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203-048
89k PST P716 U3116o Re9g, James B (CED) From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Sent: Tuesday, November 26, 2019 7:36 AM f To: Regq, James B (CED) �il(I Cc: AK, OPS FF Well Ops Comp Rep Subject: RE: East Dock #7, SSV gagged for flange leak Jim, PSI -07 SVS system has been returned to normal and is operational. ' Vince Vince Pokryfki GPB Pipeline and Well Ops Compliance BP Exploration (Alaska) Inc. P BOC — B103 Office (907) 659-5332 Cell (907)354-1352 Harmony — 7187 Alternate: Lee Hulme From: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com> Sent: Sunday, November 24, 2019 7:35 PM To: Regg, James B (DOA) <jim.regg@alaska.gov> Cc: AK, OPS FF Well Ops Comp Rep <AKOPSFFWellOpsCompRep@bp.com>; AK, OS GPB AOM <AKOPSG PBAOM @bp.com> Subject: East Dock #7, SSV gagged for flange leak Importance: High Jim, Notification that water injector PSI -07 has its LPP blocked for days and the defeated device is carried on the Safety Defeate AOGCC. Please call with any questions that you may have. Vince i Vince Pokryfki GPB Pipeline and Well Ops Compliance BP Exploration (Alaska) Inc. PBOC — B103 mce repairs. Repairs are expected to not exceed 5 log. Once returned to normal BPXA will notify the • STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMI WELL MPLETION OR RECOMPLETION REPO 'AND LOG la. Well Status: Oil 0 Gas 0 SPLUG ❑ Other ❑ Abandoned 0 ' Suspended 0 lb.Well Class: 20AAC 25.105 20AAC 25.110 Development H Exploratory 0 GINJ ❑ WINJ 0 WAG ❑ WDSPL 0 No.of Completions: Zero • Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or Aband.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 6/10/2017 • -. 203-048 • 317-020 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 4/9/2003 ' 50-029-20382-01-00 ' 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: • 4/17/2003 • PBU C-11A - Surface: 665'FNL,1222'FEL,Sec.19,T11N,R14E,UM • 9 Ref Elevations KB 61.83 17. Field/Pool(s): Top of Productive Interval: 2807'FNL,2376'FEL,Sec.19,-111N,R14E,UM GL 32.73 • BF 33.05 • PRUDHOE BAY,PRUDHOE OIL • Total Depth: 2684'FNL,1390'FEL,Sec.19,T11N,R14E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: ' 10485'/9015' • ADL 028305 • 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. DNR Approval Number: Surface:x- 664140• y- 5960549 • Zone - ASP 4 • 10645'/9017' • 80-274 TPI: x- 663041 y- 5958383 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 664024 y- 5958528 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No H 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) • 8193'/7687' ' 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper, resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary MWD,DIR,GR,RES,ABI,DEN,NEU SC ®®��ED JUL 1.2-017, 23. CASING,LINER AND CEMENTING RECORD CASING WT.PER GRADE SETTING DEPTH MD SETTING DEPTH ND HOLE SIZE CEMENTING RECORD AMOUNT TOP BOTTOM TOP BOTTOM PULLED 20"x 30" 32' 111' 32' 111' 36" 12.9 cu yds Permafrost Concrete 13-3/8" 72# L-80 31' 2667' 31' 2667' 17-1/2" 4301 cu ft Arctic Set 9-5/8" 47# L-80 29' 8193' 29' 7687' 12-1/4" 1276 cu ft Class'G',130 cu ft AS I 7" 26# L-80 2484' 9035' 2484' 8425' 8-1/2" 253 sx Class'G',438 sx Class'G',528 sx Class'G' 4-1/2" 12.6# L-80 8867' 10644' 8271' 9017' 6-1/8" 270 sx Class'G' 24. Open to production or injection? Yes 0 No ® 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): 4-1/2"12.6#L-80 8879' 8822'/8230' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. etgf4U00146-0 Wash draulic fracturinused during completion? Yes 0 No m • i)i'4 I- (),s'.L•I'(),s'. 20 AAC 25.283(i)(2)attach electronic and printed 1OP Tl F- RECEIVED information p 1-1 0-I.� DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED cptrlFn JUN 3 0 2017 10485' Set Whipstock AOGCC 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 ...3 Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corn): Press 24 Hour Rate """/ Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only ri-27.1 ) 17- RBDMS u , JUL - 6 2017 ' iCI ,of 7//7 7.7-(7 28. CORE DATA • Conventional Core(s) Yes 0 No El ' Sidewall Cores Yes El No II 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 El No H Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 9632' 8946' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. Sag River 9034' 8425' Shublik A 9070' 8458' Shublik B 9102' 8487' Shublik C 9123' 8507' Sadlerochit-Zone 4 9157' 8539' CGL-Zone 3 9355' 8727' Base of CGL-Zone 2C 9404' 8772' 23SB-Zone 2B 9431' 8796' 21 TS-Zone 2A 9632' 8946' Formation at total depth: Zone 2A 9632' 8946' 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. Authorized Name: Lastufka,Joseph N Contact Name: Leemhuis,Jacob Authorized Title: Inform ' and Dar on Iter Contact Email: Jacob.Leemhuis@bp.com Authorized Signature: /► �4Date: f5O/ii Contact Phone: +1 907 564 4989 INSTRUCTIONS General:This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska.Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. All laboratory analytical reports regarding samples or tests from a well must be submitted to the AOGCC,no matter when the analyses are conducted. Item la. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated.Each 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 ND for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only • Daily Report of Well Operations C-11 A ACTIVITYDATE SUMMARY RAN 40' x 3.70" DUMMY WHIPSTOCK AND SD HIGH @ 1,631' SLM RAN 20' x 3.70" DUMMY WHIP STOCK, 2.5" SAMPLE BAILER AND SD HIGH @ 1,632' SLM (no sample) RAN 2.50" SAMPLE BAILER AND STOP @ 3,000' SLM (no issues, full of hydrates) RAN 4 1/2" BRUSH, 3.25" GAUGE RING TO TOP OF PATCH @ 3,271' SLM (issues from 1630" to 1900') B&F W/4 1/2" BRUSH, 3.70" GAUGE RING TO TOP OF PATCH @ 3293' MD (Irs pumped 250bbls hot crude) DRIFTED TUBING WITH BOTH A 3.8" GAUGE RING AND 40' OF 3.7" DUMMY WHIPSTOCK TO 3293' MD. 3/18/2017 JARRED ON 45KB PATCH @ 3,272' SLM FOR 2hrs T/I/0=1850/1850/11 SI Assist SL as directed (CTD) Pumped 7 bbls meth followed by 200 bbls 180*crude and 70 bbls 100*crude down TBG, 270 bbls total. SL in control of well 3/18/2017 upon departure. CVs OTG FWHP=1000/2145/30 PULLED BAKER 45 KB STRADDLE PATCH FROM 3293' MD.(missing two elements) DRIFTED TUBING WITH 3.958" BRUSH AND 2.62" GRAB. (recover 4 pieces of element equalling 1 full piece) PULLED 4 1/2" x 2 7/8"X-NIPPLE REDUCER FROM 8846' MD. SET 4 1/2"WHIDDON ON XN NIPPLE @ 8853' SLM MADE UNSUCCESSFUL ATTEMPT TO PULL STA#3 @ 5,671' MD RAN 1.25" LIB TO STA#3 @ 5,671' MD (impression of latch, 2nd attempt) 3/19/2017 MADE 2 ATTEMPTS TO PULL STA#4 @ 3,297' MD T/I/0=1318/1277/36 Temp=Sl Assist SL as directed (CTD) Pumped 5 bbls meth followed by 60 bbls crude, 60 bbls 1% KCL CI MI KI-3869 .45%, 2 bbls meth spacer, 133 bbls DSL down IA to load and FP. Pumped 5 bbls meth followed by 290 bbls 1% KCL, 2 bbls meth spacer, 40 bbls DSL down TBG to load and FP. See log for details. FWHP=1318/1375/39 3/20/2017 Slickline still on well upon departure. Fluid packed annulus sign hung. PULLED BK-S/O FROM STA#3 @ 5,671' MD (check stuck open) MADE 2 ATTEMPTS TO PULL BK-LGLV FROM STA#4 @ 3,297' MD. SET BK-FLOW SLEEVE IN STA 3 @ 5671' MD. 3/20/2017 LRS LOADED IAAND TUBING AS PER PUMP PROGRAM PULLED BEK-FLOW SLEEVE FROM STA#3 @ 5,671' MD SET BK-DGLV IN STA#3 @ 5,671' MD PULLED EMPTY 4 1/2"WHIDDON FROM 8,853' MD 3/21/2017 ***WELL S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** CTU #14 - 1.75" Coil Objective: Mill XN. Mill CIBP. Dummy WS Drift. MIRU CTU. BOPs function tested upon initial rig up. SSV closure time 74 seconds. Make up and RIH with left hand milling assembly(parabolic mill), OAL = 19.73', Max OD = 3.8". Tag at 8851 CTMD and mill out XN, dry run to 8878'. POOH. Centralizer was 3.8" No Go. Make up and RIH with milling assembly (reverse clutch mill), OAL = 25.25', Max OD = 3.75". Hit a slight tight spot @ 9799' CTMD and milled through (no motor work). MIII CIBP @ 10,090' and begin to push it to to PBTD. 3/25/2017 ***In progress*** CTU#14 - 1.75" Coil ***Continued from WSR 3/25/2017*** Objective: Mill XN. Mill CIBP. Dummy WS Drift. Push CIBP to PBTD @ —10,550' CTMD. POOH and LD milling BHA. MU Packer WS drift BHA. RIH and tag @ 10547' CTMD. Freeze protect well with 38 bbls of 60/40. POOH to surface. Lay down WS drift BHA, all looks normal. RDMO 3/26/2017 ***Job Complete*** • S Daily Report of Well Operations C-11 A T/I/O = SSV/Vac/0. Temp= SI. IA FL (APE request). No AL. IA FL @ 520' (29 bbls). IA FL inconclusive on Vac, increased IAP from vac to 50 psi in 5 min with AL (C-33) to get definitive FL. 5/4/2017 SV, WV, SSV= C. MV= 0. IA, OA= OTG. 16:30 hrs CTU#14 - 1.75" CT(Set Whipstock) Road unit from DS-11. MIRU. BOP test. RIH with GR-CCL logging/WS drift BHA: OAL 35.58', max OD = 3.77'. Sat down at 9807', tried pumping, no luck. POOH to pick up a Venturi. RIH with Venturi BHA: OAL = 19.17', Max OD = 3.70". Tag TD down at top of CIBP with 2.5 klbs at 10549' (10558' - m). Performed 3 x Passes with Venturi. Start POOH. 5/17/2017 ***Job in Progress*** CTU #14 - 1.75" CT(Set Whipstock) ***Continued from WSR 05/17/2017*** POOH Venturi BHA to surface. Recovered chunk of metal and rubber pieces, and -5 cups of sand. RIH with logging and drift BHA: OAL 35.58', max OD = 3.77'. Could not go past 9814.6'. POOH. Pick up a mill. RIH with milling BHA: OAL= 25.71', max OD = 3.80". 5/18/2017 ***Job in Progress*** CTU #14 - 1.75" CT(Set Whipstock) ***Continued from WSR 05/17/2017*** POOH Venturi BHA to surface. Recovered chunk of metal and rubber pieces, and -5 cups of sand. RIH with logging and drift BHA: OAL 35.58', max OD = 3.77'. Could not go past 9814.6'. POOH. Pick up and RIH with milling BHA: OAL = 25.71', max OD = 3.80" to 10150' CTM. POOH. Change pack-offs. Start RIH with Venturi BHA. 5/18/2017 ***Job in Progress*** CTU #14 - 1.75" CT (Set Whipstock) ***Continued on WSR 05/20/2017*** RIH with Venturi BHA: OAL = 24.38', max OD = 3.70". Passed through 10150'with no issues. Tagged TD at 10550' (top of CIBP) with 2 klbs down. Performed 2 recips from 9700' to 10550'with pump on. POOH with Venturi BHA- recovered chunks of metal, rubber and 8 cups of sand. Run back in with Venturi BHA: OAL=24.38', max OD = 3.70". 2nd Venturi run yielded more fill and large pieces of CIBP Parts that could only be from TD MU Drift Logging BHA and RIH, tagged 4 time at 9815' mid point of drift. POOH MU and RIH with WS drift BHA: OAL = 24.74', max OD = 3.70". Run past 9815'with no issues. Tagged TD at 10550' and POOH with no issues. Freeze protected well with 33 bbls of 50/50 McOH. Lay down WS drift BHA. Start rigging 5/19/2017 down. T/I/0=10/0/0. Pre CDR2. Set 6"TWC#422 at 133". TWC LTT Pass. PT tree cap to 500 5/20/2017 psi. Pass. ***Job Complete***See log. T/I/O= TWC/0/0. Remove upper tree and install 6" CDR tree with TS-02. PT'd against TWC to 300/5000 PSI for 5 min each Pass. Installed 3" Piggy back temp IA valve#67. PT'd to 300/3500 psi for 5 min each Pass. RDMO ***job complete***See log for details.. 5/21/2017 Final WHPs = TWC/0/0. T/I/O = TWC/0/0. RD test spool#02 w/tapped blind flange from SV. RU temp second SV #55 w/tapped blind flange. RDMO. ***JOB COMPLETE***. See log for details. FWHP's = 6/2/2017 TWC/0/0. T/I/O = TWC/0/0. Temp = SI. WHPs (Pre Rig). No AL, wellhouse, SSV, and flowline. Prepared for rig. 6/2/2017 SV, SV, WV,WV= C. MV= O. IA, OA= OTG. 12:00 • North America-ALASKA-BP Page 1dikte Operation Summary Report Common Wet Name:C-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/7/2017 End Date:6/17/2017 X3-018C2-C:(2,849,198.00) Project:Prudhoe Bay Y Site:PB C Pad Rig Name/No.:CDR-2 Spud Date/Time:8/11/1979 12:00:00AM Rig Release:6/19/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000638 Active datum:C-11A @61.83usft(above Mean Sea Level) Date From-To i Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 6/7/2017 03:00 - 07:30 4.50 MOB P PRE RIG RELEASE FROM D-33 AT 0300 HRS ON 6/7/2017 -CONTINUE WITH RIGGING DOWN FROM D-33 07:30 - 08:00 0.50 MOB P PRE PJSM FOR MOVING OFF OF WELL D-33 INCLUDES: 12"X12"BLOCK IS IN PLACE ON MATS IN FRONT OF WELL TO PREVENT RIG ROLLING TOWARDS TREE -RADIOS ARE FUNCTION TESTED AND VERBAL COMMAND OF"STOP"IS UNDERSTOOD -HAND SIGNAL FOR"STOP"HAS BEEN DISCUSSED,4'RULE FOR PROXIMITY TO FIXED OBJECTS IN PLAY 08:00 - 10:00 2.00 MOB N WAIT PRE MOVE MODULES OFF OF D-33 WITH NO ISSUES. -STAGE MODULES ON D-PAD WHILE TOOL SERVICE CREW PLACES MATS ON PLANNED ROUTE. UNEXPECTED SOIL HAD BEEN LAID IN OVERNIGHT ON ROUTE WITHOUT ANYONE'S KNOWLEDGE. ROAD TOO SOFT TO MOVE SO MATS HAD TO BE LAID. 10:00 - 11:00 1.00 MOB P PRE MOVE MODULES TO C-PAD,STAGE MODULES ON PAD 11:00 - 12:30 1.50 MOB P PRE INSPECT TREE: IAAND OAAT 0 PSI,TREE VALVES CLOSED IN,MATTING GOOD,PLACE 12"X12"X20'BLOCK IN FRONT OF TREE. CONDUCT PRE-JOB SAFETY MEETING TO DISCUSS MOVE OVER WELL AND STOP POINTS. DISCUSS SAME VISUAL AND AUDIBLE COMMANDS OF"STOP". 12:30 - 15:00 2.50 MOB P PRE MOVE SUB MODULE IN PLACE OVER WELL -MOVE PITS MODULE AND COUPLE WITH SUB MODULE. RIG ACCEPT 1500 HRS. 1.15:00 - 00:00 9.00 RIGU P PRE PREPARE FOR OPERATIONS -PLACE SENSORS ON TREE,CYCLE VALVES I PER WELL PLAN CRITERIA -PREP LOCATION,STAGE SUPPORT EQUIPMENT 1-LEAK TIGHT TEST ON TREE CAP,NO VISIBLE LEAKS OR PRESSURE LOSS AT TREE -AOGCC REP MATTHEW HERRERA WAIVED WITNESS AT 20:18 -GREASE STACK AND CHOKE MANIFOLD. -NIPPLE UP BOPE. PERFORM PRE-SPUD WITH JURY'S CREW. 6/8/2017 00:00 - 03:00 3.00 RIGU P PRE COMPLETE NIPPLE UP OF BOPE. ANNULAR,BLIND/SHEAR,2-3/8"PIPE/SLIPS, MUD X,3"PIPE/SLIPS,2-3/8"x 3-1/2" VARIABLES,MUD X,BLIND/SHEAR,2-3/8" PIPE/SLIPS Printed 6/26/2017 10.04 43AM *All depths reported in Drillers Depths* • • North America-ALASKA-BP Page 2 apiCs Operation Summary Report Common Well Name:C-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/7/2017 End Date:6/17/2017 X3-018C2-C:(2,849,198.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:CDR-2 i Spud Date/Time:8/11/1979 12:00:OOAM Rig Release:6/19/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000638 Active datum:C-11A @61.83usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 03:00 - 07:00 4.00 BOPSUR ' P PRE CONDUCT BODY TEST,UPPER SWAB AND MASTER NOT HOLDING PRESSURE. ATTEMPT TO TEST AGAINST TWC,WOULD NOT HOLD ON INITIAL TEST. BLEED PRESSURE,RE-ATTEMPT AND PRESSURE �HELD. -TEST WITNESS WAIVED BYAOGCC REP -MATT HERRERA -DISCUSSED CLOSE APPROACH/ INTERSECTION CONTINGENCIES WITH C-PAD OPERATOR. CONFIRMED THAT C-30 IS CLOSED IN. 07:00 - 17:00 10.00 BOPSUR P PRE TEST BOPE TO 250 PSI LOW,3500 PSI HIGH FOR 5 MINUTES EACH -CONDUCT RAM LOCK TESTS IN CONJUNCTION WITH BOP RAM TESTS -TEST ALL AUDIBLE AND VISUAL ALARMS, ALL GOOD 17:00 - 20:30 3.50 BOPSUR P PRE -CONTINUE WITH FIX SOMBRARO/REPLACE 0-RINGS ON LOWER PORTION OF PDL'S -FLUID PACK COIL. TEST INNER REEL VALVE /PACKOFFS -PERFORM 250 PSI/3500 PSI 20:30 - 00:00 3.50 BOPSUR P PRE -VALVE CREW TEST TORQUE ON TREE/ SERVICE TREE VALVES -TEST BACKWARDS ON C9&C10 -RETEST TOP SWAB VALVE -TEST OFF DRILLERS PDL TO 250 LOW/3500 HIGH. GOOD TEST -DRAIN/STOW OFF DRILLER SIDE PDL. -TEST DRILLERS PDL TO 250 LOW/3500 HIGH. GOOD TEST 6/9/2017 00:00 - 04:00 4.00 CLEAN P PRE INSTALL AND TEST FLOATS. PU AND MAKE UP TO PULL TWC. PURGE STACK WITH METHANOL. PT LUBRICATOR TO 250 LOW/3500 PSI HIGH LATCH AND PULL TWC. WELL ON VACUUM PERFORM LTT TEST BETWEEN MASTER AND BOTH SWABS GOOD TEST. VERIFIED WE RETRIEVED TWC. OFFLOAD VALVE CREW EQUIPMENT. 04:00 - 06:45 2.75 CLEAN P PRE CLEAR AND CLEAN RIG FLOOR -LINE UP FLUIDS,VERIFY FLOW BACK TANK BLOWN DOWN. -MU NOZZLE AND STAB ON,DISPLACE COIL FROM FRESH WATER TO KCL. WELL ISOLATION WITH 2 CLOSED SWABS AND MASTER. -PJSM ON BULLHEAD KILL. OPEN MASTER, CONFIRM VALVE ALIGNMENT. Printed 6/26/2017 10:04:43AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page Operation Summary Report Common Well Name:C-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/7/2017 End Date:6/17/2017 X3-018C2-C:(2,849,198.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:CDR-2 Spud Date/Time:8/11/1979 12:00:00AM Rig Release:6/19/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000638 Active datum:C-11A @61.83usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 06:45 - 08:45 2.00 CONDHL P PRE BULLHEAD KILL WELL WITH 120°8.4 PPG 1% KCL AT 4.1 BPM,415 PSI INITIAL CIRC PRESSURE. -IAAT 160 PSI,OA 0 PSI WITH 60 BBLS AWAY -IA 825 PSI WITH 100 BBLS AWAY AT 4.0 BPM IAAT 1145 PSI WITH 200 BBLSAWAYAT4.0 BPM IAAT 1300 PSI WITH 250 BBLS AWAY CHASE KCL WITH 8.5 PPG HI-VIS MUD PILL FOLLOWED BY 8.5 PPG MUD SYSTEM. PUMP DOWN AT 4.0 BPM,1820 PSI AND SPOT HI-VIS PILL INTO PERFORATIONS. DOWN ON PUMPS. SLOW PRESSURE LOSS AS FLUID SETTLES INTO PERF ZONE. IA PRESSURE FELL OFF TO 425 PSI WITH PUMPS OFF AND FLUID SETTLING IN. 08:45 - 09:45 1.00 BOPSUR P PRE CONFIRM LINE-UP TO TIGER TANK WITH ISOLATION TO WELL WITH CLOSED IN SWAB VALVES. DISPLACE COIL TO MUD SYSTEM, FLUID PACKING LUBRICATOR WITH 8.5 PPG MUD. MONITOR PRESSURE ON MPD LINE (USED FOR KILL)AND FORMATION IS ON VERY SLIGHT LOSSES. -BRING ON PUMPS TO HAVE 200 PSI OVER PRESSURE BELOW SWABS(FORMATION PRESSURE). OPEN UP TO WELL WITH TESTED INJECTOR,CIRCULATE AT.5 BPM AND ESTABLISH ALMOST ONE-TO-ONE RETURNS. FLOW CHECK GOOD WITH NO !FLOW,VERY SLIGHT LOSS. 09:45 - 11:30 1.75 CLEAN P WEXIT PJSM FOR MAKING UP 3.80"CLEANOUT MILLING BHA#1 -POP OFF WITH INJECTOR,BREAK OFF NOZZLE AND STINGER ASSEMBLY -MAKE UP 3.80"MILL/STRING REAMER/ MOTOR ASSEMBLY TO BHI COILTRAK TOOLS WITH GAMMA RAY. BOTH D-331 AND STRING MILLAT 3.80"GO,3.79"NO-GO. -STAB ON,PRESSURE TEST QUICK TEST SUB -SERVICE REVERSE CIRCULATING VALVES WHILE MAKING UP BHA,TESTING QTS -BREAK CIRCULATION,WELL TOOK 5-1/2 BBLS FOR AVERAGE LOSS OF 3 BPH WHILE !AT SURFACE WITH NO PUMPS ON 11:30 - 13:00 1.50 CLEAN P WEXIT RIH TO 8700' -LOSING—30 BPH WHILE RIH AND CIRCULATING AT 1.25 BPM,1000-1200 PSI -MW IN 8.52 PPG,MW OUT 8.47 PPG,IAAT 410 PSI,OA AT 0 PSI 13:00 - 15:15 2.25 CLEAN P WEXIT LOG TIE-IN FOR GEO PDC WITH-9.5' CORRECTION -PICKUP AND LOG CCL FOR CORRELATION TO TUBING SUMMARY. LOG SHOWS JEWELRY AND MARKER JOINT VARIANCE BY —2-3'FOR EACH COMPONENT,PRETTY MUCH ON DEPTH WITH HANDOVER SUMMARIES. 15:15 - 15:45 0.50 CLEAN P WEXIT RIH WITH CLEANOUT BHA -SLACK OFF WEIGHT MOVING DOWN HOLE 23-25K;PICK UP WEIGHT 42-43K -DRY DRIFT WITH 3.80"MILL ON TRIP DOWN FROM 9400'TO 10,168';SET DOWN WITH 3.6K Printed 6/26/2017 10.04:43AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 4 owe Operation Summary Report Common Well Name:C-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/7/2017 End Date:6/17/2017 X3-018C2-C:(2,849,198.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:CDR-2 Spud Date/Time:8/11/1979 12:00:00AM Rig Release:6/19/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000638 Active datum:C-11A©61.83usft(above Mean Sea Level) Date From-To ' Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 15:45 - 18:30 2.75 CLEAN P WEXIT PICK UP,CLOSE EDC,BEGIN CLEANOUT MILLING RUN AT 2.5 BPM,2290 PSI FREE SPIN -IAAT 445 PSI -DURING PTM,PERFORMED PRESPUD WITH WARDS CREW. -CLEAN UP SECTION FROM 10,168-10,186' WITH SLIGHT MOTORWORK OF 40-50 PSI -PICK BACK UP,DRY DRIFT THROUGH WITHOUT ISSUE. COME BACK ON WITH PUMPS TO 2.5 BPM,WORK DOWN WITHOUT ANY DIFFICULTY TO 10,400',SOW 24K. PICK BACK UP WITH NO ISSUES,PUW 43K. WORK DOWN AGAIN WITH MILL AT 2.53 BPM,2330 PSI TO 10505'. WITHOUT ISSUE. -LOSING AVERAGE OF 27 BPH DURING CLEANOUT OPERATION 18:30 - 20:10 1.67 CLEAN P WEXIT i DRY DRIFTED ACROSS AREA TO BOTTOM, PUMPED 10 BBL HMS SWEEP. PULL UP TO 9200'. LOG CCL FOR BOTH LINER TOP AND WHIPSTOCK. COLLAR LOCATIONS 20:10 - 20:30 0.33 CLEAN P WEXIT MONITOR WELL FOR 10 MINUTES:STATIC -MUD WEIGHT:8.57 PPG IN,8.47 PPG OUT 20:30 - 22:30 2.00 CLEAN P WEXIT POH FROM 10500'MD TO 200'MD -MUD WEIGHT:8.56 PPG IN,8.46 PPG OUT -RATE:2.90 BPM IN,2.19 BPM OUT, CIRC PRESSURE:2087 PSI -IA PRESSURE:431 PSI, OA PRESSURE:0 PSI 22:30 - 00:00 1.50 CLEAN P WEXIT MONITOR WELL FOR 10 MINUTES AT BHA: STATIC -LAY DOWN BHA. GAUGE MILL AND STRING REAMER. 3.80"GO/3.79"NOGO -INJECTOR OFF:22:45 -PJSM, MAKE UP WHIPSTOCK BHA 6/10/2017 00:00 - 00:45 0.75 STWHIP P WEXIT MAKE UP WHIPSTOCK SETTING BHA#2 -SURFACE TESTED TOOL.GOOD TEST. -PRESSURE TEST QTS TO 250 PSI LOW FOR 5 MINUTES/3500 PSI HIGH FOR 5 MINUTES -INJECTOR ON:00:45 W 00:45 - 03:30 2.75 STWHIP P WEXIT 'RIH WITH WHIPSTOCK SETTING BHA#2 -RATE:0.31 BPM IN,0.74 BPM OUT.CIRC PRESSURE:923 PSI OPEN EDC, TRIPS -MUD WEIGHT:8.53 PPG IN,8.49 PPG OUT -LOG DOWN FOR TIE-IN FROM 9170'TO 9217.75'MD(FORMATION)WITH-8' CORRECTION CONTINUE IN HOLE SET DEPTH. PU WEIGHT 48K -RIH TO 10500.67'(10485'TOWS) 03:30 - 04:05 0.58 STWHIP P WEXIT SET WHIPSTOCK -CLOSE EDC.PRESSURE UP TO 3700 PSI AND RELEASE FROM WHIPSTOCK -TOWS:10485'MD -BOWS:10500.67'MD -SET 45 DEG ROHS -CONFIRM SET WITH 4.2K DOWN WEIGHT Printed 6/26/2017 10:04:43AM *All depths reported in Drillers Depths* M • North America-ALASKA-BP Page 5 aD Operation Summary Report Common Well Name:C-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/7/2017 End Date:6/17/2017 X3-018C2-C:(2,849,198.00) Project:Prudhoe Bay Site:PB C Pad Rig Name/No.:CDR-2 Spud Date/Time:8/11/1979 12:00:00AM Rig Release:6/19/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000638 Active datum:C-11A @61.83usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 04:05 - 07:15 3.17 STWHIP P WEXIT MONITOR WELL FOR 10 MINUTES:STATIC -MUD WEIGHT:8.56 PPG IN,8.47 PPG OUT -RATE:1.40 BPM IN,0.94 BPM OUT -POH FROM 10500'MD TO 200'MD -FLOW CHECK WELL WITH BHA BELOW BOP. FLOW CHECK GOOD,WELL ON VACUUM. -PULL BHA INTO BOP AND TAG UP POP OFF WITH INJECTOR AT 0715 07:15 - 08:30 1.25 STWHIP P WEXIT LAY DOWN WHIPSTOCK BHA MAKE UP 3.80"MILLING BHA#3. MILLS GAUGE 3.80"GO,3.79"NO-GO. MU TO COILTRAK TOOLS. STAB ON WITH INJECTOR AT 0830 08:30 - 11:00 2.50 STWHIP P WEXIT POWER ON TOOLS AND FUNCTION WHILE QTS IS PRESSURE TESTED RIH WITH 3.80"MILLING BHA -INITIAL IAAT 190 PSI,MW IN 8.5 PPG. BREAK CIRCULATION,4 BBLS LOSSES WHILE AT SURFACE -RIH AT.35 BPM IN,CIRC PRESSURE OF 715 PSI,IA INCREASED TO 250 PSI -LOG TIE-IN TO FORMATION WITH-9' CORRECTION RECORD PARAMETERS BEFORE MILLING: PICK UP WEIGHT 44K,SLACK OFF WEIGHT 25K AT 10,400' -RIH,ENGAGE WHIPSTOCK AT 10,486'. PICK UP,ON WITH PUMPS AND RE-ENGAGE AT 10 485' Vv t 11:00 - 17:15 6.25 STWHIP P WEXIT BEGIN MILLING OPERATIONS -CIRCULATION RATE OF 2.64 BPM,CIRC C„ Q 1 I PRESSURE 2400 PSI(FREE SPIN) l l rJ -IA 465 PSI,OA 0 PSI,LOSS RATE AT 2.64 BPM OF-12 BPH,MW IN 8.52 PPG,MW OUT 8.49 PPG -FOLLOW WELL PLAN FOR FIRST FOOT OF MILLING. INCREASE WOB TO 1.7-2.8K AT 2.65 1 BPM,2550 PSI TO MILL AHEAD. -MW IN 8.53 PPG,MW OUT 8.49 PPG,ECD OF 9.66 PPG,LOSS RATE FAIRLY CONSISTENT AT 6-7 BPH DURING MILLING NOSE OUT WITH MILL AT 3.6'IN TO MILLING, SLIGHT FALL OFF IN DIFFERENTIAL BUT WOB FELL FROM AS HIGH AS 2.8 TO.7-1.8K -MILLING WITH WINDOW MILL NOSED OUT HAS INCREASED IN SPEED FROM 1 FPH TO 1.2 FPH WITH LITTLE RESISTANCE-WOB DROPPED OFF TO AS LOWAS 120 LBS WITH BHA AT MIDPOINT AND STRING REAMER ACROSS WINDOW. HAVING BOT REP MAINTAIN CONSISTENT WOB WITH GOAL OF USING THE.6°BEND OF THE MOTOR TO GAIN SEPARATION. -DISCUSS AMONGST TEAM,TWO POSSIBILITIES:WHIPSTOCK FELL AWAY OR LITTLE OR NO RESISTANCE FROM CASING/ FORMATION DUE TO SET IN PERF ZONE. Printed 6/26/2017 10.04.43AM *All depths reported in Drillers Depths* North America-ALASKA-BP Page 6 04— Operation Summary Report Common Well Name:C-11 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/7/2017 End Date:6/17/2017 X3-018C2-C:(2,849,198.00) Project:Prudhoe Bay Site:PBC Pad Rig Name/No.:CDR-2 Spud Date/Time:8/11/1979 12:00:00AM Rig Release:6/19/2017 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000638 Active datum:C-11A©61.83usft(above Mean Sea Level) Date From-To Hrs Task I Code NPT Total Depth Phase Description of Operations (hr) (usft) 17:15 - 17:30 0.25 STWHIP P WEXIT PICK UP OFF WHIPSTOCK,PUW OF 45 K. PICK UP HOLE,DOWN ON PUMPS AND MOVE DOWN. SLACK OFF WEIGHT OF 23-24K. BOTH ARE IN RANGE OF ORIGINAL PARAMETERS. -MOVE DOWN,BHA TOOK WEIGHT AT WHIPSTOCK DEPTH. SET DOWN 2.3K. 17:30 - 20:30 3.00 STWHIP P WEXIT CONTINUE IN HOLE. NO REAL WOB AFTER MIDPOINT. TIME MILL TO END OF TRAY. GEO CALLED SAMPLES ALL FORMATION DRILL RATHOLE TO 10507' PUMP 10 BBLS SWEEP. MAKE TWO REAMING PASSES. SAWA LITTLE MOTOR WORK ON FIRST PASS. DRY DRIFT WINDOW,NO ISSUES 20:30 - 22:30 2.00 STWHIP P WEXIT MONITOR WELL FOR 10 MINUTES:STATIC -MUD WEIGHT:8.56 PPG IN,8.51 PPG OUT -RATE:2.71 BPM IN,2.22 BPM OUT 22:30 - 00:00 1.50 STWHIP P WEXIT MONITOR WELL FOR 10 MINUTES AT BHA: STATIC POWER DOWN INJECTOR OFF:22:50 3.80"GO/3.79"NOGO ON BOTH WINDOW MILL AND STRING REAMER 6/11/2017 00:00 - 01:20 1.33 DRILL P PROD1 MAKE UP 4.25"DRILLING BHA#4 -PICK UP 2-7/8"M1XLS MOTOR(0.94 DEG AKO)AND 3.0"COILTRAK TOOLS -MAKE UP 3.75"X 4-1/4"HCC 81-CENTER BIT -SURFACE TESTED TOOL.GOOD TEST. -PRESSURE TEST QTS TO 250 PSI LOW FOR 5 MINUTES/3500 PSI HIGH FOR 5 MINUTES -INJECTOR ON:01:20 PERFORMED MOCK RUN FOR UNDEPLOY SPACE OUT 01:20 - 04:15 2.92 DRILL P PROD1 RIH WITH 4.25"DRILLING BHA#4 -RATE:0.29 BPM IN,0.77 BPM OUT.CIRC PRESSURE:1039 PSI MUD WEIGHT:8.55 PPG IN,8.53 PPG OUT -LOG DOWN FOR TIE-IN FROM 10410'TO 10454.64'MD(FORMATION)WITH-14' CORRECTION -CLOSE EDC. PU WEIGHT 48K. RIH WEIGHT 25K -ORIENT FOR WINDOW 04:15 - 08:45 4.50 DRILL P PROD1 DRILL 4.25"LATERAL FROM 10507'MD FREE SPIN:2966 PSI,2.83 BPM -RATE:2.81-2.83 BPM IN,2.66-2.75 BPM OUT. CIRC PRESSURE:2966—3900 PSI -MUD WEIGHT:8.60 PPG IN,8.56 PPG OUT, ECD:9.90 PPG WITHOUT BACKPRESSURE, DRILLING MAINTAINING 11.1 PPG INFLUENCED ECD -ROP:DRILLING EXCEPTIONALLY FAST AT 160-225 FT/HR,WOB:.5—1.7KLBS. -LOSSES AVERAGING 3-8 BPH Printed 6/26/2017 10:04:43AM *AII depths reported in Drillers Depths* v , TREE= 6-3/8"aw FLS 411 WELLHEAD= FMC SAFE TES: WELL ANGLE>70°@ 9752. ACTUATOR= BAKER ( —1 i A v OKB.ELEV= 61.28' REF ELEV= 61.83' BF ELEV= 33.05' I ' 2206' 4-1/2"FES X NIP,D=3.813" ff KOP= 8100' Max Angie= 94°@ 10183' Datum MD= 9512' g X L R,L 2484' j—9-5/8"X 7"BKR ZXP LIP w/HGD=6.300" J — — Datum-VD= 8800'SS 2694' --19-5/8"DV PKR 113-3/8"CSG,72#,L-80,D=12_347"i—I 2666' 1 GAS LFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3297 3297 0 KBG-2 DOME BK 16 01/03/12 L 3 5671 5529 29 KBG-2 DMY BK 0 03/21/17 2 7467 7086 32 KBG-2 DMY BK 0 04/20/03 Minimum ID = 2.31" @ 8846' 1 8734 8150 25 KBG-2 DMY BK 0 04/20/03 4-1/2" X 2-7/8" NIP REDUCER Z I 8061' i—(9-5/8 X 7"BKR ZXP LIP w/HGR,D=6 280" , H EMD TT NOT LOGGED MLLOUT WINDOW 8193'-8209' TOP OF WF IPSTOCK J--L 8193' 19 518"CSG,47# L-80,D=8 681" j—[ —8193 8802' —{4-1/2"HES X NP,D=3.813" 8823' ,—L7 X 4-1/2"BKR S-3 PERM PKR,ID=3.875" 1 '► 8846' H4-1/2"HES X NP D=3.813" l .' ♦V•••iVVV_j �i _ J 8867' —4-1/2"HES XN NP MLLED TO 3.80"(03/25/17) 11.1.111 „"""' ! 8879' j-4 1/2"WLEG,D 3.958" } 8874' —7"X 5'BKR ZXP LTP lkik. w lIICR,ID=4.390" NI 9218' —MARKER Jowl 4-112"TBG,12.6#,L-80, —{ 8879' PERFORATION SUMMARY .0152 bpf,D=3.958" 4 10550'CTM —MLLED& PUSHED REF LOG MMD GR ON 04/07/03 CEP(3/25/17) ANGLE AT TOP PERF: 75°@ 9770' 17"LNR,26#,L-80, .0365 bpf,D 6.125" --I 9036' Nate:Refer to Production DB for historical pert data �e 4-1/2KB PKWHIPSTOCK(06/10/17) SIZE SPF INTERVAL OpnlSgz SHOT SQZ " R ._..___1--f 10486' 2" 6 9770-9800 0 12/29/16 3-3/8" 4 9810-9840 0 12/18/11 4\\\;, PBTD 1 10668' N`��' 3-3/8" 4 9910-9940 0 12/16/11 �___..._._ 2" 6 10025-10055 0 05/15/14 4-1/2"LNR,12.6#,L-80,.0152 bpf,D=3.958" H 10644' 2-1/2' 4 10140-10370 0 04/18/03 2-1/2" 4 10420-10555 0 04/18/03 DATE REV BY COMMENTS DATE REV BY COMbUdTS PRUDHOE BAY UNIT 03/28(80 ORIGINAL COMPLETION 02/27/17 CJWJMD GLV C/O(02/23/17) WELL: C-11A 04/21/03 DAV/KK RIG SIDETRACK(C-11A) 03/22/17 ZV/JMD PULLED PATCH&NP RED(03/19/17) PERMT No: 2030480 12/19/16 JMD PRE RIG CLEAN UP 03/22/17 ZV/JMO GLV GO(03/21/17) API No: 50-029-20382-01 01/04/17 DHSIJMD ADPERFS(12/29/16) 03/28/17 MZ/JMD'WILLED XN&PUSHED CBP DH SEC 19,T11N,R14E,665'FM..&1222'FEL 02/01/17 TH/JMD STA#4 BEHIND PATCH 06/27/17 JNJJMD SET 1A5(06/10/17) 02/01/17 JNJJMD ADDED OKB,REF&BF ELEV BP Exploration(Alaska) STATE OF ALASKA 0ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing El Change Approved Program 0 Plug for Redrill 0 Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: ❑ 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 203-048 3. Address: P.O.Box 196612 Anchorage, Development p Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20382-01-00 7. Property Designation(Lease Number): ADL 0028305 8. Well Name and Number: PRUDHOE BAY UNIT C-11A 9. Logs(List logs and submit electronic and printed data per 20AAC25.071): 10. Field/Pools: PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: +� R Total Depth: measured 10645 feet Plugs ���� ,� measured 10090 feet true vertical 9017 feet Junk measured feet JAN 3 0 7 201 Effective Depth: measured 10090 feet Packer measured 8822 feet G I I 1 true vertical 9022 feet Packer true vertical 8230.37 feet Or CC Casing: Length: Size: MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 31 -111 31-111 Surface 2635 13-3/8"72#L-80 30-2666 30-2666 4930 2670 Intermediate 8164 9-5/8"47#L-80 29-8193 29-7687 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 9770-9800 feet feet 9810-9820 feet 9820-9840 feet 9910-9930 feet 9930-9940 feet 10025-10055 feet 10140-10370 feet 10420-10555 feet True vertical depth: 9009-9015 feet feet 9017-9018 feet 9018-9019 feet 9021-9021 feet 9021-9021 feet 9021-9021 feet 9020-9015 feet 9016-9016 feet Tubing(size,grade,measured and true vertical depth) See Attachment See Attachment See Attachment Packers and SSSV(type,measured and See Attachment See Attachment See Attachment true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): r Treatment descriptions including volumes used and final pressure: �^ NEE) MAR Fey6 8 � 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 302 25553 79 840 751 Subsequent to operation: Shut-In 80 180 14.Attachments:(required per 20 AAC 25.070.25.071,a 25.283) 15.Well Class after work: Daily Report of Well Operations ® Exploratory ❑ Development I1 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil RI Gas 0 WDSPL 0 Printed and Electronic Fracture Stimulation Data 0 GSTOR ❑ 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 Phone +1 907 564 4424 Date 1/30/17 Form 10-404 Revised 5/20152/�!/V Ftp 74 i to. ( t7 RBDMS [x/ FE3 — 3 2017 Submit Original Only • • a) a. 0000000 a) r� c. � . 00 (o cflrvv �n �n � C N Lo ti C) M O� M M O O) CO N N 'Cr Cu CO CO CO CO f- Cr) Lf) I- N CO %_ CO CO I"- N �- 03 - COCO � � oNM I� � 00 O 00 M I 1 1 1 1 1 1 1 I- V CO - M CAaocoI� I,- CO M M N LO N N N N N- 00 M C Q E l" Cco O 0 Lo M OO) co CO — 0 0 0 00 U NCO CO CAOOOM as 1 1 I 1 1 ZZ Q = � OO) O:1) 26_ rsMo M co N N 000 COco N M < MOO 1...• 1111o o 0 0 • _ _ CO O O 00 00 00 J CO CO C yN1# JJcoco M y N� N X *k CV CV ~ - - CO CO r- OOO - N N - _ N _ 00 4 4 N t oMCOCOI� C co CO u) (A CO CO N CO to CA r 03 W Q C W O •5 0 W V O u_ o n c Z Z Z t W W W W m m ODI- ZZZDD U fn Z J J J I•- I- • • Packers and SSV's Attachment PRUDHOE BAY UNIT C-11A SW Name Type MD TVD Depscription C-11A PACKER 2491.79 2491.72 7" Baker ZXP Top Packer C-11A PACKER 3283 3282.86 4-1/2" Baker KB Top Packer C-11A PACKER 3318 3317.86 4-1/2" Baker KB Top Packer C-11A PACKER 8050.94 7577.08 7" Baker ZXP Top Packer C-11A TBG PACKER 8822.25 8230.37 4-1/2" Baker S-3 Perm Packer C-11A PACKER 8873.89 8277.43 5" Baker ZXP Top Packer a a O CO ;4 1-L - Nr 0- ii II 0) J CO Oci.) X o � cc 2 a ai Or- - w c Z Z a0 Lii1- -00 � Qa -3 _z as ° mi) Ow H c c wb � 0 WO U J a °') oa WW x N Q v- wc +- ZN CIS cC J O di (71 JZC - CD wwwE d V• FW a) Q ce 17- Q gZ = ' co _1 * ml- 0. U) v U) OaO 4, 0 0 Z— m-- W Y �. «- gyp W ZD F _°.] co E v0Z m ti U) 5c7) .8' Zi0 0 co oaZo cc a ct Nmo O m * O o .fl - a() � Wo 0 a 'C W Qo- m () c : Ea _jH = o 0 O > 2 W * CO aapONI—> NZ o.Cs = aom � �mN ON � (Ni > - 0 Q co a N C N 0 II ix a O D Q o Z O W NE SIL W rn Z N +J � . Q W '� p W LIJ o N = Z II 0 O -0 W _ N- 2 HQQZQ N 7OZ , U) � II >+Z J JJ � oo o . omwQcco - RN = J W- Q > m = .0 _ ,c03 v- II 2a2JW a) � -_ OU) 0 O fO Q a o < W W QZ > N a' s a' * 7' Pm * z ¢ * �* * o : a 0 a a a it * o Lu QCO CO CO CO o 0 N N N N O CO CO O) N N- N N N N m 17 0 N- < WEE= '' 6-3/8"CIW FLS • • oVVELLFEA.D= FMC 11 A SAFETY NOTES: WELL ANGLE>70"@ 9752. ACTUATOR= BAKER C in OKB.ELEV= 61.3' BF.ELEV= 34.10' KOP= 8100' , , �____ 2206' H4-1/2"HES X MP,13=3,.813" Max Angle= 94'@ 10183' Datum ND= 9512' 2484' ,—9-518"X 7 BKR ZXP LTP w/HGR,13=6.300"J Datum ND= 8800'SS i El 2694' --19-518"DV PKR 13-3/8"CSG,72#,L-80,D=12.347" 2666' 7 IS 3293'-3323' —BKR 45 WL KB STRADDLE PATCH (02/17/12)D=2.45^ S GAS LFT MANDRELS ST ND ND DEV TYPE VLV ,LATCH PORT DATE Minimum ID =2.31" 8$464 3297 3297 0 KBG-2 DOMBK 16 01/03/12 L 3 5671 5529 29 KBG-2 DONE BK 16 01/03/12 4-1/2" X 2-7/8" NIP REDUCER 2 7467 7086 32 KBG-2 DMY BK 0 04/20/03 1 8734 8150 25 KBG-2 DRAY BK 0 04/20/03 g S.- 8061• �-� MGR x 7"BKR ZXP LIP w GR p=6 280' ) H ELMD TT NOT LOGGED MLLOUT WINDOW 8193'-8209' TOP OF Wh#'STOCK J 8193' 9-5/8"CSG,47#,L-80,D=8.681" H —8193 8802' J-14-1/2"HES X MP,D=3.813" f ff $823• J-17"X 4-112"BKR S-3 PERM PKR,D 3,875" ' 8846' H 4-1 12"FES X NIP,D=3 813" NI V�V•••Y••• ' 8846' —4-1/2"X 2-7/8"NIP REDUCER 4•,, i (12128 /11),D=2.31" IM o ..1.... 886T —{4-112"HES XN NP,D=3.725" 114.1+1. $879' --`4-1/2"WLEG,p=3.958" PERFORATION SUMMARY 8874' —7"X 5"BKR ZXP LW RET LOG: MWD GR ON 04/07/03 �► w/HGR,ID=4.390" ANGLE AT TOP PERE: 75"©9770' NI Note:Refer to Production DB for historical pert data �� SCE SFF 14TERVAL OpriSgz SHOT SQZ 9218' JMARKERJONf 2" 6 9770-9800 0 12/29/16 4 10090' —4-1/2"CEP 3-3/8" 4 9810-9840 0 12/18/11 ` (12118/11) 3-3/8" 4 9910-9940 0 12/16/11 4-1/2'TBG, 12.6#,L-80, —{ 8879' 2" 6 10025- 10055 0 05!15114 .0152 bpi,D=3.958^ .j ` 10558' PI3TD 2-1/2" 4 10140-10370 C 04/18/03 2-1/2" 4 10420-10555 C 04/18/03 17'LNR,26#,L-80, 0365 bpf,p=6 125' H 9036' 41 N. 4-112"LNR,12.6#,L-80,.0152 bpf,D=3.958' 10644' DATE REV BY COM ENTS DATE REV BY COMvFNTS FRUDHOE BAY UNIT 03/28/80 ORIGINAL COMPLETION 05/19/14 LB/JM) ADPERFS(05/15/14) WELL: C-11A 04/21/03 DAV/KK RIG SIDETRACK(C-11A) 06/30/14 RB/PJC TREE CJO(06/26/14) PERMIT'No: 2030480 01/07/12 TBD/PJC PIAL PLUG GLV C/0(01/03/11) 12/19/16 ND FRE-RIG CLEAN UP API No: 50-029-20382-01 01/31/12 RCT/JM/XX PLUG SET(01/29/12) 01/04/17 DHS/JND ADPERFS(12/29/16) SEC 19,T11N,R14E,665'FTS&1222'FEL 02/20/12 JTC/JND SET STRADDLE PKR(02/17/12) 03/21/12 TJHIJM) FULL XX PLUG(03/20/12) BP Exploration(Alaska) oF rg • • 0,1":1// -4'.‘s,, THE STATE Alaska Oil and Gas At?�►.'i-�i��, of e LAsKA Conservation Commission 333 West Seventh Avenue rR ' GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS"' Fax: 907.276.7542 www.aogcc.alaska.gov John Egbejimba Drilling Supervisor c t � BP Exploration (Alaska), Inc. ,05 �'° P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU C-11A Permit to Drill Number: 203-048 Sundry Number: 317-020 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, Cathy P oerster Chair DATED this ZS day of January, 2017. RBDMS = 3 z017 STATE OF ALASKA • •LASKA OIL AND GAS CONSERVATION COMMI N APPLICATION FOR SUNDRY APPROV� 20 AAC 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 ®. Perforate New Pool 0 Re-enter Susp Well 0 Alter Casing 0 Other 0 2. Operator Name: BP Exploration(Alaska),Inc 4. Current Well Class: 5. Permit to Drill Number: 203-048 • 3, Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0. 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-20382-01-00 • 7. If perforating: 8. Well Name and Nu '•r+. What Regulation or Conservation Order governs well spacing in this pool? r z ®l Y/E Will planned perforations require a spacing exception? Yes 0 No I3• PBU C-11A • nn a� 7 D 9. Property Designation(Lease Number): 10. Field/Pools: JAN 13 2017 ADL 028305 PRUDHOE BAY,PRUDHOE OIL a ��z-r�• 11. PRESENT WELL CONDITION SUMMARY ACC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 10645- 9017• 10090 9022 2396 10090 None Casing Length Size MD TVD Burst Collapse Structural Conductor 79 20"x 30" 32-111 32-111 Surface 2636 13-3/8" 31 -2667 31-2667 4930 2670 Intermediate 8164 9-5/8" 29-8193 29-7687 6870 4760 Liner 6551 7" 2484-9035 2484-8425 7240 5410 Liner 1777 4-1/2" 8867-10644 8271-9017 8430 7500 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 9810-10555 9017-9016 4-1/2"12.6# L-80 27-8880 Packers and SSSV Type: 4-1/2"Baker S-3 Perm Packer Packers and SSSV MD(ft)and TVD(ft): 8823/8231 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary 13 Wellbore Schematic H 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch Ed Exploratory 0 Stratigraphic 0 Development Id • Service 0 14.Estimated Date for Commencing Operations: February 15,2017 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended ® • 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG ❑ 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 Hyatt,Trevor be deviated from without prior written approval. Email Trevor.Hyatt@bp.com Printed Name JohnEgbeejimba Title Drilling Supervisor / Signature `n/ ,t• . e Phone +1 907 564 4139 Date I i.. /201 7. ����JJJJ C/� COMMISSION USE ONLY ✓ Conditions of approval:Notify Commission so that a representative may witness Sundry Number: PlugIntegrity b'''''' � • 1- 02'0 g ty 0 BOP Test 19 Mechanical Integrity Test 0 Location Clearance 0 �� t +�5 () Other: 30 �-ts-.5 --fro 3 50 0 5 f I f} hnvlq✓ I���rvfvt �7✓ tri fa 2-500p51 ra✓t'Gi /I t /•Alirrhaic i1 l GcCtvnrvy+ GL�1J Post Initial Injection MIT Req'd? Yes 0 No Q J p r7 e r v f� C Z 5' Ij Z(u ) Spacing Exception Required? Yes 0 No Subsequent Form Required: /C — .q t' l APPROVED BYTHE Approved byaly P44.4.7(4.----- COMMISSIONER COMMISSION Date:i•-•Z.S..17 VI L LJy_4Ji, ORIGINAL RSDM S G FEB - 3 2017 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. Attachments in Duplicate ll /(7, /7 • • To: Alaska Oil &Gas Conservation Commission vir.N by From: Trevor Hyatt CTD Engineer 1G,I 0 Date: January 10, 2017 ' Re: C-11A Sundry Approval Sundry approval is requested to plug the C-11A liner perforations as part of the drilling and completion of the proposed C-11 B CTD sidetrack. History and current status: Well C-11 was drilled and produced in March 1980. In April 2003 a Rotary sidetrack was performed to C-11A because the original well developed a leak in the casing. In 2012, a 4-1/2" tubing patch was set over GLM#4. This well is currently not competitive and is ready for a sidetrack. Proposed plan: Nabors CDR2 Coiled Tubing Drilling rig will drill a through tubing sidetrack on or around June 1st, 2017. NIabors CDR2 will exit into lower Zone 2A formation in C-11 A perforations. The sidetrack will target Zone 1B and 2A reserves. The proposed sidetrack is a 2,940' MD horizontal Ivishak Zone 1B and 2A . producer_The lateral will be completed with a 3-1/2"x 3-1/4"x 2-7/8" L-80 liner which will be cemented and perforated isolating the current Zone 2A perforations. This Sundry covers plugging the existing C-11 A perforations via the C-11 B liner cement job or liner top packer set post-rig (alternate plug placement per 20 AAC 25.112(i)). The following describes work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current wellbore and proposed sidetrack is attached for reference. cc "cv�. ale svb,�rcr well proleco „-, �t (.70& Irl �'�i � rAevi f4 fi901 4ie. elhr"( ,'C/O '4144er- r't" 4r 6eh,ec "to dcf,1 O7 74e f% R.020 r- g11`e^ell 4*/". C),cl'4 47.1 �°✓L !�1 0 6vI1 f 'rTf `` 4h1 /e G141,:ie /(v91(1`," ,f we'll fur �vG� 1a � rr ci f fro, ► ; j / roof or dr ,11( 9/icxifcI w lle.- �'�� 0,6 /90o(, vfr/7 • o Pre-Rig Work 1 S Fish Patch. Set TTP. Pull GLV 3. Circulate IA. Dummy Valves. Pull TTP, Pull Nipple Reducer 2. F Assist SL: Circulate IA to Diesel, MIT-OA, CMIT-TxIA 3. C Mill XN, Mill CIBP, Dummy WS drift to 10,485' MD 4. V Set BPV and Pre CTD Tree Work Rig Work: 1. MIRU and test BOPE to 250 psi low and 3,50.0 psi high. Maximum expected surface pressure with gas (0.10 psi/ft)to surface is 2,396 psi. 2. Set 4-1/2" KB Packer Whipstock. 3. Mill 3.80"window plus 10'of rathole. Swap the well to 8.5-9.5 ppg drilling mud. 4. Drill 4.25"hole to TD at -13,425' MD 5. Run 3-1/2"x 3-1/4"x 2-7/8" L-80 liner leaving TOL at -9,650' MD. 6. Pump primary cement bringing TOC to between 9800' MD and TOL, 35.5-39.9 bbls of 15.3 ppg liner cement planned" 7. Cleanout liner and run GR/CCURPM log if cement job does not go as planned. 8. Test liner lap to 2,400 psi. d' 9. Freeze protect well, RDMO Post Rig: 1. V:Tree work as necessary. 2. S: LTP if necessary*. 3. F: Pressure Test LTP if necessary. 4. T:ASRC flowback. Approved alternate plug placement per 20 AAC 25.112(i) Trevor Hyatt CTD Engineer 564-4627 CC: Well File Joe Lastufka TRS= 6318"CMV FLS • SAFETIWTES: WELL ANNE>70° 9752. WELLHEAD= FMC C 11 A ACTUATOR= BAKER OKB.ELEV= 61.3' BF.ELEV= 34.10' KOP= 8100' Max Angle= 94 @ 1018833' U U 2205' H4-112"HES X NP,D=3.813' Datum MD= 9512' Datum TVD= 8800'SS J g 2484' --19-518"X 7"BKR ZXP LNR TOP PKR —, 2594' H9-5/8"DV PKR 13-3/8"CSG,72#,L-80,ID=12.347" —{ 2666' co g 3293'-3323' —BKR 45 WL KB STRADDLE PATCH (02/17/12)D=2.45" la S GAS LFT MANDRELS ST MD TVD DEV TYPE VLV LATCH FORT DATE _ 4 3297 3297 0 KBG-2 DOME BK 16 01/03/12 Minimum ID =231" @ 8846' L 3 5671 5529 29 KBG-2 DOME BK 16 01/03/12 4-112" X 2-7/8" NIP REDUCER 2 7467 7086 32 KBG-2 DMY BK 0 04/20/03 1 8734 8150 25 KBG-2 DM' BK 0 04/20/03 $ 8051' H9-518"X 7"BKR ZXP LNR TOP PKR --I ELMD TT NOT LOGGED MLLOUT WINDOW 8193-8209' TOP OF WHIPSTOCK —I 8193' r 8802' {41/2"HES XNIP,D=3.813" 9-518"CSG,47#,L-80,D=8.681" — —8193 8823' —17"X 4-1/2"BKR S-3 PERM PKR 8846' H4112'HES XNIP,D=3.813" N'//I: 41/2"X 2-718"NMS RWUCER 1i (12/28/11),1D= 2.31" Al """. 886T --14-1/2"I-ES XN NP,D=3.725" 11111/14. 8879' —14-112"WLEG,D=3.958" PERFORATION SUMMARY REF LOG MWD GR ON 04/07/03 •4a. 8874' —7"X 5"BKR ZXP ANGLE ATTOP PEW: 84°@ 9$10' • I LNR TOP PKR Note:Refer to Production DB for historical pert data 1� �� SIZE SPF INTERVAL Opn/Sgz SHOT SOZ 6� 9218' —iMAI�CERJOM 3-3/8" 4 9810-9840 0 12/18/11 (4$• 'a'0' —4-1/2"CBP 3-3/8" 4 9910-9940 0 12/16/11 , ` (12/18/11) 2" 6 10025-10055 0 05/15/14 4-1/2"TBG,12.6#,L-80, — 8879' 1' 2-1/2" 4 10140-10370 C 04/18/03 -- 2-112" 4 10420-10555 C 04/18/03 0152 bpf,ID=3.958" v:,�$tj 10558' PBTD ` 7"LNR,29#,L-80,.0365 bpf,ID=6.125' H 9035' 4,\ 4-1/2"LNR,12.6#,L-80,.0152 bpf,D=3.958" — 10644' . DATE REV BY COMMENTS DATE REV BY COI EMITS PRUDHOE BAY UNIT 03/28/80 ORIGINAL COMPLETION 05/19/14 LB/JMD ADFERFS(05/15/14) WELL: C-11A 04/21/03 DAV/KK RIG SIDETRACK(C-11A) 06/30/14 RB/PJC TREE CJO(06/26/14) FERMI No: 2030480 01/07/12 TBD/PJC RLL PLUG-GLV C/O(01/03/11) AR No: 50-029-20382-01 01/31/12 RCT/JM)XX PLUG SET(01/29/12) _ SEC 19,T11N,R14E,665'FAL&1222'FEL 02/20/12 JTC/JMD SET STRADDLE PKR(02/17/12) 03/21/12 TJWJMD RLL XX PLUG(03/20/12) BP Exploration(Alaska) WELLHEAD- FMC S LL TEs: WEANGLE>70°@ ACTUATOR= PROP SED C-1 1 B OKB.ELEV= 61.3 BE REV= 34.10' KOP= 8100• ' i 2205' J-14-1/2"FES X NIP,D=3.813", Max Angle= -04----- - 2484' 1.-19-5/8"X 7"BKR ZXP OP w/HGR,D=6.300' Datum MD= S X Datum ND= 8800'SS — — r 2594 9-5/8"DV PKR 13-3/8-CSG,72#,L-80,D=12.347" 1 r 2666' i GAS LFT MANDRELS ST NO ND DEV TY FE VLV LATCH PORT CATE 4 3297 3297 0 KBG-2 DONE BK 16 01/03/12 Minimum ID =2.377" 1O685' 3 5671 5529 29 KBG-2 DOME BK 16 01/03/12 3-3/16" X 27/8"XO 2 7467 7086 32 KBG-2 DMY BK 0 04/20/03 1 8734 8150 25 KBG-2 DMY BK 0 04/20/03 Z. 8051' .._J—{9-518"X 7"BKR ZXP LTP w/HGR D=6.280" r HTaMD TT NOT LOGGED J 9-5/8"CSG,47#,L-80,D=8_681' .1-1_ - 8193 MLLOUT VVI DOW 8193'-8209' I , `_-8802' 1-14-1/2"FES X NP,D=3.813" x I 882.Y1--17"X 4-1/2"BKR S-3 PERM PKR D=3.875"J Ell ' l__ 8846' H4-1/2"HES X NP,D=3.813" ' ' 8867' 4-1/2"FES XN NP MLLED TO 3.80"( / /_) �- 8874' —17"X 5"BKR ZXP LTP w/HGR D=4.390" 4-1/2"TBG,12.6#,L-80, H 8879' - 0152 bpf,D=3.958" $� 8879' —4-1/2"WLEG,D=3.958" 7"LW,26#,L-80,.0365 bpf,D=6.125" [—j 9036' f I , I • 9218' HMARKt32JOrtf ITOPOF 3-1/2"X 3-3/16"X 2_7!8"LNR J--{ - 9660' t--• [ _9660' —13.70"DEPLOY SLV,ID=3.00" -13-112"_XMP,D=2.813" 3-1/2'LNR, #,L-80 STL, H 10475' I 10476' --I3-1/2"X 3-3/16"XO,D=2.786" .0087 bpf,D=2.992" [41/2"KB PKR WHPSTOCK(_/—/_J I--L__10486' tLLOUT WIDOW(C-11B)10485- ' 4-1/2"LNR,12.6#,L-80..0152 bpf,D=3.958' --{ —10486' 13-1/4"LNR 6.6#,L-80 TC11,.0079 bpf,D=2.85" 1—{ 10686' I 0686'_J—I3-3116"X 2-718"XO,D=2.377" F432FORATION SU1I,AARY REF LOG: ON / / II_ PUP Jr w/RA TAG ANGLE AT TOP PERF: "Q Note:Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz SHOT SQZ I I _ [PUPJTw/RA TAG PBTD — [2-718"LNR 6.5#,L-80 STL,.0058 bpf,W.)=2.441"_I-1 13426' DATE REV BY COMMENTS DATE REV BY COMENTS PRUDHOE BAY INT 03/28/80 ORIGINAL COMPLETION WELL C-11B 04/21/03 DAV/KK RIG SIDETRACK(C-11A) - PERMIT No: / / CTD(C-11B) AR No: 50-029-20382-02 12/19/16 JMD BULT PROPOSED SEC 19,T11N,R14E,665'FNL&1222'FEL BP Exploration(Alaska) Well • Blank •R2-AC BOP Schematic Se _ Quick Test Sub to Otis Topof7"Otis O.Oft ._.—.—.—.—.—._._._ _ _._.._._._ CDR2 Rig's Drip Pan l 1 Distances from top of riser Excluding quick-test sub 0 Top of Annular =Mr= ior,000l \ 7-1/16"6k Flange X T'Otis Box C - Hydril71/16" Top Annular Element 0.7 ft Annular J Bottom Annular 2.0 ft ► 21==b1 -�- _��r�0 _■- Cu Blind/Shears 3.3 ft ( O O O 0 2-3/8"Pipe/Slips CL 2-3/8"Combi's 4.1 ft ►n, "" -.EMI BS I I B6 "" " " B7 I BrB ��T-I Fri1,4010• TL16 � lj1d0H10�C1'' 5k Mud �; I �� li JJJLLL Cross El Choke Line 3"Pipe/Slips III CL 3"Pipe/Slips 6.6 ft ix, .xiiiirl 0. t� 2-3/8"x 3-1/2"VBR CL 2-3/8"x3-1/2"VBRs 7.4 ft B1 i 11 82 B3 I B4 Choke Line FT_ 01114.4-I"-0 010114.4111141411# 0 Blind/Shear III CL Blind/Shears 10.0 ft ► "i —MooIII - 2-3/8"Pipe/Slips CL 2-3/8"Combi's 10.7 ft ► ,-1111..."I �� x' • CL of Top Swab 13.3 ft �� 1---Swab 2 Test Pump Hose ,/Swab 1 CL of Bottom Swab 14.8 ft till. T1 if T2 IK CL Flow Tee 16.2 ft •• •�• = BOP2 CL of SSV 17.5 ft 1 =T1 Master 2 } Fusable CL of Master Valve 19.0 ft BOP1 Master 1 LDS 20.5 ft ----...,_ _ .. .. .. .. ., fes. II II II II 11 Gound Level r• , I. ii II II ii I I • • • N 0 Produced Gas (Thousand Cubic Feet ("MCF") per Day) andr. Gas-Oil Ratio (MCF per Barrel) 0 O 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 0 , o - .0i 001 00 O^ 10 Ln M N .-1 o 4.) Egra' S's l 9r r° c �i •.err-� .5, r0 E •i -4► /<bci m 4l O q0s o I _ 1 � 0 E D rel I Tia c I 0 0 _ 'r Tu �l9' 0 0 i* f0 E t d ‘ I C R h - -----------------------------•--------------- l rq ca o o rr1 ° 3 P 31-1 t.) to tV Ln "( Or ALIO o -82T_ I— •• c �p1s ro Q O l Z = .O -; 0r 0 o � u �� ------- - A3y1„, ...._ / a' 'O O - (5% l0 0 ++ I O i P v U CI"L a 3 = Q _ CO T3 O (7 U U , y,,,,,iwia 0 G1°/ Y CO •-- < r0 Fo- o 0erS fl d 97P�r cc Q liiiim 0 o c :00II S l0 >. ro I 're, v D OQd� o �o a 4oG 00 Q Pes / r 0 0 0 0 0 0 0 0 0 0 0 -rP 0 / I 0 00 10 .1 N 0 0 0 0 0 O CO00 lN `"`I. N .-i .-i .-i .-i .-i 0 Aea .ied JaleM lo shins pue Aea aad No jo wing 0 0 a 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 .< a 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. I • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWellIntegrityCoordinator@bp.com> Sent: Sunday, October 25, 2015 6:49 PM To: AK, OPS GC3&PCC OSM; AK, OPS GC3 Facility OTL; AK, OPS GC3 Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan;AK, D&C Well Services Operations Superintendent;AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr;AK, RES GPB East Wells Opt Engr;AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; AK, OPS Well Pad CX; Haffener, Jordan; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator;AK, D&C DHD Well Integrity Engineer;AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R; AK, OPS FF Well Ops Comp Rep; Morrison, Spencer; Sayers, Jessica; Dickerman, Eric; Regg, James B (DOA) Subject: OPERABLE: Producer C-11A (PTD#2030480) MIT-T and CMIT T x IA Passed All, Producer C-11A(PTD#2030480) passed a MIT-T and a CMIT-T X IA on October 24, 2015 after a tubing tail plug was set. The passing tests confirm two competent barriers in the wellbore. The well is reclassified as Operable. • Well status is Operable • Annuli are fluid packed • A SSSV is not required Use caution while placing the well on production due to fluid packed annuli and the potential of annular fluid expansion. Thank you, Kevin Parks !A!tc0 0,,tc BP Alaska-Well Integrity Coordinator gljellobals Gzation SKO AUG 1 1 NIS CM4 Office: 907.659.5102 WIC Email:AKDCWeIlIntegrityCoordinator@bp.com From: AK, D&C Well Integrity Coordinator Sent: Sunday, October 11, 2015 11:37 AM To: AK, OPS GC3&PCC OSM; AK, OPS GC3 Facility OTL; AK, OPS GC3 Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead; AK,OP&GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline.Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK OPCS PCC Ops Lead; AK, OPS Well Pad CX; Haffener, Jordan; 'chris.wallace@alaska.gov' Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD WellTntegrity Engineer; AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R; AK, OPS FF Well Ops Comp Rep; Morrison, Spencer; Pettus, Whitney; 'Regg, James B (DOA) (jim.regq@alaska.gov)' Subject: UPDATE October 11, 2015: UNDER EVALUATION: Producer C-11A (PTD #20 0) Sustained Inner Annulus Casing Pressure over MOASP All, i • • Wallace, Chris D (DOA) From: AK, D&C Well Integrity Coordinator <AKDCWelllntegrityCoordinator@bp.com> Sent: Sunday, October 11, 2015 11:37 AM To: AK, OPS GC3&PCC OSM; AK, OPS GC3 Facility OTL; AK, OPS GC3 Field OTL; AK, OPS GC3 Operators; AK, OPS GC3 Wellpad Lead;AK, OPS GC3&PCC OSM; Cismoski, Doug A; Daniel, Ryan; AK, D&C Well Services Operations Superintendent; AK, D&C Wireline Operations Superintendent; AK, RES GPB West Wells Opt Engr; AK, RES GPB East Wells Opt Engr; AK, OPS Prod Controllers; AK, OPS PCC Ops Lead; AK, OPS Well Pad CX; Haffener, Jordan; Wallace, Chris D (DOA) Cc: AK, D&C Well Integrity Coordinator; AK, D&C DHD Well Integrity Engineer; AK, D&C Projects Well Integrity Engineer; Sternicki, Oliver R; AK, OPS FF Well Ops Comp Rep; Morrison, Spencer; Pettus, Whitney; Regg, James B (DOA) Subject: UPDATE October 11, 2015: UNDER EVALUATION: Producer C-11A (PTD #2030480) Sustained Inner Annulus Casing Pressure over MOASP Attachments: Producer C-11A (PTD # 2030480) TIO Plot.docx All, Producer C-11A(PTD#2030480)was found to have sustained inner annulus casing pressure over MOASP on October 09, 2015.The pressures were confirmed to be TBG/IA/OA= 2385/2050/30 psi. The well remains Under Evaluation until diagnostics have been completed. If operationally possible, please place the well on production to manage inner annulus pressure until wireline intervention can be performed. Plan Forward: 1. Downhole Diagnostics: Bleed inner annulus to 300 psi— DONE 10/09/15 2. Operations: If possible, place well on production to manage inner annulus pressure 3. Slickline: Set tubing tail plug 4. Fullbore: MIT-T&CMIT-TxIA 5. Well Integrity Engineer: Additional diagnostics as needed A copy of the TIO plot has been included for reference. Please call with any questions or concerns. Thank you, Whitney Pettus SCANNED AUG 0 4 2016 (Alternate:Kevin Parks) BP Alaska-Well Integrity Coordinator G WIC Office: 907.659.5102 WIC Email: AKDCWeIllntegrityCoordinator(caBP.com From: AK, D&C Well Integrity Coordinator Sent: Sunday, October 04, 2015 9:32 AM To: AK, OPS GC3&PCC OSM; AK, OPS GC3 Facility OTL; AK, OPS G tial OTL; AK, OPS GC3 Operators; AK, OPS GC3 1 Producer C-11A(PTD#2030480) TIO Plot October 11, 2015 TM —III—LA .a—OA 00 --a—000A ▪ Oa 041v'15 00415 0925+15 010115 0406155 08!5,11 062215 062615 10005 e e Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ;¿,O 3> - 0 Y-.ß Well History File Identifier Organizing (done) o Two-sided 1111111111111I11111 o Rescan Needed ""11/1111" 11I11/ RES CAN ~olor Items: o Greyscale Items: DIGITAL DATA ~skettes, No. ~ o Other, No/Type: 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: NOTES: Date 10 W DS" o Other:: BY: ~ 151 V}1f BY: ~ Date fa fct-t 0 5 ~ 100 Date: it; OS 151 1111111111111111111 W\f (os- (Y\P Project Proofing Scanning Preparation BY: + 5 = TOTAL PAGES (Count does not include cover sheet) 151 Production Scanning 1111111111111111111 Stage 1 Page Count from Scanned File: {¡; (p (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: ~ Date: (p / q / oS- 151 '0'\ P Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: 151 '" II 111111I" "III Scanning is complete at this point unless rescanning is required. ReScanned III II 1111111111111I BY: Maria Date: 151 Comments about this file: Quality Checked III 111/11111 II 1111I 10/6/2005 Well History File Cover Page.doc STATE OF ALASKA ALASKA. AND GAS CONSERVATION COMMISSI4110 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations El Stimulate ❑ Other ❑ Performed: Alter Casing ❑ PuII Tubing ❑ Perforate New Pool ❑ Waiver❑ Time Extension ❑ Change Approved Program ❑ Operat. Shutdown ❑ Perforate 0 Re -enter Suspended Well ❑ 2. Operator BP Exploration (Alaska), Inc. 4. Well Class Before Work: 5. Permit to Drill Number: Name: Development El Exploratory ❑ ' 203 -0480 3. Address: P.O. Box 196612 Stratigraphic Service ❑ 6. API Number: Anchorage, AK 99519 -6612 - 50- 029 - 20382 -01 -00 8. Property Designation (Lease Number) : 9. Well Name and Number: ADL- 028305 • PBU C -11A 10. Field /Pool(s): PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 10645 feet Plugs (measured) 10090 feet true vertical 10357.23 feet Junk (measured) NONE feet Effective Depth measured 10557 feet ? ‘''''I # "y' " ` kF Pecker (measured) SEE BELOW feet true vertical 9015.82 feet (true vertical) SEE BELOW feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110 20 "94# H -40 34 - 144 34 - 144 1530 520 Surface 2633 13 3/8 "72# L -80 33 - 2666 33 - 2666 4930 2670 Production 8161 9 5/8" 47# L -80 32 - 8193 32 - 7687 6870 4760 Liner 6551 7" 29# L -80 2484 - 9035 2484 - 8425 8160 7020 Liner 1765 4 1/2" 12.6# L -80 8879 - 10644 8282 - 9017 8430 7500 Perforation depth: Measured depth: SEE ATTACHED - _ - True Vertical depth: _ _ - - - Tubing: (size, grade, measured and true vertical depth) 4- 1/2" 12.6# L -80 29 - 8879 29 - 8282 Packers and SSSV (type, measured and true vertical depth) 7" BKR ZXP LNR TOP PKR 2484 2484 9 -5/8" DV PKR 2594 2594 7" BKR ZXP LNR TOP PKR 8051 7577 4 -1/2" BKR S -3 PERM PKR 8823 8231 5" BKR ZXP LTP 0 ! VF r� X 874 8278 12. Stimulation or cement squeeze summary: Intervals treated (measured): J HIV . 3 2012 Treatment descriptions including volumes used and final pressure: Maltkti Oh & 6as Cons. Goonnii3SiMi 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 576 35,876 69 871 Subsequent to operation: 663 34,338 67 185 14. Attachments: 15. Well Class after work: Copies of Logs and Surveys Run Exploratory Development ID - Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil • 0 Gas ❑ WDSPL ❑ GSTOR ❑ WINJ p WAGE 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: NA Contact Nita Summerhays Printed Name Nita Summerhays rn / Title Data Manager ,- Signatur&._.' ,., <. , ,,_ Phone 907 - 564 -4035 Date 1/13/2012� / 1. ye- �f . Form 10-404 Re S JAN 13 2012 l / ' / 3 . / Z Submit Original Only C -11 A 203 -048 PERF ATTACHMENT Sw Name I Operation Date Perf Operation Code 1 Meas Depth Top Meas Depth Base Tvd D e pth Top Tvd Depth Base C -11A 4118/03 PER 10,140. 10,370. 9,020.31 9,015.29 C -11A 4/18/03 PER 1 10,555. 9,015.95 9,015.78 C -11A 12/16/11 APF 9,910. 9,930. 9,020.69 9,021.18 C -11A 12/16/11 APF 9,930. 9,940. 9,021.18 9,021.2 C -11A 12/16/11 BPS 10,090. 1 9,021.871 9,015.78 C -11 A - -__ ' 12/17/11 ',APF 9,820. i _ 9 840. 9,017.52'i 9,018.51 � 1 -. , 9,016.61, , . - -- - - 9,017.52 C -11A 12/18111 APF 9,810. 9,820. 9,016.61 C -11A L 12/28111 BPS 8,846. 10,090. 9,021.87 C -11A 1/3/12 BPP 8,846. 10,090. 8,252.01 9,021.87 AB ABANDONED PER PERF APF ADD PERF 1 RPF REPERF • BPP BRIDGE PLUG PULLED SL SLOTTED LINER L BPS 'BRIDGE PLUG SET 1 SPR SAND PLUG REMOVED FCO I FILL CLEAN OUT SPS SAND PLUG SET l FIL FILL L ISQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED 1 SQZ :SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO f STRADDLE PACK, OPEN 1 OH [ OPEN HOLE • • . C -11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 1 ACTIVITYDATE SUM Rif " . i 12/14/2011 ** *WELL SHUT IN ON ARRIVAL* ** (E -LINE WELLTEC: SET PLUG PERF) INITIAL T /I /O 1700/1800/0 ARRIVED TO LOCATION. GOT PERMIT SIGNED AND BEGAN SPOTTING EQUIPMENT. ** *JOB IN PROGRESS * ** TO BE CONTINUED ON 15- DEC -2011 12/15/2011 ** *JOB IN PROGRESS FROM 14- DEC - 2011 * ** AT 9840' BEGIN TRACTORING TO 10100' STAYING ABOVE PERFORATIONS AT 10140'. RAN JUNK BASKET FROM 10100' -8700' AT 150 FPM. PULLED JEWELRY LOG FOR FUTURE REFERENCE, (TIE -IN TO SPERRY SUN MWD ROP /DGR /EWR APR -7 -2003 THROUGH APR -18- 2003). AT SURFACE NOTHING WAS FOUND IN JUNK BASKET. POOH AND MADE UP TOOLSTRING FOR SECOND RUN WITH HES PLUG. PERFORMED CHECKS AT SURFACE AND QTS PT. BEGAN RIG AND NOTICED GAS LEAKS IN 10FT LUBRICATOR CONNECTIONS. RIG DOWN AND CHANGED ALL THE LEAKING O- RINGS. O -RINGS WHERE FLAT FROZEN WHEN THEY WERE CHANGED. MADE UP LUBRICATOR AND PERFORMED TOOL CHECKS AT SURFACE AGAIN. PRESSURE TESTED LUBRICATOR AND NO LEAKS WERE OBSERVED. PROCEEDED TO RIH AT 100 FPM. ** *JOB IN PROGRESS * ** TO BE CONTINUED 16- DEC -2011 12/16/2011 * ** JOB IN PROGRESS FROM 15- DEC - 2011 * ** RIH TO DEVIATION AT 9800'. STARTED TRACTOR AND KEPT RIH DOWN TO 10101' CCL DEPTH AND 10119' BOTTOM OF PLUG. PERFORMED TIE IN PASS USING SLB JEWELRY LOG 12/15/11 AND PULLED TO SETTING POSITION AT MIDDLE ELEMENT SET DEPTH = 10090', CCL STOP DEPTH = 10073.3', WITH CCL TO MID ELEMENT DISTANCE = 16.7'. GOOD CONFIRMATION AT SURFACE OF SETTING. TRACTOR DOWN AND TAGGED PLUG TO CONFIRM GOOD SETTING. POOH. ONCE AT SURFACE CHECKED TRACTOR, RIGGED UP WELLTEC /CCL /10' 3 -3/8" PJ 6 SPF. ARMED GUN AND BEGAN RIH. PERFORMED TIE IN PASS AND PULLED TO POSITION AFTER CONFIRMING WITH CLIENT PERF INTERVAL = 9940' - 9930', TOP SHOT = 9930', CCL TO TOP SHOT = 10.3' AND CCL STOP DEPTH = 9919.7'. GOOD INDICATION AT SURFACE OF SHOOTING. POOH. RIGGED DOWN 1ST GUN RUN TOOLSTRING. VISUAL CONFORMATION OF SHOTS FIRED CONTINUE RIG DOWN TO CHANGE TO NEW WEAKPOINT (6X3). RIGGED UP 2ND GUN STRING WELLTEC TRACTOR /CCL /20' 3 -3/8" PJ 6 SPF. ARMED GUN AND BEGAN TO RIH AT 150 FPM (MAX TRACTOR SPEED). STOPPED DUE TO DEVIATION AT 9790'. TRACTOR DOWNHOLE. PERFORMED TIE IN PASS AFTER TAGGING PLUG AT 10090'. SHOT 20' GUN AFTER CONFIRMING WITH CLIENT PERF INTERVAL = 9930'- 9910', CCL TO TOP SHOT = 10.6', CCL STOP DEPTH = 9899.4'. GOOD CONFIRMATION OF FIRING AT SURFACE. ** *JOB IN PROGRESS * ** TO BE CONTINUED 17- DEC -2011 • • 12/17/2011 ** *JOB IN PROGRESS FROM 16- DEC - 2011 * ** POOH AT 150 FPM. ONCE AT SURFACE CLOSED THE SWAB AND SSV. RIG DOWN GUN# 2 TOOLSTRING. HOT CHECKED AND PROCEEDED TO ARM GUN# 3 AND RIH AT 150 FPM (MAX SPEED WITH TRACTOR) WITH GUN# 3 TOOLSTRING: HEAD(6X3)/WELLTEC TRACTOR /PKB /CAL -B /ATPS HOUSING/WPSA/FIRING HEAD/ 20' 3 -3/8" PJ HMX GUN. OAL /OAW /MAX OD = 62'/1110 LBS/ 3 -3/8 ". STOPPED AT 9780' DUE TO DEVIATION. RIH WITH TRACTOR. TAGGED PLUG AND PERFORMED CORRELATION PASS AND SETTING PASS AFTER CONFIRMING WITH WSL PERF INTERVAL = 9840'- 9820', CCL TO TOP SHOT = 9.3', CCL STOP DEPTH = 9810.7'. GOOD CONFIRMATION AT SURFACE OF FIRING. POOH AND RIG DOWN GUN# 3. VISUAL INDICATION OF SHOTS FIRED AT SURFACE. PROCEED TO RIG UP GUN# 4. RIH AT 150 FPM AND DEVIATED AT 9700' AND RUN WITH TRACTOR DOWNHOLE TO TAG PLUG AND BEGIN CORRELATION PASS AND SHOOTING PASS. WHEN FIRING NO INDICATION AT SURFACE WAS OBSERVED. PROCEED TO POOH. ONCE AT SURFACE CONFIRMATION OF A MISFIRE. TROUBLESHOOT AND RIG DOWN GUN# 4 TOOLSTRING. CHANGED OUT BLASTING CAP, RIG UP GUN# 4 TOOLSTRING. ** *JOB IN PROGRESS * ** TO BE CONTINUED ON 18- DEC -2011 12/18/2011 ** *JOB CONTINUED FROM 17- DEC - 2011 * ** BEGIN RIH WITH GUN# 4 TOOLSTRING AT 150 FPM (MAX TRACTOR SPEED). STOP DUE TO DEVIATION AT 9795'. TRACTOR DOWN AND TAGGED THE PLUG AT 10090'. PERFORMED CORRELATION PASS AND PULLED INTO POSITIONTO FIRE GUN# 4 AFTER CONFIRMING WITH WSL PERF INTERVAL = 9810'- 9820', CCL TO TOP SHOT = 9.3', CCL STOP DEPTH = 9800.7'. WHILE CHECKING THE SWITCHES OP CRASHED AND A NEW LOG WAS STARTED. GOOD CONFIRMATION AT SURFACE OF FIRING. LOST 200 LBS. CONTINUE LOGGING UP AND SAW NO COLLARS. TRY TO SEE SWITCHES AGAIN AND COULDN'T SEE ANY. STILL NO COLLARS. TRACTOR POWER UP OK. START POOH. CLOSED SWAB AND SSV. UNSTAB AND CONFIRMED VISUALLY GUN WENT OFF. RIGGED DOWN. PRESSURE TESTED CAP. CLOSE PERMIT AND LEFT LOCATION. ALL THE PERFORATIONS WERE DONE WITH 3 -3/8" PJ HMX HSD GUNS 6 SPF 60 DEG. PENETRATION = 36.5 ", ENTRANCE HOLE = 0.37 ", MAX EXPLOSIVE LOAD = 22.7 G. INITIAL T /I /O = 1650/1650/0 PSI ** *JOB COMPLETE * ** WELL SHUT IN UPON DEPARTURE FLUIDS PUMPED BBLS 5 METH 5 TOTAL o TREE = 6 -3/8" OW WELLHEAD = FMC C A 1 A SAFETY NOT ACTUATOR = BAKER . 111 KB EEV - 61.8' BF. E1EV = 34.10' KOP = 8100' Max Angle = 94° @ 10183' I I I 2205' H4112" HES X NIP, ID = 3.813" I Datum MD = 9512' Datum TVD = 8800 SS � S I 2484' J 19-5/8" X 7" BKR ZXP LNR TOP PKR I ' 2594 H9 -5/8" DV PKR I 113 -3/8" CSG, 72#, L -80, ID = 12.347" I-1 2666' GAS LIFT NIANORELS ST MD TVD DEV TYPE VLV PORT DATE 4 3297 3297 0 KBG -2 DOME BK 16 01/03/12 3 5671 5529 29 KBG -2 DOME BK 16 01/03/12 I. 2 7467 7086 32 KBG -2 DMY BK 0 04/20/03 1 8734 8150 25 KBG -2 DMY BK LATCH 0 0420/03 Minimum ID = 3.813" @ 2205' 4 -1/2" HES X NIPPLE Z -- 8051' H9-5/8" X 7" BKR ZIP LNR TOP PKR I H ELMD TT NOT LOGGED MILLOUT WINDOW 8193' - 8209' ITOP OF WHIPSTOCK I 8193' 8802' —14-1/2" HES X NIP, ID = 3.813" I 1 9-5/8" CSG, 47 #, L -80, ID = 8.681" --I — 8193 8823' _1 X 4-1/2" BKR S -3 PERM PKR I 8846' — 14 - 1/7' HES X NIP, ID = 3.813" I V 8846' 4 X 2 -7/8" NIP REDUCER � Ifi 1(1228/11), ID= 2.31" Ai r'v'v'v'v'v'v' 8867' H4 HES XN NIP, ID = 3.725" �1�4.4.1�4�/.4.4� j-141 /2" WLEG, ID = 3.958" I PERFORATION SUMTAARY REF LOG: MWD GR ON 04/07/03 � 8879' . I 8874' 17" X 5" BKR ZXP ANGLE AT TOP PERF: 84° @ 9810' 1r LNR TOP PKR Note. Refer to Roduction DB for historical pert data t∎ SIZE SPF INTERVAL Opn /Sqz DATE 9218' KER JOINT I 3 4 9810 - 9840 0 12/18/11 "'-- 3 4 9910 -9940 0 12/16/11 / ' 10090' 4 - 1/2' CBP 2 - 1/2" 4 10140- 10370 C 04/18/03 ` (12/18/11) 2 -1/2' 4 10420 - 10555 C 04/18/03 41/2' TBG, 12.6#, L -80, H 8879' I 0152 bpf, ID = 3.958" ` 0558 —I PBTD 1 I I 7" LNR, 29#, L - 80, .0365 bpf, ID = 6.125" JJ I 9035' 1 V .'\ \1;1�� I 4-1/2" LNR, 12.6#, L -80, 0152 bpf, ID = 3.958" I—I 10644' I DATE REV BY COW/UNITS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03128/80 ORIGINAL COMPLETION 12/30/11 RCT /JMO NIP RED/XX PLUG (1228/11) WELL: C-11A 04/21/03 OAVIKK RIG SIDETRACK (C -11A) 01/07/12 TBD/ PJC PULL PLUG- GLV C/O (01/03/11) PERMIT No "2030480 12/12/11 MBWJMD PULLED KB STRADDLE (12103/11) API No 50 -029- 20382 -01 12/12/11' MBWJMD PULLED X NIP RDCR (12/03/11) SEC 19, T11 N, R14E, 665' FNL & 1222' FEL 12/12/11 NBWJMD GLV CIO (12/06/11) 12/18/11 TTR/ PJC CIBPI ADPERF (12/16- 18/11) 11 BP Exploration (Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 0 Anchorage, Alaska 99519 -6612 t, 2 August 22, 2011 RECEIVED' Mr. Tom Maunder AUG 3 ' nil Alaska Oil and Gas Conservation Commission d es; Ccuc. 333 West 7 Avenue s10ft Anchorage, Alaska 99501 Anchorage Subject: Corrosion Inhibitor Treatments of GPB C -Pad a,03-0 Li Dear Mr. Maunder, " (f R 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 • • 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 OPERABLE: Producer C -11A (PTD #40480) Passing MITIA - Tubing integrfrestored Page 1 of 2 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWellIntegrityCoordinator @bp.com] Sent: Sunday, March 06, 2011 7:55 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC3 &PCC OSM; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, OPS Prod Controllers Cc: King, Whitney; Glasheen, Brian P; AK, D &C Well Integrity Coordinator Subject: OPERABLE: Producer C -11A (PTD #2030480) Passing MITIA - Tubing integrity restored Attachments: MIT PBU C -11A 03- 06- 11.xis All, 1 Producer C -11A (PTD #2030480) passed an MITIA on 03/06/11 after slickline set dummy gas lift valves. The passing test verifies two competent barriers. The well has been reclassified as Operable and may be placed on production when convenient for operations. Please be careful when placing the well on production as the IA is fluid packed. An MIT form has been included for reference. «MIT PBU C -11A 03- 06- 11.xis» .� Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 From: AK, D &C Well Integrity Coordinator Sent: Saturday, February 26, 2011 2:26 PM To: 'Maunder, Thomas E (DOA)'; 'Regg, James B (DOA)'; 'Schwartz, Guy L (DOA)'; AK, OPS GC3 &PCC OSM; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, OPS Prod Controllers Cc: Walker, Greg (D &C); AK, D &C Well Integrity Coordinator; Glasheen, Brian P Subject: UNDER EVALUATION: Producer C -11A (PTD #2030480) Sustained casing pressure on the IA All, Producer C -11A (PTD #2030480) has been confirmed to have sustained casing pressure on the IA. The wellhead pressures were tubing /IA/OA equal to SSV /2060/0 on 2/25/11. The well has been reclassified as Under Evaluation while diagnostics are completed. The plan forward is as follows: 1. Pumping: MIT -IA to 3000 psi, LLR if fails 3/15/2011 OPERABLE: Producer C -11A (PTD # 0480) Passing MITIA - Tubing integri restored Page 2 of 2 2. WIE: Evaluate for leak detect log pending ITIA results A TIO plot and wellbore schematic have been included for reference. «File: C - 11A TIO Plot 02 26 11.doc» «File: C 11A.pdf» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 3/15/2011 • • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION Mechanical Integrity Test Submit to: jim.regq(Dalaska.aov; doa .aoocc.prudhoe.bay(Dalaska.gov; phoebe.brooks(ctalaska.aov, tom.maunderealaska.cov OPERATOR: BP Exploration (Alaska), Inc. FIELD / UNIT / PAD: Prudhoe Bay / PBU DATE: 03/06/11 OPERATOR REP: Torin Roschinger AOGCC REP: Packer Depth Pretest Initial 15 Min. 30 Min. 45 Min. 60 Min. Well C -11A Type Inj. N ` TVD 8,231' Tubing 2200 2200 2200 2200 Interval P.T.D. 2030480 Type test M Test psi 2057.75 Casing 2815 3000 ' 2945 2925 ' P/F P Notes: MITIA to evaluate tubing integrity OA 20 20 20 20 Well Type Inj. TVD Tubing, Interval P.T.D. Type test _ Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA Well Type Inj. TVD Tubing Interval P.T.D. Type test Test psi Casing P/F Notes: OA TYPE INJ Codes TYPE TEST Codes INTERVAL Codes D = Drilling Waste M = Annulus Monitoring I = Initial Test G = Gas P = Standard Pressure Test 4 = Four Year Cycle I = Industrial Wastewater R = Internal Radioactive Tracer Survey V = Required by Variance N = Not Injecting A = Temperature Anomaly Survey T = Test during Workover W = Water D = Differential Temperature Test 0 = Other (describe in notes) Form 10 -426 (Revised 06/2010) MIT PBU C - 11A 03 06 11.xis UNDER EVALUATION: Producer C o A (PTD #2030480) Sustained casing •ssure on the IA Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] Z It Sent: Saturday, February 26, 2011 2:26 PM e ft To: Maunder, Thomas E (DOA); Regg, James B (DOA); Schwartz, Guy L (DOA); AK, OPS GC3 &PCC OSM; AK, OPS GC3 Facility & Field OTL; AK, OPS GC3 Wellpad Lead; Cismoski, Doug A; Engel, Harry R; AK, D &C Wireline Operations Team Lead; AK, D &C Well Services Operations Team Lead; AK, RES GPB West Wells Opt Engr; AK, OPS Prod Controllers Cc: Walker, Greg (D &C); AK, D &C Well Integrity Coordinator; Glasheen, Brian P Subject: UNDER EVALUATION: Producer C -11A (PTD #2030480) Sustained casing pressure on the IA Attachments: C -11A TIO Plot 02- 26- 11.doc; C- 11A.pdf All, Producer C -11A (PTD #2030480) has been confirmed to have sustained casing pressure on the IA. The wellhead pressures were tubing /IA/OA equal to SSV /2060/0 on 2/25/11. The well has been reclassified as Under Evaluation while diagnostics are completed. The plan forward is as follows: t) Z[ililL 1. Pumping: MIT -IA to 3000 psi, LLR if fails i�� 2. WIE: Evaluate for leak detect log pending MITIA results A TIO plot and wellbore schematic have been included for reference. «C -11A TIO Plot 02- 26- 11.doc» «C- 11A.pdf» Thank you, Torin Roschinger (alt. Jerry Murphy) Well Integrity Coordinator Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 2/28/2011 PBU C -11A PTD 2030480 2/26/2011 TIO Pressures Plot Well: C -11 4,000 40 3,000 - -Ai— Tbg —E— IA 2,000 - -A- OA OOA k i 1.4 —.— OOOA On ■ 1,000 - • LI , 1 1 2/04110 12118110 01101 01/15/11 01/29/11 02/12/11 a.. 02/26/11 02126111 TREE = 6 -318" CM/ • -1 i A SAFETY NAP: WELLHEAD = FMC ACTUATOR = BAKER KB. ELEV = 61 BF. ELEV = 34.10' KOP = 8100' Max Angle = 94 @ 10183' I I I 2205' I-14 -112" HES X NIP, ID = 3.813" Datum MD = 9512' Datum TV D = 8800' SS g 2 L 2484' I—I9 -518" X 7" BKR ZXP LNR TOP PKR I I 2594' H9-5/8" DV PKR I I 13 -3/8" CSG, 72 #, L -80, ID = 12.347" H 2666' I---41 3283` -3318' H "KB" STRADDLE PATCH (08/30/06), ID = 2.37" I GAS LIFT MANDRELS '� ST MD TVD DEV TYPE VLV LATCH PORT DATE ""4 3297 3297 0 KBG -2 DMY BK 0 07/15/06 3 5671 5529 29 KBG -2 DMY BK 0 06/10/06 Minimum ID = 2.313" @ 8846' 2 7467 7086 32 KBG -2 DMY BK 0 04/20/03 4 -1/2" HES X NIP REDUCER 1 8734 8150 25 KBG -2 DMY BK 0 04/20/03 * *GLM @ 329T COVERED BY KB STRADDLE (08/30/06) S 8051' I- 19 -5/8" X 7" BKR ZXP LNR TOP PKR I H ELMD TT NOT LOGGED I MILLOUT WINDOW 8193' - 8209' I TOP OF WHIPSTOCK H 8193' I 8802' H4 -1/2" HES X NIP, ID = 3.813" I 8823' I--17" X 4 -1/2" BKR S -3 PERM PKR I F � 8846' —14-1/2" HES X NIP, ID = 3.813" I i' 1' � 1 1 t ►' �' 1' � 1 . 1Z. ' .�� �1." 4► 41,` 8846' H4 -1/2" HES X NIP REDUCER, ID = 2.313" (1 ; 51.. M 8$67' H4 -1/2" HES XN NIP, ID = 3.725" I 8879' H4 -1/2" WLEG, iD = 3.958" I I 9 -5/8" CSG, 47 #, L -80, ID = 8.681" H 9055' I , ` In; 8874' I- 7" X 5" BKR ZXP 'IV "t't t. LNR TOP PKR 0 � * � * � 4► � � 1••• NIP' 9218' I-I MARKER JOINT I I 7" LNR, 29 #, L -80, .0371 bpf, ID = 6.184" H 10101' I A "'"A ""A"A 4 -1/2" TBG, 12.6 #, L -80, 8879' .0152 bpf, ID = 3.958" 10558' -I PBTD I PERFORATION SUMMARY I 7" LNR, 29 #, L -80, .0365 bpf, ID = 6.125" I 9035' REF LOG: MWD GR ON 04/07/03 4 ► \\ ANGLE AT TOP PERF: 93 @ 10140' %t ►�\ Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn /Sqx DATE 4-1/2" LNR, 12.6 #, L -80, .0152 bpf, ID= 3.958" I—J 10644' 2 -1/2" 4 10140 - 10370 0 04/18/03 2 -1/2" 4 10420 - 10555 0 04/18/03 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 03/28/80 ORIGINAL COMPLETION 09/15/06 JPK/TLH KB STRADDLE (08 /30/06) WELL: C-11A 04/21/03 DAV /KK RIG SIDETRACK (C -11A) 03/14/08 DDK/TLH WH CORRECTIONS (11/29/07) PERMIT No: 2030480 06/12/06 KSB /PAG GLV CIO (06/10/06) AR No: 50- 029 - 20382 -01 07/15/06 CJN/PJC GLV C/O SEC 19, T11 N, R14E, 665' FNL & 1222' FEL 08/07/06 JLW /PJC PXN PULLED @ 8867' 08/08/06 TWS /PJC SET HES X NIP REDUCER BP Exploration (Alaska) • • ~~. a,.:~, 11 • t 03/01/2008 DO NOT PLACE ' :~~ ~ ,;, p,.: ' ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFiche\C~+rPgs_Inserts\Microfilm Marker.doc STATE OF ALASKA _ RECEIVED ALASKA OIL AND GAS CONSERVATION COMMISSION OCT 1 REPORT OF SUNDRY WELL OPERA TtQ~~ R. Gas 0 2~06 . 1. Operations Peñormed: A COIJ~. LOt1lmlssion AbandonD Repair Well(:&J Plug PerforationsD Stimulate D nch~ Alter CasingD Pull TubingD Perforate New PoolO WaiverD Time ExtensionO Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended WellO c___ 2. Operator Name: 3. Address: BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, Ak 99519-6612 7. KB Elevation (ft): 61.83 8. Property Designation: ADL-028305 11. Present Well Condition Summary: Total Depth measured 10645 feet true vertical 9017.0 feet Effective Depth measured 10558 feet true vertical 9016.0 feet Casing Length Size CONDUCTOR 110 20" 94# H-40 SURFACE 2633 13-3/8" 72# L-80 PRODUCTION 8161 9-5/8" 47# L-80 LINER 6551 7" 29# L-80 LINER 1777 4-1/2" 12.6# L-80 Perforation depth: Measured depth: 10140-10370,10420-10555 True vertical depth: 9020-9015,9015-9016 4. Current Well Class: Development ŒI ExploratoryD 5. Permit to Drill Number: 203-048 6. API Number 50-029-20382-01-00 None None Burst Collapse 1530 520 4930 2670 6870 4760 8160 7020 8430 7500 Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 29 8879 2-7/8" 6.5# L-80 @ 3283 3318 Tubing Patch Packers & SSSV (type & measured depth): 9-5/8" BKR ZXP LNR Top PKR @ 2484 4-1/2" Baker KB Patch PKR @ 3283 4-1/2" Baker KB Patch PKR @ 3318 9-5/8" BKR ZXP LNR Top PKR @ 8051 7" Baker S-3 PERM Packer @ 8823 7" Baker ZXP LNR TOP PKR @ 8874 4-1/2" HES X Nipple @ 2205 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Representative Dailv AveraQe Production or Injection Data Gas-Mef Water-Bbl Casing Pressure 13 Prior to well operation: Subsequent to operation: Oil-Bbl 1027 699 14. Attachments: Copies of Logs and Surveys run _ Daily Report of Well Operations _ ~ StratigraphicD ServiceD 9. Well Name and Number: C-11A 10. Field/Pool(s): Prudhoe Bay Field / Prudhoe Oil Pool Plugs (measured) Junk (measured) MD TVD 34 144 34.0 144.0 33 - 2666 33.0 - 2666.0 32 - 8193 32.0 - 7687.0 2484 - 9035 2484.0 - 8425.0 8867 - 10644 8271.0 - 9017.0 ~CAMi\\j;D OCT 3 1 2006 RBDMS BFL 0 CT 1 1 2006 23088 22845 9 10 15. Well Class after proposed work: ExploratoryD 16. Well Status after proposed work: OilŒ] GasD Tubing Pressure 985 996 DevelopmentOO ServiceD WAG D GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. Sundry Number or N/A if C.O. Exempt: N/A 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Printed Name DeWayne R. Schnorr DeWayne R. Schnorr A;i~øf ..J.Lr ORIGINAL Signature Form 10-404 Revised 4/2004 Title Petroleum Engineer Phone 564-5174 Date 10/5/06 ~ C-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 10103/2006 T/I/O = 790/560/50. Temp = Warm. TIFL (post patch post POP). SI, well, stacked out Tubing to 2000 psi. lAP decreased to 400 psi. OAP unchanged. IA FL @ surface. Did not TIFL. Informed Operator to re-POP well. Final WHPs == 2000/400/50. 09/30/2006 CTU #9 w/1.75" CT. *** Continued from WSR 29-Sep-06 *** Displace 60/40 meth down flowline, open well up and let blow down, well dead. RIH w/2.0" JSN w/N2 at 400 sef/min. Run into fluid at -2400'. Park coil at 3500' w/N2 at 500 scf/min. Start working down in 500' bites to 6500' to kick off well. Monitor well at 6500' while reducing N2 rate. POOH slowly to surface. Monitor well before rigging down CT. Notify PCC and pad operator of well status. RDMO CTU #6. **** JOB COMPLETE **** 09/29/2006 CTU #6 w/1.75" CT. MIRU. 09/19/2006 CTU 6 - N2 Lift - Monitor well for flow - No flow to surface - FP well to 2500' and flowline. - RDMO - 09/18/2006 CTU 6 - N2 Lift - MIRU - Conduct weekly BOPE test - MU RIH with 2" JSN and lift well with N2 into HP Header{1160 psi) test seperator available. No good indicator of well flowing. FL temp 50 deg. Pump tank of N2. POH, monitor well for flow over night. Return in AM for additional lifting if needed. **** Job in progress **** 09/01/2006 TII/O = 220/vac/20. Temp = SI. WHPs (pre TIFL). 08/30/2006 SPOT EQUIPMENT, TGSM, RU, PRESSURE TEST SURFACE EQUIPMENT, SET 4.5" BAKER 1 RUN PATCH WITH THIRD PARTY CRANE. POOH Patch min id is 2.37", OAL = 44.5' **** JOB COMPLETE**** 08/08/2006 (Pre-Patch) DRIFTED WITH 3.70" X 20' DUMMY PATCH TO 3,850' SLM. SET 41/2" XN REDUCING NIPPLE ( 2 7/8" INNER NIPPLE) @ 8,845' SLM. NOTE: SECONDARY LOCK DOWN INSTALLED SET 2 7/8" XX PLUG IN REDUCING NIPPLE @ 8,846' SLM. PERFORMED A GAS TEST 600 PSI OVER TUBING PRESSURE. WATCHED FOR 30 MINUTES, PLUG HOLDING. PULLED 2.313 "XX" PLUG **** WELL LEFT SHUT IN **** NOTIFIED PAD OP. OF WELL STATUS 08/07/2006 **** WELL SHUT IN **** (pre patch prep) DRIFTED TO TOP OF THE PRONG @ 8,834' W/ 3.80 GAUGE RING. PULLED PRONG FROM PLUG BODY @8,834' SLM. PULLED 4 1/2" PXN PLUG @8,842' SLM. **** JOB STILL IN PROGRESS**** 07/17/2006 T/I/O= 340/450/100 Temp= 5/1 MIT IA FAILED to 3500 psi. Pumped 6.8 bbls crude down IA to pressure up IA/TBG to 3500 psi. CMIT TxlA PASSED to 3500 psi. 1 st 15 min TBG/IA lost 40/180 psi, 2nd 15 min TBG/IA lost 20/0 psi. Bled back 5 bbls crude. Final WHP's= 0/0/100 07/17/2006 T/I/O=1 00/0+/120 Temp=SIIA FL (pre-MITIA). IA FL @ surface. The IA doesn't have an integral or companion valve. Page 1 - C-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 07/15/2006 ***WELL WAS SHUT-IN ON ARRIVAL *** PULLED 1" DGLV FROM STA # 4 (FLOW-CUT) SET SUPER EXTENDED PKG DGL V AT ST#4 *** WELL WAS LEFT S/I, PAD OP NOTIFIED*** 07/02/2006 WELL SHUT-IN T/I/O 250/0/100. LEAK DETECT LOG FROM SURFACE TO 8860 FT AT 120 FPM. PUMPING CRUDE DOWN IAAT 2.5 BPM. RAN REPEAT PASSES AT 40/80 FPM. LEAK DETECTED AT 3304 FT. JUST BELOW GLM @ 3297 FT. RDMO NOTIFIED DSO OF DEPARTURE. 07/02/2006 Assist E-line Pump crude for LDL FWHP=350/150/140 07/01/2006 T/I/O=1 00/50/120 Pump 215 bbls crude to assist e-line on LDL. 07/01/2006 WELL SHUT-IN T/I/O 250/0/100. LEAK DETECT LOG FROM SURFACE TO 8860 FT. PUMPING CRUDE DOWN IA AT 2.5 BPM. FLUIDS PUMPED BBLS 6 Diesel --- PT Surface Equipment 55 60/40 Methanol Water 90 50/50 Methanol Water 611.8 Crude 762.8 TOTAL Page 2 TREE = WB...LHEAD = .; ACTUATOR = KS. B...EV = BF. REV = KOP= Max Angle = Datum MD = Datum lVO = 6-3/8" crw OCT OTIS 61.8' 34.10' 8100' 94 @ 10183' 9512' 8800' SS 13-3/8" CSG, 72#, L-80, 10 = 12.347" l-f 2666' Minimum ID = 2.313" @ 8846' 4-1/2" HES X NIP REDUCER I TOP OF WHIPSTOCK l-f 8193' 9-5/8" CSG, 47#, L-80, 10 = 8.681" l-f 9055' ".~...... -- SAFETY NOTES: C-11A ~ J g I ~ I --:--I ~ 2205' 1-f4-1/2" HES X NIP, 10 = 3.813" I 2484' 1-19-5/8" x 7" BKR ZXP LNR TOP A<R 2594' 1-19-5/8" DV A<R 1 ~ ~ ~ ~ g L I 3283'-3318'1-1 "KS" STRADDLE PA TCH (08/30/06), 10 = 2.37" GAS LIFT MANORB...S ST MD lVD OEV 1YÆ VLV LATCH PORT DATE **4 3297 3297 0 KBG-2 DMY SK 0 07/15/06 3 5671 5529 29 KBG-2 DMY BK 0 06/10/06 2 7467 7086 32 KBG-2 DMY BK 0 04/20/03 1 8734 8150 25 KBG-2 DMY BK 0 04/20/03 **GLM @ 3297' COVERS) BY KB STRADDLE (08/30/06) :8: ~ 8051' I l-i 9-5/8" X 7" BKR ZXP LNR TOP A<R 1 l-i B...MD IT NOT LOGGED 1 MILLOUTWINDOW 8193' - 8209' 8802' 1-14-1/2" HES X NIP, 10 = 3.813" 1 8823' 1-i7" x 4-112" BKR S-3 ÆRM A<R 1 8846' l-f 4-1/2" HES X NIP, 10 = 3.813" 1 8846' 1-f4-1/2" HES x NIP REDUCER, 10 = 2.313" I 8867' 1-14-1/2" HES XN NIP, 10 = 3.725" 1 8879' 1-14-1/2" WLEG, 10 = 3.958" 1 1--4 .. 1-- 8874' 1- 7" X 5" BKR ZXP LNR TOP A<R 9218' 1-1 MARKER JOINT 1 1 7" LNR. 29#, L-80, .0371 bpf, 10 = 6.184" l-f 10101' PERFORA TION SUMMA RY REF LOG: rvtINO GR ON 04/07/03 ANGLE A T TOP PERF: 93 @ 10140' Note: Refer to Production DB for historieal perf data SIZE SPF INTERVAL Opn/Sqz OA TE 2-1/2" 4 10140 - 10370 0 04/18/03 2-1/2" 4 10420 - 10555 0 04/18/03 DATE 03/28/80 04/21/03 06/12/06 07/15/06 08/07/06 08/08/06 REV BY COMMENTS ORIGINAL COM PLETION DAV/KK RIG SIDETRACK (C-11A) KSB/PAG GLV ao (06/10/06) CJNlPJC GL V C/O JLW/PJC PXN PULLED @ 8867' 1WS/PJC SET HES X NIP REDUCER 4-1/2" TBG, 12.6#. L-80, -l c0152 bpf, 10 = 3.958" 7" LNR, 29#, L-80, .0365 bpf, 10 = 6.125" 1-1 1 4-1/2" LNR, 12.6#, L-80, .0152 bpf, 10= 3.958" 1-1 10644' DA TE REV BY COMMENTS 09/15/06 JPKfTLH KB STRADDLE (08/30/06) PRUDHOE BA Y UNrT WB...L: G-11 A ÆRMrT No: 2030480 API No: 50-029-20382-01 SEe 19, T11N, R14E, 665' FNL & 1222' FB... BP Exploration (Alaska) · STATE OF ALASKA . ALASKA OIL AND GAS CONSERVATION COMMISSION RECEIVED SEP 2 7 2006 REPORT OF SUNDRY WELL OPERA TIQ~~nil J¿ r.,>~ f'nn~ ~ 1. Operations Performed: An~ AbandonD Repair WellŒ Plug Perforations 0 Stimulate 0 Alter CasingD Pull TubingD Perforate New PoolO WaiverD Time ExtensionD Change Approved ProgramD Operation ShutdownD Perforate 0 Re-enter Suspended WellD 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Drill Number: Name: Development 00 ExploratoryD 203-0480 3. Address: P.O. Box 196612 6. API Number Anchorage, Ak 99519-6612 StratigraphicO ServiceD 50-029-20382-01-00 7. KB Elevation (ft): 9. Well Name and Number: 61.83 C-11A 8. Property Designation: 10. Field/Pool(s): ADL-028305 Prudhoe Bay Field / Prudhoe Oil Pool 11. Present Well Condition Summary: Total Depth measured 10644 feet true vertical 9017 .0 feet Plugs (measured) None Effective Depth measured 10558 feet Junk (measured) None true vertical 9016.0 feet Casing Length Size MD TVD Burst Collapse CONDUCTOR 79 20" 91.5# H-40 31 - 110 31.0 - 110.0 1490 470 SURFACE 2636 13-3/8" 72# L-80 30 - 2666 30.0 - 2666.0 4930 2670 PRODUCTION 7658 9-5/8" 47# L-80 29 - 8193 29.0 - 7687.0 6870 4760 LINER 6551 7" 26# L-80 2484 - 9035 2484.0 - 8425.0 7240 5410 LINER 1777 4-1/2" 12.6# L-80 8867 - 10644 8271.0 - 9017.0 8430 7500 Perforation depth: Measured depth: 10140-10370,10420-10555 '-~C,~ ~J:~! f~ .~ True vertical depth: 9020-9015,9016-9016 ''Wi "I[" \.. \.-I,ltil~ ,___~: Tubing ( size, grade, and measured depth): 4-1/2" 12.6# L-80 @ 26 - 8879 2·1/8" 6.5# L-80 @ 3283 - 3318 Tubing Patch Packers & SSSV (type & measured depth): 9-5/8" DV Packer @ 2594 " 9-5/8" BKR ZXP LNR TOP PKR @ 8051 7" Baker S-3 PERM Packer @ 882:J 1" Baker ZXP LNR TOP PKR @ 8814 4-1/2" HES X Nipple @ 220!) 12. Stimulation or cement squeeze summary: RBDMS 8Ft 0 C1 () 3 2006 Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13 Recresentative Dailv Averaae Production or Iniection Data Oil-Bbl Gas-Mef Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 935 25161 11 -- --- Subsequent to operation: SI 0 0 --- --- 14. Attachments: 15. Well Class after proposed work: ExploratoryD DevelopmentŒ ServiceD Copies of Logs and Surveys run _ 16. Well Status after proposed work: Daily Report of Well Operations _ ~ OilOO GasD WAG 0 GINJD WINJD WDSPLD Prepared by DeWayne R. Schnorr (907) 564-5174. 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ISUndry Number or N/A if C.O. Exempt: Contact DeWayne R. Schnorr N/A Printed Name DeWayn.e R. Schnorr Title Petroleum Engineer Signature À-ø' ?L_ h--' d? Y~J! Phone 564-5174 Date 9/26/06 FI n Form 10-404 Revised 4/2004 0 RIG 1 N A L . . C-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY 09/19/2006 CTU 6 - N2 Lift - Monitor well for flow - No flow to surface - FP well to 2500' and flowline. - RDMO - 09/18/2006 CTU 6 - N2 Lift - MIRU - Conduct weekly BOPE test - MU RIH with 2" JSN and lift well with N2 into HP Header(1160 psi) test seperator available. No good indicator of well flowing. FL temp 50 deg. Pump tank of N2. POH, monitor well for flow over night. Return in AM for additional lifting if needed. **** Job in progress **** 09/01/2006 TIIIO = 220/vac/20. Temp = SI. WHPs (pre TIFL). 08/30/2006 SPOT EQUIPMENT, TGSM, RU, PRESSURE TEST SURFACE EQUIPMENT, SET 4.5" BAKER 1 RUN PATCH WITH THIRD PARTY CRANE. POOH Patch min id is 2.37", OAL = 44.5' **** JOB COMPLETE**** 08/08/2006 (Pre-Patch) DRIFTED WITH 3.70" X 20' DUMMY PATCH TO 3,850' SLM. SET 41/2" XN REDUCING NIPPLE ( 2 7/8" INNER NIPPLE) @ 8,845' SLM. NOTE: SECONDARY LOCK DOWN INSTALLED SET 27/8" XX PLUG IN REDUCING NIPPLE @ 8,846' SLM. PERFORMED A GAS TEST 600 PSI OVER TUBING PRESSURE. WATCHED FOR 30 MINUTES, PLUG HOLDING. PULLED 2.313 "XX" PLUG **** WELL LEFT SHUT IN **** NOTIFIED PAD OP. OF WELL STATUS 08/07/2006 **** WELL SHUT IN **** (pre patch prep) DRIFTED TO TOP OF THE PRONG @ 8,834' WI 3.80 GAUGE RING. PULLED PRONG FROM PLUG BODY @8,834' SLM. PULLED 4 1/2" PXN PLUG @8,842' SLM. ****JOB STILL IN PROGRESS. 07/17/2006 TIIIO= 340/450/100 Temp= SII MIT IA FAILED to 3500 psi. Pumped 6.8 bbls crude down IA to pressure up IA/TBG to 3500 psi. CMIT TxlA PASSED to 3500 psi. 1st 15 min TBGIIA lost 40/180 psi, 2nd 15 min TBG/IA lost 2010 psi. Bled back 5 bbls crude. Final WHP's= 010/100 07117/2006 TIIIO=1 0010+/120 Temp=SIIA FL (pre-MITIA). IA FL @ surface. The IA doesn't have an integral or companion valve. 07/15/2006 ***WELL WAS SHUT-IN ON ARRIVAL *** PULLED 1" DGL V FROM ST A # 4 (FLOW-CUT) SET SUPER EXTENDED PKG DGLV AT ST#4 ***WELL WAS LEFT SII, PAD OP NOTIFIED*** 07/02/2006 WELL SHUT-IN TIIIO 25010/100. LEAK DETECT LOG FROM SURFACE TO 8860 FT AT 120 FPM. PUMPING CRUDE DOWN IA AT 2.5 BPM. RAN REPEAT PASSES AT 40/80 FPM. LEAK DETECTED AT 3304 FT. JUST BELOW GLM @ 3297 FT. RDMO NOTIFIED DSO OF DEPARTURE. 07/02/2006 Assist E-line Pump crude for LDL FWHP=350/150/140 07/01/2006 T/I/O=100/50/120 Pump 215 bbls crude to assist e-line on LDL 07/01/2006 WELL SHUT-IN TIIIO 25010/100. LEAK DETECT LOG FROM SURFACE TO 8860 FT. PUMPING CRUDE DOWN IAAT 2.5 BPM. Page 1 . . C-11A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS FLUIDS PUMPED BBLS 5 Diesel --- PT Surface Equipment 10 60/40 Methanol Water 467 Crude 2900 Qals NitroQen 482 TOTAL Page 2 TREE = WELLHEAD = ; ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum lVD = 6-3/8" CrN OCT OTIS 61.8' 34.10' 8100' 94 @ 10183' 9512' 8800'SS C-11 A 13-3/8" CSG, 72#, L-80, 10= 12.347" I Minimum ID = 2.313" @ 8846' 4-1/2" HES X NIP REDUCER I TOP OF WHIPSTOCK I 9-518" CSG, 47#, L-80, 10 = 8,681" H 9055' I 7"LNR,29#,L-80,,0371bpf,10=6,184" H 10101' 4-112" TBG, 12,6#. L-80, .0152 bpf, 10 = 3,958" 2205' 2484' 2594' -14-1/2" HES X NIP, 10 = 3.813" -19-5/8" X 7" BKR ZXP LNR TOP A<R -1 9-5/8" DV A<R I 3283'·3318' -1 "KB" STRADDLE PATCH (08/30/06),10 = 2.31" GAS LIFT MANDRELS ST MD lVO OEV TYÆ VLV LATCH PORT DATE **4 3297 3297 0 KBG-2 DMY BK 0 07/15/06 3 5671 5529 29 KBG-2 DMY BK 0 06/10/06 2 7467 7086 32 KBG-2 DMY BK 0 04/20/03 1 8734 8150 25 KBG-2 DMY BK 0 04/20/03 **GLM @ 3297' COVERED BY KB STRADDLE (08/30/06) 8051' -19-5/8" X 7" BKR ZXP LNR TOP A<R I H ELMO TT NOT LOGGED I MILLOUT WINDOW 8193' - 8209' -14-1/2" HES X NIP, 10 = 3.813" I -17" X 4-1/2" BKR S-3 ÆRM A<R -14-1/2" HES X NIP, 10 = 3.813" I -14-1/2" HES X NIP REDUCER, 10 = 2.313" -i PBTD 7" LNR, 29#, L-80, .0365 bpf, 10 = 6,125" ÆRFORA TION SUMMARY REF LOG: fI..MID GR ON 04/07/03 ANGLEATTOPÆRF: 93@10140' Note: Refer to Produetion DB for historieal perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 10140 - 10370 0 04/18/03 2-1/2" 4 10420 - 10555 0 04/18/03 I 4-1/2" LNR, 12.6#, L-80, ,0152 bpf, 10 = 3,958" I DA TE REV BY COMMENTS 09/15/06 JPKlTLH KB STRADDLE (08/30/06) DATE 03128/80 04/21/03 06/12/06 07/15/06 08/07106 08/08/06 REV BY COMMENTS ORIGINAL COM PLETION DAV/KK RIG SIDETRACK (C-11A) KSB/PAG GLV C/O (06/10/06) CJNlPJC GLV C/O JLW/PJC PXN PULLED @ 8867' TWS/PJC SET HES X NIP REDUCER PRUDHOE BAY UNrr WELL: C-11A ÆRMrr No: 2030480 API No: 50-029-20382-01 SEe 19, T11N, R14E, 665' FNL & 1222' FEL BP Exploration (Alaska) Schlumberger Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage. AK 99503-2838 ATTN: Beth Well C-11A B-25 F-06A G-18A P-24 B-28 B-01 W-39A Z-02A G-03A C-26A F-26B F-26B W-39A F-04A Y -08A C-06B X-27 K-07D Y-10A F-12 K-07D X-04 A-30A 17-04B Z-30A 17-04B PB1 Petrotechnical Data Center LR2-1 900 Ec Benson Blvd. Anchorage. Alaska 99508 Job# 11225983 11217247 11258688 11209612 11216206 11221590 11211508 11216197 11212856 11211493 11225979 N/A N/A 11216197 11221602 11221604 11212883 11217274 10942217 11209611 11225984 11058256 10919925 11054295 40010183 40010092 40010183 SC:ANNED SEP 1 4 200B ¿)D~3 -(j-t?J Log Description Date 07/02106 05/11/06 03/20/06 07/19/06 07/06/06 07/04/06 06/23/06 OS/29/06 05/02/06 OS/24/06 06/07/06 06/06/06 06/06/06 OS/29/06 08/18/06 08/20/06 08/15/06 08/26/06 06/15/05 07/18/06 07/02/06 11/28/05 12/15/04 04/06/05 03/09/04 01127/04 03/08/04 LDL LDL PROD PROFILE W/DEFT MEM INJECTION PROFILE MEM INJECTION PROFILE LDL PROD LOG W/DEFT MEM PROD PROFILE INJECTION PROFILE LDL LDL MEM PROD & INJECTION MEM BORAX LOG MEM BORAX LOG SCMT SCMT USIT USIT MEMORY SCMT MEM INJECTION PROFILE LDL SBHP SURVEY PROD PROFILE W/DEFT CH EDIT OF PDC LOG W/GR OH EDIT OF MWD/LWD (REDO OF TVD DATA) OH EDIT OF MWD/LWD (REDO OF TVD DATA) OH EDIT OF MWD/LWD NO. 3941 Company: .~ -.,~""'.11, ) t\ ,-. ,- ~~. :., .)u .ì. ~ <;;0(;Ò 08/28/06 ~EJif & Gas Ccr.s. CQrr~ .Ancnorage State of Alaska Alaska Oil & Gas Cons Comm Attn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage. AK 99501 BL 1 1 1 1 1 1 1 1 1 1 1 1 1 1 Color Field: Prudhoe Bay CD 1 1 1 1 1 1 2 . . 1 1 1 1 Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 A TIN: Beth C-IIA (PTD #2030480) Classified as Problem Well ,1.-D><..- All, Well C-11A (PTD #2030480) has been found to have sustained casing pressure on the IA. The TID pressures were 2350/2330/50 on 6/7106 when a TIFL failed. The plan forward for this well is as follows: 1. DHD: TIFL - FAILED 2. SL: DGLVs, caliper, drift wi dummy patch 3. DHD: Re-TIFL seE' ::r:::A 2330f'S; .(,~ ~ Á.1.3f{p 645¿'0f5i' 33, '! ~ ol( f&- Cò 4q¿ "."", à.N;\.u::n nJh1 :; !~' ~V.n!..;"~~" ~..)~,4 ¡-,]. ~ A wellbore schematic has been included for reference. «C-11A.pdf» The well has been classified as a Problem well. Please call if you have any questions. Thank you, jlnna (])u6e Well Integrity Coordinator GPB· Wells Group Phone: (907) 659-5102 Pager: (907) 659-5100 x1154 Content-Description: C-IIA.pdf lA.pdf Content-Type: application/octet-stream Content-Encoding: base64 1 of 1 6t53d{~ 6/14/2006 5 :28 PM 1REE= WELLHEA D = ACTlJA. TOR = KB, B.EV = BF. B.EV - KOP- IVIax Angle - Detum MD - Detum lVD- 6-3/8" CIW OCT 011S 61.8' 34.10' 8100' 94 @ 10183' 9512' 8800' SS C-11A I SAFETY NOTES: Minimum ID = 3.725" @ 8867' 4-112" HES XN NIPPLE 2205' 4-1/2" HES X NP, ID = 3,813" 2484' G-5/8" x 7" BKRZXP LNRTOPPKR 2594' G-5/8" DV PKR I GAS LIFT MANDRELS ST 11I1) lVD DEV TYPE VLV LA TCH PORT Do\ TE 4 3297 3297 0 KBG-2 DOME BK 16 04/29/03 3 5671 5529 29 KBG-2 SO BK 20 04/29/03 2 7467 7086 32 KBG-2 [rvIY BK 0 04/20/03 1 8734 8150 25 KBG-2 [rvIY BK 0 04/20/03 13-318" CSG, 72#, L-80, D = 12,347" lDPOFWt-BPSTOCK 8051' 9-518" X 7" BKR ZXP LNR TOP A<R MLLOUTWINDOW 8193' - 8209' H B.MDTTNOT LOGGED 4-1/2" HES X NIP, ID = 3,813" 9-518" CSG, 47#, L-80, ID = 8,681" I 7" X 5" BKRZXP LNR TOP PKR MA.RKERJOINT I 7" LNR, 29#, L-80, ,0371 bpf, ID- 6.184" I 10101' 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID= 3.958" PERF ORA liON SUMMA. RY REF LOG: MWD GR ON 04/07/03 ANGLE AT TOP PERF: 93 @ 10140' Note: Refer to A-oduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 2-1/2" 4 10140- 10370 0 04/18/03 2-1/2" 4 10420 - 10555 0 04/18/03 4-1/2" LNR, 12,6#, L-80, .0152 bpf, ID= 3.958" Do\ TE 03/28/80 04/21/03 04/29/03 06/17/03 09/14/03 RBI BY COMMENTS ORIGINAL COM PLETION DAV/KK RIGSIDETRACK(C-11A CAO/KK GLV C/O CMO/1LP KB ELBlATION CORRECTION CMOITLP DATUM MD'Re: LOG/PERF ANGL Do\TE RBI BY COMMENTS PRUDHOE BAY UNrr WELL: C-11A ÆRMT lib: 2030480 API lib: 50-02G-20382-01 SEe 19, T11 N, R14E, 665' FNL & 1222' FB. BP Exploration (Alaska) - e WELL LOG TRANSMITTAL jD8-D48 To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West ih Ave., Suite 100 Anchorage, Alaska 99501 February 17, 2006 --- )Ô&~b RE: MWD Fonnation Evaluation Logs C-11A, The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Rob Kalish, Sperry Drilling Services, 6900 Arctic Blvd., Anchorage, AK 99518 907-273-3500 C-llA: LAS Data & Digital Log Images: 50-029-20382-01 1 CD Rom /!' ..... I t-(¡\(i,,_ tJ llJJ&Lh JI;J?/D(o µ t"'\k) ~ r DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Permit to Drill 2030480 Well Name/No. PRUDHOE BAY UNIT C-11A Operator BP EXPLORATION (ALASKA) INC Jp~ '1' ~ ,1.dO~ API No. 50-029-20382-01-00 MD 10645 ~ TVD 9017 /" Completion Date 4/20/2003 ./ Completion Status 1-01L Current Status 1-01L UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD, DIR, GR, RES, ASI, DEN, NEU Well Log Information: Logl 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 ~ ~ Directional Survey 8100 1 0645 Open 4/29/2003 ~ ~ Directional Survey 8100 10645 Open 4/29/2003 ~~ Directional Survey 8100 10645 Open 4/29/2003 MWD Directional Survey 8100 1 0645 Open 4/29/2003 MWD Rpt 11983 LIS Verification 1-6 8193 1 0645 Open 6/2/2003 -- '- ED 0 1"11983 I nd uction/Resistivity 1-6 7992 10579 Open 6/2/2003 MWD-GR, EWR4, CNP, XD SLD,ROP 0 c./11983 Neutron 1-6 7992 10579 Open 6/2/2003 MWD-GR, EWR4, CNP, i SLOt ROP i 1'ED 0 """11983 Density 1-6 7992 10579 Open 6/2/2003 MWD-GR, EWR4, CNP, I SLD, ROP ! L-________ Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments DATA SUBMITTAL COMPLIANCE REPORT 5/10/2005 Permit to Drill 2030480 Well Name/No. PRUDHOE BAY UNIT C-11A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20382-01-00 MD 10645 TVD 9017 Completion Date 4/20/2003 Completion Status 1-01L Current Status 1-01L UIC N ADDITIONAL INFORMATION Well Cored? Y @ Chips Received? - Y / N Daily History Received? Qw (i)N Formation Tops Analysis Received? y It~ Comments: -~ Compliance Reviewed By: ~ t Date: ;,V.o ~ .ûto ç- ----' ') } 803-QL/8 I 'Cf 83 WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Lisa Weepie 333 West 7th Avenue, Suite 100 Anchorage, Alaska May 13, 2003 RE: MWD Formation Evaluation Logs C-11A, AK-MW-2376326 1 LDWG formatted Disc with verification listing. API#: 50-029-20382-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Rob Kalish 6900 Arctic Blvd. Anchorage, Alaska 99518 BP Exploration (Alaska) Inc. Petro-Technical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date: S· -ed-~ \ - ( -"~ -. . 19n : \ ~> "-.)-"- ,:--r'\, :\ ",-, ~--à.-Äe5/~ 1..) \,,' \\ (: ~'. ~:,",:~ ':.'¡ ~~~~M~ ,Ii STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ) ) 1. Status of Well 181 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 665' SNL, 1222' WEL, SEC. 19, T11 N, R14E, UM At top of productive interval 2806' SNL, 2376' WEL, SEC. 19, T11 N, R14E, UM X = 663041, Y = 5958384 10. Well Number At total depth 2683' SNL, 1390' WEL, SEC. 19, T11 N, R14E, UM X = 664024, Y = 5958528 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field 1 Prudhoe Bay Pool KBE = 61.83' ADL 028305 12. Date Spudded 13. Date T.D. Reached 14. Date Camp., Susp., or Aband. 4/9/2003 4/17/2003 4/20/2003 17. Total Depth (MD+TVD) 18. Plug Back Depth (MD+TVD) 19. Directional Survey 10645 9017 FT 10557 9016 FT 181 Yes 0 No 22. Type Electric or Other Logs Run MWD, DIR, GR, RES, ABI, DEN, NEU Classification of Service Well 7. Permit Number 203-048 8. API Number 50- 029-20382-01 9. Unit or Lease Name X = 664140, Y = 5960549 Prudhoe Bay Unit C-11A 15. Water depth, if offshore 16. No. of Completions NI A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2205' MD 1900' (Approx.) 23. CASING SIZE 20" X 30" 13-3/8" 9-518" 7" 4-1/2" WT. PER FT. Insulated 72# 47# 26# 12.6# GRADE Conductor L-80 L-80 L-80 L-80 CASING, LINER AND CEMENTING RECORD SETTING DEPTH HOLE Top BOTTOM SIZE Surface 110' 36" Surface 2666' 17-1/2" Surface 8193' 12-1/4" 2484' 9035' 8-1/2" 8867' 10644' 6-1/8" CEMENTING RECORD 12.9 cu Vds Permafrost Concrete 4301 cu ft Arcticset 1276 cu ft Class 'G', 130 cu ft AS I 253 sx 'G', 438 sx 'G', 528 sx 'G' 270 sx Class 'G' AMOUNT PULLED 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2-1/2" Gun Diameter, 4spf MD TVD 10140' -10370' 9020' - 9015' 10420' - 10555' 9015' - 9016' 25. SIZE 4-1/2", 12.6#, L-80 TUBING RECORD DEPTH SET (MD) 8879' PACKER SET (MD) 8823' MD TVD 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2200' Freeze Protected with 160 Bbls of Diesel 27. Date First Production May 4, 2003 Date of Test Hours Tested 5/6/2003 4 Flow Tubing Casing Pressure Press. 229 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR Oll-BBl GAs-McF TEST PERIOD 2013 3348 CALCULATED 24-HoUR RATE Oll-BBl GAs-McF WATER-BBl 21 WATER-BBl CHOKE SIZE 67° GAS-Oil RATIO 1,663 Oil GRAVITY-API (CORR) 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core cBip.§.r'c {"'''¡' ~'-' ~ \¡;~;...... ~......,(\, .~"'~ ~"" ~ I'"'""" ,! I~ ('~ (,,.,..:, ,', ð "\~ ~"'''''''' ~~:: ~,¡.~ ~ '~' ~~'i~ 1t-.::ßt No core samples were taken. ~ ....,....,... -'.." - '.. . ~;Il.?-3. ~' ',' '$}£) ;\ ~--"~ { RBDMS Bt-l. &rJ MAY 2 u 2003 i\:' ~ 'I Î q Il!!-\ I ¡, }\]~~~r~8; rl1a~;': £, (~,~:,,;;: ~.~~ ~ .~·:.I~·:·'!:·: .~' ~~.~¡,~;; :'~, _. .,...... ...,,,-~,...-,,,,~:.:, -:.'~ O.~~G~NAð.. ~.i:\ ;'~ '~::! 1 ~)r' ,~:~:. ,;~:: Form 10-407 Rev. 07-01-80 Submit In Duplicate " ) 29. Geologic Markers Marker Name Measured Depth Sag River 9034' Shublik A 9070' Shublik 8 9102' Shublik C 9123' Sadlerochit 9157' Zone 3 9355' Zone 2C 9404' Zone 28 9431' Zone 2A 9632' GOC 9633' HOT 9830' 31. List of Attachments: ') 30. Formation Tests True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GOR, and time of each phase. 8425' 8458' 8487' 8507' 8539' 8727' 8772' 8795' 8945' 8946' 9018' 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 ~QM.i.¡¿ ~ Title Technical Assistant Date 0 S ..( (0 "0':::; C-11 A 203-048 Prepared By Name/Number: Sondra Sfewman, 564-4750 Well Number Permit No.1 Approval No. Drilling Engineer: Rob Tirpack, 564-4166 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 28: If no cores taken, indicate 'none'. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. Form 10-407 Rev. 07-01-80 Legal Name: C-11A Common Name: C-11 A Test Date 4/9/2003 4/13/2003 FIT FIT Test Type Bp···EXPLOR7\TJON l..ea·k..Qff····Test·.··S··u·rPl11·a.ry Test Depth (TMD) 5,280.0 (ft) 9,056.0 (ft) Test Depth (TVD) 5,200.0 (ft) 8,444.0 (ft) AMW 10.60 (ppg) 8.40 (ppg) SÚrfacePressute 150 (psi) 525 (psi) LeakQff Pl'essure(BHP) 3,013 (psi) 4,210 (psi) Page1of1 EMW 11.16 (ppg) 9.60 (ppg) - .~ Printed: 4/21/2003 2:38:25 PM ) ) Bp·EXPLORAXTI.ON Operations. Summary Report Page 1df 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-11 A C-11 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/4/2003 Rig Release: 4/20/2003 Rig Number: Spud Date: 4/5/2003 End: 4/20/2003 Date From·,;; To Hours Task Code NPT Phase Descri þtionof Operations 4/4/2003 17:00 - 00:00 7.00 MOB P PRE RID rig floor. RID camp, shop, pits. Move camp, pits sub and shop to C-11A. 4/5/2003 00:00 - 01 :30 1.50 MOB P PRE Finished move rig subbase onto C pad. 01 :30 - 04:30 3.00 MOB P PRE Lay mats and herculite liner. Mechanic repaired malfunctioning hydraulic valve on rig moving system. 04:30 - 07:00 2.50 MOB P PRE Spot subbase over well. Spot pits and camp. 07:00 - 09:30 2.50 RIGU P PRE R/U lines. Spot cuttings tank. Finish berms. Rig Accepted 0930 hrs 4/5/2003. 09:30 - 10:00 0.50 RIGU P PRE Prespud safety and environmental review meeting. 10:00 - 10:30 0.50 RIGU P PRE Installed secondary annular valve. 10:30 -11:30 1.00 BOPSUR P PRE RlU drill site maintenance and pulled BPV. 11 :30 - 12:30 1.00 BOPSUR P DECOMP RlU circulating lines to tree. Test lines to 2,000 psi 12:30 - 14:30 2.00 BOPSUR P DECOMP Displace well with 9.6 ppg brine. Monitor well. Tubing and annulus verified dead. Blow down surface equipment. 14:30 - 15:00 0.50 BOPSUR P DECOMP Run in and set TWC. Verify set from below. 15:00 - 16:30 1.50 BOPSUR P DECOMP Nipple down tree. 16:30 - 19:30 3.00 BOPSURP DECOMP Nipple up BOPE. Change out upper pipe rams from 3 1/2" X 6" VBR to 7" rams. 19:30 - 23:30 4.00 BOPSUR P DECOMP Test BOPE and all related valves to 250 psi low and 3,500 psi high. Witness of BOPE test waived by Chuck Schieve of the AOGCC. 23:30 - 00:00 0.50 WHSUR P DECOMP RlU DSM and pull TWC with lubricator. 4/6/2003 00:00 - 00:30 0.50 WHSUR P DECOMP Pull TWC. R/D DSM. 00:30 - 04:00 3.50 PULL P DECOMP R/U Baker spear, engage hanger, BOLDS, Pull hanger to rig floor with up weight of 225K. Monitor well. Static loss rate of 16 bph. LID Baker spear and hanger. Daylight savings time - 1 hour. 04:00 - 04:30 0.50 PULL P DECOMP R/U 7" casing equipment. 04:30 - 05:30 1.00 PULL P DECOMP Breakdown spear. R/U spooling unit. 05:30 - 08:00 2.50 PULL P DECOMP POOH with 7", 26#, L-80 tubing from 8,300' to 6,350'. Recovered 25 metal clamps with pins and 2 SS bands. Static loss rate @ 7 BPH. 08:00 - 08:30 0.50 PULL P DECOMP RID spooling unit. 08:30 - 12:00 3.50 PULL P DECOMP POOH with 7", 26#, L-80 tubing from 6,350' to 2,150'. 12:00 - 14:30 2.50 PULL P DECOMP POOH with 7", 26#, L-80 tubing from 2,150'. Recovered 204 complete joints plus 35.50' cut off. 14:30 - 15:00 0.50 PULL P DECOMP RID 7" casing handling equipment. 15:00 - 15:30 0.50 BOPSUR P DECOMP RlU test joint and set test plug. 15:30 -16:30 1.00 BOPSUR P DECOMP Test lower pipe rams, bag and all related valves to 250 psi low and 3,500 psi high. Pull test plug. Set wear bushing. 16:30 - 17:00 0.50 DHEOP P DECOMP Service top drive. 17:00 - 17:30 0.50 DHEOP P DECOMP PJSM regarding running an RTTS. P/U and M/U HES 9 5/8" RTTS to 10'. 17:30 - 18:30 1.00 DHEOP P DECOMP RIH with RTTS from 10' to 1,348', P/U drill pipe. 18:30 - 00:00 5.50 DHEOP N RREP DECOMP Brake band failure. Install blocks on new brake bands. Install DS brake band. 4/7/2003 00:00 - 06:00 6.00 DHEOP N RREP DECOMP Replace drawwork brake bands. Burn in brake pads, adjust and test. Inspect brakes and linkages. Install guards. 06:00 - 07:30 1.50 DHEOP P DECOMP P/U 4" drill pipe and RIH from 1,348' to 2,550'. 07:30 - 08:00 0.50 DHEOP P DECOMP Break circulation. P/U weight 65K, S/O weight 65K. Set RTTS at 2,550'. Printed: 4/21/2003 2:38:32 PM ') ") BP EXPLORATION Operatiøns·Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-11 A C-11 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Page 2Öf 10 Start: 4/4/2003 Rig Release: 4/20/2003 Rig Number: Spud Date: 4/5/2003 End: 4/20/2003 P/U and MIU Whip stock assembly to 92'. Orient and upload MWD. M/U whip stock. M/U and RIH with BHA from 116' to 1,050'. cIa handling equipment. Fill pipe and test MWD. Several attempts necessary to receive pulses. Good test. RIH from 1,050' to 5,534'. Fill pipe at 3,400'. RIH with drill pipe from 5,534' to 5,720'. Fill pipe and function MWD. O.K. RIH from 5,720' to 8,184'. Install blower hose. Fill pipe. Orient TF to 88 deg. RHS. Tag EZSV bridge plug at 8,217'. P/U weight 190K, S/O weight 150K. Set bottom trip anchor, shear brass pin with down weight of 25K. Rt weight 165K. Torque 6 - 8K. WEXIT Mill window in the 9 5/8", 47#, L-80 casing. TOW @ 8,193' BOW @ 8,209'. WOB 10 - 15K, RPM 88 - 96, Flow at 475 - 500 gpm, 2,000 - 2,250 psi Torque on 7 - 8K, Torque off 6 - 8K P/U 190K, S/O 155K, Rt 170K Date From - To Hours Task Code NPT Phase 4/7/2003 08:00 - 09:00 1.00 EVAL P DECaMP 09:00 - 11 :00 2.00 DHEQP P DECaMP 11 :00 - 12:00 1.00 CLEAN P DECaMP 12:00 - 13:30 1.50 CLEAN P DECaMP 13:30 - 18:30 5.00 CLEAN P DECaMP 18:30 - 20:00 1.50 CLEAN P DECaMP 20:00 - 21 :00 1.00 CLEAN P DECaMP 21 :00 - 00:00 3.00 CLEAN P DECaMP 4/8/2003 00:00 - 01 :00 1.00 CLEAN P DECaMP 01 :00 - 02:00 1.00 CLEAN P DECaMP 02:00 - 03:30 1.50 DHEQP P DECaMP 03:30 - 04:30 1.00 DHEQP P DECaMP 04:30 - 05:00 0.50 DHEQP P DECaMP 05:00 - 07:30 2.50 STWHIP P WEXIT 07:30 - 08:30 1.00 STWHIP P WEXIT 08:30 - 09:30 1.00 STWHIP P WEXIT 09:30 - 12:00 2.50 STWHIP P WEXIT 12:00 - 12:30 0.50 STWHIP P WEXIT 12:30 - 13:30 1.00 STWHIP P WEXIT 13:30 - 14:30 1.00 STWHIP P WEXIT 14:30 - 00:00 9.50 STWHIP P Desttiptiönof Operations Test the 9 5/8" casing to 3,500 psi for 30 minutes. Release RTTS and POH from 2,550'. LID RTTS and clear rig floor. PJSM. M/U BHA #2 to 229'. PJSM. Continue P/U BHA from 229' to 970'. P/U drill pipe from 970'. Tag the 7" stump at 8,289'. P/U weight 185K, S/O weight 155K. Displace the well from 9.6 ppg brine to 10.6 ppg LSND milling fluid at 8,289' at 12 bpm and 2,300 psi. Shut down for 15 minutes after weighted LCM sweep cleared the mill. Good returns throughout displacement. Monitor well, slug pipe. Cut and slip drilling line. POOH with 4" drill pipe from 8,289' to 967'. cIa elevators. POOH with BHA from 967'. Clear rig floor. PJSM regarding R/U of E-line and running bridge plug. R/U Schlumberger E-line equipment. P/U running tool with CCL and HES 9 5/8" bridge plug. RIH with E-line to 8,250'. Log up, and back down to confirm collar location. Casing collar at 8,228'. Log up into position and set bridge plug at 8,224'. Good indication of set. Line weight decrease of 250 Ibs. Log up hole and back down. Tag bridge plug, confirm set. POOH with E-line. RID E-line. Clear rig floor. Maintain YP at 35 - 36 during milling operation. Pump HiVis sweeps of YP 55. No solid evidence of cement in returns via pH measurement. Some 'chunks' of what appeared to be cement returned early in the milling process. Printed: 4/21/2003 2:38:32 PM ') ) BP EXPLORATION Operations Summary Report Page 3 of1 0 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-11 A C-11 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/4/2003 Rig Release: 4/20/2003 Rig Number: Spud Date: 4/5/2003 End: 4/20/2003 Date ·From - To Hours Task Code NPT Phase Descriptiönof Operations 4/8/2003 14:30 - 00:00 9.50 STWHIP P WEXIT 4/9/2003 00:00 - 00:30 0.50 STWHIP P WEXIT Mill window in the 9 5/8", 47#, L-80 casing. TOW @ 8,193' BOW @ 8,209'. WOB 10 - 15K, RPM 96 Flow at 475 gpm, 2,000 psi Torque on 7 - 8K, Torque off 6 - 8K P/U 190K, S/O 155K, Rt 170K Drill I Mill to 8,225' to bury upper mill 5' below window bottom. 00:30 - 01 :00 0.50 STWHIP P WEXIT Circulate and work milling assembly through window. 01 :00 - 01 :30 0.50 STWHIP P WEXIT Pump 25 bbl, 1/4 ppb sweep of Barofibre to facilitate cleaning of metal cuttings. 01 :30 - 02:00 0.50 STWHIP P WEXIT Conduct FIT to 150 psi with 10.6 ppg LSND (11.15 ppg EMW) at the cretaceous leak depth of 5,280' MD (5,200' TVD). Pressure bled from 150 psi to 80 psi in 10 minutes. 02:00 - 02:30 0.50 STWHIP P WEXIT Pump dry job 02:30 - 05:30 3.00 STWHIP P WEXIT POOH with drill pipe from 8,225' to 1,050'. cIa handling equipment. 05:30 - 06:30 1.00 STWHIP P WEXIT POOH with BHA from 1,050' to 125'. 06:30 - 07:30 1.00 STWHIP P WEXIT LID BHA from 125'. Clear rig floor. Mill in gauge. 07:30 - 08:30 1.00 DRILL P INT1 P/U and M/U 'Johnny Whacker'. Flush out the stack. Function the rams, service the wear bushing. 08:30 - 11 :00 2.50 DRILL P INT1 PJSM. M/U and RIH with the 81/2" drilling BHA to 1,188'. 11 :00 - 11 :30 0.50 DRILL P INT1 cIa handling equipment. Fill pipe and function test MWD at 505 gpm and 1,150 psi. 11 :30 - 14:30 3.00 DRILL P INT1 RIH with drill pipe from 1,188' to 8,007'. Fill pipe at 3,932' and 6,792'. 14:30 -15:00 0.50 DRILL P INT1 Service top drive, install blower hose. 15:00 - 16:30 1.50 DRILL P INT1 Orient TF to 88 deg. RHS at 8,020'. MAD pass beginning at 8,030'. Log at 250 fph to 8,214'. Slide through top of window at 8,193', no problem. Ream undergauge hole from 8,214' to 8,225'. 16:30 - 00:00 7.50 DRILL P INT1 Directional drill from 8,225' to 8,657'. Slide 59' (8,225' - 8,284') at TF 150 no problems. Flow rate 540 gpm, on btm 3,150 psi, off btm 2,950 psi. WOB 8K, Avg. Rap 60 fph Slide I Rotate 373' (8,284' - 8,657') Slide at TF 165 Flow rate 540 gpm, on btm 3,300 psi, off btm 2,950 psi. WOB 12K, Avg. Rap 60 fph Rotate at 45 RPM Flow rate 540 gpm, on btm 3,500 psi, off btm 2,950 psi. Torque on btm 9,000 - 10,000; Torque off btm 8,000 WOB 15K, Avg. Rap 150 fph ART = 1.83 hrs, AST = 2.72 hrs, ADT = 4.55 hrs P/U 205K, S/O 155K, RT 175K 4/10/2003 00:00 - 06:30 6.50 DRILL P INT1 Directional drill from 8,657' to 9,017'. Printed: 4/21/2003 2:38:32 PM ) ) BP EXPLORATION Operªtions. Summary Report Page4 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-11 A C-11 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/4/2003 Rig Release: 4/20/2003 Rig Number: Spud Date: 4/5/2003 End: 4/20/2003 Date From- To Hours Task Code NPT Phase Description of Operations 4/10/2003 00:00 - 06:30 6.50 DRILL P INT1 Slide I Rotate 360' (8,657' - 9,017') Slide at TF -90 Flow rate 540 gpm, on btm 3,300 psi, off btm 3,150 psi. WOB 12K, Avg. ROP 50 fph Rotate at 45 RPM Flow rate 540 gpm, on btm 3,500 psi, off btm 3,300 psi. Torque on btm 8,000 - 9,000; Torque off btm 7,000 WOB 12K, Avg. ROP 100 fph P/U 210K, SIO 160K, RT 175K ART = 2.85 hrs, AST = 1.75 hrs, ADT = 4.60 hrs 06:30 - 09:30 3.00 DRILL P INT1 CBU, for sample, at 410 gpm and 1,920 psi. Rotate and reciprocate pipe. Drill to 9,030', CBU for sample. Drill ahead to 9,036'. Reach casing point, section TO in Sag River formation. ART = 0.2 hrs ADT = 4.80 hrs. 09:30 - 10:00 0.50 DRILL P INT1 POOH from 9,036' to 8,105'. Hole in good shape. 10 -15K overpull. Up weight at 220K - 225K. 10:00 - 11 :30 1.50 DRILL P INT1 Slip and cut 89' of drilling line. Service top drive. 11 :30 - 12:00 0.50 DRILL P INT1 RIH from 8,105' to 9,036'. No problems. 12:00 - 13:00 1.00 DRILL P INT1 Pump Hi Vis sweep. CBU at 550 gpm and 2,900 psi. 13:00 - 13:30 0.50 DRILL P INT1 Spot a liner running pill at 9,036'. Slug pipe. 13:30 - 14:00 0.50 DRILL P INT1 POOH from 9,036' to 8,193', no problems. Blow down surface equipment. Remove blower hose. 14:00 - 16:30 2.50 DRILL P INT1 POH with drill pipe from 8,193' to 1,180'. 16:30 - 18:30 2.00 DRILL P INT1 CIO elevators. LID BHA from 1,180' to 87'. 18:30 - 19:00 0.50 DRILL P INT1 PJSM. Flush MWD tools w/ water. Download MWD. 19:00 - 20:00 1.00 DRILL P INT1 LID BHA from 87'. Clear rig floor. 20:00 - 21 :00 1.00 CASE P LNR1 PJSM. R/U 7" liner equipment. 21 :00 - 21 :30 0.50 CASE P LNR1 P/U float equipment. Check floats. 21 :30 - 23:30 2.00 CASE P LNR1 P/U 7", 26#, L-80, BTC-M liner to 970'. 23:30 - 00:00 0.50 CASE P LNR1 P/U Baker 7" HMC liner hangerl 9 5/8" X 7" ZXP liner top packer. Circulate one liner volume at 8 bpm and 220 psi. Liner hanging weight 55K. 4/11/2003 00:00 - 04:00 4.00 CASE LNR1 RIH from 1,004' to 8,180' with 7", 26#, L-80, BTC-M liner on 4" drill pipe. Fill pipe every 10 stands. 04:00 - 04:30 0.50 CASE LNR1 Circ dp volume at 5 bpm and 520 psi. P/U weight 170K, SIO weight 140K 04:30 - 05:00 0.50 CASE LNR1 RIH from 8,180' to 9,020'. M/U cement head. 05:00 - 06:00 1.00 CASE LNR1 Wash down to tag at 9,036'. Stage pumps up to 7 bpm at 1,370 psi. 06:00 - 07:30 1.50 CEMT LNR1 PJSM. Prime cement pumps. Pump 5 bbls water and test lines to 4,000 psi. Mix and pump 35 bb111.6 ppg Mud PUSH spacer. mix and pump45 bb115.8 ppg 'G' cement. Wash lines. Drop dart. Displace with mud and rig pumps at 8 - 10 bpm. Total displacement 114 bbls. Bump plug on calculated strokes, to 4,000 psi, to set the hanger. Bleed and check floats. O.K. CIP at 07:10 hours 4/10/2003. Release from hanger. Increase dp pressure to 1,000 psi. Unsting. 07:30 - 08:30 1.00 CEMT LNR1 CBU at 8,051' at 13 bpm and 3,150 psi. Trace of cement in returns. 08:30 - 09:30 1.00 CASE LNR1 Set liner top packer with 65K down weight. Rotate on liner top Printed: 4/21/2003 2:38:32 PM ) ) BP EXPLORATION Operation$SummaryReport Page 5 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-11 A C-11A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/4/2003 Rig Release: 4/20/2003 Rig Number: Spud Date: 4/5/2003 End: 4/20/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/11/2003 08:30 - 09:30 1.00 CASE LNR1 packer with 65K dn wt. Slup pipe. LID rotating cement head, lines and valves. Top of liner tieback sleeve at 8,039' MD. 7" liner shoe at 9,035'. 09:30 - 12:00 2.50 CASE LNR1 POOH with drill pipe from 8,051' to 32'. 12:00 - 12:30 0.50 CASE LNR1 LID liner running tool. Clear floor. 12:30 - 13:30 1.00 CASE LNR1 PJSM. R/U 7" liner equipment. 13:30 - 14:00 0.50 CASE LNR1 P/U and M/U float equipment. Check floats. 14:00 - 20:00 6.00 CASE LNR1 RIH with 7", 26#, L-80, BTC-M liner to 5,538'. Total of 135 joints. 20:00 - 20:30 0.50 CASE LNR1 C/O handling equipment. M/U hanger I pup and 1 stand. 20:30 - 21 :30 1.00 CASE LNR1 Circulate liner volume at 5 bpm and 530 psi. P/U weight 155K, S/O weight 140K. 21 :30 - 22:30 1.00 CASE LNR1 RIH from 5,538' to 8,019'. 22:30 - 23:00 0.50 CASE LNR1 M/U cement head, break circulation at 1 bpm and 360 psi. Tag NO-GO at 8,053' 23:00 - 00:00 1.00 CASE LNR1 P/U to up-weight of 210K plus 4'. Circulate at 3 bpm and 540 psi. 4/12/2003 00:00 - 01 :30 1.50 CEMT P LNR1 PJSM. Prime cement pumps. Pump 5 bbls water and test lines to 4,000 psi. Mix and pump 15 bbl CW100, 30 bb111.6 ppg Mud PUSH spacer. Mix and pump 77 bb113.5 ppg lead 'G' cement and 94 bb115.8 ppg tail 'G' cement. Wash lines. Drop dart. Displace with mud and rig pumps at 8 - 10 bpm. No indication of dart latch. Continue displacement at 8 - 10 bpm. 01 :30 - 02:00 0.50 CEMT P LNR1 Continue displacement to calculated strokes. Continue 'shoe tract' volume and stop. Did not bump plug. CIP at 02:10 4/12/2003. 02:00 - 02:30 0.50 CEMT P LNR1 Slack off to bottom out. Bleed off pressure. Pick up to take weight. Pressure up to 2,900 psi to set hanger. Slack off and verify hanger set. Pressure up to 3,400 psi, "see" pressure drop to 2,600 psi, indicating hydraulic setting tool shear. Rotate 20 turns and release running tool. 02:30 - 03:00 0.50 CEMT P LNR1 Pressure to 500 psi, P/U to pressure drop off, increase pump rate to 200 spm and 1,850 psi. CBU 2X. Recovered approximately 45 barrels Chemical wash and contaminated cement. 03:00 - 05:30 2.50 CEMT P LNR1 Pump dry job, LID cement head, clean out under shakers. POOH with drill pipe to running tool. Hydraulic packer setting tool did not shear. LID running tool. Clear rig floor. 05:30 - 06:00 0.50 BOPSUR P PROD1 Pull wear bushing and install test plug. 06:00 - 07:00 1.00 BOPSUR P PROD1 C/O rams from 7" to 3 1/2" X 6" VBR. 07:00 - 09:00 2.00 BOPSUR P PROD1 Test BOPE to 250 psi low and 3,500 psi high for 5 minutes. Test witnessed by John Crisp of the AOGCC. 09:00 - 10:00 1.00 BOPSUR P PROD1 Install wear bushing. Clear rig floor. 10:00 - 11 :00 1.00 CASE P PROD1 Test 7" X 9 5/8" casing from surface to 3,500 psi for 30 minutes. Good test. 11:00-12:00 1.00 DRILL P PROD1 P/U 61/8" drilling BHA to 104'. 12:00 -13:00 1.00 DRILL P PROD1 Upload MWD and load sources. 13:00 - 13:30 0.50 DRILL P PROD1 Surface test MWD at 236 gpm and 1,050 psi. M/U BHA to 235' 13:30 - 17:00 3.50 DRILL P PROD1 P/U 4" drill pipe from 235' to 891'. RIH from 891' to 7,989'. Fill pipe every 3,000 '. Install blower hose. 17:00 - 17:30 0.50 DRILL P PROD1 Service top drive. 17:30 - 22:30 5.00 DRILL P PROD1 Drill insert LlC at 8,022' and FIC at 8,024'. Drill cement from 8,024' to 8,035'. RIH from 8,035' to 8,920'. Necessary to wash Printed: 4/21/2003 2:38:32 PM ) ) BP EXPLORATION Ope .rati ()n~. ..Sumrnary.· Rèport Page:6of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 4/12/2003 4/13/2003 C-11 A C-11 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/4/2003 Rig Release: 4/20/2003 Rig Number: Spud Date: 4/5/2003 End: 4/20/2003 From - To Hours Task Code NPT Phase Description of Operations 17:30 - 22:30 5.00 DRILL P PROD1 junk from 8,035' to 8,350'. 22:30 - 23:00 0.50 DRILL P PROD1 Circulate at 350 gpm and 2,250 psi. 23:00 - 00:00 1.00 CASE P PROD1 Pressure test 9 5/8" x 7" casing and liner to 3,500 psi for 30 minutes. Good test. 00:00 - 00:30 0.50 CASE P PROD1 Continue casing pressure test to 3,500 psi. Good test. 00:30 - 04:00 3.50 DRILL P PROD1 Drill 7" drlg liner LlC at 8,950', drill cement to F/C. WOB 15 - 18 K, RPM 15 - 20 101 spm, 250 gpm, 2,100 psi 04:00 - 05:30 1.50 DRILL P PROD1 Displace well to 8.4 ppg Quick-Drill mud, drill shoe track and new hole to 9055' 05:30 - 06:30 1.00 DRILL P PROD1 Circulate hole clean with 8.4 ppg mud inlout. Perform FIT to 9.6 ppg EMW (525 psi). 06:30 - 20:00 13.50 DRILL P PROD1 Directional drill 6 1/8" hole from 9,055' to 9,381'. P/U Wt 175K, S/O Wt 145K, Rot Wt 160K. Rotate 51' (9,055' - 9,106') at 15 RPM Flow rate 250 gpm, on btm 1,700 psi, off btm 1,400 psi. Torque on btm 4,000 - 5,000; Torque off btm 4,000 WOB 12K, Avg. ROP 45 fph Slide 53' (9,106' - 9,159') Slide at TF -150 Flow rate 250 gpm, on btm 1,600 psi, off btm 1,400 psi. WOB 12K, Avg. ROP 20 fph Slide 26' (9,166' - 9,192') Slide at TF -130 Flow rate 250 gpm, on btm 1,600 psi, off btm 1,400 psi. WOB 18K, Avg. ROP 60 fph Slide 62' (9,192' - 9,254') Slide at TF -90 Flow rate 250 gpm, on btm 1,650 psi, off btm 1,450 psi. WOB 18K, Avg. ROP 55 fph Rotate 51' (9,254' - 9,355') at 60 RPM Flow rate 250 gpm, on btm 1,700 psi, off btm 1,480 psi. Torque on btm 6,000; Torque off btm 4,000 WOB 17K, Avg. ROP 45 fph Slide 62' (9,355' - 9,381') Slide at TF -50 Flow rate 250 gpm, on btm 1,700 psi, off btm 1,480 psi. WOB 18K, Avg. ROP 15 fph Drilling became increasingly difficult. Motor would stall at 2K bit weight. ROP continued to decline. Would not drill. AST= 6.46 hrs, ART= 4.35 hrs, ADT= 10.81 hrs 20:00 - 00:00 4.00 DRILL P PROD1 POOH from 9,381' to 9,013'. Open circulating sub, pump dry job. Printed: 4/21/2003 2:38:32 PM ) -) BP EXPLORATION OperéltionsSu.mmaryReport Þage 7 of to Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-11A C-11 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/4/2003 Rig Release: 4/20/2003 Rig Number: Spud Date: 4/5/2003 End: 4/20/2003 Date From-To Hours Task Code NPT Phase . Description of Operations 4/13/2003 20:00 - 00:00 4.00 DRILL P PROD1 POOH from 9,013' to 235'. 4/14/2003 00:00 - 02:30 2.50 DRILL P PROD1 POH with BHA from 235'. Remove LWD RAS. Flush MWD, LID mud motor and bit. Clean rig floor. 02:30 - 05:00 2.50 DRILL P PROD1 P/U new mud motor and Smith XR20 insert bit. Download, test , and upload LWD. Load MWD RAS, M/U BHA to 235'. 05:00 - 08:00 3.00 DRILL P PROD1 RIH with drill pipe from 235' to 9,013'. Filled pipe at 4,600'. Attempt to fill pipe at 9,013'. Drill string pressured up to 1,400 psi after pumping 22 bbl. 08:00 - 09:30 1.50 DRILL P PROD1 Cut and slip 112' of drilling line. Service top drive. 09:30 - 10:30 1.00 DRILL N DPRB PROD1 Attempt to circulate by surging drill string and pressuring up to 3,500 psi. No success. Drop dart to shear open Circ sub. No success. 10:30 - 15:00 4.50 DRILL N DPRB PROD1 POOH from 9,013' to 235' wet. C/O handling equipment. 15:00 - 18:00 3.00 DRILL N DPRB PROD1 POH with BHA, C/O jars, pull LWD RAS, Download MWD. Handle BHA. Check mud motor and bit. Drill string plugged at MWD HOC. 18:00 - 20:30 2.50 DRILL N DPRB PROD1 M/U BHA to 133'. Upload MWD, load LWD RAS. M/U BHA to 235'. Surface test MWD. 20:30 - 00:00 3.50 DRILL N DPRB PROD1 RIH with drill pipe from 235' to 9,293'. Fill pipe every 3,000 feet and break circulation. Stop and circulate at the 7" shoe. RIH to 9,293'. 4/15/2003 00:00 - 01 :00 1.00 DRILL P PROD1 Circulate, collectllFR reference surveys 01:00 -18:00 17.00 DRILL P PROD1 Directional drill from 9,381 ft to 10,087 ft. 252 GPM, 1925 psi on btm, 1750 psi off btm P/U Wt 180k, S/O Wt 150k, Rot Wt 170k, WOB 20k, 60 RPM's TO on btm 5k, TO off btm 4k. Slide 397 ft. A VG TF 30 L Slide ROP 50 ft I hr. Rotate 309 ft. Rotate ROP 92 ft / hr. AST= 7.85 hrs, ART= 3.35 hrs, ADT= 11.2 hrs. 18:00 - 18:30 0.50 DRILL N DFAL PROD1 Unable to communicate w/ MWD. Trouble shoot and attempt to establish communication. No success. 18:30 -19:30 1.00 DRILL N DFAL PROD1 CBU. 255 GPM @ 1625 psi. Rotate & reciprocate pipe. P/U Wt 180k, S/O Wt 150k, Rot Wt 170k, 80 RPM's TO 4k. No significant increase of cuttings at surface. 19:30 - 20:30 1.00 DRILL N DFAL PROD1 POH w/6 1/8" bit to 7" shoe @ 9,035 ft. Avg 10k over pull to 9,381 ft. Hole slick from 9,381 ft to shoe. 20:30 - 21 :30 1.00 DRILL N DFAL PROD1 Attempt to establish communication. No success. Open circ sub. CBU 400 GPM @ 975 psi. 21 :30 - 00:00 2.50 DRILL N DFAL PROD1 POH w/6 1/8" bit to BHA @ 2,479 ft. 4/16/2003 00:00 - 01 :00 1.00 DRILL N DFAL PROD1 Con't POH wi 6 1/8" bit to BHA @ 235 ft. 01 :00 - 03:30 2.50 DRILL N DFAL PROD1 Rack back BHA, download LWD I MWD. Unable to recover recorded Density data. LD HOC, 'Nukes' & pulser. Inspect MM & bit O-K. 03:30 - 04:00 0.50 DRILL N DFAL PROD1 Clear & clean rig floor. 04:00 - 06:30 2.50 DRILL N DFAL PROD1 MU BHA wi new HOC. Load 'Nukes' & pulser. Up load & surface test same. 06:30 - 09:00 2.50 DRILL N DFAL PROD1 RIH w/6 1/8" bit to 9,018 ft. Printed: 4/21/2003 2:38:32 PM ) ') BP EXPLORATION OpE!rations Summary Report Page 8 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-11 A C-11 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/4/2003 Rig Release: 4/20/2003 Rig Number: Spud Date: 4/5/2003 End: 4/20/2003 Date From;.. To Hours Task Code NPT Phase . Description of Operations 4/16/2003 09:00 - 09:30 0.50 DRILL N DFAL PROD1 Service Top Drive & crown. 09:30 - 10:00 0.50 DRILL N DFAL PROD1 Con't RIH w/6 1/8" bit to 9,570 ft. 10:00 - 13:30 3.50 DRILL N DFAL PROD1 MAD PASS from 9,570 ft to 10,087 ft @ 225 FPH. 13:30 - 00:00 10.50 DRILL P PROD1 Drill 6 1/8" directional hole 10,087 ft to 10,530 ft. P/U Wt 180k, S/O Wt 145k, Rot Wt 165k, WOB 20k, 60 RPM's, TO on btm 7k, TO off btm 5k, 260 GPM, 1925 psi off btm, 2175 psi on btm Slide 101 ft, Avg TF 15 L Slide ROP= 50 ft I hr Rotate 342 ft. Rotate ROP= 65 ft / hr AST= 2.02 hrs, ART= 5.28 hrs, ADT= 7.3 hrs. 4/17/2003 00:00 - 02:30 2.50 DRILL P PROD1 Drill 6 1/8" directional hole 10,530 ft to 10,645 ft. TO P/U Wt 180k, S/O Wt 145k, Rot Wt 165k, WOB 20k, 80 RPM's, TO on btm 7.5k, TO off btm 5k. 262 GPM, 1925 psi off btm, 2210 psi on btm. Slide 30 ft. A VG TF 30 L Slide ROP= 30 ft I hr Rotate 115 ft Rotate ROP= 77 ft I hr AST 1 hrs, ART 1.5 hrs, ADT= 2.5 hrs 02:30 - 03:30 1.00 DRILL P PROD1 Circ hi vis sweep. No significant increase in cuttings at surface. P/U Wt 180k, S/O Wt 145k, Rot Wt 165k, 70 RPM's, TO 4.5k 255 GPM @ 2000 psi. 03:30 - 04:30 1.00 DRILL P PROD1 POH to 7" csg shoe @ 9,035 ft. Hole in good shape. Flow checks showing well static. 04:30 - 06:00 1.50 DRILL P PROD1 Slip & cut drlg line. Service Top Drive. 06:00 - 06:30 0.50 DRILL P PROD1 RIH w/6 1/8" bit to 10,645 ft. Hole in good shape. No fill. 06:30 - 08:30 2.00 DRILL P PROD1 Circ sweep surface to surface. Spot 55 bblliner running pill. Rotate & reciprocate pipe. 08:30 - 10:00 1.50 DRILL P PROD1 POH w/6 1/8" bit to 9,002 ft. LD excess DP. Flow checks showing well static. 10:00 - 11 :00 1.00 DRILL P PROD1 Drop opening dart for circ sub. Open sub. CBU. 504 GPM @ 1450 psi. Rotate & reciprocate pipe. 11 :00 - 14:30 3.50 DRILL P PROD1 Con't POH wI 6 1/8" bit to BHA @ 239 ft. 14:30 - 17:00 2.50 DRILL P PROD1 LD BHA. Down load MWD, pull 'Nukes'. Clear rig floor. 17:00 - 18:00 1.00 CASE P COMP RU 4 1/2" csg handling equip. 18:00 - 18:30 0.50 CASE P COMP PU & MU 41/2" 12.6#, L 80, IBT shoe track. Check floats O-K. 18:30 - 20:00 1.50 CASE P COMP Con't RIH w/4 1/2" 12.6#, L 80 IBT liner to 1,751 ft. FS, 1 jt, FC, 1 jt, LC, 32 jts, Marker jt, 8 jts. Avg MU TO 3800 ft Ilbs, 20:00 - 21 :00 1.00 CASE P COMP PU & MU Baker 5" x 7" HMC liner hanger & ZXP liner top packer assy. Circ liner volume. 258 GPM @ 140 psi. 21 :00 - 00:00 3.00 CASE P COMP RIH w/4 1/2" liner on 4" DP @ controlled running speed to 7,670 ft. Fill pipe every 10 stds. 4/18/2003 00:00 - 00:30 0.50 CASE P COMP RIH w/4 1/2" liner on 4" DP @ controlled running speed to 8,952 ft. Fill pipe every 10 stds. 00:30 - 01 :00 0.50 CASE P COMP Circ liner volume. 296 GPM @ 600 psi. P/U WT 160k, S/O Wt 145k 01 :00 - 02:00 1.00 CASE P COMP Con't RIH w/4 1/2" liner on 4" DP to 10,645 ft. PU cmt head. Printed: 4/21/2003 2:38:32 PM ) ) BPEXPLORA TION Qperations Summary Report Page 9 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-11 A C-11 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/4/2003 Rig Release: 4/20/2003 Rig Number: Spud Date: 4/5/2003 End: 4/20/2003 Date From- To Hours Task Code NPT Phase Description öf·Operations . 4/18/2003 01 :00 - 02:00 1.00 CASE P COMP Hole in good shape. 02:00 - 03:30 1.50 CASE P COMP Circ & cond mud staging pump rate to 210 GPM @ 1050 psi. P/U Wt 180k, S/O Wt 155k RU cementers. Batch mix cmt. 03:30 - 04:30 1.00 CEMT P COMP Switch lines to cementers. Pump 5 bbl H20, test lines 4500 psi. Pump 15 bbls CW 100, 25 bbls 9.4 ppg Mud push, 48 bbls 15.8 ppg slurry. Wash lines thru 'Tee' on floor. Drop plug. Displace wI 49 bbls 8.5 ppg 'Perf Pill', 67 bbls 8.5 ppg mud. Bump plug 4000 psi to set hanger. Check floats O-K. CIP @ 0430 hrs 4/18/2003 04:30 - 05:30 1.00 CEMT P COMP Release from hanger wI 20 turns to the right. Unsting wI 1000 psi. Circ approx 10 bbls cement from well. 504 GPM @ 2820 psi. Set 'ZXP' packer wI 70k down wt. Repeat x 2. Rotate 20 RPM's TQ 3k, set down 60k wt x 2 to ensure packer set. 05:30 - 06:30 1.00 CEMT P COMP Displace well to 8.4 ppg seawater. 504 GPM @ 2520 psi 06:30 - 07:00 0.50 CEMT P COMP LD cmt head. 07:00 - 07:30 0.50 CEMT P COMP Clean & flush surface equip. 07:30 - 11 :30 4.00 CEMT P COMP POH wI liner running tool. Inspect & LD same. 11 :30 - 13:30 2.00 BOPSUR P COMP Change out upper pipe rams to 2 3/8". Clean & flush stack. 13:30 -14:00 0.50 BOPSUR P COMP Pull wear bushing. Install test plug. 14:00 - 15:00 1.00 BOPSUR P COMP PU test jt. Test upper pipe rams as per BP & AOGCC regs. 250 psi low I 3500 psi high. LD test jt. Pull test plug. Install wear bushing. 15:00 - 15:30 0.50 PERF P COMP RU 2 3/8" handling equip. 15:30 -16:30 1.00 PERF P COMP Test 4 1/2" x 7" x 9 5/8" csg as per BP regs 3500 psi 130 mins. O-K. Note: Cement @ 2000 psi Compressive strength. 16:30 - 17:30 1.00 PERF P COMP PU & RIH wI 365 ft 2 1/2" 'Millenium', HMX 11gr charges, 4 SPF, 90 deg phasing guns & 50 ft of blank guns. 17:30 - 18:30 1.00 PERF P COMP MU firing head. Change out handling equip. 18:30 - 20:00 1.50 PERF P COMP RIH wI perf guns on 2 3/8" DP to 1,764 ft from pipe shed. (42 jts) 20:00 - 20:30 0.50 PERF P COMP Change out handling equip. 20:30 - 23:30 3.00 PERF P COMP Con't RIH wI perf guns & 2 3/8" DP on 4" DP from derrick. Tag LC @ 10,557 ft. Space out guns wI btm shot @ 10,555 ft & top shot @ 10,140 ft. 23:30 - 00:00 0.50 PERF P COMP Presure up to 2500 psi - 30 sec. Bleed to 0 psi. Guns fired in 6 mins. Good surface indication of guns firing. Perforated interval - 10,140 ft to 10,370 ft and 10,420 ft to 10,555 ft. POH wI 5 stds to 10,092 ft. Flow check showing well static. 4/19/2003 00:00 - 04:30 4.50 PERF P COMP POH w/2 1/2" perf guns to 3,544 ft. LD 4" DP. Flow checks and hole fill showing well static. 04:30 - 05:30 1.00 PERF P COMP Slip & cut drill line. 05:30 - 07:00 1.50 PERF P COMP Con't POH wI perf guns to 1,353 ft. LD 4" DP. Run excess pipe from derrick. LD same. 07:00 - 08:30 1.50 PERF P COMP RU 2 3/8" handling equip. POH wI perf guns to 414 ft. LD 2 3/8" DP. 08:30 - 09:30 1.00 PERF P COMP LD 415 ft of 2 1/2" perf guns. All shots fired. 09:30 - 10:00 0.50 RUNCOIVP COMP Clear & clean rig floor. 10:00 -10:30 0.50 BOPSUR P COMP Pull wear bushing. 10:30 - 11 :00 0.50 RUNCOIVP COMP RU 4 1/2" tbg handling equip. 11 :00 - 17:00 6.00 RUNCOIVP COMP MU tail pipe assy & Baker 4 1/2" x 7" 'S 3" pkr. RIH with 4 1/2", Printed: 4/21/2003 2:38:32 PM ) ") BP EXPLORATION Operations Summary· Report Page 100f 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: C-11 A C-11 A REENTER+COMPLETE NABORS ALASKA DRILLING I NABORS 2ES Start: 4/4/2003 Rig Release: 4/20/2003 Rig Number: Spud Date: 4/5/2003 End: 4/20/2003 Date From - To Hours Task Code NPT Phase Description of Operations 4/19/2003 11 :00 - 17:00 6.00 RUNCOI\IP COMP 12.6#, L 80, IBT, Rg 3 completion to 8,871 ft. Avg MU TQ 2900 ft Ilbs. All connections below pkr Baker Locked. 17:00 - 18:00 1.00 RUNCOI\IP COMP Space out completion string wi 2 each 4 1/2" pup jts. P/U Wt 125k, S/O Wt 115k. 18:00 - 19:00 1.00 RUNCOI\IP COMP MU tbg hanger. Land completion wi WLEG @ 8,879 ft. RILDS. 19:00 - 22:00 3.00 RUNCOI\IP COMP Reverse circ one tbg volume clean seawater followed wi inhibited seawater in annulus. 3 BPM 200 psi. 22:00 - 23:30 1.50 RUNCOI\IP COMP Drop ball I rod. Pressure tubing to 3500 psi, set packer @ 8,822 ft. Hold for 30 min tubing test, OK. Bleed tubing pressure to 1500 psi. Pressue annulus to 3500 psi for packer test, hold for 30 min, OK. Bleed off pressure and shear DCK valve. BALL & ROD LEFT IN 'XN' NIPPLE @ 8,866 ft. 23:30 - 00:00 0.50 RUNCOI\IP COMP Install TWC. Test from below to 1000 psi. 4/20/2003 00:00 - 02:30 2.50 BOPSUR P COMP ND BOPE. Blow down surface circ lines. 02:30 - 05:00 2.50 WHSUR P COMP NU adapter & tree. Test same to 5000 psi. 05:00 - 05:30 0.50 WHSUR P COMP RU DSM lubricator. Pull TWC. 05:30 - 08:30 3.00 WHSUR P COMP RU Hot 011, freeze protect well down annulus wi 160 bbls of 70 degree diesel at 2 bpm, 1200 psi, U-tube from annulus to tbg at 2200'. 08:30 - 09:00 0.50 WHSUR P COMP Install BPV, test to 1000 psi. 09:00 - 10:00 1.00 WHSUR P COMP RD hot oil, ND secondary annulus valve, secured well, release rig at 10:00 hours on 04/20/2003 Printed: 4/21/2003 2:38:32 PM ) ) ,I AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well C-11 A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 8,100.53' MD Window / Kickoff Survey: 8,193.00 I MD (if applicable) Projected Survey: 10,645.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECEIVED APR 2 9 2003 Alaat,... l\;.I & GncI Vß Gas Cons. Commtaeion Anchorage Attachment(s) ¿;¡ 03-0Y r 24-Apr-03 Sperry-Sun Drilling Services North Slope Alaska BPXA PBU WOA C Pad C-11A c~ Job No. AKZZ2376326, Surveyed: 16 April, 2003 Survey Report 23 April, 2003 Your Ref: API 500292038201 Surface Coordinates: 5960549.00 N, 664140.00 E (70017'54.7751" N, 148040' 14.3568" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 ~' Surface Coordinates relative to Project H Reference: 960549.00 N, 164140.00 E (Grid) Surface Coordinates relative to Structure Reference: 3294.76 N, 1662.33 E (True) Kelly Bushing: 61. 83ft above Mean Sea Level Elevation relative to Project V Reference: 61.83ft Elevation relative to Structure Reference: 61.83ft spe....,...,Y-EiUI! DRILLING SERViCeS A Halliburton Company Survey Ref: 5vy4009 Sperry-Sun Drilling Services Survey Report for PBU_WOA C Pad - C-11A Your Ref: API 500292038201 Job No. AKZZ2376326, Surveyed: 16 April, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (0/100ft) 8100.53 38.380 209.790 7554.45 7616.28 1654.89 S 1011.66 W 5958872.41 N 663164.73 E -1225.85 Tie On Point AK-6 BP IFR-AK 8193.00 41.4 70 210.350 7625.35 7687.18 1706.23 S 1 041 .40 W 5958820.43 N 663136.12 E 3.364 -1262.25 Window Point 8219.07 40.470 212.140 7645.04 7706.87 1720.85 S 1050.26 W 5958805.62 N 663127.57 E 5.914 -1273.00 8311.62 3G~f)O ~1 n.330 7717.48 7779.31 1767.64 S 1083.74 W 5958758.11 N 663095.13 E 6.417 -1312.49 8404.30 32.070 228.090 7794.05 7855.88 1805.47 S 1119.59 W 5958719.51 N 663060.12 E 7.191 -1353.12 .~ 8498.34 27.090 229.590 7875.81 7937.64 1836.05 S 1154.49 W 5958688.17 N 663025.89 E 5.353 -1391.83 8591.07 25.600 230.090 7958.91 8020.74 1862.59 S 1185.94 W 5958660.95 N 662995.03 E 1.625 -1426.57 8685.11 25.000 226.450 8043.93 8105.76 1889.32 S 1215.93 W 5958633.57 N 662965.63 E 1.773 -1459.89 8777.66 24.580 223.200 8127.96 8189.79 1916.83 S 1243.28 W 5958605.48 N 662938.89 E 1.541 -1490.71 8871.50 24.210 219.110 8213.43 8275.26 1945.98 S 1268.78 W 5958575.77 N 662914.03 E 1.842 -1519.91 8951.19 23.160 218.330 8286.40 8348.23 1970.96 S 1288.81 W 5958550.36 N 662894.55 E 1.375 -1543.13 9062.76 22.440 212.320 8389.27 8451.10 2006.17 S 1313.80 W 5958514.61 N 662870.33 E 2.184 -1572.65 9098.25 22.360 210.090 8422.08 8483.91 2017.73 S 1320.81 W 5958502.90 N 662863.58 E 2.405 -1581.15 9126.00 19.060 208.220 8448.04 8509.87 2026.30 S 1325.60 W 5958494.23 N 662858.98 E 12.127 -1587.06 9157.34 16.450 190.850 8477.90 8539.73 2035.17 S 1328.86 W 5958485.29 N 662855.91 E 18.750 -1591.48 9191.53 12.900 173.980 8510.99 8572.82 2043.73 S 1329.37 W 5958476.72 N 662855.59 E 16.149 -1593.14 9222.98 15.970 154.540 8541 .46 8603.29 2051.13 S 1327.14 W 5958469.37 N 662857.98 E 18.110 -1591.94 9251.63 20.090 142.520 8568.70 8630.53 2058.60 S 1322.44 W 5958462.01 N 662862.83 E 19.306 -1588.29 9285.05 20.800 136.000 8600.02 8661.85 2067.42 S 1314.83 W 5958453.35 N 662870.64 E 7.134 -1581.94 9317.78 20.870 132.890 8630.61 8692.44 2075.57 S 1306.52 W 5958445.39 N 662879.13 E 3.386 -1574.81 9346.80 20.910 133.870 8657.73 8719.56 2082.68 S 1299.00 W 5958438.44 N 662886.80 E 1.212 -1568.32 9379.60 24.750 133.270 8687.95 8749.78 2091.45 S 1289.78 W 5958429.88 N 662896.21 E 11.729 -1560.36 9409.68 27.230 129.230 8714.99 8776.82 2100.12 S 1279.86 W 5958421.43 N 662906.32 E 10.126 -1551.70 9439.94 31.010 123.040 8741.42 8803.25 2108.75 S 1267.96 W 5958413.06 N 662918.41 E 15.959 -1541.08 9473.57 36.420 116.510 8769.40 8831.23 2117.94 S 1251.74 W 5958404.23 N 662934.82 E 19.344 -1526.25 9504.50 38.250 110.470 8794.00 8855.83 2125.39 S 1234.55 W 5958397.15 N 662952.17 E 13.233 -1510.22 9533.09 40.690 105.730 8816.07 8877.90 2131.01 S 1217.28 W 5958391.91 N 662969.55 E 13.556 -1493.87 9566.78 44.890 101.050 8840.80 8902.63 2136.27 S 1195.03 W 5958387.14 N 662991.92 E 15.629 -1472.53 9596.81 48.420 95.180 8861.41 8923.24 2139.32 S 1173.42 W 5958384.56 N 663013.58 E 18.437 -1451.54 9625.11 52.120 93.480 8879.50 8941.33 2140.95 S 1151.73W 5958383.40 N 663035.31 E 13.866 -1430.26 23 April, 2003 - 9:10 Page 2 of4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA C Pad - C-11A Your Ref: API 500292038201 Job No. AKZZ2376326, Surveyed: 16 April, 2003 North Slope A/aska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 9658.21 54.750 91.750 8899.22 8961.05 2142.16 S 1125.17 W 5958382.78 N 663061.89 E 9688.99 58.870 88.780 8916.07 8977.90 2142.26 S 1099.42 W 5958383.23 N 663087.63 E 9717.79 65.570 87.980 8929.48 8991.31 2141.54 S 1073.97 W 5958384.52 N 663113.06 E 9751.69 71.140 89.830 8941.98 9003.81 2140.95 S 1042.48 W 5958385.80 N 663144.53 E 9783.17 77 . 5GO 88.980 8950.47 9012.30 2140.63 S 1012.18W 5958386.78 N 663174.81 E 9811.38 84.250 86.350 8954.93 9016.76 2139.49 S 984.37 W 5958388.52 N 663202.60 E 9843.05 89.200 83.480 8956.74 9018.57 2136.68 S 952.89 W 5958392.01 N 663234.01 E 9905.04 87.280 83.140 8958.64 9020.47 2129.47 S 891.35 W 5958400.57 N 663295.37 E 9953.46 91.480 83.140 8959.16 9020.99 2123.68 S 843.29 W 5958407.40 N 663343.29 E 10029.05 89.010 82.650 8958.84 9020.67 2114.34 S 768.29 W 5958418.39 N 663418.07 E 10060.02 88.400 81.860 8959.54 9021.37 2110.16 S 737.61 W 5958423.23 N 663448.65 E 10091.09 89.750 82.670 8960.04 9021.87 2105.98 S 706.83 W 5958428.08 N 663479.34 E 10133.26 93.400 81.520 8958.88 9020.71 2100.19 S 665.08 W 5958434.79 N 663520.95 E 10183.25 94.020 81.060 8955.65 9017.48 2092.63 S 615.77 W 5958443.42 N 663570.08 E 10230.86 93.640 81.540 8952.47 9014.30 2085.45 S 568.82 W 5958451.63 N 663616.87 E 10278.48 88.830 79.790 8951.44 9013.27 2077.73 S 521.85 W 5958460.37 N 663663.65 E 10372.66 88.640 80.190 8953.52 9015.35 2061.36 S 429.13 W 5958478.76 N 663756.00 E 10463.03 91.050 79.330 8953.77 9015.60 2045.30 S 340.21 W 5958496.76 N 663844.55 E 10555.93 88.700 82.290 8953.97 9015.80 2030.46 S 248.52 W 5958513.60 N 663935.89 E 10596.99 89.070 82.240 8954.77 9016.60 2024.94 S 207.84 W 5958520.01 N 663976.44 E 10645.00 89.070 82.240 8955.55 9017.38 2018.45 S 160.27 W 5958527.53 N 664023.85 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 82.240° (True). Magnetic Declination at Surface is 25.90r(06-Apr-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 10645.00ft., The Bottom Hole Displacement is 2024.81ft., in the Direction of 184.540° (True). 23 April, 2003 - 9:10 Page 3 of4 BPXA Dogleg Vertical Rate Section Comment (0/100ft) 8.986 -1404.11 15.630 -1378.61 23.393 -1353.29 17.195 -1322.01 20.559 -1291.95 25.437 -1264.24 ~ 18.058 -1232.67 3.145 -1170.72 8.674 -1122.32 3.331 -1046.74 3.222 -1015.78 5.067 -984.71 9.074 -942.57 1.543 -892.69 1 .284 -845.19 10.748 -797.62 0.470 -703.53 2.831 -613.26 4.068 -520.40 0.909 -479.35 0.000 -431.35 Projected Survey ~ ---- DríIJQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA C Pad - C-11A Your Ref: API 500292038201 Job No. AKZZ2376326, Surveyed: 16 April, 2003 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8100.53 8193.00 10645.00 7616.28 7687.18 9017.38 1654.89 S 1706.23 S 2018.45 S 1011.66 W 1041 .40 W 160.27 W Tie On Point Window Point Projected Survey -- Survey tool program for C-11 A Fro m Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8100.53 0.00 8100.53 7616.28 10645.00 7616.28 BP High Accuracy Gyro (C-11) 9017.38 AK-6 BP _IFR-AK (C-11A) ~ 23 April, 2003 - 9:10 Page 4 of4 DrillQuest 3.03.02.005 ') ) a03-0Y~ 24-Apr-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well C-11A MWD Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 8,100.53' MD Window / Kickoff Survey: 8,193.00' MD (if applicable) Projected Survey: 10,645.00' MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager RECE ·Vj::: '''') U !--. t.. APR 29 2003 AJa3Kð Oi'¡' .1.\ G~",-, ""',. ", . 0: ~,> \,...{)i ¡,\, :.. li'~'¡l\'~,~~c,,\ ß.' .." .... \. '1'.,¡..~t""¡:;'~U~1 "ù1~,f!~'If~[i1~ Attachment(s) Sperry-Sun Drilling Services North Slope Alaska BPXA PBU WOA C Pad C-11A MWD ~/ Job No. AKMW2376326, Surveyed: 16 April, 2003 Survey Report 23 April, 2003 Your Ref: API 500292038201 Surface Coordinates: 5960549.00 N, 664140.00 E (70017' 54.7751" N, 148040' 14.3568" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 J -- Surface Coordinates relative to Project H Reference: 960549.00 N, 164140.00 E (Grid) Surface Coordinates relative to Structure Reference: 3294.76 N, 1662.33 E (True) Kelly Bushing: 61.83ft above Mean Sea Level Elevation relative to Project V Reference: 61.83ft Elevation relative to Structure Reference: 61.83ft 5per-'r-'Y-5LJ1! DRILLING seRVIc:es A Halliburton Company Survey Ref: svy4010 Sperry-Sun Drilling Services Survey Report for PBU_WOA C Pad - C-11A MWD Your Ref: API 500292038201 Job No. AKMW2376326, Surveyed: 16 April, 2003 BPXA North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Dogleg Vertical Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings Rate Section Comment (ft) (ft) (ft) (ft) (ft) (ft) (ft) (o/100ft) 8100.53 38.380 209.790 7554.45 7616.28 1654.89 8 1011.66 W 5958872.41 N 663164.73 E -1225.85 Tie On Point MWD Magnetic 8193.00 41.4 70 210.350 7625.35 7687.18 1706.23 8 1041.40 W 5958820.43 N 663136.12 E 3.364 -1262.25 Window Point 8219.07 40.4 70 212.140 7645.04 7706.87 1720.85 S 1050.26 W 5958805.62 N 663127.57 E 5.914 -1273.00 8311.62 36.560 219.760 7717.48 7779.31 1767.51 8 1083.90 W 5958758.23 N 663094.96 E 6.637 -1312.63 8404.30 32.070 229.170 7794.06 7855.89 1804.87 S 1120.22 W 5958720.10 N 663059.47 E 7.487 -1353.66 --- 8498.34 27.090 230.420 7875.82 7937.65 1834.858 1155.64 W 5958689.35 N 663024.72 E 5.336 -1392.80 8591.07 25.600 232.940 7958.92 8020.75 1860.38 S 1187.90 W 5958663.12 N 662993.02 E 2.009 -1428.22 8685.11 25.000 227.510 8043.95 8105.78 1886.05 S 1218.77 W 5958636.78 N 662962.72 E 2.548 -1462.27 8777.66 24.580 223.000 8127.98 8189.81 1913.348 1246.32 W 5958608.90 N 662935.77 E 2.093 -1493.25 8871.50 24.210 218.710 8213.45 8275.28 1942.63 8 1271.67 W 5958579.06 N 662911.07 E 1.929 -1522.32 8951.19 23.160 218.040 8286.43 8348.26 1967.728 1291.54 W 5958553.54 N 662891.75 E 1.360 -1545.40 9062.76 22.440 219.190 8389.28 8451.11 2001.51 S 1318.52 W 5958519.17 N 662865.51 E 0.759 -1576.69 9098.25 22.360 217.960 8422.09 8483.92 2012.08 S 1326.95 W 5958508.42 N 662857.31 E 1.340 -1586.48 9126.00 19.060 208.480 8448.05 8509.88 2020.238 1332.36 W 5958500.15 N 662852.08 E 16.917 -1592.94 9157.34 16.450 191.210 8477.92 8539.75 2029.09 S 1335.67 W 5958491.22 N 662848.97 E 18.664 -1597.41 9191.53 12.900 174.340 8511.00 8572.83 2037.64 8 1336.23 W 5958482.66 N 662848.59 E 16.149 -1599.12 9222.98 15.970 154.910 8541.47 8603.30 2045.06 8 1334.05 W 5958475.29 N 662850.94 E 18.104 -1597.96 9251.63 20.090 142.850 8568.72 8630.55 2052.56 8 1329.40 W 5958467.90 N 662855.75 E 19.335 -1594.37 9285.05 20.800 136.490 8600.04 8661.87 2061.43 S 1321.85 W 5958459.19 N 662863.49 E 6.975 -1588.09 9317.78 20.870 133.680 8630.63 8692.46 2069.68 S 1313.63 W 5958451.13 N 662871.89 E 3.061 -1581.06 9346.80 20.910 135.340 8657.74 8719.57 2076.93 8 1306.25 W 5958444.03 N 662879.42 E 2.044 -1574.73 9379.60 24.750 134.850 8687.97 8749.80 2085.94 S 1297.27 W 5958435.22 N 662888.60 E 11.722 -1567.04 9409.68 27.230 129.280 8715.01 8776.84 2094.748 1287.47 W 5958426.64 N 662898.59 E 11.560 -1558.52 -- 9439.94 31.010 123.170 8741.44 8803.27 2103.39 8 1275.58 W 5958418.25 N 662910.66 E 15.879 -1547.91 9473.57 36.420 117.660 8769.41 8831 .24 2112.788 1259.47 W 5958409.22 N 662926.97 E 18.465 -1533.22 9504.50 38.250 110.850 8794.02 8855.85 2120.458 1242.39 W 5958401.92 N 662944.22 E 14.597 -1517.32 9533.09 40.690 105.740 8816.09 8877.92 2126.138 1225.14 W 5958396.62 N 662961.59 E 14.204 -1501.00 9566.78 44.890 101.030 8840.81 8902.64 2131.398 1202.88 W 5958391.85 N 662983.96 E 15.665 -1479.66 9596.81 48.420 95.020 8861 .43 8923.26 2134.40 8 1181.28 W 5958389.31 N 663005.63 E 18.699 -1458.65 9625.11 52.120 93.320 8879.52 8941.35 2135.97 8 1159.57W 5958388.21 N 663027.36 E 13.866 -1437.36 23 April, 2003 - 9:13 Page 20f4 DrillQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA C Pad - C-11A MWD Your Ref: API 500292038201 Job No. AKMW2376326, Surveyed: 16 April, 2003 North Slope Alaska Measured Sub-Sea Vertical Local Coordinates Global Coordinates Depth Incl. Azim. Depth Depth Northings Eastings Northings Eastings (ft) (ft) (ft) (ft) (ft) (ft) (ft) 9658.21 54.750 91.800 8899.24 8961.07 2137.15S 1133.02W 5958387.61 N 663053.93 E 9688.99 58.870 89.010 8916.09 8977.92 2137.32 S 1107.27 W 5958388.00 N 663079.68 E 9717.79 65.570 88.270 8929.50 8991.33 2136.71 S 1081.81 W 5958389.17 N 663105.12 E 9751.69 71 .140 89.180 8942.00 9003.83 2136.02 S 1050.32 W 5958390.55 N 663136.58 E 9783.17 77 .560 88.4 70 8950.49 9012.32 2135.39 S 1020.03 W 5958391.84 N 663166.85 E 9811.38 84.250 85.890 8954.95 9016.78 2134.02 S 992.23 W 5958393.82 N 663194.62 E 9843.05 89.200 83.720 8956.75 9018.58 2131.15S 960.75 W 5958397.37 N 663226.03 E 9905.04 87.280 83.330 8958.66 9020.49 2124.17 S 899.19 W 5958405.70 N 663287.42 E 9953.46 91.480 84.410 8959.18 9021.01 2119.00 S 851.06 W 5958411.92 N 663335.43 E 10029.05 89.010 83.370 8958.86 9020.69 2110.95 S 775.91 W 5958421.60 N 663410.38 E 10060.02 88.400 82.330 8959.56 9021.39 2107.10S 745.19 W 5958426.13 N 663441.01 E 10091.09 89.750 83.610 8960.06 9021.89 2103.30 S 714.36 W 5958430.60 N 663471.75 E 10133.26 93.400 82.660 8958.90 9020.73 2098.26 S 672.51 W 5958436.55 N 663513.48 E 10183.25 94.020 81.540 8955.67 9017.50 2091.40 S 623.10 W 5958444.49 N 663562.73 E 10230.86 93.640 82.340 8952.49 9014.32 2084.74 S 576.07 W 5958452.17 N 663609.61 E 10278.48 88.830 81.650 8951 .46 9013.29 2078.11 S 528.94 W 5958459.83 N 663656.58 E 10372.66 88.640 80.220 8953.54 9015.37 2063.28 S 435.96 W 5958476.69 N 663749.21 E 10463.03 91.050 79.160 8953.78 9015.61 2047.11 S 347.05 W 5958494.80 N 663837.74 E 10555.93 88.700 82.220 8953.99 9015.82 2032.08 S 255.40 W 5958511.82 N 663929.05 E 10596.99 89.070 77.760 8954.79 9016.62 2024.95 S 214.98 W 5958519.84 N 663969.30 E 10645.00 89.070 77.760 8955.57 9017.40 2014.77 S 168.07 W 5958531.04 N 664015.98 E All data is in Feet (US Survey) unless otherwise stated. Directions and coordinates are relative to True North. Vertical depths are relative to Well Reference. Northings and Eastings are relative to Well Reference. Global Northings and Eastings are relative to NAD27 Alaska State Planes, Zone 4. The Dogleg Severity is in Degrees per 100 feet (US Survey). Vertical Section is from Well Reference and calculated along an Azimuth of 82.240° (True). Magnetic Declination at Surface is 25.907°(06-Apr-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 10645.00f1., The Bottom Hole Displacement is 2021.77f1., in the Direction of 184.768° (True). 23 April, 2003 - 9:13 Page 3 of4 BPXA Dogleg Vertical Rate Section Comment (0/100ft) 8.760 -1411.21 15.383 -1385.72 23.374 -1360.41 16.619 -1329.12 20.509 -1299.02 25.374 -1271.29 ~ 17.061 -1239.71 3.160 -1177.77 8.956 -1129.38 3.545 -1053.83 3.892 -1022.87 5.987 -991.81 8.943 -949.67 2.557 -899.78 1.857 -852.28 10.204 -804.69 1.531 -710.56 2.913 -620.29 4.153 -527.44 10.897 -486.43 0.000 -438.57 Projected Survey .--- Dri/lQuest 3.03.02.005 Sperry-Sun Drilling Services Survey Report for PBU_WOA C Pad· C-11A MWD Your Ref: API 500292038201 Job No. AKMW2376326, Surveyed: 16 April, 2003 BPXA North Slope Alaska Comments Measured Depth (ft) Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Comment 8100.53 8193.00 10645.00 7616.28 7687.18 9017.40 1654.89 S 1706.23 S 2014.77 S 1011.66 W 1041.40 W 168.07 W Tie On Point Window Point Projected Survey ~ Survey tool program for C-11A MWD From Measured Vertical Depth Depth (ft) (ft) To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) 0.00 8100.53 0.00 8100.53 7616.28 10645.00 7616.28 BP High Accuracy Gyro (C-11) 9017.40 MWD Magnetic (C-11A MWD) .~ 23 April, 2003 - 9:13 Page 4 of4 DrillQuest 3.03.02.005 ~~~~E ......~ ) f ~~~!Æ~~~!Æ ) \.~::.; FRANK H. MURKOWSKI, GOVERNOR ALASKA. OIL AND GAS CONSERVATION COMMISSION i 333 W. pH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Bill Isaacson Senior Drilling Engineer BP Exploration (Alaska) Inc. P. O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay Unit C-I1A BP Exploration (Alaska) Inc. Pem1it No: 203-048 Surface Location: 665' SNL, 1222' WEL, SEC. 19, TI1N, RI4E, UM Bottomhole Location: 2537' NSL, 1585' WEL, SEC. 19, TI1N, RI4E, UM Dear Mr. Isaacson: Enclosed is the approved application for pem1it to redrill the above development well. This pennit to redrill does not exelnpt you from obtaining additional pennits or approvals required by law fron1 other goven1ll1ental agencies, and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Comn1ission reserves the right to withdraw the pern1it in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Adlllinistrative Code, or a Con1mission order, or the tem1S and conditions of this pennit 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 Comn1ission's North Slope petroleuln field inspector at 659-3607 (pager). ~~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this_ day of March, 2003 cc: DepaI1ment of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. Hole 9-5/8" 8-1/2" 6-1/8" J\ . "l' S¡rATE OF ALASKA) ALASKJ.\ "'IL AND GAS CONSERVATION COMhr..-JSION PERMIT TO DRILL 20 AAC 25.005 1b. Type of well 0 Exploratory 0 Stratigraphic Test 181 Development Oil o Service [J Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool Planned KBE = 63.3' Prudhoe Bay Field I Prudhoe 6. Property Designation Bay Pool ADL 028305 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number /" C-11A 9. Approximate spud datI} 04/08/03 / Amount $200,000.00 /' 14. Number of acres in property 15. Pr9P?sed depth (MD and TVD) 2560 10476' MD /9018' TVD o 17. Anticipated pressure {S~20 AAC 25.035 (e) (2)} 90 Maximum surface 2411 psig, At total depth (TVD) 8955' / 3306 psig Setting Depth Top Bottom Mn TV~ Mf) TVn 2600' 2600' 8050' 75761 8050' 7576' 9040' 8412' 8900' 8282' 10476' 9018' Wc.:T I\- -S I '2.N·/ Z-t70 "5 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 x = 664140, Y = 5960549 665' SNL, 1222' WEL, SEC. 19, T11 N, R14E, UM At top of productive interval x = 663260, Y = 5958390 2475' NSL, 2157' WEL, SEC. 19, T11 N, R14E, UM At total depth x = 663830, Y = 5958465 2537' NSL, 1585' WEL, SEC. 19, T11N, R14E, UM 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 12. Distance to nearest property line 13. Distance to nearest well ADL 028310, 2538' MD No Close Approach 16. To be completed for deviated wells Kick Off Depth 8200' MD Maximum Hqle Angle 18. Casing ~rogram Specification~ Size '1' CasinQ WeiQht Grade CouplinQ 7" 26# L-80 BTC-M 7" 26# L-80 BTC-M 4-1/2" 12.6# L-80 IBT-M I enQth 5450' 990' 1576' Quantity of Cement Oncluc;je staQe datq) 479 sx Class 'G', 68 sx Class 'G' 227 sx Class 'GI ./ ,215 sx Class 'G' 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 Casing 10101 feet 9177 feet 1 0058 feet 9141 feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD 12.9 cu yds Permafrost 110' 110' 4301 cu ft Arcticset 2666' 2666' 1276 cu ft Class 'G', 130 cu ft AS I 9055' 8340' 489 cu ft Class 'G' 8577' - 10101' 7972' - 9177' Structural Conductor Surface Intermediate Production Liner 110' 20" x 30" 2666' 13-3/8" 9055' 9-5/8" 1524' 7" 20. Attachments Open: 9860' - 9904' Sqzd: 9793' - 9813', 9820' - 9834' true vertical Open: 8975' - 9011' Sqzd: 8919' - 8936', 8941' - 8953' 181 Filing Fee [J Property Plat [J BOP Sketch [J Diverter Sketch 181 Drilling Program 181 Drilling Fluid Program 0 Time vs Depth Plot [J Refraction Analysis 0 Seabed Report [J 20 AAC 25.050 Requirements Contact Engineer Name/Number. Rob Tirpack, 564-4166 Prepared By NameINumber. Sandra Stewman, 564-4750 21. I hereby certify that the fore~~ing lis tr ~e and correct to the be~t of my ~nowl~~ge . Signed Bill Isaacson t.J M.- . .\..~ Title Senior Dnlllng Engineer Date MA~ ZOr z.oo~ CQmmi$ÍÎòÎ1. Uø~Only; : . I. ,I): " " ",0::;-': t",,';,:.,:"'~ Permit Number , API Number I)ppr9}(Î Date See cover letter ZCJ -3 - C) 71 tr 50- 029-20382-01 b J / l...J(, D) for other reauirements Conditions of Approval: Samples Required 0 Yes 181 No Mud Log Required' 0 Yes fiI No Hydrogen Sulfide Measures S Yes 0 No Directional Survey Required BYes 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:'~St- "BoPE to ~çcÞO 1J~¿. I ~ by order of :~:o~~~~ Rev. 1~ ~O R Iljt~~oÞfL· theoommíssion Perforation depth: measured Date ~!~~e ) ) IWell Name: I C-11A Drill and Complete Plan Summary 1 Type of Well (service I producer I injector): I Horizontal Sidetrack Producer Surface Location: Estimated Target Location: Ivishak Zone 2A Bottom Hole Location: x = 664,140 Y = 5,960,549 665' FNL, 1222' FEL Sec. 19, T11 N, R14E Umiat X = 663,260 Y = 5,958,390 TVDss 8955' 2475' FSL, 2157' FEL Sec. 19, T11 N, R14E Umiat X = 663,830 Y = 5,958,465 TVDss 8955' 2537' FSL, 1585' FEL Sec. 19, T11 N, R14E Umiat / /1 /' 1 AFE Number: 1 PBD4P2041 I I Estimated Start Date: 104/08/03 I RiQ: I Nabors 2ES /' I OperatinQ days to complete: 120 I MD: 110,476' I I TVD: 19018' 1 I GL: 134.8' I I KB: 128.5' I I KBE: 163.3' I Well DesiQn (conventional, slim hole, etc.): 12 String Horizontal Sidetrack I Objective: 1 Ivishak Zone 2A Formation Markers Formation Tops (wp04c) MD TVD TVDss Kingak N/A N/A 7,576' Kick-off Point 8,200' 7,693' 7,630' Kingak JD 8,619 8,029' 7,966' Kingak JC 8,711' 8,110' 8,047' Kingak JA 8,965' 8,342' 8,279' Sag River 9,040' 8,412' 8,353' Shublik 9,073' 8,443' 8,382' TSAD - Zone 4 9,151' 8,516' 8,460' SAD - Zone 3 9,350' 8,708' 8,655' SAD - Zone 2C 9,426' 8,778' 8,709' SAD - Zone 2Bu 9,486' 8,830' 8,764' SAD - Zone 2BI 9,561' 8,888' 8,828' SAD - Zone 2A 9,659' 8,950' 8,892' TO 10,476' 8,955' 8,960' TD Criteria: Based on 300' of perfable sand in horizontal. C-11 A Permit to Drill Comments 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing Hydrocarbon bearing ... 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW -«.lR 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW 7.1 ppg EMW Page 1 ") Directional KOP: 18,200' MD Maximum Hole Angle: ) Close Approach Well: Survey Program: -420 in 8-1/2" hole - at KOP -900 in 6-1/8" horizontal section There are no close approach issues. MWD only CasinQJTubinQ PrOQram Hole Size Csgrrbg O.D. Wt1Jt Gr~e L-80 L-80 L-80 L-80 9-5/8" Csg 8-1/2" 6-1/8" Tubing 7" -Scab Liner 7"-Drilling Liner 4-1/2" 4-1/2" 26# 26# 12.6# 12.6# Mud PrOQram Section Milling Mud Properties: LSND Density (ppg) Viscosity PV 10.5 40 - 60 14-18 Intermediate Mud Properties: LSND Density (ppçr)' 10-Sec Gel PV 10.5 ¡-' 40 - 60 12-14 Production Mud Properties: Quickdril Density (ppg) TauO PV 8.3 - 8.6 3-7 7 - 11 LOQQinQ ProQram 8-1/2" Intermediate: Sample Catchers - None Drilling: Dir/GR/Res- Real time Open Hole: None Cased Hole: None Conn Length Top Btm MDrrVD MDrrVD BTC-M 5,450' 2,600'/2,600' 8,050'/7,576' ..-/ BTC-M 990' 8,050'/7,576' 9,040'/8,412' IBT-M 1,576' 8,900'/8,282' 10,476'/9,018' IBT-M 8,837' GL 8,900'/8,282' I Whip Stock Window 9 5/8" I YP 10 sec gel MBT PH API FI 40+ 15-20 6-8 9.0 - 9.5 8 I 8-1/2" hole section I YP 10 sec gel MBT PH API FI 15-21 15-20 6-8 9.0- 9.5 <6 I 6-1/8" hole section I YP LSYP MBT pH API FI 30 - 35 8-14 <6 9.0 - 9.5 4-6 6-1/8" Production: Sample Catchers - over entire interval, samples described and discarded. Drilling: MWD Dir/GR/Res/ABI- Real time; Den/Neu - recorded mode Open Hole: None Cased Hole: None Cement ProQram Casing Size I 7" 26#, L-80 Intermediate Liner Basis: Lead: None Tail: Based on 80' shoe track, 840' of 7" X 8-1/2" open hole with 30% excess, 150' 7" X 9-5/8" Liner Lap, and 200' of 9-5/8" excess. Tail TOC: 8050' MD (TaL) I Total Cement Volume: Lead None / ) Tail 46 bbls, 260 ft3~aCkS Class G @ 15.8 ppg, 1.16 ft3/sack C-11 A Permit to Drill Page 2 ) ) Casing Size I 7" 26#, L-80 Scab Liner I Basis: lead: 5000' of 7" X 9-5/8" casing annulus with 20% excess (7500' - 2500' MD) lead TOC: 2500 (Tal) Tail: 550' of 7" X 9-5/8" casing annulus (8050' to 7500' MD) Tail TOC: 7500' MD fa I Total Cement Volume: lead 154 bbls, 862 ft~JI' .. sacks Class G @ 13.5 ppg, 1.80 ft3/sack Tail 14 bbls, 79 ft3d:6I acks Class G @ 15.8 ppg, 1.16 ft3/sack Casing Size I 4.5" 12.6#, L-80 Production Liner Basis: lead: None Tail: Based on 80' shoe track, 1436' of 4-1/2" X 6-1/8" open hole with 40% excess, 150' 4-1/2" X 7" Liner lap, and 200' of 7" excess. Tail TOC: 8900' MD (Tal) I Total Cement Volume: lead None L) Tail 47 bbls, 263 ft3(;ï" sacks Class G @ 15.8 PPQ, 1.16 ft3/sack v/" Well Control Well control equipment consisting of 5000 psi working pressure pipe rams(2), blind/shear rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with the AOGCC. Intermediate Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9·5/8" Casing Test Integrity Test - 8-1/2" hole Production Interval Maximum anticipated BHP Maximum surface pressure Kick tolerance Planned BOP test pressure 9·5/8" Casingn" Liner Test Integrity Test - 6·1/8" hole Planned completion fluids 3084 psi (7.1 ppg @ 8353' TVD) 2249 psi (.10 psi/ft gas gradient to surface) Infinite with a 12.0 ppg FIT Rams test to 3,500 psi/250 psi. Annular test to 2,500 psi/250psi 3500 psi surface pressure /' ..be=P after drilling 20' outside window Ft:í We; A- ' 3306 psi (7.1 ppg @ 8955' TVD) 2411 psi (.10 psi/ft gas gradient to surface) Infinite with 9.6ppg FIT Rams test to 3,500 psi/250 psi. Annular test to 2,500 psi/250 psi .- 3500 psi surface pressure /' 9.6 ppg EMW FIT 8.4 ppg Seawater / 6.8 ppg Diesel Disposal . No annular injection in this well. . Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS-04. Any metal cuttings will be sent to the North Slope Borough. · Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I wastes to Pad 3 for disposal. C-11 A Permit to Drill Page 3 ) ) Sidetrack and Complete Procedure Summary Pre-RiQ Work: 1. Pressure test OA to 2000 psi (passed 03/08/03). 2. Pressure test Casing Pack-off to 5000 psi (passed 02/21/03). 3. Pressure Test Tubing pack-offs to 3000 psi (passed 02/21/03). 4. Rig up slickline. Drift 4-1/2" tubing tail to WLEG. 5. Rig æp . RIH to 10,058' MD. 6. Spot. 7.' bls cement across existing perforations. Obtain squeeze. 7. Pull and contaminate cement to 8,700' MD, if necessary. 8. Rig up slickline, tag TOC. 9. Rig up e-line. Chemical cut 7" tubing at 8,300' MD. 1 o. Fluid pack tubing and OA. Freeze protect same. 11. Remove the well house. If necessary, level the pad. Please provide total well preparation cost on the handover form. RiQ Operations: 1. MIRU N2es. 2. Pull BPV. Circulate out freeze protection and displace wej!)o seawater. Set TWC. 3. Nipple down tree. Nipple up and test BOPE. Pull TWC. 4. Pull 7" tubing from above pre-rig cut. 5. Rig up e-line. Make GR/JB run to top of 7" tubing stub. /"' 6. PU RTTS and RIH to 2500' MD. PT 7" casing to 3500 psi for 30 mins. POOH. 7. MU bridge plug on e-line with CCL. RIH and set at -8250' MD, set as needed to avoid cutting a /" casing collar. 8. RIH with 9-5/8" Baker bottom trip whipstoc!;lssembly. Orient whipstock and set on bridge plug. 9. Mill window in 9-5/8" casing at -8200' MD. Perform FIT. POOH 10. MU 8-1/2" drilling assembly with Dir/GR and RIH. '5J9k off and drill the 8-1/2" intermediate interval, dropping and turning at 3°/100' to a 21 ° hold angle. 11. Drill ahead to casing point at Top Sag River to an estimated depth of 9,040' MD. /" 12. Run and cement a 7" drilling liner throughout the 8-1/2" hole and back into the 9-5/8" casing to 8050' MD. Displace cement with mud. POOH. /' 13. Run and cement a 7" scab liner from 8050' MD to 2500' MD. Displace cement with mud. POOH. 14. MU 6-1/8" BHA with Dir/GR/Res/ABI/Den/Neu and ')JH to the landing collar. 15. Pressure test wellbore to 3500 psi for 30 minutes. 16. Drill shoe track. Swap over to 8.6 ppg mud and drill 20' of new formation. Perform FIT. 17. Drill the 6-1/8" production interval building at 14°/100' to horizontal, targeting Z2A Ivishak. Drill ahead /' to an estimated TD of 10,476' MD 18. Run and cement a 4-1/2" solid liner thro~hout the 6-1/8" wellbore and back into the 7" drilling liner to 8900' MD. 19. DisPlaCe~~Ir't clean seawater. 20. RIH with ðP". perf guns. Perf intervals to be determined from LWD logs. 21. POOH. P and perf guns. 22. Run 4-1/2",12.6#, L-80 completion tying into the 4-1/2" liner top. / 23. Set packer and test the tubing to 3500 psi and annulus to 3500 psi for 30 minutes. 24. Set and test TWC. 25. ND BOPE. NU and test the tree to 5000 psi. 26. Freeze protect the well to -2200' and secure the well. 27. RDMO Post-RiQ Work: 1. Install wellhouse and flowlines. 2. MIRU slickline. Pull the ball and rod / RHC plug from 'XN' nipple below the new production packer. 3. Install gas lift valves. C-11 A Permit to Drill Page 4 ) ) C-11A Drilling Program Job 1: MIRU Hazards and Contingencies ~ No wells will require well house removal or shut-in for the rig move onto C-11 A. The closest neighboring wells are spaced as follows: C-33 at -35' and C-12 at -110'. Care should be taken while moving onto the well. Spotters will be used at all times. ~ C..Pad is not designated as an H2S site. However, Standard Operating Procedures for H2S precautions should be followed at all times. Recent H2S data from the pad is as follows: The maximum level recorded of H2S on the pad was 10 ppm on C..26A and C27 A in 10/22/00. ~ Post Permit to Drill and Summary of Drilling Hazards in the dog house and camp prior to spud Reference RP .:. "Drilling/Work-over Close Proximity Surface and Subsurface Wells Procedure" SOP :;,I~:m ,\-A-¡,I~,~-"-,\-11,:,·~:o1o'1~~,~(.j~·~",.,.,,.~';';..."".,.,.,w,."..~,~,\,I,\~{o,,:o1':«-'X-"':>.,"""i,~·,~,"'W""""~'.''<~'>'''Mom,~m',I,\C,~,-,-.-¡,-':,:, ,',:':,\-,I,C,I,I':I.I.:ml,'I,I, ,I, .I,I,\I,:,~I,\I.I,I,',I',rl',~lm,I,~,I,I.U:,':,J,\I~~'':''':''':~:';:'~:':';':'''''','''.'I,,:,:,:;,<"..>,¡,~;:;; Job 2: De-complete Well Hazards and Contingencies ~ C-11 will be P&A'd in pre-rig operations. The existing perforations will be cement P&A'd. Planned TOC is -8,700' (just below 4-1/2" tubing tail at 8,622') ~ Note and record required PU weight to pull tubing at cut point. ~ NORM test all retrieved well head and completion equipment. ~ Verify the hanger type and connection. Be prepared with necessary equipment to remove. Reference RP .:. "De-completions" RP ~~. _:f:Y:'n_~1":'1'r':'r:\I',~_~".'_:""'>"~I;¡~~~_n'''· ') ·~"m:""'''''-':''''''''''''H.''''''''¡'''~~'¡C~-,,'M',;''';'''~'''' ,':0: ....,~''I. .... ,'i:''4IIi't:,~~ 11' W'l'\":'Nmm\f':'fII'ï_~l-,'.u!;-~«r./;.¡,,~.,.¡;;,~,-;,I,.,~,.+.. ",~'~'-"r.,>';';;'I'<~),':;I:I;_'1;~~'~':\,¡;', Job 4: Window Mill Hazards and Contingencies ~ Position bridge plug to avoid cutting a casing collar while milling the window. ~ Once milling is complete, make sure all BOP equipment is operable. Wash out BOP stack to remove any metal cuttings, which may have settled there. Reference RP .:. "Whipstock Sidetracks" RP ·'1,' ,I " ...... ';'" 'W , I. U þh, 1 ",II, ,I C-11A Permit to Drill Page 5 ) ') Job 5: Drill 8-1/2" Intermediate Hole Hazards and Contingencies ~ The intermediate section will kick off in the Kingak 'D' interval and TD at the top of Sag River. Since C)1 A will be at -450 inclination at a 2100 azimuth, maintain mud weight at minimum 10.5 ppg to interval TD. Follow all shale drilling practices to minimize potential problems. ~ There are no fault crossings in the intermediate section. Lost circulation is not anticipated. Follow the lost circulation decision tree should LC become problematic. ~ There are no close approach issues while drilling the intermediate hole section. ~ KICK TOLERANCE: In the worst-case scenario of 8.8 ppg pore pressure at the Sag River depth, a fracture gradien~.of .... ppg at the 9-5/8" casing window, and 10.5 ppg mud in the hole, the kick tolerance is I ini . Reference RP . .~" .:. "Shale Drilling, Kingak and HRZ" RP .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" ~,~I,':),a,:,\\I,:,~~,~;.:~~{.~ :-;''''(.'''~'T..~~~" L~.Nr.>:I"'~'.<o:'~J<.J<.,~~."....."I,I,¡....",,,,~,~,:':':,,>.u.~~),I~.ImAAJ,:,~,;,r.I,\,r" ,I,:m,al,,~::¡,I..:m,~:;'I',rm,I~~~ Job 6: Install 7" Intermediate and Tieback Liners Hazards and Contingencies ~ Avoid high surge pressures with controlled running speeds and by breaking circulation slowly. High surge pressures could lead to losses to the Sag River or exacerbate Kingak instability problems. ~ Ensure the liner top packer is set prior to POOH. This may require going through the setting process twice. Slack off with rotation to the maximum allowable down weight, as per Baker representative. ~ The cretaceous leak at -5,280' will need to hold the hydrostatic head of -2500' of cement until it sets. Be prepared with LCM as required to stop losses at the cretaceous after releasing from the drilling liner hanger (prior to POH for the scab liner). Reference RP .:. "Intermediate Casing Cementing Guidelines" RP .:. "Running and Cementing a Drilling Liner" RP ~1,;, ,I~¡,I,I,i.I,~;,I.I -" '-,ll~,I¡U,II:. ' ;l-..-,:-rl,W._I'".lt;l~I~:aU.¡ilHUI~~lIlIUUm.:IHI;UIJ--'-~~~I""<I-A. l;t'UUUUII,:.I;H;<lm;U,;..;:I~'MI;.\"t;~;1I;la..l.,¡";;.~I.;;,~.aH.l.~. ;;^;~m~II UlIJa\II 'IIJ.U::~;-::;; t¡\II~-:I(U:";'UI:-GI-.- -U ~~I'U'·.~.:II\:LI\LlI~. .~l.nl'¡'I""'. :.\~~" ,'-11". . '11.1'11"'-, , )/1\ ' o¡ C-11 A Permit to Drill Page 6 ) ) Job 7: Drill 6-1/8" Production Hole Hazards and Contingencies ~ A pump out sub will be run in the BHA to aid in placing LCM material. ~ KICK TOLERANCE: In..the worst-case scenario of 8.8 ppg pore pressure in the Ivishak, a fracture gradieqt/o~ 9.6/ppg at the 7" casing window, and 8.6 ppg mud in the hole, the kick tolerance is Infin,i,fe. C::::::::",·I Reference RP .:. "Standard Operating Procedure: Leak-off and Formation Integrity Tests" .:. "Prudhoe Bay Directional Guidelines" .:. "Lubricants for Torque and Drag Management" RP ~~'1;W;:!~~«':'.~\~A A ¡..II:::;:I:II~~J:I!~~,¡A;¡¡,I,'¡AI~~"¡'\":';'¡;";';'I,:,':";"¡' ~~~~~I;<~>~I¡IY'!;"""'-~~·~,'-;';;';;,q,;,,;;,~~~~~~~¡\'~~~w·^""""'·:··~ Job 9: Install 4-1/2" Solid Production Liner Hazards and Contingencies ~ Differential sticking is a concern. The 8.6ppg mud will be -700psi over balanced to the Ivishak formation. Minimize the time the pipe is left stationary while running the liner. ~ Ensure the liner top packer is set prior to POOH. Slack off with rotation to the maximum allowable down weight, as per Baker representative. » Sufficient 4-1/2" liner will need to be run to extend -150' back up into the 7" intermediate liner. » Condition mud after casing is on bottom prior to pumping cement. A quality cement job is required for zonal isolation. ~~~¡.;~m~,¡:¡.¡:::::,::,X····:·"······J·'''''''W·''~<'·~:::::~!!:~UIIUlm,II:"::I!ll!mlrC:ll!lr':ln:IC:':IIIII:::I:::1l_tr::LI:«'~::~»t»I!:m:mllmllm!':mI11:II:n':a::ItII:Cllalla_111 1'.~:I:::I::-Clc::~~n,:lnlmlll:m'm:I"lmm::mlllll _I:::11:_IIIII:!:::CI:III:I:II_;;';;~~lnlll:"::"la I:CII'I:111"~III:mml'III~lmll Job 12: Run Completion Hazards and Contingencies ~ Diesel will be used to freeze protect the well. The diesel flash point is 1000 F. Diesel vapor pressure is - 0.1 psia at 1000 F. Reference RP .:. "Completion Design and Running" RP .:. "Tubing connections" RP 11..1. -II. ._.,......................---nn-.-.'...""' I· .'IIILII~III. .~~;¡¡.wlmI1111I1L .I 1I'~Hma~IIIIII'L'IIII'IIJII',:llIlln'.I.ul:;II:I;LIII..IIII.II.II:LI. .11 ;:+HIIII"mIIHIIUII.I:..I. .1. ,-.a~m:··I· .,t'I;I:IIII'~· ··:II;I'~ Job 13: ND/NU/Release RiQ Hazards and Contingencies ~ No wells will require well house removal or shut-in for the rig move onto C-11 A. The closest neighboring wells are spaced as follows: C-33 at -35' and C-12 at -110'. Care should be taken while moving onto the well. Spotters will be used at all times. Reference RP .:. "Freeze Protecting an Inner Annulus" RP C-11A Permit to Drill Page 7 ) ) C-11A Well Summary of DrillinQ Hazards POST THIS NOTICE IN THE DOGHOUSE Intermediate Hole Section: · There are no close approach issues. · Differential sticking has been experienced in the past. Keep pipe moving at all times. · Lost circulation while drilling has not been problematic at C-Pad. In the event of lost circulation, consult the LCM Decision Tree. · The intermediate hole section will be drilled with a recommended mud weight of 10.5 ppg to ensure shale stability in the Kingak. · Kick tolerance is Infinite with a 12.0 ppg LOT. · There are no fault crossings expected in the intermediate hole section. Production Hole Section: · There are no fault crossings expected in the production hole section. Lost circulation risk is low. Use LCM Decision Tree in the event of losses. · Unexpected Faulting could cause drilling out of zone. Monitor drilling trends and cuttings. · Kick tolerance is Infinite. · Differential sticking had been experienced in other long horizontal sections. Keep pipe moving at all times. HYDROGEN SULFIDE - H2S /" · This drill-site not designated as an H2S drill site. Recent tests indicate a very low concentration of H2S. As a precaution, Standard Operating Procedures for H2S precautions should be followed at all times. CONSULT THE C-PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION C-11 A Permit to Drill Page 8 TREE = WELLHEAD = ACTUATOR;;' i<ääE\Ï;' ..... BF. ELEV = KOP= Max Angle = ..,.,,,.....,.,.;,,,,,,.,...........,,,,,...... Datum MD = """".,......,......................,................ DatumiVD= 6-3/8" CrN OCT ········ÖTiS .... ..""..................".......,,,,...,.......... 61.28' ) C-11 } SAFETY NOTES 4000' 43 @ 8300' ·····"972·;2i 8800' SS - I --I I-~ ~ 1999' 1-1 7" SSSV, OTIS LANDING NIP, ID = 5.962" 2594' 1-1 9-5/8" DV PKR 1 13-3/8" CSG, 72#, L-80, ID = 12.347" 1-1 2666' Minimum ID = 3.725" @ 8586' 4-1/2" OTIS XN NIPPLE - I 5,280' 1-1 Cretaceous leak in the 9 5/8" ìnterrnedíate 1 7" TBG, 26#, L-80, 0.0383 bpf, ID = 6.276" 1-1 8515' 1 TOP OF 4-1/2" TBG 1-1 8515' I TOP OF 7" LNR H 8577' I - I r , II. 4-1/2" lBG, 12.75#, L-80, 0.1522 bpI, ID = 3.958" H 8618' I , ~ 8492' 1-1 7" PBRASSY 1 ........ /' :8: :8:-1 8515' 1-1 9-5/8" X 7" GUIB PKR, ID = 3.833" 1 \ 1 8515' 1-1 7" X 4-1/2" XO 1 9-5/8" CSG, 47#, L-80, ID = 8.681" 1-1 9055' 1-.41 ~ 1 8557' 1-1 4-1/2" OTIS X NIP, ID = 3.813" 1 I 8586' 1-1 4-1/2" OTIS XN NIP, ID = 3.725" 1 I 8618' 1-1 4-1/2" TUBING TAIL 1 8622' l-i ELMD TT LOGGED 03/09/96 1 9678' l-i MA RKER JOINT . ÆRFORA TION SUMMARY REF LOG: BHCS ON 11/06/79 ANGLE AT TOP ÆRF: 36 @ 9793' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 9793-9813 S 08/13/88 3-1/8" 4 9820-9834 S 08/13/88 3-1/8" 2 9860-9888 0 10/31/87 3-1/8" 6 9888-9904 0 10/31/87 s=... š:- ==-- "::::-- s=... PBTD l-i 10058' 7" LNR, 29#, L-80, 0.0371 bpf, ID = 6.184" 1-1 10101' 1- I-"'~ DATE REV BY COMMENTS DATE REV BY COMMENTS 03/28/80 ORIGINAL COMPlETION 01/30/01 SIS-lsl CONVERTED TO CANV AS 03/09/01 SIS-LG FINAL 09/06/01 RNfTP CORRECTIONS PRUDHOE BA Y UNIT W8...L: C-11 ÆRMIT No: 79-0460 API No: 50-029-20382-00 Sec. 19,T11N,R14E BP Exploration (Alaska) PRUDHOE BA Y UNIT WB..L: C-11 ÆRMIT No: 79-0460 API No: 50-029-20382-00 Sec. 19,T11N,R14E BP Exploration (Alaska) COMMENTS DA TE REV BY ÆRFORA TION SUMMARY REF LOG: BHCS ON 11/06/79 ANGLE AT TOP ÆRF: 36 @ 9793' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-1/8" 4 9793-9813 S 08/13/88 3-1/8" 4 9820-9834 S 08/13/88 3-1/8" 2 9860-9888 0 10/31/87 3-1/8" 6 9888-9904 0 10/31/87 TRæ = 6-3/8" CrN WB..LHEAD = OCT ACTUA TOR = OTIS kB:ELË\T;'''' """" '''''''''' ""'" "61':'28i' äF.äsT; , " " '" '" "'3;;(8; . koÞ;" 4ÖÖÖi Max Angle = 43 @ 8300' 'DaiUm'MÖ;^ ,......" , ," """"9722ì "'" ........ ....",..........,,,,,,,.......,...,,.,,.... Datum lVD = 8800' SS 1 8557' 1-1 4-1/2" OTIS X NIP, ID = 3.813" 1 I 8586' 1-1 4-1/2" OTIS XN NIP, ID = 3.725" 1 I 8618' 1-1 4-1/2" TUBING TAIL 1 Proposed Top of cement @) ~ 8,700' /' 9678' 1-1 MARKER JOINT DATE REV BY COMMENTS 03/28/80 ORIGINAL COMPLETION 01/30/01 SIS-lsl CONVERTED TO CANVAS 03/09/01 SIS-LG FINAL 09/06/01 RNlTP CORRECTIONS 12/04/02 Dew Proposed Pre Rig Work '<~"J'¡~' .~~...... ~ ~~~;]~ .~~~ ~ :1;::~%1 ~:".~~~~'~~' ....'ii". ð~.~."~....- 'I"::~ ~ .. . ~-~ '~'~", ".,:~.~.: .". .~ ,: .;" ~~ ,.;Y;;: ;' . . ~/_.:,..,-~:~..' ~';;::=:-- ..I"!'."_I''''~.~ II ~ ~ ~ .... :8: ...... ~ ~ ~ Pre-rig Tubing Cut @ f¥ 8,300' 8492' 1-1 7" PBRASSY 1 ,;' :8-1 8515' 1-1 9-5/8" X 7" GUIB PKR, ID = 3.833" 1 I I 8515' 1-1 7" X 4-1/2" XO 1 - I 5,280' 1-1 Cretaceous leak in the 9 5/8" intermediate 1 Minimum ID = 3.725" @ 8586' 4-1/2" OTIS XN NIPPLE - -I 1999' 1-1 7" SSSV, OTIS LANDING NIP, ID = 5.962" --I 2594' 1-1 9-5/8" DV PKR 1 ~ ') ) C-11 Pre Rig 10101' 7" Liner, 29#, L-80, - ID = 6.184" 1 PBTD 1-1 10058' 1 Top of 4 1/2" Tbg 1-1 8515' Top of 7" Liner 1-1 8577' 4 1/2" Tubing, 12.75#, L-80, 8618' ID = 3.958" 9-5/8" CSG, 47#, 9055' L-80, ID = 8.681" 8515' 7" Tubing, 26#, L-80, ID = 6.276" 2666' 13 3/8" Casing, 72#, L-80 ~ 133/8" Casing, 72#, L-80 2666' 5,280' Cret<~c(':!ous leak in the 9 5/8" csg. 9 5/8" Whip Stock 8200' 7" Tubing, 26#, 8515' L-80, ID = 6.276" Top of 4 1/2" Tbg 1-1 8515' Top of 7" Liner 1-1 8577' 4 1/2" Tubing, 12.75#, L-80, 8618' ID = 3.958" 9-5/8" CSG, 47#, 9055' L-80, ID = 8.681" I PBTD 1-1 10058' 7" Liner, 29#, L-80, - ID = 6.184" 10101' J-11 A Proposett) ~ 2200' 2500' 2594' 1-1 41/2" 'X' Landing Nipple, ID = 3.813" W 9 5/8" X 7" Baker ZXP liner top 1 I I packer and HMC liner hanger 1-1 9-5/8" DV PKR 1 TREE = 6-3/8" CrN WELLHEAD = OCT ACTUATOR = .. ÓTIS 'kS:ELE\j'; ...... ......... ... ............... .... ..... 63jÓï ..........................."""" ,,,, BF. ELEV = 34.8' KOP = . 4ÖÒÖi . . . "."..,..,.........,.. , ,.",... ..,. Max Angle = 90° @ 9900' ÒâtumMÖ;' . 'M" .... '9900' Datum TV D = . ···....·..S95Sïáà ~"IIo-I· -;,'f 1.7;~~~1~· X~.... .. ~~tt~~~ . ~~~ ~i~~ ~:...-!¡..ì} .'~''''~- /.i.Y.:..~~1.~... ... ~~:':I. ...... ~~~-~k ~~~~ ":'·'¡;.t~.:'.o:':1~· '/.E=- ;'tlf ~ '';'. ;$;'~ :A;'.'I'~:: ;-~.~~. '-':I'~~~~":O';""" ~~.~i,'. ~ ~;('" "'. .~.~~~ .'".~ , I..~ 1 ~~.. ···~<·,:~i ... ~ 8050' 9 5/8" X 7" Baker ZXP liner top packer and HMC liner hanger w / TBS 8835' 1-1 41/2" 'X' landing nipple, ID = 3.813" 8850' 1-1 7" X 4 1/2" Baker S-3 packer 1 8865' 1-1 41/2" 'X' landing nipple, ID = 3.813" 8880' 1-1 41/2" 'XN' landing nipple, ID = 3.725" 8900' 5" X 7" Baker ZXP liner top packer and HMC liner hanger w / TBS 1-1 7",26.0#, L-80 Liner. 1 I BTG-M 9040' ... ~ 10476' 1- 41/2",12.6#, L-80 Liner. IBT-M DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BA Y UNrr 03/28/80 ORIGINAL COMPLETION WELL: G-11A 01/30/01 SIS-lsl CONVERTED TO CANV AS ÆRMrr No: 03/09/01 SIS-LG FINAL API No: 50-029-20382-01 09/06/01 RNfTP CORRECTIONS Sec. 19,T11N,R14E 12/04/03 Dew R"oposed Con-pletion BP Exploration (Alaska) ) ) sauo PETRJLEUM ro1PANY \'lELtlIEAD IOCATIOO m'm \.. 1) WELL C-ll (23-19-11-14) 2) Pad C 3) Wellread lDcation 665 SNL t 1222 WEL X = 664140 700 171 54.7711 1480 401 14.3511 rAT. I1:NG. y = 5960549 4) Bear.ing of Qýro Marker 5) IDeal Benclrnark Elevation S 57° 431 E (True) 6) Top Eflge of CP" r!r* 32.51 32.73 Ft. AMSL Ft. Þ.MSL 8) Kelly Bushing Elevation -:::'l.\ . OX G, \ tLb Ft. 1\MSL 7) Base Flange Elevation Ft. AMSL * Base Flange and Ke.Uy Bushing Not Installed This Jßte. IDrES : . 1) Items 1 axrl 2 slnuld be filled in by the Drilling .Superv:tror on the rig when a 'D£M well sp.1ds in. 2) The surveyor shcril.d fill in It:en5 3, 4, 5, and 6. 3) The carpleted fODn slnlld be returned to Drilling Dept. for distribJtion. 4) Tœ bearing of tœ Gyro Marker is required as a True, not a M:1gnetic bearing . 5) Base Flange and Kelly Bushing Elevations xœasured by the Drilling Supervisor. ( District Field Engineer - 1 District Drilling Engineer - 1 Drilling Superinterrlent - 1 Well Remrd Clerk, Geology - 1 Well Files Engineering Aide, Drilling - Original . ~~"''\..'\: ~~t: OF AI. '\ ~~..-......4J' \, ff~~ *....'1-. tt ".. ...-? { f1t! 49!!!. .., * ~ ~~.~............~.......~ ~ ';.!~_.;.~~'.~."; ....~ ~ ~ \. Richard C. Davis ...~ t . ,:%.... No. 1637-$ ...~ ~ "~ ... .0- ~ ,....- '\ v Av. ..._....... ...~ ~ \ \: "-ØFCSSIDK}. \ \.1.;. _.:- \:\. "" '\.." ~ '-~-- c::r:.R:1JIATIœ: - ~~\~ ç; ,'~'~ REFERENCE INFORM.<\T¡ON CASlNG DETAILS Size No. TVD MD Name 8412.30 903984 7" 9018.30 10476.15 4112" FORMA nON TOP DETAILS No. TVDPath MDPath Formation 1 8029.30 2 8110.30 3 8342.30 4 8412.30 5 8443.30 6 8516.30 7 870K30 8 8778.30 9 8830.30 10 8888.30 11 8950.30 12 8963.30 7.000 4.500 750 780 ';' 810 ~ '" '" C .;;¡ It 0 0; .2 t > " Þ 840 Vertíc~1 Section at 82.24° [300ft/in} SURVEY PROGRAM Depth Fm Depth To Survey!Pian 8200.00 W476.J6 PJanned: C-1 IA 'IIp(14e V2 Name +N!-S .;.-Eí-W Plan:C~1 IA wpD4c (C-! I/Plan(>l!A) Tool Created By: Ken Allen Th!te: 121312002 MWD Date: Revæwed: Date:_ Northing "VEIL DETAILS Easting Longiw.:!c SIQt Latiw.:1e N= C-II 329536 1661.71 $9<J0549.oo 664140.00 70"17'54.775N 148"4()'14.357W !J Easlmg Shape TARGET DET All.S TVD +Ni...\) +-E/·W NoI1hing SECTION DETAILS Sec MD Ine Azi TVD +NI-S +E/-W DLeg TFaœ VSee Target 1 8200.00 41.65 210.38 7692.79 ~1709.43 - 1043.29 0.00 0.00 416.64 2 8220.00 41.92 213.96 7707.71 -1720.71 -1050.38 12.00 85.00 40K09 3 8954.96 20.64 225.74 8332.77 -2018.42 -1283.17 3.00 168.94 137.22 4 9143.18 20.64 225.74 8508.91 -2064.72 -1330.69 ......-0.00 0.00 83.89 5 9901.21 90.00 83.76 9018.30 -2139.41 -927.01 14.00 -140.13 473.78 C-ll A T2ew 6 10476.16 90.00 83.76 9018.30 -2076.88 -355.4 7 0.00 0.00 1048.53 C-llA Tlew o II I' , , I I ¡; I' rI II /p ;/!~ FORMATION TOP DETAILS WlìLL DE1AfLS NaUiIf ¡.N!..."ì +Fj·W Northing Ea.!>1ìng Latitude Longitude Slot No. TVDPath MDPath Formatîon C-II 3295.36 [66J.7[ 5%0549.00 664140.00 7WI7'54.775N IM¡"4û'14351W II 1 8029.30 8618.56 TID TARGET DETAILS 2 8110.30 871 Lll TJC Nill,~ rYD <-Ni-S ~E!.W 3 8342.30 8965.14 TJA Northing Easting Shape 4 8412.30 9039.94 TSGR 5 8443.30 9073.06 TSHU 6 8516.30 9151.05 TSADITZ4 7 8708.30 9350.14 TCGLITZ3C SECTION DET AJLS 8 8778.30 9425.87 BCGLlTZlC 9 8830.30 9486.20 23SB/TZ2Bu See MD Ino Azi TVD +N/-S +E/-W Dug TFace VSec Target 10 8888.30 9560.99 22TSITZ2BI n 8950.30 9658.64 21 TSlTZ2A ¡ 8200.00 41.65 210.38 7692.79 -1709.43 -1043.29 0.00 0.00 416.64 12 8963.30 9683.68 PGOC 2 8220.00 41.92 213.96 7707.71 -1720.71 -1050.38 12.00 85.00 408.09 3 8954.96 20.64 225.74 8332.77 -2018.42 -1283.17 3.00 168.94 137.22 4 9143.18 20.64 225.74 8508.91 c2064.72 -1330.69 0.00 0.00 83.89 5 9901.21 90.00 83.76 9018.30 -2139.41 -927.01 14.00 -140.13 473.78 C-11A T2cw 6 10476.16 90.00 83.76 9018.30 -2076.88 -355.47 0.00 0.00 1048.53 C-nA Tlew COMPANY DETAILS DP Amoco REFb1ŒNCE INFORMATION TnreNorth SURVEY PROGRAM Depth Pm Depth To Surv<..'}'fPlau 8200.00 10476.16 Plrnmed:C¥IIAwp04cV2 CASlNG DETAILS No. TVD MD Name Size 8412.30 9039.94 7" 7.000 9018.30 10476.15 4112" 4.500 are 3 " ~ 8 t:!, '+ ~. 5 ~ ~ 5 00 : 8200' MD, 7692.79'TVD -1200 ·1000 -800 West(-)IEast(+) [2ooft!in] -600 -400 -200 Plan: C~¡ tA wpû4c (C-1 IPJanC-IIA) Too! Created By: Ken Allen Checked: Date: ¡ 2/3/2002 MWD D¡¡te:~ Date' Reviewed -- --~~.~~~,~-,~ o II I' I' , I I ¡; I' rI ,I 1,1 ;/!~ ) BP KW A Planning Report MAP . Cºlµp~my: Field: . . Sit~~ Wëll:. Wëllpäth: .·.Dilte: .12/3/2002 Time: 15:13:51 Co~ordinatê(NErRef~rence:V\'ell;C-11,nÜeNorth ... VertlCal(rVD) R¢fe..erice:~3;39'6~;~... ... ... ... ...... ...... Section (yS) Rèfèrence:User(;;2218.4~N,~13g4.3!3E,82;24Azi) . Survey Calculation Method: M.inimunïCUiVature··· . Db: ··Oräcle BPAmöco ·Aruphþ~Bay ÞEfC Pad ·C-11 Plan· C':11A 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 Map Zone: Coordinate System: Geomagnetic Model: 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: ') ) Alaska, Zone 4 Well Centre / BGGM2002 70 17 22.367 N 148 41 2.797 W True 1.24 deg Well: C-11 Slot Name: 11 C-11 Well Position: +N/-S 3295.36 ft Northing: 5960549.00 ft Latitude: 70 17 54.775 N +E/-W 1661.71 ft Easting : 664140.00 ft Longitude: 148 40 14.357 W Position Uncertainty: 0.00 ft Wellpath: Plan C-11A Drilled From: Tie-on Depth: 63.30 ft Above System Datum: Declination: Mag Dip Angle: +E/-W ft -1394.39 Current Datum: Magnetic Data: Field Strength: Vertical Section: 63.30' 10/4/2002 57534 nT Depth From (TVD) ft 0.00 +N/-S ft -2218.49 Height Plan: C-11A wp04c Date Composed: Version: Tied-to: Principal: Yes Casing Points C-11 8200.00 ft Mean Sea Level 26.08 deg 80.81 deg Direction deg 82.24 11/18/2002 2 From: Definitive Path MD TVD Diameter Hole Size Name ft ft in in 9039.94 8412.30 7.000 8.500 7" 10476.15 9018.30 4.500 6.125 41/2" Formations MD TVD Formations Lithology Dip Angle Dip Direction ft ft deg deg 0.00 UG4A 0.00 0.00 0.00 UG3 0.00 0.00 0.00 UG1 0.00 0.00 0.00 WS2 0.00 0.00 0.00 WS1 0.00 0.00 0.00 CM3 0.00 0.00 0.00 CM2 0.00 0.00 0.00 CM1 0.00 0.00 0.00 THRZ 0.00 0.00 0.00 BHRZ/LCU 0.00 0.00 0.00 TKNG 0.00 0.00 8618.56 8029.30 TJD 0.00 0.00 8711.11 8110.30 TJC 0.00 0.00 8965.14 8342.30 TJA 0.00 0.00 9039.94 8412.30 TSGR 0.00 0.00 9073.06 8443.30 TSHU 0.00 0.00 9151.05 8516.30 TSAD/TZ4 0.00 0.00 9350.14 8708.30 TCGL/TZ3C 0.00 0.00 9425.87 8778.30 BCGL/TZ2C 0.00 0.00 9486.20 8830.30 23SB/TZ2Bu 0.00 0.00 9560.99 8888.30 22TS/TZ2BI 0.00 0.00 9658.64 8950.30 21TS/TZ2A 0.00 0.00 ') BP KW A Planning Report MAP ) çom,paIlY: Field: ~it~: . Well: Wellpatb: D~te:. .. .12/3/2002 Time: . .15:13:51, Page: Co.()r~in*¢(NE)Reference: Wøll: C·1.~, Tru,eNorth Vertical (1'VD)R:eference: 6313Ù'6313 , , Séttiori (VS)Réference: , Ušer(-2218.49N,~1394.39E,82;24Azi) . Survey CalcUlåtioÍiN1etbod: .', Minimum CUrVåture. ..' . Db:." Oracle Formations MD ft 9683.68 TVD ft 8963.30 0.00 PGOC HOT , < J)IJ:fAngleDipJ)irection deg .d~g 0.00 0.00 0.00 0.00 Targets C-11A T1cw Map Map <:':"·..;Latitude' .:.._~ +N/~S +E/lW NQrtbÌl~g Easting , D~g. Mil1···· ~éc , ft '. 'ft ft ft· , -1839.30 -470.32 5958700.00 663710.00 70 17 36.686 N 148 40 28.064 W -1839.30 -470.32 5958700.00 663710.00 70 17 36.686 N 148 40 28.064 W -2265.24 -204.54 5958279.99 663985.00 70 17 32.497 N 148 40 20.317 W -2333.01 -536.12 5958205.00 663655.00 70 17 31.830 N 148 40 29.980 W -2303.30 -980.61 5958225.00 663210.00 70 17 32.122 N 148 40 42.934 W -1936.83 -1042.63 5958590.00 663140.00 70 17 35.726 N 148 40 44.742 W 9018.30 -2139.41 -927.01 5958390.00 663260.00 70 17 33.734 N 148 40 41.372 W 9018.30 -2076.88 -355.47 5958465.00 663830.00 70 17 34.349 N 148 40 24.716 W C-11A Poly -Polygon 1 -Polygon 2 -Polygon 3 -Polygon 4 -Polygon 5 C-11A T2cw Plan Section Information MD loci Azim TVD +N/.;S +E/';W .DLS Build Turn TFO Target ft deg deg , ft ft ft deg/1 00ftdeg/1 OOft deg/1 OOft ge9 8200.00 41.65 210.38 7692.79 -1709.43 -1043.29 0.00 0.00 0.00 0.00 8220.00 41.92 213.96 7707.71 -1720.71 -1050.38 12.00 1.32 17.90 85.00 8954.96 20.64 225.74 8332.77 -2018.42 -1283.17 3.00 -2.90 1.60 168.94 9143.18 20.64 225.74 8508.91 -2064.72 -1330.69 0.00 0.00 0.00 0.00 9901.21 90.00 83.76 9018.30 -2139.41 -927.01 14.00 9.15 -18.73 -140.13 C-11A T2cw 10476.16 90.00 83.76 9018.30 -2076.88 -355.47 0.00 0.00 0.00 0.00 C-11A T1cw Survey MD loel Azim TVD Sys TVD MapN MapE VS DLS TFO Tool/Comment ft deg deg ft ft ft ft ft d eg/1 000 deg 8200.00 41.65 210.38 7692.79 7629.49 5958817.31 663134.37 416.64 0.00 0.00 MWD 8220.00 41.92 213.96 7707.71 7644.41 5958805.88 663127.53 408.09 12.00 85.00 MWD 8300.00 39.56 214.68 7768.32 7705.02 5958762.13 663099.05 373.11 3.00 168.94 MWD 8400.00 36.63 215.69 7847.00 7783.70 5958710.94 663064.62 331.09 3.00 168.40 MWD 8500.00 33.71 216.85 7928.74 7865.44 5958663.77 663031.60 291.07 3.00 167.60 MWD 8600.00 30.79 218.20 8013.31 7950.01 5958620.75 663000.05 253.17 3.00 166.65 MWD 8618.56 30.25 218.48 8029.30 7966.00 5958613.22 662994.36 246.38 3.00 165.51 TJD 8700.00 27.90 219.81 8100.47 8037.17 5958581.99 662970.08 217.49 3.00 165.27 MWD 8711.11 27.58 220.01 8110.30 8047.00 5958577.95 662966.85 213.67 3.00 164.11 TJC 8800.00 25.03 221 .75 8189.98 8126.68 5958547.61 662941.75 184.13 3.00 163.93 MWD 8900.00 22.18 224.16 8281.61 8218.31 5958517.69 662915.16 153.18 3.00 162.37 MWD 8954.96 20.64 225.74 8332.77 8269.47 5958503.18 662901.31 137.22 3.00 160.17 MWD 8965.14 20.64 225.74 8342.30 8279.00 5958500.62 662898.79 134.34 0.00 0.00 TJA 9000.00 20.64 225.74 8374.93 8311.63 5958491.85 662890.18 124.46 0.00 0.00 MWD 9039.94 20.64 225.74 8412.30 8349.00 5958481.81 662880.32 113.14 0.00 0.00 TSGR 9073.06 20.64 225.74 8443.30 8380.00 5958473.48 662872.14 103.76 0.00 0.00 TSHU 9100.00 20.64 225.74 8468.51 8405.21 5958466.71 662865.48 96.12 0.00 0.00 MWD 9143.18 20.64 225.74 8508.91 8445.61 5958455.86 662854.82 83.89 J 0.00 0.00 MWD 9150.00 19.92 223.94 8515.31 8452.01 5958454.14 662853.19 82.01 14.00 219.87 MWD 9151.05 19.81 223.66 8516.30 8453.00 5958453.88 662852.94 81.73 14.00 221.56 TSAD/TZ4 9175.00 17.45 216.18 8539.00 8475.70 5958447.94 662848.15 76.06 14.00 221.83 MWD 9200.00 15.37 206.18 8562.98 8499.68 5958441.86 662844.61 71.61 14.00 228.91 MWD 9225.00 13.86 193.63 8587.18 8523.88 5958435.93 662842.57 68.67 14.00 238.51 MWD 9250.00 13.11 178.91 8611.50 8548.20 5958430.17 662842.05 67.25 14.00 250.66 MWD 9275.00 13.26 163.54 8635.85 8572.55 5958424.61 662843.03 67.35 14.00 264.97 MWD ) ) ) BP KW A Planning Report MAP (:ol11pany: BPArnoco Dåte:.. ···..·12/3/2.002 Time: .15:13:51·· 3 Field:. PrµdhoeBay ·Co~ord~~u\tè(N:E) :Reference: Wel.l: <>11; True North si~¢: .. ·PBCPad ... V¢rtltit,ï (J'VD)!Referenc~: 63:30'63.3 . . Well:... C~11 Section (yS) Rëfërence: tJ~er (l,;2218A9NH394.39E,82J24Azi) ... Wellpath: PlanC.,t1A , Survey·CalcülationMethod: ··MlnimumCur'lläture Db: Oracle Survey . .MD InCl Azim TV]) Sys 'rVD MapN MapE VS DLS TFO fl deg .., d~g ft. ft ft ft ft dE)g/1.o~. .. de~ 9300.0.0 14.28 149.43 866.0.13 8596.83 5958419.26 662845.53 68.98 14..0.0 279.95 MWD 9325..0.0 16..0.0 137.73 8684.27 862.0.97 5958414.13 662849.53 72.13 14..0.0 293.65 MWD 9350..0.0 18.23 128.53 87.08.17 8644.87 5958409.27 662855.02 76.79 14.0.0 3.04.95 MWD 9350.14 18.24 128.48 87.08.3.0 8645..0.0 59584.09.24 662855..05 76.82 14.0.0 313.75 TCGLlTZ3C 9375..0.0 2.0.8.0 121.39 8731.73 8668.43 59584.04.67 662861.97 82.93 14..0.0 313.80 MWD 9400..0.0 23.6.0 115.83 8754.88 8691.58 595840.0.36 662870.36 9.0.55 14..0.0 320.48 MWD 9425..0.0 26.56 111.41 8777.52 8714.22 5958396.35 66288.0.16 99.6.0 14..00 325.64 MWD 9425.87 26.66 111.27 8778.3.0 8715..0.0 5958396.22 662880.53 99.94 14..0.0 329.64 BCGLlTZ2C 9450..0.0 29.63 1.07.83 8799.58 8736.28 5958392.66 662891.33 11.0..05 14.0.0 329.77 MWD 9475..0.0 32.78 1.04.87 882.0.96 8757.66 5958389.3.0 662903.83 121.88 14.0.0 332.8.0 MWD 9486.2.0 34.21 103.71 8830.3.0 8767.0.0 5958387.91 662909.86 127.61 14..0.0 335.33 23SB/TZ2Bu 9500..0.0 35.98 102.39 8841.59 8778.29 5958386.29 662917.62 135..02 14..00 336.3.0 MWD 9525..00 39.23 1.00.26 8861.39 8798..09 5958383.63 662932.64 149.44 14.0.0 337.38 MWD 9550.0.0 42.52 98.41 8880.29 8816.99 5958381.34 662948.83 165..07 14.0.0 339..07 MWD 9560.99 43.97 97.67 8888.30 8825.0.0 595838.0.45 662956.31 172.32 14..0.0 340.47 22TS/TZ2BI 9575..00 45.83 96.78 8898.22 8834.92 5958379.42 662966.14 181.87 14..0.0 341..01 MWD 9600.0.0 49.16 95.32 8915.11 8851.81 5958377.89 662984.5.0 199.77 14..0.0 341.64 MWD 9625.0.0 52.51 94.01 893.0.9.0 8867.6.0 5958376.74 663003.85 218.69 14..0.0 342.62 MWD 9650..0.0 55.87 92.8.0 8945.53 8882.23 5958375.98 663024.10 238.58 14..00 343.45 MWD 9658.64 57.03 92.41 8950.3.0 8887.0.0 5958375.81 663.031.3.0 245.66 14..00 344.16 21TS/TZ2A 9675.0.0 59.24 91.69 8958.94 8895.64 5958375.62 663045.19 259.35 14.0.0 344.38 MWD 9683.68 60.41 91.32 8963.3.0 890.0.0.0 5958375.59 663052.70 266.76 14..00 344.75 PGOC 9700..00 62.62 90.66 8971.08 8907.78 5958375.66 663067.04 280.94 14..0.0 344.94 MWD 9725.00 66.01 89.68 8981.92 8918.62 5958376.08 663.089.56 303.25 14..0.0 345.26 MWD 9750.00 69.4.0 88.76 8991.40 8928.1 a 5958376.91 663112.67 326.20 14.0.0 345.68 MWD 9775..00 72.8.0 87.87 8999.49 8936.19 5958378.12 663136.29 349.72 14..00 346..03 MWD 9800.00 76.21 87.02 9.0.06.17 8942.87 5958379.72 663160.32 373.71 14..0.0 346.32 MWD 9825.00 79.61 86.19 9011.41 8948.11 5958381.70 663184.68 398..08 14..0.0 346.55 MWD 9850.0.0 83..02 85.38 9015.18 8951.88 5958384.05 663209.27 422.74 14.0.0 346.72 MWD 9875.00 86.43 84.59 9.017.48 8954.18 5958386.77 663234..01 447.60 14..00 346.84 MWD 9901.21 9.0..0.0 83.76 9018.30 8955..00 5958390.00 66326.0.0.0 473.78 14.0.0 346.91 C-11A T2cw 10000.0.0 90.0.0 83.76 9018.30 8955.00 5958402.89 663357.94 572.54 .0..0.0 .0..0.0 MWD 10100.00 90..00 83.76 9018.3.0 8955.0.0 5958415.93 663457..08 672.50 .0..00 0.00 MWD 1.0200.00 9.0.0.0 83.76 9.018.30 8955..00 5958428.97 663556.22 772.47 .0.0.0 .0.00 MWD 10300.00 90.0.0 83.76 9018.30 8955.00 5958442.02 663655.36 872.43 0..0.0 .0..00 MWD 10400.00 90.0.0 83.76 9.018.3.0 8955.0.0 5958455.06 663754.50 972.40 .0..00 0.00 MWD 1.0476.16 9.0.0.0 83.76 9.018.30 8955.00 5958465.00 663830.0.0 1048.53 0..0.0 .0..0.0 C-11A T1cw Re: C-ll A Permit to Drill Subject: Re: C-IIA Permit \ }ill Date: Mon, 24 Mar 2003 13:1'0:25 -0900 From: Winton Aubert <Winton_Aubert@admin.state.ak.us> Organization: AOGCC To: "Tirpack, Robert B" <TirpacRB@BP.com> ) Rob, I'll make the change in our version. Nothing more is required. Thanks, Winton "Tirpack, Robert B" wrote: > Winton, > > After reviewing the C-11A Permit to Drill that was sent over to the AOGCC, I > noticed an error in the procedure. The error is with the 8-1/2" hole > integrity testing. On Page 3/ in the Well Control section, in the > Intermediate Hole Table: the 8-1/2" hole integrity test is listed as a LOT. > .This is incorrect. The correct integrity test will be a FIT. On Page 4 in > the Procedure Summary, Step #9 correctly states that a FIT will be > performed. > > A new permit can be sent over if required. > > Thank you / > Rob Tirpack > 564-4166 office > 440-8633 cell P055027 _=~_~~_-D~li:_-_~~ 1_ _ l;¡.i'j~IS_~Q;_. 3/12/2003 I 055027 VENLJOn '--~'~~-------'-------------~ ---------------- ----------------------~--.- -- DATE INVOICE I CREDIT MEMO DESCRIPTION GROSS DISCOUNT - r---- I\jLl --------~~-~ ------~---~---~-- 3/12/2003 INV# CK030603 PERMITTC DRILL ~-iI ,~<~~~ ~·~,U ~ r, !J' "'.) \\JfJn.,.. MA R Z ; (~l \ , --------..~---~--~---~ ì'HE AìT.i\(;HED CHECK IS IN PAYMENT FOR ITEMS DESCRIBED ABOVE. _-- -. '_. .... _ "1- ~ ~. ~,T'OTAJ.. J!t ----=r- ~=J~_~~___ -~ . ----------:-- --:--,- _n___~__,______u 'I NATIONAL CITY ,BANK 56-389 No u ¡p 0 5 5 0 2 71 /\shland, Ohio 412 ' CONSOLIDATED GOMMERCI/\t. ACCOUNT I ------------------ BP EXPLORATiON, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 1 966¡ 2 ANCHORL,GE :.\K 99519-6612 PAY: ~ B ~) tf"< '' '' .! ...!) "II.. () ____~ OATE,___.._.___ March 12,2003 ~__.~._....!:~IY!(¿!JI\!l_ . " *******$1 00.00*******1 ______ ___.J NOT VAl;2~J;~<r . 'i.:":..:' ... TO THE ORDER OF: ALASKA Oil & GAS CONSERVATION COMMISSION 333 W 7TH AVENUE SUITE 100 ANCHORAGE, AK 99501-3539 ! L_____~~_~_____ --------- - II' 0 5 5 0 2 7 III i: 0 L. ~ 2 0 :Hi c¡ 5 I: 0 ~ 2 7 a E1 b 1112 ) ) TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTERJPARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME .flßrY c-- / a PTD# 2ð,,?'" 0 y?, CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (H API number 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: 07110/02 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 per.mafrost or from where samples are first caught and 10' sample intervals through target zones. ,/ /6' s"C) ~~ WELL PERMIT CHECKLIST COMPANY A/X WELLNAMEf/I?Ú /:-1)4 PROGRAM: Exp_ DevX- Redrll~ Re-Enter_ Serv tWellbOreSeg_ FIELD & POOL ~..s~fQß~TCLASS (J<IL(/ /-'::>'1 GEOLAREA ?7n UNIT# - CStð/~- ON/OFFSHORE ðlLJ ADMINISTRATION 1. Permit fee attached. . . . . . . . . . . . . . . . . . . . . . . 10 N 2. Lease number appropriate. . . . . . . . . . . . . . . . . . . Y N 3. Unique well name and number. . . . . . . . . . . . . . . . . Y N 4. Well located in a defined pool.. . . . . . . . . . . . . . . . . Y N 5. Well located proper distance from drilling unit boundary. . . . Y N 6. Well located proper distance from other wells.. . . . . . . . . Y N 7. Sufficient acreage available in drilling unit.. . . . . . . . . . . Y N ¿tJ 3 /_ Ii /., -;> 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N rIY- ~ t/...) 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.. . . . . \i) N (Service Well Only) 13. Well located wlin area & strata authorized by injection order#_ Y ~.' /,--/(A \ (Service Well Only) 14. All wells wlin ~ mile area of review identified. . . . . . . . .. YN' ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . ¥-N- 16. Surface casing protects all known USDWs. . . . . . . . . . -¥-"tV"" ¡J/A- 17. CMT vol adequate to circulate on conductor & surf csg. . . . -¥-N- . 18. CMT vol adequate to tie-in long string to surf csg. . . . . . . . ~ 19. . CMT will cover all known productive horizons. . . . . . . . '. . N 20. Casing designs adequate for C~ T, B & permafrost. . . . . . . N . / L .. E( 21. Adequate tankage or reserve pit.. . . . . . ., . . . . . . . . N ¡\.1M 0 vS 7.- 22. If a re-drill, has a 10-403 for abandonment been approved. . . . N ~/1.,.p1 0'3 ~ 23. Adequate wellbore separation proposed.. . . . . . . . . . . . N 24. If diverter required, does it meet regulations. . . . . . . .. . .-¥-N" N /.A- . 25. Drilling fluid program sChem. atic & equip list adequate. . . . . I N 1Yl~ fJI//J ,.19,5 pp~ · 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N 27. BOPEpressratingappropriate;testto 3500 psig. NfJ1Çp Z-4-I{ pç;,. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . . N WGA-- Sf2-4/0 5, 29. Work will occur without operation shutdown. . . . . . . . . . . .. N 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . Y <82. 31. Mechanical condition of wells within AOR verified. . . . . . . . ·¥-N-Al/A- y(fþ Jry N ¡u/l.. y. N N APPR DATE APPR DATE (Service Well Only) GEOLOGY APPR DATE /1/ 3Þyk . (Exploratory Only) ( 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. ...... I \ GEOLOGY: PETROLEUM ENGINEERING: RESERVOIR ENGINEERING UIC ENGINEER COMMISSIONER: Comments/Instructions: RP~ TM JH JR SP RR 0-f/¿ tf!6 ) / MW Ds03j<f/cB SFD_ WA Rev: 2/25/03 \welLpermiCchecklist ) ) Welll--1istory 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 sinlplify finding infomlation. information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically .. organize this category of information. ) ) t)03~048 " \ ~<63 Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Mon May 12 15:28:55 2003 Reel Header Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/05/12 origin. . . . . . . . . . . . . . . . . . . STS Reel Name............... . UNKNOWN Continuation Number..... .01 Previous Reel Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Tape Header Service name.... . . . . . . . . .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/05/12 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Previous Tape Name...... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Comment Record TAPE HEADER Prudhoe Bay Unit MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA C-11A 500292038201 BP Exploration (Alaska) I Inc. Sperry-Sun Drilling Services 12-MAY-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002376326 J. SACK RALL/WESLEY MWD RUN 2 MW0002376326 J. SACK BORDES/WESLE MWD RUN 3 MW0002376326 J. SACK BORDES/WESLE JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0002376326 J. SACK BORDES/WESLE MWD RUN 6 MW0002376326 J. BOBBITT BORDES/VAUGH # SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 19 11N 14E 665 1222 t:"~'~~lC~:,~C~ E:' (J 61.83 34.08 P q·.1 0, r,) 2003 v t.,·. ~ .... (/, L~C;·i·¡n1~E~~hJn K'D~\~'\~ ) # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 8.500 9.625 8193.0 6.125 7.000 9036.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTH (MD) UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH (TVD). 3. MWD RUN 1 WAS DIRECTIONAL ONLY TO POSITION THE WHIPSTOCK. THE TOP OF THE WINDOW IS 8193'MD/7687'TVD AND THE BOTTOM OF THE WINDOW IS 8209'MD/7699TVD. SROP DATA ARE INCLUDED FOR THIS RUN. 4. MWD RUN 2 COMPRISED DIRECTIONAL WITH DUAL GAMMA RAY (DGR, UTILIZING GEIGER-MUELLER TUBE DETECTORS) AND ELECTROMAGNETIC WAVE RESISTIVITY -PHASE 4 (EWR4). 5. MWD RUNS 3,5,AND 6 COMPRISED DIRECTIONAL¡ DGR¡ EWR4¡ STABILIZED LITHO-DENSITY (SLD) ¡ AND COMPENSATED THERMAL NEUTRON POROSITY (CTN). RUN 4 MADE NO FOOTAGE DUE TO AN INABILITY TO CIRCULATE. THE SLD TOOL FAILED DURING MWD RUN 5 - NO DATA WERE ACQUIRED. MAD PASS SLD DATA WERE ACQUIRED OVER THE INTERVAL FROM 9572'MD - 10085'MD (BIT DEPTHS) WHILE RIH FOR RUN 6. 6. MWD DATA ARE CONSIDERED PDC PER E-MAIL AUTHORIZATION FROM DEWAYNE SCHNORR, DATED 2 MAY 2003. 7. MWD RUNS 1,2,3,5,AND 6 REPRESENT WELL C-IIA WITH API# 50-029-20382 -01. THIS WELL REACHED A TOTAL DEPTH OF 10645' MD / 9017' TVD. SROP SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC SMOOTHED GAMMA RAY COMBINED. SEXP SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA-SHALLOW SPACING) . SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING) . SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING) . SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING) . SFXE = SMOOTHED FORMATION EXPOSURE TIME - DEEP RESISTIVITY. TNPS = SMOOTHED THERMAL NEUTRON POROSITY (SANDSTONE MATRIX, FIXED ') HOLE SIZE) . CTFA SMOOTHED AVERAGE OF FAR DETECTOR'S COUNT RATE. CTNA SMOOTHED AVERAGE OF NEAR DETECTOR'S COUNT RATE. SBD2 SMOOTHED BULK DENSITY-COMPENSATED (LOW-COUNT BIN) . SC02 = SMOOTHED STANDOFF CORRECTION (LOW-COUNT BIN) . SNP2 = SMOOTHED NEAR-DETECTOR-ONLY PHOTOELECTRIC ABSORPTION FACTOR (LOW-COUNT BIN) . SLIDE = NON-ROTATED INTERVALS REFLECTING BIT DEPTHS. SLDSLIDE = SLIDE INTERVALS ACCOUNTING FOR BIT-TO-SENSOR DISTANCE. PARAMETERS USED IN POROSITY LOG PROCESSING: HOLE SIZE: 6.125" MUD WEIGHT: 8.4 PPG MUD SALINITY: 1200 PPM CHLORIDES FORMATION WATER SALINITY: 10,994 PPM CHLORIDES FLUID DENSITY: 1.0 G/CM3 MATRIX DENSITY: 2.65 G/CM3 LITHOLOGY: SANDSTONE $ File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/12 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.OOO Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted DEPTH INCREMENT: # FILE SUMMARY PBU TOOL CODE GR RPX RPS RPM RPD FET ROP NCNT FCNT NPHI RHOB DRHO PEF $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 7992.5 8190.0 8190.0 8190.0 8190.0 8190.0 8193.5 8949.0 8949.5 8949.5 9041.0 9041.0 9041.0 STOP DEPTH 10579.5 10586.5 10586.5 10586.5 10586.5 10586.5 10645.0 10553.0 10553.5 10553.0 10566.5 10566.5 10566.5 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH $ # MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE ) MWD MWD MWD MWD MWD $ 1 2 3 5 6 8193.5 8224.5 9036.0 9382.0 10087.5 # REMARKS: MERGED MAIN PASS. $ 8224.5 9036.0 9382.0 10087.5 10645.0 # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction................ . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD FT/H 4 1 68 4 2 GR MWD API 4 1 68 8 3 RPX MWD OHMM 4 1 68 12 4 RPS MWD OHMM 4 1 68 16 5 RPM MWD OHMM 4 1 68 20 6 RPD MWD OHMM 4 1 68 24 7 FET MWD HOUR 4 1 68 28 8 NPHI MWD PU-S 4 1 68 32 9 FCNT MWD CNTS 4 1 68 36 10 NCNT MWD CNTS 4 1 68 40 11 RHOB MWD G/CM 4 1 68 44 12 DRHO MWD G/CM 4 1 68 48 13 PEF MWD BARN 4 1 68 52 14 Name DEPT ROP GR RPX RPS RPM RPD FET NPHI FCNT NCNT RHOB DRHO PEF Service Unit FT MWD FT/H MWD API MWD OHMM MWD OHMM MWD OHMM MWD OHMM MWD HOUR MWD PU-S MWD CNTS MWD CNTS MWD G/CM MWD G/CM MWD BARN Max 10645 286.18 565.27 1489.16 2000 2000 2000 212006 61.17 4034.5 56123.3 2.869 0.562 6.84 Min 7992.5 o 13.25 0.37 0.56 0.63 0.73 0.27 3.37 117.1 15124 2.063 -0.089 0.71 First Reading For Entire File......... .7992.5 Last Reading For Entire File.......... .10645 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Mean 9318.75 84.8283 69.0518 19.2328 31.6953 58.3282 58.9252 63.1389 24.5077 689.909 29159 2.30116 0.0566897 2.11043 Nsam 5306 4904 5175 4794 4794 4794 4794 4794 3208 3209 3209 2681 2681 2681 ) First Reading 7992.5 8193.5 7992.5 8190 8190 8190 8190 8190 8949.5 8949.5 8949 9041 9041 9041 Last Reading 10645 10645 10579.5 10586.5 10586.5 10586.5 10586.5 10586.5 10553 10553.5 10553 10566.5 10566.5 10566.5 version Number......... ..1.0.0 Date of Generation...... .03/05/12 Maximum Physical Record..65535 File Type................ LO Next File Name.......... .STSLIB.002 Physical EOF File Header Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation..... ..03/05/12 Maximum Physical Record..65535 File Type................ LO Previous File Name...... .STSLIB.001 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE ROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 8193.5 STOP DEPTH 8224.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE $ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: 09-APR-03 Insite o Memory 8225.0 8193.0 8225.0 .0 .0 TOOL NUMBER 8.500 8193.0 LSND 10.55 55.0 9.0 5200 3.2 .000 .000 .000 .0 124.0 .0 ) MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O .000 Name Service Order DEPT ROP MWD010 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 Name Service Unit DEPT FT ROP MWD010 FT/H Min 8193.5 0.45 Max 8224.5 7.25 Mean 8209 3.39698 First Reading For Entire File......... .8193.5 Last Reading For Entire File.......... .8224.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/12 Maximum Physical Record. .65535 File Type............... .LO Next File Name.......... .STSLIB.003 Physical EOF File Header Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/12 Maximum Physical Record. .65535 F i 1 e Type................ LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER Nsam 63 63 " .0 First Reading 8193.5 8193.5 Last Reading 8224.5 8224.5 ) FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE GR RPX RPS RPD FET RPM ROP $ 3 ) header data for each bit run in separate files. 2 .5000 START DEPTH 7992.5 8190.0 8190.0 8190.0 8190.0 8190.0 8225.0 STOP DEPTH 8997.0 8989.5 8989.5 8989.5 8989.5 8989.5 9036.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO VENDOR TOOL CODE DGR EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY ELECTROMAG. RES IS. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # 10-APR-03 Insite 66.37 Memory 9036.0 8225.0 9036.0 23.2 41.5 TOOL NUMBER 164580 134760 8.500 8193.0 LSND 10.60 46.0 9.0 4800 3.2 .790 .410 .840 1.750 66.0 135.0 66.0 66.0 ) Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type. ..0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD020 FT/H 4 1 68 4 2 GR MWD020 API 4 1 68 8 3 RPX MWD020 OHMM 4 1 68 12 4 RPS MWD020 OHMM 4 1 68 16 5 RPM MWD020 OHMM 4 1 68 20 6 RPD MWD020 OHMM 4 1 68 24 7 FET MWD020 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 7992.5 9036 8514.25 2088 7992.5 9036 ROP MWD020 FT/H 0 262.72 107.287 1623 8225 9036 GR MWD020 API 34.21 195.88 116.886 2010 7992.5 8997 RPX MWD020 OHMM 0.37 1489.16 3.10512 1600 8190 8989.5 RPS MWD020 OHMM 0.56 1489.46 3.58487 1600 8190 8989.5 RPM MWD020 OHMM 0.95 1490.72 3.20489 1600 8190 8989.5 RPD MWD020 OHMM 0.94 2000 7.74262 1600 8190 8989.5 FET MWD020 HOUR 0.27 212006 178.946 1600 8190 8989.5 First Reading For Entire File......... .7992.5 Last Reading For Entire File.......... .9036 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/12 Maximum Physical Record. .65535 File Type................ LO Next File Name.......... .STSLIB.004 Physical EOF File Header Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/12 Maximum Physical Record. .65535 F i 1 e Type.. . . . . . . . . . . . . . . LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 ) RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT NPHI FCNT FET RPD RPM RPS RPX GR ROP PEF DRHO RHOB $ header data for each bit run in separate files. 3 .5000 START DEPTH 8949.0 8949.5 8949.5 8990.0 8990.0 8990.0 8990.0 8990.0 8997.5 9036.5 9041.0 9041.0 9041.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 9293.5 9293.5 9293.5 9328.5 9328.5 9328.5 9328.5 9328.5 9321.5 9382.0 9308.5 9308.5 9308.5 TOOL STRING (TOP TO VENDOR TOOL CODE DGR SLD CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): 13-APR-03 Insite 66.37 Memory 9382.0 9036.0 9382.0 12.9 20.8 TOOL NUMBER 151107 104765 100547 156401 6.130 9036.0 Quikdril-N 8.40 57.0 8.7 1200 9.4 3.400 2.170 4.300 4.250 73.0 118.0 73.0 73.0 ,) ) # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ . Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD030 FT/H 4 1 68 4 2 GR MWD030 API 4 1 68 8 3 RPX MWD030 OHMM 4 1 68 12 4 RPS MWD030 OHMM 4 1 68 16 5 RPM MWD030 OHMM 4 1 68 20 6 RPD MWD030 OHMM 4 1 68 24 7 FET MWD030 HOUR 4 1 68 28 8 NPHI MWD030 PU-S 4 1 68 32 9 FCNT MWD030 CNTS 4 1 68 36 10 NCNT MWD030 CNTS 4 1 68 40 11 RHOB MWD030 G/CM 4 1 68 44 12 DRHO MWD030 G/CM 4 1 68 48 13 PEF MWD030 BARN 4 1 68 52 14 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 8949 9382 9165.5 867 8949 9382 ROP MWD030 FT/H 0.42 116.83 42.5939 692 9036.5 9382 GR MWD030 API 17.58 565.27 75.9047 649 8997.5 9321.5 RPX MWD030 OHMM 0.69 1147.78 72.1659 678 8990 9328.5 RPS MWD030 OHMM 0.69 1300.88 76.5613 678 8990 9328.5 RPM MWD030 OHMM 0.63 2000 340.122 678 8990 9328.5 RPD MWD030 OHMM 0.73 2000 311.826 678 8990 9328.5 FET MWD030 HOUR 0.86 72.7 11.2963 678 8990 9328.5 NPHI MWD030 PU-S 3.37 61.17 27.4646 689 8949.5 9293.5 FCNT MWD030 CNTS 117.1 4034.5 773.366 689 8949.5 9293.5 NCNT MWD030 CNTS 15124 56123.3 27941.3 690 8949 9293.5 RHOB MWD030 G/CM 2.081 2.869 2.34765 536 9041 9308.5 DRHO MWD030 G/CM -0.056 0.384 0.0754366 536 9041 9308.5 PEF MWD030 BARN 1.22 6.84 2.43004 536 9041 9308.5 First Reading For Entire File......... .8949 Last Reading For Entire File.......... .9382 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/12 Maximum Physical Record. .65535 ) File Type................ LO Next File Name.......... .STSLIB.005 Physical EOF File Header Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/12 Maximum Physical Record. .65535 File Type................LO Previous File Name...... .STSLIB.004 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE NCNT FCNT NPHI GR RPM RPX RPS RPD FET ROP $ 5 header data for each bit run in separate files. 5 .5000 START DEPTH 9294.0 9294.0 9294.0 9322.0 9329.0 9329.0 9329.0 9329.0 9329.0 9382.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # STOP DEPTH 10001.5 10001.5 10001.5 10029.5 10036.5 10036.5 10036.5 10036.5 10036.5 10087.5 TOOL STRING (TOP TO VENDOR TOOL CODE DGR CTN EWR4 $ BOTTOM) TOOL TYPE DUAL GAMMA RAY COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: 15-APR-03 Insite 66.37 Memory 10087.0 9382.0 10087.0 24.8 91.5 TOOL NUMBER 151107 100547 156401 6.130 9036.0 Quikdril-N ) MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. . Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value. . . . . . . . . . . . . . . . . . . . . . -999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O 8.40 42.0 9.1 700 8.8 3.500 2.020 3.900 2.800 70.0 126.0 70.0 70.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD050 FT/H 4 1 68 4 2 GR MWD050 API 4 1 68 8 3 RPX MWD050 OHMM 4 1 68 12 4 RPS MWD050 OHMM 4 1 68 16 5 RPM MWD050 OHMM 4 1 68 20 6 RPD MWD050 OHMM 4 1 68 24 7 FET MWD050 HOUR 4 1 68 28 8 NPHI MWD050 PU-S 4 1 68 32 9 FCNT MWD050 CNTS 4 1 68 36 10 NCNT MWD050 CNTS 4 1 68 40 11 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9294 10087.5 9690.75 1588 9294 10087.5 ROP MWD050 FT/H 5.88 286.18 86.0397 1411 9382.5 10087.5 GR MWD050 API 13.35 128.72 23.6467 1416 9322 10029.5 RPX MWD050 OHMM 4.24 135.46 18.5164 1416 9329 10036.5 RPS MWD050 OHMM 4.46 2000 58.4735 1416 9329 10036.5 RPM MWD050 OHMM 4.79 151.72 22.6347 1416 9329 10036.5 RPD MWD050 OHMM 5.77 388.95 32.0317 1416 9329 10036.5 FET MWD050 HOUR 0.37 33.21 3.67373 1416 9329 10036.5 NPHI MWD050 PU-S 7.3 31 22.7141 1416 9294 10001.5 FCNT MWD050 CNTS 411.6 2297 734.687 1416 9294 10001.5 NCNT MWD050 CNTS 24293.8 45238.4 30538.6 1416 9294 10001.5 First Reading For Entire File......... .9294 ) Last Reading For Entire File.......... .10087.5 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/12 Maximum Physical Record. .65535 F i 1 e Type................ LO Next File Name.......... .STSLIB.006 Physical EOF File Header Service name............ .STSLIB.006 Service Sub Level Name.. . Version Number.......... .1.0.0 Date of Generation...... .03/05/12 Maximum Physical Record. .65535 F i 1 e Type.... . . . . . . . . . . . . LO Previous File Name...... .STSLIB.005 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE PEF RHOB DRHO NPHI FCNT NCNT GR RPM RPS RPD FET RPX ROP $ 6 header data for each bit run in separate files. 6 .5000 START DEPTH 9494.5 9494 . 5 9494.5 10002.0 10002.0 10002.0 10030.0 10037.0 10037.0 10037.0 10037.0 10037.0 10088.0 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME) : TD DRILLER (FT): TOP LOG INTERVAL (FT): BOTTOM LOG INTERVAL (FT): BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: MAXIMUM ANGLE: # TOOL STRING (TOP TO BOTTOM) STOP DEPTH 10566.5 10566.5 10566.5 10553.0 10553.5 10553.0 10579.5 10586.5 10586.5 10586.5 10586.5 10586.5 10645.0 17-APR-03 Insite 66.37 Memory 10645.0 10087.0 10645.0 88.7 94.0 ) VENDOR TOOL CODE DGR SLD CTN EWR4 $ TOOL TYPE DUAL GAMMA RAY STABILIZED LITHO DEN COMP THERMAL NEUTRON Electromag Resis. 4 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: # NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): # TOOL STANDOFF (IN): EWR FREQUENCY (HZ): # REMARKS: $ # Data Format Specification Record Data Record Type..................O Data Specification Block Type.....O Logging Direction. . . . . . . . . . . . . . . . . Down Optical log depth units.......... .Feet Data Reference Point............. .Undefined Frame Spacing.................... .60 .1IN Max frames per record............ .Undefined Absent value..................... .-999 Depth Units. . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O TOOL NUMBER 151107 150253 110041 156401 6.130 9036.0 Quikdril-N 8.40 57.0 9.1 700 8.8 3.300 1.550 3.500 3.800 75.0 167.0 75.0 75.0 Name Service Order Units Size Nsam Rep Code Offset Channel DEPT FT 4 1 68 0 1 ROP MWD060 FT/H 4 1 68 4 2 GR MWD060 API 4 1 68 8 3 RPX MWD060 OHMM 4 1 68 12 4 RPS MWD060 OHMM 4 1 68 16 5 RPM MWD060 OHMM 4 1 68 20 6 RPD MWD060 OHMM 4 1 68 24 7 FET MWD060 HOUR 4 1 68 28 8 NPHI MWD060 PU-S 4 1 68 32 9 FCNT MWD060 CNTS 4 1 68 36 10 NCNT MWD060 CNTS 4 1 68 40 11 RHOB MWD060 G/CM 4 1 68 44 12 DRHO MWD060 G/CM 4 1 68 48 13 PEF MWD060 BARN 4 1 68 52 14 ) ) First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 9494.5 10645 10069.8 2302 9494.5 10645 ROP MWD060 FT/H 3.33 244.86 81.4167 1115 10088 10645 GR MWD060 API 13.25 222.72 36.0507 1100 10030 10579.5 RPX MWD060 OHMM 6.25 25.94 10.9873 1100 10037 10586.5 RPS MWD060 OHMM 6.79 20.68 10.4586 1100 10037 10586.5 RPM MWD060 OHMM 6.96 17.45 10.7675 1100 10037 10586.5 RPD MWD060 OHMM 7.68 17.78 12.1133 1100 10037 10586.5 FET MWD060 HOUR 0.55 20.8 3.19466 1100 10037 10586.5 NPHI MWD060 PU-S 19.01 46.22 24.9633 1103 10002 10553 FCNT MWD060 CNTS 274.6 820.7 580.391 1104 10002 10553.5 NCNT MWD060 CNTS 18270.2 32579.9 28149.8 1103 10002 10553 RHOB MWD060 G/CM 2.063 2.651 2.28954 2145 9494.5 10566.5 DRHO MWD060 G/CM -0.089 0.562 0.0520051 2145 9494.5 10566.5 PEF MWD060 BARN 0.71 4.5 2.03057 2145 9494.5 10566.5 First Reading For Entire File......... .9494.5 Last Reading For Entire File.......... .10645 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/05/12 Maximum Physical Record. .65535 F i 1 e Type................ LO Next File Name.......... .STSLIB.007 Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/05/12 Origin. . . . . . . . . . . . . . . . . . . STS Tape Name............... . UNKNOWN Continuation Number..... .01 Next Tape Name.......... .UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Reel Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . .03/05/12 Origin. . . . . . . . . . . . . . . . . . . STS Reel Name............ ... . UNKNOWN Continuation Number..... .01 Next Reel Name.......... . UNKNOWN Comments................ .STS LIS Writing Library. Scientific Technical Services Physical EOF Physical EOF End Of LIS File
