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Home My WebLink About208-101• Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ 8- ~ Q ~ Welt History File Identifier Organizing (done) RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ~.~,a~ iiummuiiiui DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: o a„v~~e~~ iiiuiiiuiuiiiii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: p~ ' D /s/ Project Proofing III II'IIIIIIII IIIII BY: Maria Date: ' ~ /s/ Scanning Preparation ~_ x 30 = 30 + ~ =TOTAL PAGES_ '~~ ~ (Count does not include cover sheet) BY: Maria Date:. ~ " ~Q /s/ Production Scanning Stage 1 Page Count from Scanned File: ~~ (Count does include cove heet) nt Matches Number in Scannin Pre aration: ~~! YES NO Page Cou 9 P BY: Maria Date: ~ ' ~ ! O /s/ V {/I 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'I II I II II I I'II ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked III IIIII III III III 10/6/2005 Well History File Cover Page doc DATA SUBMITTAL COMPLIANCE REPORT 2/8/2010 Permit to Drill 2081010 Well Name/No. KUPARUK RIV UNIT 1D-04AL1-02 Operator CONOCOPHILLIPS ALASKA INC MD 9852 TVD 6571 Completion Date 6/21/2008 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-20416-62-00 UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Ye~ DATAINFORMATDN Types Electric or Other Logs Run: MWD DIR, GR, RES Well Log Information: Log/ Electr Data Digital Dataset (data taken from Logs Portion of Master Well Data Maint Log Log Run Interval OH / Iyp meairrmt numoer Name acme mea~a no star[ stop cn rcecervea ~.omments D D Asc Directional Survey 0 9852 Open 9/12/2008 PBU 1D-04A, PBU 1D- 04AL1, &PBU 1D-04AL1- 01 also on Disk D C Lis 19031 ~ See Notes 6959 9852 Open 12/3/2009 MPR Togs plus PDF graphics og Induction/Resistivity 25 Col 7100 9852 Open 12/3/2009 MD MPR, GR og Induction/Resistivity 5 Col 7100 9852 Open 12/3/2009 TVD MPR, GR Nell Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y 11~ Chips Received? ~'7-N-' Analysis Y~ N~ Received? Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? ~ N Formation Tops ~N si ~I Comments: DATA SUBMITTAL COMPLIANCE REPORT 2/8/2010 Permit to Drill 2081010 Well Name/No. KUPARUK RIV UNIT 1D-04AL1-02 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-20416-62-00 MD 9852 TVD 6571 Completion Date 6/21/2008 Completion Status 1-OIL Current Status 1-OIL UIC N --__ Compliance Reviewed By: n Date: _ ~- ~ ~ ConocoPhillips Alaska 1 D-04AL1 -~2 RECIPIENTS No other distribution is allowed without OH FINAL OH FINAL written approval from ConocoPhillips Image files and/or Digital Data contact: Lisa Wright, 907 263-4823 hardcopy prints ConocoPhillips Alaska, Inc. 1 Hardcopy Print NSK Wells Aide, NSK 69 ATTN: MAIL ROOM 700 G Street, Anchorage, AK 99501 AOGCC 1 Hardcopy Print, Christine Mahnken 1 Graphic image file 1 Disk'`/ 333 West 7th Ave, Suite 100 in lieu of sepia** Electronic Anchorage, Alaska 99501 CGM /TIFF LIS BP 1 Hardcopy Print, Petrotechnical Data Center, MB33 1 Graphic image file 1 Disk'`/ David Douglas in lieu of sepia"* Electronic P.O. Box 196612 CGM /TIFF LIS Anchorage, Alaska 99519-6612 CHEVRON/KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk'`/ P.O.Box 196247 in lieu of sepia** Electronic Anchorage, Alaska 99519 CGM /TIFF LIS Brandon Tucker, NRT State of Alaska; DNR, Div. of Oil and Gas 1 Disk*/ 550 W. 7th Ave, Suite 800 Electronic Anchorage, Alaska 99501-3510 LIS i~ ~1 ~~~ D31 ,~ ~_ -~ ~~, ~ DEC ~ ~ 2009 rail ~ G~d~'h5. C;C3+`~~r~i~sica~~ ~~ci~crac ~~~ BAITER N~l~ME INTEL 7260 Homer Drive Anchorage, AK 99518 To Whom It May Concern: August 08, 2008 Please find enclosed directional survey data for wells: 1 D-04A 1 D-04AL 1 1 D-04AL 1-O l 1 D-04AL 1-02 ~. rr- 8 - ~ ~ ~ Q ~ ~ k ~ ~~ -- 6 $ `~ 1D-12L1PB1 1D-12L1 1D-12L2 Enclosed is: 1 ea 3.5" floppy diskette containing electronic survey file ~.~~ a~~ Cc: State of Alaska, AOGCC Christine Mahnlcen STATE OF ALASKA ALAS OIL AND GAS CONSERVATION CO~ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG ~U~ ~ ~ Z~o8 1 a. Well Status: ~ Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAACZS.,os zoAACZS.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well C a ®Developmen! ^ Explora~ery; ^ Service ^ Str 'graphic 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 6/21/2008 12. Permit to Drill Number 208-101 ' 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 6/17/2008 13. API Number S0-029-20416-62-00 - 4a. Location of Well (Governmental Section): Surface: 120' FNL 598' FEL SEC 2 T 7. Date T.D. Reached 6/19/2008 ~ 14. Well Name and Number: Kuparuk 1D-04AL1-02 ' , , . 3, 11 N, R10E, UM Top of Productive Horizon: 1475' FSL, 1227' FWL, SEC. 13, T11 N, R10E, UM 8. KB (ft above MSL): 105' ~ Ground (ft MSL): 15. Field /Pool(s): Kuparuk River Unit /Kuparuk Total Depth: 1363' FSL, 3646' FWL, SEC. 13, T11 N, R10E, UM 9. Plug Back Depth (MD+TVD) 9852' 6571' River Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 560490 ~ y- 5959545 • Zone- ASP4 10. Total Depth (MD+TVD) 9852' 6571' 16. Property Designation: ADL 025650 TPI: x- 562301 y_ 5961155 Zone- ASP4 Total Depth: x- 564720 > y- 5961064 • Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rinted information er 20 AAC 25.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1400' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): ~GD(~: 7Z r1'JD MWD DIR, GR, RES los~b~ ?Y'iD 22. CASING, LINER AND CEMENTING RECORD ~•t -0 CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM': TOP BOTTOM ' SIZE< CEMENTING RECORD PULLED 16" 65# H-40 Surface 72' Surface 72' 24" 264 sx Arcticset II 10-3/4" 45.5# K-55 Surface 2890' Surface 2690' 13-3/4" 3300 sx Arcticset II 7" 26# K-55 Surface 7042' Surface 6403' 9-7/8" 1600 sx Self-Stress Cement 5" 14.87# K-55 6746' 7' 6108' 6454' 9-7/8" 120 sx Self-Stress Cement 2-3/8" 4.44# L-80 6651' 9852' 6008' 6571' 3" Uncemented Slotted Liner 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, IISt each IntefV81 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", 9.2#, J-55 6729' 6657' MD TVD MD TVD 7545' - 9818' 6559' - 6567 Only Well Branch 1 D-04AL1-02 25. ACID, FRACTURE, CEMENT SQUEEZE, ETC. Is Directly DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Accessible 2000' Freeze Protect w/ 25 Bbls of Diesel 26. PRODUCTION TEST Date First Production: June 25, 2008 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date Of Test: 7/1/2008 HOUfS Tested: 21 PRODUCTION FOR TEST PERIOD OIL-BBL: 1,667 GAS-MCF: 1,765 WATER-BBL: 4,288 CHOKE SIZE: 86 GAS-OIL RATIO: 1,059 Flow Tubing Press. 164 CBSIng PreSS: 1,270 CALCULATED 24-HOUR RATE• OIL-BBL: 2,317 GAS-MCF: 1,464 WATER-BBL: 3,036 OIL GRAVITY-API (CORK): 24.3 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No ' Sidewal l Cores Ac uired? ^Yes ®No' If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. -OOMPt.Er101iC None DA .~ ~ ~ ~ L ~ IFIEi1 ~~ .;.0; f Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE !'v ?. (p;Qft $ ~ JUt 2 ~ 20D8 ~~ ,~~~~. ~` 2S. GEOLOGIC MARKERS (LIST ALL FORMATIONS A RKERS ENCOUNTERED): 29. FORMATION TESTS NAME D TVD Well Test ^ 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. Kuparuk C4 (From 1 D-04A) 7105' 6461' None - Kuparuk C3 8975' 6560' Kuparuk C2 9760' 6563 Kuparuk C2 9852' 6571' Formation at Total Depth (Name): Kuparuk C2 9760' ~ 6563' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foreg ing is tru and correct to the best of my knowledge. D~ / Signed Terrie Hubble ~ ~~ Title Drilling Technologist Date ! Og Kuparuk 1D-04AL1-02 208-101 Prepared ByName/Number.• Terrie Hubble, 564-4628 Well Number Drilling Engineer: Mel Rixse, 564-5620 Permit No. / A royal No. INSTRUCTIONS GeNew-r.: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and 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. ITeM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Operations .Summary Report Page 1 of 16 Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: - NPT I Phase ~ Description of Operations Date From - To Hours Task Code - 6/3/2008 105:30 - 07:30 2.00 MOB P PRE 07:30 - 11:00 3.50 MOB P PRE 11:00 - 12:30 1.50 MOB P PRE 12:30 - 14:45 2.25 MOB P PRE 14:45 - 19:00 4.25 MOB P PRE 19:00 - 22:00 3.00 MOB P PRE 22:00 - 22:30 0.50 MOB P PRE 22:30 - 23:00 0.50 MOB P PRE 23:00 - 00:00 1.00 MOB P PRE 6/4/2008 00:00 - 05:30 5.50 RIGU P PRE 05:30 - 07:30 2.00 BOPSU P PRE 07:30 - 12:20 4.83 BOPSU P PRE 12:20 - 15:30 3.17 BOPSU N PRE 15:30 - 21:00 5.50 BOPSU N PRE 21:00 - 21:45 0.751 BOPSUFj P PRE 21:45 - 22:00 0.25 RIGU P WEXIT 22:00 - 22:40 0.67 RIGU P WEXIT 22:40 - 23:15 I 0.581 BOPSUp P I I W EXIT 23:15 - 23:30 0.25 RIGU P WEXIT 23:30 - 23:40 0.17 RIGU P WEXIT 23:40 - 00:00 0.33 RIGU P WEXIT 6/5/2008 00:00 - 01:15 1.25 RIGU P WEXIT 01:15 - 04:15 3.001 RIGU P W EXIT 04:15 - 04:30 0.25 RIGU P WEXIT 04:30 - 05:45 1.25 RIGU P WEXIT 05:45 - 07:00 1.251 STWHIP P WEXIT 07:00 - 08:30 1.501 STWHIP P WEXIT Plck up rig mats and clean up around cellar area. Conduct pre move inspection of hydraulic systems. Inspect well area with CPF-2 DSO. Move from 2D pad to 2X pad entrance. Stand by for Kuparuk crew change. Move to 1 R access road Wait for SSA flights and then Field crew changeout Move from 1 R access road to 1 D pad. Move rig onto pad & down to 1 D-04. Wait for AES to finish rigging up MPD valuing. PJSM regarding moving over well. Shut in adjacent well. Spot rig over well. Rig accepted at 00:00. Level rig. Bring on boiler water. Order out 2% KCL with 2ppb Biozan milling fluid. Nipple up BOPE &MPD loop, (tree is crooked!). Rig up IA, OA & WHP gauges & crash frames. Rig up SSV &MPD SV hydraulic lines & function test same. Tighten tree bolts, found 3 loose studs. Spot tiger tank & rig up hardline. Spot cuttings box. Rig up Handy Berm around cellar. Rig up lubricator. Spot satellite camp & rig up BHI wires & main power cable. Off load miscellaneous rig equipment. MU BHI coil track tools for milling BHA on catwalk & test same. Get BOP stack measurements. Grease mud cross valves. Function test BOP's. Fill BOP stack with cold water. Perform shell test on BOP stack Test BOPE and MPD loop to 250/3500 w/ AOGCC in attendance Choke line HCR would not test. Rebuild, retest and failed Replace, grease & actuate. Retest -pass. Replaced gray lock seal on choke line HCR & test -pass. Fill coil with biozan. P.T. tiger tank line with 120psi of air & 400psi of fresh water - good. PJSM regarding coil slack management & cutting coil. PU injector & cut off coil connector. Prep a-line cable. Stab onto well. P.T. inner reel valve & injector packoffs per AOGCC regs 250/3500 psi -Pass. Pump slack. Pop off well & check for wire. PJSM regarding pulling BPV. Hoist Cameron BPV lubricator to RF & RU same to pull BPV. Stab BPV lubricator onto well. P.T. 250/2000psi. Open master valve w/ 1500psi & let equalize, 450psi WHP. Recovered 3" 'H' style BPV. Rig down Cameron lubricator. Rig up coil cutter & cut 54tt of coil. Dress end of coil. MU Kendal CTC. Open well to Tiger tank & bleed off from 450psi to Opsi. Pull test to 30k -good. Head up BHI. Replace flow sub. Pressure test to 4000psi -good. PJSM regarding making up BHA. Flow check well. MU milling BHA. Stab onto well. Power up & test tools. Set depths. RIH with milling BHA, taking returns to Tiger tank. Circ thru EDC 0.8/1040 Set down at 6738' CTD. Close EDC. Mill cement stringer from rnnteo: °i°uizuu° a:acaa Nm BP EXPLORATION Operations Summary Report Page 2 of 16 Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task 'i Code NPT Phase Description of Operations 6/5/2008 07:00 - 08:30 1.50 STWHIP P 08:30 - 11:30 3.00 STWHIP P 11:30 - 15:45 4.25 STWHIP P 15:45 - 17:45 2.00 STWHIP P • WEXIT 6738-6743' CTD 1.48/2750 and ream area twice, clean. Precautionary ream 1.5/2585 at 25'/min to WS. Tag at min rate at 7108.0' and did not correct PVT 261 WEXIT PU 21.5k start motor 1.5/2600 Ease in hole to first MW and four stalls at 7107.70' with corresponding overpulls which is the assumed pinch point. Park at 7107.67' for 30 min and let CT straighten out (7.5k hanging wt). Begin time milling from 7107.7' WEXIT Mill from 7109.30' 1.52/2730 w/ 100 psi dill, 0.4k wob w/ 10.21 ECD after swap to pump #2 to replace swab in pump #1 PreSpud mtg WEXIT Mill from 7112.2' (calc and probable BOW) 1.51/2910 w/ 100-200 psi dill, 2.0-2.5k wob w/ 10.22 ECD. Drilled very slow and had incr in diff at 7114.1', but was probably a siderite streak. Drilled formation to 7122'. Bottom's up was 90% formation sand, 5% siderite, 5% metal. WEXIT Ream and backream window area 3 times. Dry run through window, tag up at 7109ft. Clean PU. Set down at 7107ft. Clean PU. Pump at 0.5bpm & got through with no weight bobbles. Work area. Dry tag at 7107ft. clean PU. Stop pumping & set 2k down, start pumping. Stalled after 2 min. 5k overpull. Work area. Dry tag at 7107ft, spin bit past & dry tag at 7122ft. WEXIT Open EDC & swap well to 8.9ppg flo-pro. 5K overpull at 6745ft. Jet 7" casing. WEXIT Flow check while at 6540ft - no flow. WEXIT Continue to POH. PJSM regarding handling milling BHA while POH. WEXIT Flow check well - no flow. Pop off well. Attempt to blow down tools with no luck. Lay down 2-3/8" drill collars. Mill was 2.73" no-go. Heavy scarring on face of mill caused from junk on the whipstock tray, resulting in the mill to be flat on the bottom. Recovered 2 large pieces of metal jammed in 2 of the 3 jets. Metal is serrated on one side, dished on the other side & off the top of the whipstock, eureka! WEXIT Make up milling BHA consisting of 2.73" no-go Weatherford crayola tip mill and 2.73" string reamer. WEXIT Continue to make up window dressing BHA. C/O UOC o-rings. WEXIT RIH with window dressing mill. WEXIT Log down for tie-in from 6980ft (-12ft corr. WEXIT RIH & dry tag twice at 7099ft. WEXIT PU to 7095ft. Start pumping at 1.5bpm/2830psi/10.37 ECD. Mill at 30fUmin from 7095ft to 7110ft with slight motor work at 7095ft. Divert bottom's up to tiger tank (oil). PU to 7085ft. Dry tag bottom at 7112ft, clean through the window. PU to 7085ft & ream one more time through the window. Run through window dry -clean. WEXIT POH. PreSpud mtg while POH. WEXIT Flow check. Crew chg/safery mtg WEXIT Set injector on legs. LD milling BHA PRODi BHI reconfigure the BHA for drilling and test Nordic begin changeout of pulsation dampener on pump #1 PROD1 WO Nordic to fin pump #1 repair work PROD1 BHI noticed the well was beginning to flow over the lubricator 17:45 - 20:15 I 2.501 STW H I P I P 6/6/2008 20:15 - 21:15 1.00 STWHIP P 21:15 - 21:30 0.25 STWHIP P 21:30 - 22:40 1.17 STWHIP P 22:40 - 23:45 1.08 STWHIP P 23:45 - 00:00 00:00 - 00:35 00:35 - 02:00 02:00 - 02:40 02:40 - 02:55 02:55 - 04:15 04:15 - 05:55 05:55 - 06:45 06:45 - 07:30 07:30 - 08:45 08:45 - 09:30 09:30 - 10:15 0.251 STWHIPIN 0.58 STWHIP N 1.42 STWHIP N 0.67 STWHIP N 0.25 STWHIP N 1.33 STWHIP N 1.67 STWHIP N 0.83 STWHIP N 0.75 STWHIP N 1.25 DRILL N 0.75 DRILL N 0.75 DRILL N Printed: 6/30/2008 9:32:34 AM ~ ~ BP EXPLORATION Page 3 of 16 Operations Summary Report Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date '! From - To Hours Task I Code NPT Phase Description of Operations 6/6/2008 09:30 - 10:15 0.75 DRILL N PROD1 stub and driller recorded a 0.1 bbl gain. SI B/S rams and monitor pressure. After 30 min whp was 80 psi Nordic fin pulsation dampener replacement 10:15 - 10:30 0.25 DRILL N PROD1 Safety mtg re: MU nozzle assy 10:30 - 12:00 1.50 DRILL N PROD1 BHI reconfigure BHA. Close lower swab and bleed off 105 psi whp. MU nozzle BHA and had short in MWD LOC. Change it out and test okay. PT lub to 500 psi. Open swab to 115 psi whp PT pulsation dampener for pump #1 and leaked at factory MU flange 12:00 - 13:30 1.50 DRILL N PROD1 RIH w/ BHA #3 circ thru nozzle 0.35/835 holding 200 psi whp Safety mtg re: RD pulsation dampener Discuss future SIMOPS w/ Nordic 3 on D-122 w/ CPAI planner & Drlg Supv 13:30 - 15:45 2.25 DRILL N PROD1 Park at 7080' CTD Circ out crude influx w/ 8.9 ppg Flo Pro 1.25/2100 w/ 300 psi induced whp. Take 30 bbls of 7.45 ppg returns to tiger tank w/ BU at 8.3 ppg PVT 132 Second circ, incr rate to 1.60/2930 and bring returns inside at 8.9 ppg while hold 200 psi whp PVT 132 Third circ 1.6/2650 w/ open choke. Continue to circ while wo KWF Add 100 bbls of 8.9# mud to 118 bbls 9.5# mud on vac truck Remove pulsation dampner and find bladder had been baked inside rendering it useless 15:45 - 16:30 0.75 DRILL N PROD1 Add 100 bbls of 8.9# mud to 118 bbls of 9.5# mud on vac truck Find out that injection wells i C-10, 1 D-02, 1 D-05, 1 D-09, 1 D-10 and 1 D-11 are on line. 1 C-10 is the most likely culprit injecting 2000 bwpd in this fault block. The CPF-1 Engr had it SI 16:30 - 17:15 0.75 DRILL N PROD1 Start 9.25# Flo Pro 1.61/2600 Begin to install new bladder in old pulsation dampener 17:15 - 18:30 1.25 DRILL N PROD1 POOH circ 1.52/2350 while finish displacing wellbore to 9.25# mud. 18:30 - 18:35 0.08 DRILL N PROD1 Notified Chuck Scheve at AOGCC of taking a kick & shutting in blind rams due to well flowing. 18:35 - 18:45 0.17 DRILL N PROD1 Flow check well - no flow. 18:45 - 19:15 0.50 DRILL N PROD1 Blow down & lay down BHA & reconfigure same for drilling build BHA. Clean out high pressure screen in reel house -lots of goodies inside. 19:15 - 19:50 0.58 BOPSU N PROD1 Pressure test blind rams & choke line & HCR per AOGCC regs, 250/3500psi -PASS. 19:50 - 20:05 0.25 DRILL P PROD1 PJSM regarding handling drilling BHA & making drift run of BHA with slickline. 20:05 - 21:15 1.17 DRILL P PRODi MU build BHA. Deploy BHA conventionally into well using tugger with great difficulties. Stab onto well. Set counters. Power up & test tools. 21:15 - 22:40 1.42 DRILL P PROD1 RIH. Slight bobble at the D nipple. 22:40 - 23:00 0.33 DRILL P PROD1 Log down for tie-in from 7000ft (-18ft corr. 23:00 - 23:05 0.08 DRILL P PROD1 RIH, slight bobble at 7108ft in the window & tag bottom at 7112ft. 23:05 - 00:00 0.92 DRILL P PROD1 Drilling build with great difficulties from 7,112 ft to 7,123ft. With TF at HS Op 1.5/1.4 bpm at 3000 psi off bottom psi Pnntetl: 6/302008 y:32:94 AM ~ r BP EXPLORATION Operations Summary Report Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours '~, Task Code ~~ NPT 6/6/2008 23:05 - 00:00 0.92 DRILL P 6/7/2008 100:00 - 02:30 2.501 DRILL ~ P 02:30 - 04:00 I 1.501 DRILL I P 04:00 - 04:45 I 0.751 DRILL I P 04:45 - 06:30 1.75 DRILL P 06:30 - 07:10 0.67 DRILL P 07:10 - 09:40 ~ 2.50 ~ DRILL ~ P 09:40 - 11:40 ~ 2.00 ~ DRILL ~ P 11:40 - 12:00 0.33 DRILL P 12:00 - 14:40 2.67 DRILL P 14:40 - 15:30 0.83 DRILL P 15:30 - 16:00 0.50 DRILL P 16:00 - 17:20 1.33 DRILL P 17:20 - 19:20 2.00 DRILL P 19:20 - 20:40 ~ 1.33 ~ DRILL ~ P 20:40 - 21:00 0.33 DRILL P 21:00 - 22:00 1.00 DRILL P 22:00 - 22:10 I 0.171 DRILL I P 22:10 - 00:00 I 1.831 DRILL I P Start: 5/30/2008 Rig Release: 6/21/2008 Rig Number: Page 4 of 16 ~ Spud Date: 6/1 /2008 End: 6/21 /2008 Phase Description of Operations PROD1 Density = 9.07 / 9.35 ppg DHWOB = 0.8k to 1.5k. Vp = 453 bbl BHP /ECD /WHP = 3,612psi / 10.98ppg / 29psi PROD1 Drilling build from 7,123ft to 7,160ft. With TF at HS Qp 1.5/1.35 bpm at 3000 psi off bottom psi Density = 9.05 / 9.14 ppg DHWOB = 0.8k to 1.5k. Vp = 445 bbl BHP /ECD /WHP = 3,620psi / 10.93ppg / 29psi Build rate is 55 degrees/100ft -too high. PROD1 POH for 2 deg AKO motor. 4k overpull at window. PUH to 7080ft & open EDC & flow check - no flow. MWout = 9.1 ppg & BHP = 3050psi at the window. PJSM while POH regarding handling BHA. Lost 7 bbls on trip OOH. PROD1 Flow check - no flow. Pop off well. Short chain BHA & break off motor. Dial down motor to 2 deg AKO. Stab on well. Power up & test tools. Set counters. PROD1 RIH with 2 degree AKO build BHA. PROD1 Log tie-in down to GR marker at 7000', Corr -12'. Close EDC. RIH thru window, clean at min rate. Log tie-in down to RA pip in WS for tie-in to mother wellbore PRODi Drill from tag at 7160' 1.53/1.46/3100/1 R w/ open choke w/ 100-300 psi dill, 0.5-1.5k wob w/ 11.1 ECD at 10-40'/hr to 7245' where P rate slowed down which is near expected top of B Shale PROD1 Drill from 7245' 1.51/1.49/3140/258 w/ 100-300 psi dill, 0.8-1.8k wob w/ 10.96 ECD to 7300' and have 73 deg at bit PRODi Wiper to window was clean both ways PRODi Drill from 7300' 1.51/1.46/3230/208 w/ 200-400 psi dill, 1.0-2.4k wob w/ 10.99 ECD while finish the build and land at 7345' (6498' TVD) at 90 deg. Continue invert to 7401' w/ 104 deg at bit PROD1 Wiper to window was clean. Pull thru window, open EDC. POOH jetting to 6700' 1.8/3300. RBIH jetting to window. Switch to 10.8# Flo Pro mud PROD1 Circ KWF mud to bit PROD1 POOH while displace wellbore to KWF PROD1 LD build assy. Reconfigure tools with resistivity. MU lateral section BHA with 1 deg AKO motor -tools went smooth into well with tugger. Swap 5ft lubricator for Oft lubricator. Get new deployment numbers. Power up & test tools. Set counters. PROD1 RIH with lateral BHA. Bleed down IA from 550psi (gas) to 100psi, OA is not traking. Open EDC & start swapping coil to 9.1pg flo-pro while RIH. PROD1 Log down for tie-in from 7015ft (-15ft corr. PRODi RIH to 7100ft & swap well to 9.1ppg Flo-Pro while slowly PUH to reduce losses. Attempt to hold 500psi on choke while closing EDC. Slowly bled down while RIH through the window. PROD1 Wiper to TD. Turn on centrifuge'A' & gun lines. Tag bottom at 7401ft. PROD1 Drill invert from 7,401ft to 7,489ft. With TF 90-1808 Op 1.7/1.58 bpm at 3720 psi off bottom psi rnrnea: oi~urzwo a:ac.,w Hm ~ r BP EXPLORATION Operations Summary Report Legal Well Name: Common Well Name Event Name: Contractor Name: Rig Name: 1 D-04 1 D-04 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Start: 5/30/2008 Rig Release: 6/21/2008 Rig Number: Date From - To ' Hours Task Code NPT Phase i 6/7/2008 22:10 - 00:00 ~ 1.83 DRILL P PROD1 6/8/2008 100:00 - 03:05 3.081 DRILL P PROD1 03:05 - 03:15 0.17 DRILL P PROD1 03:15 - 04:10 0.92 DRILL P PROD1 04:10 - 04:25 0.25 DRILL P PROD1 04:25 - 06:40 2.25 DRILL P PROD1 06:40 - 07:15 0.58 DRILL P PROD1 07:15 - 09:00 1.75 DRILL P PROD1 09:00 - 09:50 0.831 DRILL P PROD1 09:50 - 10:05 0.25 DRILL P PROD1 10:05 - 10:30 0.42 DRILL P PROD1 10:30 - 12:30 2.00 DRILL P PROD1 12:30 - 13:30 1.00 DRILL P PROD1 13:30 - 16:40 3.17 DRILL P PROD1 16:40 - 17:40 1.00 DRILL P PROD1 17:40 - 20:10 2.50 DRILL P PROD1 20:10 - 21:45 1.581 DRILL P PROD1 21:45 - 21:55 0.17 DRILL P PROD1 21:55 - 22:35 0.67 DRILL P PROD1 Page 5 of 16 Spud Date: 6/1 /2008 End: 6/21 /2008 Description of Operations Density = 9.20 / 9.45 ppg DHWOB = 0.8k to 1.5k. Vp = 350 bbl BHP /ECD /WHP = 3,820psi / 11.55ppg / 40psi Continue drilling invert from 7,489ft to 7,550ft. With TF 90-1808 Op 1.7/1.62 bpm at 3720 psi off bottom Density = 9.28 / 9.35 ppg DHWOB = 0.8k to 3.5k Vp = 347 bbl BHP /ECD /WHP = 3,915psi / 11.65ppg / 40psi Wiper to 7,410ft. Log MAD pass up from 7,410ft to 7,110ft at 300fVhr. Wiper to TD. Drill invert from 7,550ft to 7,700ft. With TF 90-1808 Op 1.7/1.62 bpm at 3850 psi off bottom Density = 9.25 / 9.33 ppg DHWOB = 0.8k to 3.5k Vp = 335 bbl BHP /ECD /WHP = 3,927psi / 11.71 ppg / 40psi Bleed down OA from 600psi to 200psi (gas & fluid). Wiper to window was clean both ways PVT 318 Drill from 7700' 1.64/1.60/3650/1008 w/ 200-400 psi dill, 1.5-2.5k wob w/ 3897 psi dhp=11.67 ECD at 100 deg in the C2/C3 interface area. Drill to 7850' Wiper to window was clean. Pull thru window. Open EDC and jet solids out of the liners 1.74/3200 to EOT at 6700'. RBIH to 7000' Log tie-in to GR at 6996', Corr +5'. Close EDC Wiper back to TD was clean PVT 305 Drill from 7850' 1.62/1.60/3670/908 w/ 200-400 psi dill, 1.0-3.Ok wob w/ 11.72 ECD at 95 deg in the C3. Swap to left at 7900'. Drill to 8000' Wiper to window was clean both ways PVT 299 Drill from 8000' 1.55/1.51/3420/85L w/ 100-300 psi dill, 1.0-2.5k wob w/ 11.65 ECD at 93 deg in the C3 at 80-100'/hr. Get into siderite streaks from 8040' and have 3.Ok wob w/ +2k string wt. Point TF 10L at 8075' after it appears that siderite has stopped the inversion and are at 92 deg. Resume drilling in good sand w/ 1.Ok wob and 6k surface wt at 120'/hr and get back to 95 deg. Drill to 8150' W iper to window Drill lateral from 8,150ft to 8,300ft. With TF 90L-100L Op 1.6/1.57 bpm at 3850 psi off bottom Density = 9.28 / 9.34 ppg DHWOB = 0.8k to 2.5k Vp = 284 bbl BHP /ECD /WHP = 3,950psi / 11.93ppg / 40psi Wiper to the window -clean. Stop pumping & trap 350psi, PUH through window -clean & open EDC. PUH while jetting 5" liner & 7" casing to 3.5" tubing at 6680ft. Log down for tie-in (+6ft). Close EDC. Wiper to TD -clean. Conduct mud swap to 8.6ppg rnrnea: wsui~uun aacaa r+m r BP EXPLORATION Page 6 of 16 Operations Summary Report Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ' Task Code ~i NPT Phase Description of Operations 6/8/2008 ~ 21:55 - 22:35 0.67 DRILL P PROD1 while RIH. Lost DC power to pumps & traction motor ~ 8249ft 22:35 - 00:00 1.421 DRILL N RREP ~ PROD1 6/9/2008 100:00 - 01:30 1.50 ~ DRILL ~ N ~ RREP PROD1 01:30 - 04:30 ~ 3.00 ~ DRILL ~ P ~ ~ PROD1 04:30 - 06:15 1.751 DRILL P PROD1 06:15 - 09:10 2.921 DRILL P PROD1 09:10 - 10:25 I 1.251 DRILL I P I I PROD1 10:25 - 10:35 0.17 DRILL P PROD1 10:35 - 11:10 0.58 DRILL P PROD1 11:10 - 12:30 1.331 DRILL P PROD1 12:30 - 12:55 0.42 DRILL P PROD1 12:55 - 14:20 1.42 DRILL P PROD1 14:20 - 15:10 0.83 DRILL P PROD1 15:10 - 16:40 1.50 DRILL P PROD1 16:40 - 17:15 0.58 DRILL P PROD1 17:15 - 19:00 1.75 DRILL N RREP PROD1 19:00 - 19:25 ~ 0.42 ~ DRILL ~ P ~ ~ PROD1 19:25 - 20:00 I 0.581 DRILL I P I I PROD1 while RIH. Trouble shoot SCR problem. PJSM regarding pumping with Hot Oil. RU Hot Oil. P.T. to 4000psi. Begin pumping 8.6ppg Flo-pro down coil while holding 100psi WHP. Trouble shoot SCR room. Start SLB traction motor & move pipe -clean PU. Continue to swap well to 8.6ppg, bottom's up was uneventful. Slowly PUH to 7900ft & discuss with rig electricians. Possible overheat situation on DC board. Will need to replace 4-12 volt batteries that supply DC side of SCR room next time OOH - 2hrs to replace. Swap to rig pumps. RD Hot Oil truck. RIH with coil. Drill lateral from 8,300ft to 8,450ft. With TF 908-1108 Op 1.7/1.68 bpm at 3350 psi off bottom Density = 8.75 / 8.78 ppg DHWOB = 0.8k to 2.Ok Vp = 327 bbl BHP /ECD /WHP = 3,677psi / 11.34ppg / 30psi Wiper to the window & to TD was clean. Slow wiper at end while geo's decide strategy-will shoot the moon and look for D shale PVT 275 Drill from 8450' 1.53/1.50/3080/408 w/ 100-400 psi dill, 1.0-3.5k wob w/ 11.05 ECD at 94 deg and target the top of the C4/D Shale interface in this fault block. Spend and hour at 8505-12' in siderite. Drill to 8527' and find another one Drill from 8527' 1.66/1.63/3250/708 w/ 100-200 psi dill, 1.5-3.5k wob w/ 11.15 ECD at 98 deg. Drill to 8550' and see 182 api rock on GR. Geo confirms 10-12' TVD feet before planned TD 100' wiper was clean PVT 270 Drill from 8550' 1.60/1.57/3100/608 w/ 100-300 psi dill, 1.5-3.2k wob w/ 11.20 ECD at 99 deg. Drill to 8556' Slow wiper while geo checks sample. Call this deep enough. Continue wiper to window, clean. Pull thru window, clean. Open EDC and jet solids out of liners 1.76/2710 to EOT at 6700'. RBIH to 7000' Log tie-in to cased hole marker at 6996', corr +9'. Close EDC Wiper back to TD was clean to wt loss starting at 8525'. Ream to 8540' and set down. Overpull and backream w/ more overpulls and MW to 8490'. Ream back in hole to TD tagged at 8560'. Backream again to 8490' and was clean. Ream to TD, clean and confirm 8560' TD Wiper OOH leaving 2 ppb Alpine beads in open hole POOH thru window and circ 10.8# Flo Pro to surface while POH LD drilling BHA Send BTT to Deadhorse to put together an anchored WS Fill hole. SI swabs. SD rig power to replace batteries for ESD. Found loose & dirty wires. Start your engines! Let there be light! PJSM regarding RU liner handling equipment & testing mud pump #1. RU Farr tongs. RU 2-3/8" flat top elevators. MU TIW to 2" Nnntea: tiisurzuua a:~csa Hrvi a i BP EXPLORATION Page 7 of 16 Operations Summary Report Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Hours Task Code i NPT ' Phase Description of Operations Date From - To - 6/9/2008 19:25 - 20:00 0.58 DRILL P PROD1 safety joint. Open swabs & top off well -2bbls to fill hole. Reconfigure BOT tools for orientor on the catwalk, test same. HOT failed to test, C/O HOT & reprogram tools. 20:00 - 20:35 0.58 DRILL N WAIT PROD1 Wait for BOT to bring OH anchor assembly. 20:35 - 23:00 2.42 CASE P LNR1 MU liner per program. RD Farr tongs. PU & injector, check CTC & stab onto BHI tools. Stab onto well. Power up & test tools. Set counters. 23:00 - 00:00 1.00 CASE P LNRi Top off hole _ 3bbls. RIH w/ liner ~ 75ft/min. 6/10/2008 00:00 - 01:50 1.83 CASE P LNR1 RIH w/liner. WT ck at window = 22k & 11 k RIW. Set 1 k down at 7,269ft, clean PU. Orientate past, tag up at 7,274ft, clean PU. Log down for tie-in (-16ft corr. WT ck at 8,550ft = 23k & 8.8k RIW. Tag at 8,558ft. Orientate single slip at 160R. PU to neutral WOB. Pressure to 3900psi & set anchor. Set 2k down - holding. Clean PU, 21 k. 01:50 - 02:30 0.67 CASE P LNRi POH filling across the top. 02:30 - 03:00 0.50 CASE P LNR1 Discrepancy in trip sheet. Stop at 5500ft EOP & flow check - no flow. Pump down coil, 4bbls, fluid fell out of coil. Crisis averted. 03:00 - 03:50 0.83 CASE P LNR1 POH pumping down coil at min rate. PJSM while POH regarding handling BHA. 03:50 - 04:00 0.17 CASE P LNR1 Tag up. Flow check - no flow. 04:00 - 05:15 1.25 CASE P LNR1 Pop off well. Short chain tools OOH. LD setting tool. Hoist up 2 new motors. Perform bi-weekly function test of ROPE per AOGCC regs. MU sidetrack BHA. MU coil to tools. Stab onto well. Power up & test tools. Set counters. 05:15 - 06:35 1.33 STWHIP P PROD2 Open EDC. RIH with sidetrack BHA. Swap coil to 8.6ppg Flo-Pro at min rate while RIH. 06:35 - 07:00 0.42 STWHIP P PROD2 Log tie-in down to GR marker at 6996', corr -14'. Close EDC 07:00 - 07:30 0.50 STWHIP P PROD2 Wiper to top of liner while fin circ out KWF 07:30 - 08:30 1.00 STWHIP P PROD2 Tag billet at min rate at 7728'. Make two down passes from 7715' 1.55/1.53/2940/160L 08:30 - 10:10 1.67 STWHIP P PROD2 Time drill sidetrack from first MW at 7727.40'. Drill to 7729.30' stacked 3k and stalled? PU and had high circ press 1.35/3650. Assume either aluminum, motor rubber or trash in jets 10:10 - 10:30 0.33 STWHIP P PROD2 200' wiper while clearing jets, new parameters 1.53/3160 10:30 - 12:30 2.00 STWHIP P PROD2 Attempt to drill ahead slowly, but continue to stack wt and stall to 7731.3'. Acts like bit is balled up w/aluminum since can stack 5k w/ little MW. Backream to shuck 12:30 - 13:40 1.17 STWHIP P PROD2 Get off and drill from 7731.3' 1.55/1.54/3120/160L w/ 100-200 psi dill, 1.0-1.5k wob w/ 10.96 ECD. Bring TF up from 7745' to 120E and drill to 7765' which should be far enough to meet targets PVT 301 13:40 - 14:30 0.83 STWHIP P PROD2 Ream and backream billet area 30L and 30R of DTF and was clean 14:30 - 15:00 0.50 STWHIP P PROD2 Wiper to window was clean 15:00 - 16:30 1.50 STWHIP P PROD2 Open EDC. POOH circ thru EDC 1.62/2800 following pressure schedule. 16:30 - 16:45 0.25 STWHIP P PROD2 PJSM regarding pressure undeploying side track BHA. 16:45 - 18:30 1.75 STWHIP P PROD2 Pressure undeploy BHA. Crew change, PJSM 18:30 - 22:15 3.75 STWHIP P PROD2 Pressure undeploy BHA. Bit had 1 plugged jet with aluminum. Change motor AKO, PU USR tool held PJSM and pressured deployment of BHA 22:15 - 23:35 1.33 DRILL P PROD2 RIH to 7,015 ft Printetl: 6/302008 9:32:34 Ann BP EXPLORATION Page 8 of 16 Operations Summary Report Legal Well Common W Event Nam Contractor Rig Name: Date Name: 1 ell Name: 1 e: Name: From - To D-04 D-04 REENTE NORDIC NORDIC Hours R+COM CALIST 2 Task PLET A Code E NPT Start Rig Rig Phase III Spud Date: 6/1/2008 : 5/30/2008 End: 6/21/2008 Release: 6/21/2008 Number: Description of Operations 6/10/2008 23:35 - 23:50 0.25 DRILL P PROD2 Tie in at 7,015 ft and corrected -16 ft 23:50 - 00:00 0.17 DRILL P PROD2 Closed EDC and RIH with min Op through the build section and the OHST 6/11/2008 00:00 - 00:26 0.43 DRILL P PROD2 RIH and tagged bottom at 7765 ft 00:26 - 02:27 2.02 DRILL P PROD2 Drilling lateral TF at 170E HS Op = 1.57 / 1.58 bpm OBP = 3600 psi BHP/WHP=3650/33 psi Density = 8.97 / 9.01 ppg Vp = 282 bbl's ROP at 60-9 fph API at 70 Units 02:27 - 02:36 0.15 DRILL P PROD2 Wiper trip to 7780 ft. Turned TF to R-side once back on bottom 02:36 - 04:40 2.07 DRILL P PROD2 Drilling lateral TF at 90R HS Op = 1.61 / 1.60 bpm OBP = 3445 psi BHP/WHP=3678/33 psi Density = 8.97 / 9.01 ppg Vp = 279 bbl's Drilled into something hard at 7,900 ft ROP at 16 fph. Finally worked through wheras the ROP increased to 90 fph. 04:40 - 05:05 0.42 DRILL P PROD2 Wiper trip, clean 05:05 - 07:15 2.17 DRILL P PROD2 Drilling lateral TF at 90R HS Op = 1.61 / 1.60 bpm OBP = 3445 psi BHP/WHP=3678/33 psi Density = 8.97 / 9.01 PP9 Vp = 282 bbl's Drilled to 8200ft. 07:15 - 09:25 2.17 DRILL P PROD2 Wiper to window -clean. Stop pumping & pull through window - clean. Open EDC & jet 5" liner & 7" casing to 3-1/2" tubing at 6684ft & back down to 7030ft. Tie-in +3.5ft. Stop pumping & close EDC. Run through window -clean. Pump min rate through build section -clean & no pumps through billet area - clean. Wiper to TD -clean. 09:25 - 11:10 1.75 DRILL P PROD2 Drilling lateral TF at 90R HS Op = 1.7 / 1.65 bpm OBP = 3800 psi BHP /WHP = 3790 / 44 psi Density = 9.02 / 9.05 ppg Vp = 285 bbl's Drilled to 8350ft. 11:10 - 11:55 0.75 DRILL P PROD2 Wiper to 7780ft and to TD -clean both ways. 11:55 - 13:45 1.83 DRILL P PROD2 Drilling lateral TF at 90L HS Op = 1.7 / 1.69 bpm OBP = 3850 psi BHP/WHP=3815/44 psi Density = 9.02 / 9.03 ppg Vp = 284 bbl's Drilled to 8500ft. 13:45 - 14:45 1.00 DRILL P PROD2 Wiper to 7780ft and to TD -clean both ways. 14:45 - 17:10 2.42 DRILL P PROD2 Conduct mud swap Drilling lateral TF at 90L HS Op = 1.82 / 1.80 bpm OBP = 3300 psi BHP/ WHP/ECD=3578/37 psi/10.57 Density = 8.65 / 8.73 ppg Vp = 47 bbl's Drilled to 8650ft. Printed: tii3oizuue a:az:s4 fwi ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: 1 D-04 Page 9 of 16 ~ Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To ,Hours Task Code NPT Phase Description of Operations 6/11/2008 17:10 - 19:15 2.08 DRILL P PROD2 Wiper trip to the window. 8602ft, 6k overpull. Pulled above WS 19:15 - 20:04 0.82 DRILL P PROD2 20:04 - 21:50 1.77 DRILL P PROD2 21:50 - 00:00 I 2.171 DRILL I P I I PROD2 6/12/2008 ~ 00:00 - 00:15 ~ 0.25 ~ DRILL ~ P ~ ~ PROD2 00:15 - 00:40 0.421 DRILL P PROD2 00:40 - 01:50 1.171 DRILL N ~ WAIT ~ PROD2 01:50 - 02:30 0.67 ~ DRILL ~ N ~ WAIT ~ PROD2 02:30 - 03:45 1.25 DRILL N WAIT PROD2 03:45 - 06:15 2.50 DRILL P PROD2 06:15 - 07:45 1.50 DRILL P PROD2 07:45 - 11:20 3.58 DRILL P PROD2 11:20 - 13:10 ~ 1.83 ~ DRILL ~ P ~ ~ PROD2 13:10 - 14:00 0.831 DRILL P PROD2 and open EDC. PUH pumping at max flowrate to 6600 ft and clean out the 5-1/2" casing. RIH at max rate and log tie at 7015 ft. Corrected +6 ft. Closed EDC RIH, clean Drilling lateral TF at 90R HS Op = 1.82 / 1.80 bpm OBP = 3300 psi BHP/ WHP/ECD=3629/50 psi/10.79 Density = 8.65 / 8.73 ppg Vp = 182 bbl's Wiper trip while repairing cable to MWD shack. Nordic 3 started its move to 1 D Pad. Working on repairing the communications. RIH andwill use the Geosurvey directional spreadsheet from the Geologist. Placed the DD in the MWD shack and will drill using the direction spreadsheet instead of the Wellbore Architect software of BHI that is presently in question to drill the well. Without the spreadsheet would be shut down waiting on the cable coming from Deadhorse RIH and setup to drill with the geo's spreadsheet from the MWD trailer Drilling lateral TF at 90R HS from MWD shack Op=1.70/1.70 bpmOBP=3170 psi BHP/ WHP/ECD=3629/50 psi/10.79 Density = 8.65 / 8.69 ppg Vp = 375 bbl's Wiper to casing to allow Nordic 3 to pass by the reel house on 1 D Pad Open EDC at 7050 ft and Nordic 3 drove past the reel house with very little to spare. PU to 6,600 ft circulating at 2.21 bpm. RIH to 7015 ft at 75 fpm and Op = 2.21 bpm. Logging tie in, corrected Closed EDC RIH with correct TF, no Op through WS and low Op through build section. Drilling lateral TF at 90R HS Op = 1.70 / 1.70 bpm OBP = 3170 psi BHP/ WHP/ECD=3629/40 psi/10.79 Density = 8.65 / 8.69 ppg Vp = 367 bbl's Drilled to 8950ft. W iper to 7780ft and to TD -clean both ways. Drilling lateral TF at 90R HS Op = 1.70 / 1.68 bpm OBP = 3250 psi BHP/ WHP/ECD=3620/40 psi/10.79 Density = 8.71 / 8.72 ppg Vp = 365 bbl's Drilled to 9100ft. Wiper to 7780ft and to TD - 5k overpull at 9012ft & 8980ft, otherwise clean. Slight set down at 9012ft Drilling lateral TF at 90R HS Op = 1.70 / 1.68 bpm OBP = 3250 psi BHP/ WHP/ECD=3620/40 psi/10.79 Density = 8.71 / 8.72 ppg rrinteo: a~ur~~~o a:ac:av Hm ~ ~ BP EXPLORATION Operations Summary Report Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task Code NPT -----~ Start: 5/30/2008 Rig Release: 6/21/2008 Rig Number: Page 10 of 16 ~ Spud Date: 6/1 /2008 End: 6/21 /2008 Phase Description of Operations 6/12/2008 ~ 13:10 - 14:00 0.831 DRILL ~ P ~ ~ PROD2 14:00 - 14:20 I 0.331 DRILL I P I I PROD2 14:20 - 16:10 ~ 1.83 ~ DRILL ~ P ~ ~ PROD2 16:10 - 20:35 ~ 4.421 DRILL P ~ ~ PROD2 20:35 - 23:35 3.00 DRILL P PROD2 23:35 - 00:00 0.42 DRILL P PROD2 6/13/2008 00:00 - 01:30 1.50 DRILL P PROD2 01:30 - 04:15 2.75 DRILL P PROD2 04:15 - 07:30 3.251 DRILL P PROD2 07:30 - 07:35 0.08 DRILL P PROD2 07:35 - 09:40 2.08 DRILL P PROD2 09:40 - 10:25 0.75 DRILL P PROD2 10:25 - 10:35 0.17 DRILL P PROD2 10:35 - 11:50 1.25 DRILL P PROD2 11:50 - 12:00 0.17 DRILL P PROD2 12:00 - 13:00 1.00 CASE P LNR2 13:00 - 14:30 1.50 CASE P LNR2 14:30 - 15:10 0.67 CASE P LNR2 15:10 - 17:00 1.83 CASE N DFAL LNR2 17:00 - 17:45 0.75 CASE N DFAL LNR2 17:45 - 19:15 1.50 CASE P LNR2 19:15 - 19:30 0.25 CASE P LNR2 Vp = 412 bbl's Drill to 9130ft. Stacking out, PUH, very ratty & 10k over pulls. Lots of set downs at 9100ft to 9125ft. Stack out on bottom with no motor work. PUH & work area. Drilling lateral TF at 75R HS Turned TF to Left at 9200 ft Op = 1.70 / 1.68 bpm OBP = 3350 psi BHP/ WHP/ECD=3620/33 psi/10.86 Density = 8.71 / 8.80 ppg Vp = 412 bbl's Drill to 9250ft Wiper to window. 5k overpull at 8,977ft. Above WS, open EDC and cir at max rate to 6,600 ft. WSL had 1 hr meeting with RLG. RIH and tied in and corected. Closed EDC and RIH with correct TF and flow rates. Tagged bottom at 9,255 ft Drilling lateral TF at 60L HS Op = 1.70 / 1.68 bpm OBP = 3350 psi BHP/ WHP/ECD=3697/33 psi/11.09 Density = 8.71 / 8.80 ppg Vp = 387 bbl's ROP slowing down due to siderite. Wiper trip to OHST Finish RIH on wiper trip Drilling lateral TF at 90L HS Op = 1.70 / 1.68 bpm OBP = 3350 psi BHP/ WHP/ECD=3697/33 psi/11.09 Density = 8.71 / 8.80 ppg Vp = xxx bbl's ROP slowing down due to siderite or possible shale. RU to conduct mud swap. Non routine mud swap on Nordic 2 with Nordic 3 on location. Started mud swap (867 ft) at 03:20 hrs / 9,368 ft. POOH. Open EDC at 7080 ft and circulated at max rate. PUH to 6600 ft, RIH to 7015 ft and tied in corrected +8ft, closed EDC. Wiper to TD. Tag bottom at 9372ft. Wiper to window. Start pumping 10.8ppg KWF down hole while POH. Open EDC & circulate well to 10.8ppg. Flow check. POH. PJSM while POH regarding handling BHA & MU liner. Close EDC & flow check. Blow down & LD BHA, motor was weak & bit was 2-2 BT. RU 2" safety joint. RU Farr tongs. MU liner. MU setting tool to liner. MU BHI tools to setting tool & scribe same. MU coil to BHI tools. Stab injector onto well. Power up & test tools. Set counters. RIH with liner. RIH to 3100ft & problems with DPS. POH pumping across the top. Pop off well. LD tools. Found problem. Replace EDC & test tools. MU to liner. Stab onto well. RIH. to 7240 ft Tie in at 7240 ft / 7015 ft. corrected . Wt chec = 22.5k up at 15 Printetl: 6/30/2008 9:32:34 AM ~ ~ BP EXPLORATION Page 11 of 16 Operations .Summary Report Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To I Hours Task Code NPT Phase Description of Operations __ 6/13/2008 19:15 - 19:30 0.25 CASE P LNR2 fpm RIH 19:30 - 20:30 1.00 CASE P LNR2 RIH and tagged at 9373 ft. PU and flood vac line. 20:30 - 20:35 0.08 CASE P LNR2 Pump and set anchor at 3600 psi. Liner set at 9373 ft Top of Liner at 9139 ft 20:35 - 23:15 2.67 CASE P LNR2 PUH filling across the top 23:15 - 00:00 0.75 CASE P LNR2 LD CoilTrac and BOT CTLRT. 6/14/2008 00:00 - 00:50 0.83 STKOH P PRODS Circulate across wellhead. PJSM and RU to cut CT 00:50 - 02:30 1.67 STKOH P PRODS Cutting off 975 ft 2" CT for coiled tubing management. 02:30 - 03:30 1.00 STKOH P PRODS RD cutter and seal cable end. Rev cir and unable to move cable. Switch fluids around and displaced CT with 8.6 ppg flo-pro for slack management 03:30 - 05:00 1.50 STKOH P PRODS Circulating and even with the 8.6ppg flopro no wire movement. Removed 10.8 ppg from pits and lined up to load Pit 5 with freash water Line up and displace the CT with fresh water at 3 bpm. Popped off no wire movement. Back on well and try once move to get wire to move. Wire will not move 05:00 - 05:15 0.25 STKOH P PRODS Pad Evaluation with Nordic Screw. Muster up at the N3 camp and all people accounted for in 3 minutes. ', 05:15 - 07:30 2.25 STKOH P PRODS Pop off well and installed CTC, pull test to 40k and reheaded. ', Pressure test to 4000 psi -good. 07:30 - 07:35 0.08 STKOH P PRODS PJSM regarding handling BHA. 07:35 - 08:15 0.67 STKOH P PRODS MU 1.5 AKO motor to BHI tools. MU coil to BHI tools. Stab onto well. Set counters. Power up & test tools. 08:15 - 09:50 1.58 STKOH P PRODS RIH. 09:50 - 10:00 0.17 STKOH P PRODS Log down for tie-in (-15.5ft corr. 10:00 - 10:45 0.75 STKOH P PRODS Swap well to 8.6ppg Flo-Pro. Stop pumping & close EDC. 10:45 - 11:55 1.17 STKOH P PRODS Wiper to TD. Dry tag billet at 9137ft. 11:55 - 12:25 0.50 STKOH P PRODS Trough 3 times from 9118ft to 9136.5ft TF at 160R HS Op = 1.56 / 1.56 bpm CTP = 2760 psi BHP/ WHP/ECD=3759/26 psi/11.24 Density = 8.72 / 8.91 ppg Vp = 199 bbl's 12:25 - 15:35 3.17 STKOH P PRODS Drill at 0.1ft/min from 9136.5ft TF at 160R HS Op = 1.56 / 1.56 bpm CTP = 2760 psi BHP/ WHP/ECD=3759/26 psi/11.24 Density = 8.72 / 8.91 ppg Vp = 199 bbl's 15:35 - 17:05 1.50 STKOH P PRODS Drill formation from 9140ft TF at 160R HS Op = 1.65 / 1.63 bpm CTP = 3260 psi BHP/ WHP/ECD=3759/30psi/11.36 Density = 8.81 / 8.86 ppg Vp = 390 bbl's Drill to 9155ft & NBI confirms LS KO. 17:05 - 18:00 0.92 STKOH P PRODS Ream & backream 45-60 degrees L & R of drilled TF from 9118ft to 9155ft. 18:00 - 20:30 2.50 STKOH P PRODS POH following pressure schedule. 20:30 - 20:45 0.25 STKOH P PRODS PJSM on undeploying BHA 20:45 - 22:20 1.58 STKOH P PRODS Pressure undeploy BHA 22:20 - 23:00 0.67 STKOH P PRODS Change out MWD and reset motor AKO from 1.5 to 1.0 deg. Cleaned out rock catcher with big holes. Fixed leak on the koomey line and SLB changed packoff. 23:00 - 23:10 0.17 STKOH P PRODS PJSM on Pressure deploying BHA Nnntea: tiiswzuurs a:scsa Hm ~ ~ BP EXPLORATION Page 12 of 16 Operations Summary Report Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT ! Phase Description of Operations 6/14/2008 23:10 - 00:00 0.83 STKOH P PROD3 Pressure deploying BHA 6/15/2008 00:00 - 00:30 0.50 DRILL P PROD3 Finish pressure deploying BHA 00:30 - 02:00 1.50 DRILL P PROD3 RIH with EDC open 02:00 - 02:22 0.37 DRILL P PROD3 Log tie in at 7015 ft, Corrected -22 ft 02:22 - 03:55 1.55 DRILL P PROD3 RIH, tagged bottom at 9156 ft 03:55 - 08:00 4.08 DRILL P PROD3 Drilling lateral TF at 165R Qp = 1.60 / 1.60 bpm OBP = 3070 psi Density = 8.75 / 8.80 ppg BHP /EDC /WHP 3685 psi / 10.97 ppg and 30 psi Work bit slowly to get started Drilled to 9300ft. 08:00 - 10:05 2.08 DRILL P PROD3 Wiper to 7780ft & to TD -ratty at 9155ft, otherwise clean. 10:05 - 14:05 4.00 DRILL P PROD3 Drilling lateral from 9300ft TF at 90-80R Qp = 1.75 / 1.75 bpm OBP = 3760 psi Density = 8.78 / 8.80 ppg BHP /EDC /WHP 3820 psi / 11.45 ppg and 33 psi Lost resistivity for 25ft. Drilled to 9450ft. 14:05 - 14:20 0.25 DRILL P PROD3 PUH to 9430ft. MAD pass up from 9430ft to 9395ft. 14:20 - 16:40 2.33 DRILL P PROD3 Wiper to 7780ft. 1 k overpull at 9322ft. Slowly PUH through side track area to help open it up. Clean to 7780ft. Wiper to TD, minor set down at 9147ft & 9328ft. 16:40 - 19:45 3.08 DRILL P PROD3 Drilling lateral from 9450ft TF at 125-80R Turned TF to 120R at 9,504 ft to extend the path. Made 200 ft wiper at crew change Qp = 1.70 / 1.70 bpm OBP = 3,580 psi Density = 8.81 / 8.84 ppg BHP /EDC /WHP 3800 psi / 11.44 ppg and 50 psi Drilling with -3k to -6.5 k CTW ROP 10-30 fph 19:45 - 20:24 0.65 DRILL P PROD3 Wiper to billet, just stacking wt MAD pass 9525 to 9550 ft 20:24 - 23:00 2.60 DRILL P PROD3 Drilling lateral from 9550ft Op = 1.70 / 1.70 bpm OBP = 3,580 psi Density = 8.84 / 8.86 ppg BHP /EDC /WHP 3854 psi / 11.57 ppg and 55 psi Drilling with -3k to -6.5 k CTW ROP 10-30 fph 23:00 - 23:25 0.42 DRILL P PROD3 Mini wiper, stacking 23:25 - 00:00 0.58 DRILL P PROD3 Drilling lateral from 9642ft Op = 1.70 / 1.70 bpm OBP = 3,580 psi Density = 8.84 / 8.86 ppg BHP /EDC /WHP 3894 psi / 11.69 ppg and 33 psi Drilling with -3k to -6.5 k CTW ROP 10-30 fph 6/16/2008 00:00 - 02:55 2.92 DRILL P PROD3 Drilling ahead. Oriented TD to 180deg (LS) and go find out where we are at in regards to geology to the C3. Wiper trip at 9715 ft CTW at -6.7k 02:55 - 05:00 2.08 DRILL P PROD3 Drilling lateral from 9715ft Qp = 1.70 / 1.65 bpm OBP = 3,580 psi Density = 8.84 / 8.86 ppg BHP /EDC /WHP 3894 psi / 11.69 ppg and 33 psi Drilling with -3k to -6.8 k CTW ROP 5-40 fph Vp = 241 bbl Lost 51 bbl in this shift 05:00 - 05:40 0.67 DRILL P PROD3 Drilling ahead looking for the C3. Drilled to 9,795 ft and called TD. 05:40 - 08:30 2.83 DRILL P PROD3 Wiper to window -clean. Stop pumping &PUH through window Printed: 6/30/2008 9:32:34 AM BP EXPLORATION Page 13 of 16 Operations Summary Report Legal Well Name: 1 D-04 Common Well Name: 1D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/16/2008 05:40 - 08:30 2.83 DRILL P PROD3 -clean. Open EDC & jet 5" liner & 7" casing to 6600ft. 08:30 - 09:15 0.75 DRILL P PROD3 Log for tie-in +26ft correction. Stop pumping & close EDC. 09:15 - 11:10 1.92 DRILL P PROD3 Wiper to TD. Pump liner pill with 2ppb Alpine beads while wipering to TD. Check last 3 survyes. Set down at 9758ft. Tag TD twice at 9810ft. 11:10 - 12:45 1.58 DRILL P PROD3 POH laying in liner pill keeping 3600psi BHP. 12:45 - 14:50 2.08 DRILL P PROD3 Slowly PUH while pumping 10.8ppg KWF from window to surface. Flow check - u-tubing. RIH to 7075ft & circulate some more. Flow check - no flow. 14:50 - 16:05 1.25 DRILL P PROD3 POH. PJSM while POH regarding handling BHA. 16:05 - 17:00 0.92 DRILL P PROD3 Tag up. Flow check - no flow. Pop off well. Blow down tools. Break BHI tools in three segments. 17:00 - 20:30 3.50 CASE P LNR3 PJSM regarding making up liner. MU 2" safety joint & lift nubbin. C/O elevators. Hoist liner equipment to RF. Ran liner as per programme PU Billet and Coiltrac. Confirmed scribe. PU injector 20:30 - 22:00 1.50 CASE P LNR3 Testing tool and RIH with liner Set down at 6,856 ft (6,033 ft slips). PU RIH Looks like the counter is 290 ft off. The 6,856 ft tag (7,146 ft) 22:00 - 22:45 0.75 CASE N SFAL LNR3 Work CT and check the injector counter. Pull up into to casing and change counter out on injector head. 22:45 - 23:00 0.25 CASE P LNR3 RIH with new counter Stopped at 7835 ft 23:00 - 23:25 0.42 CASE P LNR3 Log tie in. Corrected 259.5 ft on the BHI counter and 33 ft on the SLB following the 894 ft BHA correction to the UDAC and 4 ft correct on the mechanical counter 23:25 - 00:00 0.58 CASE P LNR3 RIH tagged at 9800 ft PU Wt = 25.2k Set shoe at 9807 ft with 1280 ft wt down. Confirm orient at 165 LHS to single slip. Pump dow CTwith closed EDC and pressured up to 4,500 psi SD pumps and tool set. 12 k down on tool. 6/17/2008 00:00 - 02:15 2.25 CASE P LNR3 POOH with liner running tools 02:15 - 03:00 0.75 CASE P LNR3 LD Coiltrac and BOT CTLRT 03:00 - 10:20 7.33 BOPSU P PROD4 BOP Test, 250psi/3500psi. Bob Noble with AOGCC wavered witness the BOP test. Retest lower 2" combi's. Pressure test injector packoffs & inner reel valve. ALL PASSED. Fill hole 2bbls to fill hole. 10:20 - 10:25 0.08 STWHIP P PROD4 PJSM regarding handling sidetrack BHA. 10:25 - 11:20 0.92 STWHIP P PROD4 Install check valves in UOC. MU sidetrack BHA. Stab onto well. Power up & test tools. Set counters. 11:20 - 12:35 1.25 STWHIP P PROD4 Open EDC. Slowly circulate coil to 8.6ppg while RIH. 12:35 - 12:45 0.17 STWHIP P PROD4 Log down for tie-in (-12ft corr. 12:45 - 13:35 0.83 STWHIP P PROD4 Slowly PUH & swap well to 8.6ppg Flo-Pro. Close EDC. 13:35 - 14:40 1.08 STWHIP P PROD4 Wiper to TD -clean. Dry tag billet twice at 8972.5ft. 14:40 - 15:20 0.67 STWHIP P PROD4 Trough 3 times from 8971ft to 8945ft. 15:20 - 17:20 2.00 STWHIP P PROD4 Drill off AI billet at 8972 ft at 155R TF WOB 1.7 to 0.5 klbf off the billet at 8,975 ft Op = 1.68 / 1.68 bpm OBP 3,200 psi Density 8.82 / 8.93 ppg Vp = 330 psi. Turned on both centrifuges. 17:20 - 17:30 0.17 STWHIP P PROD4 Gain 40 bbl in pits due to foaming from the flo-pro. Adding Defoam X and no decrease in volume. Ordered out Screen Clean from MIDF in Deadhorse. Lost 300 psi in pump pressure. SD centrifuge. Contacted town and shut down both centrifuge. rnmea: tii~uizuuu a:~c~a Hm • • BP EXPLORATION Page 14 of 16 Operations Summary Report Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date , From - To Hours Task ~I Code NPT Phase Description of Operations 6/17/2008 17:30 - 20:00 2.501 STWHIP P PROD4 Stalled , SD pump and PUH to 8969 ft. Set TF and ream back 20:00 - 21:45 1.751 STWHIP P PROD4 21:45 - 00:00 2.25 STWHIP P PROD4 6/18/2008 00:00 - 00:30 0.50 STWHIP P PROD4 00:30 - 02:30 2.00 STWHIP P PROD4 02:30 - 04:15 1.75 DRILL P PROD4 04:15 - 06:15 2.001 DRILL P PROD4 06:15 - 07:07 0.87 DRILL P PROD4 07:07 - 09:30 2.38 DRILL P PROD4 09:30 - 09:49 0.32 DRILL P PROD4 09:49 - 11:15 1.43 DRILL P PROD4 11:15 - 11:40 0.421 DRILL N DPRB PROD4 11:40 - 16:15 4.58 DRILL P 16:15 - 19:00 2.75 DRILL P 19:00 - 19:45 I 0.751 DRILL I P 19:45 - 20:15 I 0.501 DRILL I P 20:15 - 00:00 3.751 DRILL P in the hole Working to get bit back to 8976 ft Drilled down 8973 ft and stalled. Working way back in hole. Mill to 8976'. Drill ahead. 3400 psi fs at 1.72 in/out. 100-300 psi mtr work. Drill to 8999' at 155R TF. Back ream up past billet. Make three passes up and down. W Iper trip to window. Circulate out of hole. Hold PJSM to discuss handling BHA. Continue to POOH to surface. Pressure undeploy sidetrack BHA. Bit in 1-1-0 condition. MU lateral drill BHA with 1.0 deg mtr and Smith bicenter bit. Pressure deploy BHA. Stab coild and test mwd tools. Get on well. Run in hole. Follow BHP schedule. Corrected -13 ft. Closed EDC and RIH RIH and tagged at 8,999 ft Drill lateral starting at 8,999 ft at 67-70 L HS TF Op = 1.73 / 1.71 bpm OBP 3,520 psi Density 8.9 / 8.9 ppg Vp = 358 psi. W iper trip Drill lateral starting at 9,150 ft at 67-70 L HS TF Op = 1.73 / 1.71 bpm OBP 3,520 psi Density 8.9 / 8.9 ppg BHP /EDC /WHP = 3,843 psi / 11.44 ppg / 40psi Vp = 358 psi. Pulled tight at 9215 ft Tight hole. PU wt at 22k. PU to 58k and down to -6k. Tried working with pump and without pump. Mix 150k LSRV pill 10 %Lube776. SWI and line up pumping down the annulus. Pump down well at 700 psi. Pi dropped to 550 psi and pulled free at 58k Wiper trip to 7090 ft, Pulled above WS and open EDC. PUH at 2.4 bpm to 6600 ft. Tied in and corrected +10 ft RIH Tagged bottom at 9215 ft. Pumped 150k LSRV /10% 776 Drilling from 9215 ft Op = 1.65 / 1.54 bpm Pob = 3680 psi BHP/ECD/WHP = 3970psi / 11.87 ppg / 37 psi Vp 300 bbl's. Drill to 9315'. PROD4 PROD4 PROD4 Drill ahead from 9315'. 3350 psi fs at 1.65 in/out. 100-200 psi mtr work. PROD4 Wiper trip to 8995'. Start 10 bbl hivis sweep down hole. Set do at 9160'. Reduce pump rate. Run to btm. PROD4 Drill ahead. 3700 psi fs at 1.63 in/out. 150-300 psi mtr work. WHP/BHP/ECD: 40/3900/11.67 ppg. Some trouble with weight transfer. Drill to 9495'. Printed: 6/30/2008 9:32:34 AM • BP EXPLORATION Page 15 of 16 Operations Summary Report Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Spud Date: 6/1/2008 Event Name: REENTER+COMPLETE Start: 5/30/2008 End: 6/21/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/19/2008 00:00 - 00:45 0.75 DRILL P PROD4 Wiper trip to billet at 8975'. 00:45 - 04:00 3.25 DRILL P PROD4 Drill ahead to 9569' 3450 psi fs at 1.65 in/out. 100-250 psi mtr work. Having to stack a lot of surface coil wt to drill. Difficult to keep pipe moving. 04:00 - 07:00 3.00 DRILL P PROD4 Make long wiper trip to tbg. Open EDC above window. 4350 psi fs at 2.25 in/out. 07:00 - 10:15 3.25 DRILL P PROD4 Tagged bottom at 9,569 ft. Drilling in C3 w/ TF at 90R Op = 1.70 1.61 bpm fs at 3,900 psi Density = 9.0 / 9.0 ppg BHP/ECD/WHP 4,009 psi / 11.97 ppg / 30 psi Vp = 230 bbls. Called for mud swap LSRV's and PV/YP high 10:15 - 10:41 0.43 DRILL P PROD4 Started mud swap at 9620 ft Op = 1.70 / 1.50 bpm Wiper new mud around, Wiper trip to billet 10:41 - 11:30 0.82 DRILL P PROD4 Wiper to 8975 ft 11:30 - 15:00 3.50 DRILL P PROD4 Tagged bottom at 9,620 ft. Drilling in C3 w/ TF at 90R Op = 1.70 / 1.70 bpm fs at 3,280 psi Density = 8.63 / 8.63 ppg BHP/ECD/WHP 3,662 psi / 10.9 ppg / 33 psi ROP did improve with the new mud in the wellbore 15:00 - 16:05 1.08 DRILL P PROD4 Wiper to 9000 ft 16:05 - 17:19 1.23 DRILL P PROD4 Tagged bottom at 9,775 ft. Drilling in C3 w/ TF at 150R and looking for C2/C3 transition zone on the gamma ray log. TD could be approximately 9,850 ft MD Op = 1.70 / 1.70 bpm fs at 3,280 psi Density = 8.63 / 8.63 ppg BHP/ECD/WHP 3,662 psi / 10.9 ppg / 33 psi ROP did improve with the new mud in the wellbore Projected 80deg at bit, at 9,836 ft 17:19 - 20:15 2.93 DRILL P PROD4 Wiper trip to up in to tbg tail at 6600'. Open EDC in cased hole. 3885 psi fs at 2.37 in/out. Lots of cuttings noted at shaker from liner btms up. Run back in hole to gr tie in depth. 20:15 - 21:30 1.25 DRILL P PROD4 Log GR tie in from 7010'. Add 4.5' correction. Log CCL from 6550' to 6750'. Tbg tail logged at 6674'. 21:30 - 23:30 2.00 DRILL P PROD4 Close EDC. Make wiper trip to TD. Tag TD at 9852'. 23:30 - 00:00 0.50 DRILL P PROD4 Pull out of hole. Lay in liner pill with 2 ppb alpine beads from 9500'. 6/20/2008 00:00 - 02:15 2.25 DRILL P PROD4 Pull up hole from TD at 9852'. Continue to lay in bead pill. Circulate KWF from 7000'. 02:15 - 04:15 2.00 DRILL P PROD4 KWF back to surface. Circulate out of hole. No fluid losses noted. 04:15 - 05:00 0.75 DRILL P PROD4 LD lateral drilling BHA. 05:00 - 05:45 0.75 CASE P LNR4 Rig up floor to make up 2-3/8" liner assembly 05:45 - 11:15 5.50 CASE P LNR4 PU and RIH with Liner 11:15 - 12:54 1.65 CASE P LNR4 RIH and tagged at 9,852 ft Released from liner. Lost 13k downhole wt 12:54 - 14:10 1.27 CASE P LNR4 POOH 14:10 - 15:00 0.83 CASE P LNR4 LD Liner running tool and coil track. PU nozzel BHA. rrirnea: w:tuieuus a:~csn Hm BP EXPLORATION Page 16 of 16 Operations Summary Report 'i Legal Well Name: 1 D-04 Common Well Name: 1 D-04 (Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task Code NPT 6/20/2008 15:00 - 16:15 1.25 CLEAN P 16:15 - 18:30 2.25 CLEAN P 18:30 - 20:30 2.00 CLEAN P 20:30 - 22:00 I 1.501 WHSUR I P 22:00 - 00:00 I 2.00 I DEMOB I P 6/21/2008 100:00 - 03:30 I 3.501 DEMOB I P 03:30 - 04:00 I 0.501 DEMOB I P Spud Date: 6/1 /2008 Start: 5/30/2008 End: 6/21/2008 Rig Release: 6/21/2008 Rig Number: Phase Description of Operations CLEAN RIH with Nozzel BHA to 6625 ft. CLEAN Cleaning out pits. Circulate out 10.8 ppg FloPro with seawater. POOH chasing 10.8ppg brine to surface CLEAN Spot LRS diesel pumper. Hold PJSM with rig crew. RU to cementing line. Pump 25 bbls diesel in to coil. FP well to surface. POOH. Get off well. LD tools. POST Hold PJSM to set BPV. PU and test lubricator to 1500 psi. Run and set Cameron 3-1/8" bpv. Draw down test the same. Rig down lubricator. Remove from rig. POST Empty and clean pits. Hold PJSM to discuss using a hammer wrench and ND BOPs. ND BOPS and cellar plumbing. POST Rig down external equipment (tiger tank, cuttings box etc) LD lubricator on rig floor. ND BOP and cellar MPD components. Grease injector. Check chains.- Rig released at 0330 hrs. on 6/21/08 POST Back rig off well. Standby on edge of pad. Printed: 6/30/2008 9:32:34 AM ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1 D Pad 1 D-04 1 D-04AL1-02 Design: 1 D-04AL1-02 Baker Hughes INTEQ Survey Report 27 June, 2008 ~~~r BAKER Nu+~NEs INTEQ • ConocoPhillips Alaska Company: ConocoPhtllips(Alaska) Inc Project: Kuparuk RiverU~it Site: Kuparuk 1 D Pad Well: 1 D-04 Wellbore: 1 D-04AL7-02 Design: 1 D-04ALt-02 s ConocoPhilli ~R r p sa Baker Hughes INTEQ Survey Report f~~1lS INTEQ Local Co-ordinate Reference: Well 1D-04 , TVD Reference: 1 D-04 ~ 105.OOft MD Reference: 1D-04 ~ 105:OOft 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 2:one• Alaska Zone 04 Using geodetic scale factor Site Kuparuk 1 D Pad ' Site Position: Northing: 5,959,669.68 ft Latitude; 70° 18' 1.318 N From: Map Easting: 561,086.44 ft Longitude: 149° 30' 18.921 W Position Uncertainty: 0.00 ft Slot Radius: 36 " Grid Convergence: 0.47 ° Well 1D-04 Well Poskbn +WS 0.00 ft Northing: 5,959,545.00 ft LatlWde: 70° 18' 0.139 N +EI_yy 0.00 ft Eastlng: 560,490.00 ft Longitude: 149° 30' 36.340 W Position UncertalMy 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft Wellbore 1 D-04AL1-02 Magnetics Model Name Sample Date Declinatlon Dip Angle Field SUength l°- (°- lnT1 BGGM2007 5/14/2008 17.86. 79.75 57,282 Design 1D-04AL1-02 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 8,960.70 VeRicai Section: Depth From (TVD) +W-S +E/-W Direction (ft) (ft) (ft) (°) 105.00 0.00 0.00 85.00 • • 6/27/2008 2:13:OOPM Page 2 COMPASS 2003.18 Build 42F / ConocoPhillips ConocoPhillips Baker Hughes INTEQ Survey Report Alaska Company: ConocoPhtllips(Alaska)lnc. Local Co-oMinate Reference: Protect: Kuparuk River Unk TVD Reference: Site: Kuparuk 1D Pad MD Reference: Well: 1 D-04 North Reference: Welibore: 1D-04AL7-02 Survey Calculation Method: Design: 1D-04AL1-02 Database: ri.r BAKER u ~~u~ Well 1 D-04 1 D-04 ~ 105.OOft 1D-04 ~ 105.OOft True Minimum Curvature. EDMv16 Prod Survey Program Date From To (ft) (ft) Survey {We0bore) Tool Name Description 200.00 7,000.00 1d04 (1 D-04) SEEKER MS BHI Seeker multishot 7,097.15 7,710.70 1D-04A MWD (1D-04A) MWD MWD -Standard 7,727.30 8,960.70 1D-04AL1 MWD(1D-04AL1) MWD MWD-Standard 8,972.50 9,814.06 1D-04AL1-02 MWD (1D-04AL1-02) MWD MWD -Standard Survey MD Inc Azi TVDSS WS E/W Northing EasUng DLS Vertical Section TFO Ift) 1°I 1°I lffl lfU lft) Ift! 1~! (°1100k) Iff1 1°1 8,960.70 95.47 103.79 6,456.41 1,828.19 3,479.74 5,961,400.97 563,954.58 13.66 3,625.84 60.17 8,972.50 96.57 105.26 6,455.18 1,825.25 3,491.10 5,961,398.11 563,965.96 15.50 3,636.90 53.12 9,001.12 88.96 113.00 6,453.79 1,815.89 3,518.07 5,961,388.97 563,993.00 37.87 3,662.94 134.29 9,031.16 90.18 111.50 6,454.02 1,804.51 3,545.87 5,961,377.82 564,020.89 6.44 3,689.65 -50.88 9,060.60 91.44 110.08 6,453.60 1,794.07 3,573.39 5,961,367.60 564,048.49 6.45 3,716.15 -48.41 9,090.08 93.07 107.09 6,452.44 1,784.68 3,601.30 5,961,358.44 564,076.48 11.54 3,743.14 -61.33 9,120.31 94.94 103.01 6,450.33 1,776.85 3,630.42 5,961,350.84 564,105.65 14.82 3,771.46 -65.19 9,150.33 96.21 99.70 6,447.41 1,770.97 3,659.71 5,961,345.20 564,134.98 11.76 3,800.13 -68.76 9,179.81 95.94 95.34 6,444.29 1,767.13 3,688.76 5,961,341.60 564,164.06 14.74 3,828.74 -93.33 9,210.32 95.38 91.42 6,441.28 1,765.34 3,719.06 5,961,340.05 564,194.38 12.92 3,858.77 -97.97 9,239.88 93.59 88.62 6,438.97 1,765.33 3,748.53 5,961,340.28 564,223.84 11.22 3,888.12 -122.55 9,272.02 92.30 84.74 6,437.32 1,767.19 3,780.56 5,961,342.40 564,255.86 12.71 3,920.20 -108.31 9,301.50 91.11 88.06 6,436.44 1,769.04 3,809.97 5,961,344.48 564,285.24 11.96 3,949.65 109.67 9,334.08 90.18 92.62 6,436.07 1,768.85 3,842.54 5,961,344.55 564,317.81 14.28 3,982.08 101.50 9,362.98 88.86 96.25 6,436.32 1,766.61 3,871.34 5,961,342.55 564,346.63 13.36 4,010.58 109.99 9,393.70 87.91 100.63 6,437.18 1,762.11 3,901.71 5,961,338.29 564,377.03 14.58 4,040.44 102.30 9,420.74 86.65 104.63 6,438.47 1,756.20 3,928.06 5,961,332.60 564,403.42 15.49 4,066.18 107.59 9,453.94 86.28 109.07 6,440.51 1,746.60 3,959.77 5,961,323.25 564,435.20 13.39 4,096.93 94.91 9,483.86 86.16 113.19 6,442.49 1,735.84 3,987.61 5,961,312.72 564,463.13 13.75 4,123.72 91.81 9,514.71 86.72 117.13 6,444.40 1,722.75 4,015.47 5,961,299.85 564,491.09 12.88 4,150.34 82.02 • 6/27/2008 2:13:OOPM Page 3 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1 D Pad WeN: 1 D-04 Wetlbore: 1 D-04AL1-02 Design: 1 D-04AL1-02 ConocoPhillips rr ~ Baker Hughes INTEQ Survey Report s R ~~~ INTEQ Local Co-ordinate Reference: Well 1 D•04 ND Reference: 1D-04 (4g 105.OOft MD Reference: 1 D-04 ~ 105.OOft North Reference: True Survey CalculatJon Method: Minimum Curvature Database: EDMv16 Prod Survey MD Inc Azf NDSS NIS E/W Northing Easting DLS Vertical Section TFO (ft) 1°- 1°I Ift) lffl lft- Iffl (R) (°no0ft) 1~1 l°- 9,545.44 85.70 119.85 6,446.44 1,708.13 4,042.42 5,961,285.45 564,518.15 9.43 4,175.91 110.68 9,576.35 86.10 124.11 6,448.65 1,691.80 4,068.57 5,961,269.34 564,544.43 13.81 4,200.53 84.78 9,605.46 85.83 127.83 6,450.70 1,674.75 4,092.06 5,961,252.47 564,568.06 12.78 4,222.46 94.29 9,634.98 86.41 131.62 6,452.69 1,655.93 4,114.71 5,961,233.84 564,590.85 12.96 4,243.38 81.41 9,665.80 87.24 135.14 6,454.40 1,634.80 4,137.07 5,961,212.89 564,613.38 11.72 4,263.81 76.81 9,695.21 87.39 138.39 6,455.78 1,613.40 4,157.19 5,961,191.65 564,633.67 11.05 4,281.99 87.43 9,726.02 88.31 141.90 6,456.94 1,589.77 4,176.92 5,961,168.18 564,653.59 11.77 4,299.58 75.37 9,753.54 88.53 145.58 6,457.70 1,567.59 4,193.19 5,961,146.14 564,670.03 13.39 4,313.86 86.63 9,774.86 87.85 147.70 6,458.37 1,549.79 4,204.91 5,961,128.44 564,681.89 10.44 4,323.98 107.82 9,805.33 84.51 149.57 6,460.40 1,523.84 4,220.73 5,961,102.62 564,697.92 12.56 4,337.48 150.87 9,814.06 83.52 150.28 6,461.31 1,516.32 4,225.08 5,961,095.14 564,702.33 13.93 4,341.16 144.54 9,852.00 83.52 150.28 .6,465.59 1,483.59 4,243.77 5,961,062.55 564,721.28 0.00 4,356.92 0.00 • 6/27/2008 2:13:OOPM Page 4 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska)lnc. Project: KuparukRiver Unit Site: Kuparuk 1 D Pad Well: 1 D-04 Wellbore: 1 D-04AL1-02 Design: 1 D-04AL7-02 Targets Target Name • hitlmisa target Dlp Angle Dip Dlr. TVD +N/-S +E/-W Northing Eaatlng - Shape (°) (°) (ft) (ftl Iftl lftl Ift) Latitude Longitude 1D-04AL1-01 Fault 3 0.00 0.00 105.00 2,057.66 3,725.00 5,961,632.38 564,197.96 70° 18' 20.367 N 149° 28' 47.715 W - actual wellpath misses by 6443.47ft at 9301.50ft MD (6541.44 TVD, 1769.04 N, 3809.97 E) - Polygon Point 1 105.00 1,417.00 3,797.89 5,960,992.39 564,276.00 Point2 105.00 1,761.79 3,829.65 5,961,337.39 564,304.98 Point3 105.00 2,057.66 3,725.00 5,961,632.38 564,197.96 Point4 105.00 1,761.79 3,829.65 5,961,337.39 564,304.98 1D-04AL1-01 Polygon 0.00 0.00 105.00 1,633.62 1,741.39 5,961,192.42 562,218.02 70° 18' 16.203 N 149° 29' 45.562 W - actual wellpath misses by 6689.17ft at 8960.70ft MD (6561.41 TVD, 1828.19 N, 3479.74 E) - Polygon Point 1 105.00 1,633.62 1,741.39 5,961,192.42 562,218.02 Point2 105.00 1,888.88 2,088.48 5,961,450.44 562,563.01 Point3 105.00 1,992.92 2,584.37 5,961,558.46 563,058.00 Point4 105.00 1,988.27 3,166.41 5,961,558.50 563,640.00 Points 105.00 1,853.91 3,834.42 5,961,429.53 564,309.01 Point 6 105.00 1,818.89 4,211.19 5,961,397.55 564,686.01 Point? 105.00 1,489.14 5,049.66 5,961,074.59 565,527.03 Point8 105.00 1,079.29 5,024.38 5,960,664.59 565,505.05 Point9 105.00 1,498.97 3,820.58 5,961,074.53 564,298.02 Point 10 105.00 1,773.25 3,164.69 5,961,343.49 563,640.01 Point 11 105.00 1,721.23 2,917.24 5,961,289.49 563,393.01 Point 12 105.00 1,649.25 2,538.62 5,961,214.47 563,015.02 Point 13 105.00 1,630.69 2,107.41 5,961,192.44 562,584.01 Point 14 105.00 1,502.58 1,869.36 5,961,062.43 562,347.03 ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-ordinate Reference: TVD Reference: MD Reference: Nortfi Reference: Survey Calculation Method: Database: r~.r B IA#Ki1GF~$ INTEQ weu 1 D-oa 1 D-04 ~ 105:OOft 1 D-04 (t~ 105:00ft True Minimum Curvature EDMvt6 Prod Checked By: Approved By: Date: • 6/27/2008 2:13:OOPM Page 5 COMPASS 2003.16 Build 42F Well Name: 1D-04 Wellbore Diagram (6/3/08) API # 50-029-20416-01-00 Conoco Ph i I I i ps PTD: 20&084 10-3/7" 36#/k K-55 BTC -- A~aSk8 b p ', 557 ft Camco DS Nipple 2.875" LD. 6635 ft HES X Nipple 2.810" I.D. l O ~ ~ T_.r" ".~ o 0 6657 ft BOT SAB-3 Packer 3.250" LD. ti: •' ' o-` ~ -____-` Po 6,651 ft Top of 2-3/8" Liner 6673 ft Camco D Nipple 2.75" LD 3-112" 9.3#/.k L-80 EUE Brd Tubing O'' ra 6684 ft EOT 7" 26#Ift K-55 Casing ~ 6746 ft Top of 5" Liner DRILLING ,,~~rr > 'FLUIDS F/'_' 17. v,-,n,m,,,,,., rn.,,.,Xa en,t,,.,.;,,~ 7oaz o rc RA Marker 7105 k TOWS 7097 k Abandoned C-Sand Abandoned A-Sand ST at 7,728k @160 dept y ST ,979tt 55 deB R 5" 14.9#/k K-55 Liner ~ 7500.0 k ST at 9,135 tt (@180 depR 1D-04A TD:9,560ft 1D-04AL7 TD:9,372ft 1D-04AL1-02 TD: 9,852ft C:\Documents and'~itlgs\hubbletl\Local Settings\Temporary Internet Files\OLKCEIID-04AL1 L12 WBD .xls "~U~~~~ Gig ~'~~,~ ~i~i~ ALASBi.~ OIL AVID GAS CO1~T5ERQATIOi~T CObII-IISSIOrIT Mel Rixse CT Drilling Engineer ConocoPhillips Alaska, Inc. c/o PO Box 196612 Anchorage, AK 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, 1D-04AL-02 ConocoPhillips Alaska, Inc. Permit No: 208-101 Surface Location: 120' FNL, 598' FEL, SEC. 23, T11N, R10E, UM Bottomhole Location: 1537' FSL, 3643' FWL, SEC. 13, T11N, R10E, UM Dear Mr. RIxse: Enclosed is the approved application for permit to redrill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1D-04A, Permit No 208- 084, API 50-029-20416-02. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result iri the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). Sincerely, Daniel T. Seamount, Jr. ~ Chair DATED this 1? day of June, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASIt~IL AND GAS CONSERVATION COMl~lI~IV 20Q~~ PERMIT TO DRI~LI~ !~ 20 AAC 25.005 IaS a Q11 & Gay COOS• CC±'~i 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 .' ~ 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: Kuparuk 1D-04AL1-02 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 9750' TVD 6464'ss 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface: ' ' 7. Property Designation: ADL 025650 - River Pool FEL, SEC. 23, T11N, R10E, UM . 120 FNL, 598 Top of Productive Horizon: 1199' FWL, SEC. 13, T11N, R10E, UM 1480' FSL 8. Land Use Permit: 13. Approximate Spud Date: June 17, 2008 , Total Depth: 1537' FSL, 3643' FWL, SEC. 13, T11 N, R10E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 13,500' 4b. Location of Well (State Base Plane Coordinates): Surface: x-560490 • y-5959545 ~ Zone-ASP4 10. KB Elevation (Height above GL): 105' feet 15. Distance to Nearest Well Within Pool: 2300' ' 16. Deviated Wells: Kickoff Depth: ggg5 feet Maximum Hole An le: 95 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2917 ~ Surface: 2279 18 Casin Pr ram: S ecificatio ns To = Settin ' De th -Bo ttom uantit 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 3090' 6660' 5912'ss 9750' 6464'ss Uncemented Slotted Liner 19. PRESE NT WELL CONDITION SUMMARY (robe completed for Red~iit and Re-entry Operations) Total Depth MD (ft): 7502' Total Depth TVD (ft): 6863' Plugs (measured): None Effective Depth MD (ft): 7450' Effective Depth TVD (ft): 6811' Junk (measured): None Casing Length : ize ement Volume MD TV Conductor /Structural 72' 16" 264 sx Arcticset I I 72' 72' Surface 2890' 10-3/4" 3300 sx Arcticset II 2890' 2690' Intermediate 7042' 7" 1600 sx Self-Stress Cement 7042' 6403' Production Liner 754' 5" 120 sx Self-Stress Cement 6746' - 7500' 6108' - 6861' Liner 1 D-04A 830' 2-3/8" Uncemented Slotted Liner 7728' - 8558' 6420' - 6364' Liner 1 D-04AL1 236' 2-3/ " Uncemented lotted Liner 9137' - 937 ' --641 ' - 6402' Liner 1 D-04AL1-01 667' 2-3/8" Uncemented Slotted Liner 8975' - 9642' -6434' - 6410' Perforation Depth MD (ft): 7102' - 7354' Perforation Depth TVD (ft): 6463' - 6715' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct. Contact Mel Rixse, 564-5620 Printed Name Mei ixs Title CT Drilling Engineer / Prepared By Name/Number: Si natur Phone 564-5620 Date~6" ~~ -~Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill API Number: Number: ~g "~~~ 50-029-20416-62-00 Permit A proval See cover letter for Date: • d ~ ther re uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed me~th/ane, gas hydrates, or gas contained shales: [~ Samples Req'd: ^ yes L~J No Mud Log Req'd: ^ Yes Q~No HZS Measures: Yes ^ No Directional Survey Req'd: I~Yes ^ No Other: ~~~ ~~ k \~G 7 BLS APPROVED BY THE COMMISSION Date ,COMMISSIONER Form 10-401 Revised 12/2005 Submit In Duplicate KRU-04AL1-02 Quadri-Lateral - Coil~Tubing Drilling To: Tom Maunder Petroleum Engineer ~.J~ Alaska Oil & Gas Conservation Commission I~,J From: Mel Rixse CTD Engineer Date: June 16, 2008 Re: 1 D-04AL1-02 Application for Permit to Drill A coiled tubing drilling rig (Nordic 2) will drill 1 additional lateral on well KRU 1 D-04AL1-01 using the managed pressure drilling technique. The1 D-04AL1-02 lateral will exit the 1 D-04AL1-01 at 8975' MD, and drill approximately -775' of C3 sand to the east. The lateral will be completed with 23/8" slotted liner from 9,750' MD up into the tubing tail at 6660' MD. Nordic 2 is currently preparing to run liner on 1 D-04AL1-01 (09:30 Monday, June 16, 2008). After liner is run, a bi-weekly BOPE test will be done. It is BP's desire to commence drilling this lateral June 17, 2008. Your prompt attention is requested. CTD Drill and Complete 1 D-04AL7-02 program: Spud in June 17. 2008 Ria Work 1. Perform bi-weekly ROPE test. 2. Sidetrack 1 D-04AL1-02 lateral off liner top billet from open hole liner top billet on 1 D-04AL1-01 3. Drill to TD 9,750. 4. Circulate in kill weight fluid from window to surface. 5. Run 2-3/8" solid/slotted liner to TD. Place TOL in 3-1/2" tubing tail at 6660' ELMD. 6. FP well to 2500' with diesel. 7. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 8. RDMO Nordic C«~ Post-Ria Work 1. Re-install wellhouse and FL's 2. Pull BPV. 3. Run ive gas lift design. Mud Program: • Will use chloride-based Flo-Pro mud (8.6 ppg) for drilling operations. Since there is no SCSSV installed in 1 D-04, the well will have to be killed prior to running 2-3/8" slotted liner. Will use 10.8 ppg KWF for running liner. Disposal: • No annular injection on this well. ' • Class I I liquids to KRU 1 R Pad Class I I disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Page 1 of 5 June 16, 2008 KRU ~04AL1-02 Quadri-Lateral - Coil~ubing Drilling Casing Program: • 1 D-04AL1-01:2-3/8", 4.6#, L-80, STL from TD(--9,642 MD) to 8975' ELMD. 2-3/8"slotted (2" slots, 0.1875" slot width, 8 slots per ft, 2 slot per row, 90 deg phasing) with blanks across faults where shales may be exposed. Top of liner placed («~ 8975' ELMD with aluminum sidetrack billet. • 1 D-04AL1-02 : 2-3/8", 4.6#, L-80, STL from TD(~9,750 MD) to 6,660' ELMD. 2-3/8"slotted (2" slots, 0.1875" slot width, 8 slots per ft, 2 slot per row, 90 deg phasing) with .~~,/~ blanks across B-shale and across faults where shales may be exposed. Top of liner placed C«3 6660' ELMD (4' above 3-1/2" Tubing Tail) Casing/Liner Information 10 3/4"", K-55, 45.5#, Burst 3580 psi; collapse 2090 psi. 7", K-55, 26#, Burst 4980, collapse 4320 5", K-55, 9.3#, Burst 5,700; collapse 5,500 psi, 2.74" window cut at 7097' MD • 1 D-04A : 2-3/8", 4.6#, L-80, STL from TD(8558'MD) to 7728' MD 2-3/8"slotted (2" slots, 0.1875" slot width, 8 slots per ft, 2 slot per row, 90 deg phasing). Flow through aluminum billet at TOL. • 1 D-04AL1 : 2-3/8", 4.6#, L-80, STL from TD(9,373'MD) to 9,137' MD 2-3/8"slotted (2" slots, 0.1875" slot width, 8 slots per ft, 2 slot per row, 90 deg phasing). Flow through aluminum billet at TOL. Well Control: • Two well bore volumes (200 bbls) of KW F will be on location during drilling operations. • BOP diagram is attached. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3500 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan for 1 D-04AL1-02 • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • The nearest well to 1 D-04AL1-02 is 1 D-09 which is 2300 ft. away. • Distance to the nearest property line is 13,500 (measured at closest point). Logging . • MWD directional and Gamma Ray and Resistivity will be run over all of the open hole section. Hazards • Possible losses due to faulting. , • KRU 1 D pad is considered an H2S pad. 1 D-04 has an H2S level of 80 ppm. The closest SHL to 1 D-04 is 1 D-118 and has an H2S level of 5 ppm. 1 D-12 has the closest BHL and has an H2S level of 100 ppm. All H2S monitoring equipment well be operational. Reservoir Pressure Page 2 of 5 June 16, 2008 KRU~-04AL1-02 Quadri-Lateral - Coil~'Tubing Drilling The most recent SBHP survey (April -08) was gauged at 2917 psi C~ 6389' SSTVD. The EMW is 8.8 ppg at 6389' TVD. Max. surface pressure with gas (0.1 psi/ft) to surface is 2279 psi. , Managed Pressure Drilling Managed pressure drilling techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of lighter drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifolding and the mud pits and will be independent of the BOPS choke. This well does not have a functioning tubing sub-surface safety valve that will be utilized to facilitate BHA deployments and liner running. It is possible that deployment of the BHA under trapped wellhead pressure may be necessary. Pressure deployment of the BHA will be accomplished utilizing the BOP pipe/slips (2-3/8" rams, see attached BOP configuration). The annular preventer will act as a secondary containment during deployment and not as a stripper. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at the 1 D-04AL1-02 TD: Estimated reservoir pressure: 2917 psi at 6389' TVD, 8.8 ppg EMW. • Expected annular friction losses while circulating: 650 psi at KOP and 885 psi at TD (assuming 90 psi/ft, fora 2740' lateral). • Planned mud density: 8.6 ppg equates to 2840 psi hydrostatic pressure at the window. • While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 3633 psi ` or 10.7 ppg ECD. 650 psi surface pressure will be maintained to assure a EMWt. at the window of 10.5#/gal. • When circulation is stopped, ~ 650 psi surface pressure will be applied to maintain constant BHP 3567 psi at the window. Mel Rixse CTD Engineer 564-5620 CC: Well File Sondra Stewman/Terrie Hubble Page 3 of 5 June 16, 2008 1 D-04AL1-02 10-3/4" shoe 2890' RKB Lt-Ot liner top @ 6660' ELMD r 5" liner lop @ 6746' RKB (6741 7" shoe @ 7042' RKB KOP L 7110' MD, 2.74" window C-sand perfs 71D2' - 7186' ELMD (squeezed) Liner damaye 7127' ELMD A-sand pens 733 ' - 7354" MD _ 5" 14.9# K-55 shoe 7500' 3-1/2" Camco DS nipple @ 55T RKB 3-1/2" 9.3# L-80 EUE 8rd Tubing to surface 3-1/2" Camco KBUG gas lift mandrels @ 2657'. 4036', 4949'. 6135' RKB 3-1/2" Camco KBUG gas lift mandrels @ 6558' RKB 3-1/2" HES "X" landing nipple @ 6635' RKB (2.812" min ID) Baker 3-112" PBR @ 6643' RKB Baker SAB-3 packer @ 6657' RKB (3.25" ID) 3-1/2" Camco D landing nipple @ 6673' RKB (2.75" min ID, ~ 'Mill out to 2.80" pre-ng Baker 3-1/2" x 5" monobore whips ck (cemented in place) A lat TD Q 8558' MD ~~ o ~ /, 1 ~~ 2-3/8" STL / Aluminum billet 9137 MD (wp07) lotted line ~ - - _-- AL1 TG (~ 9373' iJG ---- z $~ \~ O \ v i `~~- <~i ~ ~ ~AL1-o, 7D @ 9e1o' Alummurn billet ~ ~ I ~!~`/ID 7728 MD 2-318" STL blank ~ liner across B shat ; ~ ~, AL1-D2 TD @ 9750' MD ConocoPhillips ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1 D Pad 1 D-04 Plan 1, 1 D-04AL1-02 i Plan: Plan #1 Baker Hughes INTEQ Planning Report s 16 June, 2008 ~~~~ BAKER IAItiNE~S INTEQ ~ ConocoPhillips ~~ Conoco Philli s p Baker Hughes INTEQ Planning Report Alaska LNTEQ Company: GonocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well1D-04 Project: Kuparuk River Unit rvD Reference: Mean Sea Level Site: Kuparuk 1D Pad MD Reference: 1D-04 @ 105.OOft Well: 1D-04 North Reference: True Wellbore: Plan 1, 1D-04AL1-02 Survey Calculation Method: Minimum Curvature Design: Plan #1 Database: EDMv16 Prod Project Kuparuk River Unit, North Slope Alaska Map System: US State Plane 1927 (Exact solution) s 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 Site Position: From: Ma Position Uncertainty: Kuparuk 1D Pad _ _ Northing: 5,959,669.68 ft Latitude: 70° 18' 1.318 N p Easting: 561,086.44 ft Longitude: 149° 30' 18.921 W 0.00 ft Slot Radius: Grid Convergence: 0.47 ° Well 1D-04 _ Well Position +NI-S 0.00 ft Northing: 5,959,545.00 ft Latitude: 70° 18' 0.139 N +EI-W 0.00 ft Easting: 560,490.00 ft Longitude: 149° 30' 36.340 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Level: O.OOft Wellbore ~_ Plan 1, 1D-04AL1-02 - Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2007 5/14/2008 17.86 79.75 57,282 Design Plan #1 Audit Notes: Version: Phase: PLAN Tie On Depth: 8,960.70 Vertical Section: Depth From (rvD) +N/-S +E/-W Direction (ft) (ft) (ft) (°) 0.00 0.00 0.00 85.00 ~ 6/16/2008 3:18:25PM Page 2 COMPASS 2003.16 Build 42F ConocoPhillips ~Ger ConocoPhillips Baker Hughes INTEQ Planning Report - A~ska 1NTEQ Company: ConocoPhillips(Alaska) inc. Local Co-ordinate Reference: Well 1D-04 Project: Kuparuk River Unit TVD Reference: Mean Sea Level Site: Kuparuk 1D Pad MD Reference: 1D-04 @ 105.OOft Weil: 1D-04 North Reference: True Weilbore: Plan 1, 1D-04AL1-02 Survey Calculation Method: Minimum Curvature Design: Plan #1 Database: EDMv16 Prod Survey Tool Program Date From To (ft) (ft) Survey (Weilbore) Tool Name Description 200.00 7,000.00 1d04 (1D-04) SEEKER MS BHI Seeker multishot 7,097.15 7,710.70 MWD (1 D-04A TD) MWD MWD -Standard 7,727.30 8,960.70 MWD (1 D-04AL1 TD) MWD MWD -Standard 8,960.70 9,750.00 Plan #1 (Plan 1, 1D-04AL1-02) MWD MWD -Standard - -- - Planned Survey i i MD Inc Azi TVDSS NIS E/VN Northing Easting DLS Vert ical Section TFO (k) (°) (°) (ft) (ft) (ft) (K) (ft) (°HOOft) (ft) (°) 8,960.70 95.47 103.79 6,456.41 1,828.19 3,479.74 5,961,400.97 563,954.58 0.00 3,625.84 0.00 TIP 8,975.00 96.80 105.58 6,454.88 1,824.59 3,493.49 5,961,397.47 563,968.36 15.54 3,639.22 53.14 KOP 8,995.00 92.26 107.69 6,453.30 1,818.88 3,512.59 5,961,391.92 563,987.50 25.00 3,657.75 155.00 3 9,015.00 93.55 112.53 6,452.29 1,812.01 3,531.34 5,961,385.21 564,006.30 25.00 3,675.83 75.00 End of 25/100 DLS 9,115.00 93.68 100.51 6,445.96 1,783.69 3,626.85 5,961,357.65 564,102.02 12.00 3,768.50 -89.00 5 9,205.00 94.55 89.71 6,439.48 1,775.70 3,716.12 5,961,350.38 564,191.35 12.00 3,856.74 -85.0 6 9,263.08 90.00 95.00 6,437.18 1,773.31 3,774.07 5,961,348.46 564,249.32 12.00 3,914.27 130.62 7 9,463.08 87.16 118.84 6,442.21 1,715.57 3,963.97 5,961,292.25 564,439.65 12.00 4,098.40 97.00 8 9,703.08 85.10 90.05 6,458.75 1,656.41 4,193.37 5,961,234.95 564,669.49 12.00 4,321.77 -95.00 9 9,750.00 81.89 85.39 6,464.07 1,658.25 4,239.92 5,961,237.17 564,716.03 12.00 4,368.32 -125.00 TD - 2.3875 6/16/2008 3:18:25PM Page 3 COMPASS 2003.16 Build 42F ConocoPhillips Company: GonocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1D Pad Weli: 1 D-04 Welibore: Plan 1, 1D-04AL1-02 Design: Plan #1 Targets Target Name ConocoPhillips //.fir sw1c Baker Hughes INTEQ Planning Report INTEQ Local Co-ordinate Reference: Well 1D-04 TVD Reference: Mean Sea Level MD Reference: 1D-04 @ 105.OOft North Reference: True Survey Calculation Method: Minimum Curvature Database: EDMv16 Prod - hiUmiss target Dip Angle Dip Dir. TVD -Shape (°) (') (ft) 1D-04AL1-01 Fault 3 (cc 0.00 0.00 0.00 -plan misses by 6443.64ft at 9263.08ft MD (6437.18 TVD, 1773.31 N, 3774.07 E) -Polygon Point 1 0.00 Point 2 0.00 Point 3 0.00 Point 4 0.00 1D-04AL1-01 Polygon (c 0.00 0.00 0.00 - plan misses by 6689.17ft at 8960.70ft MD (6456.41 TVD, 1828.19 N, 3479.74 E) - Polygon Point 1 0.00 Point 2 0.00 Point 3 0.00 Point 4 0.00 Point 5 0.00 Point 6 0.00 Point 7 0.00 Point 8 0.00 Point 9 0.00 Point 10 0.00 Point 11 0.00 Point 12 0.00 Point 13 0.00 Point 14 0.00 +N/-S +EI-W Northing Easting (ft) (ft) (ft) (ft) Lakikude ,Longitude 2,057.66 3,725.00 5,961,632.38 564,197.96 70° 18' 20.367 N 149° 28' 47.715 W 1,417.00 3,797.89 5,960,992.39 564,276.00 1,761.79 3,829.65 5,961,337.39 564,304.98 2,057.66 3,725.00 5,961,632.38 564,197.96 1,761.79 3,829.65 5,961,337.39 564,304.98 1,633.62 1,741.39 5,961,192.42 562,218.02 70° 18' 16.203 N 149° 29' 45.562 W 1,633.62 1,741.39 5,961,192.42 562,218.02 1,888.88 2,088.48 5,961,450.44 562,563.01 1,992.92 2,584.37 5,961,558.46 563,058.00 1,988.27 3,166.41 5,961,558.50 563,640.00 1,853.91 3,834.42 5,961,429.53 564,309.01 1,818.89 4,211.19 5,961,397.55 564,686.01 1,489.14 5,049.66 5,961,074.59 565,527.03 1,079.29 5,024.38 5,960,664.59 565,505.05 1,498.97 3,820.58 5,961,074.53 564,298.02 1,773.25 3,164.69 5,961,343.49 563,640.01 1,721.23 2,917.24 5,961,289.49 563,393.01 1,649.25 2,538.62 5,961,214.47 563,015.02 1,630.69 2,107.41 5,961,192.44 562,584.01 1,502.58 1,869.36 5,961,062.43 562,347.03 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) lft) Name (") (") 9,750.00 6,464.07 2.3875 2-3/8 3 6/16/2008 3:18:25PM Page 4 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1D Pad Well: 1 D-04 Wellbore: Plan 1, 1D-04AL1-02 Design: Plan #1 !i Targets Target Name ', - hitlmiss target Dip Angle Dip Dir. TVD -Shape (°) (°) (ft) 1D-04AL1-01 Fault 3 (cc 0.00 0.00 0.00 - plan misses by 6443.64ft at 9263.08ft MD (6437.18 TVD, 1773.31 N, 3774.07 E) -Polygon Point 1 0.00 Point 2 0.00 Point 3 0.00 Point 4 0.00 1D-04AL1-Ot Polygon (r 0.00 0.00 0.00 - plan misses by 6689.17ft at 8960.70ft MD (6456.41 TVD, 1828.19 N, 3479.74 E) - Polygon Point 1 0.00 ~ Point 2 0.00 i Point 3 0.00 t Point 4 0.00 Point 5 0.00 Point 6 0.00 Point 7 0.00 ~ Point 8 0.00 Point 9 0.00 Point 10 0.00 Point 11 0.00 Point 12 0.00 Point 13 0.00 Point 14 0.00 ConocoPhillips Baker Hughes INTEQ Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: //~\ Well 1 D-04 Mean Sea Level 1 D-04 @ 105.OOft True Minimum Curvature EDMv16 Prod +N/-S +E/-W Northing Easting (ft) (ft) (ft) (ft) Latitude Longitude 2,057.66 3,725.00 5,961,632.38 564,197.96 70° 18' 20.367 N 149° 28' 47.715 W 1,417.00 3,797.89 5,960,992.39 564,276.00 1,761.79 3,829.65 5,961,337.39 564,304.98 2,057.66 3,725.00 5,961,632.38 564,197.96 1,761.79 3,829.65 5,961,337.39 564,304.98 1,633.62 1,741.39 5,961,192.42 562,218.02 70° 18' 16.203 N 149° 29' 45.562 W 1,633.62 1,741.39 5,961,192.42 562,218.02 1,888.88 2,088.48 5,961,450.44 562,563.01 1,992.92 2,584.37 5,961,558.46 563,058.00 1,988.27 3,166.41 5,961,558.50 563,640.00 1,853.91 3,834.42 5,961,429.53 564,309.01 1,818.89 4,211.19 5,961,397.55 564,686.01 1,489.14 5,049.66 5,961,074.59 565,527.03 1,079.29 5,024.38 5,960,664.59 565,505.05 1,498.97 3,820.58 5,961,074.53 564,298.02 1,773.25 3,164.69 5,961,343.49 563,640.01 1,721.23 2,917.24 5,961,289.49 563,393.01 1,649.25 2,538.62 5,961,214.47 563,015.02 1,630.69 2,107.41 5,961,192.44 562,584.01 1,502.58 1,869.36 5,961,062.43 562,347.03 Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name ('7 (") i 9,750.00 6,464.07 2.3875 2-3/8 3 6/16/2008 3:18:25PM Page 5 COMPASS 2003.16 Build 42F ~ hilli ConocoPhillips ri.r ps ConocoP Baker Hughes INTEQ Planning Report l~a~es ~~ 1NTEQ Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Referenc e: Well 1D-04 Project: Kuparuk River Unit TVD Reference: Mean Sea Level Site: Kuparuk 1D Pad MD Reference: 1D-04 @ 105.OOft WeII: 1D-04 North Reference: True Wellbore: Plan 1, 1D-04AL1-02 Survey Calculation Method: Minimum Curvature Design: Plan #1 Database: EDMv16 Prod Targets Target Name j - hit/miss target Dip Angle Dip Dir. TVD +N/-S +E/-W Northing Easting I -Shape (°) (°) (ft) (ft) (ft) (ft) (ft) Latitude ,.Longitude 1 D-04AL1-01 Fault 3 (cc 0.00 0.00 0.00 2,057.66 3,725.00 5,961,632.38 564,197.96 70° 18' 20.367 N 149° 28' 47.715 W -plan misses by 6443.64ft at 9263.08ft MD (6437.18 TVD, 1773.31 N, 3774.07 E) - Polygon Point 1 0.00 1,417.00 3,797.89 5,960,992.39 564,276.00 Point 2 0.00 1,761.79 3,829.65 5,961,337.39 564,304.98 Point 3 0.00 2,057.66 3,725.00 5,961,632.38 564,197.96 Point4 0.00 1,761.79 3,829.65 5,961,337.39 564,304.98 1D-04AL1-01 Polygon (c 0.00 0.00 0.00 1,633.62 1,741.39 5,961,192.42 562,218.02 70° 18' 16.203 N 149° 29' 45.562 W - plan misses by 6689.17ft at 8960.70ft MD (6456.41 TVD, 1828.19 N, 3479.74 E) - Polygon Point 1 0.00 1,633.62 1,741.39 5,961,192.42 562,218.02 Point 2 0.00 1,888.88 2,088.48 5,961,450.44 562,563.01 Point 3 0.00 1,992.92 2,584.37 5,961,558.46 563,058.00 Point4 0.00 1,988.27 3,166.41 5,961,558.50 563,640.00 Point 5 0.00 1,853.91 3,834.42 5,961,429.53 564,309.01 Point6 0.00 1,818.89 4,211.19 5,961,397.55 564,686.01 Point 7 0.00 1,489.14 5,049.66 5,961,074.59 565,527.03. Point 8 0.00 1,079.29 5,024.38 5,960,664.59 565,505.05 Point 9 0.00 1,498.97 3,820.58 5,961,074.53 564,298.02 Point 10 0.00 1,773.25 3,164.69 5,961,343.49 563,640.01 Point 11 0.00 1,721.23 2,917.24 5,961,289.49 563,393.01 Point 12 0.00 1,649.25 2,538.62 5,961,214.47 563,015.02 Point 13 0.00 1,630.69 2,107.41 5,961,192.44 562,584.01 Point 14 0.00 1,502.58 1,869.36 5,961,062.43 562,347.03 ~ Casing Points Measured Vertical Casing Hole Depth Depth Diameter Diameter (ft) (ft) Name (~~) (~~) 9,750.00 6,464.07 2.3875 2-3/8 3 6/16/2008 3:18:25PM Page 6 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1D Pad Well: 1 D-04 Wellbore: Plan 1, 1D-04AL1-02 Design: Plan #1 Plan Annotations Measured Vertical Depth Depth (ft) (ft) 8,960.70 6,456.41 8,975.00 6,454.88 8,995.00 6,453.30 9,015.00 6,452.29 9,115.00 6,445.96 9,205.00 6,439.48 9,263.08 6,437.18 ~ 9,463.08 6,442.21 I 9,703.08 6,458.75 9,750.00 6,464.07 Local Coordinates +NI-S +FJ-W (ft) (ft) 1,828.19 3,479.74 1,824.59 3,493.49 1,818.88 3,512.59 1,812.01 3,531.34 1,783.69 3,626.85 1,775.70 3,716.12 1,773.31 3,774.07 1,715.57 3,963.97 1,656.41 4,193.37 1,658.26 4,239.93 Checked By: ConocoPhillips Baker Hughes INTEQ Planning Report 1NTEQ Local Co-ordinate Reference: Well 1D-04 TVD Reference: Mean Sea Level MD Reference: 1D-04 @ 105.OOft North Reference: True Survey Calculation Method: Minimum Curvature Database: EDMv16 Prod - _ -- - __ _ _ _ _ - - - 1 Comment TIP KOP 3 End of 25/100 DLS 5 6 7 8 9 TD Approved By: Date: • 6/1G/2008 3:18:25PM Page 7 COMPASS 2003.16 Build 42F LEGEND t+I~ ~ ~ r~.Na o,. ..o ....b ~( ^ A 'oowL, ro, IDaw, ro ' - ~ Contact Information: C o n o co P h i I I i ps iR161~ ~O(10C PhIN1~1S ~~ D~~ ~m o ~ ~ ~ y Bill Michaelson : Cell: 907-301-3570 NTEQ Aua,.,Da.AL+a+ Email: bill.michaelson@in[eq.com type Target Azimul0 origin type ws ENJ From ND 1 :.-:- -:. :.~ . .. :. " , user No Targe, (FreeOandl 85011 Sbt 0.00 0.00 0.00 tD-04 Q 105.009 . , ; . . . I I . - - . I ~ _ Prulea Kuparuk Rlwr Unil 2x . - ~_ ~ -• T T ~ ~ SN Kupantll lD Pad _ { ,-F i - I .- _ I { I WNI tOM ~^' I ; { WNlbon. Plant 1D-0IALt-02 Pbn: Wan Y1110-04PMn1 tD-0uLt-02) 1. o~NU 2 I I 1 WELL DETAILS. 1DW ~ 1 1' •. . '~ ~ I t { {1 Ground LavNO % 255 i •W~S •E/~W NortNlnp Eavting Lalltlude l.onpauda Slot 0 00 0 09582% 51 1]00521 98]0 17' 59 081 M9 JO' 4] 500 W . . . . . 2J I ' - i ~ I ~ 4 SECTION DETAILS ANNOTATIONS ~ I I' ~ I i. Sae MO Inc Ai ~ TVp 4WS rE/.W OLap Tfau VSec Tarpet 1 8950.10 %A1 103.18 8438.11 1825.19 3119.]1 000 0% 362581 s: rVD MO pda6on 6456.11 0960.]0 1 ~ 1 l ~ I I 2 8975.00 %59 10558 &5188 1824.58 3193.49 15.59 53.11 383912 3 9995.00 9228 101.fi9 6113.30 191988 3512.58 25.00 155.00 3657.15 6454.% 09]5.00 OP 5330 899500 3 1 } ~ / %15.% %.55 112.53 6452.28 181201 3531.34 25.00 ]500 3675.83 6 811100 %.68 10081 6141% 1]9358 362695 1200 211.00 376830 9 8205.% 89.55 88.]1 6138.48 1]]5.]0 3718.12 1200 2)5.00 3856.14 ] 8263.% 90.00 %.00 6431.19 1]]3.31 3n40] 12.00 130.62 391411 g 5229 %1500 Entl o125I100 DL3 6445.% 911500 5 3948 920500 6431.18 926308 ] - 1 01}IN _- 11X'IO{ ID ~ D04AI.1-0 1 Fa:91 1 '" ~ ~~ ~ - r I t I 1 ' 40%b 9 8161.% 87.18 11881 BM3.21 1]15.51 3983.8] 1200 9100 604221 916306 8 ly - .; '~. I 9 8]03.% 85.10 %OS 8958.]5 1858A1 1193.3] 1300 28100 4321.7) 10 9]50.% 8189 BSSB 618107 18.5818 1239% 1300 23100 9388.32 6458.]5 9]0308 9 6464.0] 9]5000 TD ^" ..__ TB A _ Op r ._-_ _. ... ~ ~ ~- - -. { 4 II 1 { I a - ,~ 5 ~ I 9 - . 8 y D _-. I l • A65 ~ _ 6 7 4 ...-- ~ 4}41 W n 1.1 ALIOW AE . 9 i _ __ .. .i IS - .-_ F M 13 /1tl1 _.._t D[5 _ _ _ I1 I ~ ~ '~~i _ i__. .. ..__ _ - ID04/I .. - HA1111)~ -_ .-. ._ ID~MALI A 1 + I f ~ _ _ _ I - ~ I I I I~ . . ..__ 10 ~ ..{ ' I I ' . I ) ILiI { I { 41 l EI I I I I I zsw _nw zx so w 1x1 u w n a 14 w 11 m 1] w 1v ~ m 99 w 42 LU r w 4s Ln 46s B 4x % 99 so 51 60 sz ~ so 1 . I ' . ~, 61 - U . ; , I t ill_ 1 . i I r, I I. 1111 i _ i ~ .. - i. 63 _ _ ~ I 11.1 - _ I ~ } fi I -- T- t I I 1 ~ I , i ~ . iI I ~ ` I { ~ ~ _ ... 67 _- -_ _- _ - M I I . ,. -. . -1 ~ IID ALI~TD If]-IMA ~ TU r ~ ~~ { I aw, ._.. Fn~ _. _ of 25/IOQ DLS . _. _.. . ... _ __-_ __ . .- ..___-. _ ___. __- _ __-_ __ - ~. _ ~ '. _ - .', I I c '~ T KOP i ~ I I .' - 6 _ T 5 ~ 1. . ,, ~ .. '. I ~615 ~ ~ ~_ _ 1._. _ -_- _- _ T r -L ~ . ~ } ._ - _ _ _ _ I ~ I I I I I - I I ~~ ~ I I I -1D 04/Plea I .ID-04A I O")P~ pl I 1 {- .~ I ~ 651 i ~ ~ ~ .. 'I I I + ~ I I ~ { -tom 1 , I ~ L I . 1 r. . ~ .. 1 I - { 14 ~_ I _ . . 65 T I I I I l ,: ; C~ . 1~ li: I, ~ + I ' ' i ~. 65 19 _ 1 Ij " I , ~ I I I :_ 1 _ !I_I I i ' ~ -- _- I I I i I C I - - ~ I I , 1570 l6(10 361U 1fiW 1690 1]20 llw 11NU 3X111 1X4U 1X]0 JY% 19.w 39611 .tY90 4U2U !Uw lUxll lI10 41LJ 4170 42W l21U 4260 429U 4120 1150 11X0 l110 ]440 4410 1500 45.10 l56U lS9U i62U 46w VmwU Sttrmn u~ XS W^ 110 fi/inl KRU ~04AL1-02 Quadri-Lateral - Coil~ubing Drilling Mahal Viy rah a-ui' ssr ese~ ss a Eso Vrasaxa Traasda.a rte cw.r ral...~~' Ma..al Mec. Yshas Mesa fer flees i. freer Mai -.ar..~w Nee. ler Iles eat to isaee fgarcww rahas ~ sarhn tafaq raha ~ Masts rah. ~g for f-ow cross, manual wing valve ESD to be flanged connections. ping upstream from ESD to be ~" immer unions. to be 1", 5000 psi, Arctic rated. Page 5 of 5 June 16, 2008 1 D-04AL 1-02 Plan 1 export files Maunder, Thomas E (DOA) From: Hubble, Terrie L [Terrie.Hubble@bp.com] Sent: Tuesday, June 17, 2008 9:30 AM To: Saltmarsh, Arthur C (DOA); Okland, Howard D (DOA) Cc: Maunder, Thomas E (DOA); Rixse, Mel G Page 1 of 2 Subject: FW: 1D-04AL1-02 Plan 1 export files Importance: High Attachments: 1D-04AL1-02 Plan 1 Planning Report NAD27.pdf; 1D-04AL1-02 Plan 1 Excel Import File NAD27.txt; 1D-04AL1-02 Ptan 1 Excel Import File NAD83.bct; 1D-04AL1-02 Plan 1 Openworks File NAD27.txt; 1D-04AL1-02 Plan 1 Openworks File NAD83.txt; KRU 1D-04AL1-02 PTD .doc Hi Guys, This RUSH Permit to Drill is on it's way over to you. This is for the addition of one more lateral leg to the set of legs being drilled by Nordic #2. They expect to begin drilling this leg within a couple of hours. Terrie From: Rixse, Mel G Sent: Monday, June 16, 2008 3:55 PM To: Hubble, Terrie L Subject: FW: iD-04AL1-02 Plan 1 export files Terrie, Here are the electronic copies. Mel From: Michaelson, Bill G [mailto:William.Michaelson@bakerhughes.com] Sent: Monday, June 16, 2008 3:27 PM To: Rixse, Mel G Cc: Mapes, Jon Subject: iD-04AL1-02 Plan 1 export files As far as 1 know the geo will need the "excel import" and "bhi openworks" files in NAD27 to be able to evaluate them. Here they are for geo approval. Earlier I sent you a planning report in NAD83. This one attached is in NAD27 b Bill Michaelson Baker Hughes INTEQ 6/1712008 1 D-04AL 1-01 • Maunder, Thomas E (DOA) Page 1 of 1 From: Maunder, Thomas E (DOA) Sent: Saturday, June 14, 2008 9:13 AM To: Rixse, Mel G Cc: Hubble, Terrie L Subject: RE: 1D-04AL1-01 Mel and Terrie, We need to talk on Monday and sort this out. Anew permit will be required. Tom Maunder, PE AOGCC From: Rixse, Mel G [mailto:Mel.Rixse@bp.com] Sent: Fri 6/13/2008 5:02 PM To: Maunder, Thomas E (DOA) Cc: NSU, ADW Drlg Nordic 2 Supervisor; Hubble, Terrie L Subject: 1D-04AL1-Ol Tom, I wanted to notify you that Nordic 2 drilling in Kuparuk at 1D Pad drilled into the D shale on 1D-04AL1. Rather than plug back, we will keep the C4 sand and run a short liner. This will result in 1D-04AL1-01 targeting the sands originally targeting 1D-04AL1 and a new lateral 1D-04AL1-02 targeting the sands originally targeting 1D- 01AL1-01. Mel Rixse Coiled Tubing Drilling Engineer BP Exploration Alaska, Inc. (907)564-5620 -Office (907)223-3605 -Cell 6/17/2008 ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME ~. ~ _ ~ ``~ ~ i- t - ~ ~ PTD# ,~ ~ ~S ` I U ~Development~ Service Exploratory Stratigraphic Test Non-Conventional Well FIELD: ~~ ~~.~~~. ~Z~ ~'X~ ~ _ POOL: ~L-~!' v~L~i~C 4` ~ ~ Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new welJbore segment of existing well ~Z~ \~ -- ~~ ~ , (If last two digits in API number are permit No, ~-Oss-C)~s~l, API No. 50- G3-~ •~Gtiit'a -~~--. between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), ali records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and AP[ 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 J O' sample intervals throu h tar et zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of well) until after (Comaanp Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. _fComaany Name) must contact the Commission to obtain advance approval of such water we!! testing ro am. Rev: 1/1 !/2008 WELL PERMlT CHECKLIST Fiekt 8. Pool KUPARUK RIVER, KUPARUK RIVOIL - 490100 Well Name: KUPARUK RIV UNIT 1D-04AL1-02 Program DEV Well bore sag ^ PTD#:2081010 Company CONOCOPHILLIPS ALASKA INC Initial Classfl-ype DEV / PEND GeoArea 690 Unit 11160 On10ff Shore ~_ Annular Disposal ^ Administration 1 Permitfeeattaghed------------------------------------------- NA-- -------------------------- ---------------- - ----------------------------- 2 Le2senpmberapproRdate--------------------------------------- Yes- ------Entire well inAQl,Q251i50__-_-_--___---___---__-__--------____ ----- 3 Unique welt name and number -------- - - Yes- - ---------- ------ - ----- - ---- - - -- - -- ---- - 4 Well located in_a_definedpogl_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ . _KUPARUK RIVER,-KUPARUK RVOIL - 4609QQ, governed by Conservation Order Ng. 432C.- _ _ - _ _ _ _ _ _ 5 Well located proper distance from drilling unit_boundary_ _ ... _ Yes _ _ . _ _ _ _ Conservation Order Np. 432C contains rig spacing restrictions with respect to drilling unit boundaries. - - - _ _ _ _ 6 Well located proper distance f[om ether wells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ . Ggnservation Order Ng. 4320 has no inierwell_spaein-g-ngtriciigns, - - _ _ _ _ _ _ - - - - - _ - _ ------------ 7 Sufficient acreage available ln_drilling unit_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - _ _ _ Conservation Order Ng. 432G has ~o interweltspacing_restricligns, Wellborewiil be_mgre ihan 5Q0' from . _ _ _ _ - 8 If deviated, is wellbore plat-included _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - _ Yes . _ _ _ . _ - an external property line where ownership gr-lar~ownershp changes. - _ - - - - - - - ---------------- 9 OperatorgnlyaffectedDBrkY- --- ---------- - - - -- Yes- --------- ~ - -- ----- ----- - -- - ---- -- - ~-- -- -- --- 10 Operatorhea-appropriatebondinfgrre- ---- -- --------- ----------- Y~- - - -- -- - - -- ---- - ---------- - -- --- -- ------ 11 Permlteanbeissuedwjthoulconservatigncrder--------------------------- Yes- ----------.---------------------------------------. ---------------------- Appr Date 12 Permitcanbeissuedwiihouiadminist[ative_approval------------------------- Yes- -----.------------------------------------------------------------------ SFD 611712008 13 Can permit beaRRrgvedbefcre14-daYwait----------------------------- Yes- ----------------------------------------------------------------------- 14 Well IQCated within arse and strata auingrized by Injection O[de[# (putlQ# in-comments)_(Fgr- NA- - _ - _ _ _ _ _ _ _ _ - - - - - - - - - - - - _ - _ - - - - - - - - - - - - - - - - _ _ _ _ 15 Allwells_withinll4_miteareaof[eyiewidentified(Fgrsen!icewallgnly)-------------- NA-- ----------------------------------------------------- - -- -- ---- -- 16 Pre-produced injector, duration of pre production less than 3 mgnths_ (For service wall gniy) _ _ _NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ --------------------------------------- 17 Nonconven,gas-confgrmstoAS31,05,034(41.A),42.A-D)-- -- -- -- -------- ~-- -- - ------ -- ---- - ----- ----- - --- -- -------- Engineering 18 Conductorstring-provided____________-________________________ NA-- ------GonductorsetinlQ-04(176.9Q4).___.__________.__-___--------_,-_---_----_-- 19 Su-rfacecasirlgRrgtectsallkngwnUSDWs------------------------------- NA-- ------AIl84uifers8xempted,40CFR_147,1Q2(b)(3).--__---_-___-----_.-----_---____------ 20 CMTvotadequate-tocirculateoncgndugtgr&surf-csg------------------------ NA-- ---___SurfaceGasingsetin1D-Q4.___---_-___--_--_,_-_---_____---_----,_-_-__---__ ' 21 CMT vol adequateto tie-in long string tosurf csg_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ __ _ _ _ P1A- - - _ - - - _ Productign_casing set in_1D-04, - _ _ _ _ - - - _ - . _ ------------------------------ 22 CMT wilt goyerail known productive horizons_ _ _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _No_ . _ _ _ - _ _ Slotted liner completion planned.- - _ _ _ _ _ _ _ _ _ _ .. - _ 23 Casing designs adequate for C,_T, B &_permaftost - - - - - - - - - - - - - - - - - - - - - - - _ _ _NA - _ _ .. - _ Qriginal well-met design specifcations. _ NA far slotted liner._ _ _ _ _ - - _ - - _ _ - - _ _ - _ .. _ _ - - _ _ _ _ _ - 24 Adequate tank8ge_or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ _ _ _ _ Rig equipped with steel pits, No reserve pit planned,_ All waste_tg approved disposal well(s), _ _ _ _ . _ _ _ - _ _ _ _ 25 If-a_re-d[ill,hasal0-403forabandonrnent been aRP-rQuad------------------- -NA-- ---------------------------------------------------------- ----- --- -- 26 Adequate wellbore separation propgsed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - _ _ _ Nearest segment is new_ty-drilled-1D04AL1 and paths diverge, _ _ _ - - - _ - - _ _ _ _ _ _ - -- ----- 27 lfdiverterrequired,dQesitmeetragulatigns______.___._-__--_.____ _NA__ ______BQPSiack_willalreadY-be-inplace,._---------------------------------------- -- Appr Date 28 Drilling fluidprggram schematic & equip list adequate- - - - - - - - - - - - - - - - - - - - - - - - - Yes _ _ _ _ _ _ .Maximum expected fo[malion pressure 6,8_EMW._ Managed pressure-drilling teghnigpe tube used_with 8.6 ppg _ _ TEM 611712008 29 84PEs, do iheymeetregulation _ _ _ _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - MW-and aRRlied Rressure, ActualBH_EMWmay be ashigh as_11,8_ppg io-maintain constand SHP.- _ - _ - _ ~ ~ A 30 BOPS-press raiing appropriate; test to-(pui psig tn-comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ MASP calculated-at 227Qpsi: 3500_psi_BOP testplanned, _ _ _ _ _ _ _ _ _ _ - _ _ _ _ - _ - - - - - _ _ _ _ _ _ - - - _ - ~ w, 31 Choke_man~oklcgmplieswlAPl_RP-53(May$9)____________________________ Yes_ ______-_ ----------------------------------------------------------------- 32 Work will occur withoutoperationshutdown____-------------------.. -- Yes- ----------------------.--------------------------------- ---------------- 33 Is Rresence of H2S gas probable_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ H2S is reporied-a11 D pad. Mud should preclude H2S on rig. Rig has-sensors and alarms. - _ _ _ _ _ _ _ _ - - - _ _ 34 Mechanical condition of wells within AQR verified (FOrsen+lce well gnlya _ _ , _ _ . _ _ _ NA_ - - _ - - _ - -------------------------------------------------------------------- Geology 35 Permit can be issaed wfo hydtogensulfide measures_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ No_ _ _ _ - - _ H2$ is present at_1D-Pad. Mitigation _measures-must be required.... _ _ - - _ _ - _ _ - - _ _ _ _ _ . _ 36 Data-presented gn potential overpressure zones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - _ _ _ _ _ Expected reservoirpressure is 8,8_ppg EMNf; will be drilled with 8.6 ppg mud, - .. - - _ _ _ - - . .. . _ _ _ _ _ - Appr ~~ 37 Seismic analysis of shallow gas zones_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ _ _ a c9iled tubing4 and managed pressure drilling techniques. _ - - - _ _ , - _ _ - - - _ _ _ SFD 611712008 38 Seabed condjtion survey_(ifoff.-shore) _ _ _ _ _ _ _ _ _ _ _ --- --- -- ---------- -~A-- _ - - - - - - - _ - _ . _ _ - _ - - ------- - - --- - ----- ---- - - - -- -------------- 39 Contactnamelphoneforweekly_progressrepgrls.[exploratoryonry]_.__-----_-._-- NA__ _-__-----___..__------------------___-_--__---_---__ -- -- _ _ --- Geologic Engineering Public Commissioner: Date Commissioner Data Date: Commissioner: / C~~~Z(i 4 `~7