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207-160
• Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~ - ! ~ ~ Well History File Identifier Organizing (done) ^ Two-sided III II~III II III II III ^ Rescan Needed III II~III II II III III R CAN DIGITAL DATA OVERSIZED (Scannable) Color Items: ^ Diskettes, 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/ Project Proofing III IIIIIIIIIII IIIII BY: Maria Date: ~ ~ ~ /s/ Scanning Preparation ~ x 30 = sue, c.a + ~ =TOTAL PAGES_~ (Count does not include cover sheet) BY: Maria Date: ~ ~ C /s/ Production Scanning III II~IIIIIIII IIIII Stage 1 Page Count from Scanned File: ~~ (Count does includre co~v sheet) Page Count Matches Number in Scan ing Preparation: V YES NO BY: Maria Date: ~ ~ ~1(,~' 7 /s/ ~ 1` Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. ReScanned BY: Maria Date: /s/ Comments about this file: o , ,~~,oa oru~iiiiuuuu 10!6/2005 We{I History File Cover Page.doc ,.~~Rx . ~r_ ~ - ~~; _~~ ~.; ': . a ... .~' - t ~. fi~< ~ ~ • ~: ~ ~" . a ~ ,~~ v ~ MICROFILMED 6/30/2010 DO NOT PLACE ANY W EW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK91Microfilm_Marker.doc ConocoPhillips Alaska 30 -02AL2 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 TIFF LIS BP 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file 1 Diisk 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 Disk P.O.Box 196247 in lieu of sepia Electronic Anchorage, Alaska 99519 CGM TIFF -LIS Brandon Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas 1 Disk 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501 -3510 LIS v &O DATA SUBMITTAL COMPLIANCE REPORT 12/18/2008 Permit to Drill 2071600 Well Name/No. KUPARUK RIV UNIT 30-02AL2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21837-61-00 MD 11555 TVD 6572 Completion Date 3/31/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION i Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / RES / GR (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Type Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc Directional Survey 10250 11555 Open 5/23/2008 ~pt Directional Survey 10250 11555 Open 5/23/2008 _._ Well Cores/Samples Information: Name ADDITIONAL INFORM~ON WeII Cored? Y N Chips Received? .aL.L~I--- Analysis YT 1~ Received? _. ___ / Comments: ~ ~ I~~c!~ y ~~~ Compliance Reviewed By: Interval Start Stop Daily History Received? ~/ N Formation Tops ~ N ((fi l~ Sample Set Sent Received Number Comments Date: ---~--~~- ~'"6`~~ ~~ BAKER H~1+~HE Il',1TEt~- 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: May 23, 2008 Please find enclosed directional survey data for wells: 30-02A 30-02AL 1 PB 1 30-02AL1 30-02AL2 - ~. ~ ~ ~ ~ ~ 30-02AL2-O1 1R-OlBL1PBl 1R-OlBLI 1R-O1BL1-O1PB 1 1R-O1BL1-O1 Enclosed is: 1 ea 3.5" floppy diskette containing electronic survey ,file Cc: State of Alaska, AOGCC Christine Mahnken ~r ~ ~~t S ~ ~(~ sin ~ ~1 ) ~ a~~,- i ~~ ~ ~ Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, May 07, 2008 11:29 AM To: 'Hubble, Terrie L' Subject: RE: I Terrie, 3~' ~' ~' Q ~"' a- c~~~ - ~ (~~ I agree, the changes should not present a problem. Thanks, Tom Page 1 of 1 From: Hubble, Terrie L [mailto:Terrie.Hubble@bp.com] Sent: Wednesday, May 07, 2008 11:16 AM To: Maunder, Thomas E (DOA) Subject: RE: 30-02A (207-158), et al You are correct... I see the error that I made. I think you could make a hand correction on this if you would be so kind... 30-02AL2-01 No Change 30-02A No Change 30-02AL1 Well Branch 30-02AL1 Departs... 30-02AL2 Well Branch 30-02AL2 Departs... Thanks! Terrie From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Sunday, May 04, 2008 12:20 PM To: Hubble, Terrie L; Stewman, Sondra D Subject: 30-02A (207-158), et al Terrie and Sondra, I am finishing my review of the 407s for the 30-02A redrill and laterals. In block 21where the slotted section is detailed, the same statement regarding the well branch and whether it is accessible or not is made. Shouldn't that statement change depending on what segment is being reported? Thanks in advance, Tom Maunder, PE AOGCC 5/7/2008 ~ STATE OF ALASKA ~~ ALASKA~OIL AND GAS CONSERVATION COMMISSION WELL COMPLETION OR RECOMP~ETION REPORT AND LOG ~~ Y E~ ~i'r2 2 5 2008 ~:;;~a t9j€ Gas Cons. Commi~sio 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 2oAAC 2s.,os zoAAC 2s.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1b. Well Class: AnChOC~e ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aba 3/31/2008 T 12. Permit to Drill Number 207-160 3. Address: c/o P.O. Box 196612, Anchorage, AK 99519-6612 6. Date Spudded ~ 3/26/2008 13. API Number 50-029-21837-61-00 4a. Location of Well (Governmental Section): Surface: 745' FNL 1855' FWL SEC 22 T13N R0 7. Date T.D. Reached 3/28/2008 14. Well Name and Number: Kuparuk 30-02AL2 , , . , , 9E, UM Top of Productive Horizon: 3501' FSL, 4379' FEL, SEC. 16, T13N, R09E, UM 8. KB (ft above MSL): 59' Ground (ft MSL): 15. Field /Pool(s): Kuparuk River Unit /Kuparuk Total Depth: 4266' FSL, 3666' FEL, SEC. 16, T13N, R09E, UM 9. Plug Back Depth (MD+TVD) 11555' 6572' River Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 525491 y- 6022072 Zone- ASP4 10. Total Depth (MD+TVD) 11555' 6572' 16. Property Designation: ADL 025513 TPI: x- 519234 y_ 6026301 Zone- ASP4 Total De the x- 519943 p y- 6027068 Zone- ASP4 11. SSSV Depth (MD+TVD) 1787' 1585' 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rioted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1700' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and prin ed information p r 20 AAC 25.071): MWD DIR/RES/GR jNdl~l+~~lD~~f19i`l,Q 6S/~~SSTYD 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MO' SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP 'BOTTOM ° TOP BOTTOM 'SIZE CEMENT{NG RECORD PULLED 2-3/8" 4.44# L-80 10750' 11555' 6577' 6572' 3" Uncemented Slotted Liner 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-3/8" Slotted Section NOTE: 3-1/2", 9.3#, J-55 9963' 9891' MD TVD MD TVD 10759' - 10769' 6576' - 6575' Well Branch Well Branch 10896' - 11555' 6570' - 6572' 30-02A ~ 30-02A 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Departs From Is not Directly DEPTH INTERVAL MD AMOUNT Sr KIND OF MATERIAL USED 30-02AL2-01 Accessible PTD # 207-161 , at 10749' MD (6577' TVD) 26. PRODUCTION TEST Date First Production: Reported on 30-02AL2-01 C~-o~1 " ~~o ~ ~ Method of Operation (Flowing, Gas Lift, etc.): See the 1007 for 30-02AL2-01 (Dated 04/25/08, PTD 207-161) for Production & Test Data Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. Casing Press: CALCULATED 24-HOUR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. tt~~~} C a haw '2-~ / 1WSi4 None ~ ~~~ ~, < r r ',. Form 10-407 Revised 02/2007 ONTINU D ON REVERSE SIDE ~ ~~j ~~ ,°~J ~~~, ~, 28. GEOI_bGIC MARKERS (LIST ALL FORMATIONS AN KERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Tested . ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top of Kuparuk Al 10139' 6566' None Base of Kuparuk A2 10359' 6569' Top of Kuparuk Al 10394' 6570' Base of Kuparuk A2 10813' 6571' Top of Kuparuk Al 10889' 6570' Formation at Total Depth (Name): Top of Kuparuk Al 10889' 6570' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the forego'ng is true and correct to the best of my knowledge. / Si d O~! ~ gne Title Drilling Technologist Date Terrie Hubble Kuparuk 30-02AL2 207-160 Prepared By NameMumber. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Gary Eller, 529-1979 (Cell) Permit No. / A royal No. INSTRUCTIONS GeNeRnL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). ITeM 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 ND 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. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 28: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 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 BP AMERICA`. Operations .Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Event Name: REENTER+COMPLETE Start: 2/1/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Page 30 of 36 Spud Date: 10/2/1988 End: 3/31 /2008 Date From - To Hours Task Code NPT Phase Description of Operations 3/25/2008 06:35 - 07:15 0.67 CASE P LNR2 catwalk. Close both swab valves. 07:15 - 07:30 0.25 STWHIP P PROD3 MU weight bar & swizzle stick, stab onto well & jet BOP stack. 07:30 - 09:10 1.67 STWHIP P PROD3 Pop off well & LD weight bar & swizzle stick. Cut off CTC & 09:10 - 10:45 1.58 STWHIP P 10:45 - 11:20 0.58 STWHIP P 11:20 - 17:30 6.17 BOPSU P 17:30 - 18:30 1.00 BOPSU P 18:30 - 18:53 0.38 BOPSU P 18:53 - 20:00 1.12 BOPSU P 20:00 - 20:30 0.50 BOPSU P 20:30 - 21:00 0.50 BOPSU P 21:00 - 21:20 0.33 STWHIP P ~~ 4. 21:20 - 21:30 0.17 STWHIP P 21:30 - 23:00 1.50 STWHIP P p~Q - r~ ~ 23:00 - 23:30 0.50 STWHIP P 23:30 - 00:00 0.50 STWHIP 8 P 3/26/2008 00:00 - 00:10 0.17 STWHIP P 00:10 - 01:20 1.17 STWHIP P dress wire. Stab onto well & reverse circulate. Pop off well & RU cutter. Cut 100ft of coil. MU new Kendall CTC. Pressure up well via MPD loop holding 1100psi WHP & open TRSSSV. PROD3 Head up BHI's UOC. PROD3 Pull test CTC to 30k -good. Pressure test to 4000psi -good. PROD3 Perform weekly BOPE test per AOGCC regs. State witnessed by John Crisp. Pressure tested to 250psi/4500psi -PASS. PROD3 Crew change and take on 200 bbl of new flo-pro PROD3 PJSM with crew on PT the inner valve. Discuss hazards and miigated hazards PROD3 PU inject and stab on welll to test inner reel valve and stripper PROD3 Completed pressure test of all Surface equipment. Close SSSV check for flow ~ surface. PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 PROD3 3 ~~ " V 01:20 - 03:34 2.23 STWHIP P PROD3 03:34 - 06:11 2.62 STWHIP P PROD3 ~~-t c^~ 06:11 - 06:30 0.32 STWHIP P PROD3 06:30 - 07:30 1.00 STWHIP N DFAL m PROD3 07:30 - 09:10 1.671 STWHIP N DFAL ~ PROD3 09:10 - 09:55 I 0.751 DRILL I N I DFAL I PROD3 09:55 - 11:35 I 1.671 DRILL I N I DFAL I PROD3 Safety meeting/procedure review prior to P/U BHA. Deploy BHA #26, 2-3/8" Xtreme with 2.730" STR324 PDC Bit. Total BHA lenght 61.97ft. Make up Injector, RIH to 175' CTMD, pressure up WHP to 1150 psi & open SSSV. Continue to RIH Slow speed, tie in depth 9564ft CTMD. Adjusted depth + 10.5 ft (9605tt to 9615.5ft), continue RIH. Slow speed from 10,000 ft, stop pumping (~ 10,050ft through window. Tagged Billet Plug ~ 10,256 pumps at min. rate. Tagged billet ~ 10,256 ft P/U and increase pump rates to 1.4 bpm, start sidetrack ~ 10,255 ft CTMD. Establish good 1:1 returns holding 400 psi WHP using 9.8# MW. 10,256ft Getting Alum. cutting to surface, holding 1:1 returns with 400 psi WHP. MW 9.8# in/out. Sitting down 150# to 240# on bottom while time drilling. Timed mill off of billet to 10,259 ft Drilling to 10, 270 ft and back reamed above 10,250 ft TF at 158 HS Backed reamed at 30L, 158 and 608 TF RIH to drill turn section Drilling turn section Op = 1.46 / 1.46 bom at 4017 psi off bottom Density = 9.81 / 9.81 ppg DHWOB /ROP = 1.8k at 43 fph BHP /WHP = 4665 / 4100 psi ECD of 13.8 ppg Vp = 438 bbl Window 10,255 ft to 10,259 ft Plugged motor, orient TF to HS and pulled above window. Tried to circulate the CT and its still plugge. Open EDC and circulated at 1.4 bpm while hold in 400 to 600 psi on wellhead. SD and close EDC and try circulating. Motor still plugged. POOH for motor change. Held PJSM and covered hazards associated with handling the BHA and the closed SSSV. POOH, at 1600 ft and 1190 psi, closed SSSV and checked integrity. OK POOH Changed out Motor (1.5 deg AKO) and PU RR STC BC bit ST bit is plugged with Alumium and stator rubber Set counters and RIH, Pressured up on the WH to 1200 psi Printed: 4/11/2008 12:40:41 PM BP AMERICA Page 31 of 36` Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT .Phase Description of Operations 3/26/2008 11:35 - 11:50 0.25 DRILL N DFAL PRODS Log tiein at 9580 ft down Corrected +4 ft 11:50 - 12:10 0.33 DRILL N DFAL PRODS RIH 12:10 - 14:14 2.07 DRILL P PRODS Tagged bottom at 10,285 ft Op = 1.46 / 1.46 and 4,160 psi Density = 9.81 / 9.81 ppg DHWOB /ROP = 1.8k at 43 fph BHP / WHP = 4,688 / 410 psi ECD of 13.8 ppg Vp = 236 bbl Window 10,255 ft to 10,259 ft 14:14 - 16:35 2.35 DRILL P PRODS POOH, tagged up and closed SSSV with 1250 psi below. Checked flow OK Held PJSM on handling BHA 16:35 - 18:30 1.92 DRILL P PRODS LD BHA Circulating and maintaing constant BHP using MPD technique Crew change out 18:30 - 18:45 0.25 DRILL P PRODS Safety Meeting/ Procedure review prior to P/U BHA. 18:45 - 19:30 0.75 DRILL P PRODS Close SSSV, monitor well, remove night cap & P/U BHA # 28 - 2-3/8" Coiltrack, 2.7 X 3" Bi-center, AKO 1.1, total lenght 71.69ft. make up CT Injector and begin to RIH slowly. 19:30 - 19:45 0.25 DRILL P PRODS Pressure up to 1200 psi, Stop CT ~ 175' open SSSSV, RIH. 19:45 - 21:15 1.50 DRILL P PRODS Log tie in from 9580 ft. 21:15 - 21:50 0.58 DRILL P PRODS Correction depth +8.5ft. Continue to RIH slowly 21:50 - 22:20 0.50 DRILL P PRODS Mad Pass from 10255 - 10370 ft. Res tool not functioning properly. 22:20 - 00:00 1.67 DRILL P PRODS On bottom drilling 10,370ft : Op 1.5 bpm/4400 psi Density 9.81/ 9.80 DHWOB 2.9 / 21 fph BHP/WHP 4560 / 402 ECD 13.52 Current depth at midnight 10,439 ft. ROP - 60 ft/hr 3/27/2008 00:00 - 00:55 0.92 DRILL P PRODS Short trip from 10500ft to 10265'. Vac truck removed 290 bbls of dirty DM. Transferred 280 bbl of clean 9.8 DM. Total pit volume of clean DM 387 bbls. 00:55 - 01:55 1.00 DRILL P PRODS Mad Pass from 10265' to 10500'. 01:55 - 04:00 2.08 DRILL P PRODS BOBD -crews reviewed Spill response and Fire Drills procedures. GeoSteer in Kup Al sand as per Geologist 1.50 BPM/ 4300 psi Density = 9.78 / 9.82 ppg 1:1 DHWOB / ROP 1.90 / 78 fph BHP/WHP = 4600/410 psi ECD=13.58ppg Vp= 387 bbls Current depth 10600 ft 04:00 - 04:40 0.67 DRILL P PRODS Wiper trip from 10650' to 10275' 04:40 - 07:10 2.50 DRILL P PRODS GeoSteering in KupAi sand as per Geologist from 10,650 ft to 10,800 ft Op = 1.5 BPM/ 4100 psi 9.78/ 9.85 density 1:1 DHWOB/ROP = 1.4/ 67fph BHP/WHP = 4590/400 ECD 13.5 Vp = 383 bbl 07:10 - 08:28 1.30 DRILL P PRODS Wiper Trip at 10,800 ft 08:28 - 12:05 3.62 DRILL P PRODS GeoSteering in KupA1 sand as per Geologist from 10,800 ft to 10,823 ft Orient TF to 135 R and drop TVD. Op = 1.5 / 1.5 BPM ~ 4100 psi off bottom F'OntBtl: 4/11/1008 7"1:40:41 YM ~~ ~ i BP AMERICA Page 32 of 36 Operati ons Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 3/27/2008 08:28 - 12:05 3.62 DRILL P PROD3 9.78/ 9.85 ppg density 1:1 12:05 - 13:00 0.92 DRILL P 13:00 - 14:00 1.00 DRILL P 14:00 - 16:00 I 2.001 DRILL I P 16:00 - 17:50 1.83 DRILL P 17:50 - 20:00 2.17 DRILL P 20:00 - 21:15 1.25 DRILL P 21:15 - 00:00 2.75 DRILL P 3/28/2008 00:00 - 00:30 0.50 DRILL P 00:30 - 01:40 1.17 DRILL P 01:40 - 03:30 1.83 DRILL P 03:30 - 04:40 I 1.171 DRILL I P 04:40 - 05:06 0.43 DRILL P 05:06 - 06:35 1.48 DRILL P 06:35 - 06:55 0.33 DRILL P 06:55 - 10:00 3.08 DRILL P DHWOB / ROP = 1.4/ 67fph BHP/WHP = 4590 psi /400 fpm w/ ECD 13.5 ppg Vp = 371 bbl PROD3 Wiper trip at 10,950 ft Clean PROD3 GeoSteering in KupA1 sand as per Geologist Goal To drill to 11,200 MD and land at 6525 ft TVD Op = 1.5 / 1.5 BPM ~ 4140 psi off bottom 9.78/ 9.85 ppg density 1:1 DHWOB / ROP = 1.4/ 67fph BHP/WHP = 4590 psi /400 fpm w/ ECD 13.5 ppg Vp = 366 bbl PROD3 Drillled into ankerite and the ROP came to a halt then broke through Op = 1.5 / 1.5 BPM C~ 4140 psi off bottom 9.78/ 9.85 ppg density 1:1 DHWOB / ROP = 1.4/ 67fph BHP/WHP = 4616 psi /377 fpm w/ ECD 13.64 ppg Vp = 362 bbl PROD3 Wiper trip PROD3 Drillling to 11250ft prior to Wiper Op=1.5/4100 9.78/ 9.90 density 1:1 DHWOB/ROP 1.5 / 60 fph BHP/ WHP 4630psi/ 390 psi ECD 13.7 Vp 350 PROD3 Wiper trip to 10275ft. PROD3 BOBD from 11250 ft, current depth ~ midnight 11,385 ft Op = 1.5 bpm/ 4160 psi 9.9/9.80 density 1:1 DHWOB/ROP 2.3/ 60fph BHP/WHP 4660/400 ECD 13.72 VP 342 bbls PROD3 Continue drilling to 11,400' PROD3 Wiper trip to 11,275' PROD3 BOBD target depth 11,550 ft. Op = 1.48 bpm at CTP of 4,300 psi Density + 9.89/ 9.9 ppg DHWOB / ROP = 1.9 / 72 fph BHP /WHP 4690 psi / 400 psi ECD 13.73 ppg Vp = 337 bbls TD Lateral 11,545ft PROD3 Wiper up to Tie in depth 9,585 ft. Slow to min. pump rate/pinch in choke from 10,260 ft up to window. Stop pumping/close choke, no problems ~ window. increase pump rate and open choke slowly. ECD 13.63 ppg PROD3 Tie in starting depth 9,585 ft. Correction+l7 ft PROD3 RIH to confirm TD Tagged TD at 11,555 ft, PU and confirmed PROD3 Circulate liner pill down CT and lay in (no beads as per engineer) PROD3 POOH laying in liner pill and following the MPD Pressure schedule plus 100 psi Printed: a/11/2008 12:40:41 PM ,' ~ • BP AMERICA Page 33 of 36 .Operations. Summary,Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From - To .Hours Task Code NPT Phase Description of Operations 3/28/2008 06:55 - 10:00 3.08 DRILL P PROD3 At surface, closed SSSV and bleed off topside and SSSV is holding 10:00 - 10:15 0.25 DRILL P PROD3 Held PJSM and discussed Hazard associated with LD USR directional BHA 10:15 - 11:05 0.83 DRILL P PROD3 LD BHA 11:05 - 11:25 0.33 CASE P LNR3 Held PJSM and disussed Discussed with town the plan fonnrard on the L2 lateral 11:25 - 13:00 1.58 CASE P LNR3 PU slotted liner as per Summary. PU CoilTrac with GS running tools Line up Swaco choke to hold 1250 psi on the wellhead / annulus 13:00 - 14:45 1.75 CASE P LNR3 RIH and at 10,000 ft PUW = 23,000 Ib up, RIH, stopped at 10,360 ft and logged down to tie-in 14:45 - 15:08 0.38 CASE P LNR3 Log tie-in down from 10,360 ft / 9545 ft MD BHP = 4377 psi at 13.7 ppg. ECD WHP = 963 psi + 8 ft correction 15:08 - 15:40 0.53 CASE P LNR3 RIH, wt check at 11,525 ft = 26k RIH and tagged TD at 11,557 ft Lined out to pump down the CT. Op = 1.35 bpm at 4050 psi Lost 2k without pump 15:40 - 18:00 2.33 CASE P LNR3 POOH with liner running tools and Coiltrak following MPD pressure schedule 18:00 - 18:30 0.50 CASE P LNR3 CT ~ surface, weight is 2000# heavier than last trip. Discuss possibilty of Liner still attached to CT BHA during safety meeting. 18:30 - 19:15 0.75 CASE P LNR3 Close SSSV, 1250 psi WHP, bleed down and monitor pressure. Remove injenctor head, P/U BHA and the liner string did come back with the BHA. Remove upper part of BHA, install Safety joint across BOP's until GS is inspected/rebuilt. 19:15 - 20:00 0.75 CASE N DFAL LNR3 Upon tesUinspection of the BHA the knuckle joint seals were leaking. Decision made to remove the knuckle joint and re-run the BHA. 20:00 - 20:30 0.50 CASE N DFAL LNR3 P/U BHA, make up injector. Pressure up above SSSV to 1200 psi, open &RIH. 20:30 - 22:30 2.00 CASE N DFAL LNR3 RIH to Tie in depth of 10,360 ft 22:30 - 22:46 0.27 CASE N DFAL LNR3 Tie in correction of + 1ft, continue to RIH. 22:46 - 23:12 0.43 CASE N DFAL LNR3 RIH weight check ~ 11520 ft 26,000#. Down weight 4200# ~ surface. 23:12 - 23:40 0.47 CASE N DFAL LNR3 Tag bottom ~ 11556ft P/U weight 25,000# POOH up to 11540 ft. Start pumping ~ 1.6 bpm, reduce WHP to 300 psi, Circ. press. 4600psi RIH weight 2300# on CT, tag bottom sit down to -4200# on CT weight 3.0 WOB, P/U weight 20,400# still pumping same rate and pressures. Close choke & shut down pumps to verify. initial weight check 11400 ft. Currently 3000# lighter on CT weight ,POOH pumping as per MPD schedule. Liner top left at 10750' 23:40 - 00:00 0.33 CASE N DFAL LNR3 POOH pumping as per MPD schedule from 11400 ft. 3/29/2008 00:00 - 02:00 2.00 CASE N DFAL LNR3 POOH, following the MPD schedule. Close SSSV as a precaution if the liner is still attached. WHP 1200 psi, bleed Nnnted: anvzuus iz:au:ni rrvi ~.~~ • M $P AMERICA Page 34 of 36' Operations Summary`Report Legal Well Name: 30-02 Common Well Name: 30-02 Spud Date: 10/2/1988 Event Name: REENTER+COMPLETE Start: 2/1/2008 End: 3/31/2008 Contractor Name: NORDIC CALISTA Rig Release: 3/31/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase. Description of Operations 3/29/2008 00:00 - 02:00 2.00 CASE N DFAL LNR3 down at surface. 02:00 - 02:30 0.50 CASE P LNR3 Remove CT injector off well, lay down BHA -Liner was set in place. Set up valves on surface for MPD procedure at surface. Close master & swab valves, pressure up to 1200 psi, open SSSV. 02:30 - 03:15 0.75 STWHIP P PROD4 Baker surface testing BHA prior to Deployment. 03:15 - 03:35 0.33 STWHIP P PROD4 Discuss pressure deployment procedures and personnel tasks. 03:35 - 06:54 3.32 STWHIP P PROD4 Pressure deploy BHA 06:54 - 08:40 1.77 STWHIP P PROD4 RIH with STR 324 ST BHA (1.5deg AKO) 08:40 - 08:44 0.07 STWHIP P PROD4 Tie in at 9545 ft at 150 fph Corrected + 2ft 08:44 - 09:38 0.90 STWHIP P PROD4 RIH with the drilled TF and MPD Pressure schedule 09:38 - 09:44 0.10 STWHIP P PROD4 RIH and tagged the aluminum billet at 10750.8 ft dry tagged. PUH 09:44 - 13:20 3.60 STWHIP P PROD4 Time Milling off AI Billet Started at 10,749.54 ft Op = 1..52 / 1.53 bpm at 3960 psi off bottom ~ ! Milled for 1 ft and then took brake off and try to drill Some j ~ ~ packing off around the tool 13:20 - 15:10 1.83 STWHIP P PROD4 Drilling ahead from 10,753' CP=3900 psi ~~ ~ Op= In/Out = 1.52 / .51 bpm ' ~ ~ ECD 13.4 ppg WOB 3700 Ibs DH WOB 2100 Ibs with ROP 6 ft/hr Pit Volume = 276 bbls 15:10 - 15:55 0.75 STWHIP P PROD4 Hanging up at 10,758' with no motor work Short Trip to 10,265' 15:55 - 19:00 3.08 STWHIP P PROD4 10,756' first WOB indication drilling ahead Op= in 1.54 bpm out 1.53 bpm CP=3975 psi TF~17 deg RT Den=9.86/9.94 ppg DH Press.=4532 psi; DH WOB=3200 Ib Pit Vol=276 bbls Changed TF to 121 RT ~ 10,770' Hard drilling 19:00 - 19:30 0.50 STWHIP P PROD4 10,785' begin POOH/ backreaming through billet section no problems. Stop POOH ~ 9550' ft. Open Circ. sub in BHA. 19:30 - 21:00 1.50 STWHIP P PROD4 POOH from 9550' while following the MPD schedule. 21:00 - 21:15 0.25 STWHIP P PROD4 Discuss Un-deplying procedure. Shut in choke and maintain 1200 psi on WHP. 21:15 - 23:00 1.75 STWHIP P PROD4 Undeploying BHA. Milling bit was in good shape with no AI fragments in bit nozzles. 23:00 - 00:00 1.00 DRILL P PROD4 Make up & test BHA at surface. Pre-deployment safety meeting. 3/30/2008 00:00 - 02:15 2.25 DRILL P PROD4 Deploy BHA #32, Coiltrak Extreme AKO 1.1"with 2.70" X 3.0" Smith Bicenter bit. 02:15 - 04:00 1.75 DRILL P PROD4 RIH following MP schedule. 04:00 - 04:30 0.50 DRILL P PROD4 Tie depth 9580' -1 correction 04:30 - 05:12 0.70 DRILL P PROD4 RIH try MAD pass from 10730' ,resistivity tool not functioning properly. Continue in hole, no problems past billet section. 05:12 - 08:15 3.05 DRILL P PROD4 Tagged at 10,785 ft Op = 1.46 / 1.44 bpm at 4000 psi off bottom pressure DHBHP / WH = 4577 / 293 psi ECD at 6508 ft TVD = 13.56 PP9 TF average 10R to 135R deg Printed: 4/11/2008 12:40:41 PM ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 30 Pad 30-02 30-02AL2 TD Design: 30-02AL2 TD Baker Hughes INTEQ Survey Report • 03 April, 2008 r~.~r BAKER HIJ~I~IE~ INTE(,~ ConocoPhi[[ips Alaska Company: ConocoPhillips(Alaska) Inc Project: Kuparuk River Unit Site: Kuparuk 30 Pad WeII: 30-02 Wellbore: 30-02AL2 TD Design: 30-02AL2 TD t - ConocoPhillips ~R r ` . s Baker Hughes INTEQ Survey Report IMUaNEs IN"I'EQ Local Co-ordinate Reference: Well 30-02 TVD Reference: Mean Sea Level MD Reference: 30-02 @ 59.OOft (30-02) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDMv16 Prod Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Site Kuparuk 30 Pad Site Position: Northing: 6,022,094.67 ft Latitude: 70° 28' 17.333 N From: Map Easting: 525,478.25 ft Longitude: 149° 47' 30.897 W Position Uncertainty: 0.00 ft Slot Radius: 0 " Grid Convergence: 0.20 ° Well 30-02 Well PoslUon +N/-S 0.00 ft Northing: 6,022,073.89 ft Latitude: 70° 28' 17.128 N +E/-W 0.00 ft Easting: 525,490.94 ft Longitude: 149° 47' 30.526 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft Wellbore 3O-02AL2 TD Magnetics Model Name Sample Date Declination Dlp Angle Field Strength bggm2007 10/24/2007 17.95 __.___ 79.82 57,269 Design 30-02AL2 TD Audit Notes: Version: 1.0 Phase: Vertical Section: Depth From (TVDj (ft) 0.00 ACTUAL Tie On Depth: 10,250.94 +N/-S +EI-W Direction 0.00 0.00 45.00 4/3/2008 2:22:58PM Page 2 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Ina Project: Kuparuk River Unit Slte: Kuparuk 30 Pad Well: 30-02 Weilbore: 30-02AL2 TD Design: 30-02AL2 TD Survey Program Date From To (ft) (ft) Survey (Wellbore) 100.00 10,000.00 30-02 (30-02) 10,056.00 10,133.94 30-02A MWD TD (30-02A TD) 10,140.00 10,250.94 30-02AL1 MWD TD (30-02AL1 TD) 10,255.00 11,519.00 30-02AL2 MWD TD (30-02AL2 TD) Survey ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Tool Name Description BOSS-GYRO Spent'-Sun BOSS gyro multishot MWD MWD -Standard MWD MWD -Standard MWD MWD -Standard s~Rr •' M1laF1E8 INTEQ Well 30-02 Mean Sea Level 30-02 @ 59.OOft (30-02) True Minimum Curvature EDMv16 Prod MD Inc Azi TVDSS N/S FJW Northing Easting DLS Vertical Section !ft) (°) (°) ln) (n) 1~) (n) (n) (°nooft) (ft) 10,250.94 90.06 323.13 6,517.65 4,117.90 -6,186.22 6,026,170.17 519,291.27 14.35 -1,462.52 ', 10,255.00 89.96 323.59 6,517.65 4,121.16 -6,188.64 6,026,173.42 519,288.84 11.59 -1,461.93 10,270.30 96.15 325.00 6,516.83 4,133.56 -6,197.55 6,026,185.79 519,279.89 41.49 -1,459.46 10,284.97 95.68 328.20 6,515.32 4,145.74 -6,205.58 6,026,197.94 519,271.81 21.93 -1,456.53 10,300.48 95.34 331.50 6,513.83 4,159.09 -6,213.33 6,026,211.26 519,264.02 21.29 -1,452.57 10,321.42 94.42 335.85 6,512.05 4,177.78 -6,222.58 6,026,229.92 519,254.70 21.16 -1,445.89 10,334.33 93.07 338.22 6,511.21 4,189.64 -6,227.61 6,026,241.77 519,249.64 21.09 -1,441.06 10,369.41 90.09 342.20 6,510.24 4,222.63 -6,239.48 6,026,274.71 519,237.66 14.17 -1,426.13 ', 10,399.72 87.24 347.51 6,510.95 4,251.86 -6,247.39 6,026,303.91 519,229.65 19.88 -1,411.05 ', 10,427.30 86.35 349.88 6,512.49 4,278.86 -6,252.79 6,026,330.89 519,224.16 9.17 -1,395.78 ', 10,459.18 87.85 354.02 6,514.10 4,310.38 -6,257.25 6,026,362.39 519,219.59 13.80 -1,376.64 10,487.47 88.77 358.94 6,514.94 4,338.60 -6,258.98 6,026,390.60 519,217.76 17.69 -1,357.92 10,525.48 88.34 4.15 6,515.90 4,376.57 -6,257.96 6,026,428.57 519,218.65 13.75 -1,330.34 ', 10,560.57 89.02 10.24 6,516.70 4,411.36 -6,253.57 6,026,463.37 519,222.93 17.46 -1,302.64 '~~ 10,589.11 87.58 13.43 6,517.55 4,439.27 -6,247.72 6,026,491.30 519,228.68 12.26 -1,278.76 10,625.15 87.12 17.66 6,519.22 4,473.95 -6,238.07 6,026,526.01 519,238.21 11.79 -1,247.42 10,653.73 88.25 21.08 6,520.37 4,500.88 -6,228.60 6,026,552.97 519,247.58 12.59 -1,221.68 10,683.73 90.09 24.82 6,520.81 4,528.50 -6,216.91 6,026,580.63 519,259.18 13.89 -1,193.88 10,710.22 91.96 28.10 6,520.33 4,552.21 -6,205.11 6,026,604.37 519,270.90 14.25 -1,168.78 10,740.64 94.08 32.14 6,518.73 4,578.48 -6,189.87 6,026,630.69 519,286.04 14.98 -1,139.43 4/3/2008 2:22:58PM TFO l°) 87.19 102.26 12.78 98.23 95.75 101.79 119.64 126.77 118.27 110.68 70.17 79.48 94.78 83.70 114.35 96.31 71.78 63.84 60.29 62.18 Page 3 COMPASS 2003.16 Build 42F * - / Con ocoPhillips ~~t'r ConocoPhilt~ s p Baker Hughes INTEQ Survey Report B~~ES - Alaska IINTEQ Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well 30-02 Project: Kuparuk River Unit TVD Reference: Mean Sea Level Site: Kuparuk 30 Pad MD Reference: 30-02 ~ 59.OOft (30-02) Well: 30-02 North Reference: True Weilbore: 30-02AL2 TD Survey Calculatlon Method: Minimum Curvature Design: 30-02AL2 TD Database: EDMv16 Prod Survey MD Inc Azi TVDSS N!S E/W Northing Easting DLS Vertical Section TFO (n) (°) (°) (~) (ft) (ft) (ft) tft) (°/100ft) tft) (°) 10,770.29 96.05 35.20 6,516.11 4,603.05 -6,173.50 6,026,655.32 519,302.33 12.24 -1,110.47 57.00 ' 10,799.87 95.47 39.10 6,513.14 4,626.51 -6,155.73 6,026,678.83 519,320.02 13.26 -1,081.32 98.30 ', 10,830.18 ~ 93.25 42.55 6,510.84 4,649.37 -6,135.97 6,026,701.76 519,339.69 13.51 -1,051.19 122.70 ~ 10,860.09 89.85 45.42 6,510.03 4,670.88 -6,115.21 6,026,723.34 519,360.37 14.87 -1,021.30 139.79 10,890.43 86.26 49.07 6,511.06 4,691.46 -6,092.96 6,026,743.99 519,382.56 16.87 -991.01 134.59 10,921.11 87.33 54.76 6,512.78 4,710.34 -6,068.86 6,026,762.96 519,406.59 18.84 -960.61 79.50 ', 10,955.71 87.15 59.60 6,514.44 4,729.07 -6,039.82 6,026,781.78 519,435.56 13.98 -926.84 92.25 1Q986.92 86.84 63.73 6,516.08 4,743.86 -6,012.40 6,026,796.66 519,462.93 13.25 -896.99 94.40 11,014.92 87.70 67.94 6,517.41 4,755.30 -5,986.88 6,026,808.19 519,488.40 15.33 -870.86 78.55 11,044.01 87.06 72.40 6,518.74 4,765.16 -5,959.55 6,026,818.14 519,515.69 15.47 -844.56 98.27 11,072.24 86.69 76.87 6,520.28 4,772.63 -5,932.38 6,026,825.70 519,542.84 15.86 -820.07 94.86 11,103.53 88.41 81.37 6,521.62 4,778.53 -5,901.69 6,026,831.70 519,573.51 15.38 -794.20 69.17 11,133.12 88.22 81.34 6,522.49 4,782.97 -5,872.45 6,026,836.25 519,602.73 0.65 -770.38 -171.03 ', 11,159.14 88.93 77.70 6,523.14 4,787.70 -5,846.88 6,026,841.07 519,628.28 14.25 -748.95 -79.01 11,187.10 87.67 75.01 6,523.97 4,794.29 -5,819.72 6,026,847.75 519,655.41 10.62 -725.09 -115.14 11,220.18 11,247.44 90.55 91.32 71.20 67.50 6,524.48 6,524.04 4,803.90 4,813.51 -5,788.08 -5,762.58 6,026,857.47 6,026,867.17 519,687.02 519,712.48 14.44 13.86 -695.92 -671.09 -52.95 -78.22 • ', 11,277.96 91.32 64.57 6,523.33 4,825.91 -5,734.70 6,026,879.65 519,740.32 9.60 -642.62 -89.97 ', 11,303.77 89.85 59.91 6,523.07 4,837.92 -5,711.87 6,026,891.75 519,763.10 18.93 -617.97 -107.48 11,342.98 91.26 56.45 6,522.69 4,858.59 -5,678.56 6,026,912.53 519,796.34 9.53 -579.81 -67.82 ', 11,370.71 91.26 52.24 6,522.08 4,874.75 -5,656.04 6,026,928.76 519,818.80 15.18 -552.46 -89.95 ~i 11,400.74 90.86 49.61 6,521.53 4,893.67 -5,632.73 6,026,947.76 519,842.04 8.86 -522.59 -98.62 11,430.46 92.00 45.13 6,520.78 4,913.79 -5,610.88 6,026,967.95 519,863.82 15.55 -492.92 -75.67 11,460.59 94.36 40.76 6,519.11 4,935.80 -5,590.39 6,026,990.03 519,884.24 16.46 -462.86 -61.48 11,490.24 93.57 37.89 6,517.06 4,958.68 -5,571.65 6,027,012.97 519,902.90 10.02 -433.43 -105.32 II 11,507.43 93.10 35.27 6,516.06 4,972.46 -5,561.42 6,027,026.78 519,913.08 15.46 -416.46 -100.11 11,519.00 93.23 34.18 6,515.42 4,981.96 -5,554.84 6,027,036.30 519,919.62 9.47 -405.09 -83.16 4/3/2008 2:22:58PM Page 4 COMPASS 2003.16 Build 42F Conoco`Phillips Alaska Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 30 Pad Well: 30-02 Weilbore: 30-02AL2 TD Design: 30-02AL2 TD Survey MD Inc Azi TYDSS (ft) (°) l°) lft) 11,555.00 93.23 34.18 6,513.39 t , ConocoPhillips ~ ~R~r . tan ~S Baker Hughes INTEQ Survey Report 1N'I'EQ Local Co-ordinate Reference: Well 30-02 TVD Reference: Mean Sea Level MD Reference: 30-02 Q 59.OOft (30-02) North Reference: True Survey Calculation Method: Minimum Curvature: Database: EDMv16 Prod N!S EIW Northing Easting DLS Vertical Section TFO 5,011.69 -5,534.65 6,027,066.10 519,939.71 0.00 -369.79 0.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (~) Name l") (") 5,895.00 3,922.38 9 5/8" 9-5/8 12-1/4 li Checked By: Approved By: Date: • 4/3/2008 2:22:58PM Page 5 COMPASS 2003.16 Build 42F .~ `_., KRU 30-02 Producer 3'~z" TRDP SSSV at 1787' A-sand CTD Completion Updated 3/31/2008 3'/:", 9.3#, EUE 8rd Mod tubing w! 3'/i' gas lift mandrels (six) Actual Drilled Footage = 8358' sie' surface casing shoe at 5930' • 3'/z" x 7" Baker RHS packer with PBR at 9891" • 2.75" D-nipple at 9928' • 3'/:" tubing tail at 9963' 2'/." liner top 9940' AL2-01 lateral (northem, upper) A2/3 Sand, TD @ 11,471' Cement ramp exit, top of 2'/." slotted & solid liner 9940' - 11,471' cement -9970' MD _ ,~ „_ _ _ _ _ AL1 Lateral (westem, upper) ~~ ~ A2/3 Sand, TD C~ 13,186' Aluminum billet ~~ ~ 2'/a" slotted liner 10,255' -13,186' @ 10,255' ~~ Aluminum billet ii ~ 10,749' ~~ ~~ ~~ i i ~~ ~ ' .. ` ~~ ~~ ~~ ~/ Wfrxiavn7'casrg ~~ , AL1-P61 10.330' - 10,500' I @10,0617 MD II ` ~~ AL2 lateral (northern, lower) ~~ / ~ ~~ Al Sand, TD ~ 11,555' ' " ' ' ~~ ~~ ~~ 2 /. slotted liner 10,749 - 11,555 ~ A sand perfs: ~ - 'A' sidetrack (westem, lower) 'A' barefoot segment 10,052' - 10,148' (cemented) Al Sand, TD ~ 13,180' 10,140' -10,329' 2'/." slotted liner 10,329' - 13,180' .... . .......... . . . 7', 26 ppf, J-55 casing shoe at 10,392' Naming Convention for 30-02AL2 Lateral Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Friday, March 21, 2008 1:50 PM To: 'Stephen F Davies' Subject: FW: Naming Convention for 30-02AL2 Lateral Steve, Since you have been gone, things have continued to change on 30-02A, et al. They originally permitted -02A, -AL1 and -AL2. Some difficulties were encountered drilling and they obtained a permit for -AL3 which will now not be drilled. They will seek to cancel that permit. Anyway, I really don't think it is worth our time to fiddle with the naming here. It is a rats' nest down there. Hopefully they will be able to drill to their objective without any more problems. I believe I have a plot in one of the well files that diagrams what they think it looks like. Tom From: Eller, J Gary [mailto:].Gary.Eller@conocophillips.com] Sent: Friday, March 21, 2008 9:44 AM To: Maunder, Thomas E (DOA) Subject: Naming Convention for 30-02AL2 Lateral Tom - As per our phone conversation today, I wanted to confirm the naming convention for upcoming lateral 30- 02AL2 (#207-160). That lateral was planned to kick off of the 'A' sidetrack, but due to drilling conditions it will now be kicked off of the AL1 lateral. The well objectives, proposed TD, and much of the directional plan remain unchanged, but we are kicking off from a different lateral than originally planned. It is my understanding that we will contiue to call this the AL2 lateral despite the change in kickoff. If the rest of our drilling and completion go as planned, this lateral will be inaccessible for post-rig intervention regardless of the naming convention. Thanks. -Gary CPAI Wells Engineer 4/30/2008 A S RAH PAL/N, GOVERNOR ~~ OIL ~ ~ 333 W 7th AVENUE, SUITE 100 C01915I' R'QA~IOAT COl-Ti-IISSIOrIT ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Gary Eller FAx (907) 276-7542 CT Drilling Engineer Conoco Phillips Alaska Inc. C/o PO Box 196612 Anchorage, Alaska 99519-6612 Re: Kuparuk River Field, Kuparuk River Pool, 30-02AL2 Conoco Phillips Alaska Inc. Permit No: 20?-160 Surface Location: 745' FNL, 1855' FWL, SEC. 22, T13N, R09E, UM Bottomhole Location: 4264' FSL, 3664' FEL, SEC. 16, T13N, R09E, UM 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 well KRU 30-02A, Permit No 207- 158, API 50-029-21837-01. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission spec~cally 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 fission to witness any required test, contact the Commission's petroleum field ' pect rat (907) 659-3607 (pager). DATED this ~ day of November, 2007 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/ o encl. ~E~EI STATE OF ALASKA ALAS IL AND GAS CONSERVATION COMMI N NOV 4 7 ZOO7 PERMIT TO DRILL ~~~~ AlASke Oil 8t Glas Cons. Commission 20 AAC 25.005 A ..V. 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if welt is propose or. -- ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 - 11. Well Name and Number: 30-02AL2 ' 3. Address: c/o P.O. Box 196612, Anchorage, AK 99519-6612 6. Proposed Depth: MD 11630 ~ TVD 6523ss 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface: 745' FNL 1855' FWL SEC 22 T13N UM R09E 7. Property Designation: ADL 025513 .- River Pool , , . , , , Top of Productive Horizon: 3274' FSL, 4156' FEL, SEC. 16, T13N, R09E, UM 8. Land Use Permit: 13. Approximate Spud Date: January 2008 Total Depth: 4264' FSL, 3664' FEL, SEC. 16, T13N, R09E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 9,000' ' 4b. Location of Well (State Base Plane Coordinates): Surface: x-525491 y-6022072 Zone-ASP4 10. KB Elevation (Height above GL): 59' feet 15. Distance to Nearest well Within Pool: 1,000' 16. Deviated Wells: Kickoff Depth: 10225 feet Maximum Hole An le: 97 de tees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4995 Surface: 4335 ° 18. Ga in P m: S cificat' ns T - etti th - B om nC of Cem nt c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.6# L-80 STL 670' 10960' 6508' 11630' 6523' ~ Uncemented Slotted Liner 1 g. PRESE NT WELL CONDITION SUMMARY (To be completed forRedritt and Re-entry Operations) Total Depth MD (ft): 13200 Total Depth TVD (ft): 6518 Plugs (measured): None Effective Depth MD (ft): 13200 Effective Depth TVD (ft): 6518 Junk (measured): None Casing Length Size Cement Vohame M TVD Conductor /Structural 115' 16" 199 sx Ar ticset II 115' 11 ' Surface 5930' 9-5/8" 1400 sx AS III, 400 sx 'G', To Job: 100 sx AS I 5930' 4002' Intermediate Production 1 3 2' 7" 31 x CI ss'G' 17 x S I 103 2' 77 ' Liner 2900' 3" Uncemented Slotted Liner 30-02A 10300' - 13200' 6513' - 6518' Liner 2975' 3" Uncemented Slotted Liner 30-02AL1 10225' - 13200' 6 13' -6482'. Perforation Depth MD (ft): None Perforation Depth TVD (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 f oing is tru nd correct. Contact Gary Eller, 529-1979 (Cell) Printed Name Gary Elle ' Title CT Drilling Engineer Prepared By Name/Number: Si nature Phone 263-4172 Date Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill . /~O Number: API Number: 50-029-21837 6/-00 ~K•~6'o7 Permit Approval See cover letter for Date: other re uirements Conditions of Approval: _ / If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydr , or gas contained shales:~,/" Samples Req'd: ^ es ~No Mud Log Req'd: ^ Yes L7 No HZS Measures: Yes"` o it f nal Survey Req'd: Yes ^ No Other: y~ YS l ~~~ -~ ~- APPROVED BY THE COMMISSION Date ~ rO ,COMMISSIONER Form 10-401 Revised 12/2005 ~~ ~ ~~`~ ~ ~ Submit In Duplicate i KRU 30-02 Quad Sidetrack/Laterals -Coiled Tubing Drilling Summary of Operations: A coiled tubing drilling rig will drill four sidetracks & laterals in well KRU 30-02 using the managed pressure drilling technique. These horizontal laterals will target Kuparuk A2/3 and Al sand reserves to access upswept and trapped oil. The perforations in the motherbore will be plugged with cement. 1. The A sidetrack will exit the motherbore at 10,060' MD and be a 3140' horizontal targeting the Al sand to the southwest. It will be completed with 23/8" slotted liner to a TD of 13,200' MD. 2. The AL1 lateral will kick off from the A sidetrack at 10,300' MD targeting A2/3 Sands to the southwest. The AL1 lateral will be 2900' in length and will be completed with 23/8" slotted liner to a TD of 13,200' MD. 3. The AL2 lateral will kick off from the A sidetrack at 10,225' MD and will target Al Sand to the north. '` The AL2 lateral will be 1405' in length and will be completed with 23/8" slotted liner to a TD of 11,630' MD. - 4. The final lateral, AL3, will kick off from the AL2 lateral at 10,960' MD and will target the AZ/3 Sands to the north. The AL3 lateral will be 665' in length and will be completed with 23/8" slotted liner to a TD of 11,625' MD. Only the final drilled lateral will remain accessible through-tubing. CTD Drill and Complete 30-02 program: January 2008 Pre-Rig Work 1. Obtain updated static BHP on A sand. 2. Test Packoffs - T & IC. 3. Positive pressure and drawdown tests on MV and SV. 3O~_3 y, 4. Drawdown test on SCSSV. 5. Slickline tag fill and drift 3'/z" tubing. 6. Install dummy valves in GLMs 7. MIT-IA, MIT-OA. 8. Coil tubing plug existing A sand perfs with 17 ppg cement up to tubing tail at 9963' MD. 9. Slickline tag top of cement. Rig Work MIIZU Nordic Rig #2 using 2" coil tubing. NU 7-1/16" BOPE, test. 2. -side pilot hole and cement ramp for exit at 10,060' MD. Mi112.74" window and 10' of open hole r 060' MD. 3. 30-02A Sidetrack ( Lower) a. Drill pilot and cement ramp i h-side exit at 10,060' MD. b. Mi112.74" window with high-side o 'on. The planned KOP is at 10,060' MD in the A sand. c. Dril13" bi-center horizontal `A' sidetrack southwest in sand from the window to TD at 13,200' MD. d. Kill well. Run 23/8" slotted liner with aluminum billet from TD up to f 10, D. 4. 30-02AL1 Lateral (Western Upper) a. Dril13" bi-center horizontal AL1 lateral southwest in the A2/3 sand from 10,300' to TD at 13,200' MD. b. Kill well. Run 23/8" slotted liner with aluminum billet from TD up to f 10,225' MD. 5. 30-02AL2 Lateral (Northern Lower) - a. Dril13" bi-center horizontal AL2 lateral north in the Al sand from 10,225' to TD at 11,630' ~~ c'+'S`~ MD. b. Kill well. Run 23/8" slotted liner with aluminum billet from TD up to (10,960' MD. a. Dn - ` ontal AL3 lateral north in the A2/3 sands from 10,960' to TD at 11,625' MD. b. Kill well. Run 23/8" slotted liner with aluminum billet 9963' MD. 7. Freeze protect. ND BOPE. RDMO Nordic 2. tail at Page 1 of 3 November 2, 2007, FINAL • KRU 30-02 Quad Sidetrack/Laterals -Coiled Tubing Drilling Post-Rig Work 1. Run GLVs 2. Obtain static BHP 3. Produce well to sales. Mud Program: • Will use chloride-based Biozan brine (10.0 ppg) for milling operations, and chloride-based Flo-Pro mud '" 010.0 ppg) for drilling operations. Since there is an SCSSV installed in 30-02, we should not have to kill the well to deploy 23/8" slotted liner. Disposal: • No annular injection on this well. • Class II liquids to KRU 1 R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 30-02A: 23/8", 4.6#, L-80, STL slotted liner from 10,300' MD to 13,200' MD • 30-02AL1: 23/8", 4.6#, L-80, STL slotted liner from 10,225' MD to 13,200' MD • 30-02AL2: 23/8", 4.6#, L-80, STL slotted liner from 10,960' MD to 11,630' MD • 30-02AL3: 23/8", 4.6#, L-80, STL slotted liner from 9960' MD to 11,625' MD Existing Casing/Liner Information Surface: 95/8", J-55, 36 ppf Burst 3520 psi; Collapse 2020 psi. Production: 7", J-55, 26 ppf Burst 4980 psi; Collapse 4320 psi Well Control: • Two well bore volumes 0180 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 4500 psi. Maximum potential surface pressure is 4335 psi assuming a gas gradient to surface and maximum potential formation pressure based on the highest pressure measured in offset injectors (i.e. 4995 psi in 3Q-15 in July 2006). • The annular preventer will be tested to 250 psi and 2500 psi. Directional• • See attached directional plans. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 30-02A: 10,600' to property line, 1400' to 3Q-16 at the toe • 30-02AL1: 10,600' to property line, 1400' to 3Q-16 at the toe • 30-02AL2: 9000' to property line, 1000' to 3R-19 at the toe ` • 30-02AL3: 9000' to property line, 1000' to 3R-19 at the toe Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Page 2 of 3 November 2, 2007, FINAL KRU 30-02 Quad Sidetrack/Laterals - Coiled Tubing Drilling Hazards Expect to encounter increased pressure in the western laterals, particularly beyond a fault that will be encountered at 11,500' MD. The static reservoir pressure in the 3Q-16 injection well which the western laterals are drilling towards is approximately 14.5 ppg EMW. Lost circulation is a risk due to the likelihood of encountering increased formation pressure at major fault crossings, particularly in the western laterals. We1130-02 has 145 ppm HZS as measured on 1/22/07. Wells 30-01 and 30-03 are adjacent to 30-02. ,,- 30-01 has 265 ppm HZS as measured on 1/22/07, and 30-03 has 140 ppm HZS as measured on 1/25/07. The maximum HZS level on the 30 pad is 265 ppm from we1130-O1. All HZS monitoring equipment will be operational. Reservoir Pressure • The most recent static pressure measured in 30-02 is 3703 psi on 10/02/07 (i.e. 10.9 ppg EMW at 6567' TVD). Prior to that, the survey taken in January 2005 showed that reservoir pressure was 3006 psi (i.e. 8.8 ppg EMW). Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 10.0 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 BOPS 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 2'/s" pipe/slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. There is a functional SCSSV in we1130-02, so the well should not have to be killed prior to running 23/a" 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: 3703 psi at 10,101' MD (6562' TVD), or 10.9 ppg EMW. • Expected annular friction losses while circulating: 905 psi (assuming friction of 90 psi/1000 ft). • Planned mud density: 10.0 ppg equates to 3412 psi hydrostatic bottom hole pressure at 6562' TVD • While circulating 10.0 ppg fluid, bottom hole circulating pressure is estimated to be 4317 psi or 12.7 ppg EMW without holding any additional surface pressure. • When circulation is stopped, it is anticipated that 300 psi of additional surface pressure shall have to be applied to balance reservoir pressure. 905 psi of additional surface pressure must be held to maintain the same bottom hole pressure as during drilling operations. Page 3 of 3 November 2, 2007, FINAL • • ConocoPhillips Alaska, lnc. KRU 30-02 30-02 API: 500292183700 Well T : PROD An le TS: 47 d 10035 SSSV Type: TRDP Orig 10/2/1988 Angle @ TD: 43 deg @ 10420 sssv Com letion: (17a7-17aa, Annular Fluid: Last W/O: Rev Reason: NEW GLD OD:3.500) Reference L Ref Lo Date: Last U date: 6/2/2006 Last Ta : 10101 TD: 10420 ftK6 Last Ta Date: 1/23/2005 Max Hole An le: 60 d 3000 Casin Strin -ALL STRINGS Gas Lift MandrelNalve Descri lion Size To Bottom TVD Wt Grade Thread 1 - CONDUCTOR 16.000 0 115 115 62.50 H-40 (3508-3505, SUR. CASING 9.625 0 5930 4001 36.00 J-55 PROD. CASING 7.000 0 10392 6772 26.00 J-55 Tubin Strin -TUBING Gas Lift Size To Bottom TVD Wt Grade Thread MandrelNalve 2 3.500 0 9963 6468 9.30 J-55 EUE 8RD AB MOD (5255-x257, Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 10052 - 10068 6528 - 6539 A-3 16 12 3/30/1989 APERF 60 deg. phasing; 2 1/8" Gas Lin EnerJet MandrelNalve 10072 - 10098 6542 - 6559 A-2 26 12 3/30/1989 APERF 60 deg. phasing; 2 1/8" 3 (7aasaaa7 EnerJet , 10102 - 10110 6562 - 6568 A-1 8 6 3/28/1989 APERF 60 deg. phasing; 2 1/8" EnerJet Gas Lift 10110 - 10130 6568 - 6582 A-1 20 8 10/2/1988 IPERF 45 deg. phasing; 4" Ultrapak 3ndrel/Dummy CS Gun valve a 10130 - 10148 6582 - 6595 A-1 18 6 3/28/1989 APERF 60 deg. phasing; 2 1/8" (assa-assn, OD:4.750) EnerJet Gas Lift MandrelsNalves St MD TVD Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Gas Lift andrellDummy Mfr Run Cmnt valves 1 3508 2542 MMH FHMO GLV 1.0 BK 0.125 1280 5/31/2006 (seas-seas' 2 6256 4191 MMH FHMO GLV 1.0 BK 0.188 1351 5/31/2006 OD:a.750) 3 7846 5134 MMH FHMO OV 1.0 BK 0.188 0 5/31/2006 4 8658 5630 MMH FHMO DMY 1.0 BK 0.000 0 4/21/2000 Gas Lift 5 9248 6005 MMH FHMO DMY 1.0 BK 0.000 0 2!15!1998 andrel/Dummy valve 6 6 9836 6384 Otis - LBX DMY 1.5 T-2 0.000 0 9/7/1996 lsa3s-sa37, Other lu s e ui .etc. -JEWELRY OD:5.500) De th TVD T e Descri lion ID 1787 1585 SSSV Camco TRDP' 2.812 PBR 9878 6411 PBR AVA 3.000 (sale-sa7s, 9891 6420 PKR AVA'RHS' 3.000 OD:3.500) 9928 6444 NIP Camco'D' Ni le NO GO 2.750 9962 6467 SOS Baker 2.992 9963 6468 TTL 2.992 PKR Fish -FISH (sasl-sasz, De th Descri tion Comment OD:s.151) 10185 23' Stri Gun Lost in Hole General Notes Date Note 4/4/1996 WAIVERED WELL: IA x OA COMMUNICATION NIP (9928-9929, OD:3.500) TUBING (0.9963, OD:3.500, ID:2.992) Perf ',10052-10068) Perf ;10072-10098) Perf .10102-10110) - -- Perf '10110-10130) Perf '10130-10148) --- 23' Strip Gun ;10185-10208, - OD:2.000) KRU 30-02 Producer 3'rz" TRDP SSSV at 1787' Proposed A-sand CTD Completion ' Footage Drilled = 8110' gas 3'/z', 9.3#, EUE Srd Mod tubing w/ 3'/z Updated 11 /2/2007 lift mandrels (six) 9%" surface casing shoe at 5930' " • • 3'/z' x 7" Baker RHS packer with PBR at 9891 • 2.75" D-nipple at 9928' • 3'f~" tubing tail at 9963' 2'/." slotted liner top -9950' _y _ I~ Window in T' 2611 J55 casing Cement ramp exit, top of / 10,060' MD @ cement -9970' MD ~ I ~ - / \\ \ / Aluminum billet ~ ' \ @ 10,225 ~~ '~ ~ ~~ /Y./6-o7 °° AL3 lateral (northern, upper) ' : : - , ` ~ ~~ ~~ ~~ ~A ~+detreek (western, upper) A2/3 Sand, TD @ 11,625 ~ ~ ~~ ° o ~~ ~• A2/3 Sand, TD @ 13,200' _ _ _ _ A sand perFs: ' _ ~ ~ ' - ~~ \\ I \ _-_ _ - 10,148 ~` 10,052 ( lu ed) \ \ I 1 Aluminum billet ~~ p gg I 1 \~ II 11 @ 10,300' `` '' `` \~ i/ ~~ - ~~ -------------- -- ----- ~- - __~ ~ \ ~ __ -__-- ~ - - - - ~~~ ~IG ~o~ ..~/ AL2 lateral (northern, lower) - Aluminum billet -~=~r~A (western, lower) Al Sand, TD @ 11,630' @ 10,960' Al Sand, TD @ 13,200' 7", 26 ppf, J-55 casing shoe at 10,392' • • by BP Alaska $ Baker Hughes INTEQ Planning Report >1vTE Q Company: BP Amoco Daate: 10/23/2007 Tinto: 15:49:48 Page: 1 ..Field: Kupanik Co-ordwate(NE} Retereece: -`Weil: 30-02, True North Bke: KRU 30 Pad Vertical (TVD) Re[erence: 30-02 Orig;Rg 59.0 Well: 30-02 Section (VS) Reference: Well {O.OON,O.OOE,45.OOAzi) Wdipathr` Pian 6,.30-02AL7 Sarvey Calculation Method:: Minimum Curvature Db: OraGe FieM: Kuparuk Map System:US State Plane Coordinate System 192 7 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datam: Mean Sea Level Geomagnetic Model: bggm2007 Site: KRU 30 Pad UNITED STATES :North Slope Site Positron: Northing: 6022812 .21 ft Latitude: 70 28 24.450 N From: Map Fasting: 523632 .43 ft Longitude: 149 48 25.100 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.18 deg Well: 30-02 Slot Name: Well Position: +N/-S -744.80 ft Northing: 6022073 .38 ft ' Latitude: 70 28 17.123 N +E/-W 1856.56 ft Fasting : 525491 .16 ft - Longitude: 149 47 30.520 W Positron Uncertainty: 0.00 ft Wellpath: Plan 6, 30-02AL2 Drilled From: Plan 5, 30-02A 500292183761 Tie-ou Depth: 10225.00 ft Current Datum: 30-02 Orig Rig Height 59 .00 ft Above System Datum: Mean Sea Level Magnetic Data: 10/23/2007 Declination: 23.06 deg Field Strength: 57626 nT Mag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 59.00 0.00 0.00 45.00 Plan: Plan #6 Date Composed: 10/23/2007 Version: 2 Principal: Yes Tied-to: From: Definitive Path Targets Map Map. <-- Latitude --> '<-- Longitude ---> Name Description TVD +N!-S +E!-W Northing Eastiag Deg Min Sec Deg Mia Sec Dip. Dir. ft ft ft ft ft 30-02AL2 Fault 1 59.00 4586.24 -6463.13 6026637.Of 519013.01 70 29 2.200 N 149 50 40.644 W -Polygon 1 59.00 4586.24 -6463.13 6026637.01 519013.01 70 29 2.200 N 149 50 40.644 W -Polygon 2 59.00 4385.54 -6263.80 6026437.01 519213.01 70 29 0.228 N 149 50 34.775 W -Poygon 3 59.00 4184.84 -6064.46 6026237.01 519413.01 70 28 58.255 N 149 50 28.907 W 30-02AL2 Fault 2 59.00 4814.64 -5111.21 6026870.01 520364.01 70 29 4.456 N 149 50 0.879 W -Polygon 1 59.00 4814.64 -5111.21 6026870.01 520364.01 70 29 4.456 N 149 50 0.879 W -Polygon 2 59.00 5216.04 -5509.87 6027270.01 519964.01 70 29 8.401 N 149 50 12.616 W -Polygon 3 59.00 5617.45 -5908.54 6027670.01 519564.01 70 29 12.346 N 149 50 24.354 W 30-02AL2 Polygon 59.00 4112.77 -6339.74 6026164.01 519138.00 70 28 57.544 N 149 50 37.002 W -Polygon 1 59.00 4112.77 -6339.74 6026164.01 519138.00 70 28 57.544 N 149 50 37.002 W -Polygon 2 59.00 4335.07 -6420.99 6026386.01 519056.00 70 28 59.730 N 149 50 39.398 W -Polygon 3 59.00 4529.90 -6364.31 6026581.01 519112.00 70 29 1.646 N 149 50 37.735 W -Polygon 4 59.00 4699.23 -6163.71 6026751.01 519312.00 70 29 3.313 N 149 50 31.839 W -Polygon 5 59.00 4828.48 -5941.25 6026881.01 519534.00 70 29 4.586 N 149 50 25.297 W -Polygon 6 59.00 4979.83 -5745.71 6027033.01 519729.00 70 29 6.076 N 149 50 19.548 W -Polygon 7 59.00 5114.47 -5636.23 6027168.01 519838.00 70 29 7.401 N 149 50 16.331 W -Polygon 8 59.00 5035.76 -5432.48 6027090.01 520042.00 70 29 6.629 N 149 50 10.335 W -Polygon 9 59.00 4801.42 -5633.31 6026855.01 519842.00 70 29 4.323 N 149 50 16.238 W -Polygon 10 59.00 4685.00 -5806.72 6026738.01 519669.00 70 29 3.176 N 149 50 21.337 W -Polygon 11 59.00 4567.95 -6086.15 6026620.01 519390.00 70 29 2.023 N 149 50 29.554 W -Polygon 12 59.00 4399.28 -6186.74 6026451.01 519290.00 70 29 0.363 N 149 50 32.509 W -Polygon 13 59.00 4224.20 -6170.34 6026276.01 519307.00. 70 28 58.642 N f 49 50 32.022 W -Polygon 14 59.00 4124.02 -6121.68 6026176.01 519356.00 70 28 57.657 N 149 50 30.588 W -Polygon 15 59.00 4002.24 -&188.10 6026054.01 519290.00 70 28 56.458 N 149 50 32.539 W 30-02AL2 Target 3 6563.00 4781.16 -5849.40 6026834.01 519626.01 70 29 4.122 N 149 50 22.594 W • by BP Alaska r Baker Hughes INTEQ Planning Report 1NTE Q Company: BP Amoco Date: 10/23/2007 Tiroe: 15 :49:48 Paae: 2 Field:. Kuparuk Co-ordiaate(NE) Reference6 Welt: 30-02, True North 'Site: " KR113O Pad Vertical (TVD) Reference: 30-02 Org Rig 59.0 Weit: 30-02 Sectio e (VS) Reference: Well (O.OON,O.OOE,45.OOAz) Wellpat6 Plan 6, 30-02AL2 SurveyGaknintioa Metbod: Minimum Gurvature Db: Qrade Targets Msp Map <-- Latitude.. --> <-- Longitude --~ Name Description. TVD +N/-S +E/-W Nurthieg Easting De= Mie Sec.. ..Deg Min Sec Dip. Dir. ft ft ft ft ft 30-02AL2 Target 2 6567.00 4646.88 -6063.88 6026699.01 519412.01 70 29 2.799 N 149 50 28 .901 W 30-02AL2 Target 4 6572.00 4930.50 -5651.87 6026984.01 519823.01 70 29 5.592 N 149 50 16 .787 W 30-02AL2 Target 5 6582.00 5021.1 1 -5535.54 6027075.01 519939.01 70 29 6.484 N 149 50 13 .367 W 30-02AL2 Target 1 6583.00 4336.74 -6322.97 6026388.01 519154.00 70 28 59.747 N 149 50 36 .514 W Annotation MD TVD $ ft 10225.00 6572.45 KOP -Tie to 30-02A Plan 5 10245.00 6571.70 2 10265.00 6569.76 3 10324.00 6569.74 4 10564.00 6582.84 End of 25 Deg/100' DLS 10964.00 6567.02 6 11064.00 6564.04 7 11239.00 6563.35 8 11314.00 6564.79 9 11489.00 6571.98 10 11630.00 6582.07 TD Plan Section Information MD Inci Azim TVD +N/-S +E/-W DLS Build Tnro TFO Target ft deg deg. ft ft ft deg/100ft deg/100ft deg/100ft deg 10225.00 90.00 301.30 6572.45 4075.07 -6183.85 0.00 0.00 0.00 0.00 10245.00 94.33 303.80 6571.70 4085.82 -6200.69 25.00 21.64 12.52 30.00 10265.00 96.81 308.16 6569.76 4097.51 -6216.79 25.00 12.43 21.80 60.00 10324.00 83.22 313.91 6569.74 4136.14 -6261.17 25.00 -23.03 9.75 157.00 10564.00 91.09 13.52 6582.84 4355.89 -6324.90 25.00 3.28 24.84 84.80 10964.00 93.18 61.51 6567.02 4663.78 -6088.65 12.00 0.52 12.00 86.70 11064.00 90.23 73.15 6564.04 4702.22 -5996.58 12.00 -2.95 11.64 104.00 11239.00 90.22 52.15 6563.35 4782.17 -5842.01 12.00 -0.01 -12.00 270.00 11314.00 87.59 43.54 6564.79 4832.44 -5786.48 12.00 -3.50 -11.48 253.00 11489.00 87.75 64.56 6571.98 4934.51 -5645.72 12.00 0.09 12.01 90.00 11630.00 84.09 47.99 6582.07 5012.27 -5529.15 12.00 -2.60 -11.75 257.00 Survey MD Incl Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool fF deg deg ft ft ft ft ft degl100ft. ft deg. 110225.00 90.00 301.30 6513.45 4075.07 -6183.85 6026126.85 519294.01 0.00 -1491.13 0.00 MWD 10245.00 94.33 303.80 6512.70 4085.82 -6200.69 6026137.54 519277.13 25.00 -1495.44 30.00 MWD 10265.00 96.81 308.16 6510.76 4097.51 -6216.79 6026149.17 519260.99 25.00 -1498.56 60.00 MWD 10300.00 88.75 311.57 6509.06 4119.90 -6243.60 6026171.47 519234.11 25.00 -1501.68 157.00 MWD 10324.00 83.22 313.91 6510.74 4136.14 -6261.17 6026187.65 519216.48 25.00 -1502.63 157.17 MWD 10400.00 85.28 332.90 6518.42 4196.58 -6306.03 6026247.92 519171.43 25.00 -1491.61 84.80 MWD 10500.00 88.72 357.70 6523.73 4292.41 -6331.14 6026343.66 519145.99 25.00 -1441.60 82.88 MWD 10564.00 91.09 13.52 6523.84 4355.89 -6324.90 6026407.16 519152.01 25.00 -1392.30 81.56 MWD 10600.00 91.33 17.84 6523.08 4390.54 -6315.18 6026441.83 519161.61 12.00 -1360.93 86.70 MWD 10700.00 91.97 29.82 6520.19 4481.81 -6274.87 6026533.23 519201.60 12.00 -1267.88 86.79 MWD 10800.00 92.52 41.82 6516.26 4562.68 -6216.50 6026614.30 519259.69 12.00 -1169.42 87.14 MWD 10900.00 92.96 53.83 6511.45 4629.63 -6142.61 6026681.49 519333.34 12.00 -1069.84 87.61 MWD 10964.00 93.18 61.51 6508.02 4663.78 -6088.65 6026715.82 519387.18 12.00 -1007.54 88.19 MWD 11000.00 92.13 65.71 6506.35 4679.76 -6056.45 6026731.91 518419.33 12.00 -973.46 104.00 MWD 11064.00 90.23 73.15 6505.04 4702.22 -5996.58 6026754.57 519479.11 12.00 -915.25 104.19 MWD • by BP Alaska ~ Baker Hughes INTEQ Planning Report iNTE Q Co~rpany BP Amoco Date: 10/23/2007 Time: 15:49:48 Page; 3 Field: Kuparuk Go-ordiaate(NE) Reference: Welt; 30-02, True (`forth Site: KRtJ 30 Pad Vertical (TV1D) Refereacet 30-02 Orig Rig 59.0 Well: 30-02 Seetioa (VS) Retereace: Well (O.OON,O.OOE,45.OOAzi) Wellpath: Ptan 6; 30-02AL2 Sarvey £aknlatien Method: Minimum Curvature Db: Grade Survey MD ' Ind Azim SS TVD' N/S E/W MapN MapE DLS VS TFO Toof ft deg deg ft ff ft tt ft deg/100ft ft deg 11100.00 90.23 68.83 6504.89 4713.94 -5962.55 6026766.41 519513.09 12.00 -882.90 270.00 MWO 11200.00 90.22 56.83 6504.50 4759.52 -5873.75 6026812.29 519601.73 12.00 -787.88 269.98 MWD 11239.00 90.22 52.15 6504.35 4782.17 -5842.01 6026835.04 519633.39 12.00 -749.42 269.94 MWD 11300.00 88.08 45.15 6505.26 4822.43 -5796.25 6026875.46 519679.00 12.00 -688.60 253.00 MWD 11314.00 87.59 43.54 6505.79 4832.44 -5786.48 6026885.49 519688.75 12.00 -674.61 253.10 MWD 11400.00 87.63 53.87 6509.38 4889.06 -5722.01 6026942.34 519753.02 12.00 -588.98 90.00 MWO 11489.00 87.75 64.56 6512.98 4934.51 -5645.72 6026988.04 519829.14 12.00 -502.90 89.57 MWD 11500.00 87.45 63.27 6513.44 4939.35 -5635.85 6026992.91 519838.99 12.00 -492.50 257.00 MWD 11600.00 84.84 51.53 6520.18 4992.99 -5551.94 6027046.83 519922.71 12.00 -395.24 257.05 MWD ,. 11630.00 84.09 47.99 6523.07 ,. 5012.27 -5529.15 6027066.19 519945.43 12.00 -365.49 257.85 2 3/8" • • • Kuparuk Managed Pressure Drillin~ BOP Configuration for 2" Coil Tubing We I I I 30-02 Floor C 3" 5000 psi 1 HCR M Choke Line C 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 1/16" 5000 psi RX-46 HCR Kill Line 1 2 1/16" 5000 psi , RX-24 7 1/16" 5000 psi (RX-46) or ~ 4 1/16" 5000 psi (RX-39) Swab Valve Flow Tee SSV Master Valve Base Flan e Page 1 ~ *. TRANSMITTAL LETTER CHECKLIST WELL NAME ~'~Ge ~0 `~Z~~C.. Z PTD# ~ ? r ~~ V Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ~ ADD-Otis TEXT FOR APPROVAL LETTER WHAT {OPTIONS) APPLIES MULTI LATERAL The permit is for a new~l~ re se ~~ f existing f ~ well K~~ V (If last two digits in API No. 50 ~~~ -~• ~?~~~ permit No API number are , . Production should continue to be reported as a function of the between 60-69) original API number stated above. PII,OT HOLE In accordance with 20 AAC 25.005(fj, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACIPiG The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /infect is contingent upon issuance of a conservation order approving a spacing exception. , assumes the liability of any protest to the spacing exception that may occw. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of well) until after (Company Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. ~Compan~Name) must contact the Commission to obtain advance approval of such water well testing ro am. 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