Department of Commerce, Community, and Economic Development
Alaska Oil and Gas Conservation
Commission
HOME
EVENTS
DATA
Data List
Drilling
Production
Orders
Data Miner
Document Search
REPORTS
Reports and Charts
Pool Statistics
FORMS
LINKS
Links
Test Notification
Data Requests
Regulations
Industry Guidance Bulletins
How to Apply
ABOUT US
History
Staff
HELP
Loading...
The URL can be used to link to this page
Your browser does not support the video tag.
Home
My WebLink
About
205-181
STATE OF ALASKA , lik ALASKA OIL AND GAS CONSERVATION COM N WE OMPLETION OR RECOMPLETION RE T AND LOG APR s la. Well Status: Oil 0 Gas 0 SPLUG 0 Other ❑ Abandoned I Suspended 0 1b.Well Class: • 20AAC 25.105 20AAC 25.110 Develop 0- dl GINJ 0 WINJ 0 WAG 0 WDSPL 0 No.of Completions: Zero Service 0 Stratigraphic Test Il 2. Operator Name: 6. Date Comp.,SusR or Aband ) 14.Permit to Drill Number/Sundry BP Exploration(Alaska),Inc 4/7/2018 205-181 • 318-034 3. Address: 7. Date Spudded: 15. API Number: P.O.Box 196612 Anchorage,AK 99519-6612 11/29/2005 50-029-20162-02-00 • 4a. Location of Well(Governmental Section): 8. Date TD Reached: 16. Well Name and Number: 12/3/2005 PBU D-07B • Surface: 2280'FNL,1067'FEL,Sec.23,T11N,R13E,UM. 9 Ref Elevations KB 69.00 •• 17. Field/Pool(s): Top of Productive Interval: 2940'FSL,2607'FEL,Sec.14,T11N,R13E,UM GL 40.50 • BF 40.18. PRUDHOE BAY,PRUDHOE OIL • Total Depth: 2178'FSL,4050'FEL,Sec.14,T11 N,R13E,UM 10. Plug Back Depth(MD/TVD): 18. Property Designation: 12126/9031' ADL 028285 ' 4b. 4b.Location of Well(State Base Plane Coordinates,NAD 27): 11. Total Depth(MD/TVD): 19. DNR Approval Number: Surface:x- 654100' y- 5958721 • Zone - ASP 4 . 13862'/9037' • 91-32 TPI: x- 652449 y- 5963909 Zone - ASP 4 12. SSSV Depth(MD/TVD): 20 Thickness of Permafrost MD/TVD: Total Depth:x- 651022 y- 5963118 Zone - ASP 4 None 1900'(Approx.) 5. Directional or Inclination Survey: Yes ❑ (attached) No Q 13. Water Depth,if Offshore: 21. Re-drill/Lateral Top Window MDfTVD: Submit electronic and printed information per 20 AAC 25.050 N/A (ft MSL) 11862'/8995' 22. Logs Obtained List all logs run and,pursuant to AS 31.05.030 and 20 AAC 25.071,submit all electronic data and printed logs within 90 days of completion, suspension,or abandonment,whichever occurs first.Types of logs to be listed include,but are not limited to:mud log,spontaneous potential,gamma ray,caliper resistivity,porosity,magnetic resonance,dipmeter,formation tester,temperature,cement evaluation,casing collar locator,jewelry,and perforation record. Acronyms may be used.Attach a separate page if necessary MWD,GR,RES,CNL,CCL 23. CASING,LINER AND CEMENTING RECORD CASING Wr.PER GRADE SETTING DEPTH MD SETTING DEPTH TVD HOLE SIZE CEMENTING RECORD MOUNt FT. PULLE TOP BOTTOM TOP BOTTOM 20" 94" H-40 31' 135' 31' 135' 26" 150 sx Arctic Set 13-3/8" 72# N-80 31' 2683' 31' 2683' 18-1/2" 3550 sx Arctic Set 10-3/4"x9-5/8" 55.5#/47# N-eo 29' 9383' 29' 7193' Tieback/12-1/4' 1213 HES Light,200 sx Class'0,300 sx Class'G' 7-5/8" 29.7# NT-95S 9204' 11055' 7098' 8543' 8-1/2" 250 sx Class.G. 5-1/2" 17# L-80 10850' 11862' 8368' 8995' 6-3/4" 94sxClass'G' 3-1/2"x3-3/16" 8.81#/6.2# L-80 11495' 13862' 8851' 9037' 4-1/8" 145 sx Class'G. 766' x2-7/8" /6.16# 24. Open to production or injection? Yes 0 No Il 25. TUBING RECORD If Yes,list each interval open(MDT VD of Top and Bottom;Perforation GRADE DEPTH SET(MD) PACKER SET(MD/TV Size and Number): 4-1/2"12.6#L-80 10847' 10780'/8307' 26. ACID,FRACTURE,CEMENT SQUEEZE,ETC. �(�4inGtO/Le.d . Was hydraulic fracturing used during completion? �, Per 20 AAC 25.283(i)(2)attach electronic and printed Yes 0 No information 1 JUN Z 3.2IM Hfllto DEPTH INTERVAL(MD) AMOUNT AND KIND OF MATERIAL USED 12126' Set Whipstock lll�''��� 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 ...* Flow Tubing Casino Press: Calculated Oil-Bbl: Gas-MCF: Water-Bbl: Oil Gravity-API(cord: Press 24 Hour Rate ter► Form 10-407 Revised 5/2017 CONTINUED ON PAGE 2 Submit ORIGINAL only 1121 RBBMS VI APR ::6 EU18� 6,,/�, 21 CORE DATA • Conventional Core(s) Yes 0 No 0 • Sidewall Cores Yes 0 No I • If Yes to either question,list formations and intervals cored(MD+TVD of top and bottom of each),and summarize lithology and presence of oil,gas or water (submit separate sheets with this form,if needed).Submit detailed descriptions,core chips,photographs and laboratory analytical results per 20 AAC 25.071. 29. GEOLOGIC MARKERS(List all formations and markers encountered): 30. FORMATION TESTS NAME MD TVD Permafrost-Top Well Tested? Yes 0 No 0 Permafrost-Base If yes,list intervals and formations tested,briefly summarizing test results.Attach separate sheets to this form,if needed,and submit detailed test information per 20 Top of Productive Interval 11046' 8535' AAC 25.071. Sag River 10949' 8454' Shublik 10986' 8485' Sadlerochit-Zone 4 11046' 8535' Zone 1B 12090' 9027' Formation at total depth: Zone 1B • 12090' 9027' 31. List of Attachments: Summary of Pre-Rig Work,Summary of Daily Drilling Reports,Wellbore Schematic Diagram Information to be attached includes,but is not limited to:summary of daily operations,wellbore schematic,directional or inclination survey,core analysis, paleontological report,production or well test results,per 20 AAC 25.070. 32.I hereby certify that the foregoing is true and correct to the best of my knowledge. Authorized Name: Lastufka,Joseph N Contact Name: Browning,Zachary H Authorized Title: ecialist I Contact Email: Zachary.Browning@bp.com Authorized Signature: j"\yJ\, [ ,�( Date: 4 12.5/`ea Contact Phone: +1 907 564 5220 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 lb.Well Class Service wells:Gas Injection,Water Injection,Water-Alternating-Gas Injection,Salt Water Disp,Water Supply for Injection,Observation or Other. Item 4b.TPI(Top of Producing Interval). Item 9. The Kelly Bushing and Ground Level elevations in feet above mean sea level.Use same as reference for depth measurements given in other spaces on this form and in any attachments. Item 15.The API number reported to AOGCC must be 14 digits(ex:50-029-20123-00-00). Item 20.Report true vertical thickness of permafrost in Box 20.Provide MD and TVD for the top and base of permafrost in Box 29. Item 22.Review the reporting requirements of 20 AAC 25.071 and,pursuant to AS 31.05.030,submit all electronic data and printed logs within 90 days of completion,suspension,or abandonment,whichever occurs first. Item 23.Attached supplemental records should show the details of any multiple stage cementing and the location of the cementing tool. Item 24.If this well is completed for separate production from more than one interval(multiple completion),so state in item 1,and in item 23 show the producing intervals for only the interval reported in item 26.(Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). Item 27.Method of Operation:Flowing,Gas Lift,Rod Pump,Hydraulic Pump,Submersible,Water Injection,Gas Injection,Shut-in,or Other(explain). Item 28.Provide a listing of intervals cored and the corresponding formations,and a brief description in this box.Submit detailed description and analytical laboratory information required by 20 AAC 25.071. Item 30.Provide a listing of intervals tested and the corresponding formation,and a brief summary in this box.Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Item 31.Pursuant to 20 AAC 25.070,attach to this form:well schematic diagram,summary of daily well operations,directional or inclination survey,and other tests as required including,but not limited to:core analysis,paleontological report,production or well test results. Form 10-407 Revised 5/2017 Submit ORIGINAL Only S Daily Report of Well Operations D-07B ACTIVITYDATE SUMMARY T/I/0=2200/50/520 SI Assist SL as directed (DRLG SCREEN) MIT IA to 2652 psi ***PASSED*** Target pressure=2500 psi Max applied=2750 psi MIT OA to 1138 psi ***PASSED*** Target pressure=1080 psi Max applied=1200 psi Pumped a 1 bbl 60/40 down TBG followed by 265 bbls of crude. Pumped 15.4 bbls crude down IA to achieve test presure of 2750 psi. 15 min loss of 72 psi, 30 min loss of 26 psi, for total loss of 98 psi in 30 mins. Bleed IAP to 50 psi. Bled back 8 bbls. Pumped 12.8 bbls down OA to achieve test pressure of 1200 psi. 15 min loss of 51 psi, 30 min loss of 15 psi, for total loss of 66 psi in 30 mins. Bleed OAP to 250 psi Bled back 2 bbls Tags hung on IA/OA/WV AFE sign hung on _ 12/26/2017 MV***FLUID PACKED WELL*** SL on well upon departure CVs OTG FWHP=80/100/250 ***CONT WSR FROM 12/25/17*** (drlg screen-maint) LRS LOADED TUBING W/265bb1s CRUDE SET 4 1/2" LTTP IN TOP OF LTP @ 10,709' SLM LRS PERFORMED PASSING MIT-IA TO 2653psi (holding 400psi on tubing) LRS PERFORMED PASSING MIT-OA TO 1138psi PULLED 4 1/2" LTTP FROM LTP @ 10,709' SLM PULLED 45KB LTP FROM 10,709' SLM (missing 1 element) RAN 4 1/2" BRUSH, 3.62" WIRE GRAB TO TOP OF DEPLOYMENT SLEEVE @ 10,717' SLM (no recovery) RAN 20' x 3.70" DUMMY WHIPSTOCK TO TOP OF DEPLOYMENT SLEEVE @ 10,717' SLM RAN 10' x 1 3/4" DRIVE DOWN BAILER, 2 7/8" BRUSH, 2.24" WIRE GRAB TO DEVIATION @ 11,891' SLM (recovered 1/2 element) 12/26/2017 ***CONT WSR ON 12/27/17*** ***CONT WSR FROM 12/26/17*** (drlg screen-maint) RAN PDS 24 ARM CALIPER FROM 11,520' SLM TO SURFACE (good data) 12/27/2017 ***WELL LEFT S/I UPON DEPARTURE, PAD OP NOTIFIED OF WELL STATUS*** CTU#8 1.75" CT. Job Scope: Catch & Release Liner MIRU CTU. Drift new 1.75" CT with 1-3/16" ball. Perform Weekly BOP Test. MU Baker Fishing BHA. 2/19/2018 ***In Progress*** CTU#8 1.75" CT. Job Scope: Catch & Release Liner MIRU CTU. 2/19/2018 ***In Progress*** CTU#8 1.75" CT. Job Scope: Catch & Release Liner RIH w/ Baker 4" G-Spear Fishing BHA. Kill well with 1% KCL. Weight check above liner= 27k. Tag Liner at 10733' down / 10731' up. Latch liner. Pull up to —38k and picked up the liner without any jar licks. Weight check now 36k, 9k over initial. Pull liner up to 10584'. Confirm the liner is free. RBIH with liner. Pump off fish. Pooh. Freeze Protect well w/41 bbls 60/40 Methanol. Rig Down CTU. 2/20/2018 ***Job Complete*** CTU#8 1.75" CT. Job Scope: Catch & Release Liner RIH w/ Baker 4" G-Spear Fishing BHA. Kill well with 1% KCL. Weight check above liner= 27k. Tag Liner at 10733' down/ 10731' up. Latch liner. Pull up to —38k and picked up the liner without any jar licks. Weight check now 36k, 9k over initial. Pull liner up to 10584'. Confirm the liner is free. RBIH with liner. Pump off fish. Pooh. Freeze Protect well w/41 bbls 60/40 Methanol. Rig Down CTU. 2/20/2018 ***Job Complete*** T/I/0=2500/1500/500 Set 4" CIW"H"TWC#296 through tree. Installed Target 90 kill line#3. Removed tree cap bonnet, installed tapped blind with jewelry. Installed CDR work platform. 3/19/2018 FWP's TWC/1500/500 see log for details. • • Daily Report of Well Operations D-07B T/I/0 = TWC/1510/380. Temp = SI. Bleed WHPs (pre rig). No AL, flow line, scaffolding or well house. IA& OA FL near surface. Bled OAP to BT from 380 psi to 250 psi before midnight. 3/20/2018 **WSR continued on 03-21-2018. **WSR continued from 03-20-2018. T/I/0 = TWC/1510/250. Temp = SI. Bleed WHPs (pre-rig). No AL, flow line, scaffolding or well house. IA& OA FL near surface. Bled OAP from 250 psi to 70 psi in 3 hrs, 5.0 bbls. Bled IAP from 1510 psi to 30 psi in 1.5 hrs , gas. Monitor during RD. During monitor WHPs unchanged. Final WHPs = TWC/30/90. 3/21/2018 SV= ?. WV= C. SSV, MV= O. IA, OA= OTG. 04:20 T/I/0 = TWC/60/90. Temp = SI. Bleed WHPs to 0 psi (pre CTD). Wellhouse, scaffold, grating, and AL disconnected. Fusible installed SSV. IA& OA FL near surface. Bled IAP to BT from 60 psi to 0+ psi in 20 min (gas fluid mix (0.1 bbls). Currently bleeding OAP. 3/21/2018 Cont on WSR 3/22/18. Cont from WSR 3/21/18. Bleed WHPs to 0 psi (pre CTD). Bled OAP from 90 psi to 30 psi in 4 hrs 30 min (all gas). No monitor. Final WHPs =TWC/10/30. 3/22/2018 WV= C. SSV, MV= O. IA, OA= OTG. 04:30 T/I/0 = TWC/10/40. Temp = SI. Bleed (pre-rig). Wellhouse, flowline, scaffold, grating &AL disconnected. Fusible cap installed on SSV. WHPs under 50 psi did not bleed. 3/23/2018 SV= ?. WV= C. SSV, MV= O. IA, OA= OTG. 01:30 T/I/0 = TWC/10/40. Temp = SI. WHPs (pre-rig). Wellhouse, flowline, scaffold, grating &AL disconnected. Fusible cap installed on SSV. WHPs under 50 psi did not bleed. 3/26/2018 SV= ?. WV= C. SSV, MV= O. IA, OA= OTG. 01:30 T/I/0 = TWC/30/50. Temp = SI. Bleed WHPs (pre rig). Wellhouse, flowline, scaffold, grating &AL disconnected. Fusible cap installed on SSV. Started bleeding OAP. 3/31/2018 ***WSR Continued on 4/1/18.*** T/I//O = TWC/30/80. Temp = SI. WHPs (pre rig). Wellhouse, flowline, scaffold, grating &AL disconnected. Fusible cap installed on SSV. Bleed OAP from 75 psi to 20 psi in 1 hour 20 minutes (6 gallons). Monitor for 15 minutes OAP unchanged. Final WHPs = TWC/30/20. 3/31/2018 SV= ?. WV= C. SSV, MV= O. IA, OA= OTG. 14:00 ***WSR Continued from 3/31/18.*** T/I/O = TWC/30/4. Temp = SI. Bleed WHPs (pre rig). Wellhouse, flowline, scaffold, grating &AL disconnected. Fusible cap installed on SSV. Bled IAP & OAP to 0 psi. Monitored for 30 mins, IA&OA unchanged. Final WHPs =TWC/0/0. 4/1/2018 SV= ?. WV= C. SSV, MV= O. IA, OA= OTG. 0400 • • North America-ALASKA-BP "' � ` s Operation Summary Report f "" Common Well Name.D-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/1/2018 End Date:4/14/2018 X3-018X5-C:(2,733,116.00) Project:PBU Site:D Rig Name/No.:CDR-2 Spud Date/Time:6/20/1975 12:00.00AM Rig Release:4/15/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000563 Active datum:KB @69.O0usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 4/1/2018 09:00 - 18:00 9.00 RIGU P PRE PJSM.UNSTAB COIL. -REMOVE GRIPPER BLOCKS,REMOVE STRIPPER. REMOVE GOOSENECK AND SECURE ON RIG FLOOR. -CONNECT BLOCKS TO BOPE.PREP TO CHANGE OUT INJECTOR. -REMOVE ELECTRICAL LINES AND HYDRAULIC LINES FROM INJECTOR. -ADJUST DRAG CHAIN IN PIT MODULE. -DIG OUT TIGER TANK LINE.PHASE 11 ON ROAD FROM CAMP TO RIG. 18:00 - 21:00 3.00 RIGU N PRE CRANE ON LOCATION @ 18.00 HRS. PJSM WITH CRANE CREW.EMPHASIS ON COMMUNICATION. REMOVE INJECTOR AND INSTALL NEW INJECTOR IN CARRIER. CRANE RELEASED @ 21:00 HRS. 21.00 - 00:00 3.00 RIGU N PRE -RECONNECT ELECTRICAL AND HYDRAULIC LINES ON NEW INJECTOR. -BEGIN REBUILDING MUD PUMP,GREASE CHOKE VALVES AND SERVICE ACCUMLATOR. -ROADS AND PADS WORKING ON SNOW REMOVAL ON L PAD ACCESS ROAD. 4/2/2018 00:00 - 05:00 5.00 RIGU N PRE CONTINUE TO WORK ON REBUILDING MUD PUMP. WORKING ON SETTING NEW INJECTOR UP FOR SERVICE. ROADS AND PADS WORKING SNOW REMOVAL ON SPINE ROAD FROM L PAD ACCESS TOZ PAD. 05:00 - 07:00 2.00 RIGU N PRE R&P WILL TAKE-10-HRS TO CLEAR D-PAD AND STARTED AT 04:00 WE CAN START MOVING ONCE ROADS& PADS CLEARS THE ACCESS ROAD FROM D-PAD TO GC2 FOR EMERGENCY ACCESS TO GC2 WHILE WE ARE ON THE ROAD ONCE WE PASS J-PAD 07:00 - 10:50 3.83 RIGU N PRE INSTALL PACKOFF PULL TEST INJECTOR TO 100K(WITNESSED) STAB COIL AND MU CTC Printed 4/23/2018 10:56.42AM *All depths reported in Drillers Depths* • • r =�� North America-ALASKA-BP ;::. Page z c/De Operation Summary Report' Common Well Name D-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date.4/1/2018 End Date:4/14/2018 X3-018X5-C:(2,733,116.00) Project:PBU Site:D Rig Name/No.:CDR-2 Spud Date/Time:6/20/1975 12:00:00AM Rig Release:4/15/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000563 Active datum:KB @69.O0usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 10.50 - 11:10 0.33 RIGU P PRE PEAK ON LOCATION PJSM W/CREW AND TRUCK DRIVERS. -EMPHASIS ON USING GOOD COMMUNICATION TECHNIQUES. -STOP COMMAND AGREED UPON.STOP BLOCK IN PLACE ON SUB. -ANNULUS PRESSURES CHECKED.0 PSI ON ANNULI.WELL SECURE WITH ALL CASING AND TREE VALVES SHUT IN. DRILL SITE OPERATOR NOTIFIED,WAIVED WITNESSING. -WE HAVE TRIED GETTING THE OA TO BLEED DOWN BELOW 50 PSI BUT WE ARE GETTING MOSTLY FLUID BACK AND DON'T WANT TO BLEED TOO MUCH LIQUID. PRESSURE IS DOWN TO 200 PSI,CALLED WSUPTAND DISCUSSED AS PER SOP AND WE HAVE THE OK TO PULL OFF,CHOCK BLOCK IS IN PLACE AND THE VALVE IS 3' FROM THE OUTTER WALL OF THE CELLAR. 11:10 - 11:35 0.42 RIGU P I PRE HOOKUP SOWS AND MOVE RIG OFF WELL 11:35 - 12:15 0.67 RIGU P PRE PIT MODULE MOVED AWAY,HOOK UP TO THE MAIN SUB AND PULL OFF THE WELL ALL TREE AND CASING VALVES CLOSED 12:15 - 13:00 0.75 RIGU P PRE MAIN SUB MOVED OFF,CASING VALVES REOPENED TO THE GAUGES AS REQUESTED BY THE DSO.INSTALL JEEPS TO MOVE RIG THE TO D-PAD 13:00 - 14:30 1.50 RIGU P PRE MOVE RIG TO D-PAD 14:30 - 18:00 3.50 RIGU P PRE RIG STOPPED AT MOBILE PAD TO ALLOW TRAFFIC BY THEN CONTINUE MOVING -RIG ON LOCATION @ 18:00 HRS. 18:00 - 20:30 2.50 RIGU P PRE PRE JOB W/CREW AND TRUCK DRIVERS. -AGREE ON STOP COMMAND AND CONFIRMING COMMUNICATIONS BEFORE ACTING. -CHECKED ANNULIL,ALL PRESSURES ARE 0. SHUT IN VALVES ON WELLHEAD. -STOP BLOCK IN PLACE PRIOR TO MOVING SUB OVER WELL. -DRILL SITE OPERATOR NOTIFIED,WAIVED WITNESSING. -NABORS TOOLPUSHER AND WELL SITE LEADER WITNESSED SUB PULLING OVER WELL,NO ISSUES. -SPOT UP MUD PIT MODULE,RIG ACCEPTED @ 20:30 HRS,04/02/2018. 20:30 - 00:00 3.50 RIGU P PRE 'WORK ON RIG UP CHECK LIST. -CHECK PRESSURE ON SURFACE SAFETY VALVE. -FUSIBLE CAP IS ON,LOCKED OPEN AND PRESSURE BLED OFF. -OPENED UP MASTER/SWAB TO TREE CAP, NO TRAPPED PRESSURE. -HOOK UP ALL SERVIDE LINES AND HARD LINE TO TIGER TANK. -LEAK TIGHT TEST AGAINST SWAB DID NOT PASS.CALL OUT GREASE CREW. Printed 4/23/2018 10:56:42AM *All depths reported in Drillers Depths* • North America ALASKA BP • Page 3 Operation Summary Report` Common Well Name:D-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) C Start Date:4/1/2018 End Date:4/14/2018 X3-018X5-C:(2,733,116 00) Project:PBU Site:D Rig Name/No.:CDR-2 1 Spud Date/Time.6/20/1975 12:00:00AM Rig Release:4/15/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000563 Active datum:KB @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 4/3/2018 00:00 - 02:30 2.50 RIGU P PRE CONTINUE TO WORK ON RIG UP CHECK LIST. -LEAK TIGHT TEST AGAINST SWAB AND MASTER VALVES,3500 PSI,PASSING TEST. -INSTALL MPD VALVES. 02:30 - 05:00 2.50 BOPSUR P PRE 'PJSM.N/U 7 1/16"X 5M BOPE.CONFIGURED AS FOLLOWS: -ANNULAR PREVENTER,BLIND/SHEAR ,RAMS,2"PIPE/SLIP RAMS -MUD CROSS,2 3/8"X 3 1/2"VBRS,2"PIPE SLIP RAMS. 05:00 - 05:30 0.50 BOPSUR P PRE FLUID PACK TO SHELL TEST 105:30 - 06:40 1.17 BOPSUR N PRE DOOR SEALS ARE LEAKING,SUCK OUT STACK AND TRY WARMING STACK 06:40 - 12:00 5.33 BOPSUR N PRE -LOWEST SET OF RAM DOOR SEALS ARE LEAKING,HOLD A PJSM TO PULL DOORS AND REPLACE SEALS CAN'T GET THE ONE OF THE LOWER DOOR SEALS TO SEAL,CALL OUT MECHANIC TO INSPECT AND REPLACE. 12:00 - 14:30 2.50 BOPSUR P PRE RIG UP TEST EQUIPMENT. -VERIFY TEST JOINT LENGTHS AND OUTSIDE DIAMETERS. -PURGE AIR FROM SYSTEM. 14:30 - 18:30 4.40 BOPSUR P PRE TEST BOPS. -FROM TOP: ANNULAR,BLIND/SHEARS,2" PIPE/SLIPS,FLOW CROSS,2-3/8"X 3-1/2" VBRS,2"PIPE SLIPS. 1-TEST ALL BOP COMPONENTS,CHOKE VALVES AND MPD LINE VALVES TO 250/3,500 PSI. -TEST WITNESS WAS WAIVED BYAOGCC REP BOB NOBLE ON 4/1. -ANNULAR PREVENTER LEAKING,CONTINUE BOP TEST WILL CHANGE IT OUT AFTERWARDS. 18:30 - 19:00 0.50 BOPSUR N PRE TROUBLESHOOT LEAK PATH. -LEAKING MASTER VALVE,PERFORM REMAINDER OF TESTS AGAINST SWAB VALVE. 19:00 - 21:00 2.00 BOPSUR P PRE CONTINUE TO TEST BOPS. 21:00 - 22:00 1.00 BOPSUR N PRE CHANGE OUT ANNULAR PREVENTER. 22:00 - 00:00 2.00 BOPSUR P PRE CONTINUE TO TEST BOPS. 4/4/2018 00:00 - 00:30 0.50 BOPSUR P PRE CONTINUE TO TEST BOPS. 00:30 - 01:00 0.50 BOPSUR N PRE CONTINUE TO TEST BOPS.ALLOTED BOP TEST TIME HAS BEEN EXCEEDED. 01:00 - 04:00 3.00 BOPSUR P PRE RIG DOWN AFTER COMPLETING BOP TEST. CLEAN AND CLEAR RIG FLOOR.RIG DOWN TESTING EQUIPMENT.CHANGE OUT RISER. PREPARE TO CUT COILAND ELINE. RIG UP HYDRAULIC CUTTER. CUT OFF 100 FT OF CT AND 100 FT OF ELINE. PREP END OF CT FOR INSTALLING CT CONNECTOR. Printed 4/23/2018 10:56:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP 110/,?,0%,' $. Operation Summary Report =i Common Well Name:D-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/1/2018 End Date:4/14/2018 X3-018X5-C:(2,733,116.00) Project:PBU Site:D 1 Rig Name/No.:CDR-2 Spud Date/Time.6/20/1975 12:00.00AM Rig Release.4/15/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000563 Active datum:KB @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 04.00 - 06.30 2.50 BOPSUR P PRE PJSM AND REVIEW PROCEDURE FOR INSTALLING CT CONNECTOR. INSTALL CT CONNECTOR,PULL TEST TO 50K, GOOD. INSTALL NEW STRIPPER ELEMENTS. INSTALL QTS RISER. INSTALL STINGER AND NOZZLE. 06:30 - 08:30 2.00 BOPSUR P PRE FILL REEL FORWARD. CHECK TORQUE ON TREE BOLTS. PUMP SLACK BACKWARDS. 08:30 - 09:45 1.25 BOPSUR P PRE TEST IRV,C8,C9 BACKWARDS,AND CT STRIPPER. NOT ABLE TO GET A FLATLINE. TRY BUMPING UP PRESSURE SEVERAL TIMES,STILL SLOW LEAKOFF. 09:45 - 12:30 2.75 BOPSUR P PRE CYCLE VALVES,ISOLATE AND TROUBLESHOOT. CLOSE TV3 AND GET GOOD TEST ON CT STRIPPER AND IRV. FINAL TEST IS C9 AND C10 FROM BACKSIDE. UNHOOK TEST PUMP LINE FROM TV1,TV2 AND GET GOOD TEST. 12.30 - 14:00 1.50 RIGU P PRE PURGE TEST HOSE LINES WITH AIR. GREASE CHOKE VALVES LINE TO PUMP SLACK FORWARD. PUMP SLACK FORWARD,DISPLACE REEL TO KCL WATER. 14:00 - 15:30 1.50 RIGU P I PRE LIFT OFF INJECTOR. INSTALL BHI CABLE HEAD. PRESSURE TEST CT CONNECTOR TO 4,660 PSI,GOOD. PRESSURE TEST FLOATS TO 3,500 PSI, GOOD. 15:30 - 16 10 0.67 RIGU P PRE SLIDE INJECTOR BACK. PULL QTS OFF STACK. PJSM AND REVIEW PROCEDURE FOR PULLING TWC. REVIEW PRESSURE XCHECK VERIFICATION WITH DRILLER. INSTALL BPV LUBRICATOR AND PULLING TOOLS ON WELL. PUMP MEOH THROUGH AND PT TO 3,500 PSI, GOOD. 16:10 - 17:30 1.33 RIGU P PRE RETRIEVE TWC FOLLOWING NABORS AND VALVE SHOP PROCEDURE. PULL TWC ABOVE MASTER AND SHUT MASTER VALVE. 2,400 PSI UNDER TWC. BEGIN BLEEDING OFF LUBRICATOR (PRESSURE. 17:30 - 18:00 0.50 RIGU N PRE HI-LEVEL METHANE ALARM IS ACTIVATED AT SHAKER,SHUT IN BLEEDER ALL PERSONS MUSTER AND ACCOUNTED FOR IN 6 MIN. INFORM WSUP,PAD OPERATOR. SR WSLARRIVES DURING THE MUSTER.. Printed 4/23/2018 10:56:42AM *All depths reported in Drillers Depths* • North America ALASKA BP Page 5 d 4. • -;3 # ✓ Operation Summary Report vafieumgoaAl Common Well Name D-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/1/2018 End Date:4/14/2018 1X3-018X5-C:(2,733,116.00) Project:PBU Site:D Rig Name/No.:CDR-2 Spud Date/Time.6/20/1975 12:00:00AM Rig Release:4/15/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000563 Active datum:KB(869.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 18:00 - 20:00 2.00 RIGU N PRE METHANE ALARMS ARE CLEARED,AUDIBLE AND LIGHTS OFF. TWO PERSONS CHECK RIG WITH HANDHELD GAS DETECTOR. RETURN TO RIG AND CONDUCT DEBRIEF IN CONFERENCE ROOM. I HSE ADVISOR TERRY HUNT PRESENT TO CONDUCT PRELIMINARY INVESTIGATION AND PARTICIPATE IN THE AAR. RECIEVE AUTHORIZATION TO PROCEED WITH OPERATIONS FROM WSUP AND WOM. 20:00 - 20:45 0.75 RIGU P PRE CONTINUE TO RETRIEVE TWC FOLLOWING NABORS AND VALVE SHOP PROCEDURE. 400 PSI REMAINING ABOVE MASTER VALVE. CONTINUE TO BLEED OFF REMAINING LUBIRCATOR PRESSURE TO TIGER TANK. 20:45 - 22:45 2.00 RIGU P PRE PERFORM LEAK TIGHT TEST OF MASTER AND SWAB VALVES WITH WELL PRESSURE. GOOD/EST. RIG DOWN LUBRICATOR AND VALVE SHOP 'EQUIPMENT. INSTALL AND PRESSURE TEST RISER CAP IN PREPARATION FOR WELL KILL OPERATIONS. 22:45 - 00:00 1.25 KILLW P PRE ;BULLHEAD KILL WELLAT 4.8 BPM AS I:FOLLOWS: 5 BBLS METH 140 BBLS HOT KCL 25 BBLS HI-VIS(130K LSRV) 150 BBLS KCL INITIAL WHP=2370 PSI.OBSERVE PRESSURE SLOWLY DECREASE THROUGHOUT WELL KILL. 4/5/2018 00:00 - 01:30 1.50 KILLW P PRE PERFORM FLOW CHECKAND ASSESS LOSS RATE:160 BPH INITIAL LOSS RATE CREW PERFORMING VALVE CHECKLIST PICK UP FISHING BHA WHILE EVALUATING LOSS RATE AT SURFACE. 01 30 - 02:00 0.50 FISH P DECOMP MAKE UP FISHING BHA#1 PER BAKER !MWD/DD/FISHING AND BEGIN TO RUN IN THE HOLE. TEST QTS AND CTK.OPEN EDC. I OBSERVE LOSS RATE DECREASE FROM 130 BPH TO 120 BPH 02:00 - 05:30 3.50 FISH P 3,500.00 DECOMP RUN IN THE HOLE WITH BAKER FISHING BHA #1 FROM SURFACE TO 3500'MD BAKER COUNTER NOT WORKING PROPERLY, WORKING FROM NABORS COUNTER WHILE RUNNING IN THE HOLE. OBSERVE LOSS RATE DECREASE FROM 120 BPH TO 95 BPH. LOST 259 BBLS ON TRIP IN THE HOLE. Printed 4/23/2018 10:56:42AM 'Al!depths reported in Drillers Depths* • • North America-ALASKA-BP Page 6 Operation Summary Report Common Well Name:D-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/1/2018 End Date:4/14/2018 X3-018X5-C:(2,733,116.00) Project:PBU Site:D Rig Name/No.:CDR-2 Spud Date/Time:6/20/1975 12:00:OOAM Rig Release:4/15/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000563 Active datum:KB @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 05:30 - 10:30 5.00 FISH P 10,737.00 i DECOMP CLOSE EDC. RIH SLOWLY AND ENGAGE TOP OF FISH AT 10,737',UNCORRECTED. SEE SLIGHT PRESSURE BUMP AND DECREASE OF RETURNS. STACK WT DOWN AND SHUT DOWN PUMP, PICK UP SLOWLY. UP WT IS 47K. PICKUP 5 FT AND STOP,CIRCULATE BAROCLEAN PILL DOWN AT 2.7/1.2 BPM. ONCE BARACLEAN PILL IS AROUND START POOH 40 FT/MIN. INCREASE POOH TO 60 FT/MIN AFTER ABOVE LOWER JEWELRY. PUMP 25 BBLS HI-VIS AROUND. 10:30 - 14:30 4.00 FISH P 10,737.00 DECOMP STOP AT 200'. GET TWO 10 MIN LOSS RATES OF 1.2 BPM AND 1.3 BPM. HOLD PJSM WITH NABORS CREWAND BOT FOR L/D OF LINER. DISCUSS WELL CONTROL CONTINGENCIES AND TOOL BREAKS. UD BHI TOOL AND GS SPEAR AND DEPLOYMENT SLEEVE. LID ANOTHER 25 JTS OF 3-1/2"SOLID STL LINER AND SEAL STINGER. TOTAL LENGTH OF FISH RECOVERED IS 765.08'OF 3-1/2"SOLID STL LINER PLUS 7.44' OF STINGER ASSEMBLY PLUS CROSSOVER, SHOULD BE 8.04'. j BASED ON MEASUREMENTS AND APPEARANCE OF END OF STINGER,APPEAR •TO HAVE LEFT ABOUT A 0.6'PIECE ,DOWNHOLE. 14:30 - 16:30 2.00 FISH N 10,737.00 DECOMP DISCUSS PLAN FORWARD WITH BOT AND ODE. DECISION IS MADE TO RUN A HYDRAULIC SPEAR WITH JARS TO FISH WHAT IS SUSPECTED TO BE LEFT IN THE WELL. WAIT FOR BOT TO BRING FISHING TOOLS FROM DEADHORSE SHOP. 16:30 - 17:00 0.50 FISH N 10,737.00 DECOMP FISHING TOOLS ARRIVE. DISCUSS AND FINALIZE PLAN FORWARD WITH ODE. CONDUCT PJSM AND REVIEW PROCEDURE FOR MAKING UP BHA. MAKE UP BHA#2 AND RUN IN WELL. 17:00 - 17:30 0.50 FISH N 10,737.00 DECOMP SMALL HYDRAULIC LEAK SEEN ON LOWEST SET OF BOP RAMS. REMOVE BHA#2 FROM WELLAND CLOSE SWAB,KEEP WELL FULL WITH MPD LINE. 17:30 - 18:00 0.50 FISH N 10,737.00 DECOMP MAKE UP FISHING BHA#2 PER BAKER DD/MWD/FISHING TO RECOVER REMAINING FISH IN THE HOLE -COIL CONNECTOR,UQC,LQC,WEAR SUB, P&C,EDC,DPS,DGS,JARS,GS SPEAR -TOTAL LENGTH=46' -TEST QTS AND CTK -KEEP HOLE FILL WITH CHARGE PUMP PUMPING DOWN THE BACKSIDE Printed 4/23/2018 10:56:42AM *All depths reported in Drillers Depths" North America-ALASKA BP Page 7 ocztK Operation Summary Report's ,r Common Well Name.D-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/1/2018 End Date:4/14/2018 X3-018X5-C.(2,733,116.00) Project:PBU Site:D Rig Name/No..CDR-2 Spud Date/Time.6/20/1975 12.00:00AM Rig Release:4/15/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000563 Active datum:KB @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 18.00 - 20:00 2.00 FISH N 11,518.00 DECOMP RUN IN THE HOLE WITH FISHING BHA#2 FROM 46'MD TO TOP OF FISH AT 11518'MD -KEEP HOLE FILL BY PUMPING DOWN THE BACKSIDE -GR TIE IN AT 11030'MD -CHECK PU AND SO WT AT 11400'MD -PU WT=47 KLBS,SO WT=20 KLBS -TAG FISH AT 11518'MD WITH 5 KLBS DOWN -OPEN EDC AND PREPARE TO PUMP DOWN THE COIL -LOSS RATE=55 BPH 20:00 - 21 00 1.00 FISH N 11,518.00 DECOMP ENGAGE FISH PER BAKER FISHING REPRESENTATIVE -POSITIVE INDICATION OF FISH ENGAGED -JAR 2X TO FREE FISH,SET DOWN TO CONFIRM FISH STILL ENGAGED:GOOD INDICATION -LINE UP TO PUMP DOWN THE BACKSIDE TO KEEP HOLE FULL ON TRIP OUT 21:00 - 00:00 3.00 FISH N 11,518.00 DECOMP PULL OUT OF THE HOLE WITH FISH -PULL SLOWLY THROUGH LINER JEWELRY -CONTINUE TO PULL OUT OF THE HOLE TO SURFACE TO RECOVER FISH AT 70 FT/MIN -KEEP THE HOLE FULL BY PUMPING DOWN THE BACKSIDE -LOSS RATE=40 BPH DAILY DOWNHOLE LOSSES:1534 BBLS 4/6/2018 00:00 - 00:30 0.50 FISH N 11,518.00 DECOMP LAY DOWN FISHING BHA#2 WITH FISH ENGAGED -FILL HOLE ON THE BACKSIDE WITH CHARGE PUMP -LOSS RATE=35 BPH 00:30 - 01 00 0.50 FISH P 11,518 00 DECOMP MAKE UP CLEAN OUT BHA#3 FROM SURFACE 58.5'MD -COIL CONNECTOR,UQC,LOC,WEAR SUB, P&C,EDC,DPS,DGS,BLIND SUB,DRIFT/WT BARS,2-1/8"MOTOR,STRING MILL, PARABOLIC MILL 01:00 - 04:00 3.00 FISH P 11,518.00 DECOMP RUN IN THE HOLE WITH BHA#3 FROM 58.5' MD TO 12,143'MD(WHIPSTOCK SETTING DEPTH) -LOSS RATE=38 BPH -PERFORM TIE IN PASS TO CORRELATE TO PDC LOG(-21 FT) 04:00 - 06:00 2.00 FISH P 12,205.00 DECOMP CONTINUE WORKING DOWN TO 12,205'. FEW STALLS AT 12,143'AT MAX PUMP RATE, SHUT OFF PUMP AND PUSH DOWN TO 12,205',CLEAN. CONDUCT 2 CLEANING PASSES FROM 12,100' TO 12,200'AT 1.65/1.04 BPM 06.00 - 10.00 4.00 FISH P 12,205.00 DECOMP PUMP 10 BBL HI-VIS SWEEP AROUND. PERFORM JOG UP AND DOWN THROUGH 5-1/2"LINER. POOH PUMP 2.84/2.00 BPM AT 3,300 PSI. Printed 4/23/2018 10:56:42AM *All depths reported in Drillers Depths* North America-ALASKA-BP, Page 80X1 f -** *i r fi r, **r e l `7 / 47 Operation SummaryReport Common Well Name:D-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/1/2018 End Date:4/14/2018 X3-018X5-C:(2,733,116.00) Project:PBU Site:D Rig Name/No.:CDR-2 Spud Date/Time:6/20/1975 12:00:00AM Rig Release:4/15/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000563 Active datum:KB @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 10:00 - 10:30 0.50 FISH P 12,205.00 DECOMP AT SURFACE GET 10 MIN LOSS RATE OF 4.2 BBLS. LIFT UP INJECTOR AND LOOK AT LAST 20 FT OF CT,SOME GOUGES ON CT SEEN. MOVE INJECTOR BACK AND REMOVE BHA FROM WELL. MILL IS 2.72"GO,2.71"NO-GO. REAMER IS 2.74"GO,2.73"NO-GO. 10:30 - 14:00 3.50 FISH N 12,205.0Q DECOMP REMOVE CT CONNECTOR AND UQC. CUT OFF 20 FT OF CT. LOOK AT NEXT 10 FT OF PIPE,NOTHING SEEN. INSTALL CT CONNECTOR AND PULL TEST TO 50K,GOOD. INSTALL UQC. PRESSURE TEST UQC,CT CONNECTOR TO 4,700 PSI,GOOD. PT FLOATS TO 3,500 SPI,GOOD. 14:00 - 14:30 0.50 WHIP P 12,205.00 WEXIT MAKE UP WHIPSTOCK BHA#4 -SURFACE TESTED COILTRAK TOOL.GOOD TEST. -PRESSURE TEST QTS TO 3,500 PSI HIGH FOR 5 MINUTES -INJECTOR ON:14:20 14:30 - 20:00 5.50 WHIP P 12,134.00 WEXIT RIH WITH WHIPSTOCK BHA#4 -OPEN EDC -SET PUMP TRIP AT 450 PSI,SETTING TOOL STARTS SHIFT AT 500 PSI. -RATE: 0.50 BPM IN,0.27 BPM OUT.CIRC PRESSURE:250 PSI -MUD WEIGHT:8.38 PPG IN,8.38 PPG OUT -LOG DOWN FOR TIE-IN FROM 11,820'TO 11,922'MD(RA TAG/FORMATION/JEWELRY) WITH-29'CORRECTION -SWAP VALVE TO PUMP THROUGH COIL -FILL COIL WITH OPEN EDC -RUN IN THE HOLE TO WHIPSTOCK SETTING DEPTH AT 12,133.81'MD 20:00 - 20:15 0.25 WHIP P 12,134.00 WEXIT SET WHIPSTOCK -OBSERVE SHEAR AT 3100 PSI -SET DOWN 5 KLBS TO CONFIRM WHIPSTOCK SET -TOP OF WHIPSTOCK AT 12,125'MD -BASE OF WHIPSTOCK AT 12,134.81'MD 20:15 - 23:15 3.00 WHIP P 12,134.00 WEXIT PULL OUT OF THE HOLE WITH WHIPSTOCK SETTING TOOL FROM 12134'MD TO SURFACE -PAINT FLAG AT 11,300'MD -PUMPING OUT OF THE HOLE AT 1.5 BPM -MUD WEIGHT IN/OUT=8.45 PPG LOSS RATE=18 BPH 23:15 - 00:00 0.75 WHIP P 12,134.00 WEXIT LAY DOWN BHA#4,WHIPSTOCK SETTING TOOL.RECONFIGURE BHA FOR BHA#5, MILLING ASSEMBLY. -COIL CONNECTOR,UQC,LQC,WEAR SUB, P&C,EDC,DPS,DGS,BLIND SUB,XO,(2) JNTS CSH,XO,MOTOR,STRING MILL, WINDOW MILL(2.75") -KEEP HOLE FULL BY RUNNING THE CHARGE PUMP LINED UP DOWN THE BACKSIDE Printed 4/23/2018 10:56:42AM *All depths reported in Drillers Depths* • North America-ALASKA-BP II/ Page 9 Operation Summary Report Common Well Name:D-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/1/2018 End Date:4/14/2018 X3-018X5-C:(2,733,116.00) Project:PBU Site:D Rig Name/No.:CDR-2 Spud Date/Time:6/20/1975 12:00:00AM Rig Release:4/15/2018 Rig Contractor:NABORS ALASKA DRILLING INC. BPUOI:USA00000563 Active datum:KB @69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 4/7/2018 00:00 - 02:30 2.50 WHIP P 12,134.00 WEXIT RUN IN THE HOLE WITH MILLING BHA#5 FROM SURFACE TO 12,125'MD AT THE TOP OF THE WHIPSTOCK -NO ISSUES PASSING THROUGH TOP OF LINER -PUMP DOWN THE COIL WHILE RUNNING IN THE HOLE TO KEEP THE HOLE FULL -BEGIN PUMPING MILLING FLUID DOWN THE COIL AT 8000'MD TO PLACE MUD AROUND THE MILLS BEFORE INITIATING MILLING OPERATIONS -FLUID LOSS RATE WHILE RUNNING IN THE HOLE=20 BPH -RUNNING IN THE HOLE WITH EDC OPEN 02:30 - 06:30 4.00 WHIP N 12,134.00 WEXIT 'CLOSE EDC AND BEGIN PUMPING THROUGH THE MOTOR. -OBSERVE PUMP PRESSURE QUICKLY INCREASE TO 3000 PSI. -BLEED OFF PRESSURE AT PUMP. -OBSERVE TRAPPED PRESSURE FROM BORE PRESSURE SENSOR IN BHA.—2500 PSI OF TRAPPED PRESSURE BENEATH LOWER FLOATS ON BHA AND PLUGGED POINT ON MOTOR. -PULL OUT OF THE HOLE AND OBSERVE DIFFERENTIAL PRESSURE BLEEDING OFF. -DISCUSS WITH BAKER DD/MWD/FISHING AND ELECT TO COME OUT OF THE HOLE -OBSERVE DIFFERENTIAL PRESSURE CONTINUING TO BEED OFF WHILE COMING OUT OF THE HOLE -CONTINUING TO FILL THE BACKSIDE WITH KCL TO MANAGE LOSSES:RATE=20 BPH -PULLING OUT OF THE HOLE TO SURFACE TO EVALUATE CONDITION OF MILLS AND BHA.MOBILIZING REPLACEMENT MILLS AND FISHING TOOLS TO THE RIG. 06:30 - 08:00 1.50 WHIP N + 12,134.00 WEXIT AT SURFACE GETA LOSS RATE OF 2.1 BBLS OVER 10 MIN. INJECTOR OFF AT 06:45. INSPECT LAST 30 FT OF CT,NO PIPE DAMAGE SEEN. BLEED OFF TRAPPED PRESSURE IN THE BHA USING BLEED PORT ON THE LQC. BREAK APART UQC AND SLIDE INJECTOR BACK. LAY DOWN COILTRAK AND 2 JTS OF 2-1/16" CSH. INSPECT MOTOR AND MILLS,PIPE SCALE IS SEEN PACKED OFF AT THE TOP OF THE MOTOR. 08:00 - 09:00 1.00 WHIP N 12,134.00 WEXIT MAKE UP 2 JTS OF CSH IN WELLAND PUMP THROUGH THEM AT 2 BPM. MAKE UP BHA#6,WINDOW MILLING BHA. BOTH MILL AND REAMER 2.74"GO,2.73" NO-GO. INJECTOR ON AT 08:45. PRESSURE TEST QTS TO 3,500 PSI,GOOD. PUMP THROUGH MOTOR AND MILLAT SURFACE,GOOD. OPEN EDC AND RIH. • • • • Printed 4/23/2016 10:56:42AM *All depths reported in Drillers Depths* • 4111V <,� � ° • North America ALASKA BP o�. Page 1 Operation Summary Report Common Wet Name:D-07 AFE No Event Type:RE-ENTER-ONSHORE(RON) Start Date:4/1/2018 End Date:4/14/2018 X3-018X5-C:(2,733,116.00) Project:PBU Site:D Rig Name/No.:CDR-2 Spud Date/Time:6/20/1975 12:00:OOAM Rig Release:4/15/2018 Rig Contractor NABORS ALASKA DRILLING INC. BPUOI.USA00000563 Active datum:KB©69.00usft(above Mean Sea Level) Date From-To Hrs Task Code NPT Total Depth Phase Description of Operations (hr) (usft) 09:00 - 12:45 3.75 WHIP N 12,134.00 WEXIT RIH WITH 2.74"MILLING BHA#6 -RATE:0.51 BPM IN,0.31 BPM OUT.CIRC PRESSURE:890 PSI -MUD WEIGHT:8.51 PPG IN,8.48 PPG OUT —CIRC AT 7,400'THROUGH THE MOTOR FOR A SHORT TIME,ALL CLEAR. -LOG DOWN FOR TIE-IN FROM 11,822' (FORMATION)WITH-27'CORRECTION -CLOSE EDC. EASE IN AND DRY TAG PINCH POINT AT 12,129'. 12:45 - 20:00 7.25 WHIP P 12,134.00 i WEXIT PICKUP AND START PUMPING. &M -RIH SLOWLY AT 1.75/1.44 BPM FREESPIN IS N. 2,480 PSI. -LIGHT TAG AT 12,128'START TIME MILLING FROM THERE. MILL 2.74"WINDOW IN 3-3/16"CASING PER BAKER REP FROM 12,129'MD TO 12,134'MD -RATE:1.65 BPM IN,1.25 BPM OUT -MUD WEIGHT:8.52 PPG IN,8.56 PPG OUT -DWOB:1-3 KLBS I-CIRC PRESSURE:2,930 PSI -MILL 10'OF RATHOLE,OBSERVE 80% CUTTINGS IN SAMPLE • 20:00 - 20:15 0.25 WHIP P 12,134.00 WEXIT DRY DRIFT WINDOW 1X TO BOTTOM WITH NO ISSUES 20.15 - 00.00 3.75 WHIP P 12,134.00 WEXIT PULL OUT OF THE HOLE WITH MILLING BHA #6 -2.4 BPH IN/2.4 BPH OUT,2989 PSI -OBSERVE LOSSES DECREASE TO 0 BPH -PAINT FLAG FOR NEXT RUN -UD MILLING BHA#6. -MILL AND REAMER 2.74"GO,2.73 NO-GO. 4/8/2018 00.00 - 00.30 0.50 BOPSUR P 12,134.00 WEXIT FUNCTION TEST BOPE:ALL FUNCTION WITH NO ISSUE. 00.30 - 01:00 0.50 DRILL P 12,134.00 WEXIT MAKE UP 2-3/8"DRILLING BHA PER BAKER DD/MWD -COILTRAK(CTC,UQC,LOC,P&C,EDC,DPS, USMPR,DGS,HOT,2-3/8"MOTOR AND 3-1/4" BICENTER BIT) -ZERO LOSSES WHILE MAKING UP BHA 01:00 - 04:30 3.50 DRILL P 12,134.00 PROD1 RUN IN THE HOLE WITH 2-3/8"DRILLING BHA -PUMPING AT 0.5 BPM IN/OUT WITH 2230 PSI -MONITOR DISPLACEMENT:GOOD DISPLACEMENT,NO LOSSES -TIE IN TO COIL FLAG FROM MILLING RUN -TIE IN TO GR,CORRECT-28 FT. Printed 4/23/2018 10:56:42AM *All depths reported in Drillers Depths* TY NOTES:WELL IVVELLHEAD= 13-518"MCEVOY D-0 7 EVIOUS W ELLBORES NOLT SHOWN 11715'*** I CTUATOR= BAKER OKB.ELEV= 67-47' BF.I.EV= 40.18' 2072' 4-112"OTIS HXO SSSV NIP,D=3.813" KOP _3__-._.._202' 20"CONDUCTOR ? C' Max Angle= 94 @ 12554' I 2108' H9-5/8"PBR Datum ND= 11529' /' Datum TVD = 8800'SS 2122' —�9-518"CSG HGR GAS LIFT MANDRELS 13-3/8'CSG,72#BUTT,N-80,D=12.347" H 2683' ST MD DEV TYPE V LV LATCH PORT DATE 4 3050 3049 7 MMG-M DMY RK 0 12/25/17 3 6564 5622 57 MMG-M DMY RK 0 12/25/17 Minimum ID =2.36" 10726' 2 9083 7033 57 MMG-M DMY RK 0 02/14/94 6.40" SEAL STEM & LOCATOR 1 9151 7070 58 MMG-M DMY RK 0 11/08/01 TOP OF 7-5/8"LNR H 9204' 9204' —19-5/8"X 7-5/8"TIE-BACK SLV,ID=7.75" ► 0 9211' —19-5/tr X 7-5/8"BKR SBP PKR w/HGR,D=6.875" 9-5/8"CSG,47#,N-80 BUTT,ID=8.681" H 9383' BEHIND 10762' —14-1/2" 4-1/2"OTIS X NP,D=3.813" CTL R g..-4 �i 10780' H 7-5/8"X 4-1/2"BKR SABL-3 PKR, D=3.93'1 i 10811' —14-1/2"OTIS X NIP,D=3.813" 10832' H4-1/2"OTIS XN NP,NLLED TO 3.8" (11/27/05) 4-1/2"TBG,12.6#,L-80 NSCT,.0152 bpf,ID=3.958" —I 10844' 10847' —15-3/4"TIW SEAL ASSY w/6.4"LOCATOR TOP OF 5-1/2"LNR 10850' 0 I�� 10850' — I5-112"TE-BACK SLEEVE BEHIND e e 10857' H5-1/2"BKR H PKR W/HMC HGR CT LNR ! t 7-5/8"LNR 29.7#,NT-95S STL,.0459 bpf,D=6.875" H 11055' 11495' —)TOP OF CEMENT 3-1/2"LNR,8.81#,L-80 STL,.0087 bpf,D=2.992" — 11547' N A 11 o NECHA MCA L WHPSTOCK H 11850' o 4 �4 ♦4 PFORATSUMMARY DN 44 ���� B� 11515' H3-1/2"HOWCO X NIP,D=2.813" REF LOG:CCNL_RUN01_GR 01_CCNL ON 12/04/05 ► 4 o4 0 4�. 11547' H 3-1/2"X 3-3116"XO,D=2.786" ANGLE AT TOP PERF:83"@ 12110' 1•.4 �.' Note:Refer to Production DB for historical rt data o 1 o r ? H FISH-45 KB PKR SLPS-3-1/2 EA(01/17/1 ) SIZE SPF INTERVAL Opn/Sqz SHOT SQZ .�.4 14� MILLOUT WINDOW (D-07B) 11862'(TOP) 3-3-/8" 6 11750-11775 S 06/25/05 12/04/05 3-3-/8" 6 11770-11782 S 02/04/05 12/04/05 ,'�4, 2" 6 12110-12200 0 01/29/09 12126' —13-3/16"VN-BPSTOCK(04/06/18) 2" 6 12370-12400 0 02/29/08 IMP .112390' —3-3/16"X 2-718"XO, 2" 6 12470-12500 0 02/28/08 ID=2-387" 2" 6 12630-12660 0 02/28/08 ����1• �� %iv 2" 6 12900-13650 0 12/05/05 BKR IBP(02/04/05) 11923' � PBTD 13826' 2" 6 12960-12990 0 01/27109 3-3/16"LNR,6.2#,L-80 TCII, H 12390' `4%1%* 2" 6 13190-13220 0 01/27/09 2" 6 13390-13420 0 01/27/09 .0076 bpf,ID=2.80" =zi, SQUEH DURING CTD CMT'ING OF LNR 2-718"LNR,6.16#,L-80 STL, 13862' 5-1/2"LNR,17#,L-80,D=4.892" 13072' .0058 bpf,D=2.441" DATE REV BY COMMENTS DATE REV BY COMMENTS PRt1DHOE BAY UNIT 10/01/76 INITIAL COMPLETION 02/25/14 PJC SET LTP/FISH DH(02/17/14) WEI_L: D-07B 02/14/94 M.LINDER SIDETRACK (D-07A) 04/10/14 GJB/JMD GLV C/O(04/07114) PERMIT No:'2051810 12/09/05 NORDIC1 CTD SIDETRACK(D-07B) 12/28/17 ZV/JMD PULLED LTP&SEAL ASSY AR No: 50-029-20162-02 02/05/09 MLVSV ADPERF/REPERF(01/29/09) 12/28/17 ZV/JMD GLV CJO(12/25/17) SEC 23,T11 N,R13E,2280'FNL&1067'FEL 01/09/11 TAR/PJC GLV C/0(01/07/11) 11/05/13 NAUJMD PERE REF LOGJWBS CLEANUP BP Exploration(Alaska) OF T� • • • h;� //7.4. THE STATE Alaska Oil and Gas N�►►.+ � � of e LAsKA. Conservation Commission 1Z }�— 333 West Seventh Avenue rti GOVERNOR BILL WALKER Anchorage, Alaska 99501-3572 Main: 907.279.1433 ALAS Fax: 907.276.7542 www.aogcc.alaska.gov Uchenna J. Egbejimba Engineering Team Leader—CTD&RWO r .r BP Exploration(Alaska)Inc. P.O Box 196612 Anchorage,AK 99519-6612 Re: Prudhoe Bay Field, Prudhoe Oil Pool, PBU D-07B Permit to Drill Number: 205-181 Sundry Number: 318-034 Dear Mr. Egbejimba: Enclosed is the approved application for sundry approval relating to the above referenced well. Please note the conditions of approval set out in the enclosed form. As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the AOGCC grants for good cause shown,a person affected by it may file with the AOGCC an application for reconsideration. A request for reconsideration is considered timely if it is received by 4:30 PM on the 23rd day following the date of this letter, or the next working day if the 23rd day falls on a holiday or weekend. Sincerely, Hollis S. French Chair DATED this day of March, 2018. F? ....:2) - 2018 STATE OF ALASKA RECEIVED •LASKA OIL AND GAS CONSERVATION COMM! • APPLICATION FOR SUNDRY APPROVV JAN 2 6 2018 20AAC25.280 O3 30///I y 1. Type of Request: Abandon 0 Plug Perforations o Fracture Stimulate 0 Repair Well 0 oirmn.Suspend 0 Perforate 0 Other Stimulate 0 Pull Tubing 0 Chang Ate 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 205-181 • • 3. Address: P.O.Box 196612 Anchorage,AK Exploratory 0 Development 0 99519-6612 Stratigraphic 0 Service 0 6. API Number 50-029-20162-02-00 • 7. If perforating: 8. Well Name and Number What Regulation or Conservation Order governs well spacing in this pool? Will planned perforations require a spacing exception? Yes 0 No 0 PBU D-07B • 9. Property Designation(Lease Number): 10. Field/Pools: ADL 028285 • PRUDHOE BAY.PRUDHOE OIL• 11. PRESENT WELL CONDITION SUMMARY Total Depth MD(ft): Total Depth TVD(ft): Effective Depth MD: Effective Depth TVD: MPSP(psi): Plugs(MD): Junk(MD): 13862 • 9037 • 13826 • 9039 • 2424 None 11780 Casing Length Size MD TVD Burst Collapse Conductor 104 20" 31-135 31-135 1530 520 Surface 2656 13-3/8" 31-2683 31-2683 4930 2670 Intermediate 9354 10-3/4"x 9-5/8" 29-9383 29-7193 6450/6870 4020/4760 Liner 1851 7-5/8" 9204-11055 7098-8543 8180 5120 Liner 1012 5-1/2" 10850-11862 8368-8995 7740 6280 Liner 10729 3-1/2"x 3-3/16"x 2-7/8" 10729-13862 8262-9037 Perforation Depth MD(ft): Perforation Depth TVD(ft): Tubing Size: Tubing Grade: Tubing MD(ft): 12110-13420 9029-9033 4-1/2"12.6# L-80 27-10847 Packers and SSSV Type: 4-1/2"Baker SABL-3 Packer Packers and SSSV MD(ft)and TVD(ft): 10780/8306 No SSSV Installed No SSSV Installed 12.Attachments: Proposal Summary RI Wellbore Schematic 0 13.Well Class after proposed work: Detailed Operations Program 0 BOP Sketch RI Exploratory 0 Stratigraphic 0 Development 0 • Service 0 14.Estimated Date for Commencing Operations: February 1,2018 15. Well Status after proposed work: Oil 0 WINJ 0 WDSPL 0 Suspended 0 • 16.Verbal Approval: Date: GAS 0 WAG 0 GSTOR 0 SPLUG 0 Commission Representative: GINJ 0 Op Shutdown 0 Abandoned 0 17.I hereby certify that the foregoing is true and the procedure approved herein will not Contact Name: Browning,Zachary H be deviated from without prior written approval. Contact Email: Zachary.Browning(d)bp.com Authorized Name: Egbejimba,Uchenna J Contact Phone: +1 907 564 5220 Authorized Title: Enpeering Team Leader-CTD 8 RWO /al, Qr Authorized Signature: • �1 Q Date: 2 6 ' p COMMISSION USE ONLY Conditions of approval:Notify Commission so that a representative may witness Sundry Number LI Plug Integrity 0 BOP Test I Mechanical Integrity Test ❑ Location Clearance ❑ 03 Other: /30p 1--e, -/- 1-0 35 00,05,:,9 q p4v)b- V/a ! 3ry{v1 fr'` �r5t i Z5 J U0 ipSL �}/te-rs-?eptC pGv iaCe�kwCc--�� ��Jprovt— Post Initial Injection MIT Req'd? Yes 0 No f p rr,2 0 ,¢,¢C 25 . /1Z C LJ Spacing Exception Required? Yes 0 No L Subsequent Form Required: 1£2 — Q /\ APPROVED BYTHE 3 Approved by: dAX:)CCOMMISSIONER COMMISSION Date: II 1 e) itYL 3/11 IF dPC., eD ,,_,.! ORIGINAL REDS ! 2C18 Submit Form and Form 10-403 Revised 04/2017 Approved application is valid for 12 months from the date of approval. # 4Attachments in Duplicate ,,.,- r z4, ,t.e.:„. • To: Alaska Oil & Gas Conservation Commission biDFrom: Zach Browning CTD Engineer Date: January 24, 2018 Re: D-07B Sundry Approval Request Sundry approval is requested to plug off the D-07B production as part of the drilling and completing the proposed D-07C coiled tubing sidetrack. History of D-07B: Parent well D-07B was completed in 2005 and has produced 644 mbo TWB SLP. However, D-07B is currently shut in due to high gas production.'The wellbore has good integrity, and the best use of the wellbore is a CTD - sidetrack to access the oil north of the parent that has not been recovered in the area. Proposed plan for D-07C: The sidetrack D-07C will be an -2515' Zone 1B producer to provide offtake from a 33 acre area located in the NW area of D-pad. Gravity drainage will continue to be the primary recovery mechanism for this area. The sidetrack will be drilled with the Nabors CDR2 rig on or around March 15th, 2018. The rig will move in, test BOPE and kill the well. To access the kick off location, the 3-1/2" scab liner will need to be pulled by the rig. Then a 3-3/16" whipstock will be set inside the production liner. A 2.80" window will be milled, plus rathole -10' long. The well kicks-off in Zone 1B and will be drilled in zone for the duration. The proposed sidetrack will be completed with a 2-3/8" L-80 solid liner, cemented in place and selectively perforated (post-rig). This Sundry covers plugging the existing D-07B production via the liner cement job or liner top packer, , if the liner lap pressure test fails (alternate plug placement per 20 AAC 25.112(i)). The following describes the work planned and is submitted as an attachment to Form 10-403. A schematic diagram of the current well and proposed sidetrack is attached for reference. Pre-Rig Work(scheduled to begin February 1st, 2018) 1. C Catch and Release 3-1/2" Liner 2. V Pre-CTD Tree work. Rig Work(scheduled to begin March 15th, 2018) 1. MIRU and test BOPE 250 psi low and 3,500 psi high (MASP 2424 psi). 2. Pull 3-1/2" Liner. Perform cleanout/drift run. 3. Set 3-3/16"Whipstock. 4. Mill 2.80"Window. 5. Drill production lateral: 3.25" OH, 2515' (12 deg DLS planned). 6. Run 2-3/8" L-80 liner leaving TOL at-10,795' MD. 7. Pump primary cement job: 32.4 bbls, 15.3 ppg Class G, TOC at TOL (-10,795' MD)*. 8. Freeze protect well to a min 2,200' TVDss. 9. Close in tree, RDMO. * Approved alternate plug placement per 20 AAC 25.112(i) ` n Post-Rig Work: COnWr . I Me ',al lcy �t P�dav�e ,'n 1. V: Tree work as necessary. / / Q � 2. D: Liner lap test. ry 2116 @ �,v�Ut7 r to 10 6OP `441 241 M 3. S: Drift w dummy perfs guns. Set LGLVs. pwi&;, ' oli1;1,'re,, 4. S: LTP set post rig if needed, and test.* ,y ba, j�r rile afraQSQ f 0,1 5. E: Neutron/Density Log. Perforate well -250'. 1 t3 rpt cyc4tt 1n� dgfti�• >` t� Edi 1'S SCM, re rw^,f. Pldyf'I t7 (,t( for Zach BrowningCC: Well File CTD Engineer Joe Lastufka r r �' 44004allow/ for i/ii fJ re coierif 564-52201 �'V K fiON. 0 o['ri`d°► 0f POOL /7.1-9,4 WELL.IEAD= 13-5/8"MCEVOY • D u PREVIOUS WELLBORES NOT SHOWN 11715'"' ACTUATOR= BAKER OKB.ELEV= 67.5' BF.EL.EV= 40.87' 2072' —L4-1/2'OTIS HXO SSSV NP,D=3.813" KOP= 3202' 20"CONDUCTOR Max Angle= 94'(12554' 2108' H9-5/8"PBR Datum MD= 11529' Datum TVD= 8800'SS , 2127 —{9-518'CSG HGR GAS LFT MANDRELS 13-3/&"CSG,72#BUTT,N-80,D=12.347" —{ 2683' ST MD 'ND DEV TYPE VLV LATCH FORT DATE 4 3050 3049 7 MNG-M DMY RK 0 12/25/17 Minimum ID =236" @ 10726' 3 6564 5622 57 NMG-M DMY RK 0 12/25/17 2 9083 7033 57 MMG-M DMY RK 0 02/14/94 6.40" SEAL STEM & LOCATORA 1 9151 7070 58 NSAQM DM' RK 0 11/08/01 TOP OF 7-5/8"LNR -f 9204' Hi --{ 9204' _H9-5/8"X 7-5/8"TE-BACK SLV,D=7.75' 9211' —I 9-518"X 7-5/8"BKR SBP PKR w/HGR,D=6.875" 9-5/8"CSG,47#,N-80 BUTT,D=8.681" --I 9383' L H 10729' H3.70"BKR DEPLOY SLV,D=3.00' BEHIND I 10762' --14-1/2'OTs X MP,D=3.813" CT LNR OL,A 10780' H7-5/8"X 4-1/2"BKR SABL-3 PKR, D=3.93' 10811' —4-1/2"OTIS X NP,D=3.813' 10832' H4-1/2"0118 XN NP,MLLED TO 3.8" (11/27/05) 4-1/2"TBG,12.6#,L-80 NSCT,.0152 bpf,13=3.958^ H 10844' 10847' —I 5-3/4'TMJ SEAL ASSY w/6.4'LOCATOR TOP OF 5-1/2"LNR —I 10850' 10850'JH5-1/2"TE-BACK SLEEVE BEHIND 10867' H 5-1/2'BKR H PKR W/HMC HGR I CT LNR • 7-5/8"LNR,29.7#,NT-95S STL,.0459 bpf,ID=6.875" H 11055' 11494' --13-112'X 2-7/8"XO,D=2.37" 3-1/2"LNR,9.3#,L-80 STL,.0087 bpf,D=2.992' —1 11494' 11495' —1 TOP OF CEMENT 11495' --{6.40"SEAL STEM&LOCATOR,D=2.36" 3-1/2"LNR,8.81#,L-80 STL,.0087 bpf,D=2.992" — 11547' Al i s 1VI V 11496' --13.70"DEPLOY SLV,D=3.00^ MECHANICAL W-I PSTOCK I— 11850' 1�1 ��1 PERFORATION SUMMARY 1141 �•'4 11515' H3-1/2'HOWCO X PP,D=2.813" REF LOG:C(I4L_RUNDI.GR_01 COAL ON 12/04/05 111 41 1. ANGIFATTOP PERE:83"n1211O' W /1. 11547' H3-112^X3-3/16"XO,D=2.786' Note:Refer to FYoduction DB for historical pert data 41 11 41 ? H FISH-45 KB PKR SLPS-3-1/2 EA(01117/14) SEE SPF INTERVAL Opn/Sgz SHOT SQZ SS S!) 3-3-18" 6 11750-11775 S 06/25/05 12/04/05 '4•w, MILLOUT WINDOW (D-07B) 11862'(TOP) 3-3-18" 6 11770-11782 S 02/04/05 12/04/05 X4;1 2" 6 12110-12200 0 01/29/09 2" 6 12370-12400 0 02/29/08 �' 12390' -3-3/16^X 2-7/8'XO, 2" 6 12470-12500 0 02/28/08r'v�'�'�'�, D=2.387" 2" 6 12630-12660 0 02/28/08 WAWA'. 2" 6 12900-13650 0 12/05/05 BKR IBP(02/04/05) 11923' ,`FBTD 13826' 2" 6 12960 12990 O 01127/09 3-3/16'LNR,6.2#,L-80 TCI, H 12390' 2" 613190-13220 O 01/27/09 .0076 Opt,D=2.80' 2" 6 (13390-13420 0 01/27/09 Nip SQUEEZED DURING CTD CMT'ING OF LNR 2-7/8'LNR,6.16#,L-80 STL, H-13862' 5-1/7 LNR,17#,L-80,D=4.892" — 13072' .0058 bpf,D=2.441" ID 13870' DATE REV BY COMMENTS DATE REV BY COMbUNTS PRUDHOE BAY UNIT 10/01/76 INITIAL COMPLETION 02/25/14 PJC SET LW/FISH OH(02/17/14) 1NH_L: D-07B 02/14/94 M.LIM)Bi SIDETRACK (O.07A) 04/10/14 GJB/JM D GLV CIO(04/07/14) Flu r No:"2051810 12/09/05 NORDICI CTD SIDETRACK(D-07B) 12/28/17 ZV/JMD FELLED LIP&SEAL ASSY API No: 50-029-20162-02 02105/09 MLYSV ADPERF/RS'F(01/29/09) 12/28/17 ZV/JMD GLV CIO(12/25/17) SEC 23,T11N,R13E,2280'FAL&1067'FE. 01/09/11 TAR/PJC GLV C/O(01/07/11) 11/05/13 I NAL/JMD FERF REF LOG/WBS CLEANUP , BP Exploration(Alaska) TEE= 4" D T S! NOTES:WELL ANGLE>70*( 11715'*** WELLI-FAD= ' 13-518"MCEVOY PROP S w ( PR IOUS WELLBORES NOT SHOWN*** ACTUATOR= BAKER OKB.ELEV= 67.5' BF.ELEV= 40_87' I [ I 2072' j—4.1/2"OTS FICO SSSV NP,ID=3.813" KOP= 3202' (20"CONDUCTOR,— _ I Max Angle= 94 t 12554' I L 2108 —{9_5/8"PSR I DatuD= � Datum M 11529' — 2122' H 9-s/8GASLIFTM"CSG HGRM)RHS Datum'TVD= 8800'SS I. 13-3/8'CSG,72#BUTT,N-80,D=12.347" 2683' ST MD LV I DEV TY PE VLV LATCH PORT DATE 4 3050 3049 7 MMG-M DONE RK 16 04/07/14 1 3 6564 5622 57 MMG-M SO RK 20 04/07/14 Minimum ID = XXX" XXX' 2 9083 7033 57 MMG-M OMY RK 0 02/14/94 1 9151 7070 58 MAG-M OMY RK 0 11/08/01 ITOPOF 7-5/8"LM 9204' 7-4- i.---1 9204' —I--10-s/8"X 7-5/8"TE-BACK SLV,D=7.75" - 9211' H9-5/8"X 7-5/8'BKR SBP PKR w/HGR,D x.875" J 9-5/8"CSG,47#,N-80 BUTT,D=8.681" --I 9383' , jiI I. 10762' H4-1/2"011S X NP,D=3.813' 10780' 7-5/8"X 4-1/2'BKR SABL-3 PKR D=3.93" I '" /i —I 10796' - H 10796' H3.70"BKRDEPLOY SLV,D= I 10811 j—{4-1/2"OTIS X NP,D=3.813" { 10832' H4-1/2"OTS XN NP,MLLED TO 3.8" (11/27/05) 4-1/2"TBG,12.6#,L-80 NSCT,.0152 bpf,D=3.958" H 10844' 10847' H5-3/4"TNV SEAL ASSY w/6.4'LOCATOR TOP OF 5-1/2"LNR H 10850' }----i P —10850' I—5-1/2'TE-BACK SLEEVE BEHIND 10867' H5-1/2"BKR H PKR W/FMHGR CT LNR 7-5/8"LNR,29.7#,NT-95S STL, .0459 bpf,D=6.875" —I 11055' A , 11496' H TOP OF CBuErrr .'. R, ( 11496' H6.40"SEAL STEM&LOCATOR,ID=2.36'J '4 Pro 11495'LNR, D _—{3.70"DEPLOY SLV,D=3.00' BEHIND 3-1/2" 8.81#,L-80 STL,.0087 bpf, =2.992' 11547' J `4 km� r 4 km 11515' H3-1/2"HOWCO X NP,0=2.813"i CT LNR MECHANICAL WHIPSTOCK — 11860' •4 4P 41„,,, 40 11547' H3-1/2*X 3-3/16”XO,D=2.786 I 5-1/2'LNR,17#,1-80,D=4.892'J—I —11860'J _. I . ,, " I ` T H 12125' I I MILLOUT WINDOW (D-07B) 11862'(TOP) [3-3/16"LNR,6.2#,L-80 TCI, 0076 bpf,ID=2.80" I--I —12126' MLLOUT WINDOW(13.07C) 12125'- ' PERFORATION SIMvIARY REF LOG: ..____ _ _.__—_.__ON / / ANGLE ATTOP PERF: " L i—lPUP JT w/RA TAG Note:Refer to Ftoduction DB for historical perf data SIZE SPF IMLfNAL Opn/Sqz SHOT SQZ TD —I • II 1 2-3/8"LNR,.___#,L-80 STL, 0058 bpf,D=2.441" H 14640' #• DATE REV BY COMVENTS DATE REV BY COMMENTS FRIJ)HOE BAY UNT 10/01[76 IMTIAL COMPLETION WELL: D-07 02/14(94 M.LINDBiSIDETRACK (D-07A) _ FERMI No: 12/09/05 NORDICI CTD SIDETRACK(D-078) AR Pb: 50-029-20162 �i_!_ SIDETRACK(D-07C) SEC 23,T11 N,R13E,2280'MIL&1067'FEL 12/07/17 JM) BOLT PROPOSED BP Exploration(Alaska) • • Well Slimhole CDR2-AC 4 Ram BOP Schematic Date 21-Nov-17 Quick Test Sub to Otis Topof7"Otis IR 4 CDR2 Rig's Drip Pan Distances from top of riser --li Excluding quick-test sub 4 7-1/16"5k Flange X 7"Otis Box Top of Annular I 6.0 ft v ,.F-I n Th Hydril71/16" Top of Annular Element 6.7 ft Annular Bottom Annular 8.0 ft 1 ► tm. Blind/Shear CL Blind/Shears 9.3 ft ►lli,, 41 2"Pipe/Slips CL 2"Pipe/Slips 10.1 ft ► o. B1 B2 B3 I B4 moke Li,, Kill Line moimiNimiN los.a A 7-7116" ■R WP "" `I1.' s r---`' 41"Iti ' a. cross iii �"� sk'I- 101( _11 EL 2-3,8"M 3-1'2"VBRs III �- CL 2-3/8"x 3-1/2"VBRs 12.6 ft ►Ii Ili 2"Pipe/Slips CL 2" ► Pipe/Slips 13.4 ft 11"'x- p • l �` N 11, WYNN10 niiiiis Cr of Top Swab 16.0 ft Swab Test Pump Hose f>tnrt� Ar T1 i T2 CL of Flow Cross 17.4 ft :I -it r, Master CL of Master 18.8 ft ..;:oo„ LDS 111, X11: IA . .. .mi. „; ..,,, .,;;. , .:.. „..a.. . A: GA i mnk LDS %. k= Ground Level 1 • • 0 . x CO N ,--I Thousand Cubic Feet of Gas ("MCF") per Month L6 o N lD 0 N O 0 O OO W O O o o O O o O O N O O O O m I N O� ‘-i' N %-I ,-1 %-I O 0 Oe D CO 00 'Ott,r a 1 r--1 0 oo c' 00 Ln L a_ `^ r o �. a N N m rn m o >I CD v u al0 r 'o v 0a. c c O 1 F- i 0 Z v0 O i 1 I j) U _6 p ! O Q Oe`Pr L In AEI° O O o � Q L1J °c: --'_ o O 1 ° wm Or, t� O •. O : a ro 2 0 I 1 cc u 4 * o CL 3 a Ii { a CL >'14 •11E! 0 III • CO > .. I) I o o INN! V W c Z 0 2 6. ., • Qoc Na Ali - oror4 . Qill "r J Q �a I IA I a Za 111111111111111111 114 - i I !IIII1IIIiIllhII CC oo a� r o a halm 1111111111 a v CL m ■ •� ` _ Is , a �� - O 0 .�.:: ..011111111 v0 a LLI CL m soon o O O O O aO -I 4Pr 0 0 0 0 0 a-1 6 6 6 O ri O O O ri O O i-1 p r1 ai gluo j aad ialeM}o siaiie8 Jo y;uo j aad Ho jo siaJJes • 4 Sundry Application Plug for Re-drill Wells Work Flow This process is used to identify wells that are suspended for a very short time prior to being re- drilled. Those wells that are not re-drilled immediately are identified every 6 months and assigned a current status of"Suspended." Step Task Responsibl 1/ The initial reviewer will check to ensure that the "Plug for Redrill"box Geologist / in the upper left corner of Form 10-403 is checked. If the "Abandon"or "Suspend"boxes are also checked, cross out that erroneous entry and initial it on both copies of the Form 10-403 (AOGCC's and operator's copies). 2 If the "Abandon"box is checked in Box 15 (Well Status after proposed Geologist work) the initial reviewer will cross out that erroneous entry and initial 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 The drilling engineers will serve as quality control for steps 1 and 2. (QC) 3 When the Stat Tech receives a Form 10-403 with a check in the"Plug Stat Tech for Redrill" box, they will enter the Typ_Work code "IPBRD"into the History tab for the well in RBDMS. This code automatically generates a comment in the well history that states "Intent: Plug for Redrill." 4 When the Stat Tech receives any Form 10-407, they will check the Stat Tech History tab in RBDMS for the "Intent: Plug for Redrill"code (IPBRD). If present and there is no evidence that a subsequent re-drill has been COMPLETED, the Stat Tech will assign a status of SUSPENDED to the well bore in RBDMS no matter what status is listed on the 10-407. The Stat Tech will also change the status on the 10-407 form to SUSPENDED, and date and initial this change. If the Stat Tech does not see the "Intent: Plug for Redrill"comment or code,they will enter the status listed on the Form 10-407 into RBDMS. 5 When the Form 10-407 for the redrill is received, the Stat Tech will Stat Tech change the original well's status from SUSPENDED to ABANDONED. 6 The first week of every January and July, the Stat Tech and one of the Stat Tech Geologists will check the "Well by Type Work Outstanding"user query Geologist in RBDMS to ensure that all of the Plug for Redrill wells have been handled properly. At this same time, they will also review the list of suspended wells for accuracy. Image Project Well History File Gover 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_ Well History File Identifier Organizing (done) ,.~bea oiumiuimiiii ., ae.~~~eed~ iuiuiiiniuiuii R CAN Color Items: Greyscale Items:1 ~~~ ^ Poor Quality Originals: ^ Other: ^ Logs of various kinds: NOTES: BY: Maria Date: ~ 8 ^ Other:: /s/ Project Proofing II I II'I II I (III I I III BY: Maria Date: ~-- ~ Q D /s/ Scanning Preparation _~ x 30 =1~ + ~ =TOTAL PAGES ~J (Count does not include cover sheet) ~/°~,~ BY: Maria Date: ~ I ' I fa' n Q /s/ r ~/ ~ T Production Scanning Stage 1 Page Count from Scanned File: ~7 ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: ~ ~ I O ~ /s/ I ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO DIG TAL DATA Diskettes, No. i ^ Other, No/Type: OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II'I II I II II I I III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: o~,,~,~~e«ea uumiimiuuii 10/6/2005 Well History File Cover Page.doc bp BP Exploration (Alaska) Inc. Attn: Well Integrity Coordinator, PRB -20 4. Post Office Box 196612 Anchorage, Alaska 99519 -6612 March 06, 2011 Mr. Tom Maunder RECEIVED Alaska Oil and Gas Conservation Commission V 0 7 ' v1 4 • I 1 l 333 West 7 Avenue �' Anchorage, Alaska 99501 ��,� . acs Oil & eBs Cons. 0.2:::13' NOR Subject: Corrosion Inhibitor Treatments of GPB D Pad Dear Mr. Maunder, Enclosed please find multiple copies of a spreadsheet with a list of wells from D Pad that were treated with corrosion inhibitor in the surface casing by conductor annulus. The corrosion inhibitor is engineered to prevent water from entering the annular space and causing external corrosion that could result in a surface casing leak to atmosphere. The attached spreadsheet represents the well name, API and PTD numbers, top of cement depth prior to filling and volumes of corrosion inhibitor used in each conductor. As per previous agreement with the AOGCC, this letter and spreadsheet serve as notification that the treatments took place and meet the requirements of form 10 -404, Report of Sundry Operations. If you require any additional information, please contact me or my alternate, Jerry Murphy, at 659 -5102. Sincerely, Torin Roschinger BPXA, Well Integrity Coordinator BP Exploration (Alaska ) Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top -off Report of Sundry Operations (10 -404) Date: 03/04/11 Corrosion ill Initial top Vol. of cement Final top of Cement top off Corrosion inhibitor/ Well Name PTD # API # of cement pumped cement date inhibitor sealant date ft bbis ft na gal D -01 A 1970780 50029200540100 NA N/A NA N/A 1/31/2011 D -03A 2001340 50029200570100 NA 14 NA 100.30 1/19/2011 D -04B 2031100 50029200560200 NA 4 NA 56.10 2/19/2011 D -05 1700060 50029200580000 NA 0 NA trace 1/19/2011 D -06A 1970430 50029201480100 NA 0.5 NA 3.40 1/7/2011 -0416 D -07B 2051810 50029201620200 NA 0.5 NA 3.40 1/7/2011 D -08A 2021230 50029203720100 NA 0.5 NA 3.40 2/9/2011 D -09A 1990850 50029203810100 NA 0.7 NA 3.40 1/19/2011 0-10 1790530 50029203890000 NA 2.3 NA 8.50 3/2/2011 D -11 B 2100770 50029204350100 NA 3.5 NA 23.80 1/6/2011 0-12 1800150 50029204430000 NA 1.3 . NA 5.10 1/15/2011 D -13A 2000810 50029204490100 NA 0.5 NA 2.55 3/31/2010 D -14A 1961530 50029204500100 NA 0.2 NA 0.85 1/15/2011 D -15A 1972120 50029204610100 NA 0.2 NA 0.85 1/15/2011 • D -16A 2090250 50029206830100 NA 0.1 NA 0.85 2/20/2011 0 -17B 2021110 50029206920200 NA 1 NA 3.40 2/19/2011 D -18A 2011030 50029206940100 NA 5.4 NA 34.00 2/20/2011 D -19B 2011120 50029207070200 NA 0.8 NA 3.40 2/19/2011 0-20 1820440 50029207800000 NA 0.5 NA 1.70 2/19/2011 0-21 1820520 50029207880000 NA 0.2 NA 3.40 2/10/2011 D -22C 2081210 50029207370300 NA 0.2 NA 0.85 2/10/2011 D -23A 1961880 50029207380100 NA 13.5 NA 93.50 3/1/2011 D -24 1852990 50029215060000 NA 0.9 NA 6.80 1/8/2011 D -25A 2000240 50029215220100 NA 6 NA 32.30 1/15/2011 D -26B 2060980 50029215300200 NA 0.8 NA 3.40 2/19/2011 D -27A 2051930 50029215430100 NA 0.3 NA 1.70 2/10/2011 D -28B 2090890 50029215560200 NA 0.3 NA 1.70 2/10/2011 0-29 1852530 50029214700000 NA 13.3 NA 27.20 1/16/2011 0-308 2061840 50029226460200 NA 2.2 NA 13.60 12/25/2010 D -31A 1960950 50029226720100 NA 3.3 NA 27.20 1/19/2011 0-33 1960360 50029226520000 NA 2.2 NA 18.70 1/8/2011 UNDER EVALUATION: D -07B (PT1051810) Sustained casing pressure lie IA Page 1 of 1 Regg, James B (DOA) From: AK, D &C Well Integrity Coordinator [ AKDCWelllntegrityCoordinator @bp.com] (cep. 17(?f.z,/ Sent: Monday, December 27, 2010 10:05 AM A ; Schwartz, Guy L (DOA); AK, OPS GC1 OSM; AK , A � Regg, B DO To: Maunder, Thomas E DO , GC1 Facility OTL; AK, OPS GC1 Well ad Lead; AK OPS GC1 Field O &M TL; AK, OPS GC a y p AK, OPS Prod Controllers; Cismoski, Doug A; Engel, Harry R; AK, D &C Well Services Operations Team Lead; AK, D &C Wireline Operations Team Lead; AK, RES GPB West Wells Opt Engr Cc: AK, D &C Well Integrity Coordinator; Stone, Christopher; Janowski, Carrie Subject: UNDER EVALUATION: D -07B (PTD #2051810) Sustained casing pressure on the IA Attachments: D -07B TIO Plot 12- 27- 10.doc; D- 07B.pdf All, Producer D -07B (PTD #2051810) has been found to have sustained casing pressure on the IA. The wellhead pressures were tubing /IA/OA equal to 1048/2020/740 psi on 12/25/10. The plan forward if to set dummy gas lift valves and perform an MITIA when weather cooperates enough to safely conduct wellwork. the well has been reclassified as Under Evaluation and placed on a 28 -day clock. A TIO plot and wellbore schematic have been included for reference. «D -07B TIO Plot 12- 27- 10.doc» «D- 07B.pdf» Please call with any questions or concerns. Thank you, Integrity l l t Coord natoalt. Jerry Murphy) � f `�4j1 Well Office (907) 659 -5102 Harmony Radio x2376 Cell (406) 570 -9630 Pager (907) 659 -5100 Ext. 1154 12/28/2010 PBU D -07B PTD 2051810 12/27/2010 TIO Pressures Plot Well: D -07 4.000 - • 3,1.100 - —0— T bg —E— IA 100l 00A - 0 0OA On 1 • 1 10/09/10 10/23/10 11 /06/10 11/20/10 12/04/10 12/18/10 TREE = 4" CM/ • SA TES: PARENT WELLBORE NOT WELLHEAD = 13 -5/8" 5M MCEVOY ®_0 7 B SHOW N DIAGRAM ACTUATOR = BAKER KB. ELEV = 69.0' BF. ELEV = . 40.87 KOP = 3202' 2072' H4 -1/2" OTIS SSSV NIP, ID= 3.813" 1 e., Max Angle = 94 @ 12554' I Datum MID D =� 11529' ` 2108' �- 9-5/8" PBR Datum TV D = 8800' SS E 2122' H 9 -5/8" CSG HGR I 1 13 -3/8" CSG, 72 #, N-80, ID = 12.347" H 2683' ■ GAS LIFT MANDRELS ST MD ND DEV TYPE VLV LATCH PORT DATE 4 3050 2981 6 MMG -M DOME RK 16 01/03/06 Minimum ID = 2.36" @ 10726' 3 6564 5553 57 MMG -M SO RK 20 01/03/06 6.40" SEAL STEM & LOCATOR 2 9083 6965 58 MMG -M DMY RK 0 1 9151 7001 58 MMG -M DMY RK 0 11/08/01 TOP OF 7 -5/8" LNR H. 9204' I I 9204' H 7-5/8" TIE-BACK I 1 9 -5/8" CSG, 47 #, L -80, ID = 8.681" I-1 9383' 9211° 1- 17 -5/8" BKR SBP PKR W/ HMC HGR I PERFORATION SUMMARY REF LOG: '2'?' ?? ON ? ?J?? /'/? ANGLE AT TOP PERF: 83° @ 12110' ►7.4 /c/■ 10721' H KB LNR TOP PKR, ID = 2.44" 1 Note: Refer to Production DB for historical pert data " X' 10726' -16.40" SEAL STEM & LOCATOR, ID = 2.36" 1 SIZE SPF INTERVAL Opn /Sgz DATE I 10729' H3.70" BKR DEPLOY SLV, ID = 3.00" 1 3 -3 - /8" 6 11750 - 11775 S "" 06/25/05 3 -348" 6 11770 - 11782 S" 02/04/05 2" 6 12110 - 12200 0 01/29/09 I 10762' - 14 -1/2 OTIS X NIP, ID = 3.813" (BEHIND PIPE) 1 2" 6 12370 - 12400 0 02/29/08 10780' 1 7 -5/8" X 4 -1/2" BKR SABL -3 PKR, 2" 6 12470 - 12500 0 02/29/08 14 CI ID = 3.93" (BEHIND PIPE) 2" 6 12630 - 12660 0 02/29/08 111 2" 6 12900 - 13650 0 12/05/05 I 10811 -14-1/2" OTIS X NIP, ID = 3.813" (BEHIND PIPE) 1 2" 6 12960 - 12990 0 01/27/09 I 10832' -14 -1/2" OTIS XN NIP, MILLED ID = 3.8" (BEHIND PIPE) 2" 6 13190 - 13220 0 01/27/09 2" 6 13390 - 13420 0 01/27/09 4 I 10847' - 5 -3/4" TM/ SEAL ASSY W/ 6.4 OD **PERFS SQUEEZED DURING CTD CMT'ING OF LNR LOCATOR (BEHIND PIPE) 1 4 -1/2" TBG, 12.6 #, L -80, .0152 bpf, ID = 3.958" I--I 10847' 10850' -- I5 -1/2" TIE -BACK (BEHIND PIPE) I TOP OF 5 -112" LNR I 10850' :1 i:4 10$57' I 5 -1/2" BKR H PKR W/ HMC HGR (BEHIND PIPE) I 7 -5/8" LNR, 29.7 #, L -80, .0459 bpf, ID = 6.875" I--J 11055' 1---41 11494' - I3 -1/2" X 2 -7/8" XO, ID = 2.37" 1 3-1/2" LNR, 9.3 #, L -80 STL, .0087 bpf, 1D = 2.992" I 11494' 11495' -{ TOP OF CEMENT 1 �! r 4 11495' - '16.40" SEAL STEM & LOCATOR, ID = 2.36" I ��� 1�/ 11495' - 13.70" DEPLOY SLV, ID = 3.00" I X1 ' i ♦ 11515' -13-1/2" HES X NIP, ID = 2.813" 1 3 -1/2" LNR, 8.81 #, L -80 STL, .0087 bpf, ID = 2.992" H 11547' r '� 1154T -13 -112" X 3 -3116" XO ID = 2.775" I ∎., ■ + MILLOUT WINDOW (D -07B) I � t`�.1 H4 ( MECHANICAL WHIPSTOCK 11850' �f , 11862' (TOP) ,, '' ',• I BKR IBP (02/04/05) 1 11923' -- �I 71 12390' 113-3/i6" X 2 -7/8" XO r����A 1 ID = 2.441" I 5-1/2" LNR, 17 #, L -80, ID = 4.892" H 13072' +A At / I3- 3/16" LNR, 6.2 #, L -80 TCII, .0076 bpf, ID = 2.80" I-J 12390' I PBTD H 13826' a� 12 -7/8" LNR, 6.16 #, L -80 STL, .0058 bpf, ID = 2.441" H 13862' I �• 1 TO H 13870' DATE REV BY COMMENTS DATE REV BY COMMENTS PRUDHOE BAY UNIT 10/01/76 ORIGINAL COMPLETION 02/05/09 MLI/SV ADPERF /REPERF (01/29/09) WELL: D-07B 02/14/94 M.LINDER SIDETRACK (D -07A) PERMIT No: ° 205180 12/09/05 NORDIC1 CTD SIDETRACK (D -07B) API No: 50 -029- 20162 -02 01/03/06 KDC /PJC GLV C/O SEC 36, T11N, R13E, 2999' FSL & 1067' FWL 01/04/06 JGM /TLH DRLG DRAFT CORRECTIONS 03/09/08 JCM /PJC PERFORATIONS (02/29/08) BP Exploration (Alaska) STATE OF ALASKA ~~ ~q~ ALASKA OIL AND GAS CONSERVATION COMM SION ~~~~~" REPt~T' OF SUNDRY WELL OPEF~'IONS '~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulated Other ~~~ ~~~~ Performed: Alter Casing ~ Pull Tubing ~ Perforate New Pool ~ Waiver Time Extension ~ T Change Approved Program ~ Operat. Shutdown ~ Perforate ~ Re-enter Susper~(;~~ ~ ry erator BP Exploration (Alaska), Inc. N 4. Current Well Class: 5. Permit to Drill Numb~~~hOrBge ame Development I/ Exploratory ~ 205-1810 3. Address: P.O. Box 196612 StratlgraphlC ~ Service [~ 6. API Number. Anchorage, AK 99519-6612 50-029-20162-02-00 7. KB Elevation (ft): 9. Well Name and Number: 69 KB PBU D-07B - 8. Property Designation: 10. Field/Pool(s): ADLO-028285 PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 13862 feet Plugs (measured) None true vertical 9037.06 ~ feet Junk ( measured) None n Effective Depth measured 1388 feet true vertical 9039 feet Casing Length Size MD TVD Burst , Collapse Conductor 104 20" 94# H-40 27 - 131 27 - 131 1530 520 Surface 2865 13-3/8"72# N-80 28 - 2683 28 - 2683 5380 2670 Intermediate 2091 10-3/4" 55.5# N-80 29 - 2120 29 - 2120 5210 2480 Production 7275 9-5/8" 47# N-80 2108 - 9383 2108 - 7193 6870 4760 Liner 1851 7-5/8" 29.7# NT95S 9204 - 11055 7098 - 8543 8180 5120 Liner 1012 5-1/2" 17# L-80 10850 - 11862 8368 - 8995 7740 6280 Liner 2365 3-1/2X3-3/16X2-7/8 11495 - 13860 8851 - 9037 Perforation depth: Measured depth: SEE ATTACHMENT - _ _ _ True Vertical depth: _ _ _ _ _ Tubing: (size, grade, and measured depth) 4-1l2" 12.6# L-80 SURFACE - 10847 0 0 - Packers and SSSV (type and measured depth) 7-5/8" BKR SBP PKR 9211 KB LNR TOP PKR 10721 7-5/8"X4-1/2" BKR SABL S-3 PKR 10780 5-1/2" BKR H PKR 10857 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 530 28388 318 Subsequent to operation: 467 25171 472 14. Attachments: 15. Well Class after aroposed work: Copies of Logs and Surveys Run Exploratory ~ Development r Service r Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~ Gas r WAG r GINJ 1- WIND r WDSPL 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 Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 2/6/2009 unn iu-wu~r r~~eu vwicuuo ~ ~ auomii vnginai vary DIt D-076 205-1810 L~FRF ATTA(`I-IMFNT U Sw Name Operation Date Perf Operation Code Meas Depth Top Meas Depth Base Tvd Depth Top Tvd Depth Base D-07B 12/5/05 PER 12,900. 13,650. 9,034.18 9,037.25 D-076 2/28/08 APF 12,470. 12,500. 9,036.15 9,036.18 D-07B 2/28/08 APF 12,630. 12,660. 9,032.41 9,032.67 D-076 2/29/08 APF 12,370. 12,400. 9,038.28 9,037.41 D-076 1/27/09 RPF 12,960. ~/' 12,990. 9,031.72 9,030.42 D-076 1/27/09 RPF 13,190. ~~/` 13,220. . 9,032.21 9,032.96 D-07B 1/27/09 RPF 13,390. 13,420. 9,033.29 9,033.07 D-07B 1/29/09 PER 12,110. 12,140. 9,029.38 9,032.61 D-07B 1/29/09 PER 12,140. 12,170. 9,032.61 9,034.84 D-07B 1/29/09 PER 12,170. 12,200. 9,034.84 9,036.07 AB ABANDONED PER PERF APF ADD PERF RPF REPERF BPP BRIDGE PLUG P ULLED SL SLOTTED LINER BPS BRIDGE PLUG SET SPR SAND PLUG REMOVED FCO FILL CLEAN OUT SPS SAND PLUG SET FIL FILL SQF SQUEEZE FAILED MIR MECHANICAL ISOLATED REMOVED SQZ SQUEEZE MIS MECHANICAL ISOLATED STC STRADDLE PACK, CLOSED MLK MECHANICAL LEAK STO STRADDLE PACK, OPEN OH OPEN HOLE ~J • D-07B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY - "ACTIVITYDATE ~, ~,., f. t , ~' ~ ~. ~ ~'< ~~` 1/25/2009 CTU #9 w/1.75" CT. Job Objective: Adperf. MIRU CTU. *** Job Continued on WSR 01/26/09 *** 1/26/2009 CTU #9 w/1.75" CT. Job objective: Adperf. *** Continued from WSR 1/25/09 *** < InterACT not publishing> Makeup and RIH with WFD MHA and PDS GR/CCL in 2.20" carrier. Tagged 3 times at 13827' (mech depth) electronic depth was 13692'. At 10,000' elec &mech were --30' off so we are going to use mech depths for flags. OOH, elec depth is -153' mech is -20'. RIH to zero depth and mech is --10' off. Decision was made to relog. MU PDS logging toils and RIH. Tag at 13830' ctmd. Log from TD to 12650' ctmd. flagging pipe twice,. At surtace, good data was recovered from the tool (-3' correction to Schlumberger CCL/GR/CNL dated 4-Dec-2005). Makeup gun #1. *** Job Continued on WSR 01/27/09 *** ____ " *** *** 1/27/2009 CTU #9 w/1.75 CT. Adperf. Continued from WSR 01/26/09 <InterACT not publishing > RIH with Gun #1. Correct to top shot at flag. Perforate interval from 13390' to 13420' pumping 34 bbls of 60/40 meth. Gun loadeded with 2.00" Guns - 6spf-60 deg phasing- 2006PJ charge. POOH. At surface, all shots fired. Makeup Gun #2. RIH with Gun #2. Correct to top shot at flag. Perforate interval from 13190' to 13220' pumping 34.5 bbls of 60/40 meth. 2.00" Guns loadeded with; 6spf-60 deg phasing- 2006PJ charge. At surtace all shots fired and ball ` recovered. MU Gun Run #3. RIH w/Gun #3. Correct to top shot at flag. Perforate interval from 12960' to 12990' pumping 35 bbls of 60/40 meth. 2.00" uns loa eded with; 6spf-60 deg phasing- 2006PJ charge. At surface, all shots fired. **" Job Continued on WSR 01/28/09 *** _ 1/28/2009 CTU #9 w/1.75" CT. Job objective: Adperf. *** Continued from WSR 01/27/09 *** <InterACT not publishing> Makeup and RIH with logging string #2 w/PDS GR/CCL in 2.20" carrier. RIH and logged up from 12450' to 11700'. Painted EOP Flag at 12250'. OOH downloaded good data and corrected -7' (Log tied into SLB CCL/GR/CNL dated 4-Dec-2005). Shut down for BP Leadership Meeting. Makeup Gun string #4. *** Job Continued on WSR 01/29/09 *** ~~1/29/2009 CTU #9 w/1.75" CT. Job scope: Adpert *** Continued from WSR 01/28/09 *** <InterACT publishing> RIH w/gun string #4. Correct to top shot at flag. Pertorate interval from 12170' to 12200' pumping 60/40 meth. Gun loadeded with 2.00" uns -6spf-60 deg phasing- 2006PJ charge. At surface, all shots fired. MU Gun run #5, 30' of 2.00" Guns -6spf-60 deg phasing- 2006PJ charge. RIH to flag and correct to top shot, Fire guns from 12140' to 12170'. At surtace, all shots fired. MU and RIH with Gun #6, 30' of 2.00" Guns -6spf-60 deg phasing- 2006PJ charge. Fire guns from 12110' to 12140'. POOH with well flowing. At surface, all shots fired. RD CTU. Final WHP = 638/875/534. _~ *** Job Continued on WSR 01/30/09 *** ~~_ 1/30/2009~CTU #9 w/1.75" CT. Job Objective: Adperf. *** Continued from WSR 01/30/09 *** Rig down CTU. Notify pad operator of well status. *"* Job Complete *"" FLUIDS PUMPED BBLS 195 60/40 METH 195 Total • ~~~ L~ 1 °I~.4~I f~l fl//l °~~4L - ~ ~~, ProActive Diagnostic Services, Inc. To: AOCCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/C±pen Hole/Mechanical Logs and /or Tubing Inspection(Caliper / MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaskaj, Inc. ~ - '~~ -~ ~ `~~"~` - ~' ~~~~~ Petrotechnical Data Center Attn: Joe Lastufka IR2-1 900 Benson Blvd. Anchorage, Alaska 99508 and ProActive Diagnostic Services, Inc. Attn:. Robert A. Richey 130 West International Airport Road Suite C Anchorage, AK 99518 Fax: (907 245-8952 ~~ ~ ~ ~ 1 ~ ~~3 l'~~ ~~ 1) Coil Flag 26z1an-09 D-07B EDE 2) Coil Flag 28zJan-09 D-07B EDE Signed Print Name: 50029.20162-02 ~, ~. .~ .~ ~~ ~ ~ ~~~~ Date ~ ` ~' ~' PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAX: (907)245-88852 E-MAIL : odsanohorage{~sa~esstorvloC.~orn WEBSITE : ~+r~nnN.t~aatnoryloa.~oer~ C:~Dociunenls and Settings\Owner~Desktop\Trans,nit BP.docx • • V ~~~L L.OV ~~~~~fV/~~L ~- ProActive Diagnostic Services, Inc. To: ACIGCC Christine Mahnken 333 W. 7th Ave Suite 100 Anchorage, Alaska 99501 (907) 793-1225 RE : Cased Hole/Open Hole/Mechanical Logs and/or Tubing Inspection(Caliper/ MTTj The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the following BP Exploration (Alaska), Inc. Petrotechnical Data Center Attn: Joe Lastufka LR2-1 900 E. Benson Blvd. Anchorage, Alaska 99508 ~~~~E~ APR ~ ~ 2008 and ProActive Diagnostic Services, Inc. ~ ~~ _ ~~~ Attn: Robert A. Richey 130 West International Airport Road / (p ~ ~( Suite C Anchorage, AK 99518 Fax: (907) 245-8952 ( 1 j Coil Flag 26-Feb-08 D-07b \ 2) Depth Correlationn 14Mar08 DS 01.34 I Signed Print Name: ~~s.~t~ k~ ~-c.~l/ oc~ Q ~ $ ~/~ ED b 13 0-029-20162-02 EDE 50-029-21609-00 Date , :~ ~ 7M1 PROACTIVE DIAGNOSTIC SERVICES, INC., 130 W. INTERNATIONAL AIRPORT RD SUITE C, ANCHORAGE, AK 99518 PHONE: (907)245-8951 FAx: (907)2458952 E-MAIL : ~c3s~~achor~ae~mer~®rt~l~c~.c~rra WEBSITE: www.~r;erroar+ll®a.~~rrl C:\Documents and Settingsl0wner~Desktop\Transmit_BP-doc • WELL LOG TRANSMITTAL To: .State of Alaska February 29, 2008 Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7~' Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Data: D-07B AK-MW-4074252 1 LDWG formatted CD rom with verification listing. API#: 50-029-20162-02 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Dat~'~ - Signed:~~~~ ~~N MA[~ ~ ~ 200 ao~ = ~~ 1 ~/~ CZ • WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Librarian 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 RE: MWD Formation Evaluation Logs : D-07B • February 28, 2008 AK-MW-4074252 D-07B: 2" x 5" MD RESISTIVITY & GAMMA RAY Logs: 50-029-20162-02 2" x 5" TVD RESISTIVITY & GAMMA RAY Logs: 50-029-20162-02 Digital Log Images: 50-029-20162-02 1 Color Log 1 Color Log 1 CD Rom PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry Drilling Services BP Exploration (Alaska) Inc. Attn: Rob Kalish Petrotechnical Data Center, MB33 6900 Arctic Blvd. 900 E. Benson Blvd. Anchorage, Alaska 99518 Anchorage, Alaska 99508 Date: ~ - ~ ~ Signed: ~pSl~sl ~l~wt~ STATE OF ALASKA '~`~ ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS RECEIVED MAR 0 6 2008 n:r Q r~~ (:nnc_ r.On1(TtLSS~ 1. Operations Abandon ~ Repair Well ~ Plug Perforations ~ Stimulate ~ er Performed: Alter Casing ~ Pull 7ubing~ Perforate New Pool ~ Waiver Time Extension Change Approved Program ~ Operat. Shutdown ~ Perforate Q Re-enter Suspended Well 2. Operator BP Exploration (Alaska), Inc. 4. Current Well Class: 5. Permit to Dril( Number: Name: Development ~ Exploratory ' = 205-1810- 3. Address: P.O. Box 196612 Stratigraphic Service ` 6. API Number: Anchorage, AK 99519-6612 v 50-029-20162-02-00 7. KB Elevation (ft): 9. Well Name and Number: '" 69 KB ~,; PBU D-076 8. Property Designation: 10. Field/Pool{s): ~` ADLO-028285 ~' PRUDHOE BAY Field/ PRUDHOE OIL Pool 11. Present Well Condition Summary: Total Depth measured 13862 - feet Plugs (measured) None true vertical 9037.06 - feet Junk (measured) None ~~~y ~~~ MAR ~ 20~~ Effective Depth measured 13826 - feet true vertical 9039- feet Casing Length Size MD TVD Burst Collapse Conductor 104' 20" 94# H-40 27' - 131' 27' - 131' 1530 520 Surface 2865' 13-3/8" 72# N-80 28' - 2683' 28' - 2683' 5380 2670 Intermediate 2091' 10-3/4" 55.5# N-80 29' - 2120' 29' - 2120' 5210 2480 Production 7275' 9-5/8" 47# N-80 2108' - 9383' 2108' - 7193' 6870 4760 Liner 1851' 7-5/8" 29.7# NT95S 9204' - 11055' 7098' - 8543' 8180 5120 Liner 1012' 5-1/2" 17# L-80 10850' - 11862' 8368' - 8995' 7740 6280 Liner 2365' 3-1/2"x3-3/16"x2-7/8" 11495' - 13860' 8851' - 9037' ~ ~ '` Perforation depth: Measured depth: S 1 1 750 - 1 1 782 O 12370 - 12400 O 12900 - 13650 O 12470 - 12500 O 12630 - 12660 True Vertical depth: 8963 - 8973 9038 - 9037 9036 - 9036 9032 - 9033 9034.18 - 9037.25 Tubing: (size, grade, and measured depth) 4-112" 12.6# L-80 SURFACE - 10847 0 0 - Packers and SSSV (type and measured depth) 7-5/8" bkr sbp 9211 7-518"x4-112" sabl-3 pkr 10780 5-1/2" bkr h pkr 10857 0 0 12. Stimulation or cement squeeze summary: Intervals treated (measured): Treatment descriptions including volumes used and final pressure: 13. Representative Daily Average Production or Injection Data Oil-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing pressure Prior to well operation: 257 10493 0 514 Subsequent to operation: 14. Attachments: 15. Well Class after proposed work: Copies of Logs and Surveys Run Exploratory ~ Development ~' Service Daily Report of Well Operations X 16. Well Status after proposed work: Oil ~! Gas WAG ~' GINJ ~ WINJ ~ WDSPL 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 Gary Preble Printed Name Gary Prebl Title Data Management Engineer Signature Phone 564-4944 Date 3/6/2008 Form 10-404 Revised 04!2006 ~I ' 1J ~ ~ ~ ` ~ `'' P~ ~ I ~"~- Submit Original Oniy • C: D-07B DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS EVENT SUMMARY ACT{YITYflATE : SUMMARY " 2/27/2008~"'"`CTU 9 - 1.75" CT -Add Perfs ~"" «InterAct not publishing» MIRU /Conduct rweekly BOPE Test -RIH w. PDS memory GR/CCL ...Continue job on 2/28/2008... dv.___ __~.~ __.. e.d_~~ _n_. „_..~ _ .~.~~ .e.. ~____ ..a..m. ._.v__ ~...~_~_ 2/28/2008 "`*"CTU 9 Continue lob from 2/27/2008""" «InterAct not publishing» Log w. PDS GR/CCL from 12700' CTM stop C«3 12440' and flag pipe, continue logging up to ;12300' CTM OOH w. good data. -3' correction. Make three runs with 2" x 30' =HSD, 6 spf, 60 deg. phasing and add perforations. RIH w/ BHA #1 pert from 12630'-12660' BHA #2 pert from 12470'-12500' BHA #3 perf from 12370'-12400' .Continue job on 2/29/2008... 2/29/2008 """CTU 9 Continue job from 2/28/2008**'' Job Scope Add Perfs «InterAct not publishing» RIH w. Gun #3 perforate 12370'-12400' all shots fired. Freeze- protect tubing w. 38 bbls 60/40 meth. Left well S/I ""** Notify PCC / PO well ready to POP """'" Job Complete """" FLUIDS PUMPED BBLS 229 60/40 METH 25 1% KCL 254 Total ~~ aLCl 'J DATA SUBMITTAL COMPLIANCE REPORT 2is~2oo8 Permit to Drill 2051810 Well Name/No. PRUDHOE BAY UNIT D-076 MD 13862 TVD 9037 Completion Date 12/7/2005 REQUIRED INFORMATION Mud Log No DATA INFORMATION Types Electric or Other Logs Run: MWD, GR, RES, CNL, CCL Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name ED D Asc Di//rectional Survey /,, C Las 15520dGamma Ray ;.Cog Neutron A C Lis 15883 Gamma Ray Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y V Chips Received? '"YTIV"'~ Analysis ~L~4- Received? Comments: Compliance Reviewed By: _ __ __ ____ _ (data taken from Logs Portion of Master Well Data Maint Operator BP EXPLORATION (ALASKA) INC API No. 50-029-20162-02-00 Completion Status 1-OIL Current Status 1-OIL UIC N Samples No Directional Su Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments 11834 13862 Open 1/9/2006 10621 13758 Open 10/3/2007 CCL, FCNL, GR, NCNL w/EMF and PDS graphics 5 Blu 1 10632 13746 Open 1/22/2008 Mem CNL in Carrier, Mem LEE CCL, GR 4-Dec-2005 10636 13746 Case 1/22/2008 LIS Veri, GR CNT Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? Formation Tops ~/ N - --- __ _- - - --- _ -- rr- ~ - `` ~~ -- - __._ Date _-~2~~.. ~ V~ 01 /11 /08 n ~J ~chl~rmb+~rg~r NO. 4547 Alaska Data & Consulting Services Company: State of Alaska 2525 Gambeii Street, Suite 400 Alaska Oil 8 Gas Cons Comm Anchorage, AK 99503-2838 Attn: Christine Mahnken ATTN: Beth 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: P.Bay, Milne Pt. WPII Jnh # Lna Dascrintinn Data RI_ Cnlnr rn Z-O6 11594523 STATIC TEMP LOG ~ - 09/09/07 14-186 11975743 SBHP SURVEY 12/08/07 1 14-02C 11767144 SBHP LOG - 11/02/07 1 H-24A 11963073 MEM CBL -~ 11/30107 1 C-35A 11624351 CEMENT BOND & GRAVEL PACK ^a 11/03/07 1 MPH-19 11982423 USIT ~ ~f 12/10/07 1 1 E-03A 11628773 MEM PROb PROFILE - ( 05/09/07 1 E-11B 11434760 OH LDWG EDIT (DSI) - G 10/29/06 1 1 G-06A 11209587 MCNL - (~ ~-~ 02/25/06 1 1 D-07B 11162822 MCNLJr"- 12104105 1 1 G-10C 11209607 MCNL Q(p - a 06/15/06 1 1 G-096 11649989 MCNL ~ ~} - ~ ! U ( 0 C5 ~ 09/11/07 1 1 K-086 11745243 MCNL 9 "~ ~ ~S 11/06/07 1 1 V-07 11978425 COMPOSITE CBL 12/06/07 1 V-07 11978425 USIT - L 12/06/07 1 L2-33 11970801 RST / - V ~ 07/07/07 1 1 03-14A 40013340 OH MWD/LWD EDIT ~ I 04/23/06 2 1 L'~- PLtASt AGKNUW~tUGE RtGtIPT 6Y SIGNING ANU RETURNING ONE GUPY EACH TO: 8P Exploration (Alaska) Inc. Petrotechnical Data Center LR2-1 900 E. Benson Blvd. •~; Anchorage, Alaska 99508 Date Delivered: r~ °' Alaska Data & Consulting Services 2525 Gambell Street, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth ~~ Received by: 'l Date 09-28-2007 Transmittal Number:92905 .~ BPXA WELL DATA TRANSMITTAL Enclosed are the materials listed below. (BPXA FIELD LOG DATA) F you have any questions, please contact llougias Uortcn at the rli~ at oo~+-may ~ ~ Delivery Contents 1 CD-ROM Containing Field Log Data & Electronic Log Prints for the following wells: 02-35B ~OCo-U6a ~ lSSrS 07-07B ~j Cp -O ZSl ~ f 55- ~ ~- l'~- C-166 ~p(~-~5 ( ! 55 C-34A c70~-(73~- # tS~^7 jf D-07B c?O S-l ~S 1 ~ t ~~ G-06A ~b (o -bl c~ ~ ~`~ s`~O~ G-10C oZU~.-O~°! ~ ISJ~ Please Sign and Return one copy of this transmittal. Thank You, Douglas Dortch Petrotechnical Data Center Attn: State of Alaska - AOGCC Attn: Christine Mahnken 333 W. 7th Ave, Suite 100 Anchorage, Alaska 99501 Petrotechnical Data Center LR2-1 900 E. Benson Blvd. PO Box 196612 Anchorage, AK 99519-6612 RECEIVED STATE OF ALASKA ALASK~L AND GAS CONSERVATION COM ~SION FEB O 7 ZOOG WELL COMPLETION OR RECOMPLETION REPORT AND L Ai~ska Oil & Gals Cons. Commi3~~ln Anchor~ols 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned zoAAC zs.,os ^ GINJ ^ WINJ ^ WDSPL No. of Completions ^ Suspended ^ WAG zoAAC zs.,,o One Other 1b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 12/7/2005 12. Permit to Drill Number 205-181 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 11/29/2005 13. API Number 50-029-20162-02-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 12/3/2005 14. Well Name and Number: PBU D-07B 2280 FNL, 1067 FEL, SEC. 23, T11 N, R13E, UM Top of Productive Horizon: 3541' FSL, 3231' FEL, SEC. 14, T11 N, R13E, UM g, KB Elevation (ft): 69' 15. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay Pool Total Depth: 2177' FSL, 4053' FEL, SEC. 14, T11 N, R13E, UM 9. Plug Back Depth (MD+TVD) 13826 + 9039 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 654100 y- 5958721 Zone- ASP4 10. Total Depth (MD+TVD) 13862 + 9037 Ft 16. Property Designation: ADL 028285 _ TPI: x-_ 651812 __ y- 5964497 Zone- ASP4 Total Depth: x- 651019 y- 5963117 Zone- ASP4 11 • Depth where SSSV set None MD 17. Land Use Permit: ~- ~~~~~~~~~~~~~~~-~~--~ ------------------ Thi k f P f t 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL ness o erma ros c 20. 1900' (Approx.) 21. Logs Run: MWD , GR , RES , CNL , CCL 2. ASING, INER AND EMENTING ECORD CASING ETTINCa EPTH MD ETTINO EPTH ND DOLE MOUNT SIZE WT. PER FT: GRADE OP TTOM OP TTOM `SIZE CEMENTING RECORD. PULLED See Attachment 23. Perforations open to Produc tion (MD + TV D of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 2" Gun Diameter, 6 SPF 4-1/2", 12.6#, L-80 10847' 10780' MD TVD MD TVD 12900' - 13650' 9034' - 9037 25. Aclo, FRACTURE, CEMENT. SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protected with 26 Bbls McOH 26• PRODUCTION TEST Date First Production: January 5, 2006 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test 1/3/2006 Hours Tested 4 PRODUCTION FOR TEST PERIOD OIL-BBL 94 GAS-MCF 880 WATER-BBL 8 CHOKE SIZE 176 GAS-OIL RATIO 9363 Flow Tubing Press. 15 Casing Pressure 900 CALCULATED 24-HOUR RATE OIL-BBL 564 GAS-MCF 5282 WATER-BBL 48 OIL GRAVITY-API (CORK) 26.7 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chipBfi if none, state "none". CO"9~lEl'10;~~ None `('~ ~~. ht8 ~, ~ ~i)os Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE 28. GEOLOGIC MARKER 29' ORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". None Sag River 10949' 8454' Shublik 10986' 8485' Top of Sadlerochit 11046' 8535' Top of Zone 1 B 12090' 9027' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Sondr~Stewm Title Technical Assistant Date~~ " ~ ~ - (~ ~/ PBU D-07B 205-181 Prepared By Name/Number.• Sondra Stewman, 564-4750 Well Number Permit No. / A royal No. DnllingEngineer: MaryEndacott, 564-4388 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 ia: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITEM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: True vertical thickness. ITEM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITEM 29: List all test information. If none, state °None". Form 10-407 Revised 12/2003 Submit Original Only • WELL NAME: D-076 Name • 22. Attachment -Casing, Liner and Cementing Record Casing Setting Depth MD Setting Depth TVD Hole Size Wt. Per Ft. Grade Top Bottom Top Bottom Size Cementing Record 20" 94# H-40 27' 131' 27' 131' 26' 150 sx Arctic Set 13-3/8' 72# N-80 27' 2683' 27' 2683' 18-1/2" 3550 sx Arctic Set 10-3/4" 55.5# N-80 27' 2120' 27' 2120' 13-3/8" Tieback w/ 3 jts Thermocase II 9-5/8" 47# N-80 2108' 9383' 2108' 7193' 12-1/4" 1213 HES Light, 200 sx'G', 300 sx'G' 7-5/8" 29.7# NT95S 9204' 11055' 7098' 8543' 8-1/2° 250 sx Class 'G' 5-1/2` 17# L-80 10850' 11862' 8368' 8995' 6-3/4" 94 sx Class 'G' 3-1/2' x 3-3/16" x 2- 7/8' 8.81 # / 6.2# / 6.16# L-80 11495' 13860' 8851' 9037' 4-1/8" 145 sx Class 'G' BP EXPLORATION Operations Summary Report Legal Well Name: D-07 Common Well Name: D-07 Event Name: DRILL+COMPLETE Start: 11/22/2005 Contractor Name: NORDIC CALISTA Rig Release: 12/7/2005 Rig Name: NORDIC 1 Rig Number: 1 Date !From - To ~ Hours Task Code NPT Phase 11/25/2005 20:30 - 22:00 1.50 RIGD P PRE 22:00 - 00:00 2.00 MOB P PRE 11/26/2005 00:00 - 16:00 16.00 MOB P PRE 16:00 - 20:45 4.75 RIGU N PRE 20:45 - 21:00 0.25 RIGU P 21:00 - 00:00 3.00 RIGU P 11 /27/2005 100:00 - 01:00 I 1.00 I RIGU I P 01:00 - 01:30 0.50 MOB P 01:30 - 04:30 3.00 BOPSU P 04:30 - 10:00 5.50 BOPSU P 10:00 - 10:30 0.50 RIGU P 10:30 - 11:30 1.00 RIGU P 11:30 - 12:45 1.25 RIGU P 12:45 - 13:15 0.50 RIGU P 13:15 - 13:45 0.50 RIGU P 13:45 - 16:00 2.25 CLEAN P 16:00 - 16:30 0.50 CLEAN P 16:30 - 19:00 19:00 - 19:45 19:45 - 21:00 21:00 - 00:00 2.50 CLEAN P 0.75 WHIP P 1.25 WHIP P 3.00 WHIP P 11 /28/2005 ~ 00:00 - 01:25 01:25 - 03:35 03:35 - 04:00 04:00 - 04:25 1.421 WHIP I P 2.17 WHIP P 0.42 WHIP P 0.42 WHIP P PRE PRE PRE PRE PRE PRE PRE WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT WEXIT Page 1 of 6 Spud Date: 6/20/1975 End: Description of Operations Prep rig for rig move Moving CT Rig -Nordic 1 f/ DS 15-48B to D-07 Moved rig f/ DS 15-48B to D pad, spot rig on location RU Hot Oil on D-07, test lines to 4000 psi, Waiting on Vac Trks w/ KCL water, PJSM -discussed pumping operations OA - 0 psi, IA - 100 psi, Tubing - 2350 psi, RU on IA, Test line to 3000 psi, Pressured up on IA w/ McOH to 1000 psi (2 .5 bbls to fill IA and 3 .3 bbls to pressure up to 1000 psi), RU on TBG, Test line to 4000 psi, Pump 5 bbls of McOH, 286 bbls of 120 degree 2 percent KCL at 5 bpm 2500 - 500 - 1600 psi, IA 1250 psi, OA 0 psi, pump pressure started increasing f/ 500 - 1600 psi after pumping 164 bbls, final pump pressure 2150 psi w/ 285 bbls pumped, IA 1350 psi, OA 20 psi, switched to Vis Flo-Pro pumped 20 bbls displaced w/ 150 bbls of 120 degree 2 percent KCL at 5 bpm 2150 psi, Slowed pumps down to 3 bpm 1400 psi, pressure increased to 1500 psi after pumping 165 bbls, switch and pumped 5 bbls of McOH. Shut in Well Bled off IA to 0 psi, OA - 0 psi, tubing 0 psi, monitor for 30 minutes, Well Dead. P/T tubing hgr void to 5000 psi for 15 min, ok. RD Hot Oil PJSM - MI Rig, spot and set over D-07, Rig Accepted at 01:30 hours on 11/27/2005 NU BOP Stack, grease crew serviced manifold and HCR valves, support crew RU tiger tank and PR line, spot cuttings tank. Testing BOP's, all lines, valves and rams f/ 350 - 3500 psi, annular f/ 250 - 2500 psi. AOGCC Lou Grimaldi witnessing, Eiden/Bordes witnessing for BP Conduct Pre-Spud and safety meeting in doghouse with all related personnel. PU dimpled CTC with LH threads. Install connector. Pull test to 40K. Held. Displace coil volume (66 bbls total) with 2% KCI. Test Inner Reel Valve to 3500 psi. Held. Test CTC to 3500 psi. Held PU LH motor BHA to mill XN Nipple ID. RIH w/ CT and 3.8" Milling asst' to 10833' at 100 fpm. Mill Otis XN nipple. Mill with 1 K WOB, 2.5 bpm. Mill through and ream/backream through nipple several times. POOH w/ CT, LD milling asst' Behead RH CTC, pull and PR, OK MU Whipstock BHA, Stab Injector RIH w/ Whipstock BHA, surface test MWD and orientor, OK, RIH RIH w/ Whipstock to 11810', Log down to 11846', tie-in to PDF Coil Flag Log dated Feb 05, +2' correction, RIH to 11872' BOWS, closed FAIV w/ 4200 psi, Bled off, pressured up to 3300 psi, sheared off and set whipstock, TOWS at 11860', 12 deg LHS POH to BHA POH, LD WS setting tool, MWD tools MU window mill asst', stab injector Printed: 12/21/2005 1:52:34 PM BP EXPLORATION Page 2 of 6 Operations Summary Report Legal Well Name: D-07 Common W ell Name: D-07 Spud Date: 6/20/1975 Event Nam e: DRILL+C OMPLE TE Start : 11(22/2005 End: Contractor Name: NORDIC CALIS TA Rig Release: 12/7/2005 Rig Name: NORDIC 1 Rig Number: 1 Date From - To Hours Task ! Code NPT Phase Description of Operations 11/28/2005 04:25 - 07:00 2.58 WHIP P WEXIT RIH w/ window mill assy. Tag at 11862' uncorrected at 8 fpm. Attempt to PU and pulling heavy. Work pipe and still pulling heavy as well as pressuring up. Hold pressure at 3000 psi and pull to 76K as fast as possible. Came free. 07:00 - 14:45 7.75 STWHIP P WEXIT Set down on window lightly. Being milling window at 1'/hr. Using light weight and pumping at 2.5 bpm to reduce stalling (tray is sticking us pretty good initially). Window milled down to 11866.4' and then milled 10 feet of formation. Work through window several times to ensure no tight spots and that window is in good order. 14:45 - 18:00 3.25 STWHIP N WAIT WEXIT Circ while waiting on vac trucks w/ reconditioned Flo-Pro mud w/ 10 ppb KLA-CARD and 3 Percent Lubetex 18:00 - 18:45 0.75 STWHIP P WEXIT Circ Flo-Pro to window mill at 11860' 18:45 - 20:45 2.00 STWHIP P WEXIT POH to BHA while displacing well to Flo-Pro at 2.5 bpm 2115 - 2575 psi 20:45 - 21:30 0.75 STWHIP P WEXIT POH LD Window Mill BHA 21:30 - 00:00 2.50 DRILL P PROD1 MU Drlg BHA, PU 2.2 deg Motor, Bit, MWD-GR-RES, Orient, upload MWD tools, MHA, Behead to SLB CTC, pull and P/T good, stab injector 11/29/2005 00:00 - 02:15 2.25 DRILL P PROD1 RIH w/ BHA, shallow hole test MWD and Orientor, all good, RIH to 11877', no problems, Up Wt 42 K, Dn Wt 23 K 02:15 - 02:50 0.58 DRILL P PROD1 Orient TF around to 41 L 02:50 - 04:25 1.58 DRILL P PROD1 Dir Drill w/ 2.6 bpm 3400 psi, 40 fph 04:25 - 05:05 0.67 DRILL P PRODi Orient TF around to 100 L 05:05 - 05:20 0.25 DRILL P PROD1 Dir Drill w/ 2.67 bpm 3530 psi, 40 fph 05:20 - 06:30 1.17 DRILL P PROD1 Run tie-in pass to RA tags and primary. + 1.5' correction. RBIH to bottom. 06:30 - 07:15 0.75 DRILL P PROD1 Orient TF to 120L- only attaining 6 degree clicks. 07:15 - 12:15 5.00 DRILL P PROD1 Drill ahead. Q=2.5 bpm, 3300 psi (3050 FS), 43K PU/ 18K SO, 50'/hr 12:15 - 13:20 1.08 DRILL P PROD1 Orient TF to 70 L, Dir Drill w/ 2.62 bpm, 3550 psi, 55 fph 13:20 - 13:40 0.33 DRILL P PROD1 Wiper Trip to Window 13:40 - 15:50 2.17 DRILL P PROD1 Dir Drill w/ 2.65 bpm, 3550 psi, 55 fph 15:50 - 18:00 2.17 DRILL P PROD1 POH to BHA 18:00 - 21:00 3.00 DRILL P PROD1 Change out orienter and dial motor down to 1.2 degree. Down load MWD data. 21:00 - 22:45 1.75 DRILL P PROD1 RIH to 3000 shallow hole test orienter 10 degree clicks. Continue to RIH to 11930'. 22:45 - 23:00 0.25 DRILL P PROD1 Tie-in correction -1.5'. 23:00 - 23:30 0.50 DRILL P PROD1 RIH begin swapping to new mud. 23:30 - 00:00 0.50 DRILL P PRODi Orient 145L. 11/30/2005 00:00 - 03:40 3.67 DRILL P PROD1 Directionally drill 2.5/2.5 bpm @ 3' 150 psi FS = 2800 psi, CT wt 8K, ROP 30, GR 03:40 - 04:00 0.33 DRILL P PROD1 Orient gettting 10 degree clicks. to 88L 04:00 - 05:30 1.50 DRILL P PROD1 Directionally drill 2.5/2.5 bpm @ 3150 psi FS = 2800 psi, CT wt 8K, ROP 30, GR 05:30 - 06:00 0.50 DRILL P PROD1 Wiper trip to window, RIH to Btm, no problems 06:00 - 08:25 2.42 DRILL P PROD1 Directionally drill 2.7 bpm @ 3600 psi, ROP 70 - 120 fph 08:25 - 09:55 1.50 DRILL P PRODi Wiper trip to tbg tail, RIH to Btm, no problems 09:55 - 11:10 1.25 DRILL P PROD1 Directionally. drill 2.66 bpm @ 3600 psi, ROP 70 - 120 fph 11:10 - 11:40 0.50 DRILL P PROD1 Orient TF around to 110 L 11:40 - 13:45 2.08 DRILL P PROD1 Directionally drill 2.61 bpm @ 3500 psi, FS 3000, ROP 70 fph 13:45 - 14:30 0.75 DRILL P PROD1 Wiper trip to window, RIH to Btm, no problems Printed: 12/21/2005 1:52:34 PM BP EXPLORATION Operations Summary Report Page 3 of 6 Legal Well Name: D-07 Common Well Name: D-07 Spud Date: 6/20/1975 Event Name: DRILL+COMPLETE Start: 11/22/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 12/7/2005 Rig Name: NORDIC 1 Rig Number: 1 Date ~! From - To Hours ' Task Code NPT I~~ Phase ~ Description of Operations 11/30/2005 14:30 - 16:55 2.42 DRILL P PRODi Orient TF to 52 L, Directionally drill 2.65 bpm ~ 3600 psi, FS 3000, ROP 88 fph 16:55 - 20:10 3.25 DRILL P PROD1 Orient TF around to 60 R Drill to 12800'. 20:10 - 20:35 0.42 DRILL P PROD1 Wiper to tie-in C~3 11906'. 20:35 - 21:13 0.63 DRILL P PROD1 Tie-in correction +8'. 21:13 - 22:35 1.37 DRILL P PROD1 Continue wiper trip to tubing tail. Clean trip. 22:35 - 00:00 1.42 DRILL P PROD1 Directionally drill 2.5/2.5 bpm@ 3400 psi. 3000psi = FS.CT wt -5K, Drilled to 12840'. 12/1/2005 00:00 - 06:35 6.58 DRILL P PROD1 Directionally drill 2.5/2.5 bpm @ 3200 psi, FS= 3000psi. Drilling 06:35 - 07:35 I 1.00 DRILL P PROD1 07:35 - 10:45 3.17 DRILL P PROD1 10:45 - 11:20 0.58 DRILL N STUC PROD1 11:20 - 15:30 4.17 DRILL N STUC PROD1 15:30 - 15:30 24.00 DRILL N STUC PROD1 15:30 - 16:30 1.00 DRILL N STUC PROD1 16:30 - 16:45 16:45 - 18:00 18:00 - 18:30 18:30 - 22:10 0.25 DRILL N 1.25 DRILL N 0.50 DRILL N 3.67 DRILL P STUC PROD1 STUC PRODi STUC PROD1 PROD1 12/2/2005 22:10 - 00:00 00:00 - 00:15 00:15 - 04:30 04:30 - 05:50 05:50 - 06:50 06:50 - 07:40 07:40 - 09:50 09:50 - 13:05 13:05 - 13:20 13:20 - 13:50 13:50 - 15:20 15:20 - 15:50 15:50 - 16:30 16:30 - 18:30 18:30 - 21:00 1.83 DRILL P 0.25 DRILL P 4.25 DRILL P 1.33 DRILL P 1.00 DRILL P 0.83 DRILL P 2.17 DRILL P 3.25 DRILL P 0.25 DRILL P 0.50 DRILL P 1.50 DRILL P 0.50 DRILL P 0.67 DRILL P 2.00 DRILL P 2.50 DRILL P PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 with negative wt. Extremely slow drilling. stacking making short wipers. Wiper trip to window, RIH to Btm, no problems Directionally drill 2.6/2.6 bpm Q 3200 psi, FS= 3000psi, ROP 80 - 120 fph Lost differential pressure, picking up off btm, pipe stuck, attempt to work free w/ up wt 86K and do wt 10K, Motor Stalled, Working pipe, Slacked off to neutral wt 22 - 23 K, shut down pumps 15 min, worked pipe, several times Wait on Crude Tanker, continue to work pipe as above, test crude for flash point level, replaced valve block on P-14 power pack Attempt to work pipe free w/ no success, mud motor freed up, no longer stalled. RU crude lines, thaw out frozen valve on crude tanker, slacked off to neutral wt at 25 K, pump 10 bbls of crude, displace w/ 60 bbls of flo-pro at 2.5 bpm, 3650 psi Worked pipe free Perform wiper to window w/ tie-in pass tie - in correction +15'. RIH, displaced well w1 new Flo-Pro mud Directionally drill 2.6 / 2.6 bpm @3600 psi, FS = 3100 psi ,Up wt 41 K, DN wt 16K, drill to 13200. Wiper to tubing tail. Wiper to tubing tail. Clean trip. Directionally drill 2.7 / 2.7 bpm at 3600 psi FS = 3300 psi. ROP 80-120. Drill to 13350'. Wiper to window. Orient TF to 90 L, Directionally drill 2.7 / 2.7 bpm at 3600 psi FS = 3300 psi. ROP 80-120 Orient TF around to 120 L Directionally drill 2.6 / 2.6 bpm at 3600 psi FS = 3300 psi. ROP 80-120, Pit Vol 263 bbls Wiper to tbg tail w/ tie-in pass tie - in correction +10'. Directionally drill, TF 90 L, 2.6 / 2.6 bpm at 3600 psi FS = 3300 psi. ROP 80-120, Pit Vol 250 bbls Orient TF around to 90 R Directionally drill 2.66 / 2.66 bpm at 3600 psi FS = 3300 psi. ROP 80-100, Pit Vol 247 bbls Orient TF around to 22 R Directionally drill 2.6 / 2.6 bpm at 3600 psi FS = 3300 psi. ROP 80-110, Pit Vol 246 bbls Wiper to window. Directionally drill 2.7 / 2.7 bpm at 3600 psi FS = 3300 psi. ROP Printed: 12/21/2005 1:52:34 PM BP EXPLORATION Page 4 of 6 Operations Summary Report Legal Well Name: D-07 Common Well Name: D-07 Event Name: DRILL+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 1 Date From - To Hours ' Task 'Code' NPT __ _ __ - - - - - 12/2/2005 18:30 - 21:00 2.50 ~ DRILL ~ P 21:00 - 00:00 3.00 DRILL N DFAL 12/3/2005 00:00 - 05:30 5.50 DRILL N DFAL 05:30 - 09:00 3.50 DRILL N DFAL 09:00 - 09:30 0.50 DRILL N DPRB 09:30 - 11:00 1.50 DRILL P 11:00 - 11:20 I 0.331 DRILL I P 11:20 - 13:50 2.50 DRILL P 13:50 - 15:20 1.50 DRILL P 15:20 - 16:15 0.92 DRILL P 16:15 - 19:30 3.25 DRILL P 19:30 - 21:30 2.00 DRILL P 21:30 - 22:00 I 0.501 DRILL I P 22:00 - 23:45 1.75 DRILL P 23:45 - 00:00 0.25 DRILL P 12/4/2005 00:00 - 02:00 2.00 DRILL P 02:00 - 02:15 0.25 CASE P 02:15 - 09:30 7.25 CASE P 09:30 - 11:45 2.25 CASE P 11:45 - 12:10 0.42 CASE P 12:10 - 14:00 I 1.831 CASE I P Spud Date: 6/20/1975 Start: 11/22/2005 End: Rig Release: 12/7/2005 Rig Number: 1 Phase Description of Operations PROD1 60-110, Pit Vol 234 bbls. CT Wt -15K. Having trouble holding tool face. Being throw all around. Made the fault? Drilled to 13670'. Stopped drilling stalling with little wt to bit. Decided to POH to look at bit and motor. MWD working OK. PROD1 POH. Washout in XO below MWD. PROD1 LD BHA found washout in lower Sperry XO. Changeout bit, motor ,orienter and adgitator. (adgitator made up with new XO with 1" ID and torqued to 4000 ft/Ib per Stress Engr Recommendation pin connection also bakerlocked). Down load MW D data. Cut 9' of coil. Install Baker coil connector. PROD1 RIH to 11978', performed tie-in pass, -2' correction, RIH to btm PROD1 Orient TF to 36 L PROD1 Directionally drill 2.5 / 2.5 bpm at 4125 psi, FS = 3800 psi at 2.6 bpm. ROP 80-110, Pit Vol 213 bbls PROD1 Orient TF to 20 L, Directionally drill 2.5 / 2.5 bpm at 4125 psi, FS = 3800 psi at 2.6 bpm. ROP 80-110, Pit Vol 206 bbls PROD1 Wiper to window. PROD1 Orient TF to 20 L, Directionally drill 2.45 / 2.45 bpm at 3900 psi, FS = 3800 psi at 2.6 bpm. ROP 135 - 175', Pit Vol 194 bbls, Hard to hold TF, pump pressure increased 300 psi f/ 4100 to 4400 psi at 2.45 bpm, reduced pump rate to 2.25 bpm at 4100 psi. Geo called TD. PROD1 Circ off btm, RIH to btm f/ 13600' - 13851' PROD1 Madd pass openhole at 800 fph w/ 2.25 bpm w/ 4200 psi, and perform tie-in pass Correction +11'. PROD1 RIH tag TD at 13862'. Lay in Flow pro Pill. Pul! up above Window to 11211. Drop 3/4" to open Baker circulation sub. PROD1 Circulate ball to cir sub. Shear at 3300psi at 48 bbls displacement .Coil vol 60.6 bbl. PROD1 POH to surface. PROD1 LD BHA. Down load MWD data. PROD1 LD BHA. No indication of what was causing the higfher pressure. Bit in good shape graded 3-3. No jets plugged. Clear floor. RUNPRD PJSM for Pu liner. RUNPRD PU 2 7/8" x 3 3/16" x 3 1/2" Liner Assy, MU Baker CTC, Pull and P/T CTC, OK, Pump volume dart, calculated displacement 60.6 bbls, actual displacement 58.9 bbls, stab injector RUNPRD RIH w/ liner assy, EOP flag + 6', RIH, tagged btm at 13856', corrected to 13862', Up Wt 43 k, Dn wt 22 k RUNPRD Load 5/8" steel ball &circ with @ 2.57 bpm & 3215 psi, reduced rate @ 46 bbls away to 1.55 bpm at 2360 psi. Continue circ ball to seat. Ball on seat @ 51.3 bbls. Pressure up to 4750 psi & release CTLRT. P/U @ 39 k & confirm release. RUNPRD Circ well to 120 degree 2% KCL water w/ 2.57 bpm at 3075 - 2000 psi. Send used Flo-Pro to MI for reconditioning. R/U SLB cementers. Fill rig pits with KCL. Mix 30 bbl 2 ppb Biozan pert pill. 14:00 - 14:15 I 0.251 CEMT I P RUNPRD PJSM w/ SLB cementers and rig personnel concerning cementing operations, continue displacing well to 2% KCI at 2.5/2.45bpm w/ 2000 psi. PV 313 bbls Printed: 12/21/2005 1:52:34 PM BP EXPLORATION Operations Summary Report Page 5 of 6 Legal Well Name: D-07 Common Well Name: D-07 Spud Date: 6/20/1975 Event Name: DRILL+COMPLETE Start: 11/22/2005 End: Contractor Name: NORDIC CALISTA Rig Release: 12/7/2005 Rig Name: NORDIC 1 Rig Number: 1 Date i From - To ' Hours ' Task !, Code . NPT Phase Description of Operations 12/4/2005 14:00 - 14:15 ~ 0.25 CEMT ~ P ~ ~ RUNPRD I 14:15 - 15:50 1.58 CEMT P RUNPRD Batch mix 33 bbls 15.8ppg 'G' latex cmt with additives. Cmt to wt @ 14:40 hrs. Pump 5 bbls of FW, PT lines to 4k. Pump 30 bbls cmt slurry C~ 2.0/1.9 bpm w/ 1700 - 1500 psi. Close inner reel valve & clean lines. Load/launch CTWP with 500psi. Chase with 30 bbls Biozan pill & 30 bbls KCL water @ 3.0 - 2.8/2.7 - 2.80 bpm w/ 1300 - 2500 -1950 psi. slowed rate 1.5 bpm w/ 500 - 750 psi, CTW P engage LW P ~ 59.6 bbls away. Shear plug with 2970 psi. Continue displacing LWP @ 2.3 / 2.2 bpm w/ 1650 - 1800 psi, bump C~ 74.6 bbls away with 1000psi over to 2800 psi. Bleed off & check floats ~ held. Pressure up to 500 psi, sting out of liner. 23.5bbls cmt pumped around shoe. CIP @ 15:41 hrs on 12/04/05. 15:50 - 18:30 2.67 CEMT P RUNPRD POOH w/ baker R/T, circ 1 bbl Cam? .45 bpm on TOL. POOH 60 - 110 fpm pumping @ .5 - .80 bpm to replace CT voidage only. 18:30 - 19:00 0.50 BOPSU P RUNPRD Function test BOP 19:00 - 19:30 0.50 EVAL P LOWERI PJSM for picking up logging tools and cleanout assy. 19:30 - 22:30 3.00 EVAL P LOWERi Pu logging BHA and 79 stands of CSH. Pu injector and stab onto well. 22:30 - 00:00 1.50 EVAL P LOWERI RIH to 9700. 12/5/2005 00:00 - 02:45 2.75 EVAL P LOWERI WOC 02:45 - 03:00 0.25 EVAL P LOWERI RIH to 10700. 03:00 - 04:45 1.75 EVAL P LOWERI Log down from 10700 to PBTD at 30 fUmin. 04:45 - 05:45 1.00 EVAL P LOWERI Log up at 60 ft/min to 10700'. 05:45 - 07:30 1.75 EVAL P LOWERI POH to Memory CNL BHA 07:30 - 10:00 2.50 EVAL P LOWERI POH w/ CNL BHA, Std back 1 1/4" CS Hydril, LD logging tools, motor and bit 10:00 - 11:00 1.00 EVAL P LOWERI Flush stack and tree w/ swivel stick nozzle 11:00 - 12:30 1.50 CEMT P RUNPRD RU Hot Oil, P/T lines to 2000 psi, Pressure up, hold 1000 psi on IA, P/T w/ rig pumps liner lap to 2000 psi, pressure fell off to 1800 psi in 10 min, check surface lines and equipment, no visible leaks found, retest with same results, test surface lines to 2000 psi, held for 15 min, OK, retest Line lap to 2000 psi, pressure fell off to 1600 psi in 10 min. Liner Lap Pressure test failed. 12:30 - 15:00 2.50 PERFO P LOWERI Loading and position guns in pipeshed 15:00 - 17:15 2.25 PERFO P LOWERI PJSM, RU handling tools, PU, RIH w/ 36 jts of 2" 6 spf 2006PJ Perf Guns - 768', RD handling tools 17:15 - 19:00 1.75 PERFO P LOWERI RU Handling tools, Run 28 stds of 1 1/4" CSH - 1731' 19:00 - 21:30 2.50 PERFO P LOWERI RIH to TD tag and correct to 13,834 Corrected. 21:30 - 22:00 0.50 PERFO P LOWERI Pump 10 bbl pill. PU to ball drop position. Launch 1/2" steel ball with 800 psi. and 5bbl pert pill. 22:00 - 22:30 0.50 PERFO P LOWERI Circulate ball to firing head. with 53.8 bbl PU to firing depth. Pressure up and shear at 3100 psi. Positive indication shots fired. 22:30 - 00:00 1.50 PERFO P LOW ER1 POH to CSH. 12/6/2005 00:00 - 01:00 1.00 PERFO P LOWERI POH to CSH. Set back injector. 01:00 - 03:00 2.00 PERFO P LOWERI Standback 28 stands of 1-1/4" CSH. 03:00 - 05:30 2.50 PERFO P ~ LOWERI LD and removed 36 pert guns from pipeshed. Printed: 12/21/2005 1:52:34 PM BP EXPLORATION Operations Summary Report Page 6 of 6 Legal Well Common W Event Nam Contractor Rig Name: Date ~ Name: ell Name: e: Name: From - To D-07 D-07 DRILL+C NORDIC NORDIC Hours OMPLE CALIST 1 Task TE A ~ Code NPT Start Rig Rig ~ Phase Spud Date: 6/20/1975 : 11/22/2005 End: Release: 12/7/2005 Number: 1 ~~ Description of Operations 12/6/2005 05:30 - 06:00 0.50 CASE P RUNPRD PJSM w/rig crew and Baker on handling proceedures running scab liner assy, RU handling tools 06:00 - 08:25 2.42 CASE P RUNPRD PU, RIH w/ Baker Seal Assy, 25 Jts - 3 1/2" 9.3# L-80 STL tbg and Deployment sleeve, stab injector 08:25 - 10:50 2.42 CASE P RUNPRD RIH w/ Scab Liner Assy, PU wt 50 K, S/O Wt 23 KCirc at .5 bpm w/ 157 psi, sting in deployment sleeve at -11495' w/ 6' seal assy, pressure increased, returns stopped, verifing seal assy stung into deployment sleeve. P/T backside w/ 900 psi, good. Pumped down CT at 3/4 bpm at 1500 psi, PU, released f/ deployment sleeve, pressure fell off, PU Wt 41 K w/o liner. 10:50 - 13:00 2.17 CASE P RUNPRD POH w/ Baker R/T- GS spear 13:00 - 14:00 1.00 CASE P RUNPRD LD GS and PU sealstem, KB packer 14:00 - 16:30 2.50 CASE P RUNPRD RIH Tag .Sting in while circulating .5 bpm @ 150 psi. Pressure backside to 1000 psi leak off to 950psi. PU to ball drop position. 16:30 - 18:00 1.50 CASE P RUNPRD Circulate 1/2" steel ball to setting tool.l.6 bpm @ 540 psi. 54.4 bbl ball on seat. Bleed off and RIH 10733 pu to neutral wt 10726.2 PU 2'. Pressure to 2400 psi .Slack off 10K. Packer set. Pressure backside to 2000 psi.while holding OIA @ 723 psi. Bleed down to 1925psi in 30 minutes, Good Test. Bleed down backside. 18:00 - 20:00 2.00 CASE P RUNPRD POH 20:00 - 21:00 1.00 CASE P RUNPRD Freeze protect 4-1/2" tubing from 2500' to surface with 26 bbls MEOH. 21:00 - 22:00 1.00 CASE P RUNPRD L/O KB packer running BHA. Recover 100%. 22:00 - 00:00 2.00 R1GD P POST Pickle 2-3/8" coil with 10 bbl Bleach, 40 bbl fresh water, 15 bbl corrosion inhibitor and 10 bbl MEOH. Press test N2 hardline. 12/7/2005 00:00 - 02:00 2.00 RIGD P POST Blow down reel with N2. Bleed reel pressure to zero. Blow down all surface lines to frac tank. Clean rig pits. 02:00 - 04:00 2.00 RIGD P POST Puil coil stub to reel and secure coil on reel for swap. 04:00 - 10:00 6.00 RIGD P POST C/O BOP rams for 2" coil operations. ND BOPE. Released rig at 10:00. Prepare to move rig to DS 13. Further DIMS information will be under well 13-31 A. Printed: 12/27/2005 1:52:34 PM ° a Halliburton Sperry-Sun North Slope Alaska BPXA D-07B Job No. AKMW4074252, Surveyed: 3 December, 2005 Survey Report 8 December, 2005 Your Ref: API 500292016202 Surface Coordinates: 5958720.64 N, 654099.11E (70° 17' 38.8870" N, 148° 45' 08.1103" IA/) Grid Coordinate System: NAD27 Alaska State Planes, Zone 4 • Kelly Bushing Elevation: 69.OOft above Mean Sea Level DR4~.1,{NG ssRVI Es Survey Ref:svy4772 A Halliburton Company Halliburton Sperry-Sun Survey Reporf for D-076 Your Ref: API 500292016202 Job No. AKMW4074252, Surveyed: 3 December, 2005 North Slope Alaska Measured True Sub-Sea Vertical Local Coordinates Depth Incl. Azim. Depth Depth Northings Eastings (ft) (ft) (ft) (ft) (ft) 11834.40 74.700 318.500 8918.65 8987.65 5680.09 N 1968.43 W 11862.70 75.770 318.470 8925.87 8994.87 5700.58 N 1986.57 W 11894.94 81.500 314.160 8932.22 9001.22 5723.42 N 2008.40 W 11930.56 86.700 311.690 8935.88 9004.88 5747.53 N 2034.33 W 11955.67 84.070 309.960 8937.90 9006.90 5763.89 N 2053.27 W 11992.84 79.560 302.390 8943.20 9012.20 5785.60 N 2082.93 W 12021.43 80.790 297.100 8948.08 9017.08 5799.57 N 2107.38 W 12047.41 81.500 290.230 8952.09 9021.09 5809.86 N 2130.88 W 12078.04 82.470 284.940 8956.36 9025.36 5819.02 N 2159.78 W 12116.05 83.260 274.190 8961.09 9030.09 5825.28 N 2196.92 W 12145.28 85.020 266.790 8964.08 9033.08 5825.52 N 2225.97 W 12182.90 87.750 259.740 8966.46 9035.46 5821.12 N 2263.23 W 12212.75 88.370 257.450 8967.47 9036.47 5815.22 N 2292.47 W 12248.78 86.780 252.700 8968.99 9037.99 5805.95 N 2327.24 W 12280.37 91.010 250.580 8969.60 9038.60 5796.01 N 2357.21 W 12312.21 89.520 246.180 8969.45 9038.45 5784.28 N 2386.80 W 12349.04 90.220 243.530 8969.54 9038.54 5768.63 N 2420.14 W 12380.77 91.720 242.480 8969.00 9038.00 5754.23 N 2448.41 W 12412.71 91.890 241.240 8968.00 9037.00 5739.17 N 2476.56 W 12442.05 90.660 237.540 8967.34 9036.34 5724.24 N 2501.80 W 12473.54 90.040 231.550 8967.15 9036.15 5705.98 N 2527.44 W 12506.27 89.780 225.560 8967.20 9036.20 5684.33 N 2551.96 W 12535.94 91.720 223.800 8966.81 9035.81 5663.24 N 2572.82 W 12554.36 93.570 224.500 8965.96 9034.96 5650.03 N 2585.63 W 12586.64 92.690 222.030 8964.20 9033.20 5626.57 N 2607.72 W 12621.69 89.960 216.750 8963.39 9032.39 5599.50 N 2629.95 W 12661.93 89.160 212.170 8963.70 9032.70 5566.33 N 2652.71 W 12695.52 88.550 207.590 8964.37 9033.37 5537.22 N 2669.44 W 12727.12 89.960 202.120 8964.78 9033.78 5508.56 N 2682.71 W 12761.89 90.570 202.830 8964.62 9033.62 5476.43 N 2696.00 W 12799.11 87.580 209.880 8965.22 9034.22 5443.11 N 2712.51 W 12829.80 89.250 211.290 8966.07 9035.07 5416.70 N 2728.12 W 12865.98 91.190 210.400 8965.93 9034.93 5385.64 N 2746.67 W 12904.27 91.370 213.050 8965.08 9034.08 5353.08 N 2766.80 W 12935.40 92.860 214.630 8963.93 9032.93 5327.24 N 2784.12 W Global Coordinates Northings Eastings (ft) (ft) 5964359.19 N 652014.64 E 5964379.30 N 651996.09 E 5964401.68 N 651973.80 E 5964425.26 N 651947.37 E 5964441.23 N 651928.10 E 5964462.33 N 651898.00 E 5964475.79 N 651873.27 E 5964485.60 N 651849.57 E 5964494.17 N 651820.48 E 5964499.66 N 651783.23 E 5964499.31 N 5964494.14 N 5964487.64 N 5964477.67 N 5964467.11 N 651754.18 E 651717.02 E 651687.90 E 651653.33 E 651623.57 E 5964454.78 N 5964438.45 N 5964423.47 N 5964407.84 N 5964392.39 N 5964373.61 N 5964351.46 N 5964329.95 N 5964316.48 N 5964292.57 N 5964265.05 N 5964231.42 N 5964201.97 N 5964173.05 N 5964140.65 N 651594.22 E 651561.21 E 651533.25 E 651505.41 E 651480.48 E 651455.22 E 651431.15 E 651410.73 E 651398.19 E 651376.58 E 651354.92 E 651332.84 E 651316.71 E 651304.03 E 651291.40 E Dogleg Vertical Rate Section Comment (°/100ft) -4977.08 Tie On Point 3.782 -4992.18 Window Point 22.079 -5008.58 16.145 -5025.17 12.524 -5036.07 23.523 -5049.36 18.732 -5056.52 26.270 -5060.39 17.392 -5061.75 28.139 -5058.18 25.893 -5050.90 20.060 -5037.00 7.944 -5023.74 13.891 -5005.78 14.977 -4988.42 14.589 -4969.43 7.442 -4945.69 5.770 -4924.47 3.917 -4902.64 13.286 -4881.68 19.123 -4857.41 18.318 -4830.15 8.828 -4804.37 10.737 -4788.30 8.112 -4759.92 16.954 -4728.02 11.554 -4690.09 13.753 -4657.64 17.874 -4626.52 2.692 -4592.05 5964107.00 N 651275.58E 20.570 -4555.59 5964080.27 N 651260.51E 7.120 -4526.04 5964048.84 N 651242.60E 5.899 -4491.24 5964015.88 N 651223.15E 6.935 -4454.58 5963989.69 N 651206.36E 6.974 -4425.14 BPXA • 8 December, 2005 - 15:27 Page 2 of 4 DrillQuest 3.03.06.008 Halliburton Sperry-Sun Survey Report for D-076 Your Ref.• API 500292016202 Job No. AKMW4074252, Surveyed: 3 December, 2005 North Slope Alaska Measured Depth (ft) 12973.48 13005.83 13043.79 13074.81 13106.31 13139.80 13175.10 13204.75 13237.45 13274.00 13305.74 13340.21 13374.68 13415.25 13450.97 13479.78 13505.51 13538.46 13571.57 13609.82 13642.74 13674.42 13694.04 13722.40 13762.08 True Sub-Sea Vertical Local Coordinates Global Coordinates Incl. Azim. Depth Dept h Northings Eastings Northings Eastings (ft) (ft) (ft} (ft) (ft) (ft) 92. 690 219.390 8962.08 9031. 08. 5296.88 N 2807.01 W 5963958.86 N 651184.10 E 91. 100 220.630 8961.01 9030. 01 5272.12 N 2827.79 W 5963933.68 N 651163.82 E 89. 160 219.220 8960.93 9029. 93 5243.01 N 2852.15 W 5963904.08 N 651140.07 E 89. 520 216.220 8961.28 9030. 28 5218.47 N 2871.13 W 5963879.16 N 651121.60 E 90. 040 214.630 8961.40 9030. 40 5192.81 N 2889.39 W 5963853.12 N 651103.87 E 88. 810 209.700 8961.74 9030 .74 5164.47 N 2907.21 W 5963824.43 N 651086.63 E 88. 020 204.060 8962.72 9031 .72 5133.01 N 2923.16 W 5963792.65 N 651071.33 E 88. 370 203.180 8963.65 9032 .65 5105.85 N 2935.03 W 5963765.26 N 651060.02 E 90. 400 202.120 8964.00 9033 .00 5075.68 N 2947.62 W 5963734.83 N 651048.05 E 89. 520 198.770 8964.03 9033 .03 5041.44 N 2960.39 W 5963700.33 N 651035.99 E 88.810 194.720 8964.49 9033.49 89.600 193.140 8964.97 9033.97 91.540 189.080 8964.63 9033.63 90.040 182.560 8964.07 9033.07 88.630 178.860 8964.48 9033.48 89.430 175.870 8964.97 9033.97 89.430 172.170 8965.23 9034.23 90.220 173.750 8965.33 9034.33 88.630 180.630 8965.66 9034.66 87.310 182.390 8967.01 9036.01 88.810 186.970 8968.13 9037.13 91.010 189.610 8968.18 9037.18 92.690 187.850 8967.54 9036.54 89.070 184.500 8967.11 9036.11 85.290 182.210 8969.06 9038.06 5011.05 N 2969.53 W 5963669.77 N 651027.47 E 4977.60 N 2977.83 W 5963636.15 N 651019.86 E 4943.79 N 2984.47 W 5963602.21 N 651013.92 E 4903.45 N 2988.58 W 5963561.80 N 651010.63 E 4867.75 N 2989.02 W 5963526.09 N 651010.92 E 4838.97 N 2987.69 W 5963497.35 N 651012.84 E 4813.39 N 2985.01 W 5963471.83 N 651016.04 E 4780.69 N 2980.98 W 5963439.22 N 651020.75 E 4747.64 N 2979.35 W 5963406.21 N 651023.05 E 4709.43 N 2980.36 W 5963367.99 N 651022.82 E 4676.65 N 2983. 05 W 5963335.16 N 4645.31 N 2987. 61 W 5963303.73 N 4625.92 N 2990. 59 W 5963284.29 N 4597.74 N 2993 .64 W 5963256.05 N 4558.19 N 2995 .96 W 5963216.45 N 13804.52 91.010 176.220 8970.43 9039.43 4515.81 N 2995.37 W 5963174.10 N 13835.34 92.860 173.050 8969.39 9038.39 4485.15 N 2992.49 W 5963143.50 N 13862.00 92.860 173.050 8968.06 9037.06 4458.72 N 2989.27 W 5963117.14 N 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 We11 Reference and calculated along an Azimuth of 195.000° (True). Based upon Minimum Curvature type calculations. at a Measured Depth of 13862.OOft., The Bottom Hole Displacement is 5368.04ft., in the Direction of 326.161 ° (True). 651020.81 E 651016.89 E 651014.31 E 651011.84 E 651010.33 E 651011.78 E 651015.29 E 651019.05 E Dogleg Vertical Rate Section (°/100ft) 12.493 -4389.88 6.232 -4360.59 6.318 -4326.16 9.740 -4297.56 5.311 -4268.04 15.171 -4236.05 16.127 -4201.54 3.193 -4172.23 7.003 -4139.83 9.476 -4103.45 12.953 -4071.74 5.124 -4037.28 13.053 -4002.90 16.489 -3962.87 11.084 -3928.27 10.742 -3900.82 14.379 -3876.80 5.361 -3846.26 21.325 -3814.76 5.749 -3777.59 14.632 -3745.23 10.847 -3713.77 12.398 -3694.28 17.389 -3666.27 11.134 -3627.46 19.506 -3586.68 11.904 -3557.81 0.000 -3533.11 BPXA Comment Projected Survey • • 8 December, 2005 - 15:27 Page 3 of 4 DrillQuesf 3.03.06.008 Halliburton Sperry-Sun Survey Report for D-076 Your Ref: API 500292016202 Job No. AKMW4074252, Surveyed: 3 December, 2005 North Slope Alaska Comments Measured Depth (ft) 11834.40 11862.70 13862.00 Station Coordinates TVD Northings Eastings Comment (ft) (ft) (ft) 8987.65 5680.09 N 1968.43 W Tie On Point 8994.87 5700.58 N 1986.57 W Window Point 9037.06 4458.72 N 2989.27 W Projected Survey Survev tool program for D-O7B From To Measured Vertical Measured Vertical Depth Depth Depth Depth Survey Tool Description (ft) (ft) (ft) (ft) 0.00 0.00 9301.50 7150.05 CB-GYRO-MS (D-07A) 9301.50 7150.05 13862.00 9037.06 MWD Magnetic (D-07A) BPXA • • 8 December, 2005 - 15:27 Page 4 of 4 DriliQuest 3.03.06.008 TREE _ 4" CM/ i D ~O ~ ~ S NOTES: *** IA x OA COMM. OPERATING PRESSURE OF THE 13-318" ANNULUS MUST NOT EXCEED 2000 PSI (02/07/03 WAIVER) *** ® 2072' 4-1/2" OTIS SSSV NIP, ID = 3.813" 2108' 9-5/8" PBR 2122' -~ 9-5/8" CSG HGR GAS LIFT MANDRELS WELLHEAD = 13-5/8" SM MCEVOY ACTUATOR = KB. ELEV = BAKER 69.0' BF. ELEV = 40.87' KOP = 3 202' Max Angle = _ 95 @ 12210' Datum MD = 11529' Datum TVD = 8800' SS 13-3/8" CSG, 72#, N-80, ID = 12.347" ~-{ 26$$' Minimum ID = 3.725" @ 10832' 4-1 /2" OTIS XN NIPPLE (milled to 3.8" ID) TOP OF 7-5/8" LNR ~~ 9-5/8" CSG, 47#, L-80, ID = 8.681" (-~ 9383' ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3050 2981 6 MMG-M RK 3 6564 5553 57 MMG-M RK 2 9083 6965 58 MMG M RK - 1 9151 7001 58 MMG-M RK 9204' 7-5/8" TIE-BA~ 9211' 7-5/8" BKR SBP PKR W/ HMC HGR 10721' Liner Packer MIN ID = 2.375" 10762' 4-1/2" OTIS X NIP, ID = 3.813" 10780' I~ 7-5/8" X 4-1/2" BKR SABL-3 PKR, ID = 3.93" 10811' 4-1/2" OTIS X NIP, ID = 3.813" 10832' 4-1/2" OTIS XN NIP, ID = 3.725" 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" TOP OF 5-1 /2" LNR 7-5/8" LNR, 29.7#, L-80, .0459 bpf, ID = 6.875" PERFORATION SUMMARY REF LOG: SWS-MWD GAMMA RAY ON 01/10/94 ANGLE AT TOP PERF: 71 @ 11750' Note: Refer to Roduction DB for historical perf data SQE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 11750 - 11775 C 06/25/05 3-3/8" 6 11770 - 11782 C 02/04/05 3-3/8" 6 11960 - 11980 C 04/02/95 3-318" 4 12035 - 12280 C 03/01/95 3-3/8" 4 12310 - 12400 C 03/01/95 3-3/8" 6 12500 - 12520 C 03/01/95 3-3/8" 6 12535 - 12555 C 04/02/95 3-3/8" 6 12600 - 12620 C 04/02/95 3-3/8" 6 12630 - 12650 C 02/12/95 3-3/8" 6 12680 - 12700 C 02/12/95 3-3/8" 10 12740 - 12845 C 02/12/95 3-3/8" 4 12895 - 13020 C 02/12/95 2" 6 12900 - 13650 O 12/04/05 PBTD -~ 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" ~ ~ 10847' I-~ 5-3/4" TM/ SEAL ASSY W/ I 10847' ELMD TT LOGGED 05/04/97 5-1/2" BKR H PKR W/ HMC HGR 11495' Top of Cement 11495' TOP OF 3-3/16" LNR 11514' 3.5" XN Nip 2.75" ID 12389' I-{ 3-3/16 x 2-7/8 X-over LOCATOR 3-3/16" X 2-7/8" cmt'ed and perfed --~~ ~~~~~ 11850' Mechanical Whipstock DATE REV BY COMMENTS DATE REV BY COMMENTS 10/01/76 ORIGINAL COMPLETION 10/10/04 ROY/TLH DRAWING CORRECTIONS 02/14/94 M.LIND SIDETRACK COM PLETION 03/02/05 SRB/TLH IBP SET 8 ADPERF 03/03/02 RN/TP CORRECTIONS 06/25/05 RWUPJC PERFS 02/20/03 /TLH WANERSAFETY NOTE 11/10/05 MSE Proposed CTDsidetrack 07/04/03 CMO/TLP MAX ANGLE & KB ELEVATION 12/05/05 RBL Post Sidetrack 06/25/04 BY/KAK CORRECTIONS PRUDHOE BAY UNfT WELL: D-07B PERMfT No: API No: 50-029-20162-02 SEC 36, T11 N, R13E, 2999' FSL 8 1067' FWL BP Exploration (Alaska) • • 13-Dec-05 AOGCC Helen Warman 333 W. 7th Ave. Suite 100 Anchorage, AK 99501 DEFINITIVE Re: Distribution of Survey Data for Well D-07B Dear Dear Sir/Madam: Enclosed is one disk with the .PTT and *.PDF files. Tie-on Survey: 11,834.40' MD Window /Kickoff Survey: 11,862.70' MD (if applicable) Projected Survey: 13,862.00' MD PLEASE ACKNOWLEDGE RECEIPT BY SENDING AN EMAIL TO CARL.ULRICH@HALLIBURTON.COM OR SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Sperry-Sun Drilling Services Attn: Carl Ulrich 6900 Arctic Blvd. Anchorage, AK 99518 Date Signed Please call me at 273-3545 if you have any questions or concerns. Regards, Carl Ulrich Survey Manager Attachment(s) ~, ~s - c~ ~ ~1~. iviat y r.ilUc1COLL FAX (90~ 276-7542 CT Drilling Engineer BP Exploration (Alaska), Inc. P.O. Box 196612 Anchorage, AK 99519-6612 Re: PBU D-07B BP Exploration (Alaska), Inc. Permit No: 205-181 Surface Location: 2280' FNL, 1067' FEL, SEC. 23, T11N, R13E, UM Bottomhole Location: 2034' FSL, 3986' FEL, SEC. 14, T11 N, R 13E, UM Dear Ms. Endacott: Enclosed is the approved application for permit to drill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. Please provide at least twenty- four (24) hours notice for a representative of the Commission to witness any required test. Contact the Commission's petroleum field inspector at (907) 659- 3607 (pager). ~~ Chairman DATED this "' day of November, 2005 cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. RECD ` ' ~(2u~; STATE OF ALASKA ALASK~IL AND GAS CONSERVATION OMISSION NOV ~ ~ 205 PERMIT TO DRILL ;Alaska Qil & Gas Cons. Commissiofl 20 AAC 25.005 Anrhnrana 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ®Development Oil ^ Multiple Zone ^ Stratigraphic Test ^ Service ^Development Gas ^ Single Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 6194193 11. Well Name and Number: D-07B 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13950 TVD 8957ss 12. Field /Pool(s): Prudhoe Bay Field / Prudhoe Bay 4a. Location of Well (Governmental Section): Surface: 2280' FNL 1067' FEL SEC 23 T11 N R13E UM 7. Property Designation: ADL 028285 Pool , , . , , , Top of Productive Horizon: 2941' FSL, 2608' FEL, SEC. 14, T11 N, R13E, UM 8. Land Use Permit: 13. Approximate Spud Date: December 10, 2005 Total Depth: 2034' FSL, 3986' FEL, SEC. 14, T11 N, R13E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 23,600' 4b. Location of Well (State Base Plane Coordinates): Surtace: x- 654100 y- 5958721 Zone- ASP4 10. KB Elevation (Height above GL): 69' feet 15. Distance to Nearest Well Within Pool 800' 16. Deviated Wells: Kickoff Depth: 11850 feet Maximum Hole Angle: 91 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3160 Surtace: 2280 18. asing Program: Size Specifications Setting .Depth To Bottom uantlty o ement c.f! or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 4-1 /8" s-,n° x a-a~+s• 8.81 # / 6.2# L-80 CI I / ST 2300' 11650' 8927' 13950' 8957' 135 sx Class 'G' X zaie' / 6.16# 19. PRESENT WELL CONDITION SUMMARY (To be completed forAedrill AND Re-entry Operations) Total Depth MD (ft): 13072 Total Depth TVD (ft): 9038 Plugs (measured): 11923 Effective Depth MD (ft): 11923 Effective Depth TVD (ft): 9011 Junk (measured): None Casin Len th Size Cement Volume MD TVD r n uet r 104' 20" 150 sx Arcticset 131' 131' 2656' 13-3/8" 550 sx Arcticset 2683' 2683' 9-5/8" 1213 HES Li ht, 200 sx'G', 300 sx'G' 2108' - 9383' 2108' - 7193' Pr ion 1851' 7-5/8" 50 sx Class 'G' 9204' - 11055' 7098' - 8543' Liner 2222' 5-1/2" 94 sx Class 'G' 10850' - 13072' 8368' - 9038' Tieback 2120' 10-3/4" w~memrocase 2120' 2120' Perforation Depth MD (ft): 11750' - 11782' (Above IBP) Perforation Depth TVD (ft): 8963' - 8973' 20. Attachments ®Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Mary Endacott, 564-4388 Printed Name Mary Endacott Title CT Drilling Engineer Prepared By Name/Number: Si nature ~ Phone 564-4388 Date ~rl ,~ Urj~ Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number: .•Z ., API Number: 50- 029-20162-02-00 Permit Approval Date: •Q See cover letter for other requirements Conditions of Approval: Samples Required ^ Yes ~No Mud Log Required ^ Yes ~, No Hydro S (fide Measures .Yes J No Directional Survey Required 'Yes ^ No _...~ Other: 1 Y' ~ ~ (> (; i ~ S ~' (~ ~ ~' t ti = . APPROVED BY ~/ A roved - THE COMMISSVON Date Form 10-401 Re~ O6%2~ ~ ~ ~ ~ ~ ~ L ~ubmif In Duplicate BP Prudhoe Bay D-07b CTD Sidetrack Mud Program: • Well kill: 8.5 ppg • Milling/drilling: .6pg Flo Pro or biozan for milling, new Flo Pro for drilling. 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: • 3'/z" x 3 3/16" 7/8" fully cemented liner - 11650'MD to 13950'MD; 4 1/8" hole • A minimum o~i'' .,bls 15.8 PPg cement will be used for liner cementing. ~ Casing/Liner Information 13 3/8", N-80, 72#, Burst 5380 psi; collapse 2670 psi 9 5/8", L-80 47#, Burst 6870, collapse 4750 7 5/8", L-80, 29.7#, Burst 6890 ;collapse 4790 psi 5'/z", L-80, 17#, Burst 7740, Collapse 6280 Well Control: BOP diagram is attached. Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. The annular preventer will be tested to 250 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. • Distance to nearest property - 23,600 ft. • Distance to nearest well within pool - 800 ft. Logging • MWD directional, Resistivity and Gamma Ray will be run over all of the open hole section. • A cased hole CNL/GR/CCL log will be run. Hazards • The maximum recorded H2S level on D pad is 50, ppm . • Lost circulation risk is medium, two planned fault crossings. Reservoir Pressure • Res. press. is estimated to be 3160 psi at 8800'ss (6.9 ppg EMW). Max. surface pressure with gas (0.10 psi/ft) to surface is 2280 psi. TREE _ a" rlw • ~ ~ NOTES: *** IA x OA COMM. OPERATING D -O ~ ~ PRESSU RE OFTHE 13-318" ANNULUS MUST NOT EXCEED 2000 PSI (02/07/03 WAIVER) *** - 2072' 4-1/2" OTIS SSSV NIP, ID = 3.813" 2108' 9-5/8" PBR 2122' 9-5i8" CSG HGR GAS LIFT MANDRELS WELLHEA 13 5/8" 5M MCEVOY - _ . . - . ,, ACTUATOR- . P~..__ ,-.~~.~.w_. -. , BAKER KB. ELEV - 69.0' _ BF. ELEV...- . 40.87 KOP = 3202' Max Angle = 95 @ 12210' Datum MD = 11529' Datum TVD = 8800' SS 13-318" CSG, 72#, N-80, ID = 12.347" ~~ 2683' f Minimum ID = 3.725" @ 10832' 4-1 /2" OTIS XN NIPPLE TOP OF 7-5/8" LNR ~-~ 9204' 9-5/8" CSG, 47#, L-80, ID = 8.681" ~-i 9383' L4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" ~ 10$47' TOP OF 5-1/2" LNR 10$50' 7-5/8" LNR, 29.7#, L-80, .0459 bpf, ID = 6.875" ~~ 11055' PERFORATION SUMMARY REF LOG: SWS-MWD GAMMA RAY ON 01/10/94 ANGLE AT TOP PERF: 71 @ 11750' Note: Refer to Production DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 11750 - 11775 O 06/25/05 3-3/8" 6 11770 - 11782 O 02/04/05 3-3/8" 6 11960 - 11980 C 04/02/95 3-3(8" 4 12035 - 12280 C 03!01/95 3-318" 4 12310 - 12400 C 03/01/95 3-318" 6 12500 - 12520 C 03/01/95 3-3/8" 6 12535 - 12555 C 04/02/95 3-3/8" 6 12600 - 12620 C 04!02/95 3-3/8" 6 12630 - 12650 C 02/12/95 3-318" 6 12680 - 12700 C 02/12/95 3-3/8" 10 12740 - 12845 C 02/12(95 3-3/8" 4 12895 - 13020 C 02/12/95 ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3050 2981 6 MMG-M RK 3 6564 5553 57 MMG-M RK 2 9083 6965 58 MMG M RK - 1 9151 7001 58 MMG-M RK 9204' 7-5/8" TIE-BACK 9211' 7-5/8" BKR SBP PKR W/ HMC HGR 10762' - 14-1/2" OTIS X NIP, ID = 3.813" 107$0' 7-518" X 4-1/2" BKR SABL-3 PKR, ID = 3.93" 10811' 4-1/2" OTIS X NIP, ID = 3.813" 10832' 4-1/2" OTIS XN NIP, ID = 3.725" 10847' 5-3/4" TMJ SEAL ASSY W/ 6.4 OD LOCATOR 10847' ELMD TT LOGGED 05/04/97 10$50' 5-112" TIE-BACK 10857' 5-112" BKR H PKR W! HMC HGR 11923' ~-~ BKR IBP (02/04/05) PBTD ~-{ 13030' 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" ~-{ 13072' DATE REV BY COMMENTS DATE REV BY COMMENTS 10/01!76 ORIGINAL COMPLETION 10/10/04 ROY/TLH DRAWING CORRECTIONS 02!14(94 M.LINDE SIDETRACK COM PLETION 03102!05 SRB/TLH IBP SET & ADPERF 03/03102 RN/TP CORRECTIONS 06!25/05 RWLlPJC PERFS 02/20/03 /TLH WAVER SAFETY NOTE 07/04/03 CMO/TLP MAX ANGLE & KB ELEVATION 06!25104 BY/KAK CORRECTIONS PRUDHOE BAY UNIT WELL: D-07A PERMff No: 1931570 API No: 50-029-20162-01 SEC 36, T11 N, R13E, 2999' FSL & 1067' FWL BP Exploration (Alaska) 4" CM/ WELLHEAD = 13-5/8" 5M MCEVOY ACTUATOR = BAKER KB. ELEV = 69.0' BF. ELEV - 40.87 KOP = 3202' Max Angle = 95 @ 12210' Datum MD = 11529' Datum TV D = 8800' SS 13-3/8" CSG, 72#, N-80, ID = 12.347" n 2683' Minimum ID = 3.725" @ 10832' 4-1/2" OTIS XN NIPPLE il(~ t0 3.8" ICS} TOP OF 7-5/8" LNR 9~04~ ST MD TVD DEV TYPE VLV LATCH PORT DATE 4 3050 2981 6 MMG-M RK 3 6564 5553 57 MMG-M RK 2 9083 6965 58 MMG-M RK 1 9151 7001 58 MMG-M RK 920 7-5/8" TIE BACK 9211' ~-~ 7-5/8" BKR SBP PKR W/ HMC HGR 9-5/8" CSG, 47#, L-80, ID = 8.681" I-I 9383' ~I 4-1/2" TBG, 12.6#, L-80, .0152 bpf, ID = 3.958" I-I 10847' TOP OF 5-1/2" LNR ~~ 10850' I7-5/8" LNR, 29.7#, L-80, .0459 bpf, ID = 6.875" ~ 11055' PERFORATION SUMMARY REF LOG: SWS-MWD GAMMA RAY ON 01/10/94 A NGLE AT TOP PERF: 71 @ 11750' Note: Refer to Roduction DB for historical pert data SIZE SPF INTERVAL Opn/Sqz DATE 3-3/8" 6 11750 - 11775 O 06/25/05 3-3/8" 6 11770 - 11782 O 02/04/05 3-3/8" 6 11960 - 11980 C 04/02/95 3-3/8" 4 12035 - 12280 C 03/01/95 3-3/8" 4 12310 - 12400 C 03/01/95 3-3/8" 6 12500 - 12520 C 03/01/95 3-3/8" 6 12535 - 12555 C 04/02/95 3-3/8" 6 12600 - 12620 C 04/02/95 3-3/8" 6 12630 - 12650 C 02/12/95 3-3/8" 6 12680 - 12700 C 02/12/95 3-3/8" 10 12740 - 12845 C 02/12/95 3-3/8" 4 12895 - 13020 C 02/12/95 PBTD 13030' 5-1/2" LNR, 17#, L-80, .0232 bpf, ID = 4.892" 13072' 10762' ~ 4-1/2" OTIS X NIP, ID = 3.813" 10780' 7-5/8" X 4-1/2" BKR SABL-3 PKR, ID = 3.93" 10811' 4-1/2" OTIS X NIP, ID = 3.813" 10832' 4-1/2" OTIS XN NIP, ID = 3:725" rn€ e o ) 1084T 5-3/4" TM/ SEAL ASSY W/ 6.4 OD LOCATOR 10$4T ELMD TT LOGGED 05/04/97 10850' 5-1/2" TIE-BACK 1085T 5-1/2" BKR H PKR W/ HMC HGR 11640' ~ Liner Top Packer 11650' Top of Cerr~nt ~.--I 11650` 11 TOP OF 3-3/16" LNR I ~' „,~.. 11660' 3.5" XN Nip 2.75" ID F K 12400' 3-3116 x 2-718 X-over 3-:~i16" X 2-7,8" rmt'ed and perfed 1395 ~ 11850" fttechanical Whipstock 11923' BKR IBP (02/04/05) DATE REV BY COMMENTS DATE REV BY COMMENTS 10/01/76 ORIGINALCOMPLETION 10/10/04 ROY/TLH DRAWING CORRECTIONS 02/14/94 M.LIND SIDETRACKCOMPLETION 03/02/05 SRB/TLH IBP SET&ADPERF 03/03/02 RNITP CORRECTIONS 06/25/05 RWL/PJC PERFS 02/20/03 /TLH WANERSAFETYNOTE 11/10/05 MSE ProposedCTDsidetrack 07/04/03 CMO/TLP MAX ANGLE & KB ELEVATION 06/25/04 BY/KAK CORRECTIONS PRUDHOE BAY UNfI- WELL: D-07S PERMff No: API No: 50-029-20162-02 SEC 36, T11 N, R13E, 2999' FSL 8~ 1067' FWL BP Exploration (Alaska) BP Amoco neaarA7h oa7Aru ru. a. aa7a hr..e we4eau Ya1A 7r..-ra 4seae.w a.r. wm~.. se ~ r wneea aoao w.oon r ~~. e°~..~ri o sesm• o.oo o.ea xaa REFERENCE INFORMATION CocNinate (N/E) Reference: Wel Centre: D-07, True NuM Vertical (TVD)) Reference: Syyssmm: Mean Sea Level Sectlon (VS) Reference: Sbt-07 (O.OON,U.f10E) Meawrea Depth Reference: 15:071/7/1994 00:00 89.00 Calculation McMoo: Minimum Curvature e.. ro r .+ rsw .ra .uw er.e ne vew 7-eM ~ LEGEND T Plan: Plan Y2 (D-07rPlan 2. 6078) r'~;' 007 S0-07) eimruths to True North BAKER hh - PI°-0en73 o-o7i~ M 9 et+c North: 2a.69° crealea ey 8w Miareelsoo Dare- tvarzoos HUGHES tJp Ren M2 MegnBtlC Field Cnnt3cUn~ormaeon ~~QQ~---,,,,__„TT~~~~ Strengthe 57600nT sin M~cnaeison Dip Angle: 80.87° Dired (907) 267-6624 1 L(~ ate: 11(2/2005 Ceil. (907) 301-73570 Model: bggm2005 E-mail: bill.michaelaon(~inteq.com •.rroran4tt4a rvo xo Ane.rarYe "' •w.e .u.w aea i e iisio~00 RO1 .oo uw w rhea a4a '"' n n a.u tteoo.oo ~ r •n s a .~ r^~nm sham .xw ar °.M a°Onms i.'°' s.°s +us+.n e-.. x o u t:us.n r :~evn ~ i.ii iam.n a esa u~x.n e.u va7e.n so 7.w saea.n 4s ..n saeee.x m 8500 r., I:: I.; 8550 ~' i'i 6soo j? 8650 iJ: 06700 _ ...}. 8750 , I ~-i N 8800 r;j r ~ ~ 8850 ~ 8900 ErW a s• W ~V 8950 y D-071D-07A1 9000 2 9050 ~ 9100 t.i.; -5200-5150-51 West(-)/East(+) [700ft/in] Vertical Section at 195.00° [50ft/in] -3350-3300 AM • e ~ Baker Hu hes INTE g Q Baker Hughes INTEQ Planning Report ~~~~~ ~~,~~ 1~_I ~_~ ~.. _. Company: BP Amoco Date: 11/3!2005 Time: 11:53:18 Page: I Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: D-07, True North Site PB D Pad ~ ertical (TYD) Reference: 15 :07 1/7/1994 00:00 69.0 ~~~ell: D-07 Section (VS) Reference: Well (O.OON,O.OOE,195. OOAzi) ~~'ellpath: Ptan 2, D-078 Sur~~ey Calculation Method: Minimum Curvature Db: Oracle - _ Field: Prudhoe Bay _ - - - - - North Slope UNITED STATES Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2005 Site: PB D Pad TR-11-13 UNITED STATES :North Sl ope Site Position: Northing: 5955590 .34 ft Latitude: 70 17 8.492 N From: Map Easting: 652165 .06 ft Longitude: 148 46 6.316 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 1.16 deg Well: D-07 Slot Name: 07 D-07 Well Position: +N/-S 3091.09 ft Northing: 5958721 .00 ft Latitude: 70 17 38.890 N +E/-W 1998.03 ft Easting : 654100 .00 ft Longitude: 148 45 8.084 W Position Uncertainty: 0.00 ft Wellpath: Plan 2, D-076 Drilled From: D-07A Tie-on Depth: 11 834.40 ft CurrentDatum: 15:07 1/7/1994 00:00 Height 69 .00 ft Above System Datum: Mean Sea Level Magnetic Data: 11/2!2005 Declination: 24.69 deg Field Strength: 57600 nT Mag Dip Angle: 80:87 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direc tion ft ft ft deg 28.50 0.00 0.00 195.00 Plan: Plan #2 Date Composed: 11/2/2005 Copy Lamar's plan 2 Version: 3 Principal: .Yes Tied-to: From : Definitive Path Targets ~1ap Map < Latitude > <-- Longitude ? Name Description TVD +N!-S +F.l-W Northing Easting Deg Min Sec I)egNf1n Sec Dip. Dir. ft ft ft ft ft J D-07B Polygon 69.00 5720.69 -2198.35 5964395.00 651785.00 70 18 35.150 N 148 46 12.203 W -Polygon 1 69.00 5720.69 -2198.35 5964395.00 651785.00 70 18 35.150 N 148 46 12.203 W -Polygon 2 69.00 5138.07 -2810.46 5963800.00 651185.00 70 18 29.418 N 148 46 30.050 W -Polygon 3 69.00 4524.59 -2893.06 5963185.00 651115.00 70 18 23.384 N 148 46 32.452 W -Polygon 4 69.00 4007.31 -2788.64 5962670.00 651230.00 70 18 18.297 N 148 46 29.401 W -Polygon 5 69.00 3943.26 -3080.03 5962600.00 650940.00 70 18 17.666 N 148 46 37.898 W -Polygon 6 69.00 4460.24 -3169.46 5963115.00 650840.00 70 18 22.750 N 148 46 40.512 W -Polygon 7 69.00 5248.90 -3093.27 5963905.00 650900.00 70 18 30.507 N 148 46 38.299 W -Polygon 8 69.00 5918.64 -2339.33 5964590.00 651640.00 70 18 37.096 N 148 46 16.317 W D-076 Fault 1 69.00 5344.22 -3351.39 5963995.00 650640.00 70 18 31.443 N 148 46 45.829 W -Polygon 1 69.00 5344.22 -3351.39 5963995.00 650640.00 70 18 31.443 N 148 46 45.829 W -Polygon 2 69.00 5328.05 -2806.57 5963990.00 651185.00 70 18 31.286 N 148 46 29.939 W -Polygon 3 69.00 5321.30 -2721.68 5963985.00 651270.00 70 18 31.220 N 148 46 27.463 W -Polygon 4 69.00 5328.05 -2806.57 5963990.00 651185.00 70 18 31.286 N 148 46 29.939 W D-07B Fault 3 69.00 4612.53 -2791.23 5963275.00 651215.00 70 18 24.249 N 148 46 29.484 W -Polygon 1 69.00 4612.53 -2791.23 5963275.00 651215.00 70 18 24.249 N 148 46 29.484 W -Polygon 2 69.00 4868.86 -2120.79 5963545.00 651880.00 70 18 26.772 N 148 46 9.934 W D-076 Fault 2 69.00 4149.92 -3645.96 5962795.00 650370.00 70 18 19.696 N 148 46 54.403 W -Polygon 1 69.00 4149.92 -3645.96 5962795.00 650370.00 70 18 19.696 N 148 46 54.403 W -Polygon 2 69.00 4805.68 -2942.31 5963465.00 651060.00 70 18 26.148 N 148 46 33.892 W -Polygon 3 69.00 5408.70 -2349.79 5964080.00 651640.00 70 18 32.081 N 148 46 16.617 W -Polygon 4 69.00 4805.68 -2942.31 5963465.00 651060.00 70 18 26.148 N 148 46 33.892 W D-076 Target 3 9026.00 4322.23 -2927.22 5962982.00 651085.00 70 18 21.394 N 148 46 33.446 W • Baker Hu hes INTE g Q Baker Hughes INTEQ Planning Report ~~~~~ ~~~E$ ~'~"t tr}" ___._ Company: BP Amoco ___ Date: _ 11/3/2005 Time: ___ 1153:18 Page: - _' Field: Prudhoe Bay Co-ordinate(NE) Reference: Well: D-07, True North Site: PB D Pad Verti cal (TVD) Reference: 1 5: 07 1!7/1994 00:00 69.0 Well: D-07 Section (VS) Reference: WeA (O.DON,O.OOE,195. OOAzi) ~ ~I W'ellpath: Plan 2, D-07B Survey Calculation Method: Minimum Curvature Db: Oracle Targets Map Map <--- Latitude --= =Lon gitude --> Name llescription TVD +N/-S +El-1V 1`orthing Easting lleg Min Sec Dc~ Min Sec Dip. Dir. ft ft ft ft ft D-076 Target 2 9029.00 5123.62 -2934.79 5963783.00 651061.00 70 18 29.275 N 148 46 33.676 W D-076 Target 1 9034.00 5598.5 3 -2484.93 5964267.00 651501.00 70 18 33.947 N 148 46 20.561 W Annotation Mll TVD --- ft ft --- 11834.40 _ 8987.65 --- TIP - - - 11850.00 8991.77 KOP 11870.00 8996.76 End of 9°/100' DLS 11900.00 9002.45 4 12251.73 9034.18 End of 25°/100' DLS 12451.73 9034.18 6 12751.73 9032.59 7 12876.73 9031.32 8 13126.73 9028.96 9 13376.73 9027.47 10 13601.73 9026.80 11 13950.00 9025.93 TD Plan Section Information MD Inc! Azim TVD +N/-S +E/-W DLS Build "turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 11834.40 74.70 318.50 8987.65 5680.09 -1968.46 0.00 0.00 0.00 0.00 11850.00 74.70 318.87 8991.77 5691.39 -1978.40 2.29 0.00 2.37 90.05 11870.00 76.39 318.24 8996.76 5705.91 -1991.22 9.00 8.46 -3.17 340.00 11900.00 81.75 312.89 9002.45 5726.91 -2011.83 25.00 17.85 -17.84 . 315.00 12251.73 90.00 224.97 9034.18 5719.41 -2328.37 25.00 2.35 -24.99 270.30 12451.73 90.00 248.97 9034.18 5611.20 -2494.83 12.00 0.00 12.00 90.00 12751.73 90.59 212.98 9032.59 5425.41 -2724.08 12.00 0.20 -12.00 271.00 12876.73 90.57 227.98 9031.32 5330.60 -2804.99 12.00 -0.02 12.00 90.00 13126.73 90.49 197.98 9028.96 5123.28 -2939.52 12.00 -0.03 -12.00 270.00 13376.73 90.18 167.98 9027.47 4876.47 -2952.36 12.00 -0.13 -12.00 269.50 13601.73 90.16 194.98 9026.80 4653.62 -2958.11 12.00 -0.01 12.00 90.00 13950.00 90.12 153.19 9025.93 4314.83 -2923.00 12.00 -0.01 -12.00 270.00 Survey MD Inc! Azim SS TVD NlS E/~'V MapN 1YiapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg j 11834.40 74.70 318.50 8918.65 5680.09 -1968.46 5964359.13 652015.65 0.00 -4977.07 0.00 MWD 11850.00 74.70 318.87 8922.77 5691.39 -1978.40 5964370.22 652005.48 2.29 -4985.42 90.05 MWD 11870.00 76.39 318.24 8927.76 5705.91 -1991.22 5964384.47 651992.37 9.00 -4996.12 340.00 MWD 11875.00 77.28 317.33 8928.90 5709.51 -1994.49 5964388.01 651989.03 25.00 -4998.75 315.00 MWD 11900.00 81.75 312.89 8933.45 5726.91 -2011.83 5964405.05 651971.33 25.00 -5011.07 315.21 MWD 11925.00 81.83 306.57 8937.02 5742.72 -2030.85 5964420.46 651951.99 25.00 -5021.42 270.30 MWD 11950.00 82.01 300.26 8940.54 5756.34 -2051.50 5964433.66 651931.07 25.00 -5029.23 271.20 MWD 11975.00 82.28 293.96 8943.96 5767.62 -2073.54 5964444.48 651908.81 25.00 -5034.43 272.09 MWD 12000.00 82.65 287.66 8947.24 5776.42 -2096.69 5964452.81 651885.48 25.00 -5036.93 272.95 MWD 12025.00 83.11 281.38 8950.34 5782.64 -2120.69 5964458.53 651861.36 25.00 -5036.73 273.78 MWD 12050.00 83.64 275.11 8953.23 5786.20 -2145.26 5964461.59 651836.73 25.00 -5033.81 274.56 MWD 12075.00 84.25 268.86 8955.87 5787.06 -2170.09 5964461.94 651811.89 25.00 -5028.21 275.28 MWD 12100.00 84.93 262.62 8958.23 5785.21 -2194.90 5964459.58 651787.12 25.00 -5020.00 275.94 MWD 12125.00 85.67 256.39 8960.28 5780.67 -2219.38 5964454.54 651762.74 25.00 -5009.28 276.53 MWD 12150.00 86.46 250.18 8961.99 5773.50 -2243.26 5964446.88 651739.01 25.00 -4996.18 277.04 MWD 12175.00 87.29 243.97 8963.36 5763.78 -2266.24 5964436.69 651716.24 25.00 -4980.84 277.47 MWD 12200.00 88.16 237.78 8964.35 5751.63 -2288.05 5964424.10 651694.69 25.00 -4963.46 277.81 MWD Baker Hu hes INTE ~ ~~~ g Q ~~~~~~ Baker Hughes INTEQ Planning Report ~,~-~ ~:~~~ ~ --- Company: BP Amoco Field: Prudhoe Bay Site: PBD Pad Well: D-07 ~Weilpath: Plan 2, D-07B Survca MD Incl Azim ft deg deg S TVll ft /S ft /V1' ft Date: 11/3/2005 Time: 11:53.18 Co-ordinate(1~E) Reference: Welf: D-07, True North Vertical (TVll) Keference: 15:07 1/711994 00:00 Section (VS) Reference: Well (O.OON,O.OOE,195 Survey Calculation Method: Minimum Curvature NapN NIapE llLS ~"S ft ft deg/100ft It Page: 69.0 .DOAzi) Db: 7T0 dey 3 racle Tool 12225. 00 89. 04 231.59 8964.96 5737 .19 -2308. 43 5964409.24 651674. 60 25 .00 -4944.23 278. 05 MWD 12250. 00 89. 94 225.40 8965.18 5720 .63 -2327. 14 5964392.31 651656. 24 25 .00 -4923.40 278. 20 MWD 12251. 73 90. 00 224.97 8965.18 5719 .41 -2328. 37 5964391.06 651655. 03 25 .00 -4921.90 278. 26 MWD 12275. 00 90. 00 227.77 8965.18 5703. 36 -2345. 21 5964374.67 651638. 53 12 .00 -4902.03 90. 00 MWD 12300. 00 90. 00 230.77 8965.18 5687 .05 -2364. 16 5964357.97 651619. 93 12 .00 -4881.38 90. 00 MWD 12325. 00 90. 00 233.77 8965.18 5671 .75 -2383. 92 5964342.27 651600. 48 12 .00 -4861.48 90. 00 MWD 12350. 00 90. 00 236.77 8965.18 5657 .51 -2404. 47 5964327.61 651580. 23 12 .00 -4842.41 90. 00 MWD 12375. 00 90. 00 239.77 8965.18 5644 .36 -2425. 73 5964314.03 651559. 25 12 .00 -4824.21 90. 00 MWD 12400. 00 90. 00 242.77 8965.18 5632. 34 -2447. 65 5964301.57 651537. 58 12 .00 -4806.93 90. 00 MWD 12425. 00 90. 00 245.77 8965.18 5621 .49 -2470. 16 5964290.26 651515. 29 12 .00 -4790.61 90. 00 MWD 12450. 00 90. 00 248.77 8965.18 5611 .83 -2493. 22 5964280.13 651492. 44 12 .00 -4775.32 90. 00 MWD 12451. 73 90. 00 248.97 8965.18 5611 .20 -2494. 83 5964279.47 651490. 84 12 .00 -4774.30 90. 00 MWD 12475. 00 90. 05 246.18 8965.17 5602 .33 -2516. 34 5964270.16 651469. 52 12 .00 -4760.16 271. 00 MWD 12500. 00 90. 10 243.18 8965.14 5591. 64 -2538. 94 5964259.01 651447. 15 12 .00 -4743.98 271. 00 MWD 12525. 00 90. 15 240.18 8965.09 5579 .78 -2560. 94 5964246.70 651425. 39 12 .00 -4726.83 270. 99 MWD 12550. 00 90. 20 237.18 8965.01 5566 .79 -2582. 30 5964233.28 651404. 31 12 .00 -4708.76 270. 99 MWD 12575. 00 90. 26 234.18 8964.91 5552 .70 -2602. 95 5964218.77 651383. 96 12 .00 -4689.80 270. 98 MWD 12600. 00 90. 31 231.18 8964.78 5537 .54 -2622. 83 5964203.21 651364. 39 12 .00 -4670.02 270. 97 MWD 12625. 00 90. 35 228.18 8964.64 5521. 37 -2641. 89 5964186.65 .651345. 67 12 .00 -4649.47 270. 95 MWD 12650. 00 90. 40 225.19 8964.47 5504 .22 -2660. 07 5964169.13 651327. 84 12 .00 -4628.19 270. 93 MWD 12675. 00 90. 45 222.19 8964.29 5486 .15 -2677. 34 5964150.71 651310. 95 12 .00 -4606.27 270. 92 MWD 12700. 00 90. 50 219.19 8964.08 5467 .19 -2693. 63 5964131.43 651295. 05 12 .00 -4583.74 270. 89 MWD 12725. 00 90. 54 216.19 8963.86 5447 .41 -2708. 91 5964111.34 651280. 18 12 .00 -4560.68 270. 87 MWD 12750. 00 90. 58 213.19 8963.61 5426. 86 -2723. 14 5964090.50 651266. 38 12 .00 -4537.14 270. 84 MWD 12751. 73 90. 59 212.98 8963.59 5425 .41 -2724. 08 5964089.03 651265. 46 12 .00 -4535.50 270. 81 MWD 12775. 00 90. 59 215.77 8963.35 5406 .21 -2737. 22 5964069.56 651252. 72 12 .00 -4513.55 90. 00 MWD 12800. 00 90. 58 218.77 5963.10 5386 .31 -2752. 36 5964049.37 651238. 00 12 .00 -4490.42 90. 03 MWD 12825. 00 90. 58 221.77 8962.84 5367 .24 -2768. 51 5964029.97 651222. 24 12 .00 -4467.81 90. 06 MWD 12850. 00 90. 58 224.77 8962.59 5349. 04 -2785. 65 5964011.42 651205. 48 12 .00 -4445.80 90. 09 MWD 12875. 00 90. 57 227.77 8962.34 5331 .76 -2803. 71 5963993.78 651187. 78 12 .00 -4424.44 90. 12 MWD 12876. 73 90. 57 227.98 8962.32 5330 .60 -2804. 99 5963992.59 651186. 52 12 .00 -4422.98 90. 15 MWD 12900. 00 90. 57 225.19 8962.09 5314 .61 -2821. 89 5963976.26 651169. 95 12 .00 -4403.16 270. 00 MWD 12925. 00 90. 56 222.19 8961.85 5296. 54 -2839. 16 5963957.84 651153. 06 12 .00 -4381.23 269. 97 MWD 12950. 00 90. 56 219.19 8961.60 5277. 58 -2855. 45 5963938.55 651137. 16 12 .00 -4358.71 269. 94 MWD 12975. 00 90. 56 216.19 8961.36 5257 .80 -2870. 73 5963918.46 651122. 29 12 .00 -4335.65 269. 91 MWD 13000. 00 90. 55 213.19 8961.12 5237 .25 -2884. 96 5963897.62 651108. 49 12 .00 -4312.11 269. 88 MWD 13025. 00 90. 54 210.19 8960.88 5215 .98 -2898. 09 5963876.09 651095. 80 12 .00 -4288.17 269. 86 MWD 13050. 00 90. 53 207.19 8960.64 5194. 05 -2910. 09 5963853.92 651084. 25 12 .00 -4263.88 269. 83 MWD 13075. 00 90. 52 204.19 8960.42 5171 .52 -2920. 92 5963831.18 651073. 89 12 .00 -4239.32 269. 80 M W D 13100. 00 90. 51 201.19 8960.19 5148 .46 -2930. 56 5963807.93 651064. 72 12 .00 -4214.55 269. 77 MWD 13125. 00 90. 49 198.19 8959.97 5124 .93 -2938. 98 5963784.23 651056. 78 12 .00 -4189.63 269. 74 MWD 13126. 73 90. 49 197.98 8959.96 5123. 28 -2939. 52 5963782.57 651056. 28 12 .00 -4187.91 269. 72 MWD 13150. 00 90. 47 195.19 8959.76 5100. 98 -2946. 16 5963760.14 651050. 10 12. 00 -4164.65 269. 50 MWD 13175. 00 90. 44 192.19 8959.57 5076 .70 -2952. 07 5963735.74 651044. 69 12 .00 -4139.66 269. 48 MWD 13200. 00 90. 41 189.19 8959.38 5052 .13 -2956. 71 5963711.09 651040. 56 12 .00 -4114.73 269. 45 MWD 13225. 00 90. 38 186.19 8959.21 5027 .36 -2960. 05 5963686.26 651037. 72 12 .00 -4089.94 269. 43 MWD 13250. 00 90. 35 183.19 8959.05 5002. 45 -2962. 09 5963661.31 651036. 19 12. 00 -4065.35 269. 41 MWD 13275. 00 90. 32 180.19 8958.91 4977. 46 -2962. 83 5963636.32 651035. 97 12. 00 -4041.02 269. 39 MWD 13300. 00 90. 28 177.19 8958.78 4952 .47 -2962. 26 5963611.34 651037. 05 12 .00 -4017.03 269. 37 MWD 13325 .00 90. 25 174.19 8958.66 4927 .55 -2960. 38 5963586.46 651039. 44 12 .00 -3993.44 269. 36 MWD 13350. 00 90. 21 171.19 8958.56 4902 .75 -2957. 19 5963561.74 651043. 13 12 .00 -3970.32 269. 34 MWD 13375. 00 90. 18 168.19 5958.47 4878. 16 -2952. 72 5963537.25 651048. 11 12. 00 -3947.72 269. 33 MWD 13376. 73 90. 18 167.98 8958.47 4876. 47 -2952. 36 5963535.56 651048. 50 12. 00 -3946.18 269. 32 MWD Baker Hu hes INTE • ~~ g Q Baker Hughes INTEQ Planning Report >a~~E~ -~r,IQ~~ 1~13~a(t ~... ~Company~ BP Amoco Field: Prudhoe Bay Sitc: PB D Pad w'cll: D-07 Wcllpath: Plan 2, D-07B Survey Date: 11/3/2005 Time: 11:53:18 Page: 4 ~~ Co-ordinate(\'E) Reference: Well: D-07, True North Vertical (TVD) Reference: 15 : 071/7/1994 00:00 69.0 Section (VS) Reference: Well (O.OON,O.OOE,195:OOAzi) Survey Calculation Method: Minimum Curvature I)h: Oracle MD Inc! Azim SSTVll N/S E1~V MapN VIapE - DLS VS TFO Tool ft deg deg ft ft ft ft ft deg 1100ft ft deg 13400. 00 90.18 170.77 8958.40 4853.60 -2948 .07 5963512. 79 651053 .26 12. 00 -3925. 20 90. 00 MWD 13425. 00 90.17 173.77 8958.32 4828.83 -2944 .71 5963488. 09 651057 .13 12. 00 -3902. 14 90. 01 MWD 13450. 00 90.17 176.77 8958.24 4803.92 -2942 .65 5963463. 23 651059 .70 12. 00 -3878. 61 90 .02 MWD 13475. 00 90.17 179.77 8958.17 4778.93 -2941 .89 5963438. 27 651060 .97 12. 00 -3854. 67 90. 03 MWD 13500. 00 90.17 182.77 8958.09 4753.94 -2942 .45 5963413. 27 651060 .92 12. 00 -3830. 39 90. 04 MWD 13525. 00 90.17 185.77 8958.02 4729.01 -2944 .31 5963388. 32 651059. 57 12. 00 -3805. 83 90. 04 MWD 13550. 00 90.16 188.77 8957.95 4704.22 -2947 .47 5963363. 46 651056 .92 12. 00 -3781. 06 90. 05 MWD 13575. 00 90.16 191.77 8957.88 4679.62 -2951 .93 5963338. 78 651052 .97 12. 00 -3756. 15 90. 06 MWD 13600. 00 90.16 194.77 8957.81 4655.29 -2957 .67 5963314. 34 651047 .73 12. 00 -3731. 16 90. 07 MWD 13601. 73 90.16 194.98 8957.80 4653.62 -2958 .11 5963312. 66 651047 .32 12. 00 -3729. 43 90. 08 MWD 13625 .00 90.16 192.19 8957.74 4631.00 -2963 .58 5963289. 94 651042 .32 12. 00 -3706. 17 270. 00 MWD 13650. 00 90.16 189.19 8957.67 4606.44 -2968 .21 5963265. 29 651038 .19 12. 00 -3681. 25 269. 99 MWD 13675. 00 90.15 186.19 8957.60 4581.67 -2971 .56 5963240. 45 651035 .35 12. 00 -3656. 45 269. 98 MWD 13700. 00 90.15 183.19 8957.54 4556.75 -2973 .60 5963215. 50 651033 .82 12. 00 -3631. 86 269. 98 MWD 13725. 00 90.15 180.19 8957.47 4531.77 -2974 .34 5963190. 51 651033. 60 12. 00 -3607. 53 269. 97 MWD 13750 .00 90.15 177.19 8957.40 4506.78 -2973 .76 5963165. 54 651034 .69 12. 00 -3583. 54 269. 96 MWD 13775 .00' 90.15 174.19 8957.34 4481.85 -2971 .88 5963140. 66 651037 .08 12. 00 -3559. 95 269. 95 MWD 13800 .00 90.14 171.19 8957.28 4457.06 -2968 .70 5963115. 94 651040 .77 12. 00 -3536. 83 269. 94 MWD 13825. 00 90.14 168.1.9 8957.21 4432.46 -2964 .23 5963091. 44 651045 .74 12. 00 -3514. 23 .269. 94 MWD 13850 .00 90.14. 165.19 8957.15 4408.14 -2958 .47 5963067. 24 651052 .00 12. 00 -3492. 22 269. 93 MWD 13875 .00 90.13 162.19 8957.10 4384.15 -2951 .45 5963043. 40 651059 .51 12. 00 -3470. 87 .269. 92 MWD 13900 .00 90.13 159.19 8957.04 4360.56 -2943 .18 5963019. 99 651068 .26 12. 00 -3450. 22 .269. 92 MWD 13925 .00 90.12 156.19 8956.99 .4337.43 -2933 .69 5962997. 06 651078. 22 12. 00 -3430. 34 269. 91 MWD 13950 .00 !90.12 153.19 8956.93 4314.83 -2923 .00 5962974. 69 .651089 .37 12. 00 -3411. 28 269. 90 MWD are Nordic 1 bighole i N ~_ bag • BAG 7 1/16" 5000psi bttm of bag middle of slips middle of pipes middle of flow cross Blind/Shears 2 3/8" combi ram/slips Mud Cross variable bore pipe 3 1/2"-2 7/8" 2 3/8" combi ram/slips TOTs ~ 7 1/16" 5000psi Mud Cross 7 1/16" 5000psi TOTs ~ 7 1/16" 5000psi Flow Tee • • TERRIE L HU$BLE as-srizsz 239 BP EXPLORATION AK INC ,. PO BOX 196612 IVIB'7-5 Mastercard Check:" ANCHORAGE, AK 995.19-6612 DATE '~ PAYTO THE ~ ~ ' ORDER OF DOLLARS First National Bank. Alaska Anchorage, AK 99501 MEMO ~~® ~: 1 25 2000601:99 i4~~~6 2.27~~~ i SS6~~' 0 239 • • TRANSMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PARAGRAPHS TO BE INCLUDED IN TIL4NSMITTAL L°~ETTER WELL NAME ~~~ 0 _6 r 1„0~ PTD# ZO `'~ " " CHECK WHAT CLUE ADD-ONS APPLIES ~ (OPTIONS) ! ent of ~ i j ~ ~, ~ iVILTLTI The permit is for a new wellbore segm LATERAL existing well , I Permit No, API No. (If API number ~ Production should continue to be reported as last two (2) digits a function of .the original API number stated are between 60-69) above. ' I all 005(f} C 25 ~ i ~ ~ ~ f; I , . PILOT HOLE In accordance with 20 AA (per ;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 i for well (name on permit). t to full b ~ ! !, ; jec SPACIl~TG !The permit is approved su .EXCEPTION compliance with 20 AAC 25.055. Approval to ~ ;perforate and produce/infect is contingent ~ ± upon issuance of a conservation order ;approving a spacing exception. ! (Company Name) assumes ~ the liability of any protest to the spacing 'exception that may occur. d to the itt b e m DRY DITCH All dry ditch sample sets su ,SAMPLE i Commission must be in no greater than 30' ~ i sample intervals from below the permafrost or from where samples are first caught and ~ 10' sample intervals through target zones. ~ Rev: 04/01/05 Cljody\transm ittal_checklist WELL PERMIT CHECKLIST Field & Pool PRUDHOE BAY, PRUDHOE OIL - 640150 Well Name: PRUDHOE BAY UNIT D-076 Program DEV _ Well bore seg PTD#:2051810 Company BP EXPLORATION (ALASKAN INC Initial ClasslType DEV I 1-OIL GeoArea 890 Unit 11650 OnlOff Shore On Annular Disposal Administration i 1 Permit_feeattached--_____ ___ _____________----__-__--- ---.. Yes__________________-__-. ~ 2 Lease number appropriate_ - . Yes 3 Uniquewell_nameandnumber_____________________--_ __. Yes,_-____-_--__-___- ~ 4 Well located in.a-definedpool_ _ - Yes 5 Well located proper disiance_from drilling unitboundary- - Yes - -- 6 Well located properdistance_fromotherwells________ _Yes_____________________________________________________ 7 Sufficientacreage-ayailablein_drillingunit___________________________ _____Yes__________ _____..--..-.....--.. 8 If deviated, is_wellbore plat_inclu_ded _ _ - _ - - _ _ - - . _ _ Yes _ _ _ _ - - _ . - - . - - - . 9 Operator only affected party____ ___ _____________ Yes___________ -- 10 Ope[atorhasappropriate-bondinforce---- -- ------ - -- - --Yes -- _----------- -- ------- --- --- --- - - ----- -- -- ---_.. 11 Permit can be issued without conservation order_ _ - _ - _ _ _ . _ - _ Yes . - - - - Appr Date 12 Pe[mitcanbeissuedwithoutadministrative-approval_______,___________ __ __Yes----.----_----_-_--_______________________-_-_-___-_--------_---__----_-.- RPC 11!15/2005 13 Can permit be approved before 15-day wait Yes 14 Well located within areaand_strataauthorizedby_InjectionOrder#(put1O#incomments)_(For_NA___________________________________________________________________________ 15 All wells-within1/4_milearea of reviewidentified(Forse[vicewellonly)_-._____- __-__NA________.__-_______________________________________-.. ------------------ 16 Pre-produced injector;dur_ationofpreproductionl_essthan_3months_(Forseruicewell only)__NA_--___________________________________________________________________ 17 ACMP_FindingofConsistency_hasbeenissued_forthisp[oject______________ __-_NA________________-___-_-----_------__-._-__-____________________---_-__-___ Engineering 18 Conductor string_p_rovided - - NA - - - - 19 Surface casing protects all-known U$DW& - NA 20 CMT_vol-adequate_to circulate_on conductor & surf_csg - - - - - . _ NA- - - - - - - - - - - - - 21 CMT.vol-adequate_totie-in long string tosu_rfcsg__------_-_____ __-_tJA_--_-________________----------------- --- --------- 22 CMT_willcoverallknownproductivehorizons________________-.__-.- _____Yes_______Adequateexcess,_----__--__--_---__ ___ _________-__-.__-._____--_-.-_-_ 23 Casing designsadegt~atefo[C,T,B&_permafcost--------------___- - --.--Yes___-_____________-------.--...-_.-_..- -.--____________________-____ ____ ~ 24 Adequate tankage_or reserve pit _ _ - Yes CTDU. - - - - - 25 If_a_re-drill,has-a_1.0-403 for abandonment been approved--_----_--_-__ __-Yes--_---_"_____________________________ --- - 26 Adequatewellboreseparationproposed___-____________________._ __-__Yes_______--_----_.__---..-___.-_.-___.___.._._________. -------------------- 27 If diverterlequired,doesitmeet.regulations______------------------- _--. NA_-__----Sidetrack.-__________________-__---__-_-_-___-_ ------------------------- Appr Date 28 Drillingfluid-programschematic.&equip)istadequate-------------------- - Yes----..-Max MW 8,6ppg,____________.__--_--___-__---__--_-_____---- WGA 11/15!2005 29 BOPES,dotheymeeiregulation___ ______.--_________________ _____Yes___________ __-_-_-.----......--..-.-.__--___________________-----_--______ 30 BOPE_press rating appropriate; test to.(put prig in comments)- - _ _ . _ _ - - - Yes - _ _ - _ - - Test to 3500 psi. _M$P 2280 psi, _ - - . _ 31 Choke_manifoldcompliesw/API_RP-53(May84)---------------------- -----Yes------- ---,-------------------------------------------------------------- ~32 Work willoccurwithoutoperationshutdown__________________________ _____Yes_______ ___ __-.---.---.-..-_---..----_---_ -_-___-__--__---.---.-..-_-- i 33 Is presence of H2S gas. probable - - - - Yes 5Q ppm on_p_ad. - - - - - - 34 Mecha_nicalconditionofwellswithinAORyerified(For_servicewellgnly)_________ ____ NA___---_-_-.----__--__._--_______________-____--_ Geology 35 Permit_canbeissuedwlohydrogen-sulfidemeasuns_-________-__----- _-__ No______-------------------_________________-_-__--_._____--_-_ 36 Data-presented on_potentialoverpressur_ezones_______________________ _____NA---___- ___ ___________-_-___-_---____--.------_---___ -__ ________________ Appr Date 37 Seismic analysis-of shallowgas_zones ---------------------------- ----- NA___-__-- - - -. RPC 11115/2005 38 Seabed conditionsunrey_(ifoff-shore)_______________________--___ -__--NA--_----.----------_________ 39 _Contactnamelphone_forweeklyprogress_reports[exploratoryonly]____________ _____NA--__-_-.___ ________-_-_-___--_-__---.---.-_---_____-- Geologic Engineering P Date Date: Date Commissioner: Commissioner: C is r ~ rs ,; ~, s~S ~e L ,, ,5~.~~ ,~~/dam c U appendix have not been microfilmed. Well History File APPENDIX ~'!~ MAR ~ ~ ZDC Information of detailed nature that is not particularly germane to the Well-permitting Process but is part of the history file. To improve the readability of the Well History file and to simplify finding information, information of this nature is accumulated at the end of the file under APPENDIX. No special effort has been made to chronologically . organize this category of information. d-07b.tapx Sperry-Sun Drilling Services LIS Scan Utility $Revision: 3 $ LisLib $Revision: 4 $ Tue Feb 26 13:06:02 2008 Reel Header Service name .............LISTPE Date . ...................08/02/26 Origin ...................STs Reel Name. .... ........UNKNOWN continuation Number......01 Previous Reel Name.......UNKNOWN Comments .................STS LIS Writing • Library. scientific Technical services Tape Header Service name .............LISTPE Date . ...................08/02/26 Origin ...................STs Tape Name. .... ........UNKNOWN continuation Number......01 Previous Tape Name.......UNKNOWN Comments .................STS LIS writing Library. Physical EOF scientific Technical services comment Record ~~ ~i~~ ~ ~ ~~~~ ~,~ TAPE HEADER , Prudhoe Bay MWD/MAD LOGS WELL NAME: D-07B API NUMBER: 500292016202 OPERATOR: BP Exploration (Alaska) Inc. LOGGING COMPANY: Sperry Drilling Services TAPE CREATION DATE: 26-FEB-08 JOB DATA MWD RUN 2 MWD RUN 3 MWD RUN 4 lOB NUMBER: W-0004074252 w-0004074252 w-0004074252 LOGGING ENGINEER: B. JAHN S. LATZ S. LATZ OPERATOR WITNESS: T. EIDEN / R R. BORDES / R. BORDES / MAD RUN 4 JOB NUMBER: w-0004074252 LOGGING ENGINEER: S. LATZ OPERATOR WITNESS: R. BORDES / SURFACE LOCATION SECTION: 23 TOWNSHIP: 11N RANGE: 13E FNL: 2280 FSL: FEL: 1067 FWL: Page 1 SUS - / ~`~ #~~~ • d-07b.tapx ELEVATION (FT FROM MSL O) KELLY BUSHING: 69.00 DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD • OPEN HOLE CASING DRILLERS BIT SIZE (IN) SIZE (IN) DEPTH (FT) 1ST STRING 4.125 5.500 11863.0 2ND STRING 3RD STRING PRODUCTION STRING REMARKS: 1. ALL DEPTHS ARE BIT DEPTHS UNLESS OTHERWISE NOTED. THESE DEPTHS ARE MEASURED DEPTH (MD). 2. ALL VERTICAL DEPTHS ARE TRUE VERTICAL DEPTH - SUBSEA (TVDSS) . 3. THIS WELL WAS DRILLED FROM A WHIPSTOCK, THE TOP OF WHICH WAS AT 11863'MD IN THE ORIGINAL D-07 WELLBORE. 4. THE PURPOSE OF MWD RUN 1 WAS TO POSITION THE WHIPSTOCK, MILL THE WINDOW, AND DRILL A BIT OF RAT HOLE. NO DATA ARE PRESENTED. 5. MWD RUNS 2-4 COMPRISED DIRECTIONAL, DUAL GAMMA RAY (GM) UTILIZING GEIGER- MUELLER TUBE DETECTORS, AND ELECTROMAGNETIC WAVE RESISTIVITY PHASE-4 (EWR4). MAD PASS DATA WERE ACQUIRED AFTER REACHING FINAL TD ON MWD RUN 4. THESE MAD DATA ARE PRESENTED SEPARATELY. 6. LOG AND MERGED DIGITAL DATA (LDWG) ONLY WERE SHIFTED TO A SCHLUMBERGER CASED-HOLE GAMMA RAY RUN IN THE D-07B WELLBORE ON 4 DECEMBER 2005. THESE PDC LOG DATA WERE PROVIDED BY D. DORTCH (SAIC/BP) ON 4 JANUARY 2008, PER MIKE MCTEAGUE (BP). LOG HEADER DATA RETAIN ORIGINAL DRILLER'S DEPTH REFERENCES. 7. MWD RUNS 1-4 REPRESENT WELL D-07B WITH API#: 50-029-20162-02. THIS WELL REACHED A TOTAL DEPTH (TD) OF 13862'MD/8968'TVDSS. SROP = SMOOTHED RATE OF PENETRATION WHILE DRILLING. SGRC = SMOOTHED GAMMA RAY COMBINED. SEXP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (EXTRA SHALLOW SPACING). SESP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (SHALLOW SPACING). SEMP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (MEDIUM SPACING). SEDP = SMOOTHED PHASE SHIFT-DERIVED RESISTIVITY (DEEP SPACING). SFXE = SMOOTHED FORMATION EXPOSURE TIME. Page 2 • • d-07b.tapx AN 'M' SUFFIX ON CURVE MNEMONICS DENOTES MAD PASS DATA. File Header Service name... .......STSLI6.001 Service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/26 Maximum Physical Record..65535 File Type. ............Lo Previous File Name.......STSLI6.000 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MWD Depth shifted and DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR FET RPM RPX RPS RPD ROP 1 clipped curves; all bit runs merged. .5000 START DEPTH 11775.5 11845.5 11845.5 11845.5 11845.5 11845.5 11879.5 STOP DEPTH 13811.5 13824.5 13824.5 13824.5 13824.5 13824.5 13862.0 BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) --------- EQUIVALENT UNSHIFTED DEPTH BASELINE DEPTH GR 11775.5 11779.0 11778.0 11781.5 11781.0 11785.0 11787.5 11790.5 11793.5 11796.5 11795.0 11798.0 11800.5 11803.5 11848.5 11850.0 11857.0 11856.0 11862.0 11861.5 11863.5 11863.5 11870.0 11867.5 11876.0 11874.0 11877.5 11875.0 11880.5 11878.0 11883.5 11880.0 11885.0 11881.5 11903.5 11900.0 11911.5 11910.5 11935.0 11932.5 11953.5 11952.5 11967.5 11965.5 11970.5 11968.5 11972.0 11970.5 11978.5 11976.5 12001.0 11999.0 12016.5 12013.0 12040.5 12037.5 12043.0 12040.0 Page 3 • d-07b.tapx 12051.0 12048.0 12070.0 12066.0 12094.5 12091.5 12102.5 12099.5 12149.0 12146.5 12181.5 12180.0 12204.5 12205.0 12229.5 12230.0 12250.5 12251.0 12253.5 12254.0 12256.0 12259.0 12265.5 12266.5 12280.0 12281.5 12286.0 12288.0 12321.5 12322.5 12352.0 12352.0 12361.0 12361.0 12401.5 12400.5 12408.0 12407.5 12410.0 12409.0 12412.0 12411.5 12413.5 12413.5 12421.0 12419.5 12438.5 12437.0 12440.0 12440.0 12443.0 12444.0 12455.0 12453.0 12469.0 12465.5 12473.5 12470.0 12491.5 12486.5 12497.0 12494.0 12505.0 12504.5 12525.0 12520.5 12533.0 12530.5 12538.5 12536.0 12555.0 12555.0 12566.0 12565.5 12567.5 12566.5 12574.5 12574.5 12592.0 12588.5 12600.5 12597.5 12618.0 12616.0 12623.0 12621.5 12636.0 12634.5 12658.5 12659.0 12687.0 12684.5 12706.5 12703.0 12735.5 12733.0 12784.5 12783.0 12798.0 12795.0 12805.0 12806.0 12840.0 12839.0 12845.0 12843.5 12866.0 12866.0 12897.0 12894.5 12911.5 12907.5 12920.5 12915.5 12925.0 12921.5 12937.0 12933.5 12992.5 12988.5 12996.0 12991.5 13005.5 13002.5 13022.5 13019.5 Page 4 • • d-07b.tapx 13064.0 13063.0 13079.5 13078.5 13091.5 13091.0 13113.5 13112.5 13126.5 13125.0 13145.0 13142.5 13150.5 13147.0 13165.5 13159.5 13168.0 13163.0 13181.0 13178.5 13271.5 13272.0 13293.5 13293.5 13359.5 13358.5 13385.0 13384.0 13397.5 13396.5 13424.5 13422.0 13497.5 13492.0 13540.0 13535.0 13565.5 13563.0 13583.0 13582.5 13593.5 13591.0 13596.5 13594.5 13599.5 13596.5 13609.5 13605.5 13626.0 13621.0 13633.5 13627.0 13645.0 13637.5 13653.5 13642.5 13661.5 13652.5 13670.5 13664.0 13676.0 13671.5 13679.5 13674.5 13688.0 13682.5 13694.5 13690.5 13700.5 13695.5 13710.0 13706.0 13715.5 13712.0 13720.0 13717.5 13727.0 13723.5 13734.5 13733.5 13736.0 13736.0 13862.0 13862.0 MERGED DATA SOURCE PBU TOOL CODE BIT RUN NO MERGE TOP MERGE BASE MwD 2 11779.0 12202.0 MwD 3 12202.0 13676.0 wD 4 13676.0 13866.0 $ REMARKS: MERGED MAIN PASS. Data Format Specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................Down Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Page 5 • • • d-07b.tapx Depth Units. .. .. .. ..... Datum specificat ion Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD OHMM 4 1 68 4 2 RPM MWD OHMM 4 1 68 8 3 RPS MWD OHMM 4 1 68 12 4 RPX MWD OHMM 4 1 68 16 5 FET MWD HOUR 4 1 68 20 6 GR MWD API 4 1 68 24 7 ROP MWD FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11775.5 13862 12818.8 4174 11775.5 13862 RPD MWD OHMM 0.13 2000 22.5453 3959 11845.5 13824.5 RPM MWD OHMM 0.1 1919.49 16.9711 3959 11845.5 13824.5 RPS MWD OHMM 0.1 2000 17.2674 3959 11845.5 13824.5 RPX MWD OHMM 0.29 1666.41 13.0967 3959 11845.5 13824.5 FET MWD HOUR 0.26 17.21 1.77978 3959 11845.5 13824.5 GR MWD API 15.4 170.45 47.4114 4030 11775.5 13811.5 ROP MWD FT/H 0.11 1845.98 80.8335 3966 11879.5 13862 First Reading For Entire File..........11775 Last Reading For Entire File...........13862 File Trailer Service name... .......STSLIB.001 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/26 Maximum Physical Record..65535 File Type ................L0 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.......08/02/26 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.001 Comment Record FILE HEADER FILE NUMBER: EDITED MERGED MAD Depth shifted DEPTH INCREMENT: FILE SUMMARY PBU TOOL CODE GR and clipped curves; all MAD runs merged using earliest passes. .5000 START DEPTH STOP DEPTH 11846.0 13813.0 Page 6 • ~ RPD FET RPM RPS RPX RAT MERGED DATA SOURCE PBU TOOL CODE MWD REMARKS: d-07b.tapx 11862.5 13827.5 11862.5 13827.5 11862.5 13827.5 11862.5 13827.5 11862.5 13827.5 11902.5 13866.0 MAD RUN NO. MAD PASS NO. MERGE TOP MERGE BASE 4 1 11847.5 13866.0 MERGED MAD PASS. Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Log~iny Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MAD OHMM 4 1 68 4 2 RPM MAD OHMM 4 1 68 8 3 RPS MAD OHMM 4 1 68 12 4 RPX MAD OHMM 4 1 68 16 5 FET MAD HOUR 4 1 68 20 6 SGRB MAD API 4 1 68 24 7 RAT MAD FT/H 4 1 68 28 8 First Last Name servi ce unit Min Max Mean Nsam Reading Reading DEPT FT 11846 13866 12856 4041 11846 13866 RPD MAD OHMM 0.12 1493.31 15.8463 3931 11862.5 13827.5 RPM MAD OHMM 0.2 2000 15.8139 3931 11862.5 13827.5 RPS MAD OHMM 0.37 1549.25 11.7282 3931 11862.5 13827.5 RPX MAD OHMM 0.4 364.33 8.92976 3931 11862.5 13827.5 FET MAD HOUR 2.38 128.25 61.9728 3931 11862.5 13827.5 SGRB MAD API 15.61 196.04 52.3173 3935 11846 13813 RAT MAD FT/H 26 1698 732.959 3928 11902.5 13866 First Reading For Entire File..........11846 Last Reading For Entire File...........13866 File Trailer Service name... .......STSLIB.002 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/26 Maximum Physical Record..65535 File Type ................Lo Page 7 • • d-07b.tapx Next File Name...........STSLIB.003 Physical EOF File Header Service name... .......STSLI6.003 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/26 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.002 Comment Record FILE HEADER FILE NUMBER: 3 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11779.0 12158.5 RPM 11860.0 12171.5 RPS 11860.0 12171.5 FET 11860.0 12171.5 RPD 11860.0 12171.5 RPX 11860.0 12171.5 ROP 11877.0 12202.0 LOG HEADER DATA DATE LOGGED: 28-NOV-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 12202.0 TOP LOG INTERVAL (FT): 11863.0 BOTTOM LOG INTERVAL (FT): 12202.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 79.6 MAXIMUM ANGLE: 87.8 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 82758 EWR4 ELECTROMAG. RESIS. 4 178425 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 11863.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 9.0 Page 8 d-07b.tapx MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 • 26000 5.8 .110 65.0 .050 147.1 .150 65.0 .120 65.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD020 OHMM 4 1 68 4 2 RPM MWD020 OHMM 4 1 68 8 3 RPS MWD020 OHMM 4 1 68 12 4 RPX MwD020 OHMM 4 1 68 16 5 FET MwD020 HOUR 4 1 68 20 6 GR MwD020 API 4 1 68 24 7 RoP MWD020 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11779 12202 11990.5 847 11779 12202 RPD MWD020 OHMM 0.16 1834.28 38.7104 624 11860 12171.5 RPM MWD020 OHMM 0.52 1919.49 28.0078 624 11860 12171.5 RPS MWD020 OHMM 3.75 2000 33.6172 624 11860 12171.5 RPX MWD020 OHMM 1.17 1666.41 16.9778 624 11860 12171.5 FET MwD020 HOUR 0.5 16.15 1.50449 624 11860 12171.5 GR MWD020 API 15.4 164.01 33.7233 719 11779 12158.5 ROP MWD020 FT/H 0.34 702.29 59.4128 651 11877 12202 First Reading For Entire File..........11779 Last Reading For Entire File...........12202 File Trailer Service name... .......STSLIB.003 service Sub Level Name... version Number...........1.0.0 Page 9 • • d-07b.tapx Date of Generation.......08/02/26 Maximum Physical Record..65535 File TyL~e ................L0 Next File Name...........STSLIB.004 Physical EOF File Header Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/26 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLIB.003 Comment Record FILE HEADER FILE NUMBER: 4 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NUMBER: 3 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 12159.0 13632.0 FET 12172.0 13645.5 RPX 12172.0 13645.5 RPS 12172.0 13645.5 RPM 12172.0 13645.5 RPD 12172.0 13645.5 ROP 12202.5 13676.0 LOG HEADER DATA DATE LOGGED: 02-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Incite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13676.0 TOP LOG INTERVAL (FT): 12202.0 BOTTOM LOG INTERVAL (FT): 13676.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 87.3 MAXIMUM ANGLE: 93.6 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 82758 EWR4 ELECTROMAG. RESIS. 4 178425 _ # BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 11863.0 BOREHOLE CONDITIONS MUD TYPE: Flo Pro Page 10 • • d-07b.tapx MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 9,0 MUD CHLORIDES (PPM): 22000 FLUID LOSS (C3): 4.8 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .130 65.0 MUD AT MAX CIRCULATING TERMPERATURE: .050 167.7 MUD FILTRATE AT MT: .090 65.0 MUD CAKE AT MT: .190 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data Specification Block Type.....0 Logging Direction .................DOwn optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth units. .. .. ..... Datum Specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD030 OHMM 4 1 68 4 2 RPM MWD030 OHMM 4 1 68 8 3 RPS MWD030 OHMM 4 1 68 12 4 RPX MwD030 OHMM 4 1 68 16 5 FET MwD030 HOUR 4 1 68 20 6 GR MWD030 API 4 1 68 24 7 RoP MWD030 FT/H 4 1 68 28 8 First Last Name service unit Min Max Mean Nsam Reading Reading DEPT FT 12159 13676 12917.5 3035 12159 13676 RPD MWD030 OHMM 9.56 20.28 14.7739 2948 12172 13645.5 RPM MWD030 OHMM 8.24 18.66 13.2669 2948 12172 13645.5 RPS MWD030 OHMM 8.24 19.05 12.9575 2948 12172 13645.5 RPX MWD030 OHMM 7.47 20.14 12.2714 2948 12172 13645.5 FET MwD030 HOUR 0.26 9.21 1.55293 2948 12172 13645.5 GR MWD030 API 24.53 111.62 50.0047 2947 12159 13632 ROP MWD030 FT/H 0.11 874.97 74.0996 2948 12202.5 13676 First Reading For Entire File..........12159 Last Reading For Entire File...........13676 File Trailer Page 11 • • d-07b.tapx Service name... .......STSLIB.004 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/26 Maximum Physical Record..65535 File Ty e ................L0 Next File Name...........STSLIB.005 Physical EOF File Header service name... .......STSLI6.005 Service Sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/26 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......ST5LI6.004 Comment Record FILE HEADER FILE NUMBER; 5 RAW MWD curves and log header data for each bit run in separate files. BIT RUN NUMBER: 4 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 13632.5 13811.5 RPX 13646.0 13824.5 RPD 13646.0 13824.5 FET 13646.0 13824.5 RPM 13646.0 13824.5 RPS 13646.0 13824.5 ROP 13676.5 13862.0 LOG HEADER DATA DATE LOGGED: 02-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13862.0 TOP LOG INTERVAL (FT): 13676.0 BOTTOM LOG INTERVAL (FT): 13862.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.3 MAXIMUM ANGLE: 92.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 82758 EWR4 ELECTROMAG. RESIS. 4 178425 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 DRILLER'S CASING DEPTH (FT): 11863.0 Page 12 • d-07b.tapx BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S): MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3): RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TERMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format Specification Record Data Record Type... ..........0 Data specification Block Type.....0 Log~iny Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. .. ..... Datum specification Block sub-type...0 • Flo Pro 8.60 65.0 9.0 22000 4.9 .130 65.0 .050 173.6 .090 65.0 .190 65.0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MWD040 OHMM 4 1 68 4 2 RPM MWD040 OHMM 4 1 68 8 3 RPS MWD040 OHMM 4 1 68 12 4 RPX MWD040 OHMM 4 1 68 16 5 FET MwD040 HOUR 4 1 68 20 6 GR MWD040 API 4 1 68 24 7 ROP MwD040 FT/H 4 1 68 28 8 First Last Name service Unit Min Max Mean Nsam Reading Reading DEPT FT 13632.5 13862 13747.3 460 13632.5 13862 RPD MWD040 OHMM 9.93 22.3 15.0957 358 13646 13824.5 RPM MWD040 OHMM 8.99 28.2 14.4699 358 13646 13824.5 RPS MWD040 OHMM 8.79 25.94 14.2523 358 13646 13824.5 RPX MWD040 OHMM 7.49 22.51 13.9424 358 13646 13824.5 FET MWD040 HOUR 0.34 17.22 3.48589 358 13646 13824.5 GR MWD040 API 23.79 170.45 55.3175 359 13632.5 13811.5 ROP MWD040 FT/H 7.39 1845.98 175.658 372 13676.5 13862 First Reading For Entire File..........13632.5 Last Reading For Entire File...........13862 Page 13 • d-07b.tapx File Trailer Service name... .......STSLIB.005 service sub Level Name... version Number. ........1.0.0 Date of Generation.......08/02/26 Maximum Physical Record..65535 File TyPe ................LO Next File Name...........STSLIB.006 Physical EOF File Header Service name... .......STSLI6.006 service sub Level Name... version Number. ........1.0.0 Date of Generation.... .08/02/26 Maximum Physical Record..65535 File Type. ............LO Previous File Name.......STSLI6.005 Comment Record FILE HEADER r: FILE NUMBER: 6 RAW MAD Curves and log header data for each pass of each run in separate files. DEPTH INCREMENT: .5000 MAD RUN NUMBER: 4 MAD PASS NUMBER: 1 FILE SUMMARY VENDOR TOOL CODE START DEPTH STOP DEPTH GR 11847.5 13813.0 RPD 11862.0 13827.5 RPS 11862.0 13827.5 FET 11862.0 13827.5 RPM 11862.0 13827.5 RPX 11862.0 13827.5 RAT 11899.0 13866.0 LOG HEADER DATA DATE LOGGED: 02-DEC-05 SOFTWARE SURFACE SOFTWARE VERSION: Insite DOWNHOLE SOFTWARE VERSION: 4.3 DATA TYPE (MEMORY OR REAL-TIME): Memory TD DRILLER (FT): 13862.0 TOP LOG INTERVAL (FT): 11863.0 BOTTOM LOG INTERVAL (FT): 13862.0 BIT ROTATING SPEED (RPM): HOLE INCLINATION (DEG MINIMUM ANGLE: 85.3 MAXIMUM ANGLE: 92.9 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE TOOL NUMBER GM Dual GR 82758 EWR4 ELECTROMAG. RESIS. 4 178425 Page 14 • • d-07b.tapx BO EHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): 4.125 RILLER'S CASING DEPTH (FT): 11863.0 BOR OLE CONDITIONS MUD TYPE: Flo Pro MUD DENSITY (LB/G): 8.60 MUD VISCOSITY (S): 65.0 MUD PH: 9,0 MUD CHLORIDES (PPM): 22000 FLUID LOSS (C3): 4.9 RESISTIVITY (OHMM) AT TEMPERATURE (DEG F) MUD AT MEASURED TEMPERATURE (MT): .130 65.0 MUD AT MAX CIRCULATING TERMPERATURE: .050 173.6 MUD FILTRATE AT MT: .090 65.0 MUD CAKE AT MT: .190 65.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): TOOL STANDOFF (IN): EWR FREQUENCY (HZ): REMARKS: Data Format specification Record Data Record Type... ..........0 Data specification Block Type.....0 Logging Direction .................DOwn Optical log depth units...........Feet Data Reference Point ..............undefined Frame Spacing....... ............60 .lIN Max frames per record .............undefined Absent value ......................-999 Depth Units. .. .. ..... Datum specification Block sub-type...0 Name service order units size Nsam Rep Code offset Channel DEPT FT 4 1 68 0 1 RPD MAD041 OHMM 4 1 68 4 2 RPM MAD041 OHMM 4 1 68 8 3 RPS MAD041 OHMM 4 1 68 12 4 RPX MAD041 OHMM 4 1 68 16 5 FET MAD041 HOUR 4 1 68 20 6 SGRB MAD041 API 4 1 68 24 7 RAT MAD041 FT/H 4 1 68 28 8 First Last Name Service Unit Min Max Mean Nsam Reading Reading DEPT FT 11847.5 13866 12856.8 4038 11847.5 13866 RPD MAD041 OHMM 0.12 1493.31 15.3619 3932 11862 13827.5 RPM MAD041 OHMM 0.2 2000 14.0567 3932 11862 13827.5 RPS MAD041 OHMM 0.37 1549.25 11.1659 3932 11862 13827.5 RPX MAD041 OHMM 0.4 364.33 8.86975 3932 11862 13827.5 FET MAD041 HOUR 2.38 128.25 61.8555 3932 11862 13827.5 SGRB MAD041 API 15.61 196.04 52.511 3932 11847.5 13813 RAT MAD041 FT/H 26 1698 732.017 3935 11899 13866 Page 15 • • d-07b.tapx First Reading For Entire File..........11847.5 Last Reading For Entire File...........13866 File Trailer Service name... .......STSLIB.006 service sub Level Name... version Number. ........1.0.0 gate of Generation.......08/02/26 Maximum Physical Record..65535 File TyE~e ................L0 Next File Name...........STSLIB.007 Physical EOF Tape Trailer Service name .............LISTPE gate . ...................08/02/26 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 gate . ...................08/02/26 Ori gin ...................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 Page 16
