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203-059
DIVED STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMON .J U L 2 7 2016 WELL COMPLETION OR RECOMPLETION REPORT AND LOG la. Well Status: Oil ❑ Gas ❑ SPLUG 0 Other ❑ Abandoned 0 Suspended 0 1b.Well CAOGCC 20AAC 25.105 20AAC 25.110 Development 0 Exploratory 0 GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Service 0 Stratigraphic Test 0 2. Operator Name: 6. Date Comp.,Susp.,or A nd.: 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 7/1/2016 203-059 • 316-160 3. Address: 7. Date Spudded: 15' API Number: P.O.Box 196612 Anchorage,AK 99519-6612 5/3/2003 50-029-21456-01-00 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 5/8/2003 PBU H-27A • Surface: 430'FNL,1735'FEL,Sec.21,T11N,R13E,UM • 9 Ref Elevations KB 72 5 ' 17. Field/Pool(s): Top of Productive Interval: 159'FSL,1562'FEL,Sec.09,T11N,R13E,UM GL 42.9 • BF 44.14 • PRUDHOE BAY,PRUDHOE OIL • Total Depth: 1150'FSL,2683'FEL,Sec.09,T11N,R13E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: - 11260'19015' ' ADL 028284&028281' 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. Land Use Permit: Surface:x- 642835• y- 5960349 . Zone - ASP 4 . 12823'/9052'' 69-026 TPI: x- 642884 y- 5966220 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 641741 y- 5967189 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes 0 (attached) No 0 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MD/TVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) , 11227'/8995' r 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 SGRC,MGR,CCL,CNL 23. CASING,LINER AND CEMENTING RECORD CASING Wr.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD AMOUNT FT. PULLED TOP BOTTOM TOP BOTTOM 20"x30" Insulated Conductor 31' 111' 31' 111' 36" 8 cu yds Concrete 13-3/8" 72# L-80 31' 2703' 31' 2673' 17-1/2" 3763 cu ft Coldset II 9-5/8" 47# L-80 28' 10613' 28' 8581' 12-1/4" 2523 cu ft Class'G' 7" 26# 1J4S 10360' 11227' 8404' 8995' 8-1/2" 440 cu ft Class'G' 3-1/2"x3-3/16" 8.81#/6.2# L-80 10155' 12823' 8256' 9052' 3-3/4" 125 cu ft Class'G' x2-7/8" /6.16# 24. Open to production or injection? Yes 0 No 0 25. TUBING RECORD If Yes,list each interval open(MD/TVD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 5-1/2"17#L-80 10248' 10108'/8222' te' "4 aNI° 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. Was hydraulic fracturing used during completion? / Per 20 AAC 25.283(i)(2)attach electronic and printed � L(.Q _ �9 information Yes El No 0. SCANNED SEP 0 2016 DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 11319' Set CIBP • 11318' Set CIBP 11260' Set Whipstock 27. PRODUCTION TEST Date First Production: Not on Production Method of Operation(Flowing,gas lift,etc.):N/A Date of Test: Hours Tested: Production for Oil-Bbl: Gas-MCF: Water-Bbl: Choke Size: Gas-Oil Ratio: Test Period mwk► Flow Tubing Casing Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(corn): Press 24 Hour Rate ...S. Form 10-407 Revised 11/2015 CONTINUED ON PAGE 2 Submit ORIGINAL only /• q� 1/11- 8` 3// r., RBDMS l,(/ • - i0 JUL 2 9 2016 6 9z..,/4-, V//� 28. ' CORE DATA • Conventional Core(s) Yes ❑ No H ' • Sidewall Cores Yes ❑ No 0 ' If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes 0 No ll Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach Top of Productive Interval 11222' 8992' separate sheets to this form,if needed,and submit detailed test information per 20 AAC 25.071. 25N-ZONE 28 11222' 8992' 25 P 11225' 8994' 22N 11476' 9043' 22P-Zone 2A 11500' 9044' Formation at total depth: 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Wellbore Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis,paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact: Minge,David Email: David.Minge@bp.com Printed Name: Joe Lastufka Title: Drilling Technologist Signature: Phone: +1 907 564 4091 Date: 1 1 Di r‘: --e 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 TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 11/2015 Submit ORIGINAL Only • • H-27A Well History (Pre-Rig Sidetrack) ACTIVITY CTU #8 w/ 1.5" CT(CTV=23.2) Objective-CTD prep by setting CIBP and running dummy WS drift MIRU - RIH w/ BOT MHA/ PDS logging tool w/2.65" nozzle drift -Tag 3-3/16"x 2-7/8" XO @ 11,313' CTM - Log Up 40 fpm - Paint Flag @ 11,149.96' CTM - Log Up 40 fpm to 9690' CTM - POOH. OOH with logging tools Got good data (+22' FT correction) making correct EOP 11160.44'. MU/RIH w/BOT CIBP 2.56". At flag Elec 11165' Mech 11159', correct depth 11177.67' MID ELEMENT. Set CIBP ME at 11320'. Top of plug at 3/16/2016 111319.47'. Stack 3k down, good set. POOH CTU #8 w/ 1.5" CT (CTV=23.2) Objective-CTD prep by setting CIBP and running dummy WS drift MIRU - RIH w/ BOT MHA/ PDS logging tool w/2.65" nozzle drift -Tag 3-3/16"x 2-7/8" XO @ 11,313' CTM - Log Up 40 fpm - Paint Flag @ 11,149.96' CTM - Log Up 40 fpm to 3/16/2016 9690' CTM - POOH CTU#8 w/ 1.5" CT(CTV=23.2) Objective-CTD prep by setting CIBP and running dummy WS drift MIRU - RIH w/ BOT MHA/ PDS logging tool w/2.65" nozzle drift -Tag 3-3/16" x 2-7/8" XO @ 11,313' CTM - Log Up 40 fpm - Paint Flag @ 11,149.96' CTM - Log Up 40 fpm to 9690' CTM - POOH. OOH with logging tools Got good data (+22' FT correction) making correct EOP 11160.44'. MU/RIH w/BOT CIBP 2.56". At flag Elec 11165' Mech 11159', correct depth 11177.67' MID ELEMENT. Set CIBP ME at 11320'. Top of plug at 3/16/2016 111319.47'. Stack 3k down, good set. POOH CTU #8 w/ 1.5" CT (CTV=23.0) Objective-CTD prep by setting CIBP and running dummy WS drift MIT-T FAILED. Called APE wants to run another CIBP. MU/RIH w/BOT CIBP 2.56". At flag Elec 11170' Mech 11161', correct depth 11177.6' MID ELEMENT. Set CIBP ME at 11300'. Top of plug at 11299.4' CTM. Tried to set down wt on plug, plug slid down hole on top of 1st plug set 11320' ctm. Release from plug leaving top of second plug at 11298.34'. Perform passing MIT-T at initial 2452 psi, final 2303 psi. POH. LD setting tool, RIH w/ BTT 2.625" x 20' dummy WS and tag at 11310' CTM. POH. LD BHA. Stab back on w/ nozzle. Blow down reel w/WFT RDMO CTU #8 to SWS yard and stack out unit due to lack of work 3/17/2016 Job complete CTU#8 w/ 1.5" CT(CTV=23.2) Objective-CTD prep by setting CIBP and running dummy WS drift MIT-T FAILED. Called APE wants to run another CIBP. MU/RIH w/BOT CIBP 2.56". At flag Elec 11170' Mech 11161', correct depth 11177.6' MID ELEMENT. Set CIBP ME at 11300'. Top of plug at 11299.4' CTM. Tried to set down wt on plug, plug slid down hole on top of 1st plug set 11320' ctm. 3/17/2016 3/17/2016 Assist CTU#6 with WFD NGU for reel blow down. • • H-27A Well History (Pre-Rig Sidetrack) CTU #8 w/ 1.5" CT(CTV=23.0) Objective-CTD prep by setting CIBP and running dummy WS drift MIT-T FAILED. Called APE wants to run another CIBP. MU/RIH w/BOT CIBP 2.56". At flag Elec 11170' Mech 11161', correct depth 11177.6' MID ELEMENT. Set CIBP ME at 11300'. Top of plug at 11299.4' CTM. Tried to set down wt on plug, plug slid down hole on top of 1st plug set 11320' ctm. Release from plug leaving top of second plug at 11318.41'. Perform passing MIT-T at initial 2452 psi, final 2303 psi. POH. LD setting tool, RIH w/ BTT 2.625" x 20' dummy WS and tag at 11310' CTM. POH. LD BHA. Stab back on w/ nozzle. Tried to blow down reel with WFT membrane unit but could not get unit rigged up before WFT crew houred out. Retrieve N2 bottle manifold from SLB shop and blowdown coil. 3/17/2016 Job in Progress CTU #8 w/ 1.5" CT(CTV=23.0) Objective-CTD prep by setting CIBP and running dummy WS drift RDMO CTU #8 to SWS yard and stack out unit due to lack of work 3/18/2016 Job Complete T/I/O = 58/320/2. Temp = SI. MIT-IA(pre CTD). Wellhouse, grating, scaffold, and flowline removed. IA FL @ 120' (6 bbls). Bled IAP to BT from 320 psi to 210 psi (FTS). 6/22/2016 Installed railing on swab platform. Currently performing low/high PT. T/I/O= 68/225/04. Pulled tree cap. Installed TS#08 . Torqued & PT'd to API specs. 6/23/2016 (PASS). RDMO ***Job comlpete*** FWHP= 68/225/04. see log or details. Cont from WSR 6/22/16. MIT-IA to 2426 psi PASSED (pre CTD). Pressured IAP using 10.4 bbls of diesel from 267 psi to 2502 psi in 49 min. Monitored for 30 min. 1st 15 min IAP lost 54 psi. 2nd 15 min IAP lost 22 psi for a total loss of 76 psi in 30 min. Bled IAP to BT from 2426 psi 200 psi in 2 hrs (6 bbls). Monitored for 30 min. IAP increased 20 psi. Tag hung. Final WHPs = 60/230/2. 6/23/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 04:00 T/I/O = 60/230/4. Temp = SI. Bleed WHPs to 0 psi (pre CTD). Wellhouse, grating, scaffold, flowline disconnected. IA& OA FL near surface. Bled OAP to 0 psi in 1 min. Currently bleeding IAP & holding open bleed on OA. 6/24/2016 Cont on WSR 6/25/16. Cont from WSR 6/24/16. Bleed WHPs to 0 psi. Bled IAP to BT from 230 psi to 66 psi in 5 hrs. Monitored for 30 min. TP unchanged, IAP increased 20 psi. Job incomplete. Final WHPs = 60/86/0. 6/25/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 05:00. T/I/O = 60/40/VAC. Temp = SI. Bleed WHPs to 0 psi (pre CTD). Wellhouse, scafflold, flooring, and flowline disconnected. T FL @ 100' (3 bbls). IA FL near surface. Currently 6/25/2016 holding an open bleed on IA. T/I/O = 60/110/0. Temp = SI. Bleed WHP's (pre CTD). No wellhouse, grating or flowline. IA, OA FL's near surface. Bled IAP to slop tank from 110 psi to 0 psi in 2.5 hrs (gas/fluid — 1 gal). No monitor ran out of time. 6/25/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 16:30. Cont from WSR 6/25/16. Bleed WHPs to 0 psi (pre CTD). Bled TP to 0 psi in 3 min. Held open bleed for 3 hrs 30 min. Bled IAP from 40 psi to 0 psi in 5 hrs 30 min held open bleed for 30 min. Monitored for 30 min. TP increased <1 psi, IAP increased 1 psi. Final WHPs = 0+/1/VAC. 6/26/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 05:00 T/I/O = 60/8/0. Temp = SI. WHPs (pre CTD). No wellhouse, grating or flowline. IAP increased 8 psi overnight. 6/27/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 02:55 • • H-27A Well History (Pre-Rig Sidetrack) T/I/O = 10/20/0. Temp = SI. Bleed WHP's to —0 psi. (Pre-CTD). TBG & IA FL's = near surface. Bled TP from 10 psi to 0 psi in 10 minutes. Bled IAP from 20 psi to 0 psi in 25 minutes. Rig down & monitor for 30 minutes. No change in WHP's during 30 minute monitor. Final WHP's = 0+/0+/0. 6/28/2016 SV, WV, SSV= C. MV= O. IA, OA= OTG. 22:20. • • • North America ALASKA BP Page 1 Operation Summary Report Common Well Name:H-27 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/29/2016 End Date: X3-017T6-C:(3,673,378 00) Project:Prudhoe Bay Site:PB H Pad Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1985 12:00:00AM Rig Release: Rig Contractor.NORDIC CALISTA UW:500292145600 Active datum:ORIG KELLY BUSHING©72.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 1 6/29/2016 00:00 - 01:00 1.00 MOB P I PRE RIG HAS BEEN RELEASED FROM WELL K-07 AT 00:00. CONDUCT PJSM FOR PULLING OFF THE 'WELL WITH NO TWC IN PLACE. DISCUSS USE OF CHOCK BLOCK TO PREVENT THE RIG ROLLING BACK,ALSO THE 1E-STOP AND RADIO COMMUNICATIONS. PULLING OFF THE WELL WITNESSED BY WSL,TOOLPUSHER,BP OPS SPECIALIST. PARK RIG ON EDGE OF PAD,CLEAN UP AROUND WELL WHILE DRILLER DOES ROUTE DRIVE TO H-PAD. 01:00 - 06:00 . 5.00 MOB P PRE PULL RIG OFF K-PAD,LEFT ON K-PAD ROAD TO TWIN TOWERS ROAD,RIGHT ON SPINE TO H-PAD ACCESS ROAD. TOTAL MILAGE 10.8 MILES. 06:00 - 12:30 6.50 MOB P PRE ,MOVE RIG TOWARDS H-PAD -CONDUCT PRE-SPUD WITH TOWN PERSONNEL AND RIG PERSONNEL IN ATTENDANCE 12:30 - 14:00 1.50 MOB P PRE RIG ON PAD AND STAGED AT 1230 HRS 1-CHECK TREE VALVE ALIGNMENT AND CHECK PRESSURES;0 PSI ON IA/OA/ TUBING -REMOVE LADDER,PLACE T-MATS AND RIG MATS FOR OPERATIONS 14:00 - 14:30 0.50 MOB P PRE 'CONDUCT PJSM FOR MOVING RIG OVER WELL WITH CREW -DISCUSS RADIO COMUNICATION,VISUAL ,STOP SIGNAL,POSITION ASSIGNMENTS -TOOLPUSHER IN CHARGE OF FUNCTION TESTING ESD AND THEN CONTROL OF ESD WHILE PULLING OVER WELL -FLOORHAND IN CHARGE OF PLACING AND MONITORING 12"X 12"BLOCK 14:30 - 15:00 0.50 MOB P PRE PULL OVER WELL WITH NO ISSUES -- -RIG ACCEPTAT 1500 HRS. 15:00 - 15:30 0.50 I RIGU P PRE PREPARE RIG FOR OPERATIONS -TEST RIG ALARMS FOR AOGCC REQUIREMENTS -LIFT REEL,INSTALL -POSITION SUPPORT EQUIPMENT -CONDUCT RIG EVAC DRILL WITH DAY CREW. INITIATED RIG EVAC ALARM IN SECOND LEVEL DURING PRE-JOB MEETING. CREW RESPONDED BY MAKING RADIO CALLS AND EVACUTING TO MUSTER POINT. TOOLPUSHER,MOTORMAN,AND ELECTRICIAN CONDUCTED WALK THROUGH, GIVE ALL CLEAR. 15:30 - 17:00 1.50 RIGU • P PRE PERFORM LTTAGAINST CLOSED SWAB AND MASTER VALVE,GOOD TEST. INSTALL ELECTRONIC TRANSDUCER ON 'WING TO MONITOR PRESSURE IN VOID SPACE. 17:00 - 18:30 1 1.50 RIGU P PRE PJSM,REMOVE TREE CAP. LIFT REEL UP AND INSTALL IN REEL HOUSE. 118:30 - 19:30 1.00 BOPSUR P PRE 1 PJSM THEN INSTALL BOPS. Printed 7/11/2016 10:45:46AM *AII depths reported in Drillers Depths* • North America-ALASKA-BP Page 2gJy , Operation Summary Report Common Well Name:H-27 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/29/2016 End Date: I X3-017T6-C:(3,673,378.00) I i Project Prudhoe Bay Site:PB H Pad Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1985 12:00:00AM I Rig Release: Rig Contractor:NORDIC CALISTA UWI:500292145600 Active datum:ORIG KELLY BUSHING©72.50usft(above Mean Sea Level) Date j From-To j Hrs Task Code NPT NPT Depth I Phase j Description of Operations (hr) (usft) 19:30 - 21:30 2.00 RIGU P PRE ASSEMBLE INJECTOR GOOSENECK AND STRIPPER. I OUTSIDE,SPOT BRM AND FLOWBACK TANK, 1 M/U 1502 LINE FROM RIG TO FLOWBACK TANK. 21:30 - 00:00 2.50 RIGU P PRE j PREP TO PULL CT ACROSS FROM REEL HOUSE INTO INJECTOR. INSTALL GRAPPLE IN END OF CT. CONDUCT PJSM WITH NORDIC AND SLB CREW'FOR PULLING PIPE ACROSS. REVIEW PROCEDURE AND EXCLUSION ZONES FOR THE TASK. PULL PIPE ACROSS PIPE SHED ROOF AND INTO IIV/JECTOR. REMOVE GRAPPLE,STAND INJECTOR ASIDE. 6/30/2016 00:00 - 04:10 4.17 BOPSUR P PRE TEST BOPS AND CHOKE LINE VALVES. TEST WITNESS IS WAIVED BYAOGCC LOU j GRIMALDI. TEST ANNULAR ELEMENT WITH 2"AND 2-3/8" I TEST JOINT TO 250/3500 PSI. TEST BLIND SHEARS(FAIL),TEST UPPER 2" PIPE/SLIP RAMS,TEST 2-3/8"PIPE/SLIP RAMS,LOWER 2"PIPE/SLIP RAMS. NEST FLOOR VALVES AND CHOKE LINE VALVES. 04:10 - 04:30 0.33 - BOPSUR P I PRE RIG EVACUATION DRILL. ALL PERSONS MUSTER AND ACCOUNTED FOR IN 2 MIN. CONDUCT AAR WITH CREWS AFTER THE DRILL. 04:30 - 08:15 3.75 BOPSUR P PRE ;CONTINUE BOP TEST -REVIEWED INCIDENT FINDINGS FROM EVENT AT BP KHAZZAN FACILITY WITH ;CREW. DISCUSSION REVOLVED AROUND WHAT IS IN OUR CONTROL ON OUR LOCATION REGARDING EQUIPMENT INSPECTION,PROPER RIGGING,BRINGING 1IN OTHER PERSONNEL TO INSPECT WORK- -CONDUCT AAR ORK--CONDUCTAAR WITH CRW DURING PRE-TOUR MEETING OF EVACUATION DRILL I DURING RIG UP OPERATIONS. ENFORCED I THE FACT THAT ALL PERSONNEL MADE NO ASSUMPTIONS OF FALSE DRILL AND THAT THEY REACTED AS TRAINED BY EVACUATING RIG AND GOING TO MUSTER POINT. -FUNCTION AND THEN RE-TEST BLIND RAMS,GOOD TEST. 08:15 - 10:45 2.50 BOPSUR P PRE MEG TEST E-LINE,BOOT E-LINE. MAKE UP j I COIL CONNECTOR,PULL TEST TO 35K. MU BHI UPPER QUICK ASSEMBLY. -FLUID PACK REEL. STAB ON TO I LUBRICATOR PRESSURE TEST QUICK TEST SUB. 10:45 - 12:00 F 1.25 RIGU j P PRE VALVE CREW ON LOCATION TO TORQUE j I TREE BOLTS,ALL WERE GOOD. VERIFY SSV FUNCTION. SERVICE TREE VALVES. 12:00 - 13:30 j 1.50 BOPSUR P PRE PRESSURE TEST PACKOFFS,INNER REEL IRON,AND PRESSURE BULKHEAD TO 250 PSI Ii LOW/3500 PSI HIGH TO COMPLETE BOP TEST. Printed 7/11/2016 10:45:46AM *All depths reported in Drillers Depths* • • North America-ALASKA BP,r „ ..; Operation Summary Report Common Well Name:H-27 AFE No Event Type:RE-ENTER-ONSHORE(RON) i Start Date:6/29/2016 End Date: IX3-017T6-C:(3,673,378.00) Project:Prudhoe Bay Site:PB H Pad Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1985 12:00:00AM 1 Rig Release: Rig Contractor.NORDIC CALISTA UWI:500292145600 Active datum:ORIG KELLY BUSHING©72.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth j Phase ! Description of Operations (hr) (usft) 13:30 - 14:30 1.00 RIGU P PRE PJSM FOR HIGH PRESSURE TESTING. COMPLETE DISCUSSION WITH CREW WITH NORDIC PROCEDURE. REVIEW PRESSURE CROSSCHECK CHECKLIST,VERIFY PRESSURE RATING OF COMPONENTS. � -WALK LINES,BYPASS MICROMOTION AND FILTER SCREENS. LINE UP TO PRESSURE TEST FROM COIL CONNECTOR THROUGH I REEL THROUGH THE PRESSURE BULKHEAD AND INNER REEL VALVE AND THROUGH REELHOUSE IRON. I;LOW PRESSURE TEST TO 250 PSI GOOD. BEGIN TO BRING UP TO HIGH PRESSURE OF 6000 PSI BUT LEAK OFF AT 1000 PSI. INSPECT SYSTEM,LEAKING AT COIL CONNECTOR. 14:30 - 15:45 1.25 RIGU N SFAL PRE BREAK OFF UQC AND REMOVE CONNECTOR. INSTALL NEW CONNECTOR,HEAD UP TO 1 UQC. PULL TEST TO 35K,GOOD TEST. FLUID PACK REEL. 15:45 18:30 2.75 RIGU P PRE BRING UP TO 250 PSI LOW/4000 PSI HIGH FOR LEAK TIGHT VERIFICATION OF II CONNECTOR. LEAKTIGHT TEST GOOD. f-RIG UP FOR TEST PUMP. LOW TEST TO 250 PSI GOOD. INCREASE PRESSURE TO 4000 PSI,GOOD. CONTINUE WITH ATTMEPT TO INCREASE PRESSURE TO6000 PSI,SHUT DOWN TO TROUBLESHOOT TEST PUMP. 'BLEED OFF PRESSURE. -BEGIN TESTAGAIN. LOW TEST GOOD. BRING UP PRESSURE,SLOWLY BUILDING UP. REACH TEST PRESSURE OF 6300 PSI. ALLOW TO STABILIZE. 18:30 - 19:30 1.00 RIGU P PRE TEST REEL IRON INCLUDING BULKHEAD FROM CT CONNECTOR BACK TO PUMP LINE ISOLATION VALVES TO 250/6,200 PSI,GOOD. 19:30 - 20:20 0.83 RIGU P PRE INSTALL FLOATS IN UQC AND PT 250/3700 PSI,GOOD. 20:20 - 21:00 0.67 RIGU P PRE OPEN SWAB AND MASTER AGAINST A CLOSED CHOKE TO CHECK FOR WELL PRESSURE,WHP<10 PSI BLEEDS OFF QUICKLY. PUMP 1 REEL VOLUME FORWARD TO PUSH THE CABLE SLACK TO THE DOWNHOLE END. 21:00 - 22:00 1.00 STWHIP P WEXIT FILL WELL WITH 4 BBLS MEOH AND OBSERVE,FLUID LEVEL STATIC. BTTASSEMBLE WHIPSTOCK ONL CATWALK. CONDUCT PJSM FOR PICKING UP WHIPSTOCK BHA. M/U WHIPSTOCK BHAAND INJECTOR. INJECTOR ON 21:50. 22:00 - 00:00 2.00 STWHIP P WEXIT ZERO COUNTERS,TEST QTS AND COILTRAK. RIH. PUMP 1 BPM/700 PSI. HOLD 150 PSI WHP WHILE RIH. AROUND 2000 FT START GETTING GAS BACK. MAKE NOTIFICATIONS TO DSO,STOP 1 CIRCULATING AND SHUT IN WELL EACH TIME 'A STRAP IS REQUIRED,EVERY 1000 FTAS PER NORDICS FLUID MANAGEMENT POLICY. ECD>8.7 PPG WHILE RIH. 7/1/2016 00:00 - 01:15 1.25 STWHIP P WEXIT I CONTINUE RIH. Printed 7/11/2016 10:45:46AM *AII depths reported in Drillers Depths* • ! North America-ALASKA-BP Page 4 obi*. Operation Summary Report Common Well Name:H-27 AFE No Event Type:RE-ENTER-ONSHORE(RON) I Start Date:6/29/2016 End Date: 'X3-017T6-C:(3,673,378.00) Project:Prudhoe Bay I Site:PB H Pad Rig Name/No.:NORDIC 2 Spud Date/me:10/14/1985 12:00:00AM Rig Release: Rig Contractor:NORDIC CALISTA UW:500292145600 Active datum:ORIG KELLY BUSHING©72.50usft(above Mean Sea Level) --T- Date From-To Hrs Task j Code j NPT NPT Depth i Phase Description of Operations (hr) (usft) 01:15 - 02:15 1.00 STWHIP P WEXIT j LOG GR FROM 10,560 FT TO TIE-IN DEPTH. CORRECT+11 FT. 02:15 - 03:10 0.92 STWHIP P WEXIT STOP AND SHUT IN WELL. NEED TO VAC OUT TIGER TANK TO RESUME PUMPING,STILL GETTING GAS BACK. 03:10 - 04:30 1.33 STWHIP P WEXIT TRUCK IS FINISHED,OPEN WELL TO TIGER TANK HOLD 150 PSI WHP PUMP 0.5 BPM. RtH FOR LIGHT TAG OF BRIDGE PLUG. NEED TO KNOW ITS DEPTH SO WE CAN SAFELY LOG CCL ACROSS WHIPSTOCK SETTING DEPTH. TAG AT 11,320 FT. PICK UP AND LOG CCL FROM 11,000 FT. CCL LOG SHOWS CONNECTION AT 11,270 FT WITH TOP WHIPSTOCK AT 11,265 FT THIS WILL PLACE A CONNECTION OPPOSITE THE TRAY. DISCUSS WITH ODE,GEO AND DD,BTT HAND DECIDE TO MOVE WHIPSTOCK UP 5 FT. CLOSE EDC,PRESSURE UP TO 3,000 PSI TO SHEAR SETTING TOOL. SET TOP WHIPSTOCKAT 11,260 FTAT 45R TF. SET 3K ON IT TO CONFIRM SET. 04:30 - 08:15 3.75 STVVFItP WEXIT .I PICKUP 20 FT AND SWAP WELL OVER TO KCL. HOLD 150 PSI WHP,CIRC 2.4 BPM WITH EDC =8.98 PPG WHILE CIRCULATING. AFTER RETURNS CLEAN UP OPEN CHOKE, CIRC 2.43/2.41 BPM IN/OUT WITH 8.39/8.34 PPG. ECD=8.93 PPG. 08:15 - 10:20 2.08 STWHIP - P WEXIT POH TO SURFACE. PJSM FOR FLOW CHECK AND LAYING DOWN BHA. -FLOW CHECK AT SURFACE,ALL GOOD -PULL BHA INTO BOP,POP OFF WITH INJECTOR 10:20 - 11:00 0.67 STWHIP . P j � WEXIT LAY DOWN BHA. ALL TOOLS IN GOOD CONDITION. BREAK OFF WHIPSTOCK RUNNING TOOL,SET ASIDE. -INSPECT PACKOFFS ON INJECTOR DUE TO RUNNING NEW COIL THROUGH THEM. PACKOFFS SHOW ABNORMAL WEAR. CHANGE OUT PACKOFFS. 11:00 - 12:15 1.25 ! STMILL P WEXIT STAB ON WITH INJECTOR. PRESSURE TEST QUICK TEST SUB,CLOSE IN TREE VALVES. -PRESSURE TEST PACKOFFS TO 250 PSI LOW/3500 PSI HIGH. TOOKA WHILE FOR THE HIGH PRESSURE TEST TO STABILIZE, EVENTUALLY GOT GOOD TEST. -DOWN ON PUMPS,OPEN UP TO TESTED BARRIERS. NO PRESSURE. OPEN UP,NO FLOW. 12:15 - 12:40 0.42 STMILL P WEXIT I POP OFF WITH INJECTOR. MAKE-UP MILLING BHA#2. WINDOW MILL 2.75"GO,2.74" I NO-GO. MAKE-UP TO SMART TOOLS. -STAB ON WITH INJECTOR. Printed 7/11/2016 10:45:46AM *All depths reported in Drillers Depths* 1111 • North America-ALASKA-BP Page 5 o Operation Summary Report Common Well Name:H-27 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:6/29/2016 End Date: IX3-017T6-C:(3,673,378.00) Project:Prudhoe Bay Site:PB H Pad Rig Name/No.:NORDIC 2 Spud Date/Time:10/14/1985 12:00:00AM Rig Release: Rig Contractor.NORDIC CALISTA 1UW1:500292145600 Active datum:ORIG KELLY BUSHING 172.50usft(above Mean Sea Level) Date From-To Hrs Task Code NPT NPT Depth Phase Description of Operations (hr) (usft) 12:40 - 15:00 2.33 STMILL P WEXIT I TEST QUICK TEST SUB WHILE MWD TOOLS IARE BEING POWERED UP. BEGIN RUNNING 1 IN HOLE WHILE STILL TESTING. RIH WITH MILLING BHA. NO ISSUES RUNNING IN. LOG TIE IN WITH+9.5' 1CORRECTION 1-INITIAL TAG AT 11,262'. PICK UP WEIGHT OF 37K. RE-ENGAGE WHIPSTOCK LIGHTLY AT 11,261' •Tp p t ( " 15:00 - 20:00 5.00 STMILL P WEXIT BEGIN MILLING OPS FROM 11,261'. FREE 11 �—I'`�I, I SPIN OF 3600 PSI AT 1.65 BPM. � Zl' 'J j -MILLING PER WELL PLAN AND BOT REP MW IN 9.55 PPG,MW OUT 9.52 PPG,ECD OF 110.20 PPG AT 1.65 BPM I-MILL INITIALLY AT 1.65 BPM,3770-3800 PSI, .25-1.4K WOB -INITIAL:IA 55 PSI,OA 375 PSI 20:00 - 23:00 3.00 STMILL P WEXIT CONTINUE MILLING WINDOWAT 11,264.0 FT. 1.67/1.65 BPM WITH 3750 PSI FREE SPIN. ADVANCE MILL AT 0.1 FT/6 MIN WHILE _ _ I KEEPING DWOB BELOW 2.25K. 23:00 - 00:00 1.00 STMILL P WEXIT CONTINUE MILLING WINDOWAT 11,265.7 FT. 1.67/1.65 BPM. MILLING WITH 1.48 KLBS DWOB. 9.55/9.45 PPG IN/OUT. MILL TO 11,266.7 FT. MILL HAS EXITED WINDOWAT 11,266.1 FT • CONTINUE MILLING 1 FT/HR UNTIL STRING REAMER EXITS. 7/2/2016 00:00 - 03:00 3.00 STMILL P WEXIT CONTINUE MILLING RATHOLEAT 11,270.0 FT EXITED IN ZONE 2B DRILLING ABOUT 8 FT/HR WITH 1.6K DWOB. DRILL TO TD OF RATHOLE AT 11,277 FT. 03:00 - 05:00 2.00 STMILL P WEXIT CONDUCT 3 REAMING PASSES THROUGH WINDOWAT 0.5 FT/MIN. 1 SOME MOTOR WORK SEEN AT WINDOW TOP I ON FIRST PASS,SUBSEQUENT PASSES ARE CLEAN. DRY DRIFT WINDOWAFTER 3RD PASS, I CLEAN TO BOTTOM. TAG 11,277 FT. GEO HAS SAND IN BOTTOMS UP SAMPLE. 05:00 - 07:00 2.00 STMILL P WEXIT PULL ABOVE WINDOW AND OPEN EDC. CONDUCT 10 MIN PUMPS OFF FLOWCHECK, NO FLOW. POOH PUMP 2.23 BPM/3960 PSI THROUGH OPEN EDC. I-PULL TO SURFACE WITH NO ISSUES. OA I PRESSURE INCREASED TO 900 PSI,WILL MONITOR ONCE PUMPS ARE OFF. -PJSM FOR FLOW CHECK AND LAYING DOWN BHA. PULL TO SURFACE,FLOW CHECK. NO FLOW,ALL GOOD. PULL BHA INTO BOP. POP OFF WITH INJECTOR. Printed 7/11/2016 10.45:46AM `AII depths reported in Drillers Depths* TREE=' • 6-3/8"CNV FLS WWfILI LEAD= MCEVOY • H -2 7A sillry NOTES:WELL ANGLE>—70°@—11301'. ACTUATOR= BAKER C OKB.8EV= 72.5' REF ELEV= 72.5' - BF.a.EV= 44.14' rte:7 2063' H5-1/2"OTIS SSSV LANDING NP,D=4.562" KOP 112V' 7 J Max Angle= 94°@ 11397' GAS LIFT MANDRELS Datum MD= 11044' ST MD TVD DEV TYPE VLV LATCH PORT DATE Datum TVD= 8800'SS 5 3293 3177 38 OTIS DMY RM 0 01/31/16' 4 6448 5477 46 OTIS DM' RM 0 01/31/16 13-3/8"CSG,72#,L-80,D=12.347" — 2706' LI 3 8639 7108 36 OTIS DMY RA 0 05/11/03 2 9569 7818 43 OTIS DMY RA 0 05/11/03 1 9970 . 8119 41 OTIS DMY RA 0 05/11/03 � r- 10038' �5-1/2"SLD SLV,D=4.562" Minimum lD =2.372" @11344' 2-7/8" CTD LINER - j 10001915' -TBGSEAL ASSY 10110' —1 9-5/8"X 5-1/2"TNV PKR,D=4.75" 10155' —I4-3/8" BKR C2 LNR TIEBACK SLV,D=4.00" 10162' -3-1/2"BKR DEPLOY SLV,ID=3.00" 10163' H5-1/2" (BEHIND LNR) 10181' —3-1/2"X NP,D-2.813" 10206' H5-1/2"XN NP,0=4.455"(BEHIND LNR) 3-1/2"LNR,8.81#,L-80,.0087 bpf,D=2.992" H 10211' 10211' —13-1/2"x 3-3/16"XO,D=2.80" 5-1/2"TBG,17#,L-80,.0232 bpf,D=4.892" H 10251' / \ 10251' H5-1/2"WLEG(BB IND LNR) 10242' -ELMD TT LOGGED 06/21/86 TOP OF 7"LNR —{ 10360' 9-5/8"CSG,47#,L-80,ID=8.681" -H 10613' I • 10665' —I MARKER JOIYT 7"X 5-1/2"BKR WHPSTOCK 11222' I w/2 RA TAGS @ 11232 11000' —ITOP OF CMT LNR 7"LNR,26#,U4S,.0383 bpf,ID=6.276" —I -11227' ••• •�• MLLOUT WINDOW(H-27A)11227'-11233' • Z ::: ►• • W • 11260' H3-3/16" HPSTOCK(07/01/16) -' ►••� 3-3/16"BTT CIBP(03/17/16) H 11318' ` 11343' --13-3/16"X 2-7/8"XO,D=2.441" - 3-3/16"BTT CIBP(03/16/16) —I 11319' '���/`_ 11492' —12-7/8"BTT CIBP(11/16/15) PERFORATION SUMMARY 11740' H2-7/8"WFD CIBP(7/13/15) REF LOG:MCNUCCR/GR ON 05/09/03 3-3/16"LNR,6.2#, —I 11343' // `_ ANGLE AT TOP PERF: 90°@ 11448' L-80,.0076 bpf, /e f 12754' —FISH-2-7/8"CIBP Note:Refer to Rodution DB for historical pert data ID=2.805 MILLED&PUSHED TO BTM(8/30/13) SIZE SPF INTERVAL Opn/Sqz SHOT SQZ 2-7/8"BKR CEP(10/12/15) —I 11700' 2" 6 11448-11478 C 11/16/15 2" 6 11580-11610 C 07/14/15 2" 6 11610-11640 C 07/13/15 FISH-PARTIAL 2-7/8"BKR CBP JI 12766' ,i 2" 6 11800-11830 S 06/10/11 09/07/13 (MILLED&PUSI-ED TI BTM 09/01/13) 2" 6 11830-11860 S 06/10/11 09/07/13 PBTD 12788' 2" 4 12100-12470 S 05/10/03 09/07/13 2-7/8"LNR,6.16#,L-80,.0055 bpf,ID=2.372" — 12823' 2" 4 12520-12770 . S 05/10/03 DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/04/85 ORIGINAL COMPLETION 11/18/15 CJS/JMD SET CIBP/ADPERFS(11/16/15) WELL: I -27A 05/11/03 SRBITLH CTD SIDETRACK(H-27A) 02/15/16 GTW/JMD GLV GO(01/31/16) PERMIT No: 2030590 09/08/14 AVID SCHEMATIC CORRECTIONS 03/21/16 ATO/JMD SET 2 BTT GBP(03/16-17/16) API No: 50-029-21456-01 07/31/15 BLS/JMD SET CDP/GLV C/O(07/13-14/15) SEC 21,T11 N,R13E,430'FNL&1734'FEL 11/18/15 SW/JMD SET CDP(10/12/15) 11/18/15 DU/JMD TREE C/O(11/04/15) BP Exploration(Alaska) • Or Ti • 0•e0 I ,� � THE STATE Alaska Oil and Gas ~ moi'_ a_ o�ALA SJL`►1�ic� Conservation Commissionssion 1 1 , �,,,2_= !, 333 West Seventh Avenue GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS v" Fax: 907.276.7542 www.aogcc.alaska.gov John McMullen �E� a ,�1 i � 23% Engineering Team Lead ` GAS BP Exploration(Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Bay Oil Pool, PBU H-27A Permit to Drill Number: 203-059 Sundry Number: 316-160 Dear Mr. McMullen: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the 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, 444,4, Cathy '. Foerster Chair DATED this et-day of March, 2016. RBDMS L. - MAK 0 9 2016 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM! APPLICATION FOR SUNDRY APPROVALS 20 MC 25.280 1. Type of Request: Abandon 0 Plug Perforations 0 Fracture Stimulate 0 Repair Well 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Change Approved Program 0 Plug for Redrill p• 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 203-059- 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development RI 6. API Number: 50-029-21456-01-00 • 99519-6612 Stratigraphic 0 Service ❑ 7. If perforating: 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU H-27A ' RECEIVED 9. Property Designation(Lease Number): 10. Field/Pools: 16 2 6 20 ADL 028284&028281 " PRUDHOE BAY,PRUDHOE OIL ' FEBCD U U 11. PRESENT WELL CONDITION SUMMARY , OCC Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(lt): 12823 • 9052• 11492 9043 2331 11492,11700&11740, 12754&12766 Casing Length Size MD TVD Burst Collapse Structural Conductor 80 20"x 30" 31-111 31-111 Surface 2672 13-3/8" 31 -2703 31-2673 4930 2670 Intermediate 10585 9-5/8" 28-10613 28-8581 6870 4760 Liner 869 7" 10360-11229 8404-8996 7240/8160 5410/7020 Liner 2668 3-1/2"x 3-3/16"x 2-7/8" 10155-12823 8256-9052 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 11448-11640 9043-9051 5-1/2"17# L-80 26-10248 Packers and SSSV Type: 5-1/2"TIW Packer Packers and SSSV MD(ft)and ND(ft): 10108/8222 12.Attachments: Proposal Summary 0 Wellbore Schematic a 13.Well Class after proposed work: Detailed Operations Program RI BOP Sketch RI Exploratory 0 Stratigraphic 0 Development RI " Service 0 14.Estimated Date for Commencing Operations: March 15,2016 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended RI• 16.Verbal Approval: Date: GAS ❑ 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 Tempel,Troy be deviated from without prior written approval. Email Troy.Tempel@bp.com Printed Name Joh�/ • Title Engineering Team Lead Signature ...••-•—%...s.____ Phone +1 907 564 4711 Date 2�� /( 1 COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number ' 7j \�- \CQO Plug Integrity 0 BOP Test lE Mechanical Integrity Test ❑ Location Clearance 0 Other: /31:9P re-5f fc 35 7 ps..i< Flrznv/ ?r /,fir<L/ -7fC,- fz�S/ Z5-Uc2 p$-L Alterr�afvplug p/aCe-WIP -1f" a-/2prvvrd /�tr 2G �f �tc z;. /�Z << Post Initial Injection MIT Req'd? Yesn No ❑— Spacing Exception Required? Yes 0 No LK/ Subsequent Form Required: /0 - ¢Q APPROVED BYTHE Approved by: COMMISSIONER COMMISSION Date:.? 9_4( v ir- 3/4/)L ORIGINAL ScS, 1,0 RBDMS MAR 0 9 2016 Submit Form and Form 10-403 Revised 11/2015 Approved application is valid for 12 months from the date of approval. 0Attachment in Duplicate • • • To: Alaska Oil & Gas Conservation Commission h From: Troy Tempel CTD Engineer Date: February 25, 2016 Re: H-27A Sundry Approval Sundry approval is requested to abandon the H-27A perforations as part of the drilling and completion of proposed H-27B coiled tubing sidetrack. History and current status: H-27 was drilled and completed in November 1985 as an Ivishak Zone 2 producer. In May 2003, H-27A was successfully coil sidetracked and completed as an Ivishak Zone 2 • producer. After being re-perforated several times, H-27A is currently shut-in due to high GOR. - Proposed plan: Drill a through tubing sidetrack with the Nordic 1 Coiled Tubing Drilling rig on or around April 15, 2016. The M-23B sidetrack will exit the existing 3-3/16" liner and kickoff in the zone 2, targeting Zone 2 reserves. The sidetrack will be completed with a 2-3/8" liner and cemented and perforated. This Sundry covers isolating the existing M-23 perforations via the M-23A primary liner _ cement job and a liner top packer if the liner lap pressure test fails (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 proposed sidetrack is attached for reference. r CrJnG'1- /AP , Pi cct f /ro 5 4061fier,5 /r^trle ,'F Ary l�lclufe r� C�c/Pcr! 74c�// if /fo Pr`i�4i4� !ACP � / rep C� ,,,-�;�� •40 4 rp�'r worn, ; P s Pr Teas fr free"; 7-4,25, l // Gyre ion/pr �� �.,6 —44 fn,t// fOr lfc/ri1i 14(d A//aw *r 14QrUs,e/ fe(oar, ,Frtn. ryes P 11°'P vF 7-4 fad, 29/6 • • Pre-Rig Work(scheduled to begin March 15,2016) 1. C Set 3-3/16"CIBP, drift for whipstock 2. V Pre-CTD tree work. 3. 0 Remove wellhouse and level pad 7hi3 Rig Work(scheduled to begin April 15,2016) s`r-2 1. MIRU and test BOPE to 250 psi low and 3,500 psi high (MASP 2,331 psi) ✓ 2. Mill 2.74"window and 10' rathole 3. Drill Build: 3" OH, 130' (16 DLS planned) 4. Drill Lateral: 3"OH, 2595' (12 DLS planned) N z w 4. Run 2-3/8" L-80 Liner(TOL -10,145' MD) P T 5. Cement Liner: 15 bbls, 15.8 ppg (TOC to TOL)* 6. Freeze protect wellbore 7. RDMO *Approved alternative plug placement per 20 AAC 25.112 (i) Post-Rig Work 1 S Set generic GLVs, Install LTP (if necessary)* 2 F Assist SL: Load and Kill, Pressure test liner lap/LTP 3 C Perform RPM/GR/CCL log, Perforate 2-3/8" Liner 4 0 Re-install wellhouse * Approved alternate plug placement per 20 AAC 25.112(i) Troy Tempel CTD Engineer 907-570-1351 CC: Well File Joe Lastufka TREE= 6-3/8"CRN FLS WELLHEAD= MCEVOY H -2 7A SA.NOTES:WELL ANGLE>_70m @-11301'. ACTUATOR= BAKER C OKB ELEV= 72.5 BF.ETJ=V= 452' 2063' -5-117 OTIS SSSV LANDING No,D=4.562" KOP= 11225 0 I Max Angie= 94° 11397' Datum MD= 11044' GAS LFT MANDRELS Datum TVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH FORT DATE 5 3293 3177 38 ' ODS DMV RSA 0 01/31/16 13-3/8"CSG,72#,L-80,D=12.347" --[ 2706' /.----""0 4 6448 5477 46 OT1S MAY FM 0 01/31/16 3 8639 7108 36 0115 DIN RA 0 05/11/03 2 9569 7818 43 OTIS DIN RA 0 05/11/03 1 9970 8119 41 OTIS DMV RA 0 05/11/03 10038' H5-112"SLD SLV,ID=4.562" Minimum ID =2.372" © 11344' I I 2-718" CTD LINER 10096' -{TBG SEAL ASSY 10110' -19-5/8"X 5-1/2"TM/PKR,D=4.75" 10166' -14-3/8" BKR C2 LNR TIEBACK SLV,C)=4.00" 10162' --I 3-1/2"BKR DEPLOY SLV,D=3.00" MEV 10163' --15-112"X NP,D=4.562"(BEHIND LMR) 10181' --I 3-12"X NP,D-2.813' I I - 10206' -5-1/2"XN NP,D=4.455"(BEHPD LMH) 3-1/2"UV,8.81#,L-80,.0087 bpf,D=2.992' --I 10211' , �_ 10211' -�3-1/2"X3-3/16"X0,D=2.80' 5-1/2"TBG,17#,L-80,.0232 bpf,D=4.892" --J 10261' / \ 10261' 95-1/2"WMERINO INO ImoTOP OF 7"UV -- 10360' L 10242' LEiFND TT LOGGED 06/21/86 9-5/8"CSG,47#,L-80,D=8.881" -I 10613' • f 10665' -IMARKER Jaw. 7'X 5-1/2"BKR WHPSTOCK - 11222' ' w/2 RA TAGS @ 11232 L 11000• --ITOP OF CMT LMR 7"LNR,26#,U4S,.0383 bpf,D=6.276" -{ -11229 :#: :* *'. 4: MLLOUT WINDOW(H-27A)11229'-11235' ♦• ►I#• •... 11343' ---13-3/16"X 2-7/8'X0,D=2.441" 11492" --12-7/8"BIT CI3P(11/16/15) REF LOG:MCNLICCR/GR ON 05/09/03 ANGLE AT TOP PERF: 90°r' 11448' • 11740' ---{2-718"WFD CEP(7/13/15) I _ Note:Refer to Ptodution DB for historical pert data 3-3/16"LNR,6.2#, --L 11343' ,,, • SIZE SPF IVTERVAL C)pn/Sgz SHOT SQZ 1-80..0076 bpf, r 12754' -FISH-2-7/8"CUP 2" 6 11448-11478 0 11/16/15 D=2.805" M.LED&PUSHED 2" 6 11580-11610 C 07/14/15 TO BTM(8/30/13) 2" 6 11610 11640 C 07/13/15 2-718"BKR CUP(10/12/15) - 11700' 2" 6 11800-11830 S 06/10/11 09/07/13 �� 2" 6 11830-11860 S 06/10+11 09/07/13 FISH-PARTIAL 2-7/8"BKR COP -I 12766' ar 2" 4 12100-12470 S 05/10'03 09107/13 (MILLED 8 PUSHED TI BTM O9/01/13) 2" 4 12520-12770 S 05/10/03 R3TD -I 12788" 2-7/8"LNR,6.16#,L-80,.0055 bpf,D=2.372" - 12823' DATE REV BY COMMENTS DATE REV BY COPS TS PRUDH OEBAY 1.-NT 11/04/85 ORIGINAL COMPLETION 11118/15 CJS/JMD SET CUP/ADPEWS(11/16/15) WE.L: H-27A 05/11/03 SRB/TLH CTT)SIDETRACK(H-27A) 02/15/16 GTW/JMD GLV CYO(01/31/16) PERMT No:'2030590 09/08/14 JMD SCHEMATIC CORRECTIONS API No. 50-029-21456-01 07/31/15 BLS/JM) SET CEP/GLV C/O(07/13-14/15) SEC 21,T11N,R13E,430'RCL&1734'FEL 11/18/15 SW/JMD SET CEP(10/12/15) - 11/18/15 DU/JM) TREE=(11/04/15) SP Exploration(Alaska) TREE= NV 6-3/8"CFLS • H 2 7 B 1T I= AD= MCEVOY S YNOTES:WELL ANGLE>-700 @-11301'. ACTUATOR= BAKER C oKB.a_Ev= 72-5 PROPOSED CTD [SF.REV= 45.2' KOP= 11225 o 2063' HI 5-1/2"OTIS SSSV LANDING NIP,ID=4.562" Max Angle= 94°@ 11397' V Datum MD= 11044' GAS LFT MANDRELS Datum TVD= 8800'SS ST MD TVD DEV TYPE VLV LATCH FORT DATE 5 3293 3177 38 OTIS DOME RM 16 09/26/13 13-3/8"CSG,72#,L-80,D=12.347" H 2705' 4 6448 5477 46 OTIS SO RM 20 09/26/13 LI 3 8639 7108 36 OTIS DMY RA 0 05/11/03 2 9569 7818 43 OTIS DMY RA 0 05/11/03 1 9970 8119 41 OTIS DMY RA 0 05/11/03 I , 10038' H5-1/2"SLDSLV,D=4.562" Minimum ID =2.372" @ 11344' 2-7/8" CTD LINER 10095' -I TBG SEAL ASSY 10110' -19-5/8"X 5-1/2"TNV FKR,D=4.75" M MI 10145 --H3.7"DEPLOY SLV,D=3.00" 4-3/8"BKR FLUTED GUIDE - 10145° _ 10151" 2..25"SEAL BORE 2-3/8"LINER TOT H 10162° r 10155' -14-3/8" BKR C2 LNR TIEBACK S LV,D=4.00" 3-3/8"BLADED NO-GO SUB - 10162' ----- ill 10162' -13-1/2"BKR DEPLOY SLV,U=3.00" 10163' J5-1/2"X NP,ID=4.562"(BEHND LNR) l 10181' H3-1/2"X NP,D-2.813" 3-1/2"LNR,9.3#,L-80,.0087 bpf,D=2.992" -I 10211' 10206'-15-1/2"XN NP,D=4.455"(BEHND LNR) 10211' -13-1/2"X 3-3/16"XO,D=2.80" 5-1/2"TBG, 17#,L-80,.0232 bpf,D=4.892" H 10251' \ 10251' -I5-1/2"WLEG(8EHIND LtR2) TOP OF 7"LNR --I 10360' 10242' H ELMD TT LOGGED 06/21/86 - 10665' -I MARKER JOINT 9-5/8"CSG,47#,L-80,D=8.681" -I 10613' -J 1 11000' --I TOP OF CMT LNR 7"X 5-1/2"BKR WHIPSTOCK 11222' MLLOUT WINDOW(H-27A) 11229'-11235' w/2 RA TAGS @ 11232 lk••• 11265° -3-3/16"BKR MONOBORE 7"LNR,26#,U4S,.0383 bpf,D=6.276" -I -11229 ►••� •�••• WHPSTOCK •�• �•�• lit•:•••• •••.: 55°INC 11330' H3-3/16"CISP .••• ••.i Window 11343'J-3-3/16"LNR,6.2#,L-80,.0076 PERFORATION SUMMARYbpf,D=2.805 REF LOG:MCNL/CCR/GR ON 05/09/03 11343' -13-3/16"X 2-7/8"XO,D=2.441" ANGLE AT TOP PERF: 90°@ 11448' it Note:Refer to Prodution DB for historical pert data ♦ 11492' —+2-7/8"BTT CBP(11/16/15) N SEE SPF ILINAL Opn/Sqz SHOT SQZ 9/ 2" 6 11448-11478 0 11/16/15 2" 6 11580-11610 C 07/14/15 2" 6 11610-11640 C 07/13/15 2" 6 11800-11830 S 06/10/11 09/07/13 2" 6 11830-11860 S 06/10/11 09/07/13 ="-3/8"RA TAG H TBD :; 2" 4 12100-12470 S 05/10/03 09/07/13 2" 4 12520-12770 S 05/10/03 13960' IPBTD ,4i, 14000' 2-3/8"LNR,4.7#,L-80,HYD511 1, 8970°lVDss DATE REV BY COMMENTS DATE REV BY COMNBVTS PRUDHOE BAY UNIT 11/04/85 ORIGINAL COM PLETION 11/18/15 CJS/JMD SET CEIP/ADPERFS(11/16/15) WELL: H27B 05/11/03 SRB/TLH CTD SIDETRACK(H-27A) 02/24/16 TTI H-278 PROPOSAL. (SLR No: 09/08/14 JMD SCHEMATIC CORRECTIONS AR No: 50-029-21456-02 07/31/15 BLS/JIVE) SET CBP/GLV C/O(07/13-14/15) SEC 21,T11N,R13E,430'FNL&1734'FEL 11/18/15 SW/JMD SET CEP(10/12/15) 11/18/15 DU/JM9 TREE C/O(11/04/15) BP Exploration(Alaska) • lib 40 del ti m i 4'sQ b _� > ��':, V m a u V s a QIP I 1 1 I. m 9 u : '; u r `g -IMS cIo cfel , u d 0 12 ao . O f e° Q2 o m fi. e N g . p o l ',2 Q Q I m m z _ 1 4 C_1 S 1 • c.I S I a t, o r. m 1 ifp' l ICit O 9/► ^ d 1 ,ii tii I • d N a II _ II 1 C J N N Q 1 e MY Il l S 111 a i`` ttll I Z I a,g l II If I y P ON I U m !AlU�1, Ir—Q > > INIII M' I itl fil d d J V sc e$ u. 8 O J 1�3 U ' WLL U IMW fl C fl` C ' W o I 19 ic W Ili IP N m f f d"0- II I iiim .o A Q 8el U 1 F U I ' m 0 u I 0 m Iv IP. iiZ 8 I d ) : a 1 m y 111 a mN 1 billEllE ] !lilt : IP o g I " ii `F 0 rc i.i . I 11 taummaggil `2'F3 I s j 1 ale flip po k ~ (-c 111=111 : 1 11 j ! • Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsible 1 The initial reviewer will check to ensure that the "Plug for Redrill" box Geologist in the upper left corner of Form 10-403 is checked. If the "Abandon" or f "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 then / it on both copies of the Form 10-403 (AOGCC's and operator's copies). Instead, check the "Suspended"box and initial that change. Drilling Engineer v 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, she 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, she 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, she 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 in RBDMS to ensure that all of the Plug for Redrill wells have been Geologist handled properly. At this same time, they will also review the list of suspended wells for accuracy. , • STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMM N REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon ❑ Plug Perforations ® Fracture Stimulate 0 Pull Tubing 0 Operations shutdown 0 Suspend 0 Perforate 0 Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ Plug for Redrill 0 Perforate New Pool ❑ Repair Well 0 Re-enter Susp Well 0 Other: SC t clop NJ 1/7-1-- 2. /jL2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number 203-059 3. Address: P.O.Box 196612 Anchorage, Development a Exploratory 0 AK 99519-6612 Stratigraphic 0 Service ❑ 6. API Number: 50-029-21456-01-00 7. Property Designation(Lease Number): ADL 0028281 8. Well Name and Number: PBU H-27A 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: RECEIVED Total Depth: measured 12823 feet Plugs measured See Attachment feet true vertical 9052 feet Junk measured See Attachment feet DEC 15 2015 Effective Depth: measured 11492 feet Packer measured 10108 feet true vertical 9043 feet Packer true vertical 8222 feet O3 CC Casing: Length: Size: MD: NO: Burst: Collapse: Structural Conductor 80 20"x 30" 31 -111 31-111 Surface 2673 13-3/8"72#L-80 31-2703 31 -2674 4930 2670 Intermediate 10585 9-5/8"47#L-80 28-10613 28-8581 6870 4760 Production Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11446-11478 feet 11580-11610 feet 1161 0-11640 feet 11800-11830 feet 11830-11860 feet 12100-12470 12520-12770 feet True vertical depth: 9043-9043 feet 9049-9051 feet 9051-9051 feet 9046-9045 feet 9045-9044 feet 9049-9057 9058-9055 feet Tubing(size,grade,measured and true vertical depth) 5-1/2"17#L-80 26-10248 26-8323 Packers and SSSV(type,measured and 5-1/2"TIW Packer 10108 8221.68 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: FEBn•,., SCAN # E FBoo4 =U! 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 512 41644 92 560 1106 Subsequent to operation: 759 41599 180 200 1034 14.Attachments:(required per 20 AAC 25.070.25.071,&25.283) 15.Well Class after work: Daily Report of Well Operations IZI Exploratory ❑ Development I1 Service 0 Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work: Oil H Gas 0 WDSPL ❑ Printed and Electronic Fracture Stimulation Data 0 GSTOR 0 WINJ 0 WAG 0 GINJ ❑ 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 / ,i1/4-- Phone +1 907 564 4424 Date 12/14/15 Form 10-404 Revised 5/2015 VT` /Z/73L L. RBDMS DEC 212Q1� Submit Original Only lj 7 .7-=0"c� Plugs Attachement 205-081-0 SW Name Date MD Description H-27A 11/16/2015 11492 2-7/8" BOT CIBP H-27A 10/12/2015 11700 2-7/8" Baker CIBP H-27A 07/13/2015 11740 2-7/8" WFD CIBP • • Junk Attachment PBU H-27A SW Name MD Date Comments H-27A 12754 08/30/2013 MILLED CIBP H-27A 12766 09/12/2013 Milled CBP • • w rn O rn co cti O 00 N 0 N coco V w' cp LLn CA 00 I,_ m 't COco CO N CO I� CO 0) (3) IC) N N 6) O CO N CO CO CO CA CO I— CO V Ln - CO I O Nt CO CO CO N N NY O N 00 CO C)) - M M '- C3) M co CO N N N CO N N 00 N - N N 0 0 r N1111111 v o <• r". 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Co a C actsa) ll) 8%5 cCIn ODos UOa O a) O 0Or ) N0 to a) LL CL .0 ° LO a) r . a) 03 u) a5r� D � Or- � 0L a E > > mo a) ± � r . . -) -- C o, = h.ou a- a) M r ail -• O r ai O cop o 0) f- a) 0 LI" a) 0 ' N 1 - .0 C ' ni ' 013 Q a) OUCO +� 8o co 3U a) w I- = N +L. -OJ00 �(� 6� cco �N 0 E u a) U D ° � ° , w -a u O w ° 0 �o a v°)i Q * O m i-. ° o * 0 " ° O a) o > H -- (1341- ON- cI, O d 92 � a0 0_ Qw � o _ ZY o VH. -8T 'C � f- _0 -, w U O 2 E : U O a N a Qa �� D �a U -) 2 0 m H : U ° o-.° Lo in in U) r r r r o o r 0--. O o O O N N c N N N N r CV CO CO 00 r r N r r a) O p r r r r r r r r r r • S N C O E as d Q •5 G> N O 0 CO d L L •— m m co 0 0 co J 0 LoY -0 ( i L U rn ain rn 7o N Lr)N M N m " co (Ni N TREE! 6-3/8"CIw FLS OY • H -27A 1NELLHEAD= MCEVOY S NOTES:WELL ANGLE>—70°@—11301'. ACTUATOR= BAKER C OKB.ELEV= 72.5 BF.ELEV= 45.2' KOP= 11225 0 2063' LANDING OTIS SSSV LANDG NP,Q=4.562" Max Angie= 94°©11397' Datum M)= 11044' GAS LFT MANDRELS Datum TVD= 8800'SS ST MD ND DEV TYPE VLV LATCH PORT DOTE 5 3293 3177 38 0715 COME RM 16 09/26/13 13-3/8"CSG,72#,L-80,D=12.347' H 2705' 4 6448 5477 46 OTIS SO RAA 20 09/26/13 L 3 8639 7108 36 OTIS DMY RA 0 05/11/03 2 9569 7818 43 OTIS DMY RA 0 05/11/03 1 9970 8119 41 OTIS DMY RA 0 05/11/03 ' 10038' H5-1/2"SLD SLV,D=4.562' Minimum ID =2.372" @ 11344' 2-7/8" CTD LINER 110095' —{TBG SEAL ASSY 10110' H9-518"X 5.1/2"TFW PKR,D=4.75" 10155' --14-3/8" BKR C2 LNR TACK SLV,D=4.00' i:Iii 10162' —3-1/2'BKR DEPLOY SLV,D=3.00' 10163' —I5-1/2"X NP,D=4.562"(BEH./LtR2) 0 1 10181' H3-1/2"X NP,D-2.813" I I 10206' S-1 rr XN MP,D=4.455"(BEFIM)LW) 3-1/2'LNR,9.3#,L-80,.0087 bpf,D=2.992" H 10211' Imo^ 10211' H3-1/2"X3-3/16'XO,D=2.80" 5-1/2"TBG,17#,L-80,.0232 bpf,D=4.892" —I 10251' J \ 10251' —I5-1/2"WLEG(BMW LNR) LI TOP OF 7^LNR --I 10360' .� 10242'J—j BAD TT LOGGED 06/21/86 9-5/8"CSG,47#,L-80,13=8.681" H 10613' I 111. • 10665' --IMARKERJOINT T X 5-1/2"BKR W-I STOCK —{ 11222' I w/2 RA TAGS•11232 L_11000' H TOP OF CMT LNR r LNR,26#,U4S,.0383 bpf,D=6.276" --I —11229 �•� •�• •i• i% MLLOUT WINDOW(H-27A) 11229'-11235' v,, -4 11343' —13-3116"X 2-7/8"XO,D=2.441" PERFORATION SUMMARY 11492' —12-7/8"BTT CBP(11/16/15) REF LOG:MCP JCCR/GR ON 05/09/03 ANGLE AT TOP FBF: 90°0 11448' A. 11740' H2-7/8"WFD CBP(7/13/15) Note:Refer to Prodution DB for historical perf data 3-3/16"LNR,6.2#, 11343' .$, SIZE SPF INTERVAL Opn/Sqz SHOT SOZ L-80,.0076 bpf, 12754' —FISH-2-7/8'CBP %0001444 2" 6 11448-11478 0 11/16/15 D=2.805' MLLEM&PUSHED 2" 6 11580-11610 C 07/14/15 TO BIM(8/30/13) 2" 6 11610-11640 C 07/13/15 2-7/8"BKR GBP(10/12/15) 11700' 2" 6 11800-11830 S 06/10/11 09/07/13 `• 2" 6 11830-11860 S 06/10/11 09/07/13 FISH-PARTIAL 2-7/8'BKR CBP —I 12766' 2" 4 12100-12470 S 05/10/03 09/07/13 (MLLE D&PUSHFB7 TI BTM 09/01/13) 2" 4 12520-12770 S 05/10/03 PBTD —I 12788' 2-7/8'LNR,6.16#,L-80,.0055 bpf,D=2.372" --I 12823' DATE REV BY COMMENTS DATE REV BY COIVIMENTS PRUDHOE BAY MT 11/04/85 ORIGINAL COMPLETION 11/18/15 CJS/JMD SETCBFI'ADFIE2FS(11/16/15) WELL: H-27A 05/11/03 SRB/TLH CTD SIDETRACK(1427A) PERMT Mr 82030590 09/08/14 JM-.) SCHEAMTIC CORRECTIONS API No: 50-029-21456-01 07/31/15 BLS/AD SET CBPGLV C/O(07/13-14/15) SR'21,T11N,R13E,430'FPL&1734'FS 11/18/15 SW/JMD SET CEP(10/12/15) 11/18/15 DUclivD TREE CJO(11/04/15) BP Exploration(Alaska) STATE OF ALASKA LASKA OIL AND GAS CONSERVATION COMMIS 1 REPORT OF SUNDRY WELL OPERATIONS 1. Operations Performed Abandon 0 Plug Perforations ® Fracture Stimulate 0 Pull Tubing ❑ Operations shutdown 0 Suspend 0 Perforate ® Other Stimulate 0 Alter Casing 0 Change Approved Program ❑ / Plug for Redrill ❑ Perforate New Pool 0 Repair Well 0 Re-enter Susp Well 0 Other: -rjC/ C 1 5? 2. Operator Name: BP Exploration(Alaska),Inc 4. Well Class Before Work 5. Permit to Drill Number: 203-059 3 Address: P.O.Box 196612 Anchorage, Development I Exploratory 0 AK 99519-6612 Stratigraphic 0 Service 0 6. API Number 50-029-21456-01-00 7. Property Designation(Lease Number): ADL 0028281 8. Well Name and Number: PBU H-27A 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: 1 .Y, Total Depth: measured 12823 feet Plugs measured 11740 feet i� 't,, 16,". � ► true vertical 9052 feet Junk measured 12754,12766 feet Effective Depth: measured 11740 feet Packer measured 10105 feet Min 0 2,4 true vertical 9047 feet Packer true vertical 8220 feet AOGCC Casing: Length. Size' MD: TVD: Burst: Collapse: Structural Conductor 80 20"x 30" 21 -101 21 -101 0 0 Surface 2674 13-3/8"72#L-80 26-2700 26-2670 4930 2670 Intermediate 10586 9-5/8"47#L-80 28-10614 28-8582 6870 4760 Liner 57 3-1/2"8.81#L-80 10155-10211 8256-8297 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation Depth: Measured depth: 11580-11610 feet 11610-11640 feet 11800-11830 feet 11830-11860 feet 12100-12470 feet 12520-12770 True vertical depth: 9049-9051 feet 9051-9051 feet 9046-9045 feet 9045-9044 feet 9049-9057 feet 9058-9055 Tubing(size,grade,measured and true vertical depth) 5-1/2"17#L-80 23-10245 23-8321 Packers and SSSV(type,measured and 5-1/2"TIW Packer 10105 8220 true vertical depth) 12.Stimulation or cement squeeze summary: Intervals treated(measured): Treatment descriptions including volumes used and final pressure: SCANNED 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 512 41644 92 0 1106 Subsequent to operation: 759 41599 180 0 1034 14.Attachments:(required per 20 AAC 25 070 25 071,&25 283) 15.Well Class after work: Daily Report of Well Operations m Exploratory 0 Development I 1 Service ❑ Stratigraphic 0 Copies of Logs and Surveys Run 0 16.Well Status after work' Oil I7I 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 Summerhays,Nita M(WIPRO Technologies) Email Nita.Summerhays@bp com Printed Name Summ-rhays,Nita , (WIPRO Technologie Title Petrotechnical Data Engineer . _ . Signatu ��/ � i ��1jODj / Phone +1 907 564-4035 Date 08/04/2015 Form 10-404 Revised 5/2015 y / (,i w.1--RBDMSJ k AUG 1 4 2 mit Original Only g/3/45-4/3// /of Daily Report of Well Operations PBU H-27A ACTIVITYDATE SUMMARY CTU 8 w/1 5"CT(CTV=24 1) Objective: Drift, RPM Log,Cont. CIBP&Adperfs MIRU-MU Wfd MHA and SWS 2.25"JSN 7/10/2015 ***Continue on WSR 7-11-15*** CTU 8 w/1.5"CT(CTV=24.1) Objective: Drift, RPM Log,Cont. CIBP&Adperfs Pump 1%KCL 191 bbls to knock down WHP RIH w/Wfd MHA and SWS 2 25"JSN-Tag 12,725' CTM-PUH 12,725'(12,698'Mech)paint white flag-POOH @ 9700' pump 1%KCL 90 bbls to knock down WHP Perform weekly BOPE test w/no failures. WO RPM tool(in use on R-08). MIRU Baker Atlas RPM Tools-RIH w/RPM Tool while pumping 1%KCL-WHP Increasing. 7/11/2015 ***Continue on WSR 7-12-15*** TWO=1060/470/0. Temp=SI IA FL(CTD request). No AL. IA FL @ 6448'(Sta#4 SO,283 bbls) 7/12/2015 CTD in control of well upon arrival and departure. 09:00. T/I/O=1242/463/5 Assist Coil(PROFILE MODIFICATION) Pumped 305 bbls of 90*f crude down IA to fluid pack it for coil tubing.Coil tubing on well upon departure. Hung AFE sign and caution tags 7/12/2015 FWHP=1559/583/8 CTU 8 w/1.5"CT(CTV=24.1) Objective: Drift, RPM Log,Cont. CIBP&Adperfs RIH Baker Atlas RPM Tools While pumping 1%KCL Sweep Gas-WHP Increase to Max 1500 psi- Tried Surge to OTT(fluid 35 bbls w/gas)-Pump and WHP Increasing after 21 bbls-POOH RD RPM Tool. Formation is tate and will need to exceed 1500 psi due to derating of tubing from to corrosion.. DHD shoot FL on IA at SO at 6648'. LRS fill IA w/305 bbls dead crude Resume liquid pack w/1%KCI and pump 150 bbls at avg 1.5 bpm/2460 psi until whp started falling. Decrease Rate to 1.1 bpm at 247 bbls-slow increase rate to 2 bpm WHP 2372 psi-pump 500 bbls 1%KCL- MU Baker RPM Tools-RIH pumping @ 1%KCL 1 bpm-start Borax 30 bbls @ 1 bpm 7/12/2015 ***Continue on WSR 7-13-15*** CTU 8 w/1.5"CT(CTV=24.1) Objective. Drift, RPM Log,Cont CIBP&Adperfs RIH Baker Atlas RPM Tool-1st Baseline Pass 11,740'-10,450'Log Up 20 fpm-RIH-2nd Baseline Pass 11,400-11,000 Log Up 20 fpm-RIH-(66 bbls Borax behind pipe)1st Borax Pass 12,735-10,100 Log Up 60 fpm-RIH-(143 bbls Borax behind pipe)2nd Borax Pass 12,735'- 10,100'Log Up 60 fpm-Stop @ 11,699 9'and paint a Yellow w/red stripes Flag-Finish Jewellery Log to 8000'Log Up 60 fpm. POOH while overdisplace Borax w/1%KCL. Log found no evidence of gas at zones of interest so continued w/Program. RIH w/WFT 2-7/8"CIBP and set off of flag at 11740'ELMD. POH-PT Wfd MHA 3500 psi-MIRU TCP-MU Firing Head&2"6 SPF-60 deg- 2006 PJ HMX-30'Perf Guns-RIH-Tag CIBP and Correct Depth-PUH to Btm Shot 11,640'- 11,610'-Perforate-POOH 7/13/2015 ***Continue on WSR 7-14-15*** CTU 8 w/1.5"CT(CTV=24.1) Objective. Drift, RPM Log,Cont. CIBP&Adperfs POOH-Verify all Shots Fired-BD Spent Perf Guns/Firing Head-1/2"Ball recovered-MU Firing Head&2"6 SPF-60 deg-2006 PJ HMX-30'Perf Guns-RIH(taking returns to OTT)-Tag CIBP and Correct Depth-PUH to Btm Shot 11,610'-11,580'-Circ 1/2"ball-Guns Fired-POOH. LD perf gun,ASF. Change packoff. RIH w/1.90"JSN assy and N2 lift to 5000'and kicked off well to test seperator. POH. SWI. RDMO to H-19C. Turned well over to DSO and PPC to POP 7/14/2015 Job complete Fluids Summary BBLS Type 129 50/50 METH 1450 1%KCL 610 DEAD CRUDE 231 BORAX 79 SLICK SEAWATER 2499 Total C) la CD p N OD N N Tr u CO V 4r O O O to O NI- Nr cn OD m CO r M r- O N N- LC) CO N T- V.- c) - 0O C OD O N O U) N CO LCD N O O O M N OD co O co O OD CI 1 1 1 1 1 1 1 1 CO f" O <A CO 00 to O O cr C) N N CV N CV - O N CO CO OD O C _ el CD CI UD N N Tr O • CO N CO N OD N T- N O O T- T- N O t C.) 4.0 QN to v- Tr M- CD D � � � vCO CV CV N N M Ch N O O O V I— a 000 C) OO co 00 ? 00 OD O LA - J J J J = 4# OD�# i M 4k r- CV J CO *k N N XN CO r- 0 y O OD 05:30 O N I's co CD r• OCh ' N M I M O OO cq 0)O D N C OD CO LID lC) T- N- Tr N J N O T- 00 T- O W cc I— C 0 0 U W W Z W W W W W m 0 F Z Z Z Z D UD Z J J J J f TREE= 6-3/8"MCEVOY H 2 7 A @VV�LFEAD= MCEI/OY � SAFE.f NOTES:WELL ANGLE>-70" -11301'. ACTUATOR= OKB.ELEV= 72.5' BE ELEV_= 452 KOP= 11225 ( r 2063' H5-1/2"OTIS SSSV LANDING NP,D=4.562" CS 1 Max Angle= 94°@ 11397' Datum MD= 11044' GAS LFT MANDRELS Datum TVD= 8800 SS ST MO TVD DEV TYPE VLV LATCH PORT DATE 5 3293 3177 38 OTIS DOME RM 16 09/26/13 I 4 6448 5477 46 OTIS SO RM 20 09/26!13 13-3/8"CSG,72#,L-80,D=/2.347" H 2705' ({II 3 8639 7108 36 OTIS DMV RA 0 05/11/03 2 9569 7818 43 O11S DMY RA 0 05/11/03 1 9970 8119 41 011S DMY RA 0 05/11/03 10038' H5-1/2"SLD SLV,D=4 562" Minimum ID =2.372" @ 11344' Tri 2-7/8" CTD LINER l 10095' -{TBG SEAL ASSY .g 10110' -19-5/8"X 5-1/2"TM!RCR,D=4 75" 10155' -I4-318- BKR C2 LNR TIEBACK SLV,D=4.00" 10162' H 3-1/2'BKR DEPLOY SLV,D=3.00' 10163' H5-112"X NP,D=4.562'(BEHLNR) 1 10181' ---13-1/2-X NP,D-2.813' 3-1/2'LNR,9.3#,L-80, .0087 bpf,D=2.992" H 10211' ' i' 10206' -{5-ill"XN NP,D=4.455"(66D LNR) 10211' -13-1/2"X 3-3/16"XO,D=2.80" 5-112"TBG 17# L-80 .0232 bpf,D=4 .892' -� 10251' 1 � _ 10251' - 5-t/2"VLCG (BEHIND LNR) 10242' -IBEVD TT LOGGED 06/21/86 TCP OF 7"LMR -{ 10360' 9-5/8'CSG,47#,L-80,D=8.681" -1 10613' 4 16 • 10665' H MA LAGER JONT 7"X 5-1/2"BKR WF#'STOCK -{ 11222' I w/2 RA TAGS @ 11232 11000' HTO OF CMT LNR T LNR,26#,WS,.0383 bpf,D=6.276" -1 -11229 •••, ••• • ••�• MLLOUT WMDOW(H-27A) 11229'-11235' •••• ••• •li,�• ••� •• 11343' H3-3/16'x2-7/8'X0,D=2.441" PERFORATION SUMMARY 1 11740' H2-7/8"WFD CBP(7/13/15) REF LOG:MCNLJCCR/GR ON 05/09/03 ANGLE AT TOP PERE: 85°@ 11580' • 3-3/16"LNR 6.2#, -I 11343' �� 12754' -FISH-2-7/8'CBP R Note:Refer to odution DB for historical pert data MLLE)8 PUSHED SIZE SPF WTBRVAL Opn/Sgz SHOT S{� L-80,-0076 bpf, 2" 6 11580-11610 0 07/14/15 D=2.805" TO BTM(8/30/13) 2" 6 11610-11640 0 07/13/15 No, 2" 6 11800-11830 S 06/10/11 09/07/13 2' 6 11830-11860 S 06/10/11 09/07/13 FISH-PARTIAL 2-7/8"BKR GBP -1 12766' .". MILLS)8 PUSHED 11 BTM 09/01/13) 2' 4 12100- 12470 S 05/10/03 09/07/13 ( PBTD -1 12788' 2' 4 12520-12770 S 05/10/03 2-7/8'LNR 6.16#,L-80,.0055 bpf,ID=2.372" --{ 12823' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/04/85 ORIGINAL COMPLETION 09/08/14 JM) SCHEMATIC CORRECTIONS VVH.L_ I-I27A 05/11/03 SRSITLH CTD SIDETRACK(H-27A) 07/31/15 BLS/JI/EI SET CIBRGLV C/O(07/13-14/15) PERMIT No: 2030590 09/26/13 KB/JMD MLLBPUSH CERSET CBP(8/30-9/1/13) AR No: 50-029-21456-01 09/26/13 KB/JM) SQZD PERES(09/07/13) SEC 21,T11N,R13E,430'FM._&1734'FS 10/08/13 BSE/JMD GLV C/O(09/26/13) 10/15/13 GO PJC CBP MILLED'PUSH BTM(9/12/13) BP Exploration(Alaska) 2_.0- -0a) I/& zGD�5 BAKER PRINT DISTRIBUTION LIST HUGHES DATA LOGGED COMPANY BP Exploration Alaska,Inc. INTERMEDIATE No FINAL Yes $/4/2o15 (mandatory) K. BENDER WELL NAME H-27A RUN NUMBER 1 (mandatory) FIELD Prudhoe Bay Unit BH SALESMAN Paul Canizares (mandatory) (mandatory) COUNTY North Slope BH DISTRICT Prudhoe Bay,AK (mandatory) (mandatory) STATE Alaska PAGE 1 OF 1 (mandatory) /�, LOG DATE: July 13,2015 TODAYS DATE: 7/31/2015 '57")1 (mandatory) le, h � DISTRIBUTION LIST AUTHORIZED BY: Paul Canizares (mandatory) Orl �� \lb HAS CLIENT BEEN INVOICED FOR ADDITIONAL PRINTS? 0 f COMPANY A B C D ADDRESS(FEDEX WILL NOT DELIVER TO P.O.BOX) L.I.S. FILM PERSON ATTENTION #OF PRINTS#or NKIN I5#OF COPIES#OF COPIES#OF COPIES#OF COPIES 4 U U U 4 4 4 1 l ConocoPhillips Alaska Inc. 1 1 1 1 lAttn:Ricky Elgaricio A= H-27A_MRPM_PNC3D_RAW_13JUL2015_BHI_V2.meta ATO 3-344 700 C Street B= *(Folder 1 on cd/dvd) H-27A_MRPM_PNC3D_RAW_13JUL2015_BHI_V2.meta Anchorage,AK 99510 C= **(Folder 2 on cd/dvd) H-27A_MRPM_PNC3D_RAW_13JUL2015_BHI_V2.PDF D= ***(Folder 3 on cd/dvd) H-274 MRPM PNC3D RAW PASSOIUP 111112015 BHI.dlis H-27A MRPM PNC3D RAW PASSD2UP 13JUL2015 BHI.dlis AUG 0 5 2015 H-27AMRPM PNC3DBORAX RAW PASSD3UPI3JUL2DI5_BHI.dlis SC.�►ANED H-27A MRPM PNC3DBORAX RAW PASSD4UPI3JUL2015_BHI.dlis ****(Folder 4 on cd/dvd H-27A MRPM PNC3D RAW PASSOIUP 13JUL2015 BHI.las H-27A MRPM PNC3DRAW PASSU2UP I3JUL2015 BHI.las H-27A MRPM PNC3DBORAX RAW PASSD3UPI3JUL20I5_BH1.1as H-27A MRPM PNC3D BORAX_RAW_PASSD4UP I3JUL2DI5_BHI.Ias * Folder 1 on cd/dvd needs to be named"META" ** Folder 2 on cd/dvd needs to be named"PDF" *** Folder 3 on cd/dvd needs to be named"DLIS" **** Folder 4 on cd/dvd needs to be named"LAS" 2 ExxonMobil,Alaska I 1 I 1 1 I I Attn:Lynda M.Yaskell and/or Lisa Boggs 13201 C Street,Suite 505 Anchorage.AK 99503 3 State of Alaska-AOGCC 1 I 1 1 1 I 'Attn:Makana Bender 333 W.7th Ave,Suite 100 Anchorage,Alaska 99501 4 DNR-Division of Oil&Gas 0 0 1 1 I 1 Attn:Sean Clifton 1550 West 7th Avenue.Suite 802 1 Anchorage,Alaska 99501 TOTALS FOR THIS PAGE: #REF! #REF! #REF! #REF! #REF! #REF! TOTALS FOR ALL PAGES: #REF! #REF! #REF! #REF! #REF! #REF! Image ~.hject Well History File C,,~er Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. :1.03- 05~ Well History File Identifier Organizing (done) D Two-sided 11I1111111111111111 ~scan Needed I REjCAN ,?,COlor Items: o Greyscale Items: DI~L DATA tpfDiskettes, No. I o Other, NolType: OVERSIZED (Scannable) o Maps: o Other Items Scannable by a Large Scanner o Poor Quality Originals: OVERSIZED (Non-Scannable) o Other: D Logs of various kinds: Scanning Preparation I x 30 =~30 o Other:: J lit.., /0 Date: r-' 1 fI bS /s/" r II ¡ 11111.) Date: 7 I~ os- /5/ f If , + ~ <ð ~ TO~AL PAGES ,-1:) <6 (Count doeS not i,'tlude cover sheet) iAA..P. Date: ~ J tJI oS"" /5/ II r ~ NOTES: BY: Helen ~ Project Proofing BY: Helen k.MariV BY: Helen fiariV . I Production Scanning Stage 1 Page Count from Scanned File: 61 (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: V YE~ j NO Helen~ Date:7 1'3' OS- /s/ If NO in stage 1, page(s) discrepancies were found: YES NO wtP BY: Stage 1 BY: BY: Helen Maria Date: /5/ 1111111111111111111 11I1111111111111111 I Date: /5/ Quality Checked 11111111I1111111111 Helen Maria Scanning is complete at this point unless rescanning is required. ReScanned Comments about this file: ; RECEIVED STATE OF ALASKA • AKA OIL AND GAS CONSERVATION COMMIDON (I(...J 15 2011 REPORT OF SUNDRY WELL OPERATIONS {� 1.Operations Abandon U Repair Well U Plug Perforations U Perforate U Other U I\O`a^C Performed: Alter Casing ❑ Pull Tubing0 Stimulate-Frac ❑ Waiver ❑ Time Extensions . Change Approved Program ❑ Operat.Shutdown❑ Stimulate-Other 0 Re-enter Suspended WeII❑ 2.Operator 4.Well Class Before Work: 5.Permit to Drill Number: Name: BP Exploration(Alaska),Inc Development El Exploratory ❑ 203-059-0 3.Address: P.O.Box 196612 StratigraphiC Service ❑ 6.API Number: Anchorage,AK 99519-6612 50-029-21456-01-00 7.Property Designation(Lease Number): 8.Well Name and Number: ADL0028281 PBU H-27A 9.Logs(List logs and submit electronic and printed data per 20AAC25.071): 10.Field/Pool(s): GR/CCL PRUDHOE BAY,PRUDHOE OIL 11.Present Well Condition Summary: Total Depth measured 12823 feet Plugs measured None feet true vertical 9051.99 feet Junk measured See Attachment feet Effective Depth measured 12788 feet Packer measured 10111 feet true vertical 9053.92 feet true vertical 8224.23 feet Casing Length Size MD TVD Burst Collapse Structural None None None None None None Conductor 80 20"x 30" 27-107 27-107 Surface 2679 13-3/8"72#L-80 27-2706 27-2675.94 4930 2670 Intermediate None None None None None None Production 10586 9-5/8"47#L-80 27-10613 27-8581.07 6870 4760 Liner See Attachment See Attachment See Attachment See Attachment See Attachment See Attachment Perforation depth Measured depth 11800-11830 feet 11830-11860 feet 12100-12470 feet 12520-12770 feet True Vertical depth 9045.75-9045.1 feet 9045.1-9044.37 feet 9048.76-9057.48 feet 9058.48-9054.71 feet Tubing(size,grade,measured and true vertical depth) 5-1/2"17#L-80 28-10251 28-8325.93 Packers and SSSV(type,measured and true vertical depth) 5-1/2"TIW Packer 10111 8224.23 Packer None None None SSSV 12.Stimulation or cement squeeze summary: cjrl Intervals treated(measured): 11800'-12712':12%HCL. SppNED NOV 11800'-11860',12100'-12470':OrganoSeal&SqueezeCrete. 1� Treatment descriptions including volumes used and final pressure: 49 Bbls 12%HCL,1298 psi; 217 OrganoSeal,1538 psi;25 Bbls SqueezeCrete,2500 psi. 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation: 247 19692 44 0 1940 Subsequent to operation: 0 0 0 0 0 14.Attachments: 15.Well Class after work: Copies of Logs and Surveys Run Exploratory❑ Development 12 Service❑ Stratigraphic ❑ Daily Report of Well Operations X 16.Well Status after work: Oil IN Gas U WDSPLU GSTOR ❑ WINJ ❑ WAG ❑ GINJ ❑ SUSP ❑ SPLUCrJ 17.I hereby certify that the foregoing is true and correct to the best of my knowledge. Sundry Number or N/A if C.O.Exempt: N/A Contact Garry Catron Email ry Gartron _ .Ca BP.Com Printed Name Garry Catron Title PDC PE Signature ,1 9 G j Phone 564-4424 Date 10/15/2013 yT /G�,� RBDMS OCT 172' /011,/13 � Form 10-404 Revised 10/2012 Submit Original Only • • H-27A 203-059-0 Junk Attachment SW Name MD Date Description H-27A 12754 8/30/2013 MILL CIBP H-27A 12766 9/12/2013 Milled CBP Casing / Tubing Attachment ADLOO28281 Casing Length Size MD TVD Burst Collapse CONDUCTOR 80 20"x 30" 27 - 107 27 - 107 LINER 56 3-1/2" 8.81# L-80 10155 - 10211 8256.39 - 8297.06 LINER 1132 3-3/16" 6.2# L-80 10211 - 11343 8297.06 - 9045.25 LINER 869 7"26# L-80 10360 - 11229 8404 - 8996.27 7240 5410 LINER 1480 2-7/8"6.16# L-80 11343 - 12823 9045.25 - 9051.99 13450 13890 PRODUCTION 10586 9-5/8"47# L-80 27 - 10613 27 - 8581.07 6870 4760 SURFACE 2679 13-3/8" 72#L-80 27 - 2706 27 - 2675.94 4930 2670 • TUBING 10223 5-1/2" 17# L-80 28 - 10251 28 - 8325.93 7740 6280 • • . • • CO := a) a) II E ° Qa. 9.2 spa I � O o E omU oO II c 3 N v,_ o > 3 + co , , •c ° 13 m ,- 2 o — ° a) L -0 Cn U) .- a) 'c "a a) co O N- a) O -0 2i o 'O _M U) N a) voi °r° O p a)±o o pap a) a c o o a .S . , �1 U, a 0 O N U a) Q T J tU O v U O CO• .) cn o II co "a N U -c a) o p cca °co ° to (n N +• o N o a 75 o a) o M Z a) .- � � � .= map . _1 .(• -2 � u? � aa)) a) � p (D a) 0- 120 -0 a).6 a) (N - v) a a) aa)) _ I UU)) 'U) 0 a °o °) (l 3 .c= 15 o c 0 �m0 oQ cU o �� o } m * am : ti cn cnUO cn 0 _ ° Uj a, c) _o �- * E 3 a + + a- + cam co_- p m + U) (Ni c13 Cl_ O pia Lii -0 c,') (2...,a)) in To ° � cUn) N � � O c°n' 'QCOm o co co OW � a H � m � ~ o • c °0ZN +- = 1 c E0__ NY L ND N � c0 c6 = Lo O Lp N Q Z N jj E l'-- �.a J EO p,0 b �o U r a) Woo a � o5a O O , r 0 � = � nzao OOH ° 3 O = � Q C •c I O 0) N 0 c- • "6 a) N N ° •c 0 co C@� pN .... E � -0 a) a, -oEO rn•- oo II � -0 t U°'i N W > v) a u a) -- 5 •c, O- 0 tOOQ Qom 0 0 L11 (1)> � a0 E a a c a aJ -o --- Q N awe a a o a) a O ca p• E o 0 c); ,- 12 ;U 0 O J 00 U o * •O ai N in-- — ° w m o a)m as• o m c > `n O Q _1a � * 18 1-- c V U aria UN 3a0� = 2 U c°) � :�, amp * a a,a 2 - _ � @ � � CD 03 = c a) v d * � WOL � UaN � � Y g � � � a cu •�'� > Q cc Ja (DU C W a) M a ° N 4) L0 O -) U) � 2 Q °)o E a) "a ' a < 5 ,- 0 p ‘- -0 ,4• 25 0- o_ U •N 0_-CI c o O) O a) `~' Ca. cco c rn� ■ %f) co o0 oO Q OU 0 3 U) N O° U) 0 - . > ° 0 L Cl) c0 c4 � N- - ,- tear E E N U) U) * cn2 c 3 * E * cn o > 4 c *•D Q � Z rnaoU — pa oop � I- a ° 2in � � ° a�i = QU o : f- op o E J O L ~ — aao Q � U UU aNiU C) S -0a U _ _ a) ai 0 w ° 0 Q F- o * 0 LU a L (B a)� ` cn N a) c (N c 0)cn a U) rn Uo2Z � I- � 2 * ai N- Er ao ) o� 2f -3 o , 2 O oN 30 ' :° o C _ - W c 0 = .-.(1) 12 o r = }? a,— @)= a) ca a� L 0 E a Oti � J J N � Q H o � cn 2o -§- c 3 .0)-- y c 3 a) — E ° o o � .s 3 -R a ai ao .c w • c\i •�r r 0 ) Ui ° < ,- E 0) .- 11 co _0 co _, c> _0 co c n.- o o 0 E Jo CO a) In a v _0 Z Z Z O O Z >> I a- a o a m ° D .(n U ° n o L M , O N O D > L o J a) O * D D D U U a * * in M 0 1- - * 1- c p .O ? 1- o > . N O c * I - D N a N * Ct ct a' * * r * � * o a aU2 * Uii 3 .E * o o ;- cow 0 = * O - 0 — * co co co co co co co [- r r r r r ,-O O O CD O o O N N co 0) co co) co M- \ \ N N M CO CO 87 CO" CD CO CO Daily Report of Well Operations ADL0028281 CTU 8 w/ 1.75" CT. Scope; Mill CIBP,Acidize, OrganoSeal + SqueezeCrete 9/2/2013 Weekly BOP test in progress, unable to get a passing test, FP well. RD for maint. CTU-8 w/ 1.75" coil, Job scope: GSO with OrganoSEAL and SqueezeCRETE Rig up, Function test BOP's. RIH w/2" BD JSN to 9550', pump 217 bbls of ortganoseal down CTBS..followed with 195 bbls of diesel. Circ diesel from coil with returns to surface. RIH while pumping freshwater,tag composite plug at 12492' PUH to top of liner @ 10156.. **job continued on 9/6/2013 WSR 09-07-13** Continued from WSR 09-06-13 CTU 8 nw/ 1.75" CT. Job scope: GSO with OrganoSEAL and SqueezeCRETE • Position nozzle at liner top. Pump 25 bbls of squeezeCRETE. Saw pressure bump and lay in remaining cement. Preform hesitation squeeze to 2500 psi. Hold pressure for 1.5 hrs making small pressure bumps.(4 bbls behind pipe) Bleed WHP back to 360 psi. RIH and contaminate with gel to to top of plug. Tagged plug at 12492'. lay gel across perfs to 11700' . Chase returns at 80 %washing jewlery, wash thru tree and BOP's, shut SSV and swab trapping 500psi on well, RDMO, Pad op notified on departure 9/7/2013 **job complete** (will return to mill plug) T/I/O=0/1070/0 SI MIT-T to 1500 psi ***PASSED*** (CEMENT SQUEEZE) Pumped total of 2.7 bbls meth down TBG to acheive test pressure of 1500 psi. 9 attempts 15 min loss of 21 psi, 30 min loss of 19 psi, for total loss of 40 psi in 30 mins. Bleed TBG pressure to 0 psi. Hardline/Choke Skid 9/10/2013 valves closed Valve Positions=SV WV SSV closed MV open CVs OTG FWHP=0/500/0 CTU 8 w/ 1.75" CT.. Scope; Mill Composite Plug post OrganoSEAL/SqueezeCRETE 9/11/2013 Rig up.. **job continued on WSR 09-12-13** Continued from WSR 09-11-13 CTU 8 w/1.75" CT. Scope; Mill Composite Plug post OrganoSEAL/ SqueezeCRETE Perform weekly BOP test. RIH w/ BHA; 1.75" ctc, 1.69" disco, circ sub, rup sub, 1.812" dual jar, • 1.69" motor, 2.125" crossover,2.25" 3 blade mill. (oal= 20.14') Dry tagged plug at 12490' did not see any cement stringers, 1:1 returns. Pump 20 bbl gel sweep. Circulate bottoms up. Tag CBP at 12,488' start milling.Pushed CBP down to 12,766', hard tag cant make any more footage. Calling TD at 12,766' Final gel sweep off bottom 20 bbls. POOH at 80% Drop 1/2" ball open circ sub. **job 9/12/2013 continued on WSR 09-13-2013** Continued from WSR 09-12-13 CTU 8 w/1.75" CT. Scope; Mill Composite Plug post OrganoSEAL/ SqueezeCRETE Continue POOH chasing returns at 80% Freeze protect tubing 67 bbls in tubing.. At surface 1/2" ball recovered. RDMOL. 9/13/2013 ***Job Complete**** Daily Report of Well Operations ADL0028281 ***WELL S/I ON ARRIVAL*** (Cement squeeze) SET 5-1/2"WHIDDON CATCHER SUB AT 10,113' SLM. PULL RM-DGLV'S FROM ST#4 (6,448' MD) & ST#5 (3,293' MD). SET RM-LGLV AT ST#5 (3,293' MD). CURRENTLY RIH W/5-1/2" OM-1 (ST), RM-OGLV TO ST#4 (6,448' MD). 9/25/2013 ***JOB IN PROGRESS, CONTINUED ON 9/26/13 WSR*** ***CONTINUED FROM 9/25/13 WSR***(Cement squeeze) SET RM-OGLV AT ST#4 (6,448' MD). PULLED EMPTY 5-1/2"WHIDDON CATCHER SUB FROM 10,113' SLM. 9/26/2013 ***WELL S/I ON DEPARTURE, NOTIFIED PAD OPERATOR OF WELL STATUS*** • • Rai= 6-3/8" VOY H _2 7A NOS:W ELL ANGLE>-70°@-11301'. ACTUATOR= OKB.REV= 72.5 - BF.ELEV= 452 j KOP= 11225 I 2063' I-15-1/2"OTIS SSSV LANDING F' ,D=4.562" Max Angle= 94°0 11397' GAS LFT MANDF S Datum M3= 11044' ST M) TVD DEV TYPE VLV LATCH FORT DOTE DatumTVD= 8800'SS 5 3293 3177 38 OTiS DOME F2M 16 09126!13 13-3/8"CSG,72#,L-80,D=12.347" 2705' 4 6448 5477 46 OTIS SO F2M 20 09/26/13 L 3 8639 7108 36 Oils DMY RA 0 05/11/03 2 9569 7818 43 OTIS OMY RA 0 05/11/03 1 9970 8119 41 OTIS MY RA 0 05/11/03 I I I 10037' H5-112"SLD SLV,D=4.562" I Minimum ID =2.372" a@ 11344' 2-718" CTD LINER 10095' --ITBG SEAL ASSY Z 10110' --19-5/8"X 5-112"11W PKR,D=4.75" 10155' H4-3/8" BKR C2 LNR TU3ACK SLV,0=4.00' 10167 H3-1/2"BKR DEFLOY SLV,0=3.00" I 10162' I--1 5-112"X NP,D=4.562"(BEANO LNR} I 10181' I-I 3-1/2"X NP,D-2.813" r 10206' -15-1/2°XN NP,0=4.455"(BEHIND LNR) 13-1/2"U R,9.3#,L-80,.0087 bpf,D=2.992" 1-1 10211' 1-7-1-0- fl-13-1/2-X 3-3116"XO,D=2.80' 5-1/2'TBG,17#,L-80,.0232 bpf,D=4.892" H 10249' / \ I 10249' H5-1/2"WLEG(BERM LNR) 10242' HELM)TT LOGGED 06/21/86 1 TOP OF 7"LM H 10360' FALLOUT WIDOW(H-27A)11229'-11235' 19-518"CSG,47#,L-80,D=8.681" H 10613' --A , • I 10665' IHMARKER JET 7"X 5-1/2"BKR WI#'STOCK -H 11222' w/2 RA TAGS @ 11232 L 11000' HTOP OF CMT LNR 7"LNR,2911,L-80,.0371 bpf,D=6.184' H -11229 �•� ••�• ;❖ ••. I 11343' H3-3116°X 2-7/8"XO,D=2.441" I •• 4. •;• 4. • &■• \ , PERFORATX3N SURAAARY 12754' -FISH-2-7/8'CBP REF LOG:MCNI.JCCRtGR ON 05/09/03 3-3/16'LNR MLLE)&PUSHED ,6.2#, -{ 11343' TO BTM(8130113} ANGLE AT TOP PIM: 91°@ 11800' L-80,.0076 bpf, Note:Refer to Prodution DB for historical perf data 0=2.805" SIZE SPF INTERVAL Opn/Sgz SHOT SOZ 2" 6 11800-11830 S 06/10/11 09/07/13 2" 6 11830-11860 S 06110/11 09/07/13 FISH-PARTIAL 2-7/8"BKR CBP -I 12766' I --.i 2" 4 12100-12470 S 05/10/03 09/07/13 (MLLE)&PUSI-EID TI BTM 09/01/13) 2" 4 12520-12770 0 05110/03 I PBTD 1 12788' 12-718"LNR 6.16#,L-80,.0055 bpf,D=2.372" H 12823' DATE REV BY COMFITS DATE REV BY COMMENTS I PRUDHOE BAY UNIT 11/04/85 ORIGINAL COMPLETION 09/26/13 KB/JMD MLL&PUSH CBP/SET CBP(08/30 WELL H-27A 05/11103 SRBITLH CTD SIDETRACK(1427A) 09/26/13 KB/JMD SOZD PEWS(09/07/13) FAT No:w2030590 05/17/03 JCMTLH GLV CIO 10/08/13 BSFIJMD GLV C/O(09126/13) AR No: 50-029-21456-01 06/15/11 RN!PJC SET CBPI ADPERF(6/10/11) 10/15/13 GC/PJC CBP P LLHY RlSH BIM(9112/13) SEC 21,T11 N,R13E,430'F7'L&1734'F B 05/08/12 BSFIJMD GLV C/O(04/29/12) 05/08/12 MD 7Vt7S&70°CORRECTS) BP Exploration(Alaska) • • bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 Post Office Box 196612 Anchorage, Alaska 99519 -6612 May 18, 2012 Mr. Jim Regg WirAiliteD ALiG tt 8 2012 Alaska Oil and Gas Conservation Commission 333 West 7 Avenue Anchorage, Alaska 99501 ©3 _ o s � Subject: Corrosion Inhibitor Treatments of GPB H -Pad 14* 7 Dear Mr. Regg, Enclosed please find multiple copies of a spreadsheet with a list of wells from GPB Pad H 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, Mehreen Vazir 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) Date: 03/17/2012 Corrosion Initial top of Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # cement pumped cement date inhibitor sealant date ft bbls ft na gal H -01A 1951100 50029200990100 0.7 NA 0.7 NA 5.10 2/17/2010 H -02A 2021600 50029201000200 0.5 NA 0.5 NA 5.10 2/16/2010 H -03 1710190 50029201030000 0.2 NA 0.2 NA 1.70 2/16/2010 H -04A 2031610 50029201040100 0.3 NA 0.3 NA 3.40 2/14/2010 H-05B 2091000 50029201060200 0.3 NA 0.3 NA 5.10 3/9/2010 H -06 1770020 50029202380000 0.1 NA 0.1 NA 0.85 2/16/2010 H -07A 2001280 50029202420100 0.6 NA 0.6 NA 3.40 2/15/2010 H -08 1770230 50029202470000 0.4 NA 0.4 NA 3.40 2/15/2010 H -09 1800640 50029204820000 21.6 5.0 0.8 7/12/2010 3.40 7/8/2011 H -10A 1971900 50029204870100 0.3 NA 0.3 NA 1.70 2/19/2010 H -11 1800680 50029204850000 0.3 NA 0.3 NA 1.70 2/18/2010 H -12 1800670 50029204840000 0.3 NA 0.3 NA 1.70 2/18/2010 H -13A 2090440 50029205590100 0.1 NA 0.1 NA Trace 2/18/2010 H -14B 2071160 50029205800300 0.1 NA 0.1 NA Trace 2/18 /2010 H -15 1810610 50029205910000 0.4 NA 0.4 NA 3.40 2/18/2010 H -16 2000650 50029205920200 0 NA NA NA NA NA H -17A 1971520 50029208620100 21.5 6.0 0.4 7/12/2010 1.70 7/8/2011 H -18 1822100 50029208800000 0.1 NA 0.1 NA 0.50 2/27/2010 H -19B 1980940 50029208830200 3.5 NA 3.5 NA 23.80 2/24/2010 H -20 1830070 50029208960000 6.7 NA 6.7 NA 47.60 2/22/2010 H -21 1860710 50029215750000 0.5 NA 0.5 NA 3.40 2/15/2010 H -22A 1970480 50029215880100 0.1 NA 0.1 NA 0.85 2/15/2010 H -23A 1950850 50029217940100 5 NA 5 NA 32.30 2/17/2010 H -24A 2071330 50029215120100 0.7 NA 0.7 NA 3.40 2/28/2010 H -25 1852680 50029214780000 0.1 NA 0.1 NA 0.85 2/26/2010 1-1-26 1852770 50029214870000 2.3 NA 2.3 NA 17.90 2/23/2010 -4 H -27A 2030590 50029214560100 0.1 NA 0.1 NA 0.85 2/21/2010 H -28 1880440 50029218060000 0.5 NA 0.5 NA 3.40 2/17/2010 H -29A 1980380 50029218130100 5.2 NA 5.2 NA 57.80 2/16/2010 H -30 1880350 50029218000000 1.7 NA 1.7 NA 11.90 2/16/2010 H -31 1940140 50029224440000 0.7 NA 0.7 NA 5.10 2/18/2010 H -32 1940250 50029224490000 0.3 NA 0.3 NA 1.70 2/18/2010 H -33 1940380 50029224580000 0.1 NA 0.1 NA 1.70 2/16/2010 11-34 1971640 50029228030000 1.3 NA 1.3 NA 13.60 2/19/2010 1-1-35 1951490 50029226000000 1.7 NA 1.7 NA 15.30 2/16/2010 H -36A 2000250 50029226050100 1.3 NA _ 1.3 NA 11.90 2/17/2010 H -37A 2000970 50029227720100 1.2 NA 1.2 NA 10.20 2/20/2010 11-38 2081670 50029234020000 Dust cover NA NA NA NA 3/17/2012 , STATE OF ALASKA ALASKA APAND GAS CONSERVATION COMMISSIO. REPORT OF SUNDRY WELL OPERATIONS 1. Operations Abandon ❑ Repair Well ❑ Plug Perforations ❑ Stimulate Other ❑ CIBP GSO Performed: Alter Casing ❑ Pull 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 0 Exploratory ❑ r 203 -059 3. Address: P.O. Box 196612 Stratigraphic❑ Service ❑ 6. API Number: Anchorage, AK 99519 -6612 • 50- 029 - 21456 -01 -00 8. Property Designation (Lease Number) : G 9. Well Name and Number: ADLO- 028284 & 028281 PBU H -27A 10. Field /Pool(s): Q PRUDHOE BAY FIELD / PRUDHOE OIL POOL 11. Present Well Condition Summary: Total Depth measured 12823 feet Plugs (measured) 12050 feet true vertical 9052 feet Junk (measured) None feet Effective Depth measured 12788 feet Packer (measured) 10110 feet true vertical 9054 feet (true vertical) 8224 feet Casing Length Size MD TVD Burst Collapse Structural Conductor 110' 20" Surface - 110 Surface - 110 Surface 2706' 13 -3/8" Surface - 2706 Surface - 2676 5380 2670 Production 10613' 9 -5/8" Surface - 10613 Surface - 8581 6870 4760 Liner 867' 7" 10360 - 11227 8404 - 8995 8160 7020 Liner 56' 3 -1/2" 10155 - 10211 8256 - 8297 10160 10530 Liner 1132' 3- 3/16" 10211 - 11343 8297 - 9045 Liner 1480' 2 -7/8" 11343 - 12823 9045 - 9052 13450 13890 Perforation depth: Measured depth: SEE ATTACHED - _ _ - �')'f - True Vertical depth: _ _ AM U . i _ Tubing: (size, grade, measured and true vertical depth) 5 -1/2 ". 17# L -80 Surface - 10251 Surface - 8326 Packers and SSSV (type, measured and true vertical depth) 5 -1/2" TIW Packer 10110 8224 !vE 12. Stimulation or cement squeeze summary: ) Intervals treated (measured): Treatment descriptions including volumes used and final pressure: Ajs s .s Gil & Get J d5 $ i3I11flISSiWfl nrfPf�g6 » 13. Representative Daily Average Production or Injection Data Oil -Bbl Gas -Mcf Water -Bbl Casing Pressure Tubing pressure Prior to well operation: 848 42901 307 1530 Subsequent to operation: 14. Attachments: 15. Well Class after work: o Copies of Logs and Surveys Run Exploratory❑ Development 0 Service ❑ Stratigraphic ❑ Daily Report of Well Operations X 16. Well Status after work: Oil I El Gas ❑ WDSPL ❑ GSTOR ❑ WINJ ❑ WAGO 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 Elizabeth Barker Barker Title Data Manager Name Elizabeth er g Signature , / (i'a t Phone (907) 564 -5674 Date 6/30/2011 Form 10-404 Revised/ SUS JUL 0 7 2011 (-71 01 7. 7 /� ( Original Only H -27A 203 -059 PERF ATTACHMENT Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base H -27A 5/10/03 PER 12,100. 12,470. 9,048.76 9,057.48 H -27A 5/10/03 PER 12,520. 12,770. 9,058.48 9,054.71 H -27A 6/10/11 APF 11,800. 11,830. 9,045.75 9,045.1 H -27A 6/10/11 APF 11,830. 11,860. 9,045.1 9,044.37 H -27A 6/10/11 BPS 12,050. 12,770. 9,046.87 9,054.71 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG PULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED 1111 MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE i 411 • • H -27A DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY .. ,..� . 6/8/2011 Continued from 06/07/11 WSR. Objective: Drift -tag, PPROF, CIBP, contingent Adperfs. Well SI, make flag pass from 12,300'- 11000' w/ a flag @ 12000'. POOH. New batteries failed, no data recovered. Inspect and MU logging tools. RIH to flag. Allow well to stabilize and make dynamic up passes @ 40 fpm, 60 fpm and 80 fpm. ** *Job in Progress * ** 6/9/2011 Continued from WSR of 06/08/11. CTU #8, 1.75" coil. Job Scope: PPROF, Set CIBP and add perf. Close choke and RIH to flag at 12750'. Open choke. Stabilize flow and take stop counts. Close choke and RIH to 12300'. Log tie -in log. Flag coil at 12000'. POH. Data good. decision from APE to set CIBP and add perf. Decision also made to run additional coil flag due to depth discrepancy. RIH w/ memory CCL /GR. Well shut -in. Log GR /CCL tie -in log from 12300 - 11000'. Flag coil at 12008'. POH. Lay out memory logging tools. Good data. M/U Halco CIBP BHA. ** *Job in Progress * * *. 6/10/2011 Continued from WSR of 06/09/11. CTU #8, 1.75" coil, Job Scope: Set CIBP and add perfs. M/U Halco CIBP BHA. PT Lubricator. Load well with 160 bbl KCL. RIH with CIBP. Correct depth at flag. Set CIBP at 12.050'. Set down 2K on plug. It is holding and is on depth. POH with running tools. Lay out Halco tools. Cut off CTC. CIO packoff. M/U CTC and 2" x 30' perf gun. RIH and tie into CIBP, shoot perf interval 11830- 11860'.pooh. all shots fired. recovered ball. M/U 30' of 2 "PJ perf guns loaded at 6 SPF. PT lubricator and RIH with second set of perf guns. Tagged CIBP and corrected depth. Fired perf guns from 11800 - 11830'. POH. ** *Job in Progress * * *. 6/11/2011 Continued from WSR of 06/10/11. CTU #8, 1.75" coil, Job Scope: Add perfs. :POH while freeze protected 5.5" tubing to 2500' and coil with 50/50 meth. At surface. Close swab and crown valves. PJSM. Lay out SWS fired 30' perf guns. All shots fired. Total perforated interval for 2 gun runs: 11800 - 11860'. Rig down CTU. Need to remove crown valve before POP well. ** *Well left shut in, Job complete * * *. • FLUIDS PUMPED BBLS 92 50/50 METH 88 KCL WATER 260 1% KCL WATER 440 TOTAL TREE = 6-3/8" MCEVOY WEL LHEAD = MCEVOY • * CTUATOR = 11-7A SAFETY NCI. KB. ELEV = 72.5' BF. ELEV = 45.2' KOP = 11225 _ Max Angle =930 @ 11397 1 2063' 1-15-1/2" OTIS SSSV LANDING NIP, ID = 4.562" I Datum MD = 11044' 0 Datum TV D = 8800 SS 1 GAS LIFT MANDRELS STI MD TVD DEV TY PE VLV LATCH F-ORT DATE 1 13-3/8" CSG, 72#, L-80, ID = 12.347" H 2705' 1— ii 5 3292 3104 38 OTIS DOME RA 16 05/17/03 4 6447 5404 46 OTIS SO RA 20 05/17/03 3 8638 7034 36 OTIS DMY RA 0 Minimum ID = 2.372" @ 11344' LI 2 9568 7744 42 OTIS DMY RA 0 1 9970 8046 41 OTIS DMY RA 0 2-7/8" LINER 77 10037' H5-1/2" SLIDING SLV, ID = 4.562" ] 10095' I--ITBG SEAL AS 10110' H9-5/8" X 5-1/2" TIW PKR, ID = 4.75" 1 TA 10155' 1-14-3/8" BKR C2 LNR TIEBACK SLV, ID = 4.00" I 10162'1-13-1/2" BKR DEPLOYMENT SLV, ID = 3.00" I 1---------- 10162' H5-112" X NIP, ID = 4.562" (BEHIND LNR) I 10181' 1-13-1/2" X NIP, ID - 2.813" I 1 ' 10206' 5-1/2" XN NIP, ID 4.455" (BEHIND LNR) I 13 LNR, 9.3#, L .0087 bpf, ID = 2,992" H 10211' 1 10211' 3-1/2" X 3-3/16" X0, ID = 2.80" 1 1 1 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" H 10249' 1 ' 10249' H5-1/2" TBG TAIL (BEHIND LNR) 1 10242' HELMD TT LOGGED 06/21/86 I 1TOP OF 7" LNR H 10360' MILLOUT WINDOW 11229' - 11235' 1 9 CSG, 47#, L ID = 8,681" H 10613' 1 4 ith, 10665' 1 MARKER JOINT 1 L 11000' HTOP OF CMT LNR 1 17" X 5-1/2" BKR WHIPSTOCK H 11222' ;$4; ;" t 't RA TAGS (2) I—I 11232' V* tiN tt... ... I " LNR, 29#, L-80, .0371 bpf, ID = 6.184" 1 11503' 4 kaitt..... 11343 H3-3/16" X 2-7/8" X0, ID = 2.441" I itx:Mt, PERFORATION SUMMARY 11011141434 ‘ S. NO REF LOG: MCNL/CCR/GR ON 05/09/03 ,v• NA 12050' 2-7/8" HES CIBP ANGLE AT TOP PERF: 91 @ 11800' . At ......-41 (6/10/11) '4 _ Note: Refer to Prodution DB for historical perf data ■mitt..... SIZE SPF INTERVAL Opn/Sqz DATE 2" 6 11800 - 11830 0 06/10/11 3-3/16" LNR, 6.2#, L-8+)„0076 bpf, ID = 2.805" H 11343° 1 2" 6 11830 - 11860 0 06/10/11 2" 4 12100 - 12470 0 05/10/03 a- 2" 4 12520 - 12770 0 05/10/03 PBTD 1 1 12788' 40 _ 1 LNR. 6.16#, L-80, .0055 bpf, ID = 2.372" 1 12823° DATE REV BY COMMENTS 1 ' DATE REV BY COMMENTS PRUDHOE BAY UNIT 11/04/85 ORIGINAL COMPLETION WELL: H . .. 05/11/03 SRB/TLH CT° SIDETRACK (H PERMIT No. 05/17/03 JCM/TLH GLV C/0 API No: 50-029-21456-01 06/15/11 RW/ PJC SET CIBP/ A DPERF (6/10/11) SEC 21. Ti 1N, R13E, 430' FNL & 1734' FEL BP Exploration (Alaska) 06/23/2011 205 • o s9 Schhunberger No. 5755 2I OG 3 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambell Street, Suite 400 Alaska Oil & Gas Cons Comm Anchorage, AK 99503 -2838 Attn: Christine Shartzer ATTN: Stephanie Pacillo 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Well Job # Log Description Date BL Color CD 01 -34A BBSK -00069 PPROF W/ DEFT 29- May -11 1 1 09 -08 BGH4 -00054 INJECTION PROFILE 25- May -11 1 1 01 -20 BINC -00032 —.MEMORY 25- May -11 1 1 U -12A BD88 -00110 MEMORY PPROF W /DEFT 30- May -11 1 1 A -08 BBSK -00070 INJECTION PROFILE 1- Jun -11 1 1 L -122 BLPO -00103 MEMORY LEAK DETECT LOG 8-Jun-11 1 1 MPF -80 BJGT -00040 USIT 10-Jun-11 1 1 r> , H -27A BD88 -00117 PPROF WIDEFT AND GHOST 10-Jun-11 1 1 3- 291J -32 BP5G -00015 CROSSFLOW 27- Apr -11 1 1 W -207 BG4H -00050 INJECTION PROFILE W/ WFL 16- May -11 1 1 II PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Alaska Data & Consulting Services • Petrotechnical Data Center LR2 -1 2525 Gambell Street, Suite 400 900 E. Benson Blvd. Anchorage, AK 99503 -2838 .t, (+ e , li_ RECEIVED , JUN 2 7 2011 z Ma c.. ..n • ,.. • • ,~~ ~~- -,~. MICROFILMED 03/01/2008 DO NOT PLACE ,..~.., ~ ~, ~, .~ ~, :: ~., ANY NEW MATERIAL UNDER THIS PAGE. F:\I.aserFiche\CvrPgs_Inserts\Microfilm Marker.doc e e WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7'h Ave., Suite 100 Anchorage, Alaska 99501 7f¿.. Þú?Y0~ February 17,2006 ) 35D4- RE: MWD Formation Evaluation Logs H-27A, 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 H-27 A: LAS Data & Digital Log Images: 50-029-21456-01 1 CD Rom 4ill~lr\~ ðlé)~/Ö0 ,). ('.. \ --..J V v-,~ DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 Permit to Drill 2030590 Well Name/No. PRUDHOE BAY UNIT H-27A Operator BP EXPLORATION (ALASKA) INC J :1 /'1t/) À () ú )-- 5fu\- ~ / API No. 50-029-21456-01-00 MD 12823 TVD 9052 Completion Date 5/10/2003 Completion Status 1-01L Current Status 1-01L UIC N - ~----------- - .--~---- Mud Log No Samples No ~ Directional SurveY ~_¿ REQUIRED INFORMATION --- - -,-- DATA INFORMATION Types Electric or Other Logs Run: SGRC, MGR, CCL, CNL Well Log Information: (data taken from Logs Portion of Master Well Data Maint) ~~ Log/ ~taDigital Type Med/Frmt ¡ . t D Asc ¡ Electr Dataset Number Name Directional Survey Log Log Scale Media Run No Final Interval OH / Start Stop CH 11208 12823 Open Received 6/2/2003 Comments ----I I RPf/ D LIS Verification 8 10861 12779 Open 7/24/2003 j E6'/ D 11806 LIS Verification 8 10861 12779 Open 7/24/2003 I , E'[)- C Tf 12134 LIS Verification 9988 12780 Case 7/23/2003 ¡~.-- C Pds Case 7/23/2003 Compensated Neutron lED 12134 Neutron 2 9988 12780 Log - Memory ! GRlCCUCNL i I Err- C Pds 12134 Casing collar locator 2 9988 12780 Case 7/23/2003 Compensated Neutron Log - Memory GRlCCUCNL ! !~ Neutron 2 Blu 9988 12780 Case 7/23/2003 Compensated Neutron ! ' i Log - Memory GRlCCUCNL ¡ .Leg- 12134 Casing collar locator 2 Blu 9988 12780 Case 7/23/2003 Compensated Neutron I Log - Memory J GRlCCUCNL µg Production 2 Blu 10542 12699 Case 11/3/2003 Memory PPROF & IPROF LOG - MEM i GRlCCUSPINITEMP/PRES i S ! / I ((óg Gasing collar locator 2 Blu 10542 12699 Case 11/3/2003 Memory PPROF & JPROF i I LOG - MEM i ¡ GRlCCUSPINITEMP/PRES I S ! I -------- DATA SUBMITTAL COMPLIANCE REPORT 6/27/2005 Permit to Drill 2030590 Well Name/No. PRUDHOE BAY UNIT H-27A Operator BP EXPLORATION (ALASKA) INC API No. 50-029-21456-01-00 MD 12823 TVD 9052 Completion Date 5/10/2003 Completion Status 1-01L Current Status 1-01L UIC N ¡ Log -- ----_._~ . Spinner 2 Blu 1 0542 12699 Case 11/3/2003 Memory PPROF & IPROF 1./ LOG - MEM I (- GRlCCUSPINffEMP/PRES: I i S ! _.-~~ Temperature 2 Blu 10542 12699 Case 11/3/2003 Memory PPROF & IPROF 'f~ LOG - MEM GRlCCUSPINffEMP/PRES S ~ Pressure 2 Blu 1 0542 12699 Case 11/3/2003 Memory PPROF & IPROF LOG - MEM : GRlCCUSPINffEMP/PRES ¡ !~C S Asc 12319 Neutron 10542 12699 Case 12/22/2003 Memory Borax Log Mem i~ GRlCCUCNL ! Log Neutron 2 Blu 10542 12699 Case 12/22/2003 Memory Borax Log Mem i GRlCCUCNL Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y Ð Chips Received? ~- Analysis ~ Received? Daily History Received? ~N ð/N -, Formation Tops -- - - - - - - - -__0-__--- Comments: Compliance Reviewed By: ~ Date: '? --;)--;:~) Ù ~t- SchlulBbepger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth Well D.S.15-01A \ ~ <Z; ~Q.'ó2 ~ NK-62A ~0--f:.)~-r~ E-27A (1 - 0 S~ G-03A <-t "1 -0 "1- C5 F-16A lC; £0.- 1 {QtJ H-27A 8Q~'-()-5<4 E-05A }~ ~ ... Oc ¿~ E-04A r--\ ö .... \ ~ \ Job# 10703946 10572999 10558568 10563449 10558547 10700004 10672314 10662949 SCMT MCNL MCNL MCNL MCNL MCNL RST-SIGMA RST-SIGMA 11/26/03 NO. 3048 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Log Description Color Date Blueline Prints CD 10/31/03 2 05/30/03 1 1 1f-11f 08/09/03 1 1 }.v,'3j!: 06/04/03 1 1 I&W;J 05/08/03 1 1 09/30/03 1 1 ~j~);}' 09/16/03 1 1 09/15/03 1 1 ~r _ I i- ~ PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. Petro technical Data Center LR2-1 900 E. Benson Blvd. ~=? :(~ {-',- --- Anchorage, Alaska 99508 Date Delivered: ~ ~~f'Ù \C:....... DEC 22'200:3 P,J8SK¿;¡ ~:I ~ !-. _~ ._~ -_ ;\nc.~:-:~-~ - Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 A TTN: Beth - c::.. Received b~,\~'--,....."" ~-') \..C c.."L-::::::'C' ~ Scblumbepger Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth Well H-19B J <-t ~ -cFt~ H-27A SCJ~--("')h 0.5. 1-10 I '"=fFS-ð 0.5. 15-23 J ct. I - , '-~~ JX-02A Jf...( LJ .... t ' 0.5.14-23 I ~¿Q....Ocg ~~~~74-42 {J G J~~~ GNI-02 1 c¡ 13f5.l:) D.S. 6-16 f~O-O~~ P1-18A ~-n-::¡( rJ D.S. 5-28Afk)r.... \'j.5 D.S. 12-20 \ 5<ð- ~!1 J 2-32/SN-03 I q 0 '- \ \' 9/ Z-39 (-1CC<) - ~ 10/31/03 NO. 3017 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Job # Log Description Color Date Blueline Prints CD 09/29/03 1 10/01/07 1 10/25/03 1 07/10103 1 07/18/03 1 10/24/03 1 10/26/03 1 10/22/03 1 10/08/03 1 10/12/07 1 10/15/07 1 10/14/03 1 10/21/03 1 10/25/07 1 )é)!l-=S~ 09/22/03 1 MEM PPROF & IPROF LOG MEM PPROF & IPROF LOG PSP LDL RST GRAVEL PACK LOG LDL PSP LDL PROD PROFILE W/DEFT/GHOST LDL TEMP PROFILElSBHP SURVEY LDL PROD PROFILE W/DEFT LDL LDL LDL 10563105 RST -SIGMA ~--... PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage. Alaska 99508 Date Delivered: ~~\)ÿ\~~ Schlumberger GeoQuest 3940 Arctic Blvd. Suite 300 Anchorage, AK 99503-5711 A TIN: Beth ..··!::Eì'JED ~¡ () \ ! C· 7.. '):"", r -', ... . ., I . J ,...... .~ ~- -/ ...... "tJ .... J '\,.' ~~ ~ _\ - ~ Received by: \ ~ '\ ~ ¡V'\ \'::) \. C ("£ ~ Cf' /V'"\ J~~~~S;~8 J~~ 2~ t;~~; ;~~0-~1SI ~~~JrrHTI~55!On ¡~lc:noróJ]e 'I' ( { ~3-DSq \1 BOe, WELL LOG TRANSMfITAL To: State of AJaska AJaska Oil and Gas Conservation Comm. Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska July 18, 2003 RE: MWD Fonnation Evaluation Logs H-27A, AK-MW-2419293 1 LDWG fonnatted Disc with verification listing. API#: 50-029-21456-01 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COpy OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: S peny-SunDrilling 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 RECEIVED Signed: ~ Date:JUL ? 4 ï003 AI_a o¡t & Gas Cons. CommiS!ion Anchorage Sc~lumbepgep Alaska Data & Consulting Services 3940 Arctic Blvd, Suite 300 Anchorage, AK 99503-5711 ATTN: Beth D.S. 2-05A H-27 A E-02A NK-62A E-01A P2-54A D-22B D.S. 2-08B J-26 D.S. 2-29A D.S. 15-28 D.S. 12-20 J-08 D.S. 2-25 PSI-01 PSI-06 PSI-09 K-317B C-04A Well Job# 23376 23319 23275 23277 23280 23274 23348 07/02/03 NO. 2890 Company: State of Alaska Alaska Oil & Gas Cons Comm Attn: Lisa Weepie 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Prudhoe Bay Color Date Blueline Prints CD 06/02/03 1 1 jé).)3n 05/09/03 1 1 J~J(~ 03/15/03 1 1 04/27/03 1 1 )1); - 04/12/03 1 1 I~/< 03/27/03 1 1 ~). r..g OS/22/03 1 1 )~ I~ - 05/31/03 1 06/20/03 1 06/22/03 1 06/21/03 1 06/03/03 1 06/26/03 1 06/07/03 1 06/09/03 1 06/13/03 1 06/19/03 1 04/05/03 1 06/26/03 1 Log Description MCNL MCNL MCNL MCNL MCNL MCNL MCNL MEM PROD PROFILE LDL LDL LDL LDL LDL PRODUCTION PROFILE TEMPERATURE WARMBACK LOG TEMPERATURE WARMBACK LOG TEMPERATURE WARMBACK LOG SBHP SURVEY SBHP SURVEY PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COpy EACH TO: BP Exploration (Alaska) Inc. Petrotectnical Data Center LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 Date Delivered: RECEIVED JUI.t.ðL3 2003 Aiaska Of¡ & Gas Cons. Commi8eion Anchorage Schlumberger GeoQuest 3940 Arctic Blvd, Suite 300 Anchorage. AK 99503-5711 A TIN: Beth Received ~ ~ l ,~t.. G ~ ~(/'.../'f'""'...- ~ , ~ STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well iii 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 430' SNL, 1735' WEL, SEC. 21, T11 N, R13E, UM At top of productive interval 401' NSL, 1621' WEL, SEC. 09, T11 N, R13E, UM At total depth 1150' NSL, 2683' WEL, SEC. 09, T11N, R13E, UM X:: 641741, Y:: 5967189 11. Field and Pool 5. Elevation in feet (indicate KB, DF, etc.) 6. Lease Designation and Serial No. Prudhoe Bay Field / Prudhoe Bay Pool KBE = 72.5' ADL 028281 12. Date Spudded 13. Date T.D. Reached 14. Date Comp., Susp., or Aband. 5/3/2003 5/8/2003 5/10/2003 17. Total Depth (MD+ TVD) 18. Plug Back Depth (MD+ TVD) 19. Directional Survey 12823 9052 FT 12788 9054 FT a Yes 0 No ¿2. Type Electric or Other Logs Run SGRC, MGR, CCL, CNL 23. CASING SIZE 20" X 30" 13-3/8" 9-5/8" Classification of Service Well 7. Permit Number 203-059 8. API Number 50- 029-21456-01 9. Unit or Lease Name X :: 642835, Y :: 5960349 Prudhoe Bay Unit X:: 642819, Y:: 5966461 10. Well Number H-27 A 15. Water depth, if offshore 16. No. of Completions N/ A MSL One 20. Depth where SSSV set 21. Thickness of Permafrost (Nipple) 2063' MD 1900' (Approx.) WT. PER FT. Insulated 72# 47# 26# 9.3# / 6.2# / 6.16# 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 2706' 17-1/2" Surface 10613' 12-1/4" 1 0360' 11227' 8-1/2" 10155' 12823' 3-3/4" CEMENTING RECORD 8 cu Vds Concrete 3763 cu ft Coldset II 2523 cu ft Class 'G' 440 cu ft Class 'G' 125 cu ft Class 'G' AMOUNT PULLED 7" ·3-1/2" x 3-3/16" x 2-7/8" 24. Perforations open to Production (MD+ TVD of Top and Bottom and interval, size and number) 2" Gun Diameter, 4 spf MD TVD MD TVD 12100' - 12470' 9049' - 9057' 12520' - 12770' 9058' - 9055' 25. SIZE 5-1/2", 17#, L-80 TUBING RECORD DEPTH SET (MD) 1 0251' PACKER SET (MD) 10110' 26. ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED 2100' Freeze Protected with MeOH 27. Date First Production May 23, 2003 Date of Test Hours Tested 5/28/2003 4 Flow Tubing Casing Pressure Press. 1,085 PRODUCTION TEST Method of Operation (Flowing, gas lift, etc.) Flowing PRODUCTION FOR OIL-BBL TEST PERIOD 1 ,867 OIL-BBL GAs-McF 27,827 GAs-McF WATER-BBL 792 WATER-BBL CHOKE SIZE 65° OIL GRAVITY-API (CORR) 26.8 GAS-OIL RATIO 14,901 CALCULATED 24-HoUR RATE 28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core ChiRE C E ~\lE:, 0 No core samples were taken. MOMS BFl JUN G~ of ,..' ~ .".. ".~'\..'" '.',' 'f" "!~.,,. _-,\" £} 2003 JUN 0 2 2003 ORIG\N,AL Alaska Oill~. GalS Cons. Cormniss~Gn t\nchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate ( 29. Geologic Markers 30. Formation Tests Marker Name Measured Depth True Vertical Depth Include interval tested, pressure data, all fluids recovered and gravity, GaR, and time of each phase. 25N 11222' 8992' 25P 11225' 8994' 22N 11476' 9043' 22P 11500' 9044' REC;E JUN 0 2 Alaska Oil & Am:horag~ 31. List of Attachments: Summary of Daily Drilling Reports, Surveys 32. I hereby certify that the foregoing is true and correct to the best of my knowledge Signed TenieHubble ~eAAi.L ~Title Technical Assistant Date Olo-03'03 H-27 A 203-059 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number / Drilling Engineer: Ted Stagg, 564-4694 Permit No. Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. I-:-EM 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 (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 ORIG\NAL ( ,C( ( BP EXPLORATION Operations Summary Report Page 1 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-27 H-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/30/2003 Rig Release: 5/10/2003 Rig Number: N1 Spud Date: 10/14/1985 End: Date From - To Hours Task Code NPT Phase Description of Operations 4/30/2003 00:00 - 21 :00 21.00 MOB P PRE Move rig to H pad. 34 mile rig move. Total of 23.5 hrs. No problems. 21 :00 - 00:00 3.00 MOB N WAIT PRE WOW. Wind at 15-25 MPH. Unable to pick up pipe shed roof, derrick and wind walls. 5/1/2003 00:00 - 04:00 4.00 MOB N WAIT PRE WOW 04:00 - 04: 15 0.25 RIGU P PRE Safety meeting 04:15 - 04:30 0.25 RIGU P PRE Raise mast 04:30 - 05:30 1.00 RIGU P PRE Raise wind walls 05:30 - 06:30 1.00 RIGU P PRE Secure mast with guy wires. Set mast jacks on supports. 06:30 - 07:00 0.50 RIGU P PRE Pre tour safety meeting. Discuss well kill/load tubing on H-27, which will take place by HBR prior to moving rig over well. Discuss ongoing RU operations on Nordic 1. 07:00 - 08: 15 1.25 RIGU P PRE Pick up injector head and Stab pipe into injector. 08:15 - 09:45 1.50 RIGU P PRE MU Baker CTC. Pull test to 35 klbs. 09:45 -10:15 0.50 RIGU P PRE Pre job with HB&R about pumping load and kill on H-27. Discussed holding 2000 psi on IA prior to and during pump schedule to ensure there is no damage to TIW packer. Discussed the need to watch IA pressure increase due to thermal expansion during pumping, and limit it to 2500 psi max. Pump schedule is 10 bbls neat methanol spear, 450 bbls seawater, 40 bbls of 60/40 for freeze protect. Max WHP is 3000 psi duing pumping, and rate requested is maximum possible during pump sequence. 10: 15 - 10:45 0.50 RIGU P PRE Set back injector, PU BOP's. 10:45 - 13:15 2.50 RIGU P PRE Wait on HB&R to finish loading tubing with seawater. 13:15 - 14:00 0.75 RIGU P PRE Load and kill completed. Wait on HB&R to rig down, wait on pad inspection by Tool Pusher and Pad Operator. 14:00 - 14:20 0.33 MOB P PRE SAFETY MEETING. Prior to moving rig over well. 14:20 - 15:00 0.67 RIGU P PRE Move rig over well H-27. 15:00 - 17:00 2.00 BOPSUR P PRE ND tree cap, NU Stack. Accept rig at 15:00 Hrs, 05/01/2003. 17:00 - 20:30 3.50 BOPSUR P PRE Pressure test rig BOP stack. Witness of test was waived by State of Alaska, John Crisp. 20:30 - 21 :30 1.00 RIGU P PRE Pump Dart and fill coil with slick 2% KCL water. Dart on seat at 54.2 BBL. Blead off SIWHP of 300 psi to O. 21 :30 - 21 :45 0.25 KILL P DECaMP SAFETY MEETING. Review BHA make up and well conditions. 21 :45 - 22:00 0.25 KILL P DECaMP MU cementing BHA with big hole nozzle, 1 jt PH6, hyd discon and CTC. BHA = 38 ft. 22:00 - 23:30 1.50 KILL P DECaMP RIH with cementing BHA. Circ at 1.0 bpm with no returns. Pump 1.5 bpm with partial returns. 23:30 - 00:00 0.50 KILL P DECaMP Up wt at 10,240' = 46 K. Up wt at 10,860' = 47.5 K. Continue to RIH. Tag Baker Whipstock at 11,251', correct CTD to 11,225' [ -26']. Pick up 10ft and flag CT. Rig up DS cementers. 5/2/2003 00:00 - 00:45 0.75 KILL DECaMP R/U DS cementers and batch mix 52 bbls of 15.8 PPG, G emt. 00:45 - 01 :00 0.25 KILL Circ. 3 bpm, partial returns. eirc.4 bpm, 80 psi WHP. Good returns. Close choke. Pump 1 bpm = 75 WHP, 1.8 bpm = 600 psi. DECaMP SAFETY MEETING. Review cement pump procedure. Review Printed: 5/12/2003 11 :26: 12 AM ( (' BP EXPLORATION Operations Summary Report Page 2 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-27 H-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/30/2003 Rig Release: 5/10/2003 Rig Number: N1 Spud Date: 10/14/1985 End: Date From - To Hours Task Code NPT Phase Description of Operations 5/2/2003 00:45 - 01 :00 0.25 KILL DECOMP hazardes and mitigation. 01 :00 - 01 :40 0.67 KILL DECOMP Press test cement line to 4000 psi. Stg 5 bbl, neat G cement. 2.0 bpm, 900 psi pump, 50 psi whp. Stg 40 bbls, G cement with 15 #/ BBL agg. Circ. 2.5 bpm, 2700 psi PP, 75 psi whp, Stg 7 bbls neat G cement. Pumped a total of 52 bbls cement. Displace with 4 bbl water. Closed choke at 42 bbls CMT pumped, CT vol = 54 bbls. SIWHP = 900 psi, lAP = 820, OAP =100 psi. 01 :40 - 02:10 0.50 KILL DECOMP SQZ 7 bbl CMT below Whipstock and to perfs. 1.6 bpm, 2000 psi WHP, Open Choke and lay in cement at 800 psi. Pump 2.2 bpm, pull at 55 fpm. 52 K up wt. 300 psi pump. Lay in cement 1 for 1. WCTOC at 10,200'. Calculated top of cmt at 10,260'. Pull to safety of 9950'. 02:10 - 02:50 0.67 KILL DECOMP Sqz cement to 500 psi, Sqz cmt to 800 psi. Hold steady for 5 min. Good squeeze. Open choke slowly and eirc. at 1.1 bpm holding 800 - 1000 psi WHP. Hold 800 -1000 psi Sqz for 30 min. 02:50 - 04:00 1.17 KILL DECOMP RIH and clean out cement. CMT top at 10300'. Pump 3.0 bpm, RIH at 30 fpm. Clean out to flagg at 11,215'. Circ. 3.1 bpm and pull to 10800'. RIH to flag at 3.1 bpm, Dump cement returns to green tank. 04:00 - 06:30 2.50 KILL DECOMP POH at 80%. Circ. across each GLM. 06:30 - 08:00 1.50 KILL P DECOMP Continue to POH. IAP=700 psi. OAP=83 psi. Returns have been gas cut since starting to POOH. Swap returns thru gas buster to prevent gas going directly to pits. 08:00 - 09:00 1.00 KILL P DECOMP Returns have cleaned up. Swap back to the micro motion. 09:00 - 09:30 0.50 KILL P DECOMP Tag up at surface. Flow check. Well is flowing at 0.2 bpm. Watch for 1/2 hour. Continues to flow, with no reduction in rate. Possibly still have gas in hole migrating up to surface. Need to go back to bottom, circ wellbore clean, and monitor surface pressure. 09:30 - 11 :20 1.83 KILL P DECOMP RIH with BHA #1 to circ well clean of gas and check for SITP. 11 :20 - 12:25 1.08 KILL P DECOMP Zero SWS pressure transducer. Circulate KCL down coil taking returns. Getting 1 for 1. At start of circ out 3.8/3.8/2116 psi. Pit vol=295 bbls. Backside vol=214 bbls. IAP=122 psi, OAP=80 psi. After 50 bbls away, returns picked up and had gas at surface. Ship returns to tiger tank. 12:25 - 12:35 0.17 KILL P DECOMP 230 bbls back. Annular vol for bottoms up=214 bbls. SI returns. Check for flow. No flow detected. Kick on pumps. Returns still look foamy. Line up thru gas buster. 12:35 - 15:40 . 3.08 KILL P DECOMP POH, taking returns thru gas buster. POH pumping 3.1 bpm. Pit vol=262 bbls with BHA on bottom. Pump all the way OOH. Swap back to pits at 6000' while POH. In 8.5 Ib/g, out density=7.6 #/g. At 5000', returns cleaned up nicely. In density=8.56, Out=8.34 (Typically reads .25 low, so its right on.) 15:40 - 15:50 0.17 KILL P DECOMP Check for flow. No flow observed. 15:50 - 16:00 0.17 KILL P DECOMP Pop off well, lay down cement nozzle, PU swizzle stick nozzle, jet stack for 20 minutes. 16:00 -16:15 0.25 KILL P DECOMP Break off injector, rig up to PT well. Pressure up to 1000 psi as per proceedure. Cement compressive strength in excess of 2000 psi. Hold pre job safety meeting to discuss PU window Printed: 5/12/2003 11 :26: 12 AM ( BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-27 H-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Date From - To Hours Task Code NPT Phase 5/2/2003 16:00 -16:15 0.25 KILL P DECaMP 16:15 -16:30 0.25 STWHIP P WEXIT 16:30-18:15 1.75 STWHIP P WEXIT 18:15 - 18:40 0.42 STWHIP P WEXIT 18:40 - 19:00 0.33 STWHIP N SFAL WEXIT 19:00 - 21 :00 2.00 STWHIP P WEXIT 21 :00 - 22:30 1.50 STWHIP P WEXIT 22:30 - 23:30 1.00 STWHIP P WEXIT 23:30 - 00:00 0.50 STWHIP P WEXIT 5/3/2003 00:00 - 00:30 0.50 STWHIP P WEXIT 00:30 - 01 :30 1.00 STWHIP P WEXIT 01 :30 - 02:45 1.25 STWHIP P WEXIT 02:45 - 05:15 2.50 STWHIP P WEXIT 05:15 - 06:30 1.25 STWHIP P WEXIT 06:30 - 07:10 0.67 DRILL P PROD1 07: 10 - 08:00 0.83 DRILL P PROD1 08:00 - 09:50 1.83 DRILL P PROD1 09:50 - 10:40 0.83 DRILL P PROD1 10:40 - 10:50 0.17 DRILL P PROD1 10:50 - 13:55 3.08 DRILL P PROD1 13:55 - 14:00 0.08 DRILL P PROD1 14:00 - 15:10 1.17 DRILL P PROD1 15:10 - 17:00 1.83 DRILL P PROD1 Page 3 of 10 Start: 4/30/2003 Rig Release: 5/10/2003 Rig Number: N 1 Spud Date: 10/14/1985 End: Description of Operations milling BHA. Pressure bled off 30 psi in 15 minutes. Make up window milling BHA. Hughes D0261 DSM, New Hughes Diamond string reamer, Baker X-Treme motor, 2 jts PH6. RIH with BHA #2. IAP=297, OAP=212 psi. Make -28.5' correction to be consistent with last WS tag. Weight check up at 11200'=56 klbs. RIH and dry tag at 11210'. PU, kick on pumps to 2.6 bpm. Free spin 2.6/2.6/1490 psi. Tag top of cement at 11208', milling cement 50'/hr. Found lubricator o-ring leaking. PU and roll spare one into a-ring groove. No Leak. Milling Window. Found whipstock pinch point at 11,218'. Corrected CTD depth to 11,226.6'. [4.6 ft from top of whipstock by Baker drawing.] Milled to 11229.3 ft. Easy milling. 2.6 bpm, 1790/1500 psi, 1200 WOB. Milled to 11,231.1 ft. Easy milling. 2.6/2.6 bpm, 1500/1700 psi, 900 # WOB. Full returns. Milled to 11,231.8 ft. Easy milling. Two Stalls. Pick up clean and ream slow back to bottom. 2.6/2.6 bpm, 1550/1700 psi, 900 # WOB. Full returns. Milled window to 11,232.3'. Steady milling. 2.8/2.8 bpm, 1550/2040'. 1500# WOB. Total of 5.7' window milled in 5 hrs. Full returns. Milled out base of window at 11,233'. 2.7/2.7 bpm, 1550/ 1750 psi, Window = 11,227 - 11,233'. window = 6.4 ft total. Mill formation to 11,243'. Ream window area while swapping well over to FloPro. Clean window. Full returns. 2.5/2.5 bpm. 1460 psi, 23K down wt. Ream up and down 4 times. Stop pump and RIH to TD, clean. Window is good. POH while circ. FloPro. Flag CT at 11,100' EOP. Layout BKR milling BHA. Recover 100%. DSM = 3.79" aD. Reamer = 3.80" aD. Change out BKR CTC for DS CTC. Pull test and press test. Pre spud safety meeting with all rig hands, SWS CT crew, geo, DD, MWD. Make up BHA #3, Build section BHA. Picking up new DPI bi center bit, 2.57 deg Baker motor, GR-Directional MWD tool. RIH with BHA #3. Shallw hole test at 2150', orienter and MWD worked properly. Continue RIH. Make -26' correction to be consistent to window milling. Log down from 10895' bit depth @ 60 fph. +6' correction'. Orient to 20L. Free spin 2.5/2.5/2850 psi. Tag up at 11248'. PU at 44 klbs. Begin drilling. Pit vol=292 bbls. IAP=610 psi, OAP=132 psi. 11291', PU, take a click. Resume drilling. 11296', Getting 28 deg builds, needed 40 deg builds to achieve plan. Unable to do so. Pull for a bigger bend motor. Current IAP=700, OAP=450 psi. Bleed both down. IAP=60, OAP=21 psi. Printed: 5/12/2003 11 :26: 12 AM ( ( BP EXPLORATION Operations Summary Report Page 4 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-27 H-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/30/2003 Rig Release: 5/10/2003 Rig Number: N1 Spud Date: 10/14/1985 End: Date From - To Hours Task Code NPT Phase Description of Operations 5/3/2003 17:00 - 17:30 0.50 DRILL P PROD1 Tag up at surface, stand back injector. Check motor for tighness. Motor is looser than it should be. Lay down motor. Check bit. Slightly worn on pilot section, severly worn on wing cutter. Graded 2,6. Damage is consistent with chert in formation. 17:30 - 18:20 0.83 DRILL P PROD1 BHI does not have a backup short radius motor on location. Pick up a conventional radius motor adjusted to 3.6 degrees. Pick up new Hyghes bi centered bit. 18:20 - 20:30 2.17 DRILL P PROD1 RIH with BHA #4. Hughes bi center bit with alpha cutters. BHI motor adjusted to 3.6 degrees, MWD-GR/Directional package. 20:30 - 21 :00 0.50 DRILL P PROD1 RIH clean to TD. Tag TD at 11325', Corrected CT depth to 11,296' [-29']. TF = 40R. Orient TF to high side. 21 :00 - 21 :30 0.50 DRILL P PROD1 Drilling, several stalls, unable to keep L high side TF. Need to orient around. Drilled to 11,315'. 21 :30 - 22:00 0.50 DRILL P PROD1 Orient around to high side. 22:00 - 22:45 0.75 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 2860/3070 psi, 55 fph, 10L, Drilled to landing point of 11,358'. 22:45 - 23:30 0.75 DRILL P PROD1 Orient to left side. 23:30 - 00:00 0.50 DRILL P PROD1 Drilling, TF still building. Need to orient around. Drilled to 11,369'. 5/4/2003 00:00 - 00:30 0.50 DRILL P PROD1 Orient TF to left side. 00:30 - 01:15 0.75 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 2800/3200 psi, 80L TF, 50 FPH. 93 deg I ncl. Drilled to 11,410' 01: 15 - 01 :45 0.50 DRILL P PROD1 Orient around to left side again, to drop / hold incl. 01 :45 - 04:15 2.50 DRILL P PROD1 Drilling, 2.6/2.6 bpm, 2800/3000 psi, 90L TF, 50 FPH. 90 deg Incl. Drilled to 11,475'. TVDSS = 8970'. Zone 2. Clean sand. 04:15 - 06:00 1.75 DRILL P PROD1 POH for 1.37 deg motor. Flag CT at 11,100' EOP. POH. 06:00 - 08:40 2.67 DRILL P PROD1 Complete BHA change out. Hughes bit was recovered at 3,3 with several chipped cutters on both pilot and wing sections of bit. Adjust motor, Pick up DS49 bit and resistivity tool. Program/read resistivity tool. 08:40 - 10:45 2.08 DRILL P PROD1 RIH with BHA #5. Shallow hole test at 500' of MWD and RES tool passed ok. Continue RIH. 10:45 - 11 :55 1.17 DRILL P PROD1 Tag up at bottom, 11499' CTM. Make correction to last tag of 11475', for a -24' correction. Try to power up MWD tools, can't get pulses. Dogleg is apparently too high and pulser is in a bind. PUH to vertical section of hole. Pulser kicks on at 11343'. RIH, and it drops out at 11420'. Try orienting to see if that makes a difference. Orient to 90L, RIH. It works! PUH logging MAD pass. Pulser dropped out after 100'. Log remainder of MAD pass on battery. 11 :55 - 12:25 0.50 DRILL N DFAL PROD1 RIH, try to begin drilling. Pulser won't work at TD. PUH to vertical section of well. Cycle pumps to get MWD to kick on. Won't work. Troubleshoot MWD surface eq. Can't get it to work. 12:25 -14:15 1.83 DRILL N DFAL PROD1 POH. Apparently pulser failed. Plan forward is to POH, lay down RES tool, and RIH with conventional lateral assembly. 14:15 -15:20 1.08 DRILL N DFAL PROD1 Tag up at surface, read RES tool. Break out of BHA. Pick up lateral section BHA minus RES tool. 15:20 - 17:30 2.17 DRILL N DFAL PROD1 RIH with BHA #6, Lateral section BHA, 1.04 deg motor, DS49 Printed: 5/12/2003 11 :26: 12 AM ( ( BP EXPLORATION Operations Summary Report Page 5 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-27 H-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/30/2003 Rig Release: 5/10/2003 Rig Number: N1 Spud Date: 10/14/1985 End: Date From - To Hours Task Code NPT Phase Description of Operations 5/412003 15:20 - 17:30 2.17 DRILL N DFAL PROD1 bit, Directonal/GR for MWD, and no RES tool. While RIH, Sperry hand found pulser from previous run damaged. His suspicion is that it was damaged from the bind caused by the dog leg. Check tools in vertical section of hole above window, they work fine. Continue RIH. 17:30 - 17:55 0.42 DRILL P PROD1 Tag up, make -22' correction to last tag depth of 11475'. Drill ahead lateral section at 120L TF. Free spin 3000 psi. Drilling at 2.7/2.7/3350 psi. Pit vol=295 bbls. IAP=65 psi, OAP=32 psi. ROP=70 fph. 17:55 - 18:10 0.25 DRILL P PROD1 11502', Pickup for 2 clicks. 18:10 - 18:45 0.58 DRILL P PROD1 Resume drilling. TF=90L. ROP=70 FPH. 18:45 - 18:50 0.08 DRILL P PROD1 11547', PU and take 1 click. 18:50 - 19:30 0.67 DRILL P PROD1 Resume drilling. 2.5 I 2.5 bpm, 2600 I 2800 psi, 40 FPH, 86 deg I ncl. Drilled to 11570'. 19:30 - 21:15 1.75 DRILL P PROD1 Drilling, 2.6 I 2.6 bpm, 2900 I 3150 psi, 89 Incl, 50 fph, 20L TF. Drilled to 11,645'. 21:15-23:20 2.08 DRILL P PROD1 POH for RES tool. Flag CT at 10,800' EOP. POH. 23:20 - 00:00 0.67 DRILL P PROD1 C/O bit, M/U Sperry RES/GR tool. Bit #5 was 4,3,1, from drilling chert and conglomerates in Zone 2. 5/5/2003 00:00 - 01: 15 1.25 DRILL P PROD1 M/U Sperry Res/GR tool with 1.0 deg motor and re-bult HC SX404 bit. Surface test Sperry Res tool. 01:15 - 03:15 2.00 DRILL P PROD1 RIH with Shallow test Res tool and orienter. RIH. Corrected CTD to flag, -34 ft CTD. 03: 15 - 03:45 0.50 DRILL P PROD1 Log tie-in with GR. On Depth. 03:45 - 04:00 0.25 DRILL P PROD1 RIH to TD. Tag TD at 11,646 ft. 04:00 - 04:30 0.50 DRILL P PROD1 Log MAD pass with RES/GR at 400 FPH up to 11 ,440'. RIH. 04:30 - 05:00 0.50 DRILL P PROD1 Orient TF to 70L. 05:00 - 06:10 1.17 DRILL P PROD1 Drilling, 2.7 I 2.7 BPM, 3020 I 3350 psi, 75L, 91 deg Incl, 60 FPH. Drilled to 11,702 ft. 06:10 - 06:30 0.33 DRILL P PROD1 Orient around to drop Incl. 06:30 - 06:40 0.17 DRILL P PROD1 11701', Resume drilling. IAP=230 psi, OAP=98 psi, Pit vol=285 bbls. 06:40 - 06:45 0.08 DRILL P PROD1 Take 2 clicks. 06:45 - 07:20 0.58 DRILL P PROD1 Resume drilling ahead. 07:20 - 07:35 0.25 DRILL P PROD1 11748', orient to straight down. 07:35 - 07:50 0.25 DRILL P PROD1 Resume drilling ahead. 07:50 - 08:00 0.17 DRILL P PROD1 11769', orient to 90L. 08:00 - 08:25 0.42 DRILL P PROD1 Resume drilling, holding INC of 91 deg, following formation dip. 08:25 - 09:00 0.58 DRILL P PROD1 11796', Wiper trip to shoe. Slow pump rate down in build section to avoid damage to pulser in MWD tool. 09:00 - 09:10 0.17 DRILL P PROD1 Orient to 90R. 09:10 -10:30 1.33 DRILL P PROD1 Resume drilling. 2.6/2.6/3380 psi. Pit vol=277 bbls. Lost 7 bbls of pit volume since start of tour. Does not appear to be going over the shaker, probably seapage losses to matrix in high perm zones. 10:30 - 11 :45 1.25 DRILL P PROD1 11845', Pit vol=274 bbls. ROP trending down. ROP now 60-80 fph. Getting real grabby at this depth. Possibly the expected fault, or is the bit chunked? 11:45 -12:15 0.50 DRILL P PROD1 11879', ROP back up over 100 fph. Pit vol=272 bbls. 2.6/2.6/3120 psi. 12:15 -13:15 1.00 DRILL P PROD1 11894', PU to orient straight down. Geo wants to drill at 88' to deepen TVD. 13:15 - 13:45 0.50 DRILL P PROD1 11915', Pick up to orient to 90L. Printed: 5/12/2003 11 :26: 12 AM (, ( Page 6 of 10 BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date 5/5/2003 5/6/2003 Resume drilling. Pit vol 265 bbls. 11953', Wiper trip to shoe. Clean off bottom at 46 klbs. Pit vol=262 bbls. Orient to 90R. Resume drilling. 11968'. ROP very low for last hour, and having difficulty getting motor work. Probably have trashed bit. POOH to change bit. C/O bit. M/U Bit #8, HYC DS49, re-build. Down load RES/GR tool. RIH with RES/Lateral BHA #8. 1.04 deg motor. Tag TD at 11998' and correct CTD to 11,968' [-30 ft CTD]. Orient TF to 90R. Drilling, getting very high reactive torque, 200 deg. Drilled lateral to 11,985'. Drilling, 2.8/2.8 bpm, 3250/3600 psi, 89 deg incl, 100L TF. Drilled to 12,090'. Drilling, 2.8/2.8 bpm, 3250/3600 psi, 88 deg incl, 90l TF. Faster drilling at 12,120'. Drilled to 12,150". Wiper trip to window. Slow pump to 0.5 bpm from 11,550-11,300'. Clean hole. Log GR tie-in with RA tag at 11,234'. On depth, no correction. RIH. Clean hole to 12,030'. Stacked wt. RIH to TO of 12,150'. Orient TF to 90R. Drilled to 12,153'. Stacking wt. TF went to Left side. 12153', Hard drilling, poor weight transfer. Swap to new FloPro. IAP=630 psi, OAP=559 psi. 2.6/2.6/3200 psi, pits empty for mud swap. Wiper trip 400' while doing mud swap. Orient to 90R. Having difficulty getting orienter to hold a right side tool face. Keeps flopping around. It isn't reactive torque. It happens prior to us touching bottom. Resume drilling. 2.6/2.6/3300 psi. Free spin=3000 psi. Still taking on new mud. Just over 50% swapped out. 12189', Drilling along fine at 90R for 36', then TF flopped to 120L. Note - not reactive torque. Doesn't come back when we pick up off bottom. Have to orient around to get back to where we need to be. Getting 30 deg reactive torque on bottom drilling. DFAL PROD1 Try to resume drilling. Orienter flopping. Stalled on bottom and it flopped 180 deg to 90L. Pickup and it doesn't come back. RIH and stall intentionally, and it flops another 180 deg to 90R. Note - This does not appear to be reactive torque. It looks like a failed/non locking orienter. DFAL PROD1 POH to change orienters and check bit. DFAL PROD1 Tag up at surface. Down load RES tool. Check bit and motor. Motor appears tight. Bit in very good shape considering the Zone 2 we have been drilling. Bit Graded 2,1. Re run same bit and motor. Change out orienter. Change out packoffs. DFAL PROD1 RIH with BHA #9. 1.04 deg BHI motor, Hycalog 0549 bit, RES tool, MWD GR+Directional. Stop at 2200', Check orienter and MWD. Both worked fine continue RIH. Tagged TO at 12,209', correct CTD to 12,190'. DFAL PROD1 Orient TF to 95R. H-27 H-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 From - To Hours Task Code NPT Phase 13:45 - 14:50 1.08 DRILL P PROD1 14:50 - 15:25 0.58 DRILL P PROD1 15:25 - 15:35 0.17 DRILL P PROD1 15:35 - 17:00 1.42 DRILL P PROD1 17:00 - 19:20 2.33 DRILL P PROD1 19:20 - 20:30 1.17 DRILL P PROD1 20:30 - 23:00 2.50 DRILL P PROD1 23:00 - 23:20 0.33 DRILL P PROD1 23:20 - 00:00 0.67 DRILL P PROD1 00:00 - 03:00 3.00 DRILL P PROD1 03:00 - 04:00 1.00 DRILL P PROD1 04:00 - 04:30 0.50 DRILL P PROD1 04:30 - 05:00 0.50 DRILL P PROD1 05:00 - 05:45 0.75 DRILL P PROD1 05:45 - 06:00 0.25 DRILL P PROD1 06:00 - 06:30 0.50 DRILL P PROD1 06:30 - 07:00 0.50 DRILL P PROD1 07:00 - 07:25 0.42 DRILL P PROD1 07:25 - 07:55 0.50 DRILL P PROD1 07:55 - 08:10 0.25 DRILL P PROD1 08: 1 0 - 08:25 0.25 DRILL P PROD1 08:25 - 08:40 0.25 DRILL N 08:40 - 10:55 10:55 - 12:40 2.25 DRILL N 1.75 DRILL N 12:40 - 14:50 2.17 DRILL N 14:50 - 15:00 0.17 DRILL N Start: 4/30/2003 Rig Release: 5/10/2003 Rig Number: N1 Spud Date: 10/14/1985 End: Description of Operations Printed: 5/12/2003 11:26: 12 AM ( BP EXPLORATION Operations Summary Report Page 7 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-27 H-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/30/2003 Rig Release: 5/10/2003 Rig Number: N1 Spud Date: 10/14/1985 End: Date From - To Hours Task Code NPT Phase Description of Operations 5/612003 15:00 - 16:30 1.50 DRILL P PROD1 Drilling, 2.7 I 2.7 bpm, 3000 I 3400 psi, 108R, 88 deg incl. Drilled to 12264' 16:30 -18:15 1.75 DRILL P PROD1 Drilling, 2.7 I 2.7 bpm, 3000 I 3400 psi, 70R, 91 deg incl. Drilled to 12,350'. 18:15 - 19:25 1.17 DRILL P PROD1 Wiper trip to window. Slow pump down to 0.5 bpm from 11550-11300'. RBIH & set down @ 11500'. P/U & RIH clean to btm. 19:25 - 19:30 0.08 DRILL P PROD1 Orient TF to 90R. 19:30 - 19:40 0.17 DRILL P PROD1 Drill to 12353' with 90R TF, 2.7/2.7bpm, 3150/3350psi, 36fph ave ROP. TF flop to 180. 19:40 - 19:50 0.17 DRILL P PROD1 Reorient TF to 80R. 19:50 - 20:55 1.08 DRILL P PROD1 Drill to 12400' with 85-105R TF, 2.8/2.8bpm, 3150/3450psi, 45fph ave ROP. Targeting 8985ftss in search of HOT. 20:55 - 21 :45 0.83 DRILL P PROD1 Orient & drill to 12431' with 110R TF, 2.8/2.8bpm, 3150/3450psi, 40fph ave ROP. 21 :45 - 22:15 0.50 DRILL P PROD1 Orient & drill to 12450' with 135R TF, 2.8/2.8bpm, 3150/3450psi, 35fph ave ROP. 22: 15 - 22:30 0.25 DRILL P PROD1 Shoot off-btm survey & orient TF to 100L. 22:30 - 23: 1 0 0.67 DRILL P PROD1 Drill to 12470' with 85-105L TF, 2.8/2.8bpm, 3150/3450psi, 45fph ave ROP. 8985ftss projected @ the bit. Geo seeing heavy oil traces in samples - could be transition zone into HOT. Geo wants to drill up to 8982ftss. 23: 1 0 - 23:25 0.25 DRILL P PROD1 Orient & drill to 12476' with 10L TF, 2.8/2.8bpm, 3150/3300psi, 36fph ave ROP. Stacking wt. 23:25 - 00:00 0.58 DRILL P PROD1 Work BHA length & ream to btm thru tight spot @ 12476'. 5/7/2003 00:00 - 01 :40 1.67 DRILL P PROD1 Ratty drilling thru hard spot @ 12476'. Grind on with occasional stalling & slip sticking. Finally drill to 12480' with HS TF, 2.8/2.8bpm, 3100/3500psi. 01 :40 - 02:00 0.33 DRILL P PROD1 Drill to 12500' with HS TF, 2.8/2.8bpm, 3100/3450psi, 50fph ave ROP. 02:00 - 04:05 2.08 DRILL P PROD1 Wiper trip clean to window (slowing pump from 11550'-11300'). Wipe up hole to TT @ 10250'. RBIH clean to btm. 04:05 - 04:35 0.50 DRILL P PROD1 Drill to 12525' with 30L TF, 2.8/2.8bpm, 3100/3450psi, 50fph ave ROP. 04:35 - 04:45 0.17 DRILL P PROD1 Orient TF to 90L. 04:45 - 05:30 0.75 DRILL P PROD1 Drill to 12551' with 90L TF, 2.8/2.8bpm, 3100/3450psi, 45fph ave ROP. 05:30 - 06:00 0.50 DRILL P PROD1 Orient & drill to 12560' with 60L TF, 2.8/2.8bpm, 3100/3450psi, 20fph ave ROP. 06:00 - 07:00 1.00 DRILL P PROD1 Orient & drill with 20L TF, 2.8/2.8bpm, 3100/3450psi, 30fph ave ROP. Drilled to 12584' 07:00 - 07: 15 0.25 DRILL P PROD1 Orient TF to 90L. 07:15 - 09:15 2.00 DRILL P PROD1 Drilling, 2.6 I 2.6 bpm, 3000 / 3400 psi, 80L TF, 90.5 dg incl, Drilled to 12,628'. 09:15 - 10:45 1.50 DRILL P PROD1 Drilling, 2.6 I 2.6 bpm, 3000/3400 psi, 40L TF, 91 dg incl, Drilled to 12,648'. 10:45 - 12:15 1.50 DRILL P PROD1 Wiper trip to window. Slow pump from 11550-11300'. Clean hole. RIH. 12:15 - 12:30 0.25 DRILL P PROD1 Drilling, 2.6 I 2.6 bpm, 3000 I 3400 psi, 40L TF, 91 dg incl, Drilled to 12,651. Stacking wt, several stalls. Need to pull for bit. 12:30 - 14:40 2.17 DRILL P PROD1 POH for new bit and motor. 14:40 - 16:30 1.83 DRILL P PROD 1 C/O bit and motor and down load Sperry Res/GR tool. Printed: 5/12/2003 11 :26: 12 AM (' (' BP EXPLORATION Operations Summary Report Page 8 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-27 H-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/30/2003 Rig Release: 5/10/2003 Rig Number: N1 Spud Date: 10/14/1985 End: Date From - To Hours Task Code NPT Phase Description of Operations 5/7/2003 16:30 - 19:30 3.00 DRILL P PROD1 RIH with RES/GR BHA # 10. New DS49H bit and 1.04 deg motor. Set down @ 12003'. P/U & set down 2x. Attempt to orient to original drilled TF (1 05L)- TF flopping to the RHS. Reorient 2x & RBIH - still tagging up. Decide to PUH & tie-into RA pip tag. 19:30 - 19:40 0.17 DRILL N DPRB PROD1 PUH to 11305'. 19:40 - 20:00 0.33 DRILL N DPRB PROD1 Log up GR & tie into RA PIP (subtract 15' from CTD). 20:00 - 20:20 0.33 DRILL N DPRB PROD1 RBIH & tag up @ 12001'. 20:20 - 20:30 0.17 DRILL N DPRB PROD1 Orient TF to 165R. 20:30 - 21 :25 0.92 DRILL N DPRB PROD1 Carefully ream in hole to 12013' with 105L TF, 2.7bpm/3050psi, 150-250fph ave ROP. Stall @ 12013' & TF flop to 60R. Continue reaming to 12048'. Backream to 11920' with some motor work. Ream back in hole & stall @ 12066' & 12077'. P/U, SID pumps, RIH & set down @ 12077'. 21 :25 - 21 :50 0.42 DRILL N DPRB PROD1 Continue ream in hole to 12100'. Backream clean to 11985' with no motor work. SID pumps, drift thru clean & tag up @ 12100'. Looks like we're running into an undergauged hole. Bit#8 (ran from 11968' to 12651') gauges 3.70" OD. Thus reaming is due to approx. 1/16" hard zone-2 undergauged hole. 21 :50 - 23:05 1.25 DRILL N DPRB PROD1 Ream in hole to 12360' with 45R TF, 2.7bpm/3050psi, 285fph ave ROP. Stall several times @ 12360'. 23:05 - 00:00 0.92 DRILL N DPRB PROD1 Work on tight spot @ 12360' & finally ream thru. 5/8/2003 00:00 - 00:50 0.83 DRILL N DPRB PROD1 Continue reaming in hole to 12651' with 20-45R TF, 2.7/3050psi, 325fph ave ROP. 00:50-01:10 0.33 DRILL P PROD1 Orient TF to 11 OL. 01:10 - 01:30 0.33 DRILL P PROD1 Drill to 12682' with 130-140L TF, 2.7/2.7bpm, 3050/3400psi, 65fph ave ROP. 01 :30 - 01 :45 0.25 DRILL P PROD1 Orient 1 click & drill to 12692' with 110L TF, 2.7/2.7bpm, 3050/3400psi, 45fph ave ROP. 01:45 - 02:10 0.42 DRILL P PROD1 Orient 1 click & drill to 12708' with 80L TF, 2.7/2.7bpm, 3050/3150psi, 35fph ave ROP. TF rolling left. 02:10 - 02:50 0.67 DRILL P PROD1 Orient & drill to 12747' with 55-70L TF, 2.8/2.8bpm, 3050/3300psi, 65fph ave ROP. 02:50 - 03:25 0.58 DRILL P PROD1 Orient & drill to 12780' with 25-45L TF, 2.7/2.7bpm, 3050/3350psi, 55fph ave ROP. Stacking wt. 03:25 - 04:40 1.25 DRILL P PROD1 Drill to TDlend of polygon @ 12822' with 65L TF, 2.8/2.8bpm, 3050/3400psi, 35fph ave ROP. 04:40 - 05:35 0.92 DRILL P PROD1 Wiper trip clean to window (slowing pump from 11550'-11300'). 05:35 - 06:00 0.42 DRILL P PROD1 Log up GR & tie into RA PIP. Added 2ft to CTD. 06:00 - 07:15 1.25 DRILL P PROD1 RBIH to TO tagged @ 12,823'. 07:15 - 10:00 2.75 DRILL P PROD1 POH. Flag CT at 10,100' EOP and 8500' EOP. 10:00 - 11 :45 1.75 DRILL P PROD1 LlO BHA and Down load RES/GR tool. 11 :45 - 12:00 0.25 CASE P COMP SAFETY MEETING. Review procedure, hazards and mitgation for running liner. 12:00 - 13:30 1.50 CASE P COMP M/U 47 jts of 2-7/8" STL Liner with Baker float equipment. Fill Liner. 13:30 - 15:00 1.50 CASE P COMP M/U 37 jts of 3-3/16" TCII Liner, XO and 1 jt, 3-1/2" STL Liner 15:00 - 15:45 0.75 CASE P COMP M/U Baker CTLRT with 3.5" pup and 3.5" Howco X nipple [ 2.813" Profile]. M/U BKR CTC. Pull and Press Test. Total Liner = 2690.32'. with BKR running tools, BHA = 2702'. 15:45 -17:15 1.50 CASE P COMP RIH with liner on CTC. Circ. FloPro at 0.3 bpm. Correct to Flag, -12 ft CTD. Printed: 5/12/2003 11:26:12 AM t, ( BP EXPLORATION Operations Summary Report Page 9 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-27 H-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/30/2003 Rig Release: 5/10/2003 Rig Number: N1 Spud Date: 10/14/1985 End: Date From - To Hours Task Code NPT Phase Description of Operations 5/8/2003 15:45 -17:15 1.50 CASE P CaMP Up Wt at 11,202' = 51 K, Dwn wt = 29K. 17:15 -17:45 0.50 CASE P CaMP Ran thru window with no wt loss. Ran thru open hole at 60 fpm, 0.3 bpm, Clean to TD. Tagged TD at 12,841', Pick up and tag TD again at same depth. Corrected Depth = 12,823'. 17:45 - 18:20 0.58 CASE P CaMP Insert 5/8" steel ball and displace with FloPro at 2.5 bpm at 2600 psi. Ball on seat at 45.5 bbls. Sheared at 3800 psi. Pick up free at 41 K. Liner is free from CT. 18:20 - 21 :00 2.67 CEMT P CaMP Displace well to 2% KCL at 3.4/3.1 bpm & 1850psi. Ship back used mud to MI. Meanwhile R/U Dowell cementers. 21:00-21:15 0.25 CEMT P CaMP PJSM with all personnel concerning cementing operations. 21 :15 - 22:05 0.83 CEMT P CaMP Batch mix 25bbls 15.8ppg cmt with additives. Cmt to wt @ 21 :30hrs. Flush/PT lines to 4k. Pump 22.2bbls cmt slurry @ 3.2/3.0bpm & 2550psi. Close inner reel valve, clean lines & flush with bio-KCL. Load/launch CTWP with 800psi. Pump 0.2bbls. Check & observe dart on inner reel valve. Relaunch dart with 800psi & confirm launched. 22:05 - 22:40 0.58 CEMT P CaMP Chase with 36bbls biozan & follow with KCL @ 2.8/2.5bpm & 1450psi. CTWP engage LWP at 55.4bbls away. Shear plug with 3100psi. Continue displacing LWP @ 2.9/2.8bpm, 2000psi & bump @ 72.4bbls away. 20bbls cmt pumped around shoe. Pressure up to 1500 psi. Bleed off & floats held. Pressure back to 300psi & sting out of liner. CIP at 22:40 hrs 22:40 - 00:00 1.33 CEMT P CaMP POOH @ 11 Ofpm & pumping @ 0.6bpm/160psi to replace voidage only. 5/9/2003 00:00 - 00:15 0.25 CEMT P CaMP Continue POOH @ 11 Of pm & pumping @ 0.6bpm/160psi to replace void age only. 00:15 - 01 :00 0.75 CEMT P CaMP LID CTLRT. 01 :00 - 05:45 4.75 BOPSURP CaMP Perform weekly BOPE pressure/function test. AOGCC test witness waived by John Spaulding. Meanwhile changeout 13 broken bearing pins on the injector. 05:45 - 06:15 0.50 EVAL P CaMP Crew change & prep to P/U motor/mill & MCNLlCCLlGR tools. Meanwhile W.O. SWS logging crew. 06:15 - 07:00 0.75 EVAL P CaMP SWS logging truck arrives. Checkout tools. 07:00 - 07: 15 0.25 EVAL P CaMP SAFETY MEETING. Review BHA M/U procedure, hazards and mitigation. 07: 15 - 08:00 0.75 EVAL P CaMP M/U 2.3" mill, motor and CNLlGR BHA. 08:00 - 10:45 2.75 EVAL P CaMP M/U 88 Jts of 1-1/4" CSH workstring in singles. M/U DS motor head assembly. 10:45 - 12:20 1.58 EVAL P CaMP RIH with mill, motor and MCNLlGR BHA. Total length = 2,770.76 ft. Circ. at 0.3 bpm. 12:20 - 15:30 3.17 EVAL P CaMP Log down from 10,000 ft at 60 fpm. Circ. in 20 bbl high vis FloPro perf pill at 0.5 bpm. Tag TD at 12,795'. Correct Depth to 12786'. [-9 ft]. Circ. at 0.7 bpm to get pill to mill. DS cement sample at 1850 psi at 13:30 hrs. 15:30 - 14:30 23.00 EVAL P CaMP Log up at 60 fpm, 0.7 bpm, 680 psi. Lay in high vis FloPro 20 bbl pill. 14:30 - 17:15 2.75 EVAL P CaMP Circ. at 1.5 bpm while POH. 17:15 - 19:00 1.75 EVAL P CaMP Stand back 44 stds of CSH worstring. LlO CNLlGR, motor and mill. 19:00 - 19:30 0.50 EVAL P CaMP Review recent spill incident & held PJSM for LID CNL tools & motor/mill. 19:30 - 20:00 0.50 EVAL P CaMP LID CNLlCCLlGR logging tools & motor/mill. 20:00 - 20:45 0.75 EVAL P CaMP Line up to test liner lap.Compressive strength of cement Printed: 5/12/2003 11:26:12 AM ( { BP EXPLORATION Operations Summary Report Page 10 of 10 Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: H-27 H-27 REENTER+COMPLETE NORDIC CALISTA NORDIC 1 Start: 4/30/2003 Rig Release: 5/10/2003 Rig Number: N1 Spud Date: 10/14/1985 End: Date From - To Hours Task Code NPT Phase Description of Operations 5/9/2003 20:00 - 20:45 0.75 EVAL P COMP >2000psi. WH/IAlOA @ 0/34/15psi @ onset of test. Pressure up WH/IAlOA to 2140/34/15psi. After 30mins we have WH/IAlOA @ 2075/34/15psi. Good lap test. 20:45 - 21:15 0.50 PERF P COMP Load perf guns in pipeshed. R/U to run guns. R/U safety jt. Meanwhile download MCNLlCCLlGR & fax to ANC Geo. 21: 15 - 21 :30 0.25 PERF P COMP Held PJSM for P/U perf guns. ANC Geo confirms perf intervals. 21 :30 - 23:30 2.00 PERF P COMP M/U 32 2" SWS HSD perf guns & blanks with CBF firing head. 23:30 - 00:00 0.50 PERF P COMP M/U 16 1-1/4" CSH doubles. 5/10/2003 00:00 - 00:30 0.50 PERF P COMP Continue M/U a total of 33 doubles of 1-1/4" CSH. 00:30 - 02:30 2.00 PERF P COMP RIH with perf gun BHA on CT. Wt check @ 12500' = 42k. Tag PBTD 2x @ 12798'. Pull to P/U wt & depth was dead correct @ 12793' (PBTD as per MCNL log). PUH to ball drop postion @ 12767' . 02:30 - 03:05 0.58 PERF P COMP Pump 10 bbl perf pill & load 5/8" steel ball. Blow ball into CT & circ down while positioning guns for btm shot @ 12770'. Chase ball to seat slowing to 1 bpm @ 45bbls. Ball on seat after 53.4bbls away. Ramp up to 3000psi & observe guns fire with good pressure drop indication & 2bbls fluid loss. Perforated interval = 12100' - 12470' & 12520' - 12770'. 03:05 - 05:45 2.67 PERF P COMP POOH with perf gun BHA pumping across the WHD to keep hole full. Meanwhile Phase 1 driving conditions declared in GPB with 41 mph wind gusts. 05:45 - 06:00 0.25 PERF P COMP Crew change & R/U for LID CSH. 06:00 - 06:15 0.25 PERF P COMP Held PJSM for LID 1-1/4" CSH. 06:15 - 08:00 1.75 PERF P COMP LID 66 jts of 1-1/4" CSH. 08:00 - 08:15 0.25 PERF P COMP SAFEY MEETING, Review procedure, hazards and mitigation for laying out fired perf guns. 08:15 - 10:30 2.25 PERF P COMP Layout fired 2" perf guns. All shots fired. 10:30 - 11 :30 1.00 PERF P COMP Layout CSH in singles. 11 :30 - 12:30 1.00 WHSUR P COMP RIH to 2100 ft and lay in MEOH at 50 % to 200 ft and 100% to surface. 12:30 - 12:45 0.25 RIGD P POST SAFETY MEETING. Review procedure, hazards and mitigation to displace coil with N2. 12:45 - 14:00 1.25 RIGD P POST Pump N2 and bleed down coil press. 14:00 - 15:00 1.00 RIGD P POST Pull CT stub to real. Secure coil on reel. 15:00 - 17:00 2.00 RIGD P POST Clean rig pits. N/D BOPE. 17:00 - 18:00 1.00 RIGD P POST N/U tree cap and pressure test. RELEASED RIG AT 18:00 HRS, 5/10/2003. Total time on well was 9 days, 3 hours. Printed: 5/12/2003 11 :26: 12 AM ( (' 22-May-03 AOGCC 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 Re: Distribution of Survey Data for Well H-27 A Dear Dear Sir/Madam: Enclosed are two survey hard copies and 1 disk Tie-on Survey: 11,208.39' MD Window / Kickoff Survey: 11,225.00' MD (if applicable) Projected Survey: 12,823.00 I MD Please call me at 273-3545 if you have any questions or concerns. Regards, William T. Allen Survey Manager /20 3 ·-b ~ q RECEIVED Attachment(s) JUN 0 2 2003 AlaIka Oil & Gas Cons. Comrrüeeion \.n ~chorage ~fú- 0. ~ Sperry-Sun Drilling Services North Slope Alaska BPXA PBU_ WOA H Pad H-27 A '-"-- Job No. AKMW0002419293, Surveyed: 8 May, 2003 Survey Report 21 May, 2003 Your Ref: 500292145601 Surface Coordinates: 5960349.00 N, 642835.00 E (70017' 57.0884" N, 148050'35.4622" W) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 -~- Surface Coordinates relative to Project H Reference: 960349.00 N, 142835.00 E (Grid) Surface Coordinates relative to Structure Reference: 2748.27 N, 1522.96 E (True) Kelly Bushing: 72.50ft above Mean Sea Level Elevation relative to Project V Reference: 72.50ft Elevation relative to Structure Reference: 72.50ft 5r~""'v-5U"'" b A íL.-l.:fl\l G '--SER VI t::es A Halliburton Company Survey Ref: svy4030 DrillQuest 3.03.02.005 Page 2 of 4 21 May, 2003 -15:01 Sperry-Sun Drilling Services Survey Report for PBU_ WOA H Pad - H-27A Your Ref: 500292145601 Job No. AKMW0002419293, Surveyed: 8 May, 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) 11208.39 47.950 3.780 8909.99 8982.49 5859.39 N 159.21 E 5966210.36 N 642882.81 E 3802.38 Tie-on Point MWD Magnetic 11209.30 47.950 3.780 8910.60 8983.10 5860.06 N 159.25 E 5966211.03 N 642882.84 E 0.029 3802.80 11225.00 47.970 3.690 8921.11 8993.61 5871 .70 N 160.01 E 5966222.68 N 642883.38 E 0.444 3810.02 Window Point 11255.12 53.920 2.410 8940.08 9012.58 5895.05 N 161.24 E 5966246.05 N 642884.16 E 20.027 3824.73 -" 11285.02 61.920 1.390 8955.95 9028.45 5920.35 N 162.07 E 5966271.36 N 642884.51 E 26.911 3841.04 11316.97 73.830 0.440 8967.96 9040.46 5949.89 N 162.53 E 5966300.90 N 642884.41 E 37.378 3860.46 11343.42 85.020 359.720 8972.81 9045.31 5975.84 N 162.57 E 5966326.86 N 642883.95 E 42.390 3877.81 11365.49 92.990 359.130 8973.19 9045.69 5997.89 N 162.35 E 5966348.89 N 642883.31 E 36.211 3892.73 11397.24 93.920 345.440 8971.27 9043.77 6029.22 N 158.10 E 5966380.14 N 642878.47 E 43.138 3916.84 11428.54 88.900 334.160 8970.50 9043.00 6058.53 N 147.32 E 5966409.24 N 642867.13 E 39.425 3944.47 11458.36 90.220 317.590 8970.73 9043.23 6083.13 N 130.65 E 5966433.51 N 642850.00 E 55.740 3973.32 11489.16 88.990 310.900 8970.94 9043.44 6104.61 N 108.60 E 5966454.57 N 642827.54 E 22.084 4004.08 11525.21 86.700 306.490 8972.30 9044.80 6127.12 N 80.49 E 5966476.54 N 642799.01 E 13.776 4040.03 11551.86 85.550 304.550 8974.10 9046.60 6142.57 N 58.85 E 5966491.58 N 642777.08 E 8.448 4066.45 11584.26 85.460 302.260 8976.64 9049.14 6160.35 N 31.89 E 5966508.84 N 642749.79 E 7.052 4098.38 11619.86 88.190 302.440 8978.61 9051.11 6179.37 N 1.86 E 5966527.29 N 642719.41 E 7.685 4133.42 11648.02 90.930 301.740 8978.83 9051.33 6194.33 N 21.99 W 5966541 .79 N 642695.27 E 10.043 4161.16 11678.89 92.780 297.330 8977.83 9050.33 6209.53 N 48.83 W 5966556.48 N 642668.15 E 15.484 4191.27 11721.70 92.780 290.810 8975.75 9048.25 6226.96 N 87.85 W 5966573.17 N 642628.81 E 15.212 4231.94 11753.00 92.510 287.810 8974.30 9046.80 6237.30 N 117.35 W 5966582.94 N 642599.11 E 9.613 4260.78 11785.87 90.480 642567.45 E 9.701 4290.45 -, 285.350 8973.44 9045.94 6246.67 N 148.84 W 5966591.72 N 11817.64 91.370 288.170 8972.93 9045.43 6255.83 N 179.26 W 5966600.30 N 642536.87 E 9.307 4319.18 11851.27 91.450 293.980 8972.10 9044.60 6267.92 N 210.61 W 5966611.78 N 642505.29 E 17.273 4350.57 11881.14 90.660 296.800 8971.55 9044.05 6280.72 N 237.59 W 5966624.07 N 642478.07 E 9.803 4379.19 11914.09 87.220 300.150 8972.16 9044.66 6296.42 N 266.54 W 5966639.22 N 642448.83 E 14.570 4411.21 11945.89 88.460 303.670 8973.36 9045.86 6313.22 N 293.51 W 5966655.50 N 642421.54 E 11 .728 4442.49 11976.85 90.930 307.900 8973.53 9046.03 6331.32 N 318.62 W 5966673.12 N 642396.10 E 15.820 4473.26 12002.70 89.960 308.780 8973.33 9045.83 6347.35 N 338.89 W 5966688. 76 N 642375.52 E 5.066 4499.05 12036.33 88.030 305.230 8973.92 9046.42 6367.59 N 365.74 W 5966708.48 N 642348.29 E 12.013 4532.54 12071.68 87.750 302.440 8975.22 9047.72 6387.25 N 395.08 W 5966727.59 N 642318.59 E 7.927 4567.51 DrillQuest 3.03.02.005 Page 3 of 4 21 May, 2003 - 15:01 Sperry-Sun Drilling Services Survey Report for PBU_ WOA H Pad - H-27A Your Ref: 500292145601 Job No. AKMW0002419293, Surveyed: 8 May, 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 eft) eft) eft) eft) eft) eft) eft) (o/100ft) 12102.93 87.930 300.500 8976.40 9048.90 6403.55 N 421.71 W 5966743.38 N 642291.65 E 6.230 4598.21 12128.75 88.110 298.030 8977.29 9049.79 6416.17 N 444.22 W 5966755.57 N 642268.90 E 9.586 4623.38 12161.03 88.550 296.100 8978.23 9050.73 6430.85 N 472.95 W 5966769.70 N 642239.90 E 6.130 4654.55 12197.60 88.810 299.970 8979.07 9051.57 6448.03 N 505.22 W 5966786.26 N 642207.31 E 10.603 4690.02 12228.48 87.490 302.790 8980.07 9052.57 6464.10 N 531.56 W 5966801.83 N 642180.66 E 10.079 4720.36 -- 12260.95 87.840 304.200 8981.39 9053.89 6482.00 N 558.62 W 5966819.21 N 642153.27 E 4.471 4752.44 12294.28 91.010 308.960 8981.73 9054.23 6501 .86 N 585.37 W 5966838.55 N 642126.15 E 17.156 4785.61 12326.85 90.660 312.310 8981.25 9053.75 6523.06 N 610.08 W 5966859.29 N 642101.04 E 10.340 4818.16 12359.75 89.340 317.590 8981.25 9053.75 6546.30 N 633.36 W 5966882.08 N 642077.33 E 16.542 4851.00 12400.95 88.630 319.000 8981.98 9054.48 6577.05 N 660.76 W 5966912.30 N 642049.34 E 3.831 4891.95 12429.18 88.360 323.470 8982.72 9055.22 6599.05 N 678.43 W 5966933.96 N 642031.26 E 15.858 4919.79 12461.10 85.640 322.880 8984.39 9056.89 6624.56 N 697.53 W 5966959.11 N 642011.68 E 8.719 4951.06 12493.25 88.460 322.880 8986.05 9058.55 6650.16 N 716.90 W 5966984.33 N 641991.82 E 8.771 4982.59 12521.13 91.810 322.180 8985.98 9058.48 6672.28 N 733.86 W 5967006.13 N 641974.45 E 12.275 5010.00 12557.60 90.750 320.240 8985.17 9057.67 6700.70 N 756.70 W 5967034.11 N 641951.07 E 6.060 5045.98 12589.75 91.010 317.770 8984.67 9057.17 6724.96 N 777.79 W 5967057.96 N 641929.53 E 7.724 5077.89 12621.70 92.690 315.300 8983.64 9056.14 6748.14 N 799.75 W 5967080.72 N 641907.12 E 9.346 5109.72 12651.03 93.220 313.010 8982.13 9054.63 6768.54 N 820.77 W 5967100.72 N 641885.73 E 8.004 5138.99 12681.58 89.690 311.250 8981.35 9053.85 6789.02 N 843.41 W 5967120.77 N 641862.70 E 12.910 5169.52 12712.30 88.110 304.910 8981.94 9054.44 6807.96 N 867.58 W 5967139.24 N 641838.18 E 21.265 5200.15 12746.58 89.690 300.330 8982.60 9055.10 6826.43 N 896.43 W 5967157.15 N 641808.97 E 14.131 5233.95 12772.73 92.330 296.980 8982.14 9054.64 6838.96 N 919.37 W 5967169.25 N 641785.80 E 16.308 5259.39 12799.20 93.220 294.160 8980.86 9053.36 6850.37 N 943.22 W 5967180.21 N 641761.74 E 11. 1 60 5284.74 12823.00 93.220 294.160 8979.52 9052.02 6860.10 N 964.90 W 5967189.52 N 641739.88 E 0.000 5307.36 Projected Survey 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 312.000° (True). Magnetic Declination at Surface is 25.788°(02-May-03) Based upon Minimum Curvature type calculations, at a Measured Depth of 12823.00ft., The Bottom Hole Displacement is 6927.62ft., in the Direction of 351.994° (True). DrillQuest 3.03.02.005 Page 4 of4 21 May, 2003 - 15:01 -, 8982.49 BP High Accuracy Gyro (H-27) 9052.02 MWD Magnetic (H-27 A) 0.00 11208.39 8982.49 12823.00 0.00 11208.39 To Measured Vertical Depth Depth Survey Tool Description (ft) (ft) From Measured Vertical Depth Depth (ft) (ft) Survey tool program for H-27A Tie-on Point Window Point Projected Survey 159.21 E 160.01 E 964.90 W 5859.39 N 5871.70 N 6860.10 N 8982.49 8993.61 9052.02 11208.39 11225.00 12823.00 ~~-- Comment Station Coordinates TVD Northings Eastings (ft) (ft) (ft) Measured Depth (ft) Comments North Slope Alaska BPXA Sperry-Sun Drilling Services Survey Report for PBU_ WOA H Pad - H-27A Your Ref: 500292145601 Job No. AKMW0002419293, Surveyed: 8 May, 2003 ~~~~E ~. I f ~~~~~~~ FRANK H. MURKOWSKI, GOVERNOR ~ AI..A~KA. OIL AND GAS CONSERVATION COMMISSION 333 W. 7TH AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Ted Stagg CT Drilling Engineer BP Exploration (Alaska), Inc. PO Box 196612 Anchorage AK 99519 Re: Prudhoe bay Unit H-27 A BP Exploration (Alaska), Inc. Pennit No: 203-059 Surface Location: 430' SNL, 1735' WEL, Sec. 21, TIIN, RI3E, UM Bottomhole Location: 1142' NSL, 2680' WEL, Sec. 09, TI1N, RI3E, UM Dear Mr. Stagg: Enclosed is the approved application for pennit to redrill the above development well. This pennit to redrill does not exempt you from obtaining additional permits or approvals required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required pennits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this 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 Commission's North Slope petroleum field inspector at 659-3607 (pager). Sincerely, ~~ Randy Ruedrich Commissioner BY ORDER OF THE COMMISSION DATED this --=1 day of April, 2003 cc: Department ofFish & Game, Habitat Section wlo encl. Department of Environmental Conservation wlo encl. Exploration, Production and Refineries Section j,N 4 Æ- c.¡ {, , l...oC! 1 a. Type of work 0 Drill II 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 = 642835, Y = 5960349 4301 SNL, 1735' WEL, SEC. 21, T11 N, R13E, UM At top of productive interval x = 642856. Y = 5965844 5063' NSL, 1597' WEL, SEC. 16, T11 N, R13E, UM At total depth x = 641744. Y = 5967181 1142' NSL, 2680' WEL, SEC. 09, T11 N, R13E, UM 12. Distance to nearest property line 13. Distance to nearest well ADL 028284, 11421 MD No Close Approach /' 16. To be completed for deviated wells ' Kick Off Depth 11225' MD Maximum Hole Angle 18. Casing ~rogram Specifications Size ' Hole Casino Weioht Grade CouclinQ LenQth 3-3/4" 3-3/16" x 2-7/8" 6.2#/6.16# L-80 TCII / ST~ 2665' STATE OF ALASKA ' ALASK¡,. )IL AND GAS CONSERVATION COMh..lsION PERMIT TO DRILL 20 AAC 25.005 1 b. Type of well 0 Exploratory 0 Stratigraphic Test II Development Oil o Service 0 Development Gas 0 Single Zone 0 Multiple Zone 5. Datum Elevation (OF or KB) 10. Field and Pool KBE = 72.5' Prudhoe Bay Field / Prudhoe 6. Property Designation Bay Pool ADL 028281 7. Unit or Property Name Prudhoe Bay Unit 8. Well Number / H-27 A 9. Approximate spud date 05/10/03 Amount $200,000.00 14. Number of acres in property 15. P~osed depth (MD and TVD) 2560 12800' MD / 8970' TVDss 17. Anticipated pressure {S? 20 ~AAC 25.035 (e) (2)} 90 0 Maximum surface 2084 psig, At total depth (TVD) 8800' / 3140 psig Setting Depth Top Bottom Quantity of Cement MD TVD MD TVD (include staQe data) 10135' 8170' 128001 8970' 101 cu ft Class 'G' 11. Type Bond (See 20 AAC 25.025) Number 2S 100302630-277 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Structural Conductor Surface Intermediate Production Liner 11505 feet 9181 feet 11448 feet / 9142 feet Length Plugs (measured) Junk (measured) Size Cemented MD TVD 110' 20" x 30" 2706' 13-3/8" 10613' 9-5/8" 11451 7" 8 cu yds Concrete 3763 cu ft Coldset II 110' 2706' 110' 2676' 2523 cu ft Class IG' 440 cu ft Class 'G' 106131 8581' ~~e~vËlJ 91811 Perforation depth: measured Open: 10868' - 10872', 11280' - 11307', 113211 - 11343' /" Sqzd: 10860' - 10868' true vertical Open: 8754' - 8757', 9030' - 9048', 9058' - 9072' Sqzd: 8749' - 8754' II Filing Fee 0 Property Plat II BOP Sketch B Drilling Fluid Program 0 Time vs Depth Plot 0 Refraction Analysis APR 0 3 2003 20. Attachments Alaska Œ1 & GiS Gonö. Gcmmi3sion ¡1.:r.:~~-~~ o Diverter Sketch B Drilling Program o Seabed Report II 20 MC 25.050 Requirements Prepared By NamelNumber: Terrie Hubble, 564-4628 Contact Engineer Name/Number: Ted Stagg, 564-4694 21. I hereby certify that t~ f79Jtg ~ true and correct to the be~t of my kn~~ledge . Signed Ted Stagg ~~ Title CT Dnlhng Engineer . ">" ...... .,<i".:, ,',:COmmi~j,*:~.~:QD~:,,:2. ,:·:i:.,-::.\' Permit Number API Number Approval Date See cover letter ¿!..ð3 - a ..c;7 50- 029-21456-01 D '?t/ 0/(/ ¿}3 for other requirements Conditions of Approval: Samples Required 0 Yes ~ No Mud Log Required' 0 Yes ~ No Hydrogen Sulfide Measures ~ Yes 0 No Directional Survey Required 181 Yes 0 No Required Working Pressure for BOPE 0 2K 0 3K 0 4K 0 5K 0 10K 0 15K 0 3.5K psi for CTU Other: '\e..~ t 'Eo PE -b '3500 PS-tl. J:.Þ by order of :~:~~~r Rev. 12-01-7? ~-4"U~~rl:rNAccommiSSion Date ~/3ß.3 Date M ~7/òS 6u6mi; I{Tri~hcate m J-I,J(IJ-3 ) ) BP H-27a CTD Sidetrack Summary of Operations: /' A CTD through tubing sidetrack is planned for H-27. The coil sidetrack, H-27a, will exit the 7" liner in the Zone 2 and will target Zone 2. H-27a will be completed with a fully cemented liner as a producer. One possible fault will be crossed in Zone 2 but lost circulation is not expected. Real time Resistivity logging will be used to help identify the HOT as the target interval is drilled. /' Phase 1: Prep work. Planned for April 4 (step 1) and April 11 ,2003 for st~ps 2 and 3. 1. Periorm an MIT-IA and MIT-OA after all GLV's are dummied off. 2. Use e-line to set a whipstock at 11 ,22~' !f?~(~921 'ss). 3. Use service coil to pump a minimum of~s cement to squeeze all existing periorations. Phase 2: Mill window, Drill and Complete sidetrack: Planned for May 10, 2003. Drilling coil will be used to mill the window in the 7" liner then drill and complete the directional hole as per attached plan. Maximum hole angle will be 90 degrees. /' Mud Program: · Phase 1 &2: Seawater and 8.6 ppg Flo-Pro · Phase 3: Mill and drill with Flo-Pro (8.6 - 8.7 ppg) /' Disposal: · All drilling and completion fluids and all other Class II wastes will go to Grind & Inject. · All Class I wastes will go to Pad 3 for disposal. Casing Program: ./' /' The production liner will be a 3 3/16" TC II x 27/8" ST-L solid liner from TD to approx. 10,135' MD (8170'ss). The X-O between 3 3/16" x 2 7/8" will be at approx. 11,325' MD (8968'ss). A minimum ot4âJ bbls of 15.8 ppg latex cement will be used for liner cementing. Top of liner cement is planned to be~ 11,000' MD (8770ss). Well Control: · BOP diagram is attached. /' · Pipe rams, blind rams and the CT pack off will be pressure tested to 400 psi and to 3500 psi. · The annular preventer will be tested to 400 psi and 2500 psi. Directional · See attached directional plan. Max. planned hole angle is 90 deg. · Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. Logging · An MWD/GR will be run over the entire open hole interval. Resistivity will be run in open hole. CNL will be logged in cased hole. Hazards . Maximum recorded H2S on H Pad is 180 ppm o~well H-22a. The closest wells at suriace measure 20 ppm (H-20) and 10 ppm (H-26). Lost circulation is a low risk at the fault crossing. . Reservoir Pressure Res. press. is estimated to be 3140 psi at 8800'ss ( 6.9 ppg emw). Max. suriace pressure with gas (0.12 psi/ft) to suriace is 2084 psi. ../ , TREE = r 6-3/8" MCEVOY WELLHEAD = MCEVOY ACTUATOR = KB. ELEV = BF. ELEV = KOP= Max Angle = Datum MD = Datum TVD = ') 72.5' 45.2' 2058' 4~@11354' 11044' 8800' SS 113-3/8" CSG, 72#, L-80, ID = 12.347" l-i 2705' Minimum ID = 4.455" @ 10206' 5-1/2" XN NIPPLE I 5-1/2" TBG, 17#, L-80, .0232 bpf, ID = 4.892" l-i 10249' 1 I TOP OF 7" LNR l-i 10360' 19-5/8" CSG, 47#, L-80, ID = 8.681" l-i 10613' I PERFORA TION SUMMARY REF LOG: GEARHART CNL 10/30/85 ANGLE AT TOP PERF: 48 @ 10860' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 4 10860-10870 squeezed proposed 3-3/8" 4 10868-10872 squeezed proposed 3-3/8" 4 11280-11307 isolated proposed 3-3/8" 4 11287-11307 isolated proposed 3-3/8" 4 11321-11341 isolated proposed I PBTD l-i 11448' I 7" LNR, 29#, L-80, .0371 bpf, ID = 6.184" l-i 11503' DATE 11/04/85 02/17/01 03/01/01 09/21/01 REV BY COMMENTS ORIGINA L COMPLETION SIS-SL T CONVERTED TO CANVAS SIS-LG FINAL RNIKAK CORRECTIONS H-27A Proposed cro Sidetrack DATE ~ - L I I í i V ) ~ .. ~ REV BY ~ s; 4 3 2 1 I ~ . SAF' ) NOTES 2063' 1-i5-1/2" OTIS SSSV LANDING NIP, ID = 4.562" I MD 3292 6447 8638 9568 9970 GAS LIFT MANDRELS DEV ìY PE V LV LATCH PORT DA TE 38 OTIS RA 46 OTIS RA 36 OTIS RA 42 OTIS RA 41 OTIS RA TVD 3104 5404 7034 7744 8046 10037' 1-i5-1/2" SLIDING SLV, ID = 4.562" 1 10095' 10110' 10130' 10135' 10145' 10162' I-iTBG SEAL ASSY I - 9-5/8" X 5-1/2" TIW PKR, ID = 4.75" I - Liner Top Packer 2.60" ID /' - Top of 3-3/16" Liner 1-i3-1/2"XNIP,ID=2.813" I 1-i5-1/2" X NIP, ID = 4.562" 1 10206' l-i 5-1/2" XN NIP, ID = 4.455" 1 1 0249' l-i 5-1/2" TBG TAIL 1 10242' l-i ELMD IT LOGGED 06/21/86 I 10665' I-iMARKERJOINT I /' Perfs to be sqz'ed with cement 1 11000' l-i Top of cement I /' l-i 3-3/16 x 2-7/8 X-over I e . ,12601T'"" I .,/ iZ-1CC ~G,\- ~ r----'I 3-3/16" X 2-7/8" cmt'ed and perfedl-i 11225' 1-Il'v1echanical Whipstock COMMENTS Cement to be pumped past the whipstock to shut off all perfs PRUDHOE BAY UNIT WELL: H-27 ÆRMIT No: 85-2360 API No: 50-029-21456-00 Sec.21,T11N,R13E BP Exploration (Alaska) BP Amoco ~----- ,....1 WOllpalh: Tie Oft MD: Wl!LLPATH DETAIL. P!.an.... H·21A 5OØ2e21.H01 H·27 11208.39 Rill: Ref. DObll.: V.a.ctJon Angle 312.00' 38: 27 1011.,181500:00 n.5O!I ~r;n~ ~~t; 0.00 0.00 :~~D 0.00 REFERENCE INFORMATION Co-ordinale (NÆ! Reference: Well Centre: H·27, True Nonh v~~~g ~:~;:~: šro~~~ ~~o~~~ Measured Depth Reference: 36: 271~/14/1985 00:00 72.50 CalcUation Method: Minimll11 Curvature II!CTION DETAJL.S DL.. Tface Target 1 11208.38 47.15 3.71 eeot.e, 5.851.30 UIi.Z4 Æ 0.00 3&02.H 2 '11225.00 47.17 3.8' 1121.1'1 4171.70 180.05 Z 2M.13 3810.00 3 '1124'.00 ..... 2." .1).4.Z8 H88.73 180.12 .00 342.00 3811.40 .. 'I U.40.35 00.00 351.09 'MO.81 ::U::: ~~:U ::: ~~~:gg :sa.a.a.02 : : :::::~: 00.00 321.011 'H'..t 3155.71 10.00 212.01 ::::::~ 8183.83 ·12.87 15.00 27Q.00 =:~ ¡ ::~~:~: 00.00 318.&0 8S01.51 -303.151 15.00 eo.OO 10.00 ~~;::: ::::::: "21.75 -4H.2Q t 5.00 270.00 4&43.51 ~O :=:~: 00.00 1574.07 ·15'.1'0 15.00 80.00 :::::~ 80.00 ~~:~ 1"'.8t :¡~::: -105.83 15.00 270.00 11 12800.00 80.00 IHI..1 ·Iao.ail t 5.00 110.00 1S2fl.04 ANNOTATlONI TVO MO A......1Ion 1809.98 11201.38 TIP "21.11 11228.00 KOP 883.4.21 11245.00 3 1888..1 11SU.38 . 1818"1 11.2..35 8 1818..1 11IU.3' . 1"8"1 11.....' 7 1.....1 121....' I 1888..1 123...35 8 8888..1 121".35 10 1888..1 12100.00 TD H-21A~1 +EJ1'J SJu;.e -41.U ~no'" ------- 8450 8500 8550 8600 - .5 8650 m 8700 - ; 8750 A. & 8800 Ci 8850 U :e 8900 U ~ 8950 ~ 9000 _ 9050 :J"I£': XOP . T \."~ ;. ~ '""----- 9100 :-H--=-iIIiH1L._ 9150 9200 -r-- ! i -----r ----...- --~ I O ' B~-i ___ bp HUeH:£I INTEQ Direct: (907) 267-6613 E.mail: brijpotnis@inteq.com Baker Hughes INTEG: (907) 267-6600 T ^M ,---- Azimuths to True North I Plan: Plan #4 (H-27/Plan#4 H-27A) Magnetic North: 25.82° I Created By: Brij Potnis Date: 3/18/2003 Magnetic Field Contact Information: Strength: 57532nT Dip Angle: 80.80° Date: 3/18/2003 Model: BGGM2002 -- LEGEND ~~~U7'J?¿A) Plan#4 H-27 A Plan #4 ,- --- --- é , , I -I ~ noo-:- -=--- ......, :-:---- '"'--,_ Q-04A (Q-04A) - - -- -=- -==~~- --~--=-==-- -=-=---- - ~---===----=-----=------ - ------- ----.-----. -----"'-~---_.---_._------ -------,. --- ........._,- ------------ - - -------------- ---------- ----- ------- -- 7100-= -- ~ --- ------ ----------- - --- ----"----- 7000-~-=- ---~-- ------- -------~--------~------- ------------------- ----~----------- ------ ----------- ----------------- - ----- -~--...----------.----------- -_.----- ----~ -- -- - ------ - ------- --- - ------------ -------- ------- 6900- ____ _ _-==--=== ----_-~ Pla~t:I-27A;- ---=--=-_-===~__:_'<:;::=_=~==:_=_~_._-- /' 'ro' " ------- ------------ ------- ------- --- 6800-- - - c ;:¡ 6700- ~-.. Õ :: 06600- ---~- - ----------------- ---- ------------- ~ 5900-_- -- --- --- ~-1 5800======-=-~~ ~~~---:m--=--__ -_=__ ---::-::=:-- ~=- - ___~__ --:::=___ -;~IPt::r-=- i ¡ -------------". - -.------- ------ --------- 5600 - ----- - --~----~- --.--------t-------- - -------- -. ----~ -- ------ ---:-=--_-_-=-~-_=__~.. . _=--_---=-~_=_=_~~_~-_=_~_:=__==__-_=__--~-=-_:_--=--:::-:::.. _~~1-::~_:_- __~~_=-=-==:..: _. ·t---=-~~=-==--= ! ~______ _--------i_______ 5700-=---~ ------ --~_._--_.--- -~- --------- -1600-1500-1400-1300-1200-1100-1000 -900 -800 -700 -600 -500 -400 -300 -200 -100 0 100 200 300 400 500 600 700 800 900 1000 West(-)/East(+) [100ftlin] -- --~~---------- - ------------------ ----- --- ----- ----------- ----~- ----- --- ----- ------- -- - ------.- ----- -- --------- -.-------- ----- ----- --------------~---"-- ---~~---~-------~--------- ------- ~ .~ "Q-04A(Q-04A): ~-=-:::~~_-:-~~-..:.-=__ I\~~_ _=-- _ ;T_-=---_~-- _--:::X-=- ===-=---~_.10':- __==-_:=~ ~~_-=~__~~ ~-'" --------- --------_._--------~- _._--------------------~--.------------ ---------------- -- -- --------------------- ---- -----. Plan#4 H-27A: . TD' - -------- - ----- - --- - --------- ----~------ ---------------------- -----------.- --------- --------" ------.---- --------------------------------- ---- --------- ---------~--~------------- -- -------, -- ---- --------- ------ - ----~------- - -----~-------- ----- -----------"----- -------------------~---- -~---_._----- ----------- ----------- - -- -------------- ---- - ----------"_.----------- --------- - ------ --- --- ---------------- ------ ---------- ---- --------------- ~----- - -------- ------------- --~ ---- ------ ----- - -------- 3550 3600 3650 3700 3750 3800 3850 3900 3950 4000 4050 4100 4150 4200 4250 4300 4350 4400 4450 4500 4550 4600 4650 4700 4750 4800 4850 4900 4950 5000 5050 5100 5150 5200 5250 5300 5350 5400 5450 Vertical Section at 312.00° [50ft/in] 3t-t8t2003 -1:13 PM- -----~-- bp ) BP ) BaKer Hughes INTEQ Planning Report IM..I .*'- ""'H í'N"'rEQ .. " '. ~... .~"^." ,,-," " .,_., ~""",'" ." -.. on,,,, ".._" ".....,_ ~._ '~'~~'_"'" . R' .__. W"_""'_~"'_"_"' ._.., ..., .... . ...,~_.,,,.__ ..~. """.'.'"' ..........~_ ,,_ _._.....,-~~~..~.._'-~""--_..,_.-'~.".1".-...'.,,~.~....._.:,.. .,~~. ..._.~._~~.-....__..___~~~.~_.,._ _w..~._.,..__..._~_'__._,_._"L_..___h_.~'_' __..___".~__..._..._._._._._"~..._,..__, _"_,.___., .__. "...._._M.."~_.__~._._~,.__,.._.._..,_..."..._,'_.,.,._.,'~.' .,.~ Company: BP ArnOco Field: Prudh()è,B,ay Site: PB H Pad Well: H-27 W ~I!~~~~:__.~:~~~::~:~~:?~__,.:~.: _:..- :.:____. ._=:_. 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 Dåt~:311~/200~. ...·......i ........ . Tifue:\1 ~=44:1& Page: 1 Co-ordil1ate(~E) ,Refere~ce: . ,^,~lhH-27,TrueNor1h.. Yerti.cal(1'VD) R~fe~eQee: SY$tarn: Mean Sea L~vel Section(VS)Refe~ence: . . .... Wal1(O.00N,0.QOE,31~.00~i} _,__.____,...,___._._.,_.:.~~~.::.~::.~~:~~~:::::~~~~~~~~~~~!~~~~=~~~:~!.~:~:=::.:::~~~i:~.~~:~~~:~~-~~~~-:..~ .....~__. ..::~!?~.~-~.~!.~~I~-_.. Map Zone: Coordinate System: Geomagnetic Model: Alaska, Zone 4 Well Centre BGGM2002 Site: PB H Pad TR-11-13 UNITED STATES: North Slope Site Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Ground Level: 0.00 ft 5957572.25 ft 641366.07 ft Latitude: Longitude: North Reference: Grid Convergence: 70 17 30.055 N 148 51 19.802 W True 1.08 deg _ _ .___.'''_..'''_.'''' .~ ~,__~, '"".m~ ,_,._,u.,'_",._n ....' .___._._..._'_U·.~,""_"__'__'." "_..,,_, . -..,...---..--.,....,-....--.......,-...-, - ---...---....,.----.-.,.....-......., .._-,-_.... Well: H-27 Slot Name: H-27 Well Position: +N/-S 2748.85 ft Northing: 5960349.00 ft Latitude: +E/-W 1521.00 ft Easting : 642835.00 ft Longitude: Position Uncertainty: 0.00 ft 27 70 17 57.088 N 148 50 35.462 W .." .' .- .'. . - _.,..,.,,-,_.... __ ~ _"____ __u___.,·......._....._."'..__._.,.......__.._._..·" .. Wellpath: Plan#4 H-27A 500292145601 Current Datum: 36: 2710/14/198500:00 Magnetic Data: 3/18/2003 Field Strength: 57532 n1' Vertical Section: Depth From (TVD) ft 0.00 +Nl-S ft 0.00 Drilled From: Tie-on Depth: Above System Datum: Declination: Mag Dip Angle: +E/-W ft 0.00 H-27 11208.39 ft Mean Sea Level 25.82 deg 80.80 deg Direction Height 72.50 ft 312.00 Targets - . - ..--- -- -. . - - 0--.'_-.". _ Map Map <..-- Latitude --> <-- Longitude --> Name Description TVD +N/:'S fE/-W Northing East.ng Deg "'l\1in See Deg 'Mi-n "'Sec Dip. Dir. ft ft ft ft > ..' ... ·.··ft' . "'_~"C ."._ '_'.. '"."........" _ " ~....,......,'- . _.- .. , ~.J.'._.,'-..._,~~, ._____.....,.".__.......;. ". ..,..:......,;. "",~"__,,,_, '." '_'" ,,__,......,~'"'.:_,_.,!._..,;,.....;.. '-"......~,..,.,""-.~ .._~..':,:.._~',,:~. .."....:.,.,. ,.c..:...... ."" ...:.. _.,_. H-27 A Polygon4.1 0.00 5938.43 -47.14 5966285.00 642675.00 70 18 55.492 N 148 50 36.837 W -Polygon 1 0.00 5938.43 -47.14 5966285.00 642675.00 70 18 55.492 N 148 50 36.837 W -Polygon 2 0.00 5778.22 224.88 5966130.00 642949.99 70 18 53.917 N 148 50 28.901 W -Polygon 3 0.00 6136.85 301.72 5966490.00 643020.00 70 18 57.444 N 148 50 26.659 W -Polygon 4 0.00 6460.31 -402.31 5966800.00 642310.00 70 19 0.625 N 148 5047.200 W -Polygon 5 0.00 6890.73 -944.27 5967220.01 641760.00 70 19 4.858 N 148 51 3.015 W -Polygon 6 0.00 6787.26 -1026.26 5967115.00 641680.00 70 19 3.840 N 148 51 5.407 W -Polygon 7 0.00 6352.04 -494.39 5966690.01 642220.00 70 18 59.560 N 148 50 49.887 W Annotation MD 1'VD ft ft 11208.39 8909.99 TIP 11225.00 8921.11 KOP 11245.00 8934.28 3 ; 11349.35 8969.61 4 11424.35 8969.61 5 11684.35 8969.61 6 , 11934.35 8969.61 7 12134.35 8969.61 8 12384.35 8969.61 9 12584.35 8969.61 10 12800.00 8969.61 TD _,_.,.__" ,.<____'u__. _~._. .__.__.___ _~___.._____." ,,___.___.______.__. __ _._.________._..____. __ __u___ .__.__ __n__._..__ _,_.~._ n.... bp ". L' .h.....~.'_~,_".~".. Company: BPArnoco Field: Prudhoe Bay Site: PB H Pad Well: H-27 Wellpath: Plan#4H-27A .,.,,,' . - , ~"'-""-' -, ..-"'...-...~.--.-.~.' .... -~.,_."._-_._.,. ) BP ) BaKer Hughes INTEQ Planning Report ~iI.1 811I.:. ~N""rEQ . ....~,.. ....- w.._~__~_...._ "~',~~~:~:--"~'.""--''''~_.''';-''.'~'''.''':':''-'"'-:---'''";'- -:',_·-"':"·~·,:-:-i'·~·..-·~~·ft_....-:~~-:...,.-~...._~-"-::.~'~-~:--:--:.--:--'-':"·'~"~'-,""~·'-::";""""':··':'·-:'~--_··~~'~'"""':7""· ',- .. ..,_..,_....:~..':"-:'..~...._"~'_.~._"-_.;'-:-~~_.._" ~.- "~";"'- ~ ...-.---. ,-",."._..~,."..~..-.-... Plan: Plan #4 Identical to Lamar's Plan #4 I Principal: Yes Plan Section Information MD ft 11208.39 11225.00 11245.00 11349.35 11424.35 11684.35 11934.35 12134.35 12384.35 I 12584.35 112800.00 Survey MD ft 11208.39 11225.00 11245.00 11250.00 11275.00 11300.00 11325.00 11349.35 11350.00 11375.00 11400.00 11424.35 11425.00 11450.00 11475.00 11500.00 11525.00 11550.00 11575.00 11600.00 11625.00 11650.00 11675.00 11684.35 11700.00 11725.00 11750.00 11775.00 11800.00 11825.00 11850.00 11875.00 11900.00 11925.00 11934.35 11950.00 . ..-.-., .. -,.-... _.,.,,--'.-..~.- Ind deg 47.95 47.97 49.68 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 Inel deg 47.95 47.97 49.68 51.59 61.18 70.84 80.54 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 Azim deg 3.78 3.69 2.96 351.09 321.09 282.09 319.59 289.59 327.09 297.09 329.44 . "'_"_'_b'U _._..._......_. Azim deg 3.78 3.69 2.96 2.17 358.76 355.92 353.40 351.09 350.83 340.83 330.83 321.09 320.99 317.24 31.3.49 309.74 305.99 302.24 298A9 294.74 290.99 287.24 283.49 282.09 284.44 288.19 291.94 295.69 299.44 303.19 306.94 310.69 314.44 318.19 319.59 317.24 . ",,,.,,..,,,,,...,-..-.. ".,,- Ða't~:·.3/18/2003 '. .... .... Tirne:....J6:44:15 .'. '., . .... Page: 2 (;o..ordinate(~E)Reference: Well:H:27. True North Vertic'alfrYD) Reference: System: Mean Sea Level Section(VS)Ref~rence.:. Well (O.OON.0.00E,312.0QAzi) . .._.._. ...._,......_..__....._.._.,.__._~~_~~~_~.~~~.!.I.~~~_~~~~~~~,:._......~i.~ì.~~f!1..9.~~~~~.~:_....._... ..... .~~.:......<?~.~9~:__.._ ... ..·.1 __......._",,".'..__.'._ .", "..... .._...___.......·..__,.........."._....-...._._..u.. .~..".. . _.".~. _.. .." Date Composed: Version: Tied-to: 3/18/2003 3 From: Definitive Path -. .- -. - -- --- ---_.- .. -. --... -- - -- -. .-- --- -. -- -----. -.--..- - - .-.." --- - ... ".- -- ..- TVD +N/-S +E/-W ft ft ft ..,' ......' _....., u_', w." _ C,.., ......,.........~ .........",.';....._ ~....,_. .._~.;, ",'_..;.....___ ~.:.._."...,_:_... .,,'~ 8909.99 5859.39 159.24 8921.11 5871.70 160.05 8934.28 5886.73 160.92 8969.61 5982.26 154.61 8969.61 6050.05 124.56 8969.61 6183.63 -92.67 8969.61 6309.51 -303.51 8969.61 6421.75 -466.29 8969.61 6574.07 -658.90 8969.61 6706.60 -805.63 8969.61 6852.44 -960.59 DLS Build Turn deg/100ft deg/100ft deg/100ft . "--~".'"'~''' ......'... "......,.,...- ~ '"''''''._'''~''''''-'-~-''- .-......"--.-....".,,...,-... .. ~".,,"-"... 0.00 0.00 0.00 0.42 0.12 -0.54 9.00 8.57 -3.65 40.00 38.64 -11.38 40.00 0.00 -40.00 15.00 0.00 -15.00 15.00 0.00 15.00 15.00 0.00 -15.00 15.00 0.00 15.00 15.00 0.00 -15.00 15.00 0.00 15.00 TFO deg 0.00 286.63 342.00 342.00 270.00 270.00 90.00 270.00 90.00 270.00 90.00 . - ---.---- -- Target . . . ... __..__.. __..~._. ___...__...._~_.._...._..__.__._..__.. ..... ._.____...._ .__ ._.._ ..__ .... _Ø'd'U' __...... ___.._._._h.'_ ..._. _.... _'hU'_' _..... ._..._ _...._...__... ......__....... ....._... _.... SSTVD ft ~. .-,." '" ,. .. ......,. ....."...,,~ 8909.99 8921.11 8934.28 8937.45 8951.28 N/S E/W ft ft _ .:._.. ".,_ ".. __.·....h ;,:_..".~. .:.....:. ~.. .:~...:..,~...,""..~._,¡;",,:.... .. ,.....'.".. '... ,,_:~" 5859.39 159.24 5871.70 160.05 5886.73 160.92 5890.59 161.09 5911.38 161.22 MapN MapE VS DLS TFO ;.. . ......,..,.~.._"_. ."......c,..,.._....".~..",......,. ,,".., . .......... ~,_._. ...". ._.~:~!~.~.o~...,..~.:~_._.. 5966209.91 642882.83 3802.36 0.00 0.00 5966222.23 642883.40 3810.00 0.42 286.63 5966237.27 642883.99 3819.40 9.00 342.00 5966241.13 642884.09 3821.86 40.00 342.00 5966261.92 642883.83 3835.67 40.00 342.50 TIP KOP 3 MWD MWD 8961.43 8967.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 5934.16 5958.25 5982.27 5982.91 6007.12 6029.90 6050.05 6050.55 6069.45 6087.24 6103.84 6119.18 6133.20 6145.84 6157.03 6166.75 6174.93 6181.56 6183.63 6187.22 6194.24 6202.81 6212.90 6224.47 6237.46 6251.82 6267.48 6284.39 6302.46 6309.51 6321.21 160.14 157.88 154.61 154.51 148.39 138.17 124.56 124.15 107.79 90.23 71.54 51.81 31.11 9.54 -12.80 -35.83 -59.45 -83.55 -92.67 -107.90 -131.89 -155.37 -178.24 -200.40 -221.75 -242.21 -261.69 -280.10 -297.36 -303.51 -313.90 5966284.68 5966308.72 5966332.66 5966333.30 5966357.39 5966379.97 5966399.86 5966400.36 5966418.94 5966436.39 5966452.63 5966467.59 5966481.21 5966493.44 5966504.21 5966513.48 5966521.21 5966527.38 5966529.27 5966532.57 5966539.13 5966547.26 5966556.91 5966568.06 5966580.64 5966594.60 5966609.89 5966626.45 5966644.19 5966651.11 5966662.62 642882.31 642879.60 642875.87 642875.75 642869.18 642858.53 642844.53 642844.11 642827.40 642809.50 642790.51 642770.49 642749.53 642727.73 642705.18 642681.97 642658.20 642633.98 642624.83 642609.53 642585.41 642561.78 642538.72 642516.35 642494.75 642474.02 642454.26 642435.53 642417.92 642411.64 642401.04 3851.72 3869.52 3888.02 3888.53 3909.27 3932.11 3955.71 3956.35 3981.15 4006.11 4031.10 4056.03 4080.79 4105.27 4129.37 4152.99 4176.02 4198.36 4206.52 4220.24 4242.77 4265.95 4289.70 4313.90 4338.47 4363.28 4388.24 4413.23 4438.16 4447.44 4462.99 40.00 40.00 40.00 40.09 40.00 40.00 40.00 15.03 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 - n' ____..._._ ..___....._ Tool 344.40 MWD 345.56 MWD 346.18 4 270.00 MWD 270.00 MWD 270.00 MWD 270.00 5 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 6 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 7 270.00 MWD bp " .,. ." _. . _,,_._,_. _~ 0" _ .,.__."."".' _"_._~._ _ _ .__,"""__ ..~~.__...._ .... Company: BPAmoco Field: Prudhoe Bay Site: PB H Pad Well: H-27 Wellpatb: Plan#4 H-27 A Survey MD ft 11975.00 12000.00 12025.00 12050.00 12075.00 12100.00 12125.00 12134.35 12150.00 12175.00 12200.00 12225.00 12250.00 12275.00 12300.00 12325.00 12350.00 12375.00 12384.35 12400.00 12425.00 12450.00 12475.00 12500.00 12525.00 12550.00 12575.00 12584.35 12600.00 12625.00 12650.00 12675.00 12700.00 12725.00 ~750.00 }~775.00 12800.00 Inel deg 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 90.00 Azlm deg 313.49 309.74 305.99 302.24 298.49 294.74 290.99 289.59 291.94 295.69 299.44 303.19 306.94 310.69 314.44 318.19 321.94 325.69 327.09 324.74 320.99 317.24 313.49 309.74 305.99 302.24 298.49 297.09 299.44 303.19 306.94 310.69 314.44 318.19 321.94 325.69 329.44 ) BP ') Bh.Ker Hughes INTEQ Planning Report ...1 -=.:. .,,"""",,·,,·',".""'·..","'"",,"."'"'''''''i''''''''''''....~.''''''''' ~N'''rEQ __'. .' _._~~~_"' __. "___...__._..,_.__",__.._"__~__,__, _.._..._..______,_ _____~_.'__.__n"_____"_. _.~_.,.~__.__"__....__...._ ____,,____ _,__.__,__~..._~_"_,_"..~_.. .".____._ ._"_,___,___.._._.. _._._"..._._. .........__...._ .. ..........."....".,._.. .. Date: ..... .3/18/2003 '. .... . .... . . ....Time: "·16:44:15 Page: 3 Co..e,ndinate(NE) Refereo.ce: . Wen: H-27, True North 'Vertical (TVD) Reference: . System: Mean Sea tevel Section (VS)Reference: Well(0~OON,O.00E,312.00Azi) ........ ...._..~~~~~.Eal~~!~!,~~~_~~!.~,~~~..____. ...~.i.n.!~~~__~U~~~~!~_._ .....,.... .~~_~._Oracle .' ... -" ..._-" '.. ,..,._,."-~~.._..."...~.....,,,.._.._.,..,~,-~, .. ..-."~'.-"._.."."..,,,.._'..~.,_. SSTVD ft 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 8969.61 N/S ft 6339.00 6355.60 6370.94 6384.96 6397.60 6408.79 6418.51 6421.75 6427.30 6437.39 6448.95 6461.94 6476.30 6491.97 6508.87 6526.95 6546.11 6566.29 6574.07 6587.03 6606.96 6625.86 6643.65 6660.25 6675.59 6689.61 6702.24 6706.60 6714.01 6727.00 6741.36 6757.03 6773.93 6792.01 6811.17 6831.35 6852.44 E/W ft -331.46 -350.15 -369.88 -390.57 -412.14 -434.49 -457.52 -466.29 -480.92 -503.79 -525.95 -547.30 -567.76 -587.24 -605.65 -622.92 -638.96 -653.72 -658.90 -667.67 -682.76 -699.12 -716.68 -735.36 -755.10 -775.79 -797.36 -805.63 -819.41 -840.77 -861.23 -880.70 -899.11 -916.38 -932.43 -947.19 -960.59 .~ _''''_.'''... .,~ _.",,_._.~..,..._ ."......_..._'._..___..,... ....____._-...... _ _~~._,_ ...........,. ",_ .un ...... ....._ _..~._ ~"'_' __';".' ".........,,_.. u_". ,~. _...,". . 5966680.07 5966696.31 5966711.27 5966724.89 4487.94 4512.94 4537.87 4562.63 5966737.12 5966747.89 5966757.16 5966760.23 5966765.50 5966775.16 5966786.30 5966798.88 5966812.84 5966828.14 5966844.69 5966862.43 5966881.28 5966901.17 5966908.86 5966921.65 5966941.28 5966959.87 5966977.31 5966993.55 5967008.52 5967022.14 5967034.36 5967038.56 5967045.71 5967058.29 5967072.26 5967087.55 5967104.10 5967121.84 5967140.70 5967160.59 5967181.42 642301.37 642278.81 642255.60 642246.78 642232.04 642208.99 642186.61 642165.02 642144.29 642124.52 642105.79 642088.19 642071.78 642056.64 642051.32 642042.31 642026.84 642010.13 641992.23 641973.24 641953.22 641932.26 641910.46 641902.11 641888.19 641866.59 641845.86 641826.09 641807.37 641789.76 641773.36 641758.22 641744.41 4587.11 4611.21 4634.82 4643.51 4658.09 4681.84 4706.05 4730.61 4755.42 4780.38 4805.37 4830.30 4855.05 4879.51 4888.57 4903.76 4928.31 4953.11 4978.06 5003.06 5027.99 5052.75 5077.23 5086.29 5101.49 5126.06 5150.87 5175.82 5200.82 5225.74 5250.49 5274.96 5299.04 D.LS degl100ft 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 15.00 TFO deg 270.00 270.00 270.00 270.00 Tool MWD MWD MWD MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 8 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 9 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 MWD 270.00 10 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 MWD 90.00 TD ') BOP-Tree ') . Rig Floor Lubricator ID = 6.375" with 6" Otis Unions /(71/16" 5000 psi BOP's. ID = 7.06" 1/16" 5000 psi, RX-46 I ~ I 13" 5000 psi I . Swab Valve I -+ SSV I Master Valve I Base Flanue I Page 1 P 055035 DATE INVOICE / CREDIT MEMO DESCRIPTION DATE 3/12/2003 CHECK NO. 055035 , 3/12/2003 INV# CK030603H / GROSS VENDOR DISCOUNT RECEjVED APR ) 3 Z003 Ataika Œt & G~ Cons. Ccmmbsion A:r::;;"f.~ THE ATTACHED CHECK IS IN PAYMENT FOR ITEMS DeSCRIBED ABOVE. BP EXPLORATION, (ALASKA) INC. PRUDHOE BAY UNIT PO BOX 196612 ANCHORAGE, AK99519-6612 PAY: TO THE ORDER OF: :. B'·· .f?..., r; """Z'" 'm'··!ffI.. '-"'--"11. .............. .............:...... .,¡,'t... ......... rJ.........·..'..........:..... L. ¡!4.........~...... """'.'.,.11.. .... · ". .. .. :.I..J \n.. It,... ·.u'.'" m.... 7#,,, - - . - . ~ - . - .". ". . - ":..." ";:. ":. -.' ".- _'.U "': .:'". _q_'_' . " --',' - " -- - . .-. --- - : ".".,". "-'-.- "."--;..-.. .".".0,- .. . ............... .... ........ .. .. . .... '.. ...-.. .. -~ - -' . -'...- -- -. . .": :'. - - .':': :. - - .' - -:"'"'- - - -:-:~ - -. ALA1';KA OIL &\Ü",S C@NS~~\Ç4T/O~ CrøJiWi!/S$IOMi 333 W 7TH AVENtiJE .... .'. SUITE 100 ANCHORAGE, AI< 99501-3539 PERMIT TO DRILL NET ~-tJ-~Pr '.! NATIONAL CITY BANK Ashland, Ohio 56-389 412 No.p 055035 CONSOLIDATED COMMERCIAL ACCOUNT '. '." '-- ..-.- .' DATE' \/Ma.. t.€.:h t.Z;~'200a - --. -. -- - - AMOUNT i~ **~M;*$'100.00******* -:\:-L- NÒi:\¡A~'~~~:¡·~~~~y¡.t:~~~~~t5.¡:/;{\\t ...... \:~~~:~~.......~,...... ...... ..' . ~~~;:f.:t0fi~~1j~¡~i:;~;;;~~;f:~~ ~ - "- 11·0 5 SO 3 511· ':0.. * 20 3B c¡ 51: 0 * 2 ?B c¡ 1;11. H ~,;=" ---- Rev: 07/10/02 ajody\templates J ') TRANSMIT AL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME PTD# ,CHECK WHAT APPLIES ADD-ONS (OPTIONS) MULTI LATERAL (H API number last two (2) digits are between 60-69) paOT (PH) "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). SPACING EXCEPTION DRY DITCH SAMPLE The permit is approved subject to full compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing exception that may occur. All dry ditch sample sets submitted to the Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. WELL PERMIT CHECKLIST COMPANY .ðP)¿ WELL NAMEr..ll:l 11-,2 7A FIELD & POOL 6 7'ó/ J' ð INIT CLASS O~¿./ /-n"ï ADMINISTRATION 1. Permittee attached. . . . . . . . . . . . . . . . . . . . '.' . 0 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 8. If deviated, is wellbore plat included.. . . . . . . . . . . . . . Y N 9. Operator only affected party.. . . . . . . . . . . . . . . . . . Y N 10. Operator has appropriate bond in force. . . . . . . . . . . . . Y N 11. Permit can be issued without conservation order. . . . . . . . Y N 12. Permit can be issued without administrative approval.. . . . . ~y N (Service Well Only) 13. Well located w/in area & strata authorized by injection order #_ Y A/. -11. (Service Well Only) 14. All wells wlin ~ mile area of review identified. . . . . . . . .. N ENGINEERING 15. Conductor string provided. . . . . . . . . . . . . . . . . . . Y N 16. Surface casing protects all known USDWs. . . . . . . . . . Y N 17. CMT vol adequate to circulate on conductor & surf csg. . . . .V---N- /JIlt- 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 . 21. Adequate tankage or reserve pit.. . . . . . .. . . . . . . . . ., N C 'ÍTD v.-. . 22. If a re-drill, has a 10-403 for abandonment been approved. . . N tj (~l 0 ~ , 23. Adequate wellbore separation proposed.. . . . . . . . . . . . ,N 24. If diverter required, does it meet regulations. . . . . . . . . . -¥=-No Ai/It- 25. Drilling fluid program schematic & equip list adequate. . . . . .. N M-'LA/.. flI//IJ f·7 P f1 . 26. BOPEs, do they meet regulation. . . . . . . . . . . . . . . . N J 11 f) '7 tIt 27. BOPE press rating appropriate; testto 35" 00 psig. N 1\.1'(.. t;. I' (,..-0 -%'t ?( {¡ '. 28. Choke manifold complies w/API RP-53 (May 84). . . . . . . . N 29. Work will occur without operation shutdown. . . . . . . . . . . N , 30. Is presence of H2S gas probable.. . . . . . . . . . . . . . . . . N YU. ~ It\. Ç. I ~O pplAA.. . 31. Mechanical condition of wells within AOR verified. . . . . . . . --¥-N-IÚ/A- Y@ ¡r jU.A. RESERVOIR ENGINEERING APPR DATE £I¿ ~3 APPR DATE \iJ~ L4-17/ ~ ~ (Service Well Only) GEOLOGY APPR DATE A'I. ~Þ4J (Exploratory Only) Rev: 2/25/03 \wellj)erm it_checklist PROGRAM: Exp _ Dev.J( Redrll -X. Re-Enter _ Serv _ Well bore seg _ GEOL AREA ç-j~ /I~,~ð ON/OFF SHORE ðN UNIT# 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. ...... (' GEOLOGY: RP~ PETROLEUM ENGINEERING: UIC ENGINEER JR COMMISSIONER: SP y¥,'<; RR ;/' DSOtJo~/o~ Comments/lnstructions: JH TM SFD_ WA /' MW ) ) Well History File APPENDIX Infornlation of detailed nature that is not particularly germane to the Well Pennitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information. infomlation of this nature is accumulated at the end of the file under APPEN.DIX. No special effort has been made to chronologically organize this category of information. 'r ) ) ~3-0c;:;q (1 80~ Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Wed Jul 09 09:36:15 2003 Reel Header Service name........... ..LISTPE Da te . . . . . . . . . . . . . . . . . . . . . 03/07/09 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 Da te . . . . . . . . . . . . . . . . . . . . . 03/07/09 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 MWD/MAD LOGS # WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: # JOB DATA H-27A 500292145601 BP Exploration (Alaska) Inc. Sperry-Sun Drilling Services 09-JUL-03 JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 1 MW0002419293 S. LATZ SARBER/WHITL MWD RUN 2 MW0002419293 S. LATZ SARBER/WHITL MWD RUN 4 MW0002419293 S. LATZ SARBER/WHITL JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 5 MW0002419293 S. LATZ SARBER/WHITL MWD RUN 6 MW0002419293 N. WHITE G. SARBER / MWD RUN 7 MW0002419293 B. JAHN G. SARBER / JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: MWD RUN 8 MW0002419293 B. JAHN R. WHITLOW / # ) ) SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION (FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: 21 11N 13E 430 1735 72.50 .00 42.90 # WELL CASING RECORD 1ST STRING 2ND STRING 3RD STRING PRODUCTION STRING OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 4.125 5.500 10242.0 3.750 5.500 10242.0 # REMARKS: 1. ALL DEPTHS ARE MEASURED DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE BIT DEPTHS. 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTHS - SUBSEA (TVDSS) . 3. WELL KICKED OFF FROM H-27 WITH TOP OF WHIPSTOCK SET AT ABOUT 11248' MD, 8932' TVDSS. 4. MWD RUNS 1 - 2 WERE DIRECTIONAL WITH GAMMA MODULE (GM) UTILIZING GEIGER-MUELLER TUBE DETECTORS. 5. MWD RUN 3 WAS DIRECTIONAL WITH GM AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). NO FOOTAGE WAS DRILLED. A MAD PASS WAS PERFORMED WHILE POOH ACROSS THE MWD RUN 2 INTERVAL, (EWR4 SENSOR DEPTHS 11230' - 114431) THESE EWR4 DATA ARE INCLUDED WITH THE RUN 2 DATA. 6. MWD RUN 4 WAS DIRECTIONAL WITH GM. 7. MWD RUNS 5 - 8 WERE DIRECTIONAL WITH GM AND EWR4. A MAD PASS WAS PERFORMED ACROSS THE EWR4 SENSOR DEPTHS 11444' - 11618' . THESE EWR4 DATA ARE INCLUDED WITH THE RUN 4 DATA. 8. DIGITAL AND LOG DATA (LDWG) ONLY ARE DEPTH SHIFTED TO THE PDC GR LOG, (SCHLUMBERGER MCNL LOG RUN 9 MAY 2003) PER 2 JULY 2003 E-MAIL FROM D. SCHNORR (BP EXPLORATION). HEADER AND RUN INFORMATION DATA ) ) RETAIN ORIGINAL DRILLER'S DEPTH REFERENCE. 9. MWD RUNS 1, 2 AND 4 - 8 REPRESENT WELL H-27A, API # 50-029-21456-01. THIS WELL REACHED A TOTAL DEPTH (TD) OF 12823'MD / 8980'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED (GEIGER-MUELLER TUBE DETECTORS) SEXP = SMOOTHED PHASE SHALLOW SPACING) SESP = SMOOTHED PHASE SPACING) SEMP = SMOOTHED PHASE SPACING) SEDP = SMOOTHED PHASE SPACING) SFXE = SMOOTHED FORMATION EXPOSURE TIME $ SHIFT DERIVED RESISTIVITY (EXTRA SHIFT DERIVED RESISTIVITY ( SHALLOW SHIFT DERIVED RESISTIVITY (MEDIUM SHIFT DERIVED RESISTIVITY (DEEP File Header Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 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 SGRC SEDP SEMP SESP SEXP SFXE SROP $ 1 and clipped curves; all bit runs merged. .5000 START DEPTH 10861.0 11227.5 11227.5 11227.5 11227.5 11244.0 11249.0 STOP DEPTH 12779.5 12793.0 12793.0 12793.0 12793.0 12793.0 12825.0 # BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH --------- BASELINE DEPTH 10861.0 10861.5 10867.5 10872.5 10875.0 10880.5 10884.5 11221.0 11225.5 GR 10862.0 10862.5 10867.0 10873.5 10876.5 10881.0 10883.5 11222.0 11228.0 11229.0 11231.0 11236.5 11242.0 11247.5 11254.0 11262.5 11284.0 11297.5 11303.5 11319.5 11336.5 11363.5 11384.5 11402.0 11428.0 11450.5 11453.0 11460.0 11469.0 11479.0 11494.5 11502.0 11540.0 11574.0 11625.0 11686.5 11712.5 11734.5 11746.0 11754.5 11773.0 11794.5 11802.5 11821.5 11824.5 11832.0 11834.0 11837.0 11847.5 11851.0 11855.5 11861.5 11875.0 11903.5 11919.0 11924.5 11937.5 11978.5 11988.5 11991.5 11996.5 12012.0 12095.0 12128.5 12138.5 12149.5 12191.5 12207.0 12245.5 12268.5 ) ) 11231.5 11233.5 11237.0 11242.0 11247.0 11253.0 11262.5 11283.5 11297.5 11305.5 11320.5 11337.0 11365.5 11389.0 11406.5 11428.5 11450.5 11451.5 11458.5 11470.5 11480.5 11494.0 11501.0 11541.0 11577.0 11628.0 11690.5 11714.5 11736.5 11747.5 11755.5 11773.5 11796.5 11805.0 11828.5 11831.5 11840.5 11842.0 11845.0 11855.5 11857.0 11861.5 11867.0 11883.5 11911.5 11928.0 11933.0 11945.0 11987.0 11997.0 12000.0 12004.5 12017.5 12103.0 12135.5 12145.0 12154.5 12193.0 12209.5 12247.5 12272.5 12304.0 12314.0 12329.5 12385.5 12388.5 12509.0 12514.5 12543.5 12561.0 12634.5 12642.5 12655.5 12691.0 12720.0 12825.0 $ # MERGED DATA SOURCE PBU TOOL CODE MWD MWD MWD MWD MWD MWD MWD $ # REMARKS: ) 12308.5 12316.5 12331.0 12386.0 12388.5 12509.0 12514.0 12546.5 12562.5 12637.5 12644.0 12655.5 12692.5 12719.0 12824.0 BIT RUN NO 1 2 4 5 6 7 8 MERGED MAIN PASS. $ ') MERGE TOP 10862.0 11230.0 11444.0 11590.0 11925.0 12145.0 12608.0 MERGE BASE 11295.5 11474.5 11645.0 11968.0 12191.0 12653.0 12824.0 # 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 Last Name Service Unit Reading DEPT FT 12825 Min 10861 First Max Mean Nsam Reading 12825 11843 3929 10861 ) ) ROP MWD FT/H 0.3 1609.42 67.7278 3153 11249 12825 GR MWD API 14.98 426.35 27.3997 3173 10861 12779.5 RPX MWD OHMM 0.29 42.33 11.3415 3132 11227.5 12793 RPS MWD OHMM 2.28 337.62 14.2578 3132 11227.5 12793 RPM MWD OHMM 1.3 2000 26.7071 3132 11227.5 12793 RPD MWD OHMM 2.71 2000 22.3042 3132 11227.5 12793 FET MWD HOUR 0.29 25.21 4.84925 3099 11244 12793 First Reading For Entire File......... .10861 Last Reading For Entire File.......... .12825 File Trailer Service name............ .STSLIB.001 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 Maximum Physical Record. .65535 F i 1 e 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...... .03/07/09 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 SGRC SROP $ 2 header data for each bit run in separate files. 1 .5000 START DEPTH 10862.0 11248.5 STOP DEPTH 11269.5 11295.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: 03-MAY-03 Insite 4.3 ) 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 GM Dual GR $ # 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 Name Service Order DEPT ROP MWD010 GR MWD010 ') Memory 11296.0 11248.0 11296.0 48.0 61.9 TOOL NUMBER 82758 4.125 10242.0 Flo Pro 8.60 65.0 10.0 20000 7.4 .000 .000 .000 .000 .0 145.0 .0 .0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 API 4 1 68 8 3 ) " ) First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 10862 11295.5 11078.8 868 10862 11295.5 ROP MWD010 FT/H 0.3 69.69 15.4831 95 11248.5 11295.5 GR MWDOI0 API 16.25 426.35 39.3484 147 10862 11269.5 First Reading For Entire File......... .10862 Last Reading For Entire File.......... .11295.5 File Trailer Service name............ .STSLIB.002 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 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...... .03/07/09 Maximum Physical Record. .65535 File Type................ LO Previous File Name...... .STSLIB.002 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE SEMP SESP SEDP SEXP SFXE SGRC SROP $ 3 header data for each bit run in separate files. 2 .5000 START DEPTH 11230.0 11230.0 11230.0 11230.0 11244.0 11270.0 11296.0 STOP DEPTH 11443.5 11443.5 11443.5 11443.5 11443.5 11447.5 11474.5 # LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: 04-MAY-03 Insite \) 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 GOO Dual GR $ # 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. ..0 \) 4.3 Memory 11475.0 11296.0 11475.0 48.0 93.9 TOOL NUMBER 82758 4.125 10242.0 Flo Pro 8.60 65.0 10.0 20000 7.0 .000 .000 .000 .000 .0 162.6 .0 .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 11230 11474.5 11352.3 490 11230 11474.5 ROP MWD020 FT/H 1 241.45 56.0267 358 11296 11474.5 GR MWD020 API 15.13 39.96 24.8253 356 11270 11447.5 RPX MWD020 OHMM 0.29 11.36 6.26327 428 11230 11443.5 RPS MWD020 OHMM 2.28 337.62 11.2064 428 11230 11443.5 RPM MWD020 OHMM 1.3 2000 77.4728 428 11230 11443.5 RPD MWD020 OHMM 2.71 2000 44.8026 428 11230 11443.5 FET MWD020 HOUR 8.18 25.13 14.6633 400 11244 11443.5 First Reading For Entire File......... .11230 Last Reading For Entire File.......... .11474.5 File Trailer Service name............ .STSLIB.003 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 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...... .03/07/09 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.003 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: 4 header data for each bit run in separate files. 4 .5000 ) # FILE SUMMARY VENDOR TOOL CODE SFXE SEDP SEMP SESP SEXP SGRC SROP $ START DEPTH 11444.0 11444.0 11444.0 11444.0 11444.0 11448.0 11475.0 STOP DEPTH 11618.0 11618.0 11618.0 11618.0 11618.0 11618.0 11645.0 # 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) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # 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 ') 04-MAY-03 Insite 4.3 Memory 11645.0 11475.0 11645.0 85.6 89.0 TOOL NUMBER 82758 3.750 10242.0 Flo Pro 8.60 65.0 10.0 20000 7.4 .000 .000 .000 .000 .0 159.0 .0 .0 ) ) 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 MWD040 FT/H 4 1 68 4 2 GR MWD040 API 4 1 68 8 3 RPX MWD040 OHMM 4 1 68 12 4 RPS MWD040 OHMM 4 1 68 16 5 RPM MWD040 OHMM 4 1 68 20 6 RPD MWD040 OHMM 4 1 68 24 7 FET MWD040 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11444 11645 11544.5 403 11444 11645 ROP MWD040 FT/H 0.51 122.31 67.6218 341 11475 11645 GR MWD040 API 18.8 133.24 36.8298 341 11448 11618 RPX MWD040 OHMM 4.71 23.51 12.1818 349 11444 11618 RPS MWD040 OHMM 5.78 26.37 14.9076 349 11444 11618 RPM MWD040 OHMM 6.97 29.1 16.7469 349 11444 11618 RPD MWD040 OHMM 10.76 27.83 18.5184 349 11444 11618 FET MWD040 HOUR 7.3 25.21 12.0144 349 11444 11618 First Reading For Entire File......... .11444 Last Reading For Entire File.......... .11645 File Trailer Service name............ .STSLIB.004 Service Sub Level Name... Version Number......... ..1.0.0 Date of Generation...... .03/07/09 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...... .03/07/09 Maximum Physical Record. .65535 F i 1 e 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 SFXE SEXP SEDP SEMP SGRC SESP SROP $ 5 header data for each bit run in separate files. 5 .5000 START DEPTH 11590.0 11618.5 11618.5 11618.5 11618.5 11618.5 11645.5 STOP DEPTH 11937.5 11937.5 11937.5 11937.5 11924.5 11937.5 11968.0 # 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: 05-MAY-03 Insite 4.3 Memory 11968.0 11645.0 11968.0 88.5 92.8 # TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ TOOL NUMBER 93091 # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER'S CASING DEPTH (FT): 3.750 10242.0 # BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: Flo Pro 8.60 65.0 9.0 20000 6.8 .180 .080 70.0 164.8 ) ) MUD FILTRATE AT MT: MUD CAKE AT MT: .320 .520 70.0 70.0 # 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 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11590 11968 11779 757 11590 11968 ROP MWD050 FT/H 0.38 247.78 59.0206 646 11645.5 11968 GR MWD050 API 15.84 37.86 24.6033 613 11618.5 11924.5 RPX MWD050 OHMM 3.88 25.79 11.7286 639 11618.5 11937.5 RPS MWD050 OHMM 5.62 29.64 14.432 639 11618.5 11937.5 RPM MWD050 OHMM 6.59 32.15 15.9771 639 11618.5 11937.5 RPD MWD050 OHMM 10.55 28.56 16.7895 639 11618.5 11937.5 FET MWD050 HOUR 0.5 8.49 1.88835 659 11590 11937.5 First Reading For Entire File......... .11590 ) ) Last Reading For Entire File.......... .11968 File Trailer Service name............ .STSLIB.005 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 Maximum Physical Record..65535 File 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..... ..03/07/09 Maximum Physical Record. .65535 File 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 SGRC SEMP SESP SEDP SFXE SEXP SROP $ 6 header data for each bit run in separate files. 6 .5000 START DEPTH 11925.0 11938.0 11938.0 11938.0 11938.0 11938.0 11968.5 # 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 GM Dual GR STOP DEPTH 12144.5 12159.5 12159.0 12159.5 12159.0 12159.0 12191.0 06-MAY-03 Insite 4.3 Memory 12190.0 11968.0 12190.0 87.8 90.9 TOOL NUMBER 93091 ) $ # 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 ) 3.750 10242.0 Flo Pro 8.60 65.0 9.0 20000 6.8 .180 .080 .320 .520 70.0 165.0 70.0 70.0 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 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11925 12191 12058 533 11925 12191 ROP MWD060 FT/H 0.39 583.28 78.7933 446 11968.5 ) ) 12191 GR MWD060 API 18.04 33.4 25.21 440 11925 12144.5 RPX MWD060 OHMM 7.21 23.24 13.3736 443 11938 12159 RPS MWD060 OHMM 8.81 26.95 16.3269 443 11938 12159 RPM MWD060 OHMM 9.73 28.27 17.9351 444 11938 12159.5 RPD MWD060 OHMM 14.63 26.41 19.7891 444 11938 12159.5 FET MWD060 HOUR 0.29 9.25 2.39481 443 11938 12159 First Reading For Entire File......... .11925 Last Reading For Entire File.......... .12191 File Trailer Service name............ .STSLIB.006 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 Maximum Physical Record. .65535 F i 1 e Type................ LO Next File Name.......... .STSLIB.007 Physical EOF File Header Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 Maximum Physical Record. .65535 F i 1 e Type................ LO Previous File Name...... .STSLIB.006 Comment Record FILE HEADER FILE NUMBER: RAW MWD Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE SGRC SEXP SESP SFXE SEDP SEMP SROP $ 7 header data for each bit run in separate files. 7 .5000 START DEPTH 12145.0 12159.5 12159.5 12159.5 12160.0 12160.0 12191.5 STOP DEPTH 12607.5 12621.5 12621.5 12621.5 12621.5 12621.5 12653.0 # 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) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # 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 Uni t s . . . . . . . . . . . . . . . . . . . . . . . Datum Specification Block sub-type...O Name Service Order DEPT ROP MWD070 ) 07-MAY-03 Insite 4.3 Memory 12653.0 12190.0 12653.0 85.6 92.7 TOOL NUMBER 93091 3.750 10242.0 Flo Pro 8.60 65.0 9.0 21000 .0 .120 .050 .220 .200 70.0 173.6 70.0 70.0 Units Size Nsam Rep Code Offset Channel FT 4 1 68 0 1 FT/H 4 1 68 4 2 ) I '\ GR MWD070 API 4 1 68 8 3 RPX MWD070 OHMM 4 1 68 12 4 RPS MWD070 OHMM 4 1 68 16 5 RPM MWD070 OHMM 4 1 68 20 6 RPD MWD070 OHMM 4 1 68 24 7 FET MWD070 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12145 12653 12399 1017 12145 12653 ROP MWD070 FT/H 0.73 722.07 71.4841 924 12191.5 12653 GR MWD070 API 16.51 57.4 25.781 926 12145 12607.5 RPX MWD070 OHMM 4.02 27.12 11.6067 925 12159.5 12621.5 RPS MWD070 OHMM 4.41 27.07 13.5932 925 12159.5 12621.5 RPM MWD070 OHMM 4.71 29.58 14.4814 924 12160 12621.5 RPD MWD070 OHMM 6.45 23.3 14.7352 924 12160 12621.5 FET MWD070 HOUR 0.3 8.44 1.80749 925 12159.5 12621.5 First Reading For Entire File......... .12145 Last Reading For Entire File.......... .12653 File Trailer Service name............ .STSLIB.007 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 Maximum Physical Record. .65535 File Type............ ... .LO Next File Name.......... .STSLIB.008 Physical EOF File Header Service name............ .STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 Maximum Physical Record. .65535 File Type............... .LO Previous File Name...... .STSLIB.007 Comment Record FILE HEADER FILE NUMBER: 8 RAW MWD ) )' ) header data for each bit run in separate files. 8 .5000 Curves and log BIT RUN NUMBER: DEPTH INCREMENT: # FILE SUMMARY VENDOR TOOL CODE SGRC SEDP SEMP SESP SEXP SFXE SROP $ START DEPTH 12608.0 12622.0 12622.0 12622.0 12622.0 12622.0 12653.5 STOP DEPTH 12778.5 12792.0 12792.0 12792.0 12792.0 12792.0 12824.0 # 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) VENDOR TOOL CODE TOOL TYPE GM Dual GR $ # 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: $ 08-MAY-03 Insite 4.3 Memory 12823.0 12653.0 12823.0 88.1 93.2 TOOL NUMBER 93091 3.750 10242.0 Flo Pro 8.70 65.0 9.0 21000 8.4 .120 .050 .220 .200 70.0 169.6 70.0 70.0 '\ ) ') # 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 MWD080 FT/H 4 1 68 4 2 GR MWD080 API 4 1 68 8 3 RPX MWD080 OHMM 4 1 68 12 4 RPS MWD080 OHMM 4 1 68 16 5 RPM MWD080 OHMM 4 1 68 20 6 RPD MWD080 OHMM 4 1 68 24 7 FET MWD080 HOUR 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 12608 12824 12716 433 12608 12824 ROP MWD080 FT/H 4.25 1609.42 88.5997 342 12653.5 12824 GR MWD080 API 14.98 35.09 26.1115 342 12608 12778.5 RPX MWD080 OHMM 4.14 42.33 12.6215 341 12622 12792 RPS MWD080 OHMM 4.74 37 13.9423 341 12622 12792 RPM MWD080 OHMM 5.3 35.2 14.5673 341 12622 12792 RPD MWD080 OHMM 7.89 26.61 14.5165 341 12622 12792 FET MWD080 HOUR 0.39 16.02 3.37513 341 12622 12792 First Reading For Entire File......... .12608 Last Reading For Entire File.......... .12824 File Trailer Service name........... ..STSLIB.008 Service Sub Level Name... Version Number.......... .1.0.0 Date of Generation...... .03/07/09 Maximum Physical Record. .65535 F i 1 e Typ e . . . . . . . . . . . . . . . . LO Next File Name.......... .STSLIB.009 \ , ') Physical EOF Tape Trailer Service name............ .LISTPE Date. . . . . . . . . . . . . . . . . . . . . 03/07/09 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. . . . . . . . . . . . . . . . . . . . . 03/07 / 0 9 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
