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Home My WebLink About208-105Image 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. ~~~ - ~ Q ~ Well History File Identifier Organizing (done) RES AN Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria Project Proofing BY: Maria _ Scanning Preparation BY o.~a muiuiuiiuiiii DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: Date: ^ Logs of various kinds: _x30= Date:. Production Scanning + ~ =TOTAL PAGES ~~ (Count does not include cover sheet) /s/ Stage 1 Page Count from Scanned File: (count does include co/ver~sheet) Page Count Matches Number in Scanning Preparation: 'L/ YES NO BY: Maria Date: ~„/'a ~b ~s~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: lSil I II ~I II I II II I I III Scanning is complete at this point unless rescanning is required. ReScanned II I II'lII I I lII I I Ill BY: Maria Date: ~s~ Comments about this file: Quality Checked III II'lII'II II'I III A«,~~~~ iiiuiiiuiuum OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Other:: /s/ P oiimiiiiiuim v~P Date: pL.' I ~ / ~z 10/6/2005 Well History File Cover Page doc DATA SUBMITTAL COMPLIANCE REPORT 2/17/2010 Permit to Drill 2081050 Well Name/No. KUPARUK RIV UNIT 1D-12L2 Operator CONOCOPHILLIPS ALASKA INC MD 10955 TVD 6561 Completion Date 7/23/2008 Completion Status 1-OIL Current Status 1-OIL API No. 50-029-22948-61-00 UIC N REQUIRED INFORMATION ~/. Mud Log No Samples No Directional Survey DATAINFORMATpN Types Electric or Other Logs Run: MWD DIR / RES / GR (data taken from Logs Portion of Master WeII Data Maint Well Log Information: Log/ Electr Data. Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 0 10955 Open 9/12/2008 KRU 1 D-12L1 & Kru 1 D- ~ D' C Lis 19112~Induction/Resistivity 8812 10956 Open 12/11/2009 12L1PB1 also on Disk EWR logs in PDF and CGM graphics og Induction/Resistivity 25 Blu 9088 10921 Open 12/11!2009 MD MPR, GR Induction/Resistivity og 25 Blu 9088 10921 Open 12/11/2009 TVD MPR, GR _~ _ Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received .Number Comments ADDITIONAL INFORMATION Well Cored? Y Chips Received? Y / N Analysis 1~TI~ Received? Daily History Received? `fi'r'" Formation Tops ~ N Comments: DATA SUBMITTAL COMPLIANCE REPORT 2/17/2010 Permit to Drill 2081050 Well Name/No. KUPARUK RIV UNIT 1D-12L2 Operator CONOCOPHILLIPS ALASKA INC MD 10955 TVD 6561 Compliance Reviewed By: pletion Date 7/23/2008 Completion Status 1-OIL Current Status 1-OIL Date: API No. 50-029-22948-61-00 UIC N ads-/off' Company ConocoPhillips, Alaska, Inc. Weli Name 1D-12L2 Date 12N /2009 ~ ~~ n w~ ~ ~ 1`~~~~ Page 1 of 4 BAKER HUGHES Ilti1TEQ STATE OF ALASKA ~- ~ 0~ ~~c~iv ALASKA IL AND GAS CONSERVATION COM SSION AUG 2 5 LUOi3 WELL COMPLETION OR RECOMPLETION REPORT AND LOG Alaska Oil & Gas Cons. Commissioi~ 1 a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 20AAC 25.105 2DAAC zs.»D ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well 8 fag6 ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 7/23/2008 12. Permit to Drill Number 208-105 3. Address: c% P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 7/15/2008 13. API Number 50-029-22948-81-00 4a. Location of Well (Governmental Section): Surface: 7. Date T.D. Reached 7/19/2008 14. Well Name and Number: Ku aruk 1 D-12L2 224' FSL, 594' FEL, SEC. 14, T11 N, R10E, UM Top of Productive Horizon: 465' FSL, 5146' FWL, SEC. 13, T11 N, R10E, UM 8. KB (ft above MSL): 104.3' Ground (ft MSL): 15. Field /Pool(s): Kuparuk River Unit /Kuparuk Total Depth: 427' FSL, 1552' FWL, SEC. 18, T11 N, R11 E, UM 9. Plug Back Depth (MD+TVD) 10955' 6561' River Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 560491 y- 5959889 Zone- ASP4 10. Total Depth (MD+TVD) 10955' 6561' 16. Property Designation: ADL 028243 TPI: x- 566229 y- 5960178 Zone- ASP4 ASP4 n 5960155 Z 567915 h D 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: o e- : x- y- Total ept TVD f 18. Directional Survey ®Yes ^ No bmit a ectr nic and rin information r 20 AA 25.050 19. Water depth, if offshore N/A ft MSL rost ( ): 20. Thickness of Perma 1685 (Approx.) 21. Logs Obtained (List all logs here and submit electronic and MWD DIR / RES / GR {~/~/QjJ~I ~ 9J~D~/~l~ rinted infso~rm~at n per 20 AAC 25.071): 6S~f/ id 22, CASING, LINER AND CEMENTING RECORD CASING SETTING DEPTH MD SETTING DEPTH TVD HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED -4 rf 11 rf 1 r 9- / " 4 L-8 rf ce 1' ce 4 2 ' 12-1 /4" 76 x I s ' sx la s 'G' 7" 26# S rface 8 S 2' -1/2" 1 s lass' ' -1 - 4 ' -1/ " I ' 2-3/8" 4.7# L- 0 108' 1 35' 5' 3" Un m me lotte Lin r 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, list each i nterval open d N b f i Si SIZE DEPTH SET MD PACKER .SET MD er): ze an um orat on (MD+TVD of Top 8 Bottom; Per 3/8" Slotted Section 2 4-1/2", 12.6#, L-80 x 8446' - MD TVD MD TVD 3-1/2", 9.3#, L-80 8446' - 8546' 8467 9129' - 10902' 6607 - 6571' 25, ACID, FRACTURE, CEMENT SQUEEZE, ETC. DEPTH INTERVAL MD AMOUNT $c KIND OF MATERIAL USED Freeze Protect w/ Diesel 26, PRODUCTION TEST Date First Production: Reported on 1 D-12L1 Method of Operation (Flowing, Gas Lift, etc.): See 1 D-12L1 10-407 (Dated 08/22/08, PTD 208-104) for Production & Test Data Date Of Test: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL : GAS-MCF: WATER-BBL: CHOKE SIZE:. GAS-OIL RATIO: FIOW TUbing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE• OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITV-API (CORR): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No Sidewall Core s A wired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None j ~,:' Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE ~ ~~~ 2 / LWts ~~~~,~~ ~~l4~1A1 2S. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND ERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No If yes, list intervals and formations tested, briefly summarizing test Permafrost Top results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Kuparuk C2 9122' 6603' None Kuparuk C2 (inverted) 9502' 6628' Kuparuk C3 (inverted) 10152' 6601' Kuparuk C4 (inverted) 10932' 6565' Formation at Total Depth (Name): Kuparuk D Shale (entered f/ Base) 10932' 6565' 30. List of Attachments: Summary of Pre-Rig Work and Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. ~~ /~ Signed Terrie Hubble Title Drilling Technologist Date Kuparuk 1 D-12L2 208-105 Prepared ByName/Number. Terrie Hubble, 564-4628 Well Number P rm' A v I Drilling Engineer: Gary Eller, 263-4172 (Office). INSTRUCTIONS GENERAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. ITeM ia: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITEM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 28: 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. ITeM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory .information required by 20 AAC 25.07E Form 10-407 Revised 02/2007 Submit Original Only BP AMERICA Page 1 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: tD-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/21/2008 03:30- 04:00 0.50 MOB P PRE RD and pre to move rig off 1 D-04 04:00 - 04:30 0.50 MOB P PRE Move off well and spot Yig on pad waiting for well prep 04:30 - 09:30 5.00 MOB N WAIT PRE Rig on standby waiting on well 1 D-12 Prep 09:30 - 13:30 4.00 MOB N WAIT PRE Drilling Mouse Hole with ACS. Having the same problem with mousehole they did on 1 D-04 Nordic worked on BOP and changed out to 4-1/16 adaptor. Pulled accumulator bottle of rack. Pulsar damper change out and working on the suction pits. Schlumberger Change brushes on power pack and installed new pack offs. Stim 3 reel stand and greased injector and guide arch. 13:30 - 15:30 2.00 MOB N WAIT PRE Drilling Tool House shot grade and level Pad 15:30 - 18:30 3.00 MOB N WAIT PRE Install herculite and rig 40ft rig mats for rig to move on. Crew change. 18:30 - 19:30 1.00 MOB P PRE Hold PJSM to discuss moving rig over well. 1 D Pad operator on location. Move rig over well. Accept rig at 1930 hrs on 6/21/08. 19:30 - 00:00 4.50 RIGU P PRE Rig up for CTD operations. Berm cellar. Berm rig. RU MPD loop. Spot and RU external tanks. NU BOPs. Move choke line in cellar for MPD loop clearance. 6/22/2008 00:00 - 03:30 3.50 RIGU P PRE Continue to rig up MPD and BOP equipment. Install 7" lubricator to rig floor. Load pits with 1 # biozan. 03:30 - 07:00 3.50 BOPSU P PRE Pressure test. BOP equipment as per Permit to Drill #207-153 and AOGCC Regulations. PT to 250/3500 psi Test witness waived by J Crisp with AOGCC. Complete test results e-mailed to AOGCC by R. Holmes. 07:00 - 09:45 2.75 BOPSU P PRE RU the MPD Loop. Install 1 valve and plugs on SSV outer flange Installed SSV rupture disc on top side of SSV Re-oriented the MPD check valve. 09:45 - 10:50 1.08 BOPSU P PRE PT the MPL. Installed the ESD system on the rig. NOTE: ESD on Drillerside is 1 D-14 (water Injection) and off driller side ESD is 1 D-01 (Producer). PT floor valves and tiger tank line to 1000 psi. 10:50 - 11:00 0.17 BOPSU P PRE PJSM on pulling BPV 11:00 - 14:00 3.00 BOPSU P PRE RU lubricator and pull BPV WHP at 300 psi. Closed MV and RD KUP's lubricator No recovery, RIH and to retrieve BPV PT lubricator to 1000 psi and RIH worked on retrieving BPV. POOH, no plug, Get new retrieving tool Pulled plug on 3rd try. 14:00 - 14:15 0.25 BOPSU P PRE PJSM on cir IA to 2% KCL 14:15 - 14:30 0.25 BOPSU P PRE Line out to cir IA. PT the line to squeeze manifold to 2000 psi. Open well to tiger tank 14:30 - 16:45 2.25 BOPSU P PRE Circulating out IA at 3.00 / 3.00 bpm at 600 psi with 2% KCI. Density = 6.92ppg out. Taking returns to tiger tank. Circulated 85 bbl to TT and recovered in Vac truck. Sent to recycle Circulated the remainder 250 of fluid to TT. Pumped 65 bbls of 2% KCL with 1 ppb bio down tubing. SD and monitor well. 16:45 - 17:15 0.50 BOPSU P PRE Shut in IA and blow down surface line. Install IA transducer 17:15 - 17:30 0.25 PULL P DECOMP PJSM on RU Halliburton Wireline rnrne+u: a ~.vcwo c.o ~.w rrv~ BP AMERICA Page 2 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ~ From - To i Hours Task Code NPT 16/22/2008 17:30 - 18:30 1.00 PULL P 18:30 - 00:00 5.50 PULL P 16/23/2008 ~ 00:00 - 01:00 ~ 1.00 ~ PULL ~ P 01:00 - 03:30 I 2.501 ZONISO I P 03:30 - 05:00 1.501 ZONISO P 05:00 - 05:30 0.50 ZONISO P 05:30 - 06:45 1.25 ZONISO P 06:45 - 08:15 ~ 1.50 ~ ZONISO ~ P 08:15 - 09:15 1.00 ~ ZONISO ~ P Spud Date: 6/21 /2008 Start: 6/21 /2008 End: 7/24/2008 Rig Release: 7/24/2008 Rig Number: Phase Description of Operations DECOMP RU Halliburton Wireline w/ pressure control on rig floor. DECOMP Run #1. Retrieve catcher sub from 8491'. Run #2. Pull prong from CA-2 blanking plug at 8491'. No recovery. Run #3 Add centralizer to tool string. RIH to pull plug prong. Recover prong. WHP & IA = 210 psi after pulling plug. Run #4: Engage and pull C2 plug. DECOMP Continue to run slickline. Plug recovered. Rig down Halliburton. DECOMP Cut off short bad section of coil. Meg and cont test a-line. Rehead a-coil. Pull test to 35K#. DECOMP Pressure test inner reel valve and packoffs. DECOMP MU nozzle on stinger and Inteq blind sub. DECOMP RIH, gas to surface at 3000 ft, Stopped at 3,569 psi. Lined out pumping down annulus. Op 4.5 bpm PUPa = 500 psi / 371 psi Vp 140 bbl DECOMP RIH maintaining constant WHP /BHP Op=1.00 to 0.5 bpm down annulus Tagged at 9,172 ft.54 Vp = 203 bbp SD SIWHP = 320 psi = 9.3 ppg DECOMP Pump injectiviry test using 140deg 2%KCL Op = 1 bpm at 370 psi 311 psi on IA Op = 1 bpm at 370 psi 377 psi on IA Op = 1.76 bpm at 480 psi IA at 453 psi Vp = 120 bbl at 130 deg I F 09:15 - 09:30 0.25 ZONISO P DECOMP Cement Job PJSM 09:30 - 10:22 0.87 ZONISO P DECOMP Open well to choke and returns are Op = 1.77 / 0.52 bpm at 300 psi WHP Pumped a total 180 bbl 130 deg 2% KCL down CT, SD and pumped bio to reel and SD. isolated MP and lined out to cementers, pumped 2 bbl fresh water and PT to 4000 psi. Batch up 1 tub of cement. Set nozzle at 9,161 ft 10:22 - 10:45 0.38 ZONISO P DECOMP Pumped 3 bbl water Pumped 28 bbl Class G 15.9#/gal, 1.16cf/sxs yield and 5.094 gal /sxsx water requirement. 70BC at 3:18 hr:mn Op 1.55 / 0.5 bpm IA 344 psi Cement to density at 10:20 hrs. Pumped 5 bbl water. 10:45 - 11:22 0.62 ZONISO P DECOMP Displace Cement with Bio /KCL 1.75 bpm Pp = 3500 psi With 4.0 bbl out Op = 1.00 bpm at 800 psi. PUH laying in 1:1 WHP climbed to 450 and then broke back to 350 psi Reduced running speed to 67 fpm in the 4-1/2" tubing 28 bbl cement out. PUH to 7000 ft Op = 0.6 bpm Vp = 33.8 bbl 11:22 - 13:15 1.88 ZONISO P DECOMP Walking squeeze Op = 0.36 bpm Pi = 190 bbl Pf =183 psi Vp =2/26bb1 SD 10 min Pf = 157 psi Op = 0.50 bpm Pf = 155 psi Vp = 3 / 23 bbl SD 15 min Pf = 157psi Op = 0.50 bpm Pf = 185 psi Vp = 4 / 19 bbl SD 15 min Pi = 187 psi Op = 0.50 bpm Pf = 220 psi Vp = 3 / 16 bb112:25 hrs SD 8 min Pi = 220 psi Op 0.50 bpm Pf = 250 psi Vp = 3 / 15 rnmeu: aiwcwo <.u ~.ca r... ~ ~ BP AMERICA Page 3 of 31 Operations Summary Report 'Legal Well Name: 1 D-12 Common WeII Name: 1D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number:. Date From - To Hours Task Code NPT Phase Description of Operations 6/23/2008 11:22 - 13:15 13:15 - 13:50 13:50 - 14:10 14:10 - 14:30 14:30 -.21:00 21:00 - 21:15 21:15 - 21:45 21:45 - 23:00 I 123:00 - 23:30 23:30 - 00:00 6/24/2008 00:00 - 00:15 00:15 - 02:00 - 03:30 1.88 ZONISO P DECOMP bbl 12:31 hrs SD 15 min Pi = 240 psi Op = 0.40 bpm Pf = 250 psi Vp 2 / 13 bbl 12: 48 hrs SD 12 min Pi = 245 psi Op = 0.48 bpm Pf = 275 psi Vp 3 bbl / 10 bbl 13:05 hrs SD 5 min Pi 271 psi Op = 0.50 bpm 0.58 ZONISO P DECOMP RIH cleaning out wellbore for next cement job Op = 1.00 / 0.26 bpm WHP = 370 psi Tagged at 9067 ft MD PU Cement in place at 13:00 hrs 0.33 ZONISO P DECOMP Inc Op 2.85 bpm Rlh and confirm integrity Tagged hard again at 9072 ft 0.33 ZONISO P DECOMP Cir and maintain constant BHP while WOC. SWI. RU to confirm IA communication at 8,136 ft. Circulated 50 bbl down IA at 1:1 taking returns to pits. 6.50 ZONISO P DECOMP Circulating Op = 0.99 / 0.90 bpm. WHP = 179 psi. Spot SLB cement bulk truck. 0.25 ZONISO P DECOMP Perform infectivity test. 460 psi whp at 1.22 bpm. Shut in pump. WHP bled from 460 psi to 360 psi in +/- 7 minutes. 0.50 ZONISO P DECOMP Hold PJSM with rig and SLB crews. Discuss safe area, pump schedule, fluid handling, clean up issues. 1.25 ZONISO P DECOMP Prep mix water for 15 bbls Class G 15.8 ppg cement. Pump 5 bbls fresh water ahead.. PT lines to 4000 psi. Mixon the fly and pump 15.7 bbls cement into reel. Pump 5 bbls water behind. Displace cement in reel with 1 # biozan/kcl water from pits. Maintain 170 psi WHP 2700 psi at 1.67 in/1.69 out. 0.50 ZONISO P DECOMP RIH to 9060' nozzle depth. Lay in cement at 1:1. Cement in place at 23:15 hrs. POOH to safety at 7500 psi. 0.50 ZONISO P DECOMP Wait on cement for 30 min. SIWHP: 95 psi 0.25 ZONISO P DECOMP Continue to wait on cement for one hr total. 1.75 ZONISO P DECOMP Circ down coil to squeeze cement away: 00:15 Pi: 55 psi Vp: 3.6 bbls Pf: 250 psi. After 30 min: Pf: 165 psi 00:45 Pi: 165 psi Vp: 1.0 bbls Pf: 215 psi After 30 min: Pf: 172 psi 01:15 Pi: 176 psi Vp: 1.0 bbls Pf: 295 psi After 10 min: Pf: 280 psi 01:25 Pi: 280 psi Vp: 1.0 bbls Pf: 410 psi After 20 min: Pf: 340 psi 01:45 Pi: 340 psi Vp: 1.0 bbls Pf: 695 psi After 5 min: Pf: 688 psi 01:52 Pi: 688 psi Vp: 1.0 bbls Pf: 1010 psi. Held solid for 10 min. Begin circulating well with 500 psi WHP. Start 2# bio pill down coil. 1.50 ZONISO P DECOMP RIH. 4100 psi at 3.1 in/3.4 out. Maintain WHP at 300 psi. Wash tbg to 8950'. Make up pass. Wash packers at 8467' and 8542'. Circulate down IA to verify clear of cement. ~ ~ BP AMERICA Page 4 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: :.NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations b 6/24/2008 02:00 - 03:30 1.50 ZONISO P DECOMP Cement back to surface. Treat same and send to cuttings ox. Circulated approximately 3 bbl cement to surface 03:30 - 06:00 2.50 ZONISO P DECOMP Continue to circulate out of hole. Wash each GLM. 06:00 - 07:00 1.00 ZONISO P DECOMP OOH, LD Nozzle BHA and PU swizzel stick. Jet stack at 4100 psi 07:00 - 07:10 0.17 ZONISO P DECOMP Stand back injector and LD swizzle stick. Make read to conduct slack management Load pits with SW abd mix in Biozan 07:10 - 07:55 0.75 ZONISO P DECOMP Rehead CTC / UOC. Wire tested goo at >2000ohm resistance and continunity of 50mohms. Install head and failed test. Set inject over well and pump slack to get enough wire to rehead. Pumped slack and heard it move in the reel house . SD 07:55 - 10:00 2.08 ZONISO N SFAL DECOMP Re-head UOC following failed test 10:00 - 10:25 0.42 ZONISO P DECOMP PJSM on MU of clean out BHA useing pressure deployment procedure. 10:25 - 12:05 1.67 ZONISO P DECOMP MU and PU clean out BHA following pressure deployment procedures. Compressive strength of cement was 1200psi ~ 04:30hrs. via UCA 12:05 - 13:05 1.00 ZONISO P DECOMP RIH maintaining 300 psi well Head Pressure. Taged at 8496' 13:05 - 14:55 1.83 ZONISO P DECOMP PU to 8487' Free spin of 2040 ~ 1.51 bpm. Taged again at 8504' CP=3000 psi ~ 1.5 bpm free after 8502' "Ratty" conditions again at 8527' and there after in D nipples and Baker seal assembly at 8538'. 8545' CP=2700psi ®1.4 bpm and 4000# WOB 8564' CP=2500 psi ®1.75 bpm DH WOB=200# ROP=6.6 fpm 8700' RIH ~ 25 fpm. After 8700' hole was clean down to 8956'. 14:55 - 15:20 0.42 ZONISO P DECOMP Log for GR tie in from 8850' to 8908' - 6 ft correction 15:20 - 15:40 0.33 ZONISO P DECOMP Continue to RIH Tag ~ 8934' CP=2500 psi ~ 1.77 bpm 1400# WOB. free ~ 8940' 8956' CP=3300 psi 15:40 - 18:45 3.08 ZONISO P DECOMP Hard Tag r~8956' CP=3300 psi ~ 1.75 bpm DH WOB 1100 #'s ROP=.7 fpm 18:45 - 21:30 2.75 ZONISO P DECOMP 15-20 FPH ROP 2900 CTP ~ 1.6 BPM, - 1000 DH WOB 21:30 - 00:00 2.50 ZONISO P DECOMP 9075', stalled and got hung up, worked pipe with max down weight and 50k up to free. circulate 20 bbls and continue milling to 9100'. Circulate a 2 ppg bio sweep and CBU 6/25/2008 00:00 - 00:30 0.50 ZONISO P DECOMP CBU. 00:30 - 01:55 1.42 ZONISO P DECOMP Pressure test cemented perfs. BP AMERICA Page 5 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008. Rig Name: NORDIC 2 Rig Number: .Date From - To Hours Task Code NPT Phase Description of Operations. 6/25/2008 00:30 - 01:55 1.42 ZONISO P DECOMP Pressured up to 1000 WHP and pressure bled off to 450 in 10 min. Pump at .2 BPM and pressured up to 900 WHP. Able to inject at .3 BPM at 990 WHP. Consult with town engineers and decide to continue with milling 01:55 - 06:15 4.33 ZONISO P DECOMP RIH to 9100' and continue milling 2700 CTP at 1.8 BPM, 800 DH WOB, 10-15 FPH Milled from 9100' to 9149' 06:15 -06:30. 0.25 ZONISO P DECOMP Short trip to 8903' and pumped 10 bbl sweep with 2 ppg Bio Cp=2550 psi ~ 1.80 bpm I/O =1.82/1.87 While RIH 06:30 - 08:05 1.58 ZONISO P DECOMP Continue to mill ahead. 6~ 9150' CP=2650psi ~ 1.80 bpm In/Out=1.80/1.76 bpm (Annular pressure = 3496 psi / 10.35 ECD) DH WOB = 1060 #'s ROP=22 FPH Milled to 9170' 08:05 - 08:40 0.58 ZONISO P DECOMP POOH to GR tie ~ 8854' with + 3 ft correction Continue loging with GR correction for CCL tie in 08:40 - 10:05 1.42 ZONISO P DECOMP POOH maintaining 300 psi Well head pressure 10:05 - 10:15 0.17 ZONISO P DECOMP PJSM on pressure undeployment procedures while POOH 10:15 - 10:20 10:20 - 11:30 0.08 1.17 ZONISO ZONISO P P DECOMP DECOMP POOH Prusseure undeploy BHA using MPD loop to maintain 300 psi well head pressure. 11:30 - 12:00 0.50 WHIP P WEXIT LD milling BHA and PU whipstock assembly. 12:00 - 12:15 0.25 WHIP P WEXIT PJSM on PU and Pressure deployment of Whipstock BHA 12:15 - 13:30 1.25 WHIP P WEXIT Pressure deploy whipstock BHA. 13:30 - 14:00 0.50 WHIP P WEXIT RIH with Whipstock BHA maintaining 300 psi WHP with EDC open. 14:00 - 15:30 1.50 WHIP N SFAL WEXIT Stop ~ 1200 ft to check on SLB injector pack off condition. Decided Pack off needs replacement. discuss situation with SLB and complete a THA. Hold PJSM with SLB and Nordic hands. Repair SLB injector pack off assembly. 15:30 - 16:55 1.42 WHIP P WEXIT Continue to RIH after repairs. 16:55 - 17:20 0.42 WHIP P WEXIT GR tie in from 8850' to 8898' -6 ft correction. 17:20 - 18:00 0.67 WHIP N DPRB WEXIT Continue to RIH While RIH at 30 FPM, taged ~ 9017.5' w/ 5500 # WOB, PU to 9012 showing -1750# DH WOB. Stopped while Baker TT consulted with Deadhorse. Deadhorse says max up wt is 18,000 # over pull. Pulled up to -9200 #'s Down Hole WOB. Set back down and stacked down 6440 #'s DH WOB. Went Neutral and tried to rotate with orienter. -Unsuccessful. Pulled up -6500 #'s DH WOB. Sett back down = 6500 #'s DH W OB. Pdnmd~ A/t'i/200R 23129 PM BP AMERICA Page 6 of 31 Operations Summary Report Legal Well Name:. 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours Task Code NPT Phase Description of Operations 6/25/2008 17:20 - 18:00 0.67 WHIP N DPRB WEXIT Pulled up -8200 #'s slacked off to neutral and tried to orienter 18:00 - 19:30 1.50 WHIP N DPRB WEXIT 19:30 - 21:00 1.50 WHIP N DPRB WEXIT 21:00-22:10 ~ 1.17~WHIP ~N DPRB WEXIT 22:10 - 00:00 1.83 WHIP N DPRB WEXIT 6/26/2008 00:00 - 02:00 2.00 WHIP N DPRB WEXIT 02:00 - 05:10 ~ 3.17 ~ KILL ~ N ~ DPRB ~ W EXIT 05:10 - 06:45 1.58 KILL N DPRB WEXIT 06:45 - 07:05 0.33 KILL N DPRB WEXIT 07:05 - 08:30 I 1.421 FISH I N I DPRB ~ W EXIT 08:30 - 08:55 0.42 FISH N DPRB WEXIT 08:55 - 10:25 1.50 FISH N DPRB WEXIT 10:25 - 12:12 1.781 FISH N DPRB I WEXIT 12:12 - 12:22 0.17 FISH N DPRB WEXIT 12:22 - 12:27 0.08 FISH N DPRB WEXIT 12:27 - 14:10 1.72 FISH N DPRB WEXIT again. Brought pump rate up to .60 bpm with ECD open. Discuss situation with town engineers. Wait on Safe -lube. Circulate 30 Bbls 2 ppg biozan with Safe-tube, squeeze two bbl down past whipstock. Work pipe, -7000 to + 16000 DH WOB. Pressure up to set whipstock. 4400 psi to set. Top of whipstock at 9009', 45 R Still stuck, indicating the setting tool was stuck rather than the whipstock. While working pipe from -8000 to 50000, increased pump rate to 1.6 bpm, opened up to choke to attempt to clean up around setting tool. Pulled free and weight back to normal up weight at 28000. POOH Lay down WS setting BHA, setting tool looked normal with no indication of sticking mechanism. PU 2 3/8' extreme motor, 2.74 go/2.73 no-go string reamer and parabolic mill. RIH, swap well to 9.8 PPG NaCI brine with flo-vis. Slow ROP at 8480' to 20 FPM Slow to 8 FPM at 8900' Tag W S at 9012.5' Backream at 10 FPM to 8900' Ream down at 10 FPM to tag at 9012.5' CBU,POOH PJSM while POOH for LD of Clean out BHA and PU of Fishing tools Unstab injector LD clean out tools, MU fishing BHA Stop and stand by discuss new plan forward with town. LD Fishing BHA with overshoot and MU different fishing BHA with Hook retrieving system. PU BHA Stab in injector RIH to 8900' with Fishing BHA. Up WT = 29,000#'s. Continue RIH to 8975'. log from 8975' to 8995' for GR tie in. -6 ft correction. Tag fish at 9011' with 50 deg rt TF and 4000# WOB straight pull 30K -nothing set down with 35 deg RT TF, 65 RT, 80 RT, 90 RT, 20 RT, 10 RT, 0, 10 L, 25 L, 45 L, 75 L, 45 RT, 80 RT, 100 RT, 130 L, 160 L, 180, 40 RT, 55 RT, Set down with 55 RT TF and 1000 #'s DH WOB and orientate HOT from 55 deg RT TF to the left, saw orienter stops change positions. PU -nothing. Set back down with 10 RT TF and 1800 # DH WOB and orientate to the right, amped out. Try again with 750#'s DH WOB and orientat to the right saw WT and TF jump- no catch. rnniea: wiaicwo coi:cy rm ~ ~ BP AMERICA Page 7 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1D-12 Spud Date: 6/21/2008. Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/26/2008 112:27 - 14:10 1.721 FISH I N I DPRB I WEXIT 14:10 - 15:50 I 1.671 FISH I N DPRB WEXIT 15:50 - 16:30 0.67 FISH N DPRB WEXIT 16:30 - 19:00 2.50 FISH N DPRB WEXIT 19:00 - 19:30 0.50 FISH N DPRB WEXIT 19:30 - 22:00 2.50 FISH N DPRB WEXIT 22:00 -.23:50 1.831 FISH I N I DPRB WEXIT 23:50 - 00:00 I 0.171 FISH I N I DPRB I WEXIT ~ 6/27/2008 ~ 00:00 - 00:45 ~ 0.75 ~ FISH ~ N ~ DPRB ~ W EXIT 00:45 - 02:20 I 1.581 FISH I N I DPRB 02:20 - 03:30 1.171 FISH I N DPRB W EXIT 03:30 - 08:30 5.00 FISH N DPRB WEXIT 08:30 - 08:40 0.17 FISH N DPRB WEXIT 08:40 - 09:20 0.67 FISH N DPRB WEXIT 09:20 - 11:05 1.75 FISH N DPRB WEXIT 11:05 - 11:45 I 0.671 FISH I N DPRB I W EXIT 11:45 - 13:05 1.33 FISH N DPRB WEXIT 13:05 - 13:20 0.25 FISH N DPRB WEXIT 13:20 - 15:00 1.67 FISH N DPRB WEXIT try again with 25 RT TF and straight pull (twice). 60 RT TF and straight pull Set do with 10 RT, 870 #'s DH WOB and orientate to the RT. POOH with no fish. Hook did grab the bottom of the seal assembly of the FHL packer while POOH, but slacked off and rotated out of it with no trouble. unstab injector and LD fishing BHA. Shut in well using Swab and Master valves. Also shut in IA and OA casing valves. Shut down for Kuparuk field wide safety stand down. PJSM Pump Eline slack out of coil, 300' cut off. PU fishing BHA RIH 8900' weight check, 28000 up, 7700 down tag WS at 9012', PU 20K over and jarred off. RIH to re-engage. Can't gat latched in. Continue attempting to fish WS, unable to engage fish after first attempt. Can not go down past fish at 9012' POOH, pumping across top of hole. 1500# weight bobble at 8538', 2.75" nipple. Lay down BHA Over shot had a broken collet (0.5" x 1.5") and bent housing, indicating that we did latch whipstock on first tag. Over shot will need to be taken to Deadhorse machine shop for repairs Waiting on fishing tools to be repaired PJSM on MU and PU of overshot fishing BHA. MU and PU overshot BHA. RIH with Overshot BHA. Up WT ~ 8900' = 29,000#'s CT WT Dn WT @9000' 7,500#'s CT WT Tag ~ 9010' set down with 2,000#, PU with no over pull Set down with 3,500#, PU no over pull Set DN w/ 2,500 #'s pause and PU w/ no over pull Set Dn while circulating 0.25 bpm. w/1600 CT WT pumps off, pause, PU w/ no over pull. SD ~ 10 fpm 1.0 bpm CT WT of 4000#'s pause. set DN w/ .2700#, pause. Pumps off, PU to 8994' no over pull. SD w/ pumps off, 2400#'s CW, pause, PU to 8997 No over pull. SD 700#'s, PU - no over pull. SD -300#'s, PU 3300#'s, DN -400#'s, PU no overpull. SD 2700#'s, PU no overpull. SD 2400#, pause, SD 2500#, no overpull. SD 2400#, pause, SD 2200#, pause, PU no overpull. POOH POOH without fish. PJSM while POOH on BHA LD and PU LD Overshot BHA. Evaluate Overshot condition and consult with town. rnniea: wisi~uua ca i:ca rm BP AMERICA Page 8 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/27/2008 15:00 - 18:30 3.50 FISH N DPRB WEXIT Pump slack managment to be able to rehead for running Inteq tools on impression block. Cut Coil, 329'. Rehead coil. Test connection. 18:30 - 18:45 0.25 FISH N DPRB WEXIT PJSM 18:45 - 19:30 0.75 FISH N DPRB WEXIT PU BHA #8 with LIB. Scribe line to know orientation of LIB impression. 19:30 - 21:20 1.83 FISH N DPRB WEXIT RIH, orient to high side. Tag WS at 9008', set down 2000 WOB. Wait - 1min. for jars to fire. 21:20 - 23:30 2.17 FISH N DPRB WEXIT POOH 23:30 - 00:00 0.50 FISH N DPRB WEXIT OOH with LIB, Good marks but unsure of what they show. Three distinct, deep impressions. Defnitely part of the whipstock, but does not resemble the WS tray at the surface. Obstruction is -1" into well path. Call out SL. 6/28/2008 00:00 - 02:45 2.75 FISH N DPRB WEXIT Waiting on SL unit 02:45 - 03:00 0.25 FISH N DPRB WEXIT PJSM with Halliburton SL crew 03:00 - 04:00 1.00 FISH N DPRB WEXIT RU SL equipment 04:00 - 07:30 3.50 FISH N DPRB WEXIT SL run with LIB LIB marking very simular to CT LIB run. 07:30 - 09:30 2.00 FISH N DPRB WEXIT SL Run with 1.10" x 30" prong with 2.62" swedge and knuckle joint. tagout and not able to work past obstruction with prong. No conclusive marking on prong. 09:00 - 11:00 2.00 FISH N DPRB WEXIT Evaluation of prong run, decied on plan forward Wait on tools for SL. 11:30 - 12:45 1.25 FISH N DPRB WEXIT SL Run wit 2.5" x 4 ft pump bailer. No returns in basket at surface. 12:45 - 15:00 2.25 FISH N DPRB WEXIT SL Run with 2.5" x 5 ft Hydrostatic bailer. Burst disk did not shear. 15:00 - 16:20 1.33 FISH N DPRB WEXIT 2nd SL Run with Hydrostatic bailer with smaller burst disk. Burst disk fired but nothing in basket. 16:20 - 18:30 2.17 FISH N DPRB WEXIT SL run with shrouded whipstock retrieval hook on a knuckle joint and eccentric weight bar. Unable to hook into whipstock. 18:30 - 19:30 1.00 FISH N DPRB WEXIT RD SL, prep for camera run 19:30 - 20:00 0.50 FISH N DPRB WEXIT PJSM for camera run 20:00 - 21:20 1.33 FISH N DPRB WEXIT PU Inteq tool string and camera. Camera has a snorkle which allows circulation ahead of lens. Camera programed for two shots per second for two 45 second intervals 15 minutes apart. First will be taken with while pumping, second with pumps down 21:20 - 23:30 2.17 FISH N DPRB WEXIT RIH 8500', Tie in, -1' correction 23:30 - 00:00 0.50 FISH N DPRB WEXIT Tag fish at 9006' Continue circulating clean, filtered 9.5 ppg NaCI brine ~ 1.8 bbm Camera set to begin taking pictures at 00:15 6/29/2008 00:00 - 00:30 0.50 FISH N DPRB WEXIT Wait on camera timer First set of shots at 0015 hrs, circulating at 0.5 bpm. Second set at 0030 hrs, pump down, well static During both sets reciprocated down to tag and then PUH 2' and attempt to get back down to fish within the 45 sec. 00:30 - 02:20 1.83 FISH N DPRB WEXIT POOH rnntea: wi;u~uussc.~i:~a rnn BP AMERICA Page 9 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release`. 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/29/2008 ~ 02:20 - 03:00 ~ 0.67 ~ FISH ~ N ~ DPRB ~ W EXIT 03:00 - 04:20 1.33 FISH N DPRB WEXIT 04:20 - 07:00 2.67 FISH N DPRB WEXIT 07:00 - 07:15 0.25 FISH N DPRB WEXIT 07:15 - 07:30 0.25 FISH N DPRB WEXIT 07:30 - 08:30 ~ 1.00 ~ FISH ~ N ~ DPRB ~ W EXIT 08:30 - 09:00 ~ 0.50 ~ FISH ~ N ~ DPRB ~ W EXIT 09:00 - 10:30 1.50 FISH N DPRB WEXIT 10:30 - 11:00 0.50 FISH N DPRB WEXIT 11:00 - 11:30 0.50 BOPSU N DPRB WEXIT 11:30 - 12:30 1.00 FISH N DPRB WEXIT 12:30 - 14:00 1.50 FISH N DPRB WEXIT 14:00 - 14:15 0.25 FISH N DPRB WEXIT Lay down camera BHA and view pictures Consult with town engineer and decide to attempt to dress top of damaged WS with crayola mill Missing collet from overshot is not visible in photos WS tray is standing off from low side of hole about 1"and appears to have been damaged by the nose of the inner mandrel of the overshot tool. MU inteq TS with orienter, 0.4 deg. motor and 2.74" crayola mill RIH with dressing BHA. Log GR tie in from 8854'. No correction. Run in hole. 12k# dn, 27k# up wt. Circ min rate. 445 psi fs at 0.36 bpm in/out. Make a series of tags: TF 30R: 9007.8'. TF 212R: 9007.8' Circulate at 2480 psi fs at 1.77 bpm in/out. Tag TOW at 9007.6' and stall. PU and tag again. 70 psi mtr work at 9007.5'. Mill ahead at 0.05' increments. 9007.55': 2560 psi / 60 psi mtr work. 0# dhwob. TF: 33.9R. 9007.60': 2582 psi / 80 psi mtr work. Ok# dhwob: TF: 31.7R. 9007.65': 2590 psi / 90 psi mtr work. 0.01 k# dhwob: TF: 35.1 R 9007.70': 2615 psi / 115 psi mtr work: 0.02k# dhwob: TF: 29.2R. Roll TF left to 340, 297 then 180 deg opposite WS tray face, 207R. 9007.75': 2585 psi / 85 psi mtr work: 0.01 k# dhwob: TF: 207R. 9008'.0': 2622 psi then stall. PU and RIH. Continue dressing WS tray. 9007.75': 2593 psi / 60 psi mtr work. 0.07k# dhwob. TF: 203.8R. 9007.82'. 2593 psi / 50 psi mtr work. 0.10k# dhwob. TF: 213.3R. 9007.87' 2582 psi / 50 psi mtr work. 0.09k# dhwob. TF: 209.6R. 9007.90'. 2604 psi / 75 psi mtr work. 0.11 k#dhwob. TF: 206.5R. 9007.93'. 2615 psi / 85 psi ntr work. 0.18k# dhwob. TF: 211.5R. Stall. Decide this is enough footage. Estimate 3" to 4" "milled footage". Don't want to overdo it. Pull out of hole. At surface. Get off well. LD Inteq BHA. Diamond crayola mill did not show any visible wear pattern. Perform weekly BOPE function test as per AOGCC regulations. All equipment functioned properly. Hold PJSM to discuss MU and configuation of BHA. MU two drill collars w/ jars & accel with unskirted hook on Inteq tools. Scribe hook backside to high side tool face. Crew change. Run in hole. Log gr tie in from 8920'. -1' correction. BP AMERICA Page 10 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: i Date From - To Hours Task Code NPT Phase Description of Operations 6/29/2008 14:15 - 15:45 1.50 FISH N DPRB WEXIT RIH to WS. 10k# dn, 27.5k# up wt. Orient hook to 90 deg left of tray face (at 30 deg RHS) to try and get hook past TOW at 9007'. PU and RIH again. Stop at 1' above previous tag and orient to 20RHS. PU. No catch. Orient to 32R. RIH. Take wt at 9009'. Make 12 attempts at TF from 35 RHS incrementing by 3-5 deg up to 57RHS. No overpulls. 15:45 - 18:30 2.75 FISH N DPRB WEXIT PU and orient 180 deg opposite tray face to 240 RHS. RIH to check tag. Took wt at 9009.3'. Orient to 30RHS. PU and get 1.4k# overpult, then back to neutral wt. Orient to 26RHS. RIH. Set down at 9007.3 (TOW). PU and orient to 285RHS. RIH. Continue to take weight now at 9007'. Unable to get down to 9009'. Orient to 240RHS to try and get deeper again. Make to 9009.15. Orient to 15RHS. 18:30 - 19:40 1.17 FISH N DPRB WEXIT Continue with fishing Staying below 9006' with the hook, spread allowable HOT "window" for tool face to +/- 20 deg. This means the orienter does not try to correct tool face until it goes 20 deg beyond set point. This allows hook to orient to slot without the orienter trying to correct TF. Stacked down to 2000 WOB and made 1.2" deeper. After three attempts at 40R, set TF at 20 R Hooked at 32R. Pulled 5k over and let jars fire. Pulled up to 15K over and may have moved up hole -4'. Increased to 18K over and pulled free. 19:40 - 22:30 2.83 FISH N DPRB WEXIT POOH, slight weight swings, <1000 #'s, coming through nipple and jewelry. 22:30 - 00:00 1.50 FISH N DPRB WEXIT Lay down fishing BHA with the whipstock! Missing collet has not been recovered. Make up milling BHA for cleanout run. 2.80" diamond parabolic mill (D331) and 2.78" diamond string reamer. 6/30/2008 00:00 - 01:55 1.92 CLEAN N DPRB WEXIT RIH with 2.80" mill and 2.78" string mill 01:55 - 06:00 4.08 CLEAN N DPRB WEXIT Milling on nipple 2.75" nipple at 8538'. 1.8 BPM ~ 2600 CTP free spin, 7000 down weight, 27000 up. Two stall at 8540', time mill at 0.1' per six minutes. 06:00 - 12:00 6.00 CLEAN N DPRB WEXIT Continue to clean out 3.5" liner. 2675 psi fs at 1.82 bpm in/out. Some stalling, at 9007' and 9013', in WS setting interval. Circ 5 bbl hi-vis sweeps to help clean hole Smooth milling untill stall at 9021' smooth again untill 9057' stalled again running at 0.3 fpm 1.75 bpm. Mill to 9090'. 12:00 - 13:45 1.75 CLEAN N DPRB WEXIT Continue to mill ahead. Numerous stalls. Having to mill at 1.0 or less per hour. Milled down to 9140 ft. 13:45 - 16:00 2.25 CLEAN N DPRB WEXIT PU to 8860 ft and log down for GR tie in at 8854 ft. +0.5 ft correction rnnzeo: aiwc~~o c:u rca rm BP AMERICA Page 11 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common WeII Name: 1D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 6/30/2008 16:00 - 16:10 0.17 CLEAN N DPRB WEXIT RIH tag bottom at 9140 ft 16:10 - 18:00 1.83 CLEAN N DPRB WEXIT Mill ahead to 9150 ft. 40 motor stalls in all with milling from DS nipple to 9150 ft. 18:00 - 20:00 2.00 CLEAN N DPRB WEXIT POOH, pumped sweep off bottom and second sweep at 4.5" X 3.5" XO 20:00 - 20:40 0.67 CLEAN N DPRB WEXIT Lay down cleanout assembly Mill guaged 2.78 go/2.77 no-go, string reamer 2.78 go / 2.77 no-go PU dummy whipstock with jars 20:40 - 22:40 2.00 WHIP N DPRB WEXIT RIH, clean run til stack out at 9155' PU clean off bottom 22:40 - 00:00 1.33 WHIP N DPRB WEXIT POOH 7/1/2008 00:00 - 01:50 1.83 WHIP N DPRB WEXIT Lay down dummy WS. PU WS and setting tools and Inteq BHA. One PIP tag installed. Test Inteq tools 01:50 - 04:30 2.67 WHIP N DPRB WEXIT RIH with EDC open, pumping at .2 BPM, 400 CTP 04:30 - 05:00 0.50 WHIP N DPRB WEXIT 8860' Tie-in, -3' correction Continue RIH 05:00 - 05:05 0.08 WHIP N DPRB WEXIT 7000 RIW, 27000 up weight. Park at 9143.7' and close EDC. Pressure up to 4400 psi. This will put top of whipstock /Top of window at 9,135 ft 05:05 - 06:20 1.25 WHIP P WEXIT POOH 06:20 - 06:35 0.25 WHIP P WEXIT PJSM while POOH on LD/PU of whipstock BHA and window milling BHA 06:35 - 07:55 1.33 WHIP P WEXIT LD whipstock running BHA and PU Windowmilling BHA 07:55 - 09:40 1.75 STWHIP P WEXIT RIH with window milling BHA. 09:40 - 09:50 0.17 STWHIP P WEXIT Log for GR tie in at 8854 ft. Subtract 3' correction. 09:50 - 13:00 3.17 STWHIP P WEXIT Tag whipstock at 9135'. 2375 psi fs at 1.6 bpm in/out. Numerous stalls getting started. Tlme mill ahead at 0.1' per six minutes. Milling depth: 9135.7'. 13:00 - 16:00 3.00 STWHIP P WEXIT Continue to mill ahead from 9135.7'. Stall at 9136.1'. PU and resume time milling. 2560 psi fs at 1.63 bpm in/out. 1.25-1.85k# dhwob Mill to 9137.6' 16:00 - 19:15 3.25 STWHIP P WEXIT Continue milling, .1' per six minutes. 2600 ctp, 1.25 WOB Milled to 9142' 19:15 - 19:55 0.67 STWHIP P WEXIT Milling formation to 9151' 19:55 - 20:35 0.67 STWHIP P WEXIT Dress window with 3 up down passes at < 1 fpm. Drift with pump down at 5 fpm. 20:35 - 22:20 1.75 STWHIP P WEXIT POOH pumping at 1.6 BPM 22:20 - 23:15 0.92 STWHIP P WEXIT Lay down milling BHA Mill and string reamer guage, 2.74" go / 2.73" no go Face of mill shows normal wear indicative of exiting the liner Prep to blow down reel 23:15 - 23:30 0.25 RIGD P PROD1 PJSM for N2 blowdown. 23:30 - 00:00 0.50 RIGD P PROD1 Blow down reel with N2 7/2/2008 00:00 - 03:00 3.00 RIGD P PROD1 Bleeding down N2 from coil Remove Inteq UOC and cut off connector Tail pipe back to coil and secure Rig down reel hard line v~„md• wt3r~noa 23129 PM BP AMERICA Page 12 of 31 Operations Summary Report 'Legal Well Name: 1D-12 Common Well Name: 1D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task i Code NPT Phase Description of Operations 7/2/2008 ~ 03:00 - 09:30 ~ 6.501 RIGD ~ P I I PROD1 I Continue with reel swap 09:30 - 12:30 3.00 I RIGU I P PROD1 12:30 - 15:00 2.50 RIGU P PROD1 15:00 - 17:20 ~ 2.33 ~ RIGU ~ P ~ ~ PROD1 17:20 - 18:30 1.17 DRILL P PROD1 18:30 - 20:30 2.00 DRILL P PROD1 20:30 - 21:10 0.67 DRILL P PROD1 21:10 - 23:00 1.83 DRILL P PROD1 23:00 - 00:00 ~ 1.00 ~ DRILL ~ P ~ ~ PROD1 7/3/2008 ~ 00:00 - 04:15 ~ 4.25 ~ DRILL ~ P PROD1 04:15 - 04:35 0.33 DRILL P PROD1 04:35 - 06:25 1.83 DRILL P PROD1 06:25 - 07:40 ~ 1.25 ~ DRILL ~ P ~ ~ PROD1 09:10 -011:10 2.00 I DRILL I P I PROD1 11:10 - 11:30 0.33 DRILL P PROD1 11:30 - 13:15 1.75 DRILL P PROD1 13:15 - 13:35 0.33 DRILL P PROD1 13:35 - 14:10 0.58 DRILL N DFAL PROD1 Remove used 2" E-CT w/ 755K tir ana replace wi unusea 19000' 2" HS110 E-CT Begin BOP testing 250/3500. AOGCC waived witnessing of BOP test. No failures Prep injector. Install internal grapple and PT. Pull CT to floor and stab Rev fill CT w/ 52 bbls of 9.5 ppg brine 1.0/1500 Pump slack back 2.90/4500, 2.67/4200 Cut off 5' of CT and found wire. Cut off a total of 98' of CT Stab back on and pump slack back Cut off 1' of CT and found wire. Cut 5' more of CT Dress end of CT and install CTC. PT 30k. MU BHI a-line head. PT at 4000 psi. Stab on with injector. PT packoff and inner reel valve to 3500 psi MU build BHA w/ 2.2 deg motor while pump slack forward over bung hole 2.1/3000 RIH while pumping through open EDC at 1 BPM Tie-in log at 8850', -13' Drilling build from 9151', 1.6 BPM 2700 FS. Start mud swap 1-2K WOB, 7000 down, 25500 up weight Drilled to 9170' and ROP reduced to .1 FPM Continue drilling with flo-pro returns to surface. 3100 FS ~ 1.6 BPM, full returns with 9.76 ECD. 2-3000 WOB 3400-3700 CTP ~ .1 -1 FPM drilled to 9180' at midnight Continue drilling build 1.6 BPM ®3250 CTP FS. 9.7 ECD with full returns ROP between 0.1 and 1.0 FPM with 2-3000 WOB Drilled to 9320', landed in 63 shale W iper to window. Hole looks good Continue drilling. Build up to planned TVD and continue turn. 1.6 BPM ~ 3250 CTP FS, 9.75 ECD, full returns ROP at 60 - 100 with 1-2000 WOB, 300-500 PSI motor work Drill from 9360' w/ 8.72 ppg mud w/ 28k LSRV while gradually incr whp to maintain overbalance on B Shale PVT 313 Note 2" reel is -19000' 1.62/1.62/3260/908 w/ no backpressure = 9.76 ECD 1.62/1.60/3420/908 w/ 150 psi induced = 10.16 ECD 1.62/1.58/3580/908 w/ 250 psi induced = 10.44 ECD 1.61/1.56/3700/908 w/ 350 psi induced = 10.72 ECD 1.57/1.53/3600/908 w/ 350 psi induced = 10.72 ECD at 9370' Drilled to 9370' which is the end of turn PVT 310 W iper to window was clean. Pull thru window. Open EDC POOH circ thru EDC 1.6/3200 following pressure schedule Pressure undeploy holding 750 psi whp w/ MPD loop LD drilling BHA. Bit had 2 nozzles plugged w/ glauconite and one chipped nose cutter Safety mtg: pressure deploy Pressure deploy lateral assy w/ 750 psi whp RIH w/ BHA #17 (1.0 deg motor) circ thru EDC 0.82/2180 following pressure schedule Park at 1218' while BHI reboots PC several times BP AMERICA Page 13 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/3/2008 14:10 - 15:15 1.08 DRILL P PROD1 Continue RIH 15:15 - 15:30 0.25 DRILL P PROD1 Log tie-in down from 8860', Corr -2.0' 15:30 - 15:55 0.42 DRILL P PROD1 Close EDC. RIH circ thru bit 0.33/1800. Set down at 9015' three times at min rate and 208 TF. Start pump at 1.0/2500/208 and ream by w/ no wt loss or MW. Red .rate, RIH thru window, clean 15:55 - 16:05 0.17 DRILL P PROD1 Log tie-in to RA pip. Found RA pip at 9141.9'. 16:05 - 16:25 0.33 DRILL P PROD1 Precautionary ream to TD tagged at 9371' was clean. Wiper back to window was clean PVT 300 16:25 - 18:00 1.58 DRILL P PROD1 Log MAD pass for resistivity data down from 9150' to TD at 0.5/1860/DTF w/ 550 psi whp to maintain 11.0 ECD at 150'/hr rate (unable to program new res tool to higher speed for this run) 18:00.- 00:00 6.00 DRILL P PROD1 Drilling lateral 3630 FS at 1.5 BPM, 350 WHP, full returns Drilling at 908 TF, 3-4000 WOB and 3988 CTP for 10-20 fph ROP Drilled to midnight depth of 9512' 7/4/2008 00:00 - 00:15 0.25 DRILL P PROD1 Continue drilling lateral 1.6 BPM ®3500 CTP FS, 350 WH, 10.77 ECD, full returns 3800-4000 CTP with 1000-3000 WOB for 10-25 ROP Drilled to 9521' 00:15 - 00:50 0.58 DRILL P PROD1 Wiper to window, clean hole 00:50 - 06:20 5.50 DRILL P PRODi Continue drilling 1.6 BPM ~ 3470 CTP FS, 350 WHP, 10.8 ECD, full returns 3700-4000 CTP with 1000-3000 WOB for 10-40 ROP Drill to 9700' PVT 325 06:20 - 06:55 0.58 DRILL P PROD1 Wiper to window was clean both directions 06:55 - 11:25 4.50 DRILL P PRODi Drill from 9700' 1.50/1.50/3460/958 w/ 100-400 psi dill, 0.5-2.5k wob w/ 350 psi induced whp to give 11.0 ECD at 90 deg at 6556' TVD in C1/C2 interface area in 110 api rock at 20-60'/hr. Turn TF down at 9740' to search for C1. Had trouble dropping angle. Drill to 9850' w/ 88 deg NBI 11:25 - 11:55 0.50 DRILL P PROD1 Wiper to window was clean 11:55 - 12:05 0.17 DRILL P PROD1 Log tie-in down from 9160' to RA tag in WS, Corr +2' 12:05 - 12:35 0.50 DRILL P PRODi Wiper to TD had setdowns at 9639' and 9772'. Ream thru each 12:35 - 16:00 3.42 DRILL P PROD1 Drill from 9351' 1.55/1.55/3520/90L w/ 200-400 psi dill, 1-2k wob w/ 350 psi induced whp to give 10.85 ECD at 87 deg at 6556' TVD and still in 120 api rock. Swapped TF to left and had trouble making hole. BHA wipers to remove DL had 5k overpulls. Drill with slow penetration rate to 9900' 16:00 - 22:18 6.30 DRILL P PROD1 Drill from 9900' 1.55/1.55/3560/120L w/ 300 psi dill, 1-2k wob w/ 350 psi induced whp to give 10.92 ECD at 87 deg at 6560' TVD and still in 120 api rock. Got bumped up to 92 deg so turn TF down to 150L. Found siderite in samples Drilled to 10000' 22:18 - 23:30 1.20 DRILL P PROD1 Wiper to window Set down at 9670', 9700, 9735, 9780, 9970 and 9985' Worked through and continue to bottom, tagged 9997' 23:30 - 00:00 0.50 DRILL P PROD1 Continue drilling, 1.53/1.55, 3600 fs, 200-300 dif pressure, 360 WHP, 11.2 ECD, 1000 WOB at 120 L, 6560 TVD, 89 inc. ROP from 5 - 25 fph. ~ ~ BP AMERICA Page 14 of 31 Operations Summary Report Legal Well Name: 1 D-12 'Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name`. REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/4/2008 23:30 - 00:00 0.50 DRILL P PRODt Some lost returns for brief periods. Begin mud swap Drilled to 10003' at midnight 7/5/2008 00:00 - 01:30 1.50 DRILL P PROD1 Continue drilling, 1.53/1.55, 3600 fs, 200-300 dif pressure, 360 WHP, 11.2 ECD, 1000 WOB at 120 L, 6560 TVD, 89 inc. ROP from 40-50 fph. ROP has picked up but still in 110-140 API range 01:30 - 03:45 2.25 DRILL P PROD1 New mud all around. 1.53/1.54, 3460 fs, 200-300 dif pressure, 400 WHP, 10.94 ECD, 1-1500 WOB at 90 L, 6565 TVD, 85 inc. ROP 50-60 fph Drilled to 10150' 03:45 - 04:30 0.75 DRILL P PROD1 Wiper to window Over pulls and motor work from 9980' up. 9915' 20K over pull and stalled motor More overpulls and motor work from 9852 to 9775' 04:30 - 06:30 2.00 I DRILL I P 06:30 - 10:15 3.751 DRILL ~ P 10:15 - 11:00 0.751 DRILL ~ P 11:00 - 11:15 0.25 DRILL P 11:15 - 12:20 1.08 DRILL P 12:20 - 13:00 0.671 DRILL ~ P 13:00 - 14:20 1.33 DRILL P 14:20 - 16:30 2.17 DRILL P 16:30 - 16:45 0.25 STWHIP P 16:45 - 19:00 2.25 STWHIP P PROD1 PROD1 PRODi PROD1 PROD1 PROD1 PROD1 PRODi PROD1 PRODi RIH on wiper trip, tagging up at 9850, 9880, 9925, 10001, 10035'. Work through these and get to bottom Seem to be packing off above tool, ECD between 11.2 and 12 at 450 WHP and 1.5 BPM. PUH backreeming to 9800' and get hole fairly clean. Are now at 6570' TVD hardline. Point TF up and plan to go to 100 deg to crosscut to determine where we are Drill from 10150' 1.53/1.53/3500/30L w/ 200-400 psi dill, 0.8-1.5k wob w/ 425 psi induced whp to give 11.25 ECD. Build angle to 100 deg by 10240'. Drilling w/ negative wt. Drill to 10250' Wiper to window to check wellbore stability. Had several 5-10k overpulls w/ MW from 9850-9720', otherwise hole was clean. Maintain 11.0 ECD thru-out Log tie-in down from 9160', corr +5.0' Wiper back in hole was clean to set down at TF change at 9850'. Continue RIH and slow to 20'/min. Set downs started at 10038'. Work to 10126' while having 5k overpulls w/ MW and packing off while losing ground back to 10080'. Work back to 10130', but are now having 10-18k overpulls and more packing off (1/2 returns) Call uncle (Dan V) and will sidetrack Wiper to window with 5-15k overpulls and high MW to 9740'. Rest of hole was clean. Pull thru window, clean. Open EDC POOH circ thru EDC 1.91/3600 'Pressure undeploy using 750 psi on MPD loop LD BHA. Bit had no wear and was BU w/ glauconite Safety mtg re: deploy MU BTT anchored aluminum OH WS assy. Pressure deploy w/ 750 psi RIH with EDC open, follow tripping schedule 8950 Weight check, 21000 up, 5700 down Tagging up at 8997', work pipe and orienter to try to get past Will go up to 5000 max WOB, Made it to 9004.4 with 2500 WOB, clean PU 19:00 - 21:15 2.25 STWHIP P PROD1 21:15 - 22:40 1.42 STWHIP N DPRB PROD1 rnncea: a r~evua ca rca rm a • BP AMERICA Page 15 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21 /2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 21:15 - 22:40 1.42 STWHIP N DPRB PROD1 9020', 3000 WOB, attempt to orient, nothing but reactive torque, clean PU 9023' with 908 set down 2300 WOB, 2000 overpull but a faster PU 9024.7 with 108, 2300. WOB 9026', OR, 2400 WOB, 1500 overpull 9026.5' 5R 4000 WOB, 1500 overpull 22:40 - 00:00 1..33 STWHIP N DPRB PROD1 POOH, pumping down backside, EDC still open, still following tripping pressure schedule 7/6/2008 00:00 - 00:45 0.75 STWHIP N DPRB PROD1 POOH with aluminum billet after unsuccessful run. 00:45 - 01:00 0.25 STWHIP N DPRB PROD1 PJSM for undeployment 01:00 - 05:00 4.00 STWHIP N DPRB PROD1 Pressure undeploy aluminum billet BHA. LD WS assy. Shale and clay were packed on anchor Lay down Inteq tools and change out LOC due to damaged PU and deploy cleanout BHS with 1 deg motor and used bicenter bit 05:00 - 06:35 1.58 STWHIP N DPRB PROD1 RIH following pressure schedule 06:35 - 06:55 0.33 STWHIP N DPRB PROD1 Log tie-in down at 8865', corr -6' 06:55 - 08:00 1.08 STWHIP N DPRB PROD1 RIH circ thru bit at min rate and set down at 9020'. Incr rate to 1.21/2725/208 and stall. Incr rate to 1.55/3330/HS and ream thru fill from 9020' at 2'/min and find about 10' of packed solids. Ream w/o MW to 9110'. Red rate to min. RIH and set down at 9126' several times. Wash thru at 1.0/2500 w/ 100 psi MW. Red rate to min thru window 08:00 - 10:50 2.83 STWHIP N DPRB PROD1 Wiper to 9400' 1.42/3140 at 20'/min was clean both ways. Pull thru window. Backream from window to 8400' 1.56/3550 w/ LS TF using 30 bbl to-vis pill. RBIH at min rate to window. Backream from window to 8400' 1.56/3680 w/ LS TF using 25 bbl hi-vis pill. RBIH and thru window, clean. Wiper to 9400' and back to window was clean. Pull thru window to 9110', clean and open EDC. RBIH thru window circ thru EDC 1.7/3570 to EDC depth of 50' below window while 25 bbl hi-vis pill exited nozzle. POOH thru window while fin displ hi-vis pill Noted -0.3 bpm losses each time while jetting over 9020-9067 and lost a total of -25 bbls of mud 10:50 - 12:30 1.67 STWHIP N DPRB PROD1 POOH circ thru EDC1.95/3600 following pressure schedule 12:30 - 15:50 3.33 STWHIP N DPRB PROD1 Pressure undeploy w/ 750 psi whp using MPD loop. LD drilling BHA. Bit had no additional wear and was 'green' (glauconite) MU anchor billet assy . Pressure deploy w/ 750 psi using MPD loop 15:50 - 17:35 1.75 STWHIP N DPRB PROD1 RIH w/ BHA #20 circ thru EDC 17:35 - 18:00 0.42 STWHIP N DPRB PROD1 Log tie-in down to GR marker at 8854' 18:00 - 19:05 1.08 STWHIP N DPRB PROD1 7000 RIW, 20000 up wt, 740 WHP, 11.05 ECD Tagged up at 8993' with 25L TF, 2000 WOB 908 tag at 8996.5, 2800 WOB, 2000 overpull 1808 tag at 8996.4, 2600 WOB, 2000 overpull 90L tag 8996.7, 3300 WOB, 458, tag at 8996, 3300 WOB, 2000 overpull 19:05 - 19:45 0.67 STWHIP N DPRB PROD1 Shut in returns, close EDC and pressure up well bore 900 WHP, .3 BPM in and out, tag at 8996.6' with 3200 WOB, PUH rnniea: aisizwo z:a rca rm BP AMERICA Operations Summary Report Page 16 of 31 Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date ~ From - To Hours Task Code NPT Phase Description of Operations 19:05 - 19:45 I 0.671 STWHIPI N I DPRB PROD1 19:45 - 21:30 1.75 STWHIP N DPRB PROD1 21:30 - 21:45 0.25 STWHIP N DPRB PROD1 21:45 - 00:00 2.25 STWHIP N DPRB PRODi 7/7/2008 00:00 - 00:30 0.50 STWHIP N DPRB PROD1 00:30 - 01:50 1.33 STWHIP N DPRB PROD1 01:50 - 03:45 1.92 STWHIP N DPRB PROD1 03:45 - 06:10 2.42 STWHIP N DPRB PROD1 06:10-07:45 ~ 1.58~STWHIP~N DPRB ~PROD1 07:45 - 11:30 ~ 3.75 ~ STWHIP~ N ~ DPRB ~ PROD1 11:30 - 13:15 1.75 STWHIP N DPRB PROD1 13:15 - 13:35 0.33 STWHIP N DPRB PROD1 13:35 - 14:10 0.58 STWHIP N DPRB PROD1 14:10-14:30 ~ 0.33~STWHIP~P ~ ~PROD1 14:30 - 16:00 1.50 STWHIP P PROD1 16:00 - 17:15 1.25 STWHIP P PROD1 17:15 - 19:00 1.75 STWHIP P PROD1 19:00 - 20:50 1.83 STWHIP P PROD1 20:50 - 21:00 0.17 STWHIP P PROD1 21:00 - 00:00 3.00 STWHIP P PROD1 1300 WHP, 12.3 ECD, 8996.6' 3300 WOB, PUH 1500 WHP, 12.6 ECD, 8997.2', 4800 WOB, 2000 overpull No fluid losses during this operation POOH following normal tripping pressure schedule PJSM for pressure undeploy/deploy Undeploy billet PJSM for pressure deploy Pressure deploy clean out BHA with straight motor, 2.78" parabollic mill and 2.78" string reemer RIH circulating down coil Tagged at 9003' uncorrected depth. Bring pump rate up to 1.6 and mill down to 9006'with 300 PSI motor work and 500 WOB. Continue to 9020 with no MW and no WOB. PUH to 8980' and run back in to 9020' looks clean, continue RIH at 1.8 BPM, 3800 CTP, 550 WHP, 11.1 ECD. stopped at 9135' (2.78" mill) and recip between 9135 and 8990' while pumping sweeps, 20 Bbls. ea low-vis, high, spacer, low,high. Losing .1 to .25 bpm while reciping between 9016' and 9135' Chase OOH, stop at 8550 and open EDC POOH circ thru EDC 2.13/4100. Sweeps recovered more fine black shale and mudstone w/minor glauconite and very little sand Pressure undeploy w/ 750 psi whp using MPD loop. LD milling cleanout BHA MU same aluminum billet assy w/ anchor on MWD assy. Pressure deploy w/ 750 psi. IA =735 psi RIH w/ BHA #22 circ thru EDC 0.21/1480 following pressure schedule. IA maxed out at 880 psi Log tie-in from 8870', corr -7.0', 19.8k up wt. Close EDC. IA=805 RIH w/o pump and see slight wt loss in liner below 9030', but made it thru the window w/o needing to PU. Set down at 9170' w/ 5k. Clean PU's. Work to 9182' w/ 7k down wt. Pressure wellbore to 1050 psi -11.4 ECD while RIH to set depth of 9351'. IA got as high as 1000 psi Orient anchor to 20L, pressure up on CT to 3950 psi where tool stroked. Stack 3k. POOH w/ setting tool circ thru tool in OH at 0.54/2070 Left top of billet at 9340' IA=900 POOH circ thru setting tool 1.21/3080 following pressure schedule Pressure undeploy w/ 750 psi using MPD loop. IA=780 Load out BTT setting tool. BHI reconfigure MWD assy. MU HCC STR324 bit on 1.5 deg motor Pressure deploy sidetrack BHA. Total of 10 Bbls. lost during BHA swap RIH with sidetrack BHA Tie in from 8850' down, -7' correction Lost 8 Bbls. while RIH Tag billet at 9341' PUH and run in to 9339' Start time drilling, 1.6 bpm, 3350 CTP, 500 WHP, 10.95 ECD 1/10' per 5 min. Getting -100 psi motor work that drills off BP AMERICA Page 17 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 .Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/7/2008 21:00 - 00:00 3.00 STWHIP P PRODi before next tenth. Drilled to 9342' at midnight with lots of aluminum to the shaker 7/8/2008 00:00 - 02:00 2.00 STWHIP P PROD1 Continue drilling off aluminum billet 1.6 BPM, 3350 CTP, 500 WHP, 10.98 ECD Increase ROP to 3 FPH 02:00 - 02:30 0.50 STWHIP P PROD1 Continue drilling to 9360' at 10-15 FPH 02:30 - 03:40 1.17 STWHIP P PROD1 Back ream past billet three passes drift by billet with pump down Sidetrack looks clean 03:40 - 06:00 2.33 STWHIP P PROD1 POOH following pressure schedule 06:00 - 06:20 0.33 STWHIP P PROD1 Safety mtg: crew change/undeploy 06:20 - 08:00 1.67 STWHIP P PROD1 Pressure undeploy w/ 750 psi using MPD loop. LD sidetrack assy 08:00 - 08:30 0.50 DRILL P PROD1 Safety mtg: pressure deploy lateral assy Function test BOP rams as part of bi weekly BOPE test 08:30 - 10:00 1.50 DRILL P PRODi Pressure deploy lateral drilling assy w/ 750 psi on MPD loop 10:00 - 11:30 1.50 DRILL P PROD1 RIH w/ BHA #24 (1.0 deg motor w/ RR HYC bi bit) circ thru bit at min rate 11:30 - 11:45 0.25 DRILL P PROD1 Log tie-in down from 8870', Corr -7.0' 11:45 - 12:00 0.25 DRILL P PROD1 Swap to fresh mud while wiper to billet, clean 12:00 - 12:45 0.75 DRILL P PROD1 Red rate to 1.0/2700/158 and pass by billet, clean. Tag TD at 9360'. Backream/ream in three passes at 1.43/3250 at 20 deg each side of DTF w/minor MW up to 9320' 12:45 - 13:45 1.00 DRILL P PROD1 With fresh mud at bit, drill from 9360' 1.55/1.47/3410/1008 w/ 200-400 psi dill, 1.0-2.Ok wob w/ 500 psi induced whp or 10.92 ECD at 40'/hr. Inc built quicker than expected to 100 deg. Drill at 1208 TF to 9400' 13:45 - 13:55 0.17 DRILL P PROD1 Wiper to 9300' and past billet both directions 1.54/3380/DTF at 15'/min was clean. Fresh mud back to surface 13:55 - 17:35 3.67 DRILL P PROD1 Drill from 9400' 1.55/1.55/3380/1308 w/ 100-400 psi dill, 1.0-2.Ok wob w! 525 psi induced whp to give 10.90 ECD while dropping angle from 96 deg to meet targets on Plan 7. 17:35 - 21:30 3.92 DRILL P PRODi 0.15bpm losses after crossing 9460ft. Increase rate & drop WHP. Drilling lateral TF at 70-90 R Op = 1.75 / 1.60 bpm OBP = 4050 psi Density = 8.64 / 8.67 ppg BHP /EDC /WHP 3695 psi / 10.88 ppg and 500 psi 21:30 - 21:58 0.47 DRILL P PROD1 Wiper trip to base of billet at 9,360 ft. 21:58 - 22:26 0.47 DRILL P PROD1 Talking to Town Geologist about present GR and resistivity logs values. Work CT while waiting on Geologist. Added 100 bbl of Flo-Pro to active system. 22:26 - 00:00 1.57 DRILL P PROD1 Drilling lateral TF at 40 R Qp = 1.66 / 1.54" bpm; OBP = 3500 psi Density = 8.64 / 8.67 ppg BHP /EDC /WHP 3707 psi / 10.92 ppg and 500 psi Build up to 93 deg and drill to 6,530 ft TVD GR at 120 API Units Vp = 320 bbl's 7/9/2008 00:00 - 01:37 1.62 DRILL P PROD1 Drilling lateral and looking for the C1 Sand Stacking problems 01:37 - 03:50 2.22 DRILL P PROD1 Wiper trip to clean up possible cutting beds and tie in Printed: 8/13/2008 2:31:29 PM BP AMERICA Page 18 of 31 Operations Summary Report Legal Well Name: 1 D-12 .Common Well Name: 1 D-12 Spud Date: 6/21/2008 'Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Riq Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/9/2008 01:37 - 03:50 2.22 DRILL P PROD1 Open EDC at 9,115 ft Inc Op to 2.15 bpm, CTP 4100 psi Lossing 0.1 bpm to perfs PUH to 8300 ft at 2.1 bpm and RIH at 50 fpm and 2.17 bpm. Corrected +3 ft. RIH to 9,120 ft 03:50 - 10:25 6.58 DRILL P PROD1 Drilling lateral TF at 9R Acts like we drilled into a brick wall. ROP slowed to nothing Working to get it back to drilling Op = 1.66 / 1.54 bpm; OBP = 3500 psi Density = 8.64 / 8.67 ppg BHP /EDC /WHP 3707 psi / 10.92 ppg and 500 psi Vp = 272 bbl's Pump 40bb1 low vis sweep. Pump 20bb1 hi-vis sweep. Drill to 9839ft. 10:25 - 11:00 0.58 DRILL P PROD1 Slowly PUH to 9400ft & chase hi-vis pill up hole. Clean PU off bottom. Lo vis pill bottom's up was boring. RIH. Hi vis pill bottom's up was boring too. 11:00 - 12:25 1.42 DRILL P PROD1 Drill ahead from 9839ft, 90-120L. Op = 1.66 / 1.58 bpm; OBP = 3800 psi Density = 8.64 / 8.67 ppg BHP /EDC /WHP 3717 psi / 10.97 ppg and 450 psi Vp = 290 bbl's Drill to 9900ft. 12:25 - 13:25 1.00 DRILL P PROD1 Wiper to the window was clean. Wiper to TD was clean. 13:25 - 18:38 5.22 DRILL P PROD1 Drill ahead from 9900ft, 70-120L. Op = 1.61 / 1.50 bpm; OBP = 3800 psi Density = 8.68 / 8.75 ppg BHP /EDC /WHP 3742 psi / 11.03 ppg and 450 psi Vp = 324 bbl's 18:38 - 21:00 2.37 DRILL P PROD1 Wiper trip to clean up and tie in PUH to 8300 ft with EDC open and circulating at 2.13 bpm. Tied in and corrected +3 ft RIH to 9120 ft close EDC and RIH past the WS with correct TFTagged bottom at 10050 ft PU wt at 24 k. OBP = 3,650 psi 1.66 bpm 21:00 - 00:00 3.00 DRILL P PROD1 Drilling IateralTF at 75R Target at 10,300 ft MD with a NDss at 6,545 ft (5 ft lower than previous) Op = 1.64 / 1.62 bpm obp = 3,650 psi BHP /EDC /WHP = 3,698 psi / 10.89 ppg / 355 psi Vp = 318 bbls WOB = 1.4 klb and ROP at 20-50 fph 7/10/2008 00:00 - 00:53 0.88 DRILL P PROD1 Drilling lateral 00:53 - 02:22 1.48 DRILL P PROD1 Wiper trip to base of billet. While RIH, at 10034 ft (TF hange Left to R) tagged up twice, used low Op and correct TF to get past 02:22 - 05:45 3.38 DRILL P PROD1 Drilling lateral TF at 90L Op = 1.60 / 1.59 bpm obp = 3,650 psi BHP /EDC /WHP = 3,698 psi / 10.89 ppg / 355 psi Vp = 305 bbls WOB = 1-2 klb and ROP at 20-70 fph GR at 80 PI Units 05:45 - 07:25 1.67 DRILL P PROD1 Wiper to base of billet at 9,360 ft -clean. Wiper to TD -clean. 07:25 - 13:45 6.33 DRILL P PROD1 Drilling lateral TF at 90L Op = 1.60 / 1.59 bpm obp = 3,650 psi BHP /EDC /WHP = 3,761 psi / 11.14 ppg / 350 psi Vp = 284 bbls WOB = 1-2 klb and ROP at 20-70 fph GR at 120 API Units 13:45 - 14:20 0.58 DRILL P PROD1 400ft wiper trip -clean both ways. Start conducting mud swap. rnncea: aisiewa cs rcy rm BP AMERICA Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task Code NPT 17/10/2008 114:20 - 15:20 1.00 I DRILL I P 15:20 - 19:15 I 3.92 ~ DRILL I P 19:15 - 21:00 1.75 DRILL P 21:00 - 23:35 2.58 DRILL P 23:35 - 00:00 0.42 DRILL P 7/11/2008 00:00 - 01:20 1.33 DRILL P 01:20 - 01:35 0.25 DRILL P Start: 6/21 /2008 Rig Release: 7/24/2008 Rig Number: Page 19 of 31 Spud Date: 6/21 /2008 End: 7/24/2008 Phase Description of Operations PRODi PRODi PROD1 PROD1 PROD1 PROD1 PROD1 01:35 - 01:55 0.33 DRILL N SFAL PROD1 01:55 - 02:10 0.25 DRILL N SFAL PROD1 02:10 - 03:15 1.08 DRILL P PROD1 03`15 - 04:55 ~ 1.67 ~ DRILL ~ P ~ ~ PROD1 04:55 - 06:45 1.83 DRILL P PROD1 06:45 - 10:50 4.08 DRILL P PRODi 10:50 - 15:10 4.33 DRILL P I PROD1 15:10 - 15:15 0.08 DRILL P PROD1 15:15 - 16:25 1.17 DRILL P PROD1 17:20 - 18:45 I 01.42 DRILL P I PROD1 PROD1 29:23 - 29:45 0.37 DRILL I P I PRODi Drilling lateral TF at 90L Op = 1.60 / 1.59 bpm obp = 3,650 psi BHP /EDC /WHP = 3,700 psi / 10.89 ppg /350 psi Vp = 114 bbls WOB = 1-2 klb and ROP at 5-15 fph GR at 70 API Units No change in ROP with new mud. Wiper trip to 8100ft for safety stand down. Pull past the whipstock & open EDC. Pump 2.1 bpm / 4000psi & slowly PUH to jet 3-1/2" & 4-1/2" tubing. Safety Stand down with CPAI at the SRT Training Room at KOC.Subject covered. Present increase in incidient in the CPAI asset area. Left rig with two people to finish PUH and circulate wellbore clean. POOH and conducted TL meeting with rig crew. Pressure undeploy BHA as per procedure Change out Bit and PU agitator. Pressure deploy BHA Set counters and RIH RIH Tie in at 8860 ft Corrected +18 ft Found the packoff is leaking, needs changed out PJSM on changing out stripper rubber Close annular and check integrity OK: Change stripper element RIH Set down at 10,030 ft. PU and red Op to 0.4 bpm trapped 750 psi on well and RIH 'Drill lateral L1 with 90R to 50L TF Op = 1.5 / 1.47 bpm at 3850 psi Density = 8.65 / 8.50 ppg CTW above Olbf neutral datam line.(43000 Ibf) BHP /ECD /WHP = 3704 psi / 10.91 ppg / 406 psi Vp = 244 bbl CROP at 80 -100 fph starting. Slowed down at 10,575 ft Wiper trip to 9360 ft Drill lateral L1 with 90R to 50L TF Op = 1.64 / 1.63 bpm at 4240 psi Density = 8.68 / 8.60 ppg CTW 2600 Ib BHP/ECD/WHP=3730 psi/10.96 ppg/425 psi Vp = 233 bbl ROP at 10 -50 fph Drill to 10,710ft. Mad pass up from TD to the RA pip tag in the whipstock. Log down RA tag for tie-in (+5.5ft corr. Wiper to TD. Pump 150k LSRV liner pill with 2 ppb Alpine beads while RIH. Tag TD at 10715ft. Wiper to window laying 150k LSRV liner pill with 2 ppb Alpine beads keeping ECD's at 11 ppg. Stop pumping & pull through window. PUH to 8400ft & reciprocate back & forth while pumping to help clean up the tubing. Pumping 10.8 ppg KWF down CT POOH laying in 10.8 ppg KWF OOH, PJSM on LD drilling BHA and monitoring well after rnmeu: wiacwo c.u ~.ca rm BP AMERICA Page 20 of 31 Operations Summary Report Legal Well Name: 1 D-12 .Common Well Name: 1 D-12 Event Name: REENTER+COMPLETE 'Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date From - To Hours Task Code NPT Spud Date: 6/21/2008 Start: 6/21 /2008 End: 7/24/2008 Rig Release: 7/24/2008 Rig Number: Phase. Description of Operations 7/11/2008 21:23 - 21:45 0.37 DRILL P PROD1 21:45 - 22:45 1.00 DRILL P PROD1 22:45 - 23:15 0.50 CASE P LNR1 23:15 - 00:00 0.75 CASE P LNR1 7/12/2008 00:00 - 02:30 2.50 CASE P LNR1 02:30 - 03:43 1.22 CASE P LNR1 03:43 - 04:00 0.28 CASE P LNR1 04:00 - 04:40 0.67 CASE P LNR1 04:40 - 04:50 0.17 CASE P LNR1 04:50 - 06:30 I 1.671 CASE P I I LNR1 06:30 - 07:00 0.501 CASE I P LNRi 07:00 - 09:10 I 2.171 STWHIPI P PROD2 09:10 - 14:00 4.831 STWHIPI P I I PROD2 14:00 - 15:00 1.00 STWHIPI P I I PROD2 15:00 - 18:47 3.78 STWHIP N HMAN PROD2 18:47 - 21:25 2.63 STWHIP P PROD2 21:25 - 21:40 0.25 STWHIP P PROD2 21:40 - 22:25 0.75 STWHIP P PROD2 22:25 - 00:00 1.58 STWHIP N DFAL PROD2 7/13/2008 00:00 - 00:30 0.50 STWHIP N DFAL PROD2 00:30 - 01:30 1.00 STWHIP N DFAL PROD2 01:30 - 03:35 2.08 STWHIP N DFAL PROD2 03:35 - 04:04 0.48 STWHIP N DFAL PROD2 04:04 - 04:30 0.43 STWHIP N DFAL PROD2 04:30 - 04:45 0.25 STWHIP N DFAL PROD2 04:45 - 07:00 2.25 STWHIP N DFAL PROD2 07:00 - 08:00 1.00 STWHIP N DFAL PROD2 loading up with 10,8ppg KWF LD drilling BHA RU to run liner Pick up 2-3/8" Solid /Slotted Liner Finish PU liner as per Summary sheet. PU CTLRT and CoilTrac BHA. set counters to 1605 ft RIH with Liner Wt check at 9100 ft = 21.5k1bf RIH and set down at 10017 ft. Working past Working to get past 10,015 ft uncorrected RIH with liner and tagged at 10,715 ft. Released from liner. Lost 9,000 Ib string wt Top of Liner at 9,133 ft Bottom Liner at 10,695 ft POOH with liner running tools. PJSM regarding handling liner BHA while POH. Tag up. Flow check - no flow. Pop off & check for liner -gone. Blow down tools & LD on catwalk. PJSM regarding slip & cut drill line. Slip & cut drill line. Fil hole every hour - 3-1/2bbls/hr losses. PJSM regarding pumping slack & cutting coil.. Break off Baker UOC. Heat shrink end of wire. Stab onto well. Reverse circulate slack into reel. Cut 1000ft of coil. Install CTC -pull test to 40k & rehead BHI. Pressure test to 4000psi. PJSM regarding handling BHA. MU tail pipe & packer assembly to coil track tools. Scribe same. Stab onto well. Power up & test tools. Set counters. Pop off well. Send R nipple to get machined - OD too large. Installed BHA and RIH with WS tail pipe to 8,870 ft Log tie in at 8,867 ft down at 150 fpm Corrected +2.5 ft RIH to 9,100 ft and conducted wt check 20k up RIH and set the bottom of the mule shoe at 9,127.67 ft and set the MOE of the WS packer at 9,110 ft .Orientation of snap latch at 180 deg. Pressure up on the CT to set the packer 1,100 psi sheared. Set down and looks like the packer slide down hole 3 ft. Seen 1.9k at BHI tools and then fell off to 1.3klbf. then fell off to 0.6k Ibf PUH to 9,127 ft and conversed with BOT in Deadhorse. POOH Finished POOH with packer running tool LD running tools. Removed orienter, PU 2-1/2" GS with gars, FVS, Blid sub DGS,DPS and the rest of coiltrac. RIH with 2-1/2" GS Logged tie in and corrected +7.5 ft Tagged up at 9,089 ft with 30001b weight and 100 psi increase in pump pressure. PU and seen 10k over and packer seen to shear released. PU hole drag was seen as high as 9k over. RIH and stopped at 9,110 ft no set down PUH with 500 Ib extra wt. Not much drag seen at 8938 ft and 8491ft. RIH to tie-in at 8850 ft Logged tie-in. Corrected +2 ft RIH to double check things Didn't tag until 9121 ft which puts the mule. shoe at 9141 ft (BOW) PUH POOH. PJSM while POH. Flow check well. Pop off well. LD KB packer & send to Baker Pflflt2tl: tl/l:i/ZOOt3 Z:31:'Ly PM BP AMERICA Page 21 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End:. 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase 7/13/2008 07:00 - 08:00 1.00 STWHIP N DFAL PROD2 08:00 - 11:15 3.25 STWHIP N DFAL PROD2 11:15 - 12:55 1.67 STWHIP N DFAL PROD2 12:55 - 14:25 1.50 STWHIP N DFAL PROD2 14:25 - 17:40 3.25 STWHIP N DFAL PROD2 17:40 - 19:30 1.83 STWHIP P PROD2 19:30 - 21:12 1.70 STWHIP P PROD2 21:12 - 00:00 2.80 STWHIP P PROD2 7/14/2008 00:00 - 00:15 0.25 STWHIP P PROD2 00:15 - 00:35 0.33 STWHIP P PROD2 00:35 - 02:30 1.92 STWHIP P PROD2 02:30 - 04:05 1.58 STWHIP N DFAL PROD2 04:05 - 06:45 2.67 STWHIP N DFAL PROD2 06:45 - 08:20 1.58 STWHIP N DFAL PROD2 08:20 - 09:30 1.17 STWHIP P PROD2 09:30 - 11:15 1.75 STWHIP P PROD2 11:15 - 11:25 0.17 STWHIP P PROD2 11:25 - 19:00 7.58 STWHIP P PROD2 19:00 - 20:26 1.43 STWHIP P PROD2 20:26 - 22:20 1.90 STWHIP P PROD2 22:20 - 00:00 1.67 STWHIP P PROD2 Description of Operations shop to be rebuilt, slip were wom & appears not to have released all the way. MU 2.78" parabolic mill & 2.78" string reamer clean out BHA. RIH with mill BHA. Log down for tie in (+3ft corr. Start pumping 15bbls hi-vis pill. Attempt to dry tag, didn't tag but stopped RIH at 9136ft & didn't go any deeper. PU, pump 1.6bpm/3400psi & clean up area. Pump 30bbls more in sweeps. Open EDC. POH pumping through the EDC. PJSM while POH. Flow check well. Pop off well. Blow down BHA w/ air & water. Break off motor & mill, LD same. Add in HOT & reconfigure coil trak tools, test same. Hoist KB packer to RF. Make scribe line. MU tail pipe to KB packer. MU coil track tools to KB packer, scribe same. Stab onto well. Power up & test tools. set counters. RIH with KB packer, again. Log down for tie-in at 8854ft (-ift corr. WT ck ~ 9100ft, 21.8k. RIH to 9130ft. PU to to place EOP at 9127.6ft. Orientate to HS. Pump down coil & set KB packer at 1300psi, set 4.3k down. Middle element in KB packer is at 9110ft. POH. PJSM LD WS packer setting BHA. PIP tag is installed in whipstock. PU and scrib WS and Stab on well RIH Log tie in at 8850 ftCorrected -2 ft RIH with HS TF. Set WS with jars and sheared off. POOH LD coiltrac BHA and found the WS was on the bottom. Didn't set as thought. PU 2 2-3/8" DC and checked tool (OK) PU coiltrac and scribed to HS. RIH. Log down for tie-in (+0.5ft). Orientate tray. Jar down three times. Appears to have set. Top of whipstock is at 9100ft. POH. PJSM while POH regarding handling BHA. Pop off. LD BHI tools & BHA. Whipstock tray is gone. Setting tool is packed with debris, brass bolt has sheared with no marks on welded no-go lug & no marks on snout of setting tool. MU window mill BHA with drill collars. Stab onto well. Power up & test tools. Set counters. Open EDC. Reboot SLB computer, again. RIH with mill BHA. Begin swapping coil to 9.8ppg flo-pro while RIH. Log down for tie-in (-aft corr. 9.8ppg flo-pro at the bit. Close EDC. RIH & dry tag billet at 9100ft!!! Pump 1.6bpm/3190psi. Swap hole over to 9.Sppg & slowly creep in hole 0.1ft every 2 min. Initial motor work at 9099.2ft. Time mill 0.1ft every 6 min. Pump 2-15bb1 hi-vis sweeps. Drill formation from 9103.5ft to 9112ft. Drilling formation from 9103.7 ft to 9112.00 ft Window from 9099.3 ft to 9103.7 ft Reamed window clean and dry tagged at 9112 ft 9clean). PUH and flow checked at 9092 ft. OK Open EDC and inc Op to 2.2 bpm POOH Monitor well. LD milling BHA Closed both SV's n--.-.,. oi~nnnna n~~11.70 D/.A • BP AMERICA Page 22 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/14/2008 22:20 - 00:00 1.67 STWHIP P PROD2 Mills at 2.74 Go and 2.73 No Go Jetted BOP stack 7/15/2008 00:00 - 01:55 1.92 BOPSU N SFAL PROD2 Open BOP doors and cleaned out material. broke the choke line and kill in prep of lifting the rig. 01:55 - 02:10 0.25 BOPSU N SFAL PROD2 PJSM on lifting the rig. The rig is presently > 1ft off the well towards the driller side 02:10 - 03:15 1.08 BOPSU N SFAL PROD2 Level rig and it ain't easy 03:15 - 05:00 1.75 BOPSU N SFAL PROD2 NU choke line, secure BOP stack and take on drilling and millling fluid. Conducted shell test 05:00 - 12:00 7.00 BOPSU P PROD2 Conduct BOP test at 250 / 3500 psi per AOGCC regs -PASS. Jeff Jones w/ AOGCC wavered wittnessing the BOP test 12:00 - 12:30 0.50 DRILL P PROD2 Open well - no pressure. Fill hole - 2 bbls. Flow check - no flow. PU injector. Install check valves in UOC. PU 2.45 degree AKO motor & HCC bicenter-bit. Reciprocate BHA across BOP's with no hang up's (will not have to kill well). Stab onto well. Power up & test tools. Set counters. 12:30 - 14:05 1.58 DRILL P PROD2 RIH while swapping coil to 8.6ppg flo-pro. 14:05 - 14:25 0.33 DRILL P PROD2 Log down for tie-in (-10.5ft corr. 14:25 - 18:05 3.67 DRILL P PROD2 RIH. Slight bobble at 9108ft. Tag bottom at 9113ft. Drill L2 Build Op = 1.61/ 1.56 bpm at 3300 psi (still swapping to 8.6ppg) Density = 8.92 / 9.88 ppg BHP /ECD / WHP = 3530 psi / 10.50 ppg / 45 psi (will maintain 9.8ppg ECD) Vp = 247 bbl ROP at 10 -30 fph 18:05 - 19:30 1.42 DRILL P PROD2 POOH with build section BHA 19:30 - 19:50 0.33 DRILL P PROD2 PJSM on Pressure undeploy procedure and LD of build section BHA. 19:50 - 21:35 1.75 DRILL P PROD2 Pressure undeploy and LD build section BHA. 21:35 - 21:45 0.17 DRILL P PROD2 PJSM on PU and Pressure deployment of lateral BHA 21:45 - 23:00 1.25 DRILL P PROD2 PU and pressure deploy latteral section BHA with 1.0 AKO and used Smith 2.7 x 3.0 Bicenter bit. 23:00 - 00:00 1.00 DRILL P PROD2 RIH following pressure schedule. 7/16/2008 00:00 - 00:50 0.83 DRILL PROD2 RIH 00:50 - 01:05 0.25 DRILL PROD2 log for GR tie in from 8870' to 8910' - 9 ft correction. 01:05 - 01:10 0.08 DRILL P PROD2 continue RIH 01:10 - 01:35 0.42 DRILL P PROD2 MAD pass from 9,120 ft to 9,191 ft cp = 2200 psi ~ 1.1 bpm in and 1.14 bpm out density = 8.91 / 8.95 ppg in/out EDC closed 01:35 - 05:05 3.50 DRILL P PROD2 Drill ahead from 9,191 ft Drilling ~ 9,215 ft CP=3430 psi in/out= 1.65/1.65 bpm density=8.89/8.97 ppg Annular press=3354psi / 9.88 ECD 45 left TF DH W06=1340#'s CT WT=7180#'s ROP=56 FPH PVT=266 bbls loaded additional 100 bbls FloPro while drilling. rnntea: wisizuun c.~rzarm BP AMERICA Page 23 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21 /2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/16/2008 ~ 01:35 - 05:05 ~ 3.50 ~ DRILL ~ P ~ ~ PROD2 05:05 - 05:35 0.50 DRILL P PROD2 05:35 - 09:15 3.67 DRILL P PROD2 09:15 - 10:00 ~ 0.75 ~ DRILL ~ P ~ ~ PROD2 10:00 - 12:30 ~ 2.50 ~ DRILL ~ P ~ ~ PROD2 12:30 - 14:30 ~ 2.00 ~ DRILL ~ P ~ ~ PROD2 14:30 - 14:45 0.25 DRILL P PROD2 14:45 - 15:00 0.25 DRILL P PROD2 15:00 - 15:30 0.50 DRILL P PROD2 15:30 - 18:10 2.67 DRILL P PROD2 18:10 - 21:20 ~ 3.17 ~ DRILL ~ N I RREP ~ PROD2 21:20 - 21:35 ~ 0.25 ~ DRILL ~ N ~ RREP ~ PROD2 22:20 - 00:00 0.671 DRILL P RREP 1 PROD2 7/2008 ~ 00:00 - 01:20 ~ 1.33 ~ DRILL PROD2 New PVT=376bb1s. Stall at 9,346' slower drilling had started at about 9320' Drill from 9190 ft to 9350 ft. Wiper trip to window. Drill ahead from 9,350 ft to 9500'. 3267 psi fs at 1.61 bpm in/out. Hold SIMOPS mtg with CPF-1 well test crew on 1 D-112. Exchanged contact and contingency information. Make wiper trip to window. Maintain as drilled TF. Hole smooth. Drill ahead from 9500' to 9650'. 3010 psi fs at 1.62 bpm in/out. 100- 200 psi motor work. WHP/BHP/ECD: 55 psi / 3478 psi / 10.02 ppg. ROP: 40-60 fph. Weight transfer good, but samples indicate that the hole note getting fully cleaned. Make long wiper trip into casing. Open EDC above window. Jet casing to 7500'. 3977 psi fs at 2.03 bpm in. Noted a large quantity of cuttings on shaker with btms up. Circulate back in to hole. Log gr tie in from 8868'. -0.5' correction. Close EDC. Orient and RIH through window. Drill ahead from 9650'. 3600 psi fs at 1.62 bpm in/out. 100-200 psi motor work. 3-4k# dhwob. ROP variable. INC/AZM/TF: 94.0/ 327/100R. Build angle to 94-95 deg to climb and look for better sand. Drilled from 9650 ft to 9796 ft W iper to 7200 ft while repairs to Mud pump 2 are being done. Open EDC above window and jet to 7200 ft and back to 8870 ft. Log from 8870 ft to 8904 ft + 4 ft correction continue wiper trip to bottom. Drilling ahead from 9796 ft with free spin of 3375 psi multiple stalls starting at 9811.5 ft Drilling at 9820 ft CP= 3500 psi ~ 1.64 bpm ECD=10.09 ppg ~ 3414 psi APres density= 8.89/8.94 ppg DH WOB = 350#'s CT WT = 5700 #'s ROP = .2 fpm / 10 fph 60 deg Left TF drilled from 9,796' to 9,825' drilling ahead from 9,825 ft. Drilling ~ 9,830 ft. CP=3625 psi ~ 1.67 bpm density=8.89/8.94 ppg • BP AMERICA Page 24 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT 'Phase Description of Operations 7/17/2008 100:00 - 01:20 I 1.331 DRILL 01:20 - 02:35 1.251 DRILL 02:35 -03:30 0.921 DRILL 03:30 - 03:45 I 0.251 DRILL 03:45 - 04:05 I 0.331 DRILL PROD2 ECD=10.15ppg with 3440 psi Apres. DH W0B=770#'s CT WT=5500#'s ROP=.2 fpm / 14 fph TF=70 deg Left with 93.81 near bit inclination PV=367 bbls PROD2 while drilling ahead at 9835' small losses started at 1.63 bpm in / 1.17 bpm out. picked up to 9825 ft while circulating and then worked down slow again to 9835. Losses started to get better and drilled ahead to 9836.9 ft and stalled. PU to 9830' but 14 stals trying to work past 9835 ft. 15th attempt at 0.1 FPM got back to 9836.9 ft and drill ahead at 0.1 FPM PROD2 Drill ahead from 9837 ft. PROD2 PROD2 04:05 - 11.:00 ~ 6.92 (DRILL ~ N ~ RREP ~ PROD2 11:00 - 11:15 I 0.25 DRILL N RREP I PROD2 11:15 - 12:30 1.25 DRILL N RREP PROD2 12:30 - 14:30 2.00 DRILL P PROD2 14:30 - 15:30 1.00 DRILL P PROD2 15:30 - 17:30 2.00 DRILL P PROD2 Drilling at 9839 ft. CP=3340 psi ~ 1.58/1.57 bpm. ECD=10.09 ppg with 3412 psi Apress. Density=8.88/8.93 ppg DH W06=1430#'s CT WT=3700#'s CT W0B=2170#'s ROP=0.1 fpm / 8 fph 70 left TF NB inclination = 93.59 deg ~ 9823.92 ft Pit Volume = 360 bbls drilled to 9849.7 ft motor work was going away but DH WOB was still 2700#'s BHA wiper to 9,750 ft. No problems getting back to 9849 ft. Drill ahead from 9849.7 ft. Drilled to 9858.1 ft before wiper to Gassed hole. Drilling rate had started to pick back up to 30 fph before MP failure. Wiper back to cased hole while repairs to Mud Pump 2 and then MP 1 are made. Replace suction, swab, and liners on pump #1. Circulate up in casing during repairs. Log gr tie in from 8860'. Subtract 1' correction. Close EDC. Wiper trip back to bottom. Hole smooth. Drill ahead from 9858'. 3850 psi fs at 1.61 bpm in/out. 100-200 psi motor work. 0.5 - 1.5k# dhwob. ROP: 40-60 fph. BHP: 3488 psi. ECD: 10.34 ppg. ICL: 94.5 deg, AZM: 96 deg, TF: 250 deg. Continue to slowly increase mud LSRV, target of 40K. Drill to 10,000'. Make wiper trip to 9150'. Hole smooth. ,Drill ahead from 10,000'. 13850 psi fs at 1.62 bpm in/out. 100-200 psi mtr work. Printed: 8/13/2008 2:31:29 PM BP AMERICA Page 25 of 31 Operations Summary Report Legal Well Name: 1 D-12 Spud Date: 6/21/2008 Common Well Name: 1 D-12 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/17/2008 15:30 - 17:30 2.00 DRILL P PROD2 1-2,5k# dhwob. ROP: 20-50 fph. BHP: 3517 ECD: 10.41 ppg. PVT: 313 bbls. I NC: 91 deg. Resistivity reading increasing. Mud solids up to 0.8%. Call for trucks for mud swap. Drill to 10,075'. 17:30 - 19:00 1.50 DRILL P PROD2 Drill ahead from 10,075' to 10,150'. 19:00 - 21:40 2.67 DRILL P PROD2 W iper trip to 7500 ft. open EDC above window and pump at 2.03 bpm with CP=4100 psi. New mud system started in at 21:30 21:40 - 21:50 0.17 DRILL P PROD2 Log from 8870' to 8893' for GR tie in at 8854' 5 ft correction. 21:50 - 22:40 0.83 DRILL P PROD2 Continue wiper to bottom. 9,079 ft closed ECD and pump min rate through window then return to 1.7 bpm. 22:40 - 00:00 1.33 DRILL P PROD2 Drill ahead from 10,150' Drilling at 10,163 ft. CP=3175 psi IN/OUT=1.64/1.62 bpm Density=8.62/8.73 ppg (with new mud at surface) ECD=9.92 ppg with 3348 Apress DH WOB=580#'s CT WT=6150#'s CT WOB=5900#'s ROP=.6 fpm / 34 fph 80 left TF with Near bit inclination = 92.78 deg ~ 10,152 ft. Drilled to 10,182 ft. 7/18/2008 00:00 - 05:00 5.00 DRILL P PROD2 Drilling ahead from 10,182 ft. to 10,300 ft. Drilling at 10,245 ft. CP=3320 psi Dif Press=570 psi IN/OUT=1.68/1.68 bpm Density=8.64/8.56 ppg DH W0B=1450#'s TF=90 deg Left CT WT=1985#'s CT W06=4000#'s ROP=.4 FPM / 24 FPH NB Incl.=91.26 deg ~ 10,232 ft ECD=10.02 ppg Apress=3382 05:00 - 06:45 1.75 DRILL P PROD2 Wiper trip to window. Hole smooth in both directions. 06:45 - 11:45 5.00 DRILL P PROD2 Drill ahead from 10,300'. 3200 psi fs at 1.67 bpm in/out. 100-250 psi motor work. 0.5-1.5k# dhwob. BHP: 3318 psi. ECD: 9.84 ppg. PVT: 291 bbls active. Inc: 91.1 deg, Azm: 56 deg, TF: 80R. Slow drilling at 10,380'. Several stalls. Make a few 100' wiper trips. ROP increased at 10,395'. Drill to 10,431'. 11:45 - 13:30 1.75 DRILL P PROD2 ROP slowed down again. Pdnted: 8/732008 2:31:29 PM ~ ~ BP AMERICA Page 26 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT `Phase Description of Operations 7/18/2008 11:45 - 13:30 1.75 DRILL P PROD2 Make long wiper trip to 7500'. EDC opened once above the 13:30 - 15:30 ~ 2.00 ~ DRILL ~ N ~ DFAL ~ PROD2 15:30 - 17:00 1.501 DRILL I N DFAL I PROD2 17:00 - 18:00 I 1.00 DRILL N I DFAL I PROD2 18:00 - 19:30 1.50 DRILL N DFAL PROD2 19:30 - 20:05 0.58 DRILL P PROD2 20:05- 20:50 0.75 DRILL N RREP PROD2 20:50 - 21:35 0.75 DRILL P PROD2 21:35 - 22:20 0.75 DRILL P PROD2 22:20 - 00:00 I 1.671 DRILL I P I PROD2 9/2008 ~ 00:00 - 02:25 ~ 2.42 ~ DRILL ~ P ~ ~ PROD2 02:25 - 04:05 1.67 DRILL P PROD2 04:05 - 06:45 2.67 DRILL P PROD2 06:45 - 09:00 2.25 DRILL P PROD2 09:00 - 09:15 0.25 DRILL P PROD2 09:15 - 10:45 1.50 DRILL P PROD2 10:45 - 13:30 2.75 DRILL P PROD2 13:30 - 15:30 2.00 DRILL P PROD2 15:30 - 18:30 3.00 DRILL P PROD2 18:30 - 21:00 2.501 DRILL I P I PROD2 window. Circ at 4550 psi at 2.46 bpm iNout. RIH back to 3-1/2" x 4-1/2" tbg XO at 8446'. Noted a lot of "extra" cuttings over shaker at btms up. Circulate out of hole at 60%. Follow WHP schedule to maintain BHP. 4500 psi at 2.45 bpm in with EDC open. Jog back to 500' from surface. No surge in cuttings noted. Hold PJSM to dicuss pressure undeploying BHA. Pressure undeploy drilling BHA. Change bit, motor, and resistivity tool. Crew change. Hold PJSM. Pressure deploy lateral BHA with res tool. RIH w/ BHA #36 Log tie-in, Corr -11.5'. Repeat to verify, add 0.5' WO repair of pump #2 suction valve/seat RIH thru window, clean. Wiper to 10220' was clean Log at 300'/hr MAD pass for res data missed during previous drilled footage PVT 261 Drill from 10430' tag 1.61/1.58/3400/908 w/ 100-300 psi dill, 1.0-2.5k wob w/ open choke giving 10.15 ECD. Drill at 91-92 deg in the C4 to 10482' PVT 258 Continue drilling from 10482' 1.61/1.59/3450/90-1108 w/ 200-500 psi dill, 1.0-1.2k wob w/open choke to give 10.25 ECD at 92 deg in the C4. Drill to 10600' PVT 256 Wiper to window was clean both directions PVT 254 Drill from 10600' 1.58/1.56/3450/100-1458 w/ 200-400 psi dill, 1.0-1.8k wob w/ 10.30 ECD at 92 deg in the C4. Drill to 10,750'. Make long wiper trip to 7500'. 3775 psi fs at 1.80 bpm in/out in open hole. Open EDC above window. 4010 psi fs at 2.22 bpm in/2.00 out. Log gr tie in from 8860'. Add 5' correction. Close EDC. Circulate back to bottom. Drill ahead from 10,750'. 3200 psi fs at 1.62 bpm in/out. 100-250 psi mtr work. 0.5-1.5k# dhwob. ROP: 40-70 fph. BHP: 3439 psi, ECD: 10.23 ppg. PVT: 294 bbls. Inc: 96.7 deg, Azm: 137 deg, TF: HS. Make wiper trip to 9100'. 3250 psi fs at 1.61 bpm in. Drill ahead from 10,900'. 3300 psi fs at 1.62 bpm in/out. ECD: 10.26 ppg. Continue "exploratory build" with highside tool face. Inc: 103 deg. ROP slowed to 2-5 fph at 10930'. Drill from 10943' 1.62/1.59/3460/5L w/ 50-150 psi dill, 1.Ok wob, -8.4k surface wt w/ 10.26 ECD w/ 104 deg NBI. Very slow penetration rate of <5'/hr while trying to confirm D Shale. Call initial TD at 10955' where deep res is 6.1 ohms and Panted: 8/13/2008 2:31:29 PM BP AMERICA Operations Summary Report Page 27 of 31 Legal Well Name: 1 D-12 Common Well Name: 1D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008. End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 17/19/2008 18:30 - 21:00 2.50 DRILL P 21:00 - 22:20 1.33 DRILL P 22:20 - 22:35 0.25 DRILL P 22:35 - 23:35 1.00 DRILL P 23:35 - 00:00 0.42 DRILL I P 17/20/2008 100:00 - 01:00 I 1.00 (DRILL I P 01:00 - 01:45 ~ 0.75 ~ DRILL ~ P 01:45 - 03:30 I 1.751 DRILL P 03:30 - 04:30 I 1.00 I DRILL I P 04:30 - 04:45 0.25 CASE P 04:45 - 05:10 0.42 CASE P 05:10 - 09:30 4.33 CASE P 09:30 - 10:00 0.50 CASE P 10:00 - 14:00 4.00 CASE P 14:00 - 14:15 0.251 CASE P 14:15 - 15:45 1.50 CASE P 15:45 - 16:30 0.75 CASE P 16:30 - 18:00 I 1.50 18:00 - 20:40 I 2.67 20:40 - 22:30 I 1.83 22:30 - 23:15 I 0.75 PROD2 trending lower PROD2 Wiper to window 1.78/3650 was clean. Pull thru window #o logging depth PROD2 Log tie-in down from 8870', corr +3' PROD2 Wiper back to TD 1.65/3480 was clean to set down at 10938'. Clean PU at 22k. Had to red rate to get to final TD tagged at 10955' PROD2 Wiper back to window 1.65/4000 leaving fresh FloPro mud w/ 2 ppb beads in the open hole PROD2 Finish wiper to window leaving fresh mud w/ beads in OH. Pull thru window, clean. Continue wiper 1.5/3500 while fin cite 50 bbls fresh hi-vis mud to bit PROD2 Open EDC at 8560'. Resume PUH jetting 1.9/3750 in 4-1/2" tubing to 7500'. RBIH jetting while fin displacing hi-vis mud with 10.5# Naar brine PROD2 POH while displace wellbore from 9095' w/ 10.5# brine 2.05/3400 PROD2 LD drilling BHA. Bit was 1-1-I w/two PN's LNR2 Safety mfg re: RU and run liner LNR2 Bring BTT tools to floor. RU to run liner LNR2 MU Unique Indexing Guide Shoe + one jt 2-3/8" solid tubing + BTT O-ring sub. MU 56 jts 2-3/8" 4.41 # L-80 STL slotted liner LNR2 MU Inteq toots. Stab liner. Test tools. Get on well. LNR2 Run in hole. Losing approximately 5 bph 10.5 ppg brine to well. 24k# up, 8k# do wt at window. Run into open hole. Attempt to log tie in while RIH. Liner won't move at logging speed. Tag btm at 10961'. Hole smooth except for btm +/-100' or so. Subtract 6' correction from TD tag depth. Pull up hole and RIH to set liner shoe at 10,935'. Circ at 3540 psi at 1.69 bpm. PU to release. Unable to get free on first try. (Sure wish I had run a knuckle joint !) Pull into casing to relieve side force on GS spear. Release from liner above window. Push liner 5'. Get off liner. Repeat this several times. Push liner shoe back to setting depth of 10,935'. TOL at 9108', 4' below bottom of window. LNR2 Log GR tie in to verify liner top set. No additional correction. LNR2 Pull out of hole. LNR2 At surface. Get off well. LD Inteq tools. MU stinger and jet nozzle. Get on well. RUNCMP Run in hole. Fill coil with new hi-vis flopro mud. Set down at 9100' CTD RUNCMP Incr rate to 2.5/3880 and jet drilled solids from the cased hole over 9100' to 5000'. Jet from 5000' to tag at 9100.5' CTD while Circ fresh 10.5# brine to nozzle RUNCMP POOH following pressure schedule until wellbore is circa back to KWF RUNCMP LD nozzle assy BP AMERICA Page 28 of 31 Operations Summary Report .,Legal Well Name: 1D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number. Date From - To Hours Task Code' NPT .Phase Description of Operations 7/20/2008 22:30 - 23:15 0.75 BUNCO RUNCMP MU BTT bare hook assy on Bowen jars onto BHI MWD assy 23:15 - 00:00 0.75 BUNCO RUNCMP RIH w/ BHA #39 circ 0.58/1000 7/21/2008 00:00 - 00:50 0.83 BUNCO RUNCMP Fin RIH w/ WS retrieval tool circ 0.58/1000 00:50 - 01:00 0.17 BUNCO RUNCMP Log tie-in down from 8860', corr -4.5' 01:00 - 03:00 2.00 BUNCO RUNCMP RIH to 9050', 21.2k, 9.Ok RIH to wt loss at 9103.3' and work to engage hook from 9104.0' w/ 170E-170R TF Engage hook at 9102.5' up depth and 175R. Work DH wob up to 1.92k and lost wt back to neutral and assume WS released 03:00 - 05:00 2.00 BUNCO RUNCMP POOH w/ WS circ 1.05/1660 05:00 - 06:15 1.25 BUNCO RUNCMP LD WS fishing assy w/o recovery. Hook showed obvious sign of engagement with rounded edge indicating not fully inserted (because solids were in recess) Remove hook and replace with overshot w/ cutlip guide 06:15 - 08:15 2.00 FISH N DFAL RUNCMP Run in hole with half mule shoe overshot on Inteq orienter. 08:15 - 08:30 0.25 FISH N DFAL RUNCMP Log GR tie in from 8860'. Subtract 3' correction. Stop and discuss tray fishing technique. 08:30 - 09:30 1.00 FISH N DFAL RUNCMP Circ at 2550 psi at 1.09 bpm in/out. 20.3k# up, 9.5k# do wt at 9050'. RIH with mule shoe flat oriented to low side. Lightly tag TOF at 9100'. Orient and lose WOB. Set 5k# do dhwob. PU and pull over 2k# dhwob. Set back do 5k# to increase bite on fish. PU to 22k# or 2k# over, -4k# dhwob. Wait for jars to relax. Jars fire lightly. PU to -5k# over, then -8k# dhwob. Fish holding. Don't want to pull too hard and release KB anchor packer set for 15k# pull release. Set do and reset jars. PU to -4.7k# dhwob. Jars fired. Pull to 7k# dhwob over. Reset jars. PU to -6.5k# dhwob. Jars fired. Pull to 8k# over surface wob. Reset jars. PU to -7k# dhwob. Jars fired. Pull to 10k# over surf wob (-10k# dhwob) Continue to jar at 9k# over dhwob. Something came free. Pull up hole to check for drag. None noted. RIH. Tag at 9100'. PU again. 2K# overpull at pickup, then came free again. Reset jars. 09:30 - 12:00 2.50 FISH N DFAL RUNCMP Pull out of hole. Fill hole across the top. At surface. Flow check. 12:00 - 12:30 0.50 FISH N DFAL RUNCMP Unstab coil. Pull BHA. No recovery of whhipstock. Overshot in very good condition. Must have slipped off the whipstock. 12:30 - 15:30 3.00 FISH N DFAL RUNCMP Hold PJSM to discuss reel management procedures. Prep to cut 500' of coil. There is a 30% wear spot at 9100' with only 262K running feet on reel. Reverse circulate slack in reel. Cut 550' of coil and 530' of wire. MU coil connector. Pump forward. Complete connector makeup. Test same. 15:30 - 16:30 1.00 FISH N DFAL RUNCMP Hold PJSM to discuss BHA make up. BP AMERICA Page 30 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 7/22/2008 11:00 - 12:00 1.00 BUNCO RUNCMP bite between setting tool and straddle .packer. MU Inteq tool string with orienter. Stab coil. Get on well. Test tools. 12:00 - 14:00 2.00 BUNCO RUNCMP Run in hole. Circ at min rate through EDC. 14:00 - 14:15 0.25 BUNCO RUNCMP Log gr tie in. Subtract 4' correction. 14:15 - 14:45 0.50 BUNCO RUNCMP 19k# up, 8k# do wt at 9040'. Run in hole at 15 fpm. Tag at 9074.4'. PU to 20k# surface wob, 500# dhwob. Close EDC. Pressure coil to 1670 psi, setting tool stroked. Set down 3k# do wt. Set looks good. Top od straddle assembly is at 9043'. 14:45 - 16:15 1.50 BUNCO RUNCMP Pull out of hole. Hold PJSM to discuss handling the BHA and Baker TT tools. 16:15 - 17:15 1.00 BUNCO RUNCMP Lay down Inteq and BTT tools. MU nozzle assy 17:15 - 18:45 1.50 WHSUR P POST RIH w/ nozzle assy Circ 0.59/850 10.4 ppg brine 18:45 - 19:45 1.00 WHSUR P POST Circ at 9000' while WO LRS (at BBO) and SW (AES truck broke down) IAP 850, OA 0 19:45 - 20:00 0.25 WHSUR P POST Safety mtg re: LRS fill IA w/diesel 20:00 - 21:35 1.58 WHSUR P POST MIRU LRS to IA. PT 3000. Start LRS down the IA w/diesel at 2.0/1250. SWS SD Circ on CT to monitor returns. Continue to PUH 3'/min from 8840'. Use Swaco choke and 'out' MM rate while apply up to 200 psi. bp. Take returns to tiger tank (all fluid density after BU was 8.5 ppg). LRS SD after pumping 160 bbls of diesel w/ FIP 2.0/1145. Lost 18 bbls during displacement. SI IA with 600 psi. 21:35 - 23:45 2.17 WHSUR P POST Start SW down CT at 2.5/4000 and RBIH to 9000'. POOH after SW at nozzle and displace remaining 10.4# brine (and SW from IA) OOH to tiger tank while follow pressure schedule. LRS start 35 bbls diesel down CT and displace w/ 50 bbls FW followed by 10 bbls corrosion inhibitor and 10 bbls diesel to pickle the CT 23:45 - 00:00 0.25 WHSUR P POST Tag up w/ 780 psi whp, 1140 IAP, 0 OAP. SI master and swabs 7/23/2008 00:00 - 00:30 0.50 WHSUR P POST Set back injector. LD nozzle assy 00:30 - 00:40 0.17 WHSUR P POST Safety mtg re: RU and set BPV MIRU SWS N2 00:40 - 04:00 3.33 WHSUR N POST Bring FMC BPV lubricator and tools to floor and RU. PT lub at 1500 psi. Open wellbore to 600 psi, IAP 840. Attempt to set 4-1/2" BPV, but galled the threads on BPV. WO FMC to get another BPV from Valve shop. Retry and appears to be hanging up in the SSV. Remove fusible and cycle SSV and stroke to find fully open spot. Now are able to get the BPV down to the hanger, but unable to seat. Tried twice. FMC recommends wire brush, but needs slickline to make one 04:00 - 04:15 0.25 WHSUR P POST Safety mtg re: blow down CT w/ N2 04:15 - 07:00 2.75 WHSUR P POST SWS cool down N2. PT 4000. Blow down CT w/ N2 and bleed off to tiger tank. Bleed off N2 pressure from reel. 07:00 - 09:00 2.00 WHSUR N POST Hold PJSM to discuss wire brush operation. RU and pressure test lubricator to 750 psi. aan~od~ An3/'JOnR 237~29PM BP AMERICA Operations Summary Report Legal Well Name: Common Well Name: Event Name: Contractor Name: Rig Name: 1 D-12 1 D-12 REENTER+COMPLETE NORDIC CALISTA NORDIC 2 Date From - To Hours Task ~ Code ~ NPT 17/21/2008 115:30 - 16:30 I 1.00 I FISH N DFAL 16:30 - 18:00 1.50 FISH N DFAL 18:00 - 18:15 0.25 FISH N DFAL 18:15 - 19:50 1.58 FISH N DFAL 19:50 - 21:45 21:45 - 22:30 22:30 - 22:40 22:40 - 23:15 23:15 - 00:00 00:00 - 01:25 01:25 - 01:45 01:45 - 02:10 1.92 FISH N 0.75 FISH N 0.17 0.58 0.75 1.42 0.33 0.42 02:10 - 03:50 1.67 RU 03:50 - 05:00 1.17 RU 05:00 - 05:40 0.67 RU 05:40 - 06:20 0.67 RU 06:20 - 08:00 1.67 RU 08:00 - 08:15 0.25 RU 08:15 - 09:15 I 1.001 RU 09:15 - 11:00 1.75 11:00 - 12:00 1.00 DFAL DFAL SFAL DFAL Page 29 of 31 Spud Date: 6/21 /2008 Start: 6/21 /2008 End: 7/24/2008 Rig Release: 7/24/2008 Rig Number: Phase Description of Operations RUNCMP MU baited overshot BHA with splined GS, bi-directional jars, two 2-3/8" drill collars, accel, and Inteq tools including orienter. RUNCMP Run in hole. RUNCMP Log tie-in, Corr -4.5' 21.2k, 9.8k at 9050' RUNCMP RIH slow to wt loss at 9100.5'. Use orientor and jars to set overshot on WS. After three cycles pulled to 9.8k over. Jars went off and lost wt back to neutral. Set back down and repeat with 3 cycles of using orientor and jars to set OS. Jar up w/ 7-9k wob for about 8 cycles and wt fell off quickly. PUH 50' w/ no drag. Attempt to reengage three more times w/o using down jars, but had no overpulls RUNCMP POH to check BHA filling from BS. No overpulls RUNCMP LD fishing assy. Recovered WS tray. Tray and tray slots clean. Collets look normal. LD and load out fishing tools BHI change depth encoder on injector RUNCMP Safety mtg re: MU lower straddle assy RUNCMP MU BTT 35 KB lower straddle assy (30.39' OA) onto BHI MWD assy RUNCMP RIH w/ BHA #42 circ thru EDC 0.27/570 at 80'/min RUNCMP Continue RIH w/ lower straddle assy. Slow to 20'/min in 3-1/2" liner RUNCMP Log tie-in down from 8870'. BHI depth tracking problems continue. Corr -4.0' RUNCMP Continue RIH to 9100' 8.3k and had nowt loss. PUH 2O.Ok and park at 16.7k to put center of element at 9095' ELMD. Close EDC. Pressure up to 1550 psi and packer set. Stack 2.Ok wob. PUH 19.8k clean RUNCMP POOH circ 1.0/1460 RUNCMP LD KB setting tools and rod MU setting tool to upper straddle assy. MU BHI MWD assy RUNCMP RIH w/ BHA #43 circ thru EDC 0.36/630 RUNCMP Park at 2130' and replace BHI encoder on injector RUNCMP Continue to run in hole at 75 fpm. RUNCMP Log gr tie in. Subtract 5'. Hold tool box mtg to discuss setting upper straddle assembly. RUNCMP RIH. 20k# up, 10k# do wt at 9040'. RIH slow at 8 fpm to engage seal assembly. Start stacking wt at 9068'. Repeat several times. Stacking should not occur until 9073'. Looks like the seal assembly is not entering the deployment sleeve on the lower straddle assembly. Isolate reel. Preesure IA to try and establish injection rate. 220 psi at 0.54 bpm. Squeezed perfs apparently taking fluid. Continue to work packer assembly. Unable to get seal assembly to sting in. Stacking up to 7k# dhwob. Cannot go any higher as KB pkr can be weight set. RUNCMP Pull out of hole to inspect seal assembly and pick up orienter. ..RUNCMP At surface. Get off well LD BHA ans straddle assy. Markings on ID surface of mule shoe show clear evidence of having set down on circular deployment sleeve top. "Test" assembly for ability to tum with orienter. Good friction Printed: 8/132008 2:31:29 PM • BP AMERICA Page 31 of 31 Operations Summary Report Legal Well Name: 1 D-12 Common Well Name: 1 D-12 Spud Date: 6/21/2008 Event Name: REENTER+COMPLETE Start: 6/21/2008 .End: 7/24/2008 Contractor Name: NORDIC CALISTA Rig Release: 7/24/2008 Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task {Code NPT Phase Description of Operations 7/23/2008 ~ 07:00 - 09:00 ~ 2.00 ~ WHSUR N 09:00 - 10:45 I 1.75 I DEMOB I P 10:45-11:30 ~ 0.75~WHSUR~P 11:30 - 13:15 I 1.75 DEMOB I P 13:15 - 14:30 I 1.251 DEMOB ~ P 14:30 - 15:30 ~ 1.00 ~ DEMOB ~ P 15:30-00:00 ~ 8.50~WHSUR~P POST Run brush and dress BPV profile area. Make 4th attempt to set BPV. Same result. Damaged first thread on btm of BPV. RD BPV lubricator and tools. POST PJSM to ustab coil MU grapple assy. Spool coil back to reel and secure same. Rig down equipment on rig floor. Prep to lower reel to trailer. PU BPV lubricator and tools. Continue to clean pits. POST RU and test lubricator. Run and install FMC ISA style 4-1/2" BPV. Draw down test same. Good test. RU lubricator. Remove lubricator from rig. POST Hold PJSM to rig down deployment lubricator. Rig down lubricator and slickline unit. POST Hold PJSM with crew. Open reel house door. Lower reel onto CHILL lowboy trailer for transport to 1 B pad. POST Continue to blow down rig equipment including suction lines and rig pumps. POST ND well control equipment in cellar incl MPD loop. DSO disconnect ESD for adjacent wells. NU tree cap and PT ~ 4200. Finish cleaning pits. SWS finish strip down injector and remove hyd fluid and hoses from power pack Rig released at 2400 hrs 7/23/2008 ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1 D Pad 1 D-12 1 D-12L2 Design: 1 D-12L2 Baker Hughes INTEQ Survey Report ~ 21 July, 2008 .~~~ BAKER H~ItsHE~"i INTEC,~ ConocoPhillips Alaska Company: ConocoPhillips(Alaska) Inc.. Project: Kuparuk River Unit Slts: Kuparuk 1 D Pad WeU: 1 D-12 Wetibore: 1 D-12L2 Design: 1 D-12L2 ConocoPhillips ~~R r Baker Hughes INTEQ Survey Report ~~~ 1NTEQ Local Co-ordinate Reference: Well 1 D-12 ' TVD Reference: Mean Sea Level MD Reference: 1D-12 (d1 104.30ft North Reference: True: Survey Calculation Method: Minimum Curvature Database: EDMv16 Prod Project Kuparuk River Unit, North Slope Alaska, United States Map System: US State Plane 1927 (Exact solution) Geo Datum: NAD 1927 (NADCON CONUS) Map Zone: Alaska Zone 04 $ite Kuparuk 1D Pad; KRU Ske Position: Northing: From: Map Easting: Position Uncertainty: 0.00 ft Slot Radius: System Datum: Mean Sea Level Using Well Reference Point Using geodetic scale factor 5,959,669.68 ft Latitude: 70° 18' 1.318 N 561,086.44 ft Longitude: 149° 30' 18.921 W 36 " Grid Convergence: 0.47 ° WaU 1 D-12 WeU Position +PU-S 0.00 ft Northing: 5,959,888.87 ft Latitude: 70° 18' 3.521 N +EI-W 0.00 ft Easting: 560,490.53 ft Longitude: 149° 30' 36.243 W Position Uncertainty 0.00 ft Wellhead Elevation: ft Ground Leval: 0.00 ft WsUbore 1D-12L2 kiagnetics Modt+i Name Sample Date DecUnation Dip Angle Field Strength BGGM2007 5/23/2008 17.85 79.75 57,283 Desigp 1D-12L2 Audit Notes: Version: 1.0 Phase: ACTUAL Tfe On Depth: 9,074.96 Vertical Section: Depth From (TVD} +N/S +E/-W Direction (ft) (ft) Ift) 1°) o.oo o.oo o.o0 88.x4 7/21/2008 4:42:39PM Page 2 COMPASS 2003.16 Build 42F . ConocoPhillips ConocoPhillips Baker Hughes INTEQ Survey Report ss~R~~ ~~~ Alaska INTEQ Company: ConocoPhillips(Alaska) Inca Local Co-ordinate Reference: Well iD-12 Project: Kuparuk River Unit TVD Reference: Mean: Sea Level Sfie: Kuparuk 1D Pad MD Reference: 1D-12 (~ 104.30ft` Welt: 1D-12' North Reference: True Weltbore: 1 D-12L2 Survey Ca~ulatlon Method: Minimum Curvature Design: 1D-12L2 Database: EDMvt6 Prod Survey Program Date Prom - To (ft) (ft) Survey (VYeubors) Tool Name Description 115.00 9,074.96 1D-12 (1D-12) MWD MWD -Standard 9,100.00 10,955.00 MWD (1D-12L2) MWD MWD -Standard survey ~ MD inc Azf TVDSS N/S ENV Northing EasUng DLS Vertical Section TPO (tt} (°} (°) Ift1 (ft) (ft) (n) lh) ('/t00ft) 1111 t') 9,074.96 48.07 88.53 6,468.06 239.54 5,704.70 5,960,174.30 566,192.57 1.78 5,709.11 144.91 9,100.00 48.20 87.12 6,484.78 240.24 5,723.33 5,960,175.15 566,211.20 4.23 5,727.76 -83.41 9,127.32 56.31 87.00 6,501.49 241.35 5,744.89 5,960,176.44 566,232.74 29.69 5,749.34 -0.71 9,158.84 71.21 87.00 6,515.38 242.83 5,773.04 5,960,178.14 566,260.88 47.27 5,777.52 0.00 9,189.60 84.86 77.73 6,521.76 246.87 5,802.76 5,960,182.42 566,290.55 53.23 5,807.33 -34.69 9,214.38 85.21 75.37 6,523.90 252.61 5,826.76 5,960,188.36 566,314.51 9.59 5,831.49 -81.64 9,243.54 87.45 73.22 6,525.77 260.49 5,854.77 5,960,196.46 566,342.46 10.64 5,859.70 -43.84 9,275.05 88.74 70.39 6,526.82 270.32 5,884.69 5,960,206.53 566,372.29 9.87 5,889.87 -65.54 9,303.84 89.05 67.59 6,527.37 280.64 5,911.56 5,960,217.06 566,399.07 9.78 5,917.01 -83.71 9,334.81 90.58 63.98 6,527.47 293.34 5,939.80 5,960,229.99 566,427.20 12.66 5,945.59 -67.0 9,365.97 91.20 65.51 6,526.99 306.64 5,967.97 5,960,243.51 566,455.27 5.30 5,974.12 67.9 9,395.29 91.11 69.22 6,526.40 317.92 5,995.02 5,960,255.00 566,482.23 12.65 6,001.47 91.35 9,427.40 91.50 73.32 6,525.67 328.22 6,025.42 5,960,265.55 566,512.53 12.82 6,032.13 84.52 9,457.18 91.84 77.41 6,524.80 335.74 6,054.21 5,960,273.30 566,541.26 13.78 6,061.12 85.19 9,486.26 91.66 82.11 6,523.91 340.91 6,082.81 5,960,278.70 566,569.82 16.17 6,089.85 92.12 9,509.99 92.06 85.71 6,523.14 343.42 6,106.39 5,960,281.40 566,593.37 15.26 6,113.49 83.60 9,540.35 91.93 89.65 6,522.08 344.65 6,136.70 5,960,282.88 566,623.67 12.98 6,143.82 91.82 9,570.12 91.23 93.91 6,521.26 343.73 6,166.44 5,960,282.19 566,653.41 14.50 6,173.52 99.27 9,600.99 90.55 98.49 6,520.78 340.39 6,197.12 5,960,279.11 566,684.11 15.00 6,204.10 98.41 9,627.80 90.67 102.64 6,520.49 335.48 6,223.46 5,960,274.40 566,710.49 15.48 6,230.30 88.32 9,660.09 91.53 106.15 6,519.87 327.45 6,254.73 5,960,266.63 566,741.82 11.19 6,261.34 76.20 7/21/2008 4:42:39PM Page 3 COMPASS 2003.16 Build 42F ConocoPhillips Alaska Cornpany: ConocoPhillips(Alaska) Inc, Project: Kuparuk River.Unit She: Kuperuk 1D Pad Weq: - 10.12 VY+allbore: 1 D-12L2 Deaigh: 1D-12L2 ConocoPhillips Baker Hughes INTEQ Survey Report Local Co~ordlnate Reference: ND Reference: MD Reference: North Rehrence: Survey Calculation Method: Database: ri~r la ~i~s INTEQ Well tD-t2 Mean Sea Level 1D-12 ~ 104.30ft' True Minimum Curvature EDMv16 Prod 8urvay AAD Inc Azl TVDSS N/S E/W Northing Easting DLS Vertical Section TFO t~) t°) t°) t~) tft) tft) tn) tft) (°llooft) (n) t°) 9,693.25 93.19 110.41 6,518.51 317.07 6,286.18 5,960,256.50 566,773.35 13.78 6,292.49 68.62 9,726.00 93.47 115.37 6,516.61 304.35 6,316.29 5,960,244.03 566,803.56 15.14 6,322.24 86. 9,754.27 92.79 115.30 6,515.06 292.27 6,341.80 5,960,232.16 566,829.17 2.42 6,347.42 -174.13 9,782.16 93.04 112.42 6,513.64 281.01 6,367.27 5,960,221.10 566,854.73 10.35 6,372.57 -84.96 9,812.47 93.22 109.71 6,511.99 270.13 6,395.51 5,960,210.45 566,883.05 8.95 6,400.50 -86.12 9,842.31 94.36 104.50 6,510.01 261.38 6,423.96 5,960,201.92 566,911.56 17.84 6,428.70 -77.47 9,875.83 93.69 99.39 6,507.66 254.46 6,456.66 5,960,195.27 566,944.32 15.34 6,461.20 -97.30 9,906.08 94.24 95.78 6,505.57 250.48 6,486.57 5,960,191.53 566,974.25 12.04 6,490.99 -81.19 9,935.02 94.83 92.89 6,503.28 248.30 6,515.34 5,960,189.58 567,003.03 10.16 6,519.69 -78.31 9,965.48 93.19 89.75 6,501.15 247.60 6,545.71 5,960,189.13 567,033.40 11.61 6,550.03 -117.52 9,995.10 91.29 87.45 6,499.99 248.32 6,575.29 5,960,190.09 567,062.98 10.07 6,579.62 -129.53 10,025.85 91.11 83.59 6,499.35 250.72 6,605.94 5,960,192.73 567,093.60 12.56 6,610.32 -92.63 10,058.93 91.26 79.90 6,498.66 255.47 6,638.66 5,960,197.74 567,126.28 11.16 6,643.16 -87.63 10,088.37 90.58 75.28 6,498.19 261.79 6,667.40 5,960,204.30 567,154.97 15.86 6,672.06 -98.33 10,123.79 91.72 71.97 6,497.48 271.77 6,701.37 5,960,214.55 567,188.86 9.88 6,706.29 -70.96 10,152.01 92.70 69.60 6,496.39 281.05 6,728.00 5,960,224.05 567,215.40 9.08 6,733.16 -67.4 10,182.74 93.10 64.90 6,494.83 292.92 6,756.29 5,960,236.14 567,243.60 15.33 6,761.77 -85.0 10,212.47 91.26 61.37 6,493.70 306.34 6,782.79 5,960,249.77 567,269.98 13.38 6,788.62 -117.47 10,242.08 90.55 56.55 6,493.23 321.60 6,808.15 5,960,265.24 567,295.22 16.45 6,814.39 -98.34 10,270.50 90.89 53.00 6,492.88 337.99 6,831.36 5,960,281.81 567,318.29 12.55 6,838.04 -84.51 10,300.84 91.29 58.53 6,492.30 355.05 6,856.43 5,960,299.07 567,343.22 18.27 6,863.57 85.81 10,335.16 92.36 64.35 6,491.21 371.44 6,886.54 5,960,315.70 567,373.20 17.23 6,894.12 79.49 10,370.21 91.35 69.09 6,490.07 385.28 6,918.71 5,960,329.80 567,405.25 13.82 6,926.65 101.95 10,401.00 91.47 73.20 6,489.31 395.23 6,947.84 5,960,339.98 567,434.29 13.35 6,956.04 88.28 10,446.33 91.87 80.58 6,487.99 405.50 6,991.94 5,960,350.60 567,478.30 16.30 7,000.40 86.79 10,480.91 91.51 86.15 6,486.97 409.49 7,026.26 5,960,354.87 567,512.59 16.13 7,034.81 93.61 10,510.04 92.46 90.29 6,485.96 410.40 7,055.35 5,960,356.01 567,541.67 14.57 7,063.92 77.00 7/21/2008 4:42:39PM Page 4 COMPASS 2003.16 Build 42F '/ ConocoPhillips .- ConocoPhilli s g p Baker Hughes INTEQ Survey Report Alaska INTEd Company: ConocoPhillips(Alaska) Inc. Project:. Kuparuk River Unit 51te: Kuparuk 1 D Pad WeB: tD-12 VYelibore; tD-12L2 Design: 1 D-12L2 Local Co-ordinate Reference: TVD Reference: MD Reference: North Reference: Survey Calculation Method: Database: VVe11 1 D-12 Mean Sea Level 1D-12 @'104.30ft True Minimum Curvature EDMv16 Prod surrey MD Inc Azi TVDSS WS t:lVII Northing Easting DLS Vertical Section TFO (fty (°) (°~ tnl (h) tft) Inl (~) 1°noaft> (n) (°) 10,540.19 92.86 95.02 6,484.56 409.00 7,085.42 5,960,354.86 567,571.75 15.73 7,093.95 85.05 10,571.64 92.52 98.52 6,483.08 405.30 7,116.62 5,960,351.40 567,602.97 11.17 7,125.03 95.~ 10,605.39 92.18 103.72 6,481.70 398.80 7,149.69 5,960,345.17 567,636.09 15.43 7,157.91 93.63 10,635.17 90.25 107.27 6,481.07 390.85 7,178.38 5,960,337.45 567,664.84 13.57 7,186.37 118.49 10,679.80 88.65 110.41 6,481.50 376.44 7,220.61 5,960,323.38 567,707.18 7.90 7,228.19 117.01 10,710.06 91.47 115.43 6,481.46 364.66 7,248.47 5,960,311.83 567,735.13 19.03 7,255.72 60.69 10,740.57 93.01 120.06 6,480.27 350.47 7,275.44 5,960,297.86 567,762.22 15.98 7,282.30 71.51 10,782.47 93.51 126.49 6,477.88 327.53 7,310.40 5,960,275.20 567,797.35 15.37 7,316.61 85.37 10,816.16 83.63 132.11 6,475.79 306.24 7,336.41 5,960,254.13 567,823.53 16.65 7,342.03 88.60 10,846.05 94.49 137.57 6,473.67 285.23 7,357.54 5,960,233.29 567,844.83 18.45 7,362.58 80.84 10,881.71 97.61 141.01 6,469.91 258.36 7,380.66 5,960,206.60 567,868.17 12.98 7,384.97 47.46 10,912.98 101.53 140.40 6,464.71 234.50 7,400.19 5,960,182.91 567,887.88 12.68 7,403.83 -8.67 10,955.00 101.53 140.40 6,456.31 202.77 7,426.43 5,960,151.40 567,914.38 0.00 7,429.20 0.00 Projected TD - 2 ~" 7/21/1008 4:42:39PM Page 5 COMPASS 2003.16 Build 42F ~-' ConocoPhilli s p ConocoPhillips Baker Hughes INTEQ Survey Report ~~~ s~`~ Alaska INTEQ Company: ConocoPhillips(Alaska) Inc. Local Coordinate Reference: Well 1 D-12 Project: Kuparuk River Unit ND Reference: Mean Sea Level Sftti Kuparuk 1 D Pad MD Reference: 1 D-12 ~ 104:30ft Weli: 1D-12 North Reference: True' WeNbore: 1 D-12L2 Survey Calculatbn Method: Minimum Curvature Destgn: 1 D-12L2 Database: EOMv16 Prod Targets Target Name • hitlmiss target Dip Angie Dlp Dir. ND +W-S +E/-W Northing Fasting -shape (°) (°) Ift) Ift) lftl Iftl fn) Latitude Longftude 1D-12L1 Fault 2 0.00 0.00 0.00 543.88 7,287.63 5,960,491.34 567,772.85 70° 18' 8.835 N 149° 27' 3.762 W -actual wellpath misses by 6466.81ft at 10955.OOft MD (6456.31 ND, 202.77 N, 7426.43 E) - Polygon Point 1 0.00 543.88 7,287.63 5,960,491.34 567,772.85 Point2 0.00 436.87 7,661.82 5,960,387.36 568,147.85 Point 3 0.00 345.15 7,876.12 5,960,297.37 568,362.86 Point4 0.00 436.87 7,661.82 5,960,387.36 568,147.85 1D-12L1 Target 5 0.00 0.00 6,523.00 -952.19 6,533.50 5,958,989.39 567,030.85 70° 17' 54.128 N 149° 27' 25.788 W -aduai wellpath misses by 1200.05ft at 9965.48ft MD (6501.15 ND, 247.60 N, 6545.71 E) - Point 1D-12Lt Target 3 0.00 0.00 6,545.00 -418.52 6,084.76 5,959,519.39 566,577.87 70° 17' 59.380 N 149° 27' 38.856 W -aduai wellpath misses by 716.99ft at 9250.63ft MD (6526.07 ND, 262.57 N, 5861.54 E) - Point 1D-12L1 Polygon 0.00 0.00 0.00 176.23 5,627.50 5,960,110.38 566,115.89 70° 18' 5.233 N 149° 27' 52.173 W -actual wellpath misses by 6468.83ft at 9074.96ft MD (6468.06 ND, 239.54 N, 5704.70 E) -Polygon Point 1 0.00 176.23 5,627.50 5,960,110.38 566,115.89 Point 2 0.00 2.60 5,828.14 5,959,938.39 566,317.90 Point 3 0.00 -431.66 5,853.67 5,959,504.39 566,346.93 Point4 0.00 -807.53 6,081.69 5,959,130.40 566,577.94 Point 5 0.00 -1 ,502.11 6,393.17 5,958,438.42 566,894.97 Point6 0.00 -959.62 7,090.60 5,958,986.45 567,587.95 Point 7 0.00 -551.43 6,573.80 5,959,390.43 567,067.93 Point 8 0.00 -233.11 6,288.31 5,959,706.41 566,779.91 Pant9 0.00 202.07 6,147.77 5,960,140.40 566,635.89 Point 10 0.00 375.93 5,918.13 5,960,312.39 566,404.88 Point 11 0.00 378.01 5,658.12 5,960,312.38 566,144.88 1D-12L1 Target 2 0.00 0.00 6,544.00 95.22 5,999.89 5,960,032.37 566,488.88 70° 18' 4.434 N 149° 27' 41.318 W - actual wellpath misses by 205.88ft at 9308.40ft MD (6527.44 N0, 282.40 N, 5915.76 E) -Point 1D-12L1 Target 4 0.00 0.00 6,541.00 -797.44 6,441.74 5,959,143.39 566,937.86 70° 17' 55.651 N 149° 27' 28.459 W -actual wellpath misses by 1049.OOft at 9935.02ft MD (6503.28 TVD, 248.30 N, 6515.34 E) - Point 7/21/2008 4:42:39PM Page 6 COMPASS 2003.16 Build 42F ~ ConocoPhillips ~~~ s ConocoPh~llips Baker Hughes INTEQ Survey Report ~n,a"~s . Alaska INTEQ Company: ConocoPhillips(Alaska) Inc. Local Coordinate Reference: VJe11 1 D-12 Protect: KuparukRiver Unit ND Reference: Mean Sea Level SJte: Kuparuk 1D Pad MO Reference: 1D-12(~ 104:30ft We1L' 1 D-12 North Reference: True VlteltborQ: 1D-12L2 Survey Calculation Method: Minimum Curvature Design: 1 D-12L2 Database: EDMv16 Prod 1D-12L1 Target 1 0.00 0.00 6,558.00 235.24 5,875.00 5,960,171.37 566,362.89 70° 18' 5.812 N 149° 27' 44.956 W -actual wellpath misses by 43.76ft at 9255.94ft MD (6526.27 ND, 264.18 N, 5866.60 E) - Point 1D-12L1 Fault 1 0.00 0.00 0.00 -5.11 6,287.11 5,959,934.37 566,776.87 70° 18' 3.445 N 149° 27' 32.947 W -actual wellpath misses by 6498.84ft at 9074.96ft MD (6468.06 ND, 239.54 N, 5704.70 E) - Polygon Point 1 0.00 -5.11 6,287.11 5,959,934.37 566,776.87 Point 2 0.00 305.83 6,299.60 5,960,245.37 566,786.86 Point 3 0.00 619.99 6,284.11 5,960,559.37 566,768.84 Point 4 0.00 305.83 6,299.60 5,960,245.37 566,786.86 Cask-g Points Measured Vertlcat Casing Hole Depth Depth Diameter Diameter (tU tK1 Name (") ("1 10,955.00 6,456.31 2 3/8" 2-3/8 3 Design Annatatfons Measured Vertlcat .Depth Depth (tt) (tt} 10,955.00 6,456.31 Checked By: Local Coordinates +N!-S +FJ-W (ft) (ft) Comment 202.77 7,426.43 Projected TD Approved By: Date: 7/21/2008 4:42:39PM Page 7 COMPASS 2003.16 Build 42F 1 D-12L1 8~ L2 CTD Sidetrack (7/24/08) nipple @ 500' MD (3.813" min 12.6# L-80 IBT-Mod Tubing to surface 9-5/8" 40# L-80 shoe @ 5641' MD rfs shot off depth throng ?" tubing and 7" casing, 36' -8138' MD (6-15-OS) retrievable tubing patch 8128' 8143' MD. Min ID = 2.25" 7" 26# L-80 shoe @ 8696' MD Squeezed Perfs 9001 - 9031' MD (C4) 9051 - 9089' MD (C4) 9136 - 9138' M D 9171 -9181'MD(C1) 3-1/2" KB Packer at 9110' MD 1.71" R-nipple at 9123' MD Muleshoe at 9128' MD off of 3-1/2" monobore whipstock 3-112" 9.3# L-80 shoe @ 9248' MD ' Camco KBG-2 gas lift mandrels @ 2963', 4727', 5525', 6651', 8356' MD 4-1/2" Camco DB landing nipple @ 8408' MD (3.75" min ID) 4-1/2" x 3-1/2" cross-over @ 8446' MD Baker PBR @ 8453' MD Baker FHL packer @ 8467' MD - 9099' MD 3-1/2" Camco DS nipple @ 8491' MD (2.812" min ID) 1.81"' D' reducer nipple installed 7/29/08 Poor Boy Overshot @ 8502' MD 3-1/2" cut tubing @ 8502" (11/19/03) 3-1/2" Camco DS nipple @ 8538' MD (2.75" min ID) Baker 3-1/2" 80-40 seal assembly @ 8546' MD (3" ID) BAKER 7"x 3.5" SLZXP LT PACKER & Hanger w/PBR @ 8542' MD Baker SBE @ 8549' MD L2KOP@9100'MD off of 3-1/2" snap-latch tray (removed) / ~ L2 Liner: 2-3/8", 4.6 #, L-80 ST-L liner 9108' - 10935' \ \ solid liner: 9108' - 9129' L2 TD @ 10,955' MD slotted liner: 9129' - 10935' 3" borehole - - ~ anchor billet at 9340' L1 P61 9340' - 10,251' MD \ no liner L1 TD @ 10,695' MD L1 Liner: 2-3/8", 4.6 #, L-80 ST-L liner 9134' - 10695' 3" borehole solid liner: 9134' - 9271', 9334' - 9429', & 10219-10346' slotted liner: 9271' - 9334', 9429' - 10219', 10346' - 10662' BAKER NuNE~ Il\iTEC~ 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 1-01 1 D-04AL 1-02 1D-12L1PB1 1D-12L1 1 D-12L2 a- q$- L ~ .~` Enclosed is: D<<J 1":~ 2.~a-toy 1 ea 3.5" floppy diskette containing electronic survey file ~~.~ ~~ Cc: State of Alaska, AOGCC Christine Mahr?cen s Ls~- ~ ~. n :x „y L : >-:~+~-v~~ :~.v as •ax•s.~v iua 1u~a.n • at~a~ a ~r~ .~ (Fr®onu: i1liaunder, Thomas E (DOA) Sent: IVlonday, June 23, 2008 8:33 AIVi T®o °I~ISK Well Integrity Proj'; Eller, J Gary Saa6~Dec>t: RE: 1 D-12 PTD 199-084, Off depth pert and CTD sidetrack Gary end Perry, ~ ~ '- ~~ ~~ This is as ae discussed. Tom tvlaunder, PE ~~~` ~~~ AOGCC F~oon: iVSK Well Integrity Proj [mailto:N1878@conocophillips.com] See~to Saturday, June 21, 2008 3:09 PM T'o: Maunder, Thomas E (DOA); Eller, J Gary ~Ibject: RE: iD-12 PTD 199-084, Off depth perf and CTD sidetrack Tom, Per our conversation this a-mail is intended to provide a plan forward outlining well work on 1 D-12. CPAI plans to continue with the coiled tubing sidetrack. Once the side track is complete and the CTD rig has left the well head CPAI plans to install two 4.5" Weatherford ER packers to isolate the section of tubing that was mistakenly perforated at 8136-8138'. A mechanical integrity test will be performed to ensure tubing integrity before placing the wet{ on production. CPAI does not intend to gas lift below station # 5 @ 7654! 5634' MD /TVD. The production casing currently supports a column of diesel with 1600 psi surface pressure. This equates to 3700 psi or 12.0 ppg EMW at the perfs. The perfs @ 8136-8138' could experience a maximum pressure of 4000 psi with a full column of water in the production casing and full gas lift pressure. However it is not our practice to bring wells online with full gasNft pressure. We unload fluid packed wefts slowly in order to protect the orifice valve from damage. It is unlikely that maximum gas lift pressure would be applied to the IA with a fuA column of fluid. While in operation and the well lifting from station # 5 @ 7654' we estimate the pressure on the perfs to be 1598 psi. CPAI will submit a 10-403 sundry request to patch the off depth perforations in the 4.5" tubing and notes will be made in the 10-407 drilling report addressing the current condition of the tubing and plan forward. Please let me know if you have any questions Perry Klein Well Integrity Project Supervisor GonocoPhillips Alaska, (nc. Desk Phone (907} 659-7043 Cell Phone (907} 943-1244 _ __ _ _. ~co~ea Maunder, Thomas E (DOA) [mailto;tom.maundera0alaska.gov] ant: Thursday, June 19, 2008 12:19 PM 'B'oo NSK Well Integrity Proj; Regg, James B (DOA) 6/23/200:3 Si1J/-RL a 1;10 1s'>''-uus-r~ flu '.ua~~v M1llA ~.Ybx1 ll ~3~w L ydl ~ • • Cc: Eller J Gary; NSK Problem Weil Supv Subject: RE: iD-12 PTD 199-084, Off depth perf Perry, think Gary is due to come over in about 45 minutes. It appears that this well is intended to be gas-lifted. Is it intended to lift the we11 deeper than GLM #5 at 7654'? What is the calculated EMW at the oops perfs with active gas lift lifting from GLM #5? if gas lift were shut dotivn, what is the ENtti'V at the oops perfs? if gas lift pressure were to be blown down on the IA, what does CPAI expect might happen? Tom Maunder, PE AOGCC From: NSK Well Integrity Proj [mailto:N1878@conocophillips.com] Sent: Thursday, June 19, 2008 12:11 PM To: Maunder, Thomas E (DOA); Regg, James B (DOA) Cc: Eller, J Gary; NSK Problem Well Supv Subject: 1D-12 PTD 199-084, Off depth perf Tom, 1 D-12 PTD 199-084, gas lift C-sand producer, was reported on 6/17/08 for T X IA communication after squeeze perfs were mistakenly shot off depth. Diagnostics indicate that the shots have penetrated the 7" production casing. Schlumberger has provided a CADE that predicts 4" of penetration past the production casing for the 2", 6 spf big-hole Hyperjet HSD guns. The penetration is into the HRZ shale within the cemented portion of the 7" casing. The design cement top behind the 7" is 7700' MD. Full reciprocation and full returns were achieved throughout the cement job. TVD to the off-depth perforations is 5957 ft. The well does not inflow with a column of diesel. The perforated zone takes fluid at 0.5 bbl per minute with a column of diesel and 2100 psi surface pressure (estimated 4200 psi or 13.5 ppg EMW at the perfs). The well stabilizes with approximately 1600 psi surface pressure and a column of diesel (estimated 3700 psi or 12.0 ppg EMW at the perfs). Just prior to #his incident, successful pressure tests had been made on the tubing, packer, 7" casing, and tubing hanger packoff. Please see the supporting test data below. 3/28/08 - TIFL -passed , T-POT -passed, T-PPPOT -passed, IC-POT -Passed, IC-PPOT -Passed, MITOA - Passed, LDS Functional, Initial T/l/O = 165/1325/800. Stung into the T-PO test port with 0 psi. Pressured up the T-PO test void to 4500 psi with hydraulic fluid 15 min reading 4500 psi, 30 min reading 4500 psi. Bled down the T-PO test void to 0 psi. Stung into IC-TP with 0 psi. Pressured up IC-TP test void to 3000 psi with hydraulic fluid 15 min reading 3000 psi. 30 min reading - 3000 psi for a total loss of 0 psi during test. Bled IC TP down to 0 psi. Shut in the WH and GL and shot the initial IA FL @ 4727' sta. # 2 OV. Stacked out the T with LG. Bled down the IA and shot the-2nd IA FL @ the same location. Final T/I/O = 165/1325/750. MITOA-passed. Initial T/I/0= 165/1330/800. Pressure up the OA to 1800 psi. with 1.5 bbls.of diesel. T/I/0= 165/1300/1800. 15 min. T/I/0= 165/1300/1790, 30 min. T/I/0= 165/1300/1790, Bled down the OA. Final T/I/0= 15/1250/500. 6/11/08 -LOADED IA/TBG W/ DIESEL. PERFORMED COMBO MIT TO 2500 PSI- PASS. SET DV @ 4727' RKB & MIT-T 2500 PSIG- PASS. PULLED CAT SV @ 8491' RKB. PERFORMED 30 min SBHPS @ 9059'=3012 PSI, 157 DEG F. 15 MIN GRADIENT STOP MADE @ 8907'=2970 PSI. 6/15/08 -PERFORATED FROM 8136'-8138' WITH 2" HYPERJET 6SPF HSD GUNS. INFORMED AFTER SHOOTING THAT THE INTENDED INTERVAL WAS 9136'-9138' 6/17/08 -PERFORATE INTERVAL 9136'-9138' WITH 2" HYPERJET 6SPF 60-DEG PHASED HSD CHARGES. SET 2.81" CA-2 BLANKING PLUG @ 8491' RKB, SET 2.72" CATCHER, OAL=88" ON TOP OF PLUG. 6/23/?00$ b air, .r ~d ~ d1S'°llG L- ll lld/ ll73'°4~21eE3 ~191~ Oat~v~5'ILdll ~'3Gdli • 6/1E/06 - ATTEIViPTED CIUdIT, PIJIUIPING D®WN THE TUBING, UNABLE ~® PRESSt1RE ~JP T® 2500 PSI ESTABLISH LIC~IJID LEAK RATE ®F 0.5 113E/11~IN @ 2100 PSI. C~lIIT, START ~/Il®= 1790/1920/0, 15 MIN T/I/®= 1630/1320/0, 30 MII~ T/Il®= 162011770/0, 45 IVlli~ T/I/G = 1n05/1760/0 BLED T ~ IA TG 0 PSI F®R DRAW D®WN TEST - T. START T/I/® = 0/0/0. 15 fllilN. READING T/I/®= 0/0/0. 30 nlI1N. READING T/I/®= 0/0/0. Sincerely, Perry Klein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 6/23/2008 ~~u~d~~9 Th®m~~ ~ (~®A~ Frorno NSK Well Integrity Proj [N1878@conocophillips.com] Berate Tuesday, June 17, 2008 2:31 PM °to: Maunder, Thomas E (DOA) Cca NSK Problem Well Supv Saelsjecta Notification of T X IA 1 D-12 PTD 199-084 Attachmeratsa 1D-12.pdf Tom, On 6/15/08, 1 D-12 PTD 199-084, gas lift producer, was mistakenly pertorated off depth with 2' of 2" 6 spf, Hyperjet HSD guns from 8136-8138'. The well has T x IA communication and possibly IA by formation communication. The scope of the job was to prepare the well for a coiled tubing side track, sundry # 308-204. The job was designed to shoot pre cement squeeze holes at 9136-9138'. The holes were shot throu2 h the tubing above the packer, between gas lift mandrels 5 and 6. On 6/16/08 a standing valve was set in the profile at 8491 and a combination MIT was performed. Pre T/I/O = 1600 / 1720 / 25 psi Initial T/I/O = 2370 / 2500 / 25 psi 15 min T/I!O = 2280 / 2410 / 25 psi 30 min T/I/O = 2220 / 2350 / 25 psi 45 min T/I/O = 2160 / 2290 / 25 psi 60 min T/I/O = 2110 / 2240 / 25 psi 75 min T/I/O = 2060 / 2180 / 25 psi The MIT pressure loss with time is within the 5% - 10% rule but fails to stabilize and exhibits a loss of approximately 50 psi every 15 minutes. Immediate action will be to shoot squeeze pert at 9136-9138 per sundry approval. Set a positive pressure plug in the profile at 8491' and reattempt the combo MIT. Please contact me with any questions. Perry Kfein Well Integrity Project Supervisor ConocoPhillips Alaska, Inc. Desk Phone (907) 659-7043 Cell Phone (907) 943-1244 «1 D-12.pdf» 6/19/2008 r s _ ~ C:catir-~rc~~'t~illi~~5 - .. ~~~ _ -\NC ll conrG - ~. D.'.2 ~3:20G6 'fji'i ', F31 _- ~d~°ngl:c~. ool Y;3,i. Con:l:.xlo~ nw soc s.szs s~,na« GAS ll FT 6 651 `"~ GAS LIFI l.fi64 ' GAS LI FT. ~1 8_=56 NIP. 8.408 XO. 8.448 PBft. 8.483 PACKER. 8467 8502 TUBING. 8,502 NIP 8538 SEAL. 8.546 '.001-5031. 912/2004 1051-0.065 4122004 1454-5085 116/1995 i 1%19.161 111.11999 ~tlf ~ 1 ~~`~ ~ ~. ~ ~ r. , Wellbore API/UWI Field N ma Wall S¢eturs Maximum Inclin+ltion (°j Tctal Depth (fiK6) 5002922948 0 0 I(UPARUK F;IVEH 11N11 F'R_OU 50:8fi 4,24$0 . . Cnmrn^nt H23 (ppm! DaN Annotation ?nd Ua¢e KBGrtl (fi) Rig Relcaae Daie La61N/o !1/ie/2oo3 10430 9/zon9ss 'Amlotatior~ Depth (BKB) End Uatc Annotation End Date Last Tag. 9,166.0 418/200/ Rev Reason fA0 4111/2007 Casing Description OD (in) ID (in) Top (ftKB) Set Depth (ftKB)~ Set Depth (ND) (NKB) YJt Obo/ft). Grade Top Thread Conductor I6 15 062 0 G 121 0 ~i 71.0 62.5E h1 ~4U d'JL LDEO Sudace 95/8 G G9i 0 0 5,64!.C 4326 7 40.00 L-80 B~fC-MOU Production 7 6.059 194.0 8.696.0 6,323.6 26.001.-8U BTGMOD Thread p (RKB) ', Description To Comment Run Date ID (inl _ 230'HANGER FMC TUBING BANGER 11116/2003 3.958 500.0 NIP CAMCO'DB' LANDING NIPPLE 1'111612003 3 813 963.0 GAS LIFT 2 CAMCO/KBG-2/1IGLV/81(-51.1 5 611 2 64 / Comment J/28/2007 3.938 , 4,727.OGAS LIFT CAMCOIKBG-2/1/OV/BK-51313/1 Comment 3/28/2007 3938 5,525.0'GAS LIFT CAMCOIKBG-2IIIDMVIBK-5l// Comment 5/28/2005 3.938 6,651 0 OAS LIFT CAMCO/KBG-211IDMY/BK-5l/I Carrimerrt. 11/1812003 3.938 7,654.0 GAS LIFT CAMCOIKBG-2/1IDMY/BK-5//I Commem. 1111812003 3.938 8,356.0 GAS LIFT C,4MCOIKBG-217/DMYIBK-~5//I Cammenr 1112612003 3.938 8,408.0 NIP CAMCO'DB'NIPPLE 11/1612003 3.750 8,4460X0 1111612003 3.000 8,453.O~PBH BAKER 80-40 11/16/2003 3.000 8,467 O~PACKER BAKER RETRIEVABLE PACKER 11/16/2003 3.000 8,491.O~NIP CAMCO 'DS' NO GO NIPPLE 11/1612003 2.812 8,502.O,TUBING ORIGINAL TUBING, CHEMICALLY CUT @ 8.502' 9/20/1999 2.992 8,5020~Overshot POOR BOV OVERSHOT 11/1612003 3.750 8,538 0 NIP CAMCO D NIPPLE 9/20/1999 2.750 TOp (TVD) Btm (TVD) Dens uShot To ~et Total Date Zone Iah fi Comment 9,0010 9A370 6,522.5 6,54281APERF 180 4/212004 .O 2 5' HSD PJ 9,051.0' 9,065.0 6,556.3 ~ 6,565 7'RPERF _ 6.0 84',4/2/2004 2 5" HSD PJ _ 9,064.0' 9,089.0 6,565.0'. 6.582 1 APERF 4.0 100 ~ 1 118/1999 2.5" HC. DP. 180 deg +/- 90 deg low side 9,171.0 9,181.0 6,636.2 6,642.B~IPERF 4.0' 4011/5/1999 2.5"HC, DP, 180 deg+/-90 deg low side /~ ~ ~~'~ ro e.zne jJi~ ~ ~ ~ G SARAH PAL/N, GOVERNOR COP1T5FiRQ~A'ls`IO COIrII-IISS O 333 W. 7th AVENUE, SUITE 100 ANCHORAGE, ALASKA 99501-3539 PHONE (907) 279-1433 Gary Eller FAx (so7> 27s-7x42 CT Drilling Engineer ConocoPhillips Alaska Inc. c/o PO Box 196612 Anchorage AK 99519-6612 Re: Kuparuk River Field, Kuparuk River Oil Pool, Kuparuk 1 D-12L2 ConocoPhillips Alaska Inc. Permit No: 208-105 Surface Location: 224' FSL, 594' FEL, SEC. 14, T11N, R10E, UM Bottomhole Location: 620' FSL, 1601' FWL, SEC. 18, T11N, R11E, UM Dear Mr. Eller: Enclosed is the approved application for permit to redrill the above referenced development well. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 {pager). Sincerely, aniel T. Seamount, Jr. d Chair r DATED this ~ day of June, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ~~G~ Y ALAS~IL AND GAS CONSERVATION COMMI`ON JU~I 0 9 2008 PERMIT TO DRILL h3 20 AAC 25.005 Alaska 0'sl & Gay ~c~ns. Cornrrtissinn 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 we~~~ d for: ^Coalbed Methane L3 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-12L2 ' 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 10900' TVD 6490'ss 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): ' ' 7. Property Designation: ~~Zt+V 1L ZS~~~ADL - River Pool 1 ~-og FEL, SEC. 14, T11N, R10E, UM 224 FSL, 594 Top of Productive Horizon: 460' FSL, 5056' FWL, SEC. 13, T11N, R10E, UM 8. Land Use ermit: 13. Approximate Spud Date: July 2008 Total Depth: 620' FSL, 1601' FWL, SEC. 18, T11 N, R11 E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 9925' 4b. Location of Well (State Base Plane Coordinates): Surface: x-560491 y-5959889 • Zone-ASP4 10. KB Elevation (Height above GL): 104.3 feet 15. Distance to Nearest Well Within Pool: 240' 16. Deviated Wells: Kickoff Depth: 8120 ~ feet Maximum Hole An le: 92 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3259 Surface: 2621 f8. Casin Pr ram`. S cificatio ris To = Settin De th = Bo ttom Quanti of` `ment c.f. or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 3" 2-3/8" 4.7# L-80 STL 1800' 9100' 6485'ss 10900' 6490'ss Uncemented Slotted Liner g g. PRESE NT: WELL CONDITION S UMMARY (To be completed for: Redrill'and Re-entry Operations) Total Depth MD (ft): 9250' Total Depth TVD (ft): 6688' Plugs (measured): None Effective Depth MD (ft): 9205' Effective Depth TVD (ft): 6659' Junk (measured): None 'Casing Length ize Cement Volume MD TVD Conductor /Structural 115' 16" 230 sx Ar ticset I 115' 115' Surface 5641' 9-5/8" 676 sx Class'G' 600 sx Class'G' 5641' 4328' Intermediate 8696' 7" 210 sx Class'G' 8696' 6323' Produ ti n Liner 707' 3-1/2" 164 sx Class'G' 8541' - 9248' 6223' - 6687' Liner L1 1565' 2-3/8" Uncemented Slotted Liner 9135' - 6508' 10700' - 6524' Perforation Depth MD (ft): 9001' - 9181' Perforation Depth TVD (ft): 6523' - 6643' 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 c 'fy that the fore oing is true and correct. .Contact Gary EI-er, 263-4172 (Office) Printed Na Gary Eller Title CT Drilling Engineer Gary Eller, 529-1979 (Cell) Prepared By Name/Number: Si nature Phone 263-4172 Date Terrie Hubble, 56a-x628 Commission Use Onl Permit To Drill Number: 2~'~~S'~ API Number: 50-029-22948-61-00 Permit Approva C7 Date: a See cover letter for other re irements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce Coalbed me~tha/ne, gas hydrates, or gas contained shales: ~.,/ Samples Req'd: ^ Yes LrJ No Mud Log Req'd: ^ Yes 1!Q No HZS Measures: ['Yes ^ No Directional Survey Req'd: ['Yes ^ No Other: 3S®O ~S•~ ~®~ ~.5~ °' APPROVED BY THE COMMISSION Date ,COMMISSIONER Form 1U-4~ Revised~l2l2t)05 U K i~ Y /J 1 Su~~ In Duplicate Y / ~ L ~• /5' . bS -'~~%/~ Summary of Operations: KRU 1 D-12L1, L2 Laterals -Coiled Tubing Drilling Well 1D-12 is a 41h" tubing x 31/z" liner producer in the Kuparuk C-sand. Two proposed CTD laterals will improve sweep efficiency and reserve recovery, and also reduce water cut. Prior to drilling these laterals, the existing C-sand perfs in 1D-12 will be squeezed with cement to isolate a thief zone in the C4 sand. After the CTD laterals are completed, the squeeze thief interval will be isolated by a retrievable tubing patch to prevent the squeeze from breaking down during production. The 1D-12L1 lateral will exit the 31/2" liner at 9135' MD and will target the C1 sand southeast of the existing well with a 1565' undulating wellbore. The hole will be completed with a 23/8" slotted liner to the TD of 10,700' MD with the final liner top located just inside the existing 31/z" liner. The 1D-12L21ateral will exit the 31/z" liner at 9100' MD and will target the C3/4 sand east of the existing well .~ with a 1800' wellbore. The hole will be completed with a 23/8" slotted liner to the TD of 10,900' MD with the , final liner top located just inside the existing 31/z" liner. CTD Drill and Complete 1D-12 program: .Tuly 2008 Pre-Rig Work 1. Test packoffs - T & IC. 2. Positive pressure and drawdown tests on MV and SV. 3. MIT-OA. Rig Work 1. 2. ~ ~ e'~Z ~~,~ 4. 5. 4. DGLV's, load tbg & IA. MIT-IA. 5. Obtain updated static BHP on C sand after 3-5 day shut-in 6. RU CTU. Squeeze the C-sand perfs with cement. Drill out, pressure test squeeze perfs. 7. RU slickline. Run drift for 31/z" monobore whipstock. 8. Prep site for Nordic 2 MIRU Nordic Rig #2 using 2" coil tubing. NU 7-1/16" BOPE, test. 1D-12L1 Lateral a. Set 31h" monobore whipstock at 9135' MD at 20° ROHS. b. Mi112.74" window with 20° ROHS orientation at 9135' MD c. Dri112.70" x 3" bi-center lateral to the southeast to TD of 10,700' MD. d. Kill well. Run 23/8" slotted liner from TD up to the window 1D-12L2 Lateral a. Set 31/z" whipstock on a KB packer at 9100' MD b. Mi112.74" window with high-side orientation at 9100' MD c. Dri112.70" x 3" bi-center lateral to the southeast to TD of 10,900' MD. d. Kill well. Run 23/8" slotted liner from TD up to the window e. Retrieve the whipstock tray for the L2 lateral, leaving behind the KB packer Install straddle across squeezed thief zone at 9056' - 9065' Freeze protect. ND BOPE. RDMO Nordic 2. Post-Rig Work 1. Obtain static BHP 2. Run GLVs. 3. Return well to production. Page 1 of 3 June 5, 2008, FINAL • • KRU 1 D-12L1, L2 Laterals -Coiled Tubing Drilling Mud Program: • Will use chloride-based Biozan brine (8.5 ppg) for milling operations, and chloride-based Flo-Pro mud (~8.6 ppg) for drilling operations. Since there is no SCSSV installed in 1D-12, we will have to kill the well to deploy 23/8" slotted liner. Disposal: • No annular injection on this well. • Class II liquids to KRU 1R Pad Class II disposal well • Class II drill solids to Grind & Inject at PBU Drill site 4 • Class I wastes will go to Pad 3 for disposal. Casing Program: • 1D-12L1: 23/8", 4.7#, L-80, ST-L slotted liner from 9135' MD to 10,700' MD ,~,_,~, • 1D-12L2: 23/8", 4.7#, L-80, ST-L slotted liner from 9100' MD to 10,900' MD Existing Casing/Liner Information Surface: 95/8", L-80, 40 ppf Burst 5750 psi; Collapse 3090 psi. Production: 7", L-80, 26 ppf Burst 7240 psi; Collapse 5410 psi Liner: 3'h", L-80, 9.3 ppf Burst 10160 psi; Collapse 10530 psi Well Control: • Two well bore volumes 0300 bbl) of KWF will be available to the rig during drilling operations. The kill weight fluid may or may not be stored onsite, but if it is stored offsite it will be in the Kuparuk Field within a short drive to the rig. • BOP diagram is attached for operations with 2" coil tubing. • Pipe rams, blind rams and the CT pack off will be pressure tested to 250 psi and to 3000 psi. Maximum potential surface pressure is 2621 psi assuming a gas gradient to surface and maximum potential formation pressure (i.e. based on highest bottom hole pressure measurement in the vicinity, which is 3259 psi in offset injector 1D-10 in September 2007). • The annular preventer will be tested to 250 psi and 2500 psi. Directional: • See attached directional plans. • Magnetic and inclination surveys will be taken every 30 ft. No gyro will be run. • 1D-12L1 TD: 11,425' to property line, 965' from well 1D-28 at 9525' MD ~~ • 1D-12L2 TD: 9925' to property line, 240' from well 1D-28 at 10,883' MD Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Reservoir Pressure The most recent static BHP survey in well 1D-12 was taken June 2007 which measured reservoir pressure of 3043 psi at 8491'MD, 6190' TVD, which corresponds to 9.5 ppg EMW. Expect to encounter similar to slightly increasing pressure as the laterals are drilled away from the mother well, although higher pressures could be encountered with unexpected fault crossings. Page 2 of 3 June 5, 2008, FINAL KRU 1 D-12L1, L2 Laterals -Coiled Tubing Drilling Hazards • Lost circulation is not expected to be particularly troublesome. Expect to encounter similar to slightly increasing pressure as the laterals are drilled away from the mother well. • Well 1D-12 has 100 ppm H2S as measured on 7/2/07. Wells 1D-O1 and 1D-14 are located 15' to either side of the 1D-12 surface location. The 1D-14 has no measured H2S since it is an injector. The H2S - measured in 1D-Ol is 80 ppm: The maximum H2S level on the 1D pad is 130 ppm from well 1D-30 (7/2/07). All H2S monitoring equipment will be operational. - Managed Pressure Drilling Managed pressure drilling (MPD) techniques will be employed to provide constant bottom hole pressure by using 8.6 ppg drilling fluid in combination with annular friction losses and applied surface pressure. Constant BHP will be utilized to reduce pressure fluctuations to help with hole stability. Applying annular friction and choke pressure also allow use of less expensive drilling fluid and minimizes fluid losses and/or fracturing at the end of the long well bores. A hydraulic choke for regulating surface pressure will be installed between the BOPE choke manifold and the mud pits, and will be independent of the BOPE choke. Using this technique will require deployment of the BHA under trapped wellhead pressure. Pressure deployment of the 23/8" BHA will be accomplished utilizing the 23/8" pipe rams and slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. Well 1D-12 does not have a SCSSV, so the well will have to be killed prior to running slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Estimated reservoir pressure: 3239 psi at 9100' MD (6589' TVD), or 9.5 ppg EMW. " • Expected annular friction losses while circulating: 546 psi (assuming friction of 60 psi/1000 ft due to the 4'h" tubing) . • Planned mud density: 8.6 ppg equates to 2947 psi hydrostatic bottom hole pressure at 6589' TVD • While circulating 8.6 ppg mud, bottom hole circulating pressure is estimated to be 3493 psi or 10.2 ppg EMW without holding any additional surface pressure. This will sufficiently overbalance formation pressure in 1D-12. If increased formation pressure is encountered while drilling the L1 or the L2 lateral, mud weight or choke pressure will be increased to maintain overbalance. • When circulation is stopped, it is anticipated that 550 psi of surface pressure shall have to be applied to balance reservoir pressure and maintain the same borehole pressure as during drilling operations. Page 3 of 3 June 5, 2008, FINAL KRU 1 D-12 ,~ C~-no~+~Phil~ips Alaska, Ir~c. API: 500292294800 Well T e: PROD A le TS. 49 de a~ 9002 7uslNC - (0.8502, 500 OD 4 ~ SSSV Type: Nipple Orig COm letion: 9/20/1999 Angle @ TD: 49 deg @ 9250 : . , ID:3.95a) Annular Fluid; Last W/O: 11/18/2003 Rev Reason: TAG Reference Lo : Ref Lo Date: Last U ate: 4/11/2007 Last Ta : 9166 TD: 9250 ftK6 Last Ta Date' 4/8/2007 Max Hole Angle: 51 deq na 6650 ___ - .. C in Stri -'ALL" M1~ ,,. <>, _: > ~. Descri lion Size To Bottom TVD Wt Grade Thread i CONDUCTOR 16.000 0 121 121. 62.58 H-40 WELDED SURFACE 9.625 0 5641 4328 40.00 L-80 BTGMOD PRODUCTION 7.000 0 26.00 L-80 BTC-MOD LINER 3.500 8546 9248 6687 9.30 L-80 _ EUE 8R~ ~" u in S ~x __ w , ~<.i; Site To Bottom i ~TVD I~Wt Grade Thread I 4.500 0 ,_ _ ~~ ~ 6198 _~__~7 ,_ L-80 EUE 8RD Interval TVD Zone` Status Ft SPF Date T e Comment ~_ 9001 - 9031 6.524 - 6543 UNIT D C-4 30 6 4/2/2004 APERF 2.5" HSD PJ ~ 9051 - 9064 6557 - 6565 C-4 13 6 4/2/2004 RPERF 2.5" HSD PJ 9064 - 9065 6565 - 6566 C-4 1 10 4/2/2004 RPERF 2.5" HSD PJ 9065 - 9089 6566 - 6582 G4,C-3 24 4 11/8/1999 APERF 2.5" HC, DP, 180 deg +/- 9D de low side 9171 - 9181 6636 - 6643 C-1 10 4 11/5/1999 IPERF 2.5" HC, DP, 180 deg +/- 90 de low side L•~Ma relsNalve ~~ :t - ,,_ ,, , t , F' St MD ND Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt _ ' 1 2963 2586 CAMCO KBG-2 GLV 1.0 BK-5 0.156 1264 3/28/2007 l 2 4727 3734 CAMCO KBG-2 OV 1.0 BK-5 0.313 0 3/28/2007 1 3 5525 4252 CAMCO KBG-2 DMY 1.0 BK-5 0.000 0 5/28/2005 4 6651 4980 CAMCO KBG-2 DMY 1.0 BK-5 0.000 0 11/18/200 5 7654 5634 CAMCO KBG-2 DMY 1.0 BK-5 0.000 0 1/18/200 i~ 6. 8356 6103 CA MCO KBG-2 DMY 1.0 BK-5 0.000 0 1/26/200 Other , u _ ;.,:, e - c. -:JEWELRY:- PO_S_T_WQ_ CI OVER t. _t <,; < .}~~ . 's_ -' De h T VD T e D escn lion ID 23 23 HANGER FMC TUBING HANGER 3.958 500 500 NIP CAMCO'DB' LANDING NIPPLE 3.813 8408 6137 NIP CAMCO'DB'NIPPLE 3.7`~ 8446 6162 XO 3.000 8453 6166 PBR BAKER 80-40 3.000 I!` 8467 6175 PACKER BAKER RETRIEVABLE PACKER 3.000 8491 6191 NIP CAMCO'DS' NO.GO NIPPLE 2.812 8502 6198 Overshot POOR BOY OVERSHOT - 3.750 - - i Ot r s; e ui :'" etc __ ~ '. - J YYE_LRY - ~RtGINAL _ De h ND T e Descri lion ID 8502 6198 TUBING ORIGINAL TUBING, CHEMICALLY CUT .8502' 2.992 853 8 6221 NIP CAMCO D NIPPLE 2.750 $54 6 6226 SEAL BAKER 80-40 SEAL ASSY 3.000 PRODUCTION (0502, OD:7.000, r' wtzs.oo) (s5o ~sNas OD:3.500) NIP (80 X00) SEAL ~u~~ $Z 3,I2\ ~A~4~, - ~54Sr Mfl, . ~oZ25 TV 11 Q pp c C~ \'~ \ `~ ~ ~ ~d~ CUB $r (8546-8547, OD:6.500) Perf (9051-9065) Perf (9064-9069) 1 D-12L1 & L2 Proposed CTD Sidetrack shoe @ 5641' MD 7" 426# L-80 shoe @ 8696' MD C4-sand perfs 900 9031' MD (sgz'd) C4-sand perfs 9051 - 9089' MD (sgz'd ) Snap-latch tray, 3-1/2" KB Packer, 5' pup, 1.71" R nipple. Retrieve tray w/ orienting lug after running liner. Standing valve in tray. C1 leg KOP @ 9135' MD 3-1/2" monobore whipstock C1 sand perfs 9171 - 9181' MD (sgz'd) 3-1/2" 9.3# L-80 shoe ~ @ 9248' MD @ 500' MD (3.813" min ID) 4-1/2" 12.6# L-80 IBT-Mod Tubing to surface Camco KBG-2 gas lift mandrels @ 2963', 4727', 5525', 6651', 7654', MD 1/2" Camco DB landing nipple @ 8408' MD (3.75" min ID) 1/2" x 3-1/2" cross-over @ 8446' MD 1/2" Baker PBR @ 8453' MD 1/2" Baker FHL packer @ 8467' MD Camco DS nipple @ 8491' MD (2.812" min ID) Boy Overshot @ 8502' MD 'cut tubing @ 8502" /2" Camco DS nipple @ 8538' MD (2.75" min ID) <er 3-1/2" 80-40 seal assembly @ 8546' MD (3" ID) BAKER 7"x 3.5" SLZXP LT PACKER & Hanger w/PBR @ 8542' MD Baker SBE @ 8549' MD tingency: dual KB packer straddle (1 ID) covering thief zone 9056' - 9065' ~~~5 ~C(~Y~t~ ConocoPhillips Alaska ConocoPhillips(Alaska) Inc. Kuparuk River Unit Kuparuk 1 D Pad 1 D-12 Plan 4,1 D-12L2 Plan: Plan #4 Baker Hughes INTEQ Planning Report 23 May, 2008 _ .~~~ BAKER M~J~1#$ INTEi~ ~ ConocoPhillips ConocoPhillips Baker Hughes INTEQ Planning Report sa~R ~ ~~$ Alaska INTEQ Company: ConocoPhtiips(Alaska)mc. Local Coordinate Reference: Welt 1 D-12 flrojletc Kupandc River UnU TVD Reference: Mean Sea LevN Site: Kupamk 1 D Pad MD Reference: 1 D-12 ®104.30ft Yihik 1 D-12 Nortl~ Rebtence: True YifeNbore: Plan 4, 1D-12L2 Survey Calculation AAsthod: Minimum CurvaWre Destgn: Plan #4 Database: EDMv16 Prod prglect Kuparuk River Unit, North Slope Alaska Map System: US State Plane 1927 (Exact solution) System Datum: Mean Sea Level rso Dom; NAD 1927 (NADCON CONUS) Using Web Reference Point Map Zone: Alaska Zone 04 Using geodetic scale factor Slte Kuparuk 1 D Pad, KRU Sfte p~~; Northing: 5,959,669.68 ft Latitude: 70° 18' 1.318 N From: Map Fasting: 561,086.44 ft Longitude: 148° 30' 18.921 W PosWon UnceRainty: 0.00 ft Slot Radius: 36 " Grkf Comrergence: 0.47 ° Weft 1 D-12 WeM Positbn +WS 0.00 ft Northing: 5,959,888.87 ft Latkude: 70° 18' 3.521 N +EI-W 0.00 ft Fasting: 560,490.53 ft Longitude: 149° 30' 38.243 W Poskbn UncartahNy 0.00 ft WeNhead Elevation: ft Giround Leval: 0.00 ft tMelWOn Plan 4, 1D-12L2 Magnetics Model Name Sample Oats DecNnation Dip Angle Field Strength 1°) 1°i (n11 BGGM2007 5/23/2008 17.85 79.75 57,283 Dealpn Plan 1Ht Audit Notes: Versba: Phase: PLAN Tie On Deptfi: 9,074.96 .Vertical Section: Depth From (7vD1 +NI-S +E!-W Dlrectlon 1~ (tt) Ittl (°) o.oo o.oo o.oo s1.oo i 5/23/2008 3:36:03PM Page 2 COMPASS 2003.16 Build 42F ~ ConocoPhillips ~~r B ConocoPhillips Baker Hughes INTEQ Planning Report ~"~ Alaska INTEQ tampaay: ConocoPhtllips(Alsaka))nc. local Co-ordinate Reference: Well 1D-12 aj+rpj~; Kuparuk River Unlt ND Reference: Mean Sea Level ~: Kuparuk 1 D Pad tiAD Reference: 1 D-12 (81104.30ft Wsll: 10.12 tdoRh Reference: True Webbora: Plan 4, 1D-12L2 Survey Calcuiatlon Il~athod: Minimum Curvature Des1On: Plan #4 Database: EDMv16 Prod Surny Teol PrglprNa Date Frara Te t>~ (~! Survey (t+NeHhore) Tool Name Deacriptlon 115.00 9,074.96 1D-12 (1D-12) MWD MWD -Standard 9,074.96 10,900.00 Plan #4 (Plan 4, 10-12L2) MWD MWD -Standard PlsruNd Survey MD Inc Azi NDSS N13 ElVH Nortlting Easdng DLS Vertkal Section TPO (fl) CI t°! IfN 1~) Ift! IM t~) (°!10011) f~ Ct 9,074.96 48.07 88.53 6,468.06 239.54 5,704.70 5,960,174.30 566,192.57 1.78 5,899.65 144.73 TIP 9,100.00 48.20 87.12 6,484.78 240.24 5,723.33 5,960,175.15 566,211.20 4.23 5,716.27 -83.41 KOP 9,120.00 50.00 87.12 6,497.87 241.00 5,738.43 5,960,176.04 566,226.28 9.00 5,733.35 0.00 :End oIf Daphtl0' DL8 9,200.00 88.00 87.12 6,527.35 244.67 5,811.30 5,960,180.29 566,299.11 45.00 5,806.14 0.00 9,208.89 90.00 87.12 6,527.86 245.12 5,820.17 5,960,180.81 566,307.98 45.00 5,815.01 0.00 End W ~ OegH00S Dl$ 9,300.00 90.57 76.20 6,527.20 258.31 5,910.18 5,960,194.72 566,397.87 12.00 5,904.77 -87.00 9,378.89 81.05 86.75 6,526.09 283.35 5,984.89 5,960,220.36 566,472.37 12.00 5,979.03 -87.05 ti 9,400.00 91.06 89.28 6,525.70 291.25 6,004.46 5,960,228.41 568,491.87 12.00 5,998.46 89.80 9,500.00 91.11 81.28 6,523.80 316.61 6,100.98 5,960,254.55 566,588.18 12.00 6,094.53 89.65 9,600.00 91.11 93.28 6,521.85 321.34 6,200.67 5,960,260.08 566,687.82 12.00 6,194.12 89.88 9,678.89 91.08 102.75 6,520.34 310.35 6,278.68 5,960,249.72 566,765.91 12.00 .6,272.31 90.11 i . 9,700.00 91.08 100.22 6,519.94 306.15 6,299.37 5,960,245.68 568,786.82 12.00 6,293.08 -90.00 9,800.00 91.05 .88.22 6,518.08 298.81 6,398.90 5,960,239.15 566,886.20 12.00 8,392.71 -90.05 9,900.00 90.97 78.21 6,516.31 312.32 6,497.78 5,960,253.46 566,984.96 12.00 6,491.34 -90.27 9,978.89 90.87 86.75 6,515.04 337.35 6,572.49 5,960,279.08 567,059.46 12.00 6,565.60 -90.48 7 10,000.00 90.96 89.28 8,514.70 345.25 6,592.06 5,960,287.14 567,078.98 12.00 6,585.03 88.00 5/23/2008 3:38:03PM Page 3 COMPASS 2003.16 Build 42F ~ ConocoPhillips ConocoPhillips Baker Hughes INTEQ Planning Report Alaska Company: ConocoPhtlAps(Alaska) Inc. Local Co-ordit~ats Reference: Well 1 D-12 project Kuparuk River Unit ND Reference: Mean Sea Level Site: Kuparuk 1D Pad MO Reference: 1D-12 ®104,30ft WNr 1D-72 NorthReferencs: True WeBbore: Plan 4, 1D-12L2 Survey Cakulatlon Metiwd: Minimum Curvature (~i1Qn: Plan tet4 Database: EDMv16 Prod r~c.r B$ INTEQ Planned Survey MD lac Azt NDSS M!S ENV Plorthing Fasting DLS Vertical S•ctlon 7FD (fN ('1 t°- (rt1 (ftl lftl (Rl (ft) !°I1~1 ifs 1°- 10,100.00 91.35 81.26 6,512.68 370.61 6,688.58 5,960,313.28 567,175.27 12.00 6,881.09 88.04 10,200.00 91.68 93.28 6,510.03 375.36 6,788.25 5,960,318.82 567,274.89 12.00 6,780.66 88.28 10,276.89 91.88 102.74 6,507.58 364.38 6,866.24 5,960,308.48 567,352.96 12.00 8,858.84 88.60 8 10,300.00 81.88 100.21 6,506.88 360.19 6,886.92 5,960,304.45 567,373.66 12.00 6,879.58 -90.00 10,400.00 91.82 88.20 6,503.64 352.87 6,986.41 5,960,297.93 567,473.21 12.00 6,979.19 -90.08 10,500.00 91.68 76.20 6,500.57 366.41 7,085.26 5,960,312.26 567,571.93 12.00 7,077.79 -90.47 10,568.88 91.55 87.93 6,498.62 387.59 7,150.72 5,960,333.98 567,637.21 12.00 7,142.86 -90.84 • 10,800.00 91.54 71.66 6,497.78 398.33 7,179.90 5,960,344.95 567,666.30 12.00 7,171.85 90.00 10,700.00 91.49 83.67 6,495.13 419.65 7,277.38 5,960,367.04 567,763.60 12.00 7,268.95 90.10 10,800.00 91.37 85.67 6,492.63 420.22 7,377.16 5,960,368.42 567,863.36 12.00 7,368.71 90.42 70,900.00 91.19 707.67 6,490.39 400.03 7,474.89 5,960,349.02 567,961.24 12.00 7,466.77 90.72 • `~ 5/23/2008 3:36:03PM Page 4 COMPASS 2003.16 Build 42F 1 ~Ie LEGEND °...e `"` s e3 r C o n o co P h i l l i p s Y iR IR161~ [ OOOC O~Y~~IpS ~1D-1z. 1o-121o-\z v5 ~ „~ „ n ~ ~ ~ 6` Contact Information: Bill Michaelson: Ce11: 907301-3570 \TE(? c 1D-1z, PGn fi, 1D-1211. Plan p6 0 em im Email: hill.michaelson(o~inteq.mm Planw Type TxBet MnXN Orgn Type WS ENJ Fmm TVD lMe1 No TxBel lFfrexml 91.00 SMI 0.00 000 0.00 1o-1z®1w.3on I I ~ ~ ~ I I~ PictecL pIyxDf~ ' I ww: 5o-u ~ wrWxe: Plea So-52u " ' e.~ Imo.. I I ~ I l ~ PIw: PMnw11D-111tIV5 ~. 10.121]) .. °:MU. m,,w - I ~. i i WELL OEr LLB I ~ i } . 161_L? TvPAI rirautM LewlD.w aus .e]av xfxe5111e eaw.ro taamma E.pllalda sla - ~ ----i I ---- , -hWeyH]eM b_ I t - ~KT~ TVFV °_:-~ -1uT I ~4-a 4 LN Y.aW89680.2a 1TOa522N ]C Xa'2AT0 w8'Y'e1.8wW i y ;1'3 Iky lOOOLS 1 ~~ ~ i I I ' Y• ~ t ' I 6oe~ - I . ~ ] W a. .L lUl1 l wpi W ^.. i I ~ ,~ - .- ~y__. ]' ~~ .. SECTION DETFILS RNNOTATIf]I95 I ~~ ' ' ] X Sec MO Inc Azl "ND ~W~3 AEI-W Otp 1Fxe VSec Lapel ss rvD MD MnoWlron 1 _ j ,- - . ~ '. -- 1 8011.96 98.0] BB.SJ &60.00 238.59 5)09.10 000 000 5699.65 6980.08 9019.H6 TIP -.. .-- ---- -.. .. _... 2 3 8100.00 8120.00 18]0 8]12 6181]0 290.29 5]2]33 923 8391 5]102] 5000 8).12 899)e> 211.00 5)30.93 900 00 5133.35 6189.18 810000 KOP 9T e] 9120.00 Ertld8Dey500'OL i 1 5 8208.88 8318.08 9000 0]12 852]88 295.2 5820.1] 9500 000 501501 8105 66]5 fi5L009 28].]5 5881 BB 200 ]300 58]903 652]68 820888 EMd15 Dey100'D 652fi.09 83]8.08 S '~5j+• ~- , p ,--- ; 1'F 8 88>0.89 88]888 9108 0215 fi52031 310.35 02t0.0 2W BB.fiO 62Yl 31 80.> fi8 ]3 651500 331.5 0511.19 200 2000 8565.80 fi520.30 86]8.08 8 851509 991008 ] 2 ed ~ I 0 9 02]8.89 1098089 9 102 i9 B50].9B 389 21 00 8000 BBSB.w 8 55 8]93 38].59 ] 50.]T T00 2]000 ]192 BB fiS0]50 102]809 B 899082 10588.89 9 ~ ~-~ - _ 10 10800.00 9. 0]01 8980.39 90003 ]9]109 52W 90.00 ]188.]] 699039 10900.00 iD - I . I _~ - i i I ~ I 13 I 1 ' -1 I I ~I ~. I I I 0100 9(AO 98W Sqv SAO 5900 5600 SNW e20n n8p 6600 6X00 ]IW ]200 ]900 ]WO )X00 0000 ~ ~ I I I I el I ~ I I 6+ I ; l _. I e I I I 1 u i ~ _ I TIP I ~ ~ ~ '. 2 lOP : ar43 DegNOp DLS - - i I ~ ] : @. p I ~ IUIL±T vBxt} gB ~ 16 2L2 TUg.; I -_ L_ _ .._. ._ __. 1' D 6II~I ..i PLe ~ i ~r f - I w.rur r12 I I llTl I . I i I I I I i ~ I I 6 i i I ' ~ ~ I ~ I I ° .. I I I ~ i I - j ~ I - I ~ I I i ~ l 'I I ~I I 'i I 55 00 5410 S]9D 1]N) SXA 50X0 5490 6000 e0b0 01.0 fi100 6290 nNp e160 61_0 6810 n 48 6]X0 bllq o400 6460 ~ AA ]080 1190 ]+00 TM ]}.0 ]}Xp t990 ]500 >Se0 )610 ]6P0 ] ]90 \ aural4Llev v r Ie01L:iu1 C o n o co P h i l l i p s BwK[R ~--^ -- Contact Information: ~sMe c«,«ol~,au~ EeE ~~r .._, INTF',U "'" BiltMichaelson: Ce11:907301-3570 }yp¢ Tvgel rlamuNOrgnTYFe Nr5 EM'FIwnTW ~~• Emall: tzar ra}erna,IFreelurtll a,ao sk4 Da o.oo ,a.3a bill.michaelsonQinteq.com to-iz ~ tar.oon hqq: ItuWnt Rl^rllrle elte: McFerW lDltl ~~ ~ IUMI: 10.12 i~~i. n.n:wnwho-tzmnato-tzul '""""'" ~•~.`" REFERENCE MFORMATION r p Co-ordinate (NIE) Reference: WeII 7D-12, Trua North Vertical (ND) Reference: 10-12 Q 104.30(1 Section (VSt Reference: Slat-(O.OON, O.OOEI Measuretl DepN Retere ra 1 D-72 ~ 104.30(1 CakuWtwn McDiDa:nMinimum Curvature - ~uparuk Managed Pressure Drillin~ - BOP Configuration for 2" Coil Tubing Well I 1D-12 Floor ~ I 7 1/16" 5000 psi BOP's. ID = 7.06" --' J~ 7 1/16" 5000 psi, RX-46 -~ 7 1/16" 5000 psi RX-46 Tree Size 3-1/8", 5M~ TOT 7 1/16" 5000 psi (RX-46) or ~ 4 1/16" 5000 psi (RX-39) Swab Valve Flow Tee I I ~ ~ I , ---- SSV Master Valve Base Flange Page 1 ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ ~ ~ .. lZ ~-" Z' PTD# ?~8 -/oS -' Development Service Exploratory Stratigraphic Test Non-Conventional Well Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS TEXT FOR APPROVAL LETTER WHAT (OPTIONS) APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well ~~~ ~'~ _ l ~ / ~/ (If last two digits in b permit No. /q •O~° API No. 50- ~~ - ZZ - ~ er are API num production should continue to be reported as a function of the between 60-69) original API number stated above. OT HOLE PII 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 contingent upon issuance of a conservation order approving a spacing the exception. , _ assumes liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coat bed methane is not allowed Well for jname of well) until after LComoanv 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 am. Rev: 7/132007 WELL PERMIT CHECKLIST Field 8 Pool KUPARUK RIVER, KUPARUK RIVOIL - 490100 Well Name: KUPARUK RIV UNIT 1D-12L2 Program DEV Well bore seg ~ PTD#:2089050 Company CONOCOPHILLIPS ALASKA tNG Initial Classll'ype DEV I PEND GeoArea 890 Unit 11160 On10ff Shore On Annular Disposal ^ Administration 1 PetmitfQ~ attached- - - - - - - - - - - - - - - - - - ~ - No - - - - - - - - - - - - - - - - - - - - - - - - - - - - - KQP and tcp-prod interval ir! ARL 2565Q; TDin - _ _ - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Cortected omission on 10-401: 2 Lease ns~mber appropriate- - - - - - - - - - - - - - -- - - - - - - - - - - - - - - - , _ - - - - - - - - - - - _ - - _ 3 Unique welt name andnumbe[- -- --- -- ---- - - -- -- -- -Yes- - -- AD~28243• --- - - -- - ----- --- ------- -- - -- - - -- - 4 Well Ipcafed in a-definedppol _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yee _ _ _ - _ _ _KUPARUK RIVER,-KUPARUK RV Qll. - 49010Q, gpv_erned by Conservation Order No. 4$2C._ - - - _ _ _ _ _ _ 5 Well located proper distance from drilling unikboundary_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Conservation Order No. 482G contains rip spacing restrictions with respect.to dolling unit boundaries. - . _ _ _ _ _ _ 6 Well located proper distanpe from otherwells_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ - . _ _ Conservation Order No. 4$2G has no interwell_spacing-nstrictions, - _ _ _ _ _ _ _ - - _ _ _ _ - _ _ _ _ _ _ _ _ _ 7 Sufficient acreage available in-drilling unit_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _Yes _ _ _ _ Conservation Order No. 432G has no interwellspaeing-restrictions- Wellbor-e will be-more Than 500' from - _ _ _ 8 If deviated, is wellbore plat included _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ . _ _ _ . - _ _ _ _ _ - - - _ Yes _ _ _ _ an external property line where-ownership pr_landpwnershpchanges. - _ _ - _ _ _ . _ _ - _ _ _ _ _ _ _ _ _ _ - _ 9 Ope[atorpnlyaffeptedpartY --- --- --- -- - -- --- -- - Yom- --- --- - -- - - ----- -- ------ --- - - -- - ----- 10 Ope[atorhas_appropriateboDdinforce ----- - -- -- -- - - -- -- Yes - --- --- -- -- -- -- -- --- -- - --- ----- - --- - --- - - - - 11 Permikcanbeisgpedwiihoutconsen(atiprlorder------------------ ---------- Y~-- ----------------------------------------------------- --- --- ---- Appr Date 12 Pem]itcanbeissuedwithoutadministrative-app[oval--------------- ----------Yes__ __--___.__-_----.-------- ---- 13 Can permitbe approved before 15-daY-wait- - - - - - - - - - - Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - SFD 611912008 14 Wflll located within area and strata authorized by_injection Order # (put1Q# in- comments)-(Fpr_ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 15 Allwel~within114_milesreaofreyiewideotified(Forservieewellpnly)_____ ___________NA __ ___-------------------- --- -- -- - -- - - - - -- -- -_- -- 16 Pte-produced injectpe duration of pre production less than 3 months-(For ervice well only) _ _ _NA- - _ _ _ - - - . - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 17 Konoonven, gas conforms to A&31,05:03QG.1.A).(1.2.A-D) - - - - - - - - - - - -NA - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - Englneering 18 Conductor string-Provided------------- ------------------ .--NA--- -- - --- -----Condt~ct4rset_in1(?-12(199-984).----------------------------------- ---- -- - 19 Surfac~_casingproteetsallknownUSRWS___-___----------- --------- -KA--- -----All aquifersexempte4,40CFR_147.1Q2(bu3).__--______----------------- --- ---- 20 CMT-v_oiedequate_tpcircurate-oncpnduptpr8,surfcsg______________ __________NA-- -____SurfapecasingseiiRlD-12.-.________-__________------------------------- 21 CMT_v_ola~quate_torte-inlongstnngto_surfcsg-_____--_--_-- ----------NA_-- -_ --Production-casing set in-1D-12,__-______________--------------- - -- --- 22 CMTwiUcoverailknown_ptoductiyehorizons___-___------------ -----------No-- -----_Slpttedlinarcpmpleiionptanned.______.____________--------------------------- 23 Casing des~ns adequate for G,_T, i3 8~_permafrost_ _ _ _ _ _ - - _ _ - _ - _ _ _ _ _ _ _ _ _ _ NA_ _ _ _ _ _ Qriginal well met design specifications. _ NA for slotted liner,- - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ X 24 Adequate tankdge_or reserve pit _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ Rig equipped with steal pits. No reserve pit planned.- Alt waste-to approved disposal well(s), , - _ _ _ - _ _ _ _ _ _ _ 25 re-drill,bas_a10-403forabandonmenkbeen approved------------ Ifa ---------- NA-- ------308.204to_squaezeCsand,----------------------------------- -- -- --- 26 _ _Rdequate wellbore separationproppsed_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ - _ Proximity analysis performed, Nearest segment is P$~Apprtion of tD-12 and path diverge. - _ _ _ _ _ - _ _ _ _ _ _ 27 If diveriartQqukred,doesitmeetregulatipos____.______-___-- ------------NA__ -_.---@QPStapkvtili already-be inplaee,,___--_______._------------------------ ---- Appr Date 28 Drilling fluid.programschematic-& equip listadequake_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ Maximum expected formaitpn pressure 9,5-EMW, Managed pressure_drilling technique will tie used with 8.6ppg - TEM 612312008 29 BOPts,_dotheymeetregulatipn_________________________ ___________Yes_ __._--_-fluid_andsufficienipressu[etooktain~10,2EMW._______-_------------------------- !~ 30 BOPS-press rating appropriate; test to_(put psig in comments)_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ - _ MASP calculated at 2621 psi. 3500-psi-BOP kestplannad, - . _ _ . - _ _ _ - _ _ _ _ _ - - _ _ - _ _ _ _ _ _ _ - _ _ 31 Chpke_manifpld poroRlieswlAPI_RP-53 (May 84) - - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - - 32 WorKwilloccu[withoutopera6onsbutdown --- - -- - -- - ---- -Yes- ---- --- -- --- - -- -- -- --- ----- -- -- -- -- ------ 33 is presence of H2S gas probable _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ H2$ is repo~ted_at 1 D pad. Mud should preclude tizS on rig. _ Rig has-sensors and alarms. - _ _ - _ _ _ _ _ _ _ _ 34 Mechanical-ccnditicn of wells within AQR yQrrfed (Fprservice wall only) - - - - _ - _ _ _ _ _ _ _ NA- - - - - - - - - - - - - - - - - - - ~ - - - - - - - - - - - - Geology 35 Pe[mitean be issued wlo hydrogen sulfid@ measures _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ _ _ _ KRU 1D-12 measured-190 ppm H2S in June 2008._Measures required. _ _ . _ _ _ - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ - 36 Data-presented onpotential pverpressurezpnes_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes _ _ _ _ . _ Expected reservoirpressure is 9.5-ppm_EMW;_will be driiled_using coiled tubUg,.8,6 _ _ _ _ _ _ _ _ _ - _ _ _ - _ _ _ Appr Date 37 Seismic analysis of shallpwgas zonQS_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- . _ _ _ _ _ pp9 drilling mud and managed pressure drilling techniques to achieve a_cirpulaiing _ _ _ _ .. _ _ - _ _ _ _ _ _ _ _ _ SFD 611912008 38 Seabedcpnditionsurvey_(ifpff-shore)---------------------- ------- -- P!A - - --_-pressure equivalent to102ppgmud._____--_--_---------------- --- - --- 39 Contact namelphone forweekty_progress reppds-(expioratory only] _ _ _ _ _ _ _ _ _ _ _ _ _ _ NA- _ - - - - - - Geologic Commissioner: Engineering Pu Date: Commissio er: Date Com ssi d 6 Z3 ~ Date ~- ~~ ?!~