C:) Site Error: 0.00ft North Reference: True Reference Well: J-17 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore J-17D Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 2 Offset TVD Reference: Offset Datum Offset Design PB F Pad- F-40-F-40-F-40 Offset Site Error: O.00ft Survey Program: 92-GCT-MS Rule Assigned:Major Risk Offset Well Error: 0.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Well bore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (it) (ft) lit) (ft) (1 (ft) (it) (ft) lit) (ff) (ft) 12,738.14 8,970.26 10,920.24 9,139.92 33.55 36.99 139.81 -1,100.14 7,201.71 0.29 725.71 216.22 513.55 Pass-Major Risk 12,750.00 8,970.57 10,875.00 9,108.68 33.60 36.68 135.97 -1,072.44 7,219.12 0.29 716.98 214.32 505.25 Pass-Major Risk 12,750.00 8,970.57 10,900.00 9,125.94 33.60 36.85 137.34 -1,087.75 7,209.50 0.29 721.60 214.83 510.08 Pass-Major Risk 12,758.11 8,970.79 10,850.00 9,091.42 33.63 36.51 133.63 -1,057.13 7,228.74 0.29 713.10 213.11 501.88 Pass-Major Risk 12,765.24 8,970.98 10,825.00 9,074.16 33.66 36.34 131.40 -1,041.82 7,238.37 0.29 709.90 211.96 499.25 Pass-Major Risk 12,775.00 8,971.23 10,775.00 9,039.63 33.69 36.00 127.40 -1,011.20 7,257.61 0.29 705.62 210.04 496.05 Pass-Major Risk 12,775.00 8,97123 10,800.00 9,056.89 33.69 36.17 128.84 -1,026.51 7,247.99 0.29 707.40 210.55 497.67 Pass-Major Risk 12,786.62 8,971.54 10,750.00 9,022.37 33.73 35.83 124.61 -995.89 7,267.24 0.29 704.48 208.42 496.24 Pass-Major Risk 12,800.00 8,971.89 10,700.00 8,987.82 33.78 35.49 120.15 -965.28 7,286.46 0.29 704.39 206.09 498.26 Pass-Major Risk 12,800.00 8,971.89 10,725.00 9,005.11 33.78 35.66 121.60 -980.58 7,276.86 0.29 704.15 206.58 497.59 Pass-Major Risk 12,807.89 8,972.09 10,675.00 8,970.39 33.80 35.33 117.78 -950.08 7,295.95 0.29 705.34 204.79 500.56 Pass-Major Risk 12,814.87 8,972.27 10,650.00 8,952.86 33.83 35.17 115.50 -934.98 7,305.42 0.29 707.04 203.58 503.61 Pass-Major Risk 12,825.00 8,972.53 10,625.00 8,935.30 3386 35.00 112.87 -919.91 7,314.89 0.29 709.48 202.01 507.86 Pass-Major Risk 13,325.00 8,981.97 10,575.00 8,900.04 36.69 34.67 147.57 -889.88 7,333.72 0.29 695.78 236.91 459.26 Pass-Major Risk 13,325.00 8,981.97 10,600.00 8,917.70 36.69 34.83 149.09 -904.88 7,324.33 0.29 703.30 237.35 466.03 Pass-Major Risk 13,334.90 8,981.97 10,550.00 8,882.30 36.78 34.51 144.85 -874.95 7,343.08 0.29 688.96 237.16 452.72 Pass-Major Risk 13,341.30 8,981.94 10,525.00 8,86447 36.84 34.36 142.50 -860.11 7,352.40 0.29 682.96 237.15 447.39 Pass-Major Risk 13,350.00 8,981.89 10,500.00 8,846.52 36.92 34.21 139.85 -845.42 7,361.71 0.29 677.83 237.25 443.00 Pass-Major Risk,CC,ES,5 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/25/2013 10:50:33AM Page 11 of 16 COMPASS 2003.16 Build 73 Frio :u HUGHES Travelling Cylinder Report u }I INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well J-17 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB J Pad MD Reference: J-17C:@ 69.80ft(J-17C:) Site Error: 0.00ft North Reference: True Reference Well: J-17 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore J-17D Database: EDM .16-ANC Prod-WH24P Reference Design: Plan 2 Offset TVD Reference: Offset Datum Offset Design PB J Pad- J-17-J-17C-J-17C Offset Site Error: 0.00ft Survey Program: 93-GYD-CT-CMS,8931-MWD+IFR+MS Rule Assigned:Major Risk Offset Well Error: 0.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E1-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (1 (ft) (ft) Ift) (ft) (ft) (ft) 11,749.99 8,960.84 11,750.00 8,960.64 0.07 0.07 161.17 -1,088.98 5,829.45 0.36 0.31 1.12 -0.72 FAIL-Major Risk,CC,ES,S 11,774.89 8,959.83 11,775.00 8,959.18 0.15 0.14 178.23 -1,099.13 5,852.25 0.36 1.81 1.97 -0.10 FAIL-Major Risk 11,799.51 8,959.24 11,800.00 8,958.55 0.24 0.22 -171.45 -1,109.80 5,874.84 0.36 4.97 2.83 2.15 Pass-Major Risk 11,823.63 8,959.05 11,825.00 8,958.43 0.33 0.29 -169.82 -1,121.04 5,897.18 0.36 9.99 3.70 6.29 Pass-Major Risk 11,847.11 8,959.24 11,850.00 8,958.43 0.42 0.37 -171.74 -1,132.68 5,919.30 0.36 16.63 4.56 12.07 Pass-Major Risk ' 11,869.90 8,959.78 11,875.00 8,958.33 0.52 0.45 -174.96 -1,144.41 5,941.38 0.36 24.48 5.41 19.08 Pass-Major Risk 11,892.05 8,960.63 11,900.00 8,958.08 0.62 0.53 -178.51 -1,155.87 5,963.59 0.36 33.14 6.24 26.92 Pass-Major Risk 11,913.50 8,961.78 11,925.00 8,957.73 0.71 0.61 178.01 -1,167.15 5,985.90 0.36 42.66 7.05 35.65 Pass-Major Risk 11,933.90 8,963.14 11,950.00 8,957.58 0.81 0.69 175.19 -1,179.02 6,007.90 0.36 53.75 7.82 45.97 Pass-Major Risk 11,953.51 8,964.71 11,975.00 8,957.31 0.91 0.77 172.39 -1,190.71 6,029.99 0.36 65.59 8.57 57.09 Pass-Major Risk 11,972.51 8,966.21 12,000.00 8,956.56 1.01 0.85 169.49 -1,201.96 6,052.31 0.36 77.91 9.28 68.71 Pass-Major Risk 11,990.64 8,967.53 12,025.00 8,955.30 1.10 0.94 166.76 -1,213.25 6,074.58 0.36 91.15 9.97 81.30 Pass-Major Risk 12,007.93 8,968.67 12,050.00 8,954.07 1.19 1.02 164.45 -1,224.63 6,096.80 0.36 105.21 10.61 94.73 Pass-Major Risk 12,025.00 8,969.68 12,075.00 8,952.99 1.29 1.10 162.44 -1,236.08 6,119.00 0.36 120.01 11.23 108.92 Pass-Major Risk 12,040.08 8,970.48 12,100.00 8,952.21 1.37 1.19 160.88 -1,247.60 6,141.18 0.36 135.45 11.79 123.81 Pass-Major Risk 12,054.89 8,971.18 12,125.00 8,951.72 1.45 1.27 159.51 -1,259.32 6,163.25 0.36 151.63 12.31 139.46 Pass-Major Risk 12,068.76 8,971.76 12,150.00 8,951.53 1.53 1.36 158.36 -1,271.43 6,185.12 0.36 168.64 12.80 155.98 Pass-Major Risk 12,081.53 8,972.23 12,175.00 8,951.66 1.61 1.45 157.42 -1,284.20 6,206.61 0.36 186.62 13.23 173.52 Pass-Major Risk 12,093.12 8,972.59 12,200.00 8,952.14 1.67 1.54 156.88 -1,297.75 6,227.61 0.36 205.60 13.61 192.11 Pass-Major Risk 12,100.00 8,972.78 12,225.00 8,952.61 1.71 1.63 156.40 -1,311.74 6,248.33 0.36 225.33 13.87 211.56 Pass-Major Risk 12,113.73 8,973.11 12,250.00 8,952.90 1.79 1.72 155.23 -1,325.97 6,268.88 0.36 245.47 14.24 231.34 Pass-Major Risk 12,125.00 8,973.32 12,275.00 8,953.14 1.86 1.81 154.29 -1,340.23 6,289.41 0.36 265.99 14.53 251,56 Pass-Major Risk 12,132.01 8,973.43 12,300.00 8,953.37 1.90 1.90 153.79 -1,354.43 6,309.99 0.36 286.72 14.74 272.07 Pass-Major Risk 12,140.51 8,973.53 12,325.00 8,953.44 1.95 1.99 153.06 -1,368.52 6,330.64 0.36 307.65 14.97 292.78 Pass-Major Risk 12,150.00 8,973.61 12,350.00 8,953.34 2.01 2.08 152.15 -1,382.49 6,351.37 0.36 328.74 15.18 313.67 Pass-Major Risk 12,156.41 8,973.64 12,375.00 8,953.13 2.04 2.15 151.57 -1,396.38 6,372.16 0.36 350.00 23.35 326.67 Pass-Major Risk 12,160.00 8,973.66 12,387.00 8,953.03 2.07 2.18 151.23 -1,403.05 6,382.13 0.36 360.28 28.16 332.13 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/25/2013 10:50:33AM Page 12 of 16 COMPASS 2003.16 Build 73 Milli BAKER m°"'$ HUGHES Travelling Cylinder Report :, ,% o� 1 NTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well J-17 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB J Pad MD Reference: J-17C:@ 69.80ft(J-17C:) Site Error: 0.00ft North Reference: True Reference Well: J-17 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore J-17D Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 2 Offset TVD Reference: Offset Datum Offset Design PB J Pad- J-18-J-18-J-18 Offset Site Error: 0.00fc Survey Program: 100-BOSS-GYRO Rule Assigned:Major Risk Offset Well Error: 0.000 Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Wellbore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation 0) (ft) (ft) (ft) (ftl (ft/ (1 (ft) (ft) (ft) (ft) (ft) (ft) 12,183.37 8,973.60 10,575.00 7,621 81 31.33 363.97 90.67 -1,730.05 6,593.18 0.29 1,544.33 907.17 1,073.64 Pass-Major Risk 12,189.25 8,973.56 10,600.00 7,637.98 31.36 365.41 90.75 -1,737.38 6,610.78 0.29 1,537.41 900.33 1,058.44 Pass-Major Risk 12,200.00 8,973.43 10,625.00 7,654.08 31.41 366.90 90.26 -1,744.78 6,628.41 0.29 1,530.95 885.20 1,046.51 Pass-Major Risk 12,200.00 8,973.43 10,650.00 7,670.10 31.41 368.39 91.07 -1,752.32 6,646.06 0.29 1,524.92 887.89 1,029.25 Pass-Major Risk 12,200.00 8,973.43 10,675.00 7,686.06 31.41 369.88 91.88 -1,759.99 6,663.71 0.29 1,519.40 890.58 1,012.41 Pass-Major Risk 12,210.57 8,973.26 10,700.00 7,701.94 31.46 371.36 91.45 -1,767.79 6,681.37 0.29 1,514.32 875.08 1,002.52 Pass-Major Risk 12,215.38 8,973.17 10,725.00 7,717.76 31.49 372.89 91.71 -1,775.69 6,699.05 0.29 1,509.72 869.27 989.84 Pass-Major Risk 12,225.00 8,972.97 10,750.00 7,733.53 31.53 374.42 91.40 -1,783.63 6,716.74 0.29 1,505.58 854.68 981.27 Pass-Major Risk 12,225.00 8,972.97 10,775.00 7,749.26 31.53 375.95 92.26 -1,791.63 6,734.45 0.29 1,501.84 857.19 966.49 Pass-Major Risk 12,225.00 8,972.97 10,800.00 7,764.95 31.53 377.48 93.13 -1,799.69 6,752.17 0.29 1,498.57 859.70 952.18 Pass-Major Risk 12,232.94 8,972.76 10,825.00 7,780.64 31.57 379.01 93.04 -1,807.78 6,769.87 0.29 1,495.67 847.61 944.60 Pass-Major Risk 12,236.93 8,972.65 10,850.00 7,796.39 31.59 380.54 93.44 -1,815.89 6,787.51 0.29 1,493.12 842.61 934.57 Pass-Major Risk 12,240.75 8,972.54 10,87500 7,812.19 31.61 382.07 93.86 -1,824.02 6,805.10 0.29 1,490.91 837.80 925.00 Pass-Major Risk 12,250.00 8,972.25 10,900.00 7,828.04 31.65 383.60 93.63 -1,832.17 6,822.63 0.29 1,489.07 822.50 921.10 Pass-Major Risk 12,250.00 8,972.25 10,925.00 7,843.95 31.65 385.09 94.53 -1,840.36 6,840.09 0.29 1,487.53 824.67 909.32 Pass-Major Risk 12,250.00 8,972.25 10,950.00 7,859.94 31.65 386.58 95.43 -1,848.61 6,857.45 0.29 1,486.34 826.83 897.95 Pass-Major Risk 12,250.00 8,972.25 10,975.00 7,875.99 31.65 388.08 96.33 -1,856.91 6,874.72 0.29 1,485.52 828.99 887.01 Pass-Major Risk 12,250.00 8,972.25 11,000.00 7,892.12 31.65 389.57 97.24 -1,865.28 6,891.89 0.29 1,485.07 831.15 876.49 Pass-Major Risk 12,260.59 8,971.87 11,025.00 7,908.27 31.70 391.05 96.87 -1,873.70 6,909.02 0.29 1,484.93 812.34 877.90 Pass-Major Risk,CC 12,263.45 8,971.76 11,050.00 7,924.40 31.71 392.53 97.44 -1,882.16 6,926.14 0.29 1,485.27 808.63 871.92 Pass-Major Risk 12,266.21 8,971.65 11,075.00 7,940.52 31.72 394.01 98.01 -1,890.66 6,943.25 0.29 1,486.06 805.05 866.43 Pass-Major Risk 12,275.00 8,971.28 11,100.00 7,956.62 31.76 395.49 97.85 -1,899.21 6,960.36 0.29 1,487.33 789.07 868.93 Pass-Major Risk 12,275.00 8,971.28 11,125.00 7,972.71 31.76 397.00 98.77 -1,907.79 6,977.47 0.29 1,488.97 790.98 861.51 Pass-Major Risk 12,275.00 8,971.28 11,150.00 7,988.77 31.76 398.50 99.69 -1,916.38 6,994.59 0.29 1,491.05 792.88 854.67 Pass-Major Risk 12,275.00 8,971.28 11,175.00 8,004.82 31.76 400.00 100.60 -1,924.98 7,011.72 0.29 1,493.57 794.79 848.40 Pass-Major Risk 12,275.00 8,971.28 11,200.00 8,020.85 31.76 401.50 101.51 -1,933.60 7,028.86 0.29 1,496.53 796.69 842.72 Pass-Major Risk 12,275.00 8,971.28 11,225.00 8,036.84 31.76 403.03 102.42 -1,942.23 7,046.03 0.29 1,499.95 798.63 837.61 Pass-Major Risk 12,275.00 8,971.28 11,250.00 8,052.77 31.76 404.56 103.32 -1,950.89 7,063.24 0.29 1,503.85 800.57 833.14 Pass-Major Risk,ES,SF 12,285.55 8,970.80 11,275.00 8,068.64 31.80 406.10 102.92 -1,959.57 7,080.50 0.29 1,508.11 778.33 844.45 Pass-Major Risk 12,287.69 8,970.70 11,300.00 8,084.45 31.81 407.63 103.55 -1,968.27 7,097.80 0.29 1,512.90 775.48 844.72 Pass-Major Risk 12289.78 8,970.60 11,325.00 8,100.26 31.82 409.17 104.18 -1,976.97 7,115.10 0.29 1,518.10 772.70 845.60 Pass-Major Risk 12,300.00 8,970.07 11,350.00 8,116.10 31.87 410.71 103.79 -1,985.68 7,132.37 0.29 1,523.70 751.69 860.08 Pass-Major Risk 12,300.00 8,970.07 11,375.00 8,131.99 31.87 412.26 104.68 -1,994.37 7,149.61 0.29 1,529.54 753.40 859.10 Pass-Major Risk 12,300.00 8,970.07 11,400.00 8,147.91 31.87 413.80 105.55 -2,003.06 7,166.81 0.29 1,535.72 755.11 858.62 Pass-Major Risk 12,300.00 8,970.07 11,425.00 8,163.87 31.87 415.32 106.42 -2,011.76 7,183.98 0.29 1,542.25 758.77 858.69 Pass-Major Risk 12,300.00 8,970.07 11,450.00 8,179.88 31.87 416.85 107.28 -2,020.48 7,201.10 0.29 1,549.13 758.43 859.28 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor, ES-min ellipse separation 1/25/2013 10:50:33AM Page 13 of 16 COMPASS 2003.16 Build 73 BAKER r HUGHES Travelling Cylinder Report i. .=I by ow INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well J-17 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB J Pad MD Reference: J-17C:@ 69.80ft(J-17C:) Site Error: 0.00ft North Reference: True Reference Well: J-17 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore J-17D Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 2 Offset TVD Reference: Offset Datum Offset Design PB J Pad- J-18-J-18A-J-18A Offset Site Error: 0.00ft Survey Program: 100-BOSS-GYRO,12469-MWD Rule Assigned:Major Risk Offset Well Error: 0.00ft Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Well bore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (ft) (ft) (°) on on (ft) (ft) (ft) (ft) 12,183.37 8,973.60 10,575.00 7,621.81 31.33 363.97 90.67 -1,730.05 6,593.18 0.29 1,544.33 907.17 1,073.64 Pass-Major Risk 12,189.25 8,973.56 10,600.00 7,637.98 31.36 365.41 90.75 -1,737.38 6,610.78 0.29 1,537.41 900.33 1,058.44 Pass-Major Risk 12,200.00 8,973.43 10,625.00 7,654.08 31.41 366.90 90.26 -1,744.78 6,628.41 0.29 1,530.95 885.20 1,046.51 Pass-Major Risk 12,200.00 8,973.43 10,650.00 7,670.10 31.41 368.39 91.07 -1,752.32 6,646.06 0.29 1,524.92 887.89 1,029.25 Pass-Major Risk 12,200.00 8,973.43 10,675.00 7,686.06 31.41 389.88 91.88 -1,759.99 6,663.71 0.29 1,519,40 890.58 1,012.41 Pass-Major Risk 12,210.57 8,973.26 10,700.00 7,701.94 31.46 371.36 91.45 -1,767.79 6,681.37 0.29 1,514.32 87508 1,002.52 Pass-Major Risk 12,215.38 8,973.17 10,725.00 7,717.76 31.49 372.89 91.71 -1,775.69 6,699.05 0.29 1,509.72 869.27 989.84 Pass-Major Risk 12,225.00 8,972.97 10,750.00 7,733.53 31.53 374.42 91.40 -1,783.63 6,716.74 0.29 1,505.58 854.68 981.27 Pass-Major Risk 12,225.00 8,972.97 10,775.00 7,749.26 31.53 375.95 92.26 -1,791.63 6,734.45 0.29 1,501.84 857.19 966.49 Pass-Major Risk 12,225.00 8,972.97 10,800.00 7,764.95 31.53 377.48 93.13 -1,799.69 6,752.17 0.29 1,498.57 859.70 952.18 Pass-Major Risk 12,232.94 8,972.76 10,825.00 7,780.64 31.57 379.01 93.04 -1,807.78 6,769.87 0.29 1,495.67 847.61 944.60 Pass-Major Risk 12,236.93 8,972.65 10,850.00 7,796.39 31.59 380.54 93.44 -1,815.89 6,787.51 0.29 1,493.12 842.61 934.57 Pass-Major Risk 12,240.75 8,972.54 10,875.00 7,812.19 31.61 382.07 93.86 -1,824.02 6,805.10 0.29 1,490.91 837.80 925.00 Pass-Major Risk 12,250.00 8,972.25 10,900.00 7,828.04 31.65 383.60 93.63 -1,832.17 6,822.63 0.29 1,489.07 822.50 921.10 Pass-Major Risk 12,250.00 8,972.25 10,925.00 7,843.95 31.65 385.09 94.53 -1,840.36 6,840.09 0.29 1,487.53 824.67 909.32 Pass-Major Risk 12,250.00 8,972.25 10,950.00 7,859.94 31.65 386.58 95.43 -1,848.61 6,857.45 0.29 1,486.34 826.83 897.95 Pass-Major Risk 12,250.00 8,972.25 10,975.00 7,875.99 31.65 388.08 96.33 -1,858.91 6,874.72 0.29 1,485.52 828.99 887.01 Pass-Major Risk 12,250.00 8,972.25 11,000.00 7,892.12 31.65 389.57 97.24 -1,865.28 6,891.89 0.29 1,485.07 831.15 876.49 Pass-Major Risk 12,260.59 8,971.87 11,025.00 7,908.27 31.70 391.05 96.87 -1,873.70 6,909.02 0.29 1,484.93 812.34 877.90 Pass-Major Risk,CC 12,263.45 8,971.76 11,050.00 7,924.40 31.71 392.53 97.44 -1,882.16 6,926.14 0.29 1,485.27 808.63 871.92 Pass-Major Risk 12,266.21 8,971.65 11,075.00 7,940.52 31.72 394.01 98.01 -1,890.66 6,943.25 0.29 1,486.06 805.05 866.43 Pass-Major Risk 12,275.00 8,971.28 11,100.00 7,956.62 31.76 395.49 97.85 -1,899.21 6,960.36 0.29 1,487.33 789.07 868.93 Pass-Major Risk 12,275.00 8,971.28 11,125.00 7,972.71 31.76 397.00 98.77 -1,907.79 6,977.47 0.29 1,488.97 790.98 861.51 Pass-Major Risk 12,275.00 8,971.28 11,150.00 7,988.77 31.76 398.50 99.69 -1,916.38 6,994.59 0.29 1,491.05 792.88 854.67 Pass-Major Risk 12,275.00 8,971.28 11,175.00 8,004.82 31.76 400.00 100.60 -1,924.98 7,011.72 0.29 1,493.57 794.79 848.40 Pass-Major Risk 12,275.00 8,971.28 11,200.00 8,020.85 31.76 401.50 101.51 -1,933.60 7,028.86 0.29 1,496.53 796.69 842.72 Pass-Major Risk 12,275.00 8,971.28 11,225.00 8,036.84 31.76 403.03 102.42 -1,942.23 7,046.03 0.29 1,499.95 798.63 837.61 Pass-Major Risk 12,275.00 8,971.28 11,250.00 8,052.77 31.76 404.56 103.32 -1,950.89 7,063.24 0.29 1,503.85 800.57 833.14 Pass-Major Risk,ES,SF 12,285.55 8,970.80 11,275.00 8,068.64 31.80 406.10 102.92 -1,959.57 7,080.50 0.29 1,508.11 778.33 844.45 Pass-Major Risk 12,287.69 8,970.70 11,300.00 8,084.45 31.81 407.63 103.55 -1,968.27 7,097.80 0.29 1,512.90 775.48 844.72 Pass-Major Risk 12,289.78 8,970.60 11,325.00 8,100.26 31.82 409.17 104.18 -1,976.97 7,115.10 0.29 1,518.10 772.70 845.60 Pass-Major Risk 12,300.00 8,970.07 11,350.00 8,116.10 31.87 410.71 103.79 -1,985.68 7,132.37 0.29 1,523.70 751.69 860.08 Pass-Major Risk 12,300.00 8,970.07 11,375.00 8,131.99 31.87 412.26 104.68 -1,994,37 7,149.61 0.29 1,529.54 753.40 859.10 Pass-Major Risk 12,300.00 8,970.07 11,400.00 8,147.91 31.87 413.80 105.55 -2,003.06 7,166.81 0.29 1,535.72 755.11 858.62 Pass-Major Risk 12,300.00 8,970.07 11,425.00 8,163.87 31.87 415.32 106.42 -2,011.76 7,183.98 0.29 1,542.25 756.77 858.69 Pass-Major Risk 12,300.00 8,970.07 11,450.00 8,179.86 31.87 416.85 107.28 -2,020.48 7,201.10 0.29 1,549.13 758.43 859.28 Pass-Major Risk CC-Min centre to center distance or covergent point,SF-min separation factor, ES-min ellipse separation 1/25/2013 10:50:33AM Page 14 of 16 COMPASS 2003.16 Build 73 r AI BAKER 0 HUGHES Travelling Cylinder Report bP INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well J-17 .fi`"^ T.,,a.'' r ,, Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB J Pad MD Reference: J-17C:@ 69.80ft(J-17C:) Site Error: 0.00ft North Reference: True Reference Well: J-17 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore J-17D Database: EDM.16-ANC Prod-WH24P .; . Reference Design: Plan 2 Offset TVD Reference: Offset Datum Offset Design PB Q Pad- Q-06-Q-06A-Q-06A Offset Site Error: 0.00ft Survey Program: 96-BOSS-GYRO,11089-MWD Rule Assigned:Major Risk Offset Well Error: 0 00f Reference Offset Semi Major Axis Measured Vertical Measured Vertical Reference Offset Toolface+ Offset Welibore Centre Casing- Centre to No Go Allowable Warning Depth Depth Depth Depth Azimuth +N/-S +E/-W Hole Size Centre Distance Deviation (ft) (ft) (ft) (ft) (f) (ff) (°) (ft) (ft) (ft) (ft) (ft) (ft) 12,135.78 8,973.48 11,775.00 8,963.91 31.09 318.77 157.01 -2,508.39 6,797.56 0.29 1,538.75 1,072.94 465.82 Pass-Major Risk 12,137.79 8,973.50 11,800.00 8,963.95 31.10 318.77 156.76 -2,483.43 6,796.11 0.29 1,515.17 1,072.61 442.57 Pass-Major Risk i 12,139.85 8,973.52 11,825.00 8,963.87 31.11 318.77 156.51 -2,458.47 6,794.66 0.29 1,491.64 1,072.26 419.38 Pass-Major Risk 12,150.00 8,973.61 11,850.00 8,963.75 31.16 318.77 155.31 -2,433.52 6,793.13 0.29 1,468.19 1,070.04 398.16 Pass-Major Risk 12,150.00 8,973.61 11,875.00 8,963.95 31.16 318.77 155.31 -2,408.59 6,791.24 0.29 1,444.54 1,070.10 374.45 Pass-Major Risk 12,150.00 8,973.61 11,900.00 8,964.71 31.16 318.77 155.33 -2,383.72 6,788.90 0.29 1,420.79 1,070.16 350.64 Pass-Major Risk 12,150.00 8,973.61 11,925.00 8,965.68 31.16 318.77 155.36 -2,358.88 6,786.21 0.29 1,396.98 1,070.22 326.76 Pass-Major Risk 12,150.00 8,973.61 11,950.00 8,966.61 31.16 318.78 155.39 -2,334.07 6,783.28 0.29 1,373.14 1,070.28 302.86 Pass-Major Risk 12,150.00 8,973.61 11,975.00 8,967.32 31.16 318.78 155.42 -2,309.27 6,780.21 0.29 1,349.29 1,070.34 278.95 Pass-Major Risk 12,150.00 8,973.61 12,000.00 8,967.69 31.16 318.78 155.43 -2,284.48 6,777.01 0.29 1,325.44 1,070.40 255.04 Pass-Major Risk 12,150.00 8,973.61 12,025.00 8,967.73 31.16 318.78 155.42 -2,259.71 6,773.58 0.29 1,301.56 1,070.46 231.10 Pass-Major Risk 12,150.00 8,973.61 12,050.00 8,967 98 31.16 318.78 155.43 -2,234.96 6,770.09 0.29 1,277.70 1,070.51 207.18 Pass-Major Risk 12,159.89 8,973.66 12,075.00 8,968.60 31.21 318.78 154.29 -2,210.23 6,766.51 0.29 1,253.73 1,067.94 185.78 Pass-Major Risk 12,161.92 8,973.66 12,100.00 8,969.38 31.22 318.78 154.08 -2,185.54 6,762.66 0.29 1,229.80 1,067.41 162.38 Pass-Major Risk 12,163.98 8,973.66 12,125.00 8,970.24 31.23 318.78 153.88 -2,160.87 6,758.72 0.29 1,205.87 1,066.86 139.00 Pass-Major Risk 12,166.09 8,973.66 12,150.00 8,971.12 31.24 318.78 153.67 -2,136.20 6,754.76 0.29 1,181.97 1,066.27 115.70 Pass-Major Risk 12,175.00 8,973.65 12,175.00 8,971.91 31.29 318.79 152.65 -2,111.57 6,750.53 0.29 1,158.09 1,063.37 94.71 Pass-Major Risk 12,175.00 8,973.65 12,200.00 8,972.57 31.29 318.79 152.69 -2,086.97 6,746.10 0.29 1,134.07 1,063.43 70.64 Pass-Major Risk 12,175.00 8,973.65 12,225.00 8,973.03 31.29 318.79 152.71 -2,062.36 6,741.73 0.29 1,110.12 1,063.49 46.62 Pass-Major Risk 12,175.00 8,973.65 12,250.00 8,973.00 31.29 318.79 152.71 -2,037.79 6,737.13 0.29 1,086.14 1,063.56 22.58 Pass-Major Risk 12,175.00 8,973.65 12,275.00 8,972.26 31.29 318.79 152.67 -2,013.16 6,732.95 0.29 1,062.34 1,063.62 -1.28 FAIL-Major Risk 12,175.00 8,973.65 12,300.00 8,970.91 31.29 318.79 152.59 -1,988.46 6,729.34 0.29 1,038.82 1,063.68 -24.87 FAIL-Major Risk 12,175.00 8,973.65 12,325.00 8,969.24 31.29 318.79 152.50 -1,963.71 6,726.18 0.29 1,015.54 1,063.74 -48.21 FAIL-Major Risk 12,185 50 8,973.59 12,350.00 8,967.62 31.34 318.79 151.16 -1,938.93 6,723.35 0.29 992.30 1,059.90 -67.62 FAIL-Major Risk 12,188.64 8,973.56 12,375.00 8,966.15 31.36 318.79 150.70 -1,914.13 6,720.54 0.29 969.20 1,058.71 -89.53 FAIL-Major Risk 12,200.00 8,973.43 12,400.00 8,964.88 31.41 318.80 149.26 -1,889.34 6,717.56 0.29 946.20 1,053.88 -107.71 FAIL-Major Risk 12,200.00 8,973.43 12,425.00 8,963.79 31.41 318.80 149.19 -1,864.56 6,714.42 0.29 923.02 1,053.95 -130.96 FAIL-Major Risk 12,200.00 8,973.43 12,450.00 8,962.67 31.41 318.80 149.11 -1,839.79 6,711.25 0.29 899.93 1,054.02 -154.11 FAIL-Major Risk 12,200.00 8,973.43 12,475.00 8,961.22 31.41 318.80 149.01 -1,815.02 6,708.16 0.29 876.99 1,052.30 -175.32 FAIL-Major Risk 12,200 00 8,973.43 12,500.00 8,959 67 31.41 318.81 148.89 -1,790.26 6,705.08 0.29 854.19 1,046.70 -191.88 FAIL-Major Risk 12,208.29 8,973.30 12,518.90 8,958.49 31.45 318.81 147.81 -1,771.54 6,702.76 0.29 836.92 1,047 83 -205.22 FAIL-Major Risk,CC,ES,S CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/25/2013 10:50.33AM Page 15 of 16 COMPASS 2003.16 Build 73 Hill y„, BAKER HUGHES Travelling Cylinder Report " :)i> INTEQ Company: North America-ALASKA-BP Local Co-ordinate Reference: Well J-17 Project: Prudhoe Bay TVD Reference: Mean Sea Level Reference Site: PB J Pad MD Reference: J-17C:@ 69.80ft(J-17C:) Site Error: 0.00ft North Reference: True Reference Well: J-17 Survey Calculation Method: Minimum Curvature Well Error: 0.00ft Output errors are at 1.00 sigma Reference Wellbore J-17D Database: EDM.16-ANC Prod-WH24P Reference Design: Plan 2 Offset TVD Reference: Offset Datum Reference Depths are relative to J-17C:@ 69.80ft(J-17C:) Coordinates are relative to:J-17 Offset Depths are relative to Offset Datum Coordinate System is US State Plane 1927(Exact solution),Alaska Zone 04 Central Meridian is 150°0'0.00 W° Grid Convergence at Surface is: 1.09° Ladder Pict I I I 1 Ic t 1600 I 1 I I I I I I I I I I I I I I I I I V I I 1 I I I --Vi 1 1 I 1 I I 1 1 I I I I I 1 I I I [I 1200 ' c I I I I I I 0 1 1 1 I I �t I .6 I I I I I I I I I I I I cc 0_ J J J J _ _ __ J_ __ _ • J _ _ a1 I I I I I I CO I I I I I I a) I I I I I 1 1 I I I I k 1800 1 1 I I 1 1 1 1 I I I 11 400 ■ li 1 1 I I I I I I I 1 I I I 1 1 1 1 I I I 1 I I I 1 I I I I I I I 1 I I I I I I I I 1 1 0 2500 5000 7500 10000 12500 15000 M easured Depth L E G E N D -e- J-17,J-17C,J-17CVII $- F-OS.F-08A,F-08 AV3 J-18.J-18.J-18V1 F-02.F-02A,F-02AV4 ” F-08.F-08B,F-08B VO J-18,J-18A.J-18AVO F-08,F-08,F-08 V1 F-40.F-40.F-40 V1 —61/4— Q-06.0-06A.0-06AV4 CC-Min centre to center distance or covergent point,SF-min separation factor,ES-min ellipse separation 1/25/2013 10:50:32AM Page 16 of 16 COMPASS 2003.16 Build 73 _. , . 1 I L N 1 I 1 1 % 1 ot I 1 Uf U I I I e 1 • 1 11:1 -- 1 - • 1 I 1 I MI =1111 All 0 % a • 1 a-m 3 f Y ■ 11 I N 1 N I I (7 N I 0 w 1 a � � , I I I V ; 1 II ..� � 1 O J 1 I 1 I Q `1 1 1 Z 2 1 ° .. 1 0 g 1 EI I I I 3 I I " I s i 2 W v � I = 1 • .r.,�. Id" I I- -- I ( . I 1 \ 1 L ° Y 1 0 z I I• 1 \ J g s I . � 1 \ >1�u I W � �. I•Y \ [ I 2 s i I? Wg Q I W ; a� z.• \= g n y Y' I N g a z i i U \ Y 2 \ ' I ; I o I C) a .1 a F�_ _ - 0 �c > U I 0 L A r I 00" I I 4 ,„ WI ...."'--4 I 2 z I 2 . F I} ° I �� s 1 S U U I s 1 I 1 1 -I 1 i e= I 1.- 1- S 1 S . TRANSMITTAL LETTER CHECKLIST WELL NAME /9J -------T— /7 PTD# 2i 3 b (e__-- ,./Development Service Exploratory Strati ra hic Test Non-C ventioonnal Well FIELD: /— h -- / POOL: glx._c1 -L6'--2--- 6 i / Check Box for Appropriate Letter/Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well ' (If last two digits in Permit No. ,API No. 50- - - API number are between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - - ) from records, data and logs acquired for well . SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to produce/inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Non-Conventional Please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for(name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name)must contact the Commission to obtain advance approval of such water well testing program. 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