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Home My WebLink About207-161• • Image Projeet Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available ire 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 It III ^ Rescan Needed tll Il~i~t Ii i) III ill RE 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: BY: Maria Date: ~ ~ ~ ~ ^ Other:: /s/ Project Proofing 111 llllll lllll ll III BY: Maria Date: ~ Isl Scanning Preparation x 30 = + =TOTAL PAGES ~~ (Count does not include cover sheet) BY: Maria Date: ~ ~' ~ ~ ~ Q' /s/ Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ YES NO BY: Maria Date: ~ / ~ I ~ ~ /s/ ~/ ~ I t 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. II I II II II I II II I I III ReScanned III lllllllllll lllll BY: Maria Date: /s/ Comments about this file: Quality Checked ~~ 10!6/2005 Well History File Cover Page.doc ~~ `~;~, ~~ _ .,. ' '~ ~; ~ ~„~~ " ~~, ~. ~« ~~ a~ ~~ ~ ~,~~v'" a ~,$~~x ~ . MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc S ConocoPhillips Alaska 30- 02AL2 -01 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 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 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 j /6/ ND 2 7 (i i N V 2 a 2005 DATA SUBMITTAL COMPLIANCE REPORT 12/18/2008 Permit to Drill 2071610 Well Name/No. KUPARUK RIV UNIT 30-02AL2-01 Operator CONOCOPHILLIPS ALASKA INC MD 11471 TVD 6548 Completion Date 3/31/2008 REQUIRED INFORMATION Mud Log No .- DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / RES / GR Well Log Information: Log/ Electr Data Digital Dataset .Type. Med/Frmt Number Name ED D Asc Directional Survey ~pt Directional Survey Well Cores/Samples Information: Name ADDITIONAL INFORMATION Interval Start Stop API No. 50-029-21837-62-00 Completion Status 1-OIL Current Status 1-OIL UIC N Samples No Directional Survey es (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Scale Media No Start Stop CH Received Comments --- ---...__._.--------------- 10740 11741 Open 5/23/2008 10740 11741 Open 5/23/2008 Well Cored? Y /~N~ Chips Received? ~`~-td-- Analysis Y,1,N- Received? _ - - - ------ Comments: ~ ~ ~~~~~^-~ ~~, ~ ~U~S~~ - - --_ Compliance Reviewed By: _ - Sample Set Sent Received Number Comments Daily History Received? Y N Formation Tops / N Date: _~ ' ~^-~!~~-- ------ ! ~ ~~~~ BAKER H~I~HE II'~iTE~,~- 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-Ol - 1R-01BL1PB1 1R-OIBLI 1R-O1BL1-O1PB1 1R-O1BL1-01 Enclosed is: ~~~ - I~~ 1 ea 3.5" floppy diskette containing electronic survey ,file Cc: State of Alaska, AOGCC Christine Mahnken Page 1 of 1 Maunder, Thomas E (DOAj From: Maunder, Thomas E (DOA) Sent: Wednesday, May 07, 2008 11:29 AM To: 'Hubble, Terrie L' Subject: RE: Terrie, .~~~~~Q ~~~0~ I agree, the changes should not present a problem. Thanks, Tom 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. 1 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@ataska.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~IL AND GAS CONSERVATION COM~SSION .APR 2 5 2008 WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~:I - ,Gil & Gas Cons.. Cammi~- e.,rhnratlE 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAACZS.~os zoAACZS.~~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well Class: ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aba 3/31/2008 D~ 12. Permit to Drill Number 207-161 3. Address: c/o P.O. Box 196612, Anchorage, AK 99519-6612 6. Date Spudded ~ 3/29/2008 13. API Number 50-029-21837-62-00 4a. Location of Well (Governmental Section): Surface: 745' FNL 1855' FWL SEC 22 T13 7. Date T.D. Reached 3/30/2008 14. Well Name and Number: Kuparuk 30-02AL2-01 , , . , N, R09E, UM Top of Productive Horizon: 3298' FSL, 4240' 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: 4255' FSL, 3745' FEL, SEC. 16, T13N, R09E, UM 9. Plug Back Depth (MD+TVD) 11471' 6548' River Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 525491 y- 6022072 Zone- ASP4 10. Total Depth (MD+TVD) 11471' 6548' 16. Property Designation: ADL 025513 TPI: x- 619375 y- 6026098 Zone- ASP4 Total Depth: x- 519865 y- 6027057 Zone- ASP4 11. SSSV Depth (MD+TVD) 1787' 1585' 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit el ctronic and rinted 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 printe information per 20 C 25.071): MWD DIR / RES / GR ,~yroOs,~ @ ff-f~~JiMD ~~B.Sr! ssnD 22. CiASING, LINER AND CEMENTING RECORD CiASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRn,DE TOP $OTrOM TOP BOTTOM' SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surface 115' Surface 115' 24" 199 sx Arcticset II 9-5/8" 36# J-55 Surface 5930' Surface 4002' 12-1/4" 1400 sx AS III 400 sx Class 'G' To Job: 100 sx AS I 7" 26# J-55 Surf Surface 6534' 8-1/2" 315 sx CI ss'G' 175 sx CS I 2-3/8" 4.44# L-80 9940' 11471' 6453' 6548' 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 lop 8~ 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 10131' - 10289' 6564' - 6574' Only Well Branch 10447' - 10730' 6573' - 6578' 30-02AL2-01 25: AClD, FRACTURE, CEMENT SQUEEZE, ETC. 10825' - 11459' 6565' - 6548' Is Directly DEPTH INTERVAL MD AMOUNT $c KIND OF MATERIAL USED Accessible Freeze Protect w/ 30 Bbls of Diesel 26. PRODUCTION TEST Date First Production: April 8, 2008 Method of Operation (Flowing, Gas Lift, etc.): Date Of Test: 4/15/2008 HOUrS Tested: 9.75 PRODUCTION FOR TEST PERIOD OIL-BBL: 465 GAS-MCF: 382 WATER-BBL: 937 CHOKE SIZE: 176 Bean GAS-OIL RATIO: 947 Flow Tubing Press. 157 Casing Press: 1,332 CALCULATED 24-HOUR RATE• OIL-BBL: 1,055 GAS-MCF: 999 WATER-BBL: 2,277 OIL GRAVITY-API (CORK): 21.5 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. r...,w..._.~ ..~_..~.... vOt=1i~'~E ~ i01~ None - ~~~ _ ~ ~ ~~ Form 10-407 Revised 02/2007 ~ ~ ~ ~ ! n ~ONTINUE ON REVERSE SIDE ~~t~~ ~ ~/~~-- I 28. GEOI OGIC MARKERS (LIST ALL FORMATIONS AN ERS ENCOUNTERED): 29. FORMATION TESTS NAME TVD Well Teste ^ 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' 6569' Base of Kuparuk A2 10788' 6571' Formation at Total Depth (Name): Base of Kuparuk A2 10788' 6571' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ' C ~~/~/ Si d gne Terrie Hubble Title Drilling Technologist Date Kuparuk 30-02AL2-01 207-161 Prepared ByNameMumber.~ Terrie Hubble, 564-4628 Well Number Permit No. / A royal NO. Drilling Engineer: Gary Eller, 529-1979 (Cell) INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a fisting of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only ' ~i • • BP 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. ~/Tl v ~y /~ l~' f-'~ ~ 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. a ~~ l` , ~ ~ 03:15 - 03:35 03:35 - 06:54 0.33 3.32 STWHIP STWHIP P P PROD4 PROD4 Discuss pressure deployment procedures and personnel tasks. Pressure deploy BHA 17 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 `2 ~ ~ ~1j -- ` packing off around the tool // 13:20 - 15:10 1.83 STWHIP P PROD4 Drilling ahead from 10,753' CP=3900 psi t ~ 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~17deg RT Den=9.86/9.94 ppg DH Press.=4532 psi; DH WOB=3200 Ib Pit Vol=276 bbls Changed TF to i 21 RT C~3 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 f~ 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 _~ •~ • i BP AMERICA Page 35 of 36 Operations Sumrnary 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 3/30/2008 108:15 - 09:00 I 0.751 DRILL P PROD4 Wiper trip to 10,400 ft 09:00 - 11:50 2.831 DRILL I P PROD4 11:50 - 13:27 I 1.621 DRILL I P I I PROD4 13:27 - 16:05 I 2.631 DRILL I P I I PROD4 16:05 - 17:35 1.50 DRILL P PROD4 17:35 - 21:00 3.42 DRILL P PROD4 21:00 - 22:00 I 1.001 DRILL I P i PROD4 22:00 - 00:00 I 2.001 DRILL P I I PROD4 13/31/2008 100:00 - 03:00 3.00 I DRILL I P I PROD4 03:00 - 03:30 I 0.501 DRILL I P I I PROD4 03:30 - 04:00 0.50 DRILL P PROD4 04:00 - 04:15 0.25 CASE P LNR4 04:15 - 06:00 1.75 CASE P LNR4 06:00 - 06:30 0.50 CASE P LNR4 06:30 - 07:55 1.42 CASE P LNR4 08:00 - 08:30 0.50 t CASE P LNR4 08:30 - 10:10 1.67 CASE P LNR4 10:10 - 10:45 0.58 CASE P LNR4 Little motor work at 10,765 ft Mud swap Tagged at 10,950 ft drilled to 11,100 ft MD Op = 1.46 / 1.44 bpm at 4000 psi off bottom pressure DHBHP /WHP = 4577 / 293 psi ECD at 6508 ft TVD = 13.56 PP9 TF 135R deg The geologist target is a moving icon at approximately 11,200 ft MD with a corresponding TVD of 6,498 ft Wiper trip and MAD Pass (10,777 ft to 10,830 ft) Logged MAD Pass as per Geologist Tagged at 11,100 ft MD and drilled to 11,250 ft Op = 1.54 / 1.1.55 bpm at 4100 psi off bottom pressure DHBHP /WHP = 4573 / 325 psi ECD at 6496 ftTVD = 13.56 PP9 TF 64R deg 11255 ft MD TVDss 6495 ft the build 2 ft to TD Wiper trip to 10, 265 ft, Clean up and down Tagged at 11,250 ft MD. Drilled to 11468 ft (approximately) Op = 1.50 / 1.1.51 bpm at 4135 psi off bottom pressure DHBHP /WHP = 4550 / 325 psi ECD at 6496 ftTVD = 13.61 PP9 TF 145E deg Projected TD at 11468 ft MD ; 6487 ft TVDss W iper trip from TD 11,468 up to 9575' Bit depth. Tie in Correction depth +6 ft. RIH tag TD ~ 11471 ft. POOH to 10,500ft. RIH to TD spot Hi Visc pill. Complete spotting 50 bbl Pill, est. from TD to 9,000 ft. Open Circ sub once above window. Continue pumping using MP guidelines while POOH. Close SSSV with 1250 psi on WH, bleed down ~ surface. Hold Safety meeting to discuss laying down BHA & P/U liner as per tally. Lay down BHA. Safety meeting for P/U liner & tally review. Start P/U liner. Crew change and PJSM with daylite Finish PU liner as per Llner Summary. Stab in injector. RIH with Liner. While Pressureing up on the wellhead, the CT pressure increased invertly and the pump was then shut down. CTP was bleed off Unstab injector to verify liner is still attached. Liner was still attached, Stab in injector. RIH with liner. Wt check at 9,900 ft = 21k RIH (open hole) with liner Tagged at 11471 ft MD Lined up through CT with fluid and release from liner with 4k W OS With Op at 1.5 bpm and CTP at 4500 psi PU on and lost 2000 LB of liner Printed: 4/11/2008 12:40:41 PM ,~ ~ • • BP AMERICA Page 36 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 3/31/2008 10:45 - 12:45 2.00 CASE P LNR4 POOH following MPD schedule. 12:45 - 13:20 0.58 CASE P LNR4 Closed SSSV and bleed top side WHP down to 0 psi. Unstab injector and PU CoilTrak BHA. Liner gone 13:20 - 15:20 2.00 CASE P LNR4 RIH with stinger BHA 15:20 - 15:55 0.58 CLEAN P CLEAN Displace well with seawater. Op= 1.86/1.74 bpm in/out CP=4000 psi. WHP=500 psi. in /out density at start 8.73/9.84 ppg. 15:55 - 17:30 1.58 CLEAN P CLEAN POOH displacing flo pro with SW and holding 1500 to 2000 psi on well Stopped at 2,500 ft and pumped 30 bbl of Diesel. 17:30 - 18:00 0.50 CLEAN P CLEAN Ct @ surface. Close SSSV, 1600 psi on WH, bleed down ~ surface. 18:00 - 18:30 0.50 CLEAN P CLEAN Crew change & Safety meeting reviewing Rig down procedure prior to removing injector. 18:30 - 19:00 0.50 WHSUR P CLEAN Remove BHA, displace and purge CT for rig move. 19:00 - 19:30 0.50 WHSUR P CLEAN Confirm SSSV is holding ,set BPV. "0" pressure ~ surface. 19:30 - 21:00 1.50 WHSUR P CLEAN Install CT grapple, Unstab CT from Injector. Remove injector legs and stripper. Set down injector on rig floor for maintenance. 21:00 - 21:15 0.25 BOPSU P POST Pre-job safety meeting for ND BOP stack and valves. 21:15 - 00:00 2.75 BOPSU P POST ND BOP's, valves and hard line to TT. Install tree cap and Pressure test to 4000psi. Rig released ~ midnight. Nnnted: ainrzuue irnu:ai rnn ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. ~ Kuparuk River Unit Kuparuk 30 Pad 30-02 30-OZAL2-01 TD Design: 30-02AL2-01 TD Baker Hughes INTEQ Survey Report i 03 April, 2008 ~~~r BAKER Nur~NEs 1NTEi~ f ConocoPhillips ~Gir BN~~ ConocoPhill~ s p Baker Hughes INTEQ Survey Report S Alaska INTEQ 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 Wellbore: 30-02AL2-01 TD Survey Calculation Method: Minimum Curvature Design: 30-02AL2-01 TD 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 Position +N/-S 0.00 ft Northing: 6,022,073.89ft Latitude: 70° 28' 17.128 N I, +E/-W 0.00 ft Easting: 525,490.94ft Longitude: 149° 4T 30.526 W I~ Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft Wellbore 30-02AL2-01 TD - _ Magnetics Model Name Sample Date Declination Dip Angle Field Strength bggm2007 10/24/2007 17.95 79.82 57,269 Design 30-02AL2-01 TD Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,740.64 Vertical Section: Depth From (TVD) +N/-S +E!-W Direction (ft) (ft) (ft) (°) 0.00 0.00 0.00 225.00 • r ~ ICI 4/3/2008 2:24:22PM Page 2 COMPASS 2003.16 Build 42F r ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc Project: Kuparuk River Unit Site: Kuparuk 30 Pad Weil: 30-02 Welibore: 30-02AL2-07 TD Design: 30-02AL2-01 TD Survey Program From (ft) 100.00 10,056.00 10,140.00 10,255.00 10,750.00 Survey MD (ft) 10,740.64 10,750.00 10,780.79 ', 10,810.19 10,857.22 10,888.53 10,903.51 ', 10,932.39 10,963.24 10,995.05 11,025.68 ', 11,061.38 11,089.22 ~I 11,118.48 11,147.03 11,174.08 11,203.17 ', 11,234.30 ', 11,265.40 Date To (ft) Survey (Welibore) 10,000.00 30-02 (30-02) 10,133.94 30-02A MWD TD {30-02A TD) 10,250.94 30-02AL1 MWD TD (30-02AL1 TD) 10,740.64 30-02AL2 MWD TD (30-02AL2 TD) 11,430.66 30-02AL2-01 (30-02AL2-01 TD) ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-ordinate Reference TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Tool Name description ri~r B Y~ YR4 Well 30-02 Mean Sea Level 30-02 @ 59.OOft (30-02) True Minimum Curvature EDMv16 Prod BOSS-GYRO Sperry-Sun BOSS gyro multishot MWD MWD -Standard MWD MWD -Standard MWD MWD -Standard MWD MWD -Standard __ Inc Azi TVDSS N/S E/W Northing Easting DLS Vertical Section (°) (°) (ft) (ft) (n) (n) (ft) (°1100ft) (ft) 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 94.70 33.10 6,518.01 4,586.34 -6,184.84 6,026,638.57 519,291.05 12.18 1,130.31 101.00 37.55 6,513.81 4,611.21 -6,167.22 6,026,663.50 519,308.58 24.97 1,100.27 100.62 41.86 6,508.29 4,633.42 -6,148.78 6,026,685.77 519,326.94 14.46 1,071.52 97.36 42.20 6,500.94 4,667.92 -6,117.68 6,026,720.37 519,357.92 6.97 1,025.14 96.12 47.32 6,497.27 4,689.99 -6,095.79 6,026,742.51 519,379.73 16.72 994.05 94.89 48.69 6,495.83 4,699.97 -6,084.71 6,026,752.53 519,390.77 12.26 979.16 92.21 49.85 6,494.04 4,718.77 -6,062.87 6,026,771.40 519,412.55 10.11 950.42 89.45 51.54 6,493.60 4,738.31 -6,039.01 6,026,791.02 519,436.34 10.49 919.73 89.42 55.14 6,493.91 4,757.30 -6,013.49 6,026,810.09 519,461.79 11.32 888.26 86.68 58.21 6,494.95 4,774.11 -5,987.92 6,026,827.00 519,487.30 13.43 858.29 86.90 62.22 6,496.95 4,791.81 -5,956.99 6,026,844.80 519,518.17 11.23 823.90 89.32 65.90 6,497.87 4,803.98 -5,931.98 6,026,857.05 519,543.14 15.81 797.61 90.18 69.67 6,498.00 4,815.04 -5,904.89 6,026,868.21 519,570.18 13.22 770.64 90.98 71.81 6,497.71 4,824.46 -5,877.94 6,026,877.71 519,597.09 8.00 744.93 91.94 71.85 6,497.02 4,832.89 -5,852.25 6,026,886.23 519,622.75 3.55 720.80 92.06 67.72 6,496.00 4,842.93 -5,824.98 6,026,896.37 519,649.99 14.19 694.41 94.49 65.05 6,494.22 4,855.38 -5,796.50 6,026,908.91 519,678.42 11.59 665.47 91.53 62.64 6,492.59 4,869.07 -5,768.63 6,026,922.69 519,706.24 12.27 636.09 TFO (°) 62.18 57.03 34.70 94.72 174.09 103.40 131.98 156.60 148.51 90.50 131.81 86.97 56.73 77.16 69.49 2.38 -88.26 -47.58 -140.82 • r~ ~I 4/3/2008 2:24:22PM Page 3 COMPASS 2003.16 Build 42F ConocoPhiflips Alaska Company: ConocoPhillips(Alaska) Inc. Protect: Kuparuk River Unit Stte: Kuparuk 30 Pad Well: 30-02 Weilbore: 30-02AL2-01 TD Design: 30-02AL2-01 TD Survey MD lft) 11,298.62 11,328.28 11,359.50 11,390.71 11,430.66 11,471.00 Casing Points ConocoPhillips ~~iir ` B~~S Baker Hughes INTEQ Survey Report 1N't'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 Inc Azl TVDSS NIS EIW Northing Easting DLS Vertical Section TFO (°) (°) lft) (ft) (ft) (ft) (ft) (°nooft) (ft) (°1 90.43 58.91 6,492.02 4,885.28 -5,739.65 6,026,939.01 519,735.16 11.70 604.13 -106.40 90.00 54.81 6,491.91 4,901.49 -5,714.82 6,026,955.30 519,759.94 13.90 575.11 -95.98 88.87 50.07 6,492.22 4,920.52 -5,690.08 6,026,974.41 519,784.61 15.61 544.16 -103.43 90.15 46.16 6,492.49 4,941.35 -5,666.85 6,026,995.32 519,807.76 13.18 513.01 -71.90 93.65 40.85 6,491.16 4,970.30 -5,639.38 6,027,024.35 519,835.14 15.91 473.11 -56.53 93.65 40.85 6,488.59 5,000.75 -5,613.04 6,027,054.89 519,861.36 0.00 432.96 0.00 Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (") (") 5,895.00 3,922.38 9 5/8" 9-5/8 12-1/4 __ Checked By: Approved By: Date: • 4/3/2008 2:24:22PM Page 4 COMPASS 2003.16 Build 42F r KRU 30-02 Producer 3'rz' TRDP SSSV at 1787' A-sand CTD Completion Updated 3/31/2008 3'/s", 9.3#, EUE 8rd Mod tubing w/ 3Yz' gas lift mandrels (six) Actual Drilled Footage = 8358' si:' surface casing shoe at 5930' • 3'/:" 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 (northern, upper) A2/3 Sand, TD ~ 11,471' Cement ramp exit, top of 2'/." slotted & solid liner 9940' - 11,471' cement -9970' MD . _ . _ _ . . AL1 Lateral (western, upper) ~~ ~' A2/3 Sand, TD @ 13,186' Aluminum billet ~~ 2'/." slotted liner 10,255' - 13,186' @ 10,255' ~~ ~ Aluminum billet _ _ _ _ _ _ _ ii @ 10,749' v ~ / V~kxlow n T' psing ~~ AL1-PB7 I @10,060'MD `` AL2 lateral (northern, lower) ............ 10.330' - 10,500' II ,~ ~~ ~ ~~ Al Sand, TD ~ 11,555' ~~ ~~ ~ ~~ 2'/." slotted liner 10,749' - 11,555' ~~ _ ~ ~i • ~ -:r _r==rr__r- ~~~-. -_ _ -~ ~ Asandperfs: ~~ ~ _ ~-_ _ _ _ _ 10,052' - 10,148' 'A' sidetrack (western, lower) 'A' barefoot segment (cemented Al Sand, TD C~ 13,180' ) 2'/," slotted liner 10,329' -13,180' 10,140' - 10,329' . . 7", 26 ppf, J-55 casing shoe at 10,392' Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Thursday, November 29, 2007 12:52 PM To: Gary Eller Cc: 'Hubble, Terrie L'; Venhaus, Dan E; 'Stephen F Davies' Subject: 30-02AL2-01 Gary, I am working to get the final permit out for the 30-OZA, et al. As we discussed, naming the final segment L3 does not agree with the convention adopted for naming laterals and smokes. In this case the segment is a spoke since it originates for a lateral, in this case L2. Just wanted to get a note out so everyone was aware of the change. Call or message with any questions. Tam Maunder, PE AOGCC 11 /29/2007 -,, ~ !~~ ~ l 9 t 'y y._ f I.~~ 1 1 ~R` ,~ ~.a ~.a ~..~ L~ ~~~~, ~..~ T ~ ~ ~~~ ~ ~ i..[ ~ ~ i. ~..+~ ~~ `~' ~ ~ ~ ~ °~~ ~LASSA OIL A1~TD Gr~5 CO1~T5ER~~iTIOrT COM~IIS5IOrIT Gary Eller CT Drilling Engineer Conoco Phillips Alaska Inc. PO Box 196612 Anchorage, Alaska 99519-6612 SARAH PALIN, GOVERNOR 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 FAX (907) 276-7542 Re: Kuparuk River Field, Kuparuk River Pool, 30-02AL2-O1 Conoco Phillips Alaska Inc. Permit No: 207-161 Surface Location: 745' FNL, 1855' FWL, SEC. 22, T13N, R09E, UM Bottomhole Location: 4277' FSL, 3712' 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. ou from obtaining additional permits or an This permit to drill does not exempt y royal required by law from other governmental agencies and does not authorize o erations until all other required permits and approvals have app drilling p ermit in conducting ht to withdraw the p been issued. In addition, the Commission reserves the rig the event it was erroneously issued. be conducted in accordance with AS ssion specifically authorizes a Operations must Title 20, of the Alaska Administrative Code unless the Commovision of AS 31.05, Failure to comply with an applicable p variance. or a Commission order, or the ermit ter 25 of the Alaska Adminisresult in the revocation or suspension of the p Chap ermit may re uired and conditions of this p resentative of the C mission to witness any q roviding notice for a rep 659-3607 (pager). When p etroleum fie ins ect r at (907) test, contact the Comrrussion's p ATED this "Li ~ day of N ovember ~ 2007 D e Habitat Section wI o encl. ent of Eri on ~ tal Conservation w / o encl. cc: Dept ent of STATE OF ALASKA ~~~ ALAS~IL AND GAS CONSERVATION COMMI~N \ ~~~ (~ 7 ~Q~~ PERMIT TO DRILL !~°r-~ Ian 20 AAC 25.005 ®t~:a~i~a f!]il ~+ ~8# ~~~!~: fVQ(~i1111S'b10t1, 1 a. Type of work f ^ 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 well is~aOt~F ~.:~-.~. [~'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: 30-02AL ~Q, 3. Address: c/o P.O. Box 196612, Anchorage, AK 99519-6612 6. Proposed Depth: MD 11625 TVD 6493ss 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface: 745' FNL 1855' FWL 22 T13N SEC R09E UM 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: 4277' FSL, 3712' 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 a 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: 10960 feet Maximum Hole An le: 101 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4995 Surface: 4335 1 .` Ca in Pr' ram: S ' caf ' ns To - Settin De' h - Bo tt m an " of m nt .f. or sack 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 1662' 9963' 6509' 11625' 6493'. Uncemented Slotted Liner 19. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrilt 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 ement Volume MD ND Conductor /Structural 115' 16" 199 sx Arcticse I I 115' 115' Surface 5930' 9-5/8" 1400 sx AS III, 400 sx'G', To Job: 100 sx AS I 5930' 4002' Intermediate Pr d i n 10392' 7" 315 sx Class 'G' 17 x S I 10392' 6773' Liner 2900' 3" Un emented Slotted Liner 30-02A 10300' - 13200' 6513' - 6518' Liner 2975' 3" Uncemented Slotted Liner 30-02AL1 10225' - 13200' 6513' - 6482' Lin r 670' Un emented Slott d Lin r 30- 2AL2 10 ' - 1163 ' 08' - 6523' 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 ce that the for oing is true and correct. Contact Gary Eller, 529-1979 (Cell) Printed Nam ary Eller Title CT Drilling Engineer Prepared By Name/Number: Si nature Phone 263-4172 Date ~ Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill PI Number: Z /~ /4. Number: ~?`~~ ~ 50-029-21837- -00 ermit Approval See cover letter for Date: other re uirem nts Conditions of Approval If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hyd tes, r gas contained shales: [~ Samples Req'd: Q Yes ~N Mud Log Req'd: ^ Yes ~No HZS Measures: Y e al Survey Req'd: Yes ^ No Other: y~ ~ s ~ ~~ ~ ~~ S Date ,!/~ ~ O APP D BY THE COMMISSION ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ~ (~~7.X`/ ~ ~~~ /~~ S bmit In Duplicate KRU 30-02 Quad Sidetrack/Laterals -Coil 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 AZ/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 A2/3 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. 4. Drawdown test on SCSSV. 5. Slickline tag fill and drift 3%" tubing. 6. Install dummy valves in GLMs 7. MTT-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 1. MIRU Nordic Rig #2 using 2" coil tubing. NU 7-1/16" BOPS, test. 2. Drill low-side pilot hole and cement ramp for exit at 10,060' MD. Mi112.74" window and 10' of open hole from 10,060' MD. 3. 30-02A Sidetrack (Western Lower) a. Drill pilot and cement ramp for high-side exit at 10,060' MD. b. Mi112.74" window with high-side orientation. The planned KOP is at 10,060' MD in the A sand. c. Dri113" bi-center horizontal `A' sidetrack southwest in the Al 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 (10,300' MD. 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 (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' MD. b. Kill well. Run 23/8" slotted liner with aluminum billet from TD up to X10,960' MD. _ 6. 2,3 Lateral (Northern Upper) 3D--c~aA~a-~ ~ a. Drill 3" bi-center horizontal AL3 lateral north in the A2/3 sands from 10,960' to TD at ''~ht S 11 625' MD. `~-~;,~~ , b. Kill well. Run 23/8" slotted liner with aluminum billet from TD up into the 3'/z" tubing tail at ~ ' 9963 MD. ' 7. Freeze protect. ND BOPE. RDMO Nordic 2. Page 1 of 3 November 2, 2007, FINAL KRU 30-02 Quad Sidetrack/Laterals -Coil 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 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. 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: 2%8", 4.6#, L-80, STL slotted liner from 10,960' MD to 11,630' MD • 3~9-9~~ 23/8", 4.6#, L-80, STL slotted liner from 9960' MD to 11,625' MD 30 oa ~,~_a.-o ~ Existing Casing/Liner Information Surface: 95/8", J-55, 36 ppf Production: 7", J-55, 26 ppf Burst 3520 psi; Collapse 2020 psi. 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 • ~I~ 9000' to property line, 1000' to 3R-19 at the toe ' ~o -~A~.a-o 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 3 ~ Quad Sidetrack/Laterals - Coil~Tubing Drilling Hazards • Expect to encounter increased pressure in the western laterals, particularly beyond a fault that will be encountered at ~l 1,500' 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. • Well 30-02 has 145 ppm H2S as measured on 1/22/07. Wells 30-O1 and 30-03 are adjacent to 30-02. 30-01 has 265 ppm H2S as measured on 1/22/07, and 30-03 has 140 ppm H2S as measured on 1/25/07. The maximum H2S level on the 30 pad is 265 ppm from we1130-01. All H2S 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 23/8" 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 well 30-02, so the well should not 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: 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, Inc. ~J 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: (1767-17a6. Annular Fluid: Last W/O: Rev Reason: NEW GLD OD:3.500) Reference L Ref L Date: Last U ate: 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 (35oe-3sos, 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 Lirt Size To Bottom ND Wt Grade Thread MandrelNalva 2 3.500 0 9963 6468 9.30 J-55 EUE 8RD AB MOD (s2ss-s257, Perforations Summa Interval ND 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 Lift EnerJet MandrelNalve 10072 - 10098 6542 - 6559 A-2 26 12 3/30/1989 APERF 60 deg. phasing; 2 1/8" 3 paasaaa7 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" (6x56-as5s, OD:4.750) EnerJet Gas LiR MandrelsNalves St MD ND Man Man Type V Mfr V Type V OD Latch Port TRO Date Vlv Gas Lift andreuoummy Mfr Run Cmnt Valves 1 3508 2542 MMH FHMO GLV 1.0 BK 0.125 1280 5/31/2006 (9zaa-seas' 4 OD 750 2 6256 4191 MMH FHMO GLV 1.0 BK 0.188 1351 5/31/2006 . : ) 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 (sa3s-9637, 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 PsR 9878 6411 PBR AVA 3.000 (x676-x679' OD 3 500 9891 6420 PKR AVA'RHS' 3.000 : . ) 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-sas2, De th Descri lion Comment OD:6.151) 10185 23' Stri Gun Lost in Hole General Notes Date Note NIP 4/4/1996 WAIVERED WELL: IA x OA COMMUNICATION (9928-9929, 00:3.500) TUBING (0-9963, OD:3.500, ID:2.992) Perf :10052-10066) Perf :10072-10098) _ Perf - 10102-10110) -- - Perf ',10110-10130) Perf '10130.10148) - 23' Slrip Gun ;10185-10208, OD:2.000) KRU 30-02 Producer 3'/z' TRDP SSSV at 1787' Proposed A-sand CTD Completion Footage Drilled = 8110' 3'/:", 9.3#, EUE 8rd Mod tubing w/ 3'/~' gas Updated 11 /2/2007 lift mandrels (six) 93~:'surface casing shoe at 5930' • • 3'/z' x 7" Baker RHS packer with PBR at 9891" • 2.75" D-nipple at 9928' • 3'/z" tubing tail at 9963' 2'/e" slotted liner top -9950' -__ _~ _ _ Window in T' 26/t J55 casing ~j~ ti , Cement ramp exit, top of t -9970' MD ~ I ~ / 10,060' MD @ . p , cemen ~ ---- % \\ Aluminum billet \V @ 10,225' - `` °° ~'' ` ~~~ a7 .~.L3iaieral (northem, upper) 625' TD @ 11 A2/3 Sand -- ~~ ~ - ° ~ ~ ~~ ~ ~~ . ~~ rac stern, upper) ' ° ~ , , o ~ A2/3 Sand, TD @ 13,200 ~~ _~ A sand perfs: .. 10 148' -_ = =~~ ~ ~ ~ 10 052' :: ::. '.< ~ \\ 1 \ _ , ~` - , ( lu ed) \ \ I 1 bill Al i t ~~ p gg ~~ - _; I 1 um num e II 11 @ 10,300' `` ~' `` AL2 lateral (northern, lower) Aluminum billet Att'tateral (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 S Baker Hughes INTEQ Planning Report uvTE Q Compsay; BP Amoco Date: 10/23/2007 Time: 15:50:38 Page: I Fief: Kuperuk Co-ordiaate(NE) Reference: Weil: 30-Q2, True North Stie: KRU 30 Pad Vertical (TVD) Reference: 30-02 Qrig Rig 59.0 Well: 30-02 Sectioe (VS) Reference: Weil (O.OON,O.OOE,45.OOAzi) Well~thr Plan 6, 30-02AL3 Survey Cakalatien Meti-od: Minimum Curvature Db: Orade 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: bggm2007 Site: KRU 30 Pad UNITED STATES :North Slope Site Position: Northing: 6022812 .21 ft Latitude: 70 28 24.450 N From: Map Eastiog: 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 Sbt Name: Well Position: +N/-S -744.80 ft Northing: 6022073.38 ft ~ Latitude: 70 28 17.123 N +E/-W 1856.56 ft Easting : 525491 .16 ft ~ Longitude: 149 47 30.520 W Position Uncertainty: 0.00 ft Wellpath: Plan 6, 30-02AL3 Drilled From: Plan 6, 30-02AL2 500292183762 Tie-on Depth: 10960.00 ft Current Datum: 30-02 Orig Rig H eight 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 Directioe 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 e--- Latitude --> <--- Longitude -a Name Description TVD +N/-S +E/-W Northing Easting Deb Min Sec Deg Min Sec Dip. Dir. ft ft ft ft ft 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 -Poygon 13 59.00 4224.20 -6170.34 6026276.01 518307.00 70 28 58.642 N 149 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 - on 15 ~ 59.00 4002.24 -6188.10 6026054.01 519290.00 70 28 56.458 N 149 50 32.539 W ,.39.02AL~ Target 1 6544.00 4714.42 -5927.63 6026767.01 519548.01 70 29 3.465 N 149 50 24.894 W ..,30-92~AL~3 Target 2 ~ 6547.00 4930.50 -5651.87 6026984.01 519823.01 70 29 5.592 N 149 50 16.787 W ~2t3^9Pftt'3 Target 3 6552.00 5023.23 -5569.54 6027077.01 519905.01 70 29 6.504 N 149 50 14.367 W ~_~,../' . by BP Alaska ~~$ Baker Hughes INTEQ Planning Report nvTE Q Company: BP Amoco Date: 10!23/2007 Time: 15:50:36 Page: 2 Field: Kuparuk Co-ordnate(1VE) Reference: Well: 30-02. True North Site: KRU 30 Pad Vertical (TVD) Reference: ' 30-02: Orig Rig 59.0 Well: 30-02 Sectro n (VS) Retere®cec Weil (0.00N,0.00E,45.00A2) , Wellpatb: Plan 6, 30-02AL a Sarvey Cakalation Method:.:. Minimum'Cwvature Db: Orade Aeaotation MD TVD ft_ ft 10960.00 6567,24 KOP -Tie to 30-02AL2 10980.00 6565.44 2 11000.00 6562.35 3 11078.00 6548.14 4 11128.00 6543.59 End of 20 Deg/100' DLS 11329.00 6544.92 6 11504.00 6547.27 7 11625.00 6551.97 TD Plan Section Information MD Inc! Azim TVD +N/-S +E/-W DIS Band Tara `1'FO Target ft deg deg ft ft ft deg/100ft`degl100ft deg/100ft deg 10960.00 93.17 61.03 6567.24 4661.86 -6092.15 0.00 0.00 0.00 0.00 10980.00 97.17 61.03 6565.44 4671.51 -6074.73 20.00 20.00 0.00 0.00 11000.00 100.63 63.07 6562.35 4680.77 -6057.28 20.00 17.29 10.17 30.00 11078.00 100.23 78.93 6548.14 4705.65 -5984.99 20.00 -0.51 20.33 90.00 11129.00 90.03 78.93 6543.59 4715.40 -5935.21 20.00 -20.00 0.00 180.00 11329.00 89.21 54.94 6544.92 4793.19 -5752.55 12.00 -0.41 -11.99 268.00 11504.00 89.27 33.94 6547.27 4917.43 -5630.72 12.00 0.03 -12.00 270.00 11625.00 86.30 19.71 6551.97 5025.03 -5576.29 12.00 -2.45 -11.76 258.00 Snrvey MD Inc! Azim SS TVD N/S E/W MapN MapE DLS VS TFO Tool ft deg deg tt ft ft ft ft deg/100ft ft deg > 10960.00 93.17 61.03 6508.24 4661.86 -6092.15 6026713.89 519383.68 0.00 -1011.37 0.00 MWD 10980.00 97.17 61.03 6506.44 4671.51 -6074.73 6026723.59 519401.07 20.00 -992.23 0.00 MWD 11000.00 100.63 63.07 6503.35 4680.77 -6057.28 6026732.91 519418.49 20.00 -973.34 30.00 MWD 11078.00 100.23 78.93 6489.14 4705.65 -5984.99 6026758.05 519490.68 20.00 -904.63 90.00 MWD 11100.00 95.83 78.93 6486.07 4709.84 -5963.62 6026762.30 519512.04 20.00 -886.56 180.00 MWD 11129.00 90.03 78.93 6484.59 4715.40 -5935.21 6026767.96 519540.43 20.00 -862.54 1$0.00 MWD 11200.00 89.73 70.41 6484.73 4734.15 -5866.80 6026786.95 519608.77 12.00 -800.90 268.00 MWD 11300.00 89.33 58.42 6485.56 4777.26 -5776.77 6026830.36 519698.63 12.00 -706.76 268.02 MVND 11329.00 89.21 54.94 6485.92 4793.19 -5752.55 6026846.36 519722.80 12.00 -678.37 268.12 MWD 11400.00 89.22 46.42 6486.89 4838.13 -5697.68 6026881.49 519777.51 12.00 -607.79 270.00 MWD 11500.00 89.26 34.42 6488.22 4914.12 -5632.97 6026967.69 519841.96 12.00 -508.30 270.12 MWD 11504.00 89.27 33.94 6488.27 4917.43 -5630.72 6026971.01 519844.19 12.00 -504.37 270.28 MWD 11600.00 86.90 22.66 6491.49 5001.77 -5585.31 6027055.49 519889.31 12.00 -412.63 258.00 MWD 11625.00 86.30 19.71 6492.97' 5025.03 -5576.29 6027078.79 519898.25 12.00 -389.80 258.38 2 3/8" • Kuparuk Managed Pressure Drillin• BOP Configuration for 2" Coil Tubing Well ~ 30-02 Floor Lubricator ID = 6.375" with 6" Otis Unions ^ 7 1/16" 5000 psi BOP's. ID = 7.06" ~~ 7 1/16" 5000 psi, RX-4f~ - 1/4 Turn LT Valve 7 1/16" 5000 psi RX-46~ Kill Line 1 L 2 1/16" 5000 psi , RX-24 Tree Size 3-1 /8", 5M 7 1116" 5000 psi (RX-46) or ~- 4 1116" 5000 psi (RX-39) Swab Valve Flow Tee I I ~ ~ I , ---- SSV Master Valve Base Flan e Page 1 ~~ TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ ~~~ ~z•~'G.3 2.~7-1~ Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT {OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore s gment of existing well ~~~ ~~ ' (If fast two digits in ?-~S8 API No. 50-~ Z./~3 7 ~• permit No API number are . Production should continue to be reported as a function of the between 60-69) original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(fj, all records, data and togs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- -_~ from records, data and togs acquired for well SPACING The permit is approved subject to full compliance with ZO AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing the exception. , assumes liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greatec 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 (Comp~nv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Con~any~Name) mmust contact the Commission to obtain advance approval of such water well testing ro am. Rev: 7/13/2007 ~ r ~^ 0 .~ _N O ~ i ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ W ~ ~ ~ ~ ~ ~ ~ = N ~ ~ C ~ ~ ~ ~ ~~ ~ ~i ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ; ~ ~ ~ ~ ~ ~ a• ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ O n ~ m m ~ ~ M O) a' 'C' ~ ~ ~ ~ ~ ~ ~ ~ ~ V! O ~ m ~ ~ ur t6 a c. 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