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Home My WebLink About196-029Samuel Gebert Hilcorp Alaska, LLC GeoTech Assistant 3800 Centerpoint Drive, Suite 1400 Anchorage, AK 99503 Tele: 907 777-8337 Fax: 907 777-8510 E-mail: sam.gebert@hilcorp.com Please acknowledge receipt by signing and returning one copy of this transmittal or FAX to 907 777.8510 Received By: Date: DATE: 11/12/2020 To: Alaska Oil & Gas Conservation Commission Natural Resource Technician 333 W 7th Ave Suite 100 Anchorage, AK 99501 DATA TRANSMITTAL MPU C-28ai (PTD 196-029) Injection Profile 08/17/2020 Please include current contact information if different from above. Received by the AOGCC 11/13/2020 PTD: 1960290 E-Set: 34245 Abby Bell 11/13/2020 A STATE OF ALASKA A ALAS~IL AND GAS CONSERVATION CO~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG RECEIVED .APR 2 4 2006 Alaska o¡¡ & Coos" Commission 1 a. Well Status: D Oil DGas D Plugged ~ Abandoned D Suspended DWAG 1b. Well Class: nllv,',' "\:I" 20AAC 25.105 20AAC 25.110 D Development D Exploratory DGINJ DWINJ D WDSPL No. of Completions Zero Other D Stratigraphic ~ Service 2. Operator Name: 5. Date Comp., Susp., or Aband. ~ 12. pe~=Drill Number ~þ ~ BP Exploration (Alaska) Inc. ~12005 I--¿· ì- ":.:.. . 196- .t>1!f 305-322 ,¡.zÜ 3. Address: 6. Date Spudded 7/.':,.(,..ÞI 13. API Number P.O. Box 196612, Anchorage, Alaska 99519-6612 02/17/1996 50- 029-22648-00-00 4a. Location of Well (Governmental Section): 7. Date T.o. Reached 14. Well Name and Number: Surface: 04/08/1996 MPC-28i 837' FSL, 2341' FEL, SEC. 10, T13N, R10E, UM 8. KB Elevation (ft): 15. Field 1 Pool(s): Top of Productive Horizon: 3197' FSL, 226' FEL, SEC. 09, T13N, R10E, UM 46.52' Milne Point Unit 1 Kuparuk River Sands Total Depth: 9. Plug Back Depth (MD+ TVD) 3330' FSL, 410' FEL, SEC. 09, T13N, R10E, UM 8615 + 7265 Ft 4b. Location of Well (State Base Plane Coordinates): 10. Total Depth (MD+TVD) 16. Property Designation: 8720 , + 7361 . Ft ADL 047434 . Surface: x- 558121 . y- 6029119 ' Zone- ASP4 TPI: x- 554935 y- 6031454 Zone- ASP4 11. Depth where SSSV set 17. Land Use Permit: Total Depth: x- 554750 y- 6031586 Zone- ASP4 N/A MD 18. Directional Survey 19. Water depth, if offshore 20. Thickness of Permafrost DYes ~No N/A MSL 1800' 21. Logs Run: GYRO,LWD,EMSS,GRISBT/CCL 22. CASING, LINER AND CEMENTING RECORD CA$!NG : WT.~·"'· .·ii SEJTNG.DEP"R-ItAO ,.SETTING·I)E:PTfI"tyO ·.~?;;t .' .··i· <2. .i', ii' i'AA ·i Size GRA6e .' ........ ····i I ....."..,. TOÞ B01"TOM TOP B01"TOM ...... ..... ii i....'. 20· 91.1# H-40 32' 112' 32' 112' 24" 250 sx Arcticset 1 (Approx.) 9-5/8" 40# L-80 31' 5405' 31' 4642' 12-1/4" 1200 sx PF 'E'. 250 sx 'G'. 150 sx 7" 26# L-80 5476' 8696' 4698' 7339' 8-1/2" 250 sx 'G' 23. Perforations open to Production (MD + TVD of Top and 24~ )< . . ····T JBING ·).i )))I.ti;!!,. )it<..I()(;)····i ·····.·.·i.·i·······.·· Bottom Interval, Size and Number; if none, state "none"): SIZE DEPTH SET (MD) PACKER SET (MD) None 3-1/2", 9.2#, L-80 7856' - 8117' 8079' MD TVD MD TVD 25~. ..... ................ A....,'" ";':" )i<?i,·;t;ti;it.1il i.·...·· Si.·;,t..Y'~:,,\jÞ~f· DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED '"' 7932' P&A with 25 Bbls Class 'G' '""'....... ,," 5529' Set CIBP 5506' 2nd plug with 30.5 Bbls of Class 'G' 26. PRODUCTION TEST Date First Production: Method of Operation (Flowing, Gas Lift, etc.): Not on Injection N/A Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAs-McF W A TER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD ... Flow Tubing Casing Pressure CALCULATED ... OIL -BBL GAs-McF W A TER-BBL OIL GRAVITy-API (CORR) Press. 24-HoUR RATE 27. CORE DATA Brief ~escriptio~ of !ithology, por~sity, f~actures, apparent diP~nd presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; If none, state none. . '"' ,¿ . ':'>-....:J.-~ ;-"'-'"'~-", " ,~r'~ .\:\'<. :.. None t-\\'<- - J '6 ~ ~'_<-:>'v 0<"" ~ CAP!; ! 'U /Jt-V'yv'\. 41 '" ~ .iZ..:-.2fi~ ' RBDMS 8Ft APR 2 8 2006 '7 ~"~~~ " ~ 6 j .:~:~~i¡'i)' ¡ Form 10-407 Revised 12/2003 o RIG I i ~ ~ ~D ON REVERSE SIDE ~b<6 ~b c{. 2../.. .0(,. , ;/ ~11æ; ~ 28. GEOLOGIC MARKE 29. ORMATION TESTS NAME MD TVD Include and briefly summarize test results. List intervals tested, and attach detailed supporting data as necessary. If no tests were conducted, state "None". Top of Kuparuk 'C' Top of Kupaurk 'B' 8163' 6852' None 8263' 6944' Top of Kuparuk 'A' 8367' 7038' Top of Kuparuk 'A3' 8380' 7050' Top of Kuparuk 'A2' 8393' 7062' Top of Kuparuk 'A l' 8413' 7080' 30. List of Attachments: Summary of Daily Drilling Reports and Pre-Rig Summary. 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Signed Title Technical Assistant Date MPC-28i Well Number 196-069 305-322 Permit No.1 Approval No. INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Prepared By Name/Number: Drilling Engineer: Sondra Stewman, 564-4750 Skip Coyner, 564-4395 ITEM 1a: 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 legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-28A MPC-28A DRlll+COMPlETE DOYON DRilLING INC. DOYON 14 Start: Rig Release: Rig Number: 12/18/2005 1 /8/2006 Spud Date: 12/18/2005 End: 12/19/2005 19:00 - 00:00 5.00 MOB P PRE Skid rig floor, Move off MPH-15, on to road 12/20/2005 00:00 - 06:00 6.00 MOB P PRE Move rig to MPC-28A 06:00 - 08:00 2.00 MOB P PRE Spot rig over well - Shim same 08:00 - 09:00 1.00 MOB P PRE Skid rig floor from move position to move position - Spot rock washer 09:00 - 11 :00 2.00 RIGU P PRE Rig up floor - Top drive - Steam, water, air - Berm rock washer 11 :00 - 12:00 1.00 RIGU P PRE Rig up lines to tiger tank and tree (Accept rig @ 11 :00 hrs) 12:00 - 13:30 1.50 RIGU P PRE RU lubricator - Pull BPV - RU to bleed to tank 13:30 - 16:30 3.00 RIGU P PRE Displace freeze protection from well - Pump 50 bbls hot seawater - 34 bbls soap pill - 300 bbls of seawater - Spot 100 bbls 13,9 ppg LSND mud @ 7856' (tubing cut) - Chase with 40 bbls seawater - 215 gpm - @ 2130 psi 16:30 - 17:30 1.00 RIGU P PRE Install TWC - Test to 3000 psi - RD circ lines 17:30 - 18:30 1.00 RIGU P PRE ND Tree 18:30 - 21 :30 3.00 RIGU P PRE NU stack - Flow line - Mouse hole 21 :30 - 23:00 1.50 RIGU P PRE MU test joint - RU to test BOP's 23:00 - 00:00 1.00 RIGU P PRE Test BOP's - Test rig alarms - Good test on alarms - Test Annular 250 low 2500 high 5 mins each test 12/21/2005 00:00 - 07:30 7.50 EVAL N OTHCMP Attempt to test BOP's - No test loss 200 psi on Annular - Top Rams - Blind rams - Attempt to test Choke manifold - No test - Warming up manifold - Regreasing all valves - (while waiting on Lubricator from 4ES) - Change out XO's on lubricator - make up lubricator to hanger - Pull TWC - inspect TWC - Plugged with mud and debris - Change out TWC - Install same - Attempt to pressure up on TWC - Same results - Unable to get test - (Called AOGCC Chuck Scheve - Discussed body and casing test to 3500 pull tubing and retest BOPS when tubing layed down) 07:30 - 08:00 0.50 EVAL P OTHCMP RD lubricator - RU to test with blind rams closed 08:00 - 09:00 1.00 EVAL P OTHCMP Test casing to 3500 psi for 15 mins - Test good - Test recorded on chart 09:00 - 10:30 1.50 STCTPL P OTHCMP MU landing joint 3 1/2" NSCT - Pull hanger to rig floor - 105K PUW - LD Hanger 10:30 - 18:00 7,50 STCTPL P OTHCMP Stand back 5 stands in derrick - LD 233 Joints plus 16.34' of 3 1/2" NSCT 9.3# tubing 18:00 - 18:30 0.50 EVAL P OTHCMP Install test plug - RU to test BOP's - Open annulus valves 18:30 - 00:00 5.50 EVAL P OTHCMP Test BOP's - Annular 250 low 2500 high 5 mins each test - Top rams - Choke manifold - Flange on # 12 valve leaking - Tighten up flange - Retest - test good - Manual Choke / Kill valves - HCR Choke / Kill valves - Choke HCR failed high test - Greased valve - Retest - Test good - Upper / Lower IBOP valves - Floor safety valves - Blind rams - 250 low 4500 high 5 mins each test - Preformed Accumulator test - All equipment tested successful - WSL witnessed all test - John Crisp with AOGCC wavied witness of BOP test - RD testing equipment - Close annulus valves - Pull test plug - install wear ring 12/22/2005 00:00 - 01 :00 1.00 EVAL P OTHCMP RD testing equipment - Close annulus valves - Pull test plug - install wear ring - Blow down choke manifold - Choke line - Kill line 01 :00 - 01 :30 0.50 STCTPL P OTHCMP Moblize BHA to rig floor 01 :30 - 02:00 0.50 STCTPL P OTHCMP I MU bit - casging scraper - Bit Sub - XO - PU 1 stand of 4" DP from pipe shed Printed: 1/9/2006 9:41 :41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-28A MPC-28A DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 12/18/2005 1/8/2006 Spud Date: 12/18/2005 End: 12/22/2005 02:00 - 03:00 1.00 STCTPL P OTHCMP Cut drlg line - Service top drive 03:00 - 07:30 4.50 STCTPL P OTHCMP Con't PU 4" DP from pipe shed 1 x 1 to 5700' - LD a single - Pull 1 stand to 5563' 07:30 - 09:00 1.50 STCTPL P OTHCMP Pump 25 bbl Hi-vis sweep - @ 400 GPM - PP 1420 psi - Pump 2nd Hi-vis sweep - GPM 415 - PP 1425 - Pump dry job 09:00 - 11 :00 2.00 STCTPL P OTHCMP Blow down top drive - POH - LD XO's - Casg scraper - Bit 11 :00 - 12:00 1.00 STCTPL P OTHCMP Change bails - PU 350 ton elevators 12:00 - 15:30 3.50 STCTPL P OTHCMP PJSM - RU Schlumberger - RIH with Howco 7 " CIBP - CCI - Set Bridge plug @ 5529' - POH 15:30 - 16:30 1.00 STCTPL P OTHCMP RU testing equipment - Test CIBP 2500 psi for 30 mins- Record on chart - Test good 16:30 - 18:00 1.50 STCTPL P OTHCMP Pull 7" Pack·off - MU Landing joint - Establish stretch points - 50K pull 7.5" stretch indicates 2830' free - 100K pull 18.5" stretch indicates 3491' free 18:00 - 00:00 6.00 STCTPL P OTHCMP RU wire line - RIH with 7" free point tool - Take free point readings - 5494' - 0% free - 4494 33% free - 3494 72% free - 330092% free - 3170 95% free - 2900 100% free - 50K pull - Attempt to free point with 100K pull - Free point tool quit working - POH 12/23/2005 00:00 - 02:00 2.00 STCTPL P OTHCMP POH with Free point tool - Inspect free point tool - Tool functioning properly - Possible over heated motor - Change out free point tool 02:00 - 06:30 4,50 STCTPL N WAIT OTHCMP Crew over 16 hrs - Waiting on crew from Schlumberger yard to continue free point operation 06:30 - 11 :30 5.00 STCTPL P OTHCMP Run free point tool - 100K over pull - 5485 / 0% free - 5000' / 0% free - 4485/53 to 69 - 64% free - 4760 / 0% - 4640/35 to 32% - 4000 / 68 to 78% - 3485 / 80 to 86% - 3300 / 88% - 200K over 4760 / 7% free - 4640 / 57% free - 4485 / 74% free - 4000/58 to 61 % - 3485 / 80% to 82% free 11 :30 - 13:00 1.50 STCTPL P OTHCMP LD landing joint - Install pack-off - Test same 13:00 - 14:30 1.50 STCTPL P OTHCMP PJSM - Install test plug - Change top rams to 7" 14:30 - 15:00 0.50 STCTPL P OTHCMP Test door seals to 1500 psi - Test good 15:00 - 16:00 1,00 STCTPL P OTHCMP LD 350 ton casg elevators - Change out long bails 16:00 - 16:30 0.50 STCTPL P OTHCMP MU BHA - Casg cutter assy 16:30 - 18:00 1.50 STCTPL P OTHCMP RIH to 4708' - Locate collar @ 4783 18:00 - 18:30 0.50 STCTPL P OTHCMP Cut 7" casg @ 4793' - GPM 150 - PP 550 - RPM 70 - TO 2K 18:30 - 19:30 1.00 STCTPL P OTHCMP Circ through cut casg taking returns out outer annulus to bleed tank - Pump 210 bbls 8.3 ppg seawater 5 BPM @ 1200 psi 19:30 - 20:00 0.50 STCTPL P OTHCMP Pressure up on 9 5/8" to 2380 psi - Pumped 3.8 bbls - Held 5 mins - No pressure drop - Bleed off pressure 20:00 - 21 :00 1 .00 STCTPL P OTHCMP Circulate unbalanced mud - Circulate to level out - GPM 300 - PP 1980 21 :00 - 21 :30 0.50 STCTPL P OTHCMP RIH - Locate collar @ 5381' 21 :30 - 22:30 1.00 STCTPL P OTHCMP Cut 7" casg @ 5392' - RPM 70 - TO 2K - GPM 200 - PP 600 - 22:30 - 23:00 0,50 STCTPL P OTHCMP Pull 4 stands to 4890' - Locate collar @ 4983' 23:00 - 23:30 0.50 STCTPL P OTHCMP Cut 7" Casg @ 4993' - RPM 70 - TO 2K - GPM 200 - PP 550 23:30 - 00:00 0.50 STCTPL P OTHCMP CBU 1 X - GPM 380 - PP 2070 - Flow check well 12/24/2005 00:00 - 02:00 2.00 STCTPL P OTHCMP POH with Baker cutting assy 02:00 - 02:30 0.50 STCTPL P OTHCMP LD Baker cutting assy 02:30 - 04:00 1.50 STCTPL P OTHCMP Pull wear ring - Pack-off 04:00 - 04:30 0.50 STCTPL P OTHCMP Make up 7" casg spear - Engage spear - Pull casg hanger to floor- PUW 175 -160 Printed: 1/9/2006 9:41:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-28A MPC-28A DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 12/18/2005 1/8/2006 Spud Date: 12/18/2005 End: 12/24/2005 04:30 . 06:00 1,50 STCTPL P OTHCMP LD Spear - 2 joints 5" HWDP - Clear floor of fishing tools - 350 ton elevators - RU casg tools to LD 7" Casg 06:00 - 12:00 6.00 STCTPL P OTHCMP RU Casg equipment - LD 119 joints + 10.7 cut joint of 7" Casg 12:00 - 12:30 0.50 STCTPL P OTHCMP Clear rig floor 12:30 - 13:30 1.00 STCTPL P OTHCMP PU Test jt - Install test plug· Change 7" rams to 2 7/8' x 5' VBR rams 13:00 - 14:00 1.00 STCTPL P OTHCMP Test door seals to 1500 psi - LD test jt / test plug - Install wear ring 14:00 - 15:00 1,00 STCTPL P OTHCMP Moblize BHA to floor - C/O handling equipment 15:00 - 16:00 1,00 STCTPL P OTHCMP MU BHA - Spear - Jars - Bumper sub - 5" HWDP . 16:00 - 17:30 1 .50 STCTPL P OTHCMP Wait on accelerator jar from Baker 17:30 - 19:00 1.50 STCTPL P OTHCMP Make up accelerator - RIH with spear to 4793' - PUW 128 - SO 108 19:00 - 19:30 0.50 STCTPL P OTHCMP Engage spear on casg - Jar 4 times 250k jar - Casing free 19:30 - 21:30 2.00 STCTPL P OTHCMP POH with 7 casg - 200' POH over 40K - Weight dropped to 5k over PU weight 21 :30 - 23:30 2.00 STCTPL P OTHCMP Stand back HWDP - LD Jar - LD spear - LD top stub 29.20' + 4 jts 7" casg + 7.20 cut joint (total joint laid down 124 + 7.20') 23:30 - 00:00 0.50 STCTPL P OTHCMP PU Spear assy - Inspect grapples 12/25/2005 00:00 - 01 :30 1.50 STCTPL P OTHCMP RIH with spear assy to 4990' 01 :30 . 05:30 4.00 STCTPL P OTHCMP Engage fish with spear @ 4993' - Jar on casing - Release from fish 05:30 - 07:30 2,00 STCTPL P OTHCMP Blow down top drive - POH with spear assy 07:30 - 09:00 1 .50 STCTPL P OTHCMP LD Spear assy - MU Cutting assy 09:00 - 10:30 1.50 STCTPL P OTHCMP RIH with cutting assy to 5392' confim cut 10:30 - 13:00 2.50 STCTPL P OTHCMP Pull up locate collar @ 5300' cut casg @ 5310' - Pull up locate collar 5140' cut casg @ 5150' . PUW 120 - SO 108 - RPM 70 to 80 - GPM 150 to 167 - PP 600 to 630 -TQ3K 13:00 - 14:00 1.00 STCTPL P OTHCMP POH with cutter assy 14:00 - 14:30 0.50 STCTPL P OTHCMP Repair iron roughneck hydralic hose 14:30 - 15:30 1.00 STCTPL P OTHCMP Con't POH with cutter assy 15:30 - 17:30 2,00 STCTPL P OTHCMP LD BHA cutter assy - MU Spear assy - C/O Jars - Grapple - Pack-off - Accelerator 17:30 - 19:00 1.50 STCTPL P OTHCMP PJSM - Cut drlg line - Rig service 19:00 - 20:30 1.50 STCTPL P OTHCMP RIH to 4993' - PUW 133 - SO 108 - Engage spear - PU to 150K - Drag fell off to 7K over string weight - (top of fish 5150') 20:30 - 22:00 1.50 STCTPL P OTHCMP POH with fish 22:00 - 23:30 1.50 STCTPL P OTHCMP LD accelerator - Stand back HWDP - LD spear - LD stub 28,67' + 3 jts of 7" casg - LD cut joint 9.95' - (Total 7" casg recovered 128 jts + 9.95') 23:30 - 00:00 0.50 STCTPL P OTHCMP Clear rig floor - Moblize BHA to rig floor 12/26/2005 00:00 - 00:30 0.50 STCTPL P OTHCMP Moblize BHA 00:30 - 02:00 1 .50 STCTPL P OTHCMP MU BHA - PU 1261/4" DC's 02:00 - 03:30 1 .50 STCTPL P OTHCMP RIH to 5086' 03:30 - 04:00 0.50 STCTPL P OTHCMP Wash to 5150' - PUW 160 - SO 125 - Engage spear· Jar casg loose - Work casg up hole - Pulling 225 to 325 (60 to 165 over string weight) for 74' - Weight dropped to 6K over string weight to 165K . (top of fish 5310') 04:00 - 07:00 3.00 STCTPL P OTHCMP Blow down top drive - Flow check - POH with fish 07:00 - 08:00 1.00 STCTPL P OTHCMP Stand back BHA 08:00 - 08:30 0.50 STCTPL P OTHCMP LD 2 Cut joints 11' and 30.11' + 3 joints - (total recovered 122 joints + 11 ') Printed: 1/9/2006 9:41:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-28A MPC-28A DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 12/18/2005 1/8/2006 Spud Date: 12/18/2005 End: 12/26/2005 08:30 - 09:30 1.00 STCTPL P OTHCMP MU Spear Assy 09:30 - 11 :00 1.50 STCTPL P OTHCMP RIH to 5192' 11 :00 - 12:00 1.00 STCTPL P OTHCMP Wash down from 5192' to 5310' - Engage grapple - Jar fish loose - Over pull 100 to 150 for 50' - Over pull dropped to 3to 5K over normal string weight 12:00 - 13:30 1.50 STCTPL P OTHCMP POH with fish 13:30 - 16:00 2.50 STCTPL P OTHCMP Stand back HWDP - DC's - LD Accelerator - Spear - Casg stub 28.71' + 1 jt casg + 10.88 cut joint - (total 7" casg joints recovered 124 + 10.88') 16:00 - 17:30 1.50 STCTPL P OTHCMP Clear rig floor - LD jars - Bumper sub - Service break spear 17:30 - 18:00 0.50 STCTPL P OTHCMP Moblize Milling BHA to rig floor 18:00 - 19:00 1.00 STCTPL P OTHCMP PJSM - MU Milling assy - Mill - DC's - Jars - HWDP 19:00 - 20:30 1,50 STCTPL P OTHCMP RIH to @ 5390' 20:30 - 21 :30 1 .00 STCTPL P OTHCMP Circ - Bleed in milling fluid - GPM 320 - PP 580 - RPM 50 - TO 4K 21 :30 - 00:00 2.50 STCTPL P OTHCMP Milling 7" casing from 5392' to 5402' - GPM 600 - PP 1260 - RPM 80 - TO 4K - PU 140 - SO 115 - ROT 125 12/27/2005 00:00 - 12:00 12.00 STCTPL P OTHCMP Milling casg from 5402' to 5476' - WOM 6 to 8 - RPM 80 - TO 4 to 5.5K - GPM 600 - PP 1280 - PU 135 - SO 115 - ROT 120 12:00 - 15:30 3.50 STCTPL P OTHCMP Circulate - Clear metal out of hole 15:30 - 22:00 6.50 STCTPL P OTHCMP POH to shoe - Flow check - Pump dry job - POH Drag 20 to 50 over - Pump / Back ream out 5 stands - Attempt to pull with out pump back ream - Pulled tight - Con't Pump back ream to 1819' - GPM 550 - PP 890 - RPM 100 - TO 2K - POH without pump or back reaming - Stand back HWD - LD DC's - Jars - Mill - (No metal ball on BHA) 22:00 - 22:30 0.50 STCTPL P OTHCMP Clear rig floor - Pull wear ring 22:30 - 00:00 1.50 STCTPL P OTHCMP MU stack washer - Flush stack - Function rams, Annular, - Flush stack - Flush choke line / kill line - Install wear ring 12/28/2005 00:00 - 00:30 0.50 DRILL P INT1 RU tubing equipment 00:30 - 01 :00 0.50 DRILL P INT1 Run 16 joints NSCT 3 1/2" tubing to set cement kick off plug 01 :00 - 00:30 23.50 DRILL P IINT1 Change 3 1/2" handling equipment to 4" - RIH with 4" DP to 5308' - Taking weight 5 to 10K 03:00 - 04:00 1.00 DRILL INT1 Wash from 5296' to CIBP @ 5529 - PU to 5527' 04:00 - 04:30 0,50 DRILL P INT1 RU cementing lines - Beak circulation 6 BPM - PP 600 psi - 04:30 - 05:00 0.50 CEMT P INT1 Give to Dowell Close Annular - Pumping through choke Pump 5 bbls water Test lines to 3000 - Test good Pump 24.5 bbls water Pump 30.5 bbls 17 ppg cement - Yield 1,00 cuftlsx Pump 5 bbls water Rig displace with 46 bbls mud @ 5 bpm Last barrel of displacement choke plugged pressure increased to 1350 - Shut down pressure held - Bleed off pressure through fill line and kill line back through pumps - Open Annular 05:00 - 06:00 1.00 DRILL P INT1 POH slowly to 4566' 06:00 - 07:00 1.00 DRILL P INT1 Pump 30 bbl nut plug sweep - 8.6 bpm @ 550 psi - Reciprocating string 07:00 - 08:30 1.50 DRILL P INT1 Continue POH to 3 1/2" tubing 08:30 - 09:30 1,00 DRILL P INT1 LD 3 1/2" tubing 09:30 - 1 0:00 0.50 DRILL P INT1 Rig down tubing equipment- clear floor 10:00 - 13:00 3.00 DRILL P INT1 I PU 108 jts, 4" DP from shed to 3600' Printed: 1/9/2006 9:41:41 AM Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: MPC-28A MPC-28A DRILL+COMPLETE DOYON DRILLING INC. DOYON 14 Start: Rig Release: Rig Number: 12/18/2005 1/8/2006 Spud Date: 12/18/2005 End: 12/28/2005 Pump sweep- Circ. surface to surface 3X- Flow check, dry job POH Pull wear ring- Flush BOPE & function same PU test joint - Pull wear ring - Install test plug - Open annulus valves - RU to test BOPE 17:30 - 21 :00 INT1 Test BOP's - Annular 250 low 2500 high - 5 mins each test- Pipe rams - Choke manifold - HCR Choke I Kill - Manual Choke I Kill - Upper I Lower IBOP - Floor safety valves - Blind rams - 250 low 4500 high - 5 mins each test - Perform accumulator test - All test were successful - All test were witnessed by WSL - John Crisp with AOGCC waived witness of BOP test 21 :00 - 21 :30 0.50 BOPSU P INT1 RD test equipment - Pull Test plug - Install wear ring - Close annulus valves - LD test joint - Blow down choke manifold I line - Kill line - Top drive 21 :30 - 22:00 0.50 DRILL P INT1 Moblize 8 1/2" short BHA to rig floor 22:00 - 00:00 2.00 DRILL P INT1 MU 81/2" BHA - Bit - Motor @ 1.5 degree - MWD-Orient - NM DC's - Surface test 12/29/2005 00:00 - 01 :30 1.50 DRILL P INT1 MU BHA 01 :30 - 02:30 1.00 DRILL P INT1 Cut drlg line - Top drive service 02:30 - 04:00 1.50 DRILL P INT1 RIH to 4850' 04:00 - 05:00 1.00 DRILL P INT1 Wash from 4850' to 5135' - Tag Cement @ 5135' - WO pump 8 to 10K 05:00 - 08:30 3.50 DRILL P INT1 Drilling cement from 5135 -1 to 2K with pump 400 GPM - 5212 WO pump 15K - With pump 2 to 3K -Drilling firm cement fl 5245' to 5506' 8 to 1 OK with pump 400 GPM - PP 1200 - RPM 38 08:30 - 10:30 2.00 DRILL P INT1 Time drill fl 5406' to 5419' 10:30 - 12:00 1.50 DRILL P INT1 Displace well wi 8.7 ppg LSND mud. 400 gpm 70 rpm 5k tq,- No metal observed wi returns. 12:00 - 18:30 6.50 DRILL P INT1 Time drill fl 5419' to 5470' - 18:30 - 19:30 1.00 DRILL P INT1 RU test equipment - FIT - MD 5405 - TVD 4611 - MW 8.6 - Surface pressure 940 = EMW 12.52 - RD test equipment - !Jt~ down lines <:. ~X\ 19:30 - 00:00 4.50 DRILL P INT1 Directional drill from 5470 to 5708' - WOB 7 to 10 - RPM 60 - ~~~ c.-tr· TO 7 on - 6 off - GPM 545 - PP on 2300 - off 2160 - PU 162- ",,¡,-~ SO 115 - ROT 135 12/30/2005 00:00 - 00:00 24.00 DRILL P INT1 Directional Drill from 5708' to 7275' - WOB 10 to 20 - RPM 80 - TO on 6 - off 6 - GPM 550 - PP on 3760 - off 3500 - PU 150- SO 120 - ROT 137 12/31/2005 00:00 - 02:30 2,50 DRILL P INT1 Directional Drill from 7275' to 7431' - WOB 15 - RPM 80 - TO on 7 - off 6 - GPM 550 - PP on 3800 - off 3650 - PU 155 - SO 122 - ROT 136 02:30 - 04:00 1.50 DRILL P INT1 CBU 2,5 X - RPM 80 - TO - GPM 550 - PP 3600 - Flow check - Well static 04:00 - 05:30 1.50 DRILL P INT1 Pump to shoe @ 5400' - Pump at drlg rate 05:30 - 06:30 1.00 DRILL P INT1 CBU 2 X - RPM 40 - GPM 540 - PP 2900 06:30 - 07:30 1.00 DRILL P INT1 RIH- Wash last stand to bottom. 07:30 - 00:00 16.50 DRILL P INT1 Directional drill f/ 7431' to 8390' - WOB 10 to 20 - RPM 80 - TO 7 on - 6 off - GPM 510 - PP on 3900 - off 3680 - PU 168 - SO 130 - ROT 148 1/1/2006 00:00 - 12:30 12.50 DRILL P INT1 Directional Drill from 8390' to 8773' ( 8 1/2" TD)- PU 200k- SO 135k- ROT 155k- RPM 80- Tq 10k on 9k off- PP 3470 on 3200 loff-500 gprn- WOB 5-20k, I I Printed: 1/9/2006 9:41:41 AM . . . . Well: Field: API: Permit: MPC-28A Milne Point Unit I Kuparuk River Sands 50-029-22648-01-00 205-163 Accept: Spud: Release: Rig: 12/20/05 12/29/05 01/08/06 Doyon 14 PRE-RIG WORK 11/09/05 T/I/O=2960/0/240. (PREP FOR SIDETRACK). MIT IA TO 2000 PSI. PASSED. PRESSURED IA TO 2000 PSI WITH 2.7 BBLS OF METHANOL. IA LOST 0 PSI IN FIRST 15 MINUTES AND 0 PSI IN SECOND 15 MINUTES FOR A TOTAL OF 0 PSI IN 30 MINUTES. BLEED IA DOWN TO 0 PSI. FWP=2960/0/240. 11/10/05 TAGGED TD @ 8548' CMD 130' OF RAT HOLE BELOW BOTTOM PERF. SOFT BOTTOM 11/13/05 CTU 5 - MIRU - MU 2" BDN - KILL WELL - HAD TO BLEED STATIC PRES.(1200 PSI) TO 400 TO START RIH. TAG BOTTOM @ 8,536' PU DEPTH 8,532. PUH AND PAINT FLAG (WHITE) @ 8,522' IR DOWN CT 2290 @ 1 BPM. RU SLB CEMENT TRUCKS. 11/14/05 PLUG AND ABANDON PERFS 8,242 TO 8,418 WI 25 BBLS CLASS G CEMENT IR 2050 @ 1BPM. MIX & PUMP 25.4 BBLS CLASS G CEMENT. LAY IN FROM 8522 TO 7450. (4.2 BBLS BEHIND PIPE). PULL TO SAFETY AND SQUEEZE ADDITIONAL 3.2 BBLS CEMENT INTO PERFS. FINAL SQUEEZE PRESSURE 1920. TOTAL BEHIND PIPE=7.4 BBLS. CONTAMINATE CEMENT TO 7,950' AND CHASE OUT OF HOLE @ 80%. FP WI METH 2,500'. TRAP 1500 PSI ON WELL RIG DOWN JOB COMPLETE 11/17/05 TAG CEMENT @ 7932' SLM. 11/18/05 (PREP FOR SIDETRACK) MIT OA TO 1200 PSI. PASSED. PRESSURED OA TO 1200 PSI WITH 3.3 BBLS OF DIESEL. OA LOST 50 PSI IN FIRST 15 MINUTES & 0 PSI IN SECOND 15 MINUTES FOR A TOTAL OF 50 IN 30 MINUTES. BLEED OA PRESSURE DOWN TO 340 PSI. FWP=900/0/340. 11/21/05 MIT TBG TO 2000 PSI. PASSED PRESSURED TBG TO 2000 PSI WITH 1 BBL OF DIESEL. TBG LOST 10 PSI IN FIRST 15 MINUTES & 0 PSI IN SECOND 15 MINUTES FOR A TOTAL OF 10 PSI IN 30 MINUTES. BLEED TBG DOWN TO 400 PSI. FWP=400/0/330. 11/28/05 TIIIO = SI/0/320 TESTED CASING PACKOFF TO 3000 PSI. PRESSURE WAS 3000 PSI AT 15 MIN. AND 3000 PSI. AT 30 MIN. TEST PASSED. ALL LOCKDOWN SCREWS WERE FUNCTIONED. TESTED TUBING HANGER TO 5000 PSI. PRESSURE WOULD DROP OFF 500 PSI IN 5 MIN. TIGHTENED LDS TO 450 FT LBS. TRIED TWICE MORE TO PRESSURE UP TO 5000 PSI. IN ALL CASES PRESSURE WOULD DROP OFF 500 PSI IN FIRST 5 MIN. TEST FAILED. 11/30/05 TIIIO 500/0/400 SHOE BREAKDOWN ATTEMPT. PRESSURED OA TO 3500 PSI WITH 3.2 BBLS CRUDE. OA PRESSURE WAS STABLE. BLED PRESSURE OFF. FINAL WHP=500/0/400 MPC-28A Page 2 . . , . 12/04105 CUT 3.5" TUBING AT 7856.2' WITH 2.75" SCP JET CUTTER. NO LOG OR JEWELERY TO TIE IN TO. LOGGED USING PRIMARY DEPTH CONTROL, ALL DEPTHS APPROXIMATE. TOOL ZEROED USING ORIGNAL KB/DF DEPTHS AND GROUND LEVEL ELEVATIONS. 12/16/05 (PRE-RWO) FLUSH GAS INJECTION LINE W/2 BBLS NEET METH FOLLOWED BY 5 BBLS DIESEL @ 100*. FLUSH WATER INJECTION LINE W/2 BBLS NEET METH FOLLOWED BY 5 BBLS DIESEL @ 100*. ,þ'" ," ~.'. . If.,. Jir,'.Ü· .... .. 1..rF: ·11 Ü\· I? , . UiIl\, lb e lffìl ~ lÆ\ nlA.A \ ~ ftZ 1M J..U !J lru Lb 1.rü æJ U \l LrlJ e AI,ASIiA OIL A1Q) GAS CONSERVATION COMMISSION FRANK H. MURKOWSKI, GOVERNOR 333 W. 7'" AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501·3539 PHONE (907) 279-1433 FAX (907) 276-7542 Dan Kara Senior Drilling Engineer BP Exploration (Alaska), Inc. P.O, Box 196612 Anchorage, AK 99519-6612 \~Io-O~~~.,. [ JJi-'Y'It :i/. , ... Re: MPC-28i Sundry Number: 305-322 ~CANNe:C () 2 20D5 Dear Mr. Kara: Enclosed is the approved Application for Sundry Approval relating to the above referenced well. Please note the conditioJ:ls of approval set out in the enclosed form. 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). As provided in AS 31.05.080, within 20 days after written notice of this decision, or such further time as the Commission grants for good cause shown, a person affected by it may file with the Commission an application for rehearing. A request for rehearing 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. A person may not appeal a Commission decision to Superior Court unless rehearing has been requested. Sincerely, Daniel T. Seamount, Jr. Commissioner DATED this 2¡ day of October, 2005 Encl. J. .. .' HECEIVE: " . STATE OF ALASKA. OCT 20 20 .~ ALASKA OIL AND GAS CONSERVATION COMMISSION, , .,.,05. lOf;}\ APPLICATION FOR SUNDRY APPROV Jit.Ska Od & l;on~. Commission 20 AAC 25.280 AnchGrage 1. Type of Request: aa Abandon o Suspend o Operation Shutdown o Perforate aa Other Plug back for Sidetrack o Alter Casing o Repair Well aa Plug Perforations o Stimulate o Re-Enter Suspended Well o Change Approved Program o Pull Tubing o Perforate New Pool o Waiver o Time Extension 2. Operator Name: 4. Current Well Class: 5. Permit To Drill Number BP Exploration (Alaska) Inc. o Development o Exploratory 1~.~ IA-~ Sf. ,-at.. 3. Address: o Stratigraphic 181 Service 6. API Number: V P.O. Box 196612, Anchorage, Alaska 99519-6612 50- 029-22648-00-00 7. KB Elevation (ft): 46.52' 9. Well Name and Number: MPC-28i 8. Property Designation: 10. Field / Pool(s): ADL 047434 Milne Point Unit / Kuparuk River Sands 11. PRESENT WELL CONDITION SUMMARY " Total Depth MD (ft): Total Depth TVD (ft): I Effective Depth MD (ft): Effective Depth TVD (ft): Plugs (measured): Junk (measured): 8720 7361 8615 7265 None 8696 Casina Lenath Size MD TVD Burst Collacse ~tp l('tllr~1 80' 20" 112' 112' 1490 470 5374' 9-5/8" 5405' 4642' 5750 3090 8667' 7" 8696' 7339' 7240 5410 linAr Perforation Depth MD (ft): I Perforation Depth TVD (ft): Tubing Size: Tubing Grade: I Tubing MD (ft): 8242' - 8418' 6924' - 7085' 3-1/2",9.2# L-80 8117' Packers and SSSV Type: 7" Baker SAB Packer Packers and SSSV MD (ft): 8079' 12. Attachments: 13. Well Class after proposed work: o Description Summary of Proposal o BOP Sketch o Exploratory o Development 181 Service 181 Detailed Operations Program 14. Estimated Date for 15. Well Status after proposed work: Commencing Operations: November 1, 2005 o Oil o Gas o Plugged 181 Abandoned 16. Verbal Approval: Date: o WAG OGINJ OWINJ o WDSPL Commission Recresentative: 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Adrienne McVey, 564-4184 Printed Name Dan Kara Title Senior Drilling Engineer Skip Coyner, 564-4395 Sianature (t ~ cS: <- Prepared By Name/Number: h.\ 2.0\ 0 S, Phone 564-5667 Date Sondra Stewman, 564·4750 Î Commission Use Only I ~ - - 3;4;l. Conditions of approval: Notify Commission so that a representative may witness Sundry Number: "'-~ - o Plug Integrity ,(BOP Test o Mechanical Integrity Test o Location Clearance Other. 3SCO~, ""'''' \ "''' "'- \'>'0 ~ \e<, \-. \'''-r~\\ '= ~ \ \ ~'\~ CJ ~, '>'<~"-- , s"...que"tFO"~ APPROVED BY Date/(}/2/!S Approved By: COMMISSIONER THE COMMISSION Form 10-403 Reviseð'07/2005 ORIGINAL R8DMS 8Ft OCT 21 2005 Submit In Duplicate .' e e MPC-28 Plug Back Procedure Pre-Rig Operations 1. RU SLU. Set a "Pump Through" plug in the XN nipple at 8106' MD. 2. RU Schlumberger. Mix and pump 20 bbl (97 sx) class G cement and displace to 7979' MD. 3. RU E-Line. Cut the 3-1/2" tubing as deep as possible. Ria Operations 4. MIRU Doyon 14. Circulate kill weight mud. 5. NO tree. NU and test BOPE. 6. LD 3-1/2" tubing. 7. Set a CIBP in the 7" casing at ±5550' MD. 8. Cut and pull the 7" casing ~ 50' below the 9-5/8" shoe. 9. Spot a balanced cement plug from the 7" CIBP up into the 9-5/8" casing. ·' Tree: 31/8" 5M .- WellRead: FMC 11" x 1~, Ccn. 5 ../ 11" x 3.5" FMC Tbg. Hnr. wI NSCT threads top and bottom.and 3" CIW H BPV profile 20" 91,1 ppf, H-40 115' KOP @ 600' Max. hole angle = 38 to 42 deg. fl 2700' to 7100' Hole angle thru' perfs = 24 deg DLS = 4.3 deg.l100' @ 1500' 9 5/8", 40#/ft, L-80 Btrc. 15405' md I 7" 26 ppf, L-80, NSCC production casing (drift ID = 6.151", cap. = 0.0383 bpf) 31/2" NSCTTUBING 9.2# L-80 !.D. 2.992" CAP .00870 BBLS / FT Stimulation Summary 08/06/96 - High pressure breakdown I step rate test - Three stages, 20 ppt linear gel, 884bbl. total, 3020 Ibs. of 1 ppg 20-40 sand scour in second stage. Peñoration Summary Ref loa: SBT I GR I CCl 04/16 J 96 Size SPF Interval (TVD) 3 3/8" 6 824 -8266' (6925'-6947') , Sand 3 3/8" 6 8306' -8318' (6983'-6994') 3 3/8" 6 8328' -8338' (7004'-7013') 'A' S;:¡nd 3 3/8" 6 8378"~ (7049' -7085') 21 gm AlphaJet charges (EHD = 0.48" TTP = 22.8") @ 60 deg. phasing initial SBHP 4/16/96 = 3015 psig @ 8398' (7069' TVD) Fish: half of a centralizer arm (6" x 1.25" x 0.5") from anAtlas SBT - 4/16/96 MPU C - 28i Current <A DF Elev.: 46.5: (N 22E) . GL Elev. - 16.8 RT To Tbg. Spool = 28.8' (N 22E) Freeze protected with 75 bbl of diesel 10.3 ppg LSND mud below 2660' MD BAKER 7" SAB PACKER 8079' MD 3 112" "XN" NIPPLE 2.750" NO GO 8106' MD Two 7" marker joints from 8071' wlm to 8110' wlm wI RA marker at 8071' wlm 31/2" WLEG I 8117' MD 7" float collar (PBTD) 7" float shoe 8616' md 8696' md DATE REV. BY COMMENTS MILNE POINT UNIT 2 I 23 I 96 JBF Surface Hole Drilled and Cased by N22e WELL MPU C - 28i 4/10/96 JBF Production Hole Drilled and Cased API NO: 50-029-22648 4 I 22 I 96 JBF Well prepped for RWO. 5/16/96 WRR COMPLETION POLAR RIG #1 BP EXPLORATION AK l' .' Tree: 31/8" 5M _ Wellhead: FMC 11" x 1~, Gen. 5 wI 11" x 3.5" FMC Tbg. Hnr. wI NSCT threads top and bottom.and 3" CIW H BPV profile MPU C - 28i De-Com- lete 20" 91.1 ppf, H-40 115' KOP @ 600' Max. hole angle = 38 to 42 deg. fl 2700' to 7100' Hole angle thru' perfs = 24 deg DLS = 4.3 deg./100' @ 1500' 9 5/8", 40#/ft, L-80 Btrc. 15405' md I 7" 26 ppf, L-80, NSCC production casing (drift ID = 6.151", cap. = 0.0383 bpf) . DF Elev.: 46.5: (N 22E) . GL Elev. - 16.8 RT To Tbg. Spool = 28.8' (N 22E) Freeze protected with 75 bbl of diesel 10.3 ppg LSND mud below 2660' MD 1. LD 3-1/2" tubing. Kill 2. Set a 7" CIBP at ±5500' MD Weight Mud 3. Cut & pull 7" casing at ±5465' MD. 4. Spot a 30 bbl (167 sx) balanced plug from 5500' to 5125': "G" + CaCI2 mixed at 17 ppg & 1.01 cf/sk. 5. Pull 5 stands. Squeeze ±5 bbl away. Perforation Summary 8242' -8266' (6925'-6947') 8306' -8318' (6983'-6994') 8328' -8338' (7004'-7013') 8378' 8418' (7049' -7085') - BAKER 7" SAB PACKER 8079' MD 3 112" "XN" NIPPLE 2.750" NO GO 8106' MD I 8117' MD 7" float collar (PBTD) 7" float shoe 8616' md 8696' md DATE REV. BY COMMENTS MILNE POINT UNIT 2 I 23 I 96 JBF Surface Hole Drilled and Cased by N22e WELL MPU C - 28i 4/10/96 JBF Production Hole Drilled and Cased API NO: 50-029-22648 4 I 22 I 96 JBF Wellprepped for RWO. 5/16/96 WRR COMPLETION POLAR RIG #1 BP EXPLORATION AK .' .' t' 'l.. ... MPC-28A Planned Location .C-09 " ", " l " \....,¡ \ \. \ \: \. .'\ \ \.. " '~.'\. .... \\ \\ " 9 o 1000 2000 Feet 1 :12,000 ASP Zone 4 NAD 27 + LCU Marker Pick .. MPC-28A wp03 Hydraulic Units ';I \ " \ ] \ .J ,{ 1\ -¡ J I \ \ WeD Status · Abandoned "~ Gas Injector Or Gas Producer Shut-In Miscible Injector Operating Miscible Injector Shut-In · Not Yet Completed I Td Not Yet Reached. o NullJUnknown · Oil Producer Flowing · Oil Producer Gas Uft * Oil Producer Hydraulic Pump .. Oil Producer Shut-In * Oil Producer SUbmersible () Oil Suspended · 01 Well o Plugged Back For Redrill <> Suspended ~~ Water Injector D Water Injector Injecting Water Injector Shut-In ... Water Producer flowinG MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Randy Ruedrich DATE: October 14, 2003 Commissioner THRU: Jim Regg .~¢~.~ t~t?''3]0'-7>SUBJECT:' Mechanical Integrity Test BPX P.I. Supervisor ~ [L MPU C Pad FROM: Chuck Scheve Petroleum Inspector NON- CONFIDENTIAL WellI P.T.D.I Notes: WellI C-08 P.T.D. I 185-014 Notes: Well] C-28 P.T.D.I 196-029 Notes: WellI P.T.D.I Notes: P.T.D. I Notes: Packer Depth Pretest Initial 15 Min. 30 Min. c-o s I I, 4o I Tubing I I 182-194 ITypetesq P ITestpsil 1585 I CasingI 0 I 25001 24501 24501 P/F I -P Typetest}. P ITestpsi} 1660 ICasingI 0 I 24401 24201 24101 P/F I --P Type testI P I Testpsil 1695 ICasingI 0 I 25001 24001 24001 P/F I ~P IType Inj. Type test IType Inj. Type test Type INJ. Fluid Codes F = FRESH WATER INJ. G = GAS I NJ. S = SALT WATER INJ. N = NOT INJECTING Type Test M= Annulus Monitoring P= Standard Pressure Test R= Internal Radioactive Tracer Survey A= Temperature Anomaly Survey D= Differential Temperature Test Interval I= Initial Test 4= Four Year Cycle V= Required by Variance W= Test during Workover O= Other (describe in notes) Test's Details I traveled to BPXs MPU C Pad and witnessed the routine 4 year MIT on well C-02, C-08 and C-28. The pretest tubing and casing pressures were observed and found to be stable. The pressure tests were then performed with all 3 wells demonstrating good mechanical integrity. M.I.T.'s performed: _3 Number of Failures: O Attachments: Total Time during tests: 3 hours cc: MIT report form 5/12/00 L.G. 2003-1014_M IT_MP U_C-28_cs.xls 10/23/2003 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _ Plugging _ Perforate _ WAG SWAP Pull tubing _ Alter casing _ Repair well _ Other_X WAG SWAP 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 837' FSL, 2340' FEL, Sec. 10, T13N, R10E, UM At top of productive interval 2064' FNL, 252' FEL, Sec. 09, T13N, R10E, UM At effective depth 1974' FNL, 376' FEL, Sec. 09, T13N, R10E, UM At total depth 1955' FNL, 402' FEL, Sec. 09, T13N, R10E, UM 5. Type of Well: Development _ Explorato~._ Stratigraphic__ Service__X (asp's 558122, 6029119~ (asp's 554908, 6031473) (asp's 554784, 6031561) (asp's 554757, 6031580) 6. Datum elevation (DF or KB feet) RKB 46 feet 7. Unit or Property name Miline Point Unit MPC-28 9. Permit number / approval number N~ 196-029 10. APl number 50-029-22648-00 11. Field / Pool Miline Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 112' Surface 5374' Production 8665' 8696 feet Plugs (measured) 7338 feet 8616 feet Junk (measured) 7265 feet 1/2 of SBT Centralizer Arm f/Atlas (04/16/96) Size Cemented Measured Depth True Vertical Depth 20" 250 sx Arcticset 1 (approx) 144' 144' 9-5/8" 1050 sx PF 'E', 250 sx 5405' 4623' 'G', 150 sx PF 'E' 7" 255 sx Class 'G' 8696' 7338' Perforation depth: measured Open Perfs 8242' - 8266', 8306'- 8318', 8328' - 8338', 8378'- 8418' true vertical Open Perfs 6925' - 6947', 6983' - 6994', 7004' - 7013', 7049' - 7085' Tubing (siZe, grade, and measured depth) Packers & SSSV (type & measured depth) 3-1/2", 9.2#, L-80 TBG to 8117' MD. 7" x 3-1/2" SABL-3 Baker Packer @ 8079'. No SSSV. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation 02/13/2003 Subsequent to operation SHUT-IN OiI-Bbl Representative Daily Averaqe Production or Iniection Data Gas-Mcf Water-Bbl 492 Casing Pressure Tubing Pressure 3380 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil _ Gas __ Suspended __ Service WAG Injector 17. I hereby certify that the foregoing is true. and correct to the best of my knowledge. Title: Technical Assistant DeWayne R. Schnorr ~ Form 10-404 Rev 06/15/88 · 1 8DM$ BFL ORIGINAL Date February 24, 2003 PreDareci bv DeWavne R Schnorr 564-5174 SUBMIT IN DUPLICATE MPC-28 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 02/24/2003 SWAPPED WELL FROiVl WATER TO GAS. EVENT SUMMARY 09~1~2 WELL SUPPORT TECHS RIGGED UP AND SWAPPED THE BLINDS, GREASED TREE, FLUSHED THE SENSOR LINES AND CHECKED ORIFICE PLATE SIZE. ALL FLANGES WERE TORQUED TO SPEC. FESCO RIGGED UP AND PUMPED 2 METHANOL DOWN THE WATER LEG LINE AND THEN PUMPED 25 BBLS DOWN THE TUBING. PUMPED FROM 3800 TO 4300 PSI AT 1 TO 1.4 BPM. JOB COMPLETED WITH NO PROBLEMS AND WELL WAS TURNED OVER TO OPERATOR TO PUT BACK ON INJECTION. FLUIDS PUMPED BBLS DISCRIPTION 27 METHANOL 27 TOTAL Page 1 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate _X Plugging _ Perforate_ FCO ! ACID TREATMENT Pu, tubing_ Alter casing_ Repair well _ Other_ 2. Name of Operator 5. Type of Well: 6. Datum elevation (DF or KB feet) BP Exploration (Alaska), Inc. Development__ RKB 46 feet 3. Address Explorato~___ 7. Unit or Property name P. O. Box 196612 Stratigraphic__ Anchorage, AK 99519-6612 Service__X Miline Point Unit 4. Location of well at surface 837' FSL, 2340' FEL, Sec. 10, T13N, R10E, UM (asp's558122, 6029119) MPC-28 At top of productive interval 9. Permit number / approval number 2064' FNL, 252' FEL, Sec. 09, T13N, R10E, UM (asp's 554908, 6031473) 196-029 At effective depth 10. APl number 1974' FNL, 376' FEL, Sec. 09, T13N, R10E, UM (asp's 554784, 6031561) 50-029-22648-00 At total depth 11. Field / Pool 1955' FNL, 402' FEL, Sec. 09, T13N, R10E, UM (asp's 554757, 6031580) Miline Point Unit/Kuparuk River Sands 12. Present well condition summary Total depth: measured 8696 feet Plugs (measured) true vertical 7338 feet Effective depth: measured 8616 feet Junk (measured) 1/2 of SBT Centralizer Arm f/Atlas (04/16/96) true vertical 7265 feet Casing Length Size Cemented Measured Depth True Vertical Depth Conductor 112' 20" 250 sx Arcticset 1 (approx) 144' 144' Surface 5374' 9-5/8" 1050 sx PF 'E', 250 sx 5405' 4623' 'G', 150 sx PF 'E' Production 8665' 7" 255 sx Class 'G' 8696' 7338' Perforation depth: measured Open Perfs 8242' - 8266', 8306' - 8318', 8328' - 8338', 8378' - 8418' true vertical Open Perfs 6925'-6947', 6983'-6994', 7004'-7013', 7R~-G~IVFD Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 TBG to 8117' MD. NOV 0 ~ ~00~ Packers & SSSV (type & measured depth) 7" x 3-1/2" SABL-3 Baker Packer @ 8079'. ~,laska Oil & Gas eons. Commtssl .on No SSSV. Anch0raee 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Representative Daily Averaqe Production or Iniection Data OiI-Bbl Gas-Mcf Water-Bbl Casing Pressure Tubing Pressure Prior to well operation Shut-In Subsequent to operation 09/25/2002 1243 3436 15. Attachments 16. Status of well classification as: Copies of Logs and Surveys run __ Daily Report of Well Operations __ Oil __ Gas __ Suspended __ Service _WAG Iniector 17. I hereby ce~fy that the foregoing is true,and correct to the best of my knowledge. ,~~ ~'~.~ ~~~ Title: Technical Assistant Date October 07, 2002 DeWayne R. Schnorr Prepared b~/DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 SUBMIT IN DUPLICATE MPC-28 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 09/21/2002 FILL CLEAN OUT: ACID TREATMENT; FILL CLEAN OUT EVENT SUMMARY 09/21/02 MIRU UNIT. PRESSURE TEST AND RIH WITH 2" JS NOZZLE. WASH PERFS WITH BIOZAN, PUMP BIO PILL TO SURFACE. TAG SOILD BOTTOM @ 8517'. WASH PERFS 8242' - 8418' WITH 20 BBLS 15% DAD ACID, LET SOAK 30 MINUTES, POH LAYING IN 20 BBLS 15% DAD ACID. FP WELL TO 2500' AND FL WITH 50/50 MEOH. RDMO. LEFT WELL SI. <<< NOTIFY PAD OPERATOR OF WELL STATUS >>> FLUIDS PUMPED BBLS DISCRIPTION 68 METHANOL 430 1% KCL WATER 4O BIO 40 15% DAD ACID 578 TOTAL Page 1 Tree: 3 1/8" 5M MPU C -28i Wellhead: FMC 11" x 11" 5M, Orig. DF Elev. = 46.5' (N 22E) Gen. 5 w/ 11" x 3.5" FMC Tbg. Orig. GL Elev. = 16.8' Hnr. w/ NSCT threads top and bottom.and 3" CIW H BPV profile j [ RT To Tbg. Spool -- 28.8' (N 22E) 20" 91.1 ppf, U-40 I 115' I · KOP @ 600' Max. hole angle = 38 to 42 deg. f/ 2700' to 7100' Hole angle thru' perfs = 24 deg DLS = 4.3 deg./100' @ 1500' 95/8,',40#/ft, L_80 Btrc. 15405'mdl i 7" 26 ppf, L-80, NSCC production casing . ( ddft ID = 6.151", cap. = 0.0383 bpf ) 31/2" NSCT TUBING 9.2# L-80 I.D. 2.992" CAP .00870 BBLS / FT I Stimulation Summary 08/06/96 - High pressure breakdown / step rate test - Three stages, 20 ppt linear gel, 884bbl. total, 3020 lbs. of I ~ ~ BAKER 7" SAB I 8079' MD ppg 20-40 sand scour in second stage. PACKER Perforation Summary XN 3 1/2"2.750."XN"NoNIPPLEGo I 8106' MD Ref Ioo: SBT I GR I CCL 04116 / 96 - Two 7" marker joints from 8071' wlm to Size SPF Interval (TVD) rX] 8110' wlm w/RA marker at 8071' wlm 'C' Sand 3 1/2" I 8117' MD 3 3/8' 6 8242' -8266' (6925'-6947') WLEG 'B' Sand 3 3/8' 6 8306'-8318' (6983'-6994');.::: 3 3/8" 6 8328'-8338' (7004'-7013') 3 3/8" 6 8378' 8418' (7049'-7085') J 21 gm Alpha Jet charges (EHD = 0.48" TTP = 22.8") (!~ 60 deg. phasing initial SBHP 4/16/96 = 3015 psig ~ @ 8398' (7069' TVD) Fish: half of a centralizer arm (6" x · 7" float collar (PBTD) 18616' md 1.25" x 0.5") from anAtlas SBT 7" float shoe [8696' md 4/16/96 DATE REV. BY COMMENTS MILNE POINT UNIT 2 / 23 / 96 JBF Surface Hole Drilled and Cased by N22e WELL MPU C - 28i 4 / 10 / 96 JBF Production Hole Drilled and Cased APl NO: 50-029-22648 4 / 22 / 96 JBF Wellprepped for RWO. 5/16/96 WRR COMPLETION POLAR RIG #1 BP EXPLORATION IAK/ Alas h¢sred o lc s TO' Blair Wondzell FROM: Chris West DATE: October 27, 1995 SUBJECT: MPB-24 Well Suspension APl # 50-029-22642 Blair; Please find attached a copy of the Form 10-403 to temporarily suspend this well as per AOGCC 20- AAC 25.110. As discussed this morning we propose setting three plugs in this well as detailed in the attached form. This will allow us to retain the wellbore for potential future sidetrack or service well use. We would like to keep the well's 9-5/8" x 7" annulus available for the injection of liquid 'wastes. There are no other well annulii on this pad for injection. The annulus for MPB-24 was approved for injection as part of the permit dated 25 January 1996. The annulus will be freeze protected before moving the rig. Thank you for your help in this matter. Please call me if I may be of any assistance. Chris West Drilling Operations Engineer Nabors 27E (907)-564-5089 ANNULAR INJECTION DATA ENTRY SCREEN --.-- Cumulative Data Asset lYlilD.e. .......................................... Rig Name ~l.~tl~.~.r.~..2;~F,, ............................. Inj Well Name M...P..~.;~,~. ..................................... Sur Csg Dep ~..4.0..5. ................ ~l~t Well Total ........... .G?,~j ........... SCANNED NOV I ,~ 2002 Research Rig COmpletion Formation Intermittant Final M ud/Ctg Wash FlUids FlUids Freeze Freeze Permit End ........ :2~.!~/.~.Z ........ Permit Start ........ ~..1.5.~/.~.§ ........ Daily Data Legal Desc ~.e.c...1..0.,.'['.I;tbI.,.B.1.QE ............................................................................... red rvices rilling December 14, 1998 900 East Benson Boulevard, MB 8-1 · Anchorage, Alaska 99508 (907) 561-5111 Fax: (907) 564-5193 Wendy Mahan Natural Resource Manager Alaska Oil & Gas Conservation Commission 3001 Porcupine Dr. Anchorage, AK 99501-3192 RECEIVED Re: Annular Disposal Information Request Dear Ms. Mahan: DE(:: 14 1998 Alaska 0il 8, Gas COns, Commission Anchorage On October 28, 1998 you requested an update from Shared Service Drilling regarding Annular Disposal Records from July 25, 1995 through preSent time. We compared your list with our records and are able to provide you with the following data: Individual Annular Disposal Logs from the SSD database which coincide with the approved wells on your attached AOGCC Annular Log. The :SSD records are provided to you in the same order as listed on your log. · There were some wells on your list which were not injected into. These wells are identified as follows: · Endicott wells 1-03/P-16, 1-65/7V-25, 1-59/0-24 ~ · Exploration well Pete's Wicked #1 : · Milne Point wells E-22, E-23, F-O1, L-16, J-19, L-25, F-30, L-21, K-38, NMP #1 & #2, K-05, K-02, H-07, K-25, K-37, E-17, F-21, K-30, K-34, K-21i, F-66, K-06, K-54, K-33, F-49i, K-18 · PBU Wells E-38, 18-34, 15-42, S-29A, 15-46, B-36, 15-43, 11-38 · The reason many of these annuli were not used is because the waste materials generated from these wells were injected into other approved annuli. Hopefully the injection logs submitted with this letter will clarify this. In addition, please note that our records show: · The wells listed above in italics were permitted but not used for annular disposal. · The wells listed above in BOLD were not permitted for annular disposal. Wells drilled after June 6, 1996 were required by SSD procedure to be permitted with a Sundry Approval (10-403) form. Our records show that no Sundry Approval for Annular Disposal was filed for these wells. Wells drilled between July 25, 1995 and June 6, 1996 were automatically approved for annular disposal with the Permit to Drill. · We also provide you with a cumulative report from our database of records from July 25, 1995 through the present. From those records, we show the following wells not listed on your report were used for annular disposal: ,SCANNED NOV .?L 11 21102 ! .Annular Disposal Letter 12/14/9 8 ! / · Endicott wells i-23/O-15, 1-61/Q-20, 2-40/S-22 · Exploration well Sourdounh #3 - 3~;°° · Mflne Point wells F-06, H-05, ~-06, J-13, L-24 - · PBU wells-18-30, 18-31, 1444,~-43, ~-34, E-36, G-04A, and S-33' ~-o~ D~.~ ' q~,o~ Individual logs are provided to ~ou for thes~ ~gs as we~l. · Finally, our records show that the B-24 outer annulus was left open (see attached correspondence) Thank you for the opportunity to provide clarity to these records. If I can be of any further assistance please do not hesitate to contact me at 564-5183, or Karen Thomas, Environmental Advisor at 564-4305. Sincerely, Fritz P. Gunkel Shared Service Drilling Manager FPG/KMT cc: Dave Wallace - HSE Manager (w/out attachments) RECE YED Alaska OJ] & Gas Cons, Commiss%or~ Anchora,-3e ;har(l-d SerVice Ehilling mnd~'ar Injection Volumes 'uly 25, 1995 until December 1998 :urnulative Report Surface Casing ig Inj Well Depth Legal Desc ~dicott Cum Mud Cum Rig Cum Compl Cum Form Cum Interm Cum Final Disposal Period Annulus Cum Total & Ctgs Wash Fluids Fluids Freeze Freeze Start End Status 3yon 15 1-19/I-18 5000 Sec. 36, T12N, R16E 8,960 7,848 992 120 12/5/95 12/5/96 Open 3yon 15 1-23/O-15 4246 2020'FNL, 2087'FEW, SEC.36,T12N,R16E 32,084 30,604 1,160 200 120 9/30/95 12/31/95 Open 3yon 15 1-33/M-23 5013 3217'NSL, 2114'WEL, Sec 36,T12N, R16E 9,879 9,729 150 8/31/95 12/31/95 Broached :)yon 15 1-61/Q-20 4236 3075'NSL, 2207'WEL, Sec 13,T12N, R16E 25,228 21,379 2,613 1,176 60 12/5/95 12/5/96 Open )yon 15 2-40/S-22 4531 2020'FNL, 2289'FEL, Sec 36,T12N, R16E 31,195 29,952 1,063 120 60 7/25/95 12/31/95 Open )A )yon 14 15-47 3515 3648'NSL, 4956'WEL, Sec 22,T11N, R14E 3,002 903 2,009 90 11/7/95 12/31/95 Open )yon 14 DS 15-45 3829 4749' NSL, 5180' WEL, Sec. 22, T11 N, 1,882 1,697 134 51 4/4/96 4/4/97 Broached )yon 14 DS 15-48 3548 Sec. 22, T11N, R14E 3,385 216 820 2,283 66 12/21/95 12/21/96 Open )yon 14 DS 15-49 3667 4676' NSL, 5165' WEL, Sec. 22, T11N, 4,669 1,559 1,141 1,904 65 2/21/96 2/21/97 Open )yon 9 18-30 3930 1499'SNL, 26'WEL, Sec 24,T11N, R14E 2,266 936 380 800 150 7/25/95 12/31/95 Open )yon 9 18-31 3680 3719'NSL, 64'WEL, Sec 24,T11N, R14E 6,086 2,250 1,100 2,565 171 7/26/95 12/31/95 Open )yon 9 18-32 3830 3632'NSL, 41'WEL, Sec 24,T11N, R14E 3,311 1,861 200 1,100 150 8/24/95 12/31/95 Open ~yon9 18-33 4140 3690'NSL, 56'WEL, Sec.24,T11N, R14E 5,215 2,050 3,035 10 120 9/28/95 12/31/95 Open ~bors 18E 12-35 3543 348'NSL, 705'WEL, Sec 18,T10N. R14E 3,723 3,436 137 150 9/1/95 12/31/95 Open ~bors 18E 12-36 3452 63'FSL, 899'FEL, Sec 18,T10N, R15E 4,002 1,961 50 1,871 120 10/13/95 12/31/95 Open bors 18E 13-36 3431 1585'NSL, 5187'WEL, Sec 13,T10N, R14E 4,137 3,523 464 150 10/26/95 12/31/95 Open bors 18E 14-44 3288 2829'NSL, 1617'WEL, Sec 9,T10N, R14E 3,974 2,319 1,535 120 8/17/95 12/31/95 Open ploration ol 4 Sourdough #3 4236 2245'FSL, 5067' FEL, Sec. 29, TgN, R24E 5,786 4,630 1,156 1/26/96 1/26/97 Closed Ine 7E MPK- 17 3508 3648'NSL,2100'WEL, Sec.03,T12NR 11E 19,608 18,538 285 685 100 4/18/96 4/18/97 Open bors 22E MPC-23 4941 1038 NSL, 2404 WEL, Sec 10,T13N, 2,060 1,800 130 130 1/25/96 1/25/97 Open bors 22E MPC-25 8595 1143'FNL, 2436'FWL, Sec 10,T13N, R10E 1,905 1,465 300 140 1/5/96 1/5/97 Open bors 22E MPC-26 4704 1086 NSL, 2419 WEL, Sec 10.T13N, 5,228 4,483 555 190 12/19/95 12/19/96 Open bors 22E MPC-28 5405 Sec 10,T13N, R10E 425 350 75 2/15/96 2/15/97 Open Page 1 SCANNED NOV ]1 3 200~ DEC 1 4. t998 Anchora,q,oo Shard Service DHIling Annular Injection Volumes July 25, 199,~ until December 1998 Cumulative Report Surface Casing Rig Inj Well Depth Nabors 22E MPF-06 8766 Nabors 22E MPF-14 6690 Nabors 22E MPF-70 7919 Nabors 22E MPH-05 5335 Legal Desc Sec 06,T13N, R10E Sec 06,T13N, R10E UM _ 2189'NSL, 2591'WEL, Sec 6,T13N, R10E 2882'NSL 4028'WEL, Sec 34,T13N, R10E Cum Mud Cum Rig Cum Total & Ctgs Wash 1,927 1,731 18,717 17,107 1,270 19,775 18,794 735 8,283 7,711 382 CumCompl Cum Form Cum Interm Fluids Fluids Freeze 190 Cum Final Disposal Period Annulus Freeze Start End Status 196 1/25/96 1/25/97 Open 340 6/3/96 6/3/97 Open 56 6/17/96 6/17/97 Open .. 190 8/19/95 12/31/95 Open Nabors 22E Nabors 22E Nabors 22E ....... Nabors 22E ~labors 27E MPH-06 7304 2824'NSL 4044'WEL, Sec 34,T13N, R10E 8,515 8,335 180 8/5/95 12/31/95 Open MPI-07 2680 2339'NSL 3906'WEL, Sec 33,T13N, R10E 1,680 1,280 250 80 70 9/21/95 12/31/95 .Open MPJ-13 2835 2319'NSL 3179'WEL, Sec 28,T13N, R10E 14,127 13,292 645 60 130 10/17/95 12/31/95 Open MPJ-16 3112 2317'NSL 3336'WEL, Sec 28,T13N, R10E 985 915 70 11/12/95 12/31/95 Open B-24 4080 Sec 18,T13N, R11E UM 1,468 1,396 72 1/25/96 1/25/97 Open ~labors 27E MPF-22 8841 Sec 06,T13N, R10E UM 6,536 6,466 70 12/12/95 12/12/96 Open ~labors 27E MPF-25 3405 1857'NSL, 2696'WEL. Sec 6,T13N, R10E 9,897 9,357 250 225 65 12/26/95 12/26/96 Open ~labors 27E MPF-37 6621 1931'NSL, 2643'WEL, Sec 6,T13N, R10E 7,032 6,887 70 75 7/25/95 12/31/95 Open ~labors 27E MPF-38 8561 1994'NSL, 2731'WEL, Sec 6,T13N, R10E 9,232 9,157 75 12/6/95 12/31/95 Open ~labors 27E MPF-45 6678 1979'NSL, 2608'WEL, Sec 6,T13N, R10E 17,562 17,381 181 7/31/95 12/31/95 Open ~labors 27E MPF-53 6750 2028'NSL, 2572'WEL, Sec 6,T13N, R10E 6,051 5,671 165 75 60 80 8/19/95 12/31/95 Open ~labors 27E MPF-61 6585 2077'NSL, 526'WEL, Sec 31,T14N, R10E 5,732 5,657 75 8/31/95 12/31/95 Open ~labors 27E MPF-62 6059 2141'NSL, 2627'WEL, Sec 6,T13N, R10E 386 316 70 10/13/95 12/31/95 Open ~labors 27E MPF-69 5772 2125'NSL, 2502'WEL, Sec 6,T13N, R10E 9,740 9,665 75 8/31/95 12/31/95 Open ~abors 27E MPF-78 7085 2237'NSL, 2555'WEL, Sec 6,T13N, R10E 8,476 7,456 40 775 65 140 9/12/95 12/31/95 Open ~abors 27E MPL-24 6515 3654'NSL, 5180'WEL, Sec 8,T13N, R10E 6,790 4,900 1,320 165 335 70 11/27/95 12/31/95 Open VOA 8E F-33 3570 3332'NSL, 2174'WEL, Sec 2,T11N, R13E 1,468 183 660 465 160 2/21/96 2/21/97 Open 8E F-36 3691 2642'NSL, 2878'WEL, Sec 2,T11N, R13E 6,963 1,998 1,359 3,471 135 12/18/95 12/18/96 Open )oyon 9 D-30 3456' 3625' NSL, 1066' WEL, SEC. 23, T11N, 5,261 2,811 1,275 1,035 140 1/31/96 1/31/97 Open )oyon 9 D-33 3222 2965' NSL, 1067' WEL, SEO. 23, T11N, 4,661 2,425 2,106 130 2/21/96 2/21/97 Open labors 18E S-43 3121' 4211 'NSL,4503'WEL,SEC35,T12N,R12E 5,943 2,636 1,716 1,511 80 5/7/97 5/7/98 OPEN Page 2 SCANNED NOV ]. ~ ~00~ Shared, 5".ei~ice Dr..illing Ann'ul~r Injection Volumes July 25, 1995. until December 1998 Cumulative Report Surface Casing Rig Inj Well Depth Nabors 28E B-33 3504' Nabors 28E 1:-34 3664 Nabors 28E E-36 3648 Nabors 28E E-37 3810 Nabors 28E E-39 3638 · . Nabors 28E G-04A 3509 Nabors 28E G-21 3509 Cum Mud Legal Desc Cum Total & Ctgs 969'SNL, 1898'EWL, Sec 31, T11N, R14E 3,974 2,842 168'SNL, 500'WEL, Sec 6, T11N, R14E 9,656 7,228 1706'SNL, 822'WEL, Sec 6,T11N, R14E 9,271 4,417 3391'NSL, 881'WEL, Sec 6,T11N, R14E 4,695 4,241 Cum Rig Cum Compl Cum Form Wash Fluids Fluids 857 1,42O 858 1,293 3,096 374 Cum Interm Cum Final Disposal Period Annulus Freeze Freeze Start End Slalus 195 80 5/1/96 12/31/96 Broached 40 110 8/23/95 12/31/95 Open 365 100 7/25/95 12/31/95 Open 80 9/16/95 12/31/95 Open 3358'NSL, 501'WEL, Sec 6,T11N, R14E 2,250 928 220 1,022 2917'NSL, 1974'WEL, Sec 12,T11N, R131: 5,937 1,798 1,824 2,315 2911'NSL, 2368'WEL, Sec 12,T11N, R14E 11,430 3,956 3,072 4,270 80 8/28/95 1 2/31/95 Open 10/20/95 12/31/95 Open 70 62 9/8/95 12/31/95 Open Nabors 28E S-24 2750 1633'SNL, 4228'WEL, Sec 35,T12N, R12E 20,261 11,773 2,177 5,751 275 285 12/9/95 12/9/96 Open Nabors 28E S-33 2958 1639'SNL, 1487'WEL, Sec 35,T12N, R12E 18,014 6,613 2,431 8,392 270 308 12/1/95 12/1/96 Open Nabors 281: S-41 3331 4152' NSL, 4504' WEL, Sec 35,T12N, 8,062 4,159 2,034 1,754 115 2/8/96 2/8/97 Open Nabors 28E S-42 3077 Sec 35, T12N, R12E 168 100 68 3/13/96 3/13/97 Open Nabors 2ES H-35 3157 4535'NSL, 1266'WEL, Sec 21,T11N, R13E 4,860 3,725 555 480 20 80 10/26/95 12/31/95 Open Nabors2ES H-36 3550 4478'NSL, 1265'WEL, Sec21,T11N, R13E 1,452 857 100 410 85 10/26/95 12/31/95 Open Page 3 SCANNED NOV 1 $ 2002 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION REPORT OF SUNDRY WELL OPERATIONS 1. Operations performed: Operation shutdown_ Stimulate_ Plugging_ Perforate_ WAG SWAP Pull tubing _ Alter casing _ Repair well _ Other _X WAG SWAP 2. Name of Operator BP Exploration (Alaska), Inc. 3. Address P. O. Box 196612 Anchorage, AK 99519-6612 4. Location of well at surface 837' FSL, 2340' FEL, Sec. 10, T13N, R10E, UM At top of productive interval 2064' FNL, 252' FEL, Sec. 09, T13N, R10E, UM At effective depth 1974' FNL, 376' FEL, Sec. 09, T13N, R10E, UM At total depth 1955' FNL, 402' FEL, Sec. 09, T13N, R10E, UM 5. Type of Well: Development __ Exploratow__ Stratigraphic__ Service__X (asp's 558122, 6029119) (asp's n/a) (asp's 554784, 6031561) (asp's 554757, 6031580) 6. Datum elevation (DF or KB feet) RKB 46 feet 7. Unit or Property name Miline Point Unit MPC-28 9. Permit number / approval number 10. APl number 50-029-22648 11. Field / Pool Miline Point Unit / Kuparuk River Sands 12. Present well condition summary Total depth: measured true vertical Effective depth: measured true vertical Casing Length Conductor 112' Surface 5374' Production 8665' 8696 feet Plugs (measured) 7338 feet 8616 feet Junk (measured) 7265 feet Size Cemented Measured Depth True Vertical Depth 20" 250 sx Arcticset 1 (approx) 144' 144' 9-5/8" 1050 sx PF 'E', 250 sx 5405' 4623' 'G', 150 sx PF 'E' 7" 255 sx Class 'G' 8696' 7338' Perforation depth: measured Open Perfs 8242'- 8266', 8306'- 8318', 8328'- 8338', 8378'- 8418' true vertical Open Perfs 6925' - 6947', 6983' - 6994', 7004' - 7013', 7049' - 7085' Tubing (size, grade, and measured depth) 3-1/2", 9.2#, L-80 TBG to 8117' MD. Packers & SSSV (type & measured depth) 7" x 3-1/2" SABL-3 Baker Packer @ 8079'. No SSSV. 13. Stimulation or cement squeeze summary Intervals treated (measured) (see attached) Treatment description including volumes used and final pressure 14. Prior to well operation Subsequent to operation OiI-Bbl Representative Daily Average Production or Injection Data Gas-Mcr Water-Bbl Casing Pressure Tubing Pressure 15. Attachments Copies of Logs and Surveys run __ Daily Report of Well Operations __ 16. Status of well classification as: Oil __ Gas __ Suspended __ Service WAG Injector 17. I hereby certify that the foregoing is true and correct to the best of my knowledge. ,~,,~~,~/-~¢2F~ Title: Technical Assistant DeWayne R. Schnorr Date September 21, 2001 Prepared by DeWayne R. Schnorr 564-5174 Form 10-404 Rev 06/15/88 · ORIGINAL SUBMIT IN DUPLICATE MPC-28 DESCRIPTION OF WORK COMPLETED NRWO OPERATIONS 09/19/2001 SWAP WELL FROM WATER TO GAS INJECTION. EVENT SUMMARY 09/19/01 WELL WAS PERVIOUSLY SHUT-IN AND FREEZE PROTECTED WHEN BOOSTER PUMP WENT DOWN. VALVES WERE LINED UP FOR GAS INJECTION AND PUT ON AT AN INJECTION RATE OF 2000 MSCFPD. FLUIDS PUMPED BBLS DISCRIPTION 0 METHANOL 0 TOTAL Page 1 MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO: Julie Heusser, Commissioner DATE: November 18, 2000 THRU: Blair Wondzell, P. I. Supervisor FROM' Lou Grima~, ~ ~- SUBJECT: Petroleum Inspector SVS tests BPX C-pad Milne Point Unit Kuparuk River Field Saturday, November 18~ 2000; I witnessed the SVS tests on BPX C pad in the Milne Point of the Kuparuk River Field. This was the three-month test for this pad due to a 26% fail rate witnessed by Inspector Jeff Jones on 7/9/00. The wells did somewhat better this time although the fail rate of 13.6% was still above the 10% expectable limit. Again, the gas injectors gave us the most trouble with two SSV's leaking. One Oil producer also had a leaking SSV. The pilots all tripped within limits. Well C-03 had a slight gas leak on the Tubing spool adapter, Larry Niles (MPU OI advisor) will pursue this with the wellhead manufacturer as to proper repair and report back to me. The wellhouses were all very clean and it appears to be a high priority in the Milne facility. SUMMARY: I witnessed the SVS test on BPX C pad in the Milne Point Unit. 1 pad, 11 wells, 22 components, 3 failures. Wellhouse Inspections; 14 wellhouses, 1 failure (leaking T.S.A.) Attachments: SVS MPU C pad 11-18-00 LG.XLS cc: Niles/Shipley (MPU OI advisers) NON-CONFIDENTIAL SVS MPU C pad 11-'18-00 LG.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Larry Niles AOGCC Rep: Lou Grimaldi Submitted By: Lou Grimaldi Field/Unit/Pad: K.R.F./M.P.U./C pad Separator psi: LPS 140 Date: 11/18/00 HPS Well Permit Separ Set L/P Test Test Test Date Oil, WAG, GIN& Number Number PSI PSI Trip Code Code Code Passed GAS or CYCLE C-01 1811430 140 100 120 ~ P OIL C-02 1821940 C-03 1820500 140! 100 105 P P OIL C-04 1821260 140 100 105 P 4 OIL C-05A 1842430 140 100 105 P P C-06 1842410 C-07 1850020 140 100 110! P P OIL C-08 1850140 C-09 1850360 140 100 80 P P OIL C-13 1850670 C-14 1850880 140 100 105 P P OIL C-15 1851030 C-17 1852630' C-20 1890150! C-21 19408001 , C-22A 1951980 140 100 110 P P OIL, C-23 1960160 C-25A 1960210 4000 2000 ~000 P 4 WAG C-26 1952060 C'-28 1960290 4000 2000 2000 P P WAG , C-36 1980010 C-39 1972480 C-19i 1852960 4000~ 2000 2000 P 4 WAG Wells: 11 Components: 22 Failures: 3 Failure Rate: 13.6°A[] 90 Day Remarks: C-03 has gas leak on Tubing Spool adapter, Develop plan for repair, and report back. 11/20/00 Page 1 of 1 V0kl trl6.xls MEMORANDUM State of Alaska Alaska Oil and Gas Conservation Commission TO' THRU: Dan Seamount, Commissioner Blair Wondzell, P. I. Supervisor · FROM: Jeff Jones',/~T~//~{~- SUBJECT: Petroleum IhsP~ct~r DATE: July 12, 2000 Safety Valve Tests Milne Point Unit B & C Pads .July 9, 2000: I traveled to BP's Milne Point Field to witness Safety Valve System tests on MPU B & C Pads. Testing was accomplished in a safe and efficient manner by BP rep. Larry Niles. Seven failures were witnessed. MPU B-22 SV failed to hold DP. MPU C-04 SV failed to close. MPU C-05A SV failed to hold DP. MPU C-06 SV failed to hold DP. MPU C-09 failed to hold DP. MPU C-25A SV failed to hold DP. MPU C-28 SV failed to test because the tree cap o-ring leaked. The AOGCC test reports are attached for reference. Well house inspections were done on 21 well houses. All well houses inspected were clean and in satisfactory condition. SUMMARY: I witnessed SVS tests on BP's MPU B & C pads. MPU B Pad, :9 wells, 18 components tested, 1 failure. 5.5% failure rate. MPU C Pad; 12 wells, 23 components tested, 6 failures. 26% failure rate. 21 well houses were inspected, no failures. Attachments' SVS MPU B-PAD 7-9-00 JJ SVS MPU C-PAD 7-9-00 JJ cc; NON-CONFIDENTIAL SVS MPU B & C PADS 7-12-00 JJ.doc Alaska Oil and Gas Conservation Commission Safety Valve System Test Report Operator: BPX Operator Rep: Lan~ Niles AOGCC Rep: Jeff Jones Submitted By: Date: Field/Unit/Pad: Kuparuk River/MPU/C-Pad Separator psi: LPS 140 HPS 7/9/OO Well Permit Separ Set L/P Test Test Test Oil, WAG, GIN J, Number Number PSI PSI Trip Code Code Code GAS or CYCLE C-01 1811430 140 100 95 P P OIL C-03 1820500 140 100 95 P P OIL C-04 1821260 140 100 100 P 4 OIL C-05A 1842430 140 100 100 P 4 OIL C-07 1850020 140 100 100 P P OIL C-08 1850140 C-09 1850360 140 100 120 P 4 OIL C-13 1850670 C-14 1850880 140 100 100 P P OIL C-15 1851030 C-17 1852630 C-20 1890150 C-21 1940800 C-22A 1951980 140 100 95 P P OIL C-23 1960160 C-25A 1960210 4000 2000 2000 P 4 WAG C'26 1952060 ~.~(i~i:...~-' i:~-~ 1960290 4000 2000 2000 P 43 WAG C-36 1980010 Ic-39 1972480 C-02 1821940 4000 1900 P P WAG C-06 1842410 4000 1900 P 4 WAG Wells: 12 Components: 23 Failures: 6 Failure Rate: 26.0%[~ o0 Day Remarks: Wells # C-02 & C-06 are listed as water injection wells, and are not in this database Well # C-28 SV could not be pressure tested because the tree cap o-ring leaked. The SV on well # C-07 recorded a slow closing time;(2:27). Larry Niles, the BP representative, said he would have these items corrected. 8/7/00 Page 1 of 1 V 1 v7irqm.xls S,T,M,WNNOD sox LP~AT~Om~~ s~X ~&p~Tn.b~ m~s~ lI~ ~ / %/://¥ o,1. /9/~ / L//? ~ ado ~.w~ X~T'~CI LO~-OT 96/£0/0T £-I 96/9~/60 ~ItfNIa 96/9~/60 ~r~NIa 96/95/60 ~]fNIA 96/95/60 ~ItfNIa 96/£0/S0 96/IO/SO 96/IO/SO 96/I0/S0 96/I~/50 86/£1/S0 :s2e~ I~L8-OOI~ I~£8-00I/~ ~9ta-oo?~ ~a-oo?~ II~M IenPyA7puI ~ODO~ OLOL ~N-~/s~ (a~as) ~oD/~s ~oo/~/~ss 650-96 6E0-96 6~0-96 650-96 6~0-96 650-96 6E0-96 6E0-96 6E0-96 6E0-96 LI~Zd BP EXPLORATION BP Exploration (Alaska)Inc. 900 East Benson Boulevard P,O. Box 196612 Anchorage, Alaska 99519~6612 (907) 561-5111 March 10, 1997 Blair Wondzell, Senior Petroleum Engineer Alaska Oil & Gas Conservation Commission,._ E~ 3001 Porcupine Drive Anchorage, Alaska 99501-3192 RE: Milne Point Unit Well C-28i Dear Mr. Wondzell: This letter is a summary of the favorable results obtained from the Schlumberger Water Flow Log (WFL) ran in Milne Point Unit well C-28i. The ,,.~_WE~L was ran to ascertain that injected fluids were being contained within the Kuparuk interval. No channels were found behind the 7" casing and the log confirmed that all injected fluid is being confined within the Kuparuk. In addition to the WFL, conventional spinner, temperature, pressure logs were ran to determine the injection profile. Copies of these logs have been forwarded to the AOGCC and a summary of the WFL log is attached. C-28i was drilled as a water-alternating-gas injection well in April 1996. A Segmented Bond Log (SBL) was ran on 4/16/96 and copies forwarded to the AOGCC. Although the SBL indicated questionable bond quality, BP's interpretation was that sufficient cement existed to confine injected fluids to the Kuparuk interval. The well was completed in May and placed on injection in June 1996. The standard practice at MPU is to run injection surveys six to nine months after initial injection, which conforms with State regulations, and allows ample time for injectivity to stabilize. In C-28i, a WFL/Spinner/ Temperature/Pressure survey was ran in February. The primary results/conclusions obtained from these surveys are as follows: 1) Injection rate on the day of survey was 540 BWPD at approximately 2,700 psig. BP Exploration (Alaska) Inc. 2) Injection distribution is as follows: 10 BWPD is entering perforations at 8,242'-8,266'; 220 BWPD is entering perforations at 8,306'-8,318'; 0 BWPD is entering perforations at 8,328'-8,338'; and 310 BWPD is entering perforations at 8,378'-8,418' (Wellbore diagram is attached). The calculated downhole total volume entering the perforations was 540 BWPD, yet the total measured surface rate at the time of survey was 1275 BWPD. The surface meter was checked for accuracy and found to be incorrect. A work package is in progress to correct C-28i's water flow meter. 3) The WFL determined that no water is flowing up behind the 7 inch casing from the upper set of perforations at 8,242'-8,266'. The top of the Kuparuk is at 8,210'; therefore, 100% of the injected fluid is remaining within the Kuraruk formation. All depths are referenced from the GR/CCL/SBL dated 4/16/96. 5) Based on survey results, additional remedial work is not warranted at this time. It is BP's contention that continued injection into C-28i is environmentally safe, in accordance with the Area Injection Order, conforms with prudent operating practices, and will maximize secondary recovery of reserves. Therefore, continued operation of C-28i is in the best interests of the Milne Point working interest owners and the State of Alaska. If I can be of further assistance regarding C-28i, please call me at 564-5637. Verytruly yours, / Steve Rossbeig /TY~~ MPU Lead Production Engineer cc: Tim Holt, Bruce Policky, Mark Weggeland, Bill Hill, Trina Cooper, Tom Gray, Randy Thomas, John Hendrix, Hal Stevens. BP Exploration (Alaska), Inc. Date February 13, 1997 Well MPC 28i Milne Point/Kuparuk Log Data from WFL Io .... (Flow behind seven inch casing --. up direction). Time File Depth '2 ft 6ft 20ft burst cycles c~irection 'Time BWPD time of data of flow seconds 14:00 32 8180 0.0 0.0 0.0 2 13 up 0.00 0 13:30 30 8200 0.0 0.0 0.0 2 13 up 0.00 0 13:10 28 8220 0.0 0.0 0.0 10 6 up 0.00 0 12:40 26 8220 0.0 0.0 0.0 2 7 up 0.00 0 12:20 23 8230 0.0 0.0 0.0 2 7 up 0.00 0 12:05 22 8230 0.0 0.0 0.0 10 7 up 0.00 0 · Objective --- Determine if water is flowing up through a cement channel behind the 7 inch casing above the upper perorations. · There is no water flowing behind the seven inch casing in the up direction. Log Data from WFL log --- (WI Profile inside seven casing --- down direction). Time File Depth 2 ft 6 ft burst cycles direction Tir~e BWPD hr/min # ft fpm fpm time of data of flow seconds 18:30 45 8201 9.39 11.72 10 6 down 30.714 540 20:30 55 8281 9.94 11.48 10 6 down 31.357 530 20:15 54 8321 6.75 TSTM 10 7 down 17.786 310 21:00 56 8351 6.75 TSTM 10 7 down 17.786 310 21:15 57 8441 · 6.72 0.0 10 7 down 17.857 0 22:00 58 8441 · 5.77 0.0 10 7 down 20.786 0 · Objective --- Determine water injection profile. · The calculated water injection above all perforations is 540 BWPD. The estimated water injection rate at surface was 1275 BWPD @ 2725 psi. The surface meter should be checked for accuracy. · The top perforations, "C" sand, are taking only 10 BWPD. · The indicated water flow in the sump is due to thermal conductivity of the water over a two ft interval trying to come into equivalent. There is no water flowing below the bottom perforations. Calculated Injection Profile from the WFL Water Flow Loq. i T Depth water velocity Area, in2 BWPD ft fpm Casing ID -WFL OD 8201 11.72 28.70 540 10 BWPD ( 1.8 %) ---injected into the "C" sand perforations (8242 - 8266). 8281I 11.48 I 28.70 I 530 220 BWPD (40.7 %) --- injected into the upper "B" sand perforations (11722 - 11728). 8321I 6.75 I 28.70 J 310 0 BWPD ( 0.0 %) ---injected into the lower"B" sand perforations (11798 - 11828). 8351I 6.75 I 28.70 I 310 310 BWPD (57.5 %) ---injected into the "A" sand perforations (11798 - 11828). 8441 I 0.00 ] 28.70 · Objective --- Determine water injection profile. BWPD = (1.7808)(Area)(0.9)(velocity), Area equals 28.70 square inche~/i/~ Tree: 3 1/8' 5M Wellhead: FMC 11" x 11 · 5M, Gen. 5 w/ 11" x 3.5" FMC Tbg. Hnr. w/ NSCT threads top and bottom.and 3" CIW H BPV profile 20" 91.1ppf, H-40 I 115' I MPU C- 28i KOP @ 600' Max. hole angle = 38 to 42 deg. f/ 2700' to 7100' Hole angle thru' perfs = 24 deg DLS = 4.3 deg./100' @ 1500' 9 5/8", 40#/ft, L-80 Btrc. I 5405, mdI 7" 26 ppf, L-80, NSCC production casing ( drift ID = 6.151 ", cap. = 0.0383 bpf ) 3 1/2" NSCT TUBING 9.2# L-80 I I.D. 2.992" -- CAP .00870 BBLS / FT Stimulation Summary 08/06/96 - High pressure breakdown / step rate test - Three stages, 20 ppt linear gel, 884bb1. total, 3020 lbs. of 1 ppg 20-40 sand scour in second stage. Perforation Summary Ref log: SBT/GR/CCL 04/16/96 33/8"I 6 I 'B'Sand 3 3/8"I 6 18306" 8318' 33/8"I Sand 133/8"1 6 18378"8418' 7049'-7085 21 gm Alpha Jet charges EHD = 0.48" TTP = 22.8") @ 60 deg. )basing initial SBHP 4/16/96 = 3-~15 psig @ 8398' (7069' TVD) Fish: half of a centralizer arm (6" x ~ 1.25" x 0.5") from anAtlas SBT - · 4/16/96 - Inte~al (-I'VD) 'C'Sand 8242'-8266' 6925'-6947' 6983'-6994' 7004'-7013' DATE REV. BY COMMENTS 2 / 23 / 96 JBF Surface Hole Drilled and Cased by N 22E 4 / 10 / 96 JDF Production Hole Drilled and Cased 4 / 22 / 96 JBF Wellprepped for RWO. 5/16/96 WRR COMPLETION POLAR RIG #1 Orig. DF Elev. = 46.5' (N 22E) Orig. GL Elev. = 16.8' RT To Tbg. Spool = 28.8' (N 22E) BAKER 7" SAB PACKER [ 8079' MD I 2.750" NO GO Two 7" marker joints from 8071' wlm to 8110' wlm w/RA marker at 8071' wlm 3 1/2" WLEG I8117' MD I 7" float collar (PBTD) [ 8616' md I 7" float shoe I 8696' md I MILNE POINT UNIT WELL MPU C- 28i APl NO: 50-029-22648 BP EXP LO RATIO'~(J~I~)~ STATE OF ALASKA ALASKA ,JiL AND GAS CONSERVATION CO,,,,MISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1. Status of Well Classification of Service Well [] Oil [] Gas [] Suspended [] Abandoned [] Service Water & Gas Injector 2. Name of Operator 7. Permit Number BP Exploration (Alaska) Inc. 96-29 96-69 3. Address 8. APl Number P.O. Box 196612, Anchorage, Alaska 99519-6612 50-029-22648 4. Location of well at surface .,: ............ .:. ~' 9. Unit or Lease Name :¥~:".- ,: ": ':::' Milne Point Unit 837' NSL, 2341' WEL, SEC. 10, T13N, R10E At top of productive interval i ~_///~¢_~--.'..',-: !.:~ i~!} 10. Well Number . 3197' NSL, 230' WEL, SEC. 9, T13N, R10E '~ : MPC-28i At total depth ~i~ "~-;~ ~',~- 11 Field and Pool 3330' NSL, 414' WEL, SEC. 9, T13N, R10E .~.~_~_~.__-" i .... - Milne Point Unit/Kuparuk River 5. Elevation in feet (indicate KB, DF, etc.) 16. Lease Designation and Serial No. Sands KBE = 47.55'I ADL 047434 12. Date Spudded02/17/96 113' Date T'D' Reached I 14' Date C°mp" Susp" °r Aband'l15' Water depth' if °fish°re 116' N°' °f c°mpleti°ns04/08/96 05/15/96 N/A MSLI One 17. Total Depth (MD+TVD) 118. Plug Back Depth (MD+TVD)I19. Directional Surveyl20. Depth where SSSV set~21. Thickness of Permafrosi 8720 7361 FTI 8615 7265 FT~ []Yes i-lNo I N/A MDI 1800' (Approx.) 22. Type Electric or Other Logs Run Gyro, LWD, EMSS, GR/SBT/CCL 23. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH HOLE SIZE WT. PER FT. GRADE TOP BO'I-I'OM SIZE CEMENTING RECORD AMOUNT PULLED 20" 91.1# H-40 32' 112' 24" 250 sx Arcticset I (Approx.) 9-5/8" 40# L-80 31' 5405' 12-1/4" 1050 sx PF 'E', 250 sx 'G', 150 sx PF 'E' 7" 26# L-80 29' 8696' 8-1/2" 250 sx 'G' 24. Perforations open to Production (MD+TVD of Top and Bottom 25. TUBING RECORD and interval, size and number) S~ZE DEPTH SET (MD) PACKER SET (MD) 3-3/8" Gun Diameter, 6 spf 3-1/2", NSCT 81 18' 8080' MD TVD MD TVD 8242'-8266' 6924'-6946' 8306'-8318' 6983'-6994' 26. AC~D, FRACTURE, CEMENT SQUEEZE, ETC. 8328'-8338' 7003'-7012' 8378'-8418' 7048'-7085' DEPTH INTERVAL (MD) AMOUNT & KIND OF MATERIAL USED Freeze protect w/62 bbls diesel High pressure breakdown & step rate test i27. PRODUCTION TEST Date First Production Method of Operation (Flowing, gas lift, etc.) June 23, 1996 Water & Gas Injection Date of Test Hours Tested PRODUCTION FOR OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE I GAS-OIL RATIO TEST PERIOD I !Flow Tubing Casing PressureCALCULATED. !OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-APl (CORR) Press. 24-HOUR RATE !28. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water. Submit core chips. RECEIVED b40V 2 6 1996 Alaska 0il & Gas Cons. Commission Anchorage Form 10-407 Rev. 07-01-80 Submit In Duplicate 29. ' Geologic Marker~. 30. Formation Tests Measured True Vertical Include interval tested, pressure data, all fluids recovered Marker Name Depth Depth and gravity, GOR, and time of each phase. (Subsea) Top Kuparuk 'C' 8163' 6809' Top Kuparuk 'B' 8263' 6900' Top Kuparuk 'A' 8367' 6995' Top Kuparuk A3 8380' 7007' Top Kuparuk A2 8393' 7019' Top Kuparuk A1 8413' 7037' 31. List of Attachments Summary of Daily Drilling Reports, Surveys, Annular Pumping Report 32. I herebycertifythatt~ingistruqandcor~c,ttothebestofmyknowledgesigned ~ (~.,~/..~~ /,,~, /~, '13mSchofield /~y'~ - Title Senior Drilling Engineer Date ti ¢-. Prepared By Name/Number: Kathy Camp¢amor,'564-5122 INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITEM 1: Classification of Service Wells: Gas injection, water injection, steam injection, air injection, salt water disposal, water supply for injection, observation, injection for in-situ combustion. ITEM 5: Indicate which elevation is used as reference (where not otherwise shown) for depth measurements given in other spaces on this form and in any attachments. ITEM 16 AND 24: If this well is completed for separate production from more than one interval (multiple completion), so state in item 16, and in item 24 show the producing intervals for only the interval reported in item 27. Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval. ITEM 21: Indicate whether from ground level (GL) or other elevation (DF, KB, etc.). ITEM 23: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITEM 27: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, Other-explain. ITEM 28: If no cores taken, indicate 'none'. Form 10-407 Rev. 07-01-80 SUMMARY OF DALLY OPERATIONS SHARED SERVICES DRILLING - BPX/ ARCO Well Name: M P C- 2 8 i Rig Name: N - 2 2 E AFE: 3 3 7 01 8 Accept Date: 02/1 7/96 Spud Date: 02/1 7/96 Release Date: 02/22/96 Feb 17 1996 MIRU. Rig moved 75%. Spot sub, pits and motor complex. Hook up water, steam, air lines. Build berms and spot tioga. Rig accepted 02/17/96 @ 0100 hrs. RU diverter. RU flowlines. Feb 18 1996 RU drillstring handling equipment. RU skate. MU BHA #1. PU 27 jts HWDP and stood back in derrick. Test diverter. Doug Amos w/AOGCC waived witnessing test. Function test completed satisfactorily. MU BHA #1, steam and strap BHA #1. Stand back one stand of collars. MWD tool failed. Repair MWD tool. Switch out MWD tools. Run BHA #1. Orient and test MWD and andergauge. Spud and drill 12-1/4" hole f/112' t/1367'. Feb 19 1996 Run BHA #1. Drilled t/2601' Circulate, pump sweep around. Obtained bottoms up. POOH t/1000'. RIH t/2601'. Drilled t/4133'. Circulate at 4133', obtained bottoms up. Feb 20 1996 Run BHA #1. POOH t/2600'. RIH t/4133'. Drilled t/5425'. Circulate and cond mud. Pump lo/hi sweeps around. Obtained clean returns. POOH t/1000', POOH t/HWDP. Hole swabbed slightly from 2575'-1625'. Pulled slow-no problems. At kick off depth, 1000'. RIH t/5425'. Circulate and cond mud to run casing. Obtained bottoms up. POOH t/265'. Pulled BHA. Feb 21 1996 Run BHA #1. Download LWD/MWD. RU casing handling equipment. Change out elevators. Run 9-5/8" casing t/5405'. Hanger landed. Circulate at 5405'. Obtained bottoms up. Mix and pumped cement. Test casing. Cement top job. RD casing handling equipment, land jt and change out bails. Ran 5" drillpipe, t/5320', at float collar. Circulated. Displaced well with seawater and corrosion inhibitor. Page Feb 22 1996 Run 5" drillpipe. LD drillpipe t/2000'. Circulated at 2000', displaced hole with diesel. LD drillpipe t/0'. RD diverter, diverter line, fill casing with diesel. Install wellhead primary components. Suspend operations. RD fluid system. Drill adandoned-- Operation Shut-down. RD fluid system. Clean pits, remove skate rails, stabbing board from derrick, slip drilling line, disassemble top drive. Feb 23 1996 Operation shut down. Bullhead well. Freeze protect. RD fluid system. Finish cleaning pits, RD top drive. Rig released 02/22/96 @ 1000 hrs. **See Operation Shut-down approval #96-69 (10-403). Drilling operations will resume in April 1996.** Page 2 SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: MPC-28i Rig Name: N-22E AFE: 33701 8 Accept Date: 04/04/96 Spud Date: 02/1 7/96 Release Date: 04/1 0/96 Apr 3 1996 (47) Held safety meeting. RU drillfloor / derrick. Held safety meeting. RD drillfloor / derrick. Rig moved 65 %. Rig moved 90 %. Held safety meeting. Rig moved 100 %. RU additional services. RU block line. Apr 4 1996 (48) Held safety meeting. RU top drive. RU additional services. RU additional services. RU additional services. Apr 5 1996 (49) Held safety meeting. RU top drive. Rig accepted 04/04/96 @ 1100 hrs. RU drillstring handling equipment. Removed Xmas tree. RU BOP stack. Tested flowline. Tested BOP stack. Ran electric logs. Apr 6 1996 (50) Held safety meeting. Ran electric logs. Ran electric logs. MU BHA #2. MU BHA #2. Held drill (H2S). RIH to 5316 ft. Repaired standpipe manifold. Circulated at 5316 ft. POOH to 2200 ft. RIH to 5316 ft. Apr 7 1996 (51) Held safety meeting. Held drill (Spill). Drilled installed equipment - float collar. Circulated at 5435 ft. Performed formation integrity test, 12.5 ppg EMW. Drilled to 7390 ft. Circulated at 7390 ft. POOH to 2000 ft. Apr 8 1996 (52) Held safety meeting. POOH to 256 ft. Downloaded MWD tool. MU BHA #3. RIH to 5405 ft. Serviced top drive. RIH to 7390 ft. Drilled to 7956 ft. Circulated at 7956 ft. POOH to 6800 ft. RIH to 7956 ft. Drilled to 8521 ft. Apr 9 1996 (53) Held safety meeting. Held drill (kick while drilling). Drilled to 8720 ft. Circulated at 8720 ft. Flow check. POOH to 5405 ft. Serviced top drive. Repaired HP air supply. RIH to 8720 ft. Circulated at 8720 ft. Flow check. POOH to 250 ft. Pulled BHA. RD top ram. RU casing handling equipment. Ran casing to 3000 ft (7 in OD). Page Apr 10 1996 (54) Ran casing to 8696 ft (7 in OD). Circulated at 8696 ft. Mixed and pumped slurry - 51 bbl. Tested casing. RD casing handling equipment. Installed wellhead integral components. Installed tubing hanger. RD top ram. RD BOP stack. Installed Xmas tree integral components. Serviced fluid system. Rig released 04/10/96 @ 0600 hrs. Page 2 SUMMARY OF DAILY OPERATIONS SHARED SERVICES DRILLING - BPX / ARCO Well Name: M P C-2 8 i Rig Name: Polar Rig #1 AFE: 3 3 7 01 8 Accept Date: 05/1 3/96 Spud Date: Release Date: 05/1 5/96 May 10 1996 MIRU. Starting to RU BOP's. RU BOP's, fabricate choke line. May 11 1996 RU BOP's. Fabricating choke line at APC fab shop. Load pipe shed and pipe racks with 3-1/2" NSCT tubing. Install choke line and cont loading pipe racks & shed. RU to pressure test BOP's. Pressure test HB & R line. Loaded hole and closed blinds. Found that bland rams cylinder has an internal leak. Put Polar Rig on maintenance day until rams are rebuilt. Located BOP repairman, waiting on repairman. May 12 1996 Maintenance day, waiting for repairman. DSR is servicing blind and pipe ram cylinders. The closing side of both of the blind ram o-rings were washed out. Replaced all outside o-rings and inter-cylinder o-ring. Put blinds back together. Discovered the cap o-ring on the Hydril started to leak. Investigating work on the accumulator. Function tests the BOP/Hydril. Tested OK. Called HB & R to pressure test BOP's. Call AOGCC to notify inspector. Call Camco to send welder to install the flowline. Can't send welder, Peak welder on the way. RU HB & R to pressure test the BOP's. Conduct BOP test. Changed out test plug rubber (pipe rams HP failed). Pressure test pipe rams, OK. Finish BOP test, OK. NU flowline. May 13 1996 RU flowline. Rig accepted 05/13/96 @ 1230 hrs. Started to PU Baker WLSRBP pulling tool. TIH with 15 jts. Shut down & RU the slip type elevators. TIH with 3-1/2". Drift tubing. PU 250 jts. Stop to circulate wellbore. Start to reverse circ wellbore with brine. Shut down pump and check flow. Well unbalanced. Pump another 60 bbls of 8.7 ppg. Shut down and monitor flow. Remove TIW and TIH to unset WLSRBP. Tagged the BP, unset and monitored well. POOH with BP. POOH with BP at 7500'. May 14 1996 Cont POOH with BP. Finish POOH and LD BP and BHA #1. MU BHA #2 (7" casing and scraper run). Start in hole with BHA #2 and 3-1/2" tubing. Stop casing scraper and +/- 8200'. Start POOH with BHA #2. Finish POOH and LD BHA #2. PU tailpipe, XN nipple, and Baker production packer. Start in hole with 3-1/2" completion string. Check torque on all connections. Well on slight vac. Cont in hole with completion string. Page May 15 1996 Cont in hole with completion string. Shut down for repairs to rig slips. Notify State for upcoming MIT. Repairs complete. Resume operations and cont running completion. Finish in hole with 255 jt tubing, packer, and tail pipe assy. PU tubing hanger with 2- way check installed. Land hanger and run in lock down screws. Start to ND BOP stack. Finish ND BOP's. HB & R on location. NU tree. Test tubing hanger and tree. Good test. Finish RU HB & R. Pull 2-way check. Start pumping brine with corexit down annulus. End brine, start diesel freeze protect. End diesel. Hook up to tubing side and pump diesel. Drop ball/rod. Hook back up to tubing and pump. Ball on seat. Pressure up and hold. Packer set, release pressure. Hook up to annulus and perform MIT. State waived MIT witness. Pressure tested annulus. Good test. Release HB & R. Install BPV. Rig released 05/15/96 @ 2400 hrs. Page 2 ANNULAR INJECTION DATA ENTRY SCREEN Asset .M. iJ[le, ........................................ Legal Desc .Se, c...l.0.,.-[..l.3hl.,..~.l..0E. ......................................................................... Rig Name .~ab.(~r.s.2.2F_ .......................... · ...................................................................................................................... Inj Well Name .M.P..C.:2.8 .................................. Permit Start ..... 21..1.,5./.9.6 ..... Permit End ..... 2./..1.,5./.9.7. ..... Sur Csg Dep .5..4.D.5 .............. · ............................................................. Cumulative Data Rig Completion Formation Intermittant Final Well Total Mud/Ct~] Wash Fluids Fluids Freeze Freeze .......... ..4.2.~5 ..................... 3.5.1~ .............................................................................................................................................. Z5 ............ Daily Data I Mud, Ctgs, cm~ COmpletion :Fr:eeze :i:: Freeze DailY ' ! ! Annulus SOUrce Date of C°nta~inated::i RigwaSh Formation : Intermittant Final i Welll i Injection Brig MUd;,, Flui:ds I,,, Fluids FlUids ProtectionI Protection :, T~°!a! , Rate: Pressurei Status: CommentS complications MPC-28 04/09/96 350 75 425 Open ......... BP EXPLORATION MILNE PT/MPC-28i 500292264800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/17/96 DATE OF SURVEY: 040896 ELECTRONIC MULTI-SHOT SURVEY JOB NUMBER: AK-EI-60041 KELLY BUSHING ELEV. = 46.30 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS COURSE DLS TOTAL INCLN DIRECTION RECTANGULAR COORDINATES VERT. DG MN DEGREES DG/100 NORTH/SOUTH EAST/WEST SECT. 5300.00 4560.56 4514.26 5465.50 4689.50 4643.20 5560.60 4763.61 4717.31 5655.70 4837.23 4790.93 5750.80 4909.95 4863.65 38 52 N 50.38 W .00 1368.62N 1806.82W 2266.65 38 46 N 52.15 W .67 1433.53N 1887.75W 2370.35 38 49 N 54.50 W 1.55 1469.11N 1935.53W 2429.93 39 43 N 54.76 W .97 1503.96N 1984.62W 2490.10 40 31 N 54.50 W .85 1539.43N 2034.60W 2551.36 5845.90 4982.17 4935.88 5941.00 5054.20 5007.90 6036.10 5125.92 5079.62 6131.20 5197.43 5151.13 6226.30 5268.90 5222.60 40 38 N 54.64 W .15 1575.29N 2085.00W 2613.20 40 53 N 55.49 W .64 1610.85N 2135.91W 2675.25 41 12 N 55.52 W .34 1646.22N 2187.39W 2737.64 41 15 N 56.52 W .70 1681.26N 2239.37W 2800.23 41 18 N 56.97 W .32 1715.66N 2291.84W 2862.83 6321.40 5340.29 5293.99 6416.50 5411.56 5365.26_ 6511.60 5482.64 5436.34 6606.70 5553.51 5507.21 6701.80 5624.27 5577.97 41 24 N 57.15 W .16 1749.83N 2344.57W 2925.50 41 30 N 57.87 W .51 1783.64N 2397.67W 2988.25 41 45 N 58.06 W .29 1817.15N 2451.23W 3051.18 41 54 N 55.55 W 1.77 1851.87N 2504.29W 3114.44 41 55 N 55.85 W .21 1887.67N 2556.77W 3177.90 6796.90 6892.00 6987.10 7082.20 7177.30 5694.95 5648.65 42 4 5766.23 5719.93 40 48 5838.94 5792.64 39 26 5913.11 5866.81 38 1 5988.67 5942.37 36 44 N 55.97 W .17 1923.34N 2609.47W 3241.44 N 55.90 W 1.32 1958.60N 2661.61W 3304.30 N 55.81 W 1.45 1992.99N 2712.33W 3365.50 N 55.09 W 1.55 2026.73N 2761.34W 3424.94 N 54.57 W 1.39 2059.99N 2808.55W 3482.66 7272.40 7367.50 7462.60 7557.70 7652.80 6065.63 6019.33 35 11 6144.09 6097.79 33 36 6224.64 6178.34 30 34 6307.55 6261.25 28 4 6392.63 6346.33 24 59 N 54.70 W 1.64 2092.32N 2854.09W 3538.48 N 53.88 W 1.72 2123.67N 2897.72W 3592.19 N 54.92 W 3.24 2153.10N 2938.78W 3642.70 N 57.81 W 3.03 2178.93N 2977.52W 3689.17 N 58.70 W 3.26 2201.29N 3013.63W 3731.46 7747.90 7843.00 7938.10 8033.10 8128.20 6478.87 6432.57 24 51 6565.09 6518.79 25 3 6651.21 6604.91 25 9 6737.30 6691.00 24 51 6823.71 6777.41 24 30 N 58.38 W .20 2222.21N 3047.82W 3771.35 N 57.69 W .37 2243.45N 3081.86W 3811.31 N 57.65 W .11 2265.03N 3115.96W 3851.52 N 57.49 W .32 2286.57N 3149.85W 3891.55 N 57.34 W .37 2307.96N 3183.32W 3931.14 8223.30 8318.40 8381.80 8508.62 8579.00 6910.35 6864.05 24 10 6997.08 6950.78 24 15 7054.83 7008.53 24 31 7170.40 7124.10 24 6 7234.72 7188.42 23 47 N 56.22 W .60 2329.43N 3216.12W 3970.25 N 55.37 W .37 2351.36N 3248.38W 4009.21 N 55.02 W .48 2366.30N 3269.87W 4035.37 N 54.11 W .44 2396.57N 3312.41W 4087.55 N 54.21 W .44 2413.30N 3335.58W 4116.12 THE CALCULATION PROCEDURES THREE-DIMENSION MINIMUM HORIZONTAL DISPLACEMENT = 4117.04 FEET AT NORTH 54 DEG. 6 MIN. WEST AT MD = 8579 ARE BASED ON THE USE OF CURVATURE METHOD. RECEIVED VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 307.10 DEC-AJaskaOJJ&GasOons. Commission Anchorage TIED INTO GYRODATA SURVEY AT 5300' KICKOFF POINT AT 5465.5' ~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE PT/MPC-28i 500292264800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/17/96 DATE OF SURVEY: 040896 JOB NUMBER: AK-EI-60041 KELLY BUSHING ELEV. = 46.30 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 1000 FEET OF MEASURED DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 5300.00 4560.56 4514.26 1368.62 N 1806.82 W 6300.00 5324.23 5277.93 1742.15 N 2332.68 W 7300.00 6088.19 6041.89 2101.51 N 2867.07 W 8300.00 6980.31 6934.01 2347.07 N 3242.16 W 8579.00 7234.72 7188.42 2413.30 N 3335.58 W 739.44 975.77 236.33 1211.81 236.05 1319.69 107.88 1344.28 24.59 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. ~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION MILNE PT/MPC-28i 500292264800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/17/96 DATE OF SURVEY: 040896 JOB NUMBER: AK-EI-60041 KELLY BUSHING ELEV. = 46.30 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE MEASD VERTICAL DEPTH DEPTH SUB-SEA TOTAL VERTICAL RECTANGULAR COORDINATES MD-TVD DEPTH NORTH/SOUTH EAST/WEST DIFFERENCE VERTICAL CORRECTION 5300.00 4560.56 4514.26 1368.62 N 1806.82 W 739.44 5410.09 4646.30 4600.00 1412.24 N 1860.34 W 763.79 5538.38 4746.30 4700.00 1461.02 N 1924.19 W 792.08 5667.49 4846.30 4800.00 1508.31 N 1990.78 W 821.19 24.35 28.29 29.12 5798.63 4946.30 4900.00 1557.47 N 2059.90 W 852.32 5930.55 5046.30 5000.00 1606.98 N 2130.27 W 884.25 6063.20 5146.30 5100.00 1656.33 N 2202.10 W 916.90 6196.22 5246.30 5200.00 1704.84 N 2275.19 W 949.92 6329.42 5346.30 5300.00 1752.70 N 2349.02 W 983.12 31.13 31.92 32.65 33.03 33.20 6462.90 5446.30 5400.00 1799.99 N 2423.72 W 1016.60 6597.02 5546.30 5500.00 1848.21 N 2498.96 W 1050.72 6731.41 5646.30 5600.00 1898.78 N 2573.14 W 1085.11 6865.67 5746.30 5700.00 1948.95 N 2647.35 W 1119.37 6996.63 5846.30 5800.00 1996.40 N 2717.34 W 1150.33 33.48 34.12 34.39 34.26 30.96 7124.29 5946.30 5900.00 2041.56 N 2782.57 W 1177.99 7248.75 6046.30 6000.00 2084.44 N 2842.97 W 1202.45 7370.14 6146.30 6100.00 2124.52 N 2898.88 W 1223.84 7487.66 6246.30 6200.00 2160.27 N 2949.15 W 1241.36 7601.32 6346.30 6300.00 2189.55 N 2994.52 W 1255.02 27.66 24.46 21.39 17.52 13.67 7712.00 6446.30 6400.00 2214.30 N 3034.97 W 1265.70 7822.26 6546.30 6500.00 2238.76 N 3074.44 W 1275.96 7932.68 6646.30 6600.00 2263.80 N 3114.01 W 1286.38 8043.02 6746.30 6700.00 2288.81 N 3153.37 W 1296.72 8153.03 6846.30 6800.00 2313.52 N 3191.99 W 1306.73 10.68 10.26 10.42 10.34 10.01 8262.71 6946.30 6900.00 2338.41 N 3229.53 W 1316.41 8372.43 7046.30 7000.00 2364.07 N 3266.68 W 1326.13 8482.22 7146.30 7100.00 2390.24 N 3303.68 W 1335.92 8579.00 7234.72 7188.42 2413.30 N 3335.57 W 1344.28 9.68 9.72 9.79 8.36 THE CALCULATION PROCEDURES USE A LINEAR INTERPOLATION BETWEEN THE NEAREST 20 FOOT MD (FROM MINIMUM CURVATURE) POINTS ~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC MILNE POINT / MPC-28i 500292264800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/12/96 DATE OF SURVEY: 040896 JOB NUMBER: AK-MM-960208 KELLY BUSHING ELEV. = 46.52 OPERATOR: BP EXPLORATION FT. INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -46.52 46.52 46.52 .00 146.52 146.52 100.00 246.53 246.52 200.00 346.53 346.52 300.00 .00 N .02 N .56 N 1.27 N 2.09 N .00 .02 .52 .62 .84 E .00 E .00 .00 E .00 .00 E .01 .00 E .01 .00 446.53 446.52 400.00 546.54 546.52 500.00 646.55 646.52 600.00 746.57 746.52 700.00 846.59 846.52 800.00 3.01 N 1.12 E .01 .01 4.21 N 1.43 E .02 .01 5.66 N 1.61 E .03 .01 7.20 N 1.35 E .04 .01 8.84 N .20 E .07 .02 946.66 946.52 900.00 1046.92 1046.52 1000.00 1147.50 1146.52 1100.00 1248.41 1246.52 1200.00 1349.57 1346.52 1300.00 11.32 N 2.49 W .14 .07 15.44 N 8.32 W .40 .27 21.66 N 17.09 W .98 .58 29.64 N 27.94 W 1.89 .91 38.80 N 40.16 W 3.05 1.16 1451.18 1446.52 1400.00 1553.77 1546.52 1500.00 1657.46 1646.52 1600.00 1761.47 1746.52 1700.00 1866.90 1846.52 1800.00 49.60 N 63.29 N 79.93 N 97.18 N 117.08 N 54. 72. 94. 117. 144. 49 76 53 33 09 W 4.66 1.60 W 7.25 2.59 W 10.94 3.69 W 14.95 4.01 W 20.38 5.43 1974.71 1946.52 1900.00 2085.23 2046.52 2000.00 2198.34 2146.52 2100.00 2314.21 2246.52 2200.00 2433.86 2346.52 2300.00 142.09 N 172.18 N 206.21 N 242.82 N 283.12 N 175 . 211. 252. 297. 349. 61 72 13 76 6O W 28.20 7.81 W 38.71 10.52 W 51.82 13.11 W 67.69 15.87 W 87.34 19.65 2556.43 2446.52 2400.00 2681.24 2546.52 2500.00 2808.02 2646.52 2600.00 2935.31 2746.52 2700.00 3067.35 2846.52 2800.00 326.02 N 371.34 N 419.43 N 467.44 N 519.57 N 406. 465. 526. 589. 657. 01 36 68 10 76 W 109.91 22.57 W 134.72 24.82 W 161.50 26.78 W 188.79 27.29 W 220.83 32.04 3200.97 2946.52 2900.00 3332.84 3046.52 3000.00 3465.53 3146.52 3100.00 3598.50 3246.52 3200.00 3732.48 3346.52 3300.00 572.54 N 623.39 N 675.90 N 728.32 N 778.15 N 728. 798. 867. 937. 1011. 8O 11 73 95 86 W 254.45 33.62 W 286.32 31.87 W 319.01 32.69 W 351.98 32.97 W 385.96 33.98 '~RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 7 BP EXPLORATION (ALASKA) INC MILNE POINT / MPC-28i 500292264800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/12/96 DATE OF SURVEY: 040896 JOB NUMBER: AK-MM-960208 KELLY BUSHING ELEV. = 46.52 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION 3865.43 3446.52 3400.00 3996.58 3546.52 3500.00 4127.07 3646.52 3600.00 4258.36 3746.52 3700.00 4387.81 3846.52 3800.00 825.63 N 1085.49 W 871.70 N 1156.74 W 917.33 N 1227.06 W 966.49 N 1296.48 W 1014.70 N 1363.06 W 418.91 32.9 450.06 31.1 480.55 30.4 511.84 31.2 541.29 29.4 4515.90 3946.52 3900.00 4643.47 4046.52 4000.00 4772.18 4146.52 4100.00 4899.99 4246.52 4200.00 5026.59 4346.52 4300.00 1061.65 N 1108.70 N 1159.67 N 1210.92 N 1260.59 N 1427.88 W 1491.61 W 1554.59 W 1615.48 W 1675.14 W 569.38 28.0 596.95 27.5 625.66 28.7 653.47 27.8 680.07 26.6 5153.74 4446.52 4400.00 5282.12 4546.52 4500.00 5410.42 4646.52 4600.00 5538.57 4746.52 4700.00 5668.28 4846.52 4800.00 1310.19 N 1361.42 N 1411.79 N 1460.11 N 1509.75 N 1736.03 W 1798.13 W 1860.75 W 1924.69 W 1990.72 W 707.22 27.1 735.60 28.3 763.90 28.3 792.05 28.1 821.76 29.7 5799.48 4946.52 4900.00 5931.84 5046.52 5000.00 6064.81 5146.52 5100.00 6198.10 5246.52 5200.00 6331.62 5346.52 5300.00 1561.33 N 1614.31 N 1666.27 N 1717.74 N 1768.14 N 2058.19 W 2126.83 W 2197.40 W 2268.93 W 2341.65 W 852.96 31.2 885.32 32.3 918.29 32.9 951.58 33.2 985.10 33.5 6465.53 5446.52 5400.00 6599.95 5546.52 5500.00 6734.88 5646.52 5600.00 6869.62 5746.52 5700.00 7000.90 5846.52 5800.00 1818.30 N 1869.59 N 1923.69 N 1977.09 N 2027.14 N 2415.23 W 2488.95 W 2561.62 W 2634.44 W 2703.19 W 1019.01 33.9 1053.43 34.4 1088.36 34.9 1123.10 34.7 1154.38 31.2 7128.71 5946.52 5900.00 7253.24 6046.52 6000.00 7374.70 6146.52 6100.00 7492.07 6246.52 6200.00 7605.53 6346.52 6300.00 2074.57 N 2119.38 N 2162.09 N 2199.43 N 2229.81 N 2767.08 W 2826.23 W 2880.28 W 2929.04 W 2973.16 W 1182.19 27.8 1206.72 24.5 1228.18 21.4 1245.55 17.3 1259.01 13.4 7716.13 6446.52 6400.00 7826.36 6546.52 6500.00 7936.72 6646.52 6600.00 8046.96 6746.52 6700.00 8156.87 6846.52 6800.00 2255.69 N 2281.11 N 2306.90 N 2332.69 N 2358.37 N 3012.65 W 3051.45 W 3090.36 W 3128.93 W 3166.62 W 1269.61 10.5 1279.84 10.2 1290.20 10.3 1300.44 10.2 1310.35 9.9 SLNIOd (Z~QL~A~QD MD_MINIM MO~) GM iO0~ 05 LSZh~fZN ZHL NZZMLZS NOIL~Od~ZLNI %SfZNI~ ~ ZSQ SZ~ZDO~d NOIL~QD~D ZHL 8S'0I ~£'6S£I M £9'59££ N II'£6~E ~I'SI£t 99'09££ 00'0EL8 ~£'6 ~£'6££I M 6E'9LE£ N SI'L£gE 00'00IL ~S'9~I£ 98'S8~8 99'6 09'6E£I M 8£'6£E£ N ES'0I~E 00'000t ES'9~0£ EI'9££8 6S'6 ~6'6I£I M EE'£0E£ N 9E'~8£E 00'0069 E~'9~69 9~'99E8 NOIIDZHHOD ZDHZ~Z~IG q~DIIHZA ~AL-GH LSZM/LS%fZ HLflOS/HL%tON SZ3AfNIG~OOD %~FIfl~N~fLDZH ~DIL~ZA ~VOILHZA GS~ZM HLdZ~ ~ZS-~LGS ~0 IZZ~ 00I NZAZ ~OZ SZ~A ES'9~ = 'AZ~Z ONIHS~S X~Z~ 80E096-MM-~ :HZS~KYN SOD 968050 :XZA~S ~0 ZL~Q 96/EI/5 :ZL~ NOIi~i~dMOO H©~O~OS ZdO~S Hi,ON 008~gEE6E00~ T8~-DdM / iNIOd ZN~IM DNI (~S~) NOILV%IO~dXZ dE SZDIA~ZS ©NI~IHG Ni1S-X~: RRY-SUN DRILLING SE ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC. MILNE POINT / MPC-28I 500292264800 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/12/96 DATE OF SURVEY: 021996 MWD SURVEY JOB NUMBER: AK-MM-960208 KELLY BUSHING ELEV. = 46.52 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. .00 .00 -46.52 0 175.87 175.87 129.35 0 261.71 261.70 215.18 0 351.61 351.60 305.08 0 441.20 441.18 394.66 0 0 31 38 42 43 N .00 E .00 .00N .00E N 4.72 E .30 .80N .07E N 15.59 E .19 1.65N .23E N 4.56 E .16 2.68N .41E N 18.66 E .20 3.76N .63E .00 .43 .81 1.29 1.76 532.01 531.98 485.46 0 623.49 623.45 576.93 1 715.14 715.09 668.57 0 805.74 805.67 759.15 1 896.36 896.25 849.73 1 43 2 53 14 59 N .45 W .27 4.87N .81E N 9.72 W .37 6.28N .66E N 24.73 W .32 7.74N .22E N 48.23 W .61 9.03N .80W N 55.00 W .85 10.59N 2.82W 2.30 3.26 4.49 6.09 8.64 986.49 986.25 939.73 4 1082.52 1081.88 1035.36 6 1177.93 1176.60 1130.08 7 1272.83 1270.57 1224.05 8 1368.58 1365.11 1318.59 9 0 8 35 26 43 N 56.13 W 2.24 13.24N 6.72W N 55.70 W 2.22 18.01N 13.75W N 54.57 W 1.54 24.54N 23.11W N 53.59 W .90 32.31N 33.83W N 53.75 W 1.34 41.26N 46.00W 13.35 21.83 33.23 46.47 61.58 1463.74 1458.60 1412.08 11 1557.82 1550.21 1503.69 14 1653.56 1642.64 1596.12 15 1749.11 1734.38 1687.86 16 1844.71 1825.24 1778.72 19 44 31 38 49 22 N 53.47 W 2.12 51.78N 60.26W N 54.65 W 2.98 64.30N 77.58W N 53.03 W 1.24 79.01N 97.68W N 54.24 W 1.28 94.84N 119.19W N 53.56 W 2.69 112.35N 143.18W 79.29 100.66 125.57 152.27 181.97 1939.76 1914.01 1867.49 22 2034.59 2000.67 1954.15 25 2129.93 2086.02 2039.50 27 2224.82 2169.35 2122.83 29 2319.79 2251.00 2204.48 31 29 23 30 36 45 N 51.06 W 3.40 133.14N 170.01W N 49.61 W 3.12 157.72N 199.61W N 49.35 W 2.23 185.31N 231.89W N 51.02 W 2.37 214.33N 266.74W N 51.90 W 2.31 244.52N 304.64W 215.91 254.35 296.73 342.03 390.47 2415.36 2330.96 2284.44 2509.12 2407.70 2361.18 2605.24 2485.26 2438.74 2700.72 2561.00 2514.48 2793.51 2634.23 2587.71 34 35 36 38 37 39 28 55 4 41 N 52.87 W 3.07 276.44N 346.11W N 52.54 W .91 309.08N 388.96W N 53.75 W 1.68 343.12N 434.39W N 51.44 W 1.90 378.44N 480.54W N 51.52 W .42 413.92N 525.12W 442.80 496.67 553.43 611.55 668.51 2892.35 2712.14 2665.62 2988.25 2785.98 2739.46 3084.34 2858.13 2811.61 3179.99 2929.71 2883.19 3275.82 3002.16 2955.64 38 41 41 41 40 15 1 39 26 19 N 51.53 W .58 451.76N 572.74W N 51.82 W 2.88 489.69N 620.73W N 51.77 W .67 528.95N 670.60W N 53.25 W 1.05 567.56N 720.94W N 52.72 W 1.22 605.31N 771.02W 729.31 790.47 853.93 917.36 980.08 RECEIVED NOV 2 ~ 199G Al~k~ 0il & ~u~J Con~. Commission An[~hor~go RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC. MILNE POINT / MPC-28I 500292264800 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/12/96 DATE OF SURVEY: 021996 MWD SURVEY JOB NUMBER: AK-MM-960208 KELLY BUSHING ELEV. = 46.52 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 3371.07 3074.49 3027.97 40 51 N 52.20 W .67 643.07N 820.15W 3466.45 3146.51 3099.99 41 4 N 50.64 W 1.09 682.07N 869.03W 3558.36 3215.72 3169.20 41 13 N 52.26 W 1.17 719.75N 916.33W 3657.46 3290.00 3243.48 41 40 N 55.22 W 2.03 758.53N 969.21W 3750.65 3359.71 3313.19 41 28 N 56.43 W .89 793.27N 1020.37W 1042.05 1104.55 1165.01 1230.58 1292.34 3847.70 3432.87 3386.35 40 40 N 55.99 W .88 828.73N 1073.37W 3943.09 3505.35 3458.83 40 24 N 57.02 W .76 862.95N 1125.08W 4038.76 3578.48 3531.96 39 53 N 57.97 W .84 896.10N 1177.10W 4132.71 3650.29 3603.77 40 24 N 55.62 W 1.71 929.28N 1227.77W 4227.33 3722.37 3675.85 40 20 N 54.46 W .80 964.40N 1278.00W 1356.00 1417.88 1479.37 1539.79 1601.05 4322.81 3795.63 3749.11 39 25 N 53.99 W 1.01 1000.19N 1327.68W 4417.35 3868.98 3822.46 38 47 N 54.73 W .84 1034.94N 1376.15W 4513.40 3944.17 3897.65 38 10 N 54.65 W .65 1069.49N 1424.92W 4609.42 4019.32 3972.80 38 49 N 53.38 W 1.07 1104.61N 1473.27W 4704.88 4093.44 4046.92 39 17 N 50.94 W 1.69 1141.50N 1520.76W 1662.26 1721.88 1781.61 1841.36 1901.50 4800.58 4167.85 4121.33 38 37 N 51.07 W .71 1179.37N 1567.53W 4895.35 4242.16 4195.64 38 5 N 51.04 W .57 1216.34N 1613.27W 4991.19 4317.87 4271.35 37 32 N 51.40 W .61 1253.15N 1659.09W 5086.49 4393.10 4346.58 38 10 N 51.15 W .68 1289.74N 1704.72W 5181.99 4467.79 4421.27 38 55 N 50.95 W .80 1327.16N 1751.01W 1961.64 2020.43 2079.17 2137.64 2197.13 5277.37 4541.98 4495.46 38 56 N 50.86 W .06 1364.96N 1797.53W 5331.19 4583.89 4537.37 38 46 N 51.36 W .66 1386.16N 1823.81W 5425.00 4657.03 4610.51 38 46 N 51.36 W .00 1422.84N 1869.69W 2257.03 2290.78 2349.50 THE CALCULATION PROCEDURES ARE BASED ON THE USE OF THREE-DIMENSION MINIMUM CURVATURE METHOD. HORIZONTAL DISPLACEMENT = 2349.51 FEET AT NORTH 52 DEG. 43 MIN. WEST AT MD = 5425 VERTICAL SECTION RELATIVE TO WELL HEAD VERTICAL SECTION COMPUTED ALONG 307.10 DEG. '~OHI~N ~I~AHflD WIqRININ NOISN~NI~-~HI ~0 SS~ ~Hi NO ~S~ff ~H%f S~~DO~ NOI~q~D~D ~Hi £8'E6 L6'L9L M 69'698I N 58'E~5I IS'019~ £0'LS95 88'£U~ ~I'SL9 ~ 8E'~99I N OS'9S~I ~C'8t~ 98'~E~ O0'O00S TT'9~ 9E'IS5 M ~0'9SII N E6'E88 ~E'EOS£ ~£'8~5£ 00'000~ PP'PLI SI'S0~ M 6L'9E9 N 9P'~6P ££'8PL~ S8'~6L~ 00'000£ ~'0£ IL'0[ M 0~'88I N ~£'8~I LL'EE6I 6['696I 00'000g 8E' 8~' M 0~'£ N LL'£I 0E'£~6 ~L'666 00'000I 00' ~ 00' N 00' E~'9~- 00' 00' NOILDZ~OD ZDNZ~Z~I~ H£dZ~ ~ZZ~S~ZN ~0 LZZ~ 000I NZAZ ~0~ SZ~A ~ZL~O~ZLNI NOIi~f~OqdXZ ~S 'i~ ES'9~ = 'AZqZ ONIHS~S 80~096-MM-M~ :EZ~BL~L~ ~0~ 966IE0 :XZA~S ~0 ZL~ 96/EI/£ :ZL~ NOII~LQdMOD HDQOHO~ Z60%S HLHON 008~gEE6E00~ IgE-DdM / LNIO~ ZN~I~ 'DNI (kQtSk~I~) NOILk~/O~dXZ d~ $~DIA~S DNI~IH~ N_qS-X~[ ~ r ZRRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE BP EXPLORATION (ALASKA) INC. MILNE POINT / MPC-28I 500292264800 NORTH SLOPE BOROUGH COMPUTATION DATE: 3/12/96 DATE OF SURVEY: 021996 JOB NUMBER: AK-MM-960208 KELLY BUSHING ELEV. = 46.52 FT. OPERATOR: BP EXPLORATION INTERPOLATED VALUES FOR EVEN 100 FEET OF SUB-SEA DEPTH TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH TOTAL RECTANGULAR COORDINATES NORTH/SOUTH EAST/WEST MD-TVD VERTICAL DIFFERENCE CORRECTION .00 .00 -46.52 46.52 46.52 .00 146.52 146.52 100.00 246.53 246.52 200.00 346.53 346.52 300.00 .00 N .00 E .00 .00 N .00 E .00 .00 .53 N .04 E .00 .00 1.48 N .18 E .01 .01 2.61 N .40 E .01 .01 446.54 446.52 400.00 546.55 546.52 500.00 646.56 646.52 600.00 746.58 746.52 700.00 846.60 846.52 800.00 3.82 N .65 E .02 .01 5.06 N .81 E .03 .01 6.69 N .59 E .04 .01 8.18 N .02 E .06 .01 9.64 N 1.50 W .08 .02 946.67 946.52 900.00 1046.95 1046.52 1000.00 1147.58 1146.52 1100.00 1248.52 1246.52 1200.00 1349.72 1346.52 1300.00 11.71 N 4.44 15.86 N 10.61 22.21 N 19.84 30.19 N 30.95 39.38 N 43.43 W .15 .07 W .43 .28 W 1.06 .63 W 2.00 .93 W 3.20 1.20 1451.41 1446.52 1400.00 1554.02 1546.52 1500.00 1657.59 1646.52 1600.00 1761.81 1746.52 1700.00 1867.33 1846.52 1800.00 50.28 N 58.24 63.76 N 76.82 79.67 N 98.55 97.01 N 122.21 116.94 N 149.32 W 4.89 1.69 W 7.50 2.61 W 11.07 3.57 W 15.29 4.22 W 20.81 5.52 1975.10 1946.52 1900.00 2085.43 2046.52 2000.00 2198.57 2146.52 2100.00 2314.52 2246.52 2200.00 2434.27 2346.52 2300.00 141.90 N 180.73 171.96 N 216.33 206.17 N 256.65 242.80 N 302.46 282.93 N 354.68 W 28.58 7.77 W 38.91 10.33 W 52.05 13.14 W 68.00 15.95 W 87.75 19.76 2556.83 2446.52 2400.00 2682.33 2546.52 2500.00 2809.04 2646.52 2600.00 2936.53 2746.52 2700.00 3068.80 2846.52 2800.00 325.93 N 411.00 371.37 N 471.67 419.83 N 532.56 469.00 N 594.49 522.56 N 662.49 W 110.31 22.56 W 135.81 25.50 W 162.52 26.71 W 190.01 27.49 W 222.28 32.27 3202.41 2946.52 2900.00 3334.09 3046.52 3000.00 3466.46 3146.52 3100.00 3599.31 3246.52 3200.00 3733.04 3346.52 3300.00 576.44 N 732.83 628.26 N 801.04 682.07 N 869.03 736.27 N 937.67 786.82 N 1010.65 W 255.89 33.61 W 287.57 31.68 W 319.94 32.36 W 352.79 32.85 W 386.52 33.73 L6'E L6'L9L M 69'698I N ~8'EE~I IS'019~ £0'LS95 00'SE~S I£'8E 00'S9£ M 0I'£98I N LS'LI~I 00'009~ ES'9~9~ ES'II~S 9S'85 69'9££ M 85'008I N 85'L95I 00'00S~ ES'9~S~ IE'585~ 55'£~ 5I'80£ M £9'£5£I N ~5'915I 00'00~ ES'95~ S9'~SIS 5~'95 I8'089 M 05'9£9I N 68'995I 00'005~ ES'9~55 55'£EOS I9'£~ £5'~S9 M 56'SI9I N 6~'8IEI 00'00E~ ES'9~E~ 68'006~ ~6'85 S£'959 M £~'5SSI N 99'89II 00'00I~ ES'9~I~ S6'£E IS'L6S M 58'06~I N 89'tIII 00'000~ ~S'950~ 55'~9~ SS'L~ £8'69S M EP'9E~I N 9S'0LOI 00'0065 ES'9P65 65'9ISP IS'6C I0'E~S M I~'I95I N ES'~0I 00'0085 ES'9~85 £S'8855 9~'I£ 0S'EIS M 0L'~6EI N 55'9L6 00'00£5 ~s'gPL5 E0'6SE~ 99'05 ~'I8~ M EI'SE~I N 9~'LE6 00'0095 5S'9~95 9L'LEIP 65'I5 LS'0S~ M ~'~SII N I6'I88 00'00S5 ES'9~S5 60'L665 99'~£ 8I'6I~ M 60'580I N 0£'S58 00'0055 ES'9~5 0L'S98£ NOI~DZE~OD ZDNZ~Z~ZI~ ~DIL~ZA CIAI-QN · S~M/~S~ HI~OS/H~ON SZI~NIQ~OOD %5f~N%fID~ ~Oi HLdZ~ ~ZS-E~S ~O LZZ~ OOI NZAZ ~O~ SZ~A ~ZL~Od~ZLNI NOIL¥~O~dXZ dE E~'9~ = 'AZqZ ©NIHS~E 80~096-MM-M~ :~ZE~AqI~I ~OD 966IE0 :XZA%IflS ~O ZL~ 96/~I/5 :Zing NOIL~L~dNOD H©~O~OE ZdO~S HL~ON 008~9~6500~ I8~-D~N / LNIO~ ZNqIN 'DNI (~S~) NOIL~O~aXZ dE ~S%f~I~ ZO¥~OHDN~ S~DIA~S ~NI~I~ Ni1S-X~Z 6~'9~£ NS£'~S~ ~£'90~ ST'~ 0~'~0£ NSC'~C~ ~9~'T6T 8C'6L~ ~LL'gT~ ~s'gLT ~8'T LI'LSE MS8'66I ~60'E9I 6L'C EO'9CE MAS'ESI ~SS'8~I C9'0S SO'OS SE'6~ L£'6~ fiT'TOTE L6'L~IE 00'00CE ~S'LSOE 90'~0IE 00'0SIC LT'£IOE 69'6§0E O0'OOIE 0~'896T E6'~IOE O0'OSO~ TI'CE6T C9'696T 00'000E SI'9IE MET'89I NC0'9CI CS'E ~C'L6I MTn'CST NIC'~EI IE'~ SS'6LI MCS'6CI N89'CII 08'C9I MC9'9EI NOI'90I 06'8~I ML9'~II ~IE'S6 M LT'IS N C~ EE M 69'TS N 8E IE M OS'CS N 8E 6T M 6E'CS N 0 8I M 8~'CS N 0~ 9I 5E'LLSI 9L'CE6I O0'OS6I E6'OCSI ~'ttSI 00'006I 80'~8LI 09'0C8I O0'OSSI ~L'9CLI 9E'CSLI 00'008I I0'689I CS'SCLI 00'0SLI E0'SCI CI'80I 6E'S6 SS'C8 9I' Ct M6S'COI NL8'98 0I' MSE'E8 N6~'0£ ME0'EL NS£'E9 90'E ME9'E9 NTt'SS 0C'~ MIC'~S NL~'6~ M SS'ES N CC SI M C~'ES N 8C ST M SC'CS N 9 ~T M 80'CS N ~ CT M TO'CS N SS 0T 86'0~9I OS'L89I O0'OOtT 99'~ST 8I'I6SI 00'009I ~C'96~I 98'E~SI 00'0SSI ~t't~I 9E'~6~I 00'00SI S8'86CI LC'S~I 00'0S~I S6'C9 OS'SS 9£'L~ 6C'0~ T~'CC M96'9~ NC6'C~ MEE'0~ N~8'8C MC0'~C N8T'~C C8' MEI'8E NLL'6E 96' MOS'EE NC9'SE 89'I M ~0'CS N 8I 0T M S8'ES N 8 6 M 80'CS N 0~ 8 M 6S'CS N 9T 8 M E9'CS N t~ t 0L'6~CI EE'96CI 00'00~I E~'00CT ~6'9~CI 00'0SCI C0'ISEI SS'L6ET 00'00CT LS'TOET 60'8~ET 90'ESIT 8S'86TI 00'00ET 66'9E CE'IE CE'9T 60'ET 86'8 MCC'LI NCS'TE 5C'I M99'EI N9~'ST 6I'E MSS'8 N09'ST 9t'I M~I'S NSC'CT ~0'C ME9'E NE~'II S£'I M 08'5S N 9S 9 M L9'~S N LT 9 M 89'SS N IT S M 80'SS N 6T ~ M SC'ES N 8~ E 8~'EOTT 00'6~TI 00'0SIT T8'ESOI CC'660I 00'00TI £0'C00I 6S'650I 00'0SOI ~E'£S6 9L'666 00'000I ~C'C06 98'6~6 00'0S6 06'9 8£'I tI'T MC0'T NL0'0I 88' Z6L' N90'8 CS' ZOS'I N8~'9 SE' Z~S'I N86'~ 9I' Z6E'I N~9'C ti' M 08'S~ N 8S T M ~6'S£ N 8 T M 0E'6 N ~S 0 Z ~6'9 N OS 0 Z 6L'9I N C~ 0 6E'CS8 T6'668 00'006 C~'CS£ S6'66£ 00'008 ~'CS9 96'669 00'00£ S~'ESS £6'66S 00'009 9~'CS~ 86'66~ O0'OOS 9L' 5~' 0I' SO'- 00' Z66' NLS'E 90' ZEL' NOL'I ET' ZSS' N~6' 6E' ZSE' N6E' 9~' ZOO' MOO' 00' ,q S8'9I N CC 0 .q ~T'9I N 6E 0 ,w L9'5 N t~E 0 ,q 69'55 N LE 0 ,~ 00' N 0 0 L~'CSC 66'66C 00'00~ L~'CSE 66'66E 00'00E 85'CSI 00'00E 00'00E 8~'CS 00'00I 00'00l ES'9~- 00' 00' 'LDZS '&~ZA ISZM/LSVZ HLnOS/H£HON 00I/O~ SZZHDZG q~iO~ S~ ZSH~OD S~OD NO · ,T,.,:[ 80 = 'AZ%Z DNIHS~ E096-NN-M~ :~ZEKIflN ~OD XZA~nS QMN 9680~0 :XZA~S ~0 ZL~ '-- , _ SZDIA~ZS ~NIqqIZ~ 96/EI/~ :ZL~ NOIL~L~ANOD H©~OHOE ZdOqS HLEON 008~9EE6E00S (lf~S~) NOILIf~O~AXZ d~ I ZD~d ~ RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 2 BP EXPLORATION (ALASKA) INC MILNE POINT / MPC-28i 500292264800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/12/96 DATE OF SURVEY: 040896 MWD SURVEY JOB NUMBER: AK-MM-960208 KELLY BUSHING ELEV. = 46.52 FT. OPERATOR: BP EXPLORATION TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 2250.00 2191.40 2144.88 30 19 2300.00 2234.36 2187.84 31 10 2350.00 2276.77 2230.25 32 47 2400.00 2318.54 2272.02 33 52 2450.00 2359.75 2313.23 35 5 N 51.42 W 2.58 222.30N 272.02W N 51.44 W 1.72 238.24N 292.00W N 51.97 W 3.29 254.65N 312.79W N 52.33 W 2.20 271.51N 334.49W N 52.74 W 2.48 288.73N 356.96W 351.05 376.60 403.08 430.56 458.87 2500.00 2400.61 2354.09 35 17 2550.00 2441.30 2394.78 35 44 2600.00 2481.70 2435.18 36 27 2700.00 2561.29 2514.77 38 4 2750.00 2600.68 2554.16 37 56 N 52.63 W .40 306.20N 379.88W N 52.95 W .97 323.76N 403.02W N 52.91 W 1.42 341.52N 426.52W N 51.84 W 1.74 378.48N 474.46W N 51.83 W .26 397.51N 498.66W 487.69 516.73 546.19 606.72 637.50 2800.00 2640.18 2593.66 37 43 2900.00 2718.87 2672.35 38 28 3000.00 2795.79 2749.27 40 56 3100.00 2870.90 2824.38 41 40 3200.00 2945.79 2899.27 41 19 N 52.05 W .52 416.41N 522.81W N 52.62 W .83 454.11N 571.65W N 52.82 W 2.47 492.79N 622.47W N 52.80 W .74 532.69N 675.05W N 54.08 W .92 572.17N 728.28W 668.17 729.86 793.73 859.74 926.00 3300.00 3021.47 2974.95 40 17 3400.00 3097.20 3050.68 41 14 3500.00 3172.54 3126.02 41 0 3600.00 3247.64 3201.12 41 37 3700.00 3322.30 3275.78 41 46 N 53.53 W 1.09 610.76N 781.03W N 52.90 W 1.03 649.86N 833.32W N 52.82 W .25 689.57N 885.74W N 54.02 W 1.01 728.91N 938.76W N 57.25 W 2.15 766.44N 993.66W 991.35 1056.65 1122.41 1188.42 1254.85 3800.00 3397.19 3350.67 41 14 3900.00 3472.81 3426.29 40 28 4000.00 3549.14 3502.62 40 0 4100.00 3625.77 3579.25 39 57 4200.00 3702.09 3655.57 40 33 N 57.18 W .54 802.33N 1049.37W N 57.13 W .76 837.81N 1104.34W N 57.09 W .47 872.89N 1158.59W N 56.97 W .10 907.86N 1212.49W N 54.24 W 1.87 944.36N 1265.79W 1320.94 1386.18 1450.61 1514.69 1579.22 4300.00 3778.59 3732.07 39 37 4400.00 3856.00 3809.48 38 55 4500.00 3934.07 3887.55 38 26 4600.00 4012.44 3965.92 38 20 4700.00 4090.43 4043.91 39 8 N 54.02 W .95 982.09N 1317.97W N 54.26 W .72 1019.17N 1369.27W N 53.91 W .53 1055.83N 1419.89W N 53.49 W .28 1092.60N 1469.94W N 51.04 W 1.72 1130.90N 1519.42W 1643.60 1706.88 1769.37 1831.47 1894.03 4800.00 4168.22 4121.70 38 43 4900.00 4246.53 4200.01 38 10 5000.00 4325.45 4278.93 37 35 5100.00 4404.35 4357.83 38 13 5200.00 4482.57 4436.05 38 50 N 49.97 W .79 1170.87N 1567.91W N 49.84 W .56 1210.92N 1615.49W N 50.47 W .71 1250.27N 1662.63W N 50.94 W .70 1289.18N 1710.18W N 50.50 W .67 1328.62N 1758.40W 1956.82 2018.92 2080.26 2141.66 2203.91 ]RRY-SUN DRILLING SERVICES ANCHORAGE ALASKA PAGE 3 BP EXPLORATION (ALASKA) INC MILNE POINT / MPC-28i 500292264800 NORTH SLOPE BOROUGH COMPUTATION DATE: 4/12/96 DATE OF SURVEY: 040896 MWD SURVEY JOB NUMBER: AK-MM-960208 KELLY BUSHING ELEV. = 46.52 OPERATOR: BP EXPLORATION FT. TRUE SUB-SEA MEASD VERTICAL VERTICAL DEPTH DEPTH DEPTH COURS INCLN DG MN COURSE DLS TOTAL DIRECTION RECTANGULAR COORDINATES DEGREES DG/100 NORTH/SOUTH EAST/WEST VERT. SECT. 5300.00 4560.44 4513.92 38 52 5331.19 4584.74 4538.22 38 46 5482.01 4702.41 4655.89 38 40 5575.26 4774.99 4728.47 39 7 5667.39 4845.84 4799.32 40 20 N 50.38 W .08 1368.57N 1806.77W N 51.36 W 2.00 1380.91N 1821.94W N 52.93 W .65 1438.80N 1896.42W N 53.26 W .53 1473.96N 1943.24W N 52.74 W 1.37 1509.40N 1990.26W 2266.59 2286.12 2380.45 2439.00 2497.88 5761.52 4917.59 4871.07 40 20 5856.01 4989.31 4942.79 40 54 5951.15 5061.04 5014.52 41 13 6045.02 5131.64 5085.12 41 13 6140.40 5203.27 5156.75 41 25 N 52.53 W .14 1546.38N 2038.69W N 52.08 W .67 1583.99N 2087.36W N 53.12 W .80 1621.95N 2137.01W N 54.15 W .72 1658.63N 2186.83W N 54.17 W .20 1695.51N 2237.89W 2558.81 2620.32 2682.82 2744.68 2807.65 6234.87 5274.06 5227.54 41 30 6328.24 5343.99 5297.47 41 30 6423.68 5415.31 5368.79 41 46 6520.67 5487.56 5441.04 41 55 6614.79 5557.55 5511.03 41 58 N 55.28 W .78 1731.63N 2288.95W N 55.29 W .00 1766.87N 2339.81W N 55.93 W .52 1802.68N 2392.14W N 55.86 W .17 1838.97N 2445.72W N 52.99 W 2.04 1875.56N 2496.88W 2870.16 2931.98 2995.33 3059.95 3122.83 6708.68 5627.15 5580.63 42 20 6802.51 5696.56 5650.04 42 15 6897.99 5767.93 5721.41 40 59 6992.76 5840.24 5793.72 39 32 7088.32 5914.70 5868.18 38 4 N 53.61 W .59 1913.22N 2547.41W N 53.76 W .14 1950.62N 2598.29W N 53.87 W 1.32 1988.06N 2649.47W N 54.04 W 1.53 2024.10N 2698.99W N 53.12 W 1.64 2059.65N 2747.18W 3185.84 3248.98 3312.39 3373.62 3433.50 7182.05 5989.13 5942.61 7276.51 6065.51 6018.99 7375.24 6146.97 6100.45 7470.81 6228.10 6181.58 7565.30 6310.71 6264.19 36 46 35 17 33 28 30 19 27 45 N 53.08 W 1.40 2093.84N 2792.73W N 51.88 W 1.73 2127.67N 2836.81W N 51.37 W 1.87 2162.28N 2880.52W N 53.36 W 3.48 2193.15N 2920.48W N 56.16 W 3.07 2219.64N 2957.90W 3490.46 3546.02 3601.76 3652.25 3698.08 7659.48 6395.12 6348.60 24 51 7753.25 6480.21 6433.69 24 50 7846.33 6564.62 6518.10 25 1 7942.27 6651.55 6605.03 25 2 8036.22 6736.77 6690.25 24 45 N 56.88 W 3.10 2242.68N 2992.71W N 56.84 W .03 2264.22N 3025.71W N 56.54 W .24 2285.76N 3058.49W N 56.33 W .09 2308.21N 3092.32W N 56.16 W .32 2330.18N 3125.20W 3739.74 3779.05 3818.20 3858.71 3898.19 8131.48 6823.40 6776.88 24 23 8226.17 6909.74 6863.22 24 4 8320.20 6995.54 6949.02 24 13 8415.28 7082.18 7035.66 24 23 8509.41 7168.03 7121.51 24 1 N 55.50 W .47 2352.43N 3157.98W N 54.54 W .54 2374.72N 3189.83W N 54.32 W .19 2397.10N 3221.13W N 54.02 W .22 2420.02N 3252.87W N 53.39 W .48 2442.87N 3283.99W 3937.76 3976.61 4015.07 4054.21 4092.81 ,0gL8 - ,6I'I££~ NO~ X~A~DS ~MN S~SS '©ZG 0I'£0£ ~NO~ GZLQdMOD NOILDZS ~DIL~ZA (ItfZH ~ZM Oi ZAIL~Z~ NOILDZS ~DIL~ZA 0EL8 = QM i~ LSZM 'NIM I~ 'DZ~ £~ HLEON i~ LZZ~ ~0'8LI~ = LNZMZDV~SIQ ~LNOZI~OH '~OHLZM ZE~L~AE~D Wi1MINIM NOISNZMI~-ZZZHL ~O ZS~ ZHI NO ~ZS~S Z%Ilf SZ~ZDO~d NOIL~D~D ZHI 06'ttI~ ML9'E~££ NII'£6~E 00' L0'S£I~ M£0'8IC£ N06'L9~[ ££' M fi6'£fi N 9~ £E 5I'~I££ 99'09££ 00'0~£8 M fi6'£fi N 9~ £E £8'9IE£ 6£'£95£ E£'£I98 'LDZS LSZM/£S~Z HL~OS/HLEON 00I/©~ SZZ~OZ~ NM ~ HLdZ~ HLdZ~ HLdZ~ 'L~ZA SZI~NI~OOD R~f~©NtfLDZ~ NOIIDZ~I~ N~DNI ~DIL~ZA ~DIL~ZA ~S~ZM ~LOL S~G ZS~OD S~OD ~ZS-~S Z~L 'i~ E~'95 = 'AH~H DNIHS~ LEAEnS ~MN 96/EI/~ :ZL~ NOIL~LQdNOD H~O~O~ ZdO~S Hi'ON 008~9EE6~00~ TS~-D~N / £NIOd ZN~IN DNI (~tS~) NOILtfIIO~dXZ d~ SHDIAEZS DNI~IHG NflS-XH~ ~ 'GOHIZN Z~flI~A~flO PlflNINI~ NOISN~NI~-~HHI E'E9 ~£'6S£T M L9'ESEE N II'E6~E ~I'~IEL 99'09EL 00'0E£8 6'I~I EI'96EI M 09'EIIE N ~L'IEEE SE'LS99 L8'E0£9 00'0008 6'ISE 8I'~SII M EL'E0£E N 08'9EOE 0E'66£S E8'S~8S 00'000L 9'£EE EE'E06 M 8L'E9IE N SE'I~9T 9E'IS0~ 8£'L60S 00'0009 9'CEE SS'~L9 M E9'E99I N LE'0SEI £6'8£E5 S~'SEE~ 00'000S 9'9~E 98'0~ M 6S'SSII N 68'EL8 E9'E0~£ 5I'6~E 00'0005 8'ELI IE'~0E M L~'EE9 N 6L'E6~ LE'6~LE 6L'S6LE 00'000£ I'0E £C'0E M Ls'EgT N SS'8~I TI'EE6I E9'696T 00'000g E' YE' M ~T'S N SE'ET ~E'ES6 9£'666 00'000T 00' ~ 00' N 00' ES'9~- 00' 00' NOIIDZ~OD ZDHZ~Z~I~ q~DI£EZA ~DIL~ZA ~DIL~ZA JS~ZM HLdZ~ ~Z~S~ZM gO IZZ~ 000I NZAZ ~OZ SZ~A ~ZL~5Od~ZLNI ES'9~ = 'AZ~Z DNIHS~ 968050 :XZA~DS gO ZL~ 96/~I/5 :ZLVG NOIL~LQdMOD 0MI (~C~S~) NOIL~fMO~dXZ ~C~S~ Z~tOHDN%f SZDIAE~S ~NI~I~ NIIS-X~, 3 gyro/data C PAD, WELL NO. MPC-28 MILNE POINT FIELD, ALASKA Gyro Multishot Survey Of 9.625" Casing Survey date · 05 APRIL 1996 Job number · AK0496G336 RECEIVED NOV 2 6 1995 Alaska Oil & Gas Cons. Commission Anchorage SR336.DOC Gyrodata Incorporated P.O. Box 79389 Houston, Texas 77279 713/461-3146 Fax: 713/461-0920 April 11, 1996 B.P. Exploration Petrotechnical Data Center, MB 3-3 P.O. Box 196612 Anchorage, AK 99519-6612 Re; C-PAD, WELL #MPC-28, MILNE POINT FIELD, AK Enclosed please find one (1) original, six (6) copies and one (1) disk of the completed survey of Well#MPC-28 We would like to take this opportunity to thank you for using Gyrodata and we look forward to serving you in the future. Sincerely, Robert J. Shoup Operations Manager RS/fec Serving the Worldwide Energy Industry with Precision Survey Instrumentation gyro/data' CONTENTS JOB NUMBER :AK0496G336 1. DISCUSSION, SURVEY CERTIFICATION SHEET 2. SURVEY DETAILS 3. OUTRUN SURVEY LISTING 4. QUALITY CONTROL 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR336.DOC ~ldata 1. DISCUSSION , SURVEY CERTIFICATION SHEET SR336.DOC gyro/data DISCUSSION JOB NUMBER- AK0496G336 Tool 705 was run in MPC-28 on ATLAS 5/16" Wireline inside casing. Misrun on continuous survey. Changed out electronics. The survey was run without problems. SR336.DOC ,gyro/data SURVEY CERTIFICATION SHEET JOB NUMBER: AK0496G336 The data for this survey and the calculations for this survey were obtained and performed by me according to standards and procedures as set forth by Gyrodata Limited, true and correct to the best of my knowledge. TOM STODDARD OPERATIONS ENGINEER The data and calculations for this survey have been checked by me and conform to the standards and procedures as set forth by Gyrodata Limited. This report represents a directional survey of this well based on the original data obtained at the wellsite. Checked by :- ROB SHOUP OPERATIONS MANAGER SR336.DOC gym/data 2. SURVEY DETAILS SR336.DOC gyro/data SURVEY DETAILS JOB NUMBER: AK0496G336 CLIENT: B.P. EXPLORATION RIG: C-PAD LOCATION: MILNE POINT FIELD WELL: MPC-281 LATITUDE: 70.45000 N LONGITUDE: 149W SURVEY DATE: 05 APRIL 1996 SURVEY TYPE : MULTISHOT IN 9.625" CASING DEPTH REFERENCE: MAX. SURVEY DEPTH: ROTARY TABLE ELEVATION 46.0 5300 SURVEY TIED ONTO: NA SURVEY INTERVAL: 100' From 0 feet to 900 feet, 50' From 900 feet to 2800 feet, 100' From 2800 feet to 5300 feet UTM CO-ORDINATES: TARGET DIRECTION: 307.1 GRID CORRECTION: N/A CALCULATION METHOD: MINIMUM CURVATURE SURVEYOR: TOM STODDARD SR336.DOC gyro/data 3. 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If N I ~ ~ 0 0 D 'q~ 00I '6ap ~aa~ /'6~p HL~MIZIf 'LSI'G XLIHZAZS Z~SOqD ©Z~DO~ HLdZ~ NOILDZS qaaj '6ap '6ap HLdZ~ 95E©96b0~if :~aqmnN qo~ SE9'6 'ISE-DdM :qqZM NOI~k~6OqdXZ 'd'~ A Gyrodat a D i re c t iona i Survey B.P. EXPLORATION WELL: MPC-28I, 9.625 Location: C PAD, MILNE POINT FIELD, Job Number: AK0496G336 ALASKA Page MEASURED I N C L AZIMUTH VERTICAL DEPTH DEPTH feet deg. deg. feet VERTICAL SECTION. feet SUBSEA DEPTH feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. HORIZONTAL .C O 0 R D INA T E S feet 2900.0 38.47 307.38 2718.9 3000.0 40.94 307.18 2795.9 3100.0 41.68 307.20 2871.0 3200.0 41.33 305.92 2945.9 3300.0 40.30 306.47 3021.6 729.9 793.8 859.8 926.0 991.4 2672.9 2749.9 2825.0 2899.9 2975.6 .83 730.1 308.5 2.47 794.0 308.4 .74 860.0 308.3 .92 926.2 308.2 1.09 991.5 308.0 454.12 N 571.67 W 492.81 N 622.50 W 532.71 N 675.09 W 572.19 N 728.32 W 610.78 N 781.06 W 3400.0 41.24 307.10 3097.3 3500.0 41.00 307.18 3172.6 3600.0 41.63 305.98 3247.7 3700.0 41.78 302.75 3322.4 3800.0 41.24 302.82 3397.3 1056.7 1122.4 1188.5 1254.9 1321.0 3051.3 3126.6 3201.7 3276.4 3351.3 1.02 1056.8 307.9 .24 1122.6 307.9 1.01 1188.6 307.8 2.15 1255.0 307.6 .55 1321.0 307.4 649.88 N 689.59 N 728.93 N 766.47 N 802.36 N 833.35 W 885.78 W 938.80 W 993.70 W 1049.42 W 3900.0 40.48 302.87 3472.9 4000.0 40.01 302.91 3549.2 4100.0 39.95 303.03 3625.9 4200.0 40.56 305.76 3702.2 4300.0 39.62 305.98 3778.7 1386.2 1450.7 1514.8 1579.3 1643.7 3426.9 3503.2 3579.9 3656.2 3732.7 .76 1386.2 307.2 .47 1450.7 307.0 .10 1514.8 306.8 1.86 1579.3 306.7 .95 1643.7 306.7 837.84 N 872.92 N 907.89 N 944.40 N 982.13 N 1104.38 W 1158.63 W 1212.54 W 1265.85 W 1318.04 W 4400.0 38.92 305.74 3856.1 4500.0 38.44 306.09 3934.2 4600.0 38.35 306.51 4012.5 4700.0 39.14 308.96 4090.5 4800.0 38.73 310.03 4168.3 1707.0 1769.4 1831.5 1894.1 1956.9 3810.1 3888.2 3966.5 4044.5 4122.3 .72 1707.0 306.7 .52 1769.5 306.6 .28 1831.6 306.6 1.72 1894.2 306.7 .78 1956.9 306.8 1019.21 N 1055.87 N 1092.64 N 1130.94 N 1170.90 N 1369.34 W 1419.95 W 1470.01 W 1519.49 W 1567.98 W 4900.0 38.18 310.16 4246.6 5000.0 37.59 309.53 4325.6 5100.0 38.23 309.06 4404.5 5200.0 38.84 309.50 4482.7 5300.0 38.87 309.62 4560.6 2019.0 2080.3 2141.7 2204.0 2266.7 4200.6 4279.6 4358.5 4436.7 4514.6 .56 2019.0 306.9 .70 2080.3 306.9 .70 2141.7 307.0 .68 2204.0 307.1 .08 2266.7 307.1 1210.96 N 1250.30 N 1289.21 N 1328.65 N 1368.60 N 1615.56 W 1662.71 W 1710.25 W 1758.47 W 1806.84 W A Gyrodat a Di re c t i ona i Survey B.P. EXPLORATION WELL: MPC-28I, 9.625 Location: C PAD, MILNE POINT FIELD, ALASKA Job Number: AK0496G336 Page MEASURED I N C L AZIMUTH VERTICAL VERTICAL SUBSEA DEPTH DEPTH SECTION DEPTH feet deg. deg. feet feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg. / feet deg. 100 ft. HORIZONTAL COORDINATES feet Final Station Closure: Distance: 2266.66 ft Az: 307.14 deg. A Gyr~odat a Dire ct ional Survey for B.P. EXPLORATION WELL: MPC-28I, 9.625 Location: C PAD, MILNE POINT FIELD, ALASKA Job Number: AK0496G336SS Run Date: 5-Apr-96 02:30:00 Surveyor: STODDARD Calculation Method: MINIMUM CURVATURE Survey Latitude: 70.450000 deg. N Sub-sea Correction from Vertical Reference: 46 ft. Azimuth Correction: Gyro: Bearings are Relative to True North Proposed Well Direction: 307.100 deg Vertical Section Calculated from Well Head Location Closure Calculated from Well Head Location Horizontal Coordinates Calculated from Local Horizontal Reference ~ T9'CJLI ~ ~ 60'~T ~ LT'£TT ~ OC'/.TT ~ 9T'/.6 ~ 6C'~6 ~ I8'6/. ~ 89'~/. ~ SC'E9 N [~'~S ~ SS'6~ ~ 60'0~ ~ ~ 88'/.[ ~ 09'6~ M S0'/.T ~ C9'TE 0E'8 lXI PP' CJI 0S ' E NEC ' TI 06' N 66'8 LI'I N ECJ'I N t9'cj ,~ 0P'T III ,~ ET'T lq Z CJC' lXI TI'E Z CJ9' N 6E'T Z gP' N 6CJ' I'60E 9'6/.E 0'60E ~'9C~ I'60C S't6I 9'60E 6'£9I E'0IC E'CJET O'TIE E'80T C'EIE 8'E8 O'PIE 6'CJCJ /.'9lC O'TP 8'TEE 6'LC 8'ICC 8'/. 9'LPC L'T C' I'O 9'6 T'8 C'CJT L'9 P'8I E'CJ E'OE 6'E 6'LC 6'I 89'~ 95'5 6C'E CI'E 9E'I 86' 6E'I 98'T t9'T 69' gE' 0[' LT' 60' CE' 9'ELE 0'9POI 6CJ'OIE 09'9~ 0'000~ 8'CJEE 0'9P6I 00'60C EP'£E O'O06T 9'S8I 0'9P8I 60'/.0£ CI'0E 0'008I E'EST 0'9PAT 95'90E L6'9I 0'00/.I P'CET 0'9P9T 0CJ'/.0E 09'ST 0'009I T'96 0'9PCJT TL'90C 0E'PT 0'00CJI £'CL 0'9PPI 66'90E CJ6'0T 0'00PI P'CJCJ 0'9PET CJI'/.0E PI'6 0'00ET T'0P 0'9PET TP'90C CJE'8 0'00ET 9'95 0'9PTI PT'90E I6'9 0'00TI 6'CJI 0'9POT LC'POE PT'CJ O'O00I 8'8 0'9P6 ET'80C P/.'E 0'006 S'S 0'9P8 ECJ'6TC CS'T 0'008 P'E 0'9PL 6P'SEE TO'T O'OOL g'~ 0'9P9 TCJ'6CJC LC' 0'009 P'T 0'9PS ST'TI 8/.' O'OOS O'T 0'9PP 06'ST E9' O'OOP 9' 0'9PC LP'9T ES' O'OOE C' 0'9PC S6'6 ST' 0'00E O' 0'9PT PL'S~ PT' O'OOI DNISIfD ,,CJE9'6 ~ISNI NDE XZAE~S OEXD 'i~ 00ECJ - 0 ~ 00'0 N 00'0 0'0 0'0 ;aag 'Dap ;aa~ q If i N 0 Z I H 0 H MM~SO~D 00'0 0'0 0'0 00'0 00'0 0'9P- '2~ 00T XIIHZAZS MOIID~S Hid~G SS9EED96P0MIf :zaqmnM qo£ '~ZI~ iMIOd ZMqIM '~ifd D :UOTqeOo~ CJEg'6 'ICE-DdM :~qZM MOILk~60~dXZ 'd'~ z[ ~ A ~1 n S I ~uo T q m~:~ T ~ e qepoz~XD tf M 08'/.6/.I kC ET'I9CT M 98'SC/.I N ST'0T£I M E0'S/.9T N 8C'09~I M tI'SISI N CS'0IEI I'/.0C L'99EE 0'L0£ 0'TOEE 0'LOC L'ITIE 6'905 0'6IOE L'90C 6'9S6I 6I' 69' 0L' SO 'I E'960E S'8IOE 6'8E6I 09'60£ 98'8C O'OOST 6~'605 SS'8C IT'60£ St'LC O'O0£T 9I'0I£ 8I'8£ 0'00ET ~/.'605 S8'85 0'00IT M TE'T6TI N L0'60II M TS'/.ETT N ET'T90T M T9'E9CI N L£'TTOT M TL'S6ET N T0'996 M 09'9EEI N ES'tI6 9'90£ E'T68I 9'90C 9'ICSI /.'90C 0'/.0ti /.'90C /.'CT9I 8'90C C'6/.SI 06' T'8S8I 8'8L/.I /.'869I E'9T9I 8'T£ST 0'9TOT 9S'LOC 69'8C 0'000T 0'9T6C SI'90£ 5T'8£ 0'006C 0'9T8C LL'SOC I0'6C 0'008C 0'ST/.C 88'SOC E0'0T 0'00/.C 0'STSC SL'COC II'0T 0'009C M CC'9SII N CT'IL8 M CS'TSOI N IE'SE8 M 9E'IIOI N 8L'LLL M tS'LC6 N 50'SEL M SE'L98 N SS'SA9 0'LOC L'0~TI C't0C E'98CI 9'LOC 0'IECI 8't0C 9'88II 6'£0C 9'EEII 89' T9'I 66' ES' 0'£9CI L'SLEI 6'98II E'660I 0'9TSC I6'EOC CO'OT O'OOSC 0'9TIC SS'EOC SL'OT O'OOTC 0'9TEE LL'EOC I9'IT O'OOCC 0'9T~C 00'90C E9'IT 0'00CC 0'9TIC ST'/.0C 60'IT 0'00IC M C6'L6L N M II'SEA N SE'ELS M 09'AS9 N M SS'68S N CL'L9T M 0T'9ES N 8I'6IT 0'80C 8'990I E'80C S'I66 C'80C 0'098 T'80C O'T6L S'80E I'OCL LO 'T TT'T 8' L' EIOI 956 LC8 EL9 0'9TOC 89'905 09'OT O'O00C 0'9T6E ~6'SOC CC'IT 0'0065 0'9TSE 6I'LOC TT'I~ 0'008[ 0'9TL5 IC'LOC TC'6C O'OOLE 0'9T9E I6'LOC LL'LC 0'009~ M Et'SOT N IS'SEC M C6'ISE N C0'90E 9'80C O't09 8'80C T'9TS 0'605 T'6ST E'60C T'COT C'60C S'9EC 89'I C0'I 9I'E I'S6S I'OES 6'C8C 0'9TSE S6'LOC 9L'/.C O'OOS5 0'9TIE 90'LOC ES'SC 0'9ICE OT'LOC 69'TC O'OOCE 0'9TEE ET'80C E9'IC 0'00CE 0'9TIE 6C'60C T0'6E 0'00I[ S ,~ ,l, ~f N I ~ H 0 0 D ~I ~f ,l, N 0 Z I H 0 H HIflNIZ~ 'ISIG ZH~SO~D '~ 00I XLI~ZAZS NOILDZS HL6Z~ HLdZ~ DZ~DO~ ~DIL~ZA ~DIL~ZA HLDMIZ~ ~ D N I ~ZS~/1S SS95C©96T0~ :~aqmnN qop 'G~ZI~ LNIOd ZN%IM 'CYgd D :uoy~mooq SE9'6 'ISE-DdM :q%ZM NOIL~O~dXZ 'd'~ A a ~ ~[ n S I e u o ~. ~ o a ~ ~. G e j P p o ~ A ~ ~f A Gyrodat a D i re c t iona i Survey B.P. EXPLORATION WELL: MPC-28I, 9.625 Location: C PAD, MILNE POINT FIELD, ALASKA Job Number: AK0496G336SS Page SUBSEA I N C L AZIMUTH VERTICAL VERTICAL DEPTH DEPTH SECTION feet deg. deg. feet feet DOGLEG CLOSURE SEVERITY DIST. AZIMUTH deg./ feet deg. 100 ft. HORIZONTAL C 0 0 R D I N A T E S feet 4514.6 38.87 309.62 4560.6 2266.7 .08 2266.7 307.1 1368.60 N. 1806.84 W Final Station Closure: Distance: 2266.66 ft Az: 307.14 deg. gyro/data 4. QUALITY CONTROL SR336.DOC III ' - £9I ' 9£0 ' 680 ' E9'60£ I6'E0£ 8I'£0£ E6'~0£ z~ I~'60£ I00' £8'8£ L8'8£ 0'00£9 L0'£0£ 9~I' I0'0~ AI'0~ 0'000~ EE'L0£ 0~I' 00'I~ SI'I~ 0'00S£ 00'S0£ OSO' ~£'~ L£'~ O'O00T z~ ~Ia~ Dui OuI q~da~ NI/~NI Ni1EiQO UOSTx~dmoD N//EiQO/hLQHNI 9 ££096 TzOX~Z / 9££D96~OX~ : xaqmn~ 'GqEI~ INIOd ~NqIN '~ D SE9"6 'ISE-DdN :~q~M suosTxPdmoD IOX;UOD X;TIPnO .gyroldata .QUALITY CONTROL REPORT JOB NUMBER: AK0496G336 TOOL NUMBER: 7O5 MAXIMUM GYRO TEMPERATURE: 79.94 C MAXIMUM AMBIENT TEMPERATURE: 28.3 C MAXIMUM INCLINATION: 41.68 AVERAGE AZIMUTH: 307.14 WIRELINE REZERO VALUE: 0.0 REZERO ERROR / K: CALIBRATION USED FOR FIELD SURVEY: 1426 CALIBRATION USED FOR FINAL SURVEY: 1426 PRE JOB MASS BALANCE OFFSET CHECK: -.4 POST JOB MASS BALANCE OFFSET CHECKt : CONDITION OF SHOCK WATCHES -.48 USED -.44 UPON ARRIVAL AT RIG: OK UPON COMPLETION OF SURVEY: OK UPON RETURN TO ATLAS OK BOTTOM LINE COMPARISIONS M.D. INC AZIMUTH TVD NORTHING EASTING FIELD SURVEY 5300 38.87 309.62 4560.60 1368.6 N 1806.8 W FINAL SURVEY 5300 38.87 309.62 4560.60 1368.6 N 1806.84W SR336.DOC gyro/data SR336.DOC gyro/data FUNCTION TEST JOB NUMBER: AK0496G336 5 Survey stations were collected at the measured depth shown below. The tables show the repeatability of the gyro tool in both inclination and azimuth at one measured depth. INCLINATION M.D. ft 1 2 3 4 5 5323 39.01 39.01 39.01 39.01 39.01 AZIMUTH M.D. ft 1 2 3 4 5 5323 309.05 309.01 309.12 309.06 309.17 SR336.DOC gyro/data' 5. EQUIPMENT AND CHRONOLOGICAL REPORT SR336.DOC gyro/data EQUIPMENT REPORT JOB NUMBER: AK0496G336 DOWNHOLE ELECTRONICS SURFACE ELECTRONICS PRIMARY TOOL No. 705 GYRO SECTION A0082 DATA SECTION C0031 POWER SECTION C0046 COMPUTER POWER SUPPLY PRINTER INTERFACE A0222 A0085 A0079 A0074 BACKUP TOOL No. 746 GYRO SECTION A0119 DATA SECTION C0063 POWER SECTION C0059 COMPUTER POWER SUPPLY PRINTER INTERFACE A0246 A0107 A0029 A0071 WIRELINE COMPANY: ATLAS WIRELINE CABLE SIZE: 5/16" RUNNING GEAR 2 1/2" SYSTEM TOTAL LENGTH OF TOOL: 32.0 feet MAXIMUM O.D.: 3.6 INCHES TOTAL WEIGHT OF TOOL: 270Lbs SR336.DOC OOQ'9g~IS EtDV~OHONV O£ X'Id 'S£~Ifl$SPcI (IE[IN'dIdNOD "IOOJ. 7>ID 'SWI£V OJ. NJ2d 'X~tA~Ifl$ $S~tDO~I4 'SV'IJ.V ~ '~IOOJ. Q~i &riO SSVdJaIO30~9 Hr'd 'SV'-liV Flkl 'rlOO£ fllA[ 'NflklSlIA[ 'SV'-i£V (I'8 "-IOO£ GrI NfI~INI SflOflNI£NOO (IN~t ,00Eg X~tA~tflS Nfl~ SVrI£V flkI A{tGNViS 'rlOOJ. DIN NOI&VOO'-I ~tAlktklV NOLLVDO'-i O£ '5I'O S'-IOO£ SV'-I£V iV G~AI'GktV ~tdOrlS O£ 017:0I 96/t70/90 00:9I 00:£[ g17:01 gI:60 0[:80 00:80 O£:gO 017:£0 0~:~0 0£:10 96/170G0 00:~ 00: [i~ gi~:6I 96/170/170 O0:LI 0£:£I O~;:[I 96/170/£0 9gg~D96ffO>lV : EIEI~IAIFIN [lOP .L~lOd=lbl -iVOIDO-IONOEIHO WELL LOG TRANSMITTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Okland 3001 Porcupine Drive Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPC-28, September 27, 1996 AK-MM-960208 The technical data listed below is being submitted herewith. Please acknowledge receipt by rehaming a signed copy of this transmittal letter to the attention of: Jim Galvin, Sperry-Stm Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 MPC-28: 1 LDWG formatted LIS tape with verification hsting. API#: 50-029-22648-00 OCT 1996 Al~,a Oil & Gas Ccr~s. C~rm~ 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 ° Fax (907) 563-7252 A Dresser Industries, Inc. Company WELL LOG TI~4NSM1TTAL To: State of Alaska Alaska Oil and Gas Conservation Comm. Attn.: Howard Oldand 3001 Porcupine Dr. Anchorage, Alaska 99501 MWD Formation Evaluation Logs - MPC-28, AK-MM-960208 September 25, 1996 The technical data listed below is being submitted herewith. Please acknowledge receipt by returning a signed copy of this transmittal letter to the attention of.' Jim Galvin, Sperry-Sun Drilling Services, 5631 Silverado Way, #G, Anchorage, AK 99518 2" x 5" ~MD Resistivity and Gamma Ray Logs: 2" x 5" TVD Resistivity and Gamma Ray Logs: 2"x 5"MD Neutron and Density Logs: 2"x 5" TVD Neutron and Density Logs: 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia 1 Blueline 1 Rev. Folded Sepia RECEIVED SEP 2 t996 5631 Silverado Way, Suite G · Anchorage, Alaska 99518 · (9.07) 563-3256 · Fax (907) 563-7252 A Dresser Industries, Inc. Company 966[ [ 2 ~08~-~9s (~06) SSD~A~eS 6UTb60~ S~I~ uosIn~ '~ Xeupo~ 'u~::o~n~e~.pu~ uS~s ~s~I~ . . O0 '8S99 00 'AS99 O0 ' ~7~99 ' oN DOM I # unH I # un~ I # un~ :~oiaq paqT:zos~p s~ ~;~p eq; pu7~ ss~sld 'pasolou~v X~l~h'O aM~fH :Xq :;uss 966I A~N 6 :e~G 'IOS66 'X~ MD~OHON~ SMkI~G MMi~fiOHOd I00E NOI~WAMMSNOD S~O + %IO kr>IsW~W 'u~ ~o~-~ 1~o6> o~ x~ ~"'";:' ~? 8IS66 ~ 's6~oq~u~ ~ I0~ ~Tns ~a~S 8 009S I0'I999 00'I999 I0'8S99 I0'~99 · oN DDZ I # unH # unH I # unH # unH I # unH I # un~ ~H+~8 ~NIZ S~6 3F~ ~H+q8 T~NI~ ~8S/~ XH~AI%ZG GMWH :Ag %uos 966I I72dY 9g LARRY G P~.N T Attn. ALASY~A OiL + GAS CONSERVATION 3001 PORCUPINE DRI%~E AK, 9950i. Date: 25 April 1996 RE: Transmittal of Data Sent by: HAND CARRY Dear Sir/Madam, Enclosed, ~ ~ease find the data as described below: WELL DESCRIPTION 1 SBT FINAL BL+RF~/ ECC No. Run # 1 66~g.0C 1 SBT FINAL BL+RF C/ Run # 1 1 SBT FINAL BL+RF~' Run 1 PLS FINAL BL+RF /Run 1 PFC/PERF FINAL BL+RF~/' Run 6657.00 6658.00 Please sign and return to: Attn. Rodney D. Paulson Western Atlas Logging Services 5600 B Street Suite 201 Received by: Anchorage, AK 99518 ~ Date: STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION APPLICATION FOR SUNDRY APPROVALS Abandon Suspend Operation Shutdown X Re-enter suspended well 1. Type of Request: Alter casing __ Repair well Plugging __ Change approved program Pull tubing Time extension __ Vadance Perforate Stimulate Other 2. Name of Operator BP Exploration (Alaska) Inc 3. Address P. O. Box 196612, Anchorage, Alaska 99519-6612 5. Type of Well: Development __ Exploratory __ Stratigraphic __ Service X 6. Datum elevation (DF or KB) KBE = 46 feet 7. Unit or Property name Mi/ne Point Unit 4. Location of well at surface 8. 837' NSL, 2341' WEL, SEC. 10, T13N, RIOE At top of productive interval 9. Well number MPC-28 Permit number 96-29 10. APl number 50- 029-22648 3255' NSL, 255' WEL, SEC. 9, T13N, RIOE At effective depth N/A At total depth 3358' NSL, 392' WEL, SEC. 9, T13N, R10E ORIGINAL 11. Field/Pool Mi/ne Point Unit/Kuparuk River 12. Present well condition summary Total depth: measured Effective depth: Casing Structural Conductor Surface Intermediate Production Liner true vertical measured true vertical Length 80' 5374' 5405 feet Plugs (measured) 4623 feet feet Junk (measured) feet Size Cemented Measured depth True vertical depth 20" 250 sx Arcticset I (Approx.) 112' 112' 9-5/8" ~O~O~PF'~,250~'~', ~50~xPF'~ 5405' 4623' After setting the surface casing for MPC-28, we request an operation shut down. We will resume drilling operations on IIIPC-28 with Rig #22E approximately April 5, 1996. 13. Attachments Description summary of proposal ~ Detailed operations program __ BOP sketch 14. Estimated date for commencing operation 02/22/96 16. If proposal was verbally approved Name of approver Date approved 15. Status of well classification as: Oil __ Gas __ Suspended __ Service WAG Injector 17. I hereby certify that the foregoing is true jan/el correct to the best of my knowledge. ~by;,,4o.~y c~n-Yo~+ -¢~- 4 ¢~ion5 Signed l~ ~~ Title Senior Drilling Engineer Date ~ ~.' . FOR COMMISSION USE ONLY Conditions of approval: Noti~ Commission so representative may witne~ ~ Approval No. Plug integri~ ~ BOP Test ~ Location clearance ~ Mechanical Integri~Test~ Subsequent[9~(~i~¢~- ~ ~ App~o~ed CoDy ~ :.'~'a' ~0hnston ~~ed Approved by order of the Commission ~~ ..... Date Form 10-403 Rev 06/15/88 SUBMIT IN TRIPLICATE TONY KNOWLE$, GOVERNOR ALAS AND GAS CONSERVATION COMMISSION 3001 PORCUPINE DRIVE ANCHORAGE, ALASKA 99501-3192 PHONE: (907) 279-1433 FAX: (907) 276-7542 February 15, 1996 Tim Schofield, Senior Ddlling Engineer BP Exploration (Alaska), Inc. P O Box 196612 Anchorage, AK 99519-6612 Re: Milne Point Unit MPC-28 BP Exploration (Alaska), Inc. Permit No 96-029 Surf Loc 837'NSL, 2341'WEL, Sec. 10, T13N, R10E, UM Btmhole Loc 3358'NSL, 392'WEL, Sec. 09, T13N, R10E, UM Dear Mr. Schofield: Enclosed is the approved application for permit to drill the above referenced well. The permit to drill does not exempt you from obtaining additional permits required by law from other governmental agencies, and does not authorize conducting drilling operations until all other required permitting determinations are made. Blowout prevention equipment (BOPE) must be tested in accordance with 20 AAC 25.035. Sufficient notice (approximately 24 hours) of the BOPE test performed before drilling below the surface casing shoe must be given so that a representative of the Commission may witness the test. Notice may be given by Commission petroleum .field inspector on the North Slope pager at 659-3607. David Ch BY ORDER OF THE COMMISSION /enci c: Dept of Fish & Game, Habitat Section - w/o encl Dept of Environmental Conservation - w/o encl STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION PERMIT TO DRILL 20 AAC 25.005 la. Type of work Drill [] Redrill I-Illb. Type of well. Exploratoryl-I Stratigraphic Test [] Development Oil [] Re-Entry [] Deepen []1 Service [] Development Gas [] Single Zone [] Multiple Zone [] 2. Name of Operator 5. Datum Elevation (DF or KB) 10. Field and Pool BP Exploration (Alaska) Inc. KBE = 46 feet Milne Point / Kuparuk River 3. Address 6. Property Designation P. O. Box 196612, Anchorac~e. Alaska 99519-6612 ADL 047434 4. Location of well at surface 7. Unit or property Name 11. Type Bond(see 20 AAC 25.025) 837' NSL, 2341' WEL, SEC. 10, T13N, RIOE Milne Point Unit At top of productive interval 8. Well number Number 3255' NSL, 255' WEL, SEC. 9, T13N, RIOE MPC-28 2S100302630-277 At total depth 9. Approximate spud date Amount 3358°NSL, 392' WEL, SEC. 9, T13N, RIOE 02/14/96 $200,000.00 12. Distance to nearest 13. Distance to nearest well 14. Number of acres in property15. Proposed depth (MD and TVB) property line ADL 315848 3358 feet No Close Approach feet 2560 8681' MD / 7301' TVD feet 16. To be completed for deviated wells 17. Anticipated pressure (see 20 AAC 25.035 (e)(2)) Kickoff depth ¢0oo feet Maximum hole angle4o.38 o Maximum surface 3301 psig At total depth (TVD) 7000'/3998 psig 18. Casing program Setting Depth s~ze Specifications Top Bottom Quantity of cement Hole Casing Weight Grade Coupling Length MD TVD MD TVD (include stage data) 24" 20" 91.1# H-40 Weld 80' 32' 32' 112' 112' 250 sx Arcticset I (Approx.) 12-1/4" 9-5/8" 40# L-80 Btrc 5375' 31' 31' 5406' 4611' l o5o sx PF 'E', 250 sx 'G', 150 sx PF 'E' 8-1/2" 7" 26# L-80 Btrc 8651' 30' 30' 8681' 7301' 242 sx Class 'G' 19. To be completed for Redrill, Re-entry, and Deepen Operations. Present well condition summary Total depth: measured feet Plugs (measured) true vertical feet Effective depth: measured feet Junk (measured) true vertical feet Casing Length Size Cemented Measured depth True Vertical depth Structural Conductor .......... ,, ..... , .... ~.. ~,,,-~ ~.~, Surface ~; .,..- .~.¢~,~,~ ,~ ..... Intermediate Production Liner ~:~S 0 7 '~996 Perforation depth: measured ,,i~,,~'¢, Q"~ ¢; f':~ r,¢,.~q true vertical ~w,~,.¢ ....... ~ 20. Attachments Filing fee ~ Property plat ~ BOP Sketch ~ D~8'~'¢~Sketch ~ Drilling program~ Drilling fluid program ~ Time vs depth plot ~ Refraction analysis~ Seabed repod~ 20 AAC 25.050 requirements~ 21. I hereby ce~ify that the foregoing is true and correct to the best of my knowledge Signed ~~,~ ~%~~~ Title Senior Drillin~ Eng*eer Date ~ Commission Use Only Permit Number APl number Approval dat~ See cover letter ~-~ ¢ 50- O ~ ~ - ~ ~ ¢ ~ ~%/¢O for other requirements Conditions of approval Samples required ~ Yes ~ Mud log required ~Yes ~ ~ Hydrogen sulfide measures B Yes ~ ~ Directional su~ey required ~ Yes ~ ~ Required working pressure for BOPE ~2M; ~3M; ~5M; ~10M; ~15M; Other: ~y CommiSs'io"e¢".'' '.: ,ne commission Date~ __ Approved by Original ~'~' .. by order of Form 10-401 Rev. 12-1-~,~¥ Submit i)licate Target Location' 3255 NSL 255 WEL Sec 09 T13N R10E UM., AK Bottom Hole 3358 NSL 392 WEL Sec 09 T13N R10E UM., AK Location: IAFE Number: 1337018 I Date:Estimated Start 114FEB96I I Rig: I Nabors 22-E Operating days to 120 complete' I MD: 18,681'I Well Design (conventional, slimhole, etc.): IMilne Point Ultra Slimhole:9-~/8" SURFACE CASING X 7" LONGSTRING ;'""~-: ii ...... 'i..-~ !~ ...... :! -~. ~' Formation Markers: Formation Tops MD TVD (bkb) /,,..,,....~-,~: .... base permafrost 1,867 1,846 NA 4,901 4,226 Top of Schrader Bluff Sands (~'.::~"'"~'~ Seabee Shale 5,256 4,496 Base of Schrader Bluff Sands (8.3 ppg) HRZ 7,705 6,41 8 High Resistivity Zone Top Kuparuk 8,01 5 6,698 Kuparuk Cap Rock Target Sand -Target 8,272 6,931 Target Sand (9.6 ppg) Total Depth 8,681 7,301 Casinq/Tubing Pro ram: Hole Csg/ Wt/Ft Grade Corm Length Top Btm Size Tbg O.D. MD/TVD MD/TVD 24" 20" 91.1# H-40 Weld 80 32/32 112/112 12 1/4" 9-5/8" 40# L-80 btrc 5,375 31/31 5,406/4,611 8 1/2" 7" 26# L-80 btrc 8651 30/30 8,681/7301 Internal yield pressure of the 7" 26# casing is 7240 psi. Worst case surface pressure would occur with a full column of gas to the reservoir at ___7000 TVDSS. Maximum anticipated surface pressure in this case assuming a reservoir pressure of 3998 psi is 3301 psi, well below the internal yield pressure rating of the 7" casing. Logging Program: Open Hole Logs: Surface Intermediate Final Cased Hole Logs: MWD Directional surface to TD. LWD GR/RES (Across Schrader Bluff) N/A MWD Directional and LWD (GR/CDR/CDN). Mudloggers are NOT required for this well. uensity Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point gel gel Loss Production Mud Properties: I LSND freshwater mud Density Marsh Yield 10 sec 10 min pH Fluid (PPG) Viscosity Point ~]el ~]el Loss 9.0 40 10 3 7 8.5 6-8 to to to to to to to 10.4 50 15 10 20 9.5 4-6 Well Control: Well control equipment consisting of 5000 psi W.P. pipe rams, blind rams, and annular preventer will be installed and is capable of handling maximum potential surface pressures. Diverter, BOPE and drilling fluid system schematics on file with AOGCC. Directional: I KOP: ILOOO' Maximum Hole An~]le: Close Approach Well: 40.38 (No Shut Ins) Disposal: Cuttings Handling: Cuttings should be hauled to the ball mill at CC-2A. The Milne Point reserve pit can be opened in emergencies by notifying Karen Thomas (564-4305) with request. Request to AOGCC for Annular Pumping Approval for MP C-28i: 1. Approval is requested for Annular Pumping into the MP C-28i, 9-5/8" x 7" casing annulus and any well on the pad/drillsite previously permitted for disposal activities by AOGCC. 2. The base of the Permafrost for all wells located in the Milne Point Unit is _+1,850' TVD. Aquifers in the Milne Point Unit have been exempted from Class II injeCtion activities by the AOGCC by Aquifer Exemption Order #2 as referenced in Area Injection Order #10. There are no domestic or industrial use water wells located within one mile of the project area. 3. The 9-5/8" casing shoe will be set at 5,406' md (4,611' tvd) which is a minimum of 500' tvd below the Permafrost and into the Seabee/Colville formation which has an established history of annular pumping at Milne Point. 4. There are _+23 wells on Milne Pt. 'C' Pad. There may be additional unidentified wells within one quarter mile distance from the subject well. There are no domestic or industrial water use wells located within one mile of the project area. 5. The wastes to be disposed of during drilling operations can be defined as "DRILLING WASTES". 6. The burst rating (80%) for the 9-5/8" 40# LB0 casing is 4600 psig while the collapse rating (80%) of the 7" 26# L80 casing is 4325 psig. The break down pressure of the Seabee/CoIville formation is 13.5 ppg equivalent mud weight. The Maximum Allowable Surface Pressure while annular pumping regardless of fluid density is 2000 psi as per Shared Services Drilling "Recommended Cuttings Injection Procedure". 7. A determination has been made that the pumping operation will not endanger the integrity of the well being drilled by the submission of data to AOGCC on 7/24/95 which demonstrates the confining layers, porosity, and permeability of the injection zone. 8. The cement design for this well ensures that annular pumping into hydrocarbon zones will not occur. IVIIIII~., ~ L~IIII. I~J~ ,~l~l~,v ~ I Milne Point 1JANg6-31DEC96 Milne Point 1JAN96-31 DEC96 Milne Point 1JAN96-31 DEC96 Milne Point 1JAN96-31 DEC96 DO NOT EXCEED 35,000 BBLS IN ANY ANNULUS. MAXIMUM EXPECTED FLUID DENSITY IS 17.0 PPG BURTST PRESSURE 9-5/8" 40# L-80 CASING: 5750 PSI COLLAPSE 7", 26#, L-80 CASING: 5410 PSI 9-5/8" SURFACE CASING SHOE DEPTH: 5,406' MD/4,611' TVD HYDROSTATIC PRESSURE @ 4,611 TVD WITH VARIOUS DENSITY FLUIDS: (0.052) X (4611) X (FLUID DENSITY) = HYDROSTATIC PRESSURE 80% OF 7" COLLAPSE PRESSURE = (5410 PSI) X (0.8) - 4328 PSI MAXIMUM ALLOWABLE INJECTION PRESSURE 2000 PSI AT ANY PPG SURFACE CASING SHOE DEPTH (TVD): 4,6 1 I HYDROSTATIC MAXIMUM ALLOWABLE PRESSURE AT SURFACE 7" COLLAPSE ANNULAR INJECTION FLUID DENSITY CASING SHOE DEPTH PRESSURE (80%) SURFACE PRESSURE (PPG) (PSI) (PSI) (PSI) 8 1918.18 4328 2000 9 2157.95 4328 2000 1 0 2397.72 4328 1930 1 I 2637.49 4328 1691 1 2 2877.26 4328 1451 1 3 3117.04 4328 121 1 1 4 3356.81 4328 971 1 5 3596.58 4328 731 1 6 3836.35 4328 492 1 7 4076.12 4328 252 MAX ALLOWABLE INJECTION PRESSURE = 4328 PSI- HYDROSTATIC PRESSURE or 2000 psi (whichever is less), . , . , , , , o . 10. 11. 12. 13. 14. surface casing on MP C-28i. This will expedite the move out to exploration - especially with the short "window" associated with exploration work. All pertinent information required in SECTION B - of 20 AAC 25.072 SHUTDOWN OF WELL OPERATIONS - will be filed within 30 ndays of shutdown as mandated in AOGCC regulations. Drill and Set 20" Conductor. Weld a starting head and top job nipple on conductor. Prepare location for rig move. MIRU Nabors 22E drilling rig. NU and test 20" Diverter system. Build Spud Mud. Drill a 12-1/4" surface hole as per directional plan. Run Directional MWD from surface to TD and run Gamma Ray/Resistivity LWD across Schrader Bluff sands. Run and cement 9-5/8" casing. NOTE: IF NECESSARY ND DIVERTER/NU WELLHEAD. TEST SAME AND SHUTDOWN WELL OPERATIONS. LEAVE 2000' OF DIESEL IN THE TOP OF THE WELLBORE. ND 20" Diverter, NU and Test 13-5/8" BOPE. MU a PDC bit on a motor, with Directional MWD and LWD CDR/CDN (GR/RES/Dens/Neu). RIH, Drill out Float Equipment and 10' of new formation. Perform FIT to 12.5 ppg. Drill 8.5" hole to TD as per directional plan. Run and Cement 7" Casing. Displace cement with seawater and enough diesel to cover from the base of permafrost to surface. Test casing to 3500 psig. ND BOPE, NU and Test Tree. RDMO Nabors 22E drilling rig to drill next well. Perforate and Stimulate in absence of rig. Displace well with 10.2 ppg brine and set a wireline retrievable bridge plug. MIRU Nabors 4ES or Polar 1 Rig. NU & Test BOPE to 5000 psig. Complete well with 2-7/8" tubing and packer hookup. Install Surface Lines and Wellhouse and put the well on production. 4. A GYRO or IN-HOLE REFERENCE GYRO MAY be required to be run in this wellbore. LOST CIRCULATION: There were no reports of lost circulation while DRILLINGin the production intervals. However, Milne Pt. "C' Pad was developed in the early to mid 1980's with virgin reservoir pressures. Several wells at Milne Pt. 'C' Pad have experienced partial to full lost returns while running, circulating and cementing 7" casing. Have the LCM materials outlined in the Drilling Fluid Program on location and recommended pills ready to address the Lost Circulation Problem when drilling into the Kuparuk Sand. Stuck Pipe Potential: Stuck pipe has occurred on 2 wells on this pad in the Schrader Bluff Sands. These wells and the corresponding depths at which they were stuck were: C- 09 @ 4,427' ss with a mudweight of 9.4 ppg. Milne Pt. Well# C-02 @ 3,911' ss with 9.2 ppg mudweight. Gas hydrates: Although hydrates were encountered on E, H, and I Pads, no hydrates are expected on Milne Pt. 'C' pad. No hydrates were encountered during the recent drilling of MP C-25 and MP C-26, nor MP C-23. 4. No other drilling hazzards or risks have been identified for this well. WEIGHT: 12.0 ppg APPROX #1050 SACKS: YIELD:2.17 ft3/sx MIX WATER' 11.63 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. TAIL CEMENT TYPE: ADDITIVES: 2.0% CaCI2 WEIGHT: 15.8 ppg APPROX #SACKS: 250 FLUID LOSS: 100-150 cc Premium G YIELD:1.15 ft3/sx MIX WATER' 5.0 gal/sk THICKENING TIME: Greater than 4 hrs at 50° F. FREE WATER:0 TOP JOB CEMENT TYPE: Permafrost E ADDITIVES: Retarder WEIGHT: 12.0 ppg APPROX NO SACKS: 150 YIELD:2.17 ft3/sx MIX WATER: 11.63 gal/sk CENTRALIZER PLACEMENT: 1. 1 Bowspring centralizer per joint of 9-5/8" casing on bottom 15 joints of casing (15 required). 2. Place all centralizers in middle of joints using stop collars. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacedmud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 12 - 15 bpm. Mix slurry on the fly -- batch mixing is not necessary. CEMENT VOLUME: 1. The Tail Slurry volume is calculated to cover 618' md above the 9-5/8" Casing Shoe with 30% excess. 2. The Lead Slurry volume is calculated to cover from the top of the Tail Slurry to 1500' md with 30% excess and from 1500' md to surface with 100% excess. 3. 80'md 9-5/8", 40# capacity for float joints. 4. Top Job Cement Volume is 150 sacks. L, UlI~IIL IllUU W~,I~IIIL. CEMENT TYPE' Premium G ADDITIVES: 0.2% CFR-3, 0.1% HR-5, 0.4% Halad 344 WEIGHT: 15.8ppg YIELD: 1.15 cu ft/sk MIX WATER: 5.0 gal/sk APPROX # SACKS: 242 THICKENING TIME: 3 1/2 - 4 1/2 hrs @ 140° F FLUID LOSS: < 50cc/30 min @ 140° F FREE WATER: 0cc @ 45 degree angle. CENTRALIZER PLACEMENT: I , , 7" x 8-1/4" Straight Blade Rigid Centralizers. Two per joint on the bottom 22 joints of 7" casing (44). This will cover 300' above the KUPARUK C Sand. Run two (2) 7" x 8-1/4" Straight Blade Rigid Centralizers on the second full joint inside the 9-5/8" casing shoe. OTHER CONSIDERATIONS: Perform lab tests on mixed cement/spacer/mud program and ensure compatibility prior to pumping job. Ensure thickening times are adequate relative to pumping job requirement. Displace at 8-10 bpm. Batch mixing is ~not necessary. CEMENT VOLUME: , Stage I cement volume is calculated to cover 1000' md above the Kuparuk Target Sand with 30% excess. Feb-06-~6 16:§8 Anadrill DPC 907 344 2160 P .05 SHARED Sb.R~)"I Cb- __ S' DRTLLTNG ...... MPC-28 (P3) VEflTICAL SECTION VIEW · m m · Section at: 307.~0 TVD Scale.' ! inch : 1000 feet ~Dep Scale' 1 inch = 1000 feet - A wn .... ' 02/06/96 -. , · . , · .... I Ana#rJl, Y SchYum, berger · ! · I ± mmjI __ Narker Identification MD BKB SECTN INCLN ; E A) KB 0 0 0 O. O0 B) K~/BUILD 2.5/100 ]000 1000 -0 0.00 C) E~ 2.5/~00 ~ILD ~5 2485 546 40.36 - ~ D) 9-5/8" CASI~ POINT 5405 46~ 2354 40.38 I ..... ~ E) DR~ ~.5/~00 ~47 5708 32~ 40.36 F) E~ ~.5/]00 OR~ 7872 5~9 ~40 25.00 .- , -~~r'~ G) TAROT 8~72 693~ 4009 25.00 I k H) 7' CASING POINT ~Bl 7301 4~8~ 25.00 Il TO ' 868l 7301 4~8t 25.00 ANAl )RILL /kKA-D[~C NC~T A >PRC)VEE _ EX ECU'F!~kI. ,, - . . ............. .... :& ~ .... ...... -N ~ 3~Z :~ ..... ~,. ................ . ......................... .... ...... m ..... .... ~'~)~ ~ ............ m- ;;~-~ ..... ~;;~; = m= ~l~_l~l I III ~ I I III IIIIIIIIIII IIIII :lllll Illll~lllll III1~ ~1111 IIIIII)11111 ~1~1 =1 ~ - ~ ..... ~ .... ' · -' ............................ m .......... ~-- ............... ~ - - - H ....... ~= t .- - looo -5oo o 50o lO00 ]500 2000 2500 3000 3500 4000 4500 5000 5500 6000 Section Oeoarture :~11 f.I -' ' ~) ..... Feb-06-96 16:58 Anadrill DPC 907 344 2160 P.06 SHARED SERVICES DRILLINS ' I ii il, ii · i il Ifil I I I ] ~ II ~1 ~,o,.5/,oo~o~ ~ ~ ~o ~.oo B) TAROT ~72 ~3' aO09 ~.00.~...~ ~..~.VF~TTPA/~qFPTTn~ VIEW c) ~'c~,~,T ~8~ ~3o~ ~e~ ~.oo . D) TD ~ 730~ 4~8t 25.00 Section at: 307.~0 TVD Scale.' $ inch = 200 feet 5~o .... Dep Scale.' 3 inch = 200 feet ~ Drawn ..... '02/06/96 5~0 - ~ ..... ~nadrj 1] Sch]umbergen 6000 ..... ANADRILL ~KA-DPC ~J~A I ~ NC~T A DPR()VE[)FOI~ 6~00 ~1~ t,~l~k I c~c~u [ ~1q j PLA ~ ~400-~ ....... -~ - ~ B ~ ...... 6500- ~y - ~m , m - ., r ~ - - -~-~- ~ r .................. 6600 - 6700 -f~-~ ................................... 'T~ - ~ ....... -~- - - -. 6800 -z~ -~ ................... .~. _ _. ..... ~, ~ ' 6~00- - - .. ~,.,~. ........................... ]'k~x - : - .. . [ '.~ ............................... -T~ - ~ - . ............... ' ..... . - ..... ---- ..... 7000 -r~r ~ ] ! -- 'T[~ - ~ ~ - . ......... . 7~00-- -, 7200 , 7300- - . 7~00 , , , 3000 3100 3200 3~0 3400 3500 36~ 3700 3~0 3go0 4000 4t00 4200 4300 4400 Section SHARED SERVICES DRI'LLTNG Anadri ] ] Sch]umOerger · i i i MPC-2B (P3) ~ :PLAN VIEW CLOSURE · 4~B~ feet at Azimuth 307.~0 ............. ]DECLINATION.: +28.119 (E) msc,~u:.., .... : ~ ~.c,: 500 200 FI T~RGE ! FUkDIUS · ~arker Identi ficat ion MD N/S E/W B) KOP/BUILD 2.5/~00 ~000 0 0 ~ C) END 2.5/100 BUILD 2615 329 436 ........... O) 9--5/8" CASING POINT 5406 ~ El OR~ 1.5/,00 6847 ,983 2622 k F, E~ ,.5/,00 ~ 7872 ~3]6 3063 G) TAROT 8272 24,8 3,97 "~ 7" CASING POINT B,, 2522 3335 ' I, TO . ~81 2522 3335 ........ ........ ' ~ ~ ~0 ...... - ~.. N'~_ .......... ~A ~ 4250 4000 3750 3500 3250 3000 27~ 2500 2250 2000 1750 i500 l~:) 1000 750 500 2~ 0 250 <- WEST · EAST -> ~qa~')l] k196 C~8P3 Z.~.04 2:5~ IM PI )> PERMIT CHECKLIST GEOL ~ ~ ~ ~ PROGRAM:, exp [] dev []. redrll [] serv~ w UNIT~ //3~ ON/OFF SHORE ADMINISTRATION ENGINEERING 1. Permit fee attached ................... N 2. Lease number appropriate ................ N N 3. Unique well name and number ............... 4. Well located in a defined pool ............. N 5. Well located proper distance from drlg unit boundary. · 6. Well located proper distance from other wells ..... 7. Sufficient acreage available in drilling unit ..... t YIN 8. If deviated, is wellbore plat included ........ 9. Operator only affected party .............. 10. Operator has appropriate bond in force ........ i.It'~~Y 11. Permit can be issued without conservation order .... Y N 12. Permit can be issued without administrative approval. .Y N 13. Can permit be approved before 15-day wait ...... N APPR 14. Conductor string provided ............... ~ N 15. Surface casing protects all known USDWs ........ ~ N 16. CMT vol adequate to circulate on conductor & surf csg..~ N 17. CMT vol adequate to tie-in long string to surf csg . . . Y 18. CMT will cover all known productive horizons ...... ~ N 19. Casing designs adequate for C, T, B & permafrost .... ~ N 20. Adequate tankage or reserve pit ............. ~ N 21. If a re-drill, has a 10-403 for abndmnnt been approved. 22. Adequate wellbore separation proposed .......... ~ N 23. If diverter required, is it adequate .......... ~ N 24. Drilling fluid program schematic & equip list adequate ~ N 25. BOPEs adequate ..................... ~ N 26. BOPE press rating adequate; test to ~5~57_~ psig.~ N 27. Choke manifold complies w/API RP-53 (M~y 84) ...... 28. Work will occur without operation shutdown ....... ~ N 29. Is presence of H2S gas probable ............ ~ N GEOLOGY 30. Permit can be issued w/o hydrogen sulfide measures .... Y N/ 31. Data presented on potential overpressure zones ..... Y /~~ ~/ $' ~ ~] ~/ 32. Seismic analysis of shallow gas zones .......... y N ~ 33. Seabed condition survey (if off-shore) ........ /Y N 34. Contact name/phone for weekly progress reports .... /. Y N [exploratory only] ~ REMARKS GEOLOGY: ENGINEERING: COMMISSION: Comments/Instructions: HOW/lib - A:~FORMS~cheklist rev 11/95 Well History File APPENDIX 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. 0'Ig£8 00~'8 0'90P9 ~9'6 0Sg'gI 0'gII 000'0~ SH.~TIIHfI ~NISVD .~IOH N.~aO 966L £0 190 08'9I ~S'9~ ,q0I E NO~Xd '£ HXNHIZ '~ E NfI~CIM~ NOHLd ' J2 96-dHS-SE SHDIA~S ~NI~I~ N_F1S-X~HdS 'DNI (~r~S~rq~) NOIi~r~O~dXH 008~9EE6~00~ OLHL- ~NI~IS ~NI~IS DNIHIS CIN~ ~NI~S NO%tAd ' D 80E096-~-X~f I Nile GM24 :XN~d~OD ONI©OO% soo~ ~/c~ iINII A~ ~OHflflEd ~.iLE HEADER FILE NUMBER: 1 EDITED MERGED MWD Depth shifted and clipped curves; all bit runs merged. DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE GR RP NPHI RHOB $ BASELINE CURVE FOR SHIFTS: CURVE SHIFT DATA (MEASURED DEPTH) START DEPTH STOP DEPTH 42.0 8668.0 36.0 8641.0 5232.0 8649.0 5275.0 8657.0 BASELINE DEPTH $ MERGED DATA SOURCE PBU TOOL CODE $ REMARKS: EQUIVALENT UNSHIFTED DEPTH BIT RUN NO MERGE TOP MERGE BASE 1 100.0 5425.0 2 5425.0 7390.0 3 7390.0 8721.0 MERGED MAIN PASS. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPC-28 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 2 3 4 5 6 7 8 9 GR MWD 68 1 AAPI RPX MWD 68 1 OHMM RPS MWD 68 1 OHMM RPM MWD 68 1. OHMM RPD MWD 68 1 OHMM RHOB MWD 68 1 G/C3 DRHO MWD 68 1 G/C3 PEF MWD 68 1 BN/E NPHI MWD 68 1 PU-S 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 890 01 1 ~ FCNT MWD 68 1 CPS 4 11 NCNT MWD~ 68 1 CPS 4 12 FET MWD 68 1 HR 4 13 ROP MWD 68 1 FPHR 4 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 967 90 334 31 4 90 334 30 4 90 180 01 4 90 810 01 52 Tape File Start Depth = 8729.000000 Tape File End Depth = 35.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 243447 datums Tape Subfile: 2 1055 records... Minimum record length: Maximum record length: 62 bytes 1014 bytes 0 0' :(ZH) XD~IZfl0,w%{,~ %{M,W : (lqI) ,~,~OgAItfgS ~lOOg 000 ' 00' : (NI) NOIgD~R~OD ~OH ~OOg 0'0£ 0'0£ 0'86 0'0£ 000'5 00£'~ 0L6'I 00£'E S'L 008 ~'6 0'9~ 017'6 0 · : (gM) HidZ~ DNIS~D S,MZ~IM~ : (MI) ZZIS gI~ Z~OH MZdO ~g~ DNIS~D ~Nlf Z~OHZMOM 8D~D9SS0d 8D~D9S~0d 5 ' SI SZ%{ ' DtfMO%IgD,~IZ ~%tMZ (~40ggO~{ og ~Og) DNI%{gS ~IO0,1, L'I~ 0 0'SESS 0'00I 56'£ MID II'~ DSI 96-~Z~-0~ Z%ItfMg,~OS : ~ZDDO~I Zg~f~I I~£S 0 ' 9£ ~EMZ 6SES 0 ' 95 ED dOgS HgaZfI g%SfgS ZfIOD ~IO0,1, %{O(INZA X~S Z~I~ 000~' :£NZMZEDNI HgdZ~ I :ON NYI~ gI~ :~Z~PCfI~ Z%I~ ~ZfIIfZH ZqI~ SI% :~ctXq ~T £ SIT~qns REMARKS: CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPC-28 : MILNE POINT : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 7 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MW 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 FET MWD 68 1 HR 4 7 'ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 180 01 1 4 90 810 01 1 28 * DATA RECORD (TYPE# 0) 998 BYTES * Total Data Records: 349 Tape File Start Depth = 5435.000000 Tape File End Depth = 35.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 86409 datums Tape Subfile: 3 414 records... Minimum record length: Maximum record length: 62 bytes 998 bytes rape Subfile 4 i~ typ~: LIS FILE HEADER FILE NUMBER: 3 RAW MWD Curves and log header data for each bit run in separate files. BIT RUN NO: 2 DEPTH INCREMENT: .5000 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 5246.0 EWR4 5219.0 CNP 5227.0 SLD 5236.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE SURFACE SOFTWARE VERSION: DOWNHOLE SOFTWARE VERSION: DATA TYPE (MEMORY OR REAL-TIME): TD DRILLER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : BIT ROTATING SPEED (RPM) : HOLE INCLINATION (DEG) MINIMUM ANGLE: MAXIMUM ANGLE: STOP DEPTH 7329.0 7302.0 7309.0 7318.0 07-APR-96 ISC 2.11 CIM 3.94 MEMORY 7390.0 5425.0 7390.0 0 33.5 42.3 TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE EWR4 ELECTROMAG. RESIS. 4 CNP COMPENSATED NEUTRON SLD LITHO-DENSITY DGR DUAL GAMMA RAY $ TOOL NUMBER P0513CRNSLDG6 P0513CRNSLDG6 P0513CRNSLDG6 P0513CRNSLDG6 BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE (IN): DRILLER' S CASING DEPTH (FT) : 8.500 5405.0 BOREHOLE CONDITIONS MUD TYPE: MUD DENSITY (LB/G): MUD VISCOSITY (S) : MUD PH: MUD CHLORIDES (PPM): FLUID LOSS (C3) : RESISTIVITY (OHMM) AT TEMPERATURE (DEGF) MUD AT MEASURED TEMPERATURE (MT): MUD AT MAX CIRCULATING TEMPERATURE: MUD FILTRATE AT MT: MUD CAKE AT MT: LSND 9.90 48.0 9.5 1500 8.2 1.500 .977 2.000 2.100 70.0 115.0 64.0 66.0 NEUTRON TOOL MATRIX: MATRIX DENSITY: SANDSTONE 2.65 HOLE CORRECTION (IN) : TOOL STANDOFF (IN) : EWR FREQUENCY (HZ) : REMARKS: MWD RUN 2. $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPC-28 : MILNE POINT : NORTH SLOPE : ALASKA .0 000 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 13 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR MWD 68 1 AAPI 4 2 RPX MWD 68 1 OHMM 4 3 RPS MWD 68 1 OHMM 4 4 RPM MWD 68 1 OHMM 4 5 RPD MWD 68 1 OHMM 4 6 RHOB MWD 68 1 G/C3 4 7 DRHO MWD 68 1 G/C3 4 8 PEF MWD 68 1 BN/E 4 9 NPHI MWD 68 1 PU-S 4 10 FCNT MWD~ 68 1 CPS 4 11 NCNT MWD 68 1 CPS 4 12 FET MWD 68 1 HR 4 13 ROP MWD 68 1 FPHR 4 4 90 310 01 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 120 46 1 4 90 350 01 1 4 90 356 99 1 4 90 358 01 1 4 90 890 01 1 4 90 334 31 1 4 90 334 30 1 4 90 180 01 1 4 90 810 01 1 52 * DATA RECORD (TYPE# 0) 1014 BYTES * Total Data Records: 244 Tape File Start Depth = 7400.000000 Tape File End Depth = 5210.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 304782 datums Tape Subfile: 4 313 records... J~mum record length: Maximum record length: 62 bytes 1014 bytes :XLISNZC XI~L~4 :XI~L~ 0' ~L 0'~L 0 'SSI 0'9L 000'E 008'I 0S9' 00£'I 00SI 0'6 0'£~ 0£'0I O'SO~S 00S'8 : (i.~) H£dZG ONIS%fD S,EZTTIEG : (NI) ZZIS LIE ZTOH NZdO ~fi%fG ©~IIS~fO GN-%f ZTOHZEOE 90GrISN~D £I S Od 9OGTSN-~DEIS0d 9~G~ISN~D £ I S 0 d EZE~flN ~IOOJ, ZdXL TOOL ZGOD TOOL EOONZA (NOLLOE OL ~OL) ~NIELS TOOL £'0£ 8'£E 0 0 'IE£8 0'06£A 0 'Ig£8 ~6 ' E HID II ' E DSI 96-Ed~-60 ZE~fML,~OS 0'0S98 0'0E5£ 0'I~98 0'IIEL 0'~E98 0'E0££ 0'0998 0'0£££ HLdZG dOLS HLdZ~ Lh~fLS ZGOD TOOL SIT :SclK~ ST S sIT~qns sde,T · ''sp~ooa~ 6gE S :aiigqns sd~i smn~p E659ET 99 :~poo d~M :A~mmns Bu!poo~p ~poo uo.z~usss~ds~ O0000S'O = BuIm~dS I~A~ sI!M 000000'06E£ = qjd~G pu~ ~IY~ ~d~i 000000'IE£8 = q~d~G ~x~S sIY~ sd~ ~S I0 018 06 P I0 08I 06 P 0£ P££ 06 P I~ P££ 06 P I0 068 06 P I0 8S£ 06 P 66 9~£ 06 P I0 OS[ 06 P 9P 0gI 06 P 9P 0gI 06 P 9P 0gI 06 P 9P 0gI 06 P I0 0I£ 06 P po~ SiD cIXi clKi q~Busq szls AXD A~D s~Iu~ s~Idm~S ~poD IOOi ~m~M :ssA~nD £I (P9 #HdXi) ~HODZM i~4~O,~ ~ 00C . ZdO~S HLMON : iMIOd ZM~IN : 8g-DdM : (YZS~f) MOIi~f~O~dXZ dS : NiiOD NM ND : (ZH) : (MI) ,4,40GNtf, T.S : (NZ) NOI£DZMHOO Z~IOH _ _mum record length: ~,laximum record length: 62 bytes 1014 bytes · £ape Subfile 6 is type: LIS 96/ 9/25 01 **** REEL TRAILER **** 96/ 9/25 01 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Wed 25 SEP 96 3:17p Elapsed execution time = 6.49 seconds. SYSTEM RETURN CODE = 0 Tape Subfile 2 is type: LIS · TAPE HEADER MILNE POINT UNIT CASED HOLE WIRELINE LOGS WELL NAME: API NUMBER: OPERATOR: LOGGING COMPANY: TAPE CREATION DATE: JOB NUMBER: LOGGING ENGINEER: OPERATOR WITNESS: SURFACE LOCATION SECTION: TOWNSHIP: RANGE: FNL: FSL: FEL: FWL: ELEVATION(FT FROM MSL 0) KELLY BUSHING: DERRICK FLOOR: GROUND LEVEL: WELL CASING RECORD MPC - 28 500292264800 BP EXPLORATION (ALASKA) INC. WESTERN ATLAS LOGGING SERVICES 06-MAY-96 6658.00 B. ESARY M. O'MALLEY 10 13N 10E 837 2341 .00 46.52 16.80 OPEN HOLE CASING DRILLERS CASING BIT SIZE (IN) SIZE (IN) DEPTH (FT) WEIGHT (LB/FT) 1ST STRING 2ND STRING 3RD STRING 9.625 5405.0 40.00 PRODUCTION STRING 7.000 8696.0 26.00 CURVE SHIFT DATA - ALL PASSES TO STANDARD (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS SBT GRCH 1 1 16-APR-96 WESTERN ATLAS LOGGING SERVICES PBU TOOL CODE: PBU CURVE CODE: RUN NUMBER: PASS NUMBER: DATE LOGGED: LOGGING COMPANY: BASELINE DEPTH $ Marked Line GR/SBT. EQUIVALENT UNSHIFTED DEPTH REMARKS: *** THIS IS THE DEPTH REFERENCE FOR THIS WELL *** PASS 1 (MAIN PASS) WAS NOT DEPTH SHIFTED SINCE THE MAIN PASS IS THE DEPTH REFERENCE FOR THIS WELL. LOG WAS RUN WITH MAGNETIC MARKS FOR DEPTH CONTROL. STOPPED LOGGING AT 7705' AFTER TOOL HUNG UP AT 7791' & THEN AT 7711'. BOTTOM HALF OF ONE CENTROLLER ARM BELOW VDL SECTION BROKE OFF. FILE HEADER FILE NI/MBER: 1 EDITED CURVES Depth shifted and clipped curves for each pass in separate files. PASS NUMBER: 1 DEPTH INCREMENT: .5000 FILE SUMMARY PBU TOOL CODE START DEPTH STOP DEPTH GRCH 7705.0 8575.0 $ CURVE SHIFT DATA - PASS TO PASS (MEASURED DEPTH) BASELINE CURVE FOR SHIFTS PBU CURVE CODE GRCH PASS NUMBER: 1 BASELINE DEPTH $ REMARKS: EQUIVALENT UNSHIFTED DEPTH PASS 1 (MAIN PASS). THE GAMMA RAY FROM THIS PASS IS THE DEPTH REFERENCE FOR THIS WELL. CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPC - 28 : MILNE POINT/KUPARUK : NORTH SLOPE : ALASKA * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 1 Curves: Name Tool Code Samples Units 1 GRCH GR 68 1 GAPI API API API API Log Crv Crv Size Length Typ Typ Cls Mod 4 30 310 01 1 * DATA RECORD (TYPE# 0) 1022 BYTES * Total Data Records: 15 Tape File Start Depth = 8630.000000 Tape File End Depth = 7702.000000 Tape File Level Spacing = 0.500000 Tape File Depth Units = Feet **** FILE,TRAILER **** LIS representation code decoding summary: Rep Code: 68 3715 datums Tape Subfile: 2 109 records... 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Minimum record length: Maximum record length: 62 bytes 1006 bytes Tape Subfile 5 is type: LIS FILE HEADER FILE NUMBER: 4 RAW CURVES Curves and log header data for each pass in separate files; raw background pass in last file. PASS NUMBER: 2 DEPTH INCREMENT: .2500 FILE SUMMARY VENDOR TOOL CODE START DEPTH GR 8376.0 $ LOG HEADER DATA DATE LOGGED: SOFTWARE VERSION: TIME LOGGER ON BOTTOM: TD DRILLER (FT) : TD LOGGER (FT) : TOP LOG INTERVAL (FT) : BOTTOM LOG INTERVAL (FT) : LOGGING SPEED (FPHR) : DEPTH CONTROL USED (YES/NO): TOOL STRING (TOP TO BOTTOM) VENDOR TOOL CODE TOOL TYPE CCL GR ACOM SBT VDL CENT $ STOP DEPTH 8595.0 CASING COLLAR LOC. GAMMA RAY ACOUSTILOG COMMON SEGMENTED BOND TOOL VDL SUB CENTROLLER 16-APR-96 FSYS REV. J001 VER. 1.1 2058 16-APR-96 8616.0 8613.0 7705.0 8605.0 1500.0 YES TOOL NUMBER 2330XA 1309XA 1633EA 1424XA 1424PA BOREHOLE AND CASING DATA OPEN HOLE BIT SIZE(IN): DRILLER'S CASING DEPTH (FT) : LOGGER'S CASING DEPTH (FT) : .000 8696.0 .0 BOREHOLE CONDITIONS FLUID TYPE: FLUID DENSITY (LB/G): SURFACE TEMPERATURE (DEGF): BOTTOM HOLE TEMPERATURE (DEGF) : FLUID SALINITY (PPM) : FLUID LEVEL (FT) : FLUID RATE AT WELLHEAD (BPM) : WATER CUTS (PCT) : GAS/OIL RATIO: CHOKE (DEG) : SEAWATER 8.50 .0 .0 0 .0 .000 .000 .000 .0 NEUTRON TOOL TOOL TYPE (EPITHERMAL OR THERMAL) : MATRIX: MATRIX DENSITY: HOLE CORRECTION (IN): .00 .000 BLUELINE COUNT P~ATE NORMALIZATION IN OIL ZONE TOP NORMALIZING WINDOW (FT) : BASE NORMALIZING WINDOW (FT) : BLUELINE COUNT RATE SCALES SET BY FIELD ENGINEER FAR COUNT RATE LOW SCALE (CPS) : 0 FAR COUNT RATE HIGH SCALE (CPS) : 0 NEAR COUNT RATE LOW SCALE (CPS) : 0 NEAR COUNT RATE HIGH SCALE (CPS): 0 TOOL STANDOFF (IN): .0 REMARKS: PASS 2 (REPEAT PASS). $ CN WN FN COUN STAT : BP EXPLORATION (ALASKA) : MPC - 28 : MILNE POINT/KUPARUK : NORTH SLOPE : ALASKA .0 .0 * FORMAT RECORD (TYPE# 64) ONE DEPTH PER FRAME Tape depth ID: F 4 Curves: Name Tool Code Samples Units API API API API Log Crv Crv Size Length Typ Typ Cls Mod 1 GR SBT 68 1 GAPI 4 2 CCL SBT 68 1 4 3 SPD SBT 68 1 F/MN 4 4 TEN SBT 68 1 LB 4 4 81 310 01 1 4 81 150 01 1 4 81 636 99 1 4 81 635 99 1 16 * DATA RECORD (TYPE# 0) 1006 BYTES * Total Data Records: 21 Tape File Start Depth = 8630.000000 Tape File End Depth = 8374.000000 Tape File Level Spacing = 0.250000 Tape File Depth Units = Feet **** FILE TRAILER **** LIS representation code decoding summary: Rep Code: 68 6153 datums Tape Subfile: 5 97 records... Minimum record length: 62 bytes Maximum record length: 1006 bytes Tape Subfile 6 is type: LIS 96/05/06 O1 **** REEL TRAILER **** 96/ 5/ 6 O1 Tape Subfile: 6 2 records... Minimum record length: 132 bytes Maximum record length: 132 bytes End of execution: Mon 6 MAY 96 11:28p Elapsed execution time = 1.09 seconds. SYSTEM RETURN CODE = 0