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203-008
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' MIS cik,4 �/ e;, a a a a a a OO O O O OE Ual GNI C5 a f0 a) a) 01 h a) Q Q N N N N CO Q1 no ro ill cm _ a' o �.ii m V C CC O O O O O O Q Tr c4 -6 in O M in h 73 _l co 00 co h F-- O + > IR\7 a h N C N N N N N N N C m Cr) N Cr)N O N Cr) H 0 N N N N N N C O O O O O O oN t-. C 0 0 0 0 0 0 y+ 4' a) C /4 a IA In to N to IA a TS CO CM C* V l C u al O C O 11J cc Y .::,..... •U L Q�1 cD '� i— pp m_L Q Q U Q m rn :° a) C a CV i 2 L N Z N O O O E n1 V TO i C C N o f o V O Z V 73 10 w C - RSeL v 11 P c 8 i i° ' C a 0 CM a Q . a F- c ° m STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMI WELL OMPLETION OR RECOMPLETION REPOAND LOG la. Well Status: Oil ❑ Gas 0 SPLUG 0 Other 0 Abandoned 0 • Suspended 0 lb.Well Class: 20AAC 25.105 20AAC 25.110 ` Development 0 Exploratory 0 GINJ ❑ WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero " Service ❑ Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: • 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 12/3/2016 • 203-008 ' 316-565 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 4/18/2003 50-029-21775-02-00 4 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 4/20/2003 PBU C-31 B • Surface: 1800'FNL,883'FEL,Sec.19,T11N,R14E,UM • 9 Ref Elevations KB 70 9 17. Field/Pool(s): Top of Productive Interval: 3333'FNL,5204'FWL,Sec.20,T11N,R14E,UM GL 37.28 BF 37.82 PRUDHOE BAY,PRUDHOE OIL Total Depth: 3961'FNL,4182'FWL,Sec.20,T11N,R14E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: . 11325'/8746' • ADL 028305 • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 664508• y- 5959422 • Zone - ASP 4 • . 13688'/9022' • 80-274 TPI: x- 670632 y- 5958025 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20. Thickness of Permafrost MD/TVD: Total Depth:x- 669627 y- 5957375 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No 0 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) • 12047'/9014'. 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 MC 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,CCL,GR SCANNED APR 2 6 2017 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT Fr. PULLED TOP BOTTOM TOP BOTTOM 20"x 30" 37' 117' 37' 117' 8 cu yds Concrete 13-3/8" 68# L-80 36' 2828' 36' 2722' 17-1/2" 3900 cu ft Permafrost 9-5/8" 47# L-80 33' 10006' 33' 7597' 12-1/4" 2335 cu ft Class'G' 7" 29# L-80 9860' 11942' 7481' 9014' 8-1/2" 416 cu ft Class'G' 4-1/2" 12.6# L-80 11902' 12047' 9014' 9014' 6" 309 cu ft Class'G' 2-3/8" 4.6# L-80 11366' 13688' 8781' 9022' 3" 95 cu ft Class'G' 24. Open to production or injection? Yes 0 No 0 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 3-1/2"9.3#L-80 11458' 11274'/8702' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. A-15' 9 tv09 RECEIVED Was hydraulic fracturing used during completion? Yes 0 No 0 • *-- Per 20 AAC 25.283(i)(2)attach electronic and printed DEC 19 2016 information I Z 1./(4° DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED AOGCC See Attached L t- 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 Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period r".. Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corr): Press 24 Hour Rate Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only it77-- /Zg// - 4, RBDMS RBDMS IL- DEC 2 2 2016 , 4- g-r7 fG- 28., CORE DATA • Conventional Cores) Yes 0 No H • Sidewall Cores Yes 0 No H - If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes 0 No 0 Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach separate sheets to this form,if needed,and submit detailed test information per 20 Top of Productive Interval 11665' 8957 AAC 25.071. Zone 1B 11665' 8957' Zone 1 A 11688' 8965' Kicked off from Parent Well 12047' 9014' (C-31 A) Zone 1B(Invert) 13460' 9023' Formation at total depth: , 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.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Browning,Zachary H Email: Zachary.Browning@bp.com Printed Name: Joe Lastufka Title: Drilling Technologist I r Signature: e: +1 907 564 4091 Date: 1241 1/' INSTRUCTIONS General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. 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 1 a. 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 1 b.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 MC 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 11/2015 Submit ORIGINAL Only s • WELL NAME: C-31B 26. Acid, Fracture, Cement Squeeze, Etc. Depth Interval (MD) Amount & Kind of Material Used 11400' Set CIBP 11287' - 11292' Tubing Punch 11360' Set Cement Retainer 11358' 10 Bbls Class 'G' 11325' Set Whipstock • • • C-31B (Pre-Rig Sidetrack) ACTIVITYD UMJAARY Assist E-line. MIT-T PASSED to 2603 psi. Max Applied Pressure=2750 psi. Target Pressure=2500 psi. Pressured up TBG to 2704 psi w/6.3 bbls of 20 diesel. 1st 15 min TBG lost 77 psi. 2nd 15 min TBG lost 24 psi for a total pressure loss of 101 psi in 30 min. Bled TBG to 300 psi. Bled back—2 bbls. Tag hung. E-line in control of well upon departure. FWHPS=300/10/80 11/9/2016 Safety drill: loss of well control. (SLB ELINE PLUG/TUBING PUNCH/CEMENT RETAINER) LRS FINISH LOADING WITH 1%KCL AND FREEZE PROTECT. RUN 1: RIH W/GR/CCL/MSST/2-3/8"WEATHERFORD CIBP. SET PLUG ME AT 11400'. (TOP AT 11399.5'). CCL TO ME: 9.4'; CCL STOP DEPTH: 11390.6'. LRS PERFORMS MIT-T. RUN 2: RIH WITH GR/CCL/5' TUBING PUNCH LOADED 4 SPF, 0 DEG PHS, SMALL CHARGES. PUNCHED TUBING FROM 11287' - 11292'. CCL TO TS: 5.6', CCLSTOP DEPTH: 11281.4'. RUN 3: RIH W/GR/CCL/MSST/3-1/2" HAL EZSVB CMT RETAINER. SET CMT RETAINER TOP @ 11360'. CCL TO RETAINER = 9.2'. CCL STOP DEPTH = 11350.8' ALL LOGS CORRELATED TO SLB MEMORY CNL DATED 31-MAY-2007. 11/9/2016 FINAL T/I/O = 0/0/0 PSI CTU #14- 1.75" CT Job Objective: Cement behind tailpipe. MIRU. Make up Cement Stinger BHA and RIH. Test tubing to 1000 psi and lost 28 psi in 5 11/20/2016 mins. Continue RIH. CTU #14 - 1.75" Coil Job Objective: Pre-CTD Cement Continue RIH with Cement Stinger BHA. Notice gas in returns from swabbed-in packer gas. Re-pressure test tubing to confirm no communication with formation or IA. Before stinging in, pick up 1500' rapidly to drop liquid level and swab even more packer gas into the tubing to be circulated out. Pump 0.5 bpm and sting into retainer for good confirmation, able to circulate out tubing punch holes. Sweep tubing tail/ Liner lap with Slick 1% KCL at high rate to remove gas and circulate out tubing. Freeze protect coil and well, Continue to standby for HES 11/21/2016 Cementer availability. CTU #14 - 1.75" Coil (CV- 33.4) Job Objective: Pre-CTD Cement Standby for HES Cementers. RU HES cementers. Batch up cement. Pump 20 bbl freshwater spacer followed by 10 bbls of 15.8 ppg Class G cement. Circulate in 8 bbls of cement behind pipe. Unsting from retainer recipricate pipe while reverse circulating. Pump 20 bbl powervis from surface and reverse out. Cement top 2' above retainer at 11358', Top of cement in 11/22/2016 annulus 11287'. POOH while reverse circulating. Reverse circulate in freeze protect. ***WELL S/I ON ARRIVAL"**(pre-ctd) DRIFT TBG W/20'x 2.70" DUMMY WHIPSTOCK TO CEMENT RETAINER AT 11,343' SLM(11,360' MD) DRIFT TBG FOR SCMT TOOLS W/36'x1.75" DD BAILER TO CEMENT RETAINER AT 11,343' SLM (11,360' MD) CUURENTLY IN-HOLE LOGGING W/SLB MEMORY GR/CCL/SCMT FROM 11,323' SLM 11/23/2016 TO 10,900' SLM RAN SLB MEMORY GR/CCL/SCMT LOG AS PER PRORGRAM FROM 11,323' SLM TO 10,900' SLM (good data) 11/24/2016 ***WELL LEFT SHUT-IN ON DEPARTURE, PAD OP NOTIFIED*** • • C-31B (Pre-Rig Sidetrack) ***WELL S/I ON ARRIVAL*** (SLB E-LINE UNIT 2362 - WHIPSTOCK SETTING) INITIAL PRESSURES: 0/170/0 PSI MIRU AND PRESSURE TEST RUN 1 : RIH W/ HEAD, ERS, SWIVEL, WPP, BST#10, 3-1/2" MONOBORE WHIPSTOCK. OAL=50', OAW= 300LBS, MAX OD = 2.7". SET TOWS AT 11330', ORIENTED 6 DEG ROHS. CCL TO TOWS = 16', CCL STOP DEPTH = 11314'. SET WITH GOOD 11/24/2016 INDICATION. CORRELATED TO SLB MEMORY CNL DATED 31-MAY-2007. POOH, CONFIRM WHIPSTOCK SET. RDMO, NOTIFY PAD OPERATOR UPON DEPARTURE 11/25/2016 FINAL T/IA/OA= 0//170/0 T/I/O=0/0/0. RU TS#02 . Installed 6" integral flange on WV w/downcomer. Torqued and PT'd to API specs. RDMO***Job Complete***SEE LOG FOR DETAILS. Final T/I/O= 0/0/0 . 11/25/2016 Note: Tree/Valve pressure test record attached to MV handle T/I/O = 5/30Nac. Temp = SI. WHPs (Pre rig). No AL, flowline, orwellhouse. 11/26/2016 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 14:00. T/I/O = SSV/42/5. Temp = SI. MIT-OA PASSED to 1160 psi, Max pressure= 1200 psi, Target Pressure= 1100 psi. (pre RIG). Used 2.3 bbls of DSL to pressure up OAP from 5 psi to 1200 psi. IAP decreased 27 psi in 1st 15 min and 13 psi in 2nd 15 min fora total loss of 40 psi in 30 min. Bled OAP from 1160 psi to 0 psi in 10 min (1.4 bbls). Tags hung. Final WHPs = SSV/10/0. 11/29/2016 SV, WV= ??. SSV= C. MV= 0. IA, OA= OTG. 23:59 T/I/0=40/40/15 Temp=S/I (Pre RWO) MIT-T PASSED to 2803 psi, Max Applied Pressure= 3000 psi, Target Pressure= 2700 psi. Pressured Tbg to 2971 psi with 1.3 bbls of diesel. MIT- Tbg lost 117 psi in 1st 15 minutes and 51 psi in 2nd 15 minutes for a total of 168 psi during 30 minute test. Bled Tbg to 40 psi. Bled back-1.5 bbls. SV,CV,SSV=closed MV=open IA,OA=otg. Final WHPs =40/40/10. MIT tag hung. Pad Op notified of well status on 11/30/2016 departure. • • North America-ALASKA-BP Page 1 c Operation Summary Report Common Well Name:C-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/3/2016 End Date: 'X3-01854-C:(2,272,050.00) Project:Prudhoe Bay j-Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:1/2/1988 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UW1: Active datum:C-31A/B OKB @70.90usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12/1/2016 14:00 - 14:40 0.67 MOB P PRE PREP TO MOVE OFF WELL 14:40 - 15:00 0.33 MOB P PRE PJSM WITH ALL INVOLVED PARTIES TESTED AND VERIFIED ESD WAS FUNCTIONAL AND IS MANNED BY TOOLPUSHER -VERIFIED 12 X 12 WHEEL CHOCK IN PLACE ASSIGNED SPOTTERS TO AREA OF RESPONSIBILITY -DISCUSSED THAT"STOP"IS THE COMMAND TO STOP RIG -PERFORMED RADIO CHECK PRIOR TO MOVING RIG DISCUSSED WITH CREW THAT THERE IS NO BPV/TWC INSTALLED 15:00 - 16:00 1.00 MOB P PRE MOVE RIG OFF 7-19 MOVED OFF WITHOUT ANY ISSUES PU RIG MATS 16:00 - 22:30 6.50 MOB P PRE MOVE RIG TO C-PAD 22:00 NOTIFY PARKER 272 TO PREP FOR SUSPENDING OPERATIONS WHILE NORDIC 2 IS ON THE C-PAD ACCESS ROAD 22:30 NORDIC 2 ON ACCESS ROAD AND 272 HAS SUSPENDED OPERATIONS UNTIL N2 HAS CLEARED THE ACCESS ROAD 'HOLD A FACE TO FACE WITH PARKER 272 WSL AND TOOL PUSHER TO DISCUSS MOVING NORDIC 2 PAST 272 22:30 - 23:30 1.00 MOB P PRE RIG IS ON THE ACCESS ROAD TO C-PAD, HOLD A FACE TO FACE WITH PARKER 272 TOOL PUSHER AND WSL TO DISCUSS MOVING PAST 272 TO GET TO OUR WELL, ;PAD OP WAS NOT AVAILABLE AND SAID TO PROCEED 22:30 - 22:30 0.00 MOB P PRE NOTIFY PARKER 272 TO PREP FOR SUSPENDING OPERATIONS WHILE NORDIC 2 IS ON THE ACCESS ROAD TO C-PAD 23:30 - 23:45 0.25 MOB P PRE MOVE NORDIC 2 PAST PARKER 272 MOVED PAST 272 WITH PLENTY OF ROOM AND NO INCIDENTS 23:45 - 00:00 0.25 MOB P PRE PREP WELL TO SPOT RIG OVER WELL 12/2/2016 00:00 - 00:45 0.75 MOB P PRE SPOT T-MATS VERIFY ALL CASING PRESSURES,IA&OA ARE AT O PSI SHUT IN ALL TREE&CASING VALVES I PAD OP NOTIFIED WE ARE PREPPING TO SPOT THE RIG OVER THE WELL Printed 12/12/2016 3.30:56PM *All depths reported in Drillers Depths" Pa S 1T North Americae2-ALASKA-BP s Operation Summary Report Common Well Name:C-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/3/2016 End Date: X3-01854-C:(2,272,050.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:1/2/1988 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active datum:C-31A/B OKB©70.90usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 00:45 - 01:00 0.25 MOB P PRE PJSM TO SPOT RIG OVER WELL -TESTED AND VERIFIED ESD WAS FUNCTIONAL AND IS MANNED BY TOUR PUSHER -VERIFIED 12 X 12 WHEEL CHOCK IN PLACE -ASSIGNED SPOTTERS TO AREA OF RESPONSIBILITY --DISCUSSED THAT"STOP"IS THE COMMAND TO STOP RIG -PERFORMED RADIO CHECK PRIOR TO MOVING RIG -DISCUSSED WITH CREW THAT THERE IS NO BPV/TWC INSTALLED PAD OP IS HERE TO WITNESS PULLIONG OVER WELL 01:00 - 01:30 0.50 MOB P PRE SPOT RIG OVER WELL 01:30 - 02:30 1.00 RIGU P PRE RIG SPOTTED AND ACCEPTED AT 01:30 AM HOLD A PJSM WITH CREW TO START RU OPERATIONS AND RU 02:30 - 03:30 1.00 RIGU P PRE CYCLE TREE VALVES,OPEN SSV,INSTALL FUSIBLE CAP AND LTT MASTER&SWAB VALVES TO REMOVE TREE CAP AND NU BOPE 03:30 - 05:30 2.00 RIGU P PRE REMOVE TREE CAP AND NU BOPE 05:30 - 06:15 0.75 RIGU P PRE BOP'S NU,GET STACK MEASURMENTS 06:15 - 07:00 0.75 RIGU P PRE CREW CHANGE 07:00 - 08:00 1.00 RIGU P PRE FLUID PACK STACK&CHOKE MANIFOLD 08:00 14:30 6.50 BOPSUR P PRE TEST BOPE AS PER BP.AOGCC AND NORDIC ,REQUIREMENTS 1 250 PSI LOWAND 3500 PSI HIGH 14:30 - 14:45 0.25 BOPSUR P PRE BOP TEST COMPLETED, HOLD A PJSM WITH THE GREASE CREW TO CHECK TREE BOLTS 14:45 - 15:45 1.00 BOPSUR P PRE PU THE INJECTOR AND STAB ON WELL ALLOW GREASE CREW TO CHECK TREE BOLTS FOR PROPER TORQUE 15:45 - 16:40 0.92 BOPSUR P PRE TREE BOLTS CHECKED,DISPLACE DIESEL FROM COIL TO FRESH WATER TO TEST THE INNER REEL VALVE AND PACK OFF FRESH WATER AT BOTH MICRO MOTIONS SHUT DOWN AND CALIBRATE 16:40 - 17:05 0.42 BOPSUR P PRE TEST INNER REEL VALVE AND PACK OFF 17:05 - 17:15 0.17 BOPSUR P PRE PREP TO REVERSE CIRCULATE 17:15 - 19:20 2.08 BOPSUR P PRE SLACK PUMPED,HOLD A PJSM TO BLOW BACK THE COIL,PU THE INJECTOR,RU THE CUTTER AND CUT 276'OF PIPE. 19:20 - 20:45 1.42 BOPSUR P PRE PREPARE COIL TUBING FOR COIL ;CONECTOR INSTALL COIL CONNECTOR AND PULL TEST TO 38K PERFORM 350 PSI LOW/3900 PSI HIGH COIL CONNECTOR TEST. 20:45 - 23:00 2.25 BOPSUR P PRE INSTALL NOZZLE. PUMP WIRE FORWARD. TEST E-LINE. GOOD TEST ,INSTALL BHI UQC W/FLOATS. TEST CONNECTION. GOOD TEST Printed 12/12/2016 3.30:56PM *All depths reported in Drillers Depths* • North America-ALASKA-BP • Page 3 oC3 Operation Summary Report Common Well Name:C-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) i Start Date:12/3/2016 End Date: X3-01854-C:(2,272,050.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:1/2/1988 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active datum:C-31A/B OKB @70.90usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 23:00 - 00:00 1.00 BOPSUR P PRE TEST UQC TO 350 PSI LOW/4000 PSI HIGH. PRESSURE TEST FLOATS TO 350 PSI LOW/ 3700 PSI HIGH. GOOD TEST. 12/3/2016 00:00 - 01:50 1.83 BOPSUR P PRE CONTINUE CIRCULATING COIL OVER TO 1% KCL OPEN WELL TO A CLOSED CHOKE. 0+ PRESSURE. BLED OFF IMMEDIATELY FILL WELL WITH 1-1/2 BBLS METHANOL. PERFORMED FLOW CHECK. PJSM FOR MAKING UP BHA 01:50 - 02:00 0.17 STWHIP P WEXIT MAKE UP 2-3/8"WINDOW MILLING BHA#1 -PICK UP 2-3/8"XTREME MOTOR(0.6 DEG AKO)AND 2-3/8""COILTRAK TOOLS -MAKE UP 2.74"HCC WINDOW MILL/STRING REAMER(BOTH 2.74"GO/2.73"NOGO) -SURFACE TESTED TOOL.GOOD TEST. -PRESSURE TEST QTS TO 300 PSI LOW FOR 5 MINUTES/4000PSI HIGH FOR 5 MINUTES -INJECTOR ON:01:50 02:00 - 05:00 3.00 STWHIP P WEXIT RIH WITH 2-3/8"WINDOW MILLING BHA#1 FROM SURFACE. -RATE:0.30 BPM IN,0.75 BPM OUT.CIRC PRESSURE:253 PSI MUD WEIGHT:8.34 PPG IN,6.78 PPG OUT -INITIAL ENTRY, TAKING ALL RETURNS OUT TO FLOWBACK TANK. -LOG DOWN FOR TIE-IN FROM 11,000'TO 11107'MD(FORMATION)WITH-22.5' CORRECTION 05:00 - 07:00 2.00 STWHIP P WEXIT RIH TO LIGHTLY DRY TAG WHIPSTOCK AT 11327' PU 10'. INCREASE RATE 3.00 BPM IN /3.0 BPM OUT 8.45 PPG IN /8.37 PPG OUT DISPLACE WELL TO MUD 07:00 - 07:05 0.08 STWHIP P WEXIT GOOD MUD BACK AT SURFACE,LINE UP TO TAKE MUD THROUGH THE MGS FOR THE FIRST FULL CIRCULATION LIGHTLY TAG WS AGAIN TO VERIFY DEPTH TAG AT 11327 AS WELL,SHUT DOWN PUMP AND CLOSE THE EDC • 07:05 - 11:00 3.92 STWHIP P WEXIT START MILLING WINDOW FREE SPIN=3960 PSI AT 1.76 BPM C,31(./ MILL 2.74"WINDOW PER BAKER REP FROM 11326.0'MD TO 11332'MD,FIRST STAGE OF 2 -RATE:1.76 BPM IN,1.76 BPM OUT -CIRC PRESSURE:4086 PSI -MUD WEIGHT:9.60 PPG IN,9.53 PPG OUT -DWOB:0.69-2.98 KLBS 11:00 - 13:45 2.75 STWHIP P WEXIT CONTINUE MILLING WINDOW FREE SPIN=3960 PSI AT 1.76 BPM MILL 2.74"WINDOW PER BAKER REP FROM 11326.0'MD TO 11332'MD,FIRST STAGE OF 2 -RATE:1.76 BPM IN,1.76 BPM OUT -CIRC PRESSURE:4047 PSI -MUD WEIGHT:9.60 PPG IN,9.53 PPG OUT -DWOB:1.53-2.98 KLBS 13:45 - 13:55 0.17 STWHIP P WEXIT MILLED 6'OF WINDOW TO COMPLETE FIRST STAGE,ALLOW TO MILL OFF THEN MAKE REAM PASSES AS PER PLAN Printed 12/12/2016 3.30:56PM "All depths reported in Drillers Depths" • North America-ALASKA-BP Page 4 aa9 Operation Summary Report Common Well Name:C-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/3/2016 End Date: X3-01854-C:(2,272,050.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:1/2/1988 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active datum:C-31A/B OKB @70.90usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 13:55 - 15:00 1.08 STWHIP P WEXIT START REAMING PASSES FROM 11332 TO 11320' FIRST PASS 0°UP&0°DOWN SECOND PASS 15°LEFT UP&0°DOWN THIRD PASS 15°RIGHT UP&0°DOWN 15:00 - 15:10 0.17 STWHIP P WEXIT ,REAM PASSES COMPLETED,SHUT DOWN PUMP AND DRY DRIFT 'DRY DRIFT IN BOTH DIRECTIONS ARE CLEAN 15:10 - 15:40 0.50 STWHIP P WEXIT OPEN EDC AND FLOW CHECK WELL TO POOH GOOD NO FLOW,PURGE LUBRICATOR STACK AS PER PLAN AND NORDIC PROCEDURE THEN POOH 15:40 - 17:20 1.67 STWHIP P WEXIT STACK IS PURGED,POOH HOLD A PJSM WHILE POOH TO SWAP MOTORS FOR 2ND STAGE OF WINDOW 17:20 - 17:35 0.25 STWHIP P WEXIT FLOW CHECK WELL 17:35 - 17:45 0.17 STWHIP P WEXIT GOOD NO FLOW,TAG UP,REMOVE THE INJECTOR AND PULL THE BHA 17:45 - 18:25 0.67 STWHIP P WEXIT LAY DOWN BHA#1 MILL AND STRING REAMER 2.74"GO/2.73"NO GO -MAKE UP WEATHERFORD FIXED BEND MOTOR AND 2.74"FAT RADIUS MILL -INJECTOR ON:18:25 18:25 - 20:45 2.33 STWHIP P WEXIT RIH WITH 2-3/8"DRILLING BHA#2 FROM !SURFACE j-RATE:0.50 BPM IN,0.86 BPM OUT.CIRC PRESSURE:1410 PSI -MUD WEIGHT:9.52 PPG IN,9.55 PPG OUT -LOG DOWN FOR TIE-IN FROM 11085'TO 11108'MD(FORMATION)WITH-25 CORRECTION 20:45 - 00:00 3.25 STWHIP P WEXIT MILL 2.74"WINDOW IN 3-1/2"x 7" CASING/LINER PER BAKER REP FROM 11332' MD TO XXXX'MD -RATE:1.62 BPM IN,1.62 BPM OUT MUD WEIGHT:9.55 PPG IN,9.55 PPG OUT -DWOB:1.5K -CIRC PRESSURE:3920-4500 PSI -FOLLOW SCHEDULE PER PROGRAM -11333.4' TAKING LONGER TO MILL OFF 12/4/2016 00:00 - 04:00 4.00 STWHIP N DPRB WEXIT MILL 2.74"WINDOW IN 3-1/2"x 7" CASING PER BAKER REP -RATE:1.63 BPM IN,1.63 BPM OUT -MUD WEIGHT:9.58 PPG IN,9.52 PPG OUT -DWOB:3.0—3.5 KLBS -CIRC PRESSURE:3900 PSI -11333.50' EXTREMELY SLOW MILL OFF. 04:00 - 06:00 2.00 STWHIP N DPRB WEXIT ONCE 1.4' MILLED. START WORKING WOB UP. NO REAL INCREASE IN MOTOR WORK. VERY LITTLE CUTTINGS COMING ACROSS SHAKERS PU TO VERIFY PARAMETERS PU CLEAN. INCREASE RATE TO 1.75 BPM @ 4190# 736#DIFFERENTIAL AT MOTOR Printed 12/12/2016 3:30:56PM *AII depths reported in Drillers Depths* • . • North America-ALASKA-BP Page 5 _P . Operation Summary Report Common Well Name:C-31 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:12/3/2016 End Date. X3-01854-C:(2,272,050.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:NORDIC 2 Spud Date/Time:1/2/1988 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UWI: Active datum:C-31A/B OKB @70.90usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 06:00 - 06:20 0.33 STWHIP N DPRB WEXIT NOT MAKING ANY PROGRESS IN THE LAST 6 HOURS MAINTAINED<3.5K WOB AS PER THE PLAN FOR THE FIRST 1.4'.SLOWLY INCREASED WOB TO TRY AND MILL THE WINDOW UP TO 5.2K WOB BUT NOT MAKING ANY PROGRESS IN ALMOST 6-HRS. CALL ODE AND DISCUSS PULLING TO CHECK THE MOTOR&MILL HAVE HCC BRING ANOTHER MILL TO WEATHERFORDAND HAVE IT TORQUED UP READY TO GO WHEN WE GET TO SURFACE. 06:20 - 06:35 0.25 STWHIP N DPRB WEXIT FLOW CHECK WELAND POOH TO CHECK THE MOTOR&MILL _ 06:35 - 08:10 1.58 STWHIP N DPRB WEXIT POOH TO CHECK THE MOTOR&MILL 07:55 HOLD A PJSM TO PULL THE BHA AND CHECK THE MOTOR&MILL 08:10 - 08:30 0.33 STWHIP N DPRB WEXIT FLOW CHECK WELL 08:30 - 09:00 0.50 STWHIP N DPRB WEXIT GOOD NO FLOW,TAG UP,REMOVE THE INJECTOR AND PULL THE BHA .BHA OOH,TRANSMISSION ON THE MOTOR IS 1 BROKE/SHEARED OUT MILL STILL IN GAUGE AT 2.74 GO 2.73 NO GO CALL ODE AND DISCUSS PU ANOTHER WEATHERFORD MOTOR AND MILL AND RIH 09:00 - 09:30 0.50 STWHIP N DPRB WEXIT ODE AGREE'S TO RUN 2ND 2.0°MOTOR AND NEW FAT RADIUS MILL,MU BHA MILL GAUGED 2.74 GO 2.73 NO GO 09:30 - 11:35 2.08 STWHIP N DPRB WEXIT BHA MU,RIH 11:35 - 11:50 0.25 I STWHIP N DPRB WEXIT LOG TIE IN 11:50 - 12:20 0.50 STWHIP N DPRB WEXIT CORRECT DEPTH-25'AND RIH TO CONTINUE MILLING THE WINDOW WICK=38K,RIH WT=14K FREE SPIN=4120 AT 1.75 BPM RIH AT 1 FPM FROM THE TOW TO CASING CONTACT-11334.6' Printed 12/12/2016 3:30:56PM *All depths reported in Drillers Depths* TRIM= 6"X 7"CNV FLS • �WELLFEAD= McEVOY SA NOTES:WELL ANGLE>70°@ 11730'. ;.ACTUATOR= BAKERC C-31 B _OKB.REV= 67.78' REF B_EV= 70.9' BF.REV= 37.82' KOP= 1700' 2115' —13-1/2"OTIS SSSV LAND.NIP,ID=2.75" Max Angle= 96°@ 12186' O Datum MD= 11487'SS Datum TVD= 8800'SS 13-3/8"CSG,68#,L-80 BUTT,ID=12.415" — 2825' 1 GAS LIFT MANDRELS ST MD DEV TYPE VLV LATCH PORT DATE Minimum ID = 1.995" @ 11372' 3 5091 4271 50 MMG DMY RK 0 08/20/16 TOP OF 2-3/8" LINER 2 8601 6568 46 MMG DMY RK 0 08/20/16 1 11232 8665 29 MMG-2 DMY RK 0 04/30/03 9-5/8"X 7"BKR LTP w/TIEBACK SLV,ID=6.187" H 9860' 9-5/8"X 7"BKR NSCC LNR HGR,ID=6.250" H 9873' ■ I 9-5/8"SIDETRACK WINDOW-10006'-10056'(SECTION MLL) NOTE PRE-SDTRK WELLBORE NOT SHOWN BROW 9-5/8" MLLOUT WINDOW. 9-5/8"CSG,47#,L-80 NSCC/BUTT,ID=8.681" H 10006' TOC(11/22/16) -L 11287' 11260' H3-1/2"OTIS X NIP,ID=2.75" TBG PUNCH(11/09/16) H 11287'-11292' ELM0 cl 11274' H7"x 3-1/2"BKR SA BL-3 PKR,ID=3.85" 3-1/2"BKR MONOBR WS w/2 PIP TAGS(11/24/16) — 11325' ELM 'W. ��11299' 3-1/2"OTIS X NIP,ID=2.75" TOC(11/22/16) — 11358' i (•, 3-1/2"HES CMT RETAINER(11/09/16) 11360' ELM r1�0'''�'���"' 11366' H2.70"BKR DEPLOYMENT SLV,ID=2.250" 1,0 ACC 2-3/8"WFD CIBP(11/09/16) 11400' ELM 0 �1 ) 11445' —13-1/2"OTIS X NIP,ID=2.75" 11 S1, 44 H,4 3-1/2"TBG,9.3#,L-80 NSCT,.0087 bpf,ID=2.992" H 11457' At .4 11457' HI3-1/2" WLEG,ID=2.992" 11456' —{ELMD TT LOGGED 10/09/98 1•4 014 11650' —I TOP OF CEMENT /�/,1 AO 11884' H7"X 4-1/2"BKR H LNR TOP PKR,ID=4.44" RIF 4 1 I 11902' H7"X4-1/2"LTPw/BKR TIEBACK SLV,ID=5.25" Iii I 11915' H7"X 4-1/2"BKR LNR HGR,ID=4.37" 7"LNR,29#,L-80 NSCT, .0371 bpf,ID=6.184" H 11942' °1 X WHIPSTOCK W/2 RA TAGS H 12025' �; I MILLOUT WINDOW 12047'-12051' 4-1/2"LNR, 12.6#,NT-80 NSCT,.0152 bpf, ID=3.958" --I —12025' 4 Y PERFORATION SUMMARY ie. ` 12610' —I2-3/8"WFD CIBP(10/12/15) REF LOG: MWD/GR ON 04/15/03 '*Av 4 ANGLE ATTOPPERF: 90"@ 12050' _ ` 13400' —I2-3/8"CIBP(01/08/14) Note:Refer to R-oduction DB for historical pert data ••:•© // ` SIZE SPF INTERVAL Opn/Sqz DATE SQZ 13674' PBTD 1.56" 6 12080-120 C 01/11/15 // 1.56" 6 12080-1211110 C 01/10/15 1.56" 6 12110-12140 C 01/10/15 1.56" 6 12140-12170 C 01/10/15 � 1.56" 6 12170-12200 C 01/09/15 .... 1.56" 6 12200-12230 C 01/09/15 1-1/2" 4 12700-12760 C 04/23/03 1-1/2" 4 12930-13355 C 04/23/03 2-3/8"LNR,4.6#,L-80 STL,.0039 bpf,ID=1.995" H 13688' 1-1/2" 4 13480-13670 C 04/23/03 DATE REV BY COMNI8 JTS DATE REV BY CONVENTS PRUDHOE BAY UNIT 02/22/88 N18E ORIGINAL COMPLETION 11/09/15 ATO/JMD SET CIBP(10/12/15) WELL: C-31B 03/11/95 D-14 RIG SIDETRACK (C-31A) 08/24/16 JAR/JIVE)GLV C/O(08/20/16) PERMIT No:42030080 04/24/03 DAV/KK CTD SIDETRACK(C-31B) 11/16/16 MRD/JIVE)SET GBP/TBG PUNCI-VCMT RETAINER API No: 50-029-21775-02 03/20/14 RB/JND TREE C/O(03/18/14) 11/30/16 JCF/JIVE)CMT TBG&ANNULUS(11/22/16) SEC 19,T11 N,R14E,1800'FNL&883'FEL 02/10/15 MSS/JIVE)ADPERFS(01/09-11/15) 11/30/16 DHS/JM7 SET WHIPSTOCK(11/24/16) 02/10/15 JMD WBS CLEANED UP I u<TALLIES 12/19/16 JNUJIVD ADDED RQ-,BF&OKB/CHGD WS DEPTH BP Exploration(Alaska) t • y of T�� • A THE STATE Alaska Oil and Gas of® T ® 1 TAL Conservation Commission 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 OA, AL Fax: 907.276.7542 www.aogcc.alaska.gov John Egbejimba Drilling Supervisor BP Exploration(Alaska), Inc. SCANNED FEB 2 8 2017 P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-31 B Permit to Drill Number: 203-008 Sundry Number: 316-565 Dear Mr. Egbejimba: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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, Daniel T. Seamount, Jr. Commissioner DATED this 1 day of November, 2016. RBDMS 1.�- NOV - 8 2016 STATE OF ALASKA "'ALASKA OIL AND GAS CONSERVATION COMMIN • APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon 0 Plug Perforations ❑ Fracture Stimulate 0 Repair Well ❑ Operations shutdown 0 Suspend 0 Perforate ❑ Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill 0 • Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing ❑ Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number 203-008 • 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0. • 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-21775-02-00 7. If perforating: What Regulation or Conservation Order governs well spacing in this pool? 8. Well Name and Number: Will planned perforations require a spacing exception'? Yes 0 No I1 PBU C41B• 4% g 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028305 • PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARYA Or,�^�.,!��^'y� Total Depth MD(ft): Total Depth TVD(it): Effective Depth MD: Effective Depth ND: MPSP(psi): Plugs(MD): '1 ''''l_, 13688 - 9022 ' 12610 9027 2530 12610.13400 None Casing Length Size MD TVD Burst Collapse Conductor 80 20"x 30" 37-117 37-117 Surface 2792 13-3/8" 36-2828 36-2722 5020 2260 Intermediate 9973 9-5/8" 33-10006 33-7597 6870 4760 Liner 2082 7" 9860-11942 7480-9014 8160 7020 Liner 145 4-1/2" 11902-12047 9014-9014 8430 7500 Liner 2322 2-3/8" 11366-13688 8781-9022 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12050-13670 9014-9022 3-1/2"9.3# L-80 31-11458 Packers and SSSV Type: 4-1/2"Baker SABL-3 Packer Packers and SSSV MD(ft)and TVD(ft): 11274/8702 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary IZI Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch ® Exploratory 0 Stratigraphic 0 Development 121 • Service 0 14.Estimated Date for Commencing Operations: November 15,2016 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended ® • 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Browning,Zachary H be deviated from without prior written approval. Email Zachary.Browning@bp.com Printed Name John Egbejimba'/ / Title Drilling Supervisor Signature -`-J/�?-1' mb . 1 2 Phone +1 907 564 4139 Date ` -c,.. © 1 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number: Plug Integrity 0 BOP Tesf Mechanical Integrity Test 0 Location Clearance 0 Other: ' 'S? f1, —CX) `31;10 P i kt, zra . au RAM C ACINCOvv P'ZIZ. ` 0 AAL. 2c. \�?,,,�A) Post Initial Injection MIT Req'd? Yes 0 No 0 BRa ng Exoept r�Reequired? Yes 0 No Ca Subsequent Form Required: 10 r 401 Approved by4.7**-0'. APPROVED BYTHE COMMISSIONER COMMISSION Date:/f'/7/1L) ORIGINAL RBDMS L.-1\u - 0 2016 N1''tt 1'1 Ili, Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. eR"' Attach meynts in Duplicate /���/ 4P•7,'A • • . To: Alaska Oil & Gas Conservation Commission From: Zach Browning biD CTD Engineer Date: November 1, 2016 Re: C-31 B Sundry Approval Request (Revised Sundry) Sundry approval is requested to plug the C-31 B perforations as part of the preparation, • drilling and completing the proposed C-31C coiled tubing sidetrack. History of C-31 B: Parent well C-31 B, was completed in 2003 as a horizontal well in 1N1 B. In the last 13 years it has produced 1.2 MMBO. It has been a cycle well since 2007 and the cycle performance has gone down with on time being <40% and GOR being more than marginal GOR. In Jan 2014 a CIBP was set to isolate the toe perfs, it cut 8MMSCFD and 100bopd. Then in Jan 2015 180' of heel perfs were shot in an attempt to increase rate- they added —200bopd and gas rates remained the same. GOR continued to creep up and in Oct 2015 a second CIBP was set to isolate all of the original perfs. This cut -7MMSCFD and oil remained about the same, however, the well went to high GOR within 2 months. All recent POPs/attempts to cycle the well have resulted in negative IOR. There are no more adperfs to pursue in this well as any additional perfs would be coming shallower in the well and closer to the GOC. This well is currently capable to flow. Given its recent cycle performance in 2016, there is no remaining value . for this well and it is fit fora CTD sidetrack. .:()l4:. 1ncr74tS 49 2E- L'�i- Proposed plan for C-31C: Drill a through tubing sidetrack with the Nordic 2 Coiled Tubing Drilling rig on or /4 around December 1st 2016. A plug will be set pre-rig above the C-31B production liner isolating the open �� 7• perforations. Cement will be squeezed into the IA below the production packer to allow for a dual string exit. The cement will be placed between 11,359' MD and 11,280' MD (shown on the proposed schematic attached). Then a 3-1/2" monobore whipstock will be set pre-rig to allow for a 2.80" 3.5" x 7" dual string exit. The well kicks-off in lower Zone 4, and will land and target reserves in Zone 1 A/1 B above the HOT. The proposed sidetrack is a 2500' horizontal Ivishak producer to be completed with a 2-3/8" L-80 solid liner, cemented in place and selectively perforated. This Sundry covers plugging the existing C-31 B perforations via the plug set pre-rig, the liner cement job 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 November 15th, 2016) 1. S Drift. c)`„� .4( 1 l >c i 2. E Set plug, tubing punch, set cement retainer. --- act- _ 1\3 i 3. C Circulate cement into IA. -2 bbls, 15.8 ppg Class G. Target TOC=11,280' MD. 4. F MIT-IA to 3000psi. MIT-T to 2500 psi. v 5. C Cleanout(if needed) and drift. 6. E Set 3-1/2”Whipstock 7. V Pre-CTD Tree work. Y Co Cur. t k we p 0010441w; A q GOR ZD MCWir4 1144e1 7-I��n tke v �h Lvtllf on 7 pad cycle effe(m A has fin (,ttk S ' Ar M4of i r 01 line. 0 hi, cll ¢ar cpr�' i ll b4ould allot►, {or ; o (''ecovo�o ;vialrti� porr pri of The Qool . "4 rt/y(lb Rig Work(scheduled to begin December 1st, 2016) o/, 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,530 psi). CDt,1/41-) ;v't 2. Mill 2.80"window. 3. Drill build: 3.25" OH, 473' (24 deg DLS planned). 4. Drill Lateral: 3.25" OH, 1954' (12 deg DLS planned) 'e 5. Run 2-3/8" L-80 liner leaving TOL at-11,295' MD. ?Cc?-4- 6. Pump primary cement job: 17.5bbls, 15.3 ppg Class G, TOC at TOL (-11,295' MD).* pc'E"'� 7. Test liner lap to 2400 psi. \ri 8. Selectively perforate. 9. Freeze protect well to a min 2,200' TVDss. 10. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post-Rig Work: 1. 0: Re-install wellhouse, and flowline if needed. 2. V: Tree work as necessary. 3. S: LTP set post rig if needed, and test.* 4. S: Install LGLVs 5. C: RPM log. 6. O: NWKO Zach Browning CC: Well File CTD Engineer Joe Lastufka 564-5220 iEUJ-EAD= MoEVOY • w 4 I SA.NOTES:WELL ANGLE>70°@ 11730'. CILIATOR= BAKERC KB.ELEV=' 67.8' P.B_EV= 37.3' DP= 1700' ax Angle= 96°@ 12186' atom MD= 11487'SS /^., t 2116' H3-1/2"OTIS SSSV LAND.NIP,D=2.75" atum TVD:,-- 8800'SS k,J 1 13-3/8'CSG,68#,L-80 BUTT,ID=12.415" —{ 2826' GAS UFT MANDRELS ST M3 I `I) DEV TYFE VLV LATCH FORT DATE Minimum ID = 1.995" @ 11372' 3 5091 4271 50 MMG DMY RK 0 08/20/16 TOP OF 2-3/8" LINER L 2 8601 6568 46 M41G DMY RK 0 08/20/16 1 11232 8665 29 14u13-2 DMY RK 0 04/30/03 5/8"X r BKR LTP w/TEBACK SLV,D=6.187" 9860' J ' li 9-5/8"X 7"BKR NSCC LNR HGR ID=6.250" -r 9873' 1 0 9-5/8"SIDETRACK WINDOW- 10006'-10056'(SECTION KILL) NOTE PRE-SDTRK WELLBORE NOT SHOWN BELOW 9-5/8" MLLOUT WIDOW. 9-518"CSG,47#,L-80 NSCC/BUTT,D=8.681' 1-0006' 1 I I L11260' H 3-1/2"OTIS X NP,D=2.75" 1' g 1 11-27-747-1--17-x 3-1/2"BKR SABL-3 PKR,D=3.85" I I 11299' H 3-112"OTIS X NP,D=2.75" 11366' —12.70"BKR DEPLOYMENT SLV,D=2.250" I I F11446' —f3-112"OTIS X NP.D=2.75" 3-1/2"TBG,9.3#,L-80 NSCT,.0087 bpf,D=2.992" —1 11467' / \ 11467' i--13-1/2" WLEG,D=2.992" 11466' --1 ELMD TT LOGGED 10/09/98 I 1. 11660' --I TOP OF CBNBYT #4, .'. i 4 1, 11884" �7"X 4-1/2'BKR H LNR TOP PKR,D=4.44"1 `' ��`'- 11902' H7"X 4-1/2"LTP w/BKR TIEBACK SLV,D=5.25" 11 1 "" 11916' Hr X 4-1/2'BKR LNR HGR,D=4.37" 7"LNR.29#,L-80 NSCT, .0371 bpf,D=6.184" —I 11942' I k 14 WI-IPSTOCK W/2 RA TAGS H 12026' I ` MLLOUT WIDOW 1204T-12051' -1/2'LNR 12.6#.NT-80 NSCT,.0152 bpf,D=3.958" — —12026' I v PERFORATIONSUATMW RY ,,•����� I 12610' —I2-3/8" FDQBP(10/12/15) REF LOG: MVO/GR ON 04/15/03 �� ANGLE AT TOP PERF: 90°@ 12050' — 13400' `-12-3/8'CEP(01/08/14) Note:Refer to Production DB for historical perf data •••'•'•"• ,/ SIZE SPF INTERVAL Opn/Sgz DATE SQZ 1.56" 6 12050-12080 0 01/11/15 / 13674' H PBTD 1.56" 6 12080-12110 0 01/10/15 / 4441 1.56" 6 12110- 12140 0 01/10/15 1.56" 6 12140-12170 0 01/10/15 a�� 1.56" 6 12170- 12200 0 01/09/15 •• 1.56" 6 12200-12230 0 01/09/15 1-1/2" 4 12700-12760 C 04/23/03 1-1/2" 4 12930-13355 C 04/23/03 2-3/8"LNR,4.6#,L-80 STL, .0039 bpf,D=1.995" H 13688' 1-1/2" 4 13480-13670 C 04/23/03 DATE REV BY COM/Eh/TS DATE REV BY COtv&ENTS PRUDHOE BAY INT 02/22/88 N18E ORIGINAL COMPLETION 11/09/15 ATO/JM7 SET CEP(10/12/15) WELL: C-31B 03/11/95 D-14 RIG SIDETRACK (C-31A) 08/24/16 JAR/JM)GLV C/O(08/20/16) ItJMT NO:' 030080 04124/03 DAV/KK CTD SIDETRACK(C-31B) AR No: 50-029-21775-02 03/20/14 RB/JMD TRET.C/O(03/18/14) SEC 19,T11 N,R14E, 1800'EN_8 883'FJ 02/10/15 MSS/JMJ ADPERFS(01109-11115) 02/10/15 JM) WBS CLEANED UPPER TALLES BP Exploration(Alaska/ T _ McEVOY PROP•AL.. C-31 C I SA.NOTES:WELL ANGLE>70°@ '. K_B.ELEV= 67.8' F.B..EV= M_--____37.3' DP= 1700' ax Angle= _"@ alum _ O 2115' H3-1/2"OTIS SSSV LAND.NIP,AD=2.75" alum ND= 8800'SS 13-3/8"CSG,68#,L-80 BUTT,ID=12.415" H 2825' GAS LFT MANDRELS ST MD I VD DEV TYPE V LV LATCH PORT DATE Minimum ID = 1.995" @ 11372' 3 5091 4271 50 MMG DMY RK 0 08/20/16 TOP OF 2-3/8" LINER 2 8601 6568 46 MMG DMY RK 0 08/20/16 1 11232 8665 29 MMG-2 DMY RK 0 04/30/03 5/8"X 7"BKR LTP w/TEBACK SLV,ID=6.187" H I 9860' 9-5/8"X 7"BKR NSCC LNR HGR,ID=6-250" —I 9873' ■ ■ 9-5/8"CSG,47#,L-80 NSCC/BUTT,ID=8.681" H 10006' 3-1/2"OTIS X NIP,11: 2.75" H 11260' i:i ili 11274' —17"x 3-1/2"BKR SABL-3 PKR,ID=3.85" Tubing Punch —I 1! ': croj 11308" H2.70"DEPLOYMENT SLEEVE,ID= " WHIPSTOCK HIPSTOCK(_/ /_) H 11328" 3-1/2"Cement Retainer — 11361' 1•� MILLOUT WINDOW(C-31C)11328'-11338' Tubing Punch H11367' /Ii=--= A t H PUP JT w/RA TAG 3-1/2"Tubing Rug H 11359` • r ' , 14 4 14 4 3-1/2"TBG,9.3#,L-80 NSCT,.0087 bpf,ID=2.992" --I 11457' el lb ,e il ... ...my 0) NP KITE) —I �� ll) it ) . 2-3/8"LNR,4.7#,L-80 H511, H 13755' I/ 7"LNR,29#,L-80 NSCT,-0371 bpf, ID=6-184" H 11942' I Ap4 .0039 bpf,m=1.995" FA IPSTOCK W/2 RA TAGS H 12026' ' �� WI -1/2"LNR,12.6#,NT-80 NSCT,.0152 bpf,ID=3.958" H —12025' I. ib". 4,1010,.. MLLOUT WINDOW 1204T-12051' PERFORATION SUIV4MARY ) LOG: ON / l ANGLE AT TOP PERF: __"@ Note:Refer to Production DB for historical perf data \` SCE SFF INTERVAL Opn/Sqz DATE SQZ R3TD H 13674' 2-3/8"LNR,4-6#,L-80 STL,.0039 bpf,D=1.995" H 13688' . DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/22/88 N18E ORIGINAL COMPLETION WELL: C-31 03/11/95 1)14 RIG SIDETRACK (C-31A) PEWIT No: 04/24/03 DAV/KK CTD SIDETRACK(C-31B) AR No: 50-029-21775-0 / /.— CTD SIDETRACK(C-31C) SEC 19,T11 N,R14E, 1800'Fl_&883'FEL 09/08/16 JMD BOLT PROPOSAL BP Exploration(Alaska) • • , 1 A 1 1 .... ji amt„\ 11 I I I I xgwlop 11., .,!' I is 2 1 U E ,.,\ �Fry� 1 :7:. I I �G C :4as I �C SA 1n V . ., ',.,' .►.,. - , �7 I �7 Y E � 1 1 0♦4 I 1qI "- t 1 1r y 1 11 ax 2 5 1 C R C sw 1 g 1 I I I Q w r � I 0 - I a a � 1 -I I ., .. 1 J , 1 1 � ., 1 O U? I I -` I 1 IM 1 Z 1 g 74 O a E I L11 .. p, im71 I 1 U2I- - - -- -1-- 0\ 1 Ce . I 1 \ u 0i I V 1 .I ar I \ a U m > w I J W.' . i. wy z~' 3 •Ea,_) i., , i 0'i ?H 1 Ill"' �g 0 1 O '°� �• U° Zs r c \ U I U a o 1 f UJ \ i 1 74 Z a I t i' =!f % _ I CO m I U o I I fu ce Z � O g 1I I I Z m 1 AI n► I -i z a 1 ; x Z " I ° NMII Si m is LLe 12 C I 1■2 E "J v 1 C t 6 E i I c u 1. U a I I .4)1 r A _ I.- a 1 I i i 0 0 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." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist fI V in the upper left corner of Form 10-403 is checked. If the "Abandon" or 4 "Suspend" boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 ' If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist IS work) the initial reviewer will cross out that erroneous entry and initial the 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 Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech 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." 4 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 one 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 suspended wells for accuracy. STATE OF ALASKA •ALASKA OIL AND GAS CONSERVATION COMM N * APPLICATION FOR SUNDRY APPROV LS 20 AAC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill El . Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other Cement IA Eti • 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: • 5. Permit to Drill Number: 203-008 • 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic ❑ Service 0 6. API Number: 50-029-21775-02-00 • 7. If perforating: 8. Well Name and Number: What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No ® PBU C-31B • ',44,-'', to° r, µ " 9. Property Designation(Lease Number): 10. Field/Pools: D"T0 t ?3',F) ADL 028305 • PRUDHOE BAY,PRUDHOE OIL • 11. PRESENT WELL CONDITION SUMMARY / 7 '% Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth ND: MPSP(psi): t'gs(MD): Junk(MD): 13688' 9022• 12610 9027 2530 — 12610.13400 None Casing Length Size MDTVD N / Burst Collapse Structural to� Conductor 80 20"x 30" 37-117 \h7/(17 Surface 2492 13-3/8" 36-2828 6-2722 5020 2260 Intermediate 9973 9-5/8" 33-10006 33-7597 6870 4760 Liner 145 4-1/2" 11902-12047 / 9014- 014 8430 7500 Liner 2322 2-3/8" 11366-1� 1 -9022 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12050-13670 9014-9022 3- ✓i 1, L-80 31-11458 Packers and SSSV Type: 4-1/2"Baker SABL-3 Packer 4 P. k, and SSSV MD(ft)and TVD(ft): 11274/8702 %/ 1 No SSSV Installed z No SSSV Installed 12.Attachments: Proposal Summary ® Wellbore Sche tic-74.6 1 Well Class after proposed work: 1 Detailed Operations Program 0 BO Exploratory 0 Stratigraphic 0 Development ® • Service 0 14.Estimated Date for Commencing Operations: Novem,• 20 15. Well Status after proposed work: Oil 0 WINJ ❑ WDSPL 0 Suspended ® - 16.Verbal Approval: Dat>. GAS 0 WAG 0 GSTOR 0 SPLUG ❑ Commission Representative: 111. GINJ ❑ Op Shutdown 0 Abandoned ❑ 17.I hereby certify that the foregoing is true ant4 . ocedure approved herein will not Contact Browning,Zachary H be deviated from without prior written approva ----, Email Zachary.Browning@bp.com Printed Name John Egbejimba Title Drilling Supervisor Signature f /�[ j Phone +1 907 564 4139 Date 1 0/5/20 6 ` lll/// 1\\.� / COMMISSION USE ONLY Conditions of approval:Notify Commi ion so that a epresentative may witness Sundry Number: Plug Integrity 0 :OP Test Mechanical Integrity Test 0 Location Clearance 0 p� Other: �Jp -r Jr tf--v 3- SU0 YG �d-l-t-vzvI - v' pie-✓7-v, r r_ t- tv Z5-L'e pSLG Post Initial Injection MIT R q'd? Yes 0 No L"9"4/ Spacing Exception Req red? Yes 0 No NI' Subsequent Form Required: t — 4./77- APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date: SCANNED MAR C° .i 2017, ORIGINAL RBDMS N - 12016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval.,j Attachments in Duplicate /� 1 m 4 /D. 7 /G.. • To: Alaska Oil & Gas Conservation Commission 0 biD From: Zach Browning CTD Engineer Date: October 5, 2016 Re: C-31 B Sundry Approval Request Sundry approval is requested to plug the C-31 B perforations as part of the preparation, drilling and completing the proposed C-31C coiled tubing sidetrack. History of C-31B: Parent well C-31 B, was completed in 2003 as a horizontal well in 1A/1B. In the last 13 years it has produced 1.2 MMBO. It has been a cycle well since 2007 and the cycle performance has gone down with on time being <40% and GOR being more than marginal GOR. In Jan 2014 a CIBP was set to isolate the toe perfs, it cut 8MMSCFD and 100bopd. Then in Jan 2015 180' of heel perfs were shot in an attempt to increase rate- they added -200bopd and gas rates remained the same. GOR continued to creep up and in Oct 2015 a second CIBP was set to isolate all of the original perfs. This cut -7MMSCFD and oil remained about the same, however, the well went to high GOR within 2 months. All recent POPs/attempts to cycle the well have resulted in negative IOR. There are no more adperfs to pursue in this well as any additional perfs would be coming shallower in the well • and closer to the GOC. This well is currently capable to flow. Given its recent cycle performance in 2016 there is no remaining value for this well and it is fit for a CTD sidetrack. / Z6/6 46-6/(ct 278 4e. LI- 66;7L3O,��r c�. Proposed plan for C-31C: Drill a through tubing sidetrack with the Nordic 2 Coiled Tubing Drilling rig on or «=% around December 1st 2016. A plug will be set pre-rig isolating the C-31 B perforations. A-500' IA cement squeeze is planned to provide a cement packer since the planned sidetrack kicks off above the existing production packer. This IA squeeze is not needed to fix any integrity issue, but is needed for multiple dual string exits planned, both this one and ones in the future. The TOC (10,500' MD) is planned to provide pressure integrity in the IA above all possible sidetrack locations. A 2.80" window will be milled off the 3-1/2" whipstock set pre-rig. The well kicks-off in lower Zone 4, and will land and target reserves in Zone 1 A/1 B above the HOT. . The proposed sidetrack is a-2500' horizontal Ivishak producer to be completed with a 2-3/8" L-80 solid liner, cemented in place and selectively perforated. This Sundry covers plugging,the existing C-31B perforations via the plug set pre-rig, the liner cement job or liner top packer, if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(j)). 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 November 1st, 2016) 1. S Drift. 2. E Set plug, tubing punch, set cement retainer. 3. C Circulate cement into IA. 19.5 bbls, 15.8 ppg Class G. Target TOC=10,500' MD. 4. F MIT-IA to 3000psi. MIT-T to 2500 psi. 5. C Cleanout(if needed) and drift. 6. E Set 3-1/2"Whipstock • 7. V Pre-CTD Tree work. (01 iee corcvr. ti fu ecr Eli did .sloes , , 'chg7 e (�vf�n ` " f q n��' 0� rS f kr re-Q.4' liqs Rows Very Iiw4 ��Gla .1e I circ > 1 S C `h"hey- `GOR pel a'ec P /Ay"7 l�'' G�e`� �r a�- f chovi ofOr- `M free/ /ec�X�rl�y PO, j�1,3o� �'on OPre • • Rig Work(scheduled to begin December 1st, 2016) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2,530 psi). 2. Mill 2.80"window. 3. Drill build: 3.25" OH, 798' (16 deg DLS planned). 4. Drill Lateral: 3.25" OH, 1685' (12 deg DLS planned) 5. Run 2-3/8" L-80 liner leaving TOL at 11,100' MD. 6. Pump primary cement job: 17.5bbls, 15.3 ppg Class G, TOC at TOL (-11,100' MD).* 7. Test liner lap to 2400 psi. 8. Selectively perforate. 9. Freeze protect well to a min 2,200' TVDss. 10. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) Post-Rig Work: 1. 0: Re-install wellhouse, and flowline if needed. 2. V: Tree work as necessary. 3. S: LTP set post rig if needed, and test.* 4. S: Install LGLVs 5. C: RPM log. 6. O: NWKO Zach Browning CC: Well File CTD Engineer Joe Lastufka 564-5220 113±FEAD= MPEVOY SA NOTES•WELL ANGLE>70°@ 11730'. CTUATOR= , --BAKER C . C_3 1 B KB.LEV= 67.8' F.ELEV= 37.3' - OP= 1700' lax Angle= 96°@ 12186' shim MD- 11487'SS ( 2115' H3-112"OTIS SSSV LAND.NIP,D=2.75" atom TVD= 8800'SS 13-3/8"CSG,68#,L-80 BUTT,ID=12.415" - 2826' GAS LFT MANDRELS ST MJ TV() DEV TY FE VLV LATCH PORT DATE j Minimum ID = 1.995" @ 11372' ( 3 5091 4271 50 MNG DMY RK 0 08/20/16' TOP OF 2-3/8" LINER 2 8601 6568 46 MbG OM' RK 0 08/20/16 1 11232 8665 29 ttAG-2 DMY RK 0 04/30/03 j 5/8"x 7"BKR LIP w r TRACK sLv,D=6.187" H 9860' [9-5/8"X 7"BKR NSCC LNR HGR,ID=6.250" H 9873' 9-5/8"SIDETRACK WINDOW- 10006'-10056'(SECTION MLL) NOTE PRE SDTRK WELLBORE NOT SHOWN BELOW 9-5/8" MLLOUT WINDOW. 9-5/8"CSG,47#,L-80 NSCC/BIJTT,D=8.681" -r 10006' 1 I I 11260' H 3-1/2"OTIS x NP,D=2.75" ►� ( 1127 —7"x 3-1/2"BKR SA BL-3 PKR D=3.85" I 1 11299' H3-1/2'OTIS X NP,D=2.75" 11366' --12.70"BKR DEPLOYMENT SLV,D=2.250" F11446' H 3-112"OTIS X NP, D=2.75" 3-112"TBG,9.3#,L-80 NSCT,.0087 bpf,D=2.992" H 11457' / p 11457' H3-1/2' WLEG,D=2.992" 11456' H B MD TT LOGGED 10/09/98 '.►11 1#�' 11650' —{TOP OF CBvENT 01 4. CO 4r 11884' —f7"X 4-1/2"BKR H LNR TOP PKR D=4.44" lb Co +=~` 11902' H7"X4-1/2"LTPw/BKRTEBACK SLV,D=5.25" 4 11916' —7-X4-1/2"BKR LNR HGR,D=4.37" 7"LNR 29#,L-80 NSCT,.0371 bpf,D=6.184" —1 11942' i WI I'STOCK W/2 RA TAGS --f 12026' ( 1 MLLOLIT VV 12047'- 12051'• -1/2"LNR,12.6#, NT-80 NSCT,.0152 bpf,D=3.958" H -12026' PERFORATION SUMMARY ,4*1• 12610' -12-3/8"WFD CIBP(10/12/15) REF LOG: MWD/GR ON 04/15/03 ANGLE AT TOP PERF: 90°@ 12050' © L 13400' -12-3/8'CIBP(01/08/14)1 Nate:Refer to Production DB for historical pert data A4/ 4o SIZE SPF INTERVAL Opn/Sgz DATE SOZ / j 1.56" 6 12050 12080 0 01/11/15 13674' --I PBTD 1.56" 6 12080- 12110 0 01/10/15 ` 1.56" 6 12110-12140 0 01/10/15 1.56" 6 12140-12170 0 01/10/15ill"' 1.56" 6 12170-12200 0 01/09/15 'Mr 1.56" 6 12200- 12230 0 01/09/15 1-1/2" 4 12700- 12760 C 04/23/03 1-1/2" 4 12930-13355 C 04/23/03 2-3/8"LNR,4.6#,L-80 STL., .0039 bpf,ID=1.995" H 13688' • 1-1/2" 4 13480-13670 C 04/23/03 DATE REV BY COMMENTS NTTS DATE REV BY COMMENTS PRUDHOE BAY L,NT 02/22/88 N18E ORIGINAL COMPLETION 11/09/15 ATO/JMIISET CI3P(10/12/15) WELL C-31B 03/11/95 1.14 RIG SIDETRACK (C-31A) 08/24/16 JAR/JM)GLV C/O(08/20/16) 11J tv1T No:' 030080 04/24/03 DAV/KK CTD SIDETRACK(C-31B) API No: 50-029-21775-02 03/20/14 RB/JM) TREE C/O(03/18/14) SEC 19,T11 N,R14E, 1800'FN.&883'FEL 02/10/15 MSS/JMJ ADPERFS(01/09-11/15) 02/10/15 JM) 'WBS CLEANED LP PER TALLES BP Exoloration(Alas kal EIHEAD= . "° PROP•AL C 31 I SA1 NOTES:WELL ANGLE>70°0 CTUATOR= KBS EEEV= 67.8' _.ELEV= 37.3' DP= 1700' ax Angle= —°Q ' --- --------- I 2115' H 3-1/2"OTIS SSSV LAND.NIP,D=2.75" Aum MD= O 1 atumTVD= 8800'SS 13-3/8"CSG,68#,L-80 BUTT,ID=12.415" H 2825' = GAS LFT MANDRELS - ST MD TVL.) DEV TYPE VLV LATCH PORT DATE Minimum ID = 1.995" @ 11372' LE 3 5091 4271 50 MMG DMY RK 0 08/20/16 TOP OF 2-318" LINER 2 8601 6568 46 MMG DMY RK 0 08/20/16 1 11232 8665 29 MMG-2 DMY RK 0 04/30/03 5/8"X 7"BKR LTP w/TRACK SLV,D=6.187" —I 9860' J ►�/ 9-5/8"SIDETRACK WINDOW-10006'-10056'(SECTION MLL) 9-5/8"X 7"BKR NSCC LNR HGR,ID=6.250" H 9873' I NOTE FRE SDTRK WELLBORE NOT SHOWN BELOW 9-5/8" 9-5/8"CSG,47#,L-80 NSCC/BUTT,0=8.681" —I 10006' MILLOUT WINDOW. FOC H 10500' , 2-3/8"TOL —I 11100' 11100' —12.70"DEPLOYMENT SLEEVE,0= 3-1/2"W-IPSTOCK(_/_/_J 11165' • I' . G' C t MLLOUT WINDOW(C-31 C)11165'-11175' • • 3-1/2"Cement Retailer H 11230' • 3-1/2"OTIS X NP,D=2.75" --I11260' 1I:•:•: _�� ! !- -. r1 A 1 1 I I y< C U. > t $f $ ? ' LF _ 1 r 1 is S S R r. 1:: :,• • ,, 1. .:0:. . • • ♦ 1 1 . 1«.4I A 1 Vin m s w- -= .'4,::: • z g°r 1 < 'I ,. I 1 a 11 I J 0002 1 a x `v I C 1 o G 1 I 1 1 H 1 1 o a...1: I H IMI' IL V I Il ___ 1 J 1 1 _ I 1 _, NIN I Z ' `� 1 1 2 © \ 1 . 1 I ' i1 O i : III 1 IMI' I ~ u ` u-I I 1 auJahns sed I J ff Af v. u 1 •. •. 1 V �1 1- - 1 '\ e 1 re ® + 1 1 \ u u I Y 1 V . i .I I; 1 \ o W 1 J f 1 i ii 1 \ pe0._ 8 I 111 1W 1 T i; ' I = t i \\ �i90 1 1 c�i , Ili re_ • as. 1 `Uf . •�, o� ■� o I W Wg % O 1 4,„., d uv 2 u. u 1 = a .1r, �^• U Y \\ Na :• 2 a , \ i 1 i l i _ _ \ I 7.1 ?a I I 2. • -"• N rr • ® k U U INI 1 S I V 3 _i _ m I �I� _ Z Cl - I I ..,�'�` m 1 0 3 - - i i .M I o _ I 1 Z f H $ I j c r._' I i'I -4 Z $ 1 1 _8 f 1 : ! u rz 1 23 U I ,.V e g 3 _= r. 1 r og I I e5 a I I I � .4 • • • 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." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner 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 (AOGCC's and operator's copies). 2 If the "Abandon" box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial the 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 Engineer The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the "Plug Stat Tech 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." 4 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 one 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 suspended wells for accuracy. • • Carlisle, Samantha J (DOA) From: Quick, Michael J (DOA) Sent: Wednesday, November 02, 2016 8:29 AM To: Carlisle, Samantha J (DOA) Subject: FW: Please withdraw current Sundry and Permit to Drill request(PTD#203-008 and 216-134) How do we do this request? Michael Quick Sr. Petroleum Engineer Alaska Oil and Gas Conservation Commission 333 West 7th Avenue Anchorage,AK 99501 (907)793-1231(phone) (907) 276-7542(fax) mike.quick@alaska.gov CONFIDENTIALITY NOTICE:This e-mail message, including any attachments, contains information from the Alaska Oil and Gas Conservation Commission (AOGCC), State of Alaska and is for the sole use of the intended recipient(s). It may contain confidential and/or privileged information.The unauthorized review, use or disclosure of such information may violate state or federal law. If you are an unintended recipient of this e-mail, please delete it,without first saving or forwarding it, and, so that the AOGCC is aware of the mistake in sending it to you, contact Mike Quick at 907-793-1231 or mike.auick@alaska.gov. From: Lastufka,Joseph N [mailto:Joseph.Lastufka@bp.com] Sent:Wednesday, November 02,2016 8:26 AM To:Quick, Michael J (DOA)<michael.quick@alaska.gov> Cc: Browning,Zachary H<Zachary.Browning@bp.com> Subject: Please withdraw current Sundry and Permit to Drill request(PTD#203-008 and 216-134) Mike, Please withdraw the current Sundry for Plug for Redrill on C-31B (PTD# 203-008, Sundry# 316-514) and Permit to Drill for C-31C (216-134). A new Sundry and Permit to Drill will be delivered this afternoon, with the anticipated start date of November 15th for the Sundry. If you need any additional information or have questions please let me know. Thank you, Joe Lastufka Information and Data Controller Cell: (907) 227-84961 Office: (907) 564-4091 BP Exploration Alaska1900 E. Benson Blvd.IRoom: 788DlAnchorage, AK 1 V) 41- • 410o - o F— a •0 E , .wit- vo � N! �� 0 '' ° _( r O N W cc E- O QJ E Q) O z U N -iG9m ra v F a c c o a cT w +o o -c o f0 Q YI 0 a a D a, w f0 . c0 c0 c0 O O O O Q p O J m L w 7 0 0 0 Q Q Q Q c c s a/i 2 Z a .- M - N r0cs) °r N N O i c U a O +-I Zv< vii > E -0 v cc O c C N v + r0 O I- f0 a) a 0 U ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ ❑ 0 a) p W J J J J J J J J J OA c ;F U 0 CLIWLIJILLIJIIII11111LULU v, Q) E. w F- LL LL LL LL LL LL LL. LL LL 4-' C) Q1 Q1 -0 CO I- Q Q Q Q Q Q Q Q Q v C +'- «- r 0 0 Z Z Z Z Z Z Z Z Z UL N 0 a • F LL LL LL LL U. U.. LL LL LL ca — E' > C EQ' f6 0 E Y _ U O 0) E a u a,0 O ►_ I- I- Ti.. _ D c U v U . VUi N Q a co Q a 0 O N i+ g O w❑ N p > > > p a Co cv O FO O J ❑ WWWJ LL. v4) N 'u Q W y d d N P-, O _ PI N M OL>j U U U U co a yF V �" 0 11. o o !0Als .4 OM �_ R aae Uh Z . (d W U 17- a 0 Z J J 0 0 J J 0 2 4111 w r >' � rC[ ›- >- mmmmm2 1- Z F.. § z z z 0 0 0 0 0 0= 0 0 -10001_ 0000 w > > D Z > > J c ++ CI w a a a o a cc 0 c a LIF1 :)0 x coo co 0 Cif f0 O O M M 0 CD _ Tr 0 `� cc al p C. 0 0 0 O O O O r MULL (� 0 00 0 0 0 0 0 0 0 E ® 0 o3t LL LL 6 T a 4 O) ,� � � zY � vN d Q ra ai 0 LiJ 0 z0 � w oo ❑ ❑ ❑ ❑ ❑ ❑ ❑ id � amo_c O u ,�/® N N O O N O O .1-) C '11ffi7 �+ 0 0 0 0 0 0 0 09 To a tri U ago a n 0) CI N CO 4-,O N N N - COr. M M C m N a N N N N N ("4 N N N C - Q O) 0) 0) O 0) 0) 0) T O) C O 00001111 N N N N N N N N N (p ,,, O O 0 O 0 0 0 0 O . C 0 0 0 0 0 0 0 0 0 M Y C1 aa C 05 C N � in in to in in an in 0 13 m C Z �i In E a m o O W Y Q W rc N u . JO13 �y E z co 73 FA Q m o m O co N N 9 « Q1 C -0 N p r� z N N M N M N N C r0 0 u -' 10 OC N h C C a Q 5 N W x U a C. U J J J o Z v C + d co 0i/9 � k;bQ ?... aa, m STATE OF ALASKA • •ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations Q Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate ❑ Alter Casing 0 Change Approved Program 0 Plug for Redrill ❑ Perforate New Pool 0 Repair Well ❑ Re-enter Susp Well ❑ Other: .e•1 C!8CI 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 203-008 • 3. Address: P.O.Box 196612 Anchorage, Development Q Exploratory 0 • AK 99519-6612 Stratigraphic 0 Service 0 6. API Number: 50-029-21775-02-00 7. Property Designation(Lease Number): ADL 0028305 • 8. Well Name and Number: PBU C-31B • 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: e PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: r. "" Total Depth: measured 13688 • feet Plugs measured 12610/13400 feet EU true vertical 9022 • feet Junk measured feet N O V 0 9 Z015 Effective Depth: measured 12610 feet Packer measured__ 9874 feet true vertical 9027 feet Packer true vertical 7492 feet AOGC Casing: Length: Size: MD: ND: Burst: Collapse:�e,�" Structural Conductor 80 20"x 30" 38-118 38-118 Surface 2792 13-3/8"68#L-80 38-2830 38-2723 5020 2260 Intermediate 9972 9-5/8"47#L-80 34-10006 34-7597 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 12050 12080 feet 12080-1211 0 feet 12110-12140 feet 12140-12170 feet 12170-12200 feet 12200-12230 12700-12760 feet 12930-13355 feet 13480-13670 feet True vertical depth: 9014-9014 feet 9014-9014 feet 9014-9012 feet 9012-9009 feet 9009-9007 feet 9007-9007 9022-9022 feet 9023-9023 feet 9022-9022 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9.3#L-80 33-11458 33-8853 Packers and SSSV(type,measured and 7'Baker H Packer 9874 7492 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): sCANM1 FEE 2 2U1 , Treatment descriptions including volumes used and final pressure: " f 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 321 23755 31 1170 500 Subsequent to operation: 371 15585 39 1000 395 14.Attachments:(required per 20 AAC 25.070 25.071,a 25.283) 15.Well Class after work: t Daily Report of Well Operations Q 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 Contact Catron,Garry R(Wipro) Email Garry.Catron@bp.com Printed Name Catron,Garry R(Wipro) Title PDC Principal Engineer Signature -407 1!_ .. Phone +1 907 564 4424 Date 11/6/15 viz- Form 10-404 Revised 5/2015 , al /�� ` RBDMS 1 <�>OC OV 13 2015 Submit Original Only z • m Q. O O O O M 03 O Cfl 10 O L0 N N- N O O U N 0 0 0 0 0 0 i N I- CO ON CO 3 O CO m to co co � 0oQ 00 co I� V N CO N O r Ln O O O CO CA CA 00 alit i s I I H CO CO 'Cr 00 0 CO CO COV N O M 0o 0) co co O 00 t 10 O O CO O O M N r r r V 0 CU CO CO M 00 00 V CO M 8 CO CO M CO CO CO cU 0) :n co 0.a Oo 0 0 0 co o a) - -J co J J � 00 *kJ *kco *k N x O CO M •� O O 00 zo N - _ N MM N Mi O O 6N) N- ONO (NI N C 00 N- 6) O M '71- J N 0) N N W O)O C H W U *(7) U W U 0 u c Z Z a W W w W Q p i— Z_ _Z Z_ p U Cn Z J J J III- TREE= 6"X T CM/FLS • IAELLJ-f,AD= At EVOYSAFETY NOTES:WELL ANGLE>700 e 1 1 7 30 . - ACTUATOR= BAKER C C-3 1 B OKB.El..B/= 67.8' BF.ED/= 37.3' KOP= 1700' -Akix Angle= 96'-, 12186' t=MD1148T SS / 211 6' --I 3-1/2"OTIS SSSV LAND.MP,ID=2_75' M = D3 turn TVD= 8800'SS 13-3/8"CSG,68#,L-80 BUTT,ID=12.415" H 2826' -- I GAS LFT MANDRELS ST MD P.M DEV TYPE VLV LATCH FORT DATE Minimum ID = 1.995" @ 11372' 3 5091 4271 50 MMG DOME RK 16 04/30/03 TOP OF 2-3/8" LINER L 2 8601 6568 46 MMG SO RK 20 04/30/03 1 11232 8665 29 M9,IG-2 DMY RK 0 04/30/03 9-5/8X 7"BKR LTP w/TEBACK SLV,D=6.187" H 6860" Cr . 9-5/8"X r BKR NSCC LNR HGR,ID=i250n-1 9873' s i 9-5/8"SIDETRACK VVINDOW- 10006'-10056'(SECTODN PAW NOTE PRE-SDTRK WELLBORE NOT SHOWN BELOW 9-518" AALLOUT WHDOW. 9-5/8"CSG,47#,L-80 NSCC/BUTT,ID=8.681" H 10006' 1 11260' —13-1/2"OTt5 X NIP,ID=2,75" 'I . 11274' —17"* 3-1/2"BKR SABL-3 PKR,ID=3.85' I 11299' —3-1/2"OTIS X MP,D=2.75" 11366' —2_70'BKR DEPLOYMENT SLV,ID=2.250" 11446' —3-1/2-OTtS X MP,D=2.75" 3-1/2"TBG,9.3#,L-80 NiSCT„0087 bpi,13=2.992' —{ 11467' 11467' —3-1i2' NA.E.G.D=2.992" 11466' —amo TT LOGGED 10/09/98 rf 14 t. 41 11660' -1 TOP OF CEMBYT ..•• el OP 11884' Hr X 4-1/2"BKR H LNR TOP PKR,ID=4.44' ilb 'OE II 11902' —r x 4-1/2"LTP w/13KR TEBACK SLV,ID=5.25" el SO II '' 11916' —7'X 4-1/2"BKR LNR HGR,0=4.37" 0 9 7'LNR,29#,L-80 NSCT,.0371 bpf,ID=6.184' H 11942' I I WI-IPSTOCK W/2 RA TAGS — 12026' I O.. MLLOUT$A114DOW 1204T- 12051' I 4 4-1/2'LNR,12.6#,NT-80 NSCT,.0152 bpi,13=3.958' H —12026' I y FERFORATION SUIMPARY .0., ••v 12610' —12-3/8"MD CEP(10/12/15) 4. FEE LOG: AND/GR ON 04/15/03 ii _ ANGLE AT TOP PERE: 90°@ 12050 13400' H2-3/8"CEP(01/08/14) I --,.mi Note:Ffer to Production DB for historical perf data •••••, 110 SIZE SPE NTERVAL Opn/Sqz DATE , SQZ 13674' H PBTD 1.56' 6 12050-12080 0 01/11/15 r 4414Iiik 1.56" 6 12080-12110 0 01/10/15 1.56' 6 12110-12140 0 01/10/15 1.56' 6 12140-12170 0 01/10/15 411.111V 1.56" 6 12170-12200 0 01/09/15 1.56" 6 12200-12230 0 01/09/15 1-1/2' 4 12700-12760 C 04/23/03 1-1/2" 4 12930-13355 C 04/23/03 2-3/8'LNR 4.6#,L-80 STL, .0039 bpf,ID= 1.995" — 13688' 1-1/2' 4 13480-13670 C 04/23/03 DATE REV BY COMRENTS DATE REV BY COMPENTS PRUDHOE BAY UNIT 02/22/88 1418E ORIGINAL COMPLETION 11/09/15ATO/JM3tSET CEP(10/12/15) WELL C-31B 03/11/95 D-14 RIG SIDETRACK (C-31A) FERMI ND: 030080 . . . 04/24/03 DAV00( CTD SIDETRACK(C-31B) All At: 50-029-21775-02 _ . 03/20/14 F83/JAAD 111z1E GO(03/18/14) SEC 19,T11N,R14E,1800'FAL 8 883'Fa , . 02/10/15 PASS/JMD A DPERFS(01/09-11/15) 02/10/15. 14.4) NIBS CLEANED UP PER TA LLES BP Exploration(Alaska) STATE OF ALASKA AL A OIL AND GAS CONSERVATION COMMI „N REPORT OF SUNDRY WELL OPERATIONS 1 Operations Abandon El Repair Well ❑ Plug Perforations ❑ Perforate 0 Other ❑ Performed Alter Casing❑ Pull Tubing ❑ Stimulate-Frac ❑ Waived] Time Extension El Change Approved Program❑ Operat Shutdown❑ Stimulate-Other ❑ Re-enter Suspended W❑ 2 Operator 4 Well Class Before Work 5 Permit to Drill Number BP Exploration(Alaska),Inc Name Development 0 Exploratory❑ 203-008-0 3 Address P.O.Box 196612 Stratigraphic ❑ Service 6.API Number Anchorage,AK 99519-6612 50-029-21775-02-00 7 Property Designation(Lease Number) 8 Well Name and Number ADL0028305 PBU C-31B 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 RECEIVED Total Depth measured 13688 feet Plugs measured 13400 feet true vertical 9022 17 feet Junk measured None feet JAN 2 7 2015 Effective Depth measured 13400 feet Packer measured See Attachment feet A3GCC true vertical 9023 31 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"Conductor 37 05-117 05 37 05-117.05 0 0 Surface 2793 07 13-3/8"68#L-80 36 55-2829 62 36 55-2723 34 5020 2260 Intermediate 9972 85 9-5/8"47#L-80 33 15-10006 33 15-7596 74 6870 4760 Production None None None None None None Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12050-12080 feet 12080-12110 feet 12110-12140 feet 12140-12170 feet _ 12170-12200 feet 12200-12230 feet 12700-12760 feet 12930-13355 feet 13480-13670 feet True Vertical depth 9014.33-9014 2 feet 9014 2-9013 54 feet 9013 54-9012.05 feet 9012.05-9009.34 feet 9009.34-9006 75 feet 9006 75-9006.71 feet 9022.12-9021 74 feet 9022 92-9023 21 feet 9022.16-9021.65 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9 3#L-80 30 45-11457.8 30 45-8852 9 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) L. Treatment descriptions including volumes used and final pressure: SCON 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Pnor to well operation 273 20993 27 1100 445 Subsequent to operation 473 19175 45 1120 450 14 Attachments 15.Well Class after work Copies of Logs and Surveys Run Exploratory ❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work Oil 0 Gas ❑ WDSPL ❑ 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 CatronEmail Garry.CatronABP.Com Pnnted Name Garry Catron Title PDC PE Signature )14A/ticPhone 564-4424 Date 1/26/2015 (/rt- 7/1 - /J5 .if /.1---- Form 10-404 Revised 10/2012 Submit Original Only RBDIVIS JAN 3 0 2015 d E2 N C Y a_ g 0O a a ~ C M CC NJ ZN m CL W N M Q a) m CO _ = N m V ti O) 0 O O CO > CO Ncn F.,' - c4- .-- ` O co O '^ N v! O (/) Q C Cl) N- N- 0 V of 2 pMj N rn o a cc cc cc w LU LU LU Q.YYY >+UUU d d 3- m Emmcc) ca r r Z M M 6 6 6 Cn Q. 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ACTUATOR= BAKER C OKB.REV= 67.8' BF.ELEV= 37.3' KOP= 1700' Max Angle= 96°@ 12186' Datum kV== 11487'SS O 2115' H 3-1/2"OTIS SSSV LAND.NP D=2.75" -- ------ ---- Datum TVD= 8800'SS 13-3/8"CSG,72#,L-80,D=12.347" H I 2825' --, GAS LFT MANDRELS ST MD IV ) DEV TYPE VLV LATCH FORT DATE 1-1 3 5091 4271 50 MMG DOME RK 16 04/30/03 Minimum ID = 1.995" @ 11372' 2 8601 6568 46 MMG SO RK 20 04/30/03 TOP OF 2-3/8" LINER 1 11232 8665 29 MMG-2 DMY RK 0 04/30/03 7"BKR PKR TIEBACK SLEEVE,D=7.50" H 9860' - 9-5/8"X 7"BKR H PKR,D=6.187" H 9867' I g ►:� ■ 9-518"SIDETRACK WIDOW- 10006'-10056'(SECTION MLL) 9-5/8"X 7"BKR HMC LNR HGP,D=6.250' —1 9873' NOTE RRE SDTRK WELLBORE NOT SHOWN BELOW 9-5/8" MLLOUT VMNDOW. 9-5/8"CSG,47#,L-80,D=8.681" H 10006' ' I 11260' —1 3-1/2"O11S X NIP,D=2.75" S 11274' H 7"x 3-1/2'BKR SABL-3 PKR,D=3.85" I 11299' —1 3-1/2'OTIS X NIP,D=2.75' 3-1/2"TBG,9.3#,N-80,.0087 bpf,D=2.992" —1 11456' 11366" { 2.7"BKR DEPLOYMENT SLV,D=2.250" I 1 11445' —{ 3-1/2"OTIS X NIP,D=2.75" PERFORATION SUIWAARY7 11457' H 3-112' WLEG REF LOG: MWD I GR ON 04/15/03 ANGLE AT TOP PERF: 92'@ 12700' 11456' —1 ELMD TT LOGGED 10/09/98 Note:Refer to Production DB for historical perf data 40• ,44 11650' —1 TOP OF CEMENT SCE SPF INTERVAL Opn/Sqz DATE SOZ .•. 44• , 02 11884' --I 7"X 4-1/2"BKR H LNR TOP PKR,112 4.44" 1-1/2" 4 12700-12760 0 04/23/03 ++ 1-1/2" 4 12930-13355 0 04/23/03 . 1 PC1 11902' —I TOP OF BKR TACK SLEEVE,D=6.28" 1-1/2" 4 13480- 13670 C 04/23/03 1/ r 11910' H 7"X 4-1/2"BKR PKR/LNR HGP ID=4.44" 1 1 1 1 1 . MLLOUT WINDOW 1204T-12051' 7"LNR,29#,L-80, .0371 bpf,ID=6.184" —1 11942' I WI IPSTOCK W/2 RA TAGS —1 12025' `*•♦ L 13400' .1—2-3/8"CBP(01108/14) I .111.11111. 2-1/2"BKR BP(04/10/03) — 12230' _ iiiiiir 11121 .411°` 13674' — PBTD 4-1/2"LNR, 12.6#,L-80,.0152 bpf,ID=3.958" —{ 13535' V........! ``N 2-3/8"LNR,4.6#,L-80,.0039 bpf,D=1.995" -1 13688' DATE REV BY COIMENTTS DATE REV BY COMMENTS PRIDHOEBAY UNIT 02122/88 ORIGINAL COMPLETION 01/09/14 JDFWJM) SET CBP(01/08/14) WELL: C-31B 03/11/95 RIG SIDETRACK (C-31A) 03/20/14 RB/JMT TREE C/O(03/18/14) FERMT No: 2030080 04/24/03 DAV/KK CTD SIDETRACK(C-31B) AR No: 50-029-21775-02 04/30/03 JJ/KAK GLV C/O SEC 19,T11N,R14E, 1800'FTL 8 883'FEL 07/03/03 CMD/TLP KB ELEVATION CORRECTION 09/15/03 CMJ/TLP DATUM MYREF LOG/PERF ANGLE BP Exploration(Alaska) /Image f _1ject Well History File CL ~>er 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. 1.03 - DOB Well History File Identifier Organizing (done) o Two-sided 1111111111111111111 ~escan Needed 1 RESCAN ~Olor Items: o Greyscale Items: DIGITAL DATA ~iskettes, No. I o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: o Logs of various kinds: BY: Helen ~ o Other:: , t] Date:b, ~ ðS 151 YV1 . 111- I -I Date:1.o or oS" 151 V'V1, Q NOTES: Project Proofing BY: Helen ~. Scanning Preparation , x 30 = ~() + q = TOTAL PAGES ~O (COUnid.oés not nclude cover Shee·.wf) Date: (II a oS 151 I, , I, 1 BY: Helen CMaria ) 8Ÿ: Production Scanning Stage 1 Page Count from Scanned File: 4-D (Count does include :;trrSheet) Page Count Matches Number in Scanning Preparation: V YES Helen E; Date: to . cr 0 s; 151 If NO in stage 1, page(s) discrepancies were found: YES NO NO y}1J Stage 1 BY: Helen Maria Date: 151 II! 11111111111 JIIII 1111111111111111111 Scanning is complete at this point unless rescanning is required. ReScanned 1 BY: Helen Maria Date: 151 Comments about this file: Quality Checked III "1111111" 11I11 STATE OF ALASKA RECEIVED A, CA OIL AND GAS CONSERVATION COMM ON REPORT OF SUNDRY WELL OPERATIONS FEB 0 5 2014 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other Li enV GOC 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: BP Exploration(Alaska),Inc Name: Development E] Exploratory ❑ • 203-008-0 3.Address: P.O.Box 196612 StratigraphiC Service ❑ 6.API Number: Anchorage,AK 99519-6612 • 50-029-21775-02-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028305 'r • PBU C-31 B 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): i PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured • 13688 feet Plugs measured 13400 feet true vertical 9022.17 feet Junk measured None feet Effective Depth measured 13400 feet Packer measured See Attachment feet true vertical 9023.31 feet true vertical See Attachment feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"Conductor 30-110 30-110 0 0 Surface 2796 13-3/8"68#L-80 29-2825 29-2719.81 5020 2260 Intermediate None None None None None None Production 9978 9-5/8"47#L-80 28-10006 28-7596.74 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 12700-12760 feet 12930-13355 feet 13480-13670 feet True Vertical depth 9022.12-9021.74 feet 9022.92-9023.21 feet 9022.16-9021.65 feet Tubing(size,grade,measured and true vertical depth) 3-1/2"9.3#N-80 27-10603 27-8116.79 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): RBDM.MAY 17 2014 Treatment descriptions including volumes used and final pressure: same MAY 2 9 201 4 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 269 22688 39 0 731 Subsequent to operation: 177 14340 26 0 718 14.Attachments: 15.Well Class after work: I Copies of Logs and Surveys Run Exploratory Development❑✓ , Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil • U Gas U WDSPL.0 GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUC] 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 Nita Summerhays Email Nita.SummerhaysCa)bp.com Printed Name Nita Summerhays Title Data Coordinator ignatur. f Or..y. 7 /-� Phone 564-4035 Date 2/5/2014 VGF 4 // ' A 07 a.,..,,In_Ane eo..ice.1 4monl') C,,ti.,if nr4..;...,i n..i„ Daily Report of Well Operations ADL0028305 ACTIVITYDATE I SUMMARY • of '_ .. Job Objective: PPROF w/Ghost contingent CIBP/Adperfs 1/3/2014 Travel to loc/MIRU Cl U#8 1.5"Coil (CV=27bbl) Job Objective: PPROF w/GHOST contingent CIBP/Adperfs MIRU, M/U Drift BHA 1.75"OD OAL= 10.9', RIH to PBTD 13626 CTM, POOH, M/U 1.69" PPROF BHA OAL=31.48', RIH 1/4/2014 *"*Job in Progress*** Cl U#8 1.5"CT(CTV=27bb1) Job Objective: PPROF w/Ghost contingent CIBP/Adperfs 1.69" PPROF BHA OAL=31.48', RIH to flag,wait to stabalize. Perform flowing up passes only due to having to shut in to enter 2-3/8"liner. —1 hr stabalization between up passes. 40&60 fpm passes completed prior to CT pipe failure. Decision from APE to set CIBP at 13400. Well SI upon departure. Pad operator and DSO notified. Job postponed. 1/5/2014 ***Job Incomplete*** Cl U#8 1.5"Coil (CV=25bbl) 15,665ft Job Scope: Memory GR/CCL, CIBP MIRU, Discovered wire under coil controls to be shorted. E-tech on location troubleshooting, re- wiring and installing new CCAT power supply 1/6/2014 ***Job in progress*** ***Continued from 1/6/2014*** CTU#8 1.5"coil CV=25 Job Scope: Memory GR/CCL, Set CIBP @ 13400 Pumped and recovered 1"steel ball. Made up 1.69 GR/CCL OAL=11.74', Logged 13550-11000, Flagged at 13399.9, POOH, Correction +64, M/U 1.75 HST&2 3/8 CIBP OAL=10.59', RIH. Set 2- 3/8"CIBP at 13,400'. Observed high wear on one side of pipe as well as dents when POOH @ 11673'. Standby for manlift to arrive on location to inspect injector chains. Continued on 1/7/14 1/7/2014 ***Job Inprogress*** ***Continued from 1/7/2014*** CTU#8 1.5"coil CV=25 Job Scope: Memory GR/CCL, Set CIBP @ 13400 Observed high wear on one side of pipe as well as dents when POOH @ 11673'. Order manlift to inspect injector for possible damage being done to pipe. Injector inspection looks good, continue to POOH, observe wear marks/balled up metal on pipe while POOH. Inspected IH -all good. RDMO. 1/8/2014 ***Job Complete*** FLUIDS PUMPED BBLS 224.4 60/40 METH 200 1% SLICK KCL 424.4 TOTAL Q. ow 000M CO CO Lo o v N U CynO O O O O O L. I� N O CO " CO O m CO 7- 0") O O Cr) CO CO N CO I"- co N CO I- CO CO 0) CO O CO O N V CO O CO I� CO O co co co co c0 N CO IIIIIIIIICI H U7 O N CO r CO CO O O N O M C) CO O N- CO 00 N 00 N ("Ni N " CO t— 00 ++ I` co 00 00 00 C) CO O C) O CO C) O lf) O Lo O O V N CO V O NCO O � O V COLO ° I I 4 Q M Oornu) CO ocooC° rnvaornt— CON C) oo O N N N N N C o J a) N N Q (Z d O O 2_Q CZ a O 8 co co z 2 co °Q 00 i» � pppj Z . N �c N (DX 4,t CO X X N co*CO M o cn - of U moo • 000 N (A N N N N (T A c) C) C) (O r+ r3)O OC) O N- C CO O r- 00 J O N Z 0 w N D w w 111 D < ID Z p V Z w w Q- a 0 O rx E Q Z Z a c D p U _ JZZZdU) H Packers and SSV's Attachment ADL0028305 SW Name Type MD TVD Depscription C-31B PACKER 9867 7413.94 9-5/8" Top Packer C-31 B PACKER 11274 8629.81 3-1/2" Baker SABL-3 Packer TREE= 6"CIW a AEI_LhEAD= McEVOY 31 B SAFE DTES:WELL ANGLE>70°@ 11730'. ACTUATOR= 6"AXELSON OKB.ELEV= 67.8' BF.ELEV= 37.3' KOP= 1700' Max Angle= 96"Q12186' DetumM?= 11487 SS O 2115' H 3-1/2"OTIS SSSV LAND.NIP,D=2.75" DatumWD= a800' 13-3/8"CSG,72#,L-80,D=12.347" — 2825' ' GAS LET MANDRELS ST MD IVO DEV TYPE VLV LATCH FORT DATE 3 5091 4271 50 Is/SAG DOME RK 16 04/30/03 Minimum ID = 1.995" @ 11372' 2 8601 6568 46 MMG SO RK 20 04/30/03 TOP OF 2-3/8" LINER 1 11232 8665 29 MMG-2 OMY RK 0 04/30/03 7"BKR PKR TEBACK SLEEVE,D=7.50" 9860' 9-5/8"X 7"BKR H PKR,D=6.187" 9867' 9-5/8"SIDETRACK WINDOW- 10006'-10056'(SECTION WILL) 9-5/8"X 7'BKR HMC LNR HGR,D=6.250" —1 9873' NOTE PRE SDTRK WELLBORE NOT SHOWN BELOW 9-5/8" 9-5/8"CSG,47#,L-80,D=8.681" - I 10006' MLLOUT WINDOW. 11260' H 3-1/2"OTIS X NIP,D=2.75" ►�4 11274' — 7"x 3-1/2"BKR SABL-3 PKR D=3.85" 11299' —1 3-1/2"OTIS X MP,D=2.75' 3-1/2"TBG,9.3#,N-80,.0087 bpf,D=2.992" — 11456' 11366' — 2.7"BKR DEPLOYMENT SLV,D=2.250' 11445' — 3-1/2"OTIS X NIP,ID=2.75' PERFORATION SUMMARY 11457' —1 3-1/2" WLEG REF LOG: MWD/GR ON 04/15/03 ANGLE AT TOP PERF: 92"@ 12700' 11456' —{ ELMD TT LOGGED 10/09/98 Note;Refer to Production DB for historical perf data 44 4/ 11650' —1 TOP OF CEMENT SIZE SPF INTERVAL Opn/Sqz DA it SO.Z ►��I 1��� 11884' — 7"X 4-1/2"BKR H LNR TOP PKR,D 4.44' 1-1/2" 4 12700-12760 0 04/23/03 X11 12 1-1/2" 4 12930- 13355 0 04/23/03 .1 11902' — TOP OF BKR TACK SLEEVE,D=6.28" 1-1/2" 4 13480- 13670 C 04/23/03 X11 1 11910' H, 7"X 4-1/2"BKR PKR/LNR HGR,D=4.44' 14 1 1 MLLOUT WT1JOW 12047'- 12051' 7"LNR,29#,L-80,.0371 bpf,D=6.184" — 11942' 4 WHIPSTOCK W/2 RA TAGS 12025' `'•• •♦,\ 13400' I-12-3/8"CSP(01/08/14) 2-1/2"BKR BP(04/10/03) 12230' tN PBTo 4-1/2"LNR 12.6#,L-80, .0152 bpf,D=3.958" —{ 13535' Watt, ��� 2-3/8"LNR,4.6#,L-80,.0039 bpf,D= 1.995" H 13688' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 02/22/88 ORIGINAL COMPLETION 01/09/14 JDMJM) SET CEP(01/08/14) WELL C-31B 03/11/95 RIG SIDETRACK (C-31A) PERMT No: 2030080 04/24/03 DAV/KK CTD SIDETRACK(C-31B) AR Na: 50-029-21775-02 04/30/03 JJ/KAK GLV GO SEC 19,T11 N,R14E, 1800'FNL&883'FEL 07/03/03 CMO/TLP KB ELEVATION CORRECTION 09/15/03 CMO/TLP DATUM MYREF LOG/PERF ANGLE BP Exploration(Alaska) • • bp BP Exploration (Alaska) Inc. 0 Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 August 22, 2011 RECEIVE Mr. Tom Maunder AUG 7011 Alaska Oil and Gas Conservation Commission Make 011 & Gas Ca. Commission 7 333 West 7 Avenue Anchorage, Alaska 99501 Subject: Corrosion Inhibitor Treatments of GPB C -Pad 0 2.03 -06(, Dear Mr. Maunder, C 3 16 Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB C- Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Gerald Murphy, at 659- 5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator • 0 BP Exploration (Alaska) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) C -Pad 7/19/11 Corrosion Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # Initial top of cement pumped cement date inhibitor sealant date ft bbls ft na gal C - 01A 2030100 500292012101 0.3 NA 0.3 NA 3.40 11/16/2010 C -02 1730040 500292012300 0.3 NA 0.3 NA 3.40 11/16/2010 C -03B 2051580 500292012402 0.3 NA 0.3 NA 3.40 11/16/2010 C -04B 2060570 500292012502 1.25 NA 1.25 NA 23.80 10/26/2010 C -05A 2010020 500292012601 0.8 NA 0.8 NA 3.40 11/23/2010 C -06B 2061040 500292012702 1 NA 1 NA 5.10 11/22/2010 C -07A 2000520 500292012801 0.3 NA 0.3 NA 1.70 11/22/2010 C -08B 2050110 500292012902 1 NA 1 NA 5.10 11/20/2010 C -09A 2020940 500292036601 0.1 NA 0.1 NA 0.85 11/23/2010 C -10A 2051370 500292037101 0.1 NA 0.1 NA 3.40 11/12/2010 C -11A 2030480 500292038201 0.1 NA 0.1 NA 1.70 11/13/2010 C -12B 2090850 500292038702 2 NA 2 NA 10.20 11/11/2010 C -13A 1971430 500292040401 10.7 NA 10.7 NA 74.80 11/25/2010 C -15A 2090520 500292042701 10.5 NA 10.5 NA 64.60 11/25/2010 C -16B 2060510 500292043802 45 10.0 0.6 7/19/2011 3.40 7/19/2011 C -17B 2040940 500292043902 1 NA 1 NA 6.80 11/13/2010 C -18B 2090710 500292078502 9.6 NA 9.6 NA 69.70 11/23/2010 C -19B 2000050 500292073502 11 NA 11 NA 76.50 10/27/2010 C - 20C 2091300 500292074503 1.9 NA 1.9 NA 10.20 11/11/2010 C -21 1820810 500292074503 1.7 NA 1.7 NA 8.50 11/11/2010 C -22A 2060390 500292075801 0.7 NA 0.7 NA 5.10 11/11/2010 C -23C 2081700 500292077503 25 4.0 0.08 7/15/2011 0.85 7/19/2011 C -24A 2040580 500292081601 Sealed NA NA NA NA NA C -25B 2041090 500292081902 0.7 NA 0.7 NA 3.40 11/22/2010 C -26A 1981450 500292083401 0.8 NA 0.8 NA 3.40 11/22/2010 C -27B 2031860 500292084302 7.5 NA 7.5 NA 39.10 11/21/2010 C -28B 2100630 500292086702 1 NA 1 NA 5.10 11/21/2010 C -29A 1961700 500292147201 23 10.0 0.9 7/15/2011 6.80 7/19/2011 C -30A 2081690 500292177701 0.2 NA 0.2 NA 1.70 11/20/2010 C -31B 2030080 500292177502 0.8 NA 0.8 NA 5.10 11/22/2010 C -32C 2061390 500292155903 0 NA 0 NA 0.00 11/13/2010 C -33A 2002020 500292237301 1 NA 1 NA 6.80 11/11/2010 C -34A 2060370 500292178501 2.2 NA 2.2 NA 10.20 11/20/2010 C -35B _ 2061290 500292155302 1.5 NA 1.5 NA 10.20 11/15/2010 C -36A 2000020 500292179001 2 NA 2 NA 10.20 11/13/2010 C -37B 2101000 500292236002 4.7 NA 4.7 NA 30.60 10/28/2010 C -38 1860660 500292157100 0.1 NA 0.1 NA 0.85 11/15/2010 C -39A 2050030 500292238301 1 NA 1 NA 0.85 11/23/2010 C -41A 2041880 500292238501 Sealed NA NA NA NA NA C -42 1930500 500292235700 2.6 NA 2.6 NA 13.60 11/13/2010 • ~,-~,.~ MICROFILMED 03/01/2008 DO NOT PLACE ANY NEW MATERIAL -UNDER THIS PAGE F:\LaserFiche\C~rPgs_Inserts\Microfilm Marker.doc os/zs/o7 $Ch11111~1'IJ~1' NO. 4440 Alaska Data 8 Consulting Services Company: State of Alaska 2525 Gambell Street, Suite aoo ~4~> ~A~`~~ h' O, t ~ ~ ~ry~ ~ Alaska Oil & Gas Cons Comm Anchorage, AK 99503-2838 ~ lt"t.91"! iV '1 U Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Woll In6 ~f 1 .... nw~....i..ai.... n~a~ n~ n_~_- 15-0SA 11661158 MCNL it 06/21/07 1 F-266 11216200 MCNL ~[ t/ ~ 06/06/06 1 P2-11A 11285926 MCNL ~ 04/19/06 1 1 C-316 11745223 MCNL ~~/ 05!31/07 1 1 E-03A 11628773 MCNL ~ L/ 05/09/07 1 1 K-12A 11745224 MCNL p _ ~ 08/02/07 1 1 18-106 11485771 MCNL '~ ( </`}(0 11/08/06 1 1 C-08B 11209599 MCNL -V ~ ~ l $~- 04/22/08 1 1 D-30B 11628774 MCNL - L ~' 05/10/07 1 t ~ a.a.r~.~a. r~v~~nv•~a.~vvc ~~GVGIr I pl JIVI\119V hl\V nG 1 VRI.117U' V19C NVf r CNNn 1 V. BP Exploration (Alaska) Inc. _ _ _ _ , i „~ Petrotechnical Data Center LR2-1 i ji 900 E. Benson Blvd. ~ ~ - - h° ~° ~~ " ` '` ~~"~~ Anchorage, Alaska 99508 Date Delivered: ~~~"~ r~ ~ ° ~~~] Alaska Data 8i Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Received by: • • ".,n'" Schlumberger NO. 4306 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TTN: Beth 6Jo3-<:::b~ Company: State of Alaska Alaska Oil & Gas Cons I::omm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 1 î{)t\7 t"~ JU~ .,. S~ti~\-t Field: Prudhoe Bay Well Job# Loa Description Date BL Color CD l3-12 11695062 PRODUCTION PROFilE 06/06/07 1 GNI-03 11637128 PRESSITEMP SURVEY 06/06/07 1 Y·11C 11661151 MEMORY INJECTION PROFilE 06/01/07 1 C-31B 11745223 MEMORY PROD PROFilE 05/31/07 1 05-30 11801067 LDL 06/01/07 1 13-29l1 11686753 LDL 05/28/07 1 Y-05A 11628778 MEMORY INJECTION PROFILE 05/28/07 1 l5-23 11661153 MEMORY PROD PROFILE 06/05/07 1 H-37A 11594506 PPROFIIPROF 06/05/07 1 Y-35A 11661152 MEMORY PROD PROFILE 06/03/07 1 N-15 11637129 PRODUCTION PROFILE 06/13/07 1 01-07A 11626098 PRODUCTION PROFILE 05/28/07 1 13-29l1 11686753 lDl 05/28/07 1 04-24 11773112 PRODUCTION LOG 05/19/07 1 12-19 11637343 LDL 06/13/07 1 G-23A 11638639 LDl 06/03/07 1 14-0SA 11813055 PPROF WIRST BORAX 06/11/07 1 K-12A 11745224 MEMORY PROD PROFILE 06/02/07 1 P2-19A 11661154 MEMORY PROD PROFILE 06/06/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 3-41/K-39 11813054 INJECTION PROFILE 06/08/07 1 3-41/K-39 11813054 INJECTION PROFILE 06/09/07 1 Z-29 11686758 PRODUCTION PROFILE 06/15/07 1 Z·13A 11649962 MEMORY PROD PROFilE 04/21/07 1 W-17A 40012333 OH EDIT MWDILWD 09/19/05 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Alaska Data & Consultíng Services 2525 Gambe" Street. Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Date Delivered: ,HIre! ? ,n 20n¡ Received by: t)LI. \-/-7 06/18/07 . . ~'-1 {\¡~ ~ 1 DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Permit to Drill 2030080 Well Name/No. PRUDHOE BAY UNIT C-31B Operator BP EXPLORATION (ALASKA) INC 5(1cAJ I t ~ AOij"') API No. 50-029-21775-02-00 MD 13688 / lVD 9022 /' Completion Date 4/24/2003 /' Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log Yes Samples No Directional Survey eYes ) DATA INFORMATION Types Electric or Other Logs Run: CCL, GR, MWD, GR Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name (data taken from Logs Portion of Master Well Data Maint) --- Log Log Run Scale Media No Interval OH / Start Stop CH Name Interval Start Stop A Directional Survey Log is require~ s~ted. T~O""'ti£a11y creat om Permit to Drill Mule on: 1/28/2003. 11144 13670 10/10/2003 LDWG edit of 2-pass memory GRlCCL 11144 13670 1 0/1 0/2003 LDWG edit of 2-pass memory GRlCCL 12046 13688 9/16/2003 12046 13688 9/16/2003 ~~ 12046 13688 Open 3/11/2004 Gamma Ray - MWD 12046 13688 Open 3/11/2004 Gamma Ray - MWD 12046 13688 Open 3/11/2004 Gamma Ray - MWD Blu 12046 13688 Open 3/11/2004 Gamma Ray - MWD Sample Set Sent Received Number Comments I ED C H t]lr 12149 LIS Verification 4 C ;fi ~ ,\ ~ 49 Casing collar locator ~D I ItRpt i ~D C- i~C ~hO~ Log ~ ;1 r" Directional Survey Directional Survey ¡¡. 1...1 S ~455 Gamma Ray Pds 4l(55 Gamma Ray Gamma Ray Gamma Ray Well Cores/Samples Information: DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Permit to Drill 2030080 Well Name/No. PRUDHOE BAY UNIT C-31B Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21775-02-00 MD 13688 TVD 9022 Completion Date 4/24/2003 Completion Status 1-01L Current Status 1-01L UIC N ADDITIONAL INFORMATION Well Cored? Y ~ Chips Received'r Y II'<J ' Daily History Received? ()N fiyN Formation Tops Analysis Received? ~ Comments: .<~ Compliance Reviewed By: ~f) Date: 2., Þ f'1t¡ ;( ð-t) J- ./ ,,-=. ) Transmittal Form INTEQ To: AOGCC 333 West 7th Ave, Suite 100 Anchorage, Alaska 99501 Attention: Lisa Weepie Reference: C-31B Contains the following: 1 LDWG Compact Disc I tJ 1-155 (Includes Graphic ~mage files) 1 LDWG lister summary ê9ð3-0C'f!t ) r&l. BAKER HUGHES Anchorage GEOScience Center 1 blueline - GR-Directional Measured Depth Log 1 blueline - GR-Directional TVD Log LAC Job#: 466609 Sent By: Glen Borel Received B~ \ ~ ,~'-.Ü J!'<. "''', ~ Date: Mar 1, 2004 Date: PLEASE ACKNOWLEDGE RECEIPT BY SIGNING & RETURNING OR FAXING YOUR COPY FAX: (907) 267-6623 Baker Hughes INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Direct: (907) 267-6612 FAX: (907) 267-6623 ~~~ffi~ RECEIVED "'-'!:' 0 1/'~ 0004 I·"ï~. 1 t.. ,~~J~~I Oil & Gas Cons. Commision Anchorage [.__m......______..'...,.____.-.'.'---..--..._ ¡ """ '''' . 100"'" ,.,';~;;·ll :.....'. ....·..,.~" ::,i:i::öQ,··· ... ········1 i,~,~·,," .:¡" ""!;'.," ~'",~~ t~;:··:·~;:~'õi~~--:~~~~;¡~ i=· ;;:~.. f r i I .~~ [i ~~:,'_, _~"" .... .... W'I '...., :~:::~~:~~~:.::~~:.:;:;~'~'j~;;::::~;'~'::i,:~~: '..,...' '~ 1<'" .......'~';I ~ ~ ~. ~,~~~ ~ ~ ,......~~-þ". ..-..~.... "_.._----~ ..--~_......_.. .......-- ¡ ~'I\" ~'j¡l("'f I'¡'l~' \'I ~" ~..~, ._~_.:.~..~-~~,,-,..._~'..~ -~.: ,,' '" .",-... ......"..,..,.,..". . i , j ...,,, . . .. ..,. ,j ..~." . .",.. ,..,' ,,,I ..",.,.... u.....,,·.. "..i I" , :'~·:·::r.. i',; "I .< ¡ ,;),~ .. ·'...Æè ~I ' :.::',:.'.';".',' ,:,..:: T~> , Lf~L.--U . ... I 5·; ¡ 1:.···.\··:; 1,·····:lu.~,..: I~tl:~-i 'i':':~'?:~' t7:"':~-:--:--~ I ¡~...~ ¡ t. i I I I .,., i i ! ~_~..~.__~__.l__~__.__~u_____~__. 09/26/03 Scblumbepger NO. 2976 Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Well Job# Log Description Color Date Blueline Prints CD 06/11/03 ./' 1 t~\~~ 08/26/03 ~~ 1 09/16/03 1 l~ J f5 v 04/23/03 1 ) ò{ l~) 02103/03 1/ 1 01/04/03 --- MPL-01A D.S. 15-28A '- K-07C C-31 B D.S. 15-30A 3-25A1N-24 ~ -o~ YI 23433 CH EDIT MGR (PDC) .3-1 :t 23431 MCNL - .~ 10560303 RST -SIGMA .... 23423 CH EDIT MGR (PDC) ...rm 23422 CH EDIT MGR (PDC) '--\~ ~ SCMT (REPLACES 3-25A1M-27 PRINTS) -- . -.....- PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ;, ,;~. :-.-::.- ~ ~ ¡.' ~ Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage. AK 99503-5711 ATTN: Beth . - - .-""'........,- ~-~ Date Delivered: Receivedb~ ~N\~,Of:J#~ ~..,..~r.·r':...t . ..~....... ~ - - - . ." .- - - -. -;-.-.:--;: ....-...~_.,. ~~~(\\~ ) ) STATE OF ALASKA " ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well 131 Oil 0 Gas 0 Suspended 0 Abandoned 0 Service 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1800' SNL, 883' WEL, SEC. 19, T11N, R14E, UM At top of productive interval 3981' SNL, 4407' EWL, SEC. 20, T11N, R14E, UM X = 669852, Y = 5957359 10. Well Number At total depth 3961' SNL, 4182' EWL, SEC. 20, T11N, R14E, UM X = 669627, Y = 5957375 11. Field and Pool 5. Elevation in feet (indicate KB, OF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field I Prudhoe Bay Pool KBE = 72.13' ADL 028305 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 4/18/2003 4/20/2003 4/24/2003 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 13688 9022 FT 13674 9022 FT 131 Yes 0 No 22. Type Electric or Other Logs Run CCL, GR, MWD, GR 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE Top BOTTOM SIZE 20" Conductor 29' 139' 13-3/8" 68# L-80 29' 2825' 9-5/8" 47# L-80 29' 10006' 7" 29# L-80 9860' 11942' 4-1/2" 12.6# L-80 11902' 12047' 2-3/8" 4.6# L-80 11366' 13688' 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 1.56" Gun Diameter, 4 spf MD TVD 12700' - 12760' 9022' - 9022' 12930' - 13355' 9023' - 9023' 13480' - 13670' 9022' - 9022' MD TVD 27. Date First Production May 4, 2003 Date of Test Hours Tested 5/5/2003 4 Classification of Service Well 7. Permit Number 203-008 8. API Number 50- 029-21775-02 Unit or Lease Name Prudhoe Bay Unit 9. X = 664508, Y = 5959422 C-31 B 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2115' MD 1900' (Approx.) 17-1/2" 12-1/4" 8-1/2" CEMENTING RECORD 8 cu yds Concrete 3900 cu ft Permafrost 2335 cu ft Class 'G' 416 cu ft Class 'G' 309 cu ft Class 'G' 95 cu ft Class 'G' AMOUNT PUllED 6" 3" 25. TUBING RECORD DEPTH SET (MD) 11457' PACKER SET (MD) 11274' SIZE 3-1/2", 9.3#, L-80 I N-80 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2000' Freeze Protected with 18 Bbls MeOH PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR Oll-BBl TEST PERIOD 3,566 OIL-BBL Oil GRAVITY-API (CORR) 25.4 CORE DATA RF(~FIVF.r) Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. Flow Tubing Casing Pressure CALCULATED Press. 226 24-HoUR RATE 28. No core samples were taken. í ·!.,.c¿~~3 . ': ..:i~~' I~""~~-,,~..~ .'" "..,' Form 10-407 Rev. 07-01-80 GAs-McF 4,837 GAs-McF WATER-BBl -0- CHOKE SIZE 94° GAS-Oil RATIO 1,356 WATER-BBl RßDM5 brLo G( MAY G 7 MAY 2 1 2003 i..ì,.\U~\ ,~a5Ka 0;') &. Gas Cons. Comrni~n Anchorage O~tG'fVA_ Submit In Duplicate ) )) i 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. Zone 1 A 134601 90231 HOT 124501 9030' 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed Terrie Hubble ~~ ~ Title Technical Assistant Date D <3 .. :l..1- 0 .3 C-31 B 203-008 Prepared By Name/Number: Terrie Hubb/e, 564-4628 Well Number I Drilling Engineer: Alistair Sherwood, 564-4378 Permit No. Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (OF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ) ) BPE)<PLORÄTION ()!~eratiiøn~.·.··SllJh'lmål¥...Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-31 C-31 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 . . ··o¡:ne Ft"C>rTl-"[Ö Hours ".. " PhaSê tasK Code ... NAlT 1/1/1900 0.00 STKOH PROD1 4/14/2003 00:00 - 01 :30 1.50 MOB P PRE 01 :30 - 13:00 11.50 MOB N WAIT PRE 13:00 - 00:00 11.00 MOB P PRE 4/15/2003 00:00 - 06:00 6.00 MOB P PRE 06:00 - 06:30 0.50 BOPSURP PRE 06:30 - 07:00 0.50 BOPSURP PRE 07:00 - 12:30 5.50 BOPSUR P PRE 12:30 - 13:30 1.00 MOB P PRE 13:30 - 14:30 1.00 STWHIP P WEXIT 14:30 - 15:15 0.75 STWHIP N WEXIT 15:15 - 16:00 0.75 STWHIP P WEXIT 16:00 - 17:30 1.50 STWHIP P WEXIT 17:30 - 18:30 1.00 STWHIP P WEXIT 18:30 - 20:00 1.50 STWHIP N SFAL WEXIT 20:00 - 22:55 2.92 STWHIP N WEXIT 22:55 - 00:00 1.08 STWHIP N SFAL WEXIT 4/16/2003 00:00 - 00:30 0.50 STWHIP N DFAL WEXIT 00:30 - 03:00 2.50 STWHIP N DFAL WEXIT 03:00 - 05:10 2.17 STWHIP N DFAL WEXIT 05:10 - 07:30 2.33 STWHIP N DFAL WEXIT 07:30 - 09:45 2.25 STWHIP N DFAL WEXIT 09:45 - 10:30 0.75 STWHIP N DFAL WEXIT 10:30 - 14:00 3.50 STWHIP N DFAL WEXIT 14:00 - 16:00 2.00 STWHIP N DFAL WEXIT 16:00 -18:00 2.00 STWHIP N DFAL WEXIT Page.1 of8 Start: 4/14/2003 Rig Release: 4/24/2003 Rig Number: N2 Spud Date: 1/2/1988 End: 4/29/2003 Description of ()peratiôrls Move from 1 C pad at Kuparuk to Milne Pt Turn off. Wait at Milne Point turn off for Security Escort. Continue moving towards C Pad. Finish move from Kuparuk to GPB well C-31A. Position rig over well. Accept rig 05:00 hours - adjusted to 06:00 hours because of pipe stabbing operations below. Start NU BOPE. Techlimitlsafety meeting Finish NU BOPE. PT BOPE. Witness waived by AOGCC's John Crisp. Stab pipe. Rehead coil. Wait for arrival of BHI personnel. Set-up and MU BHI tools. Load 300 bbls bio water into pits. Pull and PT CTC. Open well. Check WHP. Fill hole. Trace electrical comms problems with BHI tools. Crossed +/- wiring. RIH. Tagged cement at 11990'. (PT tubing 500 psi increments. Leak-off at 1440psi) Trace electrical comms problems with BHI tools. Possible bad connection within collector wiring remove and inspect. EDC in the open position and unable to close. (displace hole to KCL w/ 1/2# biozan. No evidence of electrical problems at surface. TOH to inspect BHA. Found cable had pulled out of head and pumped down the by-pass tube. Re-head e-line. RIH with milling BHA. Short in tools at about 10000'. POOH. Cable had pulled out of head. Set screw which holds the slip sleeve was not sheared (expected weak point - 700 Ibs shear rating). Cable simply pulled through the slips (slips were new for this job). Also, after rebuilding the same head assembly on the bench, BHI was able to pound the cable through the slips without sheering the screw. Possible that 00 of cable is slightly reduced - normal for this type of armored cable over time. Will install another washer to crimp cable tighter. Now, the slack management issue - this was performed before this well and the cable moved back only about 3' - 4', and it was not pumped forward after reheading (pumping forward at surface is a step which we rarely perform). Cut CTC, stab onto well. Pump back 1-1/2 coil volumes at 3.5/3700. Cut coil. Cable 4' back. Rehead. Pull and PT. Pump forward one coil volume at 3.4 BPM. RIH. Shorted again at about 10100'. POOH. UD BHA. (E-line has again slipped out of the "slip hold down assembly". This shouldn't happen. As stated above a brass shear pin should shear before the slips ever let go. There is an option for 2 shear pins, each designed to shear with 700# overpull. We are using 1 shear pin only. Inspection of the slip assembly does not reveil anything wrong. Reviewed actual assembly method of the slips within the hold down as they can Printed: 4/28/2003 9:16:54 AM ) ) BP EXPLORATION OperatiÐns:..·S:LJmrrlêJ··ry.:··~~þÐrt be inserted upside down. No problem there either. Put micrometer to cable and found to be .320" avg or slightly over 5/16") Stab on injector. Pumped forward at 3.4bpm for 10 min. Pumped 13' of cable out. (less than expected). Discuss options. Short PJSM for plan forward of cutting 1000' of coil looking for possible "bird nest" in e-line. Then pump 120 deg 2% KCL rather than slick biowater for slack management. Rig up coil cutting equipment. DFAL WEXIT PJSM discuss coil cutting operations, risks and job assignments. DFAL WEXIT Cut 1000' of coil. No visable problem with e-line found. Dicuss options with SLB. Reel how has 14075' of coil. Expected TD of well 13800'. Will do a last ditch effort on pumping back some e-line. Prep end of e-line for slack management using KCL. Install weld-on coil connector. DFAL WEXIT Stab on injector and reverse circulate through coil with hot 2% KCL for "slack management". Setback injector. Rig-up coil cutter and cut 4' of coil. Found end of e-line. SO...was expecting to have at least 20-25' before attempting to head up and try with this reel again. Plan forward will be to swap out for new coil reel. Rig-up N2 to blowdown coil reel. Close master valve on wellhead. PJSM with N2 and rig crews. Blowdown reel with N2. Unstab coil from injector and secure to reel. Prep reel to make swap with new 2" e-line coil reel. Safety meeting. Swap reels. Stab coil into injector. Rehead with modified cable head anchoring. Hook-up hardline and bulkhead. Circulate methanol through coil slow followed by KCL water. Pump forward at 2.5 BPM. SI and pressure coil to 4600 psi. Pump another coil volume of bio water. Minimal debris over shaker. MU milling BHA. PT CTC. RIH. Tagged something at 11954'. Easy drilling through with 1 k wob. 2900psi off-bottom @ 1.6 bpm. Steadily firmer to 12005'. Good cement f/12005' 16'/hr drilled cement to 12011'. Starting at 12011' milling window with typical milling rates to 12012.8' then rates picked up to previous rates while drilling cement. Drill ahead with what appears to be ratty cement (confimed with samples taken from 12013' and 12040') to 12095'. This is 70' past expected top of whipstock. Sample taken from 12050' confirmed to be formation sand by geologist. So we've either milled an extremely fast short window and in addition drilled 82' of formation or have "pushed" the whipstock downhole below the squezzed perfs at 12038'. WEXIT Pick up hole to log top of 4 1/2" liner jewelry and 3 1/2" tubing tail. WEXIT Continue CCL logging top of 41/2" liner at 11884', 3 1/2" tubing Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-31 C-31 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 · Date From -To Hours Task Code·NPT Phøsè 4/16/2003 16:00 - 18:00 2.00 STWHIP N DFAL WEXIT 18:00 -19:00 1.00 STWHIP N DFAL WEXIT 19:00 - 20:05 1.08 STWHIP N DFAL WEXIT 20:05 - 20:20 0.25 STWHIP N 20:20 - 00:00 3.67 STWHIP N 4/17/2003 00:00 - 01 :00 1.00 STWHIP N 01 :00 - 01 :50 0.83 STWHIP N DFAL WEXIT 01 :50 - 02:00 0.17 STWHIP N DFAL WEXIT 02:00 - 03:00 1.00 STWHIP N DFAL WEXIT 03:00 - 06:30 3.50 STWHIP N DFAL WEXIT 06:30 - 07:00 0.50 STWHIP N DFAL WEXIT 07:00 - 14:00 7.00 STWHIP N DFAL WEXIT 14:00 -16:15 2.25 STWHIP N DFAl WEXIT 16:15 - 16:45 0.50 STWHIP N DFAL WEXIT 16:45 - 18:30 1.75 STWHIP N DFAl WEXIT 18:30 -19:55 1.42 STWHIP P WEXIT 19:55 - 21:05 1.17 STWHIP P WEXIT 21 :05 - 23:25 2.33 STWHIP P WEXIT 23:25 - 00:00 0.58 STWHIP P 4/18/2003 00:00 - 01 :30 1.50 STWHIP P Page 2· bf8 Start: 4/14/2003 Rig Release: 4/24/2003 Rig Number: N2 Spud Date: 1/2/1988 End: 4/29/2003 [)ßsçriþtion..qf·Op$rati()ns Printed: 4/28/2003 9:16:54 AM ) ) BP EXPLORATION Opef~tiøn~ ·Suml'l'lªryReþort Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-31 C-31 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Page 30f8 Start: 4/14/2003 Rig Release: 4/24/2003 Rig Number: N2 Spud Date: 1/2/1988 End: 4/29/2003 Date From- TÒ H01.JFS <"-å$k Code NPT Desçriptionof Operations WEXIT tail 11457' and XN nip at 11445'. Correct +52'. With correction results this puts the TD of drilling at 12147'. Possible top of window at 12063' (initially thought to start miiling at 12011 ') Discuss options with town engineer. Decided best to pick-up GR and survey package. GR will see the 2 RA tags installed on whipstock if we have in fact exited the 4 1/2" liner plus give good tie-in data. Survey package to give inclination only of possible new hole drilled. Next BHA up will have GR to bit @ 12.51' and inclination to bit @ 13.36' TOOH UD jt of PH-6. P/U GR and survey package. Check mill, no significant wear pattern observed. Change out counter wheel on injector. Stab injector and surface test tools. RIH. (11914' E = 11905' M and BHA =39'). Log tie-in at 11908' - 11940' feature. Correct E depth (+3'). RIH and log across where whipstock was set. RA found at 12051' corrected depth (PE report showed RA at 12030' corrected CTM). This puts top of whipstock at 12046' and window 12047' - 12049'. WEXIT RIH and tag TD 12131', seeing a little higher inclination across whipstock area. PUH and dress window. Seeing some motor at 12045'. Ream and backream. Pump 50 bbl of 2.5 ppb bio pill. WEXIT Log and survey our 80' milling rathole. Tag TD and mill a couple of tenths to verify no grabby junk. WEXIT Ream and backream window area again. Again, seeing some MW or higher CTP from flow restriction at 12045' down and 12039' up. Work area some more. No change in CTP bump. Note: seeing slight separation in our in and out MM trend (about 5 BPH losses). RIH through window dry. Clean. Open circ sub. POOH at 2.2 BPM. LD milling BHA. MU drilling BHA: 2.3 deg motor; HCC 2.70" x 3.0" bicenter, PWD/DWOB. RIH. Log tie-in at 11908' GR marker. No correction. RIH wI HS TF. Tag 12050'. Try 30L. Tag same depth. With weight down, send TF command to go 30R. Skipped past this tag depth as soon as orienter started moving. Position TF highside. RIH and set down 12069'. PU. Try with pumps. MW 12063', then drill off, then stall at 12065'. RIH dry and tag 12067'. RIH dry 40L and 80L and tag same depth. Roll TF up while setting down and skip another foot downhole. PUH. RIH dry 30R and tag same 12067'. RIH 170R and tag same 12067'. All PU's are with overpull (up to 15k). PUH above window and swap to mud. RIH through window clean at 40L. Tag at same 12067'. PU. Work to 12069'. PU. Bring up pumps and slowly work to TD at 12131', with several stalls and several MW spikes with drill off. Backream slowly with HS TF to bottom of window. No motor work. Down ream 4/18/2003 00:00 - 01 :30 1.50 STWHIP P 01 :30 - 04:00 2.50 STWHIP P WEXIT 04:00 - 05:10 1.17 STWHIP P WEXIT 05:10 - 07:15 2.08 STWHIP P WEXIT 07:15 - 08:15 1.00 STWHIP P WEXIT 08:15 - 09:15 1.00 STWHIP P 09:15 - 09:30 0.25 STWHIP P 09:30 - 10:15 0.75 STWHIP P 10: 15 - 11 :45 1.50 STWHIP P WEXIT 11 :45 - 12:00 0.25 STWHIP P WEXIT 12:00 - 12:30 0.50 DRILL P PROD1 12:30 - 14:30 2.00 DRILL P PROD1 14:30 -14:45 0.25 DRILL P PROD1 14:45 -15:45 1.00 DRILL N DPRB PROD1 15:45 -16:45 1.00 DRILL N DPRB PROD1 16:45 - 17:45 1.00 DRILL N DPRB PROD1 17:45 - 18:00 0.25 DRILL N DPRB PROD1 Printed: 412812003 9:16:54 AM ) ) BP EXPLORATION Operations. Summary Røport . PageA of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-31 C-31 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/14/2003 Rig Release: 4/24/2003 Rig Number: N2 Spud Date: 1/2/1988 End: 4/29/2003 Date From - To Hours Task Code NPT Phase Descri ptionof Operations 4/18/2003 18:00 - 19:35 1.58 DRILL P PROD1 Drill build section from 12131'. Very fast ROP -- up to 230 FPH. 1.55bpm in/out 2950psi free-spin 1-200 psi MW 100'+/hr 1-2k wob drill to 12268'. 19:35 - 19:50 0.25 DRILL P PROD1 Wiper trip to 12055'. 19:50 - 20:55 1.08 DRILL P PROD1 Drill f/ 12268' to 12335'. 20:55 - 21 :30 0.58 DRILL N STUC PROD1 Work differentially stuck pipe. 21 :30 - 22:25 0.92 DRILL P PROD1 Wiper trip to tubing tail. Opened EDC while in 7". No problems through window. 22:25 - 00:00 1.58 DRILL P PROD1 Drill ahead with build section f/ 12335' to 12460' end of build section. No further sticking problems. 4/19/2003 00:00 - 02:45 2.75 DRILL P PROD1 TOH for lateral BHA. No problems through window area. EDC open circulating at 2 bpm. Setback injector. 02:45 - 03: 1 0 0.42 DRILL P PROD1 Change motor setting from 2.3 deg to 1.1 deg. Check bit -- 1:1 (must have been hole geometry that gave us all those stalls right outside the window, instead of metal/junk). Surface test tools. 03:10 - 05:10 2.00 DRILL P PROD1 TIH 05:10 - 05:20 0.17 DRILL P PROD1 Log tie-in to whipstock RA tag at 12051'. +1' correction. 05:20 - 05:30 0.17 DRILL P PROD1 RIH to bottom. 05:30 - 07:00 1.50 DRILL P PROD1 Drill f/ 12460' 1.5bpm in/out 2900psi free-spin 1-200psi MW + 1 OO'/hr with 1-2K wob. Seeing HOT in samples at 8960' SSTVD. Nose it up to target 8950' SSTVD. Drill to 12645'. Some stacking. 07:00 - 07:30 0.50 DRILL P PROD1 Wiper trip to window. Hole is smooth. 07:30 - 09:00 1.50 DRILL P PROD1 Drill to 12815'. Very good ROP even in "dirtier" GR. Getting close to polygon. 09:00 - 10:30 1.50 DRILL P PROD1 Wiper trip to 11450' (through horizontal in 7"). RIH. Clean thru window and open hole. 10:30 - 13:15 2.75 DRILL P PROD1 Drill. Ratty -- definitely out of the 2' sand that we found about 12725'. Medium grain samples in this sand package suggest upper 1A, so we don't want to come up any shallower. Nose down again. Never saw this thin sand again. Will have to nose it back up (new acceptable ceiling = 8945' SSTVD), and hopefully with dip going down away from us and a little luck of lateral variation in sand beds, we'll poke into a sand soon. We did, but don't know if it's 1A or 1 B. Drill with good ROP to 13000' 13:15 -14:10 0.92 DRILL N STUC PROD1 PU to start wiper trip to window. Diff stuck. Work pipe. Pump OH volume. SD pump. Let relax for 45 minutes. No movement. Orient: able to change TF. Pull to 60k. Circulate and orient -- popped free. 14:10 -15:00 0.83 DRILL P PROD1 Wiper to window. 15:00 - 16:15 1.25 DRILL P PROD1 Drill. Started with slow progress. In sand, but drill 5' then stack and significant overpull. Perform 200' wiper, then took off drilling with good slide again. Get LSRV back up to 35k. Drill to 13155'. 16:15 -17:15 1.00 DRILL P PROD1 Wiper to tubing tail, timing high vis pill for 7". 17:15 - 17:45 0.50 DRILL P PROD1 Log tie-in. Correct depth (+14'). 17:45 -18:15 0.50 DRILL P PROD1 RIH. 18:15-18:30 0.25 DRILL P PROD1 Drill f/ 13155' to 13219'. Stack. OP. PUH slowly during crew change out. Start RIH again and differentially stuck off bottom at 13120'. 18:30 - 22:40 4.17 DRILL N PROD1 Work pipe both in tension and negitive wt. Put in neutral wt and Printed: 4/28/2003 9: 16: 54 AM ) ) BP EXPLÖRATION . O:perations$ulJIl'I1a ryReport . Page 50fS Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 4/19/2003 4/20/2003 C-31 C-31 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/14/2003 Rig Release: 4/24/2003 Rig Number: N2 Spud Date: 1/2/1988 End: 4/29/2003 From ~ To Hours Task Code NPT Phase Description· of Operations 18:30 - 22:40 4.17 DRILL N PROD1 wait. Rotate orienter all this while witing on crude. 22:40 - 23:30 0.83 DRILL N PROD1 Take on 10 bbls crude to coil. Pump 5 bbls around BHA and let set..OIP @ 23:15. Free at 23:25. 23:30 - 00:00 0.50 DRILL N PROD1 Wiper trip several times from window to 3 1/2" tbg tail 00:00 - 01 :55 1.92 DRILL N STUC PROD1 Continue with wiper trip to TD. Short wiper back up to 13100' and stuck again at 13111'. 01:55-02:10 0.25 DRILL N STUC PROD1 Work stuck pipe....unstuck. 02: 1 0 - 02:20 0.17 DRILL N STUC PROD1 RIH to TD 02:20 - 02:45 0.42 DRILL P PROD1 Directionally drilling ahead f/13219'. Free-spin 3200psi 2-300psi motorwork. 11.18ppg ECD 1-2k wob 100'/hr. Drilled to 13236'. Very sticky. (called for new mud to be picked-up) 02:45 - 04: 1 0 1.42 DRILL N STUC PROD1 Making short wipers and getting stuck often. 13215' shutdown pump...wait. Pump 10 bbls oil. OIP at 0400 free at 0410hrs. 04:10 - 05:15 1.08 DRILL N STUC PROD1 Wiper trip back through to 13000'. Work back to bottom and stuck again at 13226'. Pump another 10 bbls crude, in place at 0500 free at 0510. 05: 15 - 06:30 1.25 DRILL N STUC PROD1 Wiper trip and swapping to new Flo-Pro mud. NOTE: Drill solids of old mud at 0.4 %. Also, note that total bbls lost to formation yesterday estimated at 16 bbls. 06:30 - 06:35 0.08 DRILL N STUC PROD1 RIH to start drilling. Differential grab and OP at 13068'. 06:35 - 06:40 0.08 DRILL P PROD1 SPECIAL NOTE FOR PERF INTERVAL DISCUSSIONS: While the interval between 13050' - 13150' looks a little dirty on the GR and the ROP curve is all over the place, we think this is a very high quality and continuous sand interval. Drilling was characterized by very fast (>250 FPH) beach sand type drilling with significant differential sticking -- that is, drill fast for 10' ish then differentially stuck with signifcant overpull. Also, we've planted ourselves here several times, even well after the interval was drilled. 06:40 - 07:45 1.08 DRILL P PROD1 Drill to 13390'. Good ROP and minimal differential sticking (new mud? lithology change?). 07:45 - 08:45 1.00 DRILL P PROD1 Wiper to window. Very smooth hole, nothing tried to grab us. 08:45 - 10:15 1.50 DRILL P PROD1 Drilling slower from 13390'. Drilling a double-wrap hot shaley section for about 80', then ROP (up to 280 FPH) suggests we jumped back into a sand. Drill to 13530'. LSRV = 42k. 10:15 - 12:00 1.75 DRILL P PROD1 Wiper to tubing tail, timing high vis pill for 7". Hole in good shape. 12:00 - 13:15 1.25 DRILL P PROD1 Drill. Have about 450' of Z1 A and 60' of Z2B so far. Plan now is to stay flat for another 40' of Z1 B and then nose it down slightly at 89 deg. This will likely take us up section if the 3 deg dip is accurate, but we prefer that over getting back into that last shale. Drill to 13610' with lots of stacking, diff sticking, and overpulls in the sand. Finally grabbed us for good at this depth. 13:15 -14:15 1.00 DRILL N STUC PROD1 Stuck. Let relax for 20 minutes. Workpipe. No go. Pump 5 bbls crude, put about 1/2 this out bit and pull free. Do a 200' wiper. 14:15 - 15:15 1.00 DRILL N STUC PROD1 Drill to 13620'. Stack. PU. OP. Popped free. PUH smooth to 13600'. When BHA stopped momentarily before running back in the hole, it got differentially stuck again. Workpipe, let relax. Nope. Pump 5 bbls crude. Pulled free. 15:15 -16:30 1.25 DRILL N STUC PROD1 Wiper trip to window. Mud still at 42k. 16:30 - 22:00 5.50 DRILL N STUC PROD1 Drill for 5 minutes to 13645' at high ROP. Try to catch the drill Printed 4/28/2003 9:16:54 AM ) ) sF> EXPLORATION Oþerélti()nsSurnmaryRe port Page 6 of 8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-31 C-31 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/14/2003 Rig Release: 4/24/2003 Rig Number: N2 Spud Date: 1/2/1988 End: 4/29/2003 Date· From-To Hours Task Code NPT Phase· Description of Operations 4/20/2003 16:30 - 22:00 5.50 DRILL N STUC PROD1 off, but couldn't. Stuck again. Pump another 5 bbls crude. Drill for another 2 minutes and 5' to 13650'. Stack. PU. Free, but grabbed us 20' off bottom while PUH at 40 FPM. Pump another 5 bbls crude. Free. Drill to 13651' with some motor work. Motor work came down and stacked very little weight.. .pick-up stuck at 13635'. Pump down 25 bbls crude. 1 bbl out to formation..set..free..drill ahead to 13672'. Motor work failed off and stacked out even with oil coming around BHA. Pick-up 50' but unable to run to bottom. Slow pump to 1 bpm and work back to bottom then stuck when 1 bbl of mud came around BHA. Pulled free then stuck again at 13625'. Pump 5 bbls oil..no dice this time. Pump 15bbl oil came free. Working to clean-up hole. (called to town and advised them of deteriorating hole conditions. Agreed to call 13673' TD). 22:00 - 00:00 2.00 DRILL P PROD1 Circulate and condition hole for liner. Wiper trip back to window and tie-in. 4/21/2003 00:00 - 03:30 3.50 DRILL P PROD1 Wiper trip and condtion hole. Tie-in to RA tags on whipstock +24' correction. RIH at 1.0bpm 5k down wt. tagged TD at 13688'. Increase pump to 1.6bpm wipe up 29K string wt. to window - looks good. RIH no problems come out laying in new 80K LSRV mud 1: 1 03:30 - 06:45 3.25 DRILL P PROD1 Increase to 1.7bpm at window and TOH for liner. 06:45 - 07:30 0.75 DRILL P PROD1 RIH to 1000' and displace top of hole with water for liner running. 07:30 - 08:00 0.50 DRILL P PROD1 LD drilling BHA. Bit 1-2 (one chip on back cutter). 08:00 - 09:30 1.50 CASE P CaMP Reverse coil with drill water for slack management and FP coil with 60/40 MeOH. 09:30 - 10:00 0.50 CASE P CaMP PJSM. 10:00 - 11 :00 1.00 CASE P CaMP Unstab coil, secure to reel. 11 :00 - 11 :30 0.50 CASE P CaMP RU to run liner. 11 :30 - 12:00 0.50 CASE P CaMP PJSM 12:00 - 12:30 0.50 CASE P CaMP Bring Baker tools to floor. RU CSH drifting BHA to tugger for drifting all MU connections. 12:30 - 17:30 5.00 CASE P CaMP MU liner to 600 ft-Ibs. Had to lay down #4 -- would not drift after MU. Lower MU torque to 500 ft-Ibs. Same time swap out 2" E-line reel for cementing reel. 17:30 - 20:20 2.83 CASE P CaMP Stab coil to injector. Weld-on SLB CTC. (check ID with coil wiper dart aD). Finish installing inner reel hardline. Pull test CTC to 30K. Install dart catcher. 20:20 - 21 :45 1.42 CASE P CaMP Pump 1 coil volume to clear meth. Pump around coil wiper dart. Volume = 42.0 bbls 21 :45 - 00:00 2.25 CASE P CaMP MU injector to 2.375" CTLRT and RIH 4/22/2003 00:00 - 01 :40 1.67 CASE P CaMP Continue RIH with 2.375" 4.6# L-80 STL liner. Weight check at window 38k up, 12k dwn. RIH. Setdown at 13280'. Pickup good..work past 5k RIH wt. .. setdowns at 13444, 13465' then on to TD at 13688'. 01:40 - 02:55 1.25 CASE P CaMP Load and pump 0.625" steel ball. On seat at 35.2 bbls away. CTLRT release at 4450 psi. bleed-off, pick-up 25k and confirm liner release. Setdown -10k. 02:55 - 04:45 1.83 CASE P CaMP Swap hole to 2% KCL same time hold PJSM and plan forward with all crews covering cement job. High oil content in returned mud - not saved. 04:45 - 06:30 1.75 CEMT P CaMP Batch mix cement. Pump 5 bbl H20, PT lines to 4K. Pump 17 Printed: 4/28/2003 9:16:54 AM ) ) SPËXPLORATION Operations SummélryReport Page Tof8 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-31 C-31 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 4/14/2003 Rig Release: 4/24/2003 Rig Number: N2 Spud Date: 1/2/1988 End: 4/29/2003 Date From-To Hours Task Code NPT Phase Description of Operations 4/22/2003 04:45 - 06:30 1.75 CEMT P COMP bbls of 15.8ppg cement. Load coil wiper dart (clear cement lines back to DS) launch dart and confirm. Displace w/ 20 bbl 2#bio followed by KCL, coil dart landed as expected released LWD at 3600 psi. Continue displacement and LWD landed as expected. CIP @ 0630hrs. 06:30 - 09:20 2.83 CEMT P COMP TOH laying in 2# bio from top of liner to +/-10200' TOH at reduced pump rates. (Called AOGCC for BOP test. Witnessing wavied by Jeff Jones) 09:20 - 09:45 0.42 CEMT P COMP LID Baker liner running equipment. 09:45 - 13:30 3.75 BOPSURP COMP Weekly BOP test. 3500psi high 250psi low 5 min/ea inner/outer stack & HCR valves, Upper/Lower pipe slips rams, Blinds, Choke manifold valves. 2500 high on Annular. Check pre-charge on Koomey bottles and perform accumulator drawdown test. 13:30 - 13:45 0.25 CLEAN P COMP PJSM on handling 1" BHA 13:45 - 16:30 2.75 CLEAN P COMP P/U cleanout BHA 16:30 - 19:10 2.67 CLEAN P COMP RIH Clean down thru liner. Tagged up at 13672' CTM. (Should be 13675', pretty darn close) 19:10 - 21 :05 1.92 CLEAN P COMP POH, PU clean off bottom at 28 klbs. SWS cementers report that cement is up to 2300 psi compressive strength at 19:00 hours. OAP=32 psi, IAP=640 psi. 21 :05 - 21 :25 0.33 CLEAN P COMP Safety meeting prior to POH with CS hydril. 21 :25 - 22:20 0.92 CLEAN P COMP Tag up with CTC. Unstab injector, break Baker swivel, drop 1/2" ball to open Csub. Stab back on pump ball on seat. Unstab again. Make up safety joint for CSH. 22:20 - 23:30 1.17 CLEAN P COMP Layout 1 single, stand back 36 stds of 1" CSH work string, lay down milling BHA. 23:30 - 23:50 0.33 EVAL P COMP Safety meeting prior to picking up logging BHA. 23:50 - 00:00 0.17 EVAL P COMP Pick up SWS GR-CCL logging tool and CS hydril work string. 4/23/2003 00:00 - 01 :45 1.75 EVAL P COMP Continue picking up 1" CS hydril work string. Ran back in with same pipe string as previous run. 76 jts/38 stands of CS hydril. 01 :45 - 03:40 1.92 EVAL P COMP Make up coil injector, RIH with logging tools on coil tubing. 03:40 - 04:20 0.67 EVAL P COMP Log down from 11150' at 60 fpm. Pumping 25 bbls of perf pill at minimum rate to displace to end of coil. 04:20 - 05:45 1.42 EVAL P COMP Tag up at 13673', finish circulating perf pill to end of coil, then PUH logging at 60 fpm. Pause and paint flags at 13600' and 11200' bit depth. 05:45 - 08:35 2.83 EVAL P COMP TOH w/ logging tools to top of 1" CSH. Stand back 1". Stand back 1" to log tools. PJSM and laydown Gr/CCL. Gr/CCL shows top of liner at 11366' and PBTD 13674' 08:35 - 09:25 0.83 EVAL P COMP Test liner lap 2000psi/30 min. Good test 100psi leak-off. 09:25 - 09:40 0.25 PERF P COMP PJSM review procedures and hazards of picking up perf guns. 09:40 - 13:40 4.00 PERF P COMP P/U 984' (675' net) of 1 11/16" HSD 4spf 1606PJ perf guns an 24 stds 1" CSH 13:40 - 16:10 2.50 PERF P COMP TIH tagged PBTD at 13674'. 16:10 - 16:35 0.42 PERF P COMP Load and launch 0.500" steel ball followed by 1 bbl of 150k Flo-vis then 35bbl KCL. Ball on seat p/u slowly and fire guns with 3k psi. Continue TOH. Good indications that guns fired. Lost circulation. Regained after loosing 3 bbls to formation. Perf zones 4spf: 13670'-13480', 13355'-12930', 12760'-12700' 16:35 - 18:45 2.17 PERF P COMP TOH with perf guns. 18:45 - 19:05 0.33 PERF P COMP Tag up at surface with CTC. PJSM prior to tripping out CS hydril and guns. Discuss hazards and mitigation. Printed: 4/28/2003 9:16:54 AM I) ) BP EXPLORATION Qperéltions Sunil'11ary·· Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 4/23/2003 4/24/2003 C-31 C-31 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 From - To Hours Task Code NPT. Phase 19:05 - 23:10 4.08 PERF P CaMP 23:10 - 23:30 0.33 WHSUR P CaMP 23:30 - 00:00 0.50 WHSUR P CaMP 00:00 - 00:30 0.50 WHSUR P CaMP 00:30 - 01 :00 0.50 WHSUR P CaMP 01 :00 - 02:00 1.00 WHSUR P CaMP 02:00 - 04:00 2.00 RIGD P POST 04:00 - 04:45 0.75 RIGD P POST 04:45 - 06:00 1.25 RIGD P POST 06:00 - 07:30 1.50 RIGD P POST Page 8 of 8 Start: 4/14/2003 Rig Release: 4/24/2003 Rig Number: N2 Spud Date: 1/2/1988 End: 4/29/2003 Descri ptionof Operations Stand back CSH and lay down perf guns. All guns recovered. All shots fired, all guns fired. Pickup swizzel stick nozzle to wash stack, and FP well. RIH to FP well. RIH, wash stack, continue to RIH to FP well. On line with 60/40 meth water to FP. Stop at 2000'. Lay in methanol from 2000' to surface. Tag up at surface, stand back and secure injector. SI master and swab valves. Unstab coil from injector. Secure coil on reel. Clean pits and cuttings box. Prepare coil for .Iowering out of reel house. Lower reel to Peak flatbed for transport to F-45. Continue with rig down. Prep cuttings box for transport to peak yard. Nipple down stack, remove cuttings box with Veco bed truck, clean remainder of old spill under tank with Alaska Clean Seas crew. Continue RD. Nipple up tree cap and test to 3500 psi. Rig released at 0730 hrs 4-24-2003 PJSM with crews and Security for rig move to F-45. Printed: 4/28/2003 9: 16:54 AM ) ) 0103 --ccf5" II.. BAKU HUGIIIS INTEQ ObP BP Baker Hughes INTEQ Survey Report Company: BP. Amoco Field: PrudhO~ Bay Site: PB C Pad Well: C-31 Wellpath: C-31 B Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Site: PB C Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft Date: 5/19/2003 Time: 15:29:42 Page: Co-ordlnate(NE) Reference: Well: C-31 , True North Vertical (TVD) Reference: 38 : 31 2/10/1995 00:00 72.1 Section (VS) Reference: Well (0.00N,O.00E,262.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 5957218.72 ft 662550.03 ft Latitude: Longitude: North Reference: Grid Convergence: 70 17 22.367 N 148 41 2.797 W True 1.24 deg Well: C-31 Slot Name: 31 C-31 Well Position: +N/-S 2160.62 ft Northing: 5959422.03 ft Latitude: 70 17 43.614 N +E/-W 2005.20 ft Easting : 664507.91 ft Longitude: 148 40 4.353 W Position Uncertainty: 0.00 ft Height 72.13 ft Wellpath: C-31 B 500292177502 Current Datum: 38 : 31 2/10/1995 00:00 Magnetic Data: 4/10/2003 Field Strength: 57542 nT Vertical Section: Depth From (TVD) ft 0.00 Survey Program for Definitive Wellpath Date: 5/19/2003 Validated: Yes Actual From To Survey ft ft 51.23 10011.00 10011.00 12046.00 12046.00 13688.00 1 : Schlumberger GCT multishot 2 : MWD - Standard (1) MWD Annotation MD TVD ft ft 12046.00 9014.53 KOP 13688.00 9022.39 TO Survey: MWD Company: Baker Hughes INTEQ Tool: MWD,MWD - Standard Survey MD Incl Azlm TVD SSTVD ft deg deg ft ft 12046.00 89.62 155.32 9014.53 8942.40 12116.28 91.96 158.39 9013.56 8941 .43 12151.61 95.37 159.55 9011.30 8939.17 12186.31 95.59 162.69 9007.99 8935.86 12230.36 87.12 173.77 9006.95 8934.82 12260.88 85.09 185.86 9009.03 8936.90 12292.85 81.72 193.84 9012.70 8940.57 12324.33 79.24 205.18 9017.93 8945.80 12358.19 83.73 207.97 9022.94 8950.81 12390.00 84.88 215.11 9026.10 8953.97 12421.19 86.23 224.71 9028.52 8956.39 +N/-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 C-31 A 12046.00 ft Mean Sea Level 25.89 deg 80.82 deg Direction deg 262.00 RECEIVED ^ t'l 2 r; 000.4 ~J '\ .. .:.. (.. 4- Version: 2 Toolcode Tool Name Alaska Oil & Gas Cons.Coll1flÛf$lb1 Ñ'iA\MtJJr.& Schlumberger GCT multishotVlMII~Y MWD - Standard MWD - Standard GCT-MS MWD MWD Start Date: 4/21/2003 Engineer: Tied-to: From: Definitive Path N/S E/W MapN MapE VS DLS ft ft ft ft ft deg/10OO -1865.20 6259.17 5957694.40 670805.97 -5938.67 0.00 -1929.81 6286.78 5957630.42 670834.99 -5957.02 5.49 -1962.71 6299.44 5957597.80 670848.36 -5964.97 10.19 -1995.39 6310.61 5957565.38 670860.25 -5971.49 9.03 -2038.39 6319.56 5957522.58 670870.14 -5974.37 31.64 -2068.79 6319.67 5957492.20 670870.91 -5970.24 40.08 -2100.05 6314.25 5957460.83 670866.17 -5960.53 26.94 -2129.26 6303.91 5957431.40 670856.47 -5946.22 36.39 -2159.20 6288.93 5957401.14 670842.15 -5927.22 15.56 -2186.16 6272.38 5957373.83 670826.20 -5907.08 22.63 -2209.98 6252.45 5957349.58 670806.80 -5884.03 30.99 ) BP ) .íi. ObP 8AD1t HUGHES Baker Hughes INTEQ Survey Report tN'T EQ Company: BP Amoco Date: 5/19/2003 Time: 15:29:42 Page: 2 Field: Prudhoe. Bay Co-ordinate(NE) Reference: Well: C-31 , True North Site: PB C Pad Vertical (TVD) Reference: 38 : 312/10/1995 00:0072.1 Well: C-31 Section (VS) Reference: Well (0.00N,0.00E,262.00Azi) Wellpath: C-31 B Survey Calculation Method: Minimum Curvature Db: Oracle Survey MD Incl Azim TVD SSTVD N/S E/W MapN MapE VS DLS ft deg deg ft ft ft ft ft ft ft deg/10OO 12455.79 87.36 233.00 9030.46 8958.33 -2232.69 6226.46 5957326.31 670781.31 -5855.13 24.14 12488.38 89.69 240.92 9031.30 8959.17 -2250.43 6199.17 5957307.97 670754.42 -5825.64 25.32 12521.55 90.49 244.96 9031.25 8959.12 -2265.52 6169.64 5957292.24 670725.23 -5794.30 12.42 12549.68 91.66 250.76 9030.72 8958.59 -2276.11 6143.60 5957281.08 670699.43 -5767.04 21.03 12582.38 94.89 258.38 9028.85 8956.72 -2284.80 6112.16 5957271.72 670668.19 -5734.69 25.27 12615.22 93.78 263.66 9026.37 8954.24 -2289.90 6079.82 5957265.90 670635.98 -5701.96 16.38 12645.66 92.58 269.39 9024.68 8952.55 -2291.75 6049.50 5957263.40 670605.70 -5671.68 19.20 12684.66 92.64 261.71 9022.90 8950.77 -2294.77 6010.69 5957259.53 670566.97 -5632.82 19.67 12717.62 90.25 258.77 9022.07 8949.94 -2300.35 5978.22 5957253.23 670534.63 -5599.89 11 .49 12754.04 90.06 253.80 9021.97 8949.84 -2308.98 5942.85 5957243.83 670499.46 -5563.67 13.66 12784.39 90.06 244.38 9021.94 8949.81 -2319.80 5914.53 5957232.39 670471.39 -5534.12 31.04 12815.50 90.67 247.30 9021.74 8949.61 -2332.53 5886.15 5957219.05 670443.29 -5504.24 9.59 12846.35 88.25 250.11 9022.03 8949.90 -2343.74 5857.41 5957207.22 670414.81 -5474.22 12.02 12879.13 87.64 253.81 9023.20 8951.07 -2353.88 5826.27 5957196.40 670383.90 -5441.97 11 .43 12913.03 91.38 260.90 9023.49 8951.36 -2361.29 5793.22 5957188.26 670351.02 -5408.21 23.64 12955.60 90.43 268.98 9022.82 8950.69 -2365.04 5750.86 5957183.59 670308.75 -5365.74 19.11 12994.09 90.71 278.08 9022.44 8950.31 -2362.68 5712.48 5957185.11 670270.34 -5328.07 23.65 13030.77 89.48 284.85 9022.38 8950.25 -2355.39 5676.56 5957191.61 670234.27 -5293.50 18.76 13066.66 89.82 292.98 9022.60 8950.47 -2343.77 5642.63 5957202.49 670200.10 -5261.53 22.67 13101.42 89.42 300.55 9022.83 8950.70 -2328.12 5611.62 5957217.45 670168.75 -5233.00 21.81 13146.17 89.11 307.01 9023.40 8951.27 -2303.26 5574.45 5957241.49 670131.05 -5199.65 14.45 13181.99 90.12 314.76 9023.64 8951.51 -2279.83 5547.39 5957264.32 670103.48 -5176.11 21.82 13209.94 90.52 31 0.44 9023.49 8951.36 -2260.92 5526.82 5957282.78 670082.51 -5158.37 15.52 13249.87 91.90 302.26 9022.64 8950.51 -2237.27 5494.70 5957305.71 670049.88 -5129.85 20.77 13284.79 88.87 298.47 9022.41 8950.28 -2219.63 5464.58 5957322.69 670019.38 -5102.48 13.89 13316.65 89.02 292.07 9022.99 8950.86 -2206.04 5435.78 5957335.65 669990.30 -5075.86 20.09 13360.46 89.76 284.11 9023.46 8951.33 -2192.45 5394.18 5957348.32 669948.41 -5036.55 18.25 13393.85 90.00 279.66 9023.53 8951.40 -2185.57 5361.51 5957354.48 669915.60 -5005.16 13.35 13428.22 89.72 273.50 9023.62 8951.49 -2181.63 5327.38 5957357.67 669881.40 -4971.91 17.94 13471.06 92.52 267.03 9022.78 8950.65 -2181.44 5284.58 5957356.93 669838.60 -4929.55 16.45 13517.54 92.76 263.90 9020.64 8948.51 -2185.11 5238.30 5957352.25 669792.42 -4883.21 6.75 13554.31 90.31 269.92 9019.65 8947.52 -2187.08 5201.62 5957349.47 669755.79 -4846.61 17.67 13591.27 89.08 277.31 9019.85 8947.72 -2184.76 5164.76 5957350.99 669718.89 -4810.43 20.27 13628.76 88.35 286.36 9020.69 8948.56 -2177.08 5128.11 5957357.86 669682.09 -4775.21 24.21 13688.00 88.35 286.36 9022.39 8950.26 -2160.40 5071.29 5957373.29 669624.92 -4721.27 0.00 BP Amoco Parent Wellpath: Tie on MD: Rig: Ref. Datum: V.Sectlon Angle 262.00' WELLPATH DETAILS C-31B 500292171502 C·31A 12046.00 Nordic 2 38: 31 2/10/199500:00 72.13ft Origin +N/-S 0.00 Origin Starting +EJ-W From TVD 0.00 0.00 REFERENCE INFORMATION Co-ordinate (N/E¡ Reference: Well Centre: C-31, True North Vertical (NO Reference: System: Mean Sea Level Section (VS Reference: Slot - 31 (O.OON,O.DOE) Measured Depth Reference: 38: 31 2/10/199500:00 72.13 Calculation Method: Minimum Curvature ANNOTATIONS TVD MD Annotation 8942.40 12046.00 KOP 8950.26 13688.00 TO ..,'" ...... 000 -2œ59oC 4111.89 Pdr!µ'I 000 .1866e.c 61)3.13 Pci'tgon 000 -254362 51U32 På)"p'I æ~ ~~ iilift ~ Inr' 8350 8400 8450 8500 ë8550 ¡. ~ 8600 . It) :;;8650 I .. . ts700 ~ Q _8750 ca U " :e 8800 G.Þ " >8850 G.Þ 28900 -. . .. . : ~)_C,:1 (C-31A)1 8950, - . .~7-~~C 9000, ~ 9050 Obp Bi. B". INTEQ Direct: (907) 267·6613 E ·mail: brij.potniS@inteQ.com Baker Hughes INTEO: (907) 267·6600 T AM é LEGEND C-31.C-31B,Plan #8 C-31 (C-31) C-31 (C-31A) C-31B Wellpath: (C-31/C-31 B) Azimuths to True North Magnetic North: 25.89· Stre~~~~~~<J~~~ Dip Angle: 80.82· Date: 4(10(2003 Model: BGGM2002 /;~'~~.::"'=----- ;:~~~;-\ ~-~-0~ ',' ,Or" -~~.-.-- ~.<:~ ;::::~-- '-~ ~-~-:.:-: ~~ ~<-~:'::< ;--: ~:~ ~{;;.}:~~~ Created By: Brij Patois Date: 5/19/2003 Contact Information: -1200 +-~:...:~;-:-: -1300- r:.:...: ::.-::" -. -: ::_:::-:--:~: :." -1400-+:-~':"':":'~--"' ._ . . ::":.::;=----- . ë-160o-t:: æ-1700'~~~--:-:~'::T' 'F-::=: o :::. . ..... o -1800-::t--;---=:::~-:' ... -; - _1900-=¡-~-: . + J'" f-2000l--~- :::---:-;~~- :-': . ~- .~. .: ~: -.- ~ -2100 ~ m ;m ::~--=~=_ ~ ~ --2200-t fi 3 :: -. : : . : ::":: ~:.:..:: . . - 8 -2300-3 .:..:..:.....:....:;~: :-:~:...:.::.:_-~..::--:---;_:. en J: . . ." -2400-3~:' . -~"-:--:: . - --.--- ~ [ 4200 4300 4400 45'00 46'00 4700 4800 4900 50'00 51'00 5200 5300 5400 55'00 5600 5700 5800 5900 6000 6100 6200 6300 West(-)/East(+) [100ft/in] ------- ----~~--- -¡ ] I 1¡-¡-:- :--'-""""7 i-~-- 7 Î--;-~-í, '-;-""': . _-4_-'~-"7"~-;'--'~"'-----;---:-'-;",-:--:-~~-~.---:¡~ i; I, J , ~'~--r-~:----;--:~~~:.!~:--:,;;~ -6200 -6150 -61 00 -6050 -6000 -5950 -5900 -5850 -5800 -5750 -5700 -5650 -5600 -5550 -5500 -5450 -5400 -5350 -5300 -5250 -5200 -5150 -51 00 -5050 -5000 -4950 -4900 -4850 -4800 -4750 -4700 -4650 -4600 -4550 -4500 -4450 -4400 -4350 -4300 -4250 Vertical Section at 262.00° [50ft/in] 9100 5/19/2003 3:28 PM .- .---- (~~ -" I~ \ t.··.J -~ ~> fn1 ___:1 (-::7,", ') ,~ ç J ~~~~~~!Æ ) /. FRANK H. MURKOWSKI, GOVERNOR / 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 ~,... ALASK& OIL AND GAS CONSERVATION COMMISSION Alistair Sherwood CT Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Unit C-31 B BP Exploration (Alaska) Inc. Permit No: 203-008 Surface Location: 1800' SNL, 883' WEL, SEC. 19, T11N, RI4E, UM Bottomhole Location: 3837' SNL, 3947' WEL, SEC. 20, TI1N, RI4E, UM Dear Mr. Sherwood: Enclosed is the approved application for permit to redrill the above development well. This permit to redrill does not exelnpt you fr01TI obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations n1ust be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Comlnission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty-four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~?~ Michael L. Bill Commissioner BY ORDER OF THE COMMISSION DATED this l7~day of January, 2003 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Hole 3" ') STATE OF ALASKA ) ALASK1'\ ~IL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test 181 Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (DF or KB) 10. Field and Pool KBE = 72.13' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028305 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number /'- C-31 B 9. Approximate spud da~' 02105/03 Amount $200,000.00 14. Number of acres in property 15. Proposed depth (MD and TVD) 2560 13800' MD I 8960' TVDss o 17. Anticipated pressure {see 20 AAC 25.035 (e) (2)} 90 Maximum surface 2280 psig, At total depth (TVD) 8800' / 3220 psig Setting Depth TaD Bottom Quantitv of Cement Lenath MD TVD MD TVD (include staae data) 2450' 11350' 8774' 13800' 8960' 112 cu ft Class 'G' ít...1 (, A- ; I L--L-J 0-; 1 a. Type of work 0 Drill 181 Redrill ORe-Entry 0 Deepen 2. Name of Operator BP Exploration (Alaska) Inc. 3. Address P.O. Box 196612, Anchorage, Alaska 99519-6612 4. Location of well at surface 1800' SNL, 883' WEL, SEC. 19, T11 N, R14E, UM At top of productive interval 3335' SNL, 5203' EWL, SEC. 20, T11 N, R14E, UM At total depth 3837' SNL, 3947' EWL, SEC. 20, T11 N, R14E, UM 12. Distance to nearest property line 13. Distance to nearest well 1,/ ADL 028306,1333' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 12025' MD Maximum Hole Angle 18. Casin~ Program Specifications Size Casina Weiaht Grade Couplina 2-3/8" 4.7# L-80 ST-L 11. Type Bond (See 20 AAC 25.025) Number 2S100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical 'R.~'·"· '~"" C·' '1\". "".' 1 V" 1: ~. \\ '(- 11,... ¡. \~ J .t¡,. ,'... W"" ,~L," ¡¡.. Casing 13535 feet 8994 feet 13494 feet 8995 feet Length Plugs (measured) Baker IBP at 13020' (04/96~1\ hI ~\ :'~ 2,OOj Junk (measured) Baker I BP pushe~\~s~fJÏfl[11&~æ~~;(~~4~§¡¡(Oai9$) ¡3',f¡f;nU¡ Cemented MD TVD Size Structural Conductor Surface Intermediate Production Liner Liner 139' 20" 8 cu yds Concrete 139' 139' 2796' 13-3/8" 3900 cu ft Permafrost 2825' 2720' 9977' 9-5/8" 2335 cu ft Class 'G' 10006' 7597' 2082' 7" 416 cu ft Class 'G' 9860' - 11942' 7481' - 9014' 1633' 4-1/2" 309 cu ft Class 'G' 11902' - 13535' 9013' - 8994' Perforation depth: measured 11800' - 11850', 12038' - 12128', 12145' - 12195', 12355' - 12405', 12435' - 12620', 12645'- 12885', 13055' - 13155', 13190' - 13490' true vertical 8999' - 8995' (8 Intervals) 20. Attachments 181 Filing Fee 0 Property Plat 181 BOP Sketch 0 Diverter Sketch 181 Drilling Program 181 Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis 0 Seabed Report 181 20 AAC 25.050 Requirements Contact Engineer Name/Number: Alistair Sherwood, 564-4378 Prepared By Name/Number: Terrie Hubble, 564-4628 - 21. Is~:~::Y ~i:;' :~::: ro~~~l~;:;t to the b;::eof~; ~~~:;~~:ineer , .. ...'.. »: . ... <'CorolJljssion UseO"ly" Permit Number API Number APprL,I'{~l?t~ See cover letter .z 03 - c c ? 50- 029-21775-02 I 7" I V' I) for other requirements Conditions of Approval: Samples Required 0 Yes g] No Mud Log R quir d ,,' 0 Yes 181 No Hydrogen Sulfide Measures ~ Yes 0 No Directional Survey Required ~ Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: 'Téi5RI~fJAt[ SÎ8N~qN r)s. ¡' · by order of M L, Bill CQmmissioner the commission "~I ,/ .' ~\ i '., ,'"'. ~ il 'I L".. Date r>!rrf!o;, Approved By Form 10-401 Rev. 12-01-85 Date 1)01/O·?J sJbmit In Triplicate .. ù ¡¡ ) BP C-31 B CTD Sidetrack ') Summary of Operations: / A slim hole (3" OH size) CTD, through tubing sidetrack is planned for C-31A. The sidetrack, C-31 B, will exit the 4%" liner in the Ivishak Z1 A formation and target said formation. .,./ Phase 1, Well preparation: 1%" service coil will set an inflatable bridge plug at -12,200' to isolate 825' of the 965' of open perforations. Service coil may then set a 3Y2 x 4%" thru tubing whipstock, above the remaining open perfs at 12,025' - Note, due to the length of the setting BHA, this operation may be left to the rig to do. ,./'/ Phase 2, CrD Operations: Nordic 2 CTD rig will MIRU, mill a window in the 4%" liner and drill -1780' of 3" open hole. This will be completed with 2%" solid & cemented liner which will be selectively perforated.: Nordic 2 will most likely arrive on C-pad on the 5th Feb 03. Mud Program: Plan to mill the window with viscosified seawater, a 2% KCI w/ %-2ppb Biozan system. If losses to the open perforations become an issue then this system will be swapped to Flo-Pro to suppress the losses. Thereafter the formation will be drilled with an 8.6ppg solids free Flo-Pro system. ".., Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: / The production liner will be solid 2%",4.7#, L80, ST-L pipe run from TD, (13,800'md) to~p ,fO)<. 11 ,350'md (-8774'tvd ss). The liner will be cemented in place to hydraulically isolate the formation with approx 0 61s of Class G Latex cement. The plan is to bring the cement top - 375' above the window, 300' below the Ii top. Well Control: · BOP diagram is attached. /' · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan, (C31 B Plan #5). Max. planned hole angle is 90°. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging 1 Real time MWD & Gamma Ray logs will be run over all of the open hole section. No cased hole logging is planned. Hazards · H2S on C-31 a has not been measured. Max recorded H2S on C pad is 10ppm (C-26 & C-27, 10/00) /' · One fault crossing is anticipated, the risk of lost circulation is low to moderate. Reservoir Pressure Res. press. is estimated to be 3220 psi at -8800'ss (7.03 ppg emw). Max. surface pressure with gas (0.12 psi/ft) to surface is 2280 psi. / TREE ~ 6" crvv WELLHEAD = McEVOY ACTUA TOR=" '" '''6iïÄ5d~LsÖN J<'ff""E[E\i";" .... ..... .... ..........·..'67'~·äí' BF:'ELéJ;······,W,,......,.,. ""·"""'37:3; KOP = 1700' ..~~.~...~~~í~..~.,..: ,...,"""'~~,.~....~.~~?,~~, Datum MD = 11472' Datum 1VD = 8800' ') C-31A SP-) NOTES: WELL ANGLE> 70 deg @ 11730' & > 90 deg @12024'. RAN 2ND 7" X 4-1/2" BKR LNR TOP PKR & SET @ 11884' TO ISOLATE 7" FLOAT COLLAR. COULD NOT GET TEST ON 7" LNR PREV IOUSL Y DURING SDTRK OPS. PERFORA TION SUMMARY REF LOG: MWD GRJRES SÆRRY SUN 02/16/95 ANGLE AT TOP PERF: 75 @ 11800' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11800 - 11850 0 03/25/02 2-1/2" 4 12038 - 12128 0 03/23/96 2" 6 12145 - 12195 0 03/25/02 2" 6 12355 - 12405 0 03/25/02 2-3/4" 4 12435 - 12620 0 02/26/95 2-3/4" 4 12645 - 12885 0 02/26/95 2-3/4" 4 13055 - 13155 C 04/27/96 2-3/4" 4 13190 - 13490 C 04/27/96 4-1/2" LNR, 12.6#, L-80, .0152 bpf, ID = 3.958" 1-1 13535' DA TE REV BY COMMENTS 03/25/02 KSB/KK ADPERFS 13-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2825' ~ Minimum ID = 2.75" @ 2115' 3-1/2" OTIS SSSV NIP 7" BKR PKR TIEBACK SLEEVE, ID = 7.50" 1-1 9860' 1 ~ I 9-5/8" X 7" BKR H PKR, ID = 6.187" 1-1 9867' ~ 9-5/8" X 7" BKR HMC LNR HGR, ID = 6.250" 1-1 9873' 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 10006' J- 3-1/2" TBG, 9.3#, N-80, .0087 bpf, ID = 2.992" 1-1 11456' 1 7" X 4-1/2" BKR H LNR TOP PKR, ID= 4.44" 1-1 11884' TOP OF BKR TIEBACK SLEEVE, ID = 6.28" 1-1 11902' 7" x 4-1/2" BKR PKRI LNR HGR, ID = 4.44" 1-1 11910' 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" 1-1 11942' DATE 02/22/88 03/11/95 02/05/01 03/09/01 10102/01 REV BY COMMENTS ORIGINAL COMPLETION RIG SIDETRACK ( DOYON 14) CONVERTED TO CANVAS FINAL CORRECTIONS SIS-151 SIS-LG RNlTP - 2115' 1-1 3-1/2" OTIS SSSV LAND. NIP, ID=2.75" 1 ~ GAS LIFT MANDRELS ST MD 1VD DEV TYÆ VLV LATCH PORT DATE L 3 5091 4208 49 MMG DOME RK 16 03/05/69 2 8601 6498 45 MMG SIO RK 20 03/05/96 1 11232 8635 29 MMG-2 DV RK 0 03/05/96 ) ~ 9-5/8" SIDETRACK WINDOW 10006' -10056' (SECTION MILL) NOTE: PRE-SDTRK WELLBORE NOT SHOWN BELOW 9-5/8" MILLOUT WINDOW. I 11260' 1-1 3-1/2" OTIS X NIP, ID = 2.75" 1 I 11274' 1-1 7" x 3-1/2" BKR SABL-3 PKR, ID = 3.85" 1 11299' 1-1 3-1/2" OTIS X NIP, ID = 2.75" 1 11445' 1-1 3-1/2" OTIS X NIP, ID = 2.75" 1 11457' 1-1 3-1/2" WLEG 1 11456' 1-1 ELMD IT LOGGED 10109/98 / 13026' 1- 2-12" BKR IBP FN @ 13020' SET ON 4-27-96 I PBTD 1-1 13494' 1 I 13456' 1- FISH - BAKER IBP PUSHED TO BTM ON 3/21/96. 1-3/8" EXT FN, LENGTH 11.6" PRUDHOE BAY UNrr WELL: C-31A PERMrr No: 95-0060 API No: 50-029-21775-01 1800' SNL & 883' WEL, Sec. 19, T11 N, R14E BP Exploration (Alaska) TREE.= WELLHEAD = ACTUATOR= KB. aEV = BF. ELEV = KOP= Max Angle = Datum MD = DatumTVD= 6"Cw./ McEVOY 6" AXaSON 67.8' 37.3' 1700' 94 @ 13424' 11472' 8800' \ , Proposed CTD Sidetrack 13-3/8" CSG, 72#, L-80, 10 = 12.347" 1-1. 2825' ~ Minimum ID = 2.75" @ 2115' 3-1/2" OTIS SSSV NIP 7" BKR PKR TIEBACK SLEEVE, 10 = 7.50" 1-1. 9860' L-~ I 9-5/8" X 7" BKR H PKR, 10 = 6.187" 1-1. 9867' P 9-5/8" X 7" BKR HMC LNR HGR, 10 = 6.250" 1-1. 9873' 9-5/8" CSG, 47#, L-80, 10 = 8.681" 1-1. 10006' ~ 3-1/2" TBG, 9.3#, N-80, .0087 bpf, 10 = 2.992" 1-1. 11456' 1 7" X 4-1/2" BKR H LNR TOP PKR, 10= 4.44" 1-1. 11884' TOP OF BKR TIEBACK SLEEVE, 10 = 6.28" 1-1 11902' 7" x 4-1/2" BKR PKR/ LNR HGR, 10 = 4.44" 1-1. 11910' C-31B - SI r NOTES: waL ANGLE> 70 deg @ 11730' & > 90 de~ ~ 12024'. RA N 2ND 7" X 4-1/2" BKR LNR TOP PKR & SET @ 11884' TO ISOLATE 7" FLOAT COLLAR. COULD NOT GET TEST ON 7" LNR PREV IOUSL Y DURING SDTRK OPS. 2115' 1-1. 3-1/2" OTIS SSSV LAND. NIP, 10 = 2.75" 1 ~ GAS LIFT MANORaS L"\ ST MD TVD DEV TYÆ VLV LA TCH PORT DATE 3 5091 4208 49 MMG DOM~ RK 16 03/05/69 2 8601 6498 45 MMG SIO RK 20 03/05/96 1 11232 8635 29 MMG-2 OV RK 0 03/05/96 J ~ I . g 8 ~~~ ~,..... o g J ~ 7" LNR, 29#, L-80, .0371 bpf, 10 = 6.184" 1-1. 11942' ~ ..... ÆRFORA TION SUMMARY REF LOG: MWD GRlRES SÆRRY SUN 02/16/95 ANGLEATTOPÆRF: 75 @ 11800' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE . _2" 6 11800 fo 1,1850 cemented proposed -( 2-1/~~) 4 12038 ~,,,1~128 cemented proposed 2" 6 12145 - 12195 cemented proposed 2" 6 12355 - 12405 isolated proposed 2-3/4" 4 12435 - 12620 isolated proposed 2-3/4" 4 12645 - 12885 isolated proposed 2-3/4" 4 13055 - 13155 isolated proposed 2-3/4" 4 13190 - 13490 isolated proposed PBTD - ."- .--..--.--- c 4-1/2" LNR, 12.6#, L-80, .0152 bpf, 10 = 3.958" 13494' 13535' 0ðÐ 9-5/8" SIDETRACK WINDOW 10006' -10056' (SECTION MILL) NOTE: PRE-SOTRK WaLBORE NOT SHOWN BaOW 9-5/8" MILLOUT WINDOW. 11260' 1-1. 3-1/2" OTIS X NIP, 10 = 2.75" 1 11274' 11299' 11350' 11445' 11457' 11456' 11650' I 13026' 1- 13456' 1- DATE REV BY COMMENTS DATE REV BY COMMENTS 02/22/88 ORIGINAL COMPLETION 03/25/02 KSB/KK ADÆRFS 03/11/95 RIG SIDETRACK ( DOYON 14 ) 02/05/01 SIS-151 CONVERTED TO CANVAS 03/09/01 SIS-LG FINAL 10/02/01 RN/TP CORRECTIONS 7" x 3-112" BKR SABL-3 PKR, 10 = 3.85" 3-1/2" OTIS X NIP, 10 = 2.75" 1 - Top of 2-3/8" Liner 1 3-1/2" OTIS X NIP, 10 = 2.75" 1 - 3-1/2" WLEG 1 - aMD TT LOGGED 10/09/98 - Top of Cement I 2-318" cmt'ed and perfed 1-1. 13800' 1 .,/ ~} 1 1 12025~ 1-1. Mechanical Whipstock 12200' 1-1 Inflatable Bridge Rug ~ ~ 2-12" BKR IBP FN @ 13020' SET ON 4-27-96 FISH - BAKER IBP PUSHED TO BTM ON 3/21/96. 1-3/8" EXT FN, LENGTH 11.6" PRUDHOE BA Y UNrr waL: C-31A ÆRMrr No: 95-0060 API No: 50-029-21775-01 1800' SNL & 883' wa, Sec. 19, T11N, R14E BP Exploration (Alaska) ~---------- BP Amoco ".rent Wellpath: Tie Oft MO: IlIg: ftef. Datum: V.seeUon AnSlla WELL PATH DETAILS '1.".5 C·'1B .002112177502 C·31A 12D24.3' "1Þ' --- :::~;(.D 0.00 REFERENCE INFORMATION ~e%~e(m! ~~::r~~: ~e¿:~:n~~-~ l~elNorth Section (VS) Reference: SIoI - 31 (O.OON.O.OOE) Measured Depth Reference: 38: 31 2/10/199500:00 72.13 CaWation Method: Mirimtm Curvature 3B : 31 2110/199' 00:00 o.1f,~ ~~~ 212.00' D.oO --- aECTlON DETAILS +E:·W DL-. 1 12024.35 5~n U5.eo :::~:~ ·1845.41 :I~:~ J~ 2*~Š ·5832.51 ~ ~~g:5 155." ·1845.07 05832.14 157.15 ''''2.10 .1ðe.4.42 :~:;::: ..s83a.oa 11S.88 :m:: ·1"2.11 ~ 131.5. ·5143.54 : ~=~:;:= ~::: 1ae.31 ·1'11.sa illi:l: ·5137.38 201.21 :=:~~ ·2064.11 30.00 :j¡! -5809.01 7 12tÞ34.oo 00.00 210." ·2271.14 12.00 .s2&a.48 . 1SOa.c.OO §~ 272.11 ::''8: ~~ ·22....34 Hä* 12.00 ~m:fi 1 13334.00 302." -2170.41 12.00 1013584.00 212.11 ::::U ·2014.11 12.00 11 13800.00 211.60 -2030.12 12.00 ë8600 ~ 8650 It) -8700 .c .. 0.8750 a. ~ 8800 ca .~ 8850 1: ~ 8900 ~ 8950 I- 9000 ANNOTATION. TYD ND AnltOtatioft 1942.34 12024.3' TIP 8942.3412025.00 KOP 8942.1D 12045.00 1 8940.80 12071.00 2 8941.01 1211..00 3 .980.13 12213..9 4 198D.13 12134.00 1 1980.13 13014.00 1 1980.13 13334.00 T 1980.13 1 ¡¡¡84.DO 1 1"0.13 13100.00 TD flil ~" 8450 8500 8550 ¡: C-31JG-31J KOP ; Tlf' 21./ - C-31 (C.:J1A)-~--~ 3 . 9050 9100 9150 :~ .E/-'ff S".ape 000 -:t'QB.S.9oI 4111.69 ~ 000 · 866M ð13.3_13 ~, OCQ -256362 514732 ~ :~~ :~~* ~oH ~ ð:j6()OO -Zl36~3 "531'.)1 Po=c:: . C-~¡¡ 15t --------- -- BiI. O BAkail! -._- bp I IIIV"-.H:~ _______l~~EQ ___~___ LEGEND , g:1~þ~1it'12AP~1) C-12 (C-12) ! g:~~ !tm) i Plan#5 C-31B i Plan #5 T ^M Azimuths to True North ¡ Plan: Plan #5 (C-31/Plan#5 C-31B) Magnetic North: 26.03° l creat~~Y~~rij po~ _ _ Date:1~~26/20~__ Magnetic Field I Contact Information: -- m Strength: 57536nT I' Dip Angle: 80.81° Direct: (907) 267-6613 Date: 11/26/20021' E-mail: brij.potnis@inteq.com Model: BGGM2002 Baker Hughes INTEQ: (907) 267-6600 -----------------~~~~~~~~ -~~=-"~~~~~~~-~~~~~-= é " , __~~·i~..~ ___~______ ~----- --------- - - ------ -------- -_.-- " ---------~-~-=---- - ---------------- - ------ --. ----- ------------------------- -- - -1200 - - -- - ----\-- - __________ - ____________ ___ _______._______o_~_____________ ------- --- ----------- -- -1300 -=- - -------.-------- -- ----- - ---- ------ --------- -- -------- - - --------- ---- --- ------- ---------- ----- ----- ----- - ------ ---- -1400 --- --------------- ------- - -----r--------- ---------- ------- -- --- - ---- --- T.rget ----~,~--~------ -1500- _n- ------------- - ___ - _____ - - - ___ ___ ___________ - - __0 _ ___ ____ - - ~-1600 --=--=---=-==-=--=-~~__- ----=----=---=-==__ __ ---------- C --------- - -------- :s -1700- -- - ------------ Õ o -1800-=-- -- -- - ~ - ---------------------.---- --------- ---------\.--- - - ____________ ______c-____ _______________ ________ ______________\ - - _________ _____0- -----------. -------- - --"";------------ ---- ------ --- --- ----- ------ ---- ----------------- - --------- ------.-.- -- T~ \ ~ ~ _ ______u __________-\_,- KOP ____ ____________ '-' ----- - - --------- --------------------- +-1900--::--- - _ - Plan#5 C-31B ~ -2000 ;:-----::--------~-:: --::-~:-~-- -\----- ------ ----- ---- -- _ _ -______ ____ _ <r- -___ -2500-- . - ------ ---------- --_:"-- --- - -- --- ---------- - ----- - ---- -- - --------- " - ------ - ---------- --- --------------------- -----~- ------ -------- --- -2600--:-::=:::.:.:--~-:-..:-=-=--====-=-~=-~=--=== ==---=-:::::.--..:: ------ - . C-31BFaun3---------------- -------------------------- ---- --------'------- \ -2700--- --- """C-12Të=l2f _ _ ________n_ _________ ___._______u ------:--- -2800 ~=~~~~~::~-o,~l-- - c -cc::::~-- .-. ~. . -~= . _ ~-:=,=c~ _c==~==· ._ _ ..~____"~!C:"AI,<~~C~ 4100 4200 4300 4400 4500 4600 4700 4800 4900 5000 5100 5200 5300 5400 5500 5600 5700 5800 5900 6000 6100 6200 6300 6400 6500 6600 6700 West(-)/East(+) [100ft/in] '-' - ---~-- ----- ----------- -- - -.- ------------- --- --------------- ---=- -i--==- ----------~--- -------.------- ----------- ------------~------------- ----- ---- ---- ---- - -------- ------ --- ---------- ------------------- ------ - - ---------- ----- - --- --- - ---- - - - ---- ---- - ---- ----------- - --~----- _____. _.__________~__~______L_ Plan#5 C-31B j ---------- ------------ - - ~-- ------------ -- _____0_ _ ____L_ ---- ---.------~- ----------- ~~-===-=~=---~-:--I . ~·:::~::::~::..=_I ~=__:__:_~-~- ~ -~. __ _-~~---::.- I ---=~_ _-~-=;:_~~=-_--~-=--=-:-~~:=:::..::.::.. ;~~PB1 (C-~2APB1J~ ------- - - -------- - --------- -- ------------------1-------- ---- 0--.-- ----~ C-12A(~i:: -----~----~~_.G:31BJ.IT--- -- --------~-- --- ------------- C-31B T5.3- j - -------- ---------- - ------------- - -------------- -- --- --- ------- -- -------------------- --~------ -------- - ------ ----- ----------- ---- ; -----C-12 (C-12).. ---¡--- -------- -- ----------~-- - --------~------- ---------~- ---- ----- - - ------ ----- --------- ------------- ---- -------- -- - -------- ----- - ---- ------------- - - ----- ------~--------- -6050 -6000 -5950 -5900 -5850 -5800 -5750 -5700 -5650 -5600 -5550 -5500 -5450 -5400 -5350 -5300 -5250 -5200 -5150 -51 00 -5050 -5000 -4950 -4900 -4850 -4800 -4750 -4700 -4650 -4600 -4550 -4500 -4450 -4400 -4350 -4300 -4250 -4200 -4150 Vertical Section at 262.000 [50ft/in] --- ________nn___ - ___~___________________ ----------------.--------- ----t-tt26/2002 9 :1 9-,AM- ObP ') BP ) Baker Hughes INTEQ Planning Report lB.. .... lNTEQ - -.. _.- .~.._, --..---....---.....--.------.--------.---,------ -------- - ..---p--.-----..---.--. --......_-._----- --.-----...---.- Company: BP Amoco Field: Prudhoe Bay Site: PB C Pad Well: C-31 Wellpath: Plan#5 C-31 B Field: Prudhoe Bay North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Geo Datum: NAD27 (Clarke 1866) Sys Datum: Mean Sea Level Date: 11/26/2002 Time: 09:50:43 Page: Co-ordinate(NE) Reference: Well: C-31 , True North Vertical (TVD) Reference: System: Mean Sea Level Section (VS) Reference: Well (0.00N,0.00E,262.00Azi) ..... .... ., __,....__. :__________-::._..._ _._~:~~~_c:~~'..~~~~~~_:~~~~~}~'7=~~~~:~~.~gu~~~~~, ,__.. ___~~-~::.,.~r.~-~~. Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 " ."'-_..._---"._'.__._,-,~'".. -. .-. ,-.. ....,.." ".. .....-..... .,..._-.. ....--..,-."". ....,-.-... Site: PB C Pad TR-11-14 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5957218.72 ft 662550.03 ft Latitude: Longitude: North Reference: Grid Convergence: 70 17 22.367 N 148 41 2.797 W True 1.24 deg .....___.., ---., , __..... .,,_......_. ......... .,._..... ._.." . .0 .._."_'_~_'" _.",,,_ ....__...__.~_._.." _._'...._,_.~. .__... ".. ._,..~ ".. -. .. ._,...,.,. --.~-~_..~_.., ._, . ,..- ......~._,_., ,- -,. -.-.., ......_' .-.,-. -------. . ,.._-_.._.~... ,.....,.~" .~....,' -.,. ,,-... -,'. Well: C-31 Slot Name: C-31 Well Position: +N/-S 2160.62 ft Northing: 5959422.03 ft Latitude: +E/-W 2005.20 ft Easting: 664507.91 ft Longitude: Position Uncertainty: 0.00 ft 31 70 17 43.614 N 148 40 4.353 W .. .'n__" ._.........".. .,.. " . ".._..~_..."_....__._--_.'._.~._-- ---.-.. .'--~... .".. - ---- .. ._. ........._ __~ _..____..·__.___·__·.._n_....._'., Wellpath: Plan#5 C-31 B 500292177502 Current Datum: 38: 31 2/10/199500:00 Magnetic Data: 11/26/2002 Field Strength: 57536 nT Vertical Section: Depth From (fVD) ft 0.00 +N/-S ft 0.00 Drilled From: C-31A Tie-on Depth: 12024.35 ft 72.13 ft Above System Datum: Mean Sea Level Declination: 26.03 deg Mag Dip Angle: 80.81 deg +E/-W Direction ft deg -,..-.------... ,- ...._-_...._'.~'.._,.. ...'--_....--_....._---_.._,--,,~. ..._,--_._- ~....._- 0.00 262.00 Height .... ._ "._._.___..__._.___._,_________.___.____....,_.. ~h_ Targets . ._-_.._....,--_...._._-'._._---_....,.', --.--...--....--..--.---.---..--.'-.--.-- .-. ...... ......_..__..~_._.. .,.-. -.- '._.'--'-'-'--'."~"" . ...~..~... ....... - . '''. Map Map <-- Latitude --> <- Longitude -> Name Description TVD +N/-S +E/-W Northing Easting Deg Min See Deg Min Sec Dip. Dir. ft ft ft ft ft . _. .--.'. _.....' .~. .~.,..~'._--_._.,~.. ._,. ....___.._._... ..,_.,._ ......._____~__...._.___ _~______._"_........_.__.,...... .._.___._,. _.,~. ..'. ..._"........ n""'_'~"_'. ___..._._' ,. ........._..,. '_'4' C-31 B Polygon5.1 0.00 -2085.94 4717.89 5957440.00 669270.00 70 17 23.085 N 148 37 46.881 W -Polygon 1 0.00 -2085.94 4717.89 5957440.00 669270.00 70 17 23.085 N 148 37 46.881 W -Polygon 2 0.00 -2365.38 5602.05 5957179.99 670160.01 70 17 20.330 N 148 37 21.124 W -Polygon 3 0.00 -2402.81 5941.33 5957150.00 670500.00 70 17 19.960 N 148 37 11.239 W -Polygon 4 0.00 -2236.75 5894.95 5957314.99 670450.00 70 17 21.593 N 148 37 12.587 W .Polygon 5 0.00 -2234.30 5554.90 5957310.00 670110.00 70 17 21.620 N ' 148 37 22.495 W ·Polygon 6 0.00 -1877.51 4792.47 5957649.99 669340.00 70 17 25.134 N 148 37 44.704 W C-31 B Fault 1 0.00 -1866.84 6133.13 5957690.00 670680.00 70 17 25.229 N 148 37 5.638 W -Polygon 1 0.00 -1866.84 6133.13 5957690.00 670680.00 70 17 25.229 N 148 37 5.638 W -Polygon 2 0.00 -2247.47 6384.88 5957314.99 670940.01 70 17 21.484 N 148 36 58.312 W C-31B Fault 3 0.00 -2583.62 5747.32 5956965.00 670310.00 70 17 18.183 N 148 37 16.896 W -Polygon 1 0.00 -2583.62 5747.32 5956965.00 670310.00 70 17 18.183 N 148 37 16.896 W -Polygon 2 0.00 -2290.94 4943.48 5957239.99 669500.01 70 17 21.067 N 148 37 40.311 W C-31B Fault 2 0.00 -2149.32 5556.77 5957395.00 670110.00 70 17 22.456 N 148 37 22.439 W ·Polygon 1 0.00 -2149.32 5556.77 5957395.00 670110.00 70 17 22.456 N 148 37 22.439 W ·Polygon 2 0.00 -1631.38 4972.93 5957900.00 669515.01 70 17 27.554 N 148 37 39.441 W C-31B T5.1 8960.00 -2156.90 6131.78 5957400.00 670685.00 70 17 22.377 N 148 37 5.684 W C-31B T5.2 8960.00 -2270.17 5594.13 5957275.00 670150.00 70 17 21.267 N 148 37 21.353 W C-31B T5.3 8960.00 -2036.53 4837.01 5957492.00 669388.00 70 17 23.570 N 148 3743.409 W . -- ...-.------,.-. . - -.-. --.---.- ... -.- .-.-----,-- . -".~ ., --. ..-..- ObP ) BP ) Baker Hughes INTEQ Planning Report .. '_n' _ R ..._.~. __,.._.._.",,__._.~.. __.,.. _.,. ¥..._...,_. ... ,__. ...-.._.__ ____._._..__ .._._______ ...___.___.._.__...__... _____.__ '_._.. ..__.__ ____...,.__._._.._..._,."....._...__.__. _...,., ._, _ _,.. '. II.. .... INTEQ ..'......." ..'.. Company: BP Amoco Date: 11/26/2002 Time: 09:50:43 Page: 2 Field: Prudhoe Bay Coo.ordinate(NE) Reference: Well: C-31 , True North Site: PB C Pad Vertical (TVD) Reference: System: Mean Sea Level Well: C-31 Section (VS) Reference: Well (0.00N,0.00E,262.00Azi) . ._~!I!.~~~~.~...__~~~~~~~~. _._._....___.__.__..__________.._.__...____...._~~~y <?_~~~_~~.~~!.~.~~~~_~_~.:._.. ..~!~i.~~~.~urva.tuE~_. .. ..._..___.!>b: Oracle Annotation -.,.' ,...".---...----. ----..-----.,.-.-.-.--...---...'. .,.--....--...-.. .-....----...-.-..-.---------.---.-..------.--.....---------.-."'.-.-.----.---------.- .--..,.__..,____._.,_._._,. '__",__." ',n.. ,,_w,,_, ... .._.. ,_ ..,.._.,_.. .___.... ..._ ........ _n." MD TVD I ft ft 1··1·2Õ24jS-···· '8942.34'-'- n--TIP'''-- .-.. .- -. .. --.---.------.---.------.--.---..--..--... ...------ _.__.n_.____....._._. -.---.---...-- - u___ .- ---..- ......-... .-. ..-.-..... . .-. 112025.00 8942.34 KOP ! 12045.00 8942.10 1 I 12075.00 8940.80 2 112165.00 8949.08 3 12253.99 8960.13 4 i 12934.00 8960.13 5 ¡ 13084.00 8960.13 6 I' 13334.00 8960.13 7 13584.00 8960.13 8 113800.00 8960.13 TD 1....._..____ __ .._._._...._.. _m_ _____._.._.__._.m_.. ___.._._ _... _._.._.._._ .______.___......._....__...__.____ _____W_,·_,.._··,__·___,·····_.··~..··...._.W_,·._._.__. ... __,. ._._,.. . "-"'."""'.,. ._."_.'_..~ ..-...---'.'.'.'-.-- -,.~._--_...~...,_... -....------.-..,.-..--...--.-. ---..,-.,.-......"..-..---,-..-.-.-.-.....-.... ------.---.--.-.--.,-.-.-...---.- .--.- -...--.... ,_....~.__. ~_. .." ,.-.. ...' ..' ...'.. I' Plan: Plan #5 Date Composed: 11/25/2002 I Identical to Lamar's Plan #5 Version: 5 l...~~~~.~i_~.~~.~_ _._~~~_______._..... ... ___ ..,.__.___. _....___.______._.. _.__.__...._.._. .... .u'___ ._..__!i!~-~~~..__.._ _...... ........_._._. .~ro~:_~~fjnitive Path Plan Section Information í---·-·iïD------·ïnci-----..-·--¡.¡¡~--------..-·TVD----·+NI-s +E/-W-·---- DLS----·-B~iid..----·-T;-;~·---·-..- - TFÖ- -- --T~;:g-;t-- n_.__'·_'__' ...... .... I ft deg deg ft ft ft deg/1000 deg/1000 deg/100ft deg (.. ._.__.__.__.__...._._.____._..______.___._____._.______._________.________.__.__.._._.___.____n.__ _._._..___._._____._._._ .._.._.... _.._.._...... __._.._'_..__.. _.. ._. ....._. ...._. I 12024.35 90.06 155.90 8942.34 -1845.48 6250.23 0.00 0.00 0.00 0.00 : 12025.00 90.05 155.88 8942.34 -1846.07 6250.50 3.44 -1.54 -3.08 243.43 '12045.00 91.32 157.15 8942.10 -1864.42 6258.46 9.00 6.36 6.37 45.00 ! 12075.00 93.63 165.86 8940.80 -1892.81 6267.96 30.00 7.68 29.03 75.00 ! 12165.00 75.89 186.39 8949.08 -1981.38 6274.19 30.00 -19.71 22.80 131.50 112253.99 90.00 209.28 8960.13 -2064.58 6247.14 30.00 15.86 25.73 60.00 12934.00 90.00 290.88 8960.13 -2277.14 5660.49 12.00 0.00 12.00 90.00 13084.00 90.00 272.88 8960.13 -2246.38 5514.30 12.00 0.00 -12.00 270.00 13334.00 90.00 302.88 8960.13 -2170.49 5279.09 12.00 0.00 12.00 90.00 13584.00 90.00 272.88 8960.13 -2094.59 5043.88 12.00 0.00 -12.00 270.00 13800.00 90.00 298.80 8960.13 -2036.12 4837.85 12.00 0.00 12.00 90.00 ._~- ,p' .-. -.-..-..--..--...-.--.-----....,.-- ---_.-_.__._._---,-~---- Survey r-·-·-·--~D-..--..-Ï;j~-·~~J~ SS~ L..-- -.-.----.-. , 12024.35 90.06 155.90 8942.34 12025.00 90.05 155.88 8942.34 12045.00 91.32 157.15 8942.10 12050.00 91.71 158.60 8941.96 12075.00 93.63 165.86 8940.80 12100.00 12125.00 12150.00 12165.00 12175.00 12200.00 12225.00 12250.00 12253.99 12275.00 12300.00 12325.00 12350.00 12375.00 12400.00 12425.00 12450.00 i 12475.00 l___.!~~OO.OO 88.65 83.68 78.78 75.89 77.40 81.29 85.29 89.35 90.00 90.00 90.00 90.00 90.00 90.00 90.00 171.47 177.11 182.85 186.39 189.05 195.57 201.96 208.28 209.28 211.80 214.80 217.80 220.80 223.80 226.80 90.00 229.80 90.00 232.80 90.00 235.80 90.00 238.80 8940.30 8941.97 8945.79 8949.08 8951.39 8956.01 8958.94 8960.11 8960.13 8960.13 8960.13 8960.13 8960.13 8960.13 8960.13 8960.13 8960.13 8960.13 8960.13 -----.--.-------- .----.., ,-.-.--.--. --..--.-.-..---..--.,-.-..------.. ..- ~- ...". ~ ......_- -.......- N/S ft -1845.48 -1846.07 -1864.42 -1869.05 -1892.81 -1917.30 -1942.10 -1966.79 -1981.38 -1991.02 -2015.00 -2038.49 -2061.08 -2064.58 -2082.67 -2103.57 -2123.71 -2143.05 -2161.54 -2179.12 -2195.75 -2211.38 -2225.96 -2239.47 -...______..'______.__...___.___~._..'_.__.... __..... .,._~__.._.. _'_'·W,___ ....._._'_.__..~__.......__.... . ....w. E/W ft 6250.23 6250.50 6258.46 6260.35 6267.96 6272.87 6275.35 6275.37 6274.19 6272.89 6267.64 6259.66 6249.06 6247.14 6236.46 6222.74 6207.94 6192.11 6175.28 6157.51 6138.85 6119.34 6099.04 6078.00 MapN ft 5957713.92 5957713.33 5957695.17 5957690.58 5957666.99 5957642.61 5957617.87 5957593.19 5957578.59 5957568.92 5957544.83 5957521.17 5957498.36 5957494.82 5957476.50 5957455.31 5957434.85 5957415.16 5957396.31 5957378.35 5957361.32 5957345.27 5957330.24 5957316.28 MapE VS DLS TFO Tool ft ft deg/1 000 deg ____4._.....__ ._.._ ,_.~, __.__.____.,_... "_'_'h"~"""_' _._,...... ,_.._._.__. 670796.60 -5932.56 0.00 0.00 TIP 670796.88 -5932.74 3.44 243.43 KOP 670805.25 -5938.08 9.00 45.00 1 670807.23 -5939.30 30.00 75.00 MWD 670815.37 -5943.54 30.00 75.04 2 670820.81 670823.83 670824.39 670823.53 670822.44 670817.72 670810.25 670800.15 670798.31 670788.03 670774.77 670760.41 670745.01 670728.59 670711.21 670692.92 670673.76 670653.78 670633.05 -5944.99 -5943.99 -5940.57 -5937.38 -5934.74 -5926.21 -5915.04 -5901.40 -5899.01 -5885.92 -5869.42 -5851.96 -5833.59 -5814.35 -5794.31 -5773.51 -5752.02 -5729.89 -5707.18 ---_._---- ----------.. ..--.- 30.00 30.00 30.00 30.00 30.00 30.00 30.00 30.00 30.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 12.00 .. - ._."--'~------' -.- 131.50 MWD 131.61 MWD 131.23 MWD 130.36 3 60.00 MWD 59.38 MWD 58.18 MWD 57.43 MWD 57.13 4 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD ObP ) BP ) Bili. -=-. } Baker Hughes INTEQ Planning Report INTEQ ! Company: _._.~- -_.._---,~.~---_.~.._.~..'--- ~--,_.__._,----,_.__._--_.~---_.~.'._.._.".._- ,.- ....... .. ...- .-.....".,' ..---. BP Amoco Date: 11/26/2002 Time: 09:50:43 Page: 3 Field: Prudhoe Bay Co-ordioate(NE) Reference: Well: C-31 , True North Site: PB C Pad Vertical (fVD) Reference: System: Mean Sea Level Well: C-31 Section (VS) Reference: Well (O.00N,0.00E,262.00Azi) Wellpath: Plan#5 C-31B Survey Calculation Method: Minimum Curvature Db: Oracle -,,~ . . ..-...- '.... .......,-_... '-...---' ..- -.,. ._.__.. __. __.___..___.....____._..___......--____._____., .___·____.H'.__._··· --- .---.. .".--.--. ..---_...- .'.-- -....-. .........-- ,-.--- ......"-_..,, ".,." ."' Survey _ .."..,_.. _.n....'. ... ,__" ".___...~... ,..~ _ ._,.." .... n,. .._____. "_0'_.. ......._...__,. _.___.. _. ....n ____.__.... .,.....,.,._.___ ......HU....,WM..'__. __...._. .. _ M" ...~ _ _M. _. ._ _ ._..._w ... .,. ._ _ _... _.._ . MD Incl Azim SSTVD N/S E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/10Oft deg -.. ~.-_. - .._.- .. _.. - ., .- . . _~ ". '..._'_.. 'M '_h. ._..~. ....,_,_., ~ _._.... ~_.. . ._____. ._.. . - ......_ ..___...._ ._·_n'_· ...__........ ....__.... _"'_.'_'~" . ..... _" .~.. ......, .- ..--.-..-....... -.. . . I 12525.00 90.00 241.80 8960.13 -2251.85 6056.29 5957303.43 670611.61 -5683.95 12.00 90.00 MWD 12550.00 90.00 244.80 8960.13 -2263.08 6033.95 5957291.71 670589.53 -5660.27 12.00 90.00 MWD 12575.00 90.00 247.80 8960.13 -2273.13 6011.06 5957281.17 670566.87 -5636.21 12.00 90.00 MWD 12600.00 90.00 250.80 8960.13 -2281.96 5987.68 5957271.82 670543.69 -5611.82 12.00 90.00 MWD 12625.00 90.00 253.80 8960.13 -2289.56 5963.87 5957263.71 670520.05 -5587.18 12.00 90.00 MWD 12650.00 90.00 256.80 8960.13 -2295.90 5939.69 5957256.84 670496.01 -5562.35 12.00 90.00 MWD 12675.00 90.00 259.80 8960.13 -2300.97 5915.21 5957251.24 670471.65 -5537.41 12.00 90.00 MWD 12700.00 90.00 262.80 8960.13 -2304.75 5890.50 5957246.92 670447.03 -5512.41 12.00 90.00 MWD 12725.00 90.00 265.80 8960.13 -2307.23 5865.62 5957243.89 670422.22 -5487.44 12.00 90.00 MWD 12750.00 90.00 268.80 8960.13 -2308.41 5840.66 5957242.17 670397.29 -5462.55 12.00 90.00 MWD 12775.00 90.00 271.80 8960.13 -2308.27 5815.66 5957241.76 670372.29 -5437.81 12.00 90.00 MWD 12800.00 90.00 274.80 8960.13 -2306.83 5790.70 5957242.65 670347.31 -5413.30 12.00 90.00 MWD 12825.00 90.00 277.80 8960.13 -2304.09 5765.86 5957244.85 670322.42 -5389.08 12.00 90.00 MWD 12850.00 90.00 280.80 8960.13 -2300.05 5741.19 5957248.35 670297.67 -5365.21 12.00 90.00 MWD 12875.00 90.00 283.80 8960.13 -2294.72 5716.77 5957253.14 670273.13 -5341.77 12.00 90.00 MWD 12900.00 90.00 286.80 8960.13 -2288.12 5692.65 5957259.21 670248.89 -5318.81 12.00 90.00 MWD 12925.00 90.00 289.80 8960.13 -2280.27 5668.92 5957266.54 670224.99 -5296.40 12.00 90.00 MWD 12934.00 90.00 290.88 8960.13 -2277.14 5660.49 5957269.48 670216.49 -5288.48 12.00 90.00 5 12950.00 90.00 288.96 8960.13 -2271.69 5645.44 5957274.60 670201.33 -5274.34 12.00 270.00 MWD 12975.00 90.00 285.96 8960.13 -2264.19 5621.60 5957281.58 670177.33 -5251.77 12.00 270.00 MWD 13000.00 90.00 282.96 8960.13 -2257.95 5597.39 5957287.29 670152.99 -5228.67 12.00 270.00 MWD 13025.00 90.00 279.96 8960.13 -2252.98 5572.89 5957291.72 670128.39 -5205.10 12.00 270.00 MWD 13050.00 90.00 276.96 8960.13 -2249.30 5548.17 5957294.86 670103.60 -5181.13 12.00 270.00 MWD 13075.00 90.00 273.96 8960.13 -2246.92 5523.28 5957296.69 670078.67 -5156.82 12.00 270.00 MWD 13084.00 90.00 272.88 8960.13 -2246.38 5514.30 5957297.03 670069.68 -5148.00 12.00 270.00 6 13100.00 90.00 274.80 8960.13 -2245.31 5498.34 5957297.76 670053.69 -5132.34 12.00 90.00 MWD 13125.00 90.00 277.80 8960.13 -2242.57 5473.49 5957299.96 670028.80 -5108.12 12.00 90.00 MWD 13150.00 90.00 280.80 8960.13 -2238.52 5448.82 5957303.46 670004.05 -5084.25 12.00 90.00 MWD 13175.00 90.00 283.80 8960.13 -2233.20 5424.40 5957308.25 669979.51 -5060.81 12.00 90.00 MWD 13200.00 90.00 286.80 8960.13 -2226.60 5400.29 5957314.31 669955.27 -5037.85 12.00 90.00 MWD 13225.00 90.00 289.80 8960.13 -2218.75 5376.56 5957321.64 669931.37 -5015.44 12.00 90.00 MWD 13250.00 90.00 292.80 8960.13 -2209.67 5353.27 5957330.21 669907.89 -4993.64 12.00 90.00 MWD 13275.00 90.00 295.80 8960.13 -2199.38 5330.49 5957340.00 669884.89 -4972.52 12.00 90.00 MWD 13300.00 90.00 298.80 8960.13 -2187.91 5308.27 5957350.97 669862.43 -4952.12 12.00 90.00 MWD 13325.00 90.00 301.80 8960.13 -2175.30 5286.69 5957363.11 669840.58 -4932.50 12.00 90.00 MWD 13334.00 90.00 302.88 8960.13 -2170.49 5279.09 5957367.76 669832.88 -4925.64 12.00 90.00 7 13350.00 90.00 300.96 8960.13 -2162.02 5265.51 5957375.92 669819.11 -4913.37 12.00 270.00 MWD 13375.00 90.00 297.96 8960.13 -2149.73 5243.75 5957387.73 669797.09 -4893.53 12.00 270.00 MWD 13400.00 90.00 294.96 8960.13 -2138.59 5221.37 5957398.38 669774.4 7 -4872.92 12.00 270.00 MWD 13425.00 90.00 291.96 8960.13 -2128.64 5198.44 5957407.83 669751.33 -4851.60 12.00 270.00 MWD 13450.00 90.00 288.96 8960.13 -2119.90 5175.02 5957416.05 669727.73 -4829.62 12.00 270.00 MWD 13475.00 90.00 285.96 8960.13 -2112.40 5151.17 5957423.03 669703.73 -4807.05 12.00 270.00 MWD 13500.00 90.00 282.96 8960.13 -2106.15 5126.97 5957428.74 669679.39 -4783.95 12.00 270.00 MWD 13525.00 90.00 279.96 8960.13 -2101.19 5102.47 5957433.17 669654.79 -4760.38 12.00 270.00 MWD 13550.00 90.00 276.96 8960.13 -2097.51 5077.74 5957436.31 669629.99 -4736.41 12.00 270.00 MWD 13575.00 90.00 273.96 8960.13 -2095.13 5052.86 5957438.14 669605.07 -4712.10 12.00 270.00 MWD 13584.00 90.00 272.88 8960.13 -2094.59 5043.88 5957438.48 669596.08 -4703.28 12.00 270.00 8 13600.00 90.00 274.80 8960.13 -2093.52 5027.91 5957439.20 669580.09 -4687.62 12.00 90.00 MWD 13625.00 90.00 277.80 8960.13 -2090.77 5003.07 5957441.40 669555.19 -4663.40 12.00 90.00 MWD 13650.00 90.00 280.80 8960.13 -2086.73 4978.40 5957444.90 669530.44 -4639.53 12.00 90.00 MWD 13675.00 90.00 283.80 8960.13 -2081.40 4953.98 5957449.70 669505.91 -4616.09 12.00 90.00 MWD 13700.00 90.00 286.80 8960.13 -2074.81 4929.86 5957455.76 669481.66 -4593.13 12.00 90.00 MWD Obp \ BP ) I Baker Hughes INTEQ Planning Report 1rI.. ..... I,NTEQ . .....~_. ". _. .. ,_, .' ..__,.. _. .. ~ . . _.. .0' '.." ,." o. _.., .oO"w'... ,.. ~. .. ,.. _0' _ ......" _'._"..' _. ,,o. ___..,........_._._...... .__...___ h_..........._.. ..."...__..._.____. ___..____. "_.__~._ . ... '0_' .__ .... ." _ ..' '..' .. . ....."...... .'.-".. I' C~~~~~~:" Field: Site: Well: ,..,~~!~~,a~~: BP Amoco Prudhoe Bay PB C Pad C-31 Plan#5 C-31 B Date: 11/26/2002 Time: 09:50:43 Page: 4 Co-ordinate(NE) Reference: Well: C-31 , True North Vertical (fVD) Reference: System: Mean Sea level Section (VS) Reference: Well (0.00N,0.00E,262.00Azi) Survey Calculation Method: Minimum Curvature Db: Oracle . u___..___............ .. _." _.. .h....__,.· __ .,._,__.....____.. .__.,__._____ .".,....._.".._.._.._____..._·__..,..._.__...,__._'._0".._._....._.... _...___._, ___.. ...., .._.. .'.. .. ...._... Survey ," ...,.,......,.__ ..~_,_..' ..._._.. ___,_~._. .._~._. ,~..' ._.,. .,_.'__.. .'..._~~ ....._. ..___.,_...._.__'___._.__..____.....____..__u__. ._____.~..__...'._..___._______.__~_._~.____.._.__.__ .,,_ ____'.'..___..' ..... .._,_. ._., .~__ '. .... .,_, _.___...,. _._.. '" ".. '..... .,.' _ _.. MD Incl Azim SSTVD N/S E/W MapN MapE VS DLS TFO Tool ft deg deg ft ft ft ft ft ft deg/1000 deg ..".....-...,","- .,..~_..~_.._._., .~.._ _.··"n.._"..···_·,···,~ -- .-... "._'_.~"-'- -....- .....--,.--.--.--.,-.. ..--,--,., -..---.-'-.. '-., .- ..-..-...-.-.'--.- -.-,-..........-,--.-. ._._.~.._.. ..... -. - .... .-..-,..- -..... . .'. _....,.._ _....,..... '.·h........ ........... ".. .M' ,.. 13725.00 90.00 289.80 8960.13 -2066.96 4906.13 5957463.09 669457.77 -4570.72 12.00 90.00 MWO 13750.00 90.00 292.80 8960.13 -2057.88 4882.84 5957471.66 669434.29 -4548.92 12.00 90.00 MWO 13775.00 90.00 295.80 8960.13 -2047.59 4860.06 5957481.45 669411.29 -4527.79 12.00 90.00 MWO 13800.00 90.00 298.80 8960.13 -2036.12 4837.85 5957492.42 669388:83 -4507.39 12.00 90.00 TO ~."...,.._--.__.~._,.."...- - ......'''....., ...-....- ... .., ,-. .......'.....,,- . -.."..,-........--.-.. .'.....-...... I,~en,l C-3\~ l", I, ~N0t;.f ßLlt-\b J ~14¿1 - 1" ~~~ ~\ft J ~\P I~" 5000 psi -- ¥t\vb t..M-t( 1..3 /,\\ ~\ ~(£ f)~f ~ 2\\ ~L ~ft.l ~'-\f -- l,bÜN",) h)1,./ ð?- I ')- 'I) , , ) BOP-Tree .// Rig Floor I > I KB Elevation I Lubricator ID = 6.375" with 6" Otis Unions 171/16" 5000 psi BOP's. ID = 7.06" I I "'1"""'."'"''1''' I .¡' ~b~t:!li'I::, Choke Line I. l::I/'~""'''':I~~I;};~' II I li;¡~¡ji!j,.'¡:!r~'""·'\·' """',;!,, '1,-"'1;_ 12 1/16" 5000 psi ,RX-24 I ..,... "I. . "~I r / I ::;,I~":,i;'J:';;:',1 7 1/16" 5000 psi (RX-46) or +- 41/16" 5000 psi (RX-39) ~:::I,:::,,/I,':,:;,''':il'',:,; .. I --. Swab Valve I Tree Size I SSV I I Master Valve I I Base FlanQe I I Page 1 ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# CHECK WHAT APPLIES ADD-ONS (OPTIONS) MUL TI LATERAL (If API num ber last two (2) digits are between 60-69) "CLUE" The permit is for a new wellbore segment of existing well Permit No, API No. Production should continue to be reported as a function· of the original API number stated above. HOLE In accordance with 20 AAC 25.005(1), all records, data and logs acquired for the pilot hole must be clearly differentiated in both name (name on permit plus PH) and API number (50 70/80) from records, data and logs acquired for well (name on permit). PILOT (PH) SPACING EXCEPTION DRY DITCH SAMPLE Rev: 07/10/02 C\jody\templates The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent . upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. p054979 DATE 11/18/02 P054979 CHECK NO. DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS VENDOR DISCOUNT NET 11/18/02 INV# CKll1402 PERMIT TO DRILL FEE. RECEiVED ~-6\S JAN 1 J 2003 Alaska ou & Gas Cons. Commission Anchorage THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. TOTAL ~ BPEXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 .. ANCHO~GF, AK9951ß-6612 PAY 333 W 7TH AVENUE SUITE 1QO ANCHORAGE, AK 99501 1110 5 L, g '7 g III I: 0 L, . 20 j B g 51: O. 2 '7 B ~ bill - ._--,-._---~-~-- H ~F' WELL PERMIT CHECKLIST CÖMPANY ßf>)! WELL NAME tk -£. r.. - 3 J ß PROGRAM: Exp _ Dev L Redrll...::£. Re-Enter _ Serv _ Wellbore seg _ FIELD & POOL ~ '/ñ/'C; ~ INIT CLASS LJ,...u /.-.....~ï GEOL AREA gr7ó UNIT# //f{5ð ON/OFF SHORE ~ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . ~ N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . , . Y N 4. W ell located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. ... Y N 6. W ell located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y, N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issUed without administrative approval.. . . . . \.jI N (Service Well Only) 13. Well located wlin area & strata authorized by injection order #_ Y)t /L.I~/1~ (Service Well Only) 14. All wells wlin 14 mile area of review identified. . . . . . . . .. ~ N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . W N 16. Surface casing protects all known USDWs. . . . . . . . . r;j) N 17. CMT vol adequate to circulate on conductor & surf csg. . . . .¥--N- Ai/A- 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ¥-N- 19. CMT will cover all known productive horizons. . . . . . . . . . iN 20. Casing designs adequate for C, T, B & permafrost. . . . . . . . N C 21. Adequate tankage or reserve pit.. . . . . . . . . . . . . . . . N :r~ IÁ... 22. If a re-drill, has a 10-403 fo.r abandonment be~n approved. . . . N I( ''-h ø 'S . 23. Adequate wellbore separation proposed.. . . . . . . .. . . . . . N 24. If diverter required, does It meet regulations. .. . . . . .. . i"'-/A- 1 i J D ' 25. Drilling fluid program schematic & equip list adeq. uate. . . . . .. N mp..ct1t /ft.. AÅ ~.¿, P,pq· 26. BOPEs, do they meet regulation. . . . ... . . . . . . . . . : jN D ." , .' APPR DATE ~7: BOPE pres~ rating ap~ropriate; test to 35"00 pSlg. 7N ¡lll Ç. I l2.. ~ r...'7 yJ'-.l ~ ~r "'_ It' l../o 7 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . , N 9~ '" ;:) 29. Work will occur without operation shutdown. . . . . . . . . . . . N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . .. '-y ÆY J 31. Mechanical condition of wells within AOR verified. . . . . . . . .~ Af ,It- ~~ /1 ;~ V,(71 APPR DATE IfG ~ (Service Well Only) GEOLOGY APPR DATE ;f!(' ;)~ó3 (Exploratory Only) Rev: 10/15/02 32. Permit can be issued wlo hydrogen sulfide measures. . . . . 33. Data presented on potential overpressure zones. . . . . . . . 34. Seismic analysis of shallow gas zones. . . . . . . . . . . . . 35. Seabed condition survey (if ,off-shore). . . . . .. ...... 36. Contact namelphone for weekly progress reports. ...... ~EOLÓGY: RPc;{f1G RESERVOIR ENGINEERING JDH UIC ENGINEER JBR COMMISSIONER: COT DTS Of ( 21-1 0 ) MLB c9;):z.?/03 \J PETROLEUM ENGINEERING: TEM SFD WGA / MJW G:\geology\permits\checklist.doc ( Comments/I nstructions: ) ) Well History File APPENDIX Information of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information. information of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. ) dð3-CO~ )vri'ð **** REEL HEADER **** MWD 04/02/27 BHI 01 LIS Customer Format Tape **** TAPE HEADER **** MWD 04/01/14 466609 01 2.375" CTK *** LIS COMMENT RECORD *** ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! ! -Version Information VERSo WRAP. -Well Information Block #MNEM.UNIT Data Type #--------- ------------- STRT.FT 12030.5000: STOP.FT 13688.0000: STEP.FT 0.5000: NULL. -999.2500: COMPo COMPANY: WELL. WELL: FLD . FIELD: LOC . LOCATION: CNTY. COUNTY: STAT. STATE: SRVC. SERVICE COMPANY: TOOL. TOOL NAME & TYPE: DATE. LOG DATE: API . API NUMBER: -Parameter Information Block #MNEM.UNIT Value #--------- ------------------------- SECT. 19 TOWN.N IIN RANG. 14E PDAT. MSL EPD .F 0 LMF . RKB FAPD.F 72.13 DMF KB EKB .F 72.13 EDF .F N/A EGL .F 0.0 CASE.F 12046 OSI . DIRECTIONAL OS2 . PRESSTEQ I -Remarks Remark File Version 1.000 Extract File: Idwg.las 1.20: NO: CWLS log ASCII Standard -VERSION 1.20 One line per frame Information ------------------------------- Starting Depth Ending Depth Level Spacing Absent Value BP Exploration (Alaska) Inc. C-31B Prudhoe Bay Unit 70 deg 17' 43.614" N 148 deg 40' 4.353" W North Slope Alaska Baker Hughes INTEQ 2.375" CTK 21-Apr-03 500292177502 Description ------------------------------- Section Township Range Permanent Datum Elevation Of Perm. Datum Log Measured from Feet Above Perm. Datum Drilling Measured From Elevation of Kelly Bushing Elevation of Derrick Floor Elevation of Ground Level Casing Depth Other Services Line 1 Other Services Line 2 RECE\VED ~~~\,\\.~ 1'-1'~P 1 .' ?004 .~11I' '- rJ.it~~~on & Gas Cons. Coromann I~, lI"'f1IIf"'iI:IMgA b:"¡!I\~i-\~¥i9 .y ) ) All depths are Measured Depths (MD) unless otherwise noted. All depths are Bit Depths unless otherwise noted. All Gamma Ray data presented is Realtime data. The 3" hole section of C-31B was kicked off from 4.5" liner at 12046' MD (8942' SSTVD) and drilled to 13688' MD(8950' SSTVD). (5) Baker Hughes Inteq utilized CoilTrak downhole tools and ADVANTAGE surface system. (6) Tools ran in the string included CCL, Electrical Disconnect and Circulating sub, a Drilling Performance Sub (inner and outer downhole pressure, downhole weight on bit, downhole temperature), a Gamma and Directional Sub, and an Orienting Sub with a near bit inclination sensor. (7) The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by SWS on Apr 23, 2003. (8) The interval from 13660' MD (8949' SSTVD) to 13688' MD (8950' SSTVD) was not logged due to sensor bit offset at TD MNEMONICS: GRAX -> Gamma Ray MWD-API [MWD] (MWD-API units) ROPS -> Rate of Penetration, feet/hour TVD -> Subsea True Vertical Depth (SSTVD), feet SENSOR OFFSETS: RUN GAMMA DIRECTIONAL 1 N/A ft. N/A ft. 2 N/A ft. N/A ft. 3 N/A ft. N/A ft. 4 N/A ft. N/A ft. 5 12.52 ft. 13.36 ft. 6 28.12 ft. 27.04 ft. 7 28.12 ft. 27.04 ft. stty: No such device or address CURVE SHIFT DATA OBSERVED, ACTUAL, 12052.7, 12053.1, 12068, 12068.9, 12073.1, 12076.5, 12081.1, 12085.7, 12092.8, 12095.6, 12095.6, 12099.4, 12125.5, 12128.7, 12221. 6, 12226, 12237.8, 12242.9, 12280.3, 12285.8, 12294.4, 12299.2, 12300.3, 12304.5, 12308.7, 12314.1, 12317.2, 12322.3, 12381.3, 12389.3, 12480.3, 12481.9, 12594.1, 12595.5, 12607.1, 12607.7, 12641.5, 12642.9, 12653.2, 12654, 12701.5, 12699.6, 12759.4, 12762.1, 12804.7, 12803.3, 12895.6, 12898, 13059.3, 13067.7, 13230.3, 13228.4, 13249.8, 13248.9, 13255.8,13253.8, 13274.3, 13274.8, 13286, 13284.4, 13339.8, 13336.5, 13389, 13387.9, 13472.1, 13465.9, EOZ END ! BASE CURVE: GROH, OFFSET CURVE: GRCX ( 1 ) (2 ) (3 ) ( 4 ) DISPLACEMENT 0.420898 0.84082 3.36328 4.62402 2.73242 3.7832 3.15234 4.41309 5.04395 5.46387 4.83398 4.20312 5.46387 5.04395 7.98633 1. 63672 1. 36426 0.545898 1.36426 0.818359 -1. 91016 2.72754 -1.36426 2.45508 8.45605 -1. 91016 -0.818359 -1. 91016 0.544922 -1.63574 -3.27344 -1. 09082 -6.27441 ) ) Tape Subfile: 1 109 records... Minimum record length: Maximum record length: 10 bytes 132 bytes **** FILE HEADER **** MWD .001 1024 *** INFORMATION TABLE: CONS MNEM VALU ------------------------------------ WDFN LCC CN WN FN COUN STAT mwd.xtf 150 BP Exploration (Alaska) Inc. C-31B Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!! !! !!! ! ! !! ! !! !!!! Remark File Version 1.000 The data presented here is final and has been depth shifted to a PDC (Primary Depth Control) recorded by SWS, 23-Apr-03 *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GR ROP GR ROP GRAX01 ROPA01 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units Size Length 1 GR MWD 68 1 AAP I 4 4 ) ) 2 ROP MWD 68 1 F/HR 4 4 ------- 8 Total Data Records: 40 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 12030.500000 13688.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 2 49 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** FILE HEADER **** MWD .002 1024 *** INFORMATION TABLE: CONS MNEM VALU -------------------------------- WDFN LCC CN WN FN COUN STAT raw.xtf 150 BP Exploration (Alaska) C-31B Prudhoe Bay Unit North Slope Alaska *** LIS COMMENT RECORD *** !!!!!!!!!! !!!! ! !! !! Remark File Version 1.000 This file contains the raw-unedited field data. *** INFORMATION TABLE: CIFO MNEM CHAN DIMT CNAM ODEP ---------------------------------------------------- GRAX ROPS GRAX ROPS GRAX ROPA 0.0 0.0 * FORMAT RECORD (TYPE# 64) Data record type is: 0 Datum Frame Size is: 12 bytes Logging direction is down (value= 255) Optical Log Depth Scale Units: Feet Frame spacing: 0.500000 Frame spacing units: [F ] Number of frames per record is: 84 One depth per frame (value= 0) Datum Specification Block Sub-type is: 1 FRAME SPACE = 0.500 * F ONE DEPTH PER FRAME Tape depth ID: F 2 Curves: Name Tool Code Samples Units 1 GRAX MWD 68 1 AAPI 2 RaPS MWD 68 1 F/HR Total Data Records: 40 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units 12030.500000 13688.000000 0.500000 feet **** FILE TRAILER **** Tape Subfile: 3 49 records... Minimum record length: Maximum record length: 54 bytes 4124 bytes **** TAPE TRAILER **** MWD 04/01/14 466609 01 **** REEL TRAILER **** MWD 04/02/27 BHI 01 Tape Subfile: 4 2 records... Minimum record length: Maximum record length: 132 bytes 132 bytes ) Size Length 4 4 4 4 ------- 8 Tape Subfile 2 is type: LIS DEPTH 12030.5000 12031.0000 12050.0000 12100.0000 12150.0000 12200.0000 12250.0000 12300.0000 12350.0000 12400.0000 12450.0000 12500.0000 12550.0000 12600.0000 12650.0000 12700.0000 12750.0000 12800.0000 12850.0000 12900.0000 12950.0000 13000.0000 13050.0000 13100.0000 13150.0000 13200.0000 13250.0000 13300.0000 13350.0000 13400.0000 13450.0000 13500.0000 13550.0000 13600.0000 13650.0000 13688.0000 GR -999.2500 -999.2500 101. 8048 46.8416 38.6858 39.9094 69.0005 173.6237 52.9960 61.6686 123.7696 85.5713 81.2342 161.4411 153.6996 53.3684 43.2274 88.0991 110.2359 67.8339 42.9490 38.4993 44.5974 61. 9932 55.9860 43.6159 97.9458 49.0686 77.6033 106.0032 195.3597 36.3546 39.1706 55.7602 63.3610 -999.2500 Tape File Start Depth Tape File End Depth Tape File Level Spacing Tape File Depth Units ) ROP -999.2500 -999.2500 -999.2500 131. 8928 223.0516 44.1101 115.6569 132.6466 120.5746 104.4319 119.6718 140.4921 135.3018 110.9875 19.1806 119.6851 201.3762 100.6609 65.7230 91.0176 204.4586 80.1828 223.7163 137.7802 151.9816 187.4434 187.8647 224.3418 129.4665 106.0147 52.3358 243.7608 198.5045 181. 2936 163.9359 -999.2500 12030.500000 13688.000000 0.500000 feet ) ) Tape Subfile 3 is type: LIS DEPTH GRAX ROPS 12030.5000 -999.2500 -999.2500 12031.0000 41.8200 -999.2500 12050.0000 322.0300 -999.2500 12100.0000 47.5100 179.2000 12150.0000 52.1200 212.7200 12200.0000 50.7200 110.7200 12250.0000 108.3700 107.5500 12300.0000 118.2200 102.1200 12350.0000 53.5300 121.9700 12400.0000 73.2200 127.0100 12450.0000 123.8400 118.9800 12500.0000 81. 6500 135.7000 12550.0000 76.0300 116.3300 12600.0000 157.6000 109.2000 12650.0000 143.5300 62.9300 12700.0000 57.7500 102.5200 12750.0000 54.9300 195.5700 12800.0000 97.1200 109.0300 12850.0000 92.9000 53.0600 12900.0000 47.9000 161.5600 12950.0000 54.9300 178.2400 13000.0000 48.6050 156.3400 13050.0000 43.6800 176.2400 13100.0000 56.3400 121.1900 13150.0000 45.0900 144.9800 13200.0000 42.2800 187.9800 13250.0000 96.4200 180.2200 13300.0000 43.6800 232.1200 13350.0000 81. 6500 128.1600 13400.0000 99.9400 104.0400 13450.0000 184.3200 116.6200 13500.0000 36.6500 247.7800 13550.0000 43.6800 202.3400 13600.0000 54.9300 171.8200 13650.0000 69.0000 189.3200 13688.0000 -999.2500 -999.2500 Tape File Start Depth 12030.500000 Tape File End Depth 13688.000000 Tape File Level Spacing 0.500000 Tape File Depth Units feet
