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Home My WebLink About207-063~ II Histo File Colr Pa e Image Pro~ect We ry g XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file., ~ Q_ - Q~~ Well History File Identifier Organizing (done) p Two-sided III IIIIII II (II II III ^ Rescan Needed III II'I II I) II III III RE AN DIGITAL DATA OVERSIZED (Scannable) Color Items: iskettes, No. ! ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~S~ ~ Pro"ect Proo~n III II'lll III~ II III ! g BY: Maria Date: ~S~ Scanning Preparation ~_ x 30 = ~ ~ + = TOTAL PAGES ~ ~ ( ount does not indude cover sheet) BY: Maria Date: ~/Gr/~G~ ~S~ Production Scanning Stage 1 BY: Stage 1 BY: Page Count from Scanned File: -~-~-t- (Count does inGude cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO Maria Date: ~J ~~ ~S~ ~ ~ If NO in stage 1, page(s) discrepancies were found: YES NO Maria Date: ~~ ~ ~ ~~ ^~.~ ~ ~. ~~ ~ ~ .u Scanning is complete at this point unless rescanning is required. ReScanned II I II'I II II (II I I III BY: Maria Date: ~S~ Comments about this file: Quality Checked III II'III III II~I III 10/6/2005 Well History File Cover Page.doc • • WELL LOG TRANSMITTAL To: Alaska Oil and Gas Conservation Comm. July 28, 2011 Attn.: Howard Okland 333 West 7th Avenue, Suite 100 Anchorage, Alaska 99501 a t*` RE: Gas Lift Survey: 1C-03A ' Run Date: 7/25/2011 The technical data listed below is being submitted herewith. Please address any problems or concerns to the attention of: Klinton Wood, Halliburton Wireline & Perforating, 6900 Arctic Blvd., Anchorage, AK 99518 1C -03A Digital Data in LAS format, Digital Log Image file I _ 1 CD Rom 50- 029 - 20535 -01 ' 0 `P PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING A COPY OF THE TRANSMITTAL LETTER TO THE ATTENTION OF: Halliburton Wireline & Perforating Attn: Klinton Wood 6900 Arctic Blvd. Anchorage, Alaska 99518 Office: 907 - 273 -3527 Fax: 907-273-3535 klinton.wood @halliburton.com Date: i (p Signed: O J r � v7 -0CD) • ConocoPhillips ~~ P.O. BOX 100360 ANCHORAGE, ALASKA 99510-0360 July 16th, 2010 Commissioner Dan Seamount Alaska Oil & Gas Commission 333 West 7th Avenue, Suite 100 Anchorage, AK 99501 Commissioner Dan Seamount: ~~~ V ~® ~~~k~ ~ ~ Cas Cam. Cerssion ~ncl~3rage ao~_o63 ~G-o3R Enclosed please find a spreadsheet with a list of wells from the Kuparuk field (KRLI). Each of these wells was found to have a void in the conductor. These voids were filled with corrosion inhibitor, engineered to prevent water from entering the annulax space. As per previous agreement with the AOGCC, this letter and spreadsheet serves as notification that the treatments took place and meets the requirements of form 10-404, Report of Sundry Operations. The cement was pumped November 25th 2007 & March 21 2009, the corrosion inhibitor/sealant was pumped July 6th, 7~', 8th 2010. The attached spreadsheet presents the well name, top of cement depth prior to filling, and volumes used on each conductor. Please call Perry Klein or MJ Loveland at 907-659-7043, if you have any questions. Sincerely, Perry Klem ConocoPhillips Well Integrity Projects Supervisor s • ConocoPhillips Alaska Inc. Surface Casing by Conductor Annulus Cement, Corrosion inhibitor, Sealant Top-off Report of Sundry Operations (10-404) Kuparuk Field Date 7/16110 1A.1C.1E PAD Well Name API # PTD # Initial top o cement Vol. of cement um ed Final top of cement Cement top off date Corrosion inhibitor Corrosion inhibitor/ sealant date ft bbls ft al 1A-11 50029206850000 1811730 10" n/a 10" Na 3.4 7/8/2010 1A-12 50029206880000 1811780 2" Na 2" Na 1.7 7/8/2010 1A-13 50029207000000 1811950 11" n/a 11" n/a 3.4 7/8/2010 1A-14 50029207060000 1820100 4" n/a 4" n/a 2.1 7/8/2010 1C-01 50029205260000 1801280 SF n/a 24" Na 4.3 7/6/2010 1 C-02 50029205320000 1801350 24" n/a 24" n/a 8.5 7/6/2010 1 C-03A 50029205350100 2070630 SF Na 16" Na 7.7 7/6!2010 1C-04 50029205470000 1801550 SF n/a 5" n/a 2.6 7/6/2010 1C-06 50029205640000 1810250 76 17.70 32" 3/21/2009 9.4 7/6/2010 1C-09 50029208590000 1821850 38' 8.00 6" 11/25/2007 6.8 7/6/2010 1C-10 50029208650000 1821930 37'6" 8.00 8" 11/25/2007 6.8 7/6/2010 1 E-02 50029204720000 1800500 21 " Na 21 " Na 1.7 7/7/2010 1 E-03 50029204770000 1800560 4" Na 4" n/a 2.4 7/7/2010 1 E-06 50029204930000 1800780 12" n/a 12" n/a 13.6 7/7/2010 1 E-07 50029204950000 1800800 5" n/a 5" Na 2.6 7/7/2010 1 E-08 50029204960000 1800810 5" n/a 5" Na 2.6 7/7/2010 1 E-10 50029207250000 1820360 2" n/a 2" Na 1.7 7/7/2010 1 E-13 50029207500000 1820780 5" n/a 5" Na 2.6 7/7/2010 1E-19 50029209050000 1830170 1" n/a 1" Na 1.7 7/7/2010 1E-21 50029208920000 1830020 3" n/a 3" n/a 2.6 7/7/2010 1 E-24A 50029208570100 1971870 2" n/a 2" n/a 1.7 7/7/2010 1E-25 50029208440000 1821700 3" Na 3" n/a 1.7 7/7/2010 1E-28 50029208320000 1821580 4" n/a 4" n/a 2.5 7/8/2010 1 E-29 50029208280000 1821540 7" Na 7" Na 2.5 7/8/2010 ;~'~ ~, ~ ~~ `~ _.. -, ,,,~ ,~~ r ,.. ~ ~~'~ o- ~:,° ~ ~ e~ ~ ~_ ,~ MICROFILMED ..6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet F'tles\OLK9\Microfilm_Marker.doc ~ ConocoPhillips Alaska Greater Kuparuk Area ~ RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wright, 907 263-4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 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 / TIF~ 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 Alaska; DNR, Div. of Oii ar~d Gas 1 G~sk*f 550 W. 7th Ave, Suite 800 ~ Electronic Anchorage, Alaska 99501-3510 LIS ~~ ~~ ~a~ .~~ ~, c ~ ~; ~.~:~ ~ ~ .~.~h,_h. ~~ ~ ~' ,~' - : ;~, ~ ;,; ~ o ~ ,- ~ ti' ~ . ~ ~ ~~ ~ ~ ~ ~ ca ~e ~?' ~: ` ~{ ~ J ~, ~`( DATA SUBMITTAL COMPLIANCE REPORT 6/22/2009 Permit to Drill 2070630 Weli Name/No. KUPARUK RIV UNIT 1C-03A Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-20535-01-00 MD 12455 ND 6524 Completion Date 6/9/2007 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATI~N Types Electric or Other Logs Run: (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 9100 12455 Open 7/24/2007 Rpt Directional Survey 9100 12455 Open 7/24/2007 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORIV~ON ~ Well Cored? `K /, Daily History Received? Chips Received? .Y~~ Formation Tops y~ N Analysis ~ Received? Comments: ~.>..`..~ l~w.~-.. ~v,~~~ fi~.~.~ ~.~~u ~~~~riS. ZK Jv.~ '(~~~w~~l~c,?~ 0.~4. tt.x ~.oJc~. t, ~~{,,,1, ~,c.~q ~1 Compliance Reviewed By: Date: ~,`-~ 01.~.._. ~~"r ~ 1 ~ ~ ~ STATE OF ALASKA ~ ALASKA OIL AND GAS CONSERVATION COMMISSION ~~~~~~~+EC~ ~ ~ ~..,~ ~ Ji)l~ 4 5 2007 WELL COMPLETION OR RECOMPLETION REPORT AND LOG ,~€~ ~U f3;; ~; ~~s ~:~ras. Commissiv~ t.~~~~.2waru[a 1a. Well Status: ~ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 2o,v~c2s.~os zoewczs.~,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1b. Well Class: ~ Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 6/9/2007 ~ 12. Permit to Drill Number 207-063 ' 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 5/28/2007 ~ 13. API Number 50-029-20535-01-00 4a. Location of Well (Governmental Section): Surface: ' ' ' 7. Date T.D. Reached 6/7/2007 ~ 14. Weli Name and Number: Kuparuk 1C-03A - 1583 FNL, 1165 FWL, SEC. 12, T11N, R10E, UM Top of Productive Horizon: 3996' FNL, 4289' FEL, SEC. 11, T11 N, R10E, UM 8• KB (ft above MSL): 94' Ground (ft MSL): 15. Field / Pool(s): Kuparuk River Unit / Kuparuk ,. Total Depth: 2317' FNL, 2206' FEL, SEC. 11, T11N, R10E, UM 9. Plug Back Depth (MD+ND) 12455 ~ 6524 River Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 562173 ' y- 5968656 ~ Zone- ASP4 10. Total Depth (MD+~/D) 12455 ~ 6524 f 16. Property Designation: ADL 025649 ' TPI: x- 556740 y- 5966199 Zone- ASP4 Total Depth: x- 558809 ° y- 5967894 .~ Zone- ASP4 11. SSSV Depth (MD+~/D) 1871 1795 17. Land Use Permit: 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): 1650' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071):~:r w~' a~ : 9 rc~ ~I~D MWD DIR / RES / GR ~~f~, ~7y~ 22. CASING, LINER AND CEMENTING RECORD 7+~Q ~~ CASINfi SETTtNG DEPTH MD SETTING DEPTH TVD HOtE `AIdOUNT" ' UVT. PER Ft. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 1" 65# H-40 Surfa e 80' Surface 80' 24" 200 sx Permafrost 10-3/4" 45.5# K-55 Surface 3214' Surface 2682' 13-3/4" 1500 sx Fondu 250 sx AS II 7" 26# K-55 Surface 9103' Surface 6423' 8-3/4" 725 sx Class'G' 2-3/8" 4.6# L-80 8978' 12455' 6342' 6524' 3" Uncemented Slotted Liner 23. Open to production or inject ion? ~ Yes ^ No ~4. ' TueiNC Reea~o If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number): Size ~EPTH .SET MD PACKER cJET MD 2-3/8" Slotted Section 3-1/2", 92#, K-55 8983' 8944' MD TVD MD ND 9210~ - 10965~ 6468~ - 6456~ 11000' - 12421' 6456' - 6519' 2~J, ~CID, FRACTUaE, ~EMENT ~QUEEZE,`ETC. DEPTH INTERVAL MD AMOUNT 8c KIND OF MATERIAL USED 2500' Freeze Protected 26. PRODUCTION TEST Date First Production: June 18, 2007 Method of Operation {Flowing, Gas Lift, etc.): Gas Lift Date of Test: 6/24/2007 Hours Tested: 24 PROOUCTioN FoR TEST PERIOD OIL-BBI: 737 GAS-MCF: 953 WATER-BBL: 298 CHOKE SIZE: 176 Bean GAS-OIL RATIO: 1293 Flow Tubing Press. 249 Casing Press: 804 Cn~cuu~Teo 24-HOUR RATE• OIL-BBL: 737 GAS-MCF: 953 WATER-BBL: 298 OIL GRAVITY-API ~CORR~: 23.5 Z7. CORE DATA Conventional Core(s) Acquired? ^ Yes ~ No Sidewal l Core s Ac uired? ^ Yes ~ No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. ~F~ JUL ~ 310D7 ~ ~'`"~'`~~~~~~ None _~ C ~^ 11ER IEit ~ . _____.__.__.____._.. ~. _ : , ; _. _ ~. -,...~°" Form 10-407 Revised 02/2007 ~ ~.( ~ ~ ~ ~ ~ TINUED ~N REVERSE .SIDE ~ ~15~ _ / '~ ~J ~• /0 'p'~ ~ 1 \ ~/ 5~~~ ZH. GEOLOGIC MARKERS ~LIST ALL FORMATIONS AN ERS ENCOUNTERED~: Z9. FORMATION TESTS NAME MD ND 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. Base C4 / Top C3 9151' 6448' None Base C31 Top C2 9191' 6463' r Top C2 / Base C3 9558' 6464' ~'op C3 / Base C4 10640' 6465' Base C4 / Top C3 11833' 6468' Base C3 / Top C2 12248' 6492' Formation at Total Depth (Name): Kuparuk C2 12455' ` 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. ~ ~ ~ ~ ~ Signed Terrie Hubble Title Technical Assistant Date Kuparuk 1 C-03A 207-063 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A ~OV81 NO. Drilling Engineer: Gary Eller, 529-1979 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. Irenn ia: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). 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. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITeM 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 intenral to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). 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. ITeM 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 y t~ ~ ~ Legal Well Name: 1 C-03 Common Well Name: 1 C-03 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 5/18/2007 09:00 - 10:00 1.00 MOB P 10:00 - 00:00 14.00 MOB P 5/19/2007 00:00 - 06:00 6.00 MOB P 06:00 - 09:00 09:00 - 10:15 10:15 - 11:00 11:00 - 12:00 12:00 - 15:00 15:00 - 18:00 3.00 MOB P 1.25 MOB P 0.75 MOB P 1.00 MOB P 3.00 MOB P 3.00 MOB P 18:00 - 18:30 0.50 MOB P 18:30 - 19:30 1.00 MOB P 19:30 - 21:00 1.50 MOB P 21:00 - 23:00 2.00 MOB P 23:00 - 00:00 I 1.00 I MOB I P , 5/20/2007 00:00 - 03:25 03:25 - 03:45 03:45 - 04:20 04:20 - 05:30 3.42 BOPSU P 0.33 BOPSU P 0.581 BOPSUFI P 1.171 BOPSUFiP Spud Date: 5/15/2007 Start: 5/15/2007 End: 6/9/2007 Rig Release: 6/9/2007 Rig Number: PRE Nordic 2 mobilizing to Kuparuk iC-03 Rig at Hot Water Piant at 10:00 hrs PRE Rig mobilization. Camp on tocation at 1C-03 aY 14:00 hrs. PRE Nordic 2 mobilizing to Kuparuk 1C-03. Rig is at the Kuparuk river bridge at 00:00 hrs. Crew change with rig at MPU tumout. PRE Moving rig from MPU turnout to Kup 1 C-03. PRE Travel from KOC to 1-03 Arrived on location at 10:15 hrs. 25 hours travel time from DS4 to 1 C-03 PRE RU to set rig mats and spotting rig in front of well. Hold PJSM with DSO and crew and backing over well. PRE Back over well. PRE Rig Accetped at 12:00 hrs. Install 3-1/2" X 7-1/16" cross-over spool NU BOP's PRE NU BOP's and installing SLB's Power Pack on rig Checking the bolts on the tree. They were loose to say the least. Taking on fuel and rig water. PRE C/O & PJSM & THA with day crew. PRE Tree & BOPE bolts are tight. PJSM prior to skiding & shiming rig center over well. Clean out W HP port flange on BOPE. PRE SLB traction motor is installed & running, LOTO has been removed. Hook up kill & choke lines. RU handy berm. Spot 110% tiger tank. Spot cuttings box. BHI is rigging up & testing down hole tools for first BHA run. Get BOPE measurements for schematic. ASRC drilling group is rigging up hardline from flowback tank to rig. PRE SLB is pulling drive plates from reel package. RU 7" lubricator w/ new o-rings to top of annular bag. Install 7" lubricator cap under RF. RU BOPE hoses. Install fuseable cap & bleed off SSV actuator to 0 psi to a bucket. Label RF, SLB Ops cab & Koomey unit BOP controls. PRE Function test BOPE. Fill stack with water. Cycle swab & master to fill voidage on tree. Drain stack & pull 7" lubricator & replace cut o-ring on top of annular bag. Fill voidage again. Drain stack & puli ram door on lower BOP & repalce cut o-ring. Fill voidage again. Post permit to drill in Ops cab, Dog house & Co.Rep shack. PRE Start BC3PE test. Waived by John Crisp. Chart via chart & CCAT. Full body test against SV. Test blind/shear rams on choke side. Test valves #9,#10,#11,#13, Kill HCR & manual gate valves. Test valves #3,#4,#7,#8,#11 & manuai kill. Test valves #1,#2,#6,#12. Grease HCR valve. Test valves #1,#2,#5,#12 & manual kill & BOP #17 vaive. PRE SLB hydraulic leak on the traction motor has been fixed. Reel drive plate have been installed & torqued in place. Install reel bushings. Rig up Swaco choke & CTDS screen for PBD. Begin testing lower most 2" pipe/slip rams with test joint. Load 290 bbls of 2% KCL for milling operations into pits. PRE PJSM & THA prior to lifting reel into reel house. Test 2" upper pipe/slip rams with test joint, manual choke & BOP #18 valve. Test choke HCR & manual kill. Pull 2" test joint & run 2-3/8" test joint. Test 2-3/8" pipe slip rams & kill HCR. 2" e-coil is secure in the reel house. PRE Test annular bag. Install reel drive securing plates. Hook up Printed: 6/11/2007 11:19:39 AM ~, , ~ ~ Legal Well Name: 1 C-03 Common Well Name: 1 C-03 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 5/20/2007 0420 - 05:30 1.17 BOPSU P PRE 05:30 - 12:00 6.50 RIGU P PRE 12:00 - 14:45 2.75 RIGU P PRE 14:45 - 15:00 025 RIGU P PRE 15:00 - 15:45 0.75 RIGU P PRE 15:45 - 17:30 1.75 RIGU P PRE 17:30 - 18:00 0.50 RIGU P PRE 18:00 - 18:30 0.50 RIGU P PRE 18:30 - 21:00 2.50 RIGU P PRE 21:00 - 21:20 ! 0.331 RIGU I P I I PRE 21:20 - 21:35 0.25 RIGU P PRE 21:35 - 22:00 0.42 RIGU P PRE 22:00 - 23:30 1.50 RIGU P PRE 23:30 - 00:00 0.50 RIGU P PRE 5/21/2007 100:00 - 01:45 I 1.751 RIGU I P 01:45 - 04:10 I 2.42 I STW H I P I P 04:10 - 04:15 04:15 - 04:35 04:35 - 04:40 04:40 - 04:45 0.08 STWHIP P 0.33 STWHIP P 0.08 STWHIP P 0.08 STWHIP P PRE Start: 5/15/2007 Rig Release: 6/9/2007 Rig Number: W EXIT W EXIT W EXIT W EXIT W EXIT Spud Date: 5/15/2007 End: 6/9/2007 inner reel iron. Perform drawdown test on accumulators. BOPE test was successful. Install wellhead gauges and guards. RU hardline and bulk head in reei. BHI checking tool and testing same Megged line and OK. Working to locate a FMC hand to pull BPV. Found him on Nordic 3. Changing gripper blocks from 2-3/8" to 2" Ordering out tools for cement ramp window. Set stripped on well, PU injector head and lined up goose neck to injector top drive. Clean ice and snow from reel. Measured cable on winch for pulling CT across for replacement later. Installed 2" grapple in CT to pull across. Held PJSM and discusses the SOP's and mitigated the hazards. RU and pulled tested, OK, tighten grapple and pull CT across the pipe shed. Set injector back and RU to pull BPV. Pull BPV. LD BPV lubricator & equipment. PU injector & MU 7" lubricator & stab injector on well. C/O with day crew. PJSM & THA prior to conduction slack management. Fill coil. Pump 10 bbls of inethanol into reel followed by 2% KCL w/ 2ppb bio water ~ 0.5 bpm (reduce risk of bird nesting e-line). Coil is full of water. SD, bleed off & pop off to check end of wire - ok. Stab on & reverse circulate, 3.00 bpm C 3800 psi. E-line cable is moving, moved for -8 bbis. Stop reverse circulating, try one more time to make sure cable won't move. Cable is not moving. Stop pumping, bleed off & pop off. Start cutting coil to find end of wire. Cut 18' of coil to find end of wire. Test e-line via meg - ok. Install coiled tubing dimple connector. Pull test to 35k. Re-check dimple connector. BHI is heading up. Test e-line after UQC has been installed - ok. P.T. c~ c~ctor to 41~0 psi - ok. P.T. inner reei vaive per AC3(AGG ~443F~ te~t -~c, dlarted via SLB. PJSM & THA prior to picking up BHA. Simultaneously, complete slack management by pumping down coil - 1 coil volume. Completed slack management. Open master valve to closed BS & check for pressure. Brand new Hughes mill won't make up to BHI motor. Threads have been cut wrong. Choose another mill, 2.74" No Go 2.75" go on a D331. MU BHI BHA to motor & mill. Stab coil onto BHA. Power up & check tools. Tag up & set depths. Divert returns (diesel) to T.T. Open EDC & RIH. BHI depth not reading correctly, continue in hole. BHI ops cab does not have computer access to down hole tool. Sit down ~ 1881' (TRDP). Wake up BHI day crew. Reboot BHI's computers. Close EDC & bit assist our way past. Close EDC. RIH pumping min rate. Weight check 15.5k up, 8k down. Continue RIH. VP's = 173. Weight check 24k up, 10.5k down. Continue to RIH. Take returns out to Tiger Tank (Crude). Order Printed: 6/11/2007 11:19:39 AM . .~ ~ i Legal Well Name: 1 C-03 Common Well Name: 1 C-03 Spud Date: 5h 5/2007 Event Name: REENTER+COMPLETE Start: 5/15/2007 End: 6/9/2007 Contractor Name: NORDIC CALISTA Rig Release: 6/9/2007 Rig Name: NORDIC 2 Rig Number: 5/21/2007 04:40 - 04:45 0.08 STWHIP P WEXIT more fluids. 04:45 - 05:15 0.50 STWHIP P WEXIT Log down with CCL across GLM #2 & GLM #1. 62 bbls in Tiger Tank and getting a little gas. Tag up at 8930'. Log up with GR at 300Whr. Not much GR character to tie-in. Closed EDC and RIH to tag at 8930'. Getting gas/oil to surface, take fluid back outside. 05:15 - 06:45 1.50 STWHIP P WEXIT Volume of pits low, ordered 290 bbl from Deadhorse via Veco. Open EDC and circulate bottoms up until cleans up and 290 bbls of new fluid arrives. 06:45 - 07:12 0.45 STWHIP P WEXIT Circulating Qp = 1.67 / 1.67 bpm at 2400 psi Density = 8.54 8.47 ppg. Holding 100 psi on wellhead. Off loading fluids. SD pump and closed EDC 07:12 - 07:35 0.38 STWHIP P WEXIT RIH and set down at 8927 ft without motor work. Worked through to 8,950 ft. PUH to 8,880 ft to log GR tie-in at 8,910 ft. 07:35 - 08:20 0.75 STWHIP P WEXIT Log from 8,880 ft to 8,950 ft Corrected -5 ft GR spike at 8,914 ft RIH and tagged at 8990 ft. PUH to 8850 ft to tie-in jewelry. 08:20 - 08:45 0.42 STWHIP P WEXIT Log CCL tie-in from 8,850 ft down to 8,990 ft. Milled down to 8,992 ft. no corrections 08:45 - 10:41 1.93 STWHIP P WEXIT RIH and tagged TOC at 8,992 ft. Milling Cement TF at 180. Qp = 1.51 / 1.52 bpm CTP 1820 / 2300 WOB = 1.5k DHWOB 0.5 3.5k Milled down to 9001 ft and to much WOB PUH and tagged at 9,000 ft (? hard cement) Drill cement at an ave of 40 fph to 9,047 ft. W iper trip to 8,990 ft with 180 deg TF. RIH; Qp = 1.51 bpm 10:41 - 11:36 0.92 STWHIP P WEXIT Milling cement from 9,048 ft to 9,062 ft TF at 180 deg Qp = 1.51 / 1.52 bpm 2000 psi off bottom pressure. 11:36 - 12:00 0.40 STWHIP P WEXIT Wiper trip to 9000 ft 12:00 - 12:50 0.83 STWHIP P WEXIT Working to get it to drill. ROP at 48 fph with 3.3 k WOB Milled cement to 9090 ft and all of the ROP exceeded 40 fph and in some cases it was 50 to 55 fph 12:50 - 13:15 0.42 STWHIP P WEXIT Wiper trip to 8980 ft and back and tagged ta 9090 ft. POOH 13:15 - 13:53 0.63 STWHIP P WEXIT POOH. Open EDC and POOH. RIH to cleanout to 9,107 ft 13:53 - 14:30 0.62 STWHIP P WEXIT Drilling Cement from 9,090 ft to 9,107 ft With some restart due to stacking Average ROP > 40 fph Qp = 1.51 1.51 bpm at 2, 050 / 2,500 psi Vp = 413 bbls PU for wiper trip due to stacking 14:30 - 14:55 0.42 STWHIP P WEXIT Wiper trip to 9,050 ft RIH and milled out cement to 9107 ft. Talked with town on way forward Milled cement to 9107 ft at 45-50 ft/hr. 14:55 - 17:30 2.58 STWHIP N CEMT WEXIT POOH to PU BOT 3-1/2" 7" Under reamer. Confirmed Tie-in (o correction) Open EDC Changing out the override sprocket on reel POOH SD at 250 and checked flow and held PJSM 17:30 - 18:00 0.50 STWHIP N CEMT WEXIT Break off BHI tools from motor & mill. LD BHI tolis & motor & Printed: 6/t t/2007 11:19:39 AM ~ ~ I Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-03 1 C-03 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Spud Date: 5/15/2007 Start: 5/15/2007 End: 6/9/2007 Rig Release: 6/9/2007 Rig Number: 5/21 /2007 17:30 - 18:00 0.50 STW H I P N 18:00 - 18:30 0.50 STWHIP N 18:30 - 19:30 1.00 STWHIP N 19:30 - 2125 1.92 STWHIP N 21:25 - 22:40 22:40 - 23:50 23:50 - 00:00 I 5/22/2007 I 00:00 - 00:15 00:15 - 02:15 02:15 - 0225 02:25 - 02:49 02:49 - 03:10 03:10 - 03:45 03:45 - 06:15 06:15 - 07:10 07:10 - 08:50 08:56 - 1~0~08 1~.20 STWHtPf N 10:08-11:30 ~ 1.37ISTWHIPIN 11:30 - 13:45 I 2.251 STWHIPI N CEMT WEXIT mill. CEMT W EXIT C/O with day crew & PJSM & THA prior to handling BHA. Perform kick drill & parted coii drili. Mill was 2.73" No-Go & 2.74" Go. CEMT WEXIT PU & MU BOT 3 bladed under reamer & motor. Attach BHI tools & stab on to BHA with coil. Power up & check tools. Set counters. Open EDC. RIH with under reamer. Hold Pre spud meeting with night crew. CEMT WEXIT WT Ck 25k up & 10k down. Log down for tie in from 8875ft to 8940ft. 3ft correction needed. CEMT WEXIT Drop past end of tubing tail. Close EDC & begin pumping to open under reamer blades. VP's = 425 bbls. 1.51 bpm in / 1.48 bpm out @ 2161 psi fs. Seeing some motor work ~ 9002' (60psi DP) 1201bs WOB. Keep ROP steady at 40ft/hr and motor work below 200psi DP. CEMT WEXIT Pump 15 bbl sweep. Cement material coming back on shaker is mushy. CEMT WEXIT Pump 15 bbl sweep & back ream to TT from 9040ft C~ 4 fUmin. 1251 STWHIPIN CEMT ~ W EXIT ~ Continue to back ream to TT. Heavy motor work @ 8993', stop pumping. Work area until clean. CEMT W EXIT Continue to under ream. VP's = 427 bbls. Mix another pill in pit ' 4. 1.40 in/1.38 out ~ 1975 psi fs. 2001bs WOB CEMT W EXIT Pump 10 bbl sweep. Increase ROP, motor work is 200 psi. CEMT WEXIT Back ream from 9080ft C~3 4ft/min. CEMT WEXIT Motor work @ 8991ft. Work down past with no problems. RIH to bottom. CEMT WEXIT 300 psi stall, stop pumping & pick up. Slow ROP down while going through perfs. Pump 15 bbl sweep. CEMT WEXIT Stall. Time drill from 9,119ft to 9,125.6 ft CEMT WEXIT UR from 9125 ft. Lots stalls occurring at 9,125 ft(inside perf area 9,101 ft to 9,221 ft) Cement somewhat hard in the perf interval Qp = 1.38 / 1.38 bpm CTP 2,223 psi Vp = 417 bbl CEMT WEXIT Wiper trip / back reaming 9126 ft to 8,983 ft. Pumping sweep down CT Qp = 1.49bpm at 2200 / 2513psi. Reamed area at 8,991 ft several times and cleaned up on the downward movement. Pumped 10 bbl Biozan Sweep and RIH to cleanout to 9,126 ft. CEMT WEXIT PUH to tie in at 8,908 ft CEMT WEXIT Logged tie-in at 8908 ft and corrected -10 ft for GR. RIH and confirmed GR tie-in at 9030 ft without correction. Rih and tagged PBTD at 9,116 ft MD. POUH to 8890 to log CCL. Logged CCL from 8890 ft and tagged at 9116 ft. Open EDC Qp = 1.00 bpm, PUH. GR and CCL tied-in but the 7" casing collar ar off by 12 ft. POOH to look at the UR. CEMT W EXIT POOH. Having some trouble with SCR / Power Pack the hydraulic P-14 pump increasing speeds. Paint at 8000 ft EOP. CEMT WEXIT Stopped at 5,888 ft to wait for the SLB mechanic to look at the controllers for the power pack in the high gear switch. The 1.17 STWHIP N 0.17 STWHIP N 0.25 STWHIP N 2.00 STWHIP N 0.17 STWHIP N 0.40 STWHIP N 0.35 STWHIP N 0.58 STWHIP N 2.50 STWHIP N 0.92 STWHIP N 1.67I STWHIPI N Printed: 6/11/2007 11:19:39 AM 1 ~, ~ ~ Legai Well Name: 1 C-03 Common Well Name: 1C-03 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 5/22/2007 I 11:30 - 13:45 I 225 I STW H I P I N 13:45 - 15:00 1.25 STWHIP N 15:00 - 16:00 1.00 STWHIP N ~ 16:00 - 17:45 1.75 STWHIP N 17:45-19:45 2.00 STWHIP N ' 19:45 - 20:45 1.00 STWHIP N 20:45 - 22:45 2.00 STWHIP N 22:45 - 00:00 5/23/2007 00:00 - 02:00 02:00 - 04:30 04:30 - 06:15 06:15 - 07:00 07:00 - 10:40 10:40 - 13:00 13:00 - 14:45 14:45 - 15:30 15:30 - 20:15 20:15 - 22:30 22:30 - 00:00 5/24/2007 ( 00:00 - 03:30 1.25 STWHIP N 2.00 STWHIP N 2.50 STWHIP N 1.75 STWHIP N 0.75 STWHIP N 3.67 STWHIP N 2.331 STWHIPI P 1751 STWHIPIN 0.75 STWHIP N 4.75 STWHIP P 225 STWHIP P 1.50 STWHIP N 3.501 STWHIPIN Spud Date: 5h 5/2007 Start: 5/15/2007 End: 6/9/2007 Rig Release: 6/9/2007 Rig Number: CEMT W EXIT POOH speed goes from 80 fph to 134 fpm without making any changes to the injector or joystick. Mechanic working on SLB's hydraulic problem. PUH while SLB mechanic troublshoots the problem. Held PJSM on BHA handling. CEMT WEXIT LD and inspected UR BHA. Recovered all 3 blades and they were in good shape. Worked out details with SLB engineer on way forvvard CEMT W EXIT Spot and rig up SLB Eline. SLB reheading cable head. Gerald with SLB, spliced two logs together and came up with the correct depth presentation on the well. Used the producion log done in March of 2007 to come up with the correct tie in for the 7" casing below the WLEG CEMT W EXIT PU injector and removed UQC and condition line for cementing. PU 6 jts of 1-1/4" CSH and 2.25" nozzle. CEMT W EXIT RIH with Cementing BHA. Correct -7.5' to EOP flag. Tag btm at 9118'. 22k# up, 5.5k# dn weight. CEMT W EXIT Circulate 50 bbls clean 2% KCL water. Getting some gas cut returns. Increase W HP from 100 to 250 psi. Hotd PJSM to discuss cement job. CEMT W EXIT Batch mix 6 bbis Class G 17 ppg cement. Pressure test lines to 4000 psi. Pump 3 bbls fresh water, 6 bbis cmt, 5 bbls fresh water. Displace with biozan. Avg rate: 1.13 bpm at 850 psi. IA/OA: 282/276 psi. Lay in cmt 1:1. Puli to 8000'. Cement in place at 2215. Wait on cmt for 30 minutes. CEMT WEXIT Wash cement down to 8985' with biozan. Make three passes from 8500' to 8985'. 2950 psi at 2.45 bpm. CEMT W EXIT Continue to wash cement from 8500' to 8985'. Wait on 9.2 brine from MI. CEMT WEXIT Pull out of hole laying in 92 ppg brine. Wash each GLM and otherjewelry. Slowly reduce WHP. CEMT W EXIT At surface. Get off well. Unstab coil. LD CS hydril pipe. CEMT W EXIT RU and jet stack out CEMT W EXIT Conducted Conduct Slack Management. Cut off 240 ft 2" CT. and 4 ft wire. megged line >2000 m-ohms and conductivity at 38-42 ohms. Install dimple CTC Pulled tested to 35k (OK). Rehead cable to UQC Megged UQC / line >2000 mohms . PT CTC to 4000 psi. W EXIT Circulate down CT to finish slack management Install wire in packoff / rope socket PU pressure deployment lubricator. CEMT W EXIT RU pressure deployment lubricator and 1.75 deg bend motor BHA for drilling pilot hole CEMT WEXIT RIH and open EDC at 503 ft RIH to 2610 ft W EXIT Install Schlumberger's CT Inspect on the level wind and install the software. W EXIT Run in hole, testing CT Inspect system. CEMT WEXIT Begin GR log. BHA hung up at 8909'. Pull 50k#. Able to turn tool face. Close EDC to circulate through the bit. Finally work free downhole. Acts like junk along side tools. Pick up. Unable to get up past 8889'. Able to move up and down between 8889' and 8920' only. Easier going down with no pump. STUC W EXIT Continue to work pipe. Bit is now stalled. Still able to get above Printed: 6/11/2007 11:19:39 AM ~ ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 C-03 1 C-03 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Spud Date: 5/15/2007 Start: 5/15/2007 End: 6/9/2007 Rig Release: 6/9/2007 Rig Number: 5/24/2007 00:00 - 03:30 3.50 STWHIP N STUC WEXIT 8890' or go below 8918'. Now believe we lost a piece of e-line in the hole during cement job. The e-line removed from the CS Hydrill was 175' with a very frayed end and missing seal cap. The CS hydrill BHA was 180'. We suspect e-line came out the cementing nozzle and parted while making clean out passes with coil. SLB records for the reei indicate 214' of "extra" e-line inside the coil when new. There is possibly of +/- 39' of e-line in hole. Continue to work pipe to try and wear out e-line while waiting on flopro w/ lubricant. ', 03:30 - 04:30 1.00 STWHIP N STUC WEXIT Circulate new flo pro through open EDC. 04:30 - 06:30 2.00 STWHIP N STUC WEXIT Resume working pipe while circulating through EDC. Coil life less than 10%. Pull up to 80% (62k#). Able to run in hole ok to 8910' after first few max pulls. Hung up, then free again to move down hole. CT movement from 8926 ft to 8880 ft(46 ft) Working CT and orient TF to low side between 8,927 ft and 8,880 ft. (o k down and 40k up) See the DPS sub in the ', tension and compression modes, orienter moves and the motor ' turn at min rev. 06:30 - 08:50 2.33 STWHIP N SFAL WEXIT SD, power pack HP hydraulic filter lost seal and sprayed hydrauiic oii on the power pack wall (contained). The seal that failed is between the filter pod and the housing. Mechanic bringing out the correct o-ring 08:50 - 09:45 0.92 STWHIP N SFAL WEXIT Mechanic working on HP pod on power pack , Pumped 20 bbl 2.5%L776 and spotted around BHA ! Closed EDC and PUH to 8,890 ft and motor torqued up, SD I and PUH and BHA free POOH FREE. PUH I 09:45 - 10:30 0J5 STWHIP N STUC WEXIT Tie-in at 8000 ft corrected -5 ft Flagged pipe at 7900 ft EOP (red) 10:30 - 12:00 1.50 STWHIP N STUC WEXIT POOH, Pulled tight coming out of hole at 5,400 ft(GLM # 5) . Could have something along side of us. Pulled a little tight at 1475 ft(?) Stopped at 200 ft, Held PJSM on plan forward and way to mitigated same. 12:00 - 13:00 1.00 STWHIP N STUC WEXIT PUH looking at 2" CT. no mark, Stand injector back and inspect BHA, no mark on top side, 2 marks on the bit box of the motor. Nothing in the BOP's or tree, close the MV with 18-1/2 turns. LD BHA 13:00 - 14:00 1.00 STWHIP N STUC WEXIT Held PJSM on RU and running Wireline to fish the what ever is in the hole 14:00 - 17:00 3.00 FISH N STUC WEXIT RIH with 2.73" wire grab and brush. RIH and found something just below GLM #2 and pushed down to 8889 ft Pull tight PU and POOH dragging 100 # extra wt OOH. Recovered 3 ft of cable. 17:00 - 19:00 2.00 FISH N STUC WEXIT RIH with wireline grab #2. Work down to 8885'. Jar up to get free. POOH dragging something. Recovered 3 additional feet of cable. 19:00 - 21:00 2.00 FISH N STUC W EXIT Redress fishing tools. Run in hole with wireline grab #3. Set down at 8918'. Could not work through. POOH. Recoverec! one strand oniy of armor wire. 21:00 - 21:30 0.50 FISH N STUC WEXIT Haliburton crew change. Hold PJSM and discuss plan forward. 21:30 - 23:30 2.00 FISH N STUC WEXIT MU and RIH with wireline grab #4 (smaller OD grab). Work to get past SBR at 8918'. Apparently tagging lip inside top of SBR, possibly the slick stick. POOH. Recovered a few strands of armor only. Printed: 6/11/2007 11:19:39 AM I . ~ ~ ~ ' Legal Well Name: 1 C-03 'iCommon Well Name: 1C-03 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Spud Date: 5/15/2007 Start: 5/15/2007 End: 6/9/2007 Rig Release: 6/9/2007 Rig Number: I5/24/2007 23:30 - 00:00 0.50 FISH N STUC W EXIT 5/25/2007 00:00 - 02:30 2.50 FISH N STUC W EXIT 02:30 - 04:30 2.00 FISH N STUC W EXIT 04:30 - 07:45 I 325 I FISH I N I STUC I W EXIT 07:45 - 10:45 I 3.001 FISH I N I STUC I W EXIT 10:45 - 12:00 1.25 FISH N STUC WEXIT 12:00 - 13:45 1.75 STWHIP N CEMT WEXIT 13:45 - 14:10 0.42 STWHIP N CEMT WEXIT 14:10 - 16:00 1.83 STWHIP N CEMT WEXIT 16:00 - 16:40 I 0.671 STWHIPI N ICEMT I WEXIT 16:40 - 17:15 0.58 STWHIP N CEMT WEXIT 17:15-21:00 3.75 STWHIP N CEMT WEXIT 21:00-22:45 1.75 STWHIP N CEMT WEXIT 22:45 - 23:15 0.50 STWHIP N WEXIT 23:15 - 00:00 0.75 STWHIP N WEXIT ~ 5/26/2007 ~ 00:00 - 01:00 G 1.00 I STW H I P ~ P I I W EXIT 01:00-01:15 0.25 STWHIP P WEXIT 01:15-03:00 1.75 STWHIP P WEXIT Add a centralizer and pinch in graber prongs. Run in hole with wireline graber #5. RIH with wireline grab #5. Try to work through SBR at 8919'. Unable to get past. POH. Shorten tool string again. RIH with wireline grab #6. Get a half foot deeper to 8920'. POH, heavy. Recovered a tight ball of wire. Estimate length at 22 feet. RIH with wireline grab #7. Tag btm at 8989' (should be top of cement). POH. NO recovery. PU and RIH with 2.6" LIB and tagged at 8989 ft. POOH LIB showed some evidence of wire enbedded in the cement? PU a 2.5" pump bailer. RIH with 2.5" pump bailer Recovered cement chunks and several piece of cable armorur Redress the pump bailer and rerun in the hole. Recovered very little. Held PJSM on RD W ireline RD Halliburton Wireline PU Pilot mill BHA 1.75 deg motor RIH with cement pilot BHA. Corrected to 7,900 ft EOP flag to 7,961 RIH pumping at min rate. Logging tie-in at 8,908.5 ft to confirm depth. Corrected -1 ft to 8,947.60 ft RIH Qp = 1.51 / 1.56 bpm RIH CTP 3,200 psi Flo-pro is still shearing. TF at 182.5 deg PU at 8986 ft= 20 k up and 6.8k down Tagged at 8,988.5 ft Worked up WOB to 2 to 3 k ROP averaged 17 fph with 2-3k W08 Nice to have re-bar in the cement PU at 8,998 R and it was clean, RIH and back to drilling PU and oriented TF to HS and drill from 8988 ft to 9,001 ft Qp = 1.51 / 1.50 bpm at 2970 psi off bottom Vp = 399 bbl flo-pro. TF at HS Sample. 30% cement and 70% metal, scale and some wire/cable material PUH and orien TF to LS at 8985 ft Dilling pilot hole 9,001.8 ft TF at 180 deg Qp = 1.51 / 1.52 bpm CTP 2,850 / 3,200 psi DHWOB = 2.50-3.50k ROP at 22 fph Sample: 95 % cement, samples cleaned up. Continue to mill pilot hole. TF: 180 deg. 2950 psi fs at 1.52 in/1.53 out. 250-350 dpsi. DHWOB: 1.5-2.0 k#. ROP: 20-25 fph. Adjust TF to highside. Mill ahead to 9105'. Had a TF shift from HS to 345L at 9104.5'. Allow drill off to 2k# WOB. Back ream up through pilot hole to tbg taii with HS TF. 2650 psi fs at 1.52 in/1.53 out. Backream at 1 FPM up past ramp. 2-3 fpm back to 8980'. 22-24k# up wt. Continue to backream pilot hole up to 8980'. Run in hole oriented LS. Orient through ramp to HS. Back ream ramp again at HS TF back to 9080'. Pull up hole. Open EDC. Log GR tie in from 8910'. Add 1 ft correction. Puli out of hole. Printed: 6/11/2007 11:19:39 AM ~ ~ ~ Legal Well Name: 1 C-03 Common Well Name: 1 C-03 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 ~ Spud Date: 5/15/2007 Start: 5/15/2007 End: 6/9/2007 Rig Release: 6/9/2007 Rig Number: 5/26/2007 03:00 - 04:45 04:45 - 07:10 07:10 - 07:40 07:40 - 07:54 1.75 2.42 0.50 0.23 STWHIP STWHIP STWHIP STWHIP P P P P WEXIT WEXIT WEXIT WEXIT Get off well. Unstab coil. LD motor and pilot mill. MU WFT 2.5 motor with HTC one step mill. Stab coil and test tools. Run in hole. Bouncing through few collar. Close EDC and circ at min rate to get through SSSV and GLMs. Stopped and tied in at 8,910 ft Stacking out at 8932 ft(SPR) worked by wit 180 TF. Logging Corrected -10 ft Orient TF to HS and RIH without pump Tagged at 9105.32 ft, painted flag, PUH and stated pumps C,~~.., 07:54 - 18:00 10.10 TWHIP P W XI Mi ling win ow starting at . to . o owing `~~T~ schedule as per programmed lGQ3R Qp = 1.50 bpk and PVT at 400 bbl's. At 9,103.84 started to see WOB. 18:00 - 19:20 1.33 STWHIP P WEXIT Continue to mill window from 9106.6'. DHWOB: 323k#. Allow to milloff to 2.75k#. Resume time milling sequence. Got alot of weight back at 9107'. Looks like window btm. Continue to time drill to 9107.3'. Window top: 9104'. Window btm: 9107'. 19:20 - 21:45 2.42 STW HIP P W EXIT Drill ahead by weight from 91072 3330 psi fs at 1.53 iNout. Very slow ROP in formation (?). Stacking up to 4.5k# DHWOB. Small amount of motor work. Catch a btms up sampie from 9110'. Found 5-10% formation in sample, including glauconite and siderite. PU 1' and set down up to 4.5k#. Several times. Unable to make any footage or drill off any DHWOB. Estimate btm at 9110', leaving 3' of rat hole. _ Pump a 15 bbl hivis sweep. 21:45 - 22:30 0.75 STWHIP P WEXIT Pull up hole to log GR tie in from 8910'. Open EDC. Log GR tie. Subtract 1' correction. 22:30 - 00:00 1.50 STWHIP P WEXIT Circulate out of hole. 5/27/2007 00:00 - 00:30 0.50 STWHIP P WEXIT At surface. Get off well. Unstab coil. LD window milling BHA. 2.74" go, 2.73" no go. Good wear pattern across mill face. No damage to gauage area. 00:30 - 01:15 0.75 STWHIP P WEXIT MU window dressing BHA. (1.75 deg Xtreme with HTC 2.74" diamond btunt tip crayola, 2.74 no go/2.75 go). Stab coil. Test tools. Get on well. 01:15 - 03:15 2.00 STWHIP N DFAL WEXIT Run in hole. Circ through EDC. 03:15 - 03:30 0.25 STWHIP N DFAL WEXIT Log gr tie in from 8910'. Subtract -13 ft correction. Close EDC. 03:30 - 05:30 2.00 STWHIP N DFAL WEXIT Run in hole with pumps off, oriented HS. Set dn at 9063' PU. Circ at min rate. RIH. Set down again at 9063'. PU and orient TF to 180 deg. Increase rate to 0.5 bpm, RIH at 25 fpm. Stop at 9097. Orient TF to HS. RIH dry. Tag at 9104'. Stall. PU and repeat. Mill ahead with HS TF at 0.1 fpm. 2853 psi fs at 1.53 in/out. Stali again at 9102.2'. PU. RIH to 9102.0' Time mill ahead at 0.1' fpm. Too fast. PU and time mill from 9101.9' at 0.01 fpm. Unable to make any progess. No motor work, then a hard stall no matter how slowly we time miil. 05:30 - 07:20 1.83 STWHIP P WEXIT PuII out of hole to change dressing mills. 07:20 - 08:30 1.17 STWHIP P WEXIT Change out crayola mill to the Weatherford style The BHI carloya mill is to agreesive on the face of the milll. The water cources are to deep and there is no transitation between the water cource base and the cutting structure face. Function Tested BOP's. PU 2.74" WFT Crayloa Mill. 08:30 - 10:05 1.58 STWHIP P WEXIT RIH with crayloa mill and 1.75deg motor 10:05 - 10:25 0.33 STWHIP P WEXIT Tied-in at 8908 ft and corrected -13 ft Close EDC ~ Printed: 6/11/2007 11:19:39 AM ~ ~ Legal Well Name: Common Welt Name: Event Name: Contractor Name: Rig Name: 5/27/2007 I 1025 - 14:00 14:00 - 18:00 1 C-03 1 C-03 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 3.581 STWHIPI P 4.001 STWHIPI P 18:00 - 20:00 2.00 STWHIP P 20:00 - 20:45 0.75 STW HIP P 20:45 - 22:30 1.75 STWHIP P 22:30 - 23:15 0.75 STWHIP N Spud Date: 5/15/2007 Start: 5/15/2007 End: 6/9/2007 Rig Release: 6/9/2007 Rig Number: W EXIT WEXIT W EXIT W EXIT W EXIT DFAL WEXIT 23:15 - 00:00 0.75 STWHIP N DFAL WEXIT 5/28/2007 ~ 00:00 - 01:00 1.00 STWHIP N DFAL WEXIT I 01:00 - 01:15 0.25 STWHIP N DFAL WEXIT ' 01:15-02:00 0.75 STWHIP N DFAL WEXIT 02:00-04:30 I 2.501STWHIPIN IDFAL IWEXIT 04:30-05:00 I 0.501STWHIPIN {DFAL IWEXIT With pump off, TF at HS, RIH through pilot and ram area Tagged at 9,106 ft Btm window PUH and started pumps at 9101.5 ft. RIFi from 9101.5 ft to Qp=1.60/1.60bpm CTP = 2933 psi RIH uvt at 8,000 Ibf RIH at 0.1 fpm Stall # 1 at 9,103.98 ft PUH and restarted at 9,103 ft. Time drill (2min/ft) from 9,103.10 ft and inc Qp to 1.6 bpm Lost 1 bbl to formation and trace of oii on pits. Milling / dressing window w( DHWOB sensor. Seeing pressure swings on slack off, mill is working. Stalled at 9,104.29 ft. Milling with 6001b WOB CTP = 3090 psi Dressing window with WFT 2.74" crayola mill Qp = 1.61 / 1.61 2933 / 3350 psi WOB 1.96k PUH 9105.4 ft to 9102 ft check parameters CTP = 3000 psi, PU and restarted motor, motor work stared at 9,104.82 ft, start of window. PU and restarted at 9,105.9 ft DHWOB ~ 2.7k an dPp at 3,650 psi Miiling requires DHWOB at 2.75k and 600 psi delta P on the motor. Unable to make any progress past 9106.4' Pull out of hole to check motor and crayola mill. Open EDC and circulate out. Hold PJSM in Ops cab near surface. Flow check well at 250' while closing the EDC. Get off welt. Unstab coil. Remove motor. Stand back MW D in derrick. MIII gauges 2.73 go, 2.74 no go. Wear pattern is even, some cement in water courses. Hold PJSM for drill line cut & slip. Cut and slip drill line. MU window dressing BHA. New W FT 2.74" diamond crayola (2.75 no go) on 2.0 deg Xtreme motor. Rotated wear pad 180 deg on motor. Stab coil. Test tools. Get on well. Open EDC. Run in hole. Circ at min rate. Continue to RIH with window dressing mill #3. Log gr tie in from 8910'. Subtract 12' correction. Close EDC. Run in hole to 9097 LS TF. Orient to HS TF. Dry tag window at 9107'. 8.5k# dn wt, 29k# up wt dry. Bring pumps on line. 2850 psi fs at 1.50 in/1.50 out. Motor work noted at 9106.17'. Drilled off back to fs quickly. Time mili ahead at 0.1' fpm. Increase rop to 02' fpm. Slight motor work, wob 0.5 to 12k#. Mill ahead to 9109'. Tag btm. Mill off into formation 0.1'. Drilling off into formation slow but steady. Back ream up 1st pass with HS TF. Stalled and stuck. RIH ok. Pick up dry through window: smooth. Dry drift down through window: smooth to btm at 9109'. Attempt HS up ream again at 1.54 bpm/2850 psi. All backreaming done at 5 min/ft. Back ream to 9101' (2' above TOW). RIH dry. Orient to 30L. Back ream to 9098'. RIH dry. Back ream at 30R to 9098'. RIH dry. Log gr tie in. Add 2' correction. TD is still 9110'. Open the Printed: 6/11/2007 11:19:39 AM .~ ~~ ~ ~ Legal Well Name: 1 C-03 Common Well Name: 1 C-03 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Spud Date: 5/15/2007 Start: 5/15/2007 End: 6/9/2007 Rig Release: 6/9/2007 Rig Number: 5/28/2007 04:30-05:00 0.50 STWHIP N DFAL WEXIT 05:00-06:30 1.50 STWHIP N DFAL WEXIT 06:30 - 08:30 I 2.001 DRILL I P 08:30 - 10:10 1.67 DRILL P 10:10 - 10:30 0.33 DRILL P 10:30 - 10:55 0.42 DRILL P 10:55 - 12:00 I 1.081 DRI~L I P 12:00 - 12:15 0.25 DRILL P 12:15 - 14:10 1.92 DRILL P 14:10 - 15:25 ~ 1.25 ~ DRILL ~ P 15:25 - 16:57 I 1.531 DRILL I P 16:57 - 19:00 I 2.051 DRILL I P 19:00 - 19:30 I 0.501 DRILL I P 19:30 - 20:00 I 0.501 DRILL I P PROD1 PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 EDC. Circulate out of hole. Held PJSM on handling BHA. Close EDC at 200 ft, check flow. (OK) Mill gauaged at 2.74" NoGo LD Miliing BHA. Mill gauaged at 2.74" NoGo. Checked MWD tool. Started pulling fluids out of pits for mud swap PU 2.0 deg new motor and Coiltrac with Resistivity Tool. RIH Tiein at 8,908 ft! 8,925 ft. Corrected -13 ft SD pump and closed EDC RIH wo/ pump and TF at HS. Tagged TD at 9108.5 ft. PU to 9106 ft, started pump Qp = 1.51 bpm RIH and find bottom at 9108 ft Drilling build section as per CTD Programme. TF at HS to 17R Qp = 1.50 bpm at 2830 psi Densiry = 8.73 / 8.65 ppg BHP = 3515 psi = 1073 ppg ROP = 20-30 fph Started mud swap after tagging bottom. Working bit in somewhat tight hole between 9,123 ft and 9,110 ft. Drilling build section as per CTD Programme. TF at 17R to 45R Qp = 1.50 bpm at 2830 / 3250 psi Density = 8.73 / 8.65 ppg BHP = 3641 psi = 11.01 ppg ROP = 20-40 fph At 9,161 ft, losing 0.17 bpm to the formation Drilling build section frpm 9,160 ft TF ~ 45R ti 90 R NBI = 67.60 deg Qp = 1.49 / 1.33 bpm @ 2,830 / 3,350 psi Density = 8.73 / 8.61 ppg BHP = 3,654 psi = 11.10 ppg DHWOB = 126k ROP = 20-40 fph At 9,161 ft, losing 0.1 to 0.15 bpm to the formation Vp = 388 bbl Catching 50 ft samples PUH to turn TF around and make wiper trip to base of the window Tie in GR marker at 9100 ft to 9,104 ft Place bit at 9,125 ft Corrected +2 ft correction. RIH. Town Geo changed the landing to 6,390 ft instead of 6,383 ft. Drilling build section frpm 9,234 ft TF ~ 90R Qp = 1.51/ 1.37 bpm ~ 2,830 / 3,550 psi Density = 8.73 / 8.61 ppg BHP = 3,654 psi = 11.10 ppg DHWOB = 1.26k ROP = 20-60 fph Vp = 367 bbls Drilling build section from 9363 ft. 3350 psi fs at 1.51 iN1.33 out. 200-400 dpsi. DHWOB: 1-2k#. WHP/BHP/ECD: 33/3703/11.16 ppg. IA/OA/PVT: 570/437/344 bbls. INC/AZM/TF: 95/291.5/75R. ROP: 50-70 fph. W iper trip to the window. Hole smooth. Printed: 6/11/2007 11:19:39 AM ~ ~ Legal Well Name: 1 C-03 Common Well Name: 1 C-03 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Start: 5/15/2007 Rig Release: 6/9/2007 Rig Number: Spud Date: 5/15/2007 End: 6/9/2007 5/28/2007 20:00 - 22:30 2.50 DRILL P 22:30 - 23:00 0.50 DRILL P 23:00 - 00:00 1.00 DRILL P 5/29/2007 00:00 - 04:00 4.00 DRILL P 04:00 - 04:30 I 0.50I DRILL I P 04:30 - 07:00 ~ 2.50 DRILL P 07:00 - 08:00 ~ 1.00 ~ DRILL ~ P 08:00 - 09:05 ~ 1.08 ~ DRILL ~ P 09:05 - 10:30 1.42 DRILL P 10:30 - 12:10 1.67 DRILL P 12:10 - 12:25 0.25 DRILL P 12:25 - 12:35 ~ 0.17 ~ DRILL ~ N ~ DPRB I PROD1 12:35 - 14:30 ~ 1.92 ~ DRILL ~ N 14:30 - 15:30 ~ 1.00 I DRILL ~ N 15:30 - 17:00 ~ 1.50 ~ DRILL ~ N ~ DPRB ~ PROD1 17:00 - 18:30 1.50 DRILL 1 N DPRB PROD1 18:30 - 19:00 0.50 DRILL ~ N DPRB PROD1 19:00 - 19:15 0.25 DRILL P PRODi Run in hole dry with HS TF. Set down at 9107'. PU and orient to 30L. Pump at 025 bpm. RIH. Set down same spot. PU. RIH dry ah 25 fpm. Set down. PU. RIH at 30 fpm w/ 0.35 bpm. Set dn same. Orient to 30R. RIH 25 fpm at 0.3 bpm. Through window smooth. 19:15 - 19:45 0.50 DRILL P PROD1 Run in hole to TD. 19:45 - 22:00 2.25 DRILL P PROD1 Drill from 9730' 1.52/1.42/3130/90R w/ 100-300 psi diff, 1-3k wob w/ 11.3 ECD at 92 deg at 60'/hr. Steady drilling in 80 api sand. Drill to 9880' 22:00 - 22:15 0.25 DRILL P PROD1 W iper to window 22:15 - 23:05 0.83 DRILL P PROD1 Log up from 9620' to collect missing MAD pass data 23:05 - 23:15 0.17 DRILL P PROD1 Continue wiper to window 23:15 - 23:50 0.58 DRILL P PROD1 Log up from 9284' to window to collect more missing MAD pass data 23:50 - 00:00 0.17 DRILL P PROD1 W iper from 9115' back to TD 5/30/2007 00:00 - 0025 0.42 DRILL P PROD1 Finish wiper back to TD o.,...oa~ anv9M~ 11~1O~30AM Dril{ build from 9383'. 3450 psi fs at 1.52 in(1.36 out. ROP: 50-70 fph. INC/AZM/TF: 93.8/358.5/65R. Continue directional turn to the right. TVD: 6374'. W iper trip to window. Hole smooth. Drill ahead from 9535'. Continue to drill buiid and tum from 9594'. 3450 psi fs at 1.51 in/1.36 out. DPSI: 200-400 DHWOB: 0.5 - 1.5k#. WHP/BHP(ECD: 40l3790/11.45 ppg. IA/OA/PVT: 593/450/294 bbls. INC/AZM/TF: 92.9/15.6/85R. ROP: 50-70 fph. TD of build/turn section. W iper to window. Open EDC. Circulate out of hole. Follow BHP pressure schedule to maintain constant BHP. ,Pressure undeploy BHA. SIWNP =750 psi. 20 min WHP = 180 psi. Clean out 2" bypass line that is full of cement in the choke manifold. Build lateral BHA with 0.8 deg bend and HCC BC bit PJSM on BHA handling. PT lubricator and the resultant wellhead pressure = 240 psi Pressure deploying W HP = 200 psi as per DPS down hole RIH with lateral BHA Log tie-in from 8925 ft Corrected -7 ft, closed EDC and trapped 200 psi RIH and tagged at 9,106 ft(bottom of window) PUH and turned TF to 10R tagged at 9,106. 10L tagged tagged at 9,106 ft. Tried rolling pump and still tagged at 9,106 ft. POOH to look at bit and motor bend. Following pressure schedule as per programme Held PJSM and Pressure undeployed BHA with 165 psi WHP after stabilization. Bit looked in good shape. Would not drift 2.70". (W e only have a 2.7 long gauge for bicenters. Estimate bit gauge was 2.73" to 2.75" ) Had traces cement around pilot cutter structure. MU Hycalog re-build (2.70" drift) on 1.0 deg xtrreme motor. Hold PJSM. Pressure deploy BHA. Run in hole foflowing pressure schedule. Log gr tie in from 8910'. Subtract 12.5' correction. Close EDC. PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 DPRBIPRODI DPRBIPRODI • ~ Legal Well Name: 1C-03 Common Well Name: 1 C-03 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Spud Date: 5/15/2007 Start: 5/15/2007 End: 6/9/2007 Rig Release: 6/9/2007 Rig Number: 6/4/2007 07:15 - 08:30 125 DRILL P PROD1 08:30 - 11:45 3.25 DRILL P PROD1 11:45 - 14:00 I 2251 DRILL I N I DFAL I PROD1 14:00 - 17:15 I 3.251 DRILL I N I DFAL ( PROD1 17:15 - 19:15 2.00 DRILL N DFAL PROD1 19:15 - 20:00 0.75 DRILL N DFAL PROD1 20:00 - 22:45 2.75 DRILL N DFAL PROD1 22:45 - 00:00 1.25 DRILL N DFAL PROD1 6/5/2007 00:00 - 00:25 0.42 DRILL N DFAL PROD1 00:25 - 01:00 0.58 DRILL N DFAL PROD1 01:00 - 01:10 0.17 DRILL N DFAL PROD1 01:10 - 01:50 0.67 DRILL N DFAL PROD1 01:50 - 04:15 2.42 DRILL N DFAL PROD1 04:15 - 04:30 025 DRILL N DFAL PROD1 04:30 - 05:10 0.67 DRILL N DFAL PROD1 05:10 - 06:15 1.08 DRILL N DFAL PROD1 06:15 - 08:15 2.00 DRILL N DFAL PROD1 08:15 - 10:00 1.75 DRILL N DFAL PROD1 10:00 - 11:30 1.50 DRILL N DFAL PROD1 11:30 - 13:00 1.50 DRILL N DFAL PROD1 13:00 - 14:45 1.75 DRIL~ N DFAL PROD1 14:45 - 15:00 0.25 DRILL N DFAL PROD1 15:00 - 15:20 0.33 DRILL N DFAL PROD1 running in. Tag window lightly to get about on depth. PU and tie in again. No correction. Tag window at 106.7'. Make about 13 runs at window with ali combinations of TF, dry, 025 bpm, vary running speed. Flnally got through at 20R, 0.55 bpm, 36 fpm. Bounced through. Continue to run to bottom. 4050 psi fs at 1.44 in. Unable to communicate with MWD tools. Able to see powercomms sub, but not able to communicate with rest of down hole tool string. Systematically work through system to locate fault. Determine it is most likely in tool string and not e-line or surface. Swap to new mud while circulating and trouble shooting tools. W tper trip to window. Pull out of hole. Hold 800 psi on well, pumping displacement only (no BHP data). PJSM in Ops cab to discuss pressure undeployment. At surface. Pressure undeploy with 850 psi on welihead. Crew change/safety mtg Finish undeploy. LD toolstring Change out complete MW D assy Safety mtg re: pressure deploy Begin pressure deployment and found pin connection on GR sub was starting to washout. LD tool string and change out GR sub. Resume pressure deployment w/ 170 psi. Inspect CTC and PT ~ 4000 psi RIH w/ BHA #15 circ thru bit 0.25/1630 while following pressure schedule. Test agitator at 400' Continue RIH w/ BHA #15 circ thru bit foliowing pressure schedule Found P&C and EDC were bad on the previous run. Also were missing one hatch bolt from the resistivity tool Log tie-in down from 8900', corr -11' RIH to window at 0.25/1600 Attempt 20R and all combinations that have worked in the past w/o success. Vary pump 0-0.5 bpm, 5-45'/min, 45L to 45R. Finally got thru at 21 R at 0.35 bpm 40'/min after +/-30 tries Wiper to TD 1.35/3250 had no set downs, but a few wt loss spots. Tagged at 11869' Drill from 11869' 1.55/1.16/3780/90R w/ 0.8k wob to 11876' and try to survey w/o success PUH 100' and take check shots at prior stations. Continue wiper up hole and take check shot to 11250'. Appear to be off by 4 deg azm. Need to replace tool W iper to window Open EDC. Circulate out of hole. 3090 psi fs at 1.68 bpm. At surface. Test agitator (good). Pressure undeploy BHA w/ 850 psi on wellhead. Trouble shoot mwd tools on catwalk. Make up and test complete tool string. Pressure deploy BHA. Well had 165 psi on it. Run in hole following pressure schedule. Test agitator near surface. Continue in hole. Log GR tie in. Subtract 13' tie in. RIH to window and set down. Try it dry w/o success. After Printed: 6/11/2007 11:19:39 AM • i Legal Well Name: 1 C-03 Common Well Name: 1 C-03 Spud Date: 5/15/2007 Event Name: REENTER+COMPLETE Start: 5/15/2007 End: 6/9/2007 Contractor Name: NORDIC CALISTA Rig Release: 6/9/2007 Rig Name: NORDIC 2 Rig Number: I~ 6/5/2007 15:00 - 15:20 0.33 DRILL N DFAL PROD1 +/-10 tries got thru w/ 0.35/20R/10'/min 15:20 - 17:30 2.17 DRILL N DFAL PROD1 Precautionary ream 1.47/3550/ 26'/min to TD 17:30 - 21:25 3.92 DRILL P PROD1 Drill from 11876' 1.5/1.43/3800/90R w/ 100-300 psi diff, 0.6-1.5k wob w/ 11.54 ECD at 88 deg 21:25 - 23:15 1.83 DRILL P PROD1 W iper to 9190'. Clean. 23:15 - 23:30 0.25 DRILL P PROD1 Log tie-in down from 9190', corr 6' 23:30 - 00:00 0.50 DRILL P PROD1 Wiper to TD. 6/6/2007 00:00 - 02:00 2.00 DRILL P PROD1 Continue to wiper to bottom. 02:00 - 05:10 3.17 DRILL P PROD1 Drill from 12028' 1.5/1.43/3950/90L w/ 100-300 psi diff, 0.6-1.5k wob w/ 11.87 ECD at 88 deg , 05:10 - 07:00 1.83 DRILL P PRODi Wiper to window was clean i 07:00 - 07:15 0.25 DRILL P PROD1 Log tie-in down from 9190', corr +3' ' ~ 07:15 - 09:50 2.58 DRILL P PROD1 Wiper to TD 1.52/4320 was clean except for having to slow , down due to max neg surface wt ; 9600'=6700# 26'/min I 11000'=1000# 26'/min I 11300'=-3000# 20'/min 11500'=-4000# 14'/min 11800'=-7000# 7'/min 09:50 - 12:00 2.17 DRILL P PROD1 Tag TD at 12178' at 3'/min w/ -8000# Resume drilling 1.54/1.42/4300/100L w/ 100-200 psi diff, 0.5-0.9k wob w/ 12.33 ECD at 89 deg. Drill to 12188' while wo mud 12:00 - 16:05 4.08 DRILL P PROD1 After new mud at bit, drill from 12188' 1.55/1.45/3600/120L w! 100-200 psi diff, 0.5-1.3k wob w! 11.5 ECD and hold 80-84 deg. ROP improved dramatically after BHA cleared 85 deg. Drill to 12325' 16:05 - 18:15 2.17 DRILL P PROD1 Wiper to window was clean 18:15 - 18:30 0.25 DRILL P PROD1 Log tie-in down from 9190', +3ft corr. 18:3~ - 21:40 3.17 DR1LL P PROD1 Wiper to TD 1.44/3673 - clean. Slow down due to neg surface I wt. ~ 11600'-2000# I 11800'-1500# 11900'-3000# 21:40 - 00:00 2.33 DRILL P PRODi Tag TD at 12326' at 3'/min w/ -5000# Resume drilling 1.54/1.48/3780/100L w/ 100-200 psi diff, 0.5-0.9k wob w/ 11.91 ECD at 89 deg. VP's=312bb1s. Turn centrifuges on. 6/7/2007 00:00 - 02:00 2.00 DRILL P PROD1 Continue drilling from 12376' 1.47/1.38/3780/100L w/ 100-200 psi diff, 0.5-0.9k wob w/ 11.87 ECD at 89 deg. V P's=349bb1s. 02:00 - 05:30 3.50 DRILL P PROD1 W iper to window for last tie in - clean. 05:30 - 05:45 0.25 DRILL P PROD1 Log for tie in from 9190' +4 ft corr. 05:45 - 09:05 3.33 DRILL P PROD1 Wiper to TD 1.41/3550 12000' -4500# 8'/min 12100' -7500# 3-4'/min 09:05 - 09:15 0.17 DRILL P PROD1 Tag at official TD of 12455'. PU clean at 26.4k, fin circ KW F to bit 09:15 - 11:20 2.08 DRILL P PRODi Wiper OOH 1.3/3000 displacing 8.6# FloPro w/ 9.5# FloPro C~ 30k w/ max lubes and 2-3 ppb Alpine beads in hole. Hole was super smooth w/ the beads. Paint EOP flag at 9000' 1120 - 13:10 1.83 DRILL P PROD1 POOH for liner circ 1.0/2000 thru bit 13:10 - 13:45 0.58 DRILL P PROD1 LD drilling BHA. Bit was 1-1-1 (microduiled) Printed: 6/11/2007 11:19:39 AM • ~ Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 6/7/2007 13:45 - 14:00 14:00 - 14:15 14:15 - 16:15 1 C-03 1 C-03 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 0.25 CASE P 0.25 CASE P 2.00 CASE P Spud Date: 5/15/2007 Start: 5/15/2007 End: 6/9/2007 Rig Release: 6/9/2007 Rig Number: RUNPRD RUNPRD RUNPRD 16:15 - 17:15 1.00 CASE P RUNPRD 17:15 - 19:15 2.00 CASE P RUNPRD 19:15 - 19:30 0.25 CASE P RUNPRD 19:30 - 20:00 0.50 CASE P RUNPRD 20:00 - 21:23 1.38 CASE P RUNPRD 21:23 - 21:41 0.30 CASE P RUNPRD 21:41 - 23:15 1.57 CASE P 23:15 - 23:25 0.17 CASE P 23:25 - 00:00 0.58 CASE P 00:00 - 00:30 0.50 CASE P 00:30 - 03:30 3.00 CASE P 03:30 - 04:00 0.50 CASE P 04:00 - 05:25 1.42 CASE P 05:25 - 06:45 1.33 CASE P 06:45 - 08:20 1.58 CASE N 08:20 - 09:00 0.67 CASE N 09:00 - 10:20 1.33 CASE N 10:20 - 10:45 0.42 BOPSU P 10:45 - 10:55 0.17 CASE P 10:55 - 11:10 025 CASE N 11:10 - 13:00 1.83 CASE N 13:00 - 14:10 1.17 CASE N 14:10 - 15:30 1.33 CASE N 15:30 - 17:00 1.50 CASE N 17:00 - 18:40 I 1.671 CASE I N RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD DPRB RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD DPRB RUNPRD DPRB RUNPRD RUNPRD RUNPRD RUNPRD RUNPRD RU to run liner Safety mtg re: run liner MU Unique Indexing Guide Shoe on one solid jt 2-3/8" STL. Add BTT O-ring sub. MU 45 jts 2-3/8" 4.44# L-80 STL liner. MU BTT Deployment Sub and GS assy. MU agitator and BHI MWD assy RIH w/ liner on CT circ thru GS 0.15/700 Log for tie in from - 9200ft (gamma ray depth) +3ft corr. Continue RIH w/ liner. Lose weight C~3 12450'. Set down ~ 12452' with 3k down. PU and try again, 32k up. Set down ~ 12453' with 3k down. Increase pump rate & try to agitate liner down. Shut down pumping & pick up, 30k up, 5.5k RIW. 12455ft is the bottom of the liner. Set wieght down & start pumping & release from liner 1.3/3700. Pick up, 16k up. Liner has been released. TOL is at 10993.5' in open hole POH. 10k over puil coming through window, stop & RIH. Setting down. Increase pump rate & POH. No problems. Continue POH. Paint flag Q 8000' EOP. Continue POH PJSM for setting injector back. Flow check well for 5 min. Stand back injector, stradle bung hole. Purge BHA w/ fresh water & air. Lay down BHA. PJSM prior to picking up lower liner section. Pick up & RIH with upper liner assembly. Pick up BOT BHA & stab onto liner. Stab coil onto BHA. Stab injector onto well. Set depth counters. Test tools. RIH with liner on end of coil Tag bottom of window ~ 9110' C~3 30ft/min. Pick up, 23.5k up wt. Set down again ~ 9110', with slower speed. Pick up & try agian & surge pump rate. Pick up & try again w/ higher pump rate. Try yo-yoing pipe, try yo-yoing pump. Pick up 100ft higher & try again. Try a few other things wo success POOH w/ liner circ thru GS 0.5/970 LD MWD assy, agitator, GS and deployment sub TOH standing back 2-3/8" liner in doubles The nose of the shoe had two gouges about 120 deg apart which probably indicates the lip at the bottom of the window. Ground them down Function test BOPE while discuss BHA Safety mtg re: rerun liner MU same aluminum crayola guide shoe + cementralizer + 1' 2-3/8" STL pup + 2.0 deg BS on one solid jt 2-3/8" STL TIH w/ 2-3/8" slotted liner doubles MU BTT splined GS on Deployment sub. Add orientor to MW D assy RIH w/ liner assy on CT circ thru GS 0.25/900 8900 22.4k RIH thru ramp area to setdown at 9113' CTD at 290 deg, PU 23.2k. Orient in 45 deg increments and try at 340, 20, 62, 110, 140, 280, 240, 195, 180 w/o success. Orient in 20 deg increments w/o succes. Pick a favorite number w/o success POOH w/ liner circ thru GS 0.5/970 Printed: 6/11/2007 11:19:39 AM • ~ Legal Well Name: 1 C-03 Common Well Name: 1 C-03 Spud Date: 5/15/2007 Event Name: REENTER+COMPLETE Start: 5/15/2007 End: 6/9/2007 Contractor Name: NORDIC CALISTA Rig Release: 6/9/2007 Rig Name: NORDIC 2 Rig Number: 6/8/2007 18:40 - 19:00 0.33 CASE N RUNPRD Flow check & PJSM prior to handling liner. LD MWD & BHA. 19:00 - 21:50 2.83 CASE N RUNPRD Stand back 2-3/8" liner in doubles. 3 connections were very loose - yikes!. All liner has been recovered. Torque test little jerk tongs - tested ok. 21:50 - 00:00 2.17 CASE N RUNPRD MU unique indexing shoe on end of liner. RIH with liner & clean/dope & torque each connection. 6/9/2007 00:00 - 00:30 0.50 CASE P RUNPRD PU MW D BHA & attach to liner. PU injector & stab onto liner & onto well. Set counters. 00:30 - 01:45 1.25 CASE P RUNPRD RIH with liner on end of coil. 01:45 - 02:37 0.87 CASE P RUNPRD Wt ck ~ 8900ft, 21 k up. 10k down. Went through the window with -5001b bobble. 02:37 - 04:30 1.88 CASE P RUNPRD Set down @ 10998ft. Come on line with pump & pick up. 16k up weight, liner has been released. POH. 04:30 - 05:20 0.83 CASE P RUNPRD PJSM prior to handling BHA. Break apart & LD MWD BHA. MU stingers & nozzle. 05:20 - 07:00 1.67 CASE P RUNPRD RIH w/ nozzle assy (12') to 8950'. Start SW down CT 0.5/900 07:00 - 09:00 2.00 CASE P RUNPRD POOH from 8950' displacing 9.5# mud w/ 8.55# SW to 2500' and diesel to surface following pressure schedule. SI swab w/ 1000 psi 09:00 - 10:00 1.00 CASE P RUNPRD LD nozzle assy. Blow back CT w/ air and recover 3.6 bbls SW. Set injector on legs. Blow down surface lines. Blow down line to tiger tank. IAP 50, OAP 80 10:00 - 11:15 1.25 RIGD P POST WO FMC BPV. WO dirty vac MT pits of 9.5# mud and send to storage site SWS inspect injector 11:15 - 12:15 1.00 RIGD P POST FMC show up w/ lubricator for setting BPV thru tree, not BOP's. Send them back to get the Gray lubricator Dirty vac arrive. Clean pits SWS service injector 12:15 - 12:30 0.25 RIGD P POST Safety mtg re: set BPV ~ 12:30 - 14:00 1.50 DHB P POST RU FMC Gray lubricator. PT 1000 psi . Set 3" BPV w/ 545 psi whp and test w/ well pressure. SI MV and SV w/ 18.5 turns. RD MO FMC 14:00 - 17:00 3.00 RIGD P POST Remove lub from Hydril. Inspect annular element and needs to be replaced. ND BOPE Finish clean pits. NU tree cap and PT at 4000 w/ diesel Release rig at 1700 hrs 6/9/07 Additional entries for this date will be found on 1 B-15AL3 Printed: 6/11/2007 11:19:39 AM ~J ~ ~ bP BP Alaska Baker Hughes INTEQ Survey Report ~ ~ir ~ LNTEQ c~,m~p: ~P ~„oCO n~~: s~~~noa~ ~~: t~:ao;zo r~~: ~ F+eld: Kuparuk Caordinate(NE) Aefereace: We~: 03, True Ntrrth Site: KRU iC Pad Vertieal (TYD) ReEcrencet Datum(9+4'} 94A Well: 03 Section (VS)12etereace: WeA (O.OUN,O,OQE,~C5?.70Ati) WeUpath. 1C-03A Survey Cakalat~an MetLud: Minimum Curvature : Db: Ordds 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 Model: bggm2006 Site: KRU 1 C Pad UNITED STATES : North Slope Site Posidon: Nort6ing: 5968605.00 ft Latitude: 70 19 29.107 N From: Map Easting: 562247.20 ft Longitude: 149 29 42.918 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.48 deg Well: 03 Slot Name: Well Position: +N/-S 51.04 ft Nort6ing: 5968655.42 ft Latitude: 70 19 29.609 N +E/-W -74.21 ft Easting : 562172.58 ft Longitude: 149 29 45.084 W Position Uncertainty: 0.00 ft Wellpath: 1 G03A Drilled From: 1 C-03 Titwn Depth: 9100.00 ft Current Datum: Datum(94') Heig6t 94.00 ft Above System Datam: Mean Sea Level Magnetic Data: 3/14/2007 Declination: 23.63 deg Field Strength: 57625 nT Mag Dip Angle: 80.86 deg Verticel SecNon: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 94.00 0.00 0.00 257.70 Survey Program for Definitive Wellpath Date: 3/14/2007 Validated: No Version: 1 Actual From To Survey Tookode Tool Name ft ft 0.00 9100.00 Gyro (0.00-9700.00) (0) G2-GYRO-MS Sperry-Sun G2 multishot 9130.60 12455.00 MWD (9130.60.12455.00) MWD MWD - Standard Anuotation NID TVD ft ft 9100.00 6420.72 TIP 12455.00 6524.25 TD Survey: MWD Start Date: 5/31/2007 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MVW - Standard Tied-to: From: Definitive Path Survey MD L-cl Atim TVD ; Sys TVD N/S E/ViT MapN 1-~xpE VS 1)IS Tuol ft deg ileg ft ft ft ' ft ft'' ' ft it degf10Uft 9100.00 49.50 250.00 6420.72 6326.72 -2405.44 -53~3.50 5966205.78 556819.70 5762.51 0.00 MWD 9130.60 59.62 259.66 6438.47 6344.47 -2411.81 -5397.52 5966199.20 556795.74 5787.33 41.84 MWD 9160.50 66.33 267.48 6452.07 6358.07 -2414.74 -5423.95 5966196.06 556769.34 5813.78 32.33 MWD 9190.22 71.65 275.67 6462.73 6368.73 -2413.94 -5451.64 5966196.63 556741.64 5840.67 31.33 MWD 9219.17 76.05 282.64 6470.79 6376.79 -2409.50 -5479.07 5966200.84 556714.19 5866.52 27.67 MWD 9251.39 80.00 291.55 6477.49 6383.49 -2400.23 -5509.15 5966209.86 556684.03 5893.93 29.69 MWD 9280.14 84.10 298.65 6481.47 6387.47 -2388.16 -5534.91 5966221.72 556658.18 5916.53 28.31 MWD 9310.10 88.99 305.98 6483.28 6389.28 -2372.18 -5560.16 5966237.48 556632.80 5937.79 29.37 MWD 9342.79 94.72 314.22 6482.39 6388.39 -2351.16 -5585.12 5966258.30 556607.66 5957.71 29.68 MWD 9376.33 96.89 323.48 6479,17 6385.17 -2326.05 -5607.07 5966283.22 556585.51 5973.81 28.69 MWD 9404.25 96.65 333.20 6475.87 6381.87 -2302.48 -5621.60 5966306.66 556570.78 5982.99 34.58 MWD 9433.48 94.76 339.94 6472.96 6378.96 -2275.81 -5633.16 5966333.23 556559.01 5988.60 23.84 MWD v~.0?-0~3 • • ~ bp BP Alaska Baker Hughes INTEQ Survey Report ~ar ~~ INTEQ Survey 9463.27 93.53 349.40 9492.69 94.15 358.24 9522.06 93.84 6.76 9551.84 94.48 15.95 9582.55 93.47 24.50 9611.98 93.84 34.30 9640.23 92.70 41.41 9669.96 90.83 51.10 9700.45 89.82 60.39 9730.44 91.63 69.30 9761.03 92.83 73.79 9790.50 92.00 77.38 9823.30 91,04 81.44 9850.84 90.74 85.31 9882.37 90.15 87.41 9910.35 89.66 84.22 9942.96 90.00 80.54 9970.22 89.08 75.51 9996.37 89.75 72.50 10020.39 89.11 69.19 10050.17 89.02 66.41 10080.38 88.10 71.03 10111.93 88.13 74.82 10143.34 87.64 78.39 10180.59 87.67 82.17 10212.92 88.03 85.31 10243.44 87.54 88.93 10270.22 87.97 91.33 10300.69 85.73 85.99 10331.26 87.14 82.67 10360.18 88.10 79.54 10390.47 89.26 76.39 10420.48 91.26 72.70 10452.76 89.97 68.85 10482.40 88.90 64.67 10513.92 90.00 60.72 10561.44 90.98 54.27 10592.24 92.12 51.73 10623.54 93.13 48.74 10654.48 92.55 44.96 10684.02 91.75 41.52 10731.00 91.29 35.86 10762.27 90.92 35.84 10789.61 90.95 39.14 10817.89 90.49 42.01 10847.12 90.31 44.17 10876.98 94.77 49.84 10910.54 91.84 55.25 10940.21 91.23 61.97 10973.64 89.20 65.86 11003.72 91.26 72.87 11042.57 89.54 79.32 11074.13 87.85 84.36 `TVD ft SysTVD NfS ft' ft •EIVV ft 6470.80 6376.80 -2247.19 -5641.00 6468.83 6374.83 -2218.04 -564d.16 6466.78 6372.78 -2188.79 -5642.88 6464.61 6370.61 -2159.70 -5637.04 6462.48 6368.48 -2130.99 -5626.46 6460.60 6366.60 -2105.43 -5612.06 6458.98 6364.98 -2083.18 -5594.76 6458.07 6364.07 -2062.65 -5573.32 6457.89 6363.89 -2045.51 -5548.15 6457.51 6363.51 -2032.78 -5521.03 6456.32 6362.32 -2023.10 -5492.05 6455.08 6361.08 -2015.78 -5463.54 6454.21 6360.21 -2009.75 -5431.31 6453.78 6359.78 -2006.58 -5403.97 6453.54 6359.54 -2004.57 -5372.50 6453.58 6359.58 -2002.53 -5344.60 6453.68 6359.68 -1998.21 -5312.28 6453.90 6359.90 -1992.55 -5285.63 6454.17 6360.17 -1985.35 -5260.49 6454.40 6360.40 -1977.47 -5237.81 6454.89 6360.89 -1966.22 -5210.24 6455.65 6361.65 -1955.26 -5182.11 6456.69 6362.69 -1946.01 -5151.97 6457.85 6363.85 -1938.74 -5121.44 6459.37 6365.37 -1932.45 -5084.76 6460.59 6366.59 -1928.93 -5052.65 6461.77 6367.77 -1927.40 -5022.20 6462.81 6368.81 -1927.46 -4995.44 6464.49 6370.49 -1926.75 -4965.04 6466.39 6372.39 -1923.73 -4934.68 6467.59 6373.59 -1919.27 -4906.14 6468.29 6374.29 -1912.95 -4876.53 6468.15 6374.15 -1904.96 -4847.67 6467.81 6373.81 -1894.33 -4817.14 6468.10 6374.10 -1882.64 -4789.91 6468.40 6374.40 -1868.18 -4761.91 6468.00 6374.00 -1842.66 -4721.86 6467.16 6373.16 -1824.14 -4697.27 6465.73 6371.73 -1804.14 -4673.24 6464.20 6370.20 -1783.01 -4650.70 6463.09 6369.09 -1761.51 -4630.48 6461.84 6367.84 -1724.87 -4601.13 6461.24 6367.24 -1699.52 -4582.82 6460.79 6366.79 -1677.84 -4566.19 6460.44 6366.44 -1656.36 -4547.80 6460.23 6366.23 -1635.02 -4527.83 6458.91 6364.91 -1614.69 -4506.03 6456.97 6362.97 -1594.32 -4479.44 6456.18 6362.18 -1578.88 -4454.14 6456.05 6362.05 -1564.19 -4424.12 6455.93 6361.93 -1553.59 -4395.99 6455.66 6361.66 -1544.26 ~358.30 6456.38 6362.38 -1539.79 -4327.08 5966361.79 556550.93 5966390.91 556547.53 5966420.16 556548.56 5966449.30 556554.16 5966478.10 556564.50 5966503.77 556578.69 5966526.17 556595.80 5966546.86 556617.07 5966564.21 556642.10 5966577.17 556669.10 5966587.08 556698.01 5966594.64 556726.45 5966600.93 556758.62 5966604.34 556785.94 5966606.60 556817.38 5966608.87 556845.26 5966613.46 556877.54 5966619.34 556904.15 5966626.75 556929.22 5966634.81 556957.84 5966646.29 556979.30 5966657.48 557007.34 5966666.99 557037.40 5966674.51 557067.87 5966681.09 557104.49 5966684.88 557136.56 5966686.67 557167.00 5966686.83 557193.76 5966687.79 557224.15 5966691.05 557254.48 5966695.76 557282.98 5966702.31 557312.53 5966710.55 557341.38 5966721.43 557371.76 5966733.34 557398.89 5966748.03 557426.77 5966773.88 557466.60 5966792.61 557491.03 5966812.80 557514.90 5966834.11 557537.26 5966855.78 557557.30 5966892.66 557586.33 5966918.15 557604.43 5966939.97 557620.89 5966961.60 557639.10 5966983.10 557658.88 5967003.61 557680.51 5967024.19 557706.93 5967039.84 557732.10 5967054.78 557761.99 5967065.61 557790.03 5967075.25 557827.64 5967079.99 557858.82 5990.17 31.94 MWD 5987.05 30.05 MWD 5979.57 28.96 MWD 5967.67 30.85 MWD 5951,21 27.97 MWD 5931.70 33.26 MWD 5910.06 25.45 MWD 5884.74 33.18 MWD 5856.49 30.65 MWD 5827.29 30.31 MWD 5796.91 15.18 MWD 576~.49 12.49 MWD 5734.72 12.71 MWD 5707.33 14.09 MWD 5676.16 6.92 MWD 5648.46 11.53 MWD 5615.97 11.33 MWD 5588.72 18.76 MWD 5562.63 11.79 MWD 5538.78 14.03 MWD 5509.45 9.34 MWD 5479.63 15.59 MWD 5448.21 12.01 MWD 5416.84 11,46 MWD 5379.66 10.14 MWD 5347.54 9.77 MWD 5317.46 11.96 MWD 5291.33 9.10 MWD 5261.47 18.98 MWD 5231.17 11.78 MWD 5202.33 11.31 MWD 5172.05 11.08 MWD 5142.09 13.99 MWD 5110.06 12.58 MWD 5080.96 14.56 MWD 5050.53 13.01 MWD 5005.96 13.73 MWD 4977.99 9.04 MWD 4950.25 10.07 MWD 4923.73 12.35 MWD 4899.39 11.95 MWD 4862.92 12.08 MWD 4839.63 1.18 MWD 4818.76 12.07 MWD 4796.22 10.28 MWD 4772.16 7.42 MWD 4746.53 24.14 MWD 4716.22 18.31 MWD 4688.21 22.73 MWD 4655.75 13.12 MWD 4626.01 24.29 MWD 4587.19 17.18 MWD 4555.74 16.84 MWD ! i bP BP Alaska ~~ ~ Baker Hughes INTEQ Survey Report iNTEQ co~p: ~ ~„o~o na~. stt~r~oo~ ~m~: ~a:3o:zo 'r~r: ~ Field: Kuparuk Cu-ardinate(NE) Refereaee: We~: 03, Troe Norfh Site: KRU '1 C Pad Vertical (TVD) Refere.~cet daturn(9+~~ 94A ' WeU: 0~ Section {VS) lie#erence: Wefl (O.OQN.O.O~E,25F.74Azi) WeUpath: 1G03A Survey Cnkulation Method: 'Minirnum Curvature Db: Or~de Survey MD Incl Azim T~D Sys TVD NIS E/W MapN 11~iapE VS D~S Toot ft deg deg ft ft ft ft ft` ft ft' deg/100ft ' 11107.10 89.72 85.95 6457.08 6363.08 -1537.00 -4294.24 5967083.04 557891.63 4523.05 7.44 MWD 11150.43 88.01 78.06 6457.94 6363.94 -1530.98 -4251.37 5967089.41 557934.44 4479.89 18.63 MWD 11188.60 89.45 70.81 6458.78 6364.78 -1520.75 -4214.64 5967099.95 557971.09 4441.82 19.36 MV1fD 11225.15 90.06 65.57 6458.94 6364.94 -1507.18 -4180.72 5967113.80 558004.89 4405.78 14.43 MWD 11268.32 88.06 58.06 6459.65 6365.65 -1486.80 -4142.70 5967134.49 558042.74 4364.30 18.00 MWD 11302.46 91.20 53.21 6459.87 6365.87 -1467.54 -4114.53 5967153.98 558070.74 4332.68 16.92 MWD 11332.84 88.83 44.89 6459.86 6365.86 -1447.65 -4091.61 5967174.06 558093.50 4306.04 28.47 MWD 11362.37 88.59 40.25 6460.53 6366.53 -1425.91 -4071.64 5967195.96 558113.28 4281.91 15.73 MWD 11392.25 89.78 35.82 6460.95 6366.95 -1402.39 -4053.24 5967219.63 558131.49 4258.91 15.35 MWD 11424.06 90.37 30.58 6460.91 6366.91 -1375.78 -4035.83 5967246.38 558148.68 4236.23 16.58 MWD 11457.10 89.94 23.87 6460.82 6366.82 -1346.42 -4020.72 5967275.87 558163.54 4215.22 20.35 MWD 11488.00 88.93 14.93 6461.13 6367.13 -1317.30 -4010.47 5967305.06 558173.55 4199.00 29.11 MWD 11519.80 89.14 16.12 6461.66 6367.66 -1286.67 ~001.96 5967335.76 558181.80 4184.16 3.80 MWD 11552.26 90.31 21.48 6461.82 6367.82 -1255.95 -3991.50 5967366.56 558192.00 4167.41 16.90 MWD 11582.96 89.54 24.85 6461.86 6367.86 -1227.73 -3979.42 5967394.88 558203.84 4149.60 71,26 MWD 11614.13 87.64 29.06 6462.62 6368.62 -1199.96 -3965.30 5967422.76 558217.73 4129.89 14.81 MWD 11647.00 91.69 39.74 6462.82 6368.82 -1172.89 -3946.76 5967449.99 558236.05 4106.01 34.74 MWD 11684.22 88.22 45.26 6462.85 6368.85 -1145.46 -3921.63 5967477.62 558260.95 4075.61 17.52 MWD 11733.23 87.18 52.31 6464.82 6370.82 -1113.22 -3884.82 5967510.17 558297.49 4032.78 14.53 MWD 11760.13 89.23 56.87 6465.66 6371.66 -1097.64 -3862.91 5967525.92 558319.26 4008.05 18.58 MWD 11793.07 89.26 61.40 6466.09 6372.09 -1080.75 -3834.65 5967543.04 558347.39 3976.84 13.75 MWD 11833.80 86.41 66.23 6467.63 6373.63 -1062.79 -3798.14 5967561.30 558383.74 3937.35 13.76 MWD 11865.58 87.08 73.07 6469.44 6375.44 -1051.77 -3768.41 5967572.57 558413.38 3905.95 21.59 MWD 11895.14 87.05 82.32 6470.96 6376.96 -1045.48 -3739.60 5967579.09 558442.13 3876.46 31.25 MWD 11927.75 87.02 89.91 6472.64 6378.64 -1043.28 -3707.13 5967581.57 558474.58 3844.27 23.24 MVVD 11956.90 86.50 96.07 6474.29 6380.29 -1044.80 -3678.08 5967580.29 558503.64 3816.21 21.17 MWD 11986.87 86.87 90.06 6476.03 6382.03 -1046.39 -3648.21 5967578.94 558533.51 3787.37 20.06 MWD 12~16.24 87.45 83.55 6477.49 6383.49 -1044.76 -3618.94 5967580.81 558562.76 3758.42 22.23 MWD 12045.09 87.61 77.25 6478.73 6384.73 -1039.96 -3590.54 5967585.85 558591.12 3729.64 21.82 MWD 12075.23 86.47 69.71 6480.29 6386.29 -1031.40 -3561.70 5967594.64 558619.89 3699.65 25.2~ MWD 12106.17 88.00 63.19 6481.78 6387.78 -1019.06 -3533.39 5967607.22 558648.09 3669.36 21.62 MWD 12132.14 88.86 57.66 6482.49 6388.49 -1006.25 -3510.82 5967620.21 558670.55 3644.58 21.54 MWD 12162.85 87.45 51.06 6483.48 6389.48 -988.38 -3485.89 5967638.29 558695.33 3616.41 21.96 MWD 12202.15 84.11 43.23 6486.38 6392.38 -961.75 -3457.18 5967665.15 558723.82 3582.69 21.61 MWD 12232.52 81.61 38.86 6490.16 6396.16 -939.03 -3437.40 5967688.03 558743.41 3558.52 16.48 MWD 12266.30 81.64 32.85 6495.08 6401.08 -911.96 -3417.83 5967715.26 558762.75 3533.64 17.60 MWD 12298.21 81.08 26.95 6499.88 6405.88 -884.62 -3402.11 5967742.73 558778.24 3512.46 18.36 MWD 12330.85 81.29 19.66 65Q4.89 6410.89 -855.02 -3389.36 5967772.43 558790.75 3493.70 22.08 MWD 12360.02 81.19 15.53 6509.33 6415.33 -827.55 -3380.65 5967799.97 558799.23 3479.33 14.00 MWD 12389.81 80.69 9.12 6514.03 6420.03 -798.82 -3374.37 5967828.75 558805.27 3467.08 21.31 MWD 12407.21 80,92 6.44 6516.81 6422.81 -781.81 -3372.04 5967845.78 558807.45 3461.19 15.26 MWD 12455.00 81.20 357.00 6524.25 6430.25 -734.67 -3370.63 5967892.92 558808.47 3449.77 19.52 MWD +Well Name: 1 C-03a API # 50-029-20535-01-00 PTD: 207-063 b p Conductor 16" 62#/ft H-40 Surface 10-3/4" 45.5 #/ft K-55 3214.0 ft 3-1/2" 9.2 #/ft L-80 BTBC Tubing ID 2.992'• - Calista ~ I 9210 ft ~ 10965 ft ~ ~ 11000 ft 12421 ft ~ ~ go.o ft , ~3-1/2" Camco TRDP-1 SSSV #6 Camco KBUG DGLV 1871.21 ft Locked out 2719.24 ft #5 Camco KBUG DGLV 5399.12 ft #4 Camco KBUG DGLV 6944.30 ft #3 Camco KBUG DGLV 7852.00 ft #2 Camco KBUG DGLV 8348.45 ft #1 Camco KBUG DGLV 8882.00 ft Baker EL-1 SBR PBR 8918.33 ft w/ 2.813" Profile Baker Model FHL Packer 8944.48 ft ID = 2.80" - TOL 2-3/8" Solid Liner @ 8977.62 ft 3-1/2" D Nipple (2.75" No-Go) 8982.77 ft Milled out to 2.8" BOT 3-1/2" Shear-out Sub 8990.0 ft TOC tagged 5-8-2007 8993.00 ft 8983 WLMD TOL 2-3/8" Slotted Liner @ 9210.45 ft Prepared by Dave Hildreth Orbis Engineering Inc Houston, Texas W~ore Diagram (6-9-071 ~ 1 C-03a '~' ~ ~ ConocoPh ~ I I ~ ps Alaska 7"26#/ft K-55 -~ ;;:: ~ Unique Guide Shoe (0.66" ID) @ 10998.50 ft ;r; ~;~ 2-3/8" 4.41# L-80 SLT Liner @ 12455.00 ft \jL L1L Lj4 L•1 :;: EOC @ 9543 ft i1•y ~tii1 ~4~{ ~{ fL Bottom of Cement 9384.00 ft 9675.0 ft ~ 7/3/2007 ~ ~ ~ ~iosioa STATE OF ALASKA OIL AND GAS CONSERVATION COMMISSIt)N BOPE Test Report Submit to: ~.. Contractor: Nordic ~_._ .. Rig No.: 2 DATE: 6/1/07 Rig Rep.: Ho{r~es Rig Phone. 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 C3p. Fa~c: 659-4356 Rep.: Goodrich l Seveik E-AAail ~_ __. v~:~ Wefl Name: 1C-03A PTD # Z07-063 Operation: Drlg: XXX Workover: Explor.: Test: Initial: Weekfy: Bi-Weskly XXX Test Pressure: Rams: 250-35Q0 Annular: 25E3-3500 Valves: 250-35Q0 MISC. INSPECTtONS: TEST DATA ~L~OR SAFETY VALVES: Test Result Test Resulf Quantity Test Result Location Gen.: P Well Sign P Upper Kel1y NA Housekeeping: P D~I. Rig P Lower Kelly NA PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BQP NA BOP STACK: Quantity SizelType Test Resutt MUQ SYSTEM: Visual Alarm Stripper 1 2 3/8" P Trip Tank P P Annular Preventer 1 7 1/16" P Pit ~evel Indicators P P #1 Rams 1 Blind / Shear P Flow lndicator P P #2 Rams 1 2"combi's P Meth Gas Detector P P #3 Rams 1 2 3/8"combi'~ F H2S Gas Detector P P #4 Rams 1 2"cambi's P #5 Rams N/A NA Quantity Test Result Choke Ln. Valves 1 3 118" P Inside Reel valves 1 P HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Vafve 2 2 1/16" P Time/Pressure Test Result System Pressure 2950 P CHOKE MANIFOLD: Pressure Afler Giosure 2100 P Quantity Test Result 200 psi Attained 25sec P No. Valves 14 P Full Pressure Attained 1 min/30sec P Manual Chokes 1 P Blind Switch Covers: All stations Y Hydraulic Chokes 1 F Nitgn. Bottles (avg): 4 21Q0 Test Resutts Number of Failures: Q Test Time: 5.5 Hours Gomponents tested 31 Repair or replacement of equipment will be made within 0 days. Notify the N orth Slope Ins ector 659-3607, follow with written confirmation to Superviser at: ;„_w. __ .. _ Remarks: The inside reel valve was tested aRer the coil cos-nector was instatted 8~ stripper were tested after the injector was picked up. The two "Check" 2 1/16" vafves are onfy used during 8~ on pressure de lo ment wells. Distribution: 24 HOUR NOTICE GIVEN orig-Well File YES )OCX NO c- Oper.IRig Waived By Chuck Scheve c- Database Date 5/31107 Time ?????? c- Trip Rpt File Witness Bilf Hobart c- Inspectar Tesf start Q1:30 Finish Q7:00 Coil Tubing BFL 11/09/04 Nordic 2 BOP 6-1-07p.xls Re: Contingency Lateral from 1G03A • • Gary, It is your call on submitting the permit early. Although you roughly know the depths, they will be approximate until you know the progress of the original program. I examined the regulations and spoke with Cathy and "oral approval" is in 25.015 regarding a change in operations. Paperwork must be submitted within 3 days and although a sundry is specified, since the new segment is authorized by a permit to drill that is submitted instead. Permits and sundries will be processed in my absence and I don't think there will be any issues to really bog an approval down. For your reference, after May 23 calls should go to Jim Regg at 793-1236 or ce11301-6470. Cathy will be available through the Commission main number at 279-1433. Call or message with any questions. Tom Maunder, PE AOGCC Eller, J Gary wrote, On 5/9/2007 11:11 AM: Tom - As per our conversation today, I wanted to get your input regarding the upcoming 1 C-03A CTD sidetrack at Kuparuk. That drilling permit is currently in your office for review, which calls for a TD of 12,525' MD. That TD is very aggressive, and there is a decent chance that we'll be unable to reach it. We have been discussing the contingency of drilling an additional lateral if we're unable to achieve TD of 12,525' MD in 1 C-03A. Our plan would be to install 2-3/8" slotted liner in 1 C-03A as deep as we're able to drill, then kickoff at ~11,000' MD to drill a 1C-03AL1 lateral mostly in the C3/2 sands to a TD of -12,000' MD. How do you recommend that we handle this contingency lateral from a permitting standpoint? In the past where we have been forced to drill unplanned laterals due to hole conditions, for example, we would submit a drilling permit concurrent with drilling that unplanned lateral. I believe that the regulations allow us to get oral approval to proceed with drilling the unplanned lateral but we're obliged to submit a drilling permit within 3 calendar days. But in light of you going on vacation around the time that this could occur in 1 C-Q3A, would you prefer that we submit a drilling permit now for this contingency? If we don't exercise the contingency we could cancel the permit. Your feedback is appreciated. .7. Gary Eller Wells Engineer ConocoPhilNips - Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1535 1 of 1 5/10/2007 8:14 AM i~c. i~,-w~,i. ~.c~iicu~ iv~ ~.cuicui c~aiit~ caii~ ~ Gary, This confirms our conversation of a few moments ago regarding the process forward on this well. Since the existing perforations in the well will be covered with cement the penetration is considered abandoned. A 403 will be needed for authorization of the cementing work. Further the new penetration will now be a sidetrack so a new 401 with check for 1 C-03A will need to be submitted. CPAI should request that the existing permit be canceled. You have indicated that you are working on the 403 and that it should be delivered to the AOGCC office today. You further indicated that the pumping of the cement via service coil is the only time critical task since actual drilling is not planned for about a week. I will look forward to receiving the sundry. I should be here until at least 1630. Call or message with a.ny questions. Tom Maunder, PE AOGCC Eller, J Gary wrote, On 5/3/2007 2:52 PM: Tom - As I explained over the phone, the whipstock that was planned for weti 1 C-03L1 (PTD 207-044) will not be ready in time for the spud of that well. Instead, as was identified as our contingency plan on the original PTD application, we'll place a cement plug from PBTD (-9160' MD) up to 9010' MD for purposes of a cement ramp exit. Our procedure calls for laying in 10 bbf of cement then washing back down to the tubing tail at ~9010' MD. We plan to perform this operation tomorrow. Please let me know if you have any questions, and thanks for your help. 3. Gary Eller Wells Engineer ConocoPhillips - Alaska work: 907-Z63-4172 celi: 507-529-1979 fax: 907-265-1535 I 1 of 1 5/3/2007 4:00 PM . - - ~- ~ ~ CO~TS~It~~.~01`T CO 5SIO1dT ' Gary Eller CT Drilling Engineer ConocoPhillips Alaska, Inc. PO Box 196612 Anchorage, AK 99519-6612 SAyBAfd P.QLIW, GOVERiVOR 333 W. 7th AVEFIUE, SUITE 100 ANCHORAGE,ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, Kuparuk River Oil Pool, 1 C-03A ConocoPhillips Alaska, Inc. Permit No: 207-063 Surface Location: 1583' FNL, 1165' FWL, SEC. 12, Tl 1N, R10E, UM Bottomhole Location: 2163' FNL, 2073' FEL, SEC. 11, T 11, R l 0E, i I'.VI Dear Mr. Eller: Enclosed is the approved application for permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing we?1 KRU 1C-03, Permit No 180- 138, API 50-029-20535-0'0. 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 authonize 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 ommission to witness any required test, contact the Commission's petroleum~ld ir~e¢tor at (907) 659-3607 (pager). DATED this ~ day of May, 2007 cc: Department of Fish 8v Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMI N PERMIT TO DRILL 20 AAC 25.005 K~l~~~ v ~:~.~. ~~~~~ MAY 0 ~ 2007 Alaska 0il & Gas Cons. Commission Anchorage 1 a. Type of work ^ Drill ~ Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service F ^ Multiple Zone ^ Stratigraphic Test ~ Development Oil ^ Single Zone 1 c. Specify if well is proposed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ~ Slanket ^ Single WeU Bond No. 59-52-180 - 11. Well Name and Number: Kuparuk 1C-03A 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: , MD 12525 ~ TVD 6390ss 12. Field / Pool(s): Kuparuk River Unit / Kuparuk 4a. Location of Well (Governmental Section): 1 83' FNL 1165' FWL SEC UM ~ 12 T11 N R10E 7. Property Designation: ADL 025649 ~ River Pool , , , . , , , T o p o f P r o d u c t i v e H o r i z o n: 3991' FNL, 4210' FEL, SEC. 11, T11N, R10E, UM' 8. Land Use Permit: 13. Approximate Spud Date: May 13, 2007 ~ Total Depth: 2163' FNL, 2073' FEL, SEC. 11, T11N, R10E, UM ~ 9. Acres in Property: 2560 14. Distance to Nearest Property: 14,650' . 4b. Location of Well (State Base Plane Coordinates): Surface: x-562173 ' y- 5968656 ' Zone-ASP4 10. KB Elevation m~ L,~? ,'~ _~ "`~ (Height above ~j: 94 feet 15. Distance to Nearest Well Within Pool: 850' ~ 16. Deviated Wells: Kickoff Depth: g~ 25 feet Maximum Hole An le: 95 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3413 ~ Surface: 3072 18. asin P ram: " S' cifications T- Settin De th - Bo ttom uanf of Cement e:f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD ND MD ND inctudin sta e data 3" 2-3/8" 4.6# L-80 STL 3555' 8970' 6243' 12525' 6390' ` Uncemented Slotted Liner 19. PRESE NT WEtL CONDITION SUMMARY (To be completed for Redrill and Re-e~try Operations) i Total Depth MD (ft): 9700 Total Depth ND (ft): gg2~ Plugs (measured): None Effective Depth MD (ft): 9589 Effective Depth ND (ft): 6747 Junk (measured): None Gasing Length Size CementVolume MD TVD Conductor / Structural 80' 16" 00 sx Permafro t 80' 80' Surtace 3214' 10-3/4" 1500 sx Fondu 250 sx AS 11 3214' 2682' Intermediate Produ ion 9675' 7" 725 sx Class' ' 675' 8 4' Liner Perforation Depth MD (ft): None Perforation Depth ND (ft): None 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 Gary Euer, 529-1979 Printed Name Gary Eller Title CT Drilling Engineer Prepared By Name/Number: Si nature . F Phone 529-1979 Date S~ G7 Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: ~~"~~~ API Number: 50-029-20535-01-00 Permit Approval See cover letter for Date: otherre uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas ates, or gas contained shales: ~' Samples Req'd: ^ Yes [~No Mud Log Req'd: ^ Yes [~'No HZS Measures: [~Y No ectional Survey Req'd: [~Yes ^ No Other: '~j~ ~, i ~ ~~.~~~- ~~/ D~ APPROVED BY THE COMMISSION Date ~ ~ , COMMISSIONER Form 10-401 Revised 12/2005 Sub~n DupliCete flRI~INAL ~ ~:,~.`~~ ~U 1C-03A Sidetrack - Coiled Tu~g Drilling Summarv of Operations: A coiled tubing drilling unit will drill a single 3300' sidetrack~in producer KRU 1C-03 using the managed pressure drilling technique. This horizontal sidetrack will target Kuparuk C3/4 sand reserves for increased pattern throughput and sweep efficiency. CTD Drill and Complete 1C-03A nrogram: Planned for Mav 2007 Pre-Rig Work l. Positive pressure and drawdown tests on MV and SV. 2. Test Packoffs - T& IC. 3. Slickline tag fill. 4. Slickline dummy off GLVs. 5. MTT-IA, MTT-OA. 6. Coil tubing lay in cement plug for a cement ramp exit from PBTD to 8980' . All existing perfs --j, will be plugged. (Note: Some old schematic diagrams incorrectly show the 1C-03 tubing tail to ~re-at-~23' MD. The correct depth of the tubing tail is 8983' MD.) Rig Work 1. MIRU Nordic Rig #2 using 2" coil tubing. NU 7-1/16" BOPE, test. 2. Drill pilot hole and cement ramp for window exit at 9125' MD. '~ a. The original well plan was to set a whipstock at 9125', leaving the original perfs open. That lateral would have been named `1C-03A'. The whipstock could not be delivered in time however, so a cement ramp exit is required which results in the CTD sidetrack being named `1C-03A'. 3. Mi112.74" window and 10' of open hole from 9125' MD. ' 4. Drill the 1C-03A sidetrack to the east with a 2.74" x 3" bi-center bit from the window at 9125' MD to TD of 12,525' 1VID targeting the Kuparuk C3/4 sand. 5. Complete the A sidetrack with a 23/8" slotted liner. The top of the 23/g" liner will be inside the 3t/z" tubing tail at 8970' MD. a. There is a contingency that the A sidetrack be completed with a 23/8" solid, cemented liner. In that event, we will install a liner-top packer and perforate the liner at select intervals. The ultimate completion particulars as installed will be communicated via the 10-407 completion notice. 6. ND BOPE. RDMO Nordic 2. Post-Rig Work 1. Post CTD rig - Run GLVs, obtain static BHP. Mud Program: • Will use chloride-based Biozan brine (8.6 ppg) for milling operations, and chloride-based Flo-Pro mud 1(8.6 ppg) for drilling operations. Will have to kill the well to deploy 23/8" slotted liner since the SCSSV has been locked out. Disposal: • No annular injection on this well. - • Class II liquids to KRU 1R 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. Page 1 of 3 May 4, 2007, FINAL ~U 1 C-03A Sidetrack - Coiled Tu~g Drilling Casing Program: • 23/8", 4.6#, L-80, STL slotted liner from 8970' MD to 12,525' MD Eausting Casing/Liner Information Surface: 103/a", K-55, 45.5# Burst 3580 psi; Collapse 2090 psi. Production: 7", K-55, 26# Burst 4980 psi; Collapse 4320 psi Well Control: ~ • Two well bore volumes (~220 bbl) of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. Maximum potential surface pressure is 3072 psi assuming a gas gradient to surface and maximum expected formation pressure (i.e. 3413 psi based on SBHP in 1D-14 in October 1999). • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plans for 1C-03A. j • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • The nearest well to 1C-03A is 1C-04 which will be offset by 850' at the TD of 12,525' MD. The KRU boundary is 14,650' away. - Logging , ~ • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Hazards • Significant lost circulation is expected to be a low/medium risk due to somewhat low BHP in the 1C-03 / wellbore (i.e. 8.3 ppg EMW in October 2006) and potentially high ECD. Expect to encounter slightly increasing pressure as the sidetrack is drilled away from the mother well. • A contingency window exit is available at 9112' MD in 1C-03. • Well 1C-03 has a HZS reading of 60 ppm as measured on 6/18/06. Wells 1G14 and 1C-21 are adjacent ~, to 1C-03. Well 1G21 has 80 ppm HzS as measured on 6/18/06, and well 1C-14 has no HzS (injection well). The maximum HzS level on the 1C pad is 170 ppm from well 1C-104 on 6/18/06. All HzS monitoring equipment will be operational. Reservoir Pressure • The most recent static BHP survey in well 1C-03 in October 2006 showed reservoir pressure of 2798 psi at 6460' TVD which corresponds to 8.3 ppg EM~V. Expect to encounter increasing pressure as / sidetrack is drilled away from mother well. Maximum expected pressure is 3413 psi which corresponds to an EMW of 10.2 ppg at 6429' TVD (A KOP). Maximum surface pressure with gas (0.1 psi/ft) to surface is 3072 psi. ~ Variance request • none Page 2 of 3 May 4, 2007, FINAL ~U 1 C-03A Sidetrack - Coiled Tu~g Drilling Managed Pressure Drilling Managed pressure drilling (MPD) 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 less expensive 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 BOPE choke manifold and the mud pits, and will be independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (i.e. 23/8" rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. The SCSSV in well 1C-03 has been locked out, so the well will have to be killed prior to running 23/8" slotted liner. 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 TD: • Estimated reservoir pressure: 2798 psi at 9160' MD (6460' TVD), or 83 ppg EMW. ' • Expected annular friction losses while circulating: 824 psi (assuming friction of 90 psi/1000 ft). • Planned mud density: 8.6 ppg equates to 2889 psi hydrostatic bottom hole pressure at 6460' TVD ° • While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 3713 psi or 11.1 ppg EMW without holding any additional surface pressure. • When circulation is stopped, it is anticipated that no additional surface pressure shall have to be applied because the mud weight should slightly overbalance reservoir pressure. Page 3 of 3 May 4, 2007, FINAL ~ • KRU 1 C-03 sssv ~is~~-ia~2. OD:3.500) c~ ~~n MandreWaNe 1 (271&2720, OD:5.313) Gas Lift MandreWatie 2 (5399-5400, OD:5.313) Gas Lift iandreVDummy VaNe 3 (6944-6945, OD:5.313) Gas Lifl IandreVDummy Valve 4 (7852-7653. OD:5.313) Gas Lift iandreVDummy Va~ve 5 (8348-8349, OD:5.313) Gas Lift IandreVDummy VaNe 6 (8881-8882, OD:5.313) SBR (8947-8948, OD:3.500) PKR (89746975, OD:6.156) TUBING (Q9013, OD:3.500, ID:2.992) NIP (9012-9013, OD 3.500) Perf (9101-9221) 1 C-03 API: 500292053500 Well T e: PROD An le TS: 49 d 9101 SSSV Type: LOCKED OUT Orig Com letion: 12/31/1980 Angle @ TD: 48 deg @ 9700 Annular Fluid: Last W/O: Rev Reason: TAG Reference Lo : Ref Log Date: Last Update: 10/28/2006 Last Ta : 9384' RKB TD: 9700 ftKB Last Tag Date: 10/19/2006 Max Hole An le: 56 deg @ 8400 Casin Strin - ALL STRINGS Descri tion Size To Bottom ND Wt Grade Thread CONDUCTOR 16.000 0 80 80 6.50 H-40 SURFACE 10.750 0 3214 2682 45.50 K-55 PRODUCTION 7.000 0 9675 6804 26.00 K-55 Tubin Strin - TUBING Size To Bottom ND Wt Grade Thread 3.500 0 9013 6365 9.20 K-55 BTC Perforations Summa Interval ND Zone Status Ft SPF Date T e Comment 9101 - 9221 6421 - 6500 -4,C-3,C- O en 120 8 2/31/198 Gas Lift MandrelsNalves St MD TVD Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2719 2374 Camco KBUG GLV 1.0 BK 0.156 1211 /14/200 2 5399 3978 Camco KBUG OV 1.0 BK 0.250 0 /13/200 3 6944 4968 Camco KBUG DMY 1.0 BK 0.000 0 /13/200 4 7852 5629 Camco KBUG DMY 1.0 BK 0.000 0 2/31/198 5 8348 5959 Camco KBUG DMY 1.0 BK 0.000 0 2/31/198 6 8881 6280 Camco KBUG DMY 1.0 BK 0.000 0 /26/199 Other lu s, e ui ., etc. - JEWELRY De th ND T e Descri tion ID 1871 1795 SSSV Camco'TRDP-1AE' Locked Out 2.813 8947 6322 SBR Baker EL-1 2.813 8974 6339 PKR Baker FHL 3.000 9012 6364 NIP Camco'D' Ni le NO GO 2.750 9013 6365 SOS Baker 2.992 9013 6365 TTL 2.992 General Notes Date Note /23/199 WAIVERED WELL: IA x OA ANNULAR COMMUNICATION KRU 1 C-03 C-sand Producer Proposed CTD Completion 1 C-03A (wp05) 10-3/4" ~ 45.5# K-55 @ 3214' C-sand perfs 9101'-9221' 3'/Z" Camco TRDP-1AE SSSV (locked out) at 1871' MD ID = 2.813", X-profile 3'/2' 92# K-55 IBT Tubing , ConocoPh i I I i s p Alaska, Inc. 3%Z' Camco KBUG GLM's @ 2719', 5399', 6944', 7852', 8348', and 8881' MD SBR at 8917' MD ID = 2.813", X-profile Baker FHL Packer @ 8943' MD 23/8" STL liner top w/ 'G" fishneck and seal bore @ 8970' MD D nipple (2.750" ID) at 8981' MD (milled out to 2.80", covered by 23/" slotted liner) 3'/Z" tubing tail @ 8983' MD Cement ramp exit ~-- Window at 9125' MD :~ ~~ ~ ~~ . ~~ ~ ~ ~ ~ ~ ~~ ~ ~ ~ ~~ ~ - ~ .~.~ .~ ~- ............. ~ ~ - ~ - 3" openhole i% 2'/e' slotted liner • • 1 C-03A TD @ 12,525' MD ~ 7 26# K-55 @ 9675' MD Updated 5/4/07, JGE ~ • bp BP Alaska B~s ~ Baker Hughes INTEQ Planning Report 1NTE Q Company: BPAmoco Date: 3/14/2007 Time: 14:11;29 Page: l Fietd: Kuparuk Co-ordinate(NE) Reference: Well: 03, True North Site: KRU 1 C Pad Vertical (TVD) Reference: Datum(94') 94A We1L• 03 Welipath: Plan 5, 1 C-03,J1~A S Section (VS) Reference: Well (O.OON,O.OOE;230.OOAzi) Snrvey Galculation Method: Minimum Curvature Db: OraGe Field: Kuparuk W~ ~~ p~-y,~y."CS t'f~C~ ~C~.~-~ ~1->.V-tiG.S Q`''~s.33C~`•5 `C.'~j~j ~~ Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordioate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2006 Site: KRU 1C Pad UNITED STATES : North Slope Site Position: Northing: 5968605 .00 ft Latitude: 70 19 29.107 N From: Map Easting: 562247 .20 ft Loogitude: 149 29 42.918 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.48 deg Well: 03 Slot Name: Well Position: +N/-S 51.04 ft Nort6ing: 5968655 .42 ft Latitude: 70 19 29.609 N +E/-W -74.21 ft Easting : 562172 .58 ft Longitude: 149 29 45.084 W Position Uncertainty: 0.00 ft Welipath: Plan 5, 1C-03L1 Drilled From: 1C-03 Tie-on Depth: 9100.00 ft Current Datum: Datum(94') Height 94 .00 ft Above System Datum: Mean Sea Level ° Magnetic Data: 3/14/2007 Declination: 23.63 deg Field Strengt6: 57625 nT Mag Dip Angle: 80.86 deg Vertical Section: Dept6 From (TVD) +N/-S +E/-W Direction ft ft ft deg 94.00 0.00 0.00 230.00 Plan: Plan #5 Date Composed: 3/14/2007 Copy Lamar's Plan 5 Version: 2 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <---- Latitude -> <-- Longitude ---> Name Description TVD ' +N/-S +E/-W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 1C-03L1 Polygon 94.00 -2483.20 -5369.87 5966128.05 556823.98 70 19 5.168 N 149 32 21.770 W -Polygon 1 94.00 -2483.20 -5369.87 5966128.05 556823.98 70 19 5.168 N 149 32 21.770 W -Polygon 2 94.00 -2570.96 -5641.64 5966038.05 556552.98 70 19 4.303 N 149 32 29.698 W -Polygon 3 94.00 -2411.45 -5821.34 5966196.05 556371.98 70 19 5.871 N 149 32 34.945 W -Polygon 4 94.00 -2095.82 -5772.72 5966512.05 556417.98 70 19 8.975 N 149 32 33.533 W -Polygon 5 94.00 -1849.85 -5522.65 5966760.05 556665.98 70 19 11.396 N 149 32 26.241 W -Polygon 6 94.00 -1823.36 -5099.37 5966790.05 557088.98 70 19 11.660 N 149 32 13.890 W -Polygon 7 94.00 -1412.93 -4419.88 5967206.05 557764.98 70 19 15.701 N 149 31 54.069 W -Polygon 8 94.00 -754.04 -3551.31 5967872.05 558627.98 70 19 22.185 N 149 31 28.730 W -Polygon 9 94.00 -527.02 -3309.40 5968101.05 558867.98 70 19 24.419 N 149 31 21.673 W -Polygon 10 94.00 -741.99 -3075.15 5967888.05 559103.98 70 19 22.306 N 149 31 14.834 W -Polygon 11 94.00 -1413.23 -3780.80 5967211.05 558403.98 70 19 15.701 N 149 31 35.418 W -Polygon 12 94.00 -1904.65 -4461.96 5966714.05 557726.98 70 19 10.864 N 149 31 55.288 W -Polygon 13 94.00 -2213.37 -5345.64 5966398.05 556845.98 70 19 7.822 N 149 32 21.068 W -Polygon 14 94.00 -2483.20 -5369.87 5966128.05 556823.98 70 19 5.168 N 149 32 21.770 W 1C-03L1 Fault 1 94.00 -1719.25 -5352.54 5966892.05 556834.98 70 19 12.682 N 149 32 21.280 W -Polygon 1 94.00 -1719.25 -5352.54 5966892.05 556834.98 70 19 12.682 N 149 32 21.280 W -Polygon 2 94.00 -1944.85 -5162.38 5966668.05 557026.98 70 19 10.464 N 149 32 15.726 W -Polygon 3 94.00 -2191.47 -4971.40 5966423.05 557219.98 70 19 8.040 N 149 32 10.148 W -Polygon 4 94.00 -1944.85 -5162.38 5966668.05 557026.98 70 19 10.464 N 149 32 15.726 W 1C-03L1 Target6 6433.00 -1249.53 -3985.46 5967373.04 558197.99 70 19 17.310 N 149 31 41.394 W 1C-03L1 Target3 6453.00 -1943.88 -5159.37 5966669.05 557029.98 70 19 10.474 N 149 32 15.638 W 1C-03L1 Target 5 6456.00 -1653.21 -4511.88 5966965.04 557674.98 70 19 13.337 N 149 31 56.749 W ~ ~ bp BP Alaska ~~~ ~ Baker Hughes INTEQ Planning Report iNTE Q Company: BP Amoco Date: 3/14/2007 Time: 14:11:29 Page; 2 Field: Kuparuk Co-ordinate(NE) Refereece: Well: 03, Tnie North Site: KRU 1C Pad Vertical (TVB) Reference; Datum(94') 94A We1L• 03 Section (VS) Reference: WeU (O.OON,O.OOE,230. OOAzi) Wellpath: Plan 5, 1C-03 L1 Sarvey Calculatiou Met6od: Minimum Curvature Dbc OraGe Targets Map Map <--- I.atitude --> <-- I.oogitude --> Name Descriptioa' TVD +N/-S +E/-W Nort6ing Easting Deg Min See Deg Min Sec Dip. Dir. ft ft ft ft ft 1C-03 L1 Target 2 6460.00 -2150.54 -5565.14 5966459.05 556625.98 70 19 8.439 N 149 32 27.475 W 1C-03 L1 Target 7 6464.00 -715.48 -3379.95 5967912.03 558798.99 70 19 22.565 N 149 31 23.730 W 1C-03 L1 Target 1 6469.00 -2384.24 -5605.08 5966225.06 556587.98 70 19 6.140 N 149 32 28.635 W 1C-03 L1 Target4 6470.00 -1837.55 -4835.45 5966778.05 557352.98 70 19 11.522 N 149 32 6.188 W 1C-03 L1 Target 8 6484.00 -604.83 -3215.01 5968024.03 558962.99 70 19 23.654 N 149 31 18.917 W Annotatioo MD TVD ft ft 9100.00 6420.72 TIP ~ 9125.00 6437.00 KOP 9145.00 6449.83 End of 9 Deg/100' DLS 9175.00 6465.99 4 9245.88 6479.55 5 9370.88 6469.21 6 9495.88 6462.48 End of 45 Deg/100' DLS 9645.88 6460.01 8 9865.88 6456.63 9 10085.88 6453.17 10 10260.88 6461.17 11 10435.88 6470.26 12 10635.88 6464.76 13 10810.88 6456.21 14 10960.88 6449.33 15 11285.88 6436.01 16 11485.88 6432.91 17 11635.88 6436.95 18 11960.88 6451.80 19 12310.88 6464.07 20 12525.00 0.00 TD y Plan Section Information MD Incl Aziro TVD +N/-S +E/-W DIS Build Turn TFO Target ft deg deg ft ft ft degl100ft deg/100ft degl700ft deg 9100.00 49.50 250.00 6420.72 -2405.44 -5373.50 0.00 0.00 0.00 0.00 9125.00 49.25 250.00 6437.00 -2411.93 -5391.33 1.00 -1.00 0.00 180.00 9145.00 50.94 250.79 6449.83 -2417.07 -5405.79 9.00 8.47 3.96 20.00 9175.00 63.75 255.90 6465.99 -2424.22 -5429.95 45.00 42.68 17.03 20.00 9245.88 94.00 266.34 6479.55 -2434.48 -5497.82 45.00 42.68 14.73 20.00 9370.88 94.71 322.76 6469.21 -2384.82 -5606.61 45.00 0.57 45.14 87.00 9495.88 90.96 18.97 6462.48 -2266.48 -5625.54 45.00 -3.00 44.97 92.00 9645.88 90.91 36.97 6460.01 -2134.56 -5555.48 12.00 -0.03 12.00 90.00 9865.88 90.82 63.38 6456.63 -1994.92 -5388.03 12.00 -0.04 12.00 90.00 10085.88 90.95 89.78 6453.17 -1944.31 -5175.96 12.00 0.06 12.00 89.50 10260.88 83.86 69.98 6461.17 -1913.85 -5004.81 12.00 -4.06 -11.31 250.00 10435.88 9024 49.94 6470.26 -1826.77 -4854.41 12.00 3.65 -11.45 287.00 10635.88 92.86 73.81 6464.76 -1733.18 -4679.40 12.00 1.31 11.93 83.50 10810.88 92.67 52.78 6456.21 -1655.07 -4524.13 12.00 -0.11 -12.01 270.00 10960.88 92.54 34.76 6449.33 -1547.32 -4420.89 12.00 -0.09 -12.01 270.00 11285.88 91.97 73.79 6436.01 -1361.39 -4162.32 12.00 -0.17 12.01 90.00 11485.88 89.77 49.89 6432.91 -1267.69 -3987.30 12.00 -1.10 -11.95 265.00 11635.88 87.17 32.07 6436.95 -1154.96 -3889.36 12.00 -1.74 -11.88 261.50 11960.88 87.80 71.10 6451.80 -957.15 -3639.85 12.00 0.19 12.01 90.00 12310.88 88.36 29.08 6464.07 -737.73 -3377.52 12.00 0.16 -12.01 270.00 12525.00 81.23 53.89 6483.78 -579.18 -3237.67 12.00 -3.33 11.58 107.00 ~ ~ bp BP Alaska ~~s ~ Baker Hughes INTEQ Planning Report 1NTE 2 Compaoy: BP Amoco Date: 3/14/2007 Time: 14:11;29 Page: 3 Field: Kuparuk Co-ordinatc(NE) Reference: We11: 03, True North Site: KR U 1 C Pad Vertical (TVD) Reference: Datum(94') 94A Well: 03 Section (VS) Reference: Well (O.OON,O.OOE,230.OOAzi) Wellpath: Plan 5, 1 C-03L1 Survey Calculation Method: Minimum Curvature Db: OraGe Survey MD Inci Azim SS TVD N/S F./W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 9100.00 49.50 250.00 6326.72 -2405.44 -5373.50 5966205.78 556819.70 0.00 5662.53 0.00 MWD 9118.87 49.31 250.00 6339.00 -2410.34 -5386.97 5966200.77 556806.28 1.00 5675.99 180.00 1 C-03L 9125.00 49.25 250.00 6343.00 -2411.93 -5391.33 5966199.14 556801.93 1.00 5680.36 180.00 MWD 9145.00 50.94 250.79 6355.83 -2417.07 -5405.79 5966193.88 556787.52 9.00 5694.74 20.00 MWD 9150.00 53.06 251.76 6358.91 -2418.34 -5409.52 5966192.58 556783.80 45.00 5698.41 20.00 MWD 9150.15 53.06 251.76 6359.00 -2418.38 -5409.64 5966192.54 556783.68 0.00 5698.52 0.00 1C-03L 9155.28 55.31 252.72 6362.00 -2419.65 -5413.60 5966191.24 556779.73 46.34 5702.38 19.41 1C-03L 9162.60 58.43 253.96 6366.00 -2421.40 -5419.47 5966189.44 556773.87 45.00 5708.00 18.85 1C-03L 9170.64 61.88 255.24 6370.00 -2423.25 -5426.19 5966187.53 556767.17 45.00 5714.34 18.16 1C-03L 9175.00 63.75 255.90 6371.99 -2424.22 -5429.95 5966186.53 556763.42 45.00 5717.84 17.53 MWD 9182.19 66.79 257.10 6375.00 -2425.74 -5436.30 5966184.96 556757.08 45.00 5723.68 20.00 1 C-03L 9184.79 67.90 257.53 6376.00 -2426.27 -5438.64 5966184.41 556754.75 45.00 5725.81 19.50 1 C-03L 9200.00 74.37 259.87 6380.92 -2429.08 -5452.74 5966181.48 556740.67 45.00 5738.43 19.33 MWD 9225.00 85.06 263.45 6385.37 -2432.63 -5477.04 5966177.73 556716.40 45.00 5759.32 18.57 MWD 9245.88 94.00 266.34 6385.55 -2434.48 -5497.82 5966175.71 556695.65 45.00 5776.43 17.93 MWD 9250.00 94.09 268.19 6385.26 -2434.68 -5501.92 5966175.47 556691.54 45.00 5779.70 87.00 MWD 9275.00 94.58 279.47 6383.36 -2433.02 -5526.75 5966176.93 556666.70 45.00 5797.65 87.13 MWD 9300.00 94.88 290.75 6381.29 -2426.54 -5550.77 5966183.21 556642.64 45.00 5811.88 87.99 MWD 9325.00 95.00 302.04 6379.13 -2415.48 -5573.04 5966194.08 556620.27 45.00 5821.84 88.92 MWD 9350.00 94.92 313.33 6376.96 -2400.28 -5592.72 5966209.12 556600.47 45.00 5827.14 89.89 MWD 9370.88 94.71 322.76 6375.21 -2384.82 -5606.61 5966224.46 556586.45 45.00 5827.85 90.87 MWD 9375.00 94.65 324.62 6374.87 -2381.51 -5609.04 5966227.75 556583.99 45.00 5827.58 92.00 MWD 9400.00 94.14 335.89 6372.95 -2359.91 -5621.39 5966249.25 556571.47 45.00 5823.15 92.15 MWD 9425.00 93.47 347.15 6371.29 -2336.29 -5629.28 5966272.80 556563.38 45.00 5814.02 93.02 MWD 9450.00 92.67 358.38 6369.94 -2311.56 -5632.42 5966297.50 556560.04 45.00 5800.53 93.77 MWD 9475.00 91.77 9.61 6368.97 -2286.68 -5630.68 5966322.39 556561.57 45.00 5783.20 94.37 MWD 9495.88 90.96 18.97 6368.48 -2266.48 -5625.54 5966342.63 556566.55 45.00 5766.27 94.81 MWD 9500.00 90.96 19.47 6368.41 -2262.59 -5624.18 5966346.54 556567.88 12.00 5762.73 90.00 MWD 9525.00 90.96 22.47 6367.99 -2239.25 -5615.24 5966369.95 556576.62 12.00 5740.88 90.01 MWD 9550.00 90.95 25.47 6367.57 -2216.41 -5605.08 5966392.87 556586.59 12.00 5718.42 90.06 MWD 9575.00 90.95 28.47 6367.16 -2194.13 -5593.75 5966415.23 556597.73 12.00 5695.42 90.11 MWD 9600.00 90.94 31.47 6366.75 -2172.48 -5581.27 5966436.99 556610.04 12.00 5671.94 90.16 MWD 9625.00 90.92 34.47 6366.34 -2151.51 -5567.67 5966458.07 556623.46 12.00 5648.04 90.21 MWD 9645.88 90.91 36.97 6366.01 -2134.56 -5555.48 5966475.11 556635.51 12.00 5627.81 90.26 MWD 9650.00 90.91 37.47 6365.94 -2131.28 -5552.99 5966478.41 556637.97 12.00 5623.79 90.00 MWD 9675.00 90.91 40.47 6365.55 -2111.85 -5537.27 5966497.97 556653.53 12.00 5599.26 90.01 MWD 9700.00 90.91 43.47 6365.15 -2093.26 -5520.55 5966516.69 556670.08 12.00 5574.51 90.Q6 MWD 9725.00 90.90 46.47 6364.76 -2075.58 -5502.89 5966534.52 556687.60 12.00 5549.62 90.10 MWD 9750.00 90.89 49.47 6364.37 -2058.85 -5484.33 5966551.41 556706.02 12.00 5524.64 90.15 MWD 9775.00 90.88 52.47 6363.98 -2043.11 -5464.91 5966567.31 556725.31 12.00 5499.65 90.20 MWD 9800.00 90.86 55.47 6363.60 -2028.40 -5444.70 5966582.17 556745.39 12.00 5474.71 90.24 MWD 9825.00 90.85 58.47 6363.23 -2014.78 -5423.74 5966595.97 556766.23 12.00 5449.90 90.29 MWD 9850.00 90.83 61.47 6362.86 -2002.27 -5402.10 5966608.65 556787.77 12.00 5425.29 90.33 MWD 9865.88 90.82 63.38 6362.63 -1994.92 -5388.03 5966616.12 556801.78 12.00 5409.78 90.38 MWD 9875.00 90.83 64.47 6362.50 -1990.91 -5379.84 5966620.20 556809.93 12.00 5400.93 89.50 MWD 9900.00 90.85 67.47 6362.13 -1980.73 -5357.01 5966630.56 556832.68 12.00 5376.90 89.52 MWD 9925.00 90.87 70.47 6361.76 -1971.77 -5333.68 5966639.72 556855.93 12.00 5353.26 89.56 MWD 9950.00 90.89 73.47 6361.37 -1964.03 -5309.91 5966647.66 556879.63 12.00 5330.08 89.60 MWD 9975.00 90.91 76.47 6360.98 -1957.55 -5285.77 5966654.34 556903.71 12.00 5307.43 89.65 MWD 10000.00 90.92 79.47 6360.58 -1952.34 -5261.33 5966659.75 556928.11 12.00 5285.35 89.70 MWD 10025.00 90.94 82.47 6360.18 -1948.42 -5236.65 5966663.87 556952.76 12.00 5263.92 89.75 MWD 10050.00 90.94 85.47 6359.77 -1945.79 -5211.79 5966666.70 556977.59 12.00 5243.19 89.79 MWD 10075.00 90.95 88.47 6359.35 -1944.47 -5186.83 5966668.23 557002.53 12.00 5223.23 89.84 MWD ~ i bp BP Alaska ~$ ~ Baker Hughes INTEQ Planning Report LNTE Q Company: BP Amoco Date: 3/14/2007 Time: 14:11:29 Page: 4 Fieid: Kuparuk ' Caordinate(NE) Reterence: Well: 03, True North Site: KRU 1 G Pad Vertical (TVD) Reference: Datum(94'} 94A WeII: 03 Sectioo (VS) Refereoce: Weil (O.OON,O.OOE,230.OOAzi) Weilpat6: Plan 5, 1 C-03L1 Survey Calculation Met6od: Minimum Curvature Db: Oracle Survey MD Incl Azim SS TVD N/S E/W MapN MapE DI.S VS ' TFO Tool ft deg deg ft ft ft ft ft degHOOft ft deg 10085.88 90.95 89.78 6359.17 -1944.31 -5175.96 5966668.48 557013.41 12.00 5214.79 89.89 MWD 10100.00 90.37 88.19 6359.01 -1944.06 -5161.84 5966668.85 557027.52 12.00 5203.81 250.00 MWD 10125.00 89.35 85.37 6359.07 -1942.65 -5136.88 5966670.46 557052.46 12.00 5183.79 249.98 MWD 10150.00 88.32 82.55 6359.58 -1940.02 -5112.03 5966673.30 55707729 12.00 5163.06 249.99 MWD 10175.00 87.30 79.72 6360.53 -1936.17 -5087.35 5966677.35 557101.94 12.00 5141.68 250.05 MWD 10200.00 86.29 76.90 6361.93 -1931.12 -5062.91 5966682.61 557126.33 12.00 5119.71 250.15 MWD 10225.00 85.28 74.06 6363.77 -1924.87 -5038.77 5966689.06 557150.41 12.00 5097.20 250.31 MWD 10250.00 84.29 71.22 6366.04 -1917.44 -5015.01 5966696.68 557174.10 12.00 5074.23 250.52 MWD 10260.88 83.86 69.98 6367.17 -1913.85 -5004.81 5966700.36 557184.28 12.00 5064.10 250.78 MWD 10275.00 84.35 68.35 6368.62 -1908.85 -4991.68 5966705.46 557197.36 12.00 5050.83 287.00 MVVD 10300.00 85.25 65.48 6370.88 -1899.09 -4968.78 5966715.41 557220.18 12.00 5027.02 287.17 MWD 10325.00 86.15 62.61 6372.76 -1888.18 -4946.37 5966726.51 557242.50 12.00 5002.83 287.43 MWD 10350.00 87.06 59.75 6374.24 -1876.15 -4924.50 5966738.72 557264.26 12.00 4978.35 287.64 MWD 10375.00 87.99 56.89 6375.32 -1863.03 -4903.25 5966752.01 557285.40 12.00 4953.64 287.81 MWD 10400.00 88.91 54.03 6376.00 -1848.86 -4882.67 5966766.35 557305.86 12.00 4928.77 287.94 MWD 10425.00 89.84 51.18 6376.27 -1833.68 -4862.81 5966781.69 557325.59 12.00 4903.80 288.01 MWD 10435.88 90.24 49.94 6376.26 -1826.77 -4854.41 5966788.67 557333.93 12.00 4892.92 288.04 MWD 10450.00 90.44 51.62 6376.18 -1817.84 -4843.47 5966797.69 557344.80 12.00 4878.80 83.50 MWD 10475.00 90.77 54.60 6375.91 -1802.84 -4823.48 5966812.85 557364.66 12.00 4853.84 83.51 MWD 10500.00 91.11 57.58 6375.50 -1788.90 -4802.73 5966826.97 557385.29 12.00 4828.99 83.54 MWD 10525.00 91.44 60.57 6374.94 -1776.05 -4781.30 5966839.99 557406.62 12.00 4804.31 83.59 MWD 10550.00 91.77 63.55 6374.24 -1764.35 -4759.22 5966851.88 557428.59 12.00 4779.88 83.66 MWD 10575.00 92.10 66.53 6373.40 -1753.80 -4736.57 5966862.60 557451.15 12.00 4755.75 83.74 MWD 10600.00 92.42 69.52 6372.41 -1744.46 -4713.41 5966872.14 557474.24 12.00 4732.00 83.84 MWD 10625.00 92.73 72.51 6371.29 -1736.33 -4689.80 5966880.46 557497.78 12.00 4708.69 83.96 MWD 10635.88 92.86 73.81 6370.76 -1733.18 -4679.40 5966883.69 557508.15 12.00 4698.70 84.09 MWD 10650.00 92.86 72.11 6370.05 -1729.05 -4665.91 5966887.94 557521.60 12.00 4685.71 270.00 MWD 10675.00 92.85 69.11 6368.81 -1720.76 -4642.36 5966896.42 557545.08 12.00 4662.34 269.92 MWD 10700.00 92.84 66.10 6367.57 -1711.25 -4619.28 5966906.12 557568.08 12.00 4638.54 269.77 MWD 10725.00 92.81 63.10 6366.33 -1700.54 -4596.73 5966917.02 557590.54 12.00 4614.38 269.62 MWD 10750.00 92.78 60.10 6365.11 -1688.66 -4574.76 5966929.08 557612.40 12.00 4589.93 269.47 MWD 10775.00 92.74 57.09 6363.91 -1675.65 -4553.45 5966942.26 557633.60 12.00 4565.24 269.32 MWD 10800.00 92.70 54.09 6362.72 -1661.54 -4532.85 5966956.54 557654.08 12.00 4540.39 269.18 MWD 10810.88 92.67 52.78 6362.21 -1655.07 -4524.13 5966963.08 557662.75 12.00 4529.54 269.03 MWD 10825.00 92.67 51.09 6361.55 -1646.37 -4513.02 5966971.87 557673.78 12.00 4515.44 270.00 MWD 10850.00 92.66 48.08 6360.39 -1630.18 -4494.01 5966988.22 557692.66 12.00 4490.47 269.92 MWD 10875.00 92.65 45.08 6359.23 -1613.02 -4475.87 5967005.53 557710.65 12.00 4465.55 269.78 MWD 10900.00 92.63 42.08 6358.08 -1594.93 -4458.66 5967023.76 557727.71 12.00 4440.73 269.64 MWD 10925.00 92.60 39.07 6356.94 -1575.97 -4442.42 5967042.86 557743.80 12.00 4416.10 269.50 MWD 10950.00 92.56 36.07 6355.82 -1556.17 -4427.19 5967062.77 557758.86 12.00 4391.71 269.37 MWD 10960.88 92.54 34.76 6355.33 -1547.32 -4420.89 5967071.68 557765.08 12.00 4381.20 269.23 MWD 10975.00 92.54 36.46 6354.71 -1535.85 -4412.68 5967083.22 557773.20 12.00 4367.53 90.00 MWD 11000.00 92.53 39.46 6353.60 -1516.16 -4397.32 5967103.03 557788.40 12.00 4343.11 90.08 MWD 11025.00 92.52 42.47 6352.50 -1497.30 -4380.94 5967122.02 557804.61 12.00 4318.44 90.21 MWD 11050.00 92.50 45.47 6351.40 -1479.33 -4363.61 5967140.13 557821.80 12.00 4293.61 90.34 MWD 11075.00 92.47 48.47 6350.32 -1462.29 -4345.35 5967157.33 557839.91 12.00 4268.67 90.47 MWD 11100.00 92.43 51.47 6349.25 -1446.22 -4326.23 5967173.54 557858.90 72.00 4243.70 90.60 MWD 11125.00 92.39 54.48 634820 -1431.18 -4306.29 5967188.75 557878.71 12.00 4218.76 90.73 MWD 11150.00 92.34 57.48 6347.16 -1417.21 -4285.59 5967202.89 557899.29 12.00 4193.92 90.86 MWD 11175.00 92.29 60.48 6346.15 -1404.34 -4264.18 5967215.94 557920.59 12.00 4169.24 90.98 MWD 11200.00 92.23 63.48 6345.17 -1392.61 -4242.13 5967227.85 557942.54 12.00 4144.81 91.10 MWD 11225.00 92.16 66.48 6344.21 -1382.04 -4219.50 5967238.60 557965.08 12.00 4120.68 91.22 MWD ~ ~ r..r ~ bp BP Alaska ~s Baker Hughes INTEQ Planning Report 1NTEQ Company: BP Amoco Date: 3/14@007 Time: 14:11:29 Page: 5 Field: Kuparuk Co-ord inate(NE) Reference: Well: 03, True North Site: KR U 1C Pad Vertical (TVD) Reterence: Datum(94') 94A WeiL• 03 Sectioo (VS) Reference: Well (O.OON,O,OOE,230.OOAzi) Wellpath: Pla n 5, 1C-03L1 Snrvey Calculation Method: Minimum Curvature Db: OraGe Survey MD Inci Azim SS TVD N/S E/VY MapN MapE ' DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100R ft deg 11250.00 92.09 69.49 6343.28 -1372.68 -4196.34 5967248.16 557988.16 12.00 4096.92 91.34 MWD 11275.00 92.01 72.49 6342.39 -1364.54 -4172.72 5967256.49 558011.71 12.00 4073.60 91.45 MWD 11285.88 91.97 73.79 6342.01 -1361.39 -4162.32 5967259.73 558022.08 12.00 4063.60 91.55 MWD 11300.00 91.83 72.10 6341.54 -1357.25 -4148.82 5967263.98 558035.54 12.00 4050.60 265.00 MWD 11325.00 91.56 69.11 6340.80 -1348.95 -4125.25 59&7272.47 558059.04 12.00 4027.22 264.94 MWD 11350.00 91.29 66.12 6340.18 -1339.44 -4102.15 5967282.17 558082.06 12.00 4003.40 264.86 MWD 11375.00 91.01 63.14 6339.68 -1328.73 -4079.57 5967293.07 558104.55 12.00 3979.22 264.78 MWD 11400.00 90.74 60.15 6339.30 -1316.86 -4057.57 5967305.12 558126.45 12.00 3954.74 264.72 MWD 11425.00 90.46 57.16 6339.04 -1303.85 -4036.22 5967318.30 558147.68 12.00 3930.03 264.68 MWD 11450.00 90.18 54.18 6338.90 -1289.76 -4015.58 5967332.56 558168.21 12.00 3905.15 264.64 MWD 11475.00 89.90 51.19 6338.88 -1274.60 3995.70 5967347.88 558187.96 12.00 3880.18 264.63 MWD 11485.88 89.77 49.89 6338.91 -1267.69 -3987.30 5967354.86 558196.30 12.00 3869.31 264.63 MWD 11500.00 89.52 48.21 6339.00 -1258.43 -3976.64 5967364.21 558206.88 12.00 3855.19 261.50 MWD 11525.00 89.08 45.25 6339.30 -1241.30 -3958.44 5967381.49 558224.94 12.00 3830.23 261.51 MWD 11550.00 88.64 42.28 6339.80 -1223.25 -3941.15 5967399.68 558242.07 12.00 3805.39 261.55 MWD 11575.00 88.21 39.31 6340.49 -1204.33 -3924.83 5967418.73 558258.24 12.00 3780.72 261.61 MWD 11600.00 87.77 36.34 6341.36 -1184.60 -3909.51 5967438.59 558273.39 12.00 3756.30 261.69 MWD 11625.00 87.35 33.36 6342.43 -1164.10 -3895.24 5967459.20 558287.49 12.00 3732.20 261.79 MWD 11635.88 87.17 32.07 6342.95 -1154.96 -3889.36 5967468.39 558293.29 12.00 3721.82 267.92 MWD 11650.00 87.17 33.77 6343.65 -1143.12 -3881.70 5967480.29 558300.86 12.00 3708.34 90.00 MWD 11675.00 87.18 36.77 6344.88 -1122.74 -3867.28 5967500.79 558315.10 12.00 3684.19 89.92 MWD 11700.00 87.19 39.77 6346.11 -1103.14 -3851.82 5967520.51 558330.40 12.00 3659.75 89.77 MWD 11725.00 87.22 42.78 6347.33 -1084.37 -3835.35 5967539.41 558346.71 12.00 3635.07 89.62 MWD 11750.00 87.25 45.78 6348.54 -1066.50 -3817.92 5967557.43 558364.00 12.00 3610.23 89.47 MWD 11775.00 87.29 48.78 6349.73 -1049.56 -3799.57 5967574.52 558382.20 12.00 3585.28 89.33 MWD 11800.00 87.33 51.79 6350.90 -1033.61 -3780.36 5967590.63 558401.27 12.00 3560.32 89.19 MWD 11825.00 87.39 54.79 6352.05 -1018.68 -3760.35 5967605.72 558421.16 12.00 3535.39 89.04 MWD 11850.00 87.45 57.79 6353.18 -1004.82 -3739.57 5967619.75 558441.82 12.00 3510.56 88.91 MWD 11875.00 87.52 60.79 6354.28 -992.07 3718.10 5967632.68 558463.18 12.00 3485.92 88.77 MWD 11900.00 87.59 63.80 6355.35 -980.46 -3695.99 5967644.47 558485.19 12.00 3461.52 88.64 MWD 11925.00 87.67 66.80 6356.38 -970.02 -3673.30 5967655.10 558507.79 12.00 3437.43 88.51 MWD 11950.00 87.76 69.80 6357.38 -960.78 -3650.09 5967664.52 558530.92 12.00 3413.71 88.39 MWD 11960.88 87.80 71.10 6357.80 -957.15 -3639.85 5967668.24 558541.13 12.00 3403.53 88.27 MWD 11975.00 87.80 69.41 6358.34 -952.38 -3626.57 5967673.12 558554.37 12.00 3390.29 270.00 MWD 12000.00 87.81 66.41 6359.30 -942.98 -3603.42 5967682.71 558577.44 12.00 3366.52 270.07 MWD 12025.00 87.82 63.40 6360.26 -932.39 -3580.80 5967693.49 558599.97 12.00 3342.38 270.18 MWD 12050.00 87.84 60.40 6361.20 -920.63 3558.77 5967705.43 558621.90 12.00 3317.94 270.29 MWD 12075.00 87.86 57.40 6362.14 -907.72 -3537.38 5967718.51 558643.18 12.00 3293.26 270.41 MWD 12100.00 87.89 54.40 6363.07 -893.72 -3516.69 5967732.68 558663.75 12.00 3268.41 270.52 MWD 12125.00 87.93 51.40 6363.98 -878.65 -3496.77 5967747.91 558683.54 12.00 3243.47 270.63 MWD 12150.00 87.97 48.40 6364.88 -862.56 -3477.66 5967764.16 558702.52 12.00 3218.48 270.74 MWD 12175.00 88.02 45.39 6365.75 -845.49 -3459.42 5967781.38 558720.61 12.00 3183.54 270.85 MWD 12200.00 88.07 42.39 6366.61 -827.48 -3442.10 5967799.53 558737.78 12.00 3168.70 270.95 MWD 12225.00 88.13 39.39 6367.44 -808.60 -3425.75 5967818.55 558753.98 12.00 3144.03 271.06 MWD 12250.00 88.19 36.39 6368.24 -788.88 -3410.40 5967838.39 558769.16 12.00 3119.60 271.16 MWD 12275.00 88.26 33.39 6369.01 -768.39 -3396.11 5967859.00 558783.28 12.00 3095.48 271.25 MWD 12300.00 88.33 30.39 6369.76 -747.17 3382.91 5967880.32 558796.30 12.00 3071.73 271.35 MWD 12310.88 88,36 29.08 6370.07 -737.73 -3377.52 5967889.81 558801.61 12.00 3061.53 271.44 MWD 12325.00 87.87 30.71 6370.54 -725.49 -3370.48 5967902.10 558808.54 12.00 3048.25 107.00 MWD 12350.00 87.00 33.58 6371.66 -704.35 -3357.20 5967923.35 558821.65 12.00 3024.51 106.95 MWD 12375.00 86.13 36.46 6373.15 -683.91 -3342.88 5967943.90 558835.80 12.00 3000.41 106.82 MWD 12400.00 8528 39.34 6375.03 -664.24 -3327.57 5967963.70 558850.95 12.00 2976.03 106.65 MWD 12425.00 84.44 42.23 6377.27 -645.39 -3311.31 5967982.68 558867.05 12.00 2951.46 106.43 MWD ~ ~ bp BP Alaska ~S ~ Baker Hughes INTEQ Planning Report ~~vTE Q Company: BP Amoco Date: 3/14/2007 Time: 14:11:29 Page: 6 Field: Kupaiuk Co-ordinate(NE) Refereoce: We11: 03, True North Site: KRU 1C Pad Vertical (1'VD) Refereoce: Oatum(94') 34A We1L• 03 Section (VS) Reference: Well (O.OON,O.OOE,230.OOf1zi) Weqpath: Plan 5, 4C-03L1 Sarvey Calcalation Method: Minimum Curvature Db: Orade Survey MD Incl Azim SS TVD N/S E/W MapN MapE DLS VS 1'FO Tool ft deg deg ft ft R ft ft degH 00ft ft deg 12450.00 83.61 45.13 6379.87 -627.41 -3294.14 5968000.80 558884.07 12.00 2926.75 106.17 MWD 12475.00 82.80 48.04 6382.83 -610.35 -3276.11 5968018.00 558901.96 12.00 2901.97 105.87 MWD 12500.00 82.00 50.96 6386.14 -594.26 -3257.27 5968034.25 558920.66 12.00 2877.19 105.52 MWD ~ 12525.00 81.23 53.89 6389.78 i -579.18 -3237.67 5968049.49 558940.13 12.00 2852.49 105.74 2 3/8" ~ ~ ~ ~ ~II '~+laEi : , ,~ Iva~a : ;ri ~'', , N ~~ 11t~ ; ~ . ~ ~ I . t a t ~ ~T k ~ g ~ ~~-~1~~ a- r 1~! ~a i- ~r~ ~~I,~~~k ~~ I' ~ ~ w $~~ c~; a , ~ ~ `~ ~-i .t 1~ ~ h~ j Ft~ FI 1 ~ ~ + ~+ +~1t - -~ '~ ~ I G ~1 + ( a ~ ~{ ~~ ~WM ,~T ~- ,~ '"1' ~,T,-,~ r.~. r~.~..~. .r~ .,~, . u. ci~. ~.: . r~_::;t~i ~t ;jjj i. ~; ~~i~ N ij}1 ~ E ~+.~ r~ ij~ 4 ~' I~_~ ~. i 1 ~~, ~tf ` ~ ~7 t 'il ii ~ 1 I I ! ~ -I I 11 flf~ I~ll~ i!ij ~iij iil j~ fi ~i~l~l ~ ; ~ ;~- ~', 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I ' ~ ~ awa~Faaxxa . : ; ~ o :::: ::.::.:.::::::::: .it [t (i t~ a zsaF~~~~ ~ 8o88B88888 ' z ~d~~~~d~3~~ ~ Y S~: ~ 3'w°' ~~~~; .. ~-~fi~ii~~F ~ r N ~ A $ Y ~ $ 3 ` ~ ~ ~ t _a.ee... e °doe~~~~~d~~ ~ 9 sS ~ a - [ i"[.7ii. c S.""`""'_` Q $ e~~ ~ ;t 3 , ~ ~ fr ~ 'x 1 a ~ ~~ ~; $~ $ 3;%a~ W ..:::::::~_ :x:;:;,:_ ; ; ,~ m ~a a ~ a ' `8~ ~a~, _ : .3 t ~ ! ~ ~F ~ 8' f id:r:u:s:::::::o: f = ..:: • i e ~ : ~ ~ i??ieiefF ? ! e:l...!..:--- - -..,e ::rvse~q ':: ~ . ~ . .. ... : ::: .:.. . e ii 6 . ~~ ~3~ 3 : ~::3~~i?tF:Si?i:i!~ ~. 4 'x";=i .._.._c:.c;: i ~ i~iy g~'ige_::ia~:ij : ~:.0.:3:.:.::::: : . . " ~ _~ ~~ • ~ ~ a , • Kuparuk DOBCTD BOP configuration ~ 2" CT Well ~ 1 C-03A ~ Rig Floor ~ ~ ~ ~ C 3" 5000 psi ~.J ~ HCR M Choke Line ~ C I ~ C ~ ~ Tree Size 3-1 /8", 5M ~ ~ Lubricator ID = 6.375" with 6" Otis Unions ~ 7 1/16" 5000 psi BOP's. ID = 7.06" 7 1/16" 5000 psi, RX-46 ~ - 1/4 Turn LT Valve 7 1l16" 5000 psi RX-46 ~ Kill Line t L I 2 1/16" 5000 psi , RX-24 ~ 7 1/16" 5000 psi (RX-46) or f--- 4 1/16" 5000 psi (RX-39) Swab Valve Tee I I N M I Gi.,,., i~.,o -- SSV Master Valve Base Flan e Page 1 , , ~ ._ _ ~ bp ~ i _ ..`~!~%~ .~.` 's~. i''iiiN~~~ Terrie Hubble ~~~~~~~ Technical Assistant BP Exploration (Alaska) Inc. Drilling & Welis 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99519-6612 (9071 561-511 1 ~'~~~ ~ ~~ May 8, 2007 .~~ _._, ~, ~~ ~ ~, ,, ~ ~ -,1 ~. ~' ~° ; -; Alaska Oil & Gas Conservation Commission ~'''' _~ , 333 West 7`h Avenue, Suite 100 ;~~d,~ ~~, ? n Anchorage, Alaska 99501 ~' ~ ~'~?L~,~ ~~ ,~ ~ ; ,-, ~ ~ Reference: API # 50-029-20535-60-00 ~ ~ ~" ~~~'= ~ ~, g ;~~~,~~~~ ~~a;a8r~~'~~~ Permit # 207-044, Kuparuk 1 C-03L1 Direct: (907) 564-4628 hubbletl~bp.com To Whom It May Concern: Please cancel approved Permit to Drill for Kuparuk 1 C-03L1, Permit Number 207-044 (50-029-20535-60-00i. This well will now be drilled as a Sidetrack (1 C- 03A) instead of a lateral leg. A new Pemit to Drill for this sidetrack is respectfully submitted. Thank you very much for your assistance in this matter. Sincerely, / ~ ~,~~ f U~,C'2J Terrie Hubble xc: Well Files PDC Gary Eller, ConocoPhillips . Terri L. Hubble BP Exploration AK Inc. PO Box 196612 MB 7-5 Anchorage, AK 99519 "Mastercard Check" First National ~ank Alaska ' Anchorage, AK 99501 MEMO -~~- " lJ~l ~1 ~:L25200060~:99L462273~556~~' 0336 ~ ss-si,se2 336 DATE S 'V ~V / IOC~ .°O ~ ~ ~ TRA~YSMIT'TAI. LE~'T~R CIEiECKLIST i~VELL ~ANIE ~l/.~~'l/.C' fL~-03.q pTD# 0?4.~0630 ~ Development Service Eacp(oratory~ Stratigrapbic Test YoQ-ConventioQ$I Wett Circte 4ppropriate Letter / ParagraQhs to be Inctuded in Transmittal Getter ' CHECK ~ ADD-Oi~tS ~ •` T'EXZ' FOR APPROVAL LET`TER ~ wKAT I (OPTIONS) { ; APPLIES ~ ; ; ~ MULTI LATERAL ~ The permit is for a new we{]bore segment of existing ! ; ~(If last two digits i AP[ number ~ well ' in I _ are ; Pe~~t No. , AP[ No. ~0- - ; between 60-69) _ Production ~hould continue to be reported as a function of the i ~ ~ origina! API number stated above. ~ ; ~ PILOT EtOLE i[n accocdance with 20 AAC 2~.003(~, a!1 records: data and lo~s ; ~ j ~ acquir~d for the pilot hote must be ctearty differentiated in both ~ i i ~ well name { PI~ and API number ~ I ~ '(~0- -_,~ from records, data and logs ~ j ~ acquired for we(i ' ' i SPACING r The pcrmit is approved subject to full complisnce with 20 AAC ` ~ EXC6PTION I ~ 2~.05~. Approval to pecforate and produce / inject is contingeat ; ! i i ~ I upon issuance of a conservarion order approving a spacing j ! exception ' ~ ~ . assurc~SS the ~ liabi[ity of any protest to the spacing exception that may occur. i i ' ; DRY D[TCH ~ ~ All dry ditch sampte sets submitted to tt~e-Eommis~ion must be in ; ~ i SA!bfPLE i no greatcr rhan 30' sarr~ple intervals from below the perrrcafro~t or ; ; ~ ' I from where samp[es are first caught and l0' sample intervals j ~ ; , through target zones. ; ~ ~ ; ; j Non-Conventional ~ P(ease note the following special condition of rhis permic: ~ production or production testing of coa! bed methane is not allowed i ~ I~`e« ~ for (name of welll untit after (Cornnariv Name) has designed and ! ~ ~ ~ implement~d a water wel! testing program to provide basetine data ; ~ ; on water quality and quantity. 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