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207-153
• Image Project Well History file Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~~ ~ - ~ ~~ Well History File Identifier Organizing caone> ^ Two-sided III II~III II III II III ^ Rescan Needed III iIIIII II II III III RE AN DIGITAL DATA OVERSIZED (Scannable) Color Items: Diskettes, No. ( ^ Maps: ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: ^ Other:: BY: Maria Date: ~ /~ ~ /s/ Project Proofing ~I I II ~I ~~ I ~ III I I III BY: ~ Maria Date: ! ~- ~ /s/ Scanning Preparation ~_ x 30 = <3(~ + ~ ~ =TOTAL PAGES '~~ BY: Maria Date:I/p~- ~~ (Count does not include cover sheet) /s/ Production Scanning Stage 1 Page Count from Scanned File: (count does include cover sheet) Page Count Matches Number in Scanning Preparation: ^~YES NO BY: Maria Date: l~~/ ~ ~ /s/ ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II'I II I II II I I III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: Quality Checked 1I) II III) III II'I III 10/6/2005 well History File Cover Page.doc • ~~ q, ,~ So .j. «. W, .. 1 `~~ •r~~• MLCROFILMED 6/30/2010 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc Company Well Name Date ConocoPhillips, Alaska, Inc. 1 L-28L1 a ~~ a-` S~ 12/3/2009 ~ ~ ~~ ~p r ~. BAKED ~~~~~ ~TE~ u Page 1 of 4 DATA SUBMITTAL COMPLIANCE REPORT 12/15/2008 Permit to Drill 2071530 Well Name/No. KUPARUK RIV UNIT 1L-28L1 Operator CONOCOPHILLIPS ALASKA INC MD 11315 TVD 5964 Completion Date 2/26/2008 Completion Status 1-OIL Current Status 1-OIL REQUIRED INFORMATION API No. 50-029-22951-60-00 UIC N Mud Log No Samples No Directional Survey DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / RES / GR / (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / T e Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 11307 13150 Open 3/10/2008 1L-28L2 and 1L-28L2-01 / also on diskette Rpt Directional Survey 11307 13150 Open 3/10/2008 _- _ _ ___ _._ _ _.._ - ---- -- -_ --..- --- --- - -------- -------- ---- - ----- ----- ----- ----- ---. _.._ -- -.. ..--- - --J Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMATION W il C d? Y~' e ore Chips Received? Y / N Analysis Y / N Received? Daily History Received? t~/ N Formation Tops VY N Comments: Compliance Reviewed By: _. ...._..... Date: • STATE OF ALASKA ~~~~IV~C~ ALASKA OIL AND GAS CONSERVATION COM SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG MAR ,~ 6 2008 Alaska bil & Gas Cons. Commission 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended 20AAC 25.105 2oAAC 2e.»o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1b. Well CIA~• ®Developmen Exploratory ^ Service ^ Stratigraphic 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 2/26/2008 12. Permit to Drill Number 207-153 ' 3. Address: clo P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 2!3/2008 ' 13. API Number S0-029-22951-60-00 4a. Location of Well (Governmental Section): Surface: ' ' ' ' 7. Date T.D. Reached 2/8/2008 14. Well Name and Number: Kuparuk 1 L-28L1 89 FSL, 216 FWL, SEC. 29, T11N, R10E, UM Top of Productive Horizon: 3687' FSL, 3158' FWL, SEC. 28, T11 N, R10E, UM 8. KB (ft above MSL): 119.9' Ground (ft MSL): 15. Field /Pool(s): Kuparuk River Unit /Kuparuk Total Depth: 5201' FSL, 3367' FWL, SEC. 28, T11 N, R10E, UM 9. Plug Back Depth (MD+TVD) 13150 6085 River Pool 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 540278 ~ y- 5949060 • Zone- ASP4 10. Total Depth (MD+TVD) 13150 6085 16. Property Designation: ADL 025660 TPI: x- 548467 y_ 5952705 Zone- ASP4 Total Depth: x- 548675 ~ y- 5954221 Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and rioted information er 20 AAC 5.050 19. Water depth, if offshore N/A ft MSL 20. Thickness of Permafrost (TVD): 1650' (Approx.) 21. Logs Obtained (List all logs here and submit electronic and printed information per 20 AAC 25.071): r~~-~,~ '~~ ~ /3~s ~z~ MWD DIR / RES / GR S ~G~"'•w-~ 22. CASING, LINER AND CEMENTING RECORD ~L`. G~ CASING 'SETTING DEPTH MD SETTING DEPTH TVD' HOLE AMOUNT WT. PER FT. GRADE TOP BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surface 115' urf ce 115' 24" 9 cu ds Hi h Earl 9-518" 40# L-80 Surface 6546' Surface 3586' 12-1/4" 7 2 sx AS III 806 sx Class 'G' 7" 26# L-80 Surface 11117' Surface 5796' 8-1/2" 115 sx Class 'G' 3-1/2" 9.3# L-80 10944' 11 56 8' 5964' 6-1/8" 2 5 xCla s'G' 2-3/8" 4.44# L-80 11324' 13150' 5972' 608 ' 3" Uncemented Slotted Liner 23. Open to production or inject ion? ®Yes ^ No 24: TUBING RECORD If Yes, IISt Bach I (MD+TVD of Top & Bottom; Pe nterval Open rforation Size and Number): SIZE DEPTH SET MD PACKER .SET MD 2-318" Slotted Liner ~ ~p\ ~ ~ ~° ~ 3-112", 9.3#, L-80 10956' 10944' MD ~ TVD MD y (~~ TVD 11345' - 1137T 5990' - 6015' 11884' - 12385'/6003' - 5971' 25. ACIO, FRACTURE,r CEMENT SQUEEZE, ETC. 1238$' - 13116' V~5971' - 6069' DEPTH INTERVAL MD AMOUNT Hr KIND OF MATERIAL USED 26. PRODUCTION TEST Date First Production: March 10, 2008 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date Of Test: 3/11/2008 HOUTS Tested: 12 PRODUCTION FOR TEST PERIOD OIL-BBL: ggg GAS-MCF: gg8 WATER-BBL: 1,415 CHOKE SIZE: 15/176 GAS-OIL RATIO: 889 Flow Tubing Press. 237 CaSing Press: 1289 CALCULATED 24-HOUR RATE• OIL-BBL: 1,998 ~ GAS-MCf: 1,775 WATER-BBL: 2,830 OIL GRAVITY-API (CORK): 25.8 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No ~ Sidewal l Cores Ac uired? ^Yes ®No If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results pq~~~lf~1. ~ ~~71. U .i. e_ ~;~T~ None ~ ~ ~` tlo ~ IED ~,»~~~« S ~' Form 10-407 Revised 02/2007 CONTINUED ON REVERSE SIDE i ~3~ 1~ 3 ~+~• ~' rz. ~~ /~ 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AND ERS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested . L7 Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top Kuparuk C 11291' 5943' None (From 1 L-28, Parent Well) Top Kuparuk B 11374' 6012' Base Kuparuk C /Top Kup B 11844' 6012' (Inverted) Top Kuparuk B 13100' 6062' Formation at Total Depth (Name): ~ Top Kuparuk B 13100' 6062' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si d ~3~2~O1D ~ gne Title Drilling Technologist Date Terrie Hubble Kuparuk 1 L-28L1 207-153 Prepared ByNameMumber. Terrie Hubble, 564-4628 Well Number Drilling Engineer: Gary Eller, 263-4172 (Office) Permit No. / A royal N . INSTRUCTIONS GeNewu: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITeM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITeM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. ITeM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. ITeM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITeM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only BP AMERICA Page 1 of 25 ~~ Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours ~~ Task Code NPT Phase Description of Operations 1 /27/2008 00:00 - 0.00 STW H I P 1 /28/2008 0.00 1/29/2008 04:00 - 05:00 1.00 MOB P 05:00 - 05:30 0.50 MOB P 05:30 - 00:00 18.50 MOB P 1/30/2008 00:00 - 01:30 1.50 MOB P 01:30 - 06:00 4.50 MOB P 06:00 - 06:30 0.50 MOB P 06:30 - 00:00 17.50 MOB P 1/31/2008 00:00 - 00:30 0.50 MOB 00:30 - 05:15 4.75 MOB 05:15 - 06:00 0.75 MOB 06:00 - 17:30 11.50 MOB P 17:30 - 18:30 I 1.001 MOB I P 18:30 - 21:00 2.50 MOB P 21:00 - 00:00 3.00 BOPSU P 2/1/2008 100:00 - 06:00 6.001 BOPSUp P 06:00 - 08:15 I 2.25 08:15 - 08:35 0.33 08:35 - 12:00 3.42 P P P WEXIT PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE PRE Move off C-35 and pulled to side of Pad waiting on Security PJSM with Security and plan forward Move rig to Spin Road and conducted crew change at 06:00 hrs. Crew change near Mllne Pt access road. Continue to move rig. Continue to move rig. Rig on 1 L pad. Prep to scope derrick. Unload equipment from trucks and spot same. Prep location for spotting rig. Crew Change and PJSM. Raised derrick, RU floor. DTH working on prep location for rig. Move in heavy equipment and discussed plan forward on prep location - 6" hole in the spot for the rig. Installed 11 rig mats in hole and leveled rig Placed dirt around the mats and elimated the trip hazard. Nordic checked their choke and kill hose and they were ok, no material lost. Located and picked up a 3-1/8 SSV for the new MPD circ loop. Serviced injector and swapped gripper blocks and rebuild pack off. Stem III on reel stand and changed sprocket to 2" CT, Loaded SSV in cellar and RU to move over well PJSM on moving over well and idscussed hazards Move rig over well and set down Rig accepted at 0200 hrs oaded 410 bbl of 1 % KCL with 2 ppb biozan PJSM with Veco on loading reel in reel house. NU BOP and choke and kill lines Build tank farm at Drilling Toolhouse pad for mud storage. Loaded reel in reel house NU BOPS. Install 3-1/18" 5k SSV on wing valve. Spot office trailer and plug in. Held meeting with CPF 1 Engineer and Lead tech Hold pre spud mtg with all crews. Review well plan and planned operations. Also review HSE protocall for reporting, tracking, etc. Continue to make up SSV equipment. Complete NU BOPs. Grease chioke manifold. Pressure test BOP equipment as per driling permit to 250 psi and 3500 psi Test witness waived by AOGCC J. Crisg~ Continue to test BOP equipment. BOP PT Passed Redress upper 2" combi seals. Re-test with 2nd test joint. Still leaking. Replace 2" combi seals with proper seal components. 2-2/8" combis not testing. Redress seals in same. and tested same, passed. RD test equipment and make ready to PT the hardline to the tiger tank PT the hardline to the tiger tank to 3500 psi with diesel. PJSM on pulling BPV RU lubricator and PT. Stabbed into FMC IS-A BPV. WHP at 1900 psi. Stroked out and didn't recover BPV. Rebuild the Printed: 3/12/2008 11:46:54 AM BP AMERICA Operations Summary Report Page 2 of 25 ~ Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/1/2008 108:35 - 12:00 I 3.421 BOPSUR P I I PRE 12:00 - 13:45 I 1.751 BOPSUR P I I PRE 13:45 - 14:45 I 1.001 BOPSUR P I I PRE 14:45 - 15:00 0.25 BOPSU~P PRE 15:00 - 17:15 2.25 BOPSU P PRE 17:15 - 18:30 1.25 RIGU P PRE 18:30 - 20:30 2.00 RIGU P PRE 20:30 - 22:30 2.00 RIGU N SFAL PRE 22:30 - 00:00 1.50 RIGU P PRE 2/2/2008 00:00 - 01:30 1.50 RIGU P PRE 01:30 - 03:30 2.00 KILL P WEXIT 03:30 - 04:30 1.00 KILL P WEXIT 04:30 - 06:35 2.08 STWHIP P WEXIT 06:35 - 09:20 2.75 STWHIP P WEXIT 09:20-09:301 0.171STWHIPIP I (WEXIT releasing tool. RIH and latched into the BPV and POOH, WHP = 1700 psi. SWI and bleed pressure down to tiger tank. Didn't recover BPV Rebuild tool and go to Kup shop to get replacement. Used the old style and recovered the BPV. WHP = 2025 psi. RD FMC lubricator Welded on the wireline winch pad eye using a Nordic certified welder. The pad eyes were pull tested using a strain gauge to 2500 Ib Held PJSM on pulling CT across Stabbed pack off on well and then injector on the packoff. Thread cable through injector and pull test grapple back at reel. Pull the CT across the pipe shed. Stab in the injector and packoff. Megged wire 1500 meg ohms 49 ohms. Sealed eline and stabbed on well. LRS pumped 10 bbl of MEOH down the coiled tubing. Blow down line to tiger tank several times. Presure test packoff and inner reel valve to 3500 psi. Reverse circulate through coil to pump a-line slack back into reel. Heard a-line move in reel, but end of a-line was still out end of coil. Did not cut any coil. Begin installing kendal connector. Found a-line wadded up inside the end of the coil. Cut off coil and prepare to pump slack again. Coil frozen. Cut 150' of coil. MU kendal a-line connector. Having trouble with continuity. Re install electrical pin connector. Continue to MU a-coil connector. Having some trouble with continuity. Connector tests ok. Hold PJSM with crew to discuss well kill procedure. Get on well with injector. PT lubricator etc to 3000 psi. Line up to pump down coil and kill line. Pressure to 2100 psi. Open swab and master valves. 3.5 bpm at 2000 psi ISITP. Pump 1.05 bpm down coil, 2.61 down backside. WHP slowly droping until biozan to perfs, then slowly increased. 1550 psi WHP at 3.8 bpm final injection pressure. Pump 200 bbls total. Well bore volume is +/-95 bbls. Shut in well. Get off well with injector. Install night cap and blow down kill line. Open well and monitor WHP. Zero WHP. Circulate across the top and monitor fluid level. MU whipstock setting BHA. Orient lug to HS tool face on BHI orienter. Offsite is 25/213'360=42 deg. Open EDC Set counter at 72.34 and RIH Stopped at 1100 ft, trouble with levelwind override. Repaired same. Stopped at 6950 ft and seen fluid loss to formation at 0.4 bpm PU at 11,230 ft =22.4 k PU weight RIH and started logging at 11,230 ft Log tie- in at 11330 ft logging Corrected -3 ft Sec ounter to Printed: 3/12/2008 11:46:54 AM BP AMERICA Operations Summary Report Page 3 of 25 Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To ~' Hours Task Code NPT Phase Description of Operations 2/2/2008 09:20 - 09:30 0.17 STWHIP P WEXIT 11257 ft 09:30 - 10:00 0.50 STWHIP P WEXIT RIH and to ed the latch at 11 322 ft. Orientation of the latch is at 36 deg LOHS. Set down 3k, KB packer set looks good. . PU and cocked jars and set 2000 Ib down on latch and wait for jars to go off. Sheared off PU and released from latch. WS set at 11315 ft. Whipstock tray face is at 36 deg left of highside. 10:00 - 12:05 2.08 STWHIP P WEXIT Open EDC, POOH 12:05 - 14:45 2.67 STWHIP P WEXIT OOH, closed EDC and check for flow held PJSM. Vp = 261 bbl Once out of the hole circulation was 1:1 ratio Installed the circulating line for the MPD while out of the hole. 14:45 - 17:00 2.25 STWHIP P WEXIT RIH to mill window 17:00 - 17:30 0.50 STWHIP P WEXIT RIH to 11280 ft and logged tie-in Corrected -7 ft 17:30 - 19:30 2.00 STWHIP N DFAL WEXIT SD pump and closed the EDC. BHI software showed a Positiion Missed Error, Which means the EDC is still open and unable to pump. PUH slowly while BHI Steve is working on the problem. Lined up to fill across the top while working CT out of the hole, POOH due to tool failure 19:30 - 20:30 1.00 STWHIP N DFAL WEXIT Hold PJSM while POH. Blow down kill line at 350'. Flow check well. Get off well. Change out Inteq EDC tool. MU to coil and test BHA. Get on well. 20:30 - 23:00 2.50 STWHIP N DFAL WEXIT Run in hole. Circ at min rate with EDC closed. 23:00 - 23:15 0.25 STWHIP N WEXIT Log gr tie in from 11,275'. Add 1.5' correction. 23:15 - 00:00 0.75 STWHIP P WEXIT Tag WS at 11313'. Be in millin to establish attern. 3300 psi fs at 1.50 in/.75 out. Multiple stalls. Begin making progress. 2/3/2008 00:00 - 06:00 6.00 STWHIP P WEXIT Continue to time mill window from 11315.1' : 0.1' per 6 minutes. Having problems with Inteq power supplies on surface. Bypass UPS system. 3400 psi fs at 1.63 in/1.05 out. DHWOB: 0.35 k# ECD/BHP: 11.48 ppg/3442 psi. 06:00 - 07:20 1.33 STWHIP P WEXIT Drilling rat hole at 10 fph 11,319 ft to 11,328 ft Op = 1.63 / 1.29 bpm at 3827 psi ECD /BHP = 11.59 ppg / 3479 psi 07:20 - 07:40 0.33 STWHIP P WEXIT Reaming window area. Reamed window 3 times without incident and dry tagged 11,328 ft 07:40 - 09:50 2.17 STWHIP P WEXIT POOH, open EDC and POOH at max flowrate Op = 2.52 / 1.93 BPM, tossing 0.23 bm at 93 fpm 09:50 - 11:00 1.17 STWHIP P WEXIT Checked flow, OK, unstabbed injector. LD BHA. Gauage window mill at 2.73" tight and string mill at 2.74" go. Load out BOT tools 11:00 - 14:30 3.50 DRILL P PROD1 Held PJSM and PU 60 ft of 4-1/2" TOT lubricator. Nordic crew change and held PJSM with crew on plan forward. Stab upper sheave and stabbed 0.125" wire in lubricator. 14:30 - 14:45 0.25 DRILL P PROD1 PJSM on PU BHA 14:45 - 15:30 0.75 DRILL P PROD1 PU Build Section BHA with 2.5+ AKO setting PU 3 ft lubricator. Simulated Pressure deploy RIH with BHA and closed BOP #13 (2-3/8" Combi's) Stripped on the well and secured chain tension and open BOP #13 Zero the counter and PUH and tagged 0.76 ft. For pressure deploying, tag up, set Printed: 3/12/2008 11:46:54 AM BP AMERICA Page 4 of 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/3/2008 14:45 - 15:30 0.75 DRILL P PROD1 counter to zero and slack off 0.76 ft and then set the 2-3/8" combi's 15:30 - 17:55 2.42 DRILL P PROD1 RIH with with EDC open, Started Mud Swap by sucking out pits and pumping flo-pro down coiled tubing Corrected -9 ft. Closed EDC and RIH and tagged bottom at 11,328 ft 17:55 - 21:00 3.08 DRILL P PROD1 Drillin build section from 11 328 ft to 11 37 ' TF at 30L for 40 ft and then roll to 60L to get the turn Qp = 1.60 / 1.33 bpm Losses getting less as footage is drilled BHP /ECD = 3,386 psi at 11.18 ppg 21:00 - 00:00 3.00 DRILL P PROD1 Drill ahead in build section. 3100 psi fs at 1.65 in/1.49 out. 100-150 psi mtr wrk. 1.Ok# DHWOB. ROP: 10-30 fph. Frequent stalls. BHP/ECD: 3377 psi/11.08 ppg. PVT:248 bbls. Continue drilling at TF: 60L to get turn. INC: +/-40 deg. First good survey data showing 40 then two 60 deg doglegs. Most is in turn, but need to trip to reduce motor bend. 2/4/2008 00:00 - 02:30 2.50 DRILL P PRODi Pull out of hole for motor angle change. Open EDC. Circ at 2.05 in/1.65 out. Monitor hole fill from one pit. 02:30 - 03:30 1.00 DRILL P PROD1 Get off well. Change mtr angle from 2.5 to 2.1 deg. Get on well. Test Inteq tools. 03:30 - 06:00 2.50 DRILL P PROD1 Run in hole. 06:00 - 08:40 2.67 DRILL P PROD1 Drilling at 11440 ft TF at 40 deg L Qp = 1.50 / 1.26 bpm 3300 psi off bottom BHP /ECD = 3552 psi / 11.56 ppg Vp = 283 bbl to 245 bbl 08:40 - 09:36 0.93 DRILL P PROD1 Drilling at 11514 ft HS TF L Qp = 1.50 / 1.37 bpm 3300 psi off bottom BHP /ECD = 3611 psi / 11.74 ppg Vp = 245 bbl to 233 bbl 09:36 - 10:17 0.68 DRILL P PROD1 Wiper trip to tie in the Old hole at 11,216 ft the RA marker on the whipstock Logged from 11,230 ft and corrected to the old well (+4 ft ) Logged RA Marker and found it at 11,320.5 ft 10:17 - 12:52 2.58 DRILL P PROD1 Drilling build Section TF at HS Op = 1.58 / 1.40 bpm at 3380 psi off bottom BHP = 3636 psi at 11.73 ppg ECD ROP 20-30 fph with 1-2.5k WOB Vp = 230 bbl to 192 bbl Lost 91 bbl to formation while drilling a e small wiper tnp at 11,5 Lan ed at 5964.0 eep o plan. 12:52 - 15:10 2.30 DRILL P PROD1 POOH for lateral BHA 15:10 - 17:10 2.00 DRILL P PROD1 Well flowing a little, Open EDC and RIH circulating at 2.00 bpm. POOH and SD pump down at 200 ft. Changed AKO setting 1.00 deg, PU Res tool and RR BC bit. 17:10 - 19:00 1.83 DRILL P PRODi Get on well. Run in hole. 19:00 - 19:15 0.25 DRILL P PROD1 Log gr tie in from 11,216'. Subtract 11' correction. 19:15 - 20:30 1.25 DRILL P PROD1 Run in hole. Set down at several depths from 11,500 to 11,580'. Work through with reduced pump rate. Back ream interval. 20:30 - 21:30 1.00 DRILL P PROD1 MADD pass from 11,577' to 11320' for resistivity log. Printed: 3/12/2008 11:46:54 AM 1~ BP AMERICA Page 5 of 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase ~ Description of Operations 2/4/2008 20:30 - 21:30 1.00 DRILL P PROD1 Run back in hole. Smooth to bottom. 21:30 - 23:45 2.25 DRILL P PROD1 Drill ahead from 11580'. 3050 psi fs at 1.51 in/1.43 out. 100-200 psi mtr work. DHWOB: 2-3k#. ROP: 50-70 fph. BHP/ECD: 3479 psi/11.25 ppg. PVT: 401 bbls. I N C/AZ M/T F: 105/359/90 R . 23:45 - 00:00 0.25 DRILL P PROD1 Wiper trip to window. 2/5/2008 00:00 - 00:30 0.50 DRILL P PROD1 Continue wiper trip from 11,700'. Tight at 11,525'. Reduce pump rate from 1.5 to 1.0. Hole smooth to bottom. 00:30 - 03:30 3.00 DRILL P PROD1 Drill ahead from 11,700'. 3225 psi fs at 1.54 in/1.42 out. 200-250 psi motor work. DHWOB: 1.5-2.5k#. ROP: 50-80 fph BHP/ECD: 3575 psi/11.61 ppg. PVT: 399 bbls. INC/AZM/TF: 104.2 deg/4.1 deg/70L. 03:30 - 04:00 0.50 DRILL P PROD1 Wiper trip to window. 04:00 - 06:43 2.72 DRILL P PROD1 Drill ahead in Kuparuk C4 from 11850'. Turned TF to intercept the crest of the plan as soon as possible Op = 1.64 / 1.51 bpm, CTP 3336 psi off bottom, 3450 psi on bottom V p = 338 bbls ROP = 30-75 fph BHP = 3618 psi at 11.86 ppg ECD 06:43 - 07:15 0.53 DRILL P PROD1 Wiper trip to Tie in after drilling 150 ft. Pulled a tittle tight pulling thrrough the resistivity area below 11,870 ft, afterwards the well looks clean. 07:15 - 07:30 0.25 DRILL P PRODi Tie in and corrected + 6 ft 07:30 - 07:52 0.37 DRILL P PROD1 Wiper trip back in the hole and it was clean all of the way. 07:52 - 12:15 4.38 DRILL P PROD1 Drill ahead in Kupuruk C4 from 12,000 ft to 12,150 ft Op = 1.59 / 1.46 bpm, CTP 3336 psi off bottom, 3400 psi on bottom V p = 313 bbls ROP = 30-75 fph BHP = 3590 psi at 11.80 ppg ECD 12:15 - 13:15 1.00 DRILL P PROD1 Wiper trip after drilling 150 ft of lateral. Pulled a little tight at 11,500 ft which is the EOC. 13:15 - 15:45 2.50 DRILL P PROD1 Drill ahead in Kuparuk C4 from 12,150 ft to 12,247 ft Qp = 1.57 / 1.43 bpm CTP 3325 psi off bottom 3400 psi on bottom V p = 264 bbls ROP = 30-75 fph BHP = 3590 psi at 11.80 ppg ECD Started loading pipe shed with liner. Having to make frequent short wiper trips to drill. 15:45 - 17:30 1.75 DRILL P PROD1 Wiper trip to window. Slow down from 11,500 to 11,600'. Make 2nd short pass. Wiper back to btm was smooth the whole way. 17:30 - 21:30 4.00 DRILL P PROD1 Drill ahead from 12,247' to 12375' 21:30 - 22:20 0.83 DRILL P PROD1 Wiper to window. Slow to 15'/min thru belly from 11550' and see motor work, but no overpull's at LS TF 22:20 - 22:45 0.42 DRILL P PROD1 Log tie-in down from 11240', corr +4' 22:45 - 23:30 0.75 DRILL P PROD1 Wiper to TD was clean PVT 423 23:30 - 00:00 0.50 DRILL P PROD1 Drill from tag at 12378' (5850' TVD) 1.57/1.45/3330/908 w/ Printed: 3/12/2008 11:46:54 AM ~ ~ BP AMERICA Page 6 of 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From.- To Hours Task Code NPT Phase Description of Operations 2/5/2008 23:30 - 00:00 0.50 DRILL P PRODi 100-300 psi dill, 0.7-1.9k wob and 12.0 ECD at 89 deg to 12400' 2/6/2008 00:00 - 02:40 2.67 DRILL P PROD1 Drill from 12400' (5851' TVD) 1.59/1.45/3350/908 w/ 100-300 psi dill, 0.7-2.Ok wob and 12.4 ECD at 89 deg to 12500' while in and out of siderite PVT 390 02:40 - 04:10 1.50 DRILL P PROD1 Wiper to window had a few minor OP's, but otherwise clean PVT 372 04:10 - 06:30 2.33 DRILL P PROD1 Drill from 12500' 1.64/1.45/3600/1508 w/ 100-300 psi dill, 1-2k wob and 12.17 ECD at 88 deg. Drill to 12 566'. Be in losin 90% rtns. 1.65 in/0.21 out. 06:30 - 08:00 1.50 DRILL P PROD1 Make wiper trip to window. PVT at start of trip: 249 bbls. Call for additional flo pro fluid from MI. Hole smooth in both directions. 08:00 - 10:45 2.75 DRILL P PROD1 Drill ahead from 12,566'. 2950 psi fs at 1.50 in/0.75 out. 100-200 psi mtr work. DHWOB: 1.5-12.Ok#. ROP: 30-45 fph. BHP/ECD: 3479 psi/10.25 ppg. PVT: variable. 10:45 - 11:15 0.50 DRILL P PROD1 Decision made to modif directional Ian. Begin wiper trip while details are sorted out. 11:15 - 11:30 0.25 DRILL P PROD1 Log GR tie in. Add 6' correction. 11:30 - 13:15 1.75 DRILL P PROD1 Run back in hole 13:15 - 14:45 1.50 DRILL P PROD1 Tag bottom at 12,611'. Drill ahead to 12,622'. BHA uit drillin .Cannot get motor to stall. Weight transfer (pick ups and DHWOB) are both good. 14:45 - 17:45 3.00 DRILL P PROD1 Pull out of hole to change bit and motor.Open EDC and circulate out of tubing. 2.55 in/1.40 out. PVT: variable. 17:45 - 19:00 1.25 DRILL P PROD1 Change bit and motor. Bit was 2-2-I, balled up, but motor okay. Hole staying full 19:00 - 21:10 2.17 DRILL P PROD1 RIH w/ BHA #7 circ thru bit 0.32/1120 21:10 - 21:30 0.33 DRILL P PROD1 Log tie-in down from 11240' 0.32/0.15/1110 Corr -11' 21:30 - 22:30 1.00 DRILL P PROD1 Wiper to TD 1.4/0.7/2520 was clean PVT 250 22:30 - 23:50 1.33 DRILL P PROD1 Drill from tag at 12623' 1.49/0.79/2550/110L w/ 150-350 psi diff, 0.9-2.4k wob w/ 11.02 ECD at 85 deg continuing slow drop to TD. grill to 12683' 23:50 - 00:00 0.17 DRILL P PRODi Slow wiper while BHI work to fix MWD accellerometer problem 2/7/2008 00:00 - 00:20 0.33 DRILL P PROD1 Continue slow wiper while BHI determine tool problem. Decide to POH, but tool started working. Wiper to 12350', then wiper back to TD 00:20 - 01:20 1.00 DRILL P PRODi Drill from 12683' 1.49/0.89/2760/90L w/ 100-300 psi diff, 1.0-2.Ok wob w/ 11.17 ECD at 82 deg while continuing the drop. Drill to 12734' 01:20 - 01:30 0.17 DRILL P PROD1 Slow wiper while orient to right side and were temp immobile both directions at 12700'. Came free w/ 20k over 01:30 - 01:50 0.33 DRILL P PROD1 Wiper up hole while orient to the right side. Wiper back to TD and had stacking due to TF change. Sticky area at 12700'. Adding fresh mud to system 01:50 - 02:30 0.67 DRILL P PROD1 Drill from 12734' 1.48/0.91/2800/908 w/ 100-200 psi diff, 1.0-2.Ok wob w/ 11.06 ECD at 82 deg Drill to 12750' 02:30 - 04:30 2.00 DRILL P PROD1 Wiper to window 04:30 - 09:00 4.50 DRILL P PROD1 Drill from 12750' 1.50/0.92/2850/1108 w/ 100-300 psi diff, 1.0-2.Ok wob w/ 11.2 ECD at 83 deg while continue the drop to TD Printetl: 3/12/2008 11:46:54 AM ~ ~ $P AMERICA Page 7 of 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: - Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date ;From - To Hours Task Code NPT Phase Description of Operations 2/7/2008 09:00 - 11:30 2.50 DRILL P PRODi Drill ahead from12,840'. 2900 psi fs at 1.54 in/0.96 out. 200-250 psi mtr work. DHW0B:1.5-1.8 k#. CT WOB: -6 to -7 K#. ROP: 5'-10' FPH. BHP/ECD: 3422 psV11.21 ppg. PVT: variable INC/AZM/TF: 81.7 deg/20.8 deg/120R. Very slow drilling. Cannot determine if bit is balled up, or on a hard spot. ROP increased, and able to stall. Looks like a formation change. 11:30 - 13:15 1.75 DRILL P PROD1 Wiper trip to window. Some overpulls near bottom up to 12,700', then mostly smooth. Circulation at 11,370': Pump rate: 1.65 in/0.64 out. Tip back to btm also mostly smooth. A few set downs with no motor work. 13:15 - 16:15 3.00 DRILL P PROD1 Drill ahead from 12 900'. 3100 psi free spin at 1.63 in/0.71 out. Very erratic drilling. 16:15 - 17:15 1.00 DRILL P PRODi Make wiper trip to window. Hole sticky over btm 100' or so. Tie in just in case. 17:15 - 17:45 0.50 DRILL P PROD1 Log gr tie in. Add 11' correction. 17:45 - 18:45 1.00 DRILL P PROD1 Wiper to TD had no set downs, but motor work in TF change areas 18:45 - 20:40 1.92 DRILL P PROD1 Drill from tag at 13058' 1.48/0.71/2720/1608 w/ 100-300 psi dill, 1.0-2.2k wob w/ 10.91 ECD at 75 deg while continue to drop to TD. Returns diminished to 0.32 bpm by 13100'. Continue drilling at avg 1.47/0.40/2600/1708 w/ 10.66 ECD w/ frequent pickups and having overpulls due to no bouyancy. Drill to 13108' and sit on robable siderite 20:40 - 22:20 1.67 DRILL P PRODi A planned 300' wiper turned into a trip to 12400' and was rather rough from TD to 12850' w/ numerous overpulls and some motor work. Wiper back in hole to 12900' and find out that mud trucks are following 27E on the 1 F access road and won't arrive on time. PVT 30 Resume POH 15'/min w/ well SI and pump occasionally to keep CT warm until vac truck arrived 22:20 - 22:40 0.33 DRILL P PROD1 Wiper back in hole from 12600' 1.56/0.20/2650 was clean 22:40 - 00:00 1.33 DRILL P PROD1 Drill from tag at 13106' 1.57/0.35/2750/1708 w/ 100-300 psi dill, 1.0-1.8k wob w/ 10.72 ECD at 60 deg and continue the drop. Perform frequent pickups. Seem to be encountering numerous small faults -losing 0.1 bpm each time we cross one. Drill to 13135' 2/8/2008 00:00 - 01:05 1.08 DRILL P PROD1 Drill from 13135' 1.56/0.32/2780/1708 w/ 100-300 psi dill, 1.0-1.8k wob w/ -5k surface wt w/ 10.65 ECD at 59 deg to initial TD of 13150' (see 25' of <20 ohm rock on res tool) 01:05 - 02:20 1.25 DRILL P PROD1 Wiper to window was clean. Pull thru window, clean 02:20 - 02:40 0.33 DRILL P PRODi Log tie-in down from 11240', corr +6'. RIH thru window 02:40 - 03:45 1.08 DRILL P PROD1 Wiper to TD was clean and tac7Qed at 13150'. POH 28k 1.61/0.50/3200 while fin circ 2 ppb beads in fresh mud to bit 03:45 - 04:45 1.00 DRILL P PROD1 POOH thru open hole 1.0/0.40/2150 w/ 10.60 ECD at 30'/min laying in beads 04:45 - 07:15 2.50 DRILL P PROD1 POOH from window for liner circ thru bit 1.5/2900 07:15 - 08:00 0.75 DRILL P PROD1 Flow check. Get off well. Unstab coil. LD Inteq tools. 08:00 - 08:30 0.50 BOPSU PROD1 Perform week) BOP ram function test. 08:30 - 09:30 1.00 CASE P LNR1 Hold PJSM to discuss running liner. Printed: 3/12/2008 11:46:54 AM i +~ BP AMERICA Page 8 of 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date !From - To Hours Task Code NPT Phase Description of Operations 2/8/2008 08:30 - 09:30 1.00 CASE P LNR1 Rig up floor. MU safety joint. Sort out pipe on pipe rack and catwalk. PU Baker tools and equipment to rig floor. 09:30 - 11:15 1.75 CASE P LNR1 Make up the lower liner assembl , 2-3/8" 4.4# STL slotted and solid, no turbos. OAL: 763.24'. Decision made to run liner in 2 sections due to low return r t liner to outside of the window. 11:15 - 11:45 0.50 CASE P LNR1 MU Inteq and Baker TT tools. Engage liner. Get on well. 11:45 - 14:00 2.25 CASE P LNR1 Run in hole with liner assembly. 28.5k# up wt, 11 k# do wt at window. Pass through window and run in to open hole. 14:00 - 14:45 0.75 CASE P LNR1 Log GR tie in from 11960'. Subtract 8' correction.. 14:45 - 15:30 0.75 CASE P LNR1 Continue to run in open hole. Set down at 12,614', 12654'. Work past same. Ta bottom at 13 151'. 33k# up, 7.5k# do wt. Set liner back down on btm. 15:30 - 15:35 0.08 CASE P LNR1 Pump at 1.52 bpm at 2992 psi. Work up and down a few times. Liner came free. 25k# up wt. Liner top is at 12,388'. 15:35 - 16:15 0.67 CASE P LNR1 POOH to gr tie in depth. Add 2' correction. 16:15 - 18:20 2.08 CASE P LNRi Continue to pull out of hole. 18:20 - 18:50 0.50 CASE P LNR1 LD MWD assy 18:50 - 19:05 0.25 CASE P LNR1 Safety mtg re: run top section of liner 19:05 - 19:25 0.33 CASE P LNR1 RU to run liner 19:25 - 21:40 2.25 CASE P LNR1 MU to section of 2-3/8" 4.4# L-80 STL liner w/slotted and solid joints w/ OAL=1062.34'. MU BHI MWD assy on BTT knuckle jt, GS and deployment sleeve 21:40 - 23:25 1.75 CASE P LNR1 RIH w/ top section of liner circ thru GS 0.2/700 w/ nearly full returns 23:25 - 00:00 0.58 CASE P LNR1 11300' 26.7k, 8.9k RIH thru window, clean. RIH thru OH w/o~ um to to at 12393' CTD 2/9/2008 00:00 - 00:10 0.17 CASE P LNR1 PUH 29.1 k RIH w/ 8.1 k and stack 4k down. Start pump 1.54/3200, PUH and still had liner. Stack 5k and incr to 2.0/4400. PUH 24.7k and left top liner setting on top of bottom liner at 12387'. The to of the de to ment sub on the to liner is 3' outside the window at 11324' 00:10 - 02:00 1.83 CASE P LNR1 POOH circ thru GS 1.35/2450 02:00 - 02:30 0.50 CASE P LNR1 LD MWD assy and liner running tools 02:30 - 03:15 0.75 STWHIP P WEXIT MU BTT thru tubing WS on KB packer assy. Add BHI MWD w/ HOT 03:15 - 06:15 3.00 STWHIP P WEXIT RIH w/ WS assy circ thru EDC 0.16/600 at 75'/min 06:15 - 08:15 2.00 STWHIP P WEXIT Log GR tie in from 11216'. Subtract 8' correction. Log CCL from 11,000 to 11,310'. Collar estimated at 11,298'. 08:15 - 08:45 0.50 STWHIP P WEXIT RIH. Set whipstock top at 11,300'. TF oriented to 45 deg ROHS. Close EDC. Pressure coil to 2100 psi. Packer activated. Set 2-3k# do on pkr. Appears to have set properly although setting pressure was lower. Pick up is clean. 3-1/2" KB packer contains a standing valve. 08:45 - 11:00 2.25 STWHIP P WEXIT Circulate out of hole. Mud losses have stopped. Note: Only had losses while circulating; static losses were zero. 11:00 - 12:00 1.00 STWHIP P WEXIT At surface. Get off well. Unstab coil. LD packer setting tools. MU window milling assembly on Inteq tools. Test tools. Get on well Printed: 3/12/2008 11:46:54 AM y~ ©~ BP AMERICA Page 9 of 25 .Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date , From - To Hours Task ~ Code NPT Phase Description of Operations 2/9/2008 12:00 - 13:30 1.50 STWHIP P WEXIT Run in hole. Continue to get full returns. 13:30 - 13:45 0.25 STWHIP P WEXIT Log GR tie in from 11,246'. Subtract 7' correction. 13:45 - 19:00 5.25 STWHIP P WEXIT Tag whipstock tray at 11,301'. 3100 psi fs at 1.59 in/out. 200-300 psi motor work. Begin time milling at 0.1' per 6 minutes. 2-3k# DHWOB. Metal on magnets. Cam fire drill 19:00 - 21:20 2.33 STWHIP P WEXIT Mill from 11305.8' w/ 1.6/3300 w/ 0-200 psi dill, 1.2-2.5k wob w/ 11.45 ECD and appear to exit window at 11306.3'. Spend some time getting mill and SR thru the window before drilling in formation 21:20 - 22:00 0.67 STWHIP P WEXIT Drill formation from 11307.5' 1.6/3250 at 10-15'/hr. At 11308.5', lost most of returns 1.59/0.35. Drill ahead and ~~ returns slowly increased to 1.59/0.90 at 11.0 ECD Drill to 11316' TOW/TOWS 11301', BOW 11306' `fa ~ 1--~ 22:00 - 22:50 0.83 STWHIP P WEXIT Ream and backream window 1.59/1.10/2940. Dry drift was clean 22:50 - 00:00 1.17 STWHIP P WEXIT POOH circ thru mill 1.5/2500 2/10/2008 00:00 - 00:50 0.83 STWHIP P WEXIT Finish POOH w/ window milling BHA 00:50 - 01:30 0.67 STWHIP P WEXIT LD MWD assy, 2 jts DP, motor and mill. Mill and SR gauged 2.74" and mill had center wear 01:30 - 05:30 4.00 DRILL P PROD2 SI master and swab. Cut off CTC and seal a-line. Stab back on. Rev circ 3.0/3400 w/ 15 bbls mud and line moved. Unstab and RU hyd cutter. Cut off 68' of CT and found wire. Cut off a total of 120' of CT to move fatigue spot down hole. Install CTC. PT 35k. Head up BHI. PT 4000 psi. Set injector over bung hole and pump slack forward. Change packoff 05:30 - 11:15 5.75 BOPSU P PROD2 Test BOPE. Test witness waived by B. Noble with AOGCC. Test equipment to 250 psi low, 3500 psi high. Test equipment as per wellplan and permit to drill. Test packoffs and inner reel valve All equipment passed testing. 11:15 - 12:30 1.25 BOPSU P PROD2 Pressure test new floor manifold piping to complete MOC for MPD plumbing modifications. Camp fire drill 12:30 - 13:15 0.75 DRILL P PROD2 Hold PJSM. MU drilling build assembly for L2 lateral (2.3 deg mtr with HTC bi-center bit) Stab coil. Test MWD. Get on well. 13:15 - 15:45 2.50 DRILL P PROD2 Run in hole. Circ at min rate. 15:45 - 16:15 0.50 DRILL P PROD2 Log gr tie in from 11,220'. Subtract 5' correction. 16:15 - 18:45 2.50 DRILL P PROD2 Drill ahead from 11,316'. 2950 psi fs at 1.49 in/1.0 out. 100-200 psi mtr work. 4-6k# DHWOB. Pick up frequently to get TF as needed at 45-60 deg R. 18:45 - 22:00 3.25 DRILL P PROD2 Drill from 11356' 1.50/1.10/2800/458 w/ 0-200 psi dill, 1.5-3.5k wob w/ 11.12 ECD and go nowhere fast. Same interval on Li averaged 10'/hr. Several wipers to window and attempts to get surveys. Drill to 11392' and penetration rate is picking up 22:00 - 22:30 0.50 DRILL P PROD2 Drill from 11392' 1.5/0.98/2810/458 w/ 50-200 psi dill, 1.0-3.Ok wob w/ 11.0 ECD at 44 deg while continue the build and turn. Drill to 11410' Printed: 3/12/2008 11:46:54 AM BP AMERICA Page 10 of 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date ;From - To Hours Task ;Code NPT Phase Description of Operations 2/10/2008 22:30 - 22:40 0.17 DRILL P PROD2 Wiper to window was clean PVT 227 22:40 - 23:30 0.83 DRILL P PROD2 Drill from 11410' 1.50/1.01/2830/358 w/ 100-300 psi dill, 1-3.5k wob w/ 11.03 ECD at 48 deg, Drill to 11436' and get first good survey 23:30 - 00:00 0.50 DRILL P PROD2 Wiper while discuss directional plan. Need -40's and are getting 38's. Pull thru window clean 2/11/2008 00:00 - 00:30 0.50 DRILL P PROD2 Log tie-in while discuss. Corr +1' Will trip for larger bend motor 00:30 - 02:30 2.00 DRILL P PROD2 Open EDC. POOH circ 1.45/2750 02:30 - 03:50 1.33 DRILL P PROD2 Standback BHA. Change motor bend to 2.5 deg, rerun 1-1-I bit 03:50 - 05:50 2.00 DRILL P PROD2 RIH w/ BHA #13 circ thru EDC 0.5/910 05:50 - 06:10 0.33 DRILL P PROD2 Log tie-in down from 11230', corr -3'. Close EDC 06:10 - 06:20 0.17 DRILL P PROD2 Run in hole to TD. Hole smooth. 06:20 - 11:00 4.67 DRILL P PROD2 Drill ahead from 11,436'. 2600 psi fs at 1.48 in/0.95 bpm. 100-200 psi mtr work. 3-4k# DHWOB. ROP: variable, mostly <10 FPH. BHP/ECD: 3361 psi/10.93 ppg. PVT: 375 bbls. 11:00 - 14:30 3.50 DRILL P PROD2 Drill ahead to 11 510'. Able to stall motor. Wei ht transfer is ood. 100-200 si motor work noted. Apparently in a hard spot. 14:30 - 14:45 0.25 DRILL P PROD2 Make wiper trip to window. Hole smooth. 14:45 - 18:00 3.25 DRILL P PROD2 Drill ahead from 11,510'. Continued slow drilling. Loss rates ~, vary from 0.5 to 0.75 bpm. Drilled to 11540' 18:00 - 18:30 0.50 DRILL P PROD2 Wiper to window was essentially clean, but had a few minor overpulls PVT 238 18:30 - 21:50 3.33 DRILL P PROD2 Drill from 11540' 1.48/0.99/2900/108 w/ 100-300 psi dill, 3.0-4.4k wob w/ 10.94 ECD at 89 deg and have continued slow penetration rate to assumed micro-dulling of the bit in the B2. Getting close to the EOB/turn. Land 3' deep to plan but still in the 62 sand. Drill to 11570' and project 103 deg at bit PVT 400 21:50 - 22:10 0.33 DRILL P PROD2 Wiper to window was clean 22:10 - 00:00 1.83 DRILL P PROD2 Pull thru window, clean. Open EDC. POOH circ thru EDC 1.5/2400 2/12/2008 00:00 - 00:20 0.33 DRILL P PROD2 Finish POOH w/ build assy 00:20 - 01:30 1.17 DRILL P PROD2 LD build assy. Change bit, motor, add res tool. Bit was 1-1-I and micro-dulled 01:30 - 03:30 2.00 DRILL P PROD2 RIH w/ BHA #14 (1.0 deg) circ thru bit 0.30/1100 03:30 - 03:45 0.25 DRILL P PROD2 Log tie-in down from 11240', corr -4' 03:45 - 04:15 0.50 DRILL P PROD2 Wiper to TD 1.5/2780 at 20'/min. Set downs started at 11502'. Work to TD at 11570'. Backream to 11500' was clean. Wiper back to TD was clean 04:15 - 05:10 0.92 DRILL P PROD2 MAD pass w/ res tool at 300'/hr from 11570' back to the window 1.50/1.10/2900 05:10 - 05:20 0.17 DRILL P PROD2 Wiper back to TD was clean PVT 313 05:20 - 11:30 6.17 DRILL P PROD2 Drill from 11570' 1.48/1.08/2900/458 w/ 200-400 psi dill, 2.0-3.Ok wob w/ 11.13 ECD at 103 deg and continue the invert to the C4. Initially had good ROP, then ROP dropped to <5 fph. ROP increased to 40-60 fph at 11,620'. Assuming formation change. Drilled to 11699'. 11:30 - 12:15 0.75 DRILL P PROD2 Wiper trip to window. Hole mostly very smooth. Printed: 3/12/2008 11:46:54 AM • BP AMERICA Page 11 of 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: i Date From - To Hours ' Task Code ~ NPT Phase Description of Operations 2/12/2008 12:15 - 15:55 3.67 DRILL P PROD2 Drill ahead from 11,699'. 2480 psi fs at 1.55 iN0.87 out. 200-300 psi mtr work. Frequent stalling after wiper trip. Begin diiluting mud with 50% seawater. 8.61 ppg iN8.67 ppg out. Loss rate slowing healing: 1.52 in/1.34 out., BHP/ECD: 3125 10.17 ppg. Geologist reports that they're having much difficulty getting good cuttings samples since switching to 50:50 mud -cannot clean off fines that are clinging to the samples. Continue to climb at 103.5 INC. Drill to 11832' 15:55 - 16:25 0.50 DRILL P PROD2 Wiper to window while geo determines the top of the B2 for determining the future trajectory of the invert. Pull thru window, clean 16:25 - 16:45 0.33 DRILL P PROD2 Log tie-in down from 11220', corr +3' 16:45 - 17:20 0.58 DRILL P PROD2 Wiper back to TD and had a few set downs above 11570'. Geos finalize and DD formulate plan for drilling ahead PVT 386 17:20 - 19:00 1.67 DRILL P PROD2 Drill from 11832' 1.50/1.33/2330/1058 w/200-400 psi dill, 1.0-3.Ok wob w/ 10.24 ECD at 99 deg while continuing the invert. Drill to 11950'. 19:00 - 20:55 1.92 DRILL P PROD2 Wiper to window. Sticky off bottom, otherwise clean. Wiper to TD while pumping full rate -set downs from 11595' to 11643' - work area. End of build section (32 DLS) won't pass ~ 1.45bpm, pass thru at 1 bpm with no problem. 20:55 - 23:40 2.75 DRILL P PROD2 Drill from 11950' 1.62/1.1/2360/100L w/200-400 psi diff, 0.5-1.Ok wob w/ 10.24 ECD at 92 deg while continuing the invert. Drill to 12100'. 23:40 - 00:00 0.33 DRILL P PROD2 Wiper to window -clean. 2/13/2008 00:00 - 00:35 0.58 DRILL P PROD2 Continue to wiper to bottom -clean. 00:35 - 03:30 2.92 DRILL P PROD2 Drill from 12100' 1.64/1.3/2600/100L w/200-600 psi diff, 1.0-2.Ok wob w/ 10.44 ECD at 92 deg while continuing the invert. Drill to 12250'. 03:30 - 04:00 0.50 DRILL P PROD2 Wiper to window -clean. 04:00 - 04:10 0.17 DRILL P PROD2 Log down for tie-in (+5' corr). 04:10 - 04:50 0.67 DRILL P PROD2 Wiper to TD -set down at 11750', otherwise clean. 04:50 - 07:55 3.08 DRILL P PROD2 Drill from 12252' 1.64/1.08/2400/110L w/200-400 psi diff, 1.0-2.Ok wob w/ 10.32 ECD at 98 deg while continuing the invert. Swap to right at 12350'. Drill to 12400' 07:55 - 10:00 2.08 DRILL P PROD2 Wiper to window was clean except for one 6k OP at _11500' and with MW from 11520' to 11450'. Loss rate of 0.6 bpm gradually decreased as BHA was pulled into the window where there were 0.2 bpm losses. Wiper back in hole and loss rate increased to 0.8 bpm by 11480' and then healed to 0.3 bpm by first set down at 11545'. Reduced rate to get by, then wiper to 11680' while fin circ 20+ bbl 50k LSRV pill to bit. Backream 11600' to 11450' and ream same area 25-30'/min with pill exiting bit at 1.62/1.13/2750. Had 8k OP at 11480' with MW on PUH, and had slight wt loss w/ MW on RIH. Continue wiper to TD with one additional setdown at 11757'. Had nearly full returns and 11.34 ECD at 12000', but had dramatic loss of returns back to 0.4 bpm. Returns gradually increased to f .63/0.75/2520 at TD 10:00 - 14:50 4.83 DRILL P PROD2 Drill from 12400' 1.62/0.73/2520/1108 w/ 100-300 psi diff, Printed: 3/12/2008 71:46:54 AM r BP AMERICA Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ~ From - To Hours ~ Task Code NPT 2/13/2008 110:00 - 14:50 4.831 DRILL P 14:50 - 17:00 ~ 2.17 ~ DRILL ~ P 17:00 - 23:55 ~ 6.921 DRILL P Start: 1 /15/2008 Rig Release: Rig Number: Phase PROD2 PROD2 PROD2 23:55 - 00:00 0.08 DRILL P PROD2 2/14/2008 00:00 - 01:10 1.17 DRILL P PROD2 01:10 - 01:20 0.17 DRILL P PROD2 01:20 - 02:10 0.83 DRILL P PROD2 02:10 - 04:00 1.83 DRILL P PROD2 04:00 - 04:15 0.25 DRILL P PROD2 04:15 - 04:30 0.25 DRILL P PROD2 04:30 - 08:00 I 3.501 DRILL I P I I PROD2 08:00 - 09:50 1.83 DRILL P PROD2 09:50 - 11:50 2.00 DRILL P PROD2 11:50 - 12:05 0.25 DRILL P PROD2 12:05 - 12:55 0.83 DRILL P PROD2 12:55 - 14:30 I 1.581 DRILL I P I I PROD2 14:30 - 15:15 0.75 DRILL P PROD2 15:15 - 17:00 1.75 DRILL P PROD2 Page 12 of 25 Spud Date: 2/20/2000 End: Description of Operations 0.7-1.5k wob w/ +1 k to -1 k surf wt w/ 10.93 ECD at 95 deg at 40-120'/hr. Solids from the faster drilling reduced to loss rate to 1.62/1.05/2500 w/ 10.55 ECD by 12420'! Geo's confirm that planned fault was crossed at 12361' and another may exist at 12480'. Drill to 12550' w/ 1.62/1.03 and 10.5 ECD avg and swap to left at 12525' Wiper to window. Pumped two 20 bbl 50k pills timed for pulling thru 11600'-11450' and RIH thru same. Had minor OP w/ 300 psi MW thru 11530', but otherwise clean. Had wild fluctuation in return rate when nearing window from 0.4 bpm to 1.5 bpm. Wiper back in hole was clean to 11695'. Wiper back to 11450' w/second pill at bit was clean both directions and loss rate was only 0.2 bpm. Check shot survey at 11850'. Had full returns from 11800' w/ 11.19 ECD. Sweeps returned an extra 0.1 ppg density and noticeable additional cuttings across the shaker and had nearly full returns upon tagging TD Drill from 12550' 1.58/1.50/2725/90L w/ 100-300 psi dill, 1.0-1.75k wob w/ +0.5k surf wt w/ 11.0 ECD at 91 deg. Start drilling with 50% FloPro w/ additional 1 % tube and 50% 2% KCI. Turn on centrifuge 'A' & 'B'. Pump 10 bbl pill of Flo-Pro - improvement in sliding. Drill to 12695'. Wiper to window once the end of the 10 bbl pill exits the bit. Continue to wiper to the window -clean. Log down for tie-in (+11ft corr. Wiper to TD -clean. Drill from 12703' 1.75/1.71/2825/90L w/ 100-300 psi dill, 1.0-1.75k wob w/ -1.5k surf wt w/ 11.03 ECD at 89 deg. Centrifuge 'A' & 'B' are running. Drill to 12765' & PU for a survey. Not dropping in TVD. Increase rate to 1.9bpm & stack more wt down, drill 10 more feet & watch NBI -seems to dropping & are at 86 degrees. Drill from 12775' 1.92/1.84/3362/LS w/ 100-300 psi diff, 1.5-2.OOk wob w/ -4.5k surf wt w/ 11.35 ECD at 88 deg. Centrifuge 'A' & 'B' are running. Not dropping angle, actually it's building angle again. Call town & let them know that we are POH. Geo's report that cuttings samples have greatly improved since switching to dilution with KCI water instead of seawater. POH for fresh bit & motor, possibly the agitator. Open EDC in liner & pump 2.5bpm/3450psi while POH. Had no indication of cuttings lying in the 60 deg hole section in the tubing. LD drilling BHA. Bit was 1-1-I and micro-dulled, motor okay. Adjust motor to 1.4 deg and change bit to used 2.74" M09X RIH w/ BHA #15 circ thru EDC 0.35/570 Log tie-in down from 11230', corr -7'. Close EDC Wiper to TD w/ set downs near fault area at 12360-390', but otherwise clean PVT 382 Time drill ~ -10'/hr from 12780' 1.60/1.55/2450/1758 w/ <0.5k wob w/ <100 psi diff w/ 10.91 ECD to get thru the hard streak and get downtrend started 12792' Start to see NBI loss at 12781' 12800' Begin moving TF up while adding wt and resume Printed: 3/12/2008 11:46:54 AM • r BP AMERICA Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Event Name: REENTER+COMPLETE Start: .Contractor Name: NORDIC CALISTA Rig Release: 'Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task ~ Code ~ NPT Phase 2/14/2008 15:15 - 17:00 1.751 DRILL P 17:00 - 19:35 I 2.581 DRILL I P 19:35 - 20:20 I 0.751 DRILL I P 20:20 - 23:10 I 2.831 DRILL I P 23:10 - 00:00 I 0.831 DRILL I P 2/15/2008 100:00 - 02:20 I 2.331 DRILL I P 02:20 - 03:30 I 1.171 DRILL I P 03:30 - 05:25 1.92 DRILL P 05:25 - 05:55 0.50 DRILL P 05:55 - 07:20 1.42 DRILL P 07:20 - 08:20 1.00 DRILL P 08:20 - 08:45 I 0.421 DRILL I P 08:45 - 11:15 I 2.501 DRILL ~ P 11:15 - 12:40 I 1.421 DRILL I P 12:40 - 13:55 1.25 DRILL P 13:55 - 16:15 2.33 DRILL P 1 /15/2008 Page 13 of 25 Spud Date: 2/20/2000 End: Description of Operations PROD2 drilling the drop. Drill from 12803' w/ 1.59/1.55/2460/130L w/ 100-200 psi dill, 1.0-1.8k wob w/ 10.85 ECD. Perform a few 70' backreams to make DLS change smoother. Drill in ahead in more siderite (slow) PROD2 Drill from 12820' 1.59/1.54/2430/80L w/ 100-200 psi dill, 1.0-1.5k wob w/ 10.8 ECD at 82 deg. Slow drilling. Drill to 12838'. PROD2 Unable to drill. Back ream from 12838' to 12780' w/ TF 180 degree out drilled setting. PROD2 Drill from 12838' 1.78/1.72/2800/60L-100L w/ 100-200 psi dill, 1.0-2.5k wob w/ 11.08 ECD at 82.3 deg. Drill to 12875'. PROD2 Drilling BHA is past largest DLS area & are in a position to achieve targets. POH to dial down motor & change bits to bi-center. PROD2 Continue to POH. Open EDC in liner & jet max rate while POH. PJSM while POH regarding handling BHA. PROD2 Pop off well at 100' & inspect coil & CTC. Purge & blow down BHA w/ water & air. LD motor & bit (cutters intact, 2.73 no-go). PU new 1.0 AKO motor & new HYC bi-center bit. Change out o-rings on LOC of tool. Stab onto well. Tag up & set counters. PROD2 RIH w/ BHA #16 circ thru bit 0.44/575 PROD2 Log down for tie-in (-6' corr. PROD2 Wiper to TD 1.6bpm/2360psi w/ set downs 1 1 71 0-780'. Otherwise, mostly clean to correction run area where it was a little tite. Tag TD at 12878'. Slow backream to 12780', ream back to T PROD2 Drill from 12878' (5845' ND) 1.62/1.55/2580/90L w/ 100-250 psi dill, 1.0-1.75k wob w/ 10.84 ECD at 84 deg. Pump a leftover 37 bbl 50k LSRV pill to verify ECD's wouldn't increase losses. See ECD as high as 11.62 and losses increased by 0.1 bpm. Fresh mud arrived, but AES dirty trucks were routed to another rig job, so postpone mud swap while wo CHILL trucks. Drill to 12908' PROD2 Stacking at 12908' due to apparent loss of lubricity from the pill. Do a 120' wiper PROD2 Drill from 12908' 1.61/1.44/2720/70L w/ 100-200 psi diff, 0.5-1.5k wob w/ 11.65 ECD as pill reached surface. After pill was OOH, ECD was 11.22 and had full returns (1.61/1.60/2700) for a while, but as ECD returned to 10.92 then return rate stabilzed as before at 1.61/1.55 Drill w/ -2k surface wt to get 0.5k wob. Break out into faster drilling at 12912-950'. Begin removing used mud from pits. Drill to 13010' while building back to 90 deg PROD2 Start fresh 100% FloPro. Start wiper to window 1.60/1.54/2550 w/ 10.92 ECD First 150' was a little rough w/ 5k OP's. Rest of hole was clean to 11477' where bha got packed off and stalled motor. Had to slow backream. Found a similar spot at 11441'. Finish wiper to 11315' 1.54/1.30/3100 w/ 11.60 ECD w/fresh mud back to surface PROD2 Wiper back to TD 1.36/2820 was clean except for TF changes PROD2 Drill from tag at 13006' 1.35/1.20/2830/90L w/ 100-300 psi diff, 0.6-1.3k wob at 11.80 ECD w/ new up wt 23k. Drill at red pump rate until mud shears to keep ECD's low to keep most of Printed: 3/12/2008 11:46:54 AM BP AMERICA Page 14 of 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code ~ NPT Phase Description of Operations 2/15/2008 13:55 - 16:15 2.33 DRILL P PROD2 16:15 - 19:20 3.08 DRILL P PROD2 19:20 - 19:45 0.42 DRILL P PROD2 19:45 - 21:20 1.58 DRILL N STUC PROD2 21:20 - 23:40 2.33 DRILL N STUC PROD2 23:40 - 00:00 0.33 DRILL N STUC PROD2 2/16/2008 00:00 - 00:10 0.17 DRILL N STUC PROD2 00:10 - 00:35 0.42 DRILL N STUC PROD2 00:35 - 01:00 0.42 DRILL N STUC PROD2 01:00 - 02:05 1.08 DRILL N STUC PROD2 02:05 - 02:15 0.17 DRILL N STUC PROD2 02:15 - 02:20 0.08 DRILL N STUC PROD2 02:20 - 03:00 0.67 DRILL N STUC PROD2 03:00 - 04:10 1.17 DRILL N STUC PROD2 04:10 - 04:40 0.50 DRILL N STUC PROD2 04:40 - 04:50 0.17 DRILL N STUC PROD2 04:50 - 05:40 0.83 DRILL N STUC PROD2 05:40 - 05:50 0.17 DRILL N STUC PROD2 05:50 - 07:00 1.17 DRILL N STUC PROD2 07:00 - 08:30 1.50 DRILL N STUC PROD2 returns. Drill from 13060' w/ up to max surf neg wt while getting 1.4k max wob at 1.36/1.25/60L at 89 deg w/ 11.86 ECD. Swapped TF to right C~ 13100'. Drill to 13150'. Wiper to window. Increase pump 1.5bpm/3000psi while wipering. Started to overpull at 12875'. RIH -can't. No movement in pipe. Orientor moves freely. DHWOB varies while moving pipe. Turn pump off & let relax for 15 min. Move coil, mostly in the downward position. CBU at 1.3bpm/2800psi. Call for crude from GPB & call town engineer. Mix 40 bbl of 50/50 2% KCUFIo-pro in pill pit. Alternately let coil relax & attempt to move coil in downward position & workpipe at varying weights from -10k/50k. Still losing ~ 0.15bpm. PU to coil neutral weight & pump 15bb1 of to-vis 50/50 pill - cuttings across shaker on bottom's up. Shut down pumping at 65bbls away & let coil relax for 30 min. Move coil upto neutral weight & down to -10k. Pump rest of 50/50 pill down hole - minorcuttings across shaker on bottom's up. Returns are 1:1. Let coil/formation relax. Continue to let coil relax. Well is slow) startin to flow. Work pipe - no movement. Pump ~ 1.5bpm/3350psi wait for crude. Slight losses now, 0.25bpm difference between the two. Back crude truck into position. Got a 1.25psi VP reading on the crude -good to go. Pump 10 bbls of crude downhole. Let 5 bbls come out bit, close choke & let crude soak for 30 min. Inadvertently trap 500 psi on well while closing choke & is holding pressure (MM rates are possibly reading incorrectly & the densities too). Work pipe. No movement. Circulate last 5 bbls out of coil. Shut down & open Baker choke to bleed off coil pressure & close choke to see what WHP builds to. WHP=225psi in 45 min. Work pipe. Possibly 3.5' of movement. Pump 10bbls of crude while circulating out previously pumped crude 1.20bpm in/ 1.07bpm out, divert crude returns to TT. Pump 5 bbls of crude out of bit & wait 30 min w/ choke closed. Work pipe. No movement. Circulate last 5 bbls out of coil. Shut down & open Baker choke to bleed off coil pressure & close choke to see what WHP builds to. WHP = 370psi. Let crude soak. Work pipe. No movement. Circulate out crude holding 50 psi back pressure. 1.5/1.35/3300 w/ 12.3 ECD PVT 307 Fin circ crude to TT. Bring returns inside and circ wellbore w/ open choke 1.51/1.46/3160 w/ 11.91 ECD while keeping -8k max surface wt stacked while occasionally orient freely 360 deg w/ no change to wob Check on status of nearby injectors and find out that 1 E-04 was SI within the hour After circ two BU s 1~. ~ i/1.45/3150 w/ 11.88 ECD=3600 bhp 08:30 - 09:10 0.67 DRILL N STUC PROD2 SD pump and SI well ~ choke w/ Printed: 3/12/2008 11:46:54 AM BP AMERICA Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Event Name: REENTER+COMPLETE Start: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date I From - To Hours Task ~ Code NPT Phase 12/16/2008 108:30 - 09:10 I 0.671 DRILL I N I STUC I PROD2 09:10 - 10:30 I 1.331 DRILL I N I STUC I PROD2 10:30 - 17:25 I 6.921 DRILL I N I STUC I PROD2 17:25 - 18:45 I 1.331 DRILL I N I STUC I PROD2 18:45 - 20:35 1.83 DRILL N STUC PROD2 20:35 - 20:45 0.17 DRILL N STUC PROD2 20:45 - 21:35 I 0.831 DRILL I N I STUC I PROD2 21:35 - 22:00 0.42 DRILL N STUC PROD2 22:00 - 22:25 0.42 DRILL N STUC PROD2 22:25 - 23:00 0.58 DRILL N STUC PROD2 23:00 - 00:00 1.00 DRILL N PROD2 2/17/2008 ~ 00:00 - 02:00 2.001 DRILL N STUC PROD2 02:00 - 02:15 0.25 DRILL N STUC PROD2 02:15 - 02:55 0.67 FISH N STUC PROD2 02:55 - 04:05 1.17 FISH N STUC PROD2 04:05 - 06:15 2.17 FISH N STUC PROD2 06:15 - 07:20 1.08 FISH N STUC PROD2 1 /15/2008 Page 15 of 25 ~ Spud Date: 2/20/2000 End: Description of Operations Initial WHP=O, CTP 0, IA =725, OA 403, ECD 9.92=3006 5 min WHP 130, CT 0, IA 720, OA 402, ECD=9.94=3018 10 min WHP 215, CT 0, IA 702, OA 398, ECD 9.94=3017 15 min WHP 245, CT 0, IA 681, OA 394, ECD 9.91=3005 30 min WHP 256, CT 0, IA 657, OA 386, ECD 9.81=2977 Start pump at 0.5 bpm and at CTP=800 psi, whp incr to 260 psi Continue pumping at 0.5 bpm until whp reached 700 psi SD pump and work CT 3 cycles w/ 55k/-8k w/ 700 psi whp and no movement Note: 256 psi WHP + 8.6 ppg mud = 2917 psi = 9.43 ppg EMW at 11,300' MD, 5951' TVD. CBU w/ open choke 1.53/1.43/3200 w/ 11.93 ECD initial. See increased cuttings. Geo is seeing more 62 shale + floc'd mud Conference call Order 250 bbls 10# FloPro mud Pump 37 bbl 50k LSRV pill. With pill in annulus, 1.52/1.18/3380 w/ 12.48 ECD. Circ out pill w/minor additional cuttings. Continue Circ 1.52/1.40/3230 w/ 11.95 ECD while stack wt and recip occasionally while wo KW mud. Wear at this spot is <20% SD pump and trap 400 psi whp. Move CT to neutral wt. Open EDC. Circ thru EDC at 1.46/1.34/2670 w/ 11.88 ECD while work CT occasionally at BHI limits during crew change Pump KWF downhole 1.5bpm in /1.34bpm out. Reduce to 1 bpm in / 0.66bpm out ~ 50bbls away due to losses. Final rates are 0.94bpm in / 0.56bpm out. KWF on out MM, stop pumping. Flow check well & let formation relax. Flow stopped for 2min but started again & got to 0.03bpm flow rate. Close choke & determine shut in pressure. Initial WHP=O, CTP 0, IA 750, OA 403, ECD 10.89=3276psi 30 min WHP 51, CT 0, IA 696, OA 403, ECD 10.46=3175psi PJSM regarding bleeding IAP, RU hose & bleed off IA pressure own to chec or the possibility of Tx1A communication WHP has stabilized at 50psi. IAP =120psi. Work pipe. Open choke & circulate. 0.96bpm in/0.42bpm out. Stop pumping & flow check well. Send command to disconnect from tool. Start pumping ~ 1 bpm & PU to 32k to release. Clean PU. POH. Open hole is clean. Fill across the top while POH in the liner. Continue to POH. Weight up more 8.6 ppg Flo-Pro to 10 ppg Flo-Pro. Strap & tally 2-3/8" drill collars. PJSM while POH regarding handling BHA. Flow check well. Pop off well. LD tools. Cut off coil connector. MU BOT slip connector & pull test to 30k. Fuction test BOPE per AOGCC reps. MU BHA. Lock-tite all MT connections. Drift all drill collars as they are PU off the catwalk. Stab onto well w/ injector. Set counters &RIH. 11200' CTD 24.Ok, 5k Circ 1.30/0.52/3450 to fill CT. Red rate to 0.31/0.28/1355 and RIH 30'/min. Thru window, clean. Set Printed: 3112/2008 11:46:54 AM s r BP AMERICA Page 16 of 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations 2/17/2008 06:15 - 07:20 1.08 FISH N STUC PROD2 down at 12467' due to TF change at 12350'. Lost ground back to 12415'. RIH losing weight while pushing uphill. Start gaining RIH wt after 12650' 07:20 - 07:25 0.08 FISH N STUC PROD2 12810' 25.6', 1.5k 0.30/0.30/1350 RIH to 2k wt loss at 12835' CTD and got wt back. RIH to 3k wt loss at 12843' and got wt back. SD pump, PUH w/ 3k over and looks like fish is on PVT 67 07:25 - 08:50 1.42 FISH N STUC PROD2 P OH 20'/min thru openhole w/ 3-5k over filling from the BS. Pull thru the window 11200' 28.8k 08:50 - 11:45 2.92 FISH N STUC PROD2 POOH w/fish. Minor OP at 9050' 11:45 - 12:15 0.50 FISH N STUC PROD2 Nordic crew change Safety meeting re: LD fishing BHA 12:15 - 13:00 0.75 FISH N STUC PROD2 Set injector on legs. Pull out and cut off 204' of a-line slack! LD accelerators, 7 2-3/8" DC's, jars, hyd disc, GS. No recovery Inspect GS and found no debris behind dogs. Assuming that spear may have not been fully inserted since we did not set down and stack wt 13:00 - 13:50 0.83 FISH N STUC PROD2 MU same BHA 13:50 - 15:40 1.83 FISH N STUC PROD2 RIH w/ BHA #18 circ thru GS at min rate 15:40 - 16:40 1.00 FISH N STUC PROD2 11230' 24.2k, 5.Ok 0.6/1600 Red rate to 0.37/1300 and RIH 35'/min, clean thru window 6.2k. Smoother hole this time and higher RIH wt. No set downs. Lost wt at 12777'. Set down at 12827' and start ushin somethin to 12835' and set down solid numerous times, 24.8k u wt 16:40 - 17:25 0.75 FISH N STUC PROD2 Work to latch fish in tite hole. Hard to get to fish while pumping 1.26/0.45/3400 since will hydraulic off bottom. Wash down to 12846' and determine this is the top of fish. Wash up top of GS profile. RIH to 12846' numerous times w/ increasing speed and finally latched up and pulled 30k twice and spud to be sure fully inserted 17:25 - 18:00 0.58 FISH N STUC PROD2 Start working jars in down mode and no action after three tries. Try in up mode at 32k and 35k and no jar action. Stack wt and circ 0.45/1490 for crew change 18:00 - 20:20 2.33 FISH N STUC PROD2 tart 'arrin up & down, not able to jar in the downward position possibly due to drag and DLS. 14th jar lick up & got -4' of movement, getting - 4k up jar licks. Fill across the top to fill the hole - 1 bbl losses in 2 hrs. 20:20 - 20:50 0.50 FISH N STUC PROD2 - 10' of travel so far. Circulate down coil to warm up & let jars cool off. 20:50 - 21:15 0.42 FISH N STUC PROD2 26 'ar licks u & fish is free. 21:15 - 00:00 2.75 FISH N STUC PROD2 Fill across the top & POH - 31 k up wt. 2/18/2008 00:00 - 00:30 0.50 FISH N STUC PROD2 Continue to POH. PJSM while POH regarding handling BHA. 00:30 - 00:40 0.17 FISH N STUC PROD2 Flow check well. 00:40 - 00:50 0.17 FISH N STUC PROD2 Pop off well & place injector over bung hole &circ at min rate. 00:50 - 02:00 1.17 FISH N STUC PROD2 Pull out and cut off 99' of a-line slack. LD accelerators, 7 2-3/8" DC's, jars hyd disc, GS. Recovered entire drilling BHA. LD drilling BHA. 02:00 - 02:40 0.67 DRILL N STUC PROD2 Send out BOT fishing tools via beaver slide. Prep end of a-line prior to pumping slack. Stab onto well. Fill hole & close master. Blow down BHI tool string on catwalk & prep for shipping. 02:40 - 03:00 0.33 DRILL N STUC PROD2 Pump slack into reel. RU cutter. Pop off well. 03:00 - 04:45 1.75 DRILL N STUC PROD2 Install night cap & fill across the top to keep the hole full. Start Printed: 3/12/2008 11:46:54 AM BP AMERICA Page 17 of 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours ~ Task Code NPT ~ Phase _ _ 2/18/2008 103:00 - 04:45 1.75 DRILL N I STUC PROD2 04:45 - 07:00 2.25 DRILL N STUC PROD2 07:00 - 09:00 2.00 DRILL N STUC PROD2 09:00 - 10:10 1.17 BOPSU N STUC PROD2 10:10 - 11:15 1.08 DRILL N STUC PROD2 11:15 - 12:15 1.00 DRILL N DFAL PROD2 12:15 - 14:15 2.00 DRILL N STUC PROD2 14:15 - 14:45 0.50 DRILL N STUC PROD2 14:45 - 15:40 0.92 DRILL N STUC PROD2 15:40 - 16:00 I 0.331 DRILL I N I STUC I PROD2 16:00 - 16:45 0.75 DRILL N DPRB PROD2 16:45 - 17:15 0.50 DRILL N DPRB PROD2 17:15 - 18:25 1.17 DRILL N DPRB PROD2 18:25 - 19:25 1.00 DRILL N DPRB PROD2 19:25 - 19:30 0.081 DRILL N DPRB PROD2 19:30 - 23:00 I 3.50 I DRILL I N I SFAL I PROD2 23:00 - 23:20 0.33 DRILL N SFAL PROD2 23:20 - 00:00 0.67 RIGD N SFAL PROD2 2/19/2008 100:00 - 00:40 0.671 DRILL N ~ SFAL PROD2 Description of Operations cutting coil. Cut 320' of coil to find wire. RD cutter. Test wire - good. Prep coil for coil connector. Install Kendel dimple connector. Pull test to 25k -good. MU agitator to motor & scribe same. Circ thru coil to warm it up. Head up BHI tools. Re-test wire -good. P.T. connector to 3500psi -good. C/O injector packoffs SWS perform injector chain inspection and replace 10 pins Pump slack forward with injector over the bung hole Set injector back on well and PT packoff as part of BOPE test 250/3500 MU drilling BHA incl agitator and res tool. Add additional lub for MPD spacing. Stab onto well w/ injector and prep to RIH Have problem w/ MWD test. Find short in LOC RIH circ thru EDC 0.95/2300 while finish pump slack forward. Swap to used 8.6 ppg FloPro at 10000' Log tie-in down from 11235' 0.85/0.85/2000, corr -11'. Close EDC RIH thru window, clean. Wiper in hole. Had several set downs 11610-650' and get by at red rates. Continue wiper clean to 12780' Spot check comparing this res tool to the prior one indicated poor repeatability of shallow curves around 12750'-geos are aware Ream from 12780' 1.37/1.37/3100 at DTF at 10'/min. Slow down at 12820' to 5'/min. Stalled motor at 12824'. PU and were bit stuck. Work w/o pump to 5k over, got free in down mode. PU and stuck BHA at 12815'. Work up to 10k and were able to go down. Start pump and pull up hole slow and were able to get BHA free Wiper OOH while discuss Pull heavy and have MW at 11490'. Backream slow to window Wiper back in hole at 20'/min while WOO was clean Slowly wiper to TD. Double check handling equipment, xo's, floor valve, safety jt, rig tongs for running liner. Organize trucks for mud swap from 8.6ppg to 10ppg. Call BOT of upcoming liner lob. Start pumping 10ppg Flo-Pro down the coil. 1 bbl into the mud swap & pin hole on the coil ~ the horses head _ 12490' (not near a weld & the pin hole was from the inside out). Paint a sad 'mellow yellow' flag on the reel at the pin hole. Slowly POH to cover the pin hole w/ coil while pumping across the top to keep the hole full holding pressure on the well to prevent an influx. Call for new 2" a-line coil (has to be loaded onto a trailer via a large crane), bulkhead & N2 from Kuparuk & MI corrosion inhibitor & methanol pup trailer. Release vac trucks hauling 10ppg Flo-Pro. Fill pill pit w/ water for flushing coil. Flow check well for 10 min. PJSM regarding LD BHA. Pop off well. Place injector over bung hole & circulate fresh water 0.7bpm/1000psi. Pull BHA out of well & LD/blow down on catwalk. Close master valve. LD 5' lubricator from bottom of injector. Continue to circulate fresh water 0.9bpm/900psi. Stab onto Printed: 3/12/2008 11:46:54 AM BP AMERICA Page 18 of 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase Description of Operations __ ___ i 2/19/2008 00:00 - 00:40 __ -_ 0.67 DRILL N SFAL PROD2 _ __ well. Open master -vac. Fill hole - 3bbls per hr losses! Spot & RU N2 unit - PT to 4000psi. 00:40 - 00:55 0.25 DRILL N SFAL PROD2 PJSM regarding blowing down reel. 00:55 - 01:25 0.50 DRILL N SFAL PROD2 Pump 10bbls of water/inhibitor. Pump 10bbls of methanol. RU pull back wire. 01:25 - 01:40 0.25 DRILL N SFAL PROD2 Blow down reel with N2 & take returns to tiger tank. 01:40 - 02:30 0.83 DRILL N SFAL PROD2 Let coil bleed off. RD N2 unit. Round trip methanol pup trailer. Order dirty vac truck for TT/CB/pit#1,3,4&5. 02:30 - 03:30 1.00 DRILL N SFAL PROD2 Pop off well. Fluid pack mud pump w/ Flo-Pro. Install night cap & fill hole - 3bbls, continue to fill across the top w/ C-pump to keep hole full. Cut off coil connector. Cut a-line cable. Dress coil & install grapple connector & pull back wire. 03:30 - 05:25 1.92 DRILL N SFAL PROD2 Pull coil across into reel house & secure w/ shipping bar. Remove hardline, junction box & pressure bulkhead from inner reel. Hook up lifting slings to brige crane. 05:25 - 09:00 3.58 DRILL N SFAL PROD2 Lower the pin holed reel to the ground onto a trailer & PU new 2" a-line flash free reel. Secure reel. Remove lifting slings. Install internal grapple. 09:00 - 11:30 2.50 DRILL N SFAL PROD2 Test wire -good. Remove snow & shipping plastic covering reel. RU inner hardline inside reel. RU junction box. RU pressure bulkhead & grease same. Chain off hardline. 11:30 - 13:20 1.83 DRILL N SFAL PROD2 PJSM regarding stabbing coil. Pull coil across & stab into injector. Cut off grapple. Test wire -good test. 13:20 - 15:00 1.67 DRILL N SFAL PROD2 Pump 10bbls of methanol and chase w/ rig water. Take returns to tiger tank. PT inner hardline and bulk head to 4000psi -good test. 15:00 - 16:05 1.08 DRILL N SFAL PROD2 PJSM regarding slack management. Pump slack into reel. Pop off & cut 10', found wire. Stab onto well. Blow down stack. Blow air into reel & recover 3bbls of fluid. Pop off well. Open swab - can't see fluid level & has been 2-1/2 hrs - 1/3bbl per hr losses. Call out BOT to run liner. 16:05 - 20:30 4.42 DRILL N SFAL PROD2 Test wire -good. Prep end of coil. Install CTC & pull test to 30k - good. After reviewing plan forward. Decided to run the liner in ', two pieces and trying to conduct open hole sidetrack at 12140 ft+/- 20 ft. Filled hole after 2 hrs, took 1/2 bbl. 20:30 - 22:00 1.50 CASE N SFAL LNR2 PU Lower Liner as per Summary 22:00 - 00:00 2.00 CASE N DPRB LNR2 RIH with BHA #20: Bottom segment of 2-3/8" slotted liner with Deployment sleeve 2/20/2008 00:00 - 00:30 0.50 CASE N DPRB LNR2 RIH, Wt check at 11,300 24.3k up. 78001b down 00:30 - 00:45 0.25 CASE N DPRB LNR2 Tie in at GR marker at 11,230 ftCorrect -6 ft 00:45 - 02:45 2.00 CASE N DPRB LNR2 RIH and set down at 12,626 ft, Top of deployment sleeve at 12,214 ft. Try to working the shoe past this area at various speeds. This is the CTC depth while fishing for the lost BHA earlier. Tried several times racket the shoe, final after 35 cycles and picking up 100 ft at various times, work the liner to 12 853 ft on down stroke and its solid. Increased Op to 2.00 bpm and released from liner 02:45 - 05:15 2.50 CASE N DPRB LNR2 POOH. 05:15 - 05:45 0.50 CASE N DPRB LNR2 Pop off well. LD SHI BHA. 05:45 - 07:30 1.75 CASE N DPRB LNR2 MU liner consisting of crayola tip guide shoe, 9jts of slotted 2-3/8" tubin ,aluminum billet. No losses. MU BHI tools to liner via hyd GS. MU coil to BHI tools. tab onto well with injector. 07:30 - 10:05 2.58 CASE N DPRB LNR2 Set counters, open EDC &RIH circ ~ min rate Printed: 3/12/2008 11:46:54 AM 1 ~`. BP AMERICA Page 19 of 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: .Date. From - To Hours ' Task Code . Nf'T' Phase Description of Operations 2/20/2008 07:30 - 10:05 2.58 CASE N DPRB LNR2 0.25bpm/1200psi. Stop ~ 6000' & fix reel drive plate bolt that fell out (broken reel plate). Wt ck w/ pumps off ~ 11250' _ 22.3k, 6k RIW. Close EDC. RIH 60'/min in open hole w/liner w/out pumping. Stop ~ 11500'. 3bbl loss during trip in the hole. 10:05 - 10:20 0.25 CASE N DPRB LNR2 Log down for tie-in (-11ft). 10:20 - 11:00 0.67 CASE N DPRB LNR2 Continue to RIH w/liner. Set down ~ 12060'. RIW = 5k to 4k. Wt ck ~ 12410' = 26k. RIH w/liner & set down ~ 12441'. PU & reconfirm set down depth. Tag at 12441' & set 2.5k# DHWOB. Start pumping ~ 1.7 pm/3800 psi. PU & release from liner, lost 5k#. PU to 12400' & stop pumping up wt is 23k. Liner is released. To of liner billet = 12136'. 11:00 - 13:20 2.33 CASE N DPRB LNR2 Start pumping at 0.6bpm/1500psi. POH. PJSM regarding handling BHA while POH. 13:20 - 15:05 1.75 CASE N DPRB PROD2 Flow check well. Pop off well. Blow down BHI tools. LD BHI tools onto catwalk, MU HOT to tool string. Test tools. PU BHI sidetrack BHA. Stab coil onto tools. Stab onto well. Power up & test tools. 15:05 - 17:05 2.00 DRILL N DPRB PROD2 Set counters &RIH. 17:05 - 17:20 0.25 DRILL N DPRB PROD2 Log down for tie-in (-10ft). 2bbl loss on trip in the hole. 17:20 - 18:05 0.75 DRILL N DPRB PROD2 Wiper to 12100'. Set down at 11580' (end of build section), PU & reduce rate to lbpm & pass through. Continue to wiper to 12100' -clean. Op = 1.47 / 1.39 bpm at 3168 psi ECD /BHP = 11.96 ppg / 3660 psi 18:05 - 18:15 0.17 DRILL N DPRB PROD2 Stop RIH ~ 12100'. Zero the WOB sensor. Stop pumping & lightly tag the top of the billet. Tag top of billet ~ 12135'. PU 10' & turn umps on. 18:15 - 19:20 1.08 DRILL N DPRB PROD2 Start troughing from 12100' to 12130 5 o r. Made 2 runs Op = 1.60 / 1.37 bpm at 3450 psi ECD /BHP = 11.80 ppg / 3598 psi PVT = 334 Talked to crew and introducing them to RLG Rick 19:20 - 22:55 3.58 DRILL N DPRB PROD2 RIH and stopped at 12,133.5 ft Time drilling off of billet at 5min / 0.1 ft Op = 1.59 / 1.53 bpm at 3357 psi ~` ~ ECD /BHP = 11.90 ppg / 3635 psi PVT = 325 bbl Started 0.1 ft per 3 min at 12,133.5 ft Stall 12,135.3 ft, PU heavy at 44k (-19k over). Worked back down and started again 12,133.3 ft 5min / 0.1 ft Drilled down to 12,134 ft, just stacking wt. WOB at 1.76 and not drillling off 22:55 - 00:00 1.08 DRILL N DPRB PROD2 Backed reamed to 12,100 ft and reamed back down to 12,133 ft twice. 2/21/2008 00:00 - 00:33 0.55 DRILL N DPRB PROD2 Finished re-trough the open hole from 12,133 ft to 12, 100 ft at 60 fph 00:33 - 02:55 2.37 DRILL N DPRB PROD2 RIH, stopped at 12,133 ft (2' shallower than previous). Time drilling off of billet again at 5min / 0.1 ft Op = 1.59 / 1.51 bpm at 3260 psi ECD /BHP = 11.83 ppg / 3606 psi PVT = 302 bbl Seeing 0.4 Ib to 0.8 WOB and drill off slowly 02:55 - 03:00 0.08 DRILL N DPRB PROD2 Stall at 12,135.0 , PU and started again at 12,133.9 ft. Stall at Printed: 3/12/2008 11:46:54 AM BP AMERICA Page 20 of 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours j Task Code', NPT ~ Phase Description of Operations 2/21/2008 102:55 - 03:00 0.081 DRILL N I DPRB PROD2 03:00 - 03:45 0.75 DRILL N DPRB PROD2 03:45 - 06:20 2.58 DRILL N DPRB PROD2 06:20 - 06:30 0.17 DRILL N DPRB PROD2 06:30 - 07:15 0.75 DRILL N DPRB PROD2 07:15 - 09:15 2.00 DRILL N DPRB PROD2 09:15 - 10:10 0.92 DRILL N DPRB PROD2 10:10 - 12:25 2.25 DRILL N DPRB PROD2 12:25 - 12:50 0.42 DRILL N DPRB PROD2 12:50 - 13:20 I 0.501 DRILL I N I DPRB I PROD2 13:20 - 13:35 0.25 DRILL N DPRB PROD2 13:35 - 14:55 1.33 DRILL N DPRB PROD2 14:55 - 17:10 ~ 2.25 ~ DRILL ~ N ~ DPRB ~ PROD2 17:10 - 19:25 2.251 DRILL N I DPRB I PROD2 19:25 - 21:30 I 2.081 DRILL I N I DPRB I PROD2 12,134.2 ft. Pull up to 58k to get free. Bit stalled 2 ft higher. Believe the liner is along side of us and coming up the hole with us. Pulling up to 60 k (+35k over). Workin stuck i e at 12,125 ft. The liner is coming up the hole with us. Believe the top o t e fillet is at _12,125'. Pulled up to 60k again and got free. Total of 10 cycles was PUH and called the town team POOH with open EDC Flow check well & PJSM w/ day crew regarding handling BHA. 2 bbl loss on trip out of hole. Pop off well & place injector over bung hole, circ min rate. Blow down tools. LD tools on catwalk. Bit had 1 plugged jet from a piece of aluminum. Replace EDC on tool string. Test tools - good. Discuss w/ town regarding the current situation. Get orders. E-mail pictures. Wait on orders. Made the final decision to run a R60 bit w/ 1.7 ako motor. Dial down motor to 1.7 AKO setting. MU R-60 bit. PU BHI tools & make up to motor. PU injector & MU to tool string. Stab onto well. Power up & test tools. Set counters &RIH w/out pumping. Log down for tie-in (-9ft) corr ~ 11230'. Break circulation ~ min rate 0.32bpm/1120psi. Stop pumping & run past whipstock. RIH to 11350' & resume circ ~ 0.31bpm/1168psi. RIH to TD. Set down & bobble past 11490'. Ratty w/little motor work from 11900' to 12100'. Start pumping at max rate. Op = 1.63 / 1.30 bpm at 3373 psi ECD /BHP = 11.81 ppg / 3595 psi Turn TF 180 degrees opposite of drilled TF &PUH & attempt to knock off brass cap. 23k up wt. Reduce rate &RIH to 12115'. Work back & forth. from 11700' to 12120'. Dry tag ~ 12134', which is 9' deeper than previously thought. PU & repeat 3 times w/ 1.6K to 2.6k WOB. PU to 12110', start pumping &RIH 180 degrees out. Inadvertently tag & stall motor ~ 12132' w/ pumps on while trying to confirm that the brass cap is off. Shut down pumps, 38k overpull. Reduce pump rate &PUH to 12100'. Increase to normal pump rate, let stretch out of coil. .Start troughing from 12100' to 12035' 160R of HS ~ 30ft/hr. Op = 1.62 / 1.44 bpm at 3450 psi ECD /BHP = 12.00 ppg / 3660 psi PVT = 243 Reduce pump rate &PUH to 12100'. Increase to normal pump rate, let stretch out of coil. Start troughing from 12100' to 12060' 160R of HS ~ 60ft/hr. Op = 1.62 / 1.44 bpm at 3600 psi ECD /BHP = 12.15 ppg / 3700 psi PVT = 228 RIH and set at 12,100 ft TF at 164 R Op = 1.55 / 1.45 bpm at 3280 psi Time drilling at the start of the ST at 12,100 ft Printed: 3/12/2008 11;46:54 AM BP AMERICA Page 21 of 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: ~ Date From - To Hours Task. Code NPT .Phase Description of Operations 2/21/2008 19:25 - 21:30 2.08 DRILL N DPRB PROD2 0.1 W 2 to 3 min 21:30 - 23:00 1.50 DRILL N DPRB PROD2 Took off break and drill ST at a TF 160 deg RHS ROP at 0.1 fpm WOB 0.15 to 0.2 Ib. 3430 psi Pp off bottom at 1.57 bpm No indication on ST status from NBI or WOB sub at 12,103.9 ft to 12,106 ft at 0.1 fpm At 12,106 ft, started pushing on bit. Some evidence of ST at 12,111 ft WOB at 1.67 klbf, Pp at 3,420 psi, hole angle at 92.56 deg. Stacking. PU, 26k, RBIH With TF at 164 R, work way down ramp. Drilling ST ? at 12,114 ft, 29 fph and 2.54 klb WOB, CT weight at -6800 Ib. NBI at 92.9 deg hasn't changed in 16 ft drilled. At -9k coiled tubing wt, PUH to 12,103 ft. RBIH and seen some motor work and WOB at 12,112 ft 23:00 - 00:00 1.00 DRILL N DPRB PROD2 At 12,114 ft lost 1.00 bpm of returns and 300 psi on annulus and CT. PUH and checked all surface equipment and lines, (OK) Back to drilling Op = 1.57 / 0.87 bpm. RBIH WOB at 1.87 klb, With NBI at 12,107 ft the hole angle dropped to 91 deg from 92.5 deg. The trough did nothing to achieve this sidetrack. Turning the TF to the left while drillling sidetrack at 12,116 ft. 2/22/2008 00:00 - 00:45 0.75 DRILL N DPRB PROD2 Drilling sidetrack from 12,125 ft to 12,129 ft Op = 1.56 / 0.80. bpm. CTP=3,200 psi WOB at 1.08 klb and ROP with R60 at 9-11fph NBI at 12,113 angle at 89.72 deg 00:45 - 01:45 1.00 DRILL N DPRB PROD2 PU and RBIH and no ROP at 12,129 ft Back reamed sidetrack area from 12,129 ft to 12,080 ft at TF on the rside Dry tagged at 12,128 ft 01:45 - 04:15 2.50 DRILL N DPRB PROD2 POOH for BOP test Losing 0.6 bpm while POOH. Regained returns after pulling past 11,380 ft. Open EDC at 11290 ft and POOH pumping at 2.10 bpm. Out micro motion fluid rate increased while POOH Once out of the the hole, no fluid loss is seen 04:15 - 05:00 0.75 DRILL N DPRB PROD2 PJSM, Checked flow and unstabbed injector. LD sidetrack BHA 4 gauge cutters broke off. 1-5-2.71 go. Bit is still gauge on diamond gauge cutters, but matrix below PDC cutters is worn down to 2.65" OD. Closed Swab valve in preparation of BOP test 05:00 - 11:00 6.00 BOPSU N DPRB PROD2 BOP test per AOGCC regs. PJSM regarding PU injector. PU injector & remove checks from BHI tools. Stab onto well. PT inner reel valve & stripper per AOGCC regs. 11:00 - 11:45 0.75 DRILL N DPRB PROD2 Blow down stack. Open master & swab, fill hole ~ 1 bbl to fill hole. Place injector over bung hole & circ min rate. Place motor & bit in hole. PU BHI tools & MU to motor & bit. PU injector & stab coil onto BHA. Stab injector onto well. Set counters. 11:45 - 13:50 2.08 DRILL N DPRB PROD2 RIH. 13:50 - 14:10 0.33 DRILL N DPRB PROD2 Log down for tie-in (-10ft). 14:10 - 14:45 0.58 DRILL N DPRB PROD2 Wiper to TD. 50% losses. Op = 1.61 / 0.77 bpm. CTP=3,100 psi ECD 11.53 14:45 - 15:00 0.25 DRILL N DPRB PROD2 Drilling at 12130 ft TF at 60 deg R Op = 1.61 / 0.72 bpm 3100 psi off bottom BHP /ECD = 3484 psi / 11.42 ppg Printed: 3/12/2008 11:46:54 AM BP AMERICA Page 22 of 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Event Name: REENTER+COMPLETE Start: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code NPT Phase 2/22/2008 14:45 - 15:00 0.25 DRILL N DPRB PROD2 15:00 - 15:10 0.17 DRILL N DFAL PROD2 15:10 - 15:35 0.42 DRILL N DFAL PROD2 15:35 - 17:20 1.75 DRILL N DFAL PROD2 17:20 - 18:16 0.93 DRILL N DFAL PROD2 18:16 - 20:50 2.57 DRILL N DPRB PROD2 20:50 - 22:30 1.67 DRILL N DPRB PROD2 22:30 - 23:00 0.50 DRILL N DPRB PROD2 23:00 - 00:00 1.00 DRILL N WAIT PROD2 2/23/2008 00:00 - 00:50 0.83 DRILL N WAIT PROD2 00:50 - 02:05 1.25 DRILL N WAIT PROD2 02:05 - 02:30 0.42 DRILL N WAIT PROD2 02:30 - 03:40 1.17 DRILL N DPRB PROD2 03:40 - 05:30 1.83 DRILL N DPRB PROD2 05:30 - 07:00 1.50 DRILL N DPRB PROD2 07:00 - 09:30 2.50 DRILL N DPRB PROD2 09:30 - 10:35 1.08 DRILL N DPRB PROD2 10:35 - 11:15 0.67 DRILL N DPRB PROD2 1 /15/2008 Spud Date: 2/20/2000 End: Description of Operations Vp = 120 bbl Drilled to 12135' Need to reboot BHI computer. Slowly wiper up hole to clean up sidetrack. Need to re-install BHI database on computers. PUH into the tubing. Open EDC, circ min rate & slowly PUH. Close EDC. Wiper to TD. Drilling Lateral 2L-01 at 12134 ft to TF at 73R HS Op = 1.59 / 0.68 0.78 bpm at off bottom P= 3200 psi Vp = 429 bbl ROP 30-50 fph BHP = 3532 psi at ECD of 11.6 ppg Kupuark OC called Phase II weather conditions at 1950 hrs. Wiper trip Pulled tight with motor work at 11700 ft, 11576 ft and 11, 500 ft- At lower flowrates in the open hole, getting solids break out in the inverted section of the well At 10,420 ft, the out flow rate increased from 0.70 bpm to 1.29 bpm. At 11,325 ft, RIH at Op = 1.60 / 1.42 bpm to 11, 750 ft (clean out the belly of the well path) RIH and set down at 11,470 ft reduced Op and RIH and at 11,700 ft the out rate dropped off to losing 1.00 bpm. POOH and wait on fluid during Phase II in Kupuark Open EDC at 11,290 ft and PUH to 6000 ft and wait on fluid from tank farm during this Phase II period. Stopped at 8000 ft and check circulation Op =1.69 / 1.46 bpm. PUH to 6000 ft Op = 1.00 / 1.00 bpm BHP AT 6000 ft 1914 ps Cir waiting on fluid truck during Phase II weather condition Wait on vac truck with flo-pro during Phase II weather RIH while taking on flo-pro Tie-in at 11216 ft (GR Marker) Log tie-in at 11,240 ft (+18 ft) RIH with EDC closed and correct TF LC zone at 11,550 ft. Set down at 11580 ft, PU and reduced Op to 0.7 bpm and RIH Tagged bottom at 12253 ft Drilling lateral at 45L HS Op = 1.59 / 0.80 bpm at 3010 psi off bottom P Vp = 420 bbl's Wiper trip to window & to TD. Ratty through 11480 to 11650 w/ weight bobbles in this section. Drill lateral from 12348' TL at 60L HS Op = 1.54 / 0.76 bpm at 3060 psi w/1 k-1.5k DHWOB 1.3k surface Vp = 292 bbl's ROP 30-50 fph BHP = 3480 psi at ECD of 11.44 ppg Occasionally PU for BHA wiper to ensure proper hole cleaning. Drill to 12443'. Wiper to window -clean & few weight bobbles. Loss zone is at 11475'-11550' Wiper to TD -clean & no set downs or motor work. Printed: 3/12/2008 11:46:54 AM • BP AMERICA Page 23 of 25 ~ Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To ~ Hours ' Task Code' NPT Phase 2/23/2008 11:15 - 13:00 1.75 DRILL N DPRB PROD2 13:00 - 14:50 1.83 DRILL N DPRB PROD2 14:50 - 15:05 0.25 DRILL N DPRB PROD2 15:05 - 15:10 0.08 DRILL N DPRB PROD2 15:10 - 15:55 0.75 DRILL N DPRB PROD2 15:55 - 17:30 1.58 DRILL N DPRB PROD2 17:30 - 19:26 1.93 DRILL N DPRB PROD2 19:26 - 21:33 2.12 DRILL N DPRB PROD2 21:33 - 23:40 2.12 DRILL N DPRB PROD2 23:40 - 00:00 0.33 DRILL N DPRB PROD2 2/24/2008 00:00 - 01:30 1.50 DRILL N DPRB PROD2 01:30 - 02:50 1.33 DRILL N DPRB PROD2 02:50 - 03:45 0.92 DRILL N DPRB PROD2 03:45 - 05:10 1.42 DRILL N DPRB PROD2 05:10 - 07:10 2.00 DRILL I N DPRB PROD2 07:10 - 09:10 I 2.001 DRILL I N I DPRB I PROD2 09:10 - 11:40 2.50 DRILL N DPRB PROD2 11:40 - 12:30 0.83 DRILL N DPRB PROD2 12:30 - 12:35 I 0.081 DRILL I N I DPRB I PROD2 Description of Operations Drill lateral from 12443' TL at 60L HS Op = 1.55 / 0.77 bpm at 3010 psi w/ik-1.5k DHWOB -1k surface Vp = 389 bbl's ROP 30-50 fph BHP = 3497 psi at ECD of 11.43 ppg Pump 20 bbl to-vis pill down hole to help clean the hole. Drill to 12522ft. 28k up WT. Chase pill OOH. Wiper to window. Open EDC &PUH to 10500' RIH. Log down for tie-in (+11'). Close EDC. W iper to TD. Clean. Tag bottom. Drill lateral from 12525' TL at 120R HS Op = 1.48 / 0.82 bpm at 3010 psi w/1 k-1.5k DHWOB -1.5k surface Vp = 232 bbl's ROP 30-80 fph BHP = 3467 psi at ECD of 11.41 ppg Drill to 12625'. Clean PU 24k up wt. Wiper to window. Clean trip out. RIH Drill lateral from 12625' TL at 90L HS Op = 1.54 / 0.76 bpm at 3030 psi DHWOB 1.5 to 0.75k1b and 1.3k surface Vp = 292 bbl's ROP 30-100 fph BHP = 3495 psi at ECD of 11.50 ppg Wiper trip after drilling 100 ft formation Drill lateral from 12725' TL at 110E HS Op = 1.56 / 0.80 bpm at 3030 psi DHWOB 1.5 to 0.75k1b and 1.3k surface Vp = 433 bbl's ROP 30-100 fph BHP = 3510 psi at ECD of 11.54 ppg Drilling Lateral L2-01 PUH for wiper trip at 12,821 ft Tied in and corrected +11' RIH and tagged bottom at 12,828 ft Drilling lateral TF at 60LHS Op = 1.61 / 0.87 bpm at 3155 psi off bottom pressure WOP = 2-1 klb, ROP = 40 to 100 fph BHP = 3549 psi 11.66 ppg ECD Pulled tight at 12,903 ft (39k over to pet free) Wiper trip to window -clean. Wiper to TD -clean. swap well to 50/50 2%KCL/Flo-Pro into the pits. Drilling lateral from 12895' TF at 140LHS w/ 50/50 Op = 1.80 / 1.21 bpm at 2900 psi off bottom pressure DHWOB = 2-1 klb, Surface Wt = 0 Ibs, ROP = 40 to 100 fph BHP = 3370 psi, 11.08 ppg ECD Pump 2 10bb1 100% Flo-Pro pills to help clean the hole. Drill to 12980'. Chase pills OOH & wiper to window -clean. Wiper to TD. Drilling lateral from 12977' TF at 75LHS w/ 50/50 Op = 1.80 / 1.24 bpm at 2990 psi off bottom pressure DHWOB = 2-1 klb, Surface Wt = 600 Ibs, ROP = 30 to 60 fph BHP = 3430 psi, 11.21 ppg ECD Pump 10bb1 Flo-pro pill to help in sliding. Drill to 13002' Stacking out & not drilling. 100' wiper -clean. Wiper to TD -clean. Printed: 3/12/2008 11:46:54 AM BP AMERICA Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Event Name: REENTER+COMPLETE Start: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To i Hours Task Code NPT Phase 1 /15/2008 Page 24 of 25 Spud Date: 2/20/2000 End: Description of Operations 2/24/2008 12:35 - 14:40 2.08 DRILL N DPRB PROD2 Drilling lateral from 13002' TF at 70LHS w/ 50/50 Op = 1.80 / 1.18 bpm at 2990 psi off bottom pressure DHWOB = 2-1 klb, Surface Wt = 600 Ibs, ROP = 30 to 60 fph BHP = 3430 psi, 11.21 ppg ECD Hard drilling C~ 13045'. Pump 20 bbl 100% Flo-Pro pill. Drill to 13070' 14:40 - 16:25 1.75 DRILL P PROD2 Chase 20 bbl pill OOH. Wiper to window -clean. 16:25 - 16:40 0.25 DRILL P PROD2 Log for tie-in (+18' corr. 16:40 - 20:39 3.98 DRILL P PROD2 Wiper to TD. 1.5bpm ~ 2400psi. Start pumping 100k LSRV liner pill w/ 2ppb Alpine beads while RIH. Tag bottom ~ 13084'. La in liner pill. 20:39 - 21:40 1.02 DRILL P PROD2 LD drilling BHA, He PJSM on PU and handling liner 21:40 - 00:00 2.33 CASE P LNR3 Run 2-3/8" liner as per summary 2/25/2008 00:00 - 01:10 1.17 CASE P LNR3 Run 2-3/8" Liner as per programme. Spaced out liner 50' short PU BHI CoilTrac 01:10 - 03:39 2.48 CASE P LNR3 RIH with liner and Coiltrac Up Wt at 11,300 ft = 24.7k1b Logged GR Marker and corrected -11 ft. Set bottom of liner at 13,035 ft and the top of the liners at 11,313 ft 03:39 - 03:43 0.07 CASE P LNR3 Release from liner 03:43 - 05:45 2.03 CASE P LNR3 POOH. PJSM regarding handling BHA while POH. 05:45 - 07:00 1.25 CASE P LNR3 Flow check. Pop off well. Unstab coil from BHI tools. Place injector over bung hole. Blow down & LD BHI tools on catwalk. Liner is missing! 07:00 - 07:35 0.58 FISH P POST PJSM regarding PU fishing BHA. PU J-hook, jars, 1 drill collar, accelerator use lock-tite on each connection, scri a same. BHI BHA & MU to fishing BHA, scribe same. PU injector & stab onto BHI tools. Stab onto well. Set counters. 07:35 - 10:00 2.42 FISH P POST RIH w/fishing BHA. Circ at min rate. Pump 10 bbls of 75k LSRV pill to help clean top of the whipstock tray. WT ck ~ 11100' = 22k, RIW = 5.8k 10:00 - 11:00 1.00 FISH P POST Log down for tie-in (-11') from 11250'. Replace 4 safety reel plate bolts inside reel. WT ck = 24k up w/out pumping. 11:00 - 15:50 4.83 FISH P POST Orientate hook &RIH. Set down C~3 11314' & set 3k down. PU clean. Orientate 180 degrees out. se own a 06' & set 3k down. PU & slipped off. RIH & try to latch. Slipped off. Turn to 55 degrees. Set down & latch up ~ 11302'. PU & try to straight pull. Jars went off, continue to PU to 16K DHWOB (49k surface). Fish on. Continue to PU slowly ~ 20'/imn & break circulation @ 1 bpm. Up WT=26.8k. Swabbing is occurring. Overpull at 11035', still swabbing. Keep PUH ~ 15'/min. Weight bobbles at 10968'-Liner mule shoe, 10938'-Packer, 10900'-W nipple. Plant whipstock in W nipple. Try to cock jars. Popped free. Continue to POH, still swabbing. Circ through coil to fill hole while POH @ 60'/min. 15:50 - 17:00 1.17 FISH P POST Stop at 150'. Flow check well. PJSM regarding handling BHA. Pop off well. Slowly POH & inspect coil connector. Break off BHI tools & LD on catwalk, blow down same & replace Gamma Ray & test same. Pull rest of fishing BHA from well. LD whi stock -recovered all rubber elements & sli se ments. PU J-hook. iars. drill collar & accelerator. Scribe same. PU BHI Printed: 3/12/2008 11:46:54 AM ~ ~ BP AMERICA Page 25 of 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours ; Task Code ~ NPT i Phase Description of Operations i 2/25/2008 15:50 - 17:00 1.17 FISH P POST BHA & MU to fishing BHA. Stab coil onto BHA. Stab onto well. Test tools. Set counters. 17:00 - 19:00 2.00 FISH P POST -RIH w/fishin BHA. Circ at min rate. 19:00 - 19:25 0.42 FISH P POST Logged tiein at 11,250 ft. Corrected -14 ft, Wt check at 22k up Set jars at 11,315 ft and jarred 5 times at 40k and 1 time at 45k Came lose, PUH 19:25 - 22:22 2.95 FISH P POST POOH at 50 to 60 fph watching the hole for swabbing. Held PJSM on handling whipstock BHA 22:22 - 22:50 0.47 FISH P POST LD Fish and fishin BHA 22:50 - 23:20 0.50 FISH P POST LD fishing BHA and remove RA tag from WS. Load out BOT tools and fill hole. PU nozzle, extension and UOC 23:20 - 00:00 0.67 FISH P POST RIH to turn hole over to seawater 2/26/2008 00:00 - 01:30 1.50 WHSUR P POST RIH to turn hole over to seawater 01:30 - 03:30 2.00 WHSUR P POST POOH chasing flo-pro out of well. Stopped at 2000 ft 03:30 - 05:00 1.50 WHSUR P POST Working to get diesel out of vac truck. 05:00 - 06:00 1.00 WHSUR P POST Pumped 35 bbl diesel and displaced and POOH chasing diesel to surface 06:00 - 18:00 12.00 RIGD P POST Close master & swab. Start circulating cuttings box & super suck it out. Start circulating tiger tank & vac it out. Pop off well. Blow down BOP stack via new pressure hose to wing valve. Install night cap & check for pressure - Opsi. T bar in BPV. Close master & swab. Spot, RU & cool down nitrogen unit. Blow down reel. Opebn doors on 7-1/16" BOP and inspected ram blocks and cavity. OK Closed up and NW same. Installed tree cap and PT to 5000 psi. Rig Released at 18:00 hrs 2/26/2008 Printed: 3/12/2008 11:46:54 AM by BP Alaska $ Baker Hughes INTEQ Survey Report INTEQ ..Company: ConocoPhillips Alaska InC. Date:. 2/27/2008 Time:: 11:26:50 Page: 1 Fieldi Kuparuk River Unit Co-ordinate(NE) Reference:' Wefl: 1 L-28, True-North Site: Kuparuk 1 L Pad Vertical (TVD) Reference: 1 L-28: 119.9 Well: 1 L-28 Section (VS) Reference: Well (O.OON,O.OOE,58.77Azi) `Wellpath: 1 L 28L1 Sarvey Calculation Method: Minimum Curvature Db: Sybase Field: Kuparuk River Unit North Slope Alaska United States Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Geo Datum: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: Kuparuk 1 L Pad Site Position: Northing: 5949190.90 ft Latitude: 70 16 19.650 N From: Map Easting: 539916.78 ft Longitude: 149 40 37.763 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.30 deg We1L• 1 L-28 Slot Name: Well Position: +N/-S -133.36 ft Northing: 5949059.47 ft Latitude: 70 16 18.338 N +E/-W 360.83 ft Easting : 540278.28 ft Longitude: 149 40 27.258 W Position Uncertainty: 0.00 ft Wellpath: 1 L-28L1 Drilled From: 1 L-28 500292295160 Tie-on Depth: 11307.05 ft Current Datum: 1 L-28: Height 119.90 ft Above System Datum: Mean Sea Level . Magnetic Data: 12/11/2007 Declination: 22.98 deg Field Strength: 57619 nT Mag Dip Angle: 80.79 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 34.70 0.00 0.00 58.77 Survey Program for Definitive Wellpath Date: 12/11/2007 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 100.00 11307.05 Survey #1 (100.00-11770.00) (0) MWD MWD -Standard 11315.00 13150.00 MWD (11315.00-13150.00) MWD MWD -Standard Annotation MIJ TVD ft ft 11307.05 5957.42 TIP 11315.00 5964.47 KOP 13150.00 6085.11 TD Survey: MWD Start Date: 2/10/2008 Company: Baker Hughes INTEQ Engineer: Tool: MWO;MWD -Standard Tied-to: From: Definitive Path Survey MI) Incl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/100ft. 11307.05 27.56 89.54 5957.42 5837.52 3597.64 8221.09 5952700.70 548479.20 8895.09 0.00 MWD 11315.00 ~ 27.46 89.60 5964.47 - 5844.57 3597.66 8224.77 5952700.74 548482.87 8898.25 1.31 MWD 11345.12 35.79 70.00 5990.17 5870.27 3600.74 8240.05 5952703.90 548498.14 8912.91 43.62 MWD 11373.11 43.38 52.04 6011.79 5891.89 3609.49 8255.40 5952712.73 548513.43 8930.57 48.84 MWD 11402.16 49.13 28.00 6032.03 5912.13 3625.46 8268.53 5952728.77 548526.48 8950.08 62.68 MWD 11430.10 54.17 13.03 6049.42 5929.52 3645.91 8276.07 5952749.26 548533.91 8967.13 45.65 MWO 11459.52 63.76 8.24 6064.57 5944.67 3670.65 8280.67 5952774.02 548538.37 8983.89 35.44 MWD 11487.49 71.32 0.81 6075.26 5955.36 3696.38 8282.66 5952799.76 548540.22 8998.93 36.49 MWD 11518.74 81.33 359.17 6082.64 5962.74 3726.71 8282.64 5952830.08 548540.05 9014.64 32.43 MWD 11547.68 92.92 359.23 6084.09 5964.19 3755.56 8282.24 5952858.93 548539.49 9029.26 40.05 MWD 11580.34 103.78 359.36 6079.36 5959.46 3787.82 8281.84 5952891.18 548538.92 9045.64 33.25 MWD by BP Alaska s Baker Hughes INTEQ Survey Report 1NTE Q Company: ConocoPhillips Alaska)nc. Date: 2/27/2008 Time:. 11:26:50 Page: 2 Field:' Kuparuk River Unit Co-ordinate(NE) Reference: WeI1: 1 L-28, True North Site: Kuparuk 1 L Pad' Vertical (TVD) Reference: 1 L-28: 119.9 Well; 1 L-28 Section (VS) Reference: Well (l).OON,O.OOE,58.77 Azi) Wellpath: 1 L28L1 Survey Calculation Method: Minimum Curvature Db: Sybase Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE ' VS DLS Tool ft deg deg ft ft ft ft ft ft ft degll0pft 11609.95 105.11 3.00 6071.97 5952.07 3816.48 8282.43 5952919.85 548539.35 9061.01 12.72 MWD 11639.99 106.93 6.41 6063.68 5943.78 3845.25 8284.79 5952948.63 548541.56 9077.94 12.48 MWD 11669.57 106.01 4.10 6055.29 5935.39 3873.50 8287.39 5952976.88 548544.01 9094.81 8.11 MWD 11700.11 105.24 0.38 6047.06 5927.16 3902.88 8288.54 5953006.27 548545.00 9111.02 12.00 MWD 11731.02 104.13 356.25 6039.22 5919.32 3932.76 8287.66 5953036.14 548543.96 9125.76 13.41 MWD 11761.39 103.53 352.69 6031.96 5912.06 3962.11 8284.81 5953065.47 548540.96 9138.55 11.55 MWD 11791.48 103.53 349.14 6024.92 5905.02 3990.99 8280.19 5953094.32 548536.19 9149.57 11.47 MWD 11821.02 103.94 345.73 6017.90 5898.00 4018.99 8273.95 5953122.29 548529.80 9158.75 11.30 MWD 11850.32 103.76 341.21 6010.88 5890.98 4046.26 8265.86 5953149.51 548521.56 9165.97 14.99 MWD 11881.89 103.57 337.34 6003.42 5883.52 4074.94 8255.01 5953178.13 548510.55 9171.56 11.93 MWD 11911.99 101.87 332.82 5996.79 5876.89 4101.56 8242.64 5953204.68 548498.04 9174.78 15.70 MWD 11944.24 99.43 327.54 5990.83 5870.93 4129.04 8226.88 5953232,07 548482.14 9175.56 17.78 MWD 11974.18 97.91 323.60 5986.31 5866.41 4153.45 8210.15 5953256.39 548465.27 9173.90 13.96 MWD 12002.36 99.18 319.40 5982.13 5862.23 4175.25 8192.80 5953278.10 548447.82 9170.38 15.41 MWD 12030.61 101.74 316.19 5977.00 5857.10 4195.83 8174.15 5953298.57 548429.05 9165.09 14.39 MWD 12058.54 97.45 314.20 5972.34 5852.44 4215.36 8154.74 5953318.00 548409.55 9158.63 16.89 MWD 12087.33 96.18 319.43 5968.92 5849.02 4236.20 8135.19 5953338.73 548389.88 9152.71 18.57 MWD 12115.68 93.23 324.17 5966.60 5846.70 4258.39 8117.72 5953360.83 548372.30 9149.28 19.64 MWD 12141.38 91.84 328.60 5965.46 5845.56 4279.77 8103.52 5953382.12 548357.98 9148.22 18.05 MWD 12174.69 91.72 333.94 5964.42 5844.52 4308.96 8087.52 5953411.22 548341.83 9149.67 16.03 MWD 12203.86 90.12 338.33 5963.95 5844.05 4335.62 8075.72 5953437.82 548329.89 9153.41 16.02 MWD 12233.86 87.85 342.80 5964.49 5844.59 4363.90 8065.74 5953466.04 548319.76 9159.53 16.71 MWD 12264.09 85.17 346.82 5966.33 5846.43 4393.01 8057.84 5953495.11 548311.70 9167.87 15.96 MW D 12293.75 87.57 350.28 5968.21 5848.31 4422.01 8051.96 5953524.08 548305.67 9177.88 14.18 MWD 12323.78 87.94 353.92 5969.38 5849.48 4451.73 8047.84 5953553.77 548301.39 9189.77 12.17 MWD 12353.72 88.74 357.10 5970.25 5850.35 4481.56 8045.50 5953583.58 548298.89 9203.23 10.95 MWD 12383.23 89.54 1.25 5970.69 5850.79 4511.06 8045.07 5953613.07 548298.31 9218.16 14.32 MWD 12412.61 88.96 5.73 5971.08 5851.18 4540.37 8046.86 5953642.40 548299.94 9234.89 15.37 MWD 12442.68 90.06 10.88 5971.33 5851.43 4570.12 8051.20 5953672.16 548304.12 9254.02 17.51 MWD 12474.58 89.63 16.07 5971.42 5851.52 4601.13 8058.63 5953703.21 548311.38 9276.45 16.33 MWD 12504.59 87.42 20.11 5972.19 5852.29 4629.64 8067.95 5953731.76 548320.54 9299.20 15.34 MWD 12533.66 87.02 25.01 5973.60 5853.70 4656.44 8079.08 5953758.62 548331.53 9322.62 16.89 MWD 12560.87 87.05 29.16 5975.01 5855.11 4680.63 8091.45 5953782.88 548343.77 9345.73 15.23 MWD 12584.81 86.16 31.01 5976.43 5856.53 4701.31 8103.43 5953803.62 548355.64 9366.70 8.56 MW D 12619.73 84.78 32.74 5979.19 5859.29 4730.87 8121.81 5953833.27 548373.86 9397.74 6.33 MWD 12657.96 83.98 24.77 5982.94 5863.04 4764.20 8140.10 5953866.69 548391.97 9430.66 20.85 MWD 12689.37 85.11 20.26 5985.93 5866.03 4793.07 8152.07 5953895.63 548403.78 9455.87 14.74 MWD 12719.66 82.46 11.33 5989.21 5869.31 4822.01 8160.26 5953924.61 548411.82 9477.88 30.58 MWD 12749.08 82.71 15.05 5993.01 5873.11 4850.41 8166.92 5953953.04 548418.32 9498.29 12.57 MWD 12778.39 83.91 20.77 5996.43 5876.53 4878.10 8175.87 5953980.77 548427.12 9520.30 19.81 MWD 12809.74 81.81 23.44 6000.32 5880.42 4906.92 8187.57 5954009.65 548438.67 9545.25 10.78 MWD 12843.06 80.94 29.30 6005.32 5885.42 4936.42 8202.19 5954039.23 548453.14 9573.05 17.58 MWD 12887.93 80.60 36.96 6012.53 5892.63 4973.48 8226.38 5954076.41 548477.12 9612.94 16.87 MWD 12930.64 79.70 45.34 6019.85 5899.95 5005.14 8254.04 5954108.22 548504.61 9653.01 19.45 MWD 12959.69 78.82 49.87 6025.27 5905.37 5024.38 8275.11 5954127.57 548525.57 9681.00 15.62 MWD 12992.82 78.70 55.56 6031.73 5911.83 5044.05 8300.95 5954147.38 548551.31 9713.30 16.85 MWD 13026.23 77.13 57.41 6038.73 5918.83 5062.09 8328.19 5954165.56 548578.44 9745.94 7.17 MWD 13056.59 74.59 64.62 6046.15 5926.25 5076.35 8353.92 5954179.96 548604.09 9775.34 24.50 MW D 13103.03 62.21 65.48 6063.21 5943.31 5094.55 8392.98 5954198.36 548643.05 9818.17 26.71 MWD 13150.00 62.21 65.48 6085.11 5965.21 5111.79 8430.79 5954215.80 ~ 548680.76 ~ 9859.44 0.00 MWD KRU 1 L-28 Producer with L1, L2, & L2-01 Laterals 3'/z" Camco DS nipple, 2.813" min ID at 553' MD Note: Nipple milled out to 2.83" ID on 12/23/07 3'/2' 9.3# L-80 EUE 8rd Tubing 96/." 40# L-80 ~ 6546' MD 7" 26# L-80 ~ 11,117 MI L2 KOP 11,300' MD C4 Perfs 11295'-11320' L1 KOP 11.315' MD C3/C4 Perfs - 11334'-11364' Conoco hilli s p Alaska, Inc. 3'/2' Camco MMM GLMs @ 4258', 7197', 9051', 10316', & 10836' MD 2'/" slotted liner: 12,135' -12,853' MD intertace between liner segments at 12,440' MD Baker ZXP Packer w/SBE @ 10,944' MD aluminum billet at 12,135' MD 3'/z' Camco W nipple, 2.813" min ID @ 10,912' MD 1 L-28L2 Lateral, TD @ 13,150' MD 3'/Z' tubing muleshoe @10976' MD 2'/." slotted liner: 11,313' -13,035' MD solid jnts: 11,347' -11,817' %j ~ 2'/," slotted liner: 11,324' -13,150' MD solid juts: 11,377' -11,884' intertace between liner segments at 12,387' MD KB packers at 11,325 & 11,359 MD • Packer ID = 1.81" • 1.71" RR plug in tailpipe of lowest packer -~ Stuck WRP 11,400' MD (10/8/06) liner 10944' - 11,769' MD 1 L-28L2-01 Lateral, TD ~ 13,084' MD 1 L-28L1 Lateral, TD cLD 13,150' MD A-5 sand perfs 11518' -11538' Updated: 2-28-08 CJ Maunder, Thomas E (DOA) From: Eller, J Gary [J.Gary.Eller@conocophillips.com] Sent: Tuesday, May 13, 2008 12:45 PM To: Maunder, Thomas E (DOA) Subject: RE: 1 L-28L1, et al (207-153) Attachments: 1 L-28 CTD Liners.xls Tom -Try this. -Gary From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Tuesday, May 13, 2008 12:37 PM To: Eller, J Gary Subject: RE: 1L-28L1, et al (207-153) Gary, 1 hate to be picky, but do you have a breakdown for each lateral? Call me if the mix is complicated. Tom From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Tuesday, May 13, 2008 12:35 PM To: Maunder, Thomas E (DOA) Subject: RE: 1L-28L1, et al (207-153) Page 1 of 2 Tom -Ran 1040' of solid liner in the 1 L-28 CTD laterals out of a total of 4267' of finer run (24°!0). -Gary From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, May 12, 2008 5:07 PM To: Eller, J Gary; Hubble, Terrie L Subject: RE: 1L-28L1, et al (207-153) GaryR If you could provide the detail, 1'd appreciate. Nice to know you are drilling mostly pay. Tom From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.rnm] Sent: Monday, May 12, 2008 5:06 PM To: Maunder, Thomas E (DOA); Hubble, Terrie L Subject: RE: iL-28L1, et al (207-153) Tom - We typically only run blank across shale sections, signficant faults, and the window. I can give you a breakdown of the numbers if you like, but my guess is that solid liner constitutes ~10% of the finer in any given well -Gary 5/14/2008 From: Maunder, Thomas E (DOA) [mailto:tom.maunder@alaska.gov] Sent: Monday, May 12, 2008 5:01 PM To: Hubble, Terrie L; Eller, J Gary Subject: 1L-28L1, et al (207-153) Page 2 of 2 Terrie and Gary, I am reviewing the 407s for these recently completed wells. In the summaries, it is noted that the liners are combinations of slotted and blank. 1 see some "depth breaks" in the details in block 23. Based on the breaks, I am led to believe that not much solid liner was run in the laterals. Is that correct? Thanks in advance. Tom Maunder, PE AOGCC ~~ 5/14/2008 ~ ~ ~ ^ 1 L-28 L1 LINER SUMMARY Bottom Section ._.,_ WELL # KRDtL-28 LINER SIZE / WT/FT / GRADE t THREAD I ID 2~/8- 4.44# BOTTOM OF LINER AT 13,150.00 TOP OF LINER AT 12,386.61 -$0 DATE STL 2/8/ZOOB NO ITEM OD ID LENGTH TOP BOTTOM Unique Indebng Guide Shoe {3 ea 1/2" side ports) 2.650 0.660 1.36 13,148.64 13,150.00 1 2-318" 4.4# L-80 STL Solid Tubing 2.375 1.992 31.80 13,116.84 13,148.64 O-ring Sub 2.392 1.000 0.66 i 3,116.18 13,116.84 23 2-3/8" 4.4# L-80 ST~„$i0~IM17~ing 2.375 1.992 728.12 12,388.06 13,116.18 BTT Deployment Sleeve w/ 2-3/8" STL pin 2.700 1.920 1.45 12,386.61 12,388.06 12, 386.61 24 BHA Total Length 763.39 r ~ 1 L-28 L1 LINER SUMMARY Top Section WELL # KRD1 L-28 LINER SIZE / WT1FT 1 GRADE /THREAD / ID 2-3/8" 4.4411 BOTTOM OF LINER AT 12,38&.61 TOP OF LINER AT 11,324.27 -80 DATE STL zrs/zoas NO ITEM OD ID LENGTH TOP BOTTOM Unique Indepng Guide Shoe w/ 3/4" Center Hole 2.650 0.750 1.36 1 2,385.25 12,388.61 16 2-3/8" 4.4# L-80 STLTiubing 2.375 1.992 501.51 11,883.74 12,385.25 16 2-3/8" 4.4# L-80 STL Solid Tubing 2.375 1.992 506.78 11,376.96 11,883.74 1 2-318" 4.4# L-80 STLe~1-I'~bing 2.375 1.992 31.69 11,345.27 11,376.96 2-3/8" 4.4# L-80 STL pup joint 2.375 1.992 9.78 11,335.49 11,345.27 2-3/8" 4.4# L-80 STL pup joint 2.375 1.992 9.77 11,325.72 11,335.49 BTT Deployment Sleeve w/ 2-3/8" STL pin 2.700 1.920 1.45 11,324.27 11,325.72 11,32427 33 BHA Total Length 1i1~2.34 ri~~ BAKER 41UGI~IES INTEQ To Whom It May Concern: March 7, 2008 7260 Homer Drive Anchorage, Alaska 9951& Te1907-267-6600 Fax 907-267-6623 Please find enclosed directional survey data for wells: 1L-28L1, 1L-28L2 and 1L-28L2-O1. Enclosed is: 1 ea 3.5" floppy diskette containing electronic survey file Cc: State of Alaska, AOGCC Christine Mahnken STATE OF ALASKA 11/13/07 O !L AND GAS CONSERVATION COMMISSION BOPS Test Report Sulxnit to: Contractor: Nordic Rig No.: 2 DATE: 2/1108 Rig Rep.: Holmes/Sloan Rig Phone: 65~}-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-393 Op. Fax: 659-4356 Rep.: Hildreth/Goodrich E-Mail Well Name: Kuparuk 1L-28L7 PTD # 207-153 Operation: Drig: XX Workover: Explor.: Test: Initial: XX Weekly: Bi-Weekly Test Pressure: Rams: 250/3500 Annular: 250/3500 Valves: 250/3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Well Sign P Upper Kelly NA Housekeeping: P Dri. Rig P Lower Kelly NA PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NA BOP STACK: Quantity Size/Type Test Result MUD SYSTEM: Visual Alarm Stripper 1 2 3/8" P Trip Tank P P Annular Preventer 1 71/16" P Pit level Indicators P P #1 Rams 1 Blind/Shear P Flow Indicator NA NA #2 Rams 1 2" Combi P Meth Gas Detector P P #3 Rams 1 23/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Inside Reei valves 1 P HCR Valves 2 3 1/8" P Kill Line Valves 1 3 1/8" P ACCUMULATOR SYSTEM: Check Valve 2 21/16" P TimelPressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2200 P Quantity Test Result 200 psi Attained 20 sec. P No. Valves 14 P Fuil Pressure Attained 80 sec. P Manual Chokes 1 P Blind Switch Covers: AH stations Yes Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 2100 Test Results Number of Failures: 0 Test Time: 8_5 Hours Components tested 31 Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirrnation to Supervises at: Remarks: 24 HOUR NOTICE GIVEN YES XX NO Waived By John Cris Date 1 /29/08 Time 1200 Witness Meinhold/Goodrich Test start 2130 Finish 0600 BOP Coil for Rigs BFL 11/13/07 Nordic 2 BOP 2-1-08.x1s ~ ~ ~ ~ ~ d '~ SARAH PALIN, GOVERNOR ~-7~A OII/ taisil GAS 333 W. 7th AVENUE, SUITE 100 C01~5EItQA~l`IOr1T COl-Il-iI5SIOIQ ANCHORAGE, ALASKA 99501-3539 Gary Eller PAHONE (907) 279-1433 (907)276-7542 Drilling Engineer c/o BP Exploration Alaska, Inc. PO Box 196612 Anchorage, Alaska 99519-6612 Re: Kaparuk River Unit Field, Kaparuk River Pool, Kaparuk 1 L-28L 1 Drilling Engineer Permit No: 207-153 Surface Location: 89' FSL, 216' FWL, SEC. 29, T 11 N, R 10E, UM Bottomhole Location: 5076' FSL, 3390' FWL, SEC. 28, T 11 N, R 10E, UM Dear Mr. Eller: Enclosed is the approved application for permit to re-drill the above referenced development well. The permit is for a new wellbore segment of existing well KRU 1 L-28, Permit No 199- 098, API 50-029-22951-00. Production should continue to be reported as a function of the original API number stated above. This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field in~t~tor at (907) 659-3607 (pager). DATED this day of November, 2007 cc: Department of Fish 8v Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. STATE OF ALASKA ALAS~IL AND GAS CONSERVATION COMMON PERMIT TO DRILL ~' tt.~ 20 AAC 25.005 ~ CC , iJ C T 2 5 2007 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 ifK~ ~~ ^Coalbed Methane I~r~tes ^ 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 1 L-28L1 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD - 13150 TVD 5944ss\ 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface: 89' FSL 216' FWL SEC 29 T11N R10E UM 7. Property Designation: ADL 025660 River Pool , , . , , , Top of Productive Horizon: ~~ Il' ?•o~ 3682' FSL, 3163' FWL, SEC.T11N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: December 1, 2007 Total Depth: 5076'fSL 3 l.~fb~F-k1L ~ 36~F~3C,~WL, SEC. 28, T11 N, R10E, UM ~~' Z' °~ 9• Acres in Property: 2560 ~ 14. Distance to Nearest Property: 13,300' ' 4b. Location of Well (State Base Plane Coordinates): Surface: x-540278 y-5949060 Zone-ASP4 10. KB Elevation (Height above GL): 119.9 ~ feet 15. Distance to Nearest Well Within Pool: 633' ' 16. Deviated Wells: Kickoff Depth: 11315 -feet Maximum Hole An le: 102 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3507 ' Surface: 2887 18. C sin Pr ram: S cfica ' ns To - ettin De th - l3o m uan i of Cement c.f. or sa s Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 2.7" x 3" 2-3/8" 4.6# L-80 STL 1830' 11320' 5849'ss 13150' 5944'ss Uncemented Slotted Liner 19. PRESE NT WELL CONDITION S UMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 11770 Total Depth TVD (ft): 6379 Plugs (measured): None Effective Depth MD (ft): 11668 Effective Depth TVD (ft): 6285 Junk (measured): 11400 Casing.- Length Size- Cement Volume MD TVD Conductor /Structural 115' 16" 9 cu d Hi h Earl 115' 115' Surface 6546' 9-5/8" 702 sx AS III 806 sx Class 'G' 6546' 3586' Intermediate 11117' 7" 115 sx Class'G' 11117' 5796' Pr uction Liner 825' 3-1/2" 255 sx Class'G' 10944' - 11769' 5658' - 6378' Perforation Depth MD (ft): 11295' - 11538' Perforation Depth TVD (ft): 5947' - 6166' 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 rtify that the foreg g is true and correct. Contact Gary Eller, 529-1979 Printed Gary Eller Title CT Drilling Engineer Prepared By Name/Number: Si nature Phone 263-4172 Date ` ~ Q`7 Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: Z~7-~~ API Number: 50-029-22951-60-00 Permit A p al e~ See cover letter for Date: I other re uirements Conditions of Approval If box is checked, well may not be used to explore for, test, or produce Coalbed me~th/ane, gas hydrates, or gas contained shales: ~,~ Samples Req'd: ^ Y L1 No Mud Log Req'd: ^ ~(es LJ No T HzS Measures: s No irectional Survey Req'd: Yes ^ No Other: 3 ~ v ~ ~5~~ ~~ P '~ S~ APPROVED BY THE COMMISSION Date /~ ~ ~ ,COMMISSIONER n Form 10-401 Revised 12/2005 V `./~ ~~ Sub d In Duplicate ORIGINAL ,~,,'.°, ~~~~~ 1 L-28 Dual Laterals -Coiled Ting Drilling Summary of Operations: A coiled tubing drilling rig will drill two laterals in well KRU 1L-28 using the managed pressure drilling ~' technique. These horizontal laterals will target Kuparuk C3/4 sand reserves to increase withdrawal rates from this under-performing fault block. The perforations in the motherbore will remain open to production. The L1 lateral will exit the motherbore at 11,315' MD drilling 1835' horizontal targeting the C3/4 sands to the north, and be completed with 23/s" slotted liner to a TD of 13,150 MD. The L2 lateral will exit the motherbore at 11,300' MD and be a 2400' horizontal targeting the C3/4 sands to the south. It will be completed with 23/8" slotted liner to a TD of 13,700 MD. CTD Drill and Complete 1L-28 program: Spud in December 2007 Pre-Rig Work 1. Positive pressure and drawdown tests on MV and SV. 2. Test Packoffs - T & IC. 3. MIT-IA, MIT-OA. 4. Slickline tag fill and drift 31/z" tubing. 5. Obtain updated static BHP survey 6. CTU conduct FCO. Try to knock stuck WRP down into rathole. 7. Slickline run caliper survey in 3'/z" liner and tubing. 8. E-line set 3'/z" monobore whipstock at 11,315' MD Rid Work 1. MIRU Nordic Rig #2 using 2" coil tubing. NU 7-1/16" BOPE, test. _ 2. ~1L-28L1 Lateral ~~ S a. Mi112.74" window and 10' of open hole from 11,315' MD. ~~-~-.~~ b. Drill the 1L-28L1 lateral in the C3/4 sand to the north with a 2.70" x 3" bi-center bit from the window to 13,150' TD. --~ c. Complete the A sidetrack with 23/8" slotted liner. The top of the liner will be just outside the window at 11,315' MD. a. Pull the whipstock tray at 11,315' MD, leaving the anchor in place. RIH and stab into the anchor with a spacer tube and another whipstock tray for a window exit at 11,300' MD. b. Mi112.74" window and 10' of open hole from 11,300' MD. c. Drill the 1L-28L21ateral in the C3/4 sands to the south with a 2.70" x 3" bi-center bit to 13,700' TD. d. Complete the L2 lateral with 23/8" slotted liner. The top of the liner will be just outside the window at 11,300' MD. 4. Pull whipstock trays but not anchor assembly to allow future re-entry into laterals 5. Freeze protect. ND BOPE. RDMO Nordic 2. Post-Rig Work 1. Obtain static BHP 2. Produce well to sales. Mud Program: • Will use chloride-based Biozan brine (8.6 ppg) for milling operations, and chloride-based Flo-Pro mud (8.6 ppg) for drilling operations. Since there is no SCSSV installed in 1L-28, the well will have to be killed prior to running 23/8" slotted liner. Page 1 of 3 October 18, 2007, FINAL 1 L-28 Dual Laterals -Coiled ~ing Drilling 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: • 1L-28L1: 23/8", 4.6#, L-80, STL slotted liner from 11,320' MD to 13,150' MD • 1L-28L2: 23/8", 4.6#, L-80, STL slotted liner from 11,305' MD to 13,700' 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: 31/s", L-80, 9.3 ppf Burst 10,160 psi Collapse 10,530 psi Well Control: i • Two well bore volumes 0240 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 3500 psi. Maximum potential surface pressure is 2887 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 3507 psi in 1E-26 in 1999). • The annular preventer will be tested to 250 psi and 200 psi. Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Hazards r • Lost circulation is expected due to low BHP (i.e. 7.0 ppg EMW) in this fault block and potentially high ECD. Expect to encounter similar to slightly increasing pressure as the laterals are drilled away from the mother well • Well 1L-28 has 35 ppm H2S as measured on 7/2/07. Wells 1L-20A and 1L-10 are adjacent to 1L-28. 1L-20A, 15' apart from 1L-28, has 50 ppm H2S as measured on 7/2/07. 1L-10, 75' apart from 1L-28, is an injection well with no measured H2S. The maximum H2S level on the 1L pad is 125 ppm from well 1L-26. All H2S monitoring equipment will be operational. d Reservoir Pressure The most recent static BHP survey in well 1L-28 was taken October 16, 2007, which measured reservoir pressure of 2198 psi at 6040' TVD corresponding to 7.0 ppg EMW. Expect to encounter similar to slightly increasing pressure as the laterals are drilled away from the mother well, although higher j pressures could be encountered with unexpected fault crossings. Maximum potential pressure is 3507 / psi at 6200' TVD (i.e. measured BHP in well 1E-26 in 1999) which corresponds to an EMW of 10.9 ppg. Maximum potential surface pressure with gas (0.1 psi/ft) to surface is 2887 psi. Page 2 of 3 October 18, 2007, FINAL 1 L-28 Dual Laterals -Coiled Tffiing Drilling 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 BHA will be accomplished utilizing the 23/8" pipe/slip rams. The annular preventer will act as a secondary containment during deployment and not as a stripper. Since there is not a SCSSV installed in well 1L-28, the well will have to be killed prior to running 23/8" slotted liner. Operating parameters and fluid densities will be adjusted based on real-time bottom hole pressure measurements while drilling and shale behavior. The following scenario is expected at TD: • Estimated reservoir pressure: 2165 psi at 11,315' MD (5965' TVD), or 7.0 ppg EMW. • Expected annular friction losses while circulating: 1018 psi (assuming friction of 90 psi/1000 ft). • Planned mud density: 8.6 ppg equates to 2668 psi hydrostatic bottom hole pressure at 5965' TVD • While circulating 8.6 ppg fluid, bottom hole circulating pressure is estimated to be 3686 psi or 11.9 ppg ~ EMW without holding any additional surface pressure. • When circulation is stopped, no additional surface pressure shall have to be applied to balance reservoir pressure. 1018 psi of additional surface pressure must be held to maintain the same bottom l hole pressure as during drilling operations. Page 3 of 3 October 18, 2007, FINAL • ~~ CoinocoPhillips Alaska, Inc. KRU 1 L-28 1L-28 API: 500292295100 Well T e: PROD An le TS: 28 de 11291 TUBING (0-10952, OD:3.500, SSSV Type: NIPPLE Orig Com IetiOn: 11/23/1999 Angle @ TD: 23 deg @ 11770 ID:z.ssz> Annular Fluid: DSL/SW Last W/O: Rev Reason: GLV C/O Reference Lo Ref Lo Date: Last U ate: 10/31/2005 Last Ta : 11465 WLM TD: 11770 ftK6 SURFACE Last Ta Date: 4/9/2005 Max Hole An le: 67 d 2336 (o-ssas, oD 9 s2 Casin Strin -ALL : . s, wrao.oo) Descri lion Size To Bottom TVD Wt Grade Thread CONDUCTOR 16.000 0 115 115 52.58 H-40 WELDED SURFACE 9.625 0 6546 3586 40.00 L-80 BTCM ~ PRODUCTION 7.000 0 11117 5796 26.00 L-80 BTCM ~~~ (0-11117 LINER 3.500 10944 11769 6378 9.30 L-80 EUE 8RD , oD:7.oo0, Tubin Strin -TUBING wr.2s.oo> Size To Bottom TVD Wt Grade Thread 3.500 0 10952 5664 9.30 L80 EUE8RD Perforations Summa Gas Ufl MandroWaM Interval TVD Zone Status Ft SPF Date T e Comment 2 11295 - 11320 5947 - 5969 C-4 25 6 6/22/2000 APERF 2.5" HSD, 60 d hasin (7197a1sa, 11334 - 11364 5981 - 6008 C-4,C-3,C-1 30 4 3/19/2000 APERF 2.5" HSD, 60 d hasin 11518 - 11538 6147 - 6166 A-5 20 4 12/19/1999 IPERF 2.5" HSD, 180 de hasin Stimulations & Treatments cas Uft Interval Date T e C omment ~f°w~1° 3 11518 - 11538 2/12/2000 FRAC 'A' SAND FRAC (9051-9052, 11295 - 11364 5/7/2000 FRAC 'C' SAND FRAC Gas Lift Mandrels/Valves St MD TVO Man Mfr Man Type V Mfr V Type V OD Latch Port TRO Date Run Vlv Cmnt 1 4258 2615 CAMCO MMM CAMCO GLV 1.5 RK 0.156 1265 8/30/2005 2 7197 3864 CAMCO MMM CAMCO GLV 1.5 RK 0.188 1254 8/30/2005 3 9051 4656 CAMCO MMM CAMCO GLV 1.5 RK 0.188 1230 8/29/2005 4 10316 5234 CAMCO MMM CAMCO GLV 1.5 RK 0.188 1206 8/29/2005 5 10836 5576 CAMCO MMM CAMCO OV 1.5 RK 0.250 0 8/28/2005 Other lu s, a ui ., etc. -JEWELRY De th TVD T e Descri lion ID 553 552 NIP CAMCO DS NIPPLE 2.813 10912 5633 NIP CAMCO W NIPPLE 2.813 10944 5658 PKR BAKER ZXP LINER PACKER 4.375 NIP 10952 5664 SEAL BAKER SEAL ASSY 80-40 GBH-22 3.000 ;10912-10913, OD:4.520) PKR ;10944-10945, OD:7.000) LINER ;10944-11769, OD:3.500, W L9.30) Pert '11295.11320) FRAC '11295-11364) Perf '11334-11364) Perf '1151&11538) FRAC ` I C^ 7^ KRU 1 L-28 Producer Proposed L1 & L2 CTD Laterals 3'/i' Camco DS nipple, 2.813" min ID at 553' MD • , ~C~-C1C~C~-P'~'1[ ~ I 1 Alaska, int. 3'/z' 9.3# L-80 EUE 8rd Tubing 3'/2" Camco MMM GLMs @ 4258', 7197', 9051', 10316', & 10836' MD 95/8" 40# L-80 @ 6546' MD Baker ZXP Packer w/SBE @ 10,944' MD 7" 26# L-80 3'/" Camco W nipple, 2.813" min ID @.10,912' MD @ 11,11T MD 3'/Z' tubing muleshoe @.10976' MD 23/8" liner top @ +/-11,305' MD 3'/2' Retrievable whipstocks L2 KOP 11,300' MD 1L-28L2 Lateral, TD @ 13,700' MD C4 Perfs 11295'-11320' 2-3/8" slotted liner L1 KOP 11,315' MD 23/8' liner top @ C3/C4 Perfs 11,320' MD 3" openhole 1L-28L1 Lateral, TD @ 13,150' MD 11334'-11364' KB packers at 11,325 & 11,372' MD • Packer ID = 1.81" • 1.71" RR plug in tailpipe of lower packer Stuck WRP 11,400' MD (10/8/06) A-5 sand perfs 11518' - 11538' liner 10944' - 11,769' MD Updated: 10-23-07 • by BP Alaska Baker Hughes INTEQ Planning Report ~.r 1NTEQ company: BP Amoco Date: 1x17/2007 Tlme: 17:01:55 Pale: I Field: Kuparuk Ca-ardiiate,{NE) Rakrensr. Wt3t1: 28, True North Ske•. KRU 1 L Pad Vertical (TVD) Reference: 1 L -2m Datum 120.0 Wolf: 28 Sectisr (VS}Reference: WeU (O.OON,O.OOE,O.OOA=i) Welipath: Plan 4, 1L-28L1 Survey Calea+a4tiaa Mettted: Minimum Curvature IIM: Orac~ Field: Kuparuk Map System:US State Plane Coordinate System 1927 Map Zone: Alaska, Zone 4 Gee Datnm: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Dahm: Mean Sea Level Geomagnetk Model: bggm2007 Site: KRU 1 L Pad Site Position: Northing: 5948968 .90 ft I.atitade: 70 16 17.459 N From: Map Fasting: 540082 .88 ft Longitude: 149 40 33.550 W Position Ueeerlaiuty: 0.00 ft North Reference: True Grosnd Level: 0.00 ft Grid Convergence: 0.31 deg Well: 28 Sbt Name: Web PosNise: +N/-S 89.57 ft NorthinE: 5949059 .61 ft ' Latitnde: 70 16 18.340 N +E/-W 216.16 ft Eastlag : 540278 .34 ft Longitude: 149 40 27.257 W Position Uncertainty: 0.00 ft Welipath: Plan 4, 1 L-28L1 Drilled From: 1 L-28 500292295160 Tie-oo Depth: 11 307.05 tt Cnrrcut Datum: 1 L-28 Datum Height 120 .00 ft Above System Datum: Mean Sea Level ' Magnetic Data: 1x12/2007 Declination: 23.06 deg Fceld Strength: 57615 uT Mag Dip Angle: 80.78 deg Vertical Sect~n: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 120.00 0.00 0.00 0.00 Pao: Plan *4 Date Composed: 10/12/2007 copy Lamars Plan 4 Version: 6 Prieeipal: Yes Tied-to: From: Definitive Path Targets Map. Map c- Latitude -> <~ Loegitude --> Na®e Descriptaa TVD +N/-S +E/-W Nert6iag Ea~iag Deg Miu Sec Ikg Mio Sec Dip. Dir. ft ft n ft ft 1L-28L1 Polygon 120.00 3551.90 8200.59 5952655.00 548459.00 70 16 53.229 N 149 36 28.401 W -Polygon 1 120.00 3551.90 8200.59 5952655.00 548459.00 70 16 53.229 N 149 38 28.401 W -Poygon 2 120.00 3623.24 8326.99 5952727.00 548585.00 70 16 53.929 N 149 36 24.717 W -Polygon 3 120.00 3776.06 8363.81 5952880.00 548621.00 70 16 55.431 N 149 36 23.640 W -Polygon 4 120.00 3920.12 8355.58 5953024.00 548612.00 70 16 56.848 N 149 38 23.875 W -Polygon S 120.00 4046.32 8320.25 5953150.00 548576.00 70 18 58.090 N 149 38 24.900 W -Polygon 8 120.00 4542.18 8169.89 5953645.00 548423.00 70 17 2.968 N 149 38 29.264 W -Polygon 7 120.00 4885.29 8342.64 5953969.00 548584.00 70 17 6.144 N 149 38 24.221 W -Polygon 8 120.00 4926.57 8477.98 5954031.00 548729.00 70 17 6.745 N 149 38 20.276 W -Polygon 9 120.00 5178.84 8470.33 5954283.00 548720.00 70 17 9.224 N 149 38 20.491 W -Polygon 10 120.00 5089.79 8253.83 5954193.00 548504.00 70 17 8.353 N 149 36 26.801 W -Polygon 11 120.00 4830.93 8036.42 5953933.00 548288.00 70 17 5.809 N 149 36 33.143 W -Polygon 12 120.00 4623.15 7990.30 5953725.00 548243.00 70 17 3.766 N 149 38 34.493 W -Polygon 13 120.00 4363.03 8006.91 5953465.00 548281.00 70 17 1.208 N 149 38 34.017 W -Polygon 14 120.00 4146.58 8086.76 5953249.00 548342.00 70 16 59.078 N 149 38 31.698 W -Poygon 15 120.00 3876.03 8184.32 5952979.00 5484N .00 70 16 56.418 N 149 38 28.884 W -Poygon 16 120.00 3713.77 8228.46 5952817.00 548488.00 70 16 54.820 N 149 36 27.584 W -Polygon 17 120.00 3597.10 8184.83 5952700.00 548423.00 70 16 53.873 N 149 38 29.441 W 1 L-28L1 Fauft 1 120.00 4471.95 7837.47 5933573.00 548(191.00 70 17 2.281 N 149 38 38.949 W -Polygon 1 120.00 4471.95 7837.47 5953573.00 548091.00 70 17 2.281 N 149 38 38.949 W -Polygon 2 120.00 4471.00 8014.49 5953573.00 548288.00 70 17 2.270 N 149 38 33.793 W -Polygon 3 120.00 4469.91 8219.51 5953373.00 548473.00 70 17 2.257 N 149 38 27.821 W 1 L-28L1 Target 4 5962.00 4431.00 8014.27 5953533.00 548268.00 70 17 1.876 N 149 38 33.800 W 1L-28L1 Target 1 5965.00 3598.79 8222.83 3952700.00 548481.00 70 16 53.870 N 149 38 27.751 1M1f • by BP Alaska Baker Hughes INTEQ Planning Report Biir 1NTEQ Compaey: @P Amoco Dins: 10/17/2007 Time: 17:01:55 t'age: 2 Field: Kuparuk C~srAlsste(NE) Retere~e: WeN: 28, True North Site: KRU 1 L P~ Vertksl ('i'VD) Retereocr. 1 L-28 Datum 120.0 Welk 2 8 SectMa (VS) Refersnce: WeY (O.OON,O.OQE,0.00/1zi) Wellpath: Plsn 4, 1L-28L1 Sarrry CskaWtiof Meti~od: Minimum Curvature Db: O-ade Targets ....Map Map <.... Latitude >> <- Lougitnde _.> Naux Deseriptisa TVD +N/~ +E/-W PI®rl6iw` Eastiua Deg Mia Sec Deg Miu Sec Dig. Dir. ft ft R' ft ft 1L-28L1 Target3 6016.00 3985.38 8307.82 5953089.00 548564.00 70 18 57.294 N 149 36 25.264 W 1 L-28L1 Target 5 6064.00 4958.85 8484.14 5954081.00 548715.00 70 17 7.041 N 149 38 20 .678 W 1L-28L1 Target 2 6073.00 3699.21 8332.39 5952803.00 548590.00 70 16 54.676 N 149 36 24 .557 W Aa.otatioa MD TVD ft- ft 11307.05 5957.42 TIP 11315.00 5964.47 KOP 11335.00 5982.09 End of 9 Deg/100' DLS 11375.00 6014.35 4 11551.96 6069.29 End of 45 Deg/100' DLS 11801.96 6016.38 6 12031.96 5980.13 7 12356.98 5961.92 8 13150.00 0.00 TD Phu Section Iutormatioa MD Iad AzLn TVD +N/-S +E/-W DIS Build Tern TFO Target ft deg deg ft ft ft degit00ft deg/100ft deg/100ft deg 11307.05 27.56 89.54 5957.42 3597.79 8221.29 0.00 0.00 0.00 0.00 11315.00 27.46 89.61 5964.47 3597.82 8224.96 1.32 -1.26 0.88 162.11 11335.00 29.03 87.76 5982.09 3598.04 8234.43 9.00 7.86 -9.27 330.00 11375.00 43.49 69.24 6014.35 3603.34 8257.18 45.00 36.14 -46.28 315.00 11551.96 102.00 8.68 6069.29 3731.86 8341.15 45.00 33.07 -34.23 300.00 11801.96 101.87 338.00 6016.38 3971.66 8313.13 12.00 -0.05 -12.27 273.00 12031.96 95.94 310.69 5980.13 4154.13 8181.70 12.00 -2.58 -11.87 260.00 12358.96 90.24 349.35 5961.92 4429.94 8022.94 12.00 -1.75 11.89 97.00 13150.00 78.53 84.57 6063.70 4991.95 8436.20 12.00 -1.48 12.01 101.50 Survey MD Iaef Azirn SS TYD N/S E!W MapN MapE BLS VS TFO Tool ft' ,deg '.deg ft ft ft R ft degl100ft ft deg 11307.05 27.56 89.54 5837.42 3597.79 8221.29 5952700.99 548479.45 0.00 3597.79 0.00 MWD 11312.21 27.50 89.59 5842.00 3597.81 8223.88 5952701.02 548481.84 1.32 3597.81 162.11 1 L-28L 11315.00 27.48 89.61 5844.47 3597.82 8224.96 5952701.04 548483.13 1.32 3597.82 162.07 MWD 11315.59 27.51 89.55 5845.00 3597.82 8225.24 5952701.04 548483.40 9.00 3597.82 330.00 1 L-28L 11335.00 29.03 87.76 5862.09 3598.04 8234.43 5952701.31 548492.58 9.00 3598.04 330.05 MWD 11375.00 43.49 69.24 5894.35 3603.34 8257.18 5952706.73 548515.31 45.00 3603.34 315.00 MWD 11377.28 44.01 67.97 5896.00 3603.92 8258.65 5952707.32 548516.77 45.00 3603.92 300.00 1 L-28L 11400.00 49.88 56.48 5911.53 3611.70 8273.25 5952715.17 548531.33 45.00 3611.70 300.92 MWD 11500.00 83.28 22.77 5951.69 3682.26 8327.14 5952786.02 548584.84 45.00 3682.26 308.79 MWD 11551.98 102.00 8.88 5949.29 3731.86 8341.15 5952835.69 548598.58 45.00 3731.86 323.12 MWD 11600.00 102.24 2.79 5939.20 3778.58 8345.84 5952882.42 548803.02 12.00 3778.58 273.00 MWD 11700.00 102.33 350.50 5917.84 3875.91 8340.14 5952979.72 548596.80 12.00 3875.91 271.76 MWD 11800.00 101.88 338.24 5896.79 3969.88 8313.85 5953073.53 548570.01 12.00 3989.88 289.14 MWD 11801.98 101.87 338.00 5896.38 3971.68 8313.13 5953075.31 548569.28 12.00 3971.66 286.56 MWD 11900.00 99.80 326.25 5878.07 4056.62 8268.15 5953180.02 548523.85 12.00 4056.82 280.00 MWD 12000.00 98.88 314.44 5863.69 4132.65 8205.08 5953235.70 548460.39 12.00 4132.85 257.80 MWD 12031.96 95.94 310.69 5860.13 4154.13 8181.70 5953257.05 548438.89 12.00 4154.13 258.11 MWD 12100.00 94.89 318.83 5853.69 4201.78 8133.85 5953304.45 548388.59 12.00 4201.78 97.00 MWD 12200.00 93.18 330.73 5846.63 4283.13 8078.24 5953385.48 548330.75 12.00 4283.13 97.77 MWD 12300.00 91.32 342.80 5842.70 4374.72 8038.74 5953476.85 548290.76 12.00 4374.72 98.81 MWD ~J by BP Alaska Baker Hughes INTEQ Planning Report ~.r 1NTEQ Coe~paoy: ®P Amoco Date: 10/17/2007 Time: 17:01:53 Pace: 3 Field: Kuparuk Ce~osdittate(NE) Refertuce: Well: 28, Tn» North SMc: KRU 1 L Pad Vcttied (TVD} Reterenee: 1 L-28 Datum 120.0 WeU: 28 Ses~ (V~ Rsfereoce: Wsll (O.pON,0.00E,0.00Azi) WsUpath: Plan 4, 1 L-28 L1 Srrvey Cakr~tioa Method: Minimum Curvature Db: Orade Sarvey MD Ind Aziat S3 TVD N/S E/W 'MapN MapE D[S VS TFO Tool >t d!y deg 1t it R R tt deg/1 UOR R deg 12358.96 90.24 349.35 5841.92 4429.94 8022.94 5953531.99 548276.88 12.00 4429.94 99.08 MWD 12400.00 89.21 354.41 5842.13 4472.54 8016.87 5953574.55 548270.37 12.00 4472.54 101.50 MWD 12500.00 86.86 6.19 5845.57 4572.29 8017.38 5953674.29 548270.35 12.00 4572.29 101.48 MWD 12600.00 84.63 18.01 5853.02 4869.63 8038.23 5953771.73 548290.68 12.00 4669.63 101.07 MWD 12700.00 82.84 29.92 5864.14 4780.28 8078.51 5953862.58 548330.46 12.00 4760.28 100.19 MWD 12800.00 80.96 41.93 5878.45 4840.29 8136.44 5953942.90 548387.97 12.00 4840.29 98.86 MWD 12900.00 79.68 54.03 5895.32 4906.16 8209.52 5954009.15 548460.68 12.00 4906.16 97.15 MWD 13000.00 78.85 66.22 5914.02 4955.02 8294.53 5954058.46 548543.42 12.00 4955.02 95.10 MWD 13100.00 78.50 78.45 5933.73 4984.72 8387.76 5954088.66 548638.48 12.00 4984.72 92.82 MWD 13150.00 78.53 '~ 84.57 5943.70 - 4991.95 8436.20 5954096.14 548886.88 12.00 4991.95 90.41 2 3/8" • • ~Cuparuk Managed Pressure Drillin~ BOP Configuration for 2" Coil Tubing Well I 1 L-28 Floor 7 1/16" 5000 psi RX-46 Tree Size 3-1/8", 5M TOT 7 1/16" 5000 psi (RX-46) or 1-- 4 1/16" 5000 psi (RX-39) Swab Valve Flow SSV ~f111aster Valve ~ O a Base Flan e Page 1 TRANSMITTAL LETTER CHECKLIST WELL NAME ~~ ~L ' 2 ~ L PTn~ 20 ~ - ~s-3 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 welt ,~/2G~ ~~ -Z ~ , (If last two digits in permit No. ~9 -O API No. 50- C~9- ZZ / - Gb. API number are production should continue to be reported as a function of the between 60-69) original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(fj, all records, data and 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 exception. , assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no Beater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Welt for (name of well) untii after (Company,Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. S,Company Name) must contact the Commission to obtain advance approval of such water well testing ro m. Rev: ~n3noo~ • • ~~ N . , ~ ;~ ~Q ,, w ~N N : . . ~o Q ° ~ o ~ ` ~ ~ ~ a~ m, ~ : c v , c. c. m c. ~ ~ m o. ~ ' ~ 3 3: m. -~ ~ a '3, c c. 3 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~~ > ° OF`~ O~ O ° Z. ~ ~ ~ o. , in, .a ~ y. . `a I ~ ~ ~ ° E O N o 8 „n N a~, ~ j ~ ~ ~: ~: ~ ~ m v p ~ ~~ ~~ , y' O' L' ~ , I q p , 01 ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ O ~ a -O. ~ ~ ~ N• N' ~ 7• ~ ~ m ~ ~ O ~ ~~ O. ~ O ~ d N• ~ J• °. V. 3. V t C• C. O. O. O: gyp, ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ ~ N• ~~ G f6 ~ W ~ N~ ~ N: ~~ ~ ~~ ~ O. ~ N. ~_ 7 ~~ T y: U' U' V. ~ ~ ~ ~ ~ ~ ~ f6. 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