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Home My WebLink About207-159• Image Project Well History File Cr~~-er 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 HistoryFile Identifier Organizing (done) ^ Two-sided III IIIII II III II III ^ Rescan Needed III IIIII II II III III RES AN 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 P,vvfing III IIIIII IIIII II III BY: Maria Date: ~ © ~ ~' /s/ Scanning Preparation ~ x 30 = (~ + ~ t~' =TOTAL PAGES ~~ BY: Maria _ Date:` ~~ ~~' (Count does not include cover sheet) /s/ V Production Scanning Stage 1 Page Count from Scanned File: ~ (Count does include covers eet) Pa e Count Matches Number in Scan in Pre aration: V YES NO 9 9 p BY: Maria Date: ~ ~ ~~~ /s/ 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 IIIII Rescanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: o~a~,~~~kea uumiiuuuuii P P 10/6/2005 Wetl History File Cover Page.doc • ~_~, ~~ ~,~ :~ U~ ~~ ~~, .~ r . ~`~ .~ . .,-„~- ~. .. ,. ,... u ~. ti ,, -~ _ ~~ ~" .~ MICROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS.PAGE C:\temp\Temporary Internet. Files\OLK9\Microftlm_Marker.doc ConocoPhillips Alaska 30 -O2AL1 PB1 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 *I 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501 -3510 LIS P t.ANNE NO 20 00-R— ,..___9 7 Conoco Phillips Alaska 30 -02AL1 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 I Diskw/ David Douglas in lieu of sepia Electronic P.O. Box 196612 CGM TIFF LIS Anchorage, Alaska 99519 -6612 CHEVRON /KRU REP 1 ;ardccp y,rint, 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 *i 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501 -3510 LIS DATA SUBMITTAL COMPLIANCE REPORT 12/18/2008 Permit to Drill 2071590 Well Name/No. KUPARUK RIV UNIT 30-02AL1 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-21837-60-00 MD 10255 TVD 6518 Completion Date 3/31/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION ~ Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Log s Run: MWD DIR / RES / GR (data taken from Logs Portion of Master Well Oata 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 D Asc Directional Survey 10133 13185 Open 5/23/2008 'apt Directional Survey 10133 13185 Open 5/23/2008 ~D D Asc Directional Survey 10325 10500 Open 5/23/2008 PB 1 -Rpt Directional Survey 10325 10500 Open 5/23/2008 PB 1 ~, Well Cores/Samples Information: Interval Start Stop Sent Received Daily History Received? Formation Tops Sample Set Number Comments Name ADDITIONAL INFORMATION Well Cored? Y~ Chips Received? cY-ML_ Analysis ~ Received? Comments: Cj ~ ~,~,~~ ri ~ ~~~~ Compliance Reviewed By: __ _ __ ~l,`/N Od / N Dat~~_ t_ `fl oW 'V ~~ ~ i x BAKER. NL~HE I1~iTEt,~ 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: May 23, 2008 Please find enclosed directional survey data for wells: 30-02A 30-02AL1PB 1 30-02AL1 ~ 30-02AL2 30-02AL2-Ol 1R-O1BL1PB1 1R-O1BL1 1R-OlBLl-O1PB1 1R-O1BL1-O1 Enclosed is: lea 3.5" floppy diskette containing electronic survey file Cc: State of Alaska, AOGCC Christine Mahnken Page 1 of 1 Maunder, Thomas E (DOA) From: Maunder, Thomas E (DOA) Sent: Wednesday, May 07, 2008 11:29 AM To: 'Hubble, Terrie L' Subject: RE: - .78}-et al Terrie, ~~©~ ~L~ a~`1- 15~ 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. 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 '~%'" r~ ALASKA~IL AND GAS CONSERVATION COMA711SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 20AAC 25.105 zoAAC zs.»° ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1b. Well ClassflnCh01' ®Development ^~xploratory ^ Service ^ Stratigraphic 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aba ~ 3/31/2008 '~' 12. Permit to Drill Number 207-159 ~ 3. Address: c/o P.O. Box 196612, Anchorage, AK 99519-6612 6. Date Spudded ~ 3/17/2008 -V~ 13. API Number 50-029-21837-60-00' 4a. Location of Well (Governmental Section): Surface: 745' FNL 1855' FWL S C 7. Date T.D. Reached 3/24/2008 ~ 14. Well Name and Number: Kuparuk 30-02AL1 , , E . 22, T13N, 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: 2385' FSL, 1405' FEL, SEC. 17, T13N, R09E, UM 9. Plug Back Depth (MD+TVD) 13185' 6559' River Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 525491 y- 6022072 Zone- ASP4 10. Total Depth (MD+TVD) 13185' 6559' 16. Property D ignation: 3 ADL 025512 TPI: x- 519375 y- 6026098 Zone- ASP4 Total Depth: x- 516935 y- 6025179 Zone- ASP4 11. SSSV Depth (MD+TVD) 1787' 1585' 17. Land a Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1700' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and inted information er 20 AAC 25.071): MWD DIR / RES / GR !~/irf/GOiV G~ /Do2SS i~Jp 6ks ~G.S'ss~6~ 22. CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM' TOP BOTTOM >'SI2E CEMENTING RECORD PULLED 2-3l8" 4.44# L- 0 10256' 13185' 6577' 6559' 3" Uncemented Slotted Liner 23. Open to production or inject ion? ®Yes ^ No 24. ' TueING 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 10265' - 10357 6577 - 6570' Well Branch Well Branch 10389' - 11748' 6565' - 6540' 30-02AL'~. 30-02A 11,,, 25 ACID, FRACTURE, CEMENT SQUEEZE, ETC. 11751' - 12688' 6540' - 6543' Departs From Is not Directly DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED 12930' - 13184' 6545' - 6559' 30-02AL2-01 Accessible PTD # 207-161 , at 10255' MD (6577 TVD) 26. PRODUCTION TEST Date First Production: Reported on 30-02AL2-01 ~~-~ ~~ Method of Operation (Flowing, Gas Lift, etc.): See the 10-407 for 30-02AL2-01 (Dated 04/25108, PTD 207-161) for Production & Test Data Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing Press. CaSing PfeSS: 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 forth, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. I ~ , ~= ~ YiON_..V None ~ ~T~~ .~. _~ ~.~ ~~ l.. Form 10-407 Revised 02/2007. ,, CONTINUED N REVERSE .SIDE ~' ~ ~-~ ~ ~ [ACA L ~~--~~ ~~-~_ ~~, ~% ~~~iCI V E~ AI'R 2 5 2008 Alaska Uil & Gas Cons. Commissip>'t '28. GEOLQGIC MARKERS (LIST ALL FORMATIONS AN ERS 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 10360' 6570' Base of Kuparuk A3 11219' 6552' Top of Kuparuk A2 11918' 6549' Top of Kuparuk Al 12914' 6544' Formation at Total Depth (Name): Top of Kuparuk Al 12914' 6544' 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. O~I ~/ Signed Terrie Hubble Title Drilling Technologist Date Kuparuk 30-02AL1 207-159 Prepared By NameMumber. Te-rie Hubble, 564-4628 Well Number Permit No. / A rOVal NO. Drilling Engineer: Gary Eller, 529-1979 (Cell) INSTRUCTIONS GeNew-L: 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. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing 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. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: 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. Ire~- 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 3C ~~ 3~- ~ BP AMERICA Page 20 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 3/16/2008 17:10 - 18:00 0.83 STWHIP P PROD2 Time drill off billet, 10-15 fph. 1.5 bpm, 3925 psi, 0.8K WOB. Stacking wt, P/U several times and RIH to bottom. Drilled to 10336.0' 18:00 - 19:30 1.50 STWHIP P PROD2 Continue drilling at 10336.0'. Time drill from 10336.0' ~ 5'/hr w/ TF 30R HS. Op = 1.55 / 1.55 bpm Pt = 4000psi fs w/ 100 psi motor work. DHWOB = 0.75-1.5k# VP = 55 bbl ECD = 13.1 WHP = 300 DHT= 136 ST = 81 Had to PU start over due to stacking & had numerous 2k overpulls at 10336ft. Drill to 10350'. NBI shows that we are KO'd but shows a larger than expected jump in inclination. 19:30 - 20:45 1.25 STWHIP P PROD2 Ream 45 deg L&R of drilled TF to open up sidetrack until section is clean. Op=1.55/1.55 bpm Pt = 4000psi fs w/ 25 psi motor work. DHWOB = 0.25-0.5k# VP = 53 bbl ECD = 13.1 WHP = 300 Repeat 6 times. Smooth RIH & OH. 20:45 - 23:20 2.58 STWHIP P PROD2 PU through window to 10040'. RIH ~ 15ft/min to 10070'. No set downs in the window. POH following pressure schedule. Tag & trap 1200psi on well. Blow down chokes. 23:20 - 00:00 0.67 STWHIP P PROD2 Begin pressure undeploying BHA. C/O high pressure filter on the hardline in the reel house -filter was eroded & cracked, replace same. Circulate coil volume to purge reel w/ clean mud. Turn on gun lines & return mud across shaker to remove aluminum/debris from pits -fair quantity of aluminum/debris removed from active pits. 3/17/2008 00:00 - 01:10 1.17 STWHIP P PROD2 Continue to pressure undeploy BHA. 01:10 - 02:00 0.83 DRILL P PROD2 LD BHI coiITRAK tools on catwalk & purge/blow down same & reconfigure for resistivity. Bit was 2.73"go, partially plugged w/ aluminum from pumping it around from the pits. MU new 2-3/8" Xtreme mud motor w/ 0.9 AKO setting w/ new Hughes BC bit. Y-. ~~ C/O o-rings on LOC & clean out aluminum debris from LOC. ~ ~ Simultaneously, turn on guns lines from active pits returning across shaker again to remove solids from pits, recovered ~ ' more aluminum/debris. ' ~ 02:00 - 02:15 0.25 DRILL P PROD2 PJSM regarding pressure deploying BHA. 02:15 - 04:30 2.25 DRILL P PROD2 Begin pressure deploying lateral BHA. 04:30 - 06:30 2.00 DRILL P PROD2 RIH w/ lateral BHA following pressure schedule. 06:30 - 06:45 0.25 DRILL P PROD2 Tie-in to GR, +16' correction. 06:45 - 07:20 0.58 DRILL P PROD2 RIH, slight weight bobble when passing thru window, but went thru w/ no roblems. RIH to bottom. 07:20 - 09:15 1.92 DRILL P PROD2 Tag bottom at 10349.5'. Drill AL1 lateral at 1.55/1.55 bpm, 4100 psi, 60 fph ROP, 1.3k WOB, 98 deg incl, 15L TF, 13.5 ECD. Holding 300 psi WHP, BHP at 4590 psi. Drilled to 10427' ` 09:15 - 10:30 1.25 DRILL P PROD2 Drill AL1 lateral at 1.6/1.6 bpm, 4300 psi, 45-80 fph ROP, 0.6k ~~ (-f WOB, 95 deg incl, 90L TF, 13.6 ECD, 300 psi WHP, BHP at 4630 psi. ~ (~C 10:30 - 10:50 0.33 DRILL P PROD2 Drilled to 10500' Wiper to window. -/ ` 10:50 - 11:30 0.67 DRILL N DPRB PROD2 RIH, tag 3x at 10140'. Stall everytime we tag. S/D pumps, RIH dry and tag at 10140', stack wt and cant get thru. P/U, incr Printetl: 4/112008 12:40:41 PM $P AMERICA Page 21 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. 3/17/2008 10:50 - 11:30 0.67 DRILL N DPRB PROD2 pumps to 1.5 bpm, RIH, stall. P/U and slowly ream hole section. Ream w/ 100 psi motor work, 45L TF for 3' at 10-20 fph. WOB fell off but still had 50 psi motor work. Incr ROP to 50-100 fph, seems to be drilling w/ 150-200 psi motor work, 1.5K WOB, 45L TF, 100 fph. Drilled to 10159'. NBI indicated we were very close to as drilled wellbore, but did not drill enough to get a good survey. Appears we may be inadvertently sidetracked at 10140'. 11:30 - 13:00 1.50 DRILL N WAIT PROD2 PUH into tubing tail. Open EDC and circ. Discuss w/ town. Decide to POOH for 2.4 deg motor and BC bit. 13:00 - 14:30 1.50 DRILL N DPRB PROD2 POOH following pressure schedule. PJSM for pressure undeploying lateral drilling BHA. 14:30 - 16:10 1.67 DRILL N DPRB PROD2 Pressure undeploy BHA. Bit graded 1/1/i with 3 plugged nozzles. 16:10 - 18:00 1.83 DRILL N DPRB PROD2 L/D BHI tools on catwalk. M/U new BHI toolstring w/ 2.4 deg motor and HYC BC bit. 18:00 - 18:30 0.50 DRILL N DPRB PROD2 C/O w/ day crew. PJSM regarding pressure undeploying BHA. 18:30 - 20:15 1.75 DRILL N DPRB PROD2 Begin pressure undeploying BHA. Can't get motor/bend through BOP stack. Can't come up or down w/ tool string - we need a set of short spangs & WT bar for doing this kind of work! 20:15 - 21:20 1.08 DRILL N DPRB PROD2 Close TRSSSV & flow check well. PJSM regarding handling the stuck BHA. Pop off well & turn BHA w/wrenches. RD lubricator. MU tools to coil. Stab onto well. Power up & check tools. Set counters. 21:20 - 23:00 1.67 DRILL N DPRB PROD2 Pressure up well & open TRSSV. RIH following pressure schedule. Slightly tagged TRSSSV -possible trash building up behind flapper valve, will deal with it on the way OOH. 23:00 - 23:55 0.92 DRILL N DPRB PROD2 Log down from 9569ft for tie-in, missed the GR tie-in point. PU to 9549ft & re-log down (+28ft corr. 23:55 - 00:00 0.08 DRILL N DPRB PROD2 Continue to RIH. 3/18/2008 00:00 - 00:10 0.17 DRILL N DPRB PROD2 Continue to RIH. RIH through ramp/window was clean. RIH through OH section w/out pumps ~ 30ft/min & set down at 10159ft w/drilled TF. PU was clean. 00:10 - 00:45 0.58 DRILL N DPRB PROD2 Start pumping at 1.44bpm & RIH ~ HS past 10160ft then drilled TF to 10330ft. PU was clean to 10114ft. 00:45 - 01:10 0.42 DRILL N DPRB PROD2 RIH w/out pumps w/ HS TF ~ 15ft/min & set down ~ 10159ft. PU was clean. RIH pumping w/ HS TF to 10192. PU to 10118ft & try to back ream (drilled TF) a little but was clean. RIH w/out pumps w/ HS TF & tag ~ 10159ft. 01:10 - 02:30 1.33 DRILL N DPRB PROD2 Slowly PUH from 10159ft to 8500ft following pressure schedule & discuss w/ town eng & formulate a plan forward. 02:30 - 03:00 0.50 DRILL N DPRB PROD2 RIH following pressure schedule. 03:00 - 03:20 0.33 DRILL N DPRB PROD2 Log down for tie-in from 9565ft (+8ft). 03:20 - 04:30 1.17 DRILL N DPRB PROD2 RIH. Start pumping ~ 1.5bpm/4000psi w/ HS TF. Tag up at 10159ft, we are fighting the stops on the coil. Try 3 times. Coil has too much torque/twist & can't seem to compensate for 7F changes by the time we get to 10150ft. PU to 10100ft. Try different speeds & yo-yo pipe/pump for 3 more times with & w/out pumps. Try different TF's L & R of HS. 04:30 - 05:30 1.00 STKOH N DPRB PROD2 Set down 10158ft & get 0.5k WOB & start pumps & drill to 10161ft. WOB fell off. R1H & can't. PU & start over. Go to 10164ft. Stop & PU & discuss w/ town. ~~ BP AMERICA Page 22 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 3/18/2008 05:30 - 06:40 1.17 STKOH N DPRB PROD2 Begin OH side track from 10164ft ~ 60fUhr w/ TF 45R HS. Op = 1.43 / 1.41 bpm Pt = 4000psi fs w/ 100 psi motor work. DHWOB = 0.75-2.5k# VP = 441 bbl ECD = 13.28 WHP = 300 DHT= 136 ST = 76 Build NBI to 88 deg. Drilled to 10194'. 06:40 - 07:45 1.08 STKOH N WAIT PROD2 P/U and wait on orders from town. Discussing directional plan. PUH into tubing tail. Attempt to open EDC, but having trouble opening. 07:45 - 10:35 2.83 DRILL N DFAL PROD2 EDC at an unknown position. Have to POH for EDC failure. POOH following pressure schedule. Circulating thru kill line due to EDC problem. Saw 3K Ib overpulls going thru SSSV. PJSM for UD BHA. 10:35 - 11:20 0.75 DRILL N DFAL PROD2 Unsure of EDC position. Close TRSSSV. Flow check. S/B injector, UD BHA. 11:20 - 13:45 2.42 DRILL N DFAL PROD2 M/U new BHI toolstring on catwalk. C/O depth counter wheel on injector. 13:45 - 14:00 0.25 DRILL N DFAL PROD2 PJSM for P/U lateral drilling BHA. 14:00 - 15:25 1.42 DRILL N DFAL PROD2 P/U lateral drilling BHA w/ res tool, 1.1 deg motor, HYC BC bit. Stab injector. Set counters. 15:25 - 17:40 2.25 DRILL N DFAL PROD2 Pressure well & open TRSSV. RIH following pressure schedule. RIH past TRSSV -clean. PU through TRSSV - clean. 17:40 - 17:50 0.17 DRILL N DFAL PROD2 Log down for tie-in from 9580ft (+4ft). 17:50 - 18:20 0.50 DRILL N DFAL PROD2 RIH. Tied in at 9608 ft and correcte plus 4 ft. RIH and tagged at 10,195ft 18:20 - 19:50 1.50 DRILL P PROD2 Drilling lateral with 1.1 AKO Motor. Op = 1.48 / 1.49 bpm CTP (OffB) = 4000 psi BHP = 4566 psi w/ ECD at 13.5 ppg WHP = 227 psi Density = 9.86 / 9.88 ppg Vp = 425 bbl 19:50 - 20:15 0.42 DRILL P PROD2 Wiper and then orient TF to build up through shale section Ran MAD pass from 10,166 ft to10,195 ft 20:15 - 23:25 3.17 DRILL P PROD2 Drilling lateral with 1.1 AKO Motor. Turned TF at HS to drill through shale Op = 1.48 / 1.49 bpm CTP (OffB) = 4000 psi BHP = 4566 psi w/ ECD at 13.6 ppg WHP = 223-322 ps i Density = 9.86 / 9.88 ppg Vp = 426 bbl ROP = 20-60 fph with 1.00 to 1.50 klbf WOB 23:25 - 23:50 0.42 DRILL P PROD2 Wiper trip 23:50 - 00:00 0.17 DRILL P PROD2 Drilling lateral with 1.1 AKO Motor. Op = 1.48 / 1.49 bpm CTP (Off6) = 4087 psi BHP = 4675 psi w/ ECD at 13.8 ppg WHP = 223-322 psi Density = 9.86 / 9.9 ppg Vp = 416 bbl ROP = 50 fph with 1.00 to 1.50 klbf 3/19/2008 00:00 - 03:11 3.18 DRILL P PROD2 Drilling lateral with 1.1 AKO Motor. Walking TF around to the left to try and stay in the polygon. Op = 1.48 / 1.49 bpm CTP (OffB) = 4087 psi On bottom P = 4160 psi rnntea: an vzuuo IZ:4V:41 rm ~~ $P AMERICA Page 23 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 3/19/2008 00:00 - 03:11 3.18 DRILL P PROD2 BHP = 4675 psi w/ ECD at 13.8 ppg WHP = 223-322 ps i Density = 9.86 / 9.9 ppg Vp = 410 bbl ROP = 40-50 fph 03:11 - 03:35 0.40 DRILL P PROD2 Wiper trip and tie in at 10,125 ft 03:35 - 03:45 0.17 DRILL P PROD2 RIH at correct TF logging tie in at 150 fpm and a Op = 0.33 bpm. WHP = 600 psi ,BHP = 4484 psi, 13.38 ppg ECD No correction, Geologist wanted to correct 0.15 ft and WSL nix the idea 03:45 - 04:00 0.25 DRILL P PROD2 RIH and increased Qp at 10,200 ft to 1.45 bpm 04:00 - 06:15 2.25 DRILL P PROD2 Drilling lateral with 1.1 AKO Motor. Op = 1.50 / 1.50 bpm CTP (Off6) = 4087 psi On bottom P = 4260 psi BHP = 4638 psi w/ ECD at 13.6 ppg WHP = 253 psi Density = 9.86 / 9.9 ppg Vp = 395 bbl ROP = 40-60 fph 06:15 - 06:45 0.50 DRILL P PROD2 Drilling lateral with 1.1 AKO Motor from 10670ft w/ TF 90L HS: Op = 1.50 / 1.50 bpm CTP (OffB) = 4087 psi On bottom P = 4050 psi BHP = 4520 psi w/ ECD at 13.4 ppg WHP = 200 psi Density = 9.89 / 9.97 PP9 Vp = 395 bbl ROP = 40-60 fph Turn on centrifuge 'A' & 'B' Turn on gun lines from active system & return across shaker to remove solids. Drill to 10700ft. 06:45 - 07:15 0.50 DRILL P PROD2 Wiper from 10700ft to 10145ft, 20fUmin ~ 1.5bpm/4000psi - clean. 07:15 - 07:45 0.50 DRILL P PROD2 Reduce rate to 0.45bpm/2000psi while wiper from 10145ft to 10200ft holding 600psi WHP. Increase to 1.5bpm/4000 from 10200ft to TD reduceing WHP to 250psi. Wiper was clean. 07:45 - 09:50 2.08 DRILL P PROD2 Drilling lateral with 1.1 AKO Motor from 10700ft w/ TF 90L HS. Op = 1.56 / 1.53 bpm CTP (Off6) = 3800 psi On bottom P = 4275 psi BHP = 4636 psi w/ ECD at 13.74 ppg WHP = 200 psi Density = 9.89 / 9.97 ppg Vp = 402 bbl ROP = 30-80 fph Drill to 10850ft. 09:50 - 10:30 0.67 DRILL P PROD2 Wiper from 10850ft to 10150ft, 20ft/min ~ 1.5bpm/4000psi - clean, PU wt = 21 k. 10:30 - 11:00 0.50 DRILL P PROD2 Reduce rate to 0.45bpm/2000psi while wiper from 10145ft to 10200ft holding 600psi WHP. Increase to 1.5bpm/4000 from 10200ft to TD & reduce WHP to 250psi. Wiper was clean. RIW = 6k. 11:00 - 13:15 2.25 DRILL P PROD2 Drilling lateral with 1.1 AKO Motor from 10850ft w/ TF 95L HS. rrirned: 4n uzuua 1Z:4U:41 YM BP AMERICA Page 24 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 3/19/2008 11:00 - 13:15 2.25 DRILL P PROD2 Op = 1.55 / 1.58 bpm CTP (OffB) = 4065 psi On bottom P = 4200 psi BHP = 4636 psi w/ ECD at 13.73 ppg WHP = 275 psi Density = 9.84 / 9.84 ppg Vp = 405 bbl ROP = 30-80 fph Drill to 11000ft 13:15 - 14:00 0.75 DRILL P PROD2 W iper from 11000ft to 10150ft, 20ft/min ~ 1.5bpm/3900psi - clean, PU wt = 22k. 14:00 - 14:05 0.08 DRILL P PROD2 Reduce rate to 0.45bpm/2000psi while wiper from 10145ft to 10200ft holding 600psi WHP. Increase to 1.5bpm/4000 from 10200ft to TD & reduce WHP to 250psi -clean 14:05 - 14:20 0.25 DRILL P PROD2 Log down for tie-in from 10350ft (+2ft). 14:20 - 14:50 0.50 DRILL P PROD2 Increase rate to 1.5bpm/3890psi & wiper from 10386ft to 11000ft holding 300psi WHP -clean. 14:50 - 17:00 2.17 DRILL P PROD2 Drilling lateral with 1.1 AKO Motor from 11000ft w/ TF 90L HS. Op = 1.50 / 1.50 bpm CTP (Off6) = 3900 psi On bottom P = 4000 psi BHP = 4630 psi w/ ECD at 13.70 ppg WHP = 300 psi Density = 9.83 / 9.82 ppg Vp = 405 bbl ROP = 30-80 fph Drilled to 11150ft 17:00 - 17:35 0.58 DRILL P PROD2 Wiper from 11150ft to 10150ft, 20ft/min ~ 1.5bpm/3900psi - clean, PU wt = 23k. 17:35 - 18:22 0.78 DRILL P PROD2 Reduce rate to 0.45bpm/2000psi while wiper from 10150ft to 10200ft holding 600psi WHP. Increase to 1.5bpm/4000 from 10200ft to TD & reduce WHP to 300psi 18:22 - 21:21 2.98 DRILL P PROD2 Tagged bottom at 11,150 ft. Wiper trip good. Drilling Lateral in Kuparuk A2 Sand at per Geologist. Objective is 6487 ft TVD and then level out to 90 deg. Turned TF to 90R at 11,230 ft and 150R at 11,290 ft. Op = 1.55 / bpm at CTP of 4000 psi off bottom Density = 9.82 / 9.69 ppg BHP /WHP = 4721 psi (13.99 ppg) / 311 psi. Dropped WHP to 240 psi BHP at 4650 psi Vp = 391 bbl's 21:21 - 22:56 1.58 DRILL P PROD2 Wiper trip after drilling 150 ft lateral 22:56 - 00:00 1.07 DRILL P PROD2 Tagged bottom at 11,300 ft. Wiper trip good. Now they want to climb up to 6,482' (5 ft TVD extra) and then cross cut back down again to 11,450 ft Drilling Lateral in Kuparuk A2 Sand at per Geologist. TF at 120R to 90R Op = 1.51 /bpm at CTP of 3970 psi off bottom Density = 9.82 / 9.69 ppg BHP /WHP = 4680 psi (13.89 ppg) / 300 psi. 3/20/2008 00:00 - 03:15 3.25 DRILL P PROD2 Drilling Lateral in Kuparuk A2 Sand as per Geologist. TF at 90R Op = 1.51 /bpm at CTP of 3970 psi off bottom Density = 9.84 / 9.75 ppg BHP /WHP = 4715 psi (14.00 ppg) / 308 psi. rnniea: vn iicv~a icrv.ri rm BP AMERICA Page 25 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 3/20/2008 00:00 - 03:15 3.25 DRILL P PROD2 Tagged the Fault ? at 11,394 ft, ROP slowed down to nothing. 03:15 - 04:20 1.08 DRILL P PROD2 '04:20 - 06:10 1.83 DRILL P PROD2 06:10 - 09:25 3.25 DRILL P PROD2 09:25 - 10:40 1.25 DRILL P PROD2 10:40 - 11:35 0.92 DRILL P PROD2 11:35 - 11:50 0.25 DRILL P PROD2 11:50 - 13:05 1.25 DRILL P PROD2 13:05 - 15:25 2.33 DRILL P PROD2 15:25 - 16:40 1.25 DRILL P PROD2 16:40 - 17:50 1.17 DRILL P PROD2 17:50 - 19:10 1.33 DRILL P PROD2 19:10 - 21:50 2.67 DRILL P PROD2 Starting the mud swap at 11,393 ft (01:30 hrs) Took 1.5 hrs to get through. Sample art 11,400 showed increas in pyrite Drilling Lateral in Kuparuk Mid A2 Sand Op = 1.51 /bpm at CTP of 3970 psi off bottom Density = 9.82 / 9.90 ppg BHP /WHP = 4615 psi (13.86 ppg) / 297 psi. 'Finished Mud swap at 03:45 hrs Wiper trip -clean. Drilling lateral with 1.1 AKO Motor from 11450t w/ TF 90R HS in A2 sand. Op = 1.55 / 1.58 bpm CTP (OffB) = 4000 psi On bottom P = 4200 psi BHP = 4675 psi w/ ECD at 13.85 ppg WHP = 300 psi 0.8-1.5K WOB 5k Surface WT Density = 9.84 / 9.84 ppg Vp = 405 bbl ROP = 30-60 fph Drill to 11600ft. Wiper trip, 20fUmin 1.5bpm/3900psi. Motor work at 11520ft to 11515ft. Otherwise clean. Pull through window/ramp area -clean. Open EDC ~ 9900ft & circulate max rate 1.9bpm/4100psi while PUH ~ 21ft/min following pressure schedule. Log down for tie-in from 9585ft (+5ft corr. C/O shaker screen. RIH through ramp/window area -clean. Pump min rate past window to 10200ft. Increase rate to 1.4bpm/3700psi & wiper to TD. Slight motor work ~ 11520ft - 11525ft. Drilling lateral with 1.1 AKO Motor from 11604ft w/ TF 45R HS in A2 sand. Op = 1.5 / 1.5 bpm CTP (OffB) = 3850 psi On bottom P = 4200 psi BHP = 4675 psi w/ ECD at 13.89 ppg WHP = 300 psi 0.8-1.5K WOB 5k Surface WT Density = 9.83 / 9.86 ppg Vp = 359 bbl ROP = 30-60 fph Drilled to 11750ft. Wiper trip, slight motor work at 11520ft-11525ft, otherwise clean. Wiper to TD, clean, no motor work at 11525ft (suspect it's TF change related). Drilling lateral with 1.1 AKO Motor from 11750ft w/ TF 125R HS in A3 sand. Op = 1.5 / 1.5 bpm CTP (Off6) = 3850 psi On bottom P = 4200 psi BHP = 4675 psi w/ ECD at 13.82 ppg WHP = 300 psi 0.8-1.OK WOB 5k Surface WT Density = 9.83 / 9.80 ppg Vp = 363 bbl ROP = 30-80 fph The ankerite bed we drilled up through last night we found again going down tonight at 11820 ft. Printed: 4/11/2008 12:40:41 PM 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: Date From - To Hours 'Task Code NPT Phase 3/20/2008 19:10 - 21:50 2.67 DRILL P PROD2 21:50 - 00:00 I 2.171 DRILL I P 3/21/2008 00:00 - 01:30 1.50 DRILL P 01:30 - 03:35 2.08 DRILL P 03:35 - 06:50 3.25 DRILL P 06:50 - 08:35 1.75 DRILL P PROD2 08:35 - 08:45 0.17 DRILL P PROD2 08:45 - 10:10 1.42 DRILL P PROD2 10:10 - 13:20 3.17 DRILL P PROD2 13:20 - 14:20 1.00 DRILL P PROD2 14:20 - 16:05 1.75 DRILL P PROD2 16:05 - 18:00 1.92 DRILL P PROD2 18:00 - 19:30 1.50 DRILL P PROD2 19:30 - 22:15 2.75 DRILL P PROD2 22:15 - 00:00 1.75 DRILL P PROD2 Page.26 of 36 Spud Date: 10/2/1988 End: 3/31 /2008 Description of Operations Objective; drill down to 12050 ft (-6500 TVDss) and 90 deg Op = 1.5 / 1.5 bpm CTP (Off6) = 3870psi On bottom P = 4200 psi BHP = 4664 psi w/ ECD at 13.85 ppg WHP = 300 psi 0.8-1.OK WOB 5k Surface WT Density = 9.81 / 9.66 ppg Vp = 363 bbl ROP = 30-80 fph Working through ankrite bed TF 50L Op = 1.52 / 1.52 bpm CTP (OffB) = 3870psi On bottom P = 4043 psi BHP = 4647 psi w/ ECD at 13.80 ppg WHP = 340 psi Density = 9.81 / 9.66 ppg Vp = 354 bbl, ROP = 3-40 fph Drilled to 11,900 ft Wiper trip. Drilling lateral Hit another hard spot (ankerite) at 11,915 ft. The ankerite bed at 11,920 ft Op = 1.52 / 1.52 bpm CTP (OffB) = 3870psi On bottom P = 4175 psi BHP = 4708 psi w/ ECD at 13.98 ppg WHP = 340 psi Density = 9.81 / 9.66 ppg Vp = 341 bbl, ROP = 20-70 fph Wiper trip -clean. Log down for tie-in ~ 10350ft (+3.5ft). W iper to TD -clean. Drilling lateral in A3 sands from 12,050 ft. Op = 1.52 / 1.52 bpm CTP (Off6) = 3910psi On bottom P = 4055 psi BHP = 4696 psi w/ ECD at 13.91 ppg 0.8-1.65K WOB -2k Surface WT WHP = 245 psi Density = 9.86 / 9.96 ppg Vp = 341 bbl, ROP = 20-50 fph Drill to 12200ft Wiper trip. Motor work through the ankerite sections. W iper to trip to bottom was clean. Drilling lateral in A2 sands from 12,200 ft. Op = 1.49 / 1.48 bpm CTP (Off6) = 3810psi On bottom P = 3950 psi BHP = 4722 psi w/ ECD at 14.00 ppg 0.8-1.65K WOB -2k Surface WT WHP = 245 psi Density = 9.86 / 9.96 ppg Vp = 321 bbl, ROP = 30-60 fph Drilling Lateral Started Mud swap Op = 1.58 / 1.54 bpm CTP (OffB) = 3810psi On bottom P = 4000 psi BHP = 4722 psi w/ ECD at 14.00 ppg 0.8-1.65K WOB -2k Surface WT WHP = 245 psi Density = 9.86 / 9.96 ppg Vp = 321 bbl, ROP = 30-60 fph Wiper trip Drilling Lateral in Kup A2 1 Will drill to 12,400 ft at 6,490 ft PROD2 PROD2 PROD2 PROD2 rnmeu: Yn ucwo IL:YU.YI rm $P AMERICA Page 27 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 3/21/2008 22:15 - 00:00 1.75 DRILL P PROD2 TVD ss then to 12,500 ft 6,485 ft at 91 deg TF at 90LHS Op = 1.55 / 1.56 bpm CTP (OffB) = 3856psi On bottom P = 4000 psi BHP = 4637 psi w/ ECD at 13.73 ppg WHP = 275 psi Density = 9.77 / 9.70 ppg Vp = 266 bbl, Finishing mud swap ROP = 30-70 fph Some gas cut mud to surface, increased WHP to 350 psi, isolated 1 pit. circulated out and density increased back to 9.8 PP9 3/22/2008 00:00 - 01:10 1.17 DRILL P PROD2 Drilling lateral as per Geologist CT WOB -6700 Ib at surface and DHWOB = 1.1 klb 01:10 - 03:10 2.00 DRILL P PROD2 Wiper trip to 10,360 ft Log tie in with 450 psi WHP BHP = 4512 psi (13.34ppg ECD) Correct 5.5 ft 03:10 - 04:35 1.42 DRILL P PROD2 RIH and tagged at 12504 ft following tie-in correction 04:35 - 05:30 0.92 DRILL P PROD2 Drilling Lateral in Kup A2 TF at 90-70 L and try and hold 91 deg. Op = 1.51 / 1.50 bpm CTP (Off6) = 3812psi On bottom P = psi BHP = 4707 psi w/ ECD at 13.79 ppg WHP = 300 psi Density = 9.80 / 9.80 ppg Vp = 359 bbl, CROP = 90 fph DHWOB at 0.9k and CTW at -60001b. Getting close 05:30 - 07:00 1.50 DRILL P PROD2 Having trouble getting WOB due to wellbore configuration. Drilled to 12,548 ft and CTW at -7k. Unable to get back to 12, 548 ft presently. Make 1000 ft wiper trip to see if we can get down 07:00 - 10:00 3.00 DRILL P PROD2 Drilling Lateral in Kup A2 TF at 90-70 L from 12548ft. Op = 1.51 / 1.50 bpm CTP (OffB) = 3812psi On bottom P = 3920 psi BHP = 4700 psi w/ ECD at 13.89 ppg WHP = 320 psi Density = 9.77 / 9.72 ppg ~ Vp = 359 bbl, DHWOB at 0.9k and CTW at -40001b. Drilled to 12644ft & stacking wt. 10:00 - 12:00 2.00 DRILL P PROD2 Wiper to window -clean. Stop pumping & PU through window/ramp -clean. Open EDC ~ 9900ft & jet ~ max rate while PU to 9500ft. 12:00 - 12:30 0.50 DRILL P PROD2 Log down for tie-in from 9565ft (+6ft corr. 12:30 - 14:15 1.75 DRILL P PROD2 Close EDC &RIH through window/ramp, weight bobble at 10065ft. Pump 0.45bpm/1900psi while RIH past 10200ft. 14:15 - 15:50 1.58 DRILL P PROD2 Drilling Lateral in Kup A2 TF at 105-90 L from 12644ft. Op = 1.59 / 1.59 bpm CTP (Off6) = 4000psi On bottom P = 4050psi BHP = 4660 psi w/ ECD at 13.86 ppg WHP = 300 psi Density = 9.79 / 9.82 ppg Vp = 344 bbl, DHWOB at 0.9k-1.1 k and CTW at -60001b. Drilled to 12699ft. Hit something hard at 12699ft. Found an agitator! 15:50 - 19:40 3.83 DRILL P PROD2 POH for agitator. Pull through window/ramp -clean. Open EDC & jet max rate while POH.Jetted SSSV area with open EDC POOH and increased WHP to 950 psi, closed SSSV and it holds. 19:40 - 21:15 1.58 DRILL P PROD2 POOH, tagged up, checked flow, OK LD BHA and motor and bit (2-1) rnnteu: anvzuue ~cau:ai rnn $P AMERICA. Page 28 of 36 Operations Summary Report Legal Well Name: 30-02 Common Well Name: 30-02 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Spud Date: 10/2/1988 Start: 2/1 /2008 End: 3/31 /2008 Rig Release: 3/31 /2008 Rig Number: Date From - To ..`Hours Task Code NPT 'Phase 3/22/2008 19:40 - 21:15 1.58 DRILL P PROD2 21:15 - 22:45 1.50 DRILL P PROD2 22:45 - 23:00 0.25 BOPSU P PROD2 23:00 - 23:15 0.25 DRILL P PROD2 23:15 - 00:00 0.75 DRILL P PROD2 13/23/2008 00:00 - 00:30 0.50 DRILL P PROD2 00:30 - 02:23 1.88 DRILL P PROD2 02:23 - 02:40 0.28 DRILL P PROD2 02:40 - 05:00 2.33 DRILL P PROD2 05:00 - 05:30 0.50 DRILL I P I PROD2 05:30 - 05:50 0.331 DRILL P PROD2 05:50 - 08:00 2.171 DRILL P (PROD2 08:00 - 09:55 1.92 DRILL P PROD2 09:55 - 11:35 1.67 DRILL P PROD2 11:35 - 14:55 3.331 DRILL P PROD2 14:55 - 16:55 2.00 DRILL P PROD2 16:55 - 19:00 2.08 DRILL P PROD2 19:00 - 00:00 5.001 DRILL P PROD2 Description of Operations Lined out flow loop through Swaco choke and applied 950 psi to well head. Maintain a constant WHP while circulating at 0.25 bpm. Replaced pack-offs, counter assembly and o-ring seals on the 2" hydraulic RIH side of injector. Wipe down 480 injector. BHI checking coiltrac PJSM on CDL. Slip and cut drilling PJSM on Function testing BOP's. Function test same PJSM on PU BHA SD and trapped 950 psi on wellhead. bleed pressure off the top and confirmed the integrity of the SSSV. OK PU BHA and scribed offset on MWD tool Finish MU BHA RIH with BHA with MPD technique. Stopped at 1750 ft and open SSSV with equal pressure. RIH Logged GR marker (Plus 11 ft) RIH, (no problem in the ramp or window area). RIH with correct TF and following pressure schedule Tagged bottom at 12,699 ft . Pp high,4300 psi) with agitator Op = 1.45 / 1.47 bpm CTP = 4142 psi On bottom 4350 psi Density = 9.77 / 9.73 ppg BHP /WHP = 4628 / 300 psi ECD = 13.73 ppg Vp = 326 bbl Gas cut mud at surface, divert to tiger tank. Increased WHP to 400 psi, PU off bottom and work Notified 30 Pad Operator of the gas venting. Took 25 bbl of gas cut mud to tiger tank Tagged bottom at 12,726 ft . Op = 1.45 / 1.47 bpm CTP = 4195 psi On bottom 4350 psi Density = 9.77 / 9.00 ppg Still cleaning up BHP /WHP = 4713 / 300 psi ECD = 14.00 ppg Vp = 310 bbl Drilled to 12,850ft. Wiper trip to 10,150ft w/ 1.45bpm/4250psi -clean. Reduce to min mate while RIH from 10145ft to 10200ft. Increase to 1.4bpm/4100psi while RIH. Very ratty below 12800ft. Drilling Lateral in Kup A2 from 12850ft TF at 90-70 R Op = 1.43 / 1.43 bpm CTP = 4241 psi On bottom 4440 psi Density = 9.77 / 9.83 ppg BHP /WHP = 4725 / 350 psi ECD = 14.03 ppg Vp = 291 bbl DHWOB at 0.9k-1.5k and CTW at -65001b. ROP 40-70 fph Wiper trip to 10,150ft w/ 1.45bpm/4250psi -clean. Reduce to min mate while RIH from 10145ft to 10200ft. Increase to 1.4bpm/4100psi while RIH. Little drag at 12, 800 to 12, 850 ft, worked through. Tagged bottom at 13,025 ft Tagged bottom at 13,024 ft. Drilled lateral from 13,024 ft at Rside TF Op = 1.39 / 1.35 bpm Had to drop the Op to 1.37 bpm due to high CTP CTP = 4250 / 4570 psi WOB / DHWOB = 0.56k / 1500 Ibf Vp = 273 bbl ROP is 20 to 40 fph Printed: 4/11/2008 12:40:41 PM . ~ ~ -BP AMERICA Page 29 of 36 Operations Summary 'Report Legal Well Name: 30-02 Common Well Name: 30-02 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Start: 2/1 /2008 Rig Release: 3/31/2008 Rig Number: Spud Date: 10/2/1988 End: 3/31 /2008 Date From - To Hours Task Code NPT Phase ( Description of Operations 3/24/2008 00:00 - 00:25 0.42 DRILL P PROD2 00:25 - 02:45 2.33 DRILL P PROD2 02:45 - 03:15 0.50 DRILL P PROD2 03:15 - 05:15 2.00 DRILL P PROD2 05:15 - 10:30 5.251 DRILL P PROD2 10:30 - 10:45 0.25 DRILL P PROD2 10:45 - 11:00 0.25 DRILL P PROD2 11:00 - 12:00 1.00 DRILL P PROD2 12:00 - 12:15 0.25 DRILL P PROD2 12:15 - 15:00 2.75 CASE P LNR2 15:00 - 17:55 ~ 2.92 ~ CASE ~ P ~ ~ LNR2 17:55 - 21:04 I 3.15 I CASE I P I I LNR2 21:04 - 21:30 0.43 CASE P LNR2 21:30 - 22:10 0.67 CASE P LNR2 13/25/2008 22:10 - 00:00 00:00 - 01:10 1.83 1.17 CASE CASE P P LNR2 LNR2 01:10 - 03:25 ~ 2.25 ~ CASE ~ P ~ ~ LNR2 03:25 - 06:35 3.17 CASE P LNR2 06:35 - 07:15 0.67 CASE P LNR2 Drilling lateral to a TD of 13,1870 ft MD and 6500 ft TVDss. W iper trip to tie-in to 10166 ft RIH to 10365 ft. Logged 10,365 ft 10394 ft and corrected +8 ft RIH to confirm TD. Had trouble with the shales at 12,800 to 12,900 ft. Used lower flowrates and various speeds to get from 12,800 ft to 13, 180 ft. Tagged at 13,185 ft POOH laying in 1 ppb beads, spotted only in open hole. Reduce pulling speed at 10,900ft & increase pump rate & CBU, divert to tiger tank as needed due gas in returns. Continue to POH following pressure schedule. SD pumps & pull through window/ramp area -clean. Start pumping ~ 9900ft while POH following pressure schedule -swap to hand choke due to bead issues packing off MI choke. Close TRSSV & flow check. Continue POH pumping. Tag up, stop pumping. Flow check well. PJSM regarding LD BHA. Pop off well. Break off coil from BHI tools. Place injector over bung hole & circulate. Blow down/purge BHI's tools w/ water/air & LD on catwalk. Oil agitator prior to storage & test same - good vibrations. Smith bit was same condition prior to running. Prep BHI tools for running liner. C/O elevators. PJSM regarding running liner. MU liner per program. PU BHI tools w/ knuckle jt & 3" Hyd GS. MU coil to tools. Stab injector onto well. Pump down backside & pressure up well to 1200psi. Open TRSSSV. RIH following pressure schedule while pumping down backside to assist W HP stabilization. WT ck ~ 9900ft, 6k RIW, 23k up wt. RIH through ramp/window -clean. Log down ~ 10990ft for tie-in (+17ft corr. Continue to RIH. RIW = -5.5k # 13,000ft. Tag bottom at 13,186ft. PU to 13,175ft = 28k. Tag bottom at 13,186ft. Line up down coil & pump at 1.5bpm ~ 4500psi holding 400psi WHP. PU & release from liner, 20k up. SD pumps & trap 900 psi while slowly PUH, 22k up. POH pumping 0.87bpm/3150psi following pressure schedule. OOH and closed SSV with 1150 psi on well LD liner setting BHA PJSM on handling tubulars /liner PU and RIH with liner Finish PU liner as per Summary. Held PJSM on PU BHI's Coiltrac and BOT AI Billet. PU Same and stabbed on injector head Set counter at 1538.62 ft Set Swaco pressure set point to 1350 psi RIH with 1340 psi on well head down the backside. Wt check at 9890 ft = 22,000 Ib Run in wi 4klb. (WHP = 12000 psi). RIH Wt check at 11700 ft = 2.4 at 20 fpm. RIH and tagged at 11,739 ft. DH WO shoe at 2.7k Released from liner and PU, lost 4000 Ib of liner wt. Top of liner at 10,256'. POOH maintaining WHP Tagged up, closed SSSV and released topside WHP. Confirmed SSSV integrity. Continue OOH filling tubing. Flow check -good. PJSM regarding LD BHA. Pop off well. Blow down/purge BHI's tools with water/air. LD same BHA on Printed: 4/11/2008 12:40:41 PM • • ~~~ ~~ BP AMERICA Page 30 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 3/25/2008 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 & 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. 09:10 - 10:45 1.58 STWHIP P PROD3 Head up BHI's UOC. 10:45 - 11:20 0.58 STWHIP P PROD3 Pull test CTC to 30k -good. Pressure test to 4000psi -good. 11:20 - 17:30 6.17 BOPSU P PROD3 Perform weekly BOPE test per AOGCC regs. State witnessed by John Crisp. Pressure tested to 250psi/4500psi -PASS. 17:30 - 18:30 1.00 BOPSU P PROD3 Crew change and take on 200 bbl of new flo-pro 18:30 - 18:53 0.38 BOPSU P PROD3 PJSM with crew on PT the inner valve. Discuss hazards and miigated hazards 18:53 - 20:00 1.12 BOPSU P PROD3 PU inject and stab on well) to test inner reel valve and stripper 20:00 - 20:30 0.50 BOPSU P PROD3 Completed pressure test of all Surface equipment. Close SSSV check for flow ~ surface. 20:30 - 21:00 0.50 BOPSU P PROD3 Safety meeting/procedure review prior to P/U BHA. 21:00 - 21:20 0.33 STWHIP P PROD3 Deploy BHA #26, 2-3/8" Xtreme with 2.730" STR324 PDC Bit. Total BHA lenght 61.97ft. 21:20 - 21:30 0.17 STWHIP P PROD3 Make up Injector, RIH to 175' CTMD, pressure up WHP to 1150 psi & open SSSV. Continue to RIH 21:30 - 23:00 1.50 STWHIP P PROD3 Slow speed, tie in depth 9564ft CTMD. 23:00 - 23:30 0.50 STWHIP P PROD3 Adjusted depth + 10.5 ft (9605ft to 9615.5ft), continue RIH. 23:30 - 00:00 0.50 STWHIP P PROD3 Slow speed from 10,000 ft, stop pumping ~ 10,050ft through window. Ta ed Billet Plu ~ 10,256 pumps at min. rate. 3/26/2008 00:00 - 00:10 0.17 STWHIP P PROD3 Tagged billet ~ 10,256 ft P/U and increase pump rates to 1. bpm, start sidetrack ~ 10,255 ft CTMD. Establish good 1:1 returns holding 400 psi WHP using 9.8# MW. 00:10 - 01:20 1.17 STWHIP P PROD3 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. /~ 01:20 - 03:34 2.23 STWHIP P PROD3 Timed mill off of billet to 10,259 ft 03:34 - 06:11 2.62 STWHIP P PROD3 Drilling to 10, 270 ft and back reamed above 10,250 ft TF at 15R HS Backed reamed at 30L, 15R and 60R TF U 06:11 - 06:30 0.32 STWHIP P PROD3 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 06:30 - 07:30 1.00 STWHIP N DFAL PROD3 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. 07:30 - 09:10 1.67 STWHIP N DFAL PROD3 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 09:10 - 09:55 0.75 DRILL N DFAL PROD3 Changed out Motor (1.5 deg AKO) and PU RR STC BC bit ST bit is plugged with Alumium and stator rubber 09:55 - 11:35 1.67 DRILL N DFAL PROD3 Set counters and RIH, Pressured up on the WH to 1200 psi Printed: anvzoos tz:ao:at rnn ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 30 Pad 30-02 30-02AL1 PB1 TD Design: 30-02AL1 PB1 TD Baker Hughes INTEQ Survey Report 03 April, 2008 ~~~~ BAKER N~I~HEa*i INTE(,~ C~ ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 30 Pad Well: 30-02 Welibore: 3O-02AL1PB1 TD Design: 30-02AL1PB1 TD ConocoPhillips Baker Hughes INTEQ Survey Report A.rr BAI~R II~+t~Es LNTEQ 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 Position +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° 4T 30.526 W ', Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft Welibore 30-02AL1P61 TD Magnetics Model Name Sample Date Declination Dip Angle Fieid Strength bggm2007 10/24/2007 17.95 79.82 57,269 Design 30-02AL1PB1 TD Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 10,325.10 ~~ Vertical Section: Depth From (TVD) +NI-S +E/-W Direction (ft) (ft) (n) (°) 0.00 0.00 0.00 225.00 4/3/2008 2:20:05PM Page 2 COMPASS 2003.16 Build 42F / ConocoPhillips ~G~r r " ConoeoPh~tl~ s p Baker Hughes INTEQ Survey Report BAllls 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 Q 59.OOft (30-02) Well: 30-02 North Reference: True Wellbore: 30-02AL1 PB1 TD Survey Calculation Method: Minimum Curvature Design: 30-02AL1P61 TD Database: EDMv16 Prod Survey Program Date From To (ft) (ft) Survey (Wellbore) Tool Name Description 100.00 10,000.00 30-02 (30-02) BOSS-GYRO Sperry-Sun BOSS gyro multishot I, • 10,056.00 10,325.10 30-02A MWD TD (30-02A TD) MWD MWD -Standard 10,329.00 10,459.29 30-02AL1P61 TD (30-02AL1P61 TD) MWD MWD-Standard Survey MD Inc Azi TVDSS N/S FJW Northing Easting DLS Vertical Section TFO (ft) (°) (°) (ft) (ft) (ft) 1ft1 Ift) (°/100ft) (ft) (°) 10,325.10 91.17 303.20 6,512.80 4,120.90 -6,273.11 6,026,172.87 519,204.38 13.30 1,521.84 86.67 10,329.00 91.10 303.57 6,512.72 4,123.04 -6,276.36 6,026,175.01 519,201.12 9.65 1,522.63 100.71 10,359.67 100.37 302.53 6,509.66 4,139.67 -6,301.91 6,026,191.54 519,175.51 30.41 1,528.94 -6.32 10,395.76 99.00 301.30 6,503.59 4,158.47 -6,332.11 6,026,210.24 519,145.26 5.07 1,536.99 -138.39 10,428.31 96.11 300.19 6,499.31 4,174.97 -6,359.84 6,026,226.64 519,117.47 9.50 1,544.94 -159.08 10,459.29 94.36 297.85 6,496.48 4,189.93 -6,386.82 6,026,241.51 519,090.45 9.41 1,553.43 -126.79 10,500.00 94.36 297.85 6,493.39 4,208.89 -6,422.71 6,026,260.35 519,054.50 0.00 1,565.40 0.00 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) lft) Name (") (") 5,895.00 3,922.38 9 5/8" 9-5/8 12-1/4 Checked By: Approved By: Date: 4/3/2008 2:20:05PM Page 3 COMPASS 2003.16 Build 42F ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 30 Pad 30-02 30-02AL1 TD Design: 30-02AL1 TD Baker Hughes INTEQ Survey Report 03 April, 2008 r~,~r BAKER Nu~NEs INTEQ • i d ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 30 Pad Well: 30-02 Wellbore: 30-02AL1 TD Design: 30-02AL1 TD ConocoPhillips Baker Hughes INTEQ Survey Report see r Mu+rir~s - ' INTEQ 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 ; :~ Weil Position +N/-S 0.00 ft Nortliing: 6,022,073.89 ft Latitude: 70° 28' 17.128 N '~ +E/-W 0.00 ft Easting: 525,490.94ft Longitude: 149° 4T 30.526 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft i Wellbore 30-02AL1 TD Magnetics Model Name Sample Date Declination (°) Dip Angle (°- _.. BGGM2007 3/20/2008 17.77 Design 30-02AL1 TD Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: Vertical Section: Depth From (TVD) +N/-S +E/-W 0.00 0.00 0.00 Field Strength (nT) 79.83 57,286 10,133.94 Direction (°) 300.08 \J 4/3/2008 2:18:50PM Page 2 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 30 Pad Well: 30-02 Wellbore: 30-02AL1 TD Design: 30-02AL1 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 13,137.06 30-02AL1 MWD TD (30-02AL1 TD) Survey MD Inc (ft) (°) 10,133.94 73.15 10,140.00 74.51 10,163.36 76.94 10,191.99 88.28 ', 10,221.14 89.85 ~, 10,250.94 90.06 ', 10,279.08 89.36 10,301.89 92.70 10,325.78 96.09 10,350.58 99.53 ', 10,380.18 99.94 10,409.71 98.18 10,440.12 95.57 10,470.63 93.38 ', 10,501.50 91.78 10,530.28 92.00 ', 10,560.26 90.83 10,590.17 89.48 ', 10,643.31 88.25 ~, 10,670.70 89.02 ConocoPhillips Baker Hughes INTEQ Survey Report sa~R r Il~t~les - iN~rEQ 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 Tool Name Description BOSS-GYRO Sperry-Sun BOSS gyro multishot ', MWD MWD -Standard ', MWD MWD -Standard Azl TVDSS N/S E/W Northing Easting DLS Vertical Section (°) (ft) (ft) (ft) (ft) (ft) (°/100ft) (ft) 304.09 6,506.02 4,040.05 -6,101.68 6,026,092.62 519,376.07 12.63 7,304.87 302.18 6,507.71 4,043.23 -6,106.56 6,026,095.78 519,371.18 37.68 7,310.68 305.01 6,513.47 4,055.76 -6,125.41 6,026,108.25 519,352.29 15.69 7,333.27 313.58 6,517.15 4,073.71 -6,147.31 6,026,126.12 519,330.33 49.47 7,361.22 318.86 6,517.63 4,094.75 -6,167.46 6,026,147.09 519,310.10 18.89 7,389.21 323.13 6,517.65 4,117.90 -6,186.22 6,026,170.17 519,291.27 14.35 7,417.04 326.34 6,517.79 4,140.87 -6,202.46 6,026,193.09 519,274.95 11.68 7,442.61 325.79 6,517.38 4,159.79 -6,215.19 6,026,211.96 519,262.16 14.84 7,463.11 325.24 6,515.55 4,179.42 -6,228.67 6,026,231.54 519,248.61 14.37 7,484.61 324.42 6,512.18 4,199.50 -6,242.82 6,026,251.58 519,234.39 14.25 7,506.92 320.54 6,507.18 4,222.64 -6,260.59 6,026,274.65 519,216.55 12.99 7,533.89 317.20 6,502.52 4,244.60 -6,279.77 6,026,296.54 519,197.30 12.66 7,561.49 313.70 6,498.88 4,266.11 -6,300.94 6,026,317.97 519,176.05 14.29 7,590.60 309.86 6,496.50 4,286.37 -6,323.62 6,026,338.15 519,153.31 14.46 7,620.38 305.90 6,495.11 4,305.30 -6,347.96 6,026,357.00 519,128.91 13.82 7,650.92 302.97 6,494.16 4,321.56 -6,371.68 6,026,373.18 519,105.13 10.20 7,679.60 299.78 6,493.42 4,337.16 -6,397.26 6,026,388.69 519,079.50 11.33 7,709.56 296.34 6,493.34 4,351.23 -6,423.65 6,026,402.67 519,053.06 12.35 7,739.45 290.04 6,494.39 4,372.14 -6,472.46 6,026,423.41 519,004.19 12.08 7,792.17 286.90 6,495.05 4,380.81 -6,498.43 6,026,431.99 518,978.19 11.80 7,818.98 TFO 30.88 -53.72 48.82 37.50 73.49 87.19 102.31 -9.35 -9.17 -13.23 -83.55 -117.81 -126.69 -119.61 -111.92 -85.66 -110.10 -111.42 -101.10 -76.26 4/3/2008 2:18:50PM Page 3 COMPASS 2003.16 Build 42F ConocoPhiflips Alaska Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 30 Pad Well: 30-02 Welibore: 30-02AL1 TD Design: 30-02AL7 TD Survey ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-ordinate Reference: Well 30-02 ~~.r - B~~$ . - TVD Reference: Mean Sea Level MD Reference: 30-02 @ 59.OOft (30-02) North Reference: True Survey Calculation Method: Minimum Curvature Database: EDMv1ti Prod MD Inc Azl TVDSS NIS E/W Northing Easting DLS Vertical Section TFO l~) (°) (°) (~) (nl (ft) (ft) (ft) (°/100ft) (ft) (°) 10,703.59 89.48 283.08 6,495.48 4,389.32 -6,530.19 6,026,440.39 518,946.40 11.70 7,850.73 -83.16 ', 10,748.57 89.23 277.49 6,495.98 4,397.35 -6,574.43 6,026,448.26 518,902.14 12.44 7,893.03 -92.59 ', 10,788.09 88.83 272.26 6,496.65 4,400.70 -6,613.79 6,026,451.48 518,862.78 13.27 7,928.77 -94.42 10,813.53 89.72 269.11 6,496.98 4,401.01 -6,639.22 6,026,451.70 518,837.35 12.87 7,950.93 -74.25 10,849.61 89.29 263.59 6,497.29 4,398.71 -6,675.21 6,026,449.28 518,801.37 15.35 7,980.92 -94.47 ', 10,881.84 90.03 259.63 6,497.48 4,394.01 -6,707.09 6,026,444.47 518,769.51 12.50 8,006.15 -79.43 10,914.08 89.57 255.83 6,497.59 4,387.16 -6,738.59 6,026,437.51 518,738.04 11.87 8,029.97 -96.91 ', 10,946.26 87.85 252.63 6,498.32 4,378.42 -6,769.54 6,026,428.67 518,707.12 11.29 8,052.38 -118.29 ', 10,973.12 86.46 249.42 6,499.65 4,369.70 -6,794.91 6,026,419.86 518,681.78 13.01 8,069.96 -113.51 ~I 10,996.36 85.05 247.21 6,501.37 4,361.13 -6,816.44 6,026,411.22 518,660.28 11.26 8,084.30 -122.69 ', 11,025.39 86.77 243.71 6,503.44 4,349.11 -6,842.78 6,026,399.11 518,633.99 13.41 8,101.06 -63.90 ', 11,055.49 89.26 240.43 6,504.48 4,335.02 -6,869.35 6,026,384.93 518,607.47 13.68 8,116.99 -52.85 ', 11,085.55 91.26 237.78 6,504.35 4,319.59 -6,895.14 6,026,369.41 518,581.73 11.04 8,131.57 -52.96 11,115.23 92.24 233.88 6,503.44 4,302.93 -6,919.68 6,026,352.67 518,557.25 13.54 8,144.46 -75.83 11,145.95 94.89 231.21 6,501.53 4,284.29 -6,944.02 6,026,333.95 518,532.98 12.23 8,156.17 -45.08 11,175.23 97.24 227.89 6,498.44 4,265.40 -6,966.17 6,026,314.99 518,510.90 13.84 8,165.88 -54.39 11,203.26 97.31 224.30 6,494.89 4,246.13 -6,986.20 6,026,295.65 518,490.94 12.71 8,173.54 -88.65 11,232.51 94.59 221.63 6,491.85 4,224.84 -7,006.02 6,026,274.30 518,471.19 13.00 8,180.03 -135.54 ', 11,261.78 94.68 226.06 6,489.49 4,203.80 -7,026.23 6,026,253.19 518,451.06 15.09 8,186.97 88.65 ', 11,291.30 92.92 229.72 6,487.53 4,184.06 -7,048.07 6,026,233.37 518,429.28 13.73 8,195.97 115.60 li 11,322.25 91.14 233.64 6,486.43 4,164.88 -7,072.34 6,026,214.12 518,405.09 13.90 8,207.36 114.36 11,356.52 91.63 236.70 6,485.60 4,145.32 -7,100.45 6,026,194.46 518,377.04 9.04 8,221.88 80.86 11,388.29 92.98 239.78 6,484.33 4,128.61 -7,127.44 6,026,177.66 518,350.11 10.58 8,236.86 66.26 11,421.05 92.02 245.03 6,482.90 4,113.46 -7,156.44 6,026,162.41 518,321.17 16.28 8,254.35 100.25 ', 11,450.48 89.94 247.69 6,482.39 4,101.66 -7,183.39 6,026,150.52 518,294.26 11.47 8,271.76 128.00 11,480.12 89.75 251.72 6,482.47 4,091.38 -7,211.18 6,026,140.15 518,266.50 13.61 8,290.66 92.70 ', 11,511.79 88.53 256.70 6,482.95 4,082.77 -7,241.64 6,026,131.43 518,236.08 16.19 8,312.70 103.80 4/3/2008 2:18:50PM Page 4 COMPASS 2003.16 Build 42F • .-- ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc Project: Kuparuk River Unit Site: Kuparuk 30 Pad Well: 30-02 Wellbore: 30-02AL1 TO Deslgn: 30-02AL1 TD Survey ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: ri.r B~~t; LNTEQ Well 30-02 Mean Sea Level 30-02 @ 59.00ft (30-02) True Minimum Curvature EDMv16 Prod MD Inc Azi TVDSS N/S E/V11 Northing Easting DLS Vertical Section TFO (~) (°) t°) tft) (ft) (ft) (~) lft) (°/100ft) lft) (°) 11,539.69 86.69 258.71 6,484.11 4,076.83 -7,268.88 6,026,125.40 518,208.87 9.76 8,333.29 132.53 ', 11,570.53 87.88 256.27 6,485.57 4,070.16 -7,298.95 6,026,118.63 518,178.82 8.79 8,355.97 -64.04 11,600.71 88.87 252.79 6,486.43 4,062.11 -7,328.02 6,026,110.48 518,149.78 11.98 8,377.09 -74.17 ', 11,629.90 91.29 250.00 6,486.39 4,052.80 -7,355.68 6,026,101.08 518,122.16 12.65 8,396.36 -49.07 ', 11,660.03 92.21 243.99 6,485.47 4,041.04 -7,383.39 6,026,089.22 518,094.49 20.17 8,414.44 -81.21 11,691.00 94.68 241.13 6,483.61 4,026.80 -7,410.82 6,026,074.89 518,067.11 12.19 8,431.04 -49.06 ', 11,721.47 92.12 238.67 6,481.80 4,011.54 -7,437.13 6,026,059.55 518,040.86 11.64 8,446.16 -136.11 ', 11,767.19 88.37 234.93 6,481.60 3,986.52 -7,475.37 6,026,034.39 518,002.70 11.58 8,466.70 -135.05 11,797.03 87.97 232.10 6,482.56 3,968.79 -7,499.35 6,026,016.58 517,978.79 9.57 8,478.56 -98.09 ', 11,827.47 87.57 228.42 6,483.74 3,949.34 -7,522.73 6,025,997.06 517,955.47 12.15 8,489.05 -96.28 11,855.40 86.28 225.94 6,485.24 3,930.39 -7,543.19 6,025,978.04 517,935.09 10.00 8,497.25 -117.58 ', 11,883.58 85.26 221.28 6,487.32 3,910.05 -7,562.57 6,025,957.63 517,915.78 16.88 8,503.83 -102.54 11,911.82 85.05 217.82 6,489.71 3,888.35 -7,580.48 6,025,935.88 517,897.94 12.23 8,508.46 -93.63 11,940.89 84.31 213.85 6,492.40 3,864.89 -7,597.43 6,025,912.36 517,881.08 13.83 8,511.36 -100.78 11,976.77 85.08 214.92 6,495.72 3,835.41 -7,617.60 6,025,882.81 517,861.01 3.66 8,514.04 54.19 12,000.02 85.39 218.21 6,497.65 3,816.80 -7,631.40 6,025,864.16 517,847.27 14.16 8,516.65 84.74 .12,030,12 86.41 221.57 6,499.80 3,793.77 -7,650.65 6,025,841.07 517,828.10 11.64 8,521.77 73.20 12,060.36 89.75 225.52 6,500.82 3,771.87 -7,671.47 6,025,819.10 517,807.36 17.10 8,528.80 49.85 ', 12,090.18 91.35 229.61 6,500.53 3,751.76 -7,693.47 6,025,798.91 517,785.43 14.73 8,537.76 68.62 ', 12,120.69 92.02 232.30 6,499.63 3,732.55 -7,717.15 6,025,779.62 517,761.82 9.08 8,548.62 75.97 12,150.38 93.43 236.50 6,498.22 3,715.29 -7,741.26 6,025,762.28 517,737.77 14.91 8,560.83 71.33 ', 12,180.20 93.74 240.59 6,496.36 3,699.76 -7,766.64 6,025,746.67 517,712.44 13.73 8,575.01 85.53 12,210.18 91.87 243.54 6,494.89 3,685.74 -7,793.10 6,025,732,55 517,686.04 11.64 8,590.87 122.32 12,239.72 90.92 247.95 6,494.17 3,673.61 -7,820.01 6,025,720.33 517,659.17 15.27 8,608.09 102.10 12,273.33 91.26 251.43 6,493.53 3,661.95 -7,851.52 6,025,708.57 517,627.70 10.40 8,629.51 84.39 12,302.76 92.55 254.27 6,492.55 3,653.27 -7,879.63 6,025,699.80 517,599.63 10.59 8,649.48 65.52 ', 12,334.06 92.48 257.47 6,491.18 3,645.64 -7,909.95 6,025,692.06 517,569.34 10.22 8,671.89 91.18 4/3/2008 2:18:50PM Page 5 COMPASS 2003.16 Build 42F \J ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc, Project: Kuparuk River Unit Site: Kuparuk 30 Pad Weli: 30-02 Wellbore: 30.02AL1 TD Design: 30-02AL1 TD Survey MD (n) 12,367.66 12,397.02 ', 12,429.14 ', 12,454.68 12,483.23 12,510.70 12,541.97 12,570.07 12,599.90 ~', 12,630.14 ', 12,660.54 ', 12,691.34 12,720.27 ', 12,751.43 ', 12,780.38 ', 12,810.05 ', 12,840.17 ', 12,870.10 12,899.83 I 12,930.26 12,961.82 12,994.84 13,022.68 13,052.45 ', 13,080.53 ', 13,109.27 13,137.06 ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: N.r is ~at~s - INT'EQ Well 30-02 Mean Sea Level 30-02 @ 59.OOft (30-02) True Minimum Curvature EDMv16 Prod Inc Azi TVDSS NIS EIVY Northing Easting DLS Vertical Section TFO (°) (°) lft) (n) (ft) (~) (ft) (°1100ft) (ft) !°) 91.56 256.76 6,489.99 3,638.15 -7,942.68 6,025,684.46 517,536.64 3.46 8,696.46 -142.35 90.49 253.19 6,489.47 3,630.54 -7,971.02 6,025,676.76 517,508.32 12.69 8,717.17 -106.65 92.88 249.94 6,488.52 3,620.39 -8,001.48 6,025,666.50 517,477.91 12.56 8,738.43 -53.62 92.30 247.27 6,487.37 3,611.09 -8,025.23 6,025,657.12 517,454.19 10.69 8,754.32 -102.21 91.23 244.89 _ 6,486.49 3,599.52 -8,051.31 6,025,645.46 517,428.15 9.14 8,771.10 -114.18 90.37 241.97 6,486.11 3,587.23 -8,075.88 6,025,633.09 517,403.63 11.08 8,786.19 -106.39 90.77 239.23 6,485.80 3,571.89 -8,103.12 6,025,617.65 517,376.44 8.85 8,802.07 -81.68 93.26 236.87 6,484.81 3,557.03 -8,126.94 6,025,602.71 517,352.67 12.20 8,815.24 -43.41 94.96 235.37 6,482.67 3,540.44 -8,151.64 6,025,586.05 517,328.03 7.59 8,828.30 -41.30 93.38 233.36 6,480.47 3,522.87 -8,176.15 6,025,568.39 517,303.59 8.44 8,840.70 -128.17 91.81 230.96 6,479.09 3,504.24 -8,200.13 6,025,549.69 517,279.67 9.43 8,852.11 -123.16 89.20 226.51 6,478.82 3,483.94 -8,223.27 6,025,529.30 517,256.60 16.75 8,861.96 -120.36 89.45 221.65 6,479.16 3,463.16 -8,243.39 6,025,508.46 517,236.56 16.82 8,868.96 -87.09 90.71 217.37 6,479.12 3,439.13 -8,263.21 6,025,484.36 517,216.82 14.32 8,874.06 -73.60 89.88 212.57 6,478.97 3,415.41 -8,279.80 6,025,460.59 517,200.32 16.83 8,876.53 -99.79 88.40 207.37 6,479.42 3,389.72 -8,294.61 6,025,434.85 517,185.59 18.22 8,876.47 -105.92 86.56 203.10 6,480.74 3,362.51 -8,307.44 6,025,407.60 517,172.86 15.42 8,873.93 -113.42 85.98 206.63 6,482.69 3,335.42 -8,320.00 6,025,380.47 517,160.40 11.93 8,871.21 99.46 87.17 210.61 6,484.47 3,309.37 -8,334.21 6,025,354.38 517,146.28 13.95 8,870.45 73.45 87.85 215.54 6,485.79 3,283.91 -8,350.79 6,025,328.85 517,129.78 16.34 8,872.04 82.25 87.85 219.76 6,486.97 3,258.94 -8,370.05 6,025,303.83 517,110.61 13.36 8,876.19 90.08 86.90 224.54 6,488.49 3,234.49 -8,392.18 6,025,279.31 517,088.56 14.74 8,883.09 101.36 85.64 228.70 6,490.30 3,275.42 -8,412.37 6,025,260.16 517,068.45 15.58 8,890.99 107.01 85.33 232.26 6,492.64 3,196.53 -8,435.26 6,025,241.20 517,045.62 11.97 8,901.34 95.13 86.04 236.01 6,494.76 3,180.13 -8,457.95 6,025,224.73 517,022.99 13.55 8,912.75 79.39 86.93 239.51 6,496.52 3,164.83 -8,482.21 6,025,209.34 516,998.79 12.54 8,926.07 75.82 87.14 243.31 6,497.96 3,151.55 -8,506.57 6,025,195.98 516,974.47 13.68 8,940.50 86.93 4/3/2008 2:18:50PM Page 6 COMPASS 2003.16 Build 42F c . •-' ConocoPhillips ~~~~ ~ .~ , ConocoPhiil~ s p Baker Hughes INTEQ Survey Report s~~$ - Alaska 1N'I'EQ 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) Weil: 30-02 North Reference: True Weilbore: 30-02AL1 TD Survey Calculation Method: Minimum Curvature Design: 30-02AL1 TD Database: EDMv16 Prod Survey MD Inc Azi TVDSS N/S E/W Northing Fasting DLS Vertical Section TFO (~) (°) (°) (ft) (~) (~) (ft) (ft) (°/100ft) (ft) (°) 13,185.00 87.14 243.31 6,500.35 3,130.05 -8,549.35 6,025,174.33 516,931.77 0.00 8,966.73 0.00 • Casing Points Measured Vertical Casing Hole ', Depth Depth Diameter Diameter ', (n) lft) Name (") (") 5,895.00 3,922.38 9 5/8" 9-5/8 12-1/4 Checked By: Approved By: Date: • 4/3/2008 2:18:50PM Page 7 COMPASS 2003.16 Build 42F KRU 30-02 Producer ' 3'/d' TRDP SSSV at 1787 A-sand CTD Completion Updated 3/31/2008 3'/z", 9.3#, EUE 8rd Mod tubing w! 3'/i' gas lift mandrels (six) Actual Drilled Footage = 8358' s~s'surface casing shoe at 5930' • 3'/2' x 7" Baker RHS packer with PBR at 9891" • 2.75" D-nipple at 9928' • 3'/i' 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 @ 13,186' Aluminum billet ~~ ~ 2'/." slotted liner 10,255'-13,186' @ 10,255' ~~ Aluminum billet ii @ 10,749' _ .. ~~~~ ~ ~~ ~ ` ~\ ~ / Wfrxiwv in T' casing \` AL1-P61 10.330' - 10,500' ~I (d110,060'MD ~ ~` AL2 lateral (northem, lower) \ \\ i ~~ Al Sand, TD ~ 11,555' ~~ ~~ ~ ~~ ~ ~~i ~~ 2'/a" slotted liner 10,749' - 11,555' •~ ~` =~rr_ _~ :~_ .v -r. ~ . ~~.: '~ . - ~ . - - ~ r = _ ~ A sand perfs: 10,052' - 10,148' 'A' sidetrack (western, lower) 'A' barefoot segment - (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' Delay BOP Function Test Until OOH ~ Page 1 of 2 Maunder, Thomas E (DOA) From: Eller, J Gary [J.Gary.Eller@conocophillips.com] Sent: Friday, March 21, 2008 4:20 PM To: Maunder, Thomas E (DOA) Cc: Pat Archey; Harry Engel; Eggemeyer, Jerome C.; AOGCC North Slope Office; Nordic 2 Company Man _ Subject: RE: Delay BOP Function Test Untit OOH--30-02AL1 ~Z- ~-~ Tom -The only BOP on Nordic #2 components that have not been function tested within the last 7 days are the blind/shears, upper 2" combi pipe rams, lower 2" combi pipe rams, and the HCR on the choke line. The annular BOP, kill line HCR, and the 2-3/8" combi rams were functioned the last time we pressure deployed an assembly, which was on 3/17108. As you noted, we obviously cannot function test the blind/shears while coil tubing is in the hole. It is certainly possible to function test the 2" pipe rams (upper & lower) while we're in the hole, but it is not advisable in a non- emergency situation. Although it is highly unlikely to happen, junk or debris in the wellbore could damage the coil tubing if we were to function the rams now, which would result in a junked reel of coil and 1-2 days of downtime. I know that's not very likely to happen, but it's not unheard of. We would prefer to wait until we're out of the hole when we can function the rams on a test joint. I'll be available on my cell phone (529-1979) if you'd like to discuss it some more. Thanks. -Gary From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, March 21, 2008 1:46 PM To: Nordic 2 Company Man Cc: Eller, J Gary; Pat Archey; Harry Engel; Eggemeyer, Jerome C.; AOGCC North Slope Office Subject: RE: Delay BOP Function Test Until OOH--30-02AL1 All, It is acceptable to delay the function test until you are on the bank. While you plan to be on bottom for 24 - 48 hours, we alt know that can change. The test should be conducted when OOH. I am surprised that it is necessary to be out of the hole to conduct the function test. It is a given that it necessary to function the blind rams, however I do not understand why the pipe rams and annular cannot be functioned. I would appreciate a return message explaining the reasoning here, why closing properly sized rams on the coil is being avoided. I look forward to your reply. Please make sure any reply includes the aogcc prudhoe bay eddress. Tom Maunder, PE AOGCC From: NSU, ADW Drlg Nordic 2 Supervisor [mailto:nsuadwdrlgnordic2supv@sel.bp.com] Sent: Friday, March 21, 2008 11:22 AM To: Maunder, Thomas E (DOA) Cc: Eller, Gary (ConocoPhillips) Subject: RE: Delay BOP Function Test Until OOH Tom; To answer your question, it is all dependent on rate of penetration. As we are currently on bottom drilling, we 4/30/2008 Delay BOP Function Test Unt~00H ~ Page 2 of 2 predict 24-48hrs until we expect to be of the hole. From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Friday, March 21, 2008 10:33 AM To: Eller, Gary (ConocoPhillips) Cc: NSU, ADW Drlg Nordic 2 Supervisor Subject: RE: Delay BOP Function Test Until OOH Gary, When do you all expect to be out of the hole? Tom From: Eller, J Gary [maitto:J.Gary.Eller@conocophillips.com] Sent: Friday, March 21, 200$ 9:38 AM To: Maunder, Thomas E (DOA) Cc: Nordic 2 Company Man Subject: Decay 80P Function Test Until OOH Tom - As per our phone conversation today, on Nordic #2 we would like to delay our weekly function BOP test until the next time we trip out of the hole. We are currently drilling ahead in the 30-02AL1 lateral. Our next BOP function-pressure test is due by Thursday {3127), and Lou Grimaldi has asked for sufficient notice so that he can witness it. Please confirm that it is acceptable for us to delay that function test. -Gary Eller CPAI Wells Engineer 4/30/2008 1 day BOPE function test exempt,~n . Page 1 of 1 Regg, James B (DOA) From: Grimaldi, Louis R (DOA) Sent: Thursday, March 20, 2008 5:11 PM To: NSU, ADW Drlg Nordic 2 Supervisor n ~y~~~D~ Cc: Regg, James B (DOA) ~~~~~~. Subject: RE: 1 day BOPE function test exemption Matt, Yes, postponement is OK. We need to witness a BOP test on your rig, please provide us with adequate notice for your next BOP test. Thanx; Lou From: NSU, ADW Drlg Nordic 2 Supervisor [mailto:nsuadwdrlgnordic2supv@sei.bp.com] Sent: Thursday, March 20, 2008 2:37 PM To: Grimaldi, Louis R (DOA) Subject: 1 day ROPE function test exemption Lou; ~- o z.~ L„/.L Nordic 2, CTD rig is currently on bottom drilling in Kuparuk on well 30~~. I would like to request one day's exemption & postpone our BOPE function test that is due tonight at midnight on the 20th of March, 2008. The last time we were out of hole was 2pm on March 18th, 2008. Thanks. Matthew Ross 3/21 /2008 ~6~ `/ ~~ • Maunder, Thomas E (DQA) From: Maunder, Thomas E (DOA) Sent: Tuesday, March 18, 2008 1:47 PM To: 'Eller, J Gary' Cc: Perfetta, Patrick J; Nordic 2 Company Man; Staudinger, Garret; Michaelson, Biti(Baker Hughes Inteq); Venhaus, Dan E; Hubble, Terrie L; jon.mapesl@inteq.com Subject: RE: Lateral Naming in Well 30-02 GaryR I confirm our discussion and you have captured it correctly. Good luck with the remaining operations. ! will place a copy of this message in the -02A (2G7-'158), -02AL1 2U?-159 and -Q2AL3 {208-036) flea. You are correct that the -02AL3 permit should be cancelled since it ~n+iJl ntat b drilled. Ca1J or message with any questions.. Tom Maunder, AE ACIGCC From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Tuesday, March 18, 2008 1:21 PM To: Maunder, Thomas E (DOA) Cc: Perfetta, Patrick J; Nordic 2 Company Man; Staudinger, Garret; Michaelson, Bill(Baker Hughes Inteq); Venhaus, Dan E; Hubble, Terrie L; jon.mapesi@inteq.com Subject: Lateral Naming in Well 30-02 Tom - As per our phone conversation yesterday afternoon, we unintentionally sidetracked from well 30-02A while drilling the AL1 lateral. That lateral had been drilled to 10,500' MD, but we accidentally sidetracked at 10,140' MD during a wiper trip. We were unable to re-enter the original borehole last night in order to run slotted liner. We have instead continued drilling ahead from the sidetrack point that we were given at 10,140' MD. I propose that the unlined lateral from 10,330' MD to 10,500' MD off of the `A' sidetrack be named the AL1 PB1 lateral. It crosses the A2 shale shortly after kickoff and is not likely to remain productive without a slotted liner in place. The lateral that we are can-ently drilling will be the AL1 lateral (PTD #207-159) with a kickoff point of 10,140' from the 'A' sidetrack. The `A' sidetrack (PTD #207-158) that was drilled from 10,060' MD to 13,120' MD is tined with slotted liner from TD up to 10,330' MD. It is unlined (i.e. barefoot) from 10,330' to 10,140' MD, but since this is in clean sandstone it is our hope that this sidetrack will remain viable for production. We will be unable to drill the AL3 lateral (PTD # 208-036) that was intended to kickoff at 11,170' MD, and we will cancel that PTD in the near future. Please let me know if you need any other info at this time. Of course, our completion notice will contain a wellbore diagram to help keep track of these many laterals in 30-02, but in the meantime I will be glad to answer any questions that you might have. 7, Gary JEJller WeJlls !Engineer CcrnecoPhiiii~s -Alaska work: 9fl3-263-4172 cell: 907-529-1939 tax: 9:03-265-1533 3/18/2008 ~~ ~~~'11 Li~ i~l r~ Girl Diu ~ ALA58iA OIL A1QD GAS COIQ5ER~ATIOI~T COMIrIIS5IOI~T Gary Eller CT Drilling Engineer Conoco Phillips Alaska Inc. C/o PO Box 196612 Anchorage, Alaska 99519-6612 SARAH PAL/N, 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 Oil Pool, 30-02AL1 Conoco Phillips Alaska Inc. Permit No: 207-159 Surface Location: 745' FNL, 1855' FWL, SEC. 22, T13N, R09E, UM Bottomhole Location: 2142' FSL, 1422' FEL, SEC. 17, 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 30-02A, Permit No 207-158, API 50-029-21837-01-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the mmission to witness any required test, contact the Commission's petroleum field ' pec~tor at (907) 659-3607 (pager). DATED this ~ day of November, 2007 ~ cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COM I~N PERMIT TO DRILL ~ ,~ 20 AAC 25.005 ~ t~ov o 7 zoa~ Alaska Oil & Gas Cons. Commission Anchorage 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 well is proposed for: ^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: 30-02AL1 3. Address: Go P.O. Box 196612, Anchorage, AK 99519-6612 6. Proposed Depth: MD 13200 TVD 6482ss 12. Field /Pool(s): Kuparuk River Unit / Kuparuk 4a. Location of Well (Governmental Section): Surface: 745' FNL 1855' FWL SEC T13N R09E 22 UM 7. Property Designation: ADL 025512 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: 2142' FSL, 1422' FEL, SEC. 17, T13N, R09E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 10,600' 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: 1,400' 16. Deviated Wells: Kickoff Depth: 10300 ~ feet Maximum Hole An le: 97 de roes 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 4995 Surface: 4335 18. Casin Pr :ram: ecfi tion T - - tti ` D th -Bo ttom uan i of Cement c.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 2975' 10225'- 6513' 13200" 6482' Uncemented Slotted Liner 19. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrifl aid Re-entry Qperatons) 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 ize Cement Volume MD Conductor /Structural 115' 16" 199 sx Arcticset II 115' 115' Surface 5930' 9-5/8" 1400 sx AS III, a00 sx'G', To .lob: 100 sx AS I 5930' 4002' Intermediate Production 10392' 7" 315 sx CI ss 'G' 175 sx S I 10 2' 6773' Liner 2900' 3" Uncemented Slotted Liner 30-02A 10300' - 13200' 6513' - 6518' 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: ommission R resentative: Date: 22. I hereby certify that t, oregoing is tr a and correct. Contact Gary Eller, 529-1979 (Cell) Printed Name Gary I Title CT Drilling Engineer Prepared By NamelNumber: Si nature Phone 263-4172 Date Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: .Zf~?-~SLI API Number: 60 ~~ ~~ c7 50-029-21837- -00 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 hydrates, or gas contained shales: ,._,/ Samples Req'd: ^ Ye No Mud Log Req'd: ^ yes L~ No HZS Measures: Yes it ctional Survey Req'd: Yes ^ No Other: ~O eS~ p ~~ O '~S~ . Q B~ APPROVED BY THE COMMISSION Date / ~ ~ /f ,COMMISSIONER Form 10-401 Revised 12/2005 ~ ~`(_. ~~n' ~ ~~ Submit In Duplicate KRU 3~2 Quad Sidetrack/Laterals - Coiled Tubin Drilling 9 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. r 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 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. 3v~ "3 `.~ 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. 1. ordic Rig #2 using 2" coil tubing. NU 7-1/16" BOPS, test. 2. Drill low-si ' of hole and cement ramp for exit at 10,060' MD. Mi112.74" window and 10' of open hole from 10,0 3. 30-02A Sidetrack (Western a. Drill pilot and cement ramp for hig - ' exit at 10,060' MD. b. Mill 2.74" window with high-side orientation. lapped KOP is at 10,060' MD in the A sand. c. Dri113" bi-center horizontal `A' sidetrack southwest in the Al s om the window to TD at 13,200' MD. d. Kill well. Run 23/8" slotted liner with aluminum billet from TD up to 110,300' ,,,_, 4. 30-02AL1 Lateral (Western Upper) ~ ~~ _ \ a. Dri113" bi-center horizontal AL1 lateral southwest in the A2/3 sand from 10,300' to TD at Pec~~ 13,200' MD. b. Kill well. Run 23/8" slotted liner with aluminum billet from TD up to (10,225' MD. - atera ort ern ower ri113" bi-center horizontal AL2 lateral north in the AI sand from 10,225' to TD at 11,630' b. Kill well. Run 2~l"Siet liner with aluminum billet from TD up to (10,960' MD. 6. 30-02AL3 Lateral (Northern Upper a. Drill 3" bi-center horizontal AL3 lateral no A2/3 sands from 10,960' to TD at 11,625' MD. b. Kill well. Run 23/8" slotted liner with aluminum billet from TD up into ' "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 -Coiled Tubin Drillin 9 9 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: 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 -Coil 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-O1 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 H2S level on the 30 pad is 265 ppm from we1130-01. 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 BOPE choke manifold and the mud pits, and will be independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the BHA will be accomplished utilizing the 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. 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: (1787-17aa, Annular Fluid: Last W/O: Rev Reason: NEW GLD 00:3.500) Reference Lo 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 Litt G Casin Strin -ALL STRINGS as MandrelNalve ~ Descri lion Size To Bottom TVD Wt Grade Thread 1 CONDUCTOR 16.000 0 115 115 62.50 H-40 (35os-3509, 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 Lin MandrelNalve Size To Bottom TVD Wt Grade Thread z 3.500 0 9963 6468 9.30 J-55 EUE 8RD AB MOD (s25s-x257, 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 Lin EnerJet MandrelNalve 10072 - 10098 6542 - 6559 A-2 26 12 3/30/1989 APERF 60 deg. phasing; 2 1/8" 3 (7846-7847, 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 andrellDummy CS Gun valve a (8658-8659, 10130 - 10148 6582 - 6595 A-1 18 6 3/28/1989 APERF 60 d hasin 2 1/8" ~' p g' 00:4.750) EnerJet Gas Lift MandrelsNalves St MD ND Man Man T e V Mfr V T e V OD Latch Port TRO Date Vlv Gas Lift yp yp andrel/Dummy Mfr Run Cmnt Valves 1 3508 2542 MMH FHMO GLV 1.0 BK 0.125 1280 5/31/2006 (9248-92as, 00:4 750) 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 andrellDumm 5 9248 6005 MMH FHMO DMY 1.0 BK 0.000 0 2/15/1998 y valve 6 6 9836 6384 Otis LBX DMY 1.5 T-2 0.000 0 9/7/1996 (sa3s-ss37, Other lu s e ui etc. -JEWELRY i 00:5.500) De th TVD T e Descri lion ID 1787 1585 SSSV Camco'TRDP' 2.812 PBR 9878 6411 PBR AVA 3.000 (ss7s-ss7s, 00:3 500) gggl 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 (ssst-sssz, De th Descri lion Comment 00:6.151) 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, 00:3.500, 10:2.992) Perf I ;10052-10068) Perf :10072-10098) _ Perf i '10102-10110) Perf '10110-10130) Perf '1 01 30-1 0 1 48) - - - 23' Strip Gun ;10185-10208, 00:2.000) KRU 30-02 Producer Proposed A-sand CTD Completion Footage Drilled = 8110' Updated 11/2/2007 9%" surface casing shoe at 5930' 2'/a" slotted liner top -9950' Cement ramp exit, top of \ cement -9970' MD AL3 lateral (northern, upper) A2/3 Sand, TD @ 11,625' -~- _ A sand perfs: . ~' _~ - - - = '~ ~ ~ ~~ 10,052' - 10,148' ~ ~~ (plugged) AL2 lateral (northern, lower) \ Aluminum billet Al Sand, TD @ 11,630' @ 10,960' • 3'/i' TRDP SSSV at 1787' 3'/z", 9.3#, EUE 8rd Mod tubing w/ 3'/=' gas lift mandrels (six) • 3'/z' x 7" Baker RHS packer with PBR at 9891" • 2.75" D-nipple at 9928' • 3'/s" tubing tail at 9963' Wiridav in T' 26# J55 rasing @ 10,060' MD Aluminum billet @ 10,225' Lt ,~L~ k(western, upper) A2/3 Sand, TD @ 13,200' /`~ //. /6 • m 7 Aluminum billet @ 10,300' A s: ~1-vestern, lower) ~/ sand, TD @ 13,200' /~ ~~-b7 i 7", 26 ppf, J-55 casing shoe at 10,392' by BP Alaska Baker Hughes INTEQ Planning Report ~.r 5 INTEQ Company; BP Amoco Date: 10/23/2007 Time: 15;49:07 Page:- t Field: Kuparuk Co-ordiuate(NE) Reference: WeIL• 30-02, True North Site: KRU 30 Pad Vertical (TVD) Reference: 3t}02 Orig Rig 59.0 Well: 30-02 Section (VS) Reference: Well (O~OON,11:00E,225.00Az) Wellpath: Plan 5, 30-02AL1 Survey Calcnlatioa Method: 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 Fasting: 523632. 43 ft Lougitude: 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 SMt 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 Position Uncertainty: 0.00 ft Wellpath: Plan 5, 30-02AL1 Drilled From: Plan 5, 3O-02A 500292183760 Tie-on Depth: 10300.00 ft Current Datum: 30-02 Orig Rig Height 59. 00 ft Above System Datum: Mean Sea Level Magnetic Data: 10/22/2007 Declination: 23.06 deg Field Strength: 57625 nT blag Dip Angle: 80.91 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 59.00 0.00 0.00 225.00 Plan: Plan #5 Date Composed: 10/22/2007 Version: 4 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <--- Latitnde ---> <-- Longitude ---~ Name Description TVD +N!-S +FJ-W Northing Fasting Deg .Min Sec Deg Min Sec Dip.. Dir. ft ft ft ft ft 30-02A Western Polygon 59.00 4078.68 -6314.85 6026130.01 519163.00 70 28 57.209 N 149 50 36.269 W -Polygon 1 59.00 4078.68 -6314.85 6026130.01 519163.00 70 28 57.209 N 149 50 36.269 W -Polygon 2 59.00 4149.33 -6501.63 6026200.01 518976.00 70 28 57.902 N 149 50 41.765 W -Polygon 3 59.00 4141.60 -6874.70 6026191.01 518603.00 70 28 57.823 N 149 50 52.739 W -Polygon 4 59.00 4042.64 -7179.07 6026091.01 518299.00 70 28 56.847 N 149 51 1.689 W -Polygon 5 59.00 3961.36 -7393.37 6026009.01 518085.00 70 28 56.046 N 149 51 7.990 W -Polygon 6 59.00 3847.80 -7525.77 6025895.01 517953.00 70 28 54.928 N 149 51 11.881 W -Polygon 7 59.00 3573.83 -7832.74 6025620.01 517647.00 70 28 52.230 N 149 51 20.902 W -Polygon 8 59.00 3317.58 -8060.64 6025363.01 517420.00 70 28 49.707 N 149 51 27.597 W -Polygon 9 59.00 2768.83 -8442.56 6024813.01 517040.00 70 28 44.306 N 149 51 38.811 W -Polygon 10 59.00 2872.54 -8648.23 6024916.01 516834.00 70 28 45.324 N 149 51 44.863 W -Polygon 11 59.00 3058.56 -8647.59 6025102.01 516834.00 70 ZS 47.154 N 149 51 44.851 W -Polygon 12 59.00 3484.62 -8360.10 6025529.01 517120.00 70 28 51.347 N 149 51 36.410 W -Polygon 13 59.00 3915.58 -7749.56 6025962.01 517729.00 70 28 55.592 N 149 51 18.466 W -Polygon 14 59.00 4057.53 -7439.Q4 6026105.01 518039.00 70 28 56.991 N 149 51 9.336 W -Polygon 15 59.00 4213.68 -7185.48 6026262.01 518292.00 70 28 58.529 N 149 51 1.882 W -Polygon 16 59.00 4322.80 -6925.08 6026372.01 518552.00 70 28 59.605 N 149 50 54.226 W -Polygon 17 59.00 4381.94 -6672.85 6026432.01 518804.00 70 29 0.189 N 149 50 46.808 W -Polygon 18 59.00 4328.16 -6446.01 6026379.01 519031.00 70 28 59.662 N 149 50 40.134 W -Polygon 19 59.00 4256.49 -6253.24 6026308.01 519224.00 70 28 58.958 N 149 50 34.461 W -Polygon 20 59.00 4124.01 -6116.68 6026176.01 519361.00 70 28 57.657 N 149 50 30.441 W -Poygon 21 59.00 3992.26 -6193.14 6026044.01 519285.00 70 28 56.360 N 149 50 32:687 W 30-03AL1 Target 10 6541.00 2878.15 -8533.20 6024922.01 516949.00 70 28 45.381 N 149 51 41.481 W 30-03AL1 Target 9 6550.00 3095.77 -8415.44 6025140.01 517066.00 70 28 47.522 N 149 51 38.025 W 30-03AL7 Target 1 6554.00 4260.90 -6664.27 6026311.01 518813.00 70 28 58.998 N 149 50 46.552 W LJ by BP Alaska Baker Hughes INTEQ Planning Report ~.r ~+iins INTEQ Company: BP AmoCO Date: 10/23/2007 Timr. 15:49:07 Page: 2` Field: Kuparuk Co-ordioate(NE) Reference: 1A~11: 30-02, True North Site: KRU 30 Pad Vertical (TVD) Reference: 30-02 Orig.Rig 59.0 Well: 30-02 Sectio n (VS) Reference: Well (O.OON,O.OOE;225.OOAzi) Wellpatb: Plan 5, 30-02AL1 Survey Caknlatioa Method: Minimum Curvature Db: Orade Targets Map Map <--- Latitude. ---> <--Longitude ---~ Name Description TVD +N/-S +E/-W Northing Fasting Deg Min Sec Deg Mio Sec .Dip. Dir. ft ft ft ft ft 30-03AL1 Target 2 6561.00 4247 .63 -6878.33 6026297.01 518599.00 70 28 58.866 N 149 50 52.848 W 30-03AL1 Target 8 6563.00 3331 .21 -8242.62 6025376.01 517238.00 70 28 49.839 N 149 51 32.949 W 30-03AL1 Target 7 6568.00 3565 .42 -8005.79 6025611.01 517474.00 70 28 52.145 N 149 51 25.991 W 30-03AL1 Target 6 6570.00 3782 .49 -7727.02 6025829.01 517752.00 70 28 54.283 N 149 51 17.799 W 30-03AL1 Target 5 6577.00 3901 .96 -7568.59 6025949.01 517910.00 70 28 55.460 N 149 51 13.142 W 30-03AL1 Target 3 6578.00 4155 .45 -7121.67 6026204.01 518356.00 70 28 57.957 N 149 51 0.004 W 30-03AL1 Target 4 6582.00 4021 .43 -7411.16 6026069.01 518067.00 70 28 56.636 N 149 51 8.515 W Annotation MD TVD ft ft 10300.00 6572.45 KOP -Tie to 30-02A Pl an 5 10320.00 6571.76 End of 20 Deg/100' DLS 10350.00 6568.85 3 10422.00 6559.97 4 10522.00 6553.82 5 10747.00 6553.83 6 10847.00 6555.83 7 10972.00 6561.02 8 11222:00 6577.93 9 11297.00 6581.38 10 11472.00 6581.76 11 11572.00 6581.86 12 11747.00 6576.88 13 11822.00 6573.50 14 11947.00 6570.18 15 12087.00 6568.61 16 12312.00 6567.93 17 12412.00 6566.93 18 12652.00 6562.97 19 12802.00 6558.10 20 12952.00 6550.00 21 13200.00 6541.04 TD Plan Section Information MD Incl Azim TVD +NI-S +E/-W DLS Buiid Tnro TFO Target ft deg deg ft ft fl deg/100ft deg/100ft deg/100ft deg 10300.00 90.00 310.30 6572.45 4118.80 -6244.62 0.00 0.00 0.00 0.00 10320.00 94.00 310.30 6571.76 4131.82 -6259.86 20.00 20.00 0.00 0.00 10350.00 97.12 308.48 6568.85 4150.77 -6282.93 12.00 10.38 -6.04 330.00 10422.00 97.03 299.78 6559.97 4190.82 -6342.02 12.00 -0.11 -12.09 270.00 10522.00 90.00 290.03 6553.82 4232.74 -6432.40 12.00 -7.04 -9.75 234.50 10747.00 90.00 263.03 6553.83 4258.10 -6653.87 12.00 0.00 -12.00 270.00 10847.00 87.72 274.82 6555.83 4256.22 -6753.65 12.00 -2.27 11.79 101.00 10972.00 87.54 259.81 6561.02 4250.38 -6878.05 12.00 -0.14 -12.01 269.00 11222.00 84.87 229.85 6577.93 4145.61 -7101.26 12.00 -1.07 -11.98 264.00 11297.00 89.87 237.35 6581.38 4101.20 -7161.51 12.00 6.66 9.99 56.50 11472.00 89.88 258.35 6581.76 4035.59 -7322.69 12.00 0.00 12.00 90.00 11572.00 90.01 246.35 6581.86 4005.33 -7417.81 12.00 0.13 -12.00 270.60 11747.00 93.22 225.59 6576.88 3908.00 -7561.98 12.00 1.84 -11.87 279.00 11822.00 91.93 216.67 6573.50 3851.62 -7611.21 12.00 -1.72 -11.89 262.00 11947.00 91.09 231.65 6570.18 3762.24 -7698.02 12.00 -0.67 11.99 93.00 12087.00 90.18 248.43 6568.61 3692.58 -7818.87 12.00 -0.65 11.98 93.00 by BP Alaska Baker Hughes INTEQ Planning Report ~.r S INTEQ Company: BP Amoco Date: 10/23/2007 Time: 15:49:07 Page: 3 Field: KupaNk Co-ordinate(NE) Retereocr. WeIL 30-02, True North Site: KRU 30 Pad Vertical (TVD) Reference: 30-02 Orig Rig 59.0 Weli: 30-02 Section (VS) Reference: Well (O.OON,O.OOE,225.OOAzi) Wellpatht Plan 5, 30-02AL1 Survey Calculation Method: Minimum Curvature Db: Orade Plan Section Information MD Iecl Azim TVD +N/-S +E/-W DLS Build Tore TFO Target ft deg deg ft ft ft deg/100ft deg/100ft deg/100ft deg 12312.00 90.16 221.43 6567.93 3564.49 -8001.32 12.00 -0.01 -12.00 270.00 12412.00 90.99 209.46 6566.93 3483.18 -8059.20 12.00 0.83 -11.97 274.00 12652.00 90.86 238.26 6562.97 3311.96 -8223.72 12.00 -0.05 12.00 90.00 12802.00 92.83 220.36 6558.10 3214.63 -8336.94 12.00 1.31 -11.94 276.50 12952.00 93.31 202.34 6550.00 3087.24 -8414.54 12.00 0.32 -12.01 272.00 13200.00 90.74 232.01 6541.04 2892.01 -8562.65 12.00 -1.03 11.96 94.30 Survey MD tocl Azim SS TVD N/5 E/W MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 10300.00 90.00 310.30 6513.45 4118.90 -6244.62 6026170.46 519233.09 0.00 1503.11 0.00 MWD 10320.00 94.00 310.30 6512.76 4131.82 -6259.86 6026183.33 519217.81 20.00 1504.75 0.00 MWD 10350.00 97.12 308.48 6509.85 4150.77 -6282.93 6026202.20 519194.67 12.00 1507.67 330.00 MWD 10400.00 97.08 302.44 6503.67 4179.54 -6323.33 6026230.83 519154.19 12.00 1515.89 270.00 MWD 10422.00 97.03 299.78 6500.97 4190.82 -6342.02 6026242.04 519135.46 12.00 1521.13 269.25 MWD 10500.00 91.55 292.17 6495.12 4224.82 -6411.88 6026275.80 519065.49 12.00 1546.48 234.50 MWD 10522.00 90.00 290.03 6494.82 4232.74 -6432.40 6026283.65 519044.95 12.00 1555.39 233.93 MWD 10600.00 90.00 280.67 6494.83 4253.37 -6507.53 6026304.02 518969.75 12.00 1593.93 270.00 MWD 10700.00 90.00 268.67 6494.83 4261.50 -6607.02 6026311.81 518870.25 12.00 1658.53 270.00 MWD 10747.00 90.00 263.03 6494.83 4258.10 -6653.87 6026308.25 518823.40 12.00 1694.07 270.00 MWD 10800.00 88.79 269.28 6495.40 4254.55 -6706.72 6026304.51 518770.57 12.00 1733.95 101.00 MWD 10847.00 87.72 274.82 6496.83 4256.22 -6753.65 6026306.03 518723.64 12.00 1765.95 100.93 MWD 10900.00 87.63 268.45 6498.98 4257.73 -6806.56 6026307.36 518670.73 12.00 1802.29 269.00 MWD 10972.00 87.54 259.81 6502.02 4250.38 -6878.05 6026299.76 518599.28 12.00 1858.04 269.26 MWD 11000.00 87.20 256.46 6503.30 4244.63 -6905.42 6026293.92 518571.93 12.00 1881.46 264.00 MWD 11100.00 86.04 244.49 6509.22 4211.34 -6999.34 6026260.31 518478.14 12.00 1971.41 264.15 MWD 11200.00 85.06 232.50 6517.00 4159.35 -7084.19 6026208.03 518393.48 12.00 2068.17 264.86 MWD 11222.00 84.87 229.85 6518.93 4145.61 -7101.26 6026194.24 518376.45 12.00 2089.96 265.80 MWD 11297.00 89.87 237.35 6522.38 4101.20 -7161.51 6026149.63 518316.36 12.00 2163.96 56.50 MWD 11300.00 89.87 237.71 6522.38 4099.59 -7164.04 6026148.01 518313.84 12.00 2166.89 90.00 MVVD 11400.00 89.87 249.71 6522.60 4055.38 -7253.53 6026103.50 518224.50 12.00 2261.43 90.00 MWD 11472.00 89.88 258.35 6522.76 4035.59 -7322.69 6026083.48 518155.42 12.00 2324.32 89.97 MWD 11500.00 89.92 254.99 6522.81 4029.14 -7349.93 6026076.93 518128.21 12.00 2348.15 270.60 MWD 11572.00 90.01 246.35 6522.86 4005.33 -7417.81 6026052.89 518060.42 12.00 2412.98 270.61 MWD 11600.00 90.53 243.03 6522.73 3993.36 -7443.11 6026040.84 518035.15 12.00 2439.34 279.00 MWD 11700.00 92.38 231.17 6520.17 3939.17 -7526.90 6025986.36 517951.56 12.00 2536.91 278.98 MWD 11747.00 93.22 225.59 6517.88 3908.00 -7561.98 6025955.08 517916.59 12.00 2583.75 278.68 MWD 11800.00 92.32 219.28 6515.31 3868.95 -7597.68 6025915.91 517881.03 12.00 2636.61 262.00 MWD 11822.00 91.93 216.67 6514.50 3851.62 -7611.21 6025898.54 517867.56 12.00 2658.43 261.70 MWD 11900.00 91.42 226.02 6512.21 3793.16 -7662.66 6025839.90 517816.32 12.00 2736.15 93.00 MWD 11947.00 91.09 231.65 6511.18 3762.24 -7698.02 6025808.87 517781.07 12.00 2783.01 93.27 MWD 12000.00 90.75 238.00 6510.32 3731.73 -7741.31 6025778.21 517737.88 12.00 2835.20 93.00 MWD 12087.00 90.18 248.43 6509.61 3692.58 -7818.87 6025738.80 517660.47 12.00 2917.72 93.10 MWD 12100.00 90.18 246.87 6509.57 3687.64 -7830.89 6025733.82 547648.46 12.00 2929.72 270.00 MWD 12200.00 90.17 234.87 6509.26 3639.05 -7918.08 6025684.93 517561.45 12.00 3025.73 270.00 MWD 12300.00 90.16 222.87 6508.97 3573.39 -7993.26 6025619.02 517486.50 12.00 3125.32 269.96 MWD 12312.00 90.16 221.43 6508.93 3564.49 -8001.32 6025610.10 517478.48 12.00 3137.31 269.92 MWD 12400.00 90.89 210.89 6508.13 3493.55 -8053.17 6025538.99 517426.88 12.00 3224.14 274.00 MWD 12412.00 90.99 209.46 6507.93 3483.18 -8059.20 6025528.59 517420.88 12.00 3235.74 273.90 MWD 12500.00 90.97 220.02 6506.42 3410.97 -8109.26 6025456.23 517371.07 12.00 3322.19 90.00 MWD 12600.00 90.91 232.02 6504.78 3341.67 -8181.08 6025386.68 517299.50 12.00 3421.98 90.18 MWD 12652.00 90.86 238.26 6503.97 3311.96 -8223.72 6025356.84 517256.96 12.00 3473.14 90.38 MWD 12700.00 91.51 232.54 6502.97 3284.72 -8263.21 6025329.46 517217.58 12.00 3520.32 276.50 MWD 12800.00 92.80 220.60 6499.19 3216.15 -8335.64 6025260.65 517145.38 12.00 3620.03 276.38 MWD by BP Alaska Baker Hughes INTEQ Planning Report ~.r s INTEQ Company: BP Amoco Date: 10/23/2007 Timer 15:49:07 Pale: 4 Field: Kuparuk Co-ordioate(NE) Reference: Well: 30-02, True North Site: KRU 30 Pad Vertical (TVD) Reference: 30-02 Orig Rig 59.0 Well: 30-02 Section (VS) Reference. Well (O.OON,O:OOE,225.OOAz7 Wellpath: Plan 5, 30-02AL1 Survey Caknlatioa Method: Minimum Curvature Db: Chade .Sarvey MD Intl Azim SS TVD N/S FJV1' MapN MapE DLS VS TFO Tool ft deg deg ft ft ft ft ft deg/100ft ft deg 12802.00 92.83 220.36 6499.10 3214.63 -8336.94 6025259.12 517144.09 12.00 3622.02 275.93 MWD 12900.00 93.18 208.59 6493.95 3134.09 -8392.23 6025178.41 517089.08 12.00 3718.07 272.00 MWD 12952.00 93.31 202.34 6491.00 3087.24 -8414.54 6025131.48 517066.93 12.00 3766.97 271.38 MWD 13000.00 92.86 208.09 6488.42 3043.90 -8434.95 6025088.07 517046.67 12.00 3812.05 94.30 MWD 13100.00 91.84 220.06 6484.30 2961.29 -8490.83 6025005.28 516991.09 12.00 3909.98 94.61 MWD ..13200.00 90.74 232.01 6482.04 - 2892.01 -8562.65 6024935.76 516919.51 12.00 4009.75 95.10 MWD • .~ ,~, -a~ 1 I rI; f' ~~~ ., $mm, w ~- ~~ J oooodd Q .n I ,~ ~~~I -1 a ~r'i 1 ;t a p' _~ `~l ~ k1 tr i h ' ~~ z ,: ., ~~~~~ Y 5! i a m -- ;2 }i a ~~ S p s - ~~ . ~ P ~_ i t ~µ ~1 ~ y4 ~e~aF~a~~~~ +1 gR7~g3Ro$6= ~.. 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O~ ~. ~ ill t•_; ~~ ;-~=~ I`i. s O ~ ~ r l ~~ ~ I l~l' ~~ ~~ 'I I~~r t~al I _ ~ r~ ~,~ ! a' ~' r` 1~1 ' ~ ,~ 1 11~:. ~ B ~ Imo' j i I~1~- F ~ R ~ ~~_I~1~~h i ~~~ rt ~`F, E ~ \ € ~ ttl ; i ~ .i III r~ i it iii+' ~ ~ ~` I ~, , I ~ 1 I a ~,1 ~~ ~ -~ ~ ~~IM00 LI 4~dp IeorL~r1 ~~ul _ e®cgnc ~uparuk Managed Pressure Drillin~ BOP Configuration for 2" Coil Tubing Wel I I 30-02 Floor I Lubricator ID = 6.375" with 6" Otis Unions 1 7 1/16" 5000 psi, RX-46 7 1/16" 5000 psi RX-46 -, Tree Size 3-1/8", 5M 7 1/16" 5000 psi (RX-46) or ~- 4 1/16" 5000 psi (RX-39) Swab Valve SSV Master Valve Base Flan e Page 1 TRANSMITTAL LETTER CHECKLIST WELL NAME /'~~ -3~ _ ~~L' ~# ~~ - /~ ~Develo meat Service Exploratory Stratigraphic Test P Non-Conventional WeU Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CI~CK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing '~ ' well ~~~ •~~ _ ~2/ (If last two digits in permit No. Z 7 / API No. 50-~L - ~~S 37 ~L• 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(f), all records, data and [ogs 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 ___ SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. , assumes the 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 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 jCompanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Comaan~Name) must contact the Commission to obtain advance approval of such water well testing ro m. 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