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207-007
3 ~~~~ ~~~ DATA SUBMITTAL COMPLIANCE REPORT 7/6/2010 Permit to Drill 2070070 Well Name/No. KUPARUK RIV UNIT 2D-06BL1 Operator CONOCOPHILLIPS ALASKA INC MD 11350 TVD 6045 Completion Date 6/3/2008 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION Mud Log No Samples No API No. 50-029-21168-60-00 UIC N Directional Survey DATA INFORMATION Types Electric or Other Logs Run: MWD DIR, RES, GR (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments E~ D Asc rectional Survey D 0 11350 Open 6/30/2008 ~ ED C Lis i 18326ci(nduction/Resistivity 8403 11350 Open 7/20/2009 EWR Logs in EMF, CGM and PDS graphics og Induction/Resistivity 25 Col 8645 11350 Open 7/20/2009 MD MPR, GR og Induction/Resistivity ,25r Col 8645 11350 Open 7/20/2009 TVD MPR, GR Well Cores/Samples Information: Name Sample Interval Set Start Stop Sent Received Number Comments ADDITIONAL INFORMATION Well Cored? Y /~ Daily History Received? (~ ~,N Chips Received? ~~ Formation Tops -~`" .--~--- Analysis Y / N Received? Comments: DATA SUBMITTAL COMPLIANCE REPORT 7/6/2010 Permit to Drill 2070070 Well Name/No. KUPARUK RIV UNIT 2D-06BL1 MD 11350 TVD 6045 C' ompletion Date 6/3/2008 Compliance Reviewed By: `v-F-v ______ Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21168-60-00 Completion Status 1-OIL Current Status 1-OIL ~ ~ `I i ON Date: ~~S^~ ~ at.JU u • ConocoPhillips Alaska Greater Kuparuk Area*** Data Distribution RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wri ht, 907 263-4823 hardco rints ConocoPhillips Alaska, Inc. Sharon Allsup-Drake Drilling Tech, ATO-1530 ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 ConocoPhillips Alaska, Inc. Ricky Elgarico 1 Graphic Image 1 Disk*/ File**/*** Electronic X98-6-Sfree~ CGM /TIFF LIS ftp://b2bftp.conocophillips.com **** AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk*/ 333 West 7th Ave, Suite 100 in lieu of sepia** Electronic Anchorage, Alaska 99501 CGM /TIFF LIS BP 1 Hardcopy Print, Petrotechnical Data Center, M633 1 Graphic image file 1 Disk*/ David Douglas in lieu of sepia** Electronic P.O. Box 196612 CGM /TIFF LIS Anchorage, Alaska 99519-6612 CHEVRON/KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk*/ P.O.Box 196247 in lieu of sepia** Electronic Anchorage, Alaska 99519 CGM /TIFF LIS Kristen Dirks, Geologist State of-Alask 1 Disk*/ 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501-3510 LIS DS Engineer /Rig Foreman TOTAL Hardcop Prints 4 Gra hic Ima a File 4 Electronic Data 5 JUL 2 ~ 20u~~ Alaska Oil ~ has Cons. Com,~riissicr Anchorage *Vault documents must be pre-inventoried (bar coding on documents with digital inventory files), also tapes/disks for Well Data Specialist. Please see page 2 for definition of Reservoir Analysis Logs and Completion Logs (Cased Hole Final Services). ** AOGCC guidelines for Graphical Image File in lieu of reproducible: "The graphical file must contain information equivalent to the hardcopy materials and consist of a separate file for each blueline or sepia. A publicly distributable viewer for the graphical format is required." *** ConocoPhillips, Alaska requests anon-proprietary archive format image file (.tiff) to facilitate discontinuation of mylar reproducibles **** Files larger than 20 MB should be hosted on a CD/DVD and be sent by mail. Files less than 20 MB should be sent via FTP site. Page 1 of 2 Davies, Stephen F (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Tuesday, July 08, 2008 2:10 PM To: Davies, Stephen F (DOA) Subject: PTD#207-007, Kuparuk 2D-06BL1 D ?.g.08 H i Steve, ~"~ /`~ 0~ You are correct... the API ber needs to be corrected to 19.6°. ~- `~ Thanks for catching the error. Terrie Page 1 of 1 ZD?'~7 7/8!2008 STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,f~ ~. .. ~ ~ _ ...... ~ ~O~~i 1 a. Well Status: • ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAACZS.,os zoAACZS.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class:° `' . `d ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 6/3/2008 12. Permit to Drill Number 207-007 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 5/25/2008 13. API Number S0-029-21168-60-00 • 4a. Location of Well (Governmental Section): Surface: ' ' ' 7. Date T.D. Reached 6/1/2008 14. Well Name and Number: Kuparuk 2D-06BL1 FEL, SEC. 23, T11 N, R09E, UM FSL, 510 124 Top of Productive Horizon: 4170' FSL, 3054' FWL, SEC. 24, T11 N, R09E, UM 8. KB (ft above MSL): 121' Ground (ft MSL): 15. Field /Pool(s): Kuparuk River Unit /Kuparuk Total Depth: 1995' FSL, 3012' FWL, SEC. 24, T11 N, R09E, UM 9. Plug Back Depth (MD+TVD) 11350' 6045' River Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- .529255 y- • 5954323 Zone- ASP4 10. Total Depth (MD+TVD) ~ 11350' 6045' • 16. Property Designation: ADL 025653 TPI: x- 532800 y- 5958384 Zone- ASP4 5956209 Zone- ASP4 th: x- • 532768 - Total De 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: y . p 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1465' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): MWD DIR, RES, GR 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surface 110' Surface 110' 24" 224 sx Coldset 1 9-5/8" 36# J-55 Surface 4104' Surface 3160' 12-1/4" 1070 sx AS III 765 sx Class 'G' 7" 26# J-55 Surface 7185' Surface 5015' 8-1/2" 560 sx Class 'G' 41 Bbls AS I 3-1/2" 9.2# L-80 7024' 4 ' 4910' 5992' 6-1/8" 396 sx Class'G' 2-3/8" 4.44# L-80 8625' 11350' 5979' 6045' 3" Uncemented Slotted Liner 23. Open to production or inject ion? ®Yes ^ No 24. TueING RECORD If Yes, list each i (MD+TVD of To & Bottom Pe nterval open rforation Size and Number): SIZE DEPTH SET MD PACKER SET MD p ; 2-3/8" Slotted Section 3-1 /2", 9.3#, L-80 7024' 7032' MD TVD MD TVD 8627 - 8658' 5980' - 6000' 9640' 6110' - 6113' 8849' 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. - 9675' - 10433' 6111' - 6()76' DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED 10589' -11316' 6071' - 6048' 8645' Set 2nd Whipstock (1st Failed) 2500' Freeze Protected w/ 22 Bbls of Diesel 26. PRODUCTION TEST Date First Production: June 9, 2008 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test: 6/12/2008 HOUrS Tested: 22 PRODUCTION FOR TEST PERIOD OIL-BBL: 911 GAS-MCF: 1,083 WATER-BBL: 173 CHOKE SIZE: 176 GAS-OIL RATIO: 1,342 Flow Tubing Press. 156 Casing Press: 1,259 CALCULATeD Z4-HOUR RATE.., OIL-BBL: 923 GAS-MCF: 1,238 WATER-BBL: 187 OIL GRAVITY-API (CORK): .1 ° 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No ' Sidewal l Cores Ac wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 250.071. CObtPLET1 None ~--~v$. I/fRfF1,ED f Form 10-407 Revised 02/2007 CONTINUED ON REV ~ ~®~ ~~~ ~ ~ [UUO ~,,c~;y~y ~ ~ 7.g.oa° (7 .'1~INr 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS ARKERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. B2 8675' 6012' None • B 1 8722' 6045' Kuparuk A6 8765' 6072' Kuparuk A5 8780' 6080' Kuparuk A4 8836' 6106' Kuparuk A4 (Invert) 10465' 6075' Kuparuk A4 (Revert) 10595' 6071' Formation at Total Depth (Name): Kuparuk A4 ~ 10595' 6071' ' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the forego"ng is true and correct to the best of my knowledge. 07~ ~ 0~ QQ Signed Terrie Hubble Title Drilling Technologist Date ~CJ Kuparuk 2D-06BL1 207-007 Prepared eyName/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Gary Eller, 263-4172 (Office) INSTRUCTIONS GeNewu.: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 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. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only 2D-06BL1, Pre-Rig Work DATE SUMMARY OF OPERATIONS 3/25/08 T-POTS- PASSED, IC-POTS- PASSED, MV-PT -FAILED, SV-PT -PASSED, MITOA -PASSED, FUNCTION TEST LDS -PASSED 3/26/08 TIFL-(INCONCLUSIVE); MV PT/DD-(PASSED); SV DD-(PASSED); (PRE CTD). 4/1/08 TIFL -PASSED 4/5/08 ENCOUNTERED THICK CRUDE /ASPHALTENES BETWEEN 2344' & 2471' SLM. UNABLE TO DRIFT WITH 2.5" BAILER, RECOVERED SAMPLE. DISPLACE TBG WITH 95 BBL HOT DSL. 4/6/08 GAUGED TBG TO 2.77" TO 7000' SLM' BRUSH & FLUSH SCALE FROM GLMs. PULLED OV @ 6978' &GLV @ 5220' RKB. ATTEMPTED PULL DV @ 6221' RKB. SET 3/16" OV @ 6978' RKB. LIB'd GLM @ 6221', VERIFIED DV IN POCKET. 4/7/08 PULLED GLV C 2461' RKB & DVs C 4006' & 6221' RKB. SET GLVs C~1 6221', 5220, 4006' & 2461' RKB. 4/8/08 RAN HOLEFINDER, TESTED TBG &GLVs, GOOD TEST. JOB COMPLETE. 4/10/08 RE-TIFL (PASSED ). 5/11/08 DRIFT TBG WITH 15'_X 2..77". DMY GUN TO 8307 RKB. SET 2.79" CATCHER @ 8281' SLM. DRIFT TBG TO 1.82" TO 8788' SLM. PULLED ORIFICE @ 6979' RKB (OV PLUGGED WITH ASPHALTENES). PULLED GLV @ 5220' RKB. RECOVERED SAMPLE. 5/12/08 PULLED GLV @ 2461' RKB. REPLACED WITH DMY VLV. DROPPED DMY VLV WHILE TRYING TO SET @ 5220' RKB. SWEPT TBG WITH 2.60" BELL GUIDE & PULLING TOOL TO TOP OF CATCHER @ 8281' SLM. TBG CLEAR TO CATCHER. 5/13/08 RETRIEVED DMY VLV FROM CATCHER @ 8281' SLM. SET LIGHT DMY VLV's @ 5220' & 6978' RKB's. LOAD IA WITH DIESEL & ATTEMPT MITIA. FAILED. IA ON VAC. CHECK SET STA #1, #3 & # 5. VLV'S IN POCKET. 5/14/08 SHOT FLUID LEVEL IN IA @ 528'. RAN HOLE FINDER & TESTED TBG C~ 7008' SLM. PASSED. RAN TEST TOOL TO 7050' SLM. FAILED. PASSED @ 7020' SLM. ESTABLISHED INJECTIVITY RATE OF 1.5 BPM @ 440# DWN IA. NO CHANGE IN TBG/ OA PRESSURES. 5/15/08 RAN TEST TOOL TO 7085' SLM. TESTED TBG TO 500#. PASSED. SET 2.79" CATCHER SUB C 8281' SLM. PULL LGLV @ 6221' & 4006' RKB. REPLACE WITH LIGHT DMY VLV's. PULL CATCHER SUB @ 8281' SLM. MITIA TO 3000#. PASSED. JOB COMPLETE. 5/16/08 CUT THE 2 3/8" SLOTTED LINER AT 8725' WITH A 1 11/1.6"C'H MIC:A CUTTER. SEVERING HEAD LOOKED GOOD AT SURFACE. 5/17/08 RIH WITH BAKER 3" G SPEAR AND LATCHED TOP OF LINER @ 8306' CTMD. PUH AND FOUND THAT LINER WAS NOT CUT, PULLED 15K OVER STRING WEIGHT AND STARTED JARRING. AFTER THREE JAR LICKS SEEM GOOD INDICATION THAT WE MOVED LINER. PUMP OFF FISH & NECK. POOH AND FOUND A 4" INCH SECTION OF THE FISHING NECK ON SPEAR. RDMO. JOB INCOMPLETE. 5/18/08 CUT THE 2 3/8" SLOTTED LINER AT 8715' WITH A 1 11/16" JET PowerCutter 5/19/08 SET BAITED BAKER SPEAR (3" BAIT SUB, X0, AND 2.023 SPEAR= 26 1/2" OAL) IN LINER TOP @ 8307' RKB. 6/6/08 SET C-SUB, PULLED DMYS @ 4006', 5220', 6221', 6978' RKB. 6/7/08 PULL DMY C 2461' RKB, SET GLV'S C«~ 2461', 4006', 5220', 6221' RKB, AND OV C~3 6978' RKB. 6/8/08 PULL C-SUB W/MISSING RK RUNNING TOOL INSIDE. PERFORMED 30 MIN SBHPS=2480 psi, 122 deg F. 15 MIN GRADIENT STOP MADE C~ 6936' RKB=2451 PSI. JOB COMPLETE. ~ ~ BP AMERICA Page 1 of 12 Operations Summary Report Legal Well Name: 2D-066 Common Well Name: 2D-06B Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To I'~ Hours li Task Code NPT 5/21/2008 00:00 - 04:30 4.50 MOB P 04:30 - 07:45 3.25 MOB P 07:45 - 14:45 7.00 MOB P 14:45 - 19:00 4.25 RIGU P 19:00 - 00:00 5.00 RIGU P 5/22/2008 00:00 - 06:45 6.75 RIGU P 06:45 - 13:15 I 6.501 BOPSUR P 13:00 - 13:15 0.25 BOPSUF~ P 13:15 - 14:30 1.25 BOPSU P 14:30 - 14:45 0.25 RIGU P 14:45 - 16:00 1.25 RIGU P 16:00 - 18:30 2.50 RIGU P 18:30 - 19:00 0.50 FISH P 19:00 - 20:00 1.00 FISH P 20:00 - 21:00 1.00 FISH P 21:00 - 22:45 1.75 FISH P 22:45 - 00:00 1.25 FISH P 5/23/2008 100:00 - 01:00 1.00 ~ FISH ~ P 01:00 - 03:15 I 2.251 FISH I P 03:15 - 03:30 0.25 FISH P 03:30 - 05:30 2.00 FISH P 05:30 - 08:30 3.00 EVAL N WAIT 08:30 - 08:45 0.25 CLEAN P Spud Date: 5/25/2008 Start: 5/21 /2008 End: 6/3/2008 Rig Release: 6/3/2008 Rig Number: Phase Description of Operations PRE Pull off of well and relocate to CPF3 and stop PRE Wait on field crew change. PRE Continue on from CPF3 to DS 2D. PRE Prep location, lay herculite, set rig mats, spot rig over well. 19:00 Rig accept time. PRE NU BOP stack, managed pressure loop. PU 2" E-free coil. PRE Continue with NU of BOP stack and Managed Pressure Loop. Install and test control lines for SSV on tree and wing. Change out pipe rams. Grease Mud Cross. PRE Test BOPE, Managed Pressure Drilling Loop, and Tiger tank hard line as per well plan and AOGCC reg's. AOGCC Witness waived by Bob Noble. PRE PJSM on pulling BPV PRE RU lubricator and pull BPV. 130 psi on the well when BPV was pulled. RD Lubricator PRE PJSM on Stabing injector and Stabing coil into injector. PRE PU injector, Pull test grapple connection on coil, Stab coil into injector. PRE Fill Coil and PT Inner reel valve and Packoff. DECOMP PJSM DECOMP Kill well with 160 bls seawater. 4.2 BPM at -400 WHP. Well went on a vacuum when pump was shut down. Keep hole full with charge pump accross tree. MU 2" kendal connector. Pull test to 45000 and PT 4000 psi. DECOMP PU Baker fishing string DECOMP RIH. Weight check at 8250, 18500 up, 13000 down DECOMP Tag fish at 8310'. PUH to confirm latch. Start jarring with 3000 overpull, straight pull to 32000 Increasing up weight 2000# increments to 18000 overpull jarring and 42000 over straight pull. After 22 jar hits with no movement, jars are going off before we get to 18000 overpull. Hold 42000 overpull and allow jars to cool down. DECOMP Continue jarring at 18000 over and pulling up to 42000 over. Up weight before latching into fish was 18500. and came up hole with weight at 21000 DECOMP POOH. At 515' hung up at nipple 10000 over pull up and 2-4000 down to get free. On fourth attempt pulled through and continued to surface DECOMP PJSM DECOMP Lay down fishing tools. Deployment sleeve at top of liner was severly coroded and the bait sub had been driven down into it. This is what caused the hang up at 515' nipple. Lay down 6 solid and 8 slotted joints of 2 3/8" liner and one 7.5' jet-cut joint. Solid liner had numerous holes eroded through it. Slotted liner in decent shape. Jet cut was complete - no tab hanging onto liner below. DECOMP Waiting on PDS. Shut well in, was taking 50 bbls/hour static with seawater. DECOMP Talked to town, decided to make cleanout run since it looks like Nnntea: w~ui~uuu a:~coo Hnn ~ ~ BP AMERICA Page 2 of 12 Operations Summary Report Legal Well Name: 2D-06B Common Well Name: 2D-06B Spud Date: 5/25/2008 Event Name: REENTER+COMPLETE Start: 5/21/2008 End: 6/3/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/3/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/23/2008 08:30 - 08:45 0.25 CLEAN P DECOMP solids were holding the fish in place. PJSM on RU jet nozzle BHA and Stabbing injector on well 08:45 - 09:15 0.50 CLEAN P DECOMP RU jet nozzle, stab on injector 09:15 - 11:20 2.08 CLEAN P DECOMP RIH, In Rate=.02 Out=O bbls/min Tag top of tubing stub at 8724' 11:20 - 12:35 1.25 CLEAN P DECOMP PU to 8000' and close choke, bullheading away. Pump rate= 2.95 bbls/min CP= 4000 psi Wash back down to 8720' from 8000' at 20 fUmin. Wash up from 8720' to 8000' at 30 fpm. Blead IA and OA down from 1000 psi / 390 psi to 24/95 psi. 12:35 - 13:30 0.92 CLEAN P DECOMP POOH keeping hole full WH Press=20psi IA=425 psi OA=180 psi 13:30 - 13:50 0.33 CLEAN P DECOMP PJSM while POOH on LD of nozzle and PU of PDS caliper tool. 13:50 - 14:00 0.17 CLEAN P DECOMP POOH. 14:00 - 14:45 0.75 CLEAN P DECOMP LD Nozzle BHA and PU PDS Caliper. 14:45 - 15:05 0.33 EVAL P DECOMP RIH with PDS caliper logging tool. 15:05 - 15:30 0.42 EVAL N HMAN DECOMP POOH at 1,600' after evaluating deployment timing of PDS tool to rest for more time. 15:30 - 15:55 0.42 EVAL N HMAN DECOMP Unstab injector, change out program sub of PDS tool with new timing set for 2 hours, Restab injector. Caliper should deploy at 17:45 15:55 - 16:15 0.33 EVAL N HMAN DECOMP RIH to 1600' MD 16:15 - 17:25 1.17 EVAL P DECOMP RIH to 8700' 17:25 - 17:50 0.42 EVAL P DECOMP Wait on Caliper deployment 17:50 - 18:10 0.33 EVAL P DECOMP Start to log up at 48 fpm from 8700'-7700' with In rate=1.51 bbl/min 18:10 - 19:45 1.58 EVAL P DECOMP POOH 19:45 - 20:00 0.25 EVAL P DECOMP LD caliper tools. Initial data from caliper shows good liner throughout logged interval. Whipstock setting area at 8650' looks good. 20:00 - 21:00 1.00 CHEM P DECOMP Prep to blow down coil. Pump 50 bbls. fresh water, 10 bbls. inhibited water and 5 bbls. methanol. 21:00 - 21:30 0.50 EVAL P DECOMP PJSM for N2 blowdown 21:30 - 22:00 0.50 GASN2 P DECOMP Rig up N2 unit and cool down 22:00 - 22:30 0.50 GASN2 P DECOMP Displace fluids from coil with 25000 SCF N2 22:30 - 00:00 1.50 DEMOB P DECOMP RD reel iron. Install grapple and tail coil to reel. Secure pipe and lower reel to trailer 5/24/2008 00:00 - 04:00 4.00 WHIP P WEXIT PU 2" E-Coil. MU hard line and grapple Pull coil across to injector 04:00 - 04:40 0.67 WHIP P WEXIT MU Kendal CTC and pull test to 40K 04:40 - 05:30 0.83 WHIP P WEXIT Behead a-line and test 05:30 - 06:15 0.75 WHIP P WEXIT Fill coil. 06:15 - 06:40 0.42 WHIP P WEXIT Crew change and walk a rounds. 06:40 - 07:15 0.58 WHIP P WEXIT Pressure test Hard line. Pressure test inner reel valve. rnntea: bisuizuuu `J3Z:bb HM i BP AMERICA Page 3 of 12 Operations Summary Report Legal Well Name: 2D-066 Common Well Name: 2D-06B Spud Date: 5/25/2008 Event Name: REENTER+COMPLETE Start: 5/21 /2008 End: 6/3/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/3/2008 Rig Name: NORDIC 2 Rig Number: Date From - To ', Hours Task Code NPT Phase Description of Operations 5/24/2008 06:40 - 07:15 0.58 WHIP P 07:15 - 08:00 0.75 WHIP P 08:00 - 08:20 0.33 WHIP P 08:20 - 08:40 0.33 WHIP P 08:40 - 09:25 0.75 WHIP P 09:25 - 12:00 2.58 WHIP P 12:00-12:55 0.92WHIP P 12:55 - 14:15 1.331 WHIP ~ P 14:15 - 15:50 1.58 WHIP P 15:50 - 16:00 0.17 WHIP P 16:00 - 16:55 0.92 WHIP P WEXIT Pressure test coil connecter. WEXIT PJSM on PU and Handling of Whipstock BHA. WEXIT Install check valves and change lubricator below injector. WEXIT Fill well and WO SLB pip tags. WEXIT Install pip tags and finish PU of Whipstock assembly. WEXIT RIH with WS. EDC open. Keeping hole full down BS with charge pump. In rate=1.76 no returns WEXIT Gamma ray Logging 8435'-8524.5'. -37 ft Correction. Casing Collar logging from 8524' to 8650'. WEXIT PU WT check. UP WT = 21,200 lbs. DWN WT = 11,500 lbs. RIH to 8650' top of whipstock PU to an UP WT of 20,200 lbs. Close EDC and filled coil at .8 bbl/min Pressure up coil to set Whipstock. In/out rate = .81 bbls/min. Pressure stabilized at 2200 psi. Packer appears to be set getting 1 for 1 returns in/out rate = 1.5/1.5 bpm ~ 2440 psi PT well and packer to 1000 psi. with 15 gsVmin bleed off WEXIT POOH while Circ with no losses. WEXIT PJSM on LD of BHA and PU of window milling BHA. WEXIT Lav down whipstock setting tool. Tool has stroked p PU window milling BHA. 16:55 - 18:30 1.58 STMILL P WEXIT RIH with milling BHA 1:1 returns while RIH at .3 BPM down coil 18:30 - 18:50 0.33 STMILL P WEXIT Tie in at 8450' -38.5' correction 18:50 - 19:15 0.42 STMILL P WEXIT Continue RIH Ta ed whi stock at 8704', indicated by weight and pressure increase 19:15 - 21:20 2.08 STMILL N DFAL WEXIT POOH while discussing options for second whipstock. Pressure up well to 1000 psi to establish loss rate. bled to 100 WHPin<10min. Attempt to establish rate, 0.1 - 0.2 BPM C~ 400WHP 21:20 - 21:40 0.33 STMILL N DFAL WEXIT Lay down milling BHA 21:40 - 23:00 1.33 STMILL N DFAL WEXIT Waiting on new whipstock and packer. Reconfigure lubricator. PT CTC and UOC to 4000 psi 23:00 - 23:30 0.50 WHIP N DFAL WEXIT Set up whipstock and packer. Install two PIP tags in whipstock. 23:30 - 00:00 0.50 WHIP N DFAL WEXIT PJSM for PU whipstock 5/25/2008 00:00 - 01:00 1.00 WHIP N DFAL WEXIT Assemble packer/WS. Install double PIP tags. PU BHA 01:00 - 02:30 1.50 WHIP N DFAL WEXIT RIH, circulate through open EDC 02:30 - 02:45 0.25 WHIP N DFAL WEXIT Log tie in, -4' correction. SLB had re-aligned the counter wheel on the injector prior to RIH. 02:45 - 03:30 0.75 WHIP N DFAL WEXIT RIH to 8657.65' bit depth, top of WS at 8645'. Orient to 180 deg for low side window Close EDC and slowly bring pressure up 200 psi per step. At 1200 psi setting tool sheared. Pflfltetl: 6/3V/2W8 y:J"L:DIi AM ~ ~ r,ZO BP AMERICA Page 4 of 12 Operations Summary Report Legal Well Name: 2D-06B Common Well Name: 2D-06B Spud Date: 5/25/2008 Event Name: REENTER+COMPLETE Start: 5/21/2008 End: 6/3/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/3/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 5/25/2008 02:45 - 03:30 0.75 WHIP N DFAL WEXIT Set down 4000#, pulled up clean. PT packer to 1000 WHP for 5 min. Holding good. 03:30 - 05:00 1.50 WHIP N DFAL WEXIT POOH, 1:1 returns 05:00 - 05:10 0.17 WHIP N DFAL WEXIT Lay down WS setting BHA 05:10 - 05:30 0.33 STWHIP N DFAL WEXIT PU window milling BHA with straight motor, 2.74 mi an 3 string reamer on BHI coiltrack TS. pp ~~pLl 05:30 - 07:00 1.50 STWHIP N DFAL WEXIT RIH circulating in 9.5 ppg 1# bio 07:00 - 07:15 0.25 STWHIP N DFAL WEXIT Log GR tie in from 8450'. Subtract 1' correction. 07:15 - 12:00 4.75 STWHIP P WEXIT RIH. Ta f 4 '.pumping (top of window). Be in time millin fro ' at 10 minutes per 0.1 ft. 1980 psi fs at 1.52 in/out. IA/OA/PVT: 146/168/ variable. WHP/BHP/ECD: 30/3119/10.29. Continue to displace well from seawater to 9.5 ppg 1 # biozan. Formation sand and metal observed in the returns. 12:00 - 14:00 2.00 STWHIP P WEXIT Continue to mill ahead at 8649'. DHWOB: 1.5-2.5k#. Continue to get metal and sand back to surface. Drilling break at 8650.4'. Call this the window bottom. Mill ahead in formation to 8660'. 14:00 - 14:30 0.50 STWHIP P WEXIT Back ream window several times to dress same. Dry drift window. Smooth. 14:30 - 16:30 2.00 STWHIP P WEXIT Circulate out of hole. 1250 psi ~ 1.11 bpm. 16:30 - 17:30 1.00 DRILL P PRODi Hold PJSM. At surface. Get off well. LD window milling motor and mill. Window mill gauged 2.74" going in, 2.73 no-go after run. MU 1.9 deg x-treme motor with rebuilt Hycalog bi-center bit. Stab coil. Test MWD tools. Get on well. 17:30 - 18:50 1.33 DRILL P PROD1 Run in hole. 18:50 - 19:15 0.42 DRILL P PRODi Tie in log at 8430', -3' correction 19:15 - 19:45 0.50 DRILL P PROD1 Ta botto t '. Start drilling ahead, still on BIO. Waiting on Flo-Pro 19:45 - 21:30 1.75 DRILL N WAIT PROD1 Waiting on Flo-Pro. Roads are in bad shape to to torrential rains. Original call out for trucks was 10:00 AM... 21:30 - 00:00 2.50 DRILL P PROD1 Flo-pro arrived, start pumping DH and continue drilling ahead. 1.65 BPM, 3750 freespin, 120E TF, -25 fph with 3K WOB Drilled to 8720' at midnight 5/26/2008 00:00 - 04:00 4.00 DRILL P PROD1 Continue drilling build section. 3825 freespin, 90L TF, 2-3K WOB at 4100-4300 psi, 12.2 ECD, -25 FPH Drilled to 8810', ROP increased at 8770' to 70+ FPH 04:00 - 04:24 0.40 DRILL P PROD1 Wiper to window 04:24 - 05:15 0.85 DRILL P PRODi Continue drilling, only getting 25 Deg. dog legs. Expected 35 deg. Drilled to 8839' Formation tops appear to be -10' higher than anticipated. Trip for AKO adjustment 05:15 - 05:45 0.50 DRILL P PROD1 Trip OOH for motor adjustment 05:45 - 06:10 0.42 DRILL P PROD1 Tie in from 8430'-8446', +1 correction. RIH and log RA marker at window 06:10 - 07:40 1.50 DRILL P PRODi POOH from 8446'-1800' following pressure schedule. 07:40 - 07:50 0.17 DRILL P PRODi PJSM on pressure undeployment of build BHA, while POOH 07:50 - 08:00 0.17 DRILL P PROD1 Continue to POOH to surface. Printed: 6/30/2008 9:32:56 AM BP AMERICA Page 5 of 12 ~ Operations Summary Report Legal Well Name: 2D-06B Common Well Name: 2D-066 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task Code NPT 5/26/2008 08:00 - 09:40 1.67 DRILL P 09:40 - 09:55 0.25 DRILL P 09:55 - 10:05 0.17 DRILL P 10:05 - 10:45 0.67 DRILL P 10:45 - 10:55 0.17 DRILL P 10:55 - 11:30 I 0.581 DRILL I P 11:30 - 12:15 I 0.751 DRILL I P 12:15 - 12:20 I 0.081 DRILL I P 12:20 - 12:40 I 0.331 DRILL I P 12:40 - 13:25 0.75 DRILL P 13:25 - 14:55 1.50 DRILL P 14:55 - 15:10 0.25 DRILL P 15:10 - 15:30 0.33 DRILL P Spud Date: 5/25/2008 Start: 5/21 /2008 End: 6/3/2008 Rig Release: 6/3/2008 Rig Number: Phase Description of Operations PROD1 Pressure undeploy build section BHA. PROD1 LD motor and change AKO settings from 1.9 deg. to 2.6 deg. PROD1 PJSM on pressure deployment procedures. PROD1 Pressure deploy 2.6 deg. AKO Build section BHA. PROD1 Unable to fit BHA through well head while pressure deploying. Stop, for PJSM on how to pick up part way through pressure undeploy procedure. PROD1 Pick up at step 24 of pressure undeploy procedure and lay down BHA. PRODi LD BHA and change out EDC, which failed due to lubricator overpressure during undeploy (human error). PROD1 PJSM on slowly reducing WH press and PJSM on PU of Build BHA without pressure deployment. PRODi Shut down MP 2 and allow wellhead pressure to stabilize through MI super choke with current set point of 700 Psi. Wait 10 min to allow slow bleed off of pressure. Open both swab valves and observe slow leak off of pressure. With wellhead pressure at 0, open up MI choke and flow check to verify well is dead. PROD1 Pick up build BHA with 2.6 deg. AKO and work through wellhead. Stab in injector. PROD1 RIH following pressure schedule. PROD1 GR tie in from 8424'-8449' with -4 ft correction. PROD1 continue to RIH Free spin 3550 psi ~ 1.4 bbls/min 15:30 - 16:50 1.33 DRILL P PROD1 Drillin at 8846' CP=3700 psi with in/out=1.40/1.40 bpm density in/out=9.53/9.59 ppg PV= 99 bbls and Centafuge on. Tool face=l l deg. left ECD=12.51 ppg and BHP = 3900 psi (no back pressure on the wellhead) ROP=1.4 fUmin or 85 fUhr Drilling ~ 8915' CP=3950 psi with in/out=1.5/1.5 bpm Density in out = 9.54/9.53 ppg PV=379 bbls (2/3/4/5 active) and centrafuge on. tool face 75 deg left ECD=12.5 ppg and BHP=3900 psi (no back pressure on wellhead) ROP=1.4 Wmin or 83 Whr 16:50 - 17:15 0.42 DRILL P 17:15 - 17:40 0.42 DRILL P PROD1 Wiper trip to Window at 8660 PROD1 Drilling ~ 8970' CP=3840 psi with in/out=1.5/1.49 bpm Density=9.53/9.66 ppg PV=384 bbls and centrafuge on. tool face 75 left ECD=12.48 ppg and BHP=3883 psi ROP=1.7 ft/min or 103 ft/hr rnmea: oiswzw~s x~z:oo Nnn ~ ~ BP AMERICA Page 6 of 12 Operations Summary Report Legal Well Name: 2D-06B Common Well Name: 2D-06B Spud Date: 5/25/2008 Event Name: REENTER+COMPLETE Start: 5/21/2008 End: 6/3/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/3/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase ', Description of Operations 5/26/2008 17:40 - 19:20 1.67 DRILL P PROD1 POOH to adjust to a lower AKO setting. Current AKO is resulting in too much dog leg severity. CP=3600 psi with in/Out=1.50/1.38 bpm density= 9.53/9.59 ppg 19:20 - 19:30 0.17 DRILL P PROD1 PJSM to lay down BHA 19:30 - 21:00 1.50 DRILL P PRODi Lay down BHA Adjust AKO setting to 1.7 deg. Replace o-rings in CoilTrak tools and test TS PU BHA 21:00 - 22:30 1.50 DRILL P PROD1 RIH following pressure schedule 22:30 - 23:00 0.50 DRILL P PROD1 Tie in at RA, -6' correction Continue RIH with open choke, 1.5 BPM, 3600 freespin, 12.55 ECD 23:00 - 00:00 1.00 DRILL P PROD1 1.5 BPM in, 1.49 out 3600 FS, 12.3 ECD, 3800-4000 CTP while drilling at 100 FPH 90L TF ROP decreased to <20 FPH at 8988' Midnight depth 8999' 5/27/2008 00:00 - 03:45 3.75 DRILL P PROD1 Continue drilling build section from 8999' 1.5 BPM in, 1.49 out 3625 FS, 12.3 ECD, 3800-3900 CTP at 4.5K WOB, -5 FPH 120E TF to drop 2' TVD 03:45 - 04:10 0.42 DRILL P PROD1 Drilling break, ROP increase to 75 FPH, 4000 PSI, 1.5K WOB 04:10 - 05:00 0.83 DRILL P PROD1 At 9030 well started to take fluid, 1.5BPM in , 1.3 out. PUH 50' and ease back down as losses heal up. Continue drilling ahead at 50 FPH 1.53 BPM in, 1.49 out 1.4K WOB, 80L TF, 3900-4000 CTP, 12.38 ECD 05:00 - 07:35 2.58 DRILL P PROD1 Continue drilling with full returns. Drilling at 9097' 1.5/1.5 bpm 3570 FS 33 WHP 3812 AP PV 390 WOB = 1860 Drilling break at 9130' 67 fph Land build section at 9130' MD. 07:35 - 09:00 1.42 DRILL P PROD1 POOH following pressure schedule. 09:00 - 09:15 0.25 DRILL P PROD1 While POOH PJSM on pressure undeployment procedures, and LD of BHA. 09:15 - 09:25 0.17 DRILL P PRODi Continue POOH while following pressure schedule. 09:25 - 10:50 1.42 DRILL P PROD1 Pressure undeploy and lay down build section BHA. 10:50 - 11:45 0.92 DRILL P PROD1 Change over from build section BHA to Lateral section BHA design with 1.1 deg AKO and res tool. 11:45 - 11:55 0.17 DRILL P PROD1 PJSM on PU and pressure deployment of Lateral section BHA with 1.1 deg AKO. 11:55 - 13:50 1.92 DRILL P PROD1 PU and pressure deploy lateral section BHA. 13:50 - 15:30 1.67 DRILL P PROD1 RIH following pressure schedule. 15:30 - 15:45 0.25 DRILL P PROD1 GR tie in at 8430' with -4 ft corection. 15:45 - 16:05 0.33 DRILL P PROD1 RIH to 8760' 16:05 - 17:20 1.25 DRILL P PROD1 MAD pass from 8760' to 9130' 17:20 - 20:15 2.92 DRILL P PRODi FS CP = 3700 psi ~ 1.49/1.61 bpm rrinieo: oiow~wa a:oc:oor~m ~ ~ BP AMERICA Page 7 of 12 Operations Summary Report Legal Well Name: 2D-06B Common Well Name: 2D-066 Spud Date: 5/25/2008 Event Name: REENTER+COMPLETE Start: 5/21/2008 End: 6/3/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/3/2008 Rig Name: NORDIC 2 Rig Number: Date I From - To Hours ' Task Code NPT Phase Description of Operations 5/27/2008 17:20 - 20:15 2.921 DRILL P 20:15 - 22:00 I 1.751 DRILL I P 22:00 - 00:00 ~ 2.00 DRILL P 5/28/2008 100:00 - 01:35 1.581 DRILL P 01:35 - 03:45 I 2.171 DRILL I P 03:45 - 04:00 0.25 DRILL P 04:00 - 05:15 1.25 DRILL P 05:15 - 06:00 0.75 DRILL P 06:00 - 06:15 0.25 DRILL P PROD1 Drillin ~ 9 CP=3820 psi ~ 1.49/1.50 bpm Density= 9.52/9.56 ppg (centrafuge on) ECD= 12.33 with BHP=3843 psi and WHP=33 psi (choke full open) PV = 365 bbls TF= 50 deg Left, DH WOB=3230 lbs. CT WOB=4500 lbs. near bit depth 9124' and near bit inclination 86.46 deg. ROP=O fpm 5 fph PROD1 Back to 80-100 FPH, 2K WOB with good weight transfer 3600 FS, 3800-3900 CTP, 1.51 in/1.50 out, 12.33 ECD 70L TF, PROD1 Ankerite stringers. Geo wants to go down to get below them. 130E TF Midnight depth 9212' PROD1 Continue drilling lateral 3550 FS, 3800 psi at 2K WOB, 70 FPH, 12.35 ECD, 120E TF PROD1 POOH for AKO adjustment from 1.1 to 0.9, DLS at 17-19, target for this section was 10-12. Follow MPD schedule while POOH PJSM while POOH for pressure un-deploy PRODi Tag up, RIH and PUH to tag at full pump rate. PROD1 Pressure un-deploy following procedure (revision 4-23-2008) RIH 2.8' from tag to position tool for BOP ram closure. PROD1 Adjust AKO to 0.9, change out bit, PROD1 Pressure deploy lateral BHA with 0.9 AKO. 06:15 - 06:35 0.33 DRILL P PROD1 Crew change and PJSM for pressure deployment of BHA 06:35 - 07:50 1.25 DRILL P PROD1 Ressume pressure deployment 07:50 - 09:25 1.58 DRILL P PROD1 RIH with lateral BHA following pressures schedule. 09:25 - 09:45 0.33 DRILL P PROD1 GR tie in ~ 8430' to 8473'. Correction of -8 ft. 09:45 - 10:20 0.58 DRILL P PROD1 Continue to RIH from 8465' 10:20 - 12:15 1.92 DRILL P PROD1 FS 3640psi C~3 1.50 bpm ' ROP=1.7 fpm or 101 fph CP=3900psi ~ 1.50/1.51 bpm Density=9.5/9.53 ppg ECD=12.34 & BHP=3849 psi PVT=345 bbls DH WOB=1450# CT WOB=3100# TF is 80 deg Left. near bit incl. 91.62 deg. 12:15 - 13:15 1.00 DRILL P PROD1 Short trip to 8850' MD and back to 9500'. 13:15 - 15:05 1.83 DRILL P PROD1 FS = 3550 psi ~ 1.50 bpm Drilling ~ 9535' ROP=1.5 fpm or 91 fph CP=3770 C~3 1.50/1.50 bpm density= 9.50/9.53 ppg (centrifuge is on) ECD=12.37 ppg BHP=3854psi Tool face= 60 deg Left w/ near bit inclination = 91.15 deg. DH WOB=1300# CT WOB=3200# 15:05 - 16:05 1.00 DRILL P PROD1 Short trip to 8850' tight spot ~ 9210' & 9512' while RIH. 16:05 - 17:50 1.75 DRILL P PRODi FS = 3550 psi ~ 1.5 bpm rnntea: oituieuuts `J::SL:bb HM BP AMERICA Page 8 of 12 Operations Summary Report Legal Well Name: 2D-06B Common Well Name: 2D-06B Spud Date: 5/25/2008 Event Name: REENTER+COMPLETE Start: 5/21/2008 End: 6/3/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/3/2008 Rig Name: NORDIC 2 Rig Number: Date ~i From - To Hours Task Code NPT Phase Description of Operations __ -._ . 5/28/2008 ~ 16:05 - 17:50 1.75 ~ DRILL P PROD1 Drilling ~ 9660' Rop=1.3 fpm or 80 fph CP=3720 C~? 1.5/1.5 bpm Density=9.48/9.53 ppg w/ centrifuge on PV= 355 bbls ECD=12.3 ppg BHP=3836 psi TF= 85 deg Left w/ NB Incl.=92.8 deg DH WOB= 1250# CT WOB=3850# 17:50 - 18:30 0.67 DRILL P PROD1 Wiper trip to window. 18:30 - 18:45 0.25 DRILL P PROD1 Tie in at RA, +1' 18:45 - 19:15 0.50 DRILL P PROD1 Wiper in hole, hole is in good shape. 19:15 - 20:25 1.17 DRILL P PROD1 Continue drilling 3700-3850 CTP at 80-100 FPH, 1.5K WOB, 12.5 ECD for 3900 AP at tool 20:25 - 21:00 0.58 DRILL P PROD1 Start mud swap 21:00 - 22:30 1.50 DRILL P PROD1 Wiper trip from 9950' to window, clean hole. 22:30 - 00:00 1.50 DRILL P PROD1 Continue drilling, new mud all around 3500 FS, 3800-3900 CTP, 1.46/1.46, 1.5-2.OK WOB, 12.37 ECD ',5/29/2008 100:00 - 01:00 1.001 DRILL ~ P 01:00 - 02:30 1.50 DRILL P 02:30 - 05:15 2.75 DRILL P 05:15 - 07:25 2.17 DRILL P 07:25 - 10:25 3.00 DRILL P 10:25 - 12:40 i 2.25 ~ DRILL ~ P 12:40 - 13:20 0.671 DRILL ~ P 13:20 - 14:00 0.671 DRILL P PROD1 Continue drilling lateral 3550 FS, 3800 CTP, 1-2K WOB, 1.54/1.55, 12.56 ECD PROD1 Wiper from 10100' to window, cleanhole. PROD1 Continue drilling 3650 FS, 3900-4000 CTP, 1.5-2.5 WOB, 80-100 FPH, 1.54/1.54, 12.5 ECD Drilled to 10250' PRODi Wiper trip from 10250' to window with tie-in. +3 ft PROD1 FS=3675 psi Drilling l~ 10,355' w/ 1 fpm CP= 3900 w 1.53/1.54 bpm Density= 9.5/9.33 Centrifuge ON ECD= 12.79 BHP=3955 psi DH WOB=1000# CT WOB=7700# CT WT= -3700# drilled from 10,250' to 10,400' MD PROD1 short trip from 10,400' to 8,850' MD While picking up, SLB depth encoder failed. Tagged bottom and reset. "Tight" spots at 9470' & 10,200' & 10,370' MD PROD1 FS=3600 psi ~ 10,456 MD still RIH at 13.6 ftm and no motor work. TAG bottom C~ 10,464' reset SLB coil depth to 10,400' MD. PU off bottom and retie in Baker MWD. Tight spots RIH @ 10,060' MD, 10,100' MD TAG btm ~ 10,400' MD PROD1 FS=3800 psi C~ 1.58 bpm Drilling ~ 10,405'MD ROP=.9 fpm or 54 fph CP=3800 ~ 1.58/1.56 bpm Density= 9.5/9.53 ppg Centrifuge ON rnrnea: wsur~uun a:~coo rim ~ ~ BP AMERICA Operations Summary Report Legal Well Name: 2D-066 Common Well Name: 2D-066 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 i Date From - To '~ Hours Task Code NPT 5/29/2008 13:20 - 14:00 I 0.67 DRILL P 14:00 - 14:15 I 0.251 DRILL I P Start: 5/21 /2008 Rig Release: 6/3/2008 Rig Number: Page 9 of 12 ~ Spud Date: 5/25/2008 End: 6/3/2008 Phase ~, Description of Operations PROD1 PROD1 14:15 - 14:35 0.33 DRILL P PROD1 14:35 - 15:10 0.58 DRILL N RREP PROD1 15:10 - 17:30 2.33 DRILL N RREP PROD1 17:30 - 20:45 3.25 DRILL P PROD1 20:45 - 23:30 2.75 DRILL P PROD1 23:30 - 00:00 0.50 DRILL P PROD1 5/30/2008 00:00 - 01:30 1.50 DRILL P PROD1 01:30 - 02:10 0.67 DRILL P PROD1 02:10 - 03:00 0.831 DRILL P PROD1 03:00 - 05:05 ~ 2.08 ~ DRILL ~ P ~ ~ PROD1 05:05 - 08:30 3.42 DRILL P PROD1 08:30 - 11:00 2.50 DRILL P PROD1 11:00 - 15:10 ~ 4.17 ~ DRILL ~ P ~ ~ PROD1 ECD=12.40 ppg BHP=3840psi PV=367 bbls DH WOB=1250# CT WOB=11,640# CT WT= -6700# TF=90 RT w/ NB INCL. 92.38 deg. Drilled from 10,400' to 10,426.5' PU short trip and re log for better Baker MWD tie in. PU to 10,380' and log down Found bottom were we left it at 10,426.5' MD and continue to ririll ahaarl to 10d3q.d'MD Lost power to SLB hydraulic power pack, MP 1 and MP 2. Generators are out of sync but running. Reset SCR power supply breaker. Unable to determine what caused breaker to trip, but appears to be working OK. Wiper trip to window and tie in. with a +7 ft correction. Drilling C~? 10,452' ROP=0.7 fpm or 41 fph CP=3700 psi ~ 1.5/1.5 bpm Dens=9.48/9.42 ppg ECD=12.72 ppg BHP=3935 PV=364 bbls DH WOB=800# CT WOB=8080# CT WT= -3400 # TF=60 RT NB Incl.=92.07 deg Drilled from 10,439' to 10513' Drilled into shales, rolled tool face to 145R to drill back down. 3800- 4000 CTP ~ 1.54 in / 1.55 out, 9.47 PPG, 12.46 ECD, 1.5K WOB Drilled from 10513' to 10600' Wiper trip from 10600' to window Continue wiper trip from 10600' to window Tag bottom and continue driling ahead 3600 FS at 1.55 in / 1.54 out, 12.47 ECD Drilling at 3800-3900 CTP, 1-1.5K WOB, -75 FPH Still dropping angle Slight over pull and stacking while tripping past 10350' Stack weight at 10580' while running in. Resume drilling at 10639', 3620 FS at 1.55 in/1.54 out, 12.46 ECD 3800 CTP, 1-1.5K WOB, 100 FPH 330 TF to build angle Drilled from 10600' to 10751' Wiper trip to window from 10751' FS=3400 psi ~ 1.4 bpm Drilling ~ 10,786' ROP=.6 fpm or 34 fph CP=3550 l~ 1.38/1.36 bpm BHP=3873 PSI DH dif Press=492 psi ECD=12.54 ppg DH WOB=1080# CT WOB=11,540# CT WT= -6600# PV=318 bbls Drilled from 10,751' to 10855' MD After drill of ~ 10,855'MD, PU for short trip to 10770'. Unable to get good weight transfer. Wiper trip to 6,600' MD. Nnntea: a~wzuua a:~coo HM i • BP AMERICA Page 10 of 12 Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: Date I From - To 5/30/2008 - ~ 11:00 - 15:10 15:10 - 18:45 18:45 - 21:45 21:45 - 00:00 5/31 /2008 ~ 00:00 - 01:55 01:55 - 05:00 05:00 - 07:20 07:20 - 10:05 2D-06B 2D-06B Spud Date: 5/25/2008 REENTER+COMPLETE Start: 5/21/2008 End: 6/3/2008 NORDIC CALISTA Rig Release: 6/3/2008 NORDIC 2 Rig Number: Task Code NPT Phase Description of Operations Hours 4.17 DRILL P 3.58 DRILL P 3.00 DRILL P 2.25 DRILL P 1.92 DRILL P 3.08 DRILL P 2.33 DRILL P 2.75 DRILL N PROD1 PROD1 PROD1 PROD1 PROD1 PRODi PROD1 RREP PROD1 10:05 - 10:50 0.75 DRILL P PROD1 10:50 - 11:05 0.25 BOPSU P PRODi 11:05 - 11:15 0.17 DRILL P PROD1 11:15 - 12:35 1.33 DRILL P PROD1 12:35 - 14:15 1.67 DRILL P PROD1 14:15 - 14:25 0.17 DRILL P PROD1 14:25 - 16:25 I 2.001 DRILL I P I I PRODi pumped 10 bbl high vis sweep X6,600' GR tie in ~ 8,670 to 8,688' Correction=+5 ft. "tight" spot 10,110' Drilling ~ 10,860' ROP=.5 fpm or 30-40 fph CP=3350 psi ~ 1.44/1.44 bpm density=9.53/9.50 ppg ECD=12.56 ppg BHP=3888 psi. DH WOB=1260# CT WOB=10,300# CT WT= -5150# TF=75 deg Left NB Incl. 95.54 deg. Drill to 11000' Wiper from 11000' to window. Continue drilling from 11000' 3460 FS, 1.54 in / 1.55 out, 9.55 ppg in/ 9.6 out, 12.47 ECD 3850 psi AP 3550-3600 CTP at 0.6K - 1 K WOB (-7500 Coil wt.) 85R TF, 90.72 NBI, trying to hold 90 deg. 25-45 FPH Drilled to 11060' Continue drilling lateral from 11060' 3650 FS at 1.61 in/ 1.61 out, 9.55 ppg in / 9.54 out, 12.5 ECD 3800 CTP, 0.5K - 1 K WOB, -9000 coil wt., 25-30 FPH 75 R to maintain 90 deg. Drilled to 11,101' ROP has slowed to around 20 FPH and requires 100' PU to maintain WOB POOH to PU agitator PJSM for pressure un-deploy in Ops. cab while POOH Pressure un-deploy BHA Crew change and walk arounds. Continue with Undeployment. Found kink in wireline. Change wire on wire line unit. Clean and reinstall CT counter system on injector. Change broken spring on Mud shaker. Ressume pressure undeployment of BHA. BOP function test. PJSM on pressure deployment procedures and hazards. Pressure deploy lateral BHA #3 with 0.9 AKO and new HYC bit RIH following pressure schedule. GR tie in at RA 8,675' to 8,698' -4 Correction. Continue RIH. Tight hole conditions starting at 10,400' MD. Stacking out with little WOB at 10,566' MD. Short trip to 10,240' MD. Saw a weight bobble at 10,330' MD while pulling up for short trip Tight again but improvement starting at 10,600' MD and improving after reducing pump rate to .5 bpm. Continue RIH with 1.40 bpm (with pump rate up increase in surface wt was -3000 #'s) Current CT WT= -6700 #'s ~ 10,800' MD . Printetl: ti/;3U/LUUri `J::iL:Sti AM BP AMERICA Page 11 of 12 Operations Summary Report Legal Well Name: 2D-06B Common Well Name: 2D-06B Spud Date: 5/25/2008 Event Name: REENTER+COMPLETE Start: 5/21/2008 End: 6/3/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/3/2008 Rig Name: NORDIC 2 Rig Number: Date From - To .Hours Task Code NPT Phase Description of Operations 5/31/2008 116:25 - 20:30 I 4.081 DRILL I P I I PROD1 20:30 - 00:00 I 3.501 DRILL I P I I PROD1 6/1/2008 100:00 - 06:30 6.501 DRILL P PROD1 06:30 - 09:45 3.25 DRILL P PROD1 09:45 - 10:00 0.25 DRILL P PROD1 10:00 - 11:30 1.50 DRILL P PROD1 11:30 - 12:30 1.00 DRILL P PROD1 12:30 - 14:30 I 2.001 DRILL I P I I PROD1 14:30 - 16:45 2.25 DRILL P PROD1 16:45 - 18:30 1.75 DRILL P PROD1 18:30 - 19:00 0.50 DRILL P PROD1 19:00 - 20:45 1.75 DRILL P PROD1 20:45 - 21:00 0.25 DRILL P PROD1 21:00 - 21:45 0.75 DRILL P PROD1 21:45 - 23:00 1.25 CASE P LNR1 23:00 - 23:20 0.33 CASE P LNR1 23:20 - 00:00 0.67 CASE P LNR1 6/2/2008 00:00 - 02:30 2.50 CASE P LNR1 02:30 - 03:30 1.00 CASE P LNR1 03:30 - 05:50 2.33 CASE P LNR1 05:50 - 07:00 1.17 CASE P LNR1 07:00 - 07:10 I 0.171 CASE I P I I LNRi 07:10 - 08:00 I 0.831 CASE I P I I LNR1 Drilling ~ 11102' ROP=.6 fpm or 34fph CP=3950 ~ 1.31/1.31 bpm density=9.55/9.46 ppg ECD=12.63 ppg BHP=3905 psi Delta P=1117 psi DH WOB=1780# CT W06=11,855# CT WT= -7100# TF=120 RT & NB Inclination=91.61 deg. Drilled from 11,101 ft to 11,222' Wiper trip from 11222' to window motor work decresed to zero, after 3 attempts at pulling up hole and running back to bottom, ending up higher all the time, decided to wiper trip to window While running back in hole RIH speed had to be reduced to maintain forward progress from 10300', slowed to 5-10 FPM. Adding lubricants to mud. Continue drilling from 11222' 4000 FS at 1.34 in / 1.33 out, 9.54 in / 9.56 out 4100 CTP with 0.5 - 1 K WOB, 20 - 40 FPH, CT weight -10000 94 Deg NB inclination. Drill to 11,337'. Wiper trip to 6600'. 4043 psi fs at 1.34 in. PVT: 241 bbls. Log GR tie in across RA tag. Add 14' correction. Continue to RIH. Reduce circ rate from 10,400' to btm (0.32 bpm) Drill to 11,350'. Unable to drill anv further. Up to 50k# up weight picking up off btm. Call this TD. Wiper trip back to window. KWF and liner pill on the way from AES yard. Wiper trip back to bottom. POOH while laying in new 9.5 ppg FloPro with 2 ppb Alpine beads. 8630', Circulate 12.5 formate brine maintaining 3900 BHP POOH, circulating 12.5 formate brine across tree. PJSM, flow check well, no flow. Lay down drilling BHA Set up Inteq BHA for liner run, RU floor equipment. PJSM for running liner PU liner strina PU liner string Test CTC to 4000 psi PU inteq BHA PU injector and MU OC, test Inteq tools RIH with lower oortion of liner Wt. check at 8600', 21400 up and 10000 down Tagged bottom at 11340' uncorrected. Repeated tag two more times. Release from liner- GRTie in accross RA tag. + 10 ft correction. Correct bottom of lower liner section is 11.350'~en_ Correct ton of lower liner section is 9.673' MD. Continue to POOH Printed: 6/30/2008 9:32:56 AM BP AMERICA Page 12 of 12 Operations Summary Report Legal Well Name: 2D-06B Common Well Name: 2D-06B Spud Date: 5/25/2008 Event Name: REENTER+COMPLETE Start: 5/21/2008 End: 6/3/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/3/2008 Rig Name: NORDIC 2 Rig Number: Date 'From - To Hours Task Code NPT Phase Description of Operations 6/2/2008 08:00 - 08:10 0.17 CASE P LNR1 PJSM on unstabing injector and LD of Inteq tools 08:10 - 08:30 0.33 CASE P LNR1 LD Inteq tool and orginized liner to running order. 08:30 - 08:45 0.25 CASE P LNR1 PJSM on MU of Liner. 08:45 - 09:40 0.92 CASE P LNR1 MU liner assembly 2 09:40 - 09:45 0.08 CASE P LNR1 Kick while tripping Drill 09:45 - 10:45 1.00 CASE P LNR1 Continue to MU liner assembly 2 10:45 - 11:10 0.42 CASE P LNR1 PU Inteq tools Stab in injector 11:10 - 13:00 1.83 CASE P LNRi RIH with liner ss Pump min rate. EDC - Glossed. WT check Up WT = 21,500# DN WT = 11,000# 13:00 - 13:10 ~ 0.17 ~ CASE ~ P ~ ~ LNR1 13:10 - 14:30 1.33 CASE P LNR1 14:30 - 14:40 0.17 CASE P LNRi 14:40 - 15:35 0.92 CASE P LNR1 15:35 - 17:05 1.50 RIGD P POST 17:05 - 17:40 0.58 RIGD P POST 17:40 - 19:55 2.25 RIGD P POST 19:55 - 20:10 0.25 RIGD P POST 20:10 - 21:30 1.33 BOPSU P POST 21:30 - 21:45 0.25 BOPSU~ P POST 21:45 - 22:15 0.50 RIGD P POST 22:15 - 00:00 1.75 WHSUR P POST 16/3/2008 00:00 - 00:30 0.50 BOPSU~ P 00:30 - 05:30 5.00 BOPSU P 05:30 - 05:45 ~ 0.25 ~ RIGD ~ P UP WT = 28,200# Tag again ~ 9673' Pump Max rate of CP=4300 psi ~ 1.28 bpm PU and UP WT= 19,000# Liner is released from GS Soear. Top of liner is at 8624 ft MD. POOH PJSM on LD of Inteq tools and MU of nozzel assembly. Unstab injector, LD Inteq tools, PU nozzel, and restab injector. RIH to 8620' with Nozzel. at 8620' and displacing out 12.5 ppg formate brine with 20 bbls FloViss spacer followed by 8.4 ppg sea water. POOH to 2500' MD to Freeze protect. • Pumped 22 bbls diesel PJSM Blow down reel with N2 Blow down surface lines Bleed down reel PJSM for BPV Remove injector from well and set on legs PU Lubricator and tools for BPV Bleed off surface pressure and confirm BPV is holdin RD lubricator and valve tools POST PJSM, clean pits/ND BOP POST Cleaning pits, loading trailers and ND BOP Prep satelite camp for move and leave location at 0400 hrs PT tree cap at 4000 psi POST Safety mtg re: move off well Additional daily Operational comments will be found under 1 D-04 Printetl: 6/30/2008 9:32:5ti AM ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 2D Pad 2D-06 2D-066L1 Design: 2D-06BL1 Baker Hughes INTEQ Survey Report 18 June, 2008 ~~~r BAKER H~I~HE$ INTE+~ • ConocoPhillips Alaska Company: ConocoPhdlips(Alaska) Inc Project: Kuparuk River Unit Site: Kuparuk 2D Pad Weil: 2D-O6 Wegbore: 2D-O68L1 Design: 2D-06BL1 ConocoPhillips sAI~sR Baker Hughes INTEQ Survey Report IIYGF~ INTEQ Local Co•oMinate Reference: Well 2D-06 ND Reference: Mean Sea-Level MD Reference: 2D-06A: ~ 121.OOft (2p-06A:} North Reference: True Survey Calculation Method: Minimum Curvature Database: EDMv16 Prod Project Kuparuk River Unit, North Slope Alaska Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone• Alaska Zone 04 Using geodetic scale facer ., Site Kuparuk 2D Pad Site Position: Northing: 5,954,045.13 ft Latitude: 70° 17' 7.882 N From: Map Easting: 529,129.90 ft Longitude: 149° 45' 51.288 W PosMlon Uncertainty: 0.00 ft Slot Radius: Grid Convergence: 0.22 ° •i WeQ 2D-06 Well Position +WS 0.00 ft Northing: 5,954,323.07 ft Latitude: 70° 17' 10.611 N +E/-W 0.00 ft Easting: 529,254.76 ft LongiWde: 149° 45' 47.619 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft WeUbore 2D-06BL1 1lagnetics Model Name Sample Date Declination Dip Angle Field Strength 1°! 1°- lnTl BGGM2007 4/15/2008 17.76 79.71 57,267 Design 2D-06BL1 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,642.00 YsRlcal Sectbn: Depth From (TVD) +NI-S +E1-W Direction (~) lft) tft- (°1 0.00 0.00 0.00 185.00 •I 6/18/2008 11:36:31AM Page 2 COMPASS 2003.16 Build 42F ~--' ConocoPhillips sw ~R~r ConocoPhillips Baker Hughes INTEQ Survey Report I~~s Alaska INTEQ Company: ConocoPhillips(Alaska) Ina Local Co-ordinate Reference: Well 2D-06 Project: Kuparuk River Unit ND Reference: Mean Sea Level Site: Kuparuk 2D Pad. MD Reference: 2D-06A: ~ 121:OOft (2D-06A;) WeN: 2D-06 North Reference: True Welibore: 2D-06BL1 Survey Calculation Method: Minimum Curvature. Design: 2D-06BL1 Database: EDMv16 Prod Survey Program From (ft) 195.00 7,205.00 8,646.00 Date To (ft) Survey (Wellbore- 7,200.00 2D-06 (2D-06) 8,642.00 2D-06A (2D-06A) 11,350.00 2D-06BL1 (2D-066L1) Tool Name GCT-MS MWD MWD DescrlpUon Schlumberger GCT multishot MWD -Standard MWD -Standard Survey MD Inc Azi NDSS WS E/y11 Northing Fasting DLS Vortical Section TFO ~ (ft) t°- (°- (ft) Ift) tft) (ft- (ft) 1°HO0ft) (tq 1°) 8,642.00 49.97 349.58 5,868.77 3,946.02 3,580.12 5,958,282.60 532,819.15 3.05 -4,243.03 80.53 8,646.00 49.93 349.64 5,871.34 3,949.03 3,579.57 5,958,285.61 532,818.59 1.52 -4,245.99 131.07 8,675.42 44.62 341.12 5,891.32 3,969.92 3,574.19 5,958,306.47 532,813.13 27.87 -4,266.32 -133.14 8,711.20 46.17 330.11 5,916.48 3,993.04 3,563.68 5,958,329.54 532,802.52 22.31 -4,288.44 -82.72 8,740.81 50.85 322.89 5,936.11 4,011.47 3,551.41 5,958,347.93 532,790.19 24.14 -4,305.74 -51.57 8,778.46 56.77 313.15 5,958.36 4,033.94 3,531.06 5,958,370.32 532,769.76 26.11 -4,326.34 -55.98 8,810.22 62.68 305.77 5,974.38 4,051.31 3,509.89 5,958,387.60 532,748.51 27.35 -4,341.80 -49.08 8,838.92 69.27 301.30 5,986.07 4,065.75 3,488.04 5,958,401.96 532,726.61 27.00 X1,354.28 -32.72 8,866.71 81.72 297.58 5,993.01 4,078.93 3,464.65 5,958,415.04 532,703.17 46.63 -4,365.37 -16.64 8,895.62 88.93 289.24 5,995.37 4,090.35 3,438.24 5,958,426.36 532,676.73 38.05 -4,374.44 -49.47 8,928.67 90.31 270.80 5,995.59 4,096.07 3,405.84 5,958,431.95 532,644.30 55.95 -4,377.32 -85.82 8,958.33 89.63 255.29 5,995.61 4,092.49 3,376.49 5,958,428.26 532,614.97 52.34 -4,371.20 -92.50 8,988.27 89.26 240.82 5,995.90 4,081.33 3,348.79 5,958,416.99 532,587.32 48.34 -4,357.67 -91.53 9,021.54 87.05 231.94 5,996.97 4,062.94 3,321.13 5,958,398.50 532,559.73 27.49 -4,336.94 -104.10 9,052.68 87.48 223.08 5,998.46 4,041.95 3,298.22 5,958,377.42 532,536.90 28.45 -4,314.03 -87.44 9,089.79 88.90 211.29 5,999.64 4,012.46 3,275.84 5,958,347.84 532,514.64 31.98 -4,282.69 -83.34 9,121.56 86.74 201.98 6,000.85 3,984.11 3,261.62 5,958,319.44 532,500.54 30.06 -4,253.22 -103.22 9,150.09 88.89 197.00 6,001.94 3,957.24 3,252.12 5,958,292.54 532,491.14 19.00 -4,225.63 -66.74 9,179.03 88.71 191.78 6,002.55 3,929.23 3,244.93 5,958,264.50 532,484.06 18.04 -4,197.09 -92.03 9,211.50 86.68 185.66 6,003.85 3,897.18 3,240.01 5,958,232.44 532,479.27 19.84 -4,164.73 -108.47 • 6/18/2008 11:36:31AM Page 3 COMPASS 2003.16 Build 42F ~/ ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Ina Protect: KuparukRivefUnit Site: Kuparuk 2D Pad Well: 2D-O6 Wallbore: 2D-06BL1 Design: 2D-086L1 Survey MD Ift) s,2ao.s2 9,272.77 9,301.26 9, 331.06 9,362.30 9, 391.99 9,427.75 9,462.49 9,490.87 9, 520.43 9,552.20 9, 587.64 9,619.95 9,652.30 9,680.96 9,711.52 9,744.66 9,774.90 9,805.19 9,839.32 9,871.52 9, 900.29 9,931.84 9,960.75 9,990.07 10,020.21 10,050.96 Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: ri.~ s~~~s INTEQ Well 2D-O6 Mean Sea Level. 2D-06A: (d1 121.OOft (2D-O6A:) True Minimum Curvature EDMv16 Prod Inc Azi NDSS N/S E/W Nortfiing Feeling DLS Vertical Section 'i'PO 1°- 1°- Iftl Ift1 lft1 (ft1 Iftl 1°nooft) Ift1 (°i 87.67 180.68 6,005.30 3,867.85 3,238.39 5,958,203.10 532,477.76 17.24 -4,135.37 -78.87 89.17 175.55 6,006.18 3,836.04 3,239.43 5,958,171.30 532,478.93 16.77 -4,103.78 -73.78 92.79 174.24 6,005.70 3,807.67 3,241.97 5,958,142.95 532,481.57 13.51 -4,075.74 -19.88 92.42 179.04 6,004.34 3,777.96 3,243.71 5,958,113.25 532,483.43 16.14 -4,046.29 94.30 91.41 179.10 6,003.30 3,746.74 3,244.22 5,958,082.03 532,484.06 3.24 -4,015.24 176.60 92.24 176.01 6,002.35 3,717.10 3,245.48 5,958,052.40 532,485.44 10.77 -3,985.82 -74.91 92.58 172.80 6,000.85 3,681.55 3,248.97 5,958,016.86 532,489.06 9.02 -3,950.70 -83.88 92.83 169.42 5,999.21 3,647.27 3,254.33 5,957,982.61 532,494.55 9.75 -3,917.02 -85.69 92.06 166.33 5,998.00 3,619.55 3,260.28 5,957,954.92 532,500.62 11.21 -3,889.93 -103.94 91.17 162.39 5,997.16 3,591.10 3,268.25 5,957,926.50 532,508.69 13.66 -3,862.28 -102.67 92.03 160.00 5,996.27 3,561.04 3,278.48 5,957,896.48 532,519.04 7.99 -3,833.23 -70.17 93.72 157.68 5,994.50 3,528.03 3,291.26 5,957,863.53 532,531.95 8.09 -3,801.46 -53.84 92.64 155.44 5,992.70 3,498.44 3,304.09 5,957,833.99 532,544.89 7.69 -3,773.10 -115.71 92.86 153.22 5,991.15 3,469.32 3,318.09 5,957,804.92 532,559.00 6.89 -3,745.31 -84.28 92.61 150.77 5,989.78 3,444.04 3,331.53 5,957,779.71 532,572.54 8.58 -3,721.30 -95.77 92.06 148.68 5,988.54 3,417.68 3,346.92 5,957,753.40 532,588.03 7.07 -3,696.37 -104.71 92.86 146.27 5,987.12 3,389.76 3,364.72 5,957,725.56 532,605.94 7.66 -3,670.12 -71.57 92.21 144.18 5,985.78 3,364.95 3,381.95 5,957,700.82 532,623.26 7.23 -3,646.90 -107.24 92.89 146.45 5,984.43 3,340.07 3,399.17 5,957,676.00 532,640.58 7.82 -3,623.61 73.26 92.03 149.76 5,982.97 3,311.12 3,417.18 5,957,647.13 532,658.70 10.01 -3,596.35 104.50 92.49 153.89 5,981.70 3,282.77 3,432.37 5,957,618.84 532,674.00 12.90 -3,569.42 83.56 92.64 157.08 5,980.41 3,256.62 3,444.30 5,957,592.74 532,686.02 11.09 -3,544.42 87.23 93.10 161.29 5,978.83 3,227.17 3,455.49 5,957,563.34 532,697.33 13.41 -3,516.06 83.65 92.94 161.38 5,977.30 3,199.82 3,464.73 5,957,536.03 532,706.68 0.63 -3,489.61 150.67 92.82 159.71 5,975.83 3,172.21 3,474.48 5,957,508.46 532,716.54 5.70 -3,462.96 -94.07 92.27 157.25 5,974.49 3,144.20 3,485.53 5,957,480.49 532,727.69 8.36 -3,436.02 -102.56 93.22 154.00 5,973.02 3,116.23 3,498.20 5,957,452.57 532,740.47 11.00 -3,409.26 -73.61 ConocoPhillips Baker Hughes INTEQ Survey Report • L. J 6/18/2008 11:36:31AM Page 4 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc. Protect: Kuparuk River Unit Site: Kuparuk 2D Pad WeB: 2D-06 Wallbore: 2D-068L1 Design: 2D-068L1 ConocoPhillips Baker Hughes INTEQ Survey Report ~.r s ~~s INTEQ Local Co-ordinate Reference: Well 2D-06 TVD Reference: Mean Sea Level MD Reference: 2D-06A: C~ 121.OOft (2D-06A:) North Reference: True Survey Calculation AAethod: Minimum Curvature Database: EDMv16 Prod $UNBy lND Inc Azl TVDSS N/S E/W Northing Eastlng OLS Vertical Section TFO Ift1 (°! 1°- (ft) Iftl Ift1 Iftl Ift! l°/toOQ- 1~1 1°- 10,080.21 94.49 150.69 5,971.05 3,090.38 3,511.75 5,957,426.78 532,754.11 12.10 -3,384.69 -68.86 10,109.93 91.96 148.13 5,969.38 3,064.84 3,526.84 5,957,401.31 532,769.31 12.10 -3,360.57 -134.63 10,140.15 92.03 146.08 5,968.33 3,039.49 3,543.25 5,957,376.01 532,785.81 6.78 -3,336.73 -88.01 10,170.24 92.73 149.36 5,967.08 3,014.07 3,559.30 5,957,350.67 532,801.96 11.14 -3,312.82 77.88 10,200.70 93.78 153.42 5,965.35 2,987.38 3,573.86 5,957,324.03 532,816.62 13.75 -3,287.49 75.37 10,230.01 94.02 156.47 5,963.35 2,960.89 3,586.24 5,957,297.60 532,829.10 10.41 -3,262.19 85.39 10,260.95 93.31 159.53 5,961.38 2,932.27 3,597.81 5,957,269.02 532,840.78 10.13 -3,234.68 102.99 10,292.15 92.27 162.39 5,959.86 2,902.81 3,607.97 5,957,239.61 532,851.06 9.74 -3,206.22 109.93 10,328.16 91.81 167.62 5,958.57 2,868.06 3,617.28 5,957,204.90 532,860.50 14.57 -3,172.42 94.93 10,363.15 90.95 172.48 5,957.73 2,833.62 3,623.32 5,957,170.48 532,866.67 14.10 -3,138.63 99.97 10,390.82 91.93 177.29 5,957.04 2,806.08 3,625.79 5,957,142.95 532,869.24 17.73 -3,111.41 78.43 10,420.42 92.39 180.31 5,955.92 2,776.51 3,626.41 5,957,113.39 532,869.98 10.31 -3,082.01 81.28 10,449.86 92.42 183.52 5,954.68 2,747.11 3,625.42 5,957,083.99 532,869.11 10.89 -3,052.64 89.40 10,482.18 94.11 187.61 5,952.84 2,715.01 3,622.30 5,957,051.88 532,866.11 13.67 -3,020.38 67.41 10,513.49 93.90 190.71 5,950.65 2,684.18 3,617.32 5,957,021.03 532,861.26 9.90 -2,989.23 93.78 10,547.09 90.95 192.79 5,949.23 2,651.31 3,610.49 5,956,988.15 532,854.55 10.74 -2,955.90 144.79 10,581.25 87.91 195.42 5,949.57 2,618.19 3,602.17 5,956,955.00 532,846.36 11.77 -2,922.18 139.14 10,613.28 86.35 195.05 5,951.18 2,587.33 3,593.76 5,956,924.10 532,838.07 5.01 -2,890.70 -166.68 10,652.62 86.04 190.80 5,953.79 2,549.08 3,584.98 5,956,885.82 532,829.44 10.81 -2,851.83 -94.32 10,679.32 86.77 187.92 5,955.46 2,522.79 3,580.65 5,956,859.52 532,825.21 11.11 -2,825.26 -75.84 10,713.95 87.42 182.74 5,957.22 2,488.37 3,577.44 5,956,825.09 532,822.14 15.06 -2,790.69 -82.97 10,749.66 89.51 177.54 5,958.18 2,452.68 3,577.35 5,956,789.41 532,822.19 15.69 -2,755.14 -68.18 10,780.12 90.71 174.16 5,958.12 2,422.31 3,579.55 5,956,759.04 532,824.51 11.77 -2,725.07 -70.46 10,810.13 94.12 172.34 5,956.85 2,392.54 3,583.08 5,956,729.29 532,828.15 12.88 -2,695.72 -28.04 10,843.77 95.10 170.11 5,954.15 2,359.40 3,588.19 5,956,696.18 532,833.39 7.22 -2,663.15 -66.12 10,876.27 96.21 167.96 5,950.95 2,327.65 3,594.34 5,956,664.46 532,839.67 7.42 -2,632.06 -62.48 10,906.23 95.72 170.48 5,947.83 2,298.38 3,599.92 5,956,635.21 532,845.35 8.52 -2,603.39 100.93 6/18/2008 11:36:3fAM Page 5 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhilRps(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 2D Pad Well: 2D-06 WeUbore: 2D-06BL1 Design: 2D-068L1 ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculatlon Method: Database: r~.r s ~~ INTEQ We112D-06 Mean Sea Level 2D-06A: ~ 121.OOft (2D-06A:) True Minimum Curvature EDMv16 Prod ~ Survey ~ MD Inc Azi NDSS WS E/W Northing Fasting DLS Vertical Section TFO tft) t°- 1°) (fU (ftl tff) (fU (ft) (°nooft- (tt- (°) i 10,935.41 93.54 172.55 5,945.48 2,269.62 3,604.21 5,956,606.47 532,849.75 10.29 -2,575.11 136.49 10,967.21 91.45 174.70 5,944.09 2,238.05 3,607.73 5,956,574.91 532,853.40 9.42 -2,543.97 134.16 10,999.37 90.46 177.87 5,943.56 2,205.97 3,609.82 5,956,542.84 532,855.61 10.33 -2,512.19 107.32 11,029.52 89.91 181.43 5,943.46 2,175.82 3,610.00 5,956,512.70 532,855.91 11.95 -2,482.17 98.77 11,074.91 89.72 186.33 5,943.61 2,130.55 3,606.93 5,956,467.42 532,853.02 10.80 -2,436.81 92.23 11,115.46 92.02 190.55 5,942.99 2,090.46 3,600.98 5,956,427.31 532,847.23 11.85 -2,396.35 61.39 11,145.62 92.39 192.55 5,941.83 2,060.93 3,594.95 5,956,397.76 532,841.31 6.74 -2,366.41 79.47 11,178.83 93.68 195.80 5,940.07 2,028.78 3,586.83 5,956,365.59 532,833.31 10.52 -2,333.67 68.24 11,211.82 96.21 199.16 5,937.23 1,997.44 3,576.96 5,956,334.21 532,823.57 12.72 -2,301.59 52.78 11,243.17 95.50 201.34 5,934.03 1,968.18 3,566.16 5,956,304.91 532,812.89 7.28 -2,271.50 108.01 11,277.81 95.16 203.64 5,930.81 1,936.32 3,552.97 5,956,273.00 532,799.82 6.68 -2,238.61 98.34 11,306.33 95.00 206.37 5,928.28 1,910.57 3,540.97 5,956,247.21 532,787.92 9.55 -2,211.92 93.25 11,350.00 95.00 206.37 • 5,924.48 1,871.60 3,521.64 ~ 5,956,208.17 • 532,768.75 0.00 -2,171.41 0.00 • 6/18/2008 11:36:31AM Page 6 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk RivecUnit Site: Kuparuk 2D Pad Well: 2D-06 WeUbore: 2D-068L1 Design: 2D-06BL1 ConocoPhillips ~~~~ B~ ~ ~ Baker Hughes INTEQ Survey Report ~ i ~ INTEQ Local Coordinate Reference: Well 20-06 TVD Reference: Mean Sea Level MD Reference: 2D-06A: ~ 121.OOft (2D-06A:) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDMv16 Prod Targets Target Name - hittmiss target Dlp Angle Dip Dir. TVD +W-S +E/-W Northing Easting • Shape 1°! (°) (ft) Ift) Iftl Ift) Ift1 Latitude Longitude 2D-06BL1 Target 8 (cop 0.00 0.00 5,930.00 1,620.44 3,510.92 5,955,957.00 532,759.00 70° 17' 26.540 N 149° 44' 5.311 W - actual wellpath misses by 251.44ft at 11350.OOft MD (5924.48 TVD, 1871.60 N, 3521.64 E) - Point 2D-066L1 Target 7 (cop 0.00 0.00 5,925.00 2,137.38 3,541.93 5,956,474.00 532,788.00 70° 17' 31.624 N 149° 44' 4.401 W -actual wellpath misses by 68.OOft at 11077.98ft MD (5943.62 TVD, 2127.50 N, 3606.58 E) -Point 2D-066L1 Polygon NEVI 0.00 0.00 0.00 3,982.11 3,662.36 5,958,319.00 532,901.24 70° 17' 49.766 N 149° 44' 0.865 W - actual wellpath misses by 5869.46ft at 8642.OOft MD (5868.77 TVD, 3946.02 N, 3580.12 E) - Polygon Point 1 0.00 3,982.11 3,662.36 5,958,319.00 532,901.24 Point2 0.00 4,101.56 3,548.61 5,958,438.00 532,787.23 Point3 0.00 4,160.91 3,460.02 5,958,496.99 532,698.22 Point4 0.00 4,161.44 3,320.01 5,958,496.98 532,558.23 Points 0.00 4,119.85 3,213.84 5,958,454.98 532,452.23 Point6 0.00 4,052.23 3,111.57 5,958,386.97 532,350.23 Point? 0.00 3,912.33 3,081.03 5,958,246.97 532,320.24 Point 8 0.00 3,734.29 3,088.35 5,958,068.97 532,328.25 Point 9 0.00 3,602.24 3,096.84 5,957,936.97 532,337.26 Point 10 0.00 3,465.94 3,172.33 5,957,800.98 532,413.27 Point 11 0.00 3,317.60 3,256.77 5,957,652.98 532,498.28 Point 12 0.00 3,203.29 3,333.34 5,957,538.98 532,575.28 Point 13 0.00 3,139.01 3,405.10 5,957,474.99 532,647.28 Point 14 0.00 3,044.76 3,467.74 5,957,380.99 532,710.28 Point 15 0.00 2,998.61 3,505.57 5,957,335.00 532,748.29 Point 16 0.00 2,794.47 3,534.79 5,957,130.99 532,778.30 Point 17 0.00 2,671.54 3,513.31 5,957,007.99 532,757.30 Point 18 0.00 2,540.66 3,478.81 5,956,876.99 532,723.31 Point 19 0.00 2,468.60 3,491.53 5,956,804.99 532,736.31 Point 20 0.00 2,323.59 3,490.97 5,956,659.99 532,736.32 Point 21 0.00 2,200.70 3,460.50 5,956,537.00 532,706.33 Point 22 0.00 1,984.94 3,391.66 5,956,320.99 532,638.33 Point 23 0.00 1,822.99 3,374.04 5,956,158.99 532,621.35 • • 6/18/2008 11:36:31AM Page 7 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc Project: Kuparuk River Unit Site: Kuparuk 2D Pad Weil: 2D-0& Wetlboro: 2D-068L1 Desfgn: 2D-06BLt ConocoPhillips ~R r sa Baker Hughes INTEQ Survey Report 1~1t3NE8 INTEQ Local Co-oMinate Reference: Well 2D-06 ND Reference: Mean Sea Level AAD Reference: 2D-06A; ~ 121.OOft {2D-06A:) North Reference: True Survey Cakulatlon Method: Minimum Curvature. Database: EpMv16 Prod Point 24 _... 0.00 1,636.99 3,369.33 5,955,972.99 532,617.36 Point 25 0.00 1,639.95 3,640.37 5,955,977.01 532,888.36 Point 26 0.00 1,859.95 3,646.21 5,956,197.00 532,893.34 Point 27 0.00 2,060.00 3,637.98 5,956,397.00 532,884.34 Point 28 0.00 2,238.00 3,642.66 5,956,575.00 532,888.32 Point 29 0.00 2,407.95 3,661.32 5,956,745.00 532,906.32 Point 30 0.00 2,585.77 3,712.00 5,956,923.00 532,956.30 Point 3l 0.00 2,806.71 3,734.86 5,957,144.01 532,978.30 Point 32 0.00 2,929.65 3,752.33 5,957,267.00 532,995.29 Point 33 0.00 3,077.86 3,701.89 5,957,415.00 532,944.28 Point 34 0.00 3,180.13 3,634.28 5,957,517.00 532,876.28 Point 35 0.00 3,290.40 3,566.69 5,957,626.99 532,808.27 Point 36 0.00 3,367.75 3,477.98 5,957,703.99 532,719.27 Point 37 0.00 3,503.08 3,397.49 5,957,838.99 532,638.26 Point 38 0.00 3,724.60 3,267.33 5,958,059.98 532,507.25 Point 39 0.00 3,881.61 3,267.93 5,958,216.98 532,507.24 Point 40 0.00 3,957.54 3,289.23 5,958,292.98 532,528.24 Point 4l 0.00 3,996.38 3,331.38 5,958,331.98 532,570.24 Point 42 0.00 4,013.04 3,420.45 5,958,348.99 532,659.23 Point 43 0.00 3,974.81 3,480.31 5,958,310.99 532,719.24 Point 44 0.00 3,880.47 3,564.96 5,958,216.99 532,804.24 Point 45 0.00 3,956.19 3,641.26 5,958,293.00 532,880.24 Point 46 0.00 3,982.11 3,662.36 5,958,319.00 532,901.24 2D-06BL1 Target 3 (cop 0.00 0.00 5,973.00 3,622.83 3,209.67 5,957,958.00 532,450.00 70° 17' 46.235 N 149° 44' 14.065 W - actual wellpath misses by 54.89ft at 9478.11ft MD (5998.49 ND, 3631.97 N, 3257.42 E) - Point 2D-06BL1 Target 5 (cop 0.00 0.00 5,938.00 3,163.22 3,610.93 5,957,500.00 532,853.00 70° 17' 41.713 N 149° 44' 2.375 W - actual wellpath misses by 126.60ft at 10063.99ft MD (5972.22 ND, 3104.61 N, 3504.05 E) - Point 2D-06BL1 Target 4 {cop 0.00 0.00 5,966.00 3,353.13 3,382.64 5,957,689.00 532,624.00 70° 17' 43.582 N 149° 44' 9.027 W - actual wellpath misses by 20.35ft at 9785.88ft MD (5985.33 ND, 3356.00 N, 3388.31 E) - Point 2D-06BL1 Target 10 (co 0.00 0.00 5,922.00 954.76 3,668.34 5,955,292.00 532,919.00 70° 17' 19.992 N 149° 44' 0.733 W - actual wellpath misses by 928.SOft at 11350.OOft MD (5924.48 N0, 1871.60 N, 3521.64 E) -Point 2D-068L1 Target 9 (cop 0.00 0.00 5,931.00 1,227.24 3,553.39 5,955,564.00 532,803.00 70° 17' 22.673 N 149° 44' 4.079 W - actual wellpath misses by 645.17ft at 11350.OOft MD (5924.48 ND, 1871.60 N, 3521.64 E) - Point C~ • 6/18/2008 11:36:31AM Page 8 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPh0lips(Alaska) Ina Project: Kuparuk River Unit Site: Kuparuk 2D Pad Web: 2D-O6 WeBbore: 2D-06BL1 Design: 2D-06BL1 ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: ri.r e s vss We112D-O6 Mean Sea Level 2D-06A: C~ t21.0oft (2D-06A:) True Minimum Curvature EDMv16 Prod 2D-086L1 Target 6 (cop 0.00 0.00 5,945.00 2,607.53 3,516.76 5,956,944.00 532,761.00 70° 17' 36.248 N 149° 44' 5.128 W - actual welipath misses by 79.85ft at 10613.28ft MD (5951.18 ND, 2587.33 N, 3593.76 E) -Point 2D-O6BL1 Target 1 (cop 0.00 0.00 6,002.00 4,028.98 3,439.28 5,958,365.00 532,678.00 70° 17' 50.228 N 149° 44' 7.367 W - actual welipath misses by 56.80ft at 8870.90ft MD (5993.58 ND, 4080.81 N, 3460.95 E) - Point 2D-066L1 Target 2 (cop 0.00 0.00 5,991.00 3,914.86 3,210.81 5,958,250.00 532,450.00 70° 17' 49.107 N 149° 44' 14.028 W - actual wellpath misses by 33.42ft at 9197.94ft MD (6003.17 N0, 3910.62 N, 3241.65 E) - Point Checked By: Approved By: Date: 6/18/2008 11:36:31 AM Page 9 COMPASS 2003.16 Build 42F KRU 2D-06BL1 A-sand Producer 3-1/2" Camco DS nipple, 2.812" min ID at 515' MD 3-1/2" 9.3# L-80 AB-mod EUE Tubing 3-'/" Camco MMM GLMs @ 2461', 4006', 5220', 6221', & 6978' MD Conoco hilli s p Alaska, Inc. 9-518" 40# J-55 ~ 4104' MD 3" openhole 2g/" slotted liner Baker C-2 ZXP liner packer w/SBE @ 7032' MD 7" 26# J-55 ~ 7185' MD 2D-06BL1 KOP @ 8645' MD (low-side exit) 2D-06B window @ 8767' MD 3-'/z' Camco D nipple, 2.80" min ID @ 7022' MD (milled to 2.80" during 1998 2D-06B sidetrack) 3'/z' marker joints @ 8510' & 8526' RKB 2'/" liner top @ 8626' and 3%Z' KB packer/ whipstock with standing valve at 8645' Fish: 3'/z" KB packer/ whipstock with standing valve, fell to 8704' 2'/" liner cut @ 8715' (5/18/08) 3-112" 9.3# L-80 ~ 7024' MD 2D-06BL1 southern lateral TD ~ 11,350' and 2'/" liner junction at 9673' MD 3" openhole 2D-06B east lateral TD @ 11004' md, 2'/e' slotted liner drilled in 1998 6/4/08 ~~~ BAKER N~~ME INTEC~ 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: June 26, 2008 Please find enclosed directional survey data for wells: 3F-16AL1PB1 3F-16AL1 3F-16AL1-Ol/ 2D-06BL1./ Enclosed is: 1 ea 3.5" floppy diskette containing electronic survey file Cc: State of Alaska, AOGCC Christine Mahnken ~-~~~ ®~ ~~ Vr~a7 co~s~iavA~®~ c®r~rIISSa®~ May 14, 2008 Gary Eller CT Drilling Engineer ConocoPhillips Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 333 W. 7th AVENUE. SUITE 100 ANCHORAGE, ALASKA 9950?-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2D-06BL1 ConocoPhilhps Alaska, Inc. Permit No: 207-007 Dear Mr. Eller: An Application for Permit to Drill (Form 10-401} for KRU 2D-06BL1 was received on May 9, 2008. After discussing this matter with you and researching the files, it has been determined that a permit to drill was issued for 2D-06BL1 on January 23, 2007. That approval is still valid. You have indicated that the reason for submitting the revision is that it will likely not be possible to drill to the total depth as originally specified, however the planned well trajectory is essentially the same as originally considered. These changes are not considered significant, so we are returning both copies of the applications recently received. The actual drilled BHL will be captured on the completion report, Form 10- 407. Please call me at (907) 793-1250 with any questions. Sincerely, ~' ' ~a P Thomas E. Maunder, PE Senior Petroleum Engineer SARAH PALIN, GOVERNOR STATE OF ALASKA • ALASK~IL AND GAS CONSERVATION CIS~N2008 ' ~ PERMIT TO D~I~L 20 AAC 25.00 as a Oil ~ Gas Cons. {i0CT11'Y1ISSIIJi` Revised: 05/07/08 1 a. Type of rk ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone ecify if we is proposed for: ^ Coalbed ethane ^ Gas Hydrates ^ Shale s 2. Operator Name: Conoco Phillips A ska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 11. ell Name and Number: Kuparuk 2D-06BL1 3. Address: c/o P.O. Box 196612, nchorage, Alaska 99519-6612 6. Proposed Depth: MD 11400 TVD 5928ss .Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Gover ental Section): Surface: ' ' 7. Property Designation: ADL 025653 River Pool 124 FSL, 510 FEL, SEC. 23, 11 N, R09E, UM Top of Productive Horizon: 4000' FSL, 3085' FWL, SEC. 24, 1 N, R09E, UM 8. Land Use Permit: 13. Approximate Spud Date: May 19, 2008 Total Depth: 2002' FSL, 2948' FWL, SEC. 24, T11N, 09E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 21,200' 4b. Location of Well (State Base Plane Coo inates): Surface: x-529255 y-5954323 ne-ASP4 10. KB Elevation (Height above L): 121 feet 15. Distance to Nearest Well Within Pool: 1300' 16. Deviated Wells: Kickoff Depth: 86 feet Maximum Hole An le: 100 de rees 17. Maximum ticipated Pressures in psig (see 20 AAC 25.035) Downho 2276 Surface: 2972 18. Casin Pr 'ram: S c~catio ns To - Settin De th -Bo ttom Quanf of ment c.f. or asks Hole Casin Wei ht Grade Cou li Len th M TVD MD TVD includin sta a data 3" 2-3/8" 4.7# L-80 STL 2770' 8 0' 5863'ss 11400' 5928'ss Uncemented S ed Liner 1g. PRESE NT!WELL CONDITIONS MARY (To a completed for Redrill and Re-entry Operations) Total Depth MD (ft): 11283 Total Depth TVD (ft): 6151 Plugs (me ured): N e Effecti Depth MD (ft): 1283 Effective Depth TVD (ft): 6151 Junk (measured): 11250 'Casing Length Size Cem t Volume MD TVD Conductor /Structural 110' 16" 2240 sx Coldset 1 110' 110' Surface 4104' 9-5/8" 1070 sx Arcticset III 765 Class'G' 4104' 3160' Intermediate 7185' 7" 560 sx Class'G' 41 Bbls A 1 7185' 5015' Pro u ion Liner 2056' -1/2" 396 sx Class'G' 7024' - 9080' 4910' - 6110' Liner 2697' 2-3/8" Uncemented Slotted Liner 8307' -11004' 5773' - 6145' Perforation Depth MD (ft): Slotted finer: 8820' - 8850' Perforation Depth TVD (ft 6101' - 6112' 20. Attachments ^ Filing F , $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Prope Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Ap val: ommi ion Representative: Date: 22. I hereby ce th the foreg g is true and correct. Conta Gary Eller, 263-4172 (Office) Printed Na ary Eller Title CT Drilling Engineer a Eller, 529-1979 Ce( II) Prepared By Name/Number: Si nature Phone 263-4172 Date ~ Te 'e Hubble, 564-4628 Commission UseAnl - Permit To II Number: 207-007 Number: 50-029-21168-60-00 Permit Approval See cover I er for Date: 01/23/07 other re uire nts Conditio of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shale ^ Samples Req'd: ^ Yes ^ No Mud Log Req'd: ^ Yes No HZS Measures: ^ Yes ^ No Directional Survey Req'd: ^ Yes ^ No Other: APPROVED BY THE COMMISSION Date ,COMMISSIONER Form 10-401 Revised 12/2005° ~ ~ i/o ~ Jr; ~ Submit In Duplicate ~.-~ t I ~ `j,.~` Page 1 of 2 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Tuesday, May 13, 2008 4:13 PM To: 'Eller, J Gary' Cc: Hubble, Terrie L Subject: RE: 2D-06BL1 PTD (207-007) Covers Pulling 400' of 2-3/8" Liner? Gary, After finally getting in the right wellbore (the permit number had an extra 7), speaking with you and talking with Steve Davies; it is our consensus that you already have a valid permit to perform the planned operations. If you were drilling more than 499' beyond the permitted presently permitted depth/length a new permitting action would be needed. According to you, the directional trajectory is essentially the same. Stopping the well shorter than permitted is not an issue. The actual drilled BHL will be captured on the 407. It would appear that pulling the 2- 3!8" liner section was also authorized when the permit was approved. Technically a sundry is probably needed due to pulling the top of the liner that is presently set in 2D-06B (198-176), but that additional paper would not really serve any purpose right now. Please be sure that a 10-404 updating the liner length is filed for 2D-06B. A copy of this message should be included with that 404. We wi{I return the recently submitted applications. I will place a copy of this message in both well files over here. Call or message with any questions. Tom Maunder, PE AOGCC From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Tuesday, May 13, 2008 3:25 PM To: Maunder, Thomas E (DOA) Cc: Hubble, Terrie L Subject: RE: 2D-06BL1 PTD Covers Pulling 400' of 2-3/8" Liner? Tom - We could be moving the rig as early as this weekend, depending on how quickly this last lateral drills. I assumed that you have seen the PTD for 2D-06BL1 - it was an amendment to a 10-401 that was approved in early 2007 (#207-007}. The amended version was sent out last week. In short, we want to cut and pull 400' of 2- 3/8" slotted liner that is inside of 3-1/2" cemented liner where we'll kickoff the L1 lateral. There is no mechanical problem whatsoever with pulling this 400' of liner -the liner top will still be above the existing window, and it's not providing pressure isolation anyway. Please let me know if you need anything else. -Gary From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, May 13, 2008 2:40 PM To: Eller, J Gary Cc: Venhaus, Dan E Subject: RE: 2D-06BL1 PTD Covers Pulling 400' of 2-3/8" Liner? Gary, I have to take a look at the intended procedure. When does it look like you will get started? Tom From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com) Sent: Tuesday, May 13, 2008 1:28 PM To: Maunder, Thomas E (DOA) Cc: Venhaus, Dan E Subject: 2D-066L1 PTD Covers Pulling 400' of 2-3/8" Liner? 5/13/2008 Page 2 of 2 Tom -You should have before you a 10-401 for well 2D-06BL1, a single CTD lateral of a gas lifted Kuparuk producer. That lateral calls for first cutting and pulling 400' of 2-3/8" slotted liner that was set high in 2D-06B back in 1998. Is that cut and pull of slotted liner covered by the 10-401 (once it gets approved), or is a separate 10-403 required? Thanks. ]. Gary Elfer Wells Engineer ConocoPhllllps -Alaska work: 407-263-4172 cell: 907-529-1979 fax: 9fl7-265-1535 5/13/2008 RE: [Fwd: 2D-06BL1] Subject: RE: [Fwd: 2D-06BL1] From: "Worthington, Aras J" <Aras.Worthington a bp.com> Date: Wed, 24 Jan 2007 l 3:50:21 -0900 `f`o: ~f~hom~is Maunder ~=torn mauncier(uadn~in.statc.ak.us~= Tom, Well, the good news is that the Conoco a-mail address is defunct, so you simplify your life if you delete it from your address bookl As for the MPD issues: You are correct that we'll be overbalanced even with just the drilling fluid, but in an effort to maintain a consfanf overbalance we'll hold the 800 psi at surface every time the pumps are shut down just to keep constant pressure on the shales, even though we don't anticipate the need to hold any extra pressure for weN control, Having said that; the highest pressure in the general area is 4400 psi BHP; so it is always possible (especially near the toe of the well} that we'll encounter some higher pressures than expected. As is typical with MPD, we monitor the realtime downhole pressure sensor as well as employ good well control practices to indicate whether we've drilled into a higher pressure zone. IF that happens we'll hold more back pressure on the choke and/or weight up as needed. Hope that answers your questions}, if not drop me another e-mail or call. Cheers, Aras Worthington CTD Engineer 564-4102 (office) 440-7692 (mobile) ___ ___ __ __ From: Thomas Maunder [mailto:tom_maunder@admin.state.ak.us] Sent: Wednesday, January 24, 2007 11:21 AM To: Worthington, Aras J Subject: [Fwd: 2D-06BL1] Not sure which desk you are at. -- Original Message -------- Subject:2D-06BL1 Date:Wed, 24 Jan 2007 11:20:31 -0900 From:Thomas Maunder Cton~ n~aunciertcuadn,in,state.ak.us> Organization:State of Alaska To:Aras Worthington <_area.j.worthinton(cc?conoco~hillips,conl> CC:gary eller ~j.;~a~-t%.eller(acot~ocopl~.illips.corn>, Steve Davies <ste~•e daviesvad~nin.state.ak.us> 1 of 2 1/24/2007 2:00 PM RE: [Fwd: 2D-06BL1] Aras, I am reviewing the drilling permit. The bottomhole pressure is given as 8.3 EMW and 8.6 ppg fluid is planned. Based on the BHP, the well will be overbalanced without any pressure application. The discussion of managed pressure drilling reads as if the well will be underbalanced with the planned drilling fluid. Are higher pressures possible with the fault crossings? I look forward to your reply. Tom Maunder, PE AOGCC 2 of 2 1 /24/2007 2:00 PM ~a ~s~~~~ ® ~ ssa~ Aras Worthington CT Drilling Engineer ConocoPhillips Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 333 W. 74hAVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, Kuparuk River Oil Pool, 2D-06BL1 ConocoPhillips Alaska, Inc. Permit No: 207-007 Surface Location: 124' FSL, 510' FEL, SEC. 23, T11N, R09E, UM Bottomhole Location: 1080' FSL, 3164' FWL, SEC. 24, Tl 1N, R09E, UM Dear Mr. Worthington: Enclosed is the approved application for permit to redrill the above referenced development well. The permit is for a new welbore segment of existing well KRU 2D-06B, Permit No. 198- 176, API No. 50-029-21168-02. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspec~~or at (907) 659-3607 (pager). DATED thi day of January, 2007 S~AR.4H P.QLIN, GOVERNOR cc: Department of Fish 8s Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMMIS ION PERMIT TO DRILL ~`Ia~, 20 AAC 25.005 dr~1~GD :)AN ~ 6 2007 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ MuRiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Spe i or: ^ Coalbed Methar~fl(~j3iiydrates ^ Shale Gas 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 ' 11. Well Name and Number: 2D-066L1 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12200 - TVD 5922ss 12. Field /Pool(s): Kuparuk River Unit / Kuparuk 4a. Location of Well (Governmental Section): Surface: ~ ' ' 7. Property Designation: ADL 025653 - River Pool FSL, 510 FEL, SEC. 23, T11 N, R09E, UM 124 Top of Productive Horizon: SEC. 24 T11 N, R09E, UM 3085' FWL 4000' FSL 8. Land Use Permit: 13. Approximate Spud Date: February 15, 2007 , , , Total Depth: 1080' FSL, 3164' FWL, SEC. 24, T11N, R09E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 21,200' 4b. Location of Well (State Base Plane Coordinates): Surface: x-529255 • y- 5954323 ~ Zone-ASP4 10. KB Elevation (Height above GL): 121 feet 15. Distance to Nearest Well within Pool: 900' 16. Deviated Wells: Kickoff Depth: 8650 ' feet Maximum Hole An le: 95 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2617 ~ Surface: 2007 - 1 Ca in Pr ra ~fi ~ n To - th - tt u of f C ent .f. r sa k Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 70' 8630' ~ 8 122 0' 922' Uncemented Sloe in r 19, PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 11283 Total Depth TVD (ft): 6151 Plugs (measured): None Effective Depth MD (ft): 11283 Effective Depth TVD (ft): 6151 Junk (measured): 11250 asing Length.. ize ement o tame D D Conductor /Structural 11 1 2240 sx Id I 110' Surface 41 4' 9-5/8" 1070 sx Ar i t III 765 x CI ss 'G' 41 3160' Intermediate 71 7" 56 sx CI s 41 Bbls AS I 71 5015' Pr cti n Liner 2056' 3-1/2" 396 sx Class ' 7024' - 9080' 4910' - 6110' Liner 2697' 2-3/8" nc ment d Slotted Liner 8307' - 11004' 5773' - 6145' Perforation Depth MD (ft): Slotted Liner: 8820' - 8850' Perforation Depth TVD (ft): 6101' - 6112' 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Aras Worthington, 564-x102 Printed Name Aras orthington Title CT Drilling Engineer Gary Eller, 529-1979 I Prepared By Name/Number: Si nature Phone 564-4102 Date / JG/i~~ Terrie Hubble, 564-x628 Commission .Use Onl Permit To Drill Numb r: X70 • DDS API Number: 50-029-21168-60-00 Permit Approv I See cover letter for (• ~ • (, her it m nt Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed met1hane, gas hydrates, or gas contained shales: Samples Req'd: Yes yJ No Mud Log Req'd: ^ Yes ~No HZS Measures: ~f Yes N D' ctional Survey Req'd: ~ Yes ^ No Other: ~~ ~~ ~ ~~ ~-C. S ~' c~S ~Q\Grt~~~ 1 APPROVED BY THE COMMISSION Date ~"!~ ~ ,COMMISSIONER Form 10-401 Revised 12/2005 ~„/ ~ ~ Su¢mit In Duplicate t ~R~C1~1AL ~~©!~ ~ • KRU 2D-06BL1 Sidetrack -Coiled Tubing Drilling Summary of Operations: ~ Acoiled tubing drilling unit will drill one new lateral in KRU 2D-06B using the managed pressure drilling technique (MPD, see description below). The 2D-06BL1 horizontal lateral will target Kuparuk A4 sand reserves for production. CTD Drill and Complete 2D-06BL1: Planned for February 15, 2007 Pre-Rid Work 1. S Obtain pressure data (SBHPS) from A sand reservoir (done, 2600 psi 11/14/06) 2. S DGLVS, Drift to 8750' into 3 2/8" slotted liner _ 3. DHD MIT-IA and OA 4. E Chemical cut 2 3/8" liner @ 8700' MD 5. C Spear liner top and PU liner to ensure that it is free 6. DHD PT Master & Swab to 4500 psi 7. DHD Drawdown test on Master & Swab to 0 psi 8. O Torque wellhead flange-bolts to spec 9. O Set BPV. Bleed OAP and IAP to 0 psi 10. O Bleed gas lift and production flowlines down to zero and blind flange 11. O Remove wellhouse, drill mouse hole, level pad Rig Work 1. MIRU Nordic 2. NU 7-1/16" BOPE, test 2. Kill well and spear liner top. POOH w/ 400' of liner and lay-down. 3. MU and set 3'/z" whipstock @ 8650' MD' 4. Mi112.74" window off of whipstock. The planned KOP is at 8650' 5. Dri113" bicenter hole horizontal lateral from window to 12,200' TD targeting Kuparuk A4 sands ~ 6. Kill well & complete with 2 3/8" slotted liner from TD to 8630' md. 7. ND BOPE. RDMO Nordic 2. Post Ris work 8. Post CTD rig -Run GLVs. Mud Program: • Step 2-5: chloride-based flo-pro (8.6 ppg) • Step 6: chloride-based brine or flo-pro (8.8 ppg)' Disposal: • No annular injection on this well. • Class II liquids to KRU 1 R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 2D-06BL1: 2 3/8", 4.6#, L-80, STL o Slotted liner from 8,630' and -12,200' and Casing/Liner Information 9 5/8", J-55, 36#, Burst 3520; collapse 2020 psi. 7", J-55, 26#, Burst 4980; collapse 4320 psi 3-1/2", L-80, 9.3#, Burst 10,160; collapse 10,530 psi Well Control: • Two well bore volumes 0250 bbls) of KWF will mixed and in the Kuparuk field during drilling operations. • BOP diagram is on file. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 4000 psi. • The annular preventer will be tested to 250 psi and 2500 psi. • • KRU 2D-06BL1 Sidetrack -Coiled Tubing Drilling Directional See attached directional plan for 2D-06BL1. Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. ' The nearest well to 2D-06BL1 is 2D-08 which is offset by 900'. The KPA boundary is 21,200' away. ~ Logging • MWD directional, Gamma Ray, and resistivity will be run over all of the open hole section. Hazards 2D-06BL1 will cross several mapped faults. Lost circulation risk is moderate. Well 2D-06 has an H2S level of 70 ppm.' All H2S monitoring equipment will be operational. Reservoir Pressure ~ • The most recent SBHP survey (11-14-06) was gauged at 2617 psi. The EMW is 8.3 ppg at 6100' TVD. Max. surface pressure with gas (0.1 psi/ft) to surface is 2007 psi. Variance request ~~~©~ ~ ~ ~~.~ ~~~ .~5~ ~ ~®~ , ~ ~~~ • BPXA requests a variance to the provisions of 20 AAC 25.036 (d)(4) HROUGH UBING DRILLING AND COMPLETION. This is regarding the function pressure test requirement after the use of BOP ram type equipment for other than well control or equivalent purposes. The variance will not apply when the routine use of BOP ram type equipment may have compromised their effectiveness. (Example would be when pipe rams are inadvertently closed on a tool joint during routine operations.) While drilling 2D-06BL1 it will be routine to close the 2" combi rams (pipe/slip) on the BHA during deployment and undeployment. These activities will not compromise the integrity of the BOP equipment. Managed Pressure Drilling Managed pressure drilling techniques will be employed to provide constant bottom hole pressure by using ,/ 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPS choke manifolding and the mud pits and will be independent of the BOPS choke. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (2" rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at the 2D-06BL1 at TD: • Estimated reservoir pressure: 2600 psi at 6100' TVD, 8.3 ppg EMW. ~--- • Expected annular friction losses while circulating: 780 psi (based on 90 psi/1000 ft) • Planned mud density: 8.6 ppg equates to 2730 psi hydrostatic bottom hole pressure. • While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 3510 psi or 110 ppg ECD • When circulation is stopped, a minimum of 780 psi surface pressure will be applied to maintain constant BHP. • • ~~ ConocoPhillips Alaska, Inc. NIP (. OI o~ Mandl (gal andrel (401 O Mand (52: andrel (sz. 0 Mand (ss (70 c (70 C (70 C Pi C V (88 (83C C ;112f C KRU 2D-06B 2D-O66 API: 500292116802 Well T e: PROD An le TS: 49 d 8553 is-sis, SSSV Type: NIPPLE Orig Com letion: 10/12/1998 Angle @ TD: 90 deg @ 11283 ':4.5ao) Annular Fluid: DSUSW Last W/O: Rev Reason: TAG FILL Tubing ~-7o2a Reference Lo Ref Lo Date: Last U date: 12/5/2004 , r3.5oo, Last Ta : 8806 TD: 11282 ftKB 'z.ss2> Last Ta Date: 12/2/2004 Max Hole An le: 97 d 10074 Casin Strin -ALL was Lift lv lN Descri lion Size To Bottom TVD Wt Grade Thread a a e i Conductor 16.000 0 110 110 62.58 H-40 Welded ~-zasz, Surface 9.625 0 4104 3158 36.00 J-55 BTC Production 7.000 0 7185 5014 26.00 J-55 BTC Production 3.500 7024 9080 6108 9.23 L-80 ABM-BTC G Lift Casin Strin -Slotted finer as Dummy Descri lion Size To Bottom TVD Wt Grade Thread Valve 2 Liner 2.375 8307 11004 6143 4.60 L-80 FL4S s-aoo7, 018) ):6 Tubin Strin -Tubin . Size To Bottom TVD Wt Grade Thread 3.500 0 7024 4908 9.30 L-80 ABM-EUE Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment Gas Lift alNalve 8820 - 8850 6100 - 6109 A-4 30 4 8/26/1996 IPERF 2.5" HCC, 180 deg. ph, 0 de CCW, Bi Hole 3 o-5zzi Gas Lift MandrelsNalves , St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2461 2209 CAMCO MMM CAMCO GLV 1.5 RK 0.250 1419 10/15/199 Gas Lift 2 4006 3100 CAMCO MMM CAMCO DMY 1.5 RK 0.000 0 10/11/199 Dummy Valve 4 3 5220 3803 CAMCO MMM CAMCO GLV 1.5 RK 0.250 1381 10/15/199 f-6222, 4 6221 4399 CAMCO MMM CAMCO DMY 1.5 RK 0.000 0 10/11/199 rs.o~s) 5 6978 4878 CAMCO MMM CAMCO OV 1.5 RK 0.188 0 10/15/199 Other lu s, a ui etc. - Jewelr De th TVD T e Descri Lion ID Gas Lift 515 515 NIP CAMCO DS 2.812 elNalve ~ 7022 4907 NIP CAMCO D 2.810 '8-6979, ~ 7032 4913 PKR Baker Liner Packer 2.810 7045 4922 SBE 2.992 11003 6143 Shoe 0.000 NIP Fish -FISH zaoz3, De th Descri lion Comment ~:a.5ao> 11250 FISH 1.5" Orifice Valve w/RK latch lost downhole 5/1/2001 General Notes Date Note 0/12/199 WELL SIDETRACKED PKR 2/12/1999 MIN ID= 1.995" THRU SLOTTED LINER 12-7033, x:4.540) SBE 15-7046, 7:6.750) )duction (0-7185, x:7.000, 'L26.00) Perf !0-8850) Liner r-11004, D:2.375, f/t:4.60) FISH - )-11251, D:t.500) _ I KRU 2D-06BL1 A-sand Producer Proposed CTD Completion 3-1/2" Camco DS nipple, 2.812" min ID at 515' MD 3-1/2" 9.3# L-80 AB-mod EUE Tubing 3-'/z" Camco MMM GLMs @ 2461', 4006', 5220', 6221', 8~ 6978' MD 9-518" 40# J-ss ~ 4104' MD • • ConocoPh~llips Alaska, Inc. 3-'/z" Camco D nipple, 2.80" min ID @ 7022' MD (milled to 2.80" during 1996 2D-066 sidetrack) Baker C-2 ZXP liner packer w/SBE @ 7032' MD r' 28# J-ss ~ 7185' MD 3-%z' marker joints @ 8510' & 8526' RKB 2-3/8" proposed liner top @ 8630' and 2D-06BL1 KOP @ 8650' MD 3-'/Z" thru-tubing flow-by whipstock 2D-O6B window @ 8767' MD 2-3/8" liner cut & pull @ 8700' 3" openhole 2_3/8" Slotted liner 7024' MD 3" openhole 2D-O6BL1 south lateral, proposed TD~22OO' and 2D-06B east lateral TD @ 11282' md, drilled in 1996 12/13/06 • • • by BP Alaska ~ Baker Hughes INTEQ Planning Report I.NTEQ Companye BP Amoco Date: 1/8/2007 Time: 14:47:55 Page: 1 Fiehl: Kuparuk Co-ordinate(NE) Reference: Well: 2D-O6, True North Site: KRIJ 2D Pad Vertieal (1'VD) Reference: 2D-06A/B Orig Rig 121. 0 R'ell: 2D-06 Sectioq(VS)Reference: V11eN(O.OON,O.OOE,180.OOAzi) Wellpath Plan 4 2D-06BL1 Survey Cakalatiotr Method: Minimum Curvature Db: Oracle Field: Kuparuk Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Modei: bggm2006 Site: KRU 2D Pad UNITED STATES :North Slope Site Position: Northing: 5954200. 61 ft Latitude: 70 17 9.387 N From: Map Fasting: 529765. 39 ft Longitude: 149 45 32.755 W Positron Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.23 deg Weil: 2D-06 Srot Name: Well Position: +N/-S 126.00 ft Northing: 5954324. 57 ft ' Latitude: 70 17 10.626 N +E/-W -510.88 ft Fasting : 529254. 07 ft ~ Longitude: 149 45 47.639 W Position Uncertainty: 0.00 ft Wellpath: Plan 4, 2D-O66L1 Drilled From: 2D-O6B Tie-on Depth: 8650.00 ft Current Datum: 2D-O6A/B Orig Rig Height 121. 00 ft Above System Datum: Mean Sea Level Magnetic Data: 1/7/2007 Declination: 23.56 deg Field Strength: 57608 nT Mag Dip Angle: 80.80 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 121.00 0.00 0.00 180.00 Plan: Plan #4 Date Composed: 1/7/2007 copy Lamar's plan 4 Version: 7 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <---- Latitude ---> <-- .Longitude ---~ Name Description TVD +N/-S +E/-W Northing Eastiug Deg Mia Sec Deg, Min Sec ..Dip. Dir. ft ft ft ft ft 2D-066L1 Polygon 121.00 964.06 3720.08 5955303.00 532970.00 70 17 20.098 N 149 43 59.246 W -Polygon 1 121.00 964.06 3720.08 5955303.00 532970.00 70 17 20.098 N 149 43 59.246 W -Polygon 2 121.00 1695.43 3644.91 5956034.00 532892.00 70 17 27.292 N 149 44 1.426 W -Polygon 3 121.00 2300.53 3637.27 5956639.00 532882.00 70 17 33.243 N 149 44 1.640 W -Polygon 4 121.00 2728.34 3696.94 5957067.00 532940.00 70 17 37.450 N 149 43 59.895 W -Polygon 5 121.00 3090.15 3757.35 5957429.00 532999.00 70 17 41.008 N 149 43 58.129 W -Polygon 6 121.00 3460.41 3699.78 5957799.00 532940.00 70 17 44.650 N 149 43 59.801 W -Polygon 7 121.00 3879.82 3604.41 5958218.00 532843.00 70 17 48.775 N 149 44 2.575 W -Polygon 8 121.00 4513.26 3508.86 5958851.00 532745.00 70 17 55.006 N 149 44 5.352 W -Polygon 9 121.00 4436.51 3187.53 5958773.00 532424.00 70 17 54.252 N 149 44 14.720 W -Polygon 10 121.00 3716.10 3271.73 5958053.00 532511.00 70 17 47.167 N 149 44 12.274 W -Polygon 11 121.00 3315.61 3387.19 5957653.00 532628.00 70 17 43.227 N 149 44 8.914 W -Polygon 12 121.00 3081.36 3445.28 5957419.00 532687.00 70 17 40.923 N 149 44 7.224 W -Polygon 13 121.00 2554.42 3414.23 5956892.00 532658.00 70 17 35.741 N 149 44 8.136 W -Polygon 14 121.00 1949.48 3381.87 5956287.00 532628.00 70 17 29.792 N 149 44 9.087 W -Polygon 15 121.00 1365.28 3418.60 5955703.00 532667.00 70 17 24.046 N 149 44 8.025 W -Polygon 16 121.00 847.81 3524.60 5955186.00 532775.00 70 17 18.956 N 149 44 4.943 W -Potygon 17 121.00 865.94 3748.70 5955205.00 532999.00 70 17 19.133 N 149 43 58.413 W 2D-06BL1 Faultl 121.00 4193.03 3303.59 5958530.00 532541.00 70 17 51.857 N 149 44 11.340 W -Polygon 1 121.00 4193.03 3303.59 5958530.00 532541.00 70 17 51.857 N 149 44 11.340 W -Polygon 2 -Polygon 3 121.00 121.00 3942.92 3760.46 3580.65 5958281.00 532819.00 4208.00 5958101.00 533447.00 70 17 49.396 N 70 17 47.598 N 149 44 3.267 W 149 43 44.983 W -Potygon 4 121.00 3942.92 3580.65 5958281.00 532819.00 70 17 49.396 N 149 44 3.267 W 2D-066L1 Fautt3 121.00 3559.12 3262.12 5957896.00 532502.00 70 17 45.623 N 149 44 12.557 W -Polygon 1 121.00 3559.12 3263.12 5957896.00 532503.00 70 17 45.623 N 149 44 12.527 W -Potygon 2 121.00 3391.91 3569.50 5957730.00 532810.00 70 17 43.977 N 149 44 3.800 W • • by BP Alaska ~ Baker Hughes INTEQ Planning Report INTEQ Compapy: BP Amoco Date: 1/8!2007 Time: 14:47:55 Page: 2 Field: KupaRlk ` Go-erdieste(NE) Refercncc: Welf 2D-O6, True North Site: KRl12D Pad Vertical (TVD) Reterencr. 2D-O6A/B Orig Rig 121 .0 Well: 2D-06 Sectioe (VS) Reference: Wel) (O. OON,O.OOE,180 .OOAzi) Wellpat6: Plan 4, 2D-O6BL1 Survey Cakalation Method: Minimum C urvature Db: Oracle Targets Map Map ~--~- Latitude -> <- Longitude --> Name Deseription TVD +N/-S +E/-W Nort4iag Easting ' Deg Mie Sec Deg Min Sec Dip.:. Dir, it ft ft ft ft -Polygon 3 121.00 3176.32 3971.71 5957516.00 533213.00 70 17 41.855 N 149 43 51.880 W -Polygon 4 121.00 3391.91 3569.50 5957730.00 532810.00 70 17 43.977 N 149 44 3.600 W 2D-06BL1 Fault2 121.00 3754.56 3154.87 5958091.00 532394.00 70 17 47.545 N 149 44 15.680 W -Polygon 1 121.00 3754.56 3154.87 5958091.00 532394.00 70 17 47.545 N 149 44 15.680 W -Polygon 2 121.00 3657.57 3405.52 5957995.00 532645.00 70 17 46.590 N 149 44 8.376 W -Polygon 3 121.00 3381.72 3875.50 5957721.00 533116.00 70 17 43.875 N 149 43 54.681 W -Polygon 4 121.00 3657.57 3405.52 5957995.00 532645.00 70 17 46.590 N 149 44 8.376 W 2D-06BL1 Fault6 121.00 1940.82 3294.83 5956278.00 532541.00 70 17 29.707 N 149 44 11.624 W -Polygon 1 121.00 1940.82 3294.83 5956278.00 532541.00 70 17 29.707 N 149 44 11.624 W -Polygon 2 121.00 1779.97 3508.23 5956118.00 532755.00 70 17 28.124 N 149 44 5.408 W -Polygon 3 121.00 1753.14 3722.15 5956092.00 532969.00 70 17 27.859 N 149 43 59.174 W -Polygon 4 121.00 1779.97 3508.23 5956118.00 532755.00 70 17 28.124 N 149 44 5.408 W 2D-O66L7 Fault8 121.00 1062.40 3378.42 5955400.00 532628.00 70 17 21.067 N 149 44 9.199 W -Polygon 1 121.00 1062.40 3378.42 5955400.00 532628.00 70 17 21.067 N 149 44 9.199 W -Polygon 2 121.00 1045.70 3558.38 5955384.00 532808.00 70 17 20.902 N 149 44 3.956 W -Polygon 3 121.00 1344.18 3701.55 5955683.00 532950.00 70 17 23.837 N 149 43 59.780 W -Polygon 4 121.00 1045.70 3558.38 5955384.00 532808.00 70 17 20.902 N 149 44 3.956 W 2D-O68L1 Fault? 121.00 1598.72 3312.50 5955936.00 532560.00 70 17 26.342 N 149 44 11.113 W -Polygon 1 121.00 1598.72 3312.50 5955936.00 532560.00 70 17 26.342 N 149 44 11.113 W -Polygon 2 121.00 1455.76 3553.97 5955794.00 532802.00 70 17 24.935 N 149 44 4.079 W -Polygon 3 121.00 1519.34 3663.23 5955858.00 532911.00 70 17 25.560 N 149 44 0.894 W -Polygon 4 121.00 1455.76 3553.97 5955794.00 532802.00 70 17 24.935 N 149 44 4.079 W 2D-066L1 Faults 121.00 2359.94 3276.46 5956697.00 532521.00 70 17 33.829 N 149 44 12.154 W -Polygon 1 121.00 2359.94 3276.46 5956697.00 532521.00 70 17 33.829 N 149 44 12.154 W -Polygon 2 121.00 2295.00 3515.23 5956633.00 532760.00 70 17 33.189 N 149 44 5.196 W -Polygon 3 121.00 2143.55 3626.65 5956482.00 532872.00 70 17 31.699 N 149 44 1.951 W -Polygon 4 121.00 2295.00 3515.23 5956633.00 532760.00 70 17 33.189 N 149 44 5.196 W 2D-O6BL1 Fault4 121.00 2876.87 3307.47 5957214.00 532550.00 70 17 38.913 N 149 44 11.244 W -Polygon 1 121.00 2876.87 3307.47 5957214.00 532550.00 70 17 38.913 N 149 44 11.244 W -Polygon 2 121.00 2855.86 3566.42 5957194.00 532809.00 70 17 38.705 N 149 44 3.697 W -Polygon 3 121.00 2806.01 3785.25 5957145.00 533028.00 70 17 38.214 N 149 43 57.320 W -Polygon 4 121.00 2855.86 3566.42 5957194.00 532809.00 70 17 38.705 N 149 44 3.697 W 2D-06BL1 Target 9 6043.00 953.26 3669.03 5955292.00 532919.00 70 17 19.992 N 149 44 0.733 W 2D-068L1 Target 6 6046.00 2135.88 3542.62 5956474.00 532788.00 70 17 31.624 N 149 44 4.401 W 2D-06BL1 Target 7 6051.00 1618.94 3511.60 5955957.00 532759.00 70 17 26.540 N 149 44 5.311 W 2D-O66L1 Target 8 6052.00 1225.74 3554.08 5955564.00 532803.00 70 17 22.673 N 149 44 4.079 W 2D-O6BL1 Target 4 6059.00 3111.64 3631.42 5957450.00 532873.00 70 17 41.220 N 149 44 1.799 W 2D-O6BL1 Target 5 6066.00 2606.03 3517.44 5956944.00 532761.00 70 17 36.248 N 149 44 5.128 W 2D-066L1 Target 3 6094.00 3555.25 3485.13 5957893.00 532725.00 70 17 45.584 N 149 44 6.057 W 2D-O66L1 Target 2 6112.00 3764.78 3355.93 5958102.00 532595.00 70 17 47.645 N 149 44 9.820 W 2D-066L1 Target 1 6123.00 4027.48 3439.96 5958365.00 532678.00 70 17 50.228 N 149 44 7.367 W ~ • by BP Alaska ~~~ Baker Hughes INTEQ Planning Report INTEQ Company: 8P Amoca Date: 1/8/2007 Time: 14:47:55 Page: 3 Field: Kuparuk Co-erdiaate(NE) Refercucec Well: 2D-O6, True North ' ..Site: KRU`2D Pad Vertkal (TVD) Reference; 2D-06A/B Orig Rig 121.0 - Well: 2D-06 Section(VS)Refereoce: Well ( O.OON,O.OOE,180.OOAzi) Welipat6: Plan 4, 2D-O66L1 Survey Calculation Metfod: Minimum Curvature - Db: OraGe Anaotatan MD` TVD ft ft 8642.00 5989.85 TIP 8650.00 5995.00 KOP 8670.00 6008.12 End of 9 Deg/100 DLS 8700.00 6030.24 4 8889.78 6123.20 5 9064.78 6118.54 End of 45 Deg/100 DLS 9189.78 6112.11 7 9434.78 6093.91 8 9759.78 6067.20 9 9959.78 6059.01 10 10159.78 6061.91 11 10459.78 6066.45 12 10709.78 6056.18 13 10959.78 6046.16 14 11209.78 6048.70 15 11459.78 6051.23 16 11709.78 6051.98 17 11909.78 6052.23 18 12009.78 6050.17 19 12200.00 0.00 TD Plan Section Information NID Intl Azim TVD +N/-S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 8642.00 49.97 349.58 5989.85 3946.66 3579.71 0.00 0.00 0.00 0.00 8650.00 49.89 349.64 5995.00 3952.68 3578.61 1.15 -1.00 0.75 150.17 8670.00 48.09 349.64 6008.12 3967.53 3575.89 9.00 -9.00 0.00 180.00 8700.00 36.87 338.42 6030.24 3986.97 3570.55 45.00 -37.39 -37.39 210.00 8889.78 90.50 256.78 6123.20 4025.66 3430.25 45.00 28.26 -43.02 277.00 9064.78 92.06 178.02 6118.54 3897.40 3332.15 45.00 0.89 -45.01 272.00 9189.78 93.80 163.10 6112.11 3774.61 3352.55 12.00 1.39 -11.94 277.00 9434.78 94.53 133.63 6093.91 3568.86 3479.27 12.00 0.30 -12.03 272.50 9759.78 94.53 172.76 6067.20 3285.36 3622.53 12.00 0.00 12.04 88.40 9959.78 90.10 196.37 6059.01 3087.62 3606.68 12.00 -2.21 11.81 100.00 10159.78 88.26 172.44 6061.91 2889.69 3591.44 12.00 -0.92 -11.97 265.50 10459.78 90.06 208.40 6066.45 2599.50 3538.07 12.00 0.60 11.99 87.50 10709.78 94.54 178.70 6056.18 2359.45 3480.12 12.00 1.79 -11.88 279.00 10959.78 89.95 149.02 6046.16 2122.26 3548.87 12.00 -1.83 -11.87 262.00 11209.78 88.91 179.01 6048.70 1884.68 3616.94 12.00 -0.42 11.99 92.10 11459.78 89.96 208.99 6051.23 1644.88 3557.16 12.00 0.42 11.99 88.20 11709.78 89.71 178.99 6051.98 1405.06 3497.41 12.00 -0.10 -12.00 269.50 11909.78 90.14 154.99 6052.23 1211.61 3542.10 12.00 0.22 -12.00 271.00 12009.78 92.21 143.17 6050.17 1126.00 3593.37 12.00 2.07 -11.82 280.00 12200.00 92.04 166.01 6043.03 955.43 3674.39 12.00 -0.09 12.01 90.00 Survey MD IBCI Azim SS TVD N/S E/W MapN MapE .DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg ; 8642. 00 49.97 349.58 5868.85 3946.66 3579.71 5958284.74 532818.05 0.00 -3946.66 0.00 MWD 8650. 00 49.89 349.64 5874.00 3952.68 3578.61 5958290.75 532816.92 1.15 -3952.68 150.17 MWD 8670. 00 48.09 349.64 5887.12 3967.53 3575.89 5958305.59 532814.15 9.00 -3967.53 180.00 MWD 8675. 00 46.15 348.08 5890.52 3971.12 3575.19 5958309.18 532813.43 45.00 -3971.12 210.00 MWD 8700. 00 36.87 338.42 5909.24 3986.97 3570.55 5958325.00 532808.73 45.00 -3986.97 211.06 MWD 8716. 09 38.34 326.79 5922.00 3995.64 3566.04 5958333.66 532804.19 45.00 -3995.64 277.00 2D-O6 L 8719. 92 38.85 324.15 5925.00 3997.62 3564.68 5958335.63 532802.82 45.00 -3997.62 286.23 2D-06 8725 .00 39.62 320.75 5928.93 4000.16 3562.72 5958338.16 532800.85 45.00 -4000.16 288.29 MWD 8726.39 39.84 319.83 5930.00 4000.84 3562.16 5958338.84 532800.28 45.00 -4000.84 290.93 2D-06 8727 .69 40.06 318.99 5931.00 4001.48 3561.61 5958339.48 532799.74 45.00 -4001.48 291.63 2D-O6 8736 .96 41.79 313.19 5938.00 4005.84 3557.40 5958343.82 532795.51 45.00 -4005.84 292.28 2D-O6 8746.50 43.86 307.65 5945.00 4010.04 3552.47 5958348.00 532790.56 45.00 -4010.04 296.66 2D-06 • ~ b BP Alaska S P Baker Hughes INTEQ Planning Report INTEQ Compnnye BP Amoco Date: 1f8/2007 Time: 14 :47:55 Page: 4 Field: Kuparuk Ca-o`dinate(NE) Refereecec Wett: 2D-06, True North ` Site: KRIJ 2D Pad Vertical (TVD) Refere®ce: - 2D-06A/B Orig Rig 121.0 We11: 2D-06 Sectio n (VS) Reference. Well ( O.OON,O.OOE,180.OOAzi) Wellpath Plap 4, 2D-O6B11 Survey Cakulatiou Method:. Minimum Curvature Db: OraGe Survey MD Iaci Aaim SS TYD N/S FJW " MapN MapE DLS VS TE'O Tool ft deg deg ft ft' ft ft ft deg/100ft R deg 8750.00 44.68 305.72 5947.51 4011.50 3550.51 5958349.45 532788.59 45.00 -4011.50 300.73 MWD 8775.00 51.35 293.51 5964.26 4020.55 3534.37 5958358.44 532772.42 45.00 -4020.55 302.11 MWD 8789.72 55.80 287.40 5973.00 4024.67 3523.28 5958362.52 532761.32 45.00 -4024.67 310.31 2D-O6 L 8800.00 59.07 283.52 5978.53 4026.98 3514.93 5958364.79 532752.96 45.00 -4026.98 313.94 MWD 8825.00 67.44 275.09 5989.79 4030.52 3492.93 5958368.25 532730.95 45.00 -4030.52 316.03 MWD 8828.23 68.55 274.08 5991.00 4030.76 3489.95 5958368.47 532727.97 45.00 -4030.76 319.84 2D-06 8850.00 76.20 267.64 5997.59 4031.05 3469.23 5958368.68 532707.25 45.00 -4031.05 320.22 MWD 8875.00 85.16 260.75 6001.64 4028.54 3444.73 5958366.08 532682.76 45.00 -4028.54 322.17 MWD 8889.78 90.50 256.78 6002.20 4025.66 3430.25 5958363.14 532668.30 45.00 -4025.66 323.29 MWD 8900.00 90.66 252.18 6002.10 4022.92 3420.41 5958360.37 532658.46 45.00 -4022.92 272.00 MWD 8925.00 91.03 240.94 6001.73 4013.00 3397.51 5958350.35 532635.61 45.00 -4013.00 271.95 MWD 8950.00 91.36 229.69 6001.21 3998.79 3376.99 5958336.07 532615.15 45.00 -3998.79 271.79 MWD 8975.00 91.63 218.44 6000.55 3980.86 3359.64 5958318.08 532597.86 45.00 -3980.86 271.55 MWD 9000.00 91.85 207.18 5999.79 3959.90 3346.12 5958297.06 532584.43 45.00 -3959.90 271.26 MWD 9025.00 91.99 195.93 5998.95 3936.70 3336.95 5958273.83 532575.35 45.00 -3936.70 270.92 MWD 9050.00 92.06 184.67 5998.07 3912.15 3332.49 5958249.27 532570.99 45.00 -3912.15 270.54 MWD 9064.78 92.06 178.02 5997.54 3897.40 3332.15 5958234.51 532570.70 45.00 -3897.40 270.14 MV11D 9075.00 92.21 176.80 5997.15 3887.19 3332.61 5958224.31 532571.20 12.00 -3887.19 277.00 MWD 9100.00 92.57 173.82 5996.11 3862.30 3334.65 5958199.43 532573.34 12.00 -3862.30 276.95 MWD 9125.00 92.92 170.84 5994.92 3837.56 3337.98 5958174.70 532576.77 12.00 -3837.56 276.83 MWD 9150.00 93.27 167.85 5993.57 3813.03 3342.60 5958150.19 532581.48 12.00 -3813.03 276.69 MWD 9175.00 93.60 164.87 5992.07 3788.78 3348.49 5958125.97 532587.46 12.00 -3788.78 276.53 MWD 9189.78 93.80 163.10 5991.11 3774.61 3352.55 5958111.81 532591.58 12.00 -3774.61 276.35 MWD 9200.00 93.85 161.87 5990.43 3764.88 3355.62 5958102.10 532594.69 12.00 -3764.88 272.50 MWD 9225.00 93.97 158.87 5988.73 3741.39 3364.00 5958078.64 532603.16 12.00 -3741.39 272.42 MWD 9250.00 94.08 155.86 5986.97 3718.37 3373.60 5958055.67 532612.85 12.00 -3718.37 272.21 MWD 9275.00 94.18 152.85 5985.17 3695.90 3384.39 5958033.24 532623.72 12.00 -3695.90 272.00 MWD 9300.00 94.27 149.85 5983.33 3674.02 3396.34 5958011.41 532635.76 12.00 -3674.02 271.79 MWD 9325.00 94.34 146.84 5981.45 3652.80 3409.42 5957990.24 532648.92 12.00 -3652.80 271.56 MWD 9350.00 94.41 143.83 5979.54 3632.30 3423.60 5957969.80 532663.18 12.00 -3632.30 271.34 MWD 9375.00 94.46 140.82 5977.61 3612.58 3438.83 5957950.14 532678.48 12.00 -3612.58 271.11 MWD 9400.00 94.50 137.81 5975.65 3593.68 3455.07 5957931.30 532694.80 12.00 -3593.68 270.88 MWD 9425.00 94.53 134.81 5973.69 3575.66 3472.29 5957913.35 532712.08 12.00 -3575.66 270.64 MWD 9434.78 94.53 133.63 5972.91 3568.86 3479.27 5957906.58 532719.09 12.00 -3568.86 270.40 MWD 9450.00 94.58 135.46 5971.70 3558.22 3490.09 5957895.98 532729.95 12.00 -3558.22 88.40 MWD 9475.00 94.65 138.47 5969.69 3540.00 3507.09 5957877.84 532747.02 12.00 -3540.00 88.55 MWD 9500.00 94.71 141.48 5967.65 3520.93 3523.11 5957858.83 532763.11 12.00 -3520.93 88.79 MWD 9525.00 94.75 144.49 5965.59 3501.04 3538.11 5957839.00 532778.19 12.00 -3501.04 89.03 MWD 9550.00 94.79 147.50 5963.51 3480.39 3552.04 5957818.40 532792.20 12.00 -3480.39 89.28 MWD 9575.00 94.80 150.51 5961.42 3459.03 3564.87 5957797.10 532805.11 12.00 -3459.03 89.53 MWD 9600.00 94.81 153.52 5959.32 3437.04 3576.56 5957775.15 532816.88 12.00 -3437.04 89.78 MWD 9625.00 94.80 156.53 5957.23 3414.46 3587.08 5957752.62 532827.48 12.00 -3414.46 90.04 MWD 9650.00 94.78 159.54 5955.14 3391.35 3596.39 5957729.55 532836.89 12.00 -3391.35 90.29 MWD 9675.00 94.74 162.55 5953.07 3367.79 3604.49 5957706.03 532845.07 12.00 -3367.79 90.54 MWD 9700.00 94.70 165.56 5951.01 3343.84 3611.33 5957682.10 532852.01 12.00 -3343.84 90.79 MWD 9725.00 94.63 168.57 5948.97 3319.56 3616.91 5957657.84 532857.68 12.00 -3319.56 91.04 MWD 9750.00 94.56 171.58 5946.97 3295.01 3621.20 5957633.32 532862.07 12.00 -3295.01 91.28 MWD 9759.78 94.53 172.76 5946.20 3285.36 3622.53 5957623.67 532863.43 12.00 -3285.36 91.52 MWD 9775.00 94.21 174.56 5945.04 3270.27 3624.20 5957608.59 532865.17 12.00 -3270.27 100.00 MWD 9800.00 93.68 177.52 5943.32 3245.40 3625.93 5957583.72 532866.99 12.00 -3245.40 100.14 MWD 9825.00 93.13 180.47 5941.83 3220.45 3626.36 5957558.78 532867.52 12.00 -3220.45 100.34 MWD 9850.00 92.58 183.43 5940.59 3195.49 3625.51 5957533.83 532866.77 12.00 -3195.49 100.52 MWD 9875.00 92.02 186.38 5939.58 3170.61 3623.38 5957508.94 532864.73 12.00 -3170.61 100.66 MWD • • by BP Alaska r Baker Hughes INTEQ Planning Report INTE Q Compaays BP Amoco Date: 1/8/2007 Time: 14 :47:55 Page: 5 Field: Kuparuk Co-ordiuate(NE) Reference: ` ` Well: 2D-06, True North .:Site: KRU 2D Pad Vertical (1'VD) Refer~ce: " 2D-O6A/B Orig Rig 121.0 Well: - 2D-O6- Sectio n (VS)Retereocee Well (O.OON,O.OOE,180.OOAzi) Wellpath: Plan 4; 2D-06BL1 Survey CalcalationMetYod: Minimum Curvature Db: OraGe Survey MD Iacl Azim SS TVD N/S E/W MapN MapE DL5 VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 9900.00 91.46 189.33 5938.82 3145.86 3619.97 5957484.17 532861.41 12.00 -3145.86 100.78 MWD 9925.00 90.89 192.27 5938.31 3121.31 3615.28 5957459.61 532856.83 12.00 -3121.31 100.87 MWD 9950.00 90.32 195.22 5938.04 3097.03 3609.35 5957435.31 532850.98 12.00 -3097.03 100.93 MWD 9959.78 90.10 196.37 5938.01 3087.62 3606.68 5957425.89 532848.36 12.00 -3087.62 100.96 MWD 9975.00 89.96 194.55 5938.00 3072.95 3602.63 5957411.20 532844.36 12.00 -3072.95 265.50 MWD 10000.00 89.72 191.56 5938.07 3048.60 3596.98 5957386.83 532838.81 12.00 -3048.60 265.50 MWD 10025.00 89.49 188.57 5938.24 3023.99 3592.61 5957362.21 532834.54 12.00 -3023.99 265.51 MWD 10050.00 89.25 185.57 5938.52 2999.18 3589.54 5957337.39 532831.56 12.00 -2999.18 265.53 MWD 10075.00 89.02 182.58 5938.90 2974.25 3587.76 5957312.46 532829.88 12.00 -2974.25 265.56 MWD 10100.00 88.79 179.59 5939.37 2949.26 3587.29 5957287.47 532829.50 12.00 -2949.26 265.61 MWD 10125.00 88.57 176.60 5939.95 2924.28 3588.12 5957262.50 532830.43 12.00 -2924.28 265.66 MWD 10150.00 88.35 173.61 5940.62 2899.39 3590.25 5957237.61 532832.66 12.00 -2899.39 265.73 MWD 10159.78 88.26 172.44 5940.91 2889.69 3591.44 5957227.92 532833.88 12.00 -2889.69 265.81 MWD 10175.00 88.34 174.26 5941.36 2874.57 3593.20 5957212.81 532835.70 12.00 -2874.57 87.50 MWD 10200.00 88.48 177.26 5942.06 2849.65 3595.05 5957187.91 532837.65 12.00 -2849.65 87.45 MWD 10225.00 88.62 180.26 5942.69 2824.67 3595.59 5957162.93 532838.29 12.00 -2824.67 87.36 MWD 10250.00 88.76 183.25 5943.26 2799.69 3594.82 5957137.95 532837.62 12.00 -2799.69 87.29 MWD 10275.00 88.91 186.25 5943.77 2774.79 3592.75 5957113.04 532835.64 12.00 -2774.79 87.22 MWD 10300.00 89.06 189.25 5944.21 2750.02 3589.38 5957088.26 532832.37 12.00 -2750.02 87.16 MWD 10325.00 89.21 192.24 5944.59 2725.47 3584.72 5957063.69 532827.81 12.00 -2725.47 87.10 MWD 10350.00 89.37 195.24 5944.90 2701.19 3578.78 5957039.39 532821.96 12.00 -2701.19 87.06 MIND 10375.00 89.52 198.24 5945.14 2677.25 3571.58 5957015.43 532814.86 12.00 -2677.25 87.02 MWD 10400.00 89.68 201.23 5945.31 2653.72 3563.14 5956991.87 532806.51 12.00 -2653.72 86.99 MWD 10425.00 89.84 204.23 5945.42 2630.67 3553.48 5956968.78 532796.94 12.00 -2630.67 86.97 MWD 10450.00 90.00 207.22 5945.45 2608.15 3542.63 5956946.22 532786.18 12.00 -2608.15 86.96 MWD 10459.78 90.06 208.40 5945.45 2599.50 3538.07 5956937.55 532781.65 12.00 -2599.50 86.96 MWD 10475.00 90.35 206.59 5945.39 2586.00 3531.04 5956924.03 532774.68 12.00 -2586.00 279.00 MWD 10500.00 90.82 203.63 5945.14 2563.36 3520.44 5956901.35 532764.16 12.00 -2563.36 278.99 MWD 10525.00 91.28 200.66 5944.68 2540.21 3511.01 5956878.17 532754.83 12.00 -2540.21 278.96 MWD 10550.00 91.74 197.70 5944.02 2516.61 3502.80 5956854.54 532746.71 12.00 -2516.61 278.91 MWD 10575.00 92.20 194.73 5943.16 2492.62 3495.83 5956830.53 532739.83 12.00 -2492.62 278.83 MWD 10600.00 92.66 191.76 5942.10 2468.31 3490.10 5956806.20 532734.20 12.00 -2468.31 278.73 MWD 10625.00 93.10 188.79 5940.84 2443.75 3485.65 5956781.62 532729.84 12.00 -2443.75 278.60 MWD 10650.00 93.54 185.82 5939.40 2419.00 3482.48 5956756.85 532726.76 12.00 -2419.00 278.45 MWD 10675.00 93.96 182.84 5937.76 2394.12 3480.59 5956731.98 532724.98 12.00 -2394.12 278.28 MWD 10700.00 94.38 179.87 5935.94 2369.20 3480.00 5956707.05 532724.48 12.00 -2369.20 278.09 MWD 10709.78 94.54 178.70 5935.18 2359.45 3480.12 5956697.31 532724.64 12.00 -2359.45 277.87 MWD 10725.00 94.28 176.89 5934.01 2344.29 3480.71 5956682.15 532725.29 12.00 -2344.29 262.00 MWD 10750.00 93.85 173.91 5932.24 2319.43 3482.71 5956657.30 532727.38 12.00 -2319.43 261.86 MWD 10775.00 93.41 170.94 5930.65 2294.70 3486.00 5956632.59 532730.77 12.00 -2294.70 261.65 MWD 10800.00 92.96 167.97 5929.26 2270.17 3490.57 5956608.07 532735.43 12.00 -2270.17 261.46 MWD 10825.00 92.51 165.00 5928.07 2245.89 3496.40 5956583.82 532741.37 12.00 -2245.89 261.30 MWD 10850.00 92.04 162.03 5927.08 2221.94 3503.49 5956559.90 532748.55 12.00 -2221.94 261.15 MWD 10875.00 91.57 159.07 5926.29 2198.38 3511.81 5956536.38 532756.96 12.00 -2198.38 261.04 MWD 10900.00 91.10 156.10 5925.71 2175.28 3521.34 5956513.32 532766.57 12.00 -2175.28 260.94 MWD 10925.00 90.62 153.14 5925.33 2152.70 3532.05 5956490.78 532777.37 12.00 -2152.70 260.87 MWD 10950.00 90.14 150.18 5925.17 2130.70 3543.92 5956468.82 532789.32 12.00 -2130.70 260.83 MWD 10959.78 89.95 149.02 5925.16 2122.26 3548.87 5956460.41 532794.30 12.00 -2122.26 260.81 MWD 10975.00 89.89 150.85 5925.18 2109.09 3556.49 5956447.27 532801.98 12.00 -2109.09 92.10 MWD 11000.00 89.78 153.85 5925.25 2086.95 3568.10 5956425.18 532813.67 12.00 -2086.95 92.10 MWD 11025.00 89.67 156.84 5925.38 2064.23 3578.52 5956402.50 532824.18 12.00 -2064.23 92.09 MWD 11050.00 89.56 159.84 5925.54 2041.00 3587.75 5956379.31 532833.50 12.00 -2041.00 92.07 MWD • • by BP Alaska r Baker Hughes INTEQ Planning Report 1NTE Q Company: BP AmoCO Date: 1/8/2007 : Time: 14:47:55 Page: 6 ::Field: Kupan~krr Go-ordioate(NE) Reference: Well: 2D-06, True North Site: KRU 2D Pad Vertieal(1'VDjRefereece: 2D-06A/B Orig Rig 121.0 Well: 2D-O6 Secta e (VS) Reference: Well ( O.OON,O.OOE,180.OOAzi) Wellpat6: Pian 4, 2D-O6BU Survey Cakubtiou Mstbod: Minimum Curvature Db: OraGe Survey MID:. Iacl Azim SS TVD N/S ElVV MapN MapE DLS VS TFO Tool ft deg deg ft tt ft ft' ft deg/100ft ft deg 11075.00 89.45 162.84 5925.76 2017.32 3595.75 5956355.66 532841.59 12.00 -2017.32 92.05 MWD 11100.00 89.35 165.84 5926.02 1993.25 3602.49 5956331.62 532848.43 12.00 -1993.25 92.03 MWD 11125.00 89.24 168.84 5926.33 1968.86 3607.97 5956307.26 532854.00 12.00 -1968.86 92.00 MWD 11150.00 89.14 171.83 5926.68 1944.22 3612.17 5956282.63 532858.29 12.00 -1944.22 91.96 MWD 11175.00 89.04 174.83 5927.08 1919.40 3615.07 5956257.82 532861.29 12.00 -1919.40 91.92 MWD 11200.00 88.95 177.83 5927.52 1894.45 3616.67 5956232.89 532862.98 12.00 -1894.45 91.87 MWD 11209.78 88.91 179.01 5927.70 1884.68 3616.94 5956223.12 532863.29 12.00 -1884.68 91.82 MWD 11225.00 88.97 180.83 5927.98 1869.46 3616.96 5956207.90 532863.37 12.00 -1869.46 88.20 MWD 11250.00 89.06 183.83 5928.41 1844.49 3615.94 5956182.93 532862.45 12.00 -1844.49 88.17 MWD 11275.00 89.16 186.83 5928.80 1819.60 3613.62 5956158.04 532860.23 12.00 -1819.60 88.11 MWD 11300.00 89.27 189.83 5929.14 1794.87 3610.00 5956133.29 532856.70 12.00 -1794.87 88.07 MWD 11325.00 89.37 192.83 5929.44 1770.36 3605.09 5956108.77 532851.89 12.00 -1770.36 88.03 MWD 11350.00 89.48 195.82 5929.69 1746.15 3598.91 5956084.53 532845.80 12.00 -1746.15 87.99 MWD 11375.00 89.58 198.82 5929.89 1722.28 3591.46 5956060.64 532838.45 12.00 -1722.28 87.96 MWD 11400.00 89.69 201.82 5930.05 1698.84 3582.78 5956037.17 532829.86 12.00 -1698.84 87.94 MWD 11425.00 89.80 204.82 5930.16 1675.89 3572.89 5956014.18 532820.06 12.00 -1675.89 87.92 MWD 11450.00 89.91 207.82 5930.22 1653.48 3561.81 5955991.73 532809.06 12.00 -1653.48 87.90 MWD 11459.78 89.96 208.99 5930.23 1644.88 3557.16 5955983.11 532804.45 12.00 -1644.88 87.90 MWD 11475.00 89.94 207.16 5930.25 1631.45 3549.99 5955969.66 532797.34 12.00 -1631.45 269.50 MWD 11500.00 89.91 204.16 5930.28 1608.92 3539.17 5955947.08 532786.60 12.00 -1608.92 269.50 MWD 11525.00 89.89 201.16 5930.32 1585.85 3529.53 5955923.98 532777.06 12.00 -1585.85 269.51 MWD 11550.00 89.86 198.16 5930.38 1562.31 3521.12 5955900.41 532768.74 12.00 -1562.31 269.51 MWD 11575.00 89.84 195.16 5930.44 1538.36 3513.96 5955876.44 532761.67 12.00 -1538.36 269.52 MWD 11600.00 89.81 192.16 5930.52 1514.07 3508.05 5955852.13 532755.86 12.00 -1514.07 269.53 MWD 11625.00 89.79 189.16 5930.61 1489.51 3503.43 5955827.55 532751.33 12.00 -1489.51 269.53 MWD 11650.00 89.77 186.16 5930.70 1464.74 3500.09 5955802.76 532748.09 12.00 -1464.74 269.54 MWD 11675.00 89.74 183.16 5930.81 1439.82 3498.06 5955777.84 532746.16 12.00 -1439.82 269.56 MWD 11700.00 89.72 180.16 5930.93 1414.84 3497.34 5955752.86 532745.53 12.00 -1414.84 269.57 MWD 11709.78 89.71 178.99 5930.98 1405.06 3497.41 5955743.08 532745.64 12.00 -1405.06 269.58 MWD 11725.00 89.74 177.16 5931.05 1389.85 3497.92 5955727.87 532746.21 12.00 -1389.85 271.00 MWD 11750.00 89.80 174.16 5931.15 1364.92 3499.81 5955702.96 532748.20 12.00 -1364.92 271.01 MWD 11775.00 89.85 171.16 5931.23 1340.13 3503.00 5955678.18 532751.48 12.00 -1340.13 271.02 MWD 11800.00 89.90 168.16 5931.28 1315.54 3507.49 5955653.61 532756.06 12.00 -1315.54 271.03 MWD 11825.00 89.96 165.17 5931.31 1291.21 3513.25 5955629.31 532761.92 12.00 -1291.21 271.04 MWD 11850.00 90.01 162.17 5931.32 1267.22 3520.28 5955605.35 532769.05 12.00 -1267.22 271.04 MWD 11875.00 90.07 159.17 5931.30 1243.64 3528.56 5955581.80 532777.41 12.00 -1243.64 271.04 MWD 11900.00 90.12 156.17 5931.26 1220.52 3538.06 5955558.72 532787.00 12.00 -1220.52 271.04 MWD 11909.78 90.14 154.99 5931.23 1211.61 3542.10 5955549.83 532791.08 12.00 -1211.61 271.03 MWD 11925.00 90.46 153.19 5931.15 1197.92 3548.75 5955536.17 532797.78 12.00 -1197.92 280.00 MWD 11950.00 90.98 150.24 5930.84 1175.91 3560.59 5955514.20 532809.71 12.00 -1175.91 279.99 MWD 11975.00 91.50 147.28 5930.30 1154.54 3573.55 5955492.89 532822.75 12.00 -1154.54 279.95 MWD 12000.00 92.01 144.33 5929.53 1133.88 3587.59 5955472.28 532836.87 12.00 -1133.87 279.89 MWD 12009.78 92.21 143.17 5929.17 1126.00 3593.37 5955464.42 532842.68 12.00 -1126.00 279.80 MWD 12025.00 92.21 145.00 5928.59 1113.68 3602.30 5955452.14 532851.65 12.00 -1113.68 90.00 MWD 12050.00 92.20 148.00 5927.63 1092.85 3616.08 5955431.37 532865.52 12.00 -1092.85 90.07 MWD 12075.00 92.19 151.00 5926.67 1071.33 3628.76 5955409.90 532878.28 12.00 -1071.33 90.19 MWD 12100.00 92.17 154.00 5925.72 1049.17 3640.29 5955387.79 532889.89 12.00 -1049.17 90.30 MWD 12125.00 92.15 157.01 5924.78 1026.44 3650.65 5955365.10 532900.34 12.00 -1026.44 90.42 MWD 12150.00 92.11 160.01 5923.85 1003.19 3659.80 5955341.89 532909.58 12.00 -1003.19 90.53 MWD 12175.00 92.08 163.01 5922.93 979.50 3667.72 5955318.24 532917.59 12.00 -979.50 90.64 MWD / 12200.00 92.04 166.01 5922.03 i 955.43 3674.39 5955294.19 532924.36 12.00 -955.43 90.75 2 3/8" • • a ~ ~ rtJt~ ~1 ~>7~ 17I 11i ytlt11 ~'+ ""FI { ~I-~;? 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I! ~ i .. ;: .- r~r~ gg gg k z ~i9~ISii33~13339~3~z ;_, f 3 • • by BP Alaska Anticollision Report ~.r 1NTEQ Company: BP Amoco Date: 1/8!2007 Time: 10:32:35: .Page: I Field: Kwparuk Reference Site: KRU 2D Pad Co-ordinate(NE) Reference: Well: 2¢06, True No rth Reference Well: 2D-O6 Vertical (TVD} Reference: 2D-06A/6 Orig Rig 121.0 Refereuce Wellpath: P{an 4, 2D-O68L1 Db: Oracle NO GLOBAL SCAN: Using user defined selection & scan criteria Reference: Principal Plan & PLANNED PROGRAM Interpolation Method: MD Inte rval: 100.00 ft Error Model: ISCWSA Ellipse Depth Range: 8642.00 to 12200.00 ft Scan Method: Trav Cylinder North Maaimum Radius: 5000.00 ft Error Surface: Ellipse + Casing Survey Program for Definitive Wellpath Date: 1/7/2007 Validated: No Version: 0 Actual From To Survey Toolcode Tool Name ft ft -5.00 7200.00 Gyro (-5.00-9135.00) (0) GCT-MS Schlumberger GCT muttishot 7420.00 8641.99 MWD (7420.00-9080.00) (1) MWD MWD -Standard 8642.00 11282.00 Gyro (8642.00-11282.00) (2) MWD MWD -Standard Casing Points MD TVD Diameter Hok Size Name ft ft in in 12200.00 0.00 2.375 3.000 2 3/8" Summary <--- Offset Wellpath.. -------> Reference Otfset Ctr-Ctr No-Go Allowable Situ Well Wellpath. MD MD Distance Area Deviation Warning ft ft ft ft ft; KRU 2D Pad 2D-~01 2D-01 V1 11800.00 5400.00 4129.05 1530.86 2598.20 Pass: Major Risk KRU 2D Pad 2D••02 2D-02 VO Out of range KRU 2D Pad 2D••03 2D-03 VO 11662.94 4500.00 4702.681461.57 3241.11 Pass: Major Risk KRU 2D Pad 2D•~04 2D-04 VO Out of range KRU 2D Pad 2D••05 2D-05 VO 9050.00 7985.00 1410.27 208.58 1201.68 Pass: Major Risk KRU 2D Pad 2D••05 Plan 3, 2D-05L1 VO Pla 9020.00 8200.00 1260.79 218.15 1042.64 Pass: Major Risk KRU 2D Pad 20••05 Plan 3, 2D-05L2 VO Pla 9020.00 8200.00 1260.79 218.15 1042.64 Pass: Major Risk KRU 2D Pad 2D-•06 2D-06 V3 9737.80 8100.00 /610.13 302.31 307.82 Pass: Major Risk KRU 2D Pad 2D••06 2D-06A VO 8699.22 8700.00 4.51 184.49 -179.98 FAIL: Major Risk KRU 2D Pad 2D••06 2D-06B V3 8699.23 8700.00 4.44 185.65 -181.21 FAIL: Major Risk KRU 2D Pad 2D••07 2D-07 VO 11766.61 6831.00 1626.871517.14 109.74 Pass: Major Risk KRU 2D Pad 2D••08 2D-08 VO 12191.48 7100.00 ~ 677.62 2041.95 - 1364.32 FAIL: Major Risk KRU 2D Pad 2D••09 2D-09 VO ------ Out of range KRU 2D Pad 2D••10 2D-10 VO Out of range KRU 2D Pad 2D-•11 2D-11 VO Out of range KRU 2D Pad 2D-•12 2D-12 VO Out of range KRU 2D Pad 2D••13 2D-13 VO Out of range KRU 2D Pad 2D••14 2D-14 VO Out of range KRU 2D Pad 2D-•15 2D-15 VO Out of range KRU 2D Pad 2D-•16 2D-16 VO Out of range Site: KRU 2D Pad Well: 2D-01 Rule Assigned: Major Risk Wellpath: 2D-01 V1 Inter-Site Error: 0.00 ft Re[ereACe Offset Semi-Major Adis Ctr-Gtr No,Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-IiS Casing/lISflistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11887.82 6052.28 3000.00 2999.79 557.25 0.78 209.95 52.32 ~"4993.941582.13 3411.81 Pass 11887.78 6052.28 3100.00 3099.79 557.24 0.87 210.87 53.24 4933.381579.30 3354.07 Pass 11887.76 6052.28 3200.00 3199.79 557.23 1.11 211.82 54.18 4874.191576.56 3297.63 Pass 11887.64 6052.28 3300.00 3299.78 557.19 1.25 212.79 55.15 4816.371573.57 3242.80 Pass 11887.20 6052.28 3400.00 3399.70 557.04 1.36 213.83 56.13 4759.571570.44 3189.14 Pass 11886.30 6052.28 3500.00 3499.35 556.73 1.58 214.94 57.13 4703.721567.50 3136.22 Pass 11875.00 6052.30 3600.00 3598.51 552.84 1.89 217.30 58.14 4648.941563.26 3085.68 Pass 11875.00 6052.30 3'700.00 3696.85 552.84 2.26 218.33 59.16 4595.451561.17 3034.28 Pass 11875.00 6052.30 3800.00 3794.09 552.84 2.69 219.37 60.20 4544.651559.27 2985.38 Pass 11875.00 6052.30 3900.00 3890.13 552.84 3.15 220.44 61.27 4497.971557.45 2940.53 Pass 11875.00 6052.30 4000.00 3984.63 552.84 3.62 221.51 62.35 4455.321555.72 2899.60 Pass 11875.00 6052.30 4100.00 4077.64 552.84 4.04 222.59 63.43 4414.681554.01 2860.66 Pass 11875.00 6052.30 4200.00 4169.60 552.84 4.49 223.68 64.51 4375.971552.43 2823.55 Pass ~ • by BP Alaska Anticollision Report ~.r s LNTEQ `Company:. BP Amoco Date: 1/8/2007 Time: 10:32:35 Page: 2 Field:. Kuparuk Reference Site: KRU 3D Pad Co-ordin9te(NE) Reference: Well: 2D-O6, Tfue North Reterenee Well: 2D-06 ` Vertical (TVD) Reference:; 2D-06A/ B Orig Rig 121.0 Reference Wellpatb: Plan 4 2D-O6Bt1 Db: made Site: KRU 2D Pad Well: 2D-01 Rnle Assigned: Major Risk Wellpath: 2D-01 V1 Inter-Site Error: 0.00 ft Reference' Offset Semi-MajorAxiv Ctr-Ctr Nato Allowable MD` TVD MD TVD Ref OffsM TFO+AZI TFO-HS Casing/H3)istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11861.08 6052.31 4300.00 4260.86 548.08 4.92 226.46 65.63 4340.961549.01 2791.95 Pass 11850.00 6052.32 4400.00 4351.17 544.29 5.35 228.92 66.76 4311.021546.45 2764.58 Pass 11850.00 6052.32 4500.00 4439.72 544.29 5.86 230.06 67.90 4285.741545.62 2740.12 Pass 11850.00 6052.32 4600.00 4526.10 544.29 6.39 231.19 69.03 4264.371544.99 2719.38 Pass 11850.00 6052.32 4700.00 4610.83 544.29 6.81 232.31 70.14 4244.651544.23 2700.42 Pass 11825.00 6052.31 4800.00 4694.21 535.81 7.17 236.41 71.24 4224.911538.87 2686.04 Pass 11825.00 6052.31 4900.00 4775.88 535.81 7.55 237.49 72.33 4204.491538.50 2665.98 Pass 11825.00 6052.31 5000.00 4854.93 535.81 8.02 238.54 73.37 4184.341538.47 2645.87 Pass 11825.00 6052.31 5100.00 4932.51 535.81 8.42 239.57 74.40 4165.821538.36 2627.46 Pass 11800.00 6052.28 5200.00 5010.05 527.40 8.72 243.61 75.45 4149.561530.86 2618.71 Pass 11800.00 6052.28 5300.00 5087.59 527.40 9.05 244.68 76.51 4136.881530.72 2606.16 Pass 11800.00 6052.28 5400.00 5164.85 527.40 9.44 245.75 77.59 4129.051530.86 2598.20 Pass 11788.67 6052.26 5500.00 5241.38 523.62 9.88 248.19 78.67 4126.781526.60 2600.19 Pass 11775.00 6052.23 5600.00 5317.83 519.06 10.13 250.91 79.75 4128.601520.94 2607.67 Pass 11775.00 6052.23 5700.00 5395.16 519.06 10.19 252.02 80.85 4132.601520.40 2612.20 Pass 11775.00 6052.23 5800.00 5473.72 519.06 10.28 253.13 81.97 4138.931519.98 2618.95 Pass 11763.55 6052.19 5900.00 5553.35 515.27 10.37 255.63 83.09 4147.291513.42 2633.86 Pass 11750.00 6052.15 6000.00 5633.03 510.79 10.64 258.38 84.21 4159.131506.37 2652.76 Pass 11750.00 6052.15 6100.00 5712.99 510.79 10.94 259.50 85.34 4173.591506.82 2666.76 Pass 11750.00 6052.15 6200.00 5794.17 510.79 11.06 260.63 86.47 4189.471506.81 2682.66 Pass 11750.00 6052.15 6300.00 5876.56 510.79 11.20 261.77 87.61 4206.251506.92 2699.33 Pass 11735.84 6052.10 6400.00 5960.13 506.14 11.30 264.61 88.75 4223.221497.17 2726.05 Pass 11725.00 6052.05 6500.00 6044.89 502.59 11.43 267.06 89.90 4241.071489.80 2751.28 Pass 11725.00 6052.05 6600.00 6131.09 502.59 11.61 268.23 91.06 4259.861490.19 2769.67 Pass 11725.00 6052.05 6700.00 6218.45 502.59 11.82 269.39 92.23 4279.951490.70 2789.25 Pass 11718.30 6052.02 6774.00 6283.36 500.41 12.02 271.05 93.09 4295.961485.78 2810.18 Pass Site: KRU 2D Pad Well: 2D-03 Rule Assigned: Major Risk Wellpath: 2D-03 VO Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go- Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSflistaoce Area Deviation WaroinE ft ft ft ft ft ft deg deg in ft ft ft 11725.00 6052.05 3500.00 3040.20 502.59 10.94 230.11 52.95 4999.831519.49 3480.33 Pass 11725.00 6052.05 3600.00 3111.24 502.59 11.08 230.83 53.66 4963.441518.92 3444.52 Pass 11719.16 6052.02 3700.00 3182.87 500.69 11.23 232.26 54.40 4928.401513.47 3414.94 Pass 11709.78 6051.98 3800.00 3255.26 497.63 11.40 234.14 55.15 4894.581505.09 3389.49 Pass 11704.73 6051.95 3900.00 3328.23 496.00 11.61 235.53 55.93 4862.041500.25 3361.79 Pass 11700.00 6051.93 4000.00 3401.32 494.47 11.99 236.89 56.73 4831.251496.16 3335.08 Pass 11700.00 6051.93 4100.00 3474.27 494.47 12.55 237.70 57.54 4802.481496.77 3305.71 Pass 11675.00 6051.81 4200.00 3547.22 486.42 12.95 241.52 58.36 4775.291473.37 3301.92 Pass 11675.00 6051.81 4300.00 3620.17 486.42 13.43 242.37 59.20 4749.801473.74 3276.06 Pass 11675.00 6051.81 4400.00 3693.19 486.42 13.90 243.22 60.06 4725.811474.13 3251.68 Pass 11662.94 6051.76 4500.00 3766.30 482.57 14.28 245.53 60.92 4702.681461.57 3241.11 Pass 10775.00 6051.65 4600.00 3839.42 240.36 14.97 232.59 61.65 4675.80 756.05 3919.75 Pass 10761.64 6052.48 4700.00 3912.63 237.34 15.27 235.03 62.50 4643.89 749.76 3894.13 Pass 10750.00 6053.24 4800.00 3986.02 234.71 15.56 237.27 63.36 4614.01 744.37 3869.64 Pass 10750.00 6053.24 4900.00 4059.73 234.71 15.88 238.06 64.15 4585.86 744.76 3841.11 Pass 10750.00 6053.24 5000.00 4133.73 234.71 16.22 238.86 64.95 4559.72 745.23 3814.49 Pass 10725.00 6055.01 5100.00 4207.44 229.10 16.62 242.86 65.97 4535.37 732.57 3802.80 Pass 10725.00 6055.01 5200.00 4280.65 229.10 17.14 243.67 66.78 4511.80 733.70 3778.09 Pass 10718.68 6055.49 5300.00 4353.83 227.69 17.55 245.29 67.66 4489.29 730.87 3758.42 Pass • ~ by BP Alaska Anticollision Report ~.r ~il~s 1NTEQ Company: BP Amoco Date. 4/8/2007 Time: 10:32.35 Page: 3 F'uad: Kuparuk Reference Site: KRU 2D Pad Co-ordinatc(NE) Reference: '- WetL 2D-06, True North Reference Weil: 2D-06 Vertical (TYD) Reference: 2D-06A/B Orrg Rig 121.0 Reference Welipat6t Plan 4, 2D-06811 Db: Orate Site: KRU 2D Pad Well: 2D-03 Rule Assigned: Major Risk Weilpath: 2D-03 VO Inter-Site Error: 0.00 ft ".Reference Offset Semi-Major Axis Ctr-Ctr ATo-Go Aliowable MD TVD MD TVD Ref -0ffset TFO+AZI TFO-HS Casiog/HSDi~tance Area Deviation Warning ft R _ ft ft ft ft deg deg in ft ft ft 10709.78 6056.18 5400.00 4427.23 225.70 17.88 247.27 68.57 4468.67 726.31 3742.36 Pass 10703.67 6056.66 5500.00 4500.91 224.37 18.22 248.90 69.47 4450.01 723.22 3726.79 Pass 10700.00 6056.94 5600.00 4575.02 223.58 18.58 250.24 70.37 4433.28 721.69 3711.59 Pass 10688.10 6057.83 5700.00 4649.40 221.02 18.92 252.64 71.36 4418.49 714.80 3703.69 Pass 10675.00 6058.76 5800.00 4723.66 218.20 19.30 255.20 72.36 4405.07 707.34 3697.74 Pass 10675.00 6058.76 5900.00 4797.18 218.20 19.81 256.09 73.25 4392.27 708.56 3683.71 Pass 9175.00 6113.07 6000.00 4869.97 27.66 20.61 238.29 73.43 4368.97 158.32 4210.65 Pass 9175.00 6113.07 6100.00 4942.68 27.66 21.06 239.09 74.23 4334.33 160.16 4174.17 Pass 9150.00 6114.57 6200.00 5015.82 27.59 21.53 243.09 75.24 4301.60 163.65 4137.95 Pass 9150.00 6114.57 6300.00 5089.44 27.59 21.97 243.95 76.10 4270.48 165.51 4104.97 Pass 9150.00 6114.57 6400.00 5162.81 27.59 22.46 244.81 76.96 4240.89 167.55 4073.34 Pass 9136.17 6115.33 6500.00 5234.87 27.64 23.00 247.42 77.92 4213.29 170.74 4042.55 Pass 9125.00 6115.92 6600.00 5306.34 27.68 23.49 249.70 78.86 4189.03 173.58 4015.45 Pass 9125.00 6115.92 6700.00 5378.50 27.68 23.94 250.60 79.77 4167.63 175.45 3992.18 Pass 9113.06 6116.51 6800.00 5451.76 27.79 24.38 253.03 80.77 4148.45 178.32 3970.13 Pass 9100.00 6117.11 6900.00 5525.84 27.90 24.83 255.61 81.80 4131.54 181.28 3950.26 Pass 9100.00 6117.11 7000.00 5600.69 27.90 25.29 256.59 82.78 4116.83 183.20 3933.63 Pass 9100.00 6117.11 7100.00 5676.42 27.90 25.74 257.59 83.77 4104.59 185.12 3919.48 Pass 9075.00 6118.15 7200.00 5752.42 28.23 26.15 261.71 84.91 4095.01 188.97 3906.04 Pass 9075.00 6118.15 7300.00 5828.01 28.23 26.62 262.73 85.93 4089.09 190.85 3898.25 Pass 9068.98 6118.38 7400.00 5903.08 28.33 27.08 264.49 86.98 4085.87 193.22 3892.65 Pass 9064.78 6118.54 7500.00 5977.39 28.39 27.58 266.02 88.00 4084.35 195.47 3888.88 Pass 9060.00 6118.71 7600.00 6050.87 28.76 28.02 269.25 89.08 4084.89 198.89 3886.01 Pass 9060.00 6118.71 7700.00 6123.86 28.76 28.55 270.23 90.07 4087.68 200.79 3886.90 Pass 9060.00 6118.71 7800.00 6196.54 28.76 29.08 271.22 91.05 4092.36 202.67 3889.69 Pass 9055.31 6118.88 7900.00 6269.11 29.14 29.52 274.38 92.10 4098.94 205.75 3893.19 Pass 9054.94 6118.89 7917.00 6281.45 29.16 29.60 274.72 92.27 4100.30 206.14 3894.15 Pass Site: KRU 2D Pad Well: 2D-05 Rule Assigned: Major Risk Weilpath: 2D-05 VO Inter-Site Error: 0.00 ft Reference Offset Semi-MajorAais Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS CasieglHS1)istance Area Deviation .Warning ft ft ft ft ft ft deg .deg irr ft ft ft 11775.00 6052.23 2500.00 2222.47 519.06 9.76 210.67 39.50 4963.751566.67 3397.08 Pass 11775.00 6052.23 2600.00 2295.54 519.06 10.18 210.82 39.65 4879.161567.30 3311.87 Pass 11764.71 6052.20 2700.00 2368.25 515.65 10.76 212.20 39.80 4795.111560.17 3234.94 Pass 11750.00 6052.15 2800.00 2440.82 510.79 11.24 214.12 39.95 4711.531549.59 3161.94 Pass 11750.00 6052.15 2900.00 2513.09 510.79 11.64 214.28 40.12 4628.121550.27 3077.85 Pass 11750.00 6052.15 3000.00 2584.70 510.79 12.15 214.44 40.28 4545.061551.07 2993.98 Pass 11734.38 6052.09 3100.00 2655.74 505.67 12.76 216.47 40.44 4462.331539.30 2923.03 Pass 11725.00 6052.05 3200.00 2726.46 502.59 13.37 217.77 40.60 4380.291532.58 2847.71 Pass 11717.99 6052.02 3300.00 2796.67 500.31 13.98 218.78 40.78 4298.961527.51 2771.45 Pass 11709.78 6051.98 3400.00 2866.19 497.63 14.60 219.95 40.96 4218.391521.47 2696.91 Pass 11700.00 6051.93 3500.00 2935.24 494.47 15.23 221.30 41.14 4138.561513.94 2624.62 Pass 11700.00 6051.93 3600.00 3004.03 494.47 15.82 221.50 41.34 4059.551514.88 2544.68 Pass 11675.00 6051.81 3700.00 3072.59 486.42 16.51 224.71 41.54 3981.271493.25 2488.02 Pass 11675.00 6051.81 3800.00 3141.15 486.42 16.88 224.95 41.79 3903.591493.86 2409.73 Pass 11663.97 6051.76 3900.00 3209.88 482.90 17.04 226.53 42.04 3826.751483.30 2343.45 Pass 11650.00 6051.70 4000.00 3278.56 478.44 17.37 228.49 42.32 3751.031470.00 2281.03 Pass 11650.00 6051.70 4100.00 3348.07 478.44 17:63 228.83 42.67 3677.081470.09 2206.99 Pass ; by BP Alaska Anticollision Report • ~.r ~s 1NTEQ `Company: BP Amoco Date: 1/8/2007 Tune: 10:32 :35 Page: a Fielde Kuparuk Reference Site: KRU 2D Pad Co-ordinate(NE) Reference: Well- 2D-06, True North Reference Weil:- 2D-06 Vertical(TVl)) Reference: ` 2D-08A/B Orig Rig 121.0. Reference Welipath: Plan 4, 2D-O6BL1 Db: Oracle Site: KRU 2D Pad Well: 2D-05 Rule Assigned: Major Risk Welipath: 2D-05 VO Inter-Site Error: 0.00 ft Reference Offset Semi-MajorAxs Gtr-Ctr No-Go- A~owabie MD TVD MD TVD Ref`. Offset TFO+AZI TFO-HS Casiog/HSUistanee Area Deviation Warning ft_ ft ft ft ft ft deg deg in ft ft ft 11625.00 6051.61 4200.00 3418.50 470.52 17.89 232.23 43.07 3605.111444.28 2160.83 Pass 10800.00 6050.26 4300.00 3489.08 246.04 16.77 211.31 43.34 3525.25 775.89 2749.36 Pass 10800.00 6050.26 4400.00 3559.71 246.04 16.93 211.50 43.53 3442.72 776.04 2666.68 Pass 10785.88 6051.02 4500.00 3630.35 242.83 17.40 213.48 43.83 3361.00 769.90 2591.10 Pass 10775.00 6051.65 4600.00 3700.85 240.36 18.01 215.07 44.14 3280.26 765.59 2514.68 Pass 10775.00 6051.65 4700.00 3771.63 240.36 18.29 215.33 44.39 3200.47 766.05 2434.42 Pass 10750.00 6053.24 4800.00 3842.64 234.71 18.75 218.78 44.87 3121.65 753.91 2367.74 Pass 10750.00 6053.24 4900.00 3914.35 234.71 19.01 219.13 45.22 3044.01 754.30 2289.71 Pass 10738.68 6054.02 5000.00 3987.38 232.17 19.22 220.99 45.73 2968.11 748.38 2219.73 Pass 10725.00 6055.01 5100.00 4061.14 229.10 19.56 223.24 46.35 2894.76 741.38 2153.37 Pass 10717.21 6055.60 5200.00 4134.96 227.36 20.05 224.80 46.98 2823.63 737.68 2085.96 Pass 10705.04 6056.55 5300.00 4208.71 224.67 20.72 226.97 47.70 2754.10 731.72 2022.37 Pass 10690.71 6057.64 5400.00 4282.83 221.58 21.31 229.52 48.54 2688.12 723.90 1964.22 Pass 10675.00 6058.76 5500.00 4357.66 218.20 21.77 232.38 49.53 2626.90 714.87 1912.03 Pass 10661.18 6059.69 5600.00 4432.79 215.27 22.33 235.09 50.60 2568.77 707.03 1861.75 Pass 10650.00 6060.40 5700.00 4507.89 212.90 22.89 237.55 51.72 2512.88 700.89 1811.99 Pass 10625.00 6061.84 5800.00 4583.03 207.67 23.44 241.81 53.02 2459.44 685.14 1774.30 Pass 10616.36 6062.30 5900.00 4658.28 205.88 23.75 244.11 54.29 2408.50 679.62 1728.88 Pass 10600.00 6063.10 6000.00 4733.73 202.50 24.10 247.45 55.69 2360.26 668.70 1691.55 Pass 9259.12 6107.32 6100.00 4809.29 29.24 20.28 210.45 55.68 2308.41 132.43 2175.99 Pass 9250.00 6107.97 6200.00 4884.91 28.95 20.58 212.51 56.65 2231.66 133.92 2097.75 Pass 9236.65 6108.91 6300.00 4960.59 28.63 20.97 215.20 57.74 2156.62 136.01 2020.61 Pass 9225.00 6109.73 6400.00 5036.25 28.34 21.53 217.77 58.90 2083.43 138.54 1944.89 Pass 9212.57 6110.58 6500.00 5112.33 28.13 22.05 220.54 60.18 2012.33 141.46 1870.87 Pass 9200.00 6111.43 6600.00 5189.01 27.91 22.41 223.47 61.60 1943.49 144.41 1799.09 Pass 9189.78 6112.11 6700.00 5265.88 27.78 22.83 226.21 63.11 1877.16 147.57 1729.59 Pass 9175.00 6113.07 6800.00 5342.65 27.66 23.52 229.66 64.79 1813.55 151.82 1661.73 Pass 9159.40 6114.02 6900.00 5419.86 27.62 24.16 233.36 66.63 1753.06 156.50 1596.56 Pass 9150.00 6114.57 7000.00 5498.44 27.59 24.55 236.48 68.62 1696.24 160.38 1535.86 Pass 9125.00 6115.92 7100.00 5578.77 27.68 25.23 241.78 70.95 1643.54 166.89 1476.65 Pass 9118.03 6116.26 7200.00 5660.87 27.74 25.59 245.06 73.39 1595.10 171.04 1424.06 Pass 9100.00 6117.11 7300.00 5744.85 27.90 26.15 249.95 76.14 1551.43 177.07 1374.36 Pass 9092.46 6117.44 7400.00 5830.79 28.00 26.51 253.78 79.07 1512.54 181.56 1330.98 Pass 9075.00 6118.15 7500.00 5918.42 28.23 27.05 259.06 82.26 1478.72 187.54 1291.19 Pass 9069.25 6118.37 7600.00 6007.20 28.32 27.37 263.09 85.60 1450.90 191.54 1259.37 Pass 9062.65 6118.61 7700.00 6096.98 28.56 27.80 268.11 89.13 1429.82 196.34 1233.48 Pass 9060.00 6118.71 7800.00 6187.94 28.76 28.18 272.96 92.79 1416.12 200.31 1215.81 Pass 9055.81 6118.86 7900.00 6279.57 29.09 28.66 278.60 96.55 1409.92 204.46 1205.47 Pass 9050.00 6119.07 7985.00 6357.54 29.56 29.25 284.47 99.80 1410.27 208.58 1201.68 Pass Site: KRU 2D Pad Well: 2D-05 Ruk Assigned: Major Risk Welipath: Plan 3, 2D-05L1 VO Plan: Plan #3 V5 Inter-Site Error: 0.00 ft Reference - Ofteet Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref. Offset TFO+AZI TFO-AS Casiog/HSUistaoce Area Deviation VVsrning ft tt ft ft ft ft deg deg in ft' ft ft 11775.00 6052.23 2500.00 2222.47 519.06 9.76 210.67 39.50 3.125 4963.75 1566.70 3397.05 Pass 11775.00 6052.23 2600.00 2295.54 519.06 10.18 210.82 39.65 3.125 4879.16 1567.33 3311.83 Pass 11764.71 6052.20 2700.00 2368.25 515.65 10.76 212.20 39.80 3.125 4795.11 1560.20 3234.91 Pass 11750.00 6052.15 2800.00 2440.82 510.79 11.24 214.12 39.95 3.125 4711.53 1549.62 3161.91 Pass 11750.00 6052.15 2900.00 2513.09 510.79 11.64 214.28 40.12 3.125 4628.12 1550.30 3077.82 Pass • • by BP Alaska Anticollision Report ~.r ~~$ INTEQ Company: BP Amoco Date: 1/8/2007 Tiroe: 10:32:35 Pager 5 Ftield: Kupatuk Retereoee Site: KRIJ 2D Pad Go-ordiuate(NE) Reference: WeII: 2D-06, True No rth Reference Well: 2D-O6 Verltcal (TVD) Reference: ` 2D-06A/B Orig Rig 121.0 Reference Welipat6: Plan 4, 2D-O6BL1 Db: Oracle Site: KRU 2D Pad Well: 2D-05 Rule Assigned: Major Risk Wellpath: Plan 3, 2 D-05L1 VO P lan: Plan #3 V5 Inter-Site Error: 0.00 ft lteterence Oftset Semi-Major Axis Ctr-Ctr No-Go AOowable NID TVD MD TVD 13ei Offset TFO+A2J TFO-HS Casing/HSDistaace Area ,, Deviation Warning ft ft ft ft ft ft deg deg in ft' ft ft 11750.00 6052.15 3000.00 2584.70 510.79 12.15 214.44 40.28 3.125 4545.061 551.10 2993.95 Pass 11734.38 6052.09 3100.00 2655.74 505.67 12.76 216.47 40.44 3.125 4462.331 539.33 2923.00 Pass 11725.00 6052.05 3200.00 2726.46 502.59 13.37 217.77 40.60 3.125 4380.291 532.61 2847.68 Pass 11717.99 6052.02 3300.00 2796.67 500.31 13.98 218.78 40.78 3.125 4298.961 527.54 2771.42 Pass 11709.78 6051.98 3400.00 2866.19 497.63 14.60 219.95 40.96 3.125 4218.391 521.50 2696.88 Pass 11700.00 6051.93 3500.00 2935.24 494.47 15.23 221.30 41.14 3.125 4138.561 513.97 2624.59 Pass 11700.00 6051.93 3600.00 3004.03 494.47 15.82 221.50 41.34 3.125 4059.551 514.91 2544.65 Pass 11675.00 6051.81 3700.00 3072.59 486.42 16.51 224.71 41.54 3.125 3981.271 493.28 2487.99 Pass 11675.00 6051.81 3800.00 3141.15 486.42 16.88 224.95 41.79 3.125 3903.591 493.89 2409.70 Pass 11663.97 6051.76 3900.00 3209.89 482.90 17.04 226.53 42.04 3.125 3826.751 483.33 2343.41 Pass 11650.00 6051.70 4000.00 3278.56 478.44 17.37 228.49 42.32 3.125 3751.031 470.04 2281.00 Pass 11650.00 6051.70 4100.00 3348.07 478.44 17.63 228.83 42.67 3.125 3677.081 470.12 2206.96 Pass 11625.00 6051.61 4200.00 3418.50 470.52 17.89 232.23 43.07 3.125 3605.111 444.31 2160.80 Pass 10800.00 6050.26 4300.00 3489.08 246.04 16.77 211.31 43.34 3.125 3525.25 775.92 2749.33 Pass 10800.00 6050.26 4400.00 3559.71 246.04 16.93 211.50 43.53 3.125 3442.72 776.08 2666.65 Pass 10785.88 6051.02 4500.00 3630.35 242.83 17.40 213.48 43.83 3.125 3361.00 769.93 2591.07 Pass 10775.00 6051.65 4600.00 3700.85 240.36 18.01 215.07 44.14 3.125 3280.26 765.62 2514.64 Pass 10775.00 6051.65 4700.00 3771.63 240.36 18.29 215.33 44.39 3.125 3200.47 766.08 2434.39 Pass 10750.00 6053.24 4800.00 3842.64 234.71 18.75 218.78 44.87 3.125 3121.65 753.94 2367.71 Pass 10750.00 6053.24 4900.00 3914.35 234.71 19.01 219.13 45.22 3.125 3044.01 754.33 2289.68 Pass 10738.68 6054.02 5000.00. 3987.38 232.17 19.22 220.99 45.73 3.125 2968.11 748.42 2219.70 Pass 10725.00 6055.01 5100.00 4061.14 229.10 19.56 223.24 46.35 3.125 2894.76 741.41 2153.34 Pass 10717.21 6055.60 5200.00 4134.96 227.36 20.05 224.80 46.98 3.125 2823.63 737.71 2085.92 Pass 10705.04 6056.55 5300.00 4208.71 224.67 20.72 226.97 47.70 3.125 2754.10 731.75 2022.34 Pass 10690.71 6057.64 5400.00 4282.83 221.58 21.31 229.52 48.54 3.125 2688.12 723.93 1964.19 Pass 10675.00 6058.76 5500.00 4357.66 218.20 21.77 232.38 49.53 3.125 2626.90 714.90 1912.00 Pass 10661.18 6059.69 5600.00 4432.79 215.27 22.33 235.09 50.60 3.125 2568.77 707.06 1861.71 Pass 10650.00 6060.40 5700.00 4507.89 212.90 22.89 237.55 51.72 3.125 2512.88 700.92 1811.96 Pass 10625.00 6061.84 5800.00 4583.03 207.67 23.44 241.81 53.02 3.125 2459.44 685.17 1774.27 Pass 10616.36 6062.30 5900.00 4658.28 205.88 23.75 244.11 54.29 3.125 2408.50 679.65 1728.85 Pass 10600.00 6063.10 6000.00 4733.73 202.50 24.10 247.45 55.69 3.125 2360.26 668.73 1691.52 Pass 9259.12 6107.32 6100.00 4809.29 29.24 20.28 210.45 55.68 3.125 2308.41 132.46 2175.96 Pass 9250.00 6107.97 6200.00 4884.91 28.95 20.58 212.51 56.65 3.125 2231.66 133.95 2097.71 Pass 9236.65 6108.91 6300.00 4960.59 28.63 20.97 215.20 57.74 3.125 2156.62 136.04 2020.58 Pass 9225.00 6109.73 6400.00 5036.25 28.34 21.53 217.77 58.90 3.125 2083.43 138.58 1944.86 Pass 9212.57 6110.58 6500.00 5112.33 28.13 22.05 220.54 60.18 3.125 2012.33 141.49 1870.84 Pass 9200.00 6111.43 6600.00 5189.01 27.91 22.41 223.47 61.60 3.125 1943.49 144.44 1799.05 Pass 9189.78 6112.11 6700.00 5265.88 27.78 22.83 226.21 63.11 3.125 1877.16 147.60 1729.56 Pass 9175.00 6113.07 6800.00 5342.65 27.66 23.52 229.66 64.79 3.125 1813.55 151.85 1661.70 Pass 9159.40 6114.02 6900.00 5419.86 27.62 24.16 233.36 66.63 3.125 1753.06 156.53 1596.53 Pass 9150.00 6114.57 7000.00 5498.44 27.59 24.55 236.48 68.62 3.125 1696.24 160.41 1535.83 Pass 9125.00 6115.92 7100.00 5578.77 27.68 25.23 241.78 70.95 3.125 1643.54 166.92 1476.62 Pass 9118.03 6116.26 7200.00 5660.87 27.74 25.59 245.06 73.39 3.125 1595.10 171.07 1424.03 Pass 9100.00 6117.11 7300.00 5744.85 27.90 26.15 249.95 76.14 3.125 1551.43 177.10 1374.33 Pass 9092.46 6117.44 7400.00 5830.79 28.00 26.51 253.78 79.07 3.125 1512.54 181.59 1330.95 Pass 9075.00 6118.15 7500.00 5918.42 28.23 27.05 259.06 82.26 3.125 1478.72 187.55 1291.17 Pass 9069.25 6118.37 7600.00 6007.20 28.32 27.26 263.09 85.60 3.125 1450.90 191.95 1258.95 Pass 9062.06 6118.63 7700.00 6091.75 28.60 27.53 268.16 88.92 3.125 1427.00 195.99 1231.01 Pass 9054.83 6118.89 7800.00 6124.86 29.17 28.03 272.74 90.25 3.125 1395.13 200.63 1194.50 Pass 9050.00 6119.07 7900.00 6127.20 29.56 28.42 274.96 90.29 3.125 1354.56 203.51 1151.04 Pass 9040.00 6119.42 8000.00 6127.77 30.37 29.08 279.53 90.36 3.125 1303.05 208.90 1094.16 Pass • ~ by BP Alaska Anticollision Report ~.r 1NTEQ Company: BP Amoco Date: 1/8/2007 Time: 10:32:35 Page:. 6 Field: Kupatuk Reference Site: KRU 2D Pad Go-ordinate(NE) Reference: Well: 2D-O6, True North Reference Well: 2D-06 Vertical ('I'VD} Reference: 2D-06A1B Orig Rig 121.0 Reference Wellpath: Plan 4 2D-06BL1 Db: Orate Site: KRU 2D Pad Well: 2D-05 Rule Assigned: Major Risk Wellpath: Plan 3, 2 D-05L1 VO Plan: Plan #3 V5 Inter-Site Error: 0.00 ft Reference. Offset Semi-MajorAats Ctr-Ctr No-Go' Allowable MD TVD MD TVD Ref Offset. TFO+AZI TFO-HS Casing/HSUistance Area Deviation Warnieg ft $ ft ft ft ft deg deg in ft' ft, ft 9030.00 6119.78 8100.00 6128.21 31.16 29.66 284.08 90.40 3.125 1268.38 213.74 1054.64 Pass 9020.00 6120.12 8200.00 6128.98 31.89 30.21 288.62 90.44 3.125 1260.79 218.15 1042.64 Pass 9010.00 6120.46 8300.00 6129.80 32.55 30.71 293.15 90.47 3.125 1281.04 222.00 1059.05 Pass 9004.97 6120.63 8400.00 6130.53 32.83 31.05 295.37 90.43 3.125 1320.19 224.02 1096.17 Pass 9000.00 6120.79 8500.00 6131.00 33.11 31.40 297.56 90.38 3.125 1349.06 226.02 1123.03 Pass 8990.00 6121.11 8600.00 6130.48 33.56 31.70 302.05 90.37 3.125 1387.82 228.45 1159.36 Pass 8980.00 6121.41 8700.00 6128.52 33.89 31.82 306.50 90.32 3.125 1449.37 229.90 1219.47 Pass 8980.00 6121.41 8800.00 6125.21 33.89 32.15 306.29 90.11 3.125 1528.59 230.88 1297.72 Pass 8974.61 6121.56 8900.00 6120.71 33.99 32.14 308.58 89.97 3.125 1619.88 231.20 1388.69 Pass 8970.00 6121.69 9000.00 6116.48 34.09 31.97 310.56 89.87 3.125 1717.93 231.00 1486.93 Pass 8970.00 6121.69 9100.00 6113.55 34.09 31.94 310.48 89.79 3.125 1817.68 230.91 1586.77 Pass 8974.77 6121.56 9200.00 6111.93 33.99 32.14 308.25 89.71 3.125 1915.51 231.18 1684.33 Pass 8975.21 6121.55 9300.00 6110.17 33.98 32.13 308.02 89.68 3.125 2015.06 231.12 1783.94 Pass 8974.44 6121.57 9400.00 6105.92 34.00 32.14 308.26 89.58 3.125 2113.92 231.21 1882.71 Pass 8970.00 6121.69 9500.00 6101.59 34.09 31.95 310.20 89.51 3.125 2208.32 230.93 1977.39 Pass 8970.00 6121.69 9600.00 6101.80 34.09 32.20 310.19 89.50 3.125 2295.05 231.67 2063.38 Pass 8970.00 6121.69 9700.00 6105.03 34.09 32.54 310.25 89.56 3.125 2376.14 232.70 2143.44 Pass 8964.92 6121.83 9800.00 6108.45 34.12 32.29 312.66 89.69 3.125 2466.92 232.08 2234.84 Pass 8960.00 6121.96 9900.00 6111.63 34.15 31.86 315.00 89.82 3.125 2564.66 230.88 2333.78 Pass 8960.00 6121.96 10000.00 6115.53 34.15 31.83 315.10 89.91 3.125 2664.39 230.80 2433.58 Pass 8960.00 6121.96 10100.00 6120.24 34.15 31.79 315.20 90.02 3.125 2763.94 230.66 2533.28 Pass 8960.00 6121.96 10200.00 6124.78 34.15 31.84 315.29 90.10 3.125 2862.62 230.83 2631.78 Pass 8960.00 6121.96 10300.00 6128.95 34.15 32.02 315.35 90.16 3.125 2956.47 231.36 2725.12 Pass 8960.00 6121.96 10400.00 6132.45 34.15 32.30 315.39 90.20 3.125 3042.03 232.21 2809.82 Pass 8960.00 6121.96 10500.00 6133.91 34.15 32.68 315.38 90.19 3.125 3116.63 233.38 2883.26 Pass 8955.09 6122.08 10600.00 6134.25 34.11 32.32 317.61 90.22 3.125 3195.24 232.14 2963.10 Pass 8950.00 6122.21 10700.00 6134.35 34.07 31.75 319.94 90.25 3.125 3285.67 230.27 3055.40 Pass 8950.00 6122.21 10800.00 6133.99 34.07 31.88 319.92 90.23 3.125 3383.06 230.66 3152.40 Pass 8950.00 6122.21 10900.00 6132.82 34.07 31.87 319.89 90.20 3.125 3482.86 230.63 3252.23 Pass 8950.00 6122.21 10945.00 6132.04 34.07 31.82 319.88 90.19 3.125 3527.38 230.49 3296.89 Pass Site: KRU 2D Pad Well: 2D-05 Rule Assigned: Major Risk Wellpath: Plan 3, 2D-05L2 VO Plan: Plan #3 V4 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/H~istance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11775.00 6052.23 2500.00 2222.47 519.06 9.76 210.67 39.50 3.125 4963.751566.70 3397.05 Pass 11775.00 6052.23 2600.00 2295.54 519.06 10.18 210.82 39.65 3.125 4879.161567.33 3311.83 Pass 11764.71 6052.20 2700.00 2368.25 515.65 10.76 212.20 39.80 3.125 4795.111560.20 3234.91 Pass 11750.00 6052.15 2800.00 2440.82 510.79 11.24 214.12 39.95 3.125 4711.531549.62 3161.91 Pass 11750.00 6052.15 2900.00 2513.09 510.79 11.64 214.28 40.12 3.125 4628.121550.30 3077.82 Pass 11750.00 6052.15 3000.00 2584.70 510.79 12.15 214.44 40.28 3.125 4545.061551.10 2993.95 Pass 11734.38 6052.09 3100.00 2655.74 505.67 12.76 216.47 40.44 3.125 4462.331539.33 2923.00 Pass 11725.00 6052.05 3200.00 2726.46 502.59 13.37 217.77 40.60 3.125 4380.291532.61 2847.68 Pass 11717.99 6052.02 3300.00 2796.67 500.31 13.98 218.78 40.78 3.125 4298.961527.54 2771.42 Pass 11709.78 6051.98 3400.00 2866.19 497.63 14.60 219.95 40.96 3.125 4218.391521.50 2696.88 Pass 11700.00 6051.93 3500.00 2935.24 494.47 15.23 221.30 41.14 3.125 4138.561513.97 2624.59 Pass 11700.00 6051.93 3600.00 3004.03 494.47 15.82 221.50 41.34 3.125 4059.551514.91 2544.65 Pass 11675.00 6051.81 3700.00 3072.59 486.42 16.51 224.71 41.54 3.125 3981.271493.28 2487.99 Pass 11675.00 6051.81 3800.00 3141.15 486.42 16.88 224.95 41.79 3.125 3903.591493.89 2409.70 Pass 11663.97 6051.76 3900.00 3209.89 482.90 17.04 226.53 42.04 3.125 3826.751483.33 2343.41 Pass • by BP Alaska Anticollision Report ~.r ~i~s LNTEQ Company: BP AmOCA Date: 1!8(2007 Time: 1032:35 Page: 7 Field: Kuparuk Reference Site: KRU 2D Pad Go-ordinate(NE) References. Well: 2D-06, True No rth Reference Well:. 2D-~ Vertical (TVD) Rekrence: 2D-06A/B Orig Rig 121.0 Reference Wellpath: Plan: 4, 2D-O6BL1 Db: OraGe Site: KRU 2D Pad Well: 2D-05 Rule Assigned: Major Risk Wellpath: Plan 3, 2 D-05L2 VO Plan: Plan #3 V4 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Onset; TFO+AZI TF0.IIS Casjng/H~istance Area - Deviation Warning ft R ft ft ft ft deg deg in ft ft ft 11650.00 6051.70 4000.00 3278.56 478.44 17.37 228.49 42.32 3.125 3751.031 470.04 2281.00 Pass 11650.00 6051.70 4100.00 3348.07 478.44 17.63 228.83 42.67 3.125 3677.081 470.12 2206.96 Pass 11625.00 6051.61 4200.00 3418.50 470.52 17.89 232.23 43.07 3.125 3605.111 444.31 2160.80 Pass 10800.00 6050.26 4300.00 3489.08 246.04 16.77 211.31 43.34 3.125 3525.25 775.92 2749.33 Pass 10800.00 6050.26 4400.00 3559.71 246.04 16.93 211.50 43.53 3.125 3442.72 776.08 2666.65 Pass 10785.88 6051.02 4500.00 3630.35 242.83 17.40 213.48 43.83 3.125 3361.00 769.93 2591.07 Pass 10775.00 6051.65 4600.00 3700.85 240.36 18.01 215.07 44.14 3.125 3280.26 765.62 2514.64 Pass 10775.00 6051.65 4700.00 3771.63 240.36 18.29 215.33 44.39 3.125 3200.47 766.08 2434.39 Pass 10750.00 6053.24 4800.00 3842.64 234.71 18.75 218.78 44.87 3.125 3121.65 753.94 2367.71 Pass 10750.00 6053.24 4900.00 3914.35 234.71 19.01 219.13 45.22 3.125 3044.01 754.33 2289.68 Pass 10738.68 6054.02 5000.00 3987.38 232.17 19.22 220.99 45.73 3.125 2968.11 748.42 2219.70 Pass 10725.00 6055.01 5100.00 4061.14 229.10 19.56 223.24 46.35 3.125 2894.76 741.41 2153.34 Pass 10717.21 6055.60 5200.00 4134.96 227.36 20.05 224.80 46.98 3.125 2823.63 737.71 2085.92 Pass 10705.04 6056.55 5300.00 4208.71 224.67 20.72 226.97 47.70 3.125 2754.10 731.75 2022.34 Pass 10690.71 6057.64 5400.00 4282.83 221.58 21.31 229.52 48.54 3.125 2688.12 723.93 1964.19 Pass 10675.00 6058.76 5500.00 4357.66 218.20 21.77 232.38 49.53 3.125 2626.90 714.90 1912.00 Pass 10661.18 6059.69 5600.00 4432.79 215.27 22.33 235.09 50.60 3.125 2568.77 707.06 1861.71 Pass 10650.00 6060.40 5700.00 4507.89 212.90 22:89 237.55 51.72 3.125 2512.88 700.92 1811.96 Pass 10625.00 6061.84 5800.00 4583.03 207.67 23.44 241.81 53.02 3.125 2459.44 685.17 1774.27 Pass 10616.36 6062.30 5900.00 4658.28 205.88 23.75 244.11 54.29 3.125 2408.50 679.65 1728.85 Pass 10600.00 6063.10 6000.00 4733.73 202.50 24.10 247.45 55.69 3.125 2360.26 668.73 1691.52 Pass 9259.12 6107.32 6100.00 4809.29 29.24 20.28 210.45 55.68 3.125 2308.41 132.46 2175.96 Pass 9250.00 6107.97 6200.00 4884.91 28.95 20.58 212.51 56.65 3.125 2231.66 133.95 2097.71 Pass 9236.65 6108.91 6300.00 4960.59 28.63 20.97 215.20 57.74 3.125 2156.62 136.04 2020.58 Pass 9225.00 6109.73 6400.00 5036.25 28.34 21.53 217.77 58.90 3.125 2083.43 138.58 1944.86 Pass 9212.57 6110.58 6500.00 5112.33 28.13 22.05 220.54 60.18 3.125 2012.33 141.49 1870.84 Pass 9200.00 6111.43 6600.00 5189.01 27.91 22.41 223.47 61.60 3.125 1943.49 144.44 1799.05 Pass 9189.78 6112.11 6700.00 5265.88 27.78 22.83 226.21 63.11 3.125 1877.16 147.60 1729.56 Pass 9175.00 6113.07 6800.00 5342.65 27.66 23.52 229.66 64.79 3.125 1813.55 151.85 1661.70 Pass 9159.40 6114.02 6900.00 5419.86 27.62 24.16 233.36 66.63 3.125 1753.06 156.53 1596.53 Pass 9150.00 6114.57 7000.00 5498.44 27.59 24.55 236.48 68.62 3.125 1696.24 160.41 1535.83 Pass 9125.00 6115.92 7100.00 5578.77 27.68 25.23 241.78 70.95 3.125 1643.54 166.92 1476.62 Pass 9118.03 6116.26 7200.00 5660.87 27.74 25.59 245.06 73.39 3.125 1595.10 171.07 1424.03 Pass 9100.00 6117.11 7300.00 5744.85 27.90 26.15 249.95 76.14 3.125 1551.43 177.10 1374.33 Pass 9092.46 6117.44 7400.00 5830.79 28.00 26.51 253.78 79.07 3.125 1512.54 181.59 1330.95 Pass 9075.00 6118.15 7500.00 5918.42 28.23 27.05 259.06 82.26 3.125 1478.72 187.55 1291.17 Pass 9069.25 6118.37 7600.00 6007.20 28.32 27.26 263.09 85.60 3.125 1450.90 191.95 1258.95 Pass 9062.06 6118.63 7700.00 6091.75 28.60 27.53 268.16 88.92 3.125 1427.00 195.99 1231.01 Pass 9054.83 6118.89 7800.00 6124.86 29.17 28.03 272.74 90.25 3.125 1395.13 200.63 1194.50 Pass 9050.00 6119.07 7900.00 6127.20 29.56 28.42 274.96 90.29 3.125 1354.56 203.51 1151.04 Pass 9040.00 6119.42 8000.00 6127.77 30.37 29.08 279.53 90.36 3.125 1303.05 208.90 1094.16 Pass 9030.00 6119.78 8100.00 6128.21 31.16 29.66 284.08 90.40 3.125 1268.38 213.74 1054.64 Pass 9020.00 6120.12 8200.00 6128.98 31.89 30.21 288.62 90.44 3.125 1260.79 218.15 1042.64 Pass 9010.00 6120.46 8300.00 6129.80 32.55 30.71 293.15 90.47 3.125 1281.04 222.00 1059.05 Pass 9004.97 6120.63 8400.00 6130.53 32.83 31.05 295.37 90.43 3.125 1320.19 224.02 1096.17 Pass 9000.00 6120.79 8500.00 6131.00 33.11 31.40 297.56 90.38 3.125 1349.06 226.02 1123.03 Pass 8990.00 6121.11 8600.00 6130.48 33.56 31.70 302.05 90.37 3.125 1387.82 228.45 1159.36 Pass 8980.00 6121.41 8700.00 6128.52 33.89 31.82 306.50 90.32 3.125 1449.37 229.90 1219.47 Pass 8980.00 6121.41 8800.00 6125.21 33.89 32.15 306.29 90.11 3.125 1528.59 230.88 1297.72 Pass 8974.61 6121.56 8900.00 6120.71 33.99 32.14 308.58 89.97 3.125 1619.88 231.20 1388.69 Pass • by BP Alaska Anticollision Report ~.r ~c;~s 1NTEQ Company: BP Amoco Date: 1/8/2007 Time: 10:32:35 Page: 8 ..Field: Kuparuk Reference Site: KRU 2D Pad ' Co-ordiuate(NE) Reference: Well: 2D -06, True North Reference Well: 2 17-06 Vertical (TVD) Reference: 2D-06A/B Orig Rq 121:0 Reference Welipat6: Plan 4, 2D-O6BL1 Db: OraGe Site: KRU 2D Pad Well: 2D-05 Rule Assigned: Major Risk Wellpath: Plan 3, 2D-05L2 VO P lan: Plan #3 V4 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axi4 Ctr-Ctr Nato Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistance Area Deviation. Warning ft ft ft ft ft ft deg deg in ft- ft ft 8970.00 6121.69 9000.00 6116.48 34.09 31.97 310.56 89.87 3.125 1717.93 231.00 1486.93 Pass 8970.00 6121.69 9100.00 6113.55 34.09 31.94 310.48 89.79 3.125 1817.68 230.91 1586.77 Pass 8974.77 6121.56 9200.00 6111.93 33.99 32.14 308.25 89.71 3.125 1915.51 231.18 1684.33 Pass 8975.22 6121.55 9300.00 6110.13 33.98 32.13 308.02 89.68 3.125 2015.06 231.12 1783.94 Pass 8980.00 6121.41 9400.00 6105.57 33.89 32.37 305.71 89.52 3.125 2112.28 231.50 1880.78 Pass 8980.00 6121.41 9500.00 6103.60 33.89 32.14 305.72 89.53 3.125 2193.09 230.81 1962.28 Pass 8980.00 6121.41 9600.00 6104.42 33.89 31.86 305.81 89.62 3.125 2254.38 229.97 2024.41 Pass 8990.00 6121.11 9700.00 6106.84 33.56 32.18 301.31 89.62 3.125 2301.00 229.78 2071.21 Pass 8990.00 6121.11 9800.00 6109.84 33.56 31.91 301.46 89.77 3.125 2331.99 229.01 2102.98 Pass 9000.00 6120.79 9900.00 6111.03 33.11 32.10 296.92 89.74 3.125 2346.51 228.01 2118.50 Pass 9000.00 6120.79 10000.00 6109.43 33.11 31.89 296.96 89.78 3.125 2344.51 227.38 2117.13 Pass 9010.00 6120.46 10100.00 6103.12 32.55 31.97 292.23 89.55 3.125 2326.20 225.56 2100.64 Pass 9010.00 6120.46 10200.00 6092.29 32.55 31.83 292.03 89.35 3.125 2292.25 225.09 2067.15 Pass 9020.00 6120.12 10300.00 6081.90 31.89 31.80 287.17 88.99 3.125 2243.08 222.48 2020.61 Pass 9020.00 6120.12 10400.00 6076.90 31.89 31.72 287.08 88.90 3.125 2179.90 222.20 1957.70 Pass 9030.00 6119.78 10500.00 6075.86 31.16 31.52 282.43 88.75 3.125 2112.50 218.73 1893.77 Pass 9030.00 6119.78 10600.00 6074.81 31.16 31.33 282.45 88.78 3.125 2063.86 218.17 1845.69 Pass 9040.00 6119.42 10700.00 6073.62 30.37 30.97 277.84 88.66 3.125 2038.49 213.88 1824.61 Pass 9040.00 6119.42 10800.00 6072.34 30.37 30.83 277.90 88.73 3.125 2038.24 213.49 1824.75 Pass 9044.26 6119.27 10820.00 6072.07 30.02 30.69 275.93 88.67 3.125 2041.20 211.58 1829.62 Pass Site: KRU 2D Pad Weil: 2D-O6 Rule Assigned: Major Risk Wellpath: 2D-O6 V3 Inter-site Error: 0.00 ft Reference Offset Semi-Major Aais Ctr-Ctr No-Go Allowable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Casing/HSDistaoce Area Deviation Warning ft ft ft ft ft ft deg .deg in ft ft ft 11825.00 6052.31 2400.00 2167.63 535.81 9.18 202.84 37.68 4908.311599.92 3308.39 Pass 11825.00 6052.31 2500.00 2235.38 535.81 9.69 202.69 37.53 4812.991600.45 3212.54 Pass 11825.00 6052.31 2600.00 2299.90 535.81 10.21 202.49 37.32 4718.721601.10 3117.62 Pass 11815.08 6052.30 2700.00 2360.79 532.47 10.74 203.41 37.06 4625.791594.99 3030.80 Pass 11810.40 6052.29 2800.00 2418.60 530.90 11.27 203.65 36.74 4534.231592.66 2941.57 Pass 11800.00 6052.28 2900.00 2474.07 527.40 11.81 204.53 36.37 4443.901586.49 2857.40 Pass 11800.00 6052.28 3000.00 2528.65 527.40 12.12 204.14 35.98 4354.161587.73 2766.43 Pass 11800.00 6052.28 3100.00 2583.41 527.40 12.19 203.73 35.57 4264.691589.00 2675.70 Pass 11789.53 6052.26 3200.00 2638.58 523.91 12.25 204.58 35.16 4175.291582.46 2592.84 Pass 11783.87 6052.25 3300.00 2694.26 522.02 12.32 204.83 34.73 4085.961579.44 2506.52 Pass 11775.00 6052.23 3400.00 2750.52 519.06 12.33 205.46 34.30 3996.781573.73 2423.05 Pass 11775.00 6052.23 3500.00 2807.19 519.06 12.28 205.03 33.86 3907.911574.55 2333.35 Pass 11765.02 6052.20 3600.00 2864.10 515.75 12.31 205.78 33.41 3819.431567.42 2252.01 Pass 11750.00 6052.15 3700.00 2921.41 510.79 12.40 207.12 32.95 3731.361556.20 2175.16 Pass 11750.00 6052.15 3800.00 2979.18 510.79 12.43 206.66 32.50 3643.511557.16 2086.36 Pass 11750.00 6052.15 3900.00 3037.30 510.79 12.49 206.19 32.03 3556.151558.15 1998.00 Pass 11734.26 6052.09 4000.00 3095.97 505.62 12.67 207.61 31.55 3469.051545.84 1923.21 Pass 11725.00 6052.05 4100.00 3155.56 502.59 12.86 208.25 31.08 3382.191538.95 1843.25 Pass 11715.83 6052.01 4200.00 3215.25 499.60 13.25 208.87 30.61 3296.041531.89 1764.15 Pass 11705.69 6051.96 4300.00 3273.98 496.31 13.85 209.58 30.10 3211.151524.05 1687.09 Pass 11700.00 6051.93 4400.00 3332.()0 494.47 14.42 209.74 29.58 3127.451520.14 1607.31 Pass 11683.49 6051.85 4500.00 3389.75 489.16 15.05 211.18 29.03 3044.781506.28 1538.50 Pass 11675.00 6051.81 4600.00 3447.14 486.42 15.59 211.65 28.49 2963.461499.69 1463.77 Pass 11657.43 6051.73 4700.00 3504.36 480.81 16.18 213.21 27.94 2883.521484.44 1399.07 Pass 11642.69 6051.67 4800.00 3561.51 476.13 16.74 214.45 27.41 2805.001471.71 1333.30 Pass • • by BP Alaska Anticollision Report ~.r Wit; iNTEQ Company: BP Amoco Date: 1/8@007 Time: 10:32:35 Page: 9 Field:. Kuparuk Reference Site: KRU 2D Pad Co-ordinate(NE) Reference: Weil 2Q-06, True No rth Reference Wetl: 2D-06 Vertical (TVD) Reference: 2D-O6AJB-Orig Rig 121.0 Reference Welipathb Pian 4, 2D-06811 Db: Orade Site: KRU 2D Pad Well: 2D-O6 Rule Assigned: Major Risk Welipath: 2D-06 V3 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axiv Ctr-Ctr No-Go Aibwable MD TVD MD TVD Ref Offset TFO+AZI TFO-HS' Casiog/HSDistaece Area Deviation Warning ft' ft ft ft ft ft deg.: deg in ft ft ft 11625.00 6051.61 4900.00 3618.76 470.52 17.35 216.06 26.90 2728.041 456.08 1271.95 Pass 11609.35 6051.55 5000.00 3676.27 465.60 17.92 217.47 26.43 2652.451 442.10 1210.36 Pass 11590.85 6051.49 5100.00 3733.85 459.81 18.58 219.24 25.98 2578.231 425.32 1152.92 Pass 11575.00 6051.44 5200.00 3791.48 454.86 19.27 220.75 25.58 2505.631411.07 1094.55 Pass 10875.00 6047.29 5300.00 3849.21 263.40 16.42 184.11 25.04 2426.90 827.72 1599.18 Pass 10875.00 6047.29 5400.00 3906.89 263.40 16.86 183.00 23.93 2343.44 830.33 1513.11 Pass 10859.89 6047.74 5500.00 3964.68 259.87 17.28 183.68 22.82 2261.12 824.47 1436.64 Pass 10850.00 6048.08 5600.00 4022.89 257.56 17.58 183.66 21.63 2179.94 821.34 1358.61 Pass 10838.88 6048.49 5700.00 4081.78 254.98 17.91 183.75 20.40 2099.86 817.31 1282.55 Pass 10825.00 6049.07 5800.00 4141.46 251.77 18.27 184.13 19.13 2020.90 811.42 1209.48 Pass 10812.16 6049.66 5900.00 4201.56 248.83 18.70 184.34 17.82 1943.42 805.97 1137.45 Pass 10800.00 6050.26 6000.00 4262.12 246.04 19.15 184.41 16.45 1867.50 800.74 1066.75 Pass 10775.00 6051.65 6100.00 4323.44 240.36 19.66 186.06 15.13 1792.98 787.15 1005.83 Pass 10757.33 6052.75 6200.00 4385.45 236.37 20.17 186.78 13.74 1720.05 777.91 942.14 Pass 10733.88 6054.36 6300.00 4447.71 231.09 20.89 188.20 12.37 1649.13 764.83 884.30 Pass 10705.26 6056.54 6400.00 4509.98 224.72 21.76 190.28 11.04 1580.50 748.26 832.24 Pass 10650.98 6060.34 6500.00 4572.42 213.11 23.22 195.66 9.96 1513.59 715.02 798.58 Pass 10587.65 6063.65 6600.00 4635.13 199.97 25.03 202.24 9.01 1447.68 676.97 770.72 Pass 10515.96 6065.87 6700.00 4698.39 185.58 27.03 209.98 8.25 1382.03 635.01 747.02 Pass 10418.86 6066.40 6800.00 4762.39 166.91 27.83 211.15 7.66 1315.75 579.55 736.20 Pass 10292.40 6065.08 6900.00 4827.21 144.01 25.71 194.93 6.59 1246.30 510.51 735.79 Pass 10202.00 6063.11 7000.00 4892.42 128.59 24.43 182.32 4.83 1175.26 465.39 709.87 Pass 10145.76 6061.50 7100.00 4957.75 119.52 24.45 176.40 2.29 1105.07 440.81 664.25 Pass 10103.43 6060.45 7200.00 5023.48 113.04 25.57 178.49 359.31 1037.28 424.17 613.11 Pass 10051.70 6059.54 7300.00 5089.56 105.40 26.95 181.65 356.28 972.12 403.23 568.89 Pass 9989.20 6059.03 7400.00 5156.63 96.54 28.75 186.17 353.32 908.56 378.09 530.47 Pass 9935.70 6059.16 7500.00 5224.22 89.26 29.32 184.00 350.47 846.70 358.71 487.99 Pass 9896.55 6059.91 7600.00 5292.07 84.14 28.78 175.80 346.88 788.71 346.84 441.87 Pass 9860.24 6061.14 7700.00 5360.42 79.56 28.17 166.98 342.35 735.98 336.48 399.50 Pass 9826.42 6062.75 7800.00 5429.04 75.43 27.68 157.50 336.86 690.16 327.54 362.62 Pass 9794.86 6064.65 7900.00 5498.02 71.72 27.36 147.37 330.46 652.72 319.63 333.10 Pass 9765.72 6066.73 8000.00 5567.65 68.39. 27.13 136.65 323.19 625.24 311.62 313.62 Pass 9737.80 6068.94 8100.00 5637.61 65.30 26.92 125.28 315.17 610.13 302.31 307.82 Pass 9712.64 6070.98 8200.00 5706.57 62.58 26.81 113.87 306.78 610.60 292.02 318.58 Pass 9690.07 6072.82 8300.00 5773.57 60.21 26.85 102.93 298.57 627.93 281.08 346.85 Pass 9669.99 6074.48 8400.00 5838.70 58.15 26.96 92.92 290.97 660.97 269.72 391.25 Pass 9650.00 6076.14 8500.00 5902.86 56.15 27.07 83.74 284.20 706.87 257.58 449.29 Pass 8687.54 6020.57 9100.00 6245.84 28.26 36.12 93.25 109.57 1017.06 192.55 824.51 Pass 8695.18 6026.43 9135.00 6263.92 28.80 37.06 92.02 111.44 1041.32 190.32 851.00 Pass Site: KRU 2D Pad WeIL• 2D-06 Rule Assigned: Major Risk Welipath: 2D-O6A VO Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr•Ctr No-Go A®ownble MD TVD MD TVD Ref Offset TFO+AZI TFO-HS Gasing/HSDistanee Area; Deviation Warning, it ft ft ft ft ft deg ..deg in ft ft ft 11825.00 6052.31 2400.00 2167.63 535.81 9.18 202.84 37.68 4908.311599.92 3308.39 Pass 11825.00 6052.31 2500.00 2235.38 535.81 9.69 202.69 37.53 4812.991600.45 3212.54 Pass 11825.00 6052.31 2600.00 2299.90 535.81 10.21 202.49 37.32 4718.721601.10 3117.62 Pass 11815.08 6052.30 2700.00 2360.79 532.47 10.74 203.41 37.06 4625.791594.99 3030.80 Pass 11810.40 6052.29 2800.00 2418.60 530.90 11.27 203.65 36.74 4534.231592.66 2941.57 Pass 11800.00 6052.28 2900.00 2474.07 527.40 11.81 204.53 36.37 4443.901586.49 2857.40 Pass • by BP Alaska Anticollision Report • ~.r ~t~s INTEQ Gompaay: BP Amoco Date: 1!812007 Time: 10:32:35 Page: 10 'Field: ' Kuparuk Reference Ske: KRU 2D Pad Go•ordinate(NE) Reference: Well: 2D-06, True North Referenee Well: 2D-O6 Vertical (1'VD)12efereuce: 2D-06AlB Orig Rig 121.0 Reference Wellpat6: PIan,4, 2D-O6BL1 Db: Orade Site: KRU 2D Pad Well: 2D-O6 Rule Assigned: Major Risk Wellpath: 2D-O6A VO Inter-Site Error: 0.00 ft Reference. Offset Semi-Major Axi4 Ctr-Ctr No-Go Allowable MD TVD MD -TVD Ref tMSeE TFO+AZI TFO-HS Casing/HSDtstance Area Deviation Warniag ft ft ft ft ft ft deg deg in ft ft ft 11800.00 6052.28 3000.00 2528.65 527.40 12.12 204.14 35.98 4354.161587.73 2766.43 Pass 11800.00 6052.28 3100.00 2583.41 527.40 12.19 203.73 35.57 4264.691589.00 2675.70 Pass 11789.53 6052.26 3200.00 2638.58 523.91 12.25 204.58 35.16 4175.291582.46 2592.84 Pass 11783.87 6052.25 3300.00 2694.26 522.02 12.32 204.83 34.73 4085.961579.44 2506.52 Pass 11775.00 6052.23 3400.00 2750.52 519.06 12.33 205.46 34.30 3996.781573.73 2423.05 Pass 11775.00 6052.23 3500.00 2807.19 519.06 12.28 205.03 33.86 3907.911574.55 2333.35 Pass 11765.02 6052.20 3600.00 2864.10 515.75 12.31 205.78 33.41 3819.431567.42 2252.01 Pass 11750.00 6052.15 3700.00 2921.41 510.79 12.40 207.12 32.95 3731.361556.20 2175.16 Pass 11750.00 6052.15 3800.00 2979.18 510.79 12.43 206.66 32.50 3643.511557.16 2086.36 Pass 11750.00 6052.15 3900.00 3037.30 510.79 12.49 206.19 32.03 3556.151558.15 1998.00 Pass 11734.26 6052.09 4000.00 3095.97 505.62 12.67 207.61 31.55 3469.051545.84 1923.21 Pass 11725.00 6052.05 4100.00 3155.56 502.59 12.86 208.25 31.08 3382.191538.95 1843.25 Pass 11715.83 6052.01 4200.00 3215.25 499.60 13.25 208.87 30.61 3296.041531.89 1764.15 Pass 11705.69 6051.96 4300.00 3273.98 496.31 13.85 209.58 30.10 3211.151524.05 1687.09 Pass 11700.00 6051.93 4400.00 3332.00 494.47 14.42 209.74 29.58 3127.451520.14 1607.31 Pass 11683.49 6051.85 4500.00 3389.75 489.16 15.05 211.18 29.03 3044.781506.28 1538.50 Pass 11675.00 6051.81 4600.00 3447.14 486.42 15.59 211.65 28.49 2963.461499.69 1463.77 Pass 11657.43 6051.73 4700.00 3504.36 480.81 16.18 213.21 27.94 2883.521484.44 1399.07 Pass 11642.69 6051.67 4800.00 3561.51 476.13 16.74 214.45 27.41 2805.001471.71 1333.30 Pass 11625.00 6051.61 4900.00 3618.76 470.52 17.35 216.06 26.90 2728.041456.08 1271.95 Pass 11609.35 6051.55 5000.00 3676.27 465.60 17.92 217.47 26.43 2652.451442.10 1210.36 Pass 11590.85 6051.49 5100.00 3733.85 459.81 18.58 219.24 25.98 2578.231425.32 1152.92 Pass 11575.00 6051.44 5200.00 3791.48 454.86 19.27 220.75 25.58 2505.631411.07 1094.55 Pass 10875.00 6047.29 5300.00 3849.21 263.40 16.42 184.11 25.04 2426.90 827.72 1599.18 Pass 10875.00 6047.29 5400.00 3906.89 263.40 16.86 183.00 23.93 2343.44 830.33 1513.11 Pass 10859.89 6047.74 5500.00 3964.68 259.87 17.28 183.68 22.82 2261.12 824.47 1436.64 Pass 10850.00 6048.08 5600.00 4022.89 257.56 17.58 183.66 21.63 2179.94 821.34 1358.61 Pass 10838.88 6048.49 5700.00 4081.78 254.98 17.91 183.75 20.40 2099.86 817.31 1282.55 Pass 10825.00 6049.07 5800.00 4141.46 251.77 18.27 184.13 19.13 2020.90 811.42 1209.48 Pass 10812.16 6049.66 5900.00 4201.56 248.83 18.70 184.34 17.82 1943.42 805.97 1137.45 Pass 10800.00 6050.26 6000.00 4262.12 246.04 19.15 184.41 16.45 1867.50 800.74 1066.75 Pass 10775.00 6051.65 6100.00 4323.44 240.36 19.66 186.06 15.13 1792.98 787.15 1005.83 Pass 10757.33 6052.75 6200.00 4385.45 236.37 20.17 186.78 13.74 1720.05 777.91 942.14 Pass 10733.88 6054.36 6300.00 4447.71 231.09 20.89 188.20 12.37 1649.13 764.83 884.30 Pass 10705.26 6056.54 6400.00 4509.98 224.72 21.76 190.28 11.04 1580.50 748.26 832.24 Pass 10650.98 6060.34 6500.00 4572.42 213.11 23.22 195.66 9.96 1513.59 715.02 798.58 Pass 10587.65 6063.65 6600.00 4635.13 199.97 25.03 202.24 9.01 1447.68 676.97 770.72 Pass 10515.96 6065.87 6700.00 4698.39 185.58 27.03 209.98 8.25 1382.03 635.01 747.02 Pass 10418.86 6066.40 6800.00 4762.39 166.91 27.83 211.15 7.66 1315.75 579.55 736.20 Pass 10292.40 6065.08 6900.00 4827.21 144.01 25.71 194.93 6.59 1246.30 510.51 735.79 Pass 10202.00 6063.11 7000.00 4892.42 128.59 24.43 182.32 4.83 1175.26 465.39 709.87 Pass 10145.76 6061.50 7100.00 4957.75 119.52 24.45 176.40 2.29 1105.07 440.81 664.25 Pass 10103.43 6060.45 7200.00 5023.48 113.04 25.57 178.49 359.31 1037.28 424.17 613.11 Pass 10049.06 6059.51 7300.00 5090.38 105.01 26.83 182.27 356.58 970.93 403.04 567.90 Pass 9980.91 6059.01 7400.00 5158.53 95.39 28.54 188.56 354.72 904.31 376.33 527.98 Pass 9925.58 6059.30 7500.00 5227.41 87.91 28.26 186.13 353.80 836.89 355.40 481.49 Pass 9876.39 6060.53 7600.00 5296.43 81.57 27.09 179.52 352.98 770.34 337.81 432.53 Pass 9825.40 6062.81 7700.00 5365.32 75.31 25.93 172.71 352.19 705.06 320.22 384.84 Pass 9772.80 6066.20 7800.00 5434.69 69.19 24.91 165.82 351.52 640.24 302.74 337.50 Pass 9711.03 6071.11 7900.00 5502.58 62.41 24.06 157.38 350.49 578.37 283.08 295.28 Pass 9646.54 6076.43 8000.00 5569.56 55.82 23.51 147.14 348.02 519.97 264.53 255.45 Pass • • by BP Alaska Anticollision Report ~.r S INTEQ Gompaoyi BP Amoco Date: 1/8/2007 Time: 10:32:35 Page: 11 .:Field: Kuparuk ReferenceSite: KRU 2D Pad Co-ordinate{NE) Reference: Well: 2D-06, True North Reference' Well: 2D-013 Vertical (TVD) Reference. 2D-O6A/B Ong Rig 121.0 Reference Wellpat6: Plan 4, 2D-O66L1 Db: Orate Site: KRU 2D Pad Well: 2D-06 Rule Assigned: Major Risk Welipath: 2D-06A VO Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Ctr-Ctr- No-Go Allowable MD TVD MD TVD Ref Onset TFO+AZI TFO-HS Caciog/HSUistance' Area: Deviation Waruiag ft' ft: ft ft ft ft deg deg. in ft ft ft 9584.07 6081.66 8100.00 5635.90 49.93 23.27 135.39 343.79 465.84 248.73 217.12 Pass 9527.19 6086.40 8200.00 5701.50 45.01 23.25 121.60 336.85 420.07 236.04 184.02 Pass 8699.22 6029.61 8700.00 6027.36 29.09 29.12 13.08 34.29 4.51 184.49 -179.98 FAIL 8775.41 6085.51 8800.00 6093.02 28.51 28.54 34.11 100.78 51.31 144.23 -92.91 FAIL 8814.38 6106.41 8900.00 6160.05 28.94 28.99 36.35 117.83 128.03 136.98 -8.95 FAIL 8834.82 6114.29 9000.00 6228.18 29.32 29.38 35.97 123.90 216.17 142.14 74.03 Pass 8844.87 6117.29 9080.00 6282.18 29.55 29.62 35.23 126.12 290.46 147.01 143.45 Pass Site: KRU 2D Pad Well: 2D-06 Rule Assigned: Major Risk Welipath: 2D-O66 V3 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Axis Gtr-Ctr No-Go AUowabie MD TW MD TVD Ref Offset TFO+AZI TF0.HS Casiug/HSi)istance' Area. Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 11825.00 6052.31 2400.00 2167.63 535.81 9.18 202.84 37.68 4908.311599.92 3308.39 Pass 11825.00 6052.31 2500.00 2235.38 535.81 9.69 202.69 37.53 4812.991600.45 3212.54 Pass 11825.00 6052.31 2600.00 2299.90 535.81 10.21 202.49 37.32 4718.721601.10 3117.62 Pass 11815.08 6052.30 2700.00 2360.79 532.47 10.74 203.41 37.06 4625.791594.99 3030.80 Pass 11810.40 6052.29 2800.00 2418.60 530.90 11.27 203.65 36.74 4534.231592.66 2941.57 Pass 11800.00 6052.28 2900.00 2474.07 527.40 11.81 204.53 36.37 4443.901586.49 2857.40 Pass 11800.00 6052.28 3000.00 2528.65 527.40 12.12 204.14 35.98 4354.161587.73 2766.43 Pass 11800.00 6052.28 3100.00 2583.41 527.40 12.19 203.73 35.57 4264.691589.00 2675.70 Pass 11789.53 6052.26 3200.00 2638.58 523.91 12.25 204.58 35.16 4175.291582.46 2592.84 Pass 11783.87 6052.25 3300.00 2694.26 522.02 12.32 204.83 34.73 4085.961579.44 2506.52 Pass 11775.00 6052.23 3400.00 2750.52 519.06 12.33 205.46 34.30 3996.781573.73 2423.05 Pass 11775.00 6052.23 3500.00 2807.19 519.06 12.28 205.03 33.86 3907.911574.55 2333.35 Pass 11765.02 6052.20 3600.00 2864.10 515.75 12.31 205.78 33.41 3819.431567.42 2252.01 Pass 11750.00 6052.15 3700.00 2921.41 510.79 12.40 207.12 32.95 3731.361556.20 2175.16 Pass 11750.00 6052.15 3800.00 2979.18 510.79 12.43 206.66 32.50 3643.511557.16 2086.36 Pass 11750.00 6052.15 3900.00 3037.30 510.79 12.49 206.19 32.03 3556.151558.15 1998.00 Pass 11734.26 6052.09 4000.00 3095.97 505.62 12.67 207.61 31.55 3469.051545.84 1923.21 Pass 11725.00 6052.05 4100.00 3155.56 502.59 12.86 208.25 31.08 3382.191538.95 1843.25 Pass 11715.83 6052.01 4200.00 3215.25 499.60 13.25 208.87 30.61 3296.041531.89 1764.15 Pass 11705.69 6051.96 4300.00 3273.98 496.31 13.85 209.58 30.10 3211.151524.05 1687.09 Pass 11700.00 6051.93 4400.00 3332.00 494.47 14.42 209.74 29.58 3127.451520.14 1607.31 Pass 11683.49 6051.85 4500.00 3389.75 489.16 15.05 211.18 29.03 3044.781506.28 1538.50 Pass 11675.00 6051.81 4600.00 3447.14 486.42 15.59 211.65 28.49 2963.461499.69 1463.77 Pass 11657.43 6051.73 4700.00 3504.36 480.81 16.18 213.21 27.94 2883.521484.44 1399.07 Pass 11642.69 6051.67 4800.00 3561.51 476.13 16.74 214.45 27.41 2805.001471.71 1333.30 Pass 11625.00 6051.61 4900.00 3618.76 470.52 17.35 216.06 26.90 2728.041456.08 1271.95 Pass 11609.35 6051.55 5000.00 3676.27 465.60 17.92 217.47 26.43 2652.451442.10 1210.36 Pass 11590.85 6051.49 5100.00 3733.85 459.81 18.58 219.24 25.98 2578.231425.32 1152.92 Pass 11575.00 6051.44 5200.00 3791.48 454.86 19.27 220.75 25.58 2505.631411.07 1094.55 Pass 10875.00 6047.29 5300.00 3849.21 263.40 16.42 184.11 25.04 2426.90 827.72 1599.18 Pass 10875.00 6047.29 5400.00 3906.89 263.40 16.86 183.00 23.93 2343.44 830.33 1513.11 Pass 10859.89 6047.74 5500.00 3964.68 259.87 17.28 183.68 22.82 2261.12 824.47 1436.64 Pass 10850.00 6048.08 5600.00 4022.89 257.56 17.58 183.66 21.63 2179.94 821.34 1358.61 Pass 10838.88 6048.49 5700.00 4081.78 254.98 17.91 183.75 20.40 2099.86 817.31 1282.55 Pass 10825.00 6049.07 5800.00 4141.46 251.77 18.27 184.13 19.13 2020.90 811.42 1209.48 Pass 10812.16 6049.66 5900.00 4201.56 248.83 18.70 184.34 17.82 1943.42 805.97 1137.45 Pass 10800.00 6050.26 6000.00 4262.12 246.04 19.15 184.41 16.45 1867.50 800.74 1066.75 Pass 10775.00 6051.65 6100.00 4323.44 240.36 19.66 186.06 15.13 1792.98 787.15 1005.83 Pass • • by BP Alaska Anticollision Report ~.r S 1NTEQ Company: BP AmoCO Date: 1!8/2007 'l'ime: 10:32:35 Page: 12 Field: Kuparuk Reference Site: KRU.2D Pad Co-ordinnte(NE) Reference: WeIL 2D-06, True No rth Reference Well:" 2D-06 Vertical (TVD) Reference; 2D-06A/B Orig Rig 121.0 Reference Wellpath: Plan 4, 2D-06BL1 1)b: OraGe Site: KRU 2D Pad Well: 2D-O6 Rule Assigned: Major Risk Wellpath: 2D-066 V3 Inter-Site Error: 0.00 ft Reference Offset Semi-Major Azis Ctr-Ctr No-Go ` Allowable MD 1'VD - MD TVD Ref Offset TFO+AZLTFO-HS CasiAg/HSUistance Area Deviation Warning ft ft ft ft ft ft deg deg in ft ft ft 10757.33 6052.75 6200.00 4385.45 236.37 20.17 186.78 13.74 1720.05 777.91 942.14 Pass 10733.88 6054.36 6300.00 4447.71 231.09 20.89 188.20 12.37 1649.13 764.83 884.30 Pass 10705.26 6056.54 6400.00 4509.98 224.72 21.76 190.28 11.04 1580.50 748.26 832.24 Pass 10650.98 6060.34 6500.00 4572.42 213.11 23.22 195.66 9.96 1513.59 715.02 798.58 Pass 10587.65 6063.65 6600.00 4635.13 199.97 25.03 202.24 9.01 1447.68 676.97 770.72 Pass 10515.96 6065.87 6700.00 4698.39 185.58 27.03 209.98 8.25 1382.03 635.01 747.02 Pass 10418.86 6066.40 6800.00 4762.39 166.91 27.83 211.15 7.66 1315.75 579.55 736.20 Pass 10292.40 6065.08 6900.00 4827.21 144.01 25.71 194.93 6.59 1246.30 510.51 735.79 Pass 10202.00 6063.11 7000.00 4892.42 128.59 24.43 182.32 4.83 1175.26 465.39 709.87 Pass 10145.76 6061.50 7100.00 4957.75 119.52 24.45 176.40 2.29 1105.07 440.81 664.25 Pass 10103.43 6060.45 7200.00 5023.48 113.04 25.57 178.49 359.31 1037.28 424.17 613.11 Pass 10049.06 6059.51 7300.00 5090.38 105.01 26.83 182.27 356.58 970.93 403.04 567.90 Pass 9980.91 6059.01 7400.00 5158.53 95.39 28.54 188.56 354.72 904.31 376.33 527.98 Pass 9925.58 6059.30 7500.00 5227.41 87.91 28.26 186.13 353.80 836.89 355.40 481.49 Pass 9876.39 6060.53 7600.00 5296.43 81.57 27.09 179.52 352.98 770.34 337.81 432.53 Pass 9825.40 6062.81 7700.00 5365.32 75.31 25.93 172.71 352.19 705.06 320.22 384.84 Pass 9772.80 6066.20 7800.00 5434.69 69.19 24.91 165.82 351.52 640.24 302.74 337.50 Pass 9711.03 6071.11 7900.00 5502.58 62.41 24.06 157.38 350.49 578.37 283.08 295.28 Pass 9646.54 6076.43 8000.00 5569.56 55.82 23.51 147.14 348.02 519.97 264.53 255.45 Pass 9584.07 6081.66 8100.00 5635.90 49.93 23.27 135.39 343.79 465.84 248.73 217.12 Pass 9527.19 6086.40 8200.00 5701.50 45.01 23.25 121.60 336.85 420.07 236.04 184.02 Pass 8699.23 6029.63 8700.00 6027.37 29.09 29.09 11.49 32.71 4.44 185.65 -181.21 FAIL 8774.55 6084.98 8800.00 6090.47 28.50 28.48 31.36 97.65 52.89 148.97 -96.08 FAIL 8802.39 6100.75 8900.00 6115.93 28.77 28.76 19.83 97.17 140.59 167.55 -26.96 FAIL 8809.49 6104.19 9000.00 6111.16 28.87 28.86 12.08 91.91 237.08 180.31 56.77 Pass 8807.01 6103.02 9100.00 6108.31 28.83 28.84 12.05 91.03 336.54 180.20 156.34 Pass 8800.00 6099.53 9200.00 6110.30 28.74 28.78 15.18 91.66 433.17 175.16 258.01 Pass 8790.00 6094.16 9300.00 6108.81 28.62 28.76 19.38 92.09 522.36 168.38 353.98 Pass 8777.09 6086.55 9400.00 6101.87 28.52 28.84 24.45 91.85 601.19 160.85 440.33 Pass 8765.34 6079.05 9500.00 6099.79 28.45 29.08 30.29 92.37 669.43 153.20 516.24 Pass 8753.60 6071.05 9600.00 6094.65 28.42 29.47 36.42 92.62 723.78 147.25 576.53 Pass 8740.00 6061.26 9700.00 6089.76 28.45 30.00 43.32 91.94 760.71 144.81 615.90 Pass 8730.00 6053.76 9800.00 6093.14 28.52 30.47 50.37 92.87 781.76 144.80 636.96 Pass 8722.90 6048.31 9900.00 6087.61 28.61 30.84 56.58 94.44 800.77 146.95 653.83 Pass 8713.83 6041.22 10000.00 6083.61 28.77 31.25 63.21 94.84 815.54 154.05 661.49 Pass 8705.13 6034.34 10100.00 6077.55 28.99 31.65 69.51 94.88 839.90 163.48 676.41 Pass 8695.79 6026.91 10200.00 6075.39 28.85 31.60 75.42 95.10 877.86 172.88 704.97 Pass 8684.34 6018.20 10300.00 6083.10 28.03 30.75 80.79 95.92 930.57 180.62 749.95 Pass 8672.86 6010.05 10400.00 6092.43 27.19 29.87 85.25 96.49 997.17 186.94 810.23 Pass 9688.62 6072.94 10900.00 6138.74 60.06 27.52 71.33 267.14 1320.88 272.08 1048.81 Pass 9712.83 6070.96 11000.00 6143.45 62.60 28.12 74.04 266.93 1358.56 282.92 1075.65 Pass 9736.99 6069.01 11100.00 6146.67 65.21 28.69 76.81 266.79 1392.72 293.34 1099.38 Pass 9759.78 6067.20 11200.00 6150.14 67.73 29.26 79.47 266.71 1443.36 303.04 1140.32 Pass 9775.00 6066.04 11282.00 6148.96 69.44 29.72 81.35 266.79 1489.38 309.71 1179.67 Pass • by BP Alaska Anticollision Report ~.r ~i~s INTEQ :Company: BP Amoco Date: 1!8!2007 Time: 10:32:35 Fage: l3 .Field: Kuparuk 'Reference Site: KRU 2D Pad Co-ordlnate(NE) Reference: Well: 2D-06, True No rth Reference Weii: 2D-O6 Vertical{TVD) Reference: 2D-06A/B Orig Rig 121.0 `Refereace'Wel)pat6: Pian 4, 2D-06BL1 Db: Orade Site: KRU 2D Pad Well: 2D-07 Rule Assigned: Major Risk Wellpath: 2D-07 VO Inter-Site Error: 0.00 ft Reference ' Offset Semi-Major Aaig Ctr-Ctr No-Go Allowable NID TVD MD TVD Ref Offset TFO+AZI TFO-HS Casiag/HSflistance Area Deviation Warning ft _~ ft' ft ft ft deg deg in tt ft ft 11875.00 6052.30 2700.00 2689.59 552.84 5.50 206.28 47.11 4941.851604.71 3337.14 Pass 11865.11 6052.31 2800.00 2783.10 549.45 5.92 208.01 47.66 4853.881599.21 3254.67 Pass 11863.41 6052.31 2900.00 2874.38 548.87 6.33 208.72 48.16 4764.291597.55 3166.74 Pass 11861.38 6052.31 3000.00 2963.08 548.18 6.75 209.42 48.62 4673.221595.87 3077.35 Pass 11850.00 6052.32 3100.00 3048.52 544.29 7.20 211.18 49.02 4580.631590.48 2990.16 Pass 11850.00 6052.32 3200.00 3130.64 544.29 7.63 211.53 49.37 4486.721590.01 2896.72 Pass 11850.00 6052.32 3300.00 3211.50 544.29 7.70 211.87 49.70 4392.611589.23 2803.38 Pass 11850.00 6052.32 3400.00 3292.26 544.29 7.78 212.22 50.05 4298.761588.42 2710.34 Pass 11850.00 6052.32 3500.00 3372.98 544.29 7.88 212.59 50.42 4205.191587.62 2617.57 Pass 11850.00 6052.32 3600.00 3453.72 544.29 7.94 212.97 50.80 4111.971586.69 2525.28 Pass 11850.00 6052.32 3700.00 3534.33 544.29 8.18 213.37 51.20 4019.101585.80 2433.31 Pass 11838.69 6052.32 3800.00 3615.27 540.45 8.17 215.16 51.64 3926.571579.64 2346.93 Pass 11835.59 6052.31 3900.00 3696.58 539.40 8.16 215.99 52.09 3834.181577.41 2256.77 Pass 11825.00 6052.31 4000.00 3778.03 535.81 8.33 217.73 52.56 3741.661572.21 2169.45 Pass 11825.00 6052.31 4100.00 3859.55 535.81 8.52 218.23 53.06 3649.031571.58 2077.45 Pass 11825.00 6052.31 4200.00 3941.19 535.81 8.70 218.75 53.59 3556.491570.88 1985.60 Pass 11825.00 6052.31 4300.00 4023.37 535.81 8.82 219.31 54.15 3464.061570.01 1894.05 Pass 11825.00 6052.31 4400.00 4106.47 535.81 8.86 219.92 54.76 3372.021568.89 1803.13 Pass 11825.00 6052.31. 4500.00 4190.20 535.81 8.80 220.58 55.42 3280.631567.50 1713.13 Pass 11825.00 6052.31 4600.00 4274.29 535.81 8.70 221.29 56.12 3189.971565.92 1624.05 Pass 11825.00 6052.31 4700.00 4358.63 535.81 8.64 222.04 56.88 3100.041564.30 1535.74 Pass 11814.51 6052.30 4800.00 4442.75 532.28 8.85 224.10 57.68 3010.261558.39 1451.88 Pass 11812.58 6052.30 4900.00 4526.69 531.63 9.03 225.17 58.51 2920.911556.27 1364.63 Pass 11810.57 6052.30 5000.00 4610.83 530.95 9.00 226.31 59.41 2832.441553.73 1278.71 Pass 11800.00 6052.28 5100.00 4695.09 527.40 9.11 228.53 60.36 2744.981547.90 1197.08 Pass 11800.00 6052.28 5200.00 4779.31 527.40 9.39 229.55 61.38 2658.261546.75 1111.51 Pass 11800.00 6052.28 5300.00 4863.72 527.40 9.55 230.65 62.48 2572.681545.32 1027.36 Pass 11800.00 6052.28 5400.00 4948.59 527.40 9.53 231.84 63.67 2488.661543.46 945.20 Pass 11800.00 6052.28 5500.00 5033.82 527.40 9.54 233.12 64.96 2406.231541.55 864.68 Pass 11800.00 6052.28 5600.00 5119.47 527.40 9.57 234.52 66.35 2325.641539.59 786.05 Pass 11800.00 6052.28 5700.00 5205.62 527.40 9.64 236.03 67.87 2247.241537.63 709.61 Pass 11791.26 6052.26 5800.00 5291.89 524.48 9.88 238.71 69.50 2170.741532.26 638.48 Pass 11788.40 6052.26 5900.00 5378.66 523.53 10.10 240.82 71.26 2096.951529.54 567.42 Pass 11785.43 6052.25 6000.00 5466.52 522.54 10.21 243.12 73.20 2027.031526.55 500.48 Pass 11775.00 6052.23 6100.00 5555.47 519.06 10.39 246.49 75.32 1961.491520.81 440.68 Pass 11775.00 6052.23 6200.00 5645.50 519.06 10.53 248.80 77.64 1900.361519.52 380.84 Pass 11775.00 6052.23 6300.00 5736.38 519.06 10.70 251.30 80.14 1843.801518.53 325.28 Pass 11775.00 6052.23 6400.00 5827.92 519.06 10.89 253.97 82.81 1791.951517.91 274.04 Pass 11775.00 6052.23 6500.00 5919.95 519.06 11.10 256.82 85.65 1744.911517.78 227.13 Pass 11775.00 6052.23 6600.00 6012.34 519.06 11.30 259.82 88.66 1703.091518.10 185.00 Pass 11775.00 6052.23 6700.00 6104.90 519.06 11.50 262.98 91.81 1666.641519.08 147.56 Pass 11767.21 6052.20 6800.00 6197.47 516.48 11.78 267.19 95.10 1635.411516.78 118.63 Pass 11766.61 6052.20 6831.00 6226.17 516.28 11.86 268.31 96.14 1626.871517.14 109.74 Pass Site: KRU 2D Pad Well: 2D-08 Rule Assigned: Major Risk Weilpath: 2D-08 VO later-Site Error: 0.00 ft Reference Offset Semi Major Axis Ctr-Ctr No-Go Allowable MD TVD NID TVD Ref Offset TFO+AZI TFO-HS Casing/IiSDistaace Area Deviatioe Warning ft' ft ft ft ft ft deg deg in ft ft ft 11889.48 6052.28 2300.00 2125.91 557.83 8.43 195.22 37.79 4968.341640.38 3327.96 Pass 11889.76 6052.28 2400.00 2199.85 557.92 8.82 195.09 37.70 4868.671640.78 3227.89 Pass • • by BP Alaska Anticollision Report ~.r 1NTEQ Compahy: BP Amoco Date: 1/8/2007 Time: 10:32:35 Page: 14 Field: Kuparuk Reference Site: KRtJ 2D Pad Go-ordinate(NE) Reference: WeII: 2D-06, True North Reference Weil: 2D-06 Vertical (TVD) Reference: 2D-O6A16 Orig.. Rig 121.0 =Reference Weilpath: Plan 4, 2D-O6BL1 Db: OraGe Site: KRU 2D Pad Well: 2D-08 Rule Assigned: Major Risk Wellpath: 2D-08 VO Inter-Site Error: 0.00 ft Reference Offset Scmi-Major Aais Ctr-Ctr No-Go AOowable MD TVD -`i~ID TVD Ref Offset - TFO+AZI TF0.HS Casing/HSDjstance Area' Deviation Warning ft- ~ ft ft ft ft deg - .deg in ft ft< ft 11889.82 6052.28 2500.00 2271.97 557.94 9.26 194.96 37.57 4769.271641.10 3128.16 Pass 11889.80 6052.28 2600.00 2342.87 557.94 9.72 194.80 37.41 4670.091641.41 3028.68 Pass 11889.82 6052.28 2700.00 2413.62 557.94 9.93 194.63 37.25 4570.981641.84 2929.14 Pass 11889.90 6052.28 2800.00 2484.33 557.97 10.08 194.45 37.07 4471.911642.35 2829.56 Pass 11890.11 6052.28 2900.00 2555.02 558.04 10.30 194.25 36.89 4372.901642.93 2729.97 Pass 11890.54 6052.27 3000.00 2625.71 558.19 10.45 194.01 36.70 4273.961643.70 2630.26 Pass 11891.16 6052.27 3100.00 2696.50 558.40 10.55 193.74 36.51 4175.071644.65 2530.42 Pass 11900.00 6052.26 3200.00 2767.43 561.45 10.65 192.47 36.30 4076.271650.80 2425.47 Pass 11900.00 6052.26 3300.00 2838.24 561.45 11.01 192.25 36.09 3977.501651.37 2326.13 Pass 11900.00 6052.26 3400.00 2908.75 561.45 11.52 192.02 35.86 3878.871651.94 2226.92 Pass 11900.00 6052.26 3500.00 2978.99 561.45 11.95 191.78 35.61 3780.391652.58 2127.80 Pass 11900.00 6052.26 3600.00 3049.22 561.45 12.18 191.52 35.35 3682.001653.38 2028.62 Pass 11900.00 6052.26 3700.00 3119.65 561.45 12.22 191.25 35.08 3583.681654.37 1929.31 Pass 11900.00 6052.26 3800.00 3190.43 561.45 12.21 190.97 34.80 3485.371655.44 1829.94 Pass 11900.00 6052.26 3900.00 3260.86 561.45 12.44 190.67 34.50 3387.271656.46 1730.80 Pass 11900.00 6052.26 4000.00 3331.24 561.45 12.66 190.35 34.18 3289.251657.59 1631.66 Pass 11901.99 6052.25 4100.00 3402.20 562.14 12.65 189.78 33.86 3191.141660.21 1530.93 Pass 11903.07 6052.25 4200.00 3473.82 562.51 12.62 189.32 33.52 3092.931662.29 1430.64 Pass 11904.10 6052.25 4300.00 3546.17 562.87 12.59 188.86 33.19 2994.621664.38 1330.23 Pass 11905.27 6052.24 4400.00 3618.73 563.28 12.77 188.37 32.84 2896.381666.52 1229.86 Pass 11906.75 6052.24 4500.00 3691.20 563.79 13.12 187.82 32.46 2798.321668.89 1129.43 Pass 11908.52 6052.24 4600.00 3763.34 564.40 13.55 187.20 32.05 2700.551671.61 1028.94 Pass 11911.55 6052.23 4700.00 3833.38 565.46 14.06 186.34 31.55 2603.801675.71 928.09 Pass 11915.96 6052.21 4800.00 3901.80 567.00 14.54 185.23 30.97 2508.051681.49 826.56 Pass 11920.82 6052.18 4900.00 3970.24 568.70 14.77 184.04 30.35 2412.631688.12 724.51 Pass 11925.00 6052.15 5000.00 4038.90 570.16 14.82 182.88 29.69 2317.481694.61 622.87 Pass 11931.93 6052.09 5100.00 4107.87 572.59 14.89 181.35 28.98 2222.581703.55 519.03 Pass 11938.13 6052.02 5200.00 4177.09 574.76 14.99 179.86 28.22 2127.961712.26 415.70 Pass 11944.71 6051.92 5300.00 4246.51 577.07 15.14 178.26 27.39 2033.651721.72 311.94 Pass 11952.10 6051.80 5400.00 4315.73 579.67 15.48 176.48 26.49 1939.981732.32 207.66 Pass 11961.49 6051.62 5500.00 4383.70 582.98 16.01 174.34 25.46 1847.731745.31 102.42 Pass 11972.82 6051.36 5600.00 4450.81 586.98 16.46 171.85 24.31 1756.841761.01 -4.17 FAIL 11985.55 6051.00 5700.00 4517.81 591.50 16.89 169.08 23.04 1666.851778.73 -111.87 FAIL 12200.50 6043.02 6700.00 5189.13 670.15 18.67 161.65 355.58 856.98 2080.59 -1223.61 FAIL 12198.07 6043.10 6800.00 5257.91 669.24 18.85 155.76 349.98 797.85 2077.16 -1279.32 FAIL 12195.84 6043.18 6900.00 5326.96 668.40 19.07 149.09 343.58 747.15 2070.34 -1323.19 FAIL 12193.69 6043.26 7000.00 5396.34 667.59 19.31 141.61 336.36 706.62 2058.88 -1352.25 FAIL 12191.48 6043.34 7100.00 5466.39 666.76 19.54 133.42 328.43 677.62 2041.95 -1364.32 FAIL 12189.27 6043.42 7200.00 5537.18 665.93 19.76 124.69 319.97 661.55 2020.11 -1358.56 FAIL 12187.15 6043.49 7300.00 5609.07 665.13 19.98 115.75 311.29 658.831995.38 -1336.55 FAIL 12185.41 6043.56 7400.00 5682.38 664.48 20.20 106.95 302.69 669.121971.03 -1301.91 FAIL 12184.14 6043.60 7500.00 5757.18 664.00 20.42 98.59 294.48 691.681949.98 -1258.30 FAIL 12183.38 6043.63 7600.00 5833.77 663.72 20.64 90.86 286.84 724.891934.07 -1209.18 FAIL 12183.24 6043.63 7700.00 5912.25 663.67 20.87 83.87 279.87 767.081924.00 -1156.92 FAIL 12183.73 6043.62 7800.00 5992.37 663.85 21.09 77.66 273.60 817.031919.35 -1102.32 FAIL 12184.47 6043.59 7900.00 6073.90 664.13 21.32 72.16 268.01 873.631918.53 -1044.91 FAIL 12185.19 6043.56 8000.00 6156.93 664.40 21.54 67.27 263.03 935.501920.03 -984.53 FAIL 12185.84 6043.54 8100.00 6241.30 664.64 21.77 62.92 258.61 1001.791922.99 -921.20 FAIL 12186.42 6043.52 8200.00 6326.17 664.86 22.01 59.09 254.71 1072.681927.00 -854.32 FAIL 12186.51 6043.52 8215.00 6338.90 664.89 22.05 58.56 254.17 1083.711927.67 -843.96 FAIL • E I o T Plan: Plan N (2D-0dPlan 4, 7D-0BBl1) - a+ aon a_,ZpDazj BP Alaska a<I=p-0, yD as~zD-051 =o~s~P~~3 ~D-0z~„ zooslPa~~:o.osszl y~ AM Mnr.roroTrve NOnn Creabtl By: BP Dala: 1Id2007 BAKER TT :1 Wg::a+clbM2asa- Checked: D.I.: `' a~+alcF~Y HUGHES - 1.~~ d.+qn sz4oenr .awarnonuu 2Dn5 (2pac1 zoos acasnl Dp A+qk: ,,:i,~ i ii. - . 11 : ~ pa1 w.• aoaeekt iDat(iDLa91 xcall~DUrl k~l.l e I t I+ hwettlYtlMte: 3e4be TYwYe: NN.N xD-oe l~Daal P N n~o ~ ~ I t . ~C.M IW 1.0011 1 m ] Oa l w o.y wY 10 ~izDD-iil Y~Y °.wi '.e9i T~lo - is i=°D.iS +s +s ~D - l r wm o.N e.w tmm o~az.on - szlaaozl oa ¢z oar REFERENCEINFORMATIOI4 -- of jzi-0s~ oa liz.osl Co-advute IN/E Refererce'. Well Centre: 2D-06. True N0M - Zarb VarECal (TVD~ Reference: 2D-0eA/B Ori9 Rig 121.00 ~gj i? 09 ~+ci i Section (V6)Rebrence_ 3101- (O.OON,O OOE) Measuretl DepN Rebrence: 2D-0fiA/B Orig Rig 121 00 - IzZ.1 z~ Calculation McMOd. Minimum Curvature ,z j2l.+tnl _ +31Fan s+. 2z +s (xz_+sl _ - ~,IL x~ ~3 (2z x.~i l 1 1 95]Z WS.+I 5BL1 i .x i ii~'u ~ iaii ~ifii µ ~% ; 2D-OS (Plan 3 2D-OSL2}' 2D-Of 6 2D-06A' - ~1---- '2D-0612D-068)1 _ _, - - ~ T 4200 - 2D-O5 Plan 3 2D-05L2 ~ ~ '~- ~ r ~ --a ~` -_-. ~-t~---,TT-r` T'-"I.:T_ ~=f t-$+,.,-~._"$.=^ ~--- ~ -- _. i 2D-06 (2D-O6) _ _ 2D-OS 2D-05 +~ - I ~ _ - 4000 --~- 3~ :Plan 4 2D-O6BL~ 6000 _~ -J--rte-- ~ - $ -r-„-~" ' , ~ r ~ ~-5-~_ .Tr-I - ~ ' __ 6000 -i.--" a -~ - _ T-1. _'--~-rr--ry-_:_i-y =:- - . 3600 -' - -. 5700 __ _ 6000 ~ -~ ~ rt ~-~ 3800 _•-. '-•---:~`- . ~T 5700 i, _ _-~-- t+ 1-~ -2' '' .. 5400 :. - , w 3aoD ... ~ ~ ~, r ... 5700 _ 1 -Y 2D-O6 (2D-068) "i _ r 1-~ .. - _ - - -.- r-.+ r-.- -r L- _ 00 ~~~ ~1 - ~ 5100 _. 3200 ~ _ -"r_ T + _ _ -r+- " ~ - . :. - ~-. _..rT . -~t~~ I' : --r 3DDD ;~ _ _ 4800 }~-~ -l g pp { - ~ ---- r~ ~ r - 2600 .~y-`.-- -+-•- ~. ~ -.i -. _ 4500 -t 7 - _~ ~ -. _ _ _ ,. ,; 4800 ~ ~- ~ ~- ~~ ~ ~' - --,-.- ~ r~ 2600 ! __ ._._ + -t + ~ ~ ~-r- 4200 ,'4 _ ~~ -1--^` s ~ 50D - r i ~ - - 1- .r _~"_ __ _ _ l _.-.`r"-"r r7 ~-~ ~ ._ +-._~ 3900 ~~T-~ ~ - ,- - 2200 - 4200 . -y-. ~ ` ' - _..T.T __ 3600 __.. ~ ... ~ _ 3900 1,.+:- - - -~ ~.-~-- ~_~ I - N,-_-. `- ~- I --- . , ".~ '~"_`S-` 16oD .' ~~=.- ^ -' +----r - I-~~ ;*`-.. `-1, ~'' :~ '. ; 3300 - ..-- ~ ~ -T^ 3600 _ ~ + ' : teoo , -..- ~ -~-. ~f -. ~ ~^ .. 08 (2D-OB) .,_~ r-r' ~~ - ~ ' ~ ~ ~ ~ + 6300 - ~ tzoo-- 6000 T - '3000 ~' F .- 5700 t --~~'=-- 000 ~~-k----,-':_-i--.-~~.-_ -- -{-"`~--,-r^ 570 5400 - ,-. y-r~-• taco h~ ~~ r ~ .. ... ~ 0 - ~-_ Ty ...~_ ~T_~ '~""- '; 1 - ~ - 51 DD _ - : - . _ .+ ' 4800 -> -,- .... , eoo- - ` 4800 ._ 4500 4200 4500 _ ~,5_ i-~~ ,-'- ~~ ~~ ~ ~ _ 3900 ~~ ~ ~ ~ .. ~ - - - 4200 eoo- . -~ - 3900 3600 '~- - . i- 3300 - _ _ ____ - __ _ 5200 5400 5600 5800 8000 6200 6400 6600 8600 7000 7200 7400 7800 7800 200 400 8030 DD 600 1000 1200 1400 1600 1800 2000 2200 2400 2600 2800 3000 3200 3400 3600 3800 4000 4200 4400 4600 4800 5000 West(-)/East(+) [200ft/in] PM Alaska Department of Natural Resources Land Administration System Page 1 of,~ / ., ._ a, ,_ ..~_rl t , '-' ` ~' L%Lg1S „~~~JfG~t'~S .'iatCt~ S'#£3'c' 1..2,E}IfIS ~~tu~a~ ~ ~~ ~...... Alaska DN12 Cass Summary File Type. ADL,,, File Number: 25653 ' ~ Printable Case File_$ummary See Township, Range, Section and Acreage? ~~ ~" Yes ~ NO ~ New Search LAS Mens~ 1 Case Abstract !Case Detail 1 Land Abstract Pile: ADL 2~fi~3 ~'_`'~= ;~s cif 01 17 x'00 Customer: 000106346 CONOCOPHILLIPS ALASKA, INC. ATTENTION: LAND MANAGER PO BOX 100360 ANCHORAGE AK 995100360 Case Ti~pe: 78~ OIL & GAS LEASE COMP DNR Unit: 780 OIL AND GAS File Location: DOG DIV OIL AND GAS Case Stags: 35 ISS/APPRV/ACTV AUTH Status Date: Ol /28/1965 Total Acres: 2560.000 Date b~itiated: 1 I /02/1964 O~ce ofPrin7ary Responsibility: DOG DIV OIL AND GAS Last Transaction Dcrte: 05/06/2005 Case Subtype: NS NORTH SLOPE Las? Transaction: AA-NRB ASSIGNMENT APPROVED ~lleridicrn: U To~~r~.chi~~: OI~iN Range' 009E ~~~~c~rc~fr. f~ Seeti+~rt _~lcr~s: (~4{} Se~.rch Plats Meridian.' t' 7oirn.~~{ii~>: 01 tN Kan~c~: 009 L' Sc~c~tion: l-1 Secti{~it,lcrE~.c: fi~i Mer'idian.~ 1 ; 7inrj~slu~~: U ] IN Rczns~~c~: 0091 S'ectirn~: ~3 Secti~ur .~f~~re.e.~ 640 Meridicr~r.~ t_ luu~j~sltij~: O1 I ~~ Rar1Lc~.~ 0091_; S'rrc~ir,rr: ~'~ / Sectiu~t _~lc~~~c~.~: 540 Lc„ al Uesc~~iption 11-02-196=~ * * *S.9LE NOTICE LEGAL DESCRIPTION* U-3-6-28 ALL SEC. 13, T.IIN,R9E, U1LI6-~0 ALL SEC. 1~, """"6d0 ALL SEC'. 23, ° " " " 6~1 D ALL SEC. 2~, „ „ „ „ 6~0 260 CONTAINING ?, ~ 60 ACRES, MORE OR LESS. http://www.dnr.state.ak.us/las/Case_Summary.cfm?FileType=ADL&FileNumber=25653&... 1 /17/2007 ~~ TRAYS1d~IITTAL L~TTEIa CI~IECKLIST vvELL r~AIVIE ~.PL/ ~D• DGBL~ PTD# ~ off, ooh / Development Service Exploratory Stratigraphic Test Yon-Conventions! Wel! Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter I CHECK I ADD-ONS TEXT FOR APPROVAL LETTER ,'' 1~'HAT I (OPTIONS) APPLIES ~ I MliLTI LATERAL ~ The permit is for a new wellbore segment of existing u ~-0~8 j well : , j ~ (If last two digits in I permit ~Io. -~~~, AP[ No. ~0-~- 2Il - d 2. I i API number are Production should continue to be reported as a function of the ,' between 60-69) I original AP[ number stated above. I PILOT HOLE i In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both i ;well name ( PH) and API number ~ ~ ' (50- - -_~ from records, data and logs i ~ acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION ~ 2.055. Approval to perforate and produce /inject is contingent i I upon issuance of a conservation order approving a spacing i j I exception. assumes the i liability of any protest to the spacing exception that may occur. i ;DRY D[TCH ;All dry ditch sample sets submitted to the Commission must be in SAMPLE I no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals j I ~ through target zones. ;Please note the following special condition of this permit: Non-Conventional i production or production testing of coal bed methane is not allowed Well ;for (name of we!!) until afrer (Com~anv Name) has designed and I implemented a water wel[ testing program to provide baseline data j ', on water quality and quantity. (Comaanv Name) must contact the ~ !Commission to obtain advance approval of such water well testing i ~ Program. i Rev: 12~i06 C ^ jody~transmittal_checklist WELL PERMIT CHECKLIST Field & Pool KUPARUK RIVER-.490000 Well Name: KUPARUK RIV UNIT 2D-066L1 Program DEV -_.._____ Well bore seg PTD#:2070070 Company CONOCOPHILLIPS ALASKA INC __ _. __ -____ Initial ClasslType _ _ DEV! PEND GeoArea 890 ____. Unit 11160 _ OnfOff Shore On __ Annular Disposal U Administration 11 Permit fee attache_d_ NA_ Multilateral well bore; fee waived-per 20 AAC 25.005(e) 12 .Lease number appropriate_ Yes Multilateral-well se ment: to roductive interval and Tl) in ADL 025653. 9- PP ~~3 Unrque well_n_ame and number - - - - - - - - Yes - - - - - - - - - ~ - - - - - - - - - - '~4 Well located in-a_defined_pool_ Yes Kuparuk River Oil Poo(, governed by Conservation Order No. 4320 5 Well located proper distance. from dulling unitboundary_ Yes - - - Conservation Order No. 4320 contains n4 spacing restrictions with respect_to drilling unit boundaries. ~6 Well located proper distance from other wells_ Yes Conservation Order No. 4320 has.no in_tenvell spacing-restrictions, 7 Sufficient acreage available in_drilling unit_ Yes - .. - _ -Conservation Order No. 4320 has no in_terwell.spacing_restrictions, Wellbore will be_more than 500' from 8 If_deviated, is-wel4bore plat_included Yes . - - - an external property line where_o_wnership or-landownership-changes. - - - 9 Operator only affected party_ Yes Nearest well-in this-pool is 2D-08, about 80.0' away.. 10 Operator has_appr_opriate_bond in force - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - 11 Permit-can be issued without conservation order_ _ Yes _ _ ... _ - - - - _ - Appr Date 12 Permit-can be issued without administrative-approval _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - - - - _ _ _ _ _ _ _ _ _ . _ _ . _ - - _ - _ - - . _ ACS 1122/2007 13 Can permit be approved before 15-day wait Yes 14 Well located within area and strata authorized ay-Injection Order # (puk10# in-comments) (For NA- - . _ . _ - _ _ _ _ _ 1,15 All wells-within 1/4_mile area of review identified (For service well only)- - _ - - - - - NA- - - - - - - - - - - _ '~16 Pre-produced injector: duration of pre-production Less than. 3 months_ (For_service well only) NA_ 17 Nonconven, gas conforms to A$31,05.030(1.1.A),(y2.A-D) _ NA_ - _ _ _ _ _ _ ---- - _ _ - . _ - - Engineering F !18 _- _-- -- - _ -- -- Conductor string_provided - - -_ _ -- NA- . Conductor installed_ in 2D-06 (184-142).- - . - - - i~19 Surface casing-protects all known.USDWs--------------------- ---------NA_- _-----All aquifers exempted, 40CFR_147.102jb)(3)..._-_____.--. _-------.. -. -- _- -- j20 CMT, vol adequate_io circulate on conductor & surf csg - - - .. - - NA_ Surface casing installed in 2D-06. - 21 CMT vol adequate-to tie-in long string tosurf csg_ NA_ Prooduction_ casing installed in-2l)-O6, I22 CtVtf wll] coyer all knownproductiye horizon_s_ No- - - - - - Slotted liner completion plaanned._ ',23 Casing des~ns adequate far C,_T, B &-permafrost_ - - _ ... . - - - NA_ 9riginal well_met design specifications. NA for slotted liner._ ',24 Adequate tankage-or reserve pit - - - - - Yes . - - Rig is_equipped with steel_pits. No rese_rve_p_itplanned, All waste to approved disposal_wells. i~25 If a_re-drill, has-a 10-403 for abandonment been approved N_A - No abandonment tak_in lace. 9P 26 , Adequate weflpore separationproposed- - - - - - - _ - - - - - - - - -- - - -Yes . _ _ _ _ - .Proximity analysis performed, Nearest wellbore-is original-penetration-800' distant. - - - - - - - _ _ _ _ - - - - _ - - ',27 If diverter required, does it meet regulations_ NA- _ - - BOP stack.will already_be in place. ---------------------------------- Appr Date 128 Drillir~q fluid_ program schematic.& equip list adequate.. _ - - - Yes . ... Maximum expected formation pressure 8,3_EMW. Planned MW 8,6ppg.-Actual EMW_on formation will be_higheri t` TEM 1/2412007 ',29 BOPEs,dotheymeet_regulation_____________________ ___ __ ____ __ Yes_ _____ _ordertocontrolshales,___-_-------__ -----_..-__--__-..._..__---_- 30 BOPE press rating appropriate; test to-(put prig in comments).. Yes - - MA$P calculated at 2007 psi. BOP test planned at 4000 psi. 31 Chokemanifold complies wlAPIRP-53 GMay 84) Yes 132 Work will occur rout operation shutdown_ Yes - - ~'~33 Is presence_ of H2S gas_ probable. _ - - - - - - - Yes - - . _ - - - H2S has been reported on 2D pad. Mud should-preclude H2S on rig. -Rig has_sensors_andolarms, '34 Mechanical.condition of wells within AOR verifed (For service well only) - . NA- . - Geology 35 Permit can be issued w!o hydrogen_sulfide measures - - No _ - Well KRU 2D-06B measured 70 m H2S on 10/17/2006._ - PP- '36 D_ata_presented onpotential overpressure zones. Yes - - - -Expected r_eservoirpressure is 8.3.ppg EMW; willt~e drilled with 8.6 ppg mud using managedpressure techniques Appr Date !37 Seismic analysis. of shallow gas-zones . - NA_ - - - - - -resulting in an-ECD of 11.D ppg. ACS 1122/2007 ''38 Seabed condition sucvey_(if off-shore) NA_ ',39 Contact nameFphone.far weekly_p_rogress reports-[exploratory only] _ _ - .. _ Yes - _ _ _ _ _ ARAB WORTHIN_GTON_(564.4102) - 0R-- GARY_ EL_LER X529-4628x - - - - - - - - - - - - - - - - - - - - - - - - - Geologic Engineering u is Date Date: ' Date Review by Art Saltmarsh. Additional comments by Davies, 1-22-2007. Commissioner: sinner C Commissioner: ~~ / ~ 12~' 17 ~"A~~'-'r7 •
