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208-086
i 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. a Q S - o ~ ~ Well History File Identifier Organizing (done) ^ Two-sided III 111111 II II I II III ^ Rescan Needed RES N DIGITAL DATA OVERSIZED (Scannable) Color Items: ^ Diskettes, No. ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Dater U /s/ ~ 1 Pro "ect Proofin II I II ~I II I I III I I II I ! g BY: Maria Date: /s/ __- Scanning Preparation BY: Maria ~_ x 30 = Date: Production Scanning 3 O + ~ 3 =TOTAL PAGES~~ //~ (Count does not include cover sheet) ' n/~ /s/ Y ~/ Stage 1 Page Count from Scanned File: ~_ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: J~YES _ BY: Maria Date: ~, ~//~ Stage 7 If NO in stage 1, page(s) discrepancies were found: YES BY: Maria Date: Scanning is complete at this point unless rescanning is required. -vn P ~Illlllllllllglllll ReScanned III 111111 VIII II III BY: Maria Date: /s/ Comments about this file: Quality Checked III IIiIII III II') III 10/6/2005 Well History File Cover Page.doc DATA SUBMITTAL COMPLIANCE REPORT 2/8/2010 Permit to Drill 2080860 Well Name/No. KUPARUK RIV UNIT 1D-04AL1-01 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-20416-61-00 MD 9810 TVD 6556 Completion Date 6/21!2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other 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 / 1yF./C IrICWI-IIIIL I~u111YG1 name V~.wlc nlcVlw IYV JLQIL JLVF/ ~+fl RCL.CIYCY 1rV111111C11W D D Asc Directional Survey 0 9810 Open 9/12/2008 PBU 1D-04A, PBU 1D- 04AL1, &PBU 1D-04AL1- ~ 02 also on Disk D C Lis 19030~ee Notes 6959 9810 Open 12/3/2009 MPR Logs plus PDF graphics og Induction/Resistivity 25 Col 9137 9810 Open 12/3/2009 MD MPR, GR ~ g Induction/Resistivity 5 Col 9137 9810 Open 12/3/2009 TVD MPR, GR Well CoreslSamples Information: Name Sample Interval Set Start Stop Sent Received Number Comments • ADDITIONAL INFORMATION W ll C d? Y e ore Chips Received? ~C-LAL_ Analysis Y /~N -_ Received? Daily History Received? Y / N Formation Tops ~ N Comments: DATA SUBMITTAL COMPLIANCE REPORT 2/812010 Permit to Drill 2080860 Well Name/No. KUPARUK RIV UNIT 1D-04AL1-01 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-20416-61-00 MD 9810 TVD 6556 Completion Date 6/21!2008 Completion Status 1-OIL Current Status 1-OIL UIC N Compliance Reviewed By: Date: e d, ~ t~ • • ConocoPhillips Alaska 1 D-O4AL1 -o C~ 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, M633 1 Graphic image file 1 Disk*/ David Douglas in lieu of sepia*" Electronic P.O. Box 196612 CGM /TIFF LIS Anchorage, Alaska 99519-6612 CHEVRON/KRU REP 1 Hardcopy Print, Glenn Fredrick 1 Graphic image file 1 Disk*/ P.O.Box 196247 in lieu of sepia'`'` Electronic Anchorage, Alaska 99519 CGM /TIFF LIS 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 ~~ o DV f9o~a F ~ ~ ~ ~. ~, ~~ ~LV ~ V LV~~ :~~~sks (iii has ~o~s. ~f~ ~_~~+;,~in;~ Anch~ra~G i ~~~ BAKER H~ME~ INTEC~ 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 1D-12L1PB1 1D-12L1 1 D-12L2 Enclosed is: 1 ea 3.5" floppy diskette containing electronic survey file Cc: State of Alaska, AOGCC Christine Mahr?cen STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION CO ISSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG JUG ~ g 2008 n r.._r_ 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoAAC 2s.~os zoAAC zs.~~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 I ' ' '~ ° ~ °' •, . - ®Develo,~gnent [~ Exploratlriq'0 ^ Service ~°"Stratigraphic 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 6/21!2008 - 12. Permit to Drill Number 208-086 • 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 6/14/2008 13. API Number S0-029-20416-61-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 6/16/2008 y 14. Well Name and Number: Kuparuk 1D-04AL1-01 120 FNL, 598 FEL, SEC. 23, T11N, R10E, UM Top of Productive Horizon: 1718' FSL, 1690' 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: 1471' FSL, 3668' FWL, SEC. 13, T11 N, R10E, UM 9. Plug Back Depth (MD+TVD) 9810' 6556' River Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 560490• y- 5959545 ~ Zone- ASP4 10. Total Depth (MD+TVD) 9810' ~ 6556' ~ 16. Property Designation: ADL 025650 ' TPI: x- 562762 y- 5961401 Zone- ASP4 Total Depth: x- 564742. y- 5961171 Zone- ASP4 11. SSSV Depth (MD+ND) 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 (ND): 1400' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): ~P 9/,3 S /f!D MWD DIR, GR, RES G53~i ~TYA 22. CASING, LINER AND CEMENTING RECORD 7'~• CASING SETTING DEPTH NID SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE ' ,TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 2-3/8" 4.44# L-80 8978' 9810' 6560' 6556' 3" Uncemented Slotted Liner 23. Open to production or inject ion? ®Yes ^ No 24 TueING RECORD If Yes, list each i (MD+ND of Top & Bottom; Pe nterval open rforation 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 8989' - 9778' 6558' - 6546' Well Branch Well Branch 1D-04AL1- 1D-04AL1-01 25.' ACID, FRACTURE, CEMENT SQUEEZE, ETC. Departs From Is not Directly DEPTH INTERVAL MD AMOUNT H~ KIND OF MATERIAL USED Well Branch Accessible 1 D 04AL1 - PTD # 208-085 at 9137' MD ' ND) (6536 26. PRODUCTION TEST Date First Production: Reported on 1 D-04AL1-02 Method of Operation (Flowing, Gas Lift, etc.): See 1 D-04AL1-02 (Dated xxx, PTD # 208-101) for Production & Test Data Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No - Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+ND of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. COIVIi~LE110@l None ~} n •ON OL / ~ ~ ~ ~ "~ /w~ p Firm ~n-an7 Revised n~ianm ~.(1NTINIIFfI C)N REVERSE S~IIF 8 ~! 7.~~• 01 S ~~~, JUL. ~ ~ 100 ~ ~~~-mod r_ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS RKERS ENCOUNTERED): 29. FORMATION TESTS NAME D TVD Well Tes ? ^ 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 C3 (From 1D-04AL1) 7735' 6522' None Kuparuk C4 9135' 6536' Kuparuk C3 9736' 6534' Kuparuk C3 9810' 6556' Formation at Total Depth (Name): Kuparuk C3 9736' 6534' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore ing is true and correct to the best of my knowledge. ' 07~17~~ Si d gne Terrie Hubble Title Drilling Technologist Date Kuparuk 1 D-04AL1-01 208-086 Prepared By Name/Number. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Mel Rixse, 564-5620 Permit No. / A royal No. INSTRUCTIONS GeNeRA~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a 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. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP EXPLORATION Page 1 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 6/3/2008 05:30 - 07:30 2.00 MOB P PRE Plck up rig mats and clean up around cellar area. Conduct pre move inspection of hydraulic systems. Inspect well area with CPF-2 DSO. 07:30 - 11:00 3.50 MOB P PRE Move from 2D pad to 2X pad entrance. 11:00 - 12:30 1.50 MOB P PRE Stand by for Kuparuk crew change. 12:30 - 14:45 2.25 MOB P PRE Move to 1 R access road 14:45 - 19:00 4.25 MOB P PRE Wait for SSA flights and then Field crew changeout 19:00 - 22:00 3.00 MOB P PRE Move from 1 R access road to 1 D pad. 22:00 - 22:30 0.50 MOB P PRE Move rig onto pad & down to 1 D-04. 22:30 - 23:00 0.50 MOB P PRE Wait for AES to finish rigging up MPD valving. PJSM regarding moving over well. Shut in adjacent well. 23:00 - 00:00 1.00 MOB P PRE Spot rig over well. 6/4/2008 00:00 - 05:30 5.50 RIGU P PRE 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. 05:30 - 07:30 2.00 BOPSU P PRE Fill BOP stack with cold water. Perform shell test on BOP stack 07:30 - 12:20 4.83 BOPSU P PRE Test ROPE and MPD loop to 250/3500 w/ AOGCC in attendance 12:20 - 15:30 3.17 BOPSU N PRE Choke line HCR would not test. Rebuild, retest and failed 15:30 - 21:00 5.50 BOPSU N PRE Replace, grease & actuate. Retest -pass. Replaced gray lock seal on choke line HCR & test -pass. Fill coil with biozan. 21:00 - 21:45 0.75 BOPSU P PRE P.T. tiger tank line with 120psi of air & 400psi of fresh water - good. 21:45 - 22:00 0.25 RIGU P WEXIT PJSM regarding coil slack management & cutting coil. 22:00 - 22:40 0.67 RIGU P WEXIT PU injector & cut off coil connector. Prep a-line cable. Stab onto well. 22:40 - 23:15 0.58 BOPSU P WEXIT P.T. inner reel valve & injector packoffs per AOGCC regs 250/3500 psi -Pass. 23:15 - 23:30 0.25 RIGU P WEXIT Pump slack. Pop off well & check for wire. 23:30 - 23:40 0.17 RIGU P WEXIT PJSM regarding pulling BPV. 23:40 - 00:00 0.33 RIGU P WEXIT Hoist Cameron BPV lubricator to RF & RU same to pull BPV. 6/5/2008 00:00 - 01:15 1.25 RIGU P WEXIT 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. 01:15 - 04:15 3.00 RIGU P WEXIT 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. 04:15 - 04:30 0.25 RIGU P WEXIT PJSM regarding making up BHA. 04:30 - 05:45 1.25 RIGU P WEXIT Flow check well. MU milling BHA. Stab onto well. Power up & test tools. Set depths. 05:45 - 07:00 1.25 STWHIP P WEXIT RIH with milling BHA, taking returns to Tiger tank. Circ thru EDC 0.8/1040 07:00 - 08:30 1.50 STWHIP P WEXIT Set down at 6738' CTD. Close EDC. Mill cement stringer from Printed: 6/30/2008 9:32:34 AM BP EXPLORATION Page 2 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 i Task Code NPT Phase ~ Description of Operations i 6/5/2008 07:00 - 08:30 1.50 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 08:30 - 11:30 3.00 STWHIP P 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 11:30 - 15:45 4.25 STWHIP P 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 15:45 - 17:45 2.00 STWHIP P 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 dill at 7114.1', but was probably a siderite streak. Drilled formation to 7122'. Bottom's up was 90% formation sand, 5% siderite, 5% metal. 17:45 - 20:15 2.50 STWHIP P 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. 20:15 - 21:15 1.00 STWHIP P WEXIT Open EDC & swap well to 8.9ppg flo-pro. 5K overpull at 6745ft. Jet 7" casing. 21:15 - 21:30 0.25 STWHIP P WEXIT Flow check while at 6540ft - no flow. 21:30 - 22:40 1.17 STWHIP P WEXIT Continue to POH. PJSM regarding handling milling BHA while POH. 22:40 - 23:45 1.08 STWHIP P 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! 23:45 - 00:00 0.25 STWHIP N WEXIT Make up milling BHA consisting of 2.73" no-go Weatherford crayola tip mill and 2.73" string reamer. 6/6/2008 00:00 - 00:35 0.58 STWHIP N WEXIT Continue to make up window dressing BHA. C/O UOC o-rings. 00:35 - 02:00 1.42 STWHIP N WEXIT RIH with window dressing mill. 02:00 - 02:40 0.67 STWHIP N WEXIT Log down for tie-in from 6980ft (-12ft corr. 02:40 - 02:55 0.25 STWHIP N WEXIT RIH & dry tag twice at 7099ft. 02:55 - 04:15 1.33 STWHIP N WEXIT PU to 7095ft. Start pumping at 1.5bpm/2830psU10.37 ECD. Mill at 30ft/min 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. 04:15 - 05:55 1.67 STWHIP N WEXIT POH. PreSpud mtg while POH. 05:55 - 06:45 0.83 STWHIP N WEXIT Flow check. Crew chg/safety mtg 06:45 - 07:30 0.75 STWHIP N WEXIT Set injector on legs. LD milling BHA 07:30 - 08:45 1.25 DRILL N PROD1 BHI reconfigure the BHA for drilling and test Nordic begin changeout of pulsation dampener on pump #1 08:45 - 09:30 0.75 DRILL N PROD1 WO Nordic to fin pump #1 repair work 09:30 - 10:15 0.75 DRILL N PROD1 BHI noticed the well was beginning to flow over the lubricator Printed: 6/302008 9:32:34 AM BP EXPLORATION Operations Summary Report Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Event Name: REENTER+COMPLETE Start: 5/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: I I Date !From - To Hours ; Task Code NPT Phase 6/6/2008 09:30 - 10:15 0.75 DRILL N PROD1 10:15 - 10:30 0.25 DRILL N PROD1 10:30 - 12:00 1.50 DRILL N PROD1 12:00 - 13:30 1.50 DRILL N PROD1 13:30 - 15:45 2.25 DRILL N PROD1 15:45 - 16:30 0.75 DRILL N PROD1 16:30 - 17:15 0.75 DRILL N PROD1 17:15 - 18:30 1.25 DRILL N PROD1 18:30 - 18:35 0.08 DRILL N PROD1 18:35 - 18:45 0.17 DRILL N PROD1 18:45 - 19:15 0.50 DRILL N PRODi 19:15 - 19:50 0.58 BOPSU N PROD1 19:50 - 20:05 0.25 DRILL P PROD1 20:05 - 21:15 1.17 DRILL P PROD1 21:15 - 22:40 1.42 DRILL P PROD1 22:40 - 23:00 0.33 DRILL P PROD1 23:00 - 23:05 0.08 DRILL P PROD1 23:05 - 00:00 0.92 DRILL P PROD1 Page 3 of 16 ~ Spud Date: 6/1/2008 End: 6/21 /2008 Description of Operations 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 Safety mtg re: MU nozzle assy 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 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 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 retums 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 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, i 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 Start 9.25# Flo Pro 1.61/2600 Begin to install new bladder in old pulsation dampener POOH circ 1.52/2350 while finish displacing wellbore to 9.25# mud. Notified Chuck Scheve at AOGCC of taking a kick & shutting in blind rams due to well flowing. Flow check well - no flow. Blow down & lay down BHA & reconfigure same for drilling build BHA. Clean out high pressure screen in reel house -lots of goodies inside. Pressure test blind rams & choke line & HCR per AOGCC regs, 250/3500psi -PASS. PJSM regarding handling drilling BHA & making drift run of BHA with slickline. MU build BHA. Deploy BHA conventionally into well using tugger with great difficulties. Stab onto well. Set counters. Power up & test tools. RIH. Slight bobble at the D nipple. Log down for tie-in from 7000ft (-18ft corr. RIH, slight bobble at 7108ft in the window & tag bottom at 7112ft. 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 Printed: 6/30/2008 9:32:34 AM BP EXPLORATION Page 4 of 16 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 00:00 - 02:30 2.50 DRILL P 02:30 - 04:00 1.50 DRILL P 04:00 - 04:45 0.75 DRILL 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 0.17 DRILL P 22:10 - 00:00 1.83 DRILL 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 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 Op 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 PROD1 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.Sk wob w/ 10.96 ECD to 7300' and have 73 deg at bit PROD1 Wiper to window was clean both ways PROD1 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 9.1 pg flo-pro while RIH. PROD1 Log down for tie-in from 7015ft (-15ft corr). PROD1 RIH to 7100ft & swap well to 9.1 ppg 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 Printed: 6/30/2008 9:32:34 AM • BP EXPLORATION Operations Summary Report Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Event Name: REENTER+COMPLETE Start: 5/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours ( Task Code ~ NPT Phase 6/7/2008 122:10 - 00:00 I 1.831 DRILL P I PROD1 6/8/2008 ~ 00:00 - 03:05 ~ 3.08 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 0.83 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 PRODi 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 I P I 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 300fUhr. 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' W iper 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 diff, 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' Wiper 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 / t 1.93ppg / 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 rnnteo: w~ui~vuo a:~ca4 Hm ~J BP EXPLORATION Operations Summary Report Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Event Name: REENTER+COMPLETE Start: 5/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: ~. Page 6 of 16 ~ Spud Date: 6/1 /2008 End: 6/21 /2008 Date From - To Hours Task Code NPT ~ Phase Description of Operations 6/8/2008 21:55 - 22:35 0.67 DRILL P PROD1 22:35 - 00:00 1.42 DRILL N RREP PROD1 6/9/2008 00:00 - 01:30 1.50 DRILL N RREP PRODi 01:30 - 04:30 I 3.001 DRILL I P 04:30 - 06:15 1.75 DRILL P 06:15 - 09:10 2.92 DRILL P 09:10 - 10:25 1.25 DRILL P 10:25 - 10:35 0.17 DRILL P 10:35 - 11:10 0.58 DRILL P 11:10 - 12:30 1.33 DRILL P 12:30 - 12:55 0.42 DRILL P 12:55 - 14:20 1.42 DRILL P 14:20 - 15:10 0.83 DRILL P 15:10 - 16:40 1.50 DRILL P 16:40 - 17:15 0.58 DRILL P 17:15 - 19:00 1.75 DRILL N 19:00 - 19:25 0.42 DRILL P 19:25 - 20:00 0.58 DRILL P while RIH. Lost DC power to pumps & traction motor ~ 8249ft 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" PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 PROD1 RREP PROD1 PROD1 PROD1 rnmeu. wu~icvuo aacaY ruv~ 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: Date From - To Hours ~ Task Code NPT ~ Phase Description of Operations 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 LNR1 Top off hole _ 3bbls. RIH w/ liner ~ 75Wmin. 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 LNR1 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 BOPE 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 Print®d: 8/30/2008 9:32:34 AM BP EXPLORATION Page 8 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 (6/10/2008 23:35 - 23:50 0.25 DRILL P 23:50 - 00:00 0.17 DRILL P 16/11/2008 00:00 - 00:26 0.43 DRILL P 00:26 - 02:27 2.02 DRILL P 02:27 - 02:36 ~ 0.151 DRILL ~ P 02:36 - 04:40 2.07 ~ DRILL ~ P 04:40 - 05:05 0.42 DRILL P 05:05 - 07:15 2.17 DRILL P 07:15 - 09:25 I 2.171 DRILL I P 09:25 - 11:10 I 1.751 DRILL I P 11:10 - 11:55 0.75 DRILL P 11:55 - 13:45 1.83 DRILL P 13:45 - 14:45 1.00 DRILL P 14:45 - 17:10 2.42 DRILL P PROD2 Tie in at 7,015 ft and corrected -16 ft PROD2 Closed EDC and RIH with min Op through the build section and the OHST PROD2 RIH and tagged bottom at 7765 ft 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 PROD2 Wiper trip to 7780 ft. Turned TF to R-side once back on bottom 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. PROD2 Wiper trip, clean 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 = 282 bbl's Drilled to 8200ft. 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. W iper to TD -clean. 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. PROD2 W iper to 7780ft and to TD -clean both ways. 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. PROD2 Wiper to 7780ft and to TD -clean both ways. 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. Punted: st3orzooa s::iz:~a Ann BP EXPLORATION Page 9 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 6/11/2008 17:10 - 19:15 ~ 2.08 ~ DRILL ~ P 19:15 - 20:04 0.82 DRILL P 20:04 - 21:50 1.77 DRILL P 21:50 - 00:00 I 2.171 DRILL I P 6/12/2008 00:00 - 00:15 0.25 DRILL P 00:15 - 00:40 0.42 DRILL P 00:40 - 01:50 1.17 DRILL N 01:50 - 02:30 0.67 DRILL N 02:30 - 03:45 1.25 DRILL N 03:45 - 06:15 2.50 DRILL P 06:15 - 07:45 1.50 DRILL P 07:45 - 11:20 3.58 DRILL P 11:20 - 13:10 1.83 DRILL P 13:10 - 14:00 0.83 DRILL P PROD2 Wiper trip to the window. 8602ft, 6k overpull. Pulled above WS 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 PROD2 RIH, clean PROD2 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 PROD2 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 Geosunrey 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 PROD2 RIH and setup to drill with the geo's spreadsheet from the MWD trailer PROD2 Drilling lateral TF at 90R HS from MWD shack Op = 1.70 / 1.70 bpm OBP = 3170 psi BHP/ WHP/ECD=3629/50 psi/10.79 Density = 8.65 / 8.69 ppg Vp = 375 bbl's WAIT PROD2 Wiper to casing to allow Nordic 3 to pass by the reel house on 1 D Pad WAIT PROD2 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 WAIT PROD2 RIH with correct TF, no Op through WS and low Op through build section. PROD2 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. PROD2 Wiper to 7780ft and to TD -clean both ways. PROD2 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 pP9 Vp = 365 bbl's Drilled to 9100ft. PROD2 Wiper to 7780ft and to TD - 5k overpull at 9012ft & 8980ft, otherwise clean. Slight set down at 9012ft PROD2 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 PfIfltBtl: (i/30/LWtl `J::7'L::i4 AM • BP EXPLORATION Page 10 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: i Date From - To Hours Task ~ Code NPT Phase Description of Operations 6/12/2008 ~ 13:10 - 14:00 ~ 0.83 ~ DRILL ~ P 14:00 - 14:20 I 0.331 DRILL P 14:20 - 16:10 I 1.831 DRILL ~ P 16:10 - 20:35 I 4.421 DRILL P 20:35 - 23:35 3.00 DRILL P 23:35 - 00:00 0.42 DRILL P 6/13/2008 00:00 - 01:30 1.50 DRILL P 01:30 - 04:15 2.75 DRILL P 04:15 - 07:30 I 3.251 DRILL P PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 PROD2 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 Tumed 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 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 I 1.501 CASE P I 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 BP EXPLORATION Page 11 of 16 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 Spud Date: 6/1 /2008 Start: 5/30/2008 End: 6/21 /2008 Rig Release: 6/21/2008 Rig Number: Date From - To Hours Task Code NPT ~ Phase 6/13/2008 19:15 - 19:30 0.25 CASE P 19:30 - 20:30 1.00 CASE P 20:30 - 20:35 0.08 CASE P 20:35 - 23:15 2.67 EASE P 23:15 - 00:00 0.75 CASE P 6/14/2008 00:00 - 00:50 0.83 STKOH P 00:50 - 02:30 1.67 STKOH P 02:30 - 03:30 1.00 STKOH P 03:30 - 05:00 I 1.501 STKOH P 05:00 - 05:15 I 0.25 I STKOH I P 05:15 - 07:30 2.25 I STKOH I P 07:30 - 07:35 0.08 STKOH P 07:35 - 08:15 0.67 STKOH P 08:15 - 09:50 1.58 STKOH P 09:50 - 10:00 0.17 STKOH P 10:00 - 10:45 0.75 STKOH P 10:45 - 11:55 1.17 STKOH P 11:55 - 12:25 0.50 STKOH P 12:25 - 15:35 3.17 STKOH ~ P 15:35 - 17:05 I 1.50 I STKOH I P 17:05 - 18:00 0.92 STKOH I P 18:00 - 20:30 2.50 STKOH P 20:30 - 20:45 0.25 STKOH P 20:45 - 22:20 1.58 STKOH P 22:20 - 23:00 0.67 STKOH P 23:00 - 23:10 I 0.17 I STKOH I P LNR2 LNR2 LNR2 LNR2 LNR2 PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS PRODS Description of Operations fpm RIH RIH and tagged at 9373 ft. PU and flood vac line. Pump and set anchor at 3600 psi. Liner set at 9373 ft Top of Liner at 9139 ft PUH filling across the top LD CoilTrac and BOT CTLRT. Circulate across wellhead. PJSM and RU to cut CT Cutting off 975 ft 2" CT for coiled tubing management. 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 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 Pad Evaluation with Nordic Screw. Muster up at the N3 camp and all people accounted for in 3 minutes. Pop off well and installed CTC, pull test to 40k and reheaded. Pressure test to 4000 psi -good. PJSM regarding handling BHA. MU 1.5 AKO motor to BHI tools. MU coil to BHI tools. Stab onto well. Set counters. Power up & test tools. RIH. Log down for tie-in (-15.5ft corr. Swap well to 8.6ppg Flo-Pro. Stop pumping & close EDC. Wiper to TD. Dry tag billet at 9137ft. 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 Drill at 0.1fUmin from 9136.5ft TF at 160R HS Op = 1.56 / 1.56 bpm CTP = 2760 psi BHP/ WHP/ECD=3759/26psi/11.24 Density = 8.72 / 8.91 ppg Vp = 199 bbl's Drill formation from 9140ft TF at 160R HS Op = 1.65 / 1.63 bpm CTP = 3260 psi BHP/ WHP/ECD=3759/30 psi/11.36 Density = 8.81 / 8.86 ppg Vp = 390 bbl's Drill to 9155ft & NBI confirms LS KO. Ream & backream 45-60 degrees L & R of drilled TF from 9118ft to 9155ft. POH following pressure schedule. PJSM on undeploying BHA Pressure undeploy BHA 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. PJSM on Pressure deploying BHA Printed: 6/30/2008 9:32:34 AM 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 Start: 5/30/2008 Rig Release: 6/21/2008 Rig Number: Date From - To I Hours Task Code NPT ~ Phase Page 12 of 16 Spud Date: 6/1/2008 End: 6/21 /2008 Description of Operations 6/14/2008 23:10 - 00:00 0.83 STKOH P PRODS Pressure deploying BHA 6/15/2008 00:00 - 00:30 0.50 DRILL P PRODS Finish pressure deploying BHA 00:30 - 02:00 1.50 DRILL P PRODS RIH with EDC open 02:00 - 02:22 0.37 DRILL P PRODS Log tie in at 7015 ft, Corrected -22 ft 02:22 - 03:55 1.55 DRILL P PRODS RIH, tagged bottom at 9156 ft 03:55 - 08:00 4.08 DRILL P PRODS Drilling lateral TF at 165R Op = 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 PRODS Wiper to 7780ft & to TD -ratty at 9155ft, otherwise clean. 10:05 - 14:05 4.00 DRILL P PRODS Drilling lateral from 9300ft TF at 90-80R Op = 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 PRODS PUH to 9430ft. MAD pass up from 9430ft to 9395ft. 14:20 - 16:40 2.33 DRILL P PRODS 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 PRODS Dolling 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 Op = 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 PRODS Wiper to billet, just stacking wt MAD pass 9525 to 9550 ft 20:24 - 23:00 2.60 DRILL P PRODS 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 PRODS Mini wiper, stacking 23:25 - 00:00 0.58 DRILL P PRODS Drilling lateral from 9642ft Qp = 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 CT1N ROP 10-30 fph 6/16/2008 00:00 - 02:55 2.92 DRILL P PRODS Drilling ahead. Oriented TD to 180deg (LS) and go find out where we are at in regards to geology to the C3. W iper trip at 9715 ft CTW at -6.7k 02:55 - 05:00 2.08 DRILL P PRODS Drilling lateral from 9715ft Op = 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 = 2d1 bbl Lost 51 bbl in this shift 05:00 - 05:40 0.67 DRILL P PRODS Drilling ahead looking for the C3. Drilled to 9,795 ft and called TD. 05:40 - 08:30 2.83 DRILL P PRODS Wiper to window -clean. Stop pumping &PUH through window Printed: 6/302008 9:32:34 AM i • BP EXPLORATION Page 13 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 6/16/2008 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. Printed: 6/30/2008 9:32:34 AM BP EXPLORATION Operations Summary Report Legal Well Name: 1 D-04 Common Well Name: 1 D-04 Event Name: REENTER+COMPLETE Start: 5/30/2008 Contractor Name: NORDIC CALISTA Rig Release: 6/21/2008 Rig Name: NORDIC 2 Rig Number: Page 14 of 16 Spud Date: 6/1/2008 End: 6/21 /2008 Date From - To Hours Task Code NPT Phase Description of Operations 6/17/2008 ~ 17:30 - 20:00 ~ 2.50 ~ STWHIP~ P ~ ~ PROD4 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 2.00 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 0.42 DRILL N DPRB PROD4 11:40 - 16:15 4.58 DRILL P PROD4 16:15 - 19:00 2.75 DRILL P PROD4 19:00 - 19:45 0.75 DRILL P PROD4 19:45 - 20:15 0.50 DRILL P PROD4 20:15 - 00:00 3.751 DRILL I P PROD4 Stalled , SD pump and PUH to 8969 ft. Set TF and ream back 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. Wlper 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. Wiper 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 fDC. PUH at 2.4 bpm to 6600 tt. 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'. Drill ahead from 9315'. 3350 psi fs at 1.65 in/out. 100-200 psi mtr work. W iper trip to 8995'. Start 10 bbl hivis sweep down hole. Set do at 9160'. Reduce pump rate. Run to btm. 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 tt 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. Printed: 6/30/2008 9:32:34 AM • BP EXPLORATION Page 16 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 6/20/2008 15:00 - 16:15 1.25 CLEAN P CLEAN RIH with Nozzel BHA to 6625 ff. 16:15 - 18:30 2.25 CLEAN P CLEAN Cleaning out pits. Circulate out 10.8 ppg FloPro with seawater. POOH chasing 10.8ppg brine to surface 18:30 - 20:30 2.00 CLEAN P 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. 20:30 - 22:00 1.50 WHSUR P 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. 22:00 - 00:00 2.00 DEMOB P POST Empty and clean pits. Hold PJSM to discuss using a hammer wrench and ND BOPS. ND BOPs and cellar plumbing. 6/21/2008 00:00 - 03:30 3.50 DEMOB P 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 03:30 - 04:00 0.50 DEMOB P 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-04AL1-01 Design: 1 D-04AL1-01 Baker Hughes INTEQ Survey Report ~ 27 June, 2008 ~~~r BAKER FI~I~NES INTE(~ ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc: Project Kuparuk River Unit Site: Kuparuk 1 D Pad Well: 1 D-04 Wellbore: 1 D-04AL7-01 Design: 1 D-04AL7-01 ConocoPhillips sn~R~r Baker Hughes INTEQ Survey Report ~~~ INTEQ Local Co-ordinate Reference: Well 1 D-04 TVD Reference: 1D-04 @ 105.OOft MD Reference: 1D-04 ~ 105:OOft North Reference: True Survey Calculation Method: Minimum Curvature Database: EDMv16 Prod proj~t Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (6cact solution) System Datum: Mean Sea Level Geo Datum: NAD 1927 (NADCON CONUS) Using Well Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor ~, .. Site Kuparuk 1D 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 ° Weg tD-04 Well Position +WS 0.00 ft Northing: 5,959,545.00 ft Latitude: 70° 18' 0.139 N +Ef-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: 0.00 ft Wellbore 1 D-04AL1-01 Magnetics Model Name Sample Date Declination Dip Angle Field Strength BGGM2007 6/13/2008 17.83 79.75 57,285 Design 1 D-04AL1-01 Audit Notes: Version: 1.0 Phase: ACTUAL Tie On Depth: 9,109.38 Vertical Section: Depth From (TVD) +N!-S +E/•W Direction (ftY !ft) Iftl (°) 105.00 0.00 0.00 85.00 • 6/27/2008 2:11:DOPM Page 2 COMPASS 2003.16 Build 42F / ConocoPhillips Ba~R r ' ConocoPhillips Baker Hughes INTEQ Survey Report '"'~"E$ Alaska INTEQ Company: ConocoPhillips(Alaska) Inc. Local Co-ordinate Reference: Well 1 D-04 Project• Kuparuk River Unit TVD Reference: 1D-04 ~ 105.OOft Site: Kuparuk 1D Pad MD Reference: 1D-04 ~ 105.OOft Well: 1D-04 North Reference: True Wellbore: 1D-04AL1-01 Survey Calculation Method: Minimum Curvature Design: 1D-04AL1-O7 Database: EDMv16 Prod Survey Program From (fU 200.00 7,097.15 7,727.30 9,137.00 Date To Ift) Survey (Weilbore) 7,000.00 1d04 (1D-04) 7,710.70 1D-04A MWD (1D-04A) 9,109.38 10-04AL1 MWD(1D-04AL1) 9,773.46 1D-04AL1-01 (1D-04AL1-01) Tool Name SEEKER MS MWD MWD MWD Description BHI Seeker multlshot MWD -Standard MWD-Standard MWD-Standard survey MD Inc Azl TVDSS PUS EIW Northing EasGng DLS Vertical Section TFO tff) 1°) 1°) lftl Ift1 1~) IfU Iffl 1°no0ft- (ft) 1°1 9,109.38 96.12 123.85 6,434.37 1,769.33 3,613.56 5,961,343.19 564,088.86 14.40 3,754.02 121.47 9,137.00 97.40 128.45 6,431.11 1,753.15 3,635.70 5,961,327.19 564,111.13 17.18 3,774.67 74.08 9,167.57 92.73 128.00 6,428.42 1,734.32 3,659.62 5,961,308.55 564,135.19 15.35 3,796.85 -174.50 9,190.28 92.51 125.00 6,427.38 1,720.83 3,677.85 5,961,295.21 564,153.53 13.23 3,813.84 -94.13 9,221.00 94.05 122.64 6,425.62 1,703.76 3,703.33 5,961,278.35 564,179.14 9.16 3,837.73 -56.77 9,250.26 93.68 118.91 6,423.65 1,688.82 3,728.41 5,961,263.62 564,204.34 12.78 3,861.41 -95.55 9,280.17 93.62 114.27 6,421.74 1,675.47 3,755.09 5,961,250.48 564,231.13 15.48 3,886.83 -90.59 9,310.27 93.50 110.02 6,419.87 1,664.14 3,782.91 5,961,239.38 564,259.03 14.10 3,913.56 -91.49 9,340.32 94.18 105.69 6,417.86 1,654.95 3,811.45 5,961,230.42 564,287.63 14.55 3,941.18 -80.91 9,370.19 94.12 101.04 6,415.70 1,648.07 3,840.42 5,961,223.77 564,316.66 15.53 3,969.45 -90.57 9,401.11 91.90 96.45 6,414.07 1,643.38 3,870.93 5,961,219.32 564,347.21 16.47 3,999.43 -115.71 9,430.02 91.66 91.61 6,413.17 1,641.35 3,899.75 5,961,217.53 564,376.03 16.75 4,027.96 -92.76 9,460.39 91.87 87.66 6,412.24 1,641.54 3,930.10 5,961,217.96 564,406.38 13.02 4,058.21 -86.90 9,492.23 91.32 83.33 6,411.35 1,644.04 3,961.82 5,961,220.72 564,438.08 13.70 4,090.03 -97.18 9,523.33 89.05 85.51 6,411.25 1,647.06 3,992.77 5,961,223.99 564,469.00 10.12 4,121.12 136.15 9,552.66 88.74 89.48 6,411.82 1,648.34 4,022.06 5,961,225.51 564,498.27 13.57 4,150.41 94.50 9,580.61 88.80 93.14 6,412.42 1,647.71 4,049.99 5,961,225.09 564,526.21 13.09 4,178.18 89.10 9,610.16 86.78 97.46 6,413.56 1,644.98 4,079.38 5,961,222.60 564,555.62 16.13 4,207.23 115.15 9,640.55 85.83 102.24 6,415.51 1,639.79 4,109.25 5,961,217.66 564,585.53 16.00 4,236.53 101.41 9,673.99 84.50 107.21 6,418.34 1,631.33 4,141.47 5,961,209.46 564,617.81 15.33 4,267.89 105.23 • 6/27/2008 2:11:OOPM Page 3 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Company: ConocoPhAlips(Alaska) Inc Project Kupanak River Unit Site: Kuparuk 1D Pad: WeU: 1 D-04 , Wellbore: 1 D-04AL1-01 Design: 10.04AL1-01 ConocoPhillips Baker Hughes INTEQ Survey Report Local Co-ordinate Reference: ND Reference: MD Reference: North Reference: Survey Calculation Method: Database: ri.r s ~ ` ~ I 1 N1 $ INTEQ Well 1 D-04 1 D-04 ~ 105.OOft: 1 D-04 ~ 105,OOft True Minimum Curvature EDMv16 Prod Survey MD inc Azi NDSS WS E/W Northing Eaating DLS Vertical Section TFO (ft) 1°I l°) (ft) Iftl lft) lft) Ift) (°I100ft) lft) 1°! 9,700.04 81.87 107.94 6,421.43 1,623.52 4,166.12 5,961,201.85 564,642.52 10.47 4,291.77 164.63 9,730.00 76.32 108.44 6,427.09 1,614.34 4,194.06 5,961,192.89 564,670.53 18.60 4,318.80 174.99 9,761.21 72.17 107.94 6,435.56 1,604.96 4,222.59 5,961,183.75 564,699.13 13.39 4,346.41 -173.45 9,773.46 70.83 107.88 6,439.45 1,601.39 4,233.65 5,961,180.26 564,710.21 10.95 4,357.11 -177.58 9,810.00 70.83 107.88 6,451.45 - 1,590.80 4,266.49 5,961,169.93 564,743.14 0.00 4,388.90 0.00 Targets Target Nama - hit/misa target Dip Angie Dip Dir. TVD +N1_S +E/-W Northing Fasting • Shape 1°I 1°) Ift) Iftl Iftl Ift! Iftl Latitude Longitude 1D-04AL1 Polygon 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 - actual weilpath misses by 6803.44ft at 9109.38ft MD (6539.37 TVD, 1769.33 N, 3613.56 E) - Polygon Point 1 0.00 1,633.62 1,741.39 5,961,192.42 562,218.02 Point2 0.00 1,888.88 2,088.48 5,961,450.44 562,563.01 Point3 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? 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 Point9 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 J • Checked By: Approved By: Date: I 6/27/2008 2:11:OOPM Page 4 COMPASS 2003.16 Build 42F Wgll Name: 1D-04 Wellbore Diagram (6/3/08) API# 50-02&2041Er01-00 ~'~ PTD: 208-084 ConocoPh i I 1 i ps 10-3/7" 36#!ft K-55 BTC -- " Alaska by ia~ 557 ft Camco DS Nipple 2.875" I.D. Schlumberger 7" 26#!ft K-55 BTC ID = 6.26" ®© -Calista 7" 20#/ft K-55 Casing -- ~, DRILLING ~, , FLUIDS I-S rrya..,,u,.<.• n,..,,rxrr F„xm.•r.r,.X 7042.0 ft 6657 ft BOT SAB-3 Packer 3.250" I.D. 6,651 ft Top of 2-3/8" Liner 6673 ft Camco D Nipple 2.75" I D }112" 9.3#/.ft L-80 EUE 8rtl Tubing 6684 ft EOT 6746 ft Top of 5" Liner RA Markee 7105 ft TOWS 7097 ft Abandoned C-Sand Abandoned A-Sand 5" 14.9#/ft K-55 Liner ~ 7500.0 k 2,657 ft DGLM # 1 4,036 ft DGLM # 2 4,949 ft DGLM # 3 5,620 ft DGLM # 4 ~ ' 6,135 ft DGLM # 5 6,558 ft DGLM # 6 6635 ft HES X Nipple 2.810" I.D. ST at 7,72eft ~ fso aaa ~ y ST ,97eft 55 dap R ST at H,735 ft Q>l 180 de0R 1D-04A 1D-04AL1 TD:8,560ft TD:9,372ft 1D-04AL1-02 rD: s,eszn C:\Documents and~gllidgs\hubbletl\Local Settings\Temporary Internet Files\OLKCE\1D-04AL1 L12 WBD .xls SARAH PAL/N, GOVERNOR u' • 7 ~.7I~iA OIL ~`~ GAS 333 W. 7th AVENUE, SUITE 100 C01~5ERQA'TIO1~T COMI~IISSIOIQ ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Mel Rixse FAX (907) 276-7542 CT Drilling Engineer ConocoPhillips Alaska, Inc. c/o PO Box 196612 Anchorage, AK 99519-6612 Re: Kuparuk River Field, Kuparuk River Oil Pool, Kuparuk 1D-04AL-O1 ConocoPhillips Alaska, Inc. Permit No: 208-086 Surface Location: 120' FNL, 598' FEL, SEC. 23, T11N, R10E, UM Bottomhole Location: 154?' FSL, 3768' FWL, SEC. 13, T11N, R10E, UM Dear Mr. Rixse: Enclosed is the approved application for permit to redrlll the above referenced development well. The permit is for a new wellbore segment of existing well. KRU 1D-04A, Permit No 208- 084, API 50-029-20416-01. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission speci$cally authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). cere y, Daniel T. Seamount, Jr. Chair `~ `) DATED this ~ day of May, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALASI(~IL AND GAS CONSERVATION COMMI~N~~3~ MAY 2 ~ 2008 PERMIT TO DRILL Alaska Oil & Gas Cons. Commission 20 AAC 25.005 „_ , 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ~ ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is propo ^ 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-04AL1-01 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 9840 TVD 6411' 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, T11 N, 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 1, 2008 , Total Depth: 1547' FSL, 3768' 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: gg70 feet Maximum Hole An le: 97 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 2917 Surface: 2279 18. Gasin P ram: cificatio ns To - Se in D th - Bo om u n i of C ment c.f. or sa s 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 3180' 6660' S917'ss 9840' 6411'ss Uncemented Slotted Liner 19. PRESE NT WELL GONDlTION S UMAAARY (To be completed for Rectrill 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 asing ; Length ize ement Voltame M D Conductor /Structural 72' 16" 2 4 sx Arcticset I I 72' 72' Surface 2890' 10-3/4" 3300 sx Arcticset II 2890' 2690' Intermediate 7042' 7" 1600 sx Self-Stress C ment 7042' 6403' Pr i n Liner 754' 5" 120 sx Self-Stress Cement 6746' - 7500' 6108' - 6861' Liner 1 D-04A 900' 2-3/8" Uncemented Slotted Liner 7750' - 8650' 7006' - 6362' ss Lin r 1 D-04AL1 9 0' 2-3/8" Unc m n I ed Liner 8850' - 750' 81 ' - 6413' ss Perforation Depth MD (ft): 7102' - 7354' Perforation Depth ND (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 Mel ix Title CT Drilling Engineer Prepared By Name/Number. Si nature Phone 564-5620 Dat~• •~1 Terrie Hubble, 564-x628 Commission Uae Onl Permit To Drill ~~p~ Numb r: ZOS ""'~ API Number: 50-029-20416-60-00 Permit Ap r val See cover letter for Date: ~ other re uiremen s Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained shales:L-~,,C Samples Req'd: ^ es [a'No Mud Log Req'd: ^ Yes ~ no `^ HZS Measures: ~J Yes ^ No Directional Survey Req'd: [des ^ No Other: ~~~d>~Sr~~~ --~.~~- APPROVED BY THE COMMISSION QQQ Date ,COMMISSIONER Form 10-401 Revised 12/2005 Submit to Duplica®te `~ ~ ~ ~ ~ ~ ~ ~~ Si21~ ~J KRU 1 D-04A, KRU 1 D-04~ &KRU 1 D-04AL1-01 Trilateral oiled Tubing Drilling To: Tom Maunder Petroleum Engineer {.~~ Alaska Oil & Gas Conservation Commission I~,j From: Mel Rixse CTD Engineer Date: May 15, 2008 Re: 1 D-04A, 1 D-04AL1, 1 D-04A11-01 Application for Permit to Drill Request A coiled tubing drilling rig will drill three laterals in well KRU 1 D-04 using the managed pressure drilling technique. These horizontal laterals will target Kuparuk C3/C4 sand reserves to capture and protect currently nonrecoverable resources. The perforations in the motherbore will be cement squeezed. The A lateral will exit the motherbore at 7110' MD, and drill a 1540' horizontal lateral which will target the C4 sands to the east. It will be completed with 23/8" slotted liner from 8650' MD to a TOL of 7750' MD. The AL1 lateral will exit the A lateral off a flow through liner top sidetrack billet and drill a 2000' horizontal targeting the C4 sands in a fault block further east. It will be completed with 23/" slotted liner from TD at 9750' MD to 8850'MD. T AL1-01 lateral vrili exit the AL1 lateral off a flow throu h liner 'adc billet and drill 1Q00' hori _ . San sin the same au at . It Ise owed 2 8 aloft ~ner from at 9840'MD to the window, then with skid liner to 4' into tubing tail at 6660' ELMD. CTD Drill and Complete 1D-04A, 1D-04AL1, 1D-04AL1-01 program: Spud in June 1, 2008 CTD Sidetrack Summary Pre-Rig Work: 1. O PT Master & Swab valve to 4500 psi. Drawdown test MV and SV to 0 psi DONE 2. O MIT-OA DONE 3. O PPPOT-T & IC DONE 4. O TIFL DONE 5. S Drift to 7127'MD for Baker 2-5/8" X 5" Thru-Tubing Whipstock. DONE 6. S Calliper log 5" liner and 3-1/2" tubing to surface. DONE 7. E Video log of 5" liner -Found collapsed liner at 7127' ELM DONE 8. S Dummy Gas Lift Valve's 9. O Load tubing & IA, MIT-IA 10. O Obtain static bottom hole pressure , 11. E Set Whipstock (TOWS 7110' MD) using gyro-orienter for vertical hole 12. C Test for infectivity 13. C Lay in cement above perfs, Squeeze cement past whipstock. 14. O Function test LDS. 15. O Set BPV 16. O Bleed production flow lines and GL lines down to zero and blind flange 17. O Install second swab valve & SSV 18. O Remove wellhouse, level pad, drill mouse hole. Rig Sidetrack Operations: (Scheduled to begin on June 15, 2008) 1. NU 7-1/16" CT Drilling BOPE and test to 250 psi low and 3500 psi high 2. Pull BPV. Page 1 of 5 May 15, 2008 KRU 1 D-04A, KRU 1 D-04~ &KRU 1 D-04AL1-01 Trilateral oiled Tubing Drilling 3. Mill 2.74" window at 7110'. Swap well to Flo-Pro. Use managed pressure drilling techniques to maintain 800 psi pressure over formation pressure at the window. 4. Drill build/turn section with 3" bicenter bit, and land well. 5. Drill lateral section to 8,650' MD. 6. Circulate in kill weight fluid from window to surface. 7. Run 2-3/8" slotted liner to TD. Place aluminium liner top billet at 7,750' MD. 8. Sidetrack L1 lateral off liner top billet. 9. Drill L1 lateral to 9750' MD. 10. Circulate in kill weight fluid from window to surface. 1 i Q~ ~n 24/!?» ~Ina<<..J 1:.~.... a.. TI"1 DL..... ..1........-.....Y c__- a_.- v:u~a .a n nrnr ~ ~r~ 12. Sidetrack AL1-01 lateral off liner top billet. 13. Drill L1-01 lateral to 9840' MD. ~ 14. Circulate in kill weight fluid from window to surface. 15. Run 2-3/8" solid/slotted liner to TD. Place TOL in 3-1/2" tubing tael at 6660' ELMD. 16. FP well to 2500' with diesel. \ 17. Set BPV. ND 7-1/16" stack. FP tree and PT tree cap to 3500 psi. 's ~~ 18. RDMO Nordic 2. Post-Rig Work: 1. Re-install wellhouse and FL's. 2. Pull BPV. 3. Run Live gas lift design 4. RU test separator, flow test well. Mud Program: • Well kill: 11.8 ppg brine • Milling/drilling: 8.6 ppg Flo Pro or biozan for milling, new Flo Pro for drilling. Maintain 800 psi overbalance on reservoir while drilling. ~ Disposal: • No annular injection on this well. • Class II liquids to KRU 1 R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 1 D-04A : 2-3/8", 4.6#, L-80, STL from TD(8650'MD) to 7750' 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(9,750'MD) to 8850' 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-04AL1-01:2-3/8", 4.6#, L-80, STL from TD(~9,840 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, inside existing casing, and across faults where shales may be exposed. Top of liner placed C~3 6660' ELMD (4' above 3-1/2" Tubing Tail) Casino/Liner Information Page 2 of 5 May 15, 2008 KRU 1 D-04A, KRU 1 D-04~ &KRU 1 D-04AL1-01 Trilateral oiled Tubing Drilling 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 Well Control: • Two well bore volumes (200 bbls) of KWF 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 4000 psi. • The annular preventer will be tested to 250 psi and 2500 psi. Directional • See attached directional plan for 1 D-04A, AL1, AL1-01 ' • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • The nearest well to 1 D-04A, AL1, AL1-01 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. • Possibility may drill into D shale above the C4. Will be forced to do an open hole sidetrack. • KRU 16 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 H2S. 1 D-12 has the closest BHL an H2S level of 100 ppm. All H2S monitoring equipment will be operational. Reservoir Pressure • The most recent SBHP surrey (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 i 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 stabili 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 BOPE 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-04A, AL1, AL1-01 TD: Estimated reservoir pressure: 2917 psi at 6389' TVD, 8.8 ppg ~ EMW. Page 3 of 5 May 15, 2008 KRU 1 D-04A, KRU 1 D-04~ &KRU 1 D-04AL1-01 Trilateral oiled Tubing Drilling • 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 i or 10.7 ppg ECD. 150 psi surface pressure while drilling will be maintained to assure a EMWt. at the window of 10.7#/gal. • When circulation is stopped, a minimum of 790 psi surface pressure will be applied to the well to maintain constant BHP 3630 psi. Mel Rixse CTD Engineer 564-5620 CC: Well File Sondra Stewman/Terrie Hubble Page 4 of 5 May 15, 2008 ConocoPhillips Alaska, Inc. KRU 1 D-04 ~' 1 D-04 API: 500292041600 Well T e: PROD An le TS: 2 d 7099 TUBING 500 O 3 SSSV Type: Nipple Orig 1/28/1980 Angle @ TD: 3 deg @ 7502 , D: . iD:2.ssz) Annular Fluid: Last W/O: 5/31/2000 Rev Reason: TAG FILL Reference Lo Ref L Date: Last U ate: 4/13/2008 Last Ta : 7244' RKB TD: 7502 ftK6 Last Ta Date: 4/5/2008 Max Hole An le: 36 de 4100 Casin Strin -ALL STRINGS Descri Lion Size To Bottom TVD WI Grade Thread CONDUCTOR 16.000 0 80 80 65.00 H-40 ' SUR. CASING 10.750 0 2890 2690 45.50 K-55 '` PROD. CASING 7.000 0 7042 6399 26.00 K-55 LINER 5.000 6746 7500 6856 14.87 K-55 Tubin Strin -TUBING Size To Bottom TVD Wt Grade Thread 3.500 0 6729 6086 9.20 J-55 BTC Perforations Summa Interval TVD Zone Status Ft SPF Date T e Comment 7102 - 7114 6458 - 6470 C-4 12 4 8/10/1980 IPERF 2 1/8" Ener et '- 7114 - 7123 6470 - 6479 C-4 9 8 8/10/1980 IPERF 2 1/8" Ener et 7123 - 7186 6479 - 6542 C-4,C-3,C-2 63 4 8/10/1980 IPERF 2 1/8" Ener et 7337 - 7354 6693 - 6710 A-5 17 4 7/28/1980 IPERF 2 1/8" Ener et Gas Lift MandrelsNalves - St MD TVD Man Mfr Man Type V Mir V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 2657 249 2 Camco KBUG CAMCO GLV 1.0 BK 0.156 1214 8/26/2007 2 4036 364 0 Camco KBUG CAMCO GLV 1.0 BK 0.188 1252 8/26/2007 3 4949 438 6 Camco KBUG CAMCO OV 1.0 BTM 0.188 0 8/26/2007 4 5620 499 6 Camco KBUG CAMCO DMY 1.0 BK 0.000 0 5/31/2000 ' S 6135 549 5 Camco KBUG CAMCO DMY i.0 BK 0.000 0 5/31/2000 6 6558 591 5 Camco MMM CAMCO DMY 1.5 RK 0.000 0 6/4/2000 Other lu s, a ui ., et c. -COMPLETION De th TVD T e Descri lion ID 557 557 NIP Camco DS NIPPLE 2.875 6635 5992 NIP HES X NIPPLE 2.810 ' 6657 6014 PKR Baker'SAB-3' 3.250 ^ ~ 6673 6030 NIP Camco D NIPPLE 2.750 6684 6041 WLEG TTL ELMD 6664' 2992 I General Notes Date Note 2/25/200 NOTE: WAIVERED WELL: IA X OA COMMUNICATION J Perf (7102-7123) Perf (7337-7354) 1 D-04A , 1 D-04AL1, 1 D-04AL1-01 10-3/4" shoe Q 2890' RKB 5" liner top ~ 6746' RKB (6741' ELMD) 7" shoe ~ 7047 RKB - 12.74" window I ~ ~ -~ :: C-sand perfs 7107 - 7186' ~ • • \ ELMD (squeezed) ~ • : \ Liner damage ~ 7127' ELMD Slickline to ~ 7225' SLM ti•ti•ti„•{ ,•;.{•ti• r.r•r•r•:••: •r•r•r S • ti.1, • ~ • ti.1.5~ • L • 5 r•r•r•r•r•r.r•r•r 1.ti.ti. t.~.•.. ti. •..ti. r•r•r•r•r.r•r•r•r A-Sand pelts 733T - +•+•ti•1•~.•ti•ti•ti•ti• r•r•r•r•r•r•r•r•r 1.ti.S.ti.ti.q.ti....y 7354' MD r•r•r•r•r•r•r•r•r {....ti.ti.ti ti.ti.ti.ti. Sit:"r•r•F•r•r•r•r L.L.• ti•t.'4•ti• tr~r•r•f•r•r•r•r•r 1.1•• \•••Y•.• 5" 14.9k K-55 r.i•r•r•~•r•r•r•r ti.ti.1.1•S NtiK•ti• Shoe ~ 7500' •r•r•r•r•r•r•r•r•r 3-1/2" Camco DS nipple ~ 557' RKB 3-1/2" 9.3N L-80 EUE Brd Tubing to surface 3-1/2" Camco KBUG gas lift mandrels ~ 2657', 4036', 4949', 5620', 6135' RKB 3-1/2" Camco KBUG gas lift mandrels ~ 6558' RKB 3-112" HES "X" landing nipple ~ 6635' RK8 (2.812" min D) Baker3-1/2" PBR ~ 6643' RKB Baker SAB-3 packer ®6657' RKB (3.25" tD) 3-1/2" Camco D landirg nipple ~ 6673' RKB (2.75" min ID, No-Go) `Mill out to 2.80" pre-rig 3-1/2" tubing tail ®6684' RKB 6664' ELMD) in // / ~ // Aluminum billet / 8850' MD (wp07) / i~ _- • i ~_ ~ Aluminum billet ~ 7750 MD (wp07) ~ ~ 2-3/8" STL - STL blank slotted liner - ;ross Bshale AL1-01 TD ~ 9850' MD (wp07) ConocoPhillips ~~ ConocoPhillips(Alaska) Inc. ,, Kuparuk River Unit Kuparuk 1 D Pad 1 D-04 Plan 7, 1 D-04AL1-01 Plan: Plan #7 Baker Hughes INTEQ Planning Report ~ 14 May, 2008 ~~~~ BAIC~R ~~~~ INTEQ ConocoPhillips Company: ConocoPhillips(Alaska) Inc. Project: Kuparuk River Unit Site: Kuparuk 1D Pad Well: 1 D-04 Wellbore: Plan 7, 1D-04AL1-01 Design: Plan #7 Survey Tool Program Date From To (ft) (ft) Survey (Wellbore) 200.00 7,100.00 1d04 (1D-04) 7,100.00 7,750.00 Plan #7 (Plan 7 , 1D-04A) 7,750.00 8,850.00 Plan #7 (Plan 7 , 1D-04AL1) 8,850.00 9,840.00 Plan #7 (Plan 7 , 1D-04AL1-01) Planned Survey MD Inc Azi 8,850.00 92.68 98.25 KOP 8,870.00 88.74 97.56 End of 20 Deg1100 ' DLs 8,900.00 85.99 95.24 8,920.00 84.15 93.68 3 8,970.00 85.53 87.82 4 9,000.00 86.01 91.40 9,100.00 87.71 103.30 9,200.00 89.50 115.17 9,240.00 90.23 119.91 5 9,300.00 91.47 112.82 9,400.00 93.49 100.98 9,500.00 95.36 89.09 9,560.00 96.37 81.92 6 9,600.00 96.52 86.75 9,700.00 96.68 98.83 ConocoPhillips Baker Hughes INTEQ Planning Report Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: Tool Name SEEKER MS MWD MWD MWD Description BHI Seeker multishot MWD -Standard MWD -Standard MWD -Standard /e~ i 1NTEQ Well 1 D-04 Mean Sea Level 1D-04 @ 105.OOft True _ Minimum Curvature EDMv16 Prod DSS N/S E/W Northing Easting DLS Vertical Section (ft) (ft) (ft) (ft) (ft) (°l100ft) (ft) 6,444.98 1,842.57 3,409.01 5,961,414.77 563,883.74 12.00 3,556.63 6,444.74 1,839.82 3,428.82 5,961,412.18 563,903.57 20.00 3,576.12 6,446.11 1,836.48 3,458.59 5,961,409.08 563,933.37 12.00 3,605.49 6,447.83 1,834.93 3,478.46 5,961,407.69 563,953.24 12.00 3,625.14 6,452.33 1,834.28 3,528.23 5,961,407.44 564,003.01 12.00 3,674.67 6,454.54 1,834.48 3,558.14 5,961,407.89 564,032.92 12.00 3,704.48 6,460.04 1,821.73 3,656.99 5,961,395.93 564,131.85 12.00 3,801.84 6,462.49 1,788.86 3,751.20 5,961,363.82 564,226.32 12.00 3,892.84 6,462.59 1,770.37 3,786.66 5,961,345.62 564,261.92 12.00 3,926.55 6,461.70 1,743.74 3,840.38 5,961,319.43 564,315.85 12.00 3,977.74 6,457.36 1,714.75 3,935.79 5,961,291.21 564,411.49 12.00 4,070.27 6,449.62 1,706.01 4,034.93 5,961,283.27 564,510.68 12.00 4,168.26 6,443.48 1,710.68 4,094.39 5,961,288.42 564,570.09 12.00 TV 4,227.90 6,438.99 1,714.61 4,133.93 5,961,292.66 564,609.60 12.00 4,267.64 6,427.46 1,709.78 4,232.96 5,961,288.64 564,708.66 12.00 4,365.87 TFO r) 80.14 -170.00 -140.00 -139.89 -77.00 82.24 81.58 81.29 -80.00 -80.11 -80.62 -81.54 88.00 88.54 5/14/2008 4:59:20PM Page 3 COMPASS 2003.16 Build 42F ~ ConocoPhillips ~ . ' Co11000Phillips Baker Hughes INTEQ Planning Report NaSka 1NTkQ 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 Well: 1D-04 North Reference: True Wellbore: Plan 7, 1D-04AL1-01 Survey Calculation Method: Minimum Curvature Design: Plan #7 Database: EDMv16 Prod Planned Survey MD Inc Azi TVDSS N/S E/W Northing Easting DLS Vertical Section TFO (ft) (°) (°) (ft) (ft) Ift) (ft) (ft) (°I100ft) (ft) (°) 9,800.00 96.54 110.91 6,415.91 1,684.34 4,328.79 5,961,263.97 564,804.68 12.00 4,459.12 89.9 9,839.99 96.41 115.74 6,411.40 1,668.61 4,365.27 5,961,248.54 564,841.27 12.00 4,494.08 91. TD 9,840.00 96.41 115.74 6,411.40 1,668.61 4,365.27 5,961,248.53 564,841.28 12.00 4,494.09 91.87 2.375" i 5/14/2008 4:59:20PM Page 4 COMPASS 2003.16 Build 42F ConocoPhillips TYDs Targai Pzlmulb Origin Typo NIS ENJ F wn NO User N9 Taf9el lFreenand7 BS 00 Sla 0.00 O00 r 000 1D-04 @ 105 006 PntM' Nupvrue Mwr Unll SNe. KuPruM 10 Pvd wens D41a wl... WNlbon Plan]1D-04A p,~n. w,xn. ow Plvn. Pl.n n no-0uvlan ]. maul ... ,. now WELL DETAILS: 1D-04 Ground L.vN0.00 +W-3 +EI-W NoHHing EMllnq LNIHUde Longltutle Sbl 0.00 O.OR959]98 51 1]p05]9 98]0° t]' S9 09] M9° 30' 41504 W .. . I Irv In tale 9NNOTAT ONS 9.r~ un 1 ilmm rc IS) A FI BJ NO 935190 •Nr.s 15M B5 r w awa 9)IU Om TF..e vs.1 Om I¢Y 59 ~~ : Tw ND AnnplNiwl fi]5 5 1110m IBS e1% Bk 41 15M )9 9)119 M 11% 14NM 0 ]tm 00 TP 515 5 >t1000 KOP ] Itk1m J15 9]51 B.HI11 159519 19]99-0 900 Sm I%]% fi39 ) 113000 Ertl N90 tb]]J 5 IIn ]l ItOm t0A 83 1091 9)15 850119 M]099 1fi5B da 161615 109190 4)00 m199] 1100 Bm )IMM %% ))191] 550 38313 EMN4)I ] fl9 4]3.13 S e ]M]n ] )et]1] 9993 %M ul9 sl )0 eu999 MOP% IMe ]s 118JM )IM )) 1)m )J90M 1)% IMm )]osu )rim )531)1 n ]ss3 t3 s ~ 95 PI)]3 ] 9 BIM ]l M1J )] 91M 9t 91 9841 e918 e]1111 BIM n) IM>e1 1909M )]1094 I)M )a9]M Ilm %b 1eML )10m Ili )3 tM )J 8 13 ]] 9 10 99mm AI J1 918] 9.M)m 19]SM 31M.w I)m %m ]l.N O.9 5]fi. 995n On Tp Cor+oco`PF,Bnps G g%~a, , nM9lIm.P~, 9 9 m Um ;~K~ ism $wN h99n IJm IIm - - - M. - I Contact Information: Bill Michaelson : Cell: 907-307-3570 Email: bill.michaelson@inteq.wm X11 ~~ III l _ I~T ~, _ I_ ~~ II I _ L I I - ; I I I I ~ ~ { 1 yI ~i --'Il ' II L j I I 4 I IJ~i ~ ~ ~ ~ ~ ~ ; l i I Lt. - j I . 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I , ~ I 1 l , I , ' ~ 1-r_ I_ _~- f ~ ; _ I! f I I r' , ~ r I I I ! ~ . , ! ~ ~ j -i; i I + } ~- LI l ~ di 1 ..' ll L li ~ t i_~ : ~ ,; I Lil! ~ _ I , ': . ,~I __ ~ ~ !itl .:_, I~ ~i ~: .II( ~ ~ , ~~ I , I ! I .l II I , i i . _ $ ( v0 ) ~ ~m I I ~ I ~ r I I I 11 _ _A L~-~ .n _ . L u r I ar ru niW .._ .. a re ars Iw w rv. n zr m „ T- a. ~y ! r•-.-.T .~ ,. r.T ~ „~ ,~ ,. __ I ~ .,~ ,,. r I I b o :00 vi Q o ~ ~..T , gel O_ - o - - o o , - ~ '.--~-• ^-~ -- -~- r-r~ -i-•-•-. --r~ ~, T:-. Klll Un~ Manual Wing Valve 3-t/8" SSV used as an ESD y Check Valve Pressure Transducer Mass for flow in from Mud manifold Moae for flow out to Swaco Superchoke Manual Block Valves Double Swab Valvea ~--- Surtace Safety Valve f' Master Valve Piping for flow cross, manual wing valve and ESD to be flanged connections. Piping upstream from ESD to be 2" hammer unions. Hoses to be 1 ", 5000 psi, Arctic rated. TRANSMITTAL LETTER CHECKLIST WELL NAME ~~u l D ~~ ~" ~ ~ Develo menu Service - p < Non-Conventional Well FIELD: Exploratory Stratigraphic Test POOL: 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 wellbore's/egm t of existing ~' ~ well ~~ / 7 / (If last two digits in permit No. ZD8 ~ D~ AP[ No. 50-OZ~ - Zd /lo -G~ >,/ API number are , . 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}, all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_, from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingept upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed mejhane is not allowed for (name of well) until after (Comaanv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Company Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 1/11/2008 WEtL PERMIT C HECKLIST' Field il< Pool KUPARUK RIVER, KUPARUK RIVOIL - 490100 Well Name: KUPARUK RIV UNIT 1D-04AL1-01 Program DEV Well bore seg PTD#:2080860 Co mpany ~ONOCOPHILLIPS ALASKA INC Initial Classffype DEV I PEND GeoArea 890 Unit 11160 OMOff Shore ~_ Annular Disposal Administration 1 Permit fee attached- - - - - - - - - - - - - - - - - NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 2 Leasenumtx.rappropriate--________--_--___------------------- Yes- ------EntireweNbo[e inADL025650______------------------------ - - - -- 3 Unique weN-name and number - - - - - - - - - - - - - - YeS - Yes - - - - - - - - - - - - - - - - - - - - - - KUPARUK RVOIL - 490100, gov_emed by Conservation Order No. 4320.- - _ _ - - _ _ - _ _ - KUPARUK RIVER, 4 Well located in-a_definedp991- - - - _ - _ _ " - - - - - - - - - - - - - - - - - - - - _ Yes _ _ _ _ Conservation order No. 432G contains no spacing restrictions with respectto drilling unit boundaries. - _ - _ _ 5 Well located proper distance from drilling unitboundary- - - " _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ 6 Well located proper distance from other wells_ - - - _ _ _ _ _ _ _ - _ - - - _ - - _ _ - Yes _ _ - - _ _ Censervaiion Order No. 4320 has_na interweil_spaeing-restrictions, - _ " _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ i Yes Conservation Order No, 4320 has no interwell-spacng-restrictions, Wellbor-e wilt be-more than 500' from - - _ _ _ - 7 Sufficient acreage available in-dolling unit- - - - - - - - - - - - - - - - - - - - - - - - - - - _ - _ _ 8 Jf-deviated, is-wellbore plat-included _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ " - - _ - - - - _ Yes _ _ _ _ _ anexternal propettyline-where-ownership ortandownersh~ changes. _ - - _ " _ - _ . - - - - - - - - - - - - - 9 Operator only aff_ecled par4+ - - - - - - - - - - - - - - - Yes - -------------------------------------------------- - - - - - - - - - - - - 10 Operator has appropriate bond inforce - - - - - - - - - - - - - - - Yes - - - - - - - ~ - - - - - - - - - - - - - - - - - - - - 11 Permitean be issued w]thout co_nservatien order- - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Appr Date 12 Permitcanbeissuedwitbcutadministrativ_e-approval---------------- _-_-- Yes. -.------------------------ -- - ----- --- -- - - - -- -- 13 Can permit be approved befere 15-day-wait - - - - - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - SFD 5!28!2008 14 Well located within area and-strata authorized bKlnjecti9n Order # (put1O# jn_comments)-(For- NA- - - _ _ _ _ _ _ _ _ - - _ _ - . _ _ - _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - " - - 15 All wells-withint(4_mile area ofn;viewidentified(ForseNicewellonlyj___"__-___--_-_ NA__ __________________________"__------------------------- - -- 16 Pre-produced injector duration of preproduction less than 3 months-(Forservice well only) - _ AtA_ _ _ _ _ _ - _ _ _ _ _ - " _ _ - _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - 17 Nonconven,gas_confcrmstoAS$1:05,03Q1~.1.A),((.2.A-D)--------------------- NA-- ------------------------------- ------------- Engineering 18 Conductotstring_provided------------------------- --- ---- -NA-_ -___-ConductorsQtin 1D-04(179.004).----------------------------------- -- -- 19 Surfece_casingproieci&all_kngwnU$DWS______________________________ NA_- -____Allaquifersexempted,"40 CFR-147.102-(b)(3).____.-__-____"-_---__-___-------- 20 CMT"voladequate-tocireulate-onconductor&surf_csg_-_____--__"-_-_- --___ NA__ ___-_Surf_acecasing set in lD-04.-"___-__-______--_- --------- --- 21 CMT_v_oladequatetotie-inlongstringko_surfcsg------------------------- -- NA-- --.--Production-casin9set in_1D-94,------------------------------------ - - - 22 willcoverahkn2wnproductiyehcrizons____-_------------------- --- CMT No-- -_-__Slotledlinercompletionplanned.-_"__-"___________"-__--__-------------- ----- 23 _ Easing desgns adequate for C, T, B & permafrosi_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes - _ _ " _ - 9r-iginal well_met design specifications.-NA for slotted liner.- - _ - - - - _ _ - - _ - - _ - - _ - - _ _ _ - - 24 Adequate tankage-or reserve pit " - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - " _ Yes _ - - - _ _ -Rig equipped with steel pits, No reserve pit planned._ All waste_to approved disposal well(s)! _ _ _ - _ _ _ _ _ _ _ _ - 25 If-a_re-drill,hasa10.40$for abandonment been approved------------------ --- NA-_ _--________-------_------------------ - - - - - - ---- - 26 Adequatewetlboreseparatjon-proposed_________________________________ Yes_ ______Nearestsegmentisnew"h/_drilied-1D-04ALtand-paths diverge.-___-"._--__--____-____-__--__ 27 required, doeslimeetregulaiions____-_-___-.----------- -- -- Ifdiverter N?-- ------BpPStack_vnllalreadY-be in place=---------------------------------- -- Appr Date 28 _ Drilling ffuid.program schematic & equip list adequate- - - - - - - - - - - - - - - - - - - - - Yes _ _ - _ _ _ Maximum expected fo[maiton pressure 8,8-EMW.- Maoagedpressure-drilling teohnigs~e to be used-wish 6,6-ppg - - TEM 513012008 29 BOPEs, da they meet regulation _ - _ - _ - _ _ - - _ - " _ _ " _ _ __ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ - _ - _ MYV and applied pressure. ActuatBli EMW"may be as high as U,8 ppg tomaintain-constant BHP. _ _ 130 BOPE_press rating appropriate;test to-(put prig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ - HASP calculated at 2279 psi, 3500_psi-BOP testplanned, - _ _ . _ _ _ _ _ _ - - - . _ . _ _ _ - - - _ - - - 31 Choke_manifold ccmplieswlAPI_RP-53 (_May 6`!) - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 Work willgccurwikhoutoperationshutdown_______________-----------__- Yes- ------------------------------------- -- -- - - - 33 Is presence of H2S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ H2S is reported-at 1q pad. "Mud should preclude H_2S on rig.- Rig has-sensors and alarms. - - - _ - _ - _ _ _ _ , 134 Mechanical-condition of wells wkhin AOR verified (Fo[service wail ony) - _ _ _ _ _ _ _ _ _ _ - - NA_ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - -_ - - - - - - " " - - - - - - - - - - Geology 135 Permit-can be issued wlo hydrogen-sulfide measures _ _ _ _ _ _ _ _ _ _ _ _ _ " _ _ - _ - - _ _ _ _ _ No- _ - _ _ _ - - KRU 1 D-04 measured 60ppm H2S on June 1842096. H2S_measures_required. - - _ - _ _ _ - - _ - - _ _ _ . - - _ - _ 36 Data-presented on potential9verpressurezones _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - - - Recent BHP_survey measured 8,8_ppg EMW. Weli_will be dritled_using coiled cubing rig with-6.6 ppg_mud-and - _ - Appr Date 37 Seismieanalysis of shallow gas~ones_ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - NA_ _ - - _ 600-psi-overbalance will be maintained on reseryoic _ _ - _ _ - - _ _ _ _ _ - - _ _ _ _ _ _ - - - - - - - - - - - - SFD 512812006 38 Seabed conditiorrsvrvey-(ifoff-shore) - - - - - - - - - - - NA- - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 39 Coniaci namelphoneforweekl .progress reports-[exploratory onl N_A_ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - " - - - Geologic Commissioner: Engineering Public Date Dat e Commissioner Date: Commissioner: p ~y~ ~L1~?~,/ '~ c7Cl'QO C~
