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Home My WebLink About207-154• Image Projecfi Well History File Over 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 (done> ^ Two-sided III II~III II III II III ^ Rescan Needed III II~III II II III III RES N Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria ~-- Project Proofing BY: Maria _ Scanning Preparation BY: Maria DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: Date: p~- Date: _x30= Date: ~ / `~,~ OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) ^ Logs of various kinds: ^ Other:: L/ y /s/ ~ Y IIIIIIIIIIIIIIIIIII /s/ + ~ =TOTAL PAGES ~ (Count does not include cover sheet) (~/~~~ ~ /s/ ~ ~ r Production Scanning Illllllllllllllill Stage 1 Page Count from Scanned File: ~~ (Count does include cover sheet) Page Count Matches Number in Scannin Preparation: ~ES NO BY: Maria Date: l / ~ /s/ 9 Stage 7 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. III II'I II I II II I I III ReScanned III IIIIIIIIIII IIIII BY: Maria Date: /s/ Comments about this file: o „~~e~,e, iuiimimumu 10/6/2005 Well History File Cover Page.doc • ~1. ~u ~~ ~. 4ti ,: ,' ,~ s ~ . ~ ~ k /~ -~ .*., y s ~ 1 v~^. ~' yA.. '9 Y > ~~ ~ '~.~ s __...,. MICROFILMED 6/301210 DO NOT PLACE ANY NEW MATERIAL UNDER THIS PAGE. C:\temp\Temporary Internet Files\OLK9\Microfilm_Marker.doc Company Well Name Date ~~ _ l~~/ ConocoPhillips, Alaska, Inc. ~ 9 /~~~ 1L-28L2 -< 4 7 ~ sjF~~ eti v ~.~~~~' ."~a!~~"~ L,... 12/312009 - v~ } ~~ BAKER ~~~~~~ L~1TE(~ • Page 1 of 4 DATA SUBMITTAL GOMPLIANCE REPORT 12/17/2008 Permit to Drill 2071540 Well Name/No. KUPARUK RIV UNIT 1L-28L2 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22951-61-00 MD 11301 TVD 5952 Completion Date 2/26/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Log s Run: MWD DIR / RES / GR (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr S Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D D Asc Directional Survey 11209 13150 Open 3/10/2008 1 L-18L1 and 1 L-28L2-01 ~ ~ l also on Diskette i"'f2pt Directional Survey 11209 13150 Open 3/10/2008 Well Cores/Samples Information: Sample Interval Set Name Start Stop Sent Received Number Comments ADDITIONAL INFORMA~10~ ` Well Cored? Y / fl W\ Chips Received? YY N~ Analysis Y~~ Received? Daily History Received? ~ / N Formation Tops ~N Comments: Compliance Reviewed By: _____ _-~'v_-__ ____ ____ _ Date: • Page 1 of 2 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, I 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) Tom -Ran 1040' of solid liner in the 1 L-28 CTD laterals out of a total of 4267 of liner run (24%). -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) Gary, If you could provide the detail, I'd appreciate. Nice to know you are drilling mostly pay. Tom From: Eller, J Gary [mailto:J.Gary.Eller@conocophillips.com] Sent: Monday, May 12, 2008 5:06 PM To: Maunder, Thomas E (DOA); Hubble, Terrie L Subject: RE: 1L-28L1, et al (207-153) Tom - We typically only run blank across shale sections, significant 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 liner 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 ~ e 1 L-28 LZ LINER SUMMARY TOp S@CtOn ~~ YYELL 4 KRD1L 28 LINER SIZE / tR-T/Ff i GRADE /THREAD / ID 23B" 4.44# BOTTOM OF LINER AT 12,440.57 TOP OF LINER AT ~0 DATE STL 2120/2008 NO ITEM OD ID LENGTH TOP BOTTOM Steel Grayota Guide Shce 2.375 1.920 1.37 12,439.20 12,440.57 9 2-3/8" 4:4# L-80 STL SMMd Tubing 2.375 1.992 284.37 12,154.83 12,439.20 23/8" 4.4# L-80 STL Solid Pup Jant 2.700 1.000 9.87 12,144.96 12,154.83 BTT Aluminum WS w/ GS Profile & 2318" STL pin 2.700 1.000 9.50 12,135.46 12,144.96 12,135.46 9 BHA Total Length 305.11 1L-Z8 L2 LINER SUMMARY ~ a BOttOm S@CtiOn WELL i~ 0 LZ LINER SIZE / WT1FT /GRADE !THREAD / ID 2-318" 4A4# BOTTOM OF LINER AT 12,853.00 TOP OF LINER AT -80 DATE STL 2119/2008 NO ITEM OD ID LENGTH TOP BOTTOM Steel Crayda Guide Shoe 2.375 1.920 1.40 12,851.60 12,853.00 13 2-38" 4.411 L-80 STL wTubing 2.375 1.982 409.55 12,442.05 12,851.60 Depbyment Sleeve 2.7 1.992 1.48 12,440.57 12,442.05 Steel GS Profile x 2-3/8" STL ~n 2700 0.375 2.00 12,438.57 12,440.57 12,438.57 13 BHA Total Length 414.43 i STATE OF ALASKA ~~ ~~~~~~~~ ALASKA~L AND GAS CONSERVATION COM II SIGN WELL COMPLETION OR RECOMPLETION REPORT AND LOG MAR 2 6 2008 1 a. Well Status: ®Oil . ^ Gas ^ Plugged ^ Abandoned ^ Suspended zoaac zs.,os zoaac zs.,,o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well CI ®Deve~~~~ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 2/26/2008 12. Permit to Drill Number 207-154 ' 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 2/10/2008 13. API Number 50-029-22951-61-00 - 4a. Location of Well (Governmental Section): Surface: 89' FSL 216' FWL S C 7. Date T.D. Reached 2/15/2008 14. Well Name and Number: Kuparuk 1L-28L2 , , E . 29, T11N, R10E, UM Top of Productive Horizon: 3299' FSL, 3190' 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: 2157' FSL, 3170' FWL, SEC. 28, T11N, R10E, UM 9. Plug Back Depth (MD+TVD) 12853 5964 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 5980 16. Property Designation: ADL 025660 ' TPI: x- 548503 y_ 5952318 Zone- ASP4 Total Depth: x- 548501. y- 5951171 • 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 25.050 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): ~ i~~' ' c.Zti 1/3d!°'nl> MWD DIR / RES / GR ~ -2'~-Vp 22. CASING, LINER AND CEMENTING RECORD ~,~/~, , G. 7 GASING SETTING DEPTR MD SETTING DEPTH TVD HALE AMOUNT WT. PER FT. GRADE TOP BOTTOM ' -TOP BOTTOM SIZE GEMENTING RECORD PULLED 2-3/ " 4.44# L-80 12135' 12853' 5987' 5964' 3" Un emented Slotted Liner 23. Open to production or inject ion? ®Yes ^ No 24. TUBING RECORD If Yes, IISt each IntefVal Open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-3/8" Slott ed Liner / S®~Z tl ~'rhfGPte: 3-1/2", 9.3#, L-80 10956' 10944' ^ MD / TVD MD TVD , 12155' - 12439' X~986' - 5957 Well Branch Well Branch 12442' - 12852'~/'S957' - 5964' 1 L-28L2 1 L-28L2 25. ACID, FRACTURE, GEMENT SQUEEZE, ETC. Departs From is not Direct ly DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Well Branch Accessible 1 L-28L2-01 11301' Top of Window (from 3-1/2" Casing) PTD# 208-029 at 12101' MD ' TVD (xxx ) 26. PRODUCTION TEST Date First Production: Reported on 1 L-28L1 Method of Operation (Flowing, Gas Lift, etc.): See 1 L-28L1 10-407 (Dated 03/25/08), PTD 207-153) for Production & Test Data Date Of Test: HOUfS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE Dara Conventional Core(s) Acquired? ^Yes ®No Sidewal l Core s A wired? ^Yes ®No If Yes to either question, -ist formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. . ~~~1 ~}i~:w5 None I.A k ,Z-' y .` ~ _ ~~ =i~u ,.,;.. Form 10-407 Revised 02/2007 J CONTINUED Ord REVERSE SIDE /~ "~• J~.Cw ~3/-^TI~~S G 28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN RS ENCOUNTERED): 29. FORMATION TESTS NAME MD TVD Well Tested? ^ Yes ®No Permafrost Top If yes, list intervals and formations tested, briefly summarizing test results. Attach separate sheets to this form, if needed, and submit Permafrost Base detailed test information per 20 AAC 25.071. Top Kuparuk B 11374' 6013' None ` Base Kuparuk C /Top Kup B 11793' 6018' (Inverted) Formation at Total Depth (Name): Base Kuparuk C /Top Kup B 11793' 6018' ' 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. ~3/~ (~/ Si d ' gne Terrie Hubble Title Drilling Technologist Date Kuparuk 1 L-28L2 207-154 Prepared ey Namemiumber. Terrie Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Gary Eller, 263-4172 (Office) INSTRUCTIONS GeNew-~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). 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). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITeM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. ITeM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only ~~ ~ ~~ BP AMERfCA 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: i 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 iNout. 200-300 psi motor work. 1 ~... ~ ~~ a`~~ _ ~ S Begin time milling at 0.1' per 6 minutes. ~v.J 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' 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 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Event Name: REENTER+COMPLETE Start: 1/15/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Page 10 of 25 ~ Spud Date: 2/20/2000 End: .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 23:30 - 00:00 0.50 DRILL P 2/11/2008 00:00 - 00:30 0.50 DRILL P 00:30 - 02:30 2.00 DRILL P 02:30 - 03:50 1.33 DRILL P 03:50 - 05:50 2.00 DRILL P 05:50 - 06:10 0.33 DRILL P 06:10 - 06:20 0.17 DRILL P 06:20 - 11:00 4.67 DRILL P 11:00 - 14:30 3.50 DRILL P 14:30 - 14:45 0.25 DRILL P 14:45 - 18:00 3.25 DRILL P 18:00 - 18:30 0.50 DRILL P 18:30 - 21:50 3.33 DRILL P 2/12/2008 21:50 - 22:10 22:10 - 00:00 00:00 - 00:20 00:20 - 01:30 01:30 - 03:30 03:30 - 03:45 03:45 - 04:15 04:15 - 05:10 05:10 - 05:20 05:20 - 11:30 0.33 DRILL P 1.83 DRILL P 0.33 DRILL P 1.17 DRILL P 2.00 DRILL P 0.25 DRILL P 0.50 DRILL P 0.92 DRILL P 0.17 DRILL P 6.17 DRILL P 11:30 - 12:15 I 0.751 DRILL I P wob w/ 11.03 ECD at 48 deg, Drill to 11436' and get first good survey PROD2 Wiper while discuss directional plan. Need -40's and are getting 38's. Pull thru window clean PROD2 Log tie-in while discuss. Corr +1' Will trip for larger bend motor PROD2 Open EDC. POOH circ 1.45/2750 PROD2 Standback BHA. Change motor bend to 2.5 deg, rerun 1-1-I bit PROD2 RIH w/ BHA #13 circ thru EDC 0.5/910 PROD2 Log tie-in down from 11230', corr -3'. Close EDC PROD2 Run in hole to TD. Hole smooth. PROD2 Drill ahead from 11,436'. 2600 psi. fs at 1.48 iN0.95 bpm. 100-200 psi mtr work. 3-4k# DHWOB. ROP: variable, mostly <10 FPH. BHP/ECD: 3361 psi/10.93 ppg. PVT: 375 bbls. PROD2 Drill ahead to 11,510'. Able to stall motor. Weight transfer is Apparenny in a naro spot. PROD2 Make wiper trip to window. Hole smooth. PROD2 Drill ahead from 11,510'. Continued slow drilling. Loss rates vary from 0.5 to 0.75 bpm. Drilled to 11540' PROD2 Wiper to window was essentially clean, but had a few minor overpulls PVT 238 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 B2 sand. Drill to 11570' and project 103 deg at bit PVT 400 PROD2 Wiper to window was clean PROD2 Pull thru window, clean. Open EDC. POOH circ thru EDC 1.5/2400 PROD2 Finish POOH w/ build assy PROD2 LD build assy. Change bit, motor, add res tool. Bit was 1-1-I and micro-dulled PROD2 RIH w/ BHA #14 (1.0 deg) circ thru bit 0.30/1100 PROD2 Log tie-in down from 11240', corr -4' 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 PROD2 MAD pass w/ res tool at 300'/hr from 11570' back to the window 1.50/1.10/2900 PROD2 Wiper back to TD was clean PVT 313 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'. PROD2 Wiper trip to window. Hole mostly very smooth. Printed: 3/12/2008 11:46:54 AM BP AMERICA Qperations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Event Name: REENTER+COMPLETE Start: 1/15/2008 Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date ~ From - To ~ Hours I Task Code NPT Phase 12/12/2008 112:15 - 15:55 I 3.671 DRILL I P I I PROD2 15:55 - 16:25 I 0.501 DRILL I P I I PROD2 16:25 - 16:45 0.33 DRILL P PROD2 16:45 - 17:20 0.58 DRILL P PROD2 17:20 - 19:00 1.671 DRILL I P PROD2 19:00 - 20:55 I 1.921 DRILL I P I I PROD2 20:55 - 23:40 2.75 DRILL P PROD2 23:40 - 00:00 0.33 DRILL P PROD2 2/13/2008 00:00 - 00:35 0.58 DRILL P PROD2 00:35 - 03:30 2.92 DRILL P PROD2 03:30 - 04:00 0.50 DRILL P PROD2 04:00 - 04:10 0.17 DRILL P PROD2 04:10 - 04:50 0.67 DRILL P PROD2 04:50 - 07:55 3.08 DRILL P PROD2 07:55 - 10:00 I 2.081 DRILL I P I I PROD2 10:00 - 14:50 I 4.831 DRILL I P I I PROD2 Page 11 of 25 Spud Date: 2/20/2000 End: Description of Operations 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 dilluting mud with 50% seawater. 8.61 ppg iN8.67 ppg gout. Loss rate slowing healing: 1.52 iN1.34 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' Wiper to window while geo determines the top of the 62 for determining the future trajectory of the invert. Pull thru window, clean Log tie-in down from 11220', corr +3' Wiper back to TD and had a few set downs above 11570'. Geos finalize and DD formulate plan for drilling ahead PVT 386 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'. 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. Drill from 11950' 1.62/1.1/2360/100L w/200-400 psi dill, 0.5-1.Ok wob w/ 10.24 ECD at 92 deg while continuing the invert. Drill to 12100'. W iper to window -clean. Continue to wiper to bottom -clean. Drill from 12100' 1.64/1.3/2600/100L w/200-600 psi dill, 1.0-2.Ok wob w/ 10.44 ECD at 92 deg while continuing the invert. Drill to 12250'. W iper to window -clean. Log down for tie-in (+5' corr). W iper to TD -set down at 11750', otherwise clean. Drill from 12252' 1.64/1.08/2400/110L w/200-400 psi dill, 1.0-2.Ok wob w/ 10.32 ECD at 98 deg while continuing the invert. Swap to right at 12350'. Drill to 12400' W iper 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 1.63/0.75/2520 at TD Drill from 12400' 1.62/0.73/2520/1108 w/ 100-300 psi dill, Printed: 3/12/2008 11:46:54 AM BP AMERICA Page 12 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 12/13/2008 110:00 - 14:50 I 4.831 DRILL I P I I PROD2 14:50 - 17:00 I 2.171 DRILL I P I I PROD2 17:00 - 23:55 I 6.92 I DRILL I P I I 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 I 0.251 DRILL P I PROD2 04:15 - 04:30 I 0.251 DRILL I P I I PROD2 04:30 - 08:00 I 3.501 DRILL P ~ PROD2 08:00 - 09:50 I 1.831 DRILL I P I I 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 P PROD2 14:30 - 15:15 0.75 DRILL P PROD2 15:15 - 17:00 1.75 DRILL P PROD2 Spud Date: 2/20/2000 1 /15/2008 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 noticeab-e 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'. W iper 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 (+11 ft 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 dill, 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 W iper 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 dill 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 BP AMERICA Qperations 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 12/14/2008 15:15 - 17:00 1.751 DRILL I 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 2.83 I DRILL I P 23:10 - 00:00 I 0.831 DRILL I P 12/15/2008 100:00 - 02:20 2.331 DRILL P 02:20 - 03:30 I 1.17 I 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 I 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 5 PROD2 Drill from 12878' (5845' TVD) 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 dill, 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 dill, 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 i NPT Phase Description of Operations 12/15/2008 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 I 2.33 I DRILL I N I STUC I 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 05:50 - 07:00 07:00 - 08:30 0.17 DRILL N 1.17 DRILL N 1.50 DRILL N STUC PROD2 STUC PROD2 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 ~ 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 i e. rientor 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 slowly starting 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 1 s o cru e w i e circu ating 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 After circ two BU's 1.51/1.45/3150 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 ! i 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 Start: Rig Release: Rig Number: Phase 12/16/2008 108:30 - 09:10 1 0.671 DRILL N I STUC I PROD2 09:10 - 10:30 1.331 DRILL N I STUC I PROD2 10:30 - 17:25 I 6.92 I 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 1.831 DRILL I N STUC PROD2 20:35 - 20:45 20:45 - 21:35 0.171 DRILL I N STUC I PROD2 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 12/17/2008 100:00 - 02:00 1 2.00 DRILL I N I 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 sto um in .Flow check well & let formation relax. Flow stopped for 2min but started again & oot 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 c eck or the possibility of TxIA 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. i 1200' 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 BP AMERICA Operations Summary Report Printed: 3/12/2008 11:46:54 AM 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: _ i i I 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 um PUH w/ 3k over and looks like fish is on PVT 67 07:25 - 08:50 1.42 FISH N STUC PROD2 POOH 20' min thru open ole 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 recove 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 pushin something to 12835' and set down solid numerous times, 24.Sk up 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 Start jarring 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 up & fish is free. 21:15 - 00:00 2.75 FISH N STUC PROD2 Fill across t e top _ 1 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 j Task.. Gode I NPT Phase Description of Operations 2/18/2008 03:00 - 04:45 1.75 DRILL N STUC PROD2 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. 04:45 - 07:00 2.25 DRILL N STUC PROD2 Head up BHI tools. Re-test wire -good. P.T. connector to 3500psi -good. C/O injector packoffs 07:00 - 09:00 2.00 DRILL N STUC PROD2 SWS pertorm injector chain inspection and replace 10 pins Pump slack forward with injector over the bung hole 09:00 - 10:10 1.17 BOPSU N STUC PROD2 Set injector back on well and PT ackoff 250/3500 10:10 - 11:15 1.08 DRILL N STUC PROD2 MU drilling BHA incl agitator and res tool. Add additional lub for MPD spacing. Stab onto well w/ injector and prep to RIH 11:15 - 12:15 1.00 DRILL N DFAL PROD2 Have problem w/ MWD test. Find short in LOC 12:15 - 14:15 2.00 DRILL N STUC PROD2 RIH circ thru EDC 0.95/2300 while finish pump slack forward. Swap to used 8.6 ppg FloPro at 10000' 14:15 - 14:45 0.50 DRILL N STUC PROD2 Log tie-in down from 11235' 0.85/0.85/2000, Corr -11'. Close EDC 14:45 - 15:40 0.92 DRILL N STUC PROD2 RIH thru window, clean. Wiper in hole. Had several set downs 1 1 61 0-650' 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 15:40 - 16:00 0.33 DRILL N STUC PROD2 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 16:00 - 16:45 0.75 DRILL N DPRB PROD2 Wiper OOH while discuss 16:45 - 17:15 0.50 DRILL N DPRB PROD2 Pull heavy and have MW at 11490'. Backream slow to window 17:15 - 18:25 1.17 DRILL N DPRB PROD2 Wiper back in hole at 20'/min while WOO was clean 18:25 - 19:25 1.00 DRILL N DPRB PROD2 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 f finer job. 19:25 - 19:30 0.08 DRILL N DPRB PROD2 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. 19:30 - 23:00 3.50 DRILL N SFAL PROD2 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. 23:00 - 23:20 0.33 DRILL N SFAL PROD2 Flow check well for 10 min. PJSM regarding LD BHA. 23:20 - 00:00 0.67 RIGD N SFAL PROD2 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, 2/19/2008 00:00 - 00:40 0.67 DRILL N SFAL PROD2 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 i Hours Task Code ~ NPT Phase Description of Operations 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 track 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 i e o e a er 2 rs, 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 BHI BHA. 05:45 - 07:30 1.75 CASE N DPRB LNR2 MU liner consisting of crayola tip guide shoe, Sits of slotted 2-3/8" t i No losses. MU BHI tools to liner via hyd GS. MU coil to BHI tools. Stab 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 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. Frorn - To ~ Hours' Task ~ Code NPT 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 l~ 11250' _ 22.3k, 6k RIW. Close EDC. RIH 60'/min in open hole w/liner w/out pumping. Stop (~ 11500'. 3bb1 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 ~ 1.7bpm/3800 psi. PU & release from liner, lost 5k#. PU to 12400' & stop pumping up wt is 23k. Liner is released. Top of liner (billet = 12136'. 11:00 - 13:20 2.33 CASE N DPRB LNR2 tart 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 1 bpm & 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 C~ 12100'. Zero the WOB sensor. Stop pumping & lightly tag the top of the billet. Tag top of billet ~ 12135'. PU 10' & turn um son. 18:15 - 19:20 1.08 DRILL N DPRB PROD2 Start troughing from 12100' to 12130' 50R of HS ~ 60ft/hr. 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 71:46:54 AM • by BP Alaska ~ Baker Hughes INTEQ Survey Report 1NTE Q Company: ConocoPhillipS Alaska Inc. bate: 2/27/2008 Time: 11:27:31 Page: 1 Field: 1<uparuk River Unit Co-ordinate(NE) Reference: ' Well: 1 L-28, Tr ue North Site: Kuparuk 1 L Pad Vertical (TVD) Reference: 1L-28:119.9 Well: 1 L-28 Section (VS) Reference: We{I (O.OON,O.OOE,75.90Azi) Wellpath: it-28L2 Survey 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: 59491 90.90 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 Well: 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-28L2 Drilled From: 1 L-28 500292295161 Tie-on Depth: 11209.74 ft Current Datum: 1 L-28: Height 1 19.90 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 75.90 Survey Program for Definitive Wellpath Date: 12/11/2007 Validated: Yes Version: 2 Actual From To Survey Toolcode Tool Name ft ft 100.00 11209.74 Survey #1 (100.00-11770.00) (0) MWD MWD -Standard 11301.00 13150.00 MWD (11301.00-13150.00) MWD MWD -Standard Annotation MD TVD ft ft_ 11209.74 5872.95 TIP 1 f 301.00 5952.07 KOP 13150.00 5979.54 TD Survey: MWD Start Date: 2/21 /2008 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD Tncl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tool ft deg deg ft ft ft ft ft ft ft deg/1OOft 11209.74 31.95 85.24 5872.95 5753.05 3595.32 8172.90 5952698.12 548431.02 8802.41 0.00 MWD 11301.00 - 27.83 89.24 5952.07 - 5832.17 3597.61 8218.28 5952700.65 548476.39 8846.99 5.01 MWD 11331.14 30.74 119.21 5978.49 5858.59 3593.92 8232.12 5952697.04 548490.24 8859.51 49.12 MWD 11360.55 39.83 125,75 6002.48 5882.58 3584.73 8246.36 5952687.92 548504.53 8871.08 33.43 MWD 11390.07 45.46 135.79 6024.21 5904.31 3571.63 8261.40 5952674.91 548519.63 8882.48 29.87 MWD 11419.67 53.55 148.68 6043.47 5923.57 3553.83 8275.00 5952657.18 548533.33 8891.33 42.85 MWD 11452.48 64.91 159.98 6060.26 5940.36 3528.46 8287.01 5952631.88 548545.47 8896.80 45.47 MWD 11482.56 72.08 168.11 6071.30 5951.40 3501.58 8294.64 5952605.04 548553.25 8897.66 34.63 MWD 11514.14 83.24 174.34 6078.04 5958.14 3471.15 8299.30 5952574,64 548558.07 8894.77 40.24 MWD 11541.85 93.31 178.44 6078.88 5958.98 3443.55 8301.04 5952547.05 548559.96 8889.74 39.23 MWD 11570.34 102.35 180.34 6075.00 5955.10 3415.36 8301.35 5952518.87 548560.42 8883.17 32.41 MWD • by BP Alaska $ Baker Hughes INTEQ Survey Report 1NTEQ Company: ConocoPhillips Alaska Inc. Date: 2/27/2008 Time: 11:27:31 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1 L-28, True North Site: Kuparuk 1 L Pad Vertical (TVD) Reference: '1 L-28: #19.9 Well: i L-28 Section (VS) Reference: Well (OOON,O,OOE,75.90Azi) Wellpath: 1 L-28L2 Survey Calculation Method: Minimum Curvature Db: 5ybase 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 deg/1t)Ott 11604.18 104.24 184.76 6067.22 5947.32 3382.47 8299.89 5952485.97 548559.13 8873.74 13.88 MWD 11635.58 106.43 188.14 6058.91 5939.01 3352.38 8296.49 5952455.87 548555.90 8863.12 12.51 MWD 11664.84 106.82 191.96 6050.53 5930.63 3324.78 8291.60 5952428.25 548551.15 8851.65 12.58 MWD 11696.74 106.05 196.62 6041.51 5921.61 3295.14 8284.05 5952398.57 548543.76 8837.11 14.22 MWD 11726.82 104.62 201.07 6033.55 5913.65 3267.70 8274.68 5952371.08 548534.54 8821.34 15.04 MWD 11758.39 103.69 205.38 6025.82 5905.92 3239.58 8262.61 5952342.90 548522.62 8802.78 13.56 MWD 11788.57 103.25 209.65 6018.79 5898.89 3213.55 8249.05 5952316.81 548509.21 8783.30 13.84 MWD 11822.46 99.56 215.00 6012.08 5892.18 3185.50 8231.29 5952288.66 548491.59 8759.24 18.92 MWD 11859.87 99.24 222.73 6005.97 5886.07 3156.79 8208.15 5952259.83 548468.61 8729.80 20.40 MWD 11889.27 96.73 226,91 6001.88 5881.98 3136.14 8187.63 5952239.08 548448.20 8704.87 16.46 MWD 11919.98 94.95 232,40 5998.75 5878.85 3116.38 8164.35 5952219.19 548425.04 8677.48 18.70 MWD 11949.63 92.98 227,00 5996.70 5876.80 3097.25 8141.80 5952199.94 548402.59 8650.96 19.34 MWD 11979.81 94.89 221.97 5994.63 5874.73 3075.78 8120.71 5952178.36 548381.62 8625.27 17.79 MWD 12010.65 92.67 219.86 5992.60 5872.70 3052.53 8100.56 5952155.00 548361.59 8600.06 9.92 MWD 12041.72 92.18 213.40 5991.28 5871.38 3027.63 8082.05 5952130.01 548343.22 8576.05 20.83 MWD 12070.78 91.81 209.02 5990.27 5870.37 3002.80 8067.00 5952105.10 548328.31 8555.41 15.12 MWD 12100.85 92.93 204.20 5989.02 5869.12 2975.94 8053.55 5952078.18 548315.00 8535.82 16.44 MWD 12131.18 92.70 198.43 5987.53 5867.63 2947.73 8042.54 5952049.91 548304.14 8518.27 19.02 MWD 12163.11 95.01 194.74 5985.39 5865.49 2917.21 8033.45 5952019.34 548295.22 8502.02 13.61 MWD 12189.80 97.42 190.94 5982.50 5862.60 2891.35 8027.55 5951993.45 548289.46 8490.00 16.79 MWD 12220.73 98.02 184.69 5978.34 5858.44 2861.00 8023.39 5951963.08 548285.46 8478.57 20.12 MWD 12251.50 97.44 179.12 5974.19 5854.29 2830.54 8022.38 5951932.62 548284.61 8470.17 18.04 MWD 12280.83 95.97 173.45 5970.77 5850.87 2801.48 8024.26 5951903.58 548286.65 8464.93 19.84 MWD 12312.87 95.41 167.79 5967.59 5847.69 2770.04 8029.46 5951872.17 548292.01 8462.31 17.66 MWD 12342.90 95.35 172.24 5964.77 5844.87 2740.60 8034.64 5951842.76 548297.35 8460.17 14.75 MWD 12387.45 95.38 182.16 5960.60 5840.70 2696.36 8036.81 5951798.53 548299.75 8451.49 22.17 MWD 12417.70 93.01 187.87 5958.38 5838.48 2666.32 8034.17 5951768.48 548297.28 8441.62 20.39 MWD 12449.67 91.20 193.84 5957.21 5837.31 2634.96 8028.15 5951737.09 548291.43 8428.15 19.50 MWD 12486.34 93.53 201.25 5955.69 5835.79 2600.05 8017.12 5951702.13 548280.58 8408.94 21.16 MWD 12516.74 92.27 20$.10 5954.15 5834.25 2572.48 8004.45 5951674.49 548268.06 8389.94 22.88 MWD 12545.73 90.68 203.83 5953.40 5833.50 2546.43 7991.77 5951648.38 548255.52 8371.29 15.71 MWD 12575.91 88.83 197.28 5953.53 5833.63 2518.19 7981.18 5951620.08 548245.08 8354.15 22.55 MWD 12600.26 88.89 189.71 5954.02 5834.12 2494.53 7975.50 5951596.40 548239.53 8342.88 31.08 MWD 12630.16 89.14 180.72 5954.53 5834.63 2464.79 7972.78 5951566.65 548236.98 8333.00 30.07 MW D 12665.95 89.11 176.78 5955.08 5835.18 2429.02 7973.57 5951530.89 548237.95 8325.05 11.01 MWD 12692.46 89.75 172.78 5955.34 5835.44 2402.63 7975.98 5951504.51 548240.50 8320.96 15.28 MWD 12721.02 89.23 169.83 5955.60 5835.70 2374.40 7980.29 5951476.31 548244.97 8318.27 10.49 MWD 12755.01 89.79 169.45 5955.89 5835.99 2340.96 7986.41 5951442.91 548251.26 8316.06 1.99 MWD 12784.70 87.79 171.61 5956.52 5836.62 2311.69 7991.29 5951413.66 548256.30 8313.66 9.91 MWD 12799.33 83.01 170.96 5957.69 5837.79 2297.28 7993.50 5951399.27 548258.58 8312.30 32.97 MWD 12815.23 82.24 165.83 5959.73 5839.83 2281.84 7996.67 5951383.85 548261.84 8311.61 32.36 MWD 12830.72 82.42 161.38 5961.80 5841.90 2267.11 8001.00 5951369.15 548266.25 8312.23 28.49 MWD 12859.98 84.16 154.27 5965.22 5845.32 2240.22 8011.96 5951342.32 548277.35 8316.31 24.85 MWD 12894.74 84.22 145.28 5968.75 5848.85 2210.38 8029.35 5951312.57 548294.90 8325.91 25.73 MWD 12925.47 84.96 139.72 5971.65 5851.75 2186.11 8047.97 5951288.41 548313.65 8338.06 18.17 MWD 12956.20 86.19 135.51 5974.02 5854.12 2163.49 8068.62 5951265.90 548334.41 8352.58 14.23 MWD 12985.30 87.39 131.64 5975.65 5855.75 2143.47 8089.67 5951245.99 548355.56 8368.11 13.90 MWD 13017.17 87.94 126.12 5976.95 5857.05 2123.49 8114.44 5951226.14 548380.45 8387.28 17.39 MWD 13047.29 88.90 119.55 5977.78 5857.88 2107.17 8139.73 5951209.96 548405.82 8407.83 22.04 MWD 13076.94 89.26 113.70 5978.26 5858.36 2093.89 8166.22 5951196.83 548432.38 8430.29 19.76 MWD 13106.39 88.93 110.46 5978.72 5858.82 2082.82 8193.50 5951185.91 548459.72 8454.05 11.06 MWD • 13150.00 88.93 110.46 5979.54 5859.64 2067.58 8234.35 5951170.89 548500.64 .8489.96 0.00 MWD KRU 1 L-28 Producer with L1, L2, & L2-01 Laterals COI'1000P~'11~~1 S p Alaska, Inc. 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'/" 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 Peffs 11334'-11364' 3'/z' Camco MMM GLMs @ 4258', 7197', 9051', 10316', & 10836' MD 2'/•" slotted liner: 12,135' -12,853' MD interface between liner segments at 12,440' MD Baker ZXP Packer w/SBE @ 10,944' MD aluminum billet at 12,135' MD 3%" Camco W nipple, 2.813" min ID @ 10,912' MD 1 L-28L2 Lateral, TD @ 13,150' MD 3'/" tubing muleshoe @10976' MD 2'/::" slotted liner: 11,313' -13,035' MD solid jnts: 11,347' -11,817' /~, i/ ~ 2'/." slotted liner: 11,324' -13,150' MD solid juts: 11,377' -11,884' interface between liner segments at 12,387' MD KB packers at 11, 325 & 11, 359 M D • 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 1L-28L1 Lateral, TD @ 13,150' MD A-5 sand perfs 11518' - 11538' Updated: 2-28-08 ri~~ BAKER NUGNES INTEQ 7260 Homer Drive Anchorage, Alaska 99518 Tel 907-267-6600 Fax 907-267-6623 To Whom It May Concern: March 7, 2008 Please find enclosed directional survey data for wells: 1L-28L1, 1L-28L2 and 1L-28L2-O1. Enclosed is: lea 3.5" floppy diskette containing electronic survey file Cc: State of Alaska, AOGCC Christine Mahnken ~.~~-~sy STATE OF ALASKA 11113!07 O IL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Contractor: Nordic Rig No.: 2 DATE: 2/10/08 Rig Rep.: Mckeiman/Sloan R~ Phone: 659-4398 R~ Fax: 659-4356 Operator. BPX Op. Phone: 659659-4393 Op. Fax: 659-4356 Rep.: Goodrich/Sevcik E-Malt _ Well Name: «~~Z ~ PTD~I Operation: Drig: X Workover: Explor.: Test: lnitiaL• Weekly: Bi-Weekly X Test Pressure: Rams: 250/3500 Annular. 250/350f1 Valves: 25813500 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 Drl. Rig P Lower Kelly NA PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted F Inside BOP NA BOP STACK: Quantity SizelType 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 P P #2 Rams 1 2" Combi P Meth Gas Detector P P #3 Rams 1 2318" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams NA Quantity Test Result Choke Ln. Valves 1 3118" P Inside Reet valves 1 P HCR Valves 2 3118" P Kill Line Valves 1 3118" P ACCUMULATOR SYSTEM: Check Valve 2 21116" P Time/Pressure Test Result Syctem Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2200 P Quantity Test Result 200 psi Attained 25 sec P No. Valves 14 P Full Pressure Attained 85 sec. P Manual Chokes 1 P Blind Switch Covers: Ali stations Yes Hydraulic Chokes 1 P Nitgn. Bottles (avg}: 4 2125 Test Resuffs Number of Failures: 0 Test Time: 6 Hours Components tested 31 Repair or replacement of equipment will be made within days. Notify the North Slope Inspector 659-3607, follow with written confirmation to Supervises at: Remarks: 24 HOUR N071CE GIVEN YES XX NO Waived By Tom Noble Date 2/9/08 Time 0700 Witness Test start 0530 Finish 1130 BOP Coil for Rigs BFL 11/13/07 Nordic 2 BOP 2-10-08.x1s i ~ r l €€ ~. ~ SARAH PAUN GOV ~S~ ~~ ~ ~ 333 W. 7th AVENUE, SUITE 100 COlYSi' RQA7`IO1~T COl-II~-iISSI011T ANCHORAGE, ALASKA 99501-3539 Gary Eller FAHXONE (907) 279-1433 Drilling Engineer (so7> 27s-7sa2 c/o BP Exploration Alaska, Inc. PO Box 196612 Anchorage, Alaska 99519-6612 Re: Kaparuk River Unit Field, Kaparuk River Pool, Kaparuk 1 L-28L2 Drilling Engineer Permit No: 207-154 Surface Location: 89' FSL, 216' FWL, SEC. 29, T11N, R10E, UM Bottomhole Location: 1730' FSL, 3487' 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 Co fission to witness any required test, contact the Commission's petroleum field insp cto at (907) 659-3607 (pager). DATED this ~ day of November, 2007 cc: Department of Fish 8s; Game, Habitat Section w/ o encl. Department of Environmental Conservation w/o encl. ~~EI\/E® STATE OF ALASKA ALAS~OIL AND GAS CONSERVATION COMM~O J C T ~ 5 2007 PERMIT TO DRILL ~~tij~ 20 AAC 25.005 ~1(aska Oil & Gas Cons. Commission 1 a. Type of work ^ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ^ Development Gas ^ Service ^ Multiple Zone ^ Stratigraphic Test ®Development Oil ^ Single Zone 1 c. Specify if well is pro B ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 11. Well Name and Number: Kuparuk 1L-28L2 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13700 ~ TVD 5871 ss 12. Field / Poo!(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface: ' FS ' 7. Property Designation: ADL 025660 ' River Pool 89 L, 216 FWL, SEC. 29, T11 N, R10E, UM Top of Productive Horizon: L~j hD ~~• ~•d7 3682' FSL, 3163' FWL, SEC.2~T, T11N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: December 1, 2007 Total Depth: , 1730' FSL', 3487' FWL, SEC. 28, T11 N, R10E, UM 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 Wetl Within Pool: 691' 16. Deviated Wells: Kickoff Depth: 11300 • feet Maximum Hole An le: 102 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3507 ° Surface: 2887 18. Casin Pr .ram: S do ns Ta - Settin De th -Bo ttom uantit of Cement c.f. or sacks 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 2395' 11305' 5836'ss 13700' 5871'ss Uncemented Slotted Liner 19. PRESE NT WELL CONDiTIf)N SUMMARY (To be completed for Redrill and Re-entry Operations) Total Depth MD (ft): 11770 Total Depth TVD (ft): 637g 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 ds 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' Pro uc ion Liner 825' 3-112" 255 sx Class 'G' 10944' - 11769' 5658' - 6378' Liner L1 1830' 2-3/8" Uncemented Slotted Liner 11320' - 13150' 5849' - 5944' 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 ify that the fore ing is true and correct. Contact Gary Eller, 529-1979 Printed Na Gary Eller Title CT Drilling Engineer Prepared By Name/Number: Si nature Phone 263-4172 Date' i Terrie Hubble, 564-4628 Commission Use Onl Permit To Drill Number: ~ '-~S API Number: 50-029-22951-61-00 Permit proval See cover letter for Date: other re uirements Conditions of Approval: - / If box is checked, well may not be used to explore for, test, or produce coalbed methane, gas hydrates, or gas contained. shales: (~~,/' Samples Req'd: ^ es LJ No Mud Log Req'd: ~es LrJ No HzS Measures: No ctional Survey Req'd: Yes ^ No Other: 3Jr~t~S ~ ~~~ '~'~ S~ APPROVED BY THE COMMISSION Date. l/~~ ~ V ,COMMISSIONER Form 10-401 Revised 12/2005Submit In Duplicate ORIGINAL '(•'~°~ ,.~ ~~r~~ KRU 1 L-28 Dual Laterals -Coiled Tubing Drilling Summary of Operations: A coiled tubing drilling rig will drill two laterals in well KRU 1 L-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 23/8" 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 3'/i" 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%2" liner and tubing. 8. E-line set 3'/i" monobore whipstock at 11,315' MD Rig Work 1. MIRU Nordic Rig #2 using 2" coil tubing. NU 7-1/16" BOPE, test. 2. 1L-28L1 Lateral 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 ~x~inrlncv at 1 1 21 S° ANTI 3. 1L-28L2 Lateral 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. ~G~~-C 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 • KRU 1 L-28 Dual Laterals -Coiled Tubing 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: 3'h", L-80, 9.3 ppf Burst 10,160 psi Collapse 10,530 psi Well Control: • 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 2500 psi. Logging • MWD directional, resistivity, and gamma ray will be run over the entire open hole section. Hazards 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 ~' 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 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 • • KRU 1 L-28 Dual Laterals -Coiled Tubing 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 1 L-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 hole pressure as during drilling operations. Page 3 of 3 October 18, 2007, FINAL • ~~ ColnocoPhillips Alaska, Inc. KRU 1 L-28 1L-28 API: 500292295100 Well T : PROD An le TS: 28 d 11291 TUBING SSSV Type: NIPPLE Orig 11/23/1999 Angle @ TD: 23 deg @ 11770 (0-10952, OD:3.500, Com IeUon: ID:z.s9z) Annular Fluid: DSUSW Last W/O: Rev Reason: GLV C/O Reference L Ref L 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-s5as, Casin Strin -ALL OD:9.625, wt:ao oo) DeSCrI lion Size To Bottom ND VYt 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 ~ (o-ttt17 LINER 3.500 10944 11769 6378 9.30 L-80 EUE 8RD , oD:7.oo0, Tubin Strin -TUBING wt:zs.oo> Size To Bottom TVD Wt Grade Thread 3.500 0 10952 5664 9.30 L80 EUE8RD Perforations Summa cas Lift M W 1 Interval ND Zone Status Ft SPF Date T e Comment i1dfe a ~ z 11295 - 11320 5947 - 5969 C-4 25 6 6/22/2000 APERF 2.5" HSD, 60 d hasin (7ts7.7t9a. 11334 - 11364 5981 - 6008 C-4,C-3,C-1 30 4 3/19/2000 APERF 2.5" HSD, 60 de hasin 11518 - 11538 6147 - 6166 A-5 20 4 12/19/1999 IPERF 2.5" HSD, 180 d hasin Stimulations 8 Treatments Gas utt Interval Date T e Comment Mand~euvan~s 11518 - 11538 2/12/2000 FRAC 'A' SAND FRAC 3 (905t-9052 11295 - 11364 5/7/2000 FRAC 'C' SAND FRAC , Gas Lift MandrelsNalves St MD ND Man Man Type V Mir V Type V OD Latch Port TRO Date Vlv Mir Run Cmnt 1 4258 261 5 CAMCO MMM CAMCO GLV 1.5 RK 0.156 1265 8/30/2005 2 7197 386 4 CAMCO MMM CAMCO GLV 1.5 RK 0.188 1254 8/30!2005 3 9051 465 6 CAMCO MMM CAMCO GLV 1.5 RK 0.188 1230 8/29/2005 i 4 10316 523 4 CAMCO MMM CAMCO GLV 1.5 RK 0.188 1206 8/29/2005 '. 5 10836 557 6 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 t:9.30) Perf '11295.11320) FRAC '11295.11364) Perf '11334-11364) Pert '1151&11538) ` FRAC i KRU 1 L-28 Producer ~rrr-' , Proposed L1 & L2 CTD Laterals ~C~rnc~Ct~-~`~~~l~ Alaska, Int. 3'/2" .Camco DS nipple, 2.813" min ID at 553' MD 3'/z" 9.3# L-80 EUE 8rd Tubing 3'/i' Camco MMM GLMs @.4258', 7197', 9051', 10316', & 10836' MD 95/8' 40# L-80 @ 6546' M D Baker ZXP Packer w/SBE @.10,944' MD 7" 26# L-80 3'/z" Camco W nipple, 2.$13" min ID @ 10,912' MD @ 11,117 MD 3'/2' tubing muleshoe @.10976' MD 23/a" liner top @ +/-11,305' MD 3'/2' Retrievable ' whipstocks L2 KOP 11,300' MD C4 Perfs 11295'-11320' 2-3l8" slotted liner L1 KOP 11,315' MD 23/8' liner top @ C3/C4 Perfs - 11,320' MD 3" openhole 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 1 L-28L2 Lateral, TD @ 13,700' MD - 1L-28L1 Lateral, TD @ 13,150' MD Updated: 10-23-07 n LJ • by BP Alaska Baker Hughes INTEQ Planning Report ~.r LNTEQ Company: BP Amoco Date: 10/17/2007 Time: 17:03:01 Pale: 1 Field: Kuparuk Co~ordioate(NE) Reference: Well: 28, Tnm North Site: KRU 1 L Pad Vertical (TVD) Retsreucr. 1 L-28 Datum 120.0 Weil: 28 Section (VS) Rekreuee: WeN (O.OON,O.OOE,180. OOAEi) WeNpath: Plan S, 1L-28L2 Srtrvey Cako{rtdon Method: Minimum Curvature Dh: Oratie Field: Kuparuk Map System:US State Plane Coordinak System 1927 Map Zonr. Alaska, Zone 4 Gen Datum: NA027 (Clarke 1866) Coardiaate System: Well Centre Sys Datum: Mean Sea Level Geoma=eetic Model: bggm2007 Site: KRU 1 L Pad Site Posfdiou: Northing: 5948968. 90 ft I.atitade: 70 16 17.459 N From: Map EasNug: 540062. 68 ft i:.osgNede: 149 40 33.550 W Position Uncertainty: 0.00 ft North Rekreece: True Gressel Levei: 0.00 ft Grid Convergence: 0.31 deg Well: 28 Slat Name: Well Positioe: +N/-S 89.57 ft Northi®g: 5949059. 61 ft I.atitnde: 70 16 18.340 N +E/-W 216.16 ft Easting : 540278. 34 ft LoaSitede: 149 40 27.257 W Position Uncertainty: 0.00 ft WeUpath: Plan 5, 1L-28L2 Drilled From: Plan 4, 1L-28L1 500292295161 Tie-ou Depth: 11 209.74 ft Current Datam: 1 L-28 Datum Height 120. 00 ft Above System Datum: Mean Sea Level Magnetic Data: 10/17/2007 Decliuatioo: 23.06 deg Fieh1 Strength: 57616 nT Mag Dip Angle: 80.78 deg Vertical Section: Depth From (TVD) +N/-S +E/-W Direction ft ft ft deg 120.00 0.00 0.00 180.00 Pfau: Plan p5 Date Composed: 10/17/2007 Version: 4 Principal: Yes Ticd-to: From: Definitive Path Targets Map Map ~-- Enfilade -> <- Lougitnde -> Na®e Deseription ' TVD +N/-S +E/-W No'(;hiag Eastit+g Deg Miu Sec Deg Mie Sec Dip.. Dir. tt ft ft' ft ft 1L-28L2 Polygon 120.00 3632.72 8237.03 5952736.00 548495.00 70 16 54.023 N 149 36 27.337 W -Polygon 1 120.00 3632.72 8237.03 5852736.00 548495.00 70 16 54.023 N 149 36 27.337 W -Polygon 2 120.00 3587.33 8308.79 5952891.00 548567.00 70 16 53.576 N 149 36 25.248 W -Polygon 3 120.00 3488.18 8335.26 5952592.00 548594.00 70 16 52.600 N 149 38 24.480 W -Polygon 4 120.00 3317.16 8334.35 5952421.00 548594.00 70 16 50.918 N 149 38 24.512 W -Polygon 5 120.00 3191.30 8306.67 5952295.00 548567.00 70 16 49.681 N 149 38 25.323 W -Polygon 8 120.00 2932.00 8170.27 5952035.00 548432.00 70 18 47.132 N 149 38 29.304 W -Polygon 7 120.00 2932.00 8170.27 5952035.00 548432.00 70 16 47.132 N 149 36 29.304 W -Polygon 8 120.00 2554.30 8105.24 5951857.00 548369.00 70 16 43.418 N 149 38 31.209 W -Polygon 9 120.00 2238.99 8157.56 5951342.00 548423.00 70 16 40.316 N 149 38 29.896 W -Poygon 10 120.00 1993.62 8407.28 5951098.00 548674.00 70 16 37.901 N 149 38 22.431 W -Polygon 11 120.00 1902.27 8471.79 5951007.00 548739.00 70 16 37.001 N 149 36 20.558 W -Polygon 12 120.00 1723.78 8559.85 5950829.00 548828.00 70 16 35.245 N 149 38 17.997 W -Polygon 13 120.00 1463.42 8621.48 5950589.00 548881.00 70 16 32.884 N 149 36 16.212 W -Polygon 14 120.00 1482.67 8387.54 5950587.00 548657.00 70 16 32.876 N 149 36 23.023 W -Polygon 15 120.00 1751.98 8334.97 5950856.00 548603.00 70 16 35.525 N 149 36 24.545 W -Polygon 16 120.00 2087.08 7949.72 5951189.00 548218.00 70 16 38.825 N 149 36 35.753 W -Polygon 17 120.00 2294.63 7831.82 5951396.00 548117.00 70 16 40.887 N 149 36 38.597 W -Polygon 18 120.00 2609.61 7862.51 5951711.00 548126.00 70 18 43.965 N 149 38 38.277 W -Poygon 19 120.00 2833.34 7917.71 5951935.00 548180.00 70 16 48.t84 N 149 38 36.882 W -Polygon 20 120.00 3030.82 8017.78 5952133.00 548279.00 70 18 48.106 N 149 38 33.742 W -Polygon 21 120.00 3363.70 8235.59 5952487.00 548495.00 70 1 t3 51.377 N 149 38 27.387 W -Polygon 22 120.00 3596.98 8191.83 3932700.00 548450.00 70 16 53.872 N 149 38 28.855 W 1L-28L2 Fault 1 120.E 2739.00 7791.19 5951840.00 548034.00 70 18 45.238 N 149 ~ 40.350 W -Polygon 1 120.00 2739.00 7791.19 5951840.00 548054.00 70 18 45.238 N 149 38 40.330 W -Polygon 2 120.00 2773.03 7973.40 5951875.00 548236.00 70 18 45.571 N 149 38 35.042 W -Polygon 3 120.00 2694.92 8180.00 5951798.00 548443.00 70 18 44.E N 149 38 29.028 W • by BP Alaska Baker Hughes INTEQ Planning Report ~.r INTEQ compaay: BP Amxo Drte: 1x17/2007 Time: 17:03:01 Psae: 2 [rieW: Kuparuk Co~srdfnate(NE) Retererce: Wed: 28, True NoAh SNe: KRU 1 L Pad VsAkal (TVD) Reteresce: 1 L-28 Datum 120.0 WeU: 28 SetHor (VS) Refereree: Wed (O.OON,0.00l,180. OOsAai) We~atY: Plan 5, 1 L-28L2 Sarvey Cakrlrtion MetYad: Minimum Curvature Db: Orade Tar=ets M4! Mxp <--- LAtilyde ---> <~ I,oa;ilyda ~ Name De9criptior TVD +N/.S +E/•W Nwt6i~ E~~ Dea Min Sec De; Mir Set Dip. Dh. R ft A R ft -Polygon 4 120.00 2773.03 7973.40 5951875.00 548236.00 70 16 45.571 N 149 38 35.042 W 1L-28L2 Fault 2 120.00 2242.99 8344.60 5951347.00 548610.00 70 16 40.354 N 149 38 24.249 W -Polygon 1 120.00 2242.99 8344.60 5951347.00 548610.00 70 18 40.354 N 149 38 24.249 W -Poygon 2 120.00 1902.34 8458.79 5851007.00 548726.00 70 16 37.002 N 149 36 20.934 W -Polygon 3 120.00 1721.92 8345.81 5950826.00 548814.00 70 16 35.229 N 149 38 24.230 W -Polygon 4 120.00 1902.34 8458.79 5951007.00 548726.00 70 16 37.002 N 149 36 20.934 W 1 L-28L2 Target 5 5941.00 2435.36 7904.58 5951537.00 548169.00 70 16 42.250 N 149 38 37.057 W 1 L-28L2 Target 1 5951.00 3596.83 8215.83 5952700.00 548474.00 70 16 53.670 N 149 36 27.955 W 1 L-28L2 Target 4 5968.00 2715.20 7940.08 5951817.00 548203.00 70 18 45.002 N 149 36 36.014 W 1 L-28L2 Target 6 5991.00 . 1663.94 8528.52 5950769.00 548797.00 70 16 34.657 N 149 36 18.912 W 1L-28L2 Target 3 6012.00 3191.77 8217.67 5952295.00 548478.00 70 16 49.686 N 149 36 27.915 W 1L-28L2 Target 2 6084.00 3472.32 8307.18 5952576.00 548566.00 70 16 52.445 N 149 36 25.299 W Annotation MD TVD ft ft 11209.74 5872.95 TIP 11300.00 5951.18 KOP 11320.00 5968.76 End of 9 Deg/100' DLS 11350.00 5993.99 4 11537.56 6066.41 End of 45 Deg/100' DLS 11817.56 6012.32 6 11967.56 5992.06 7 12382.56 5967.91 8 12487.56 5956.87 9 12677.56 5941.57 10 13152.56 5959.10 11 13700.00 0.00 TD Plan Section Information MD Intl Aaim TVD : +N/S +E/-W DL$ ~~ Ts~^n TFO Target ft deg deg ft ft ft deg/100R dogM 00R deg/100ft deg 11209.74 31.95 85.24 5872.95 3595.47 8173.09 0.00 0.00 0.00 0.00 11300.00 27.87 89.19 5951.18 3597.75 8218.01 5.02 -4.52 4.38 155.93 11320.00 29.17 91.80 5988.76 3597,67 8227.56 9.00 6.49 13.06 45.00 11350.00 36.78 112.50 5993.99 3593.98 8243.23 45.00 25.36 68.98 85.00 11537.56 100.00 178.83 6066.41 3453.86 8309.41 45.00 33.71 35.37 65.00 11817.56 101.63 213.02 6012.32 3193.53 8235.37 12.00 0.58 12.21 84.00 11967.56 93.80 229.39 5992.06 3082,31 8137.73 12.00 -5.22 10.91 114.50 12382.56 92.45 179.52 5967.91 2716,93 7971.70 12.00 -0.32 -12.01 270.00 12487.56 99.60 189.97 5956.87 2613.08 7963.14 12.00 6.81 9.94 55.00 12677.56 89.55 169.40 5941.57 2424.95 7964.42 12.00 -5.29 -10.82 245.00 13152.56 86.57 112.44 5959.10 2071.38 8251.28 12.00 -0.83 -11.99 266.20 13700.00 87.50 178.23 5991.00 1648.10 8545.21 12.00 0.17 12.02 91.20 i • by BP Alaska Baker Hughes INTEQ Planning Report ~.r 1NTEQ Sarvey MD [acl Axtm SS TVD 1t ~g deg R 11209.74 31.95 85.24 5752.95 11288.45 28.39 88.63 5821.00 11299.79 27.88 89.18 5831.00 11300.00 27.87 89.19 5831.18 11319.13 29.11 91.69 5848.00 11320.00 29.17 91.80 5848.76 11346.30 35.67 110.39 5871.00 11350.00 38.78 112.50 5873.99 11373.29 42.13 126.72 5892.00 11400.00 49.97 139.43 5910.56 11500.00 85.83 169.59 5948.32 11537.56 100.00 178.83 5946.41 11600.00 100.70 186.42 5935.18 11700.00 101.42 198.62 5915.93 11800.00 101.64 210.87 5895.86 11817.56 101.63 213.02 5892.32 11900.00 97.40 222.09 5878.66 11967.56 93.80 229.39 5872.06 12000.00 93.79 225.48 5869.92 12100.00 93.65 213.46 5863.41 12200.00 93.36 201.44 5857.27 12300.00 92.91 189.43 5851.79 12382.56 92.45 179.52 5847.91 12400.00 93.65 181.24 5846.99 12487.56 99.60 189.97 5836.87 12500.00 98.96 188.60 5834.87 12600.00 93.72 177.73 5823.79 12677.56 89.55 169.40 5821.57 12700.00 89.38 166.72 5821.78 12800.00 88.61 154.74 5823.55 12900.00 87.90 142.75 5826.61 13000.00 87.28 130.76 5830.84 13100.00 86.78 118.75 5836.05 13152.58 86.57 112.44 5839.10 13200.00 86.47 118.14 5841.98 13300.00 86.37 130.17 5848.25 13400.00 86.43 142.19 5854.56 13500.00 86.64 154.21 5860.63 13800.00 87.00 166.22 5866.19 ,13700.00 87.50 178.23 5871.00 N/3` E/VN ~N R R R 3595.47 8173.09 5952698.42 3597.85 8212.57 5952700.80 3597.75 8217.91 5952700.94 3597.75 8218.01 5952700.94 3597.68 8227.14 5952700.91 3597.67 6227.56 5952700.90 3594.78 8241.20 5952698.09 3593.98 8243.23 5952697.30 3586.62 8255.97 5952890.01 3573.45 8269.86 5952676.91 3491.04 8305.62 5952594.71 3453.86 8309.41 5952557.55 3392.55 8306.61 5952496.23 3296.93 8285.39 5952400.51 3208.13 8244.47 5952311.49 3193.53 8235.37 5952296.86 3129.18 8185.85 5952232.25 3082.31 8137.73 5952185.12 3060.41 8113.89 5952163.10 2983.52 8050.58 5952085.88 2895.11 8004.65 5951997.23 2799.04 7978.13 5951901.03 2716.93 7971.70 5951818.89 2699.51 7971.58 5951801.48 2613.08 7963.14 5951715.01 2600.96 7961.16 5951702.88 2501.90 7955.74 5951603.81 2424.95 7964.42 5951526.91 2403.00 7969.06 5951504.98 2308.79 8002.00 5951410.96 2223.50 8053.76 5951325.95 2150.85 8122.09 5951253.68 2094.02 8203.98 5951197.30 2071.36 8251.28 5951174.90 2051.14 8294.08 5951154.90 1995.21 8376.51 5951099.42 1923.34 8445.49 5951027.93 183E.66 8497.99 5950943.54 1744.88 8531.73 5950849.95 . 1648.10 8545.21 5950731.25 MapE DLS VS TFO ToAI tt degH OOR R deg 548431.27 0.00 -3595.47 0.00 MIND 548470.73 5.02 -3597.85 155.93 1 L-2 548476.08 5.02 -3597.75 153.00 1 L-2 548478.17 5.02 -3597.75 152.51 MWD 548485.30 9.00 -3397.68 45.00 1 L-2 548485.72 9.00 -3597.67 42.80 MIND 548499.38 45.00 -3594.78 65.00 1 L-28 548501.41 45.00 -3593.98 49.24 MWD 548514.19 45.00 -3386.62 65.00 1 L-28L 548528.14 45.00 -3573.45 53.98 MWD 548584.35 45.00 -3491.04 45.12 MWD 548568.34 45.00 -3453.88 32.96 MWD 548565.86 12.00 -3392.55 84.00 MWD 548545.16 12.00 -3296.93 85.36 MWD 548504.72 12.00 -3208.13 87.71 MWD 548495.70 12.00 -3193.53 90.17 MWD 548446.52 12.00 -3129.18 114.50 MWD 548398.66 12.00 -3082.31 116.00 MWD 548374.94 12.00 -3060.41 270.00 MWD 548312.05 12.00 -2983.52 268.74 MWD 548266.60 12.00 -2895.11 268.96 MVVD 548240.59 12.00 -2799.04 268.22 MWD 548234.60 12.00 -2716.93 267.56 MWD 548234.58 12.00 -2699.51 55.00 MWD 548226.60 12.00 -2613.08 55.09 MWD 548224.69 12.00 -2600.95 245.00 MWD 548219.79 12.00 -2501.90 244.78 MWD 548228.89 12.00 -2424.95 243.57 MWD 548233.65 12.00 -2403.00 266.20 MWD 548267.09 12.00 -2308.79 266.23 MWD 548319.30 12.00 -2223.49 266.44 MWD 548388.00 12.00 -2150.85 266.80 MWD 548470.19 12.00 -2094.02 267.31 MWD 548517.60 12.00 -2071.36 287.94 MWD 548580.51 12.00 -2051.14 91.20 MIND 548643.23 12.00 -1995.21 90.85 MWD 548712.59 12.00 -1923.34 90.10 MWD 548765.54 12.00 -1838.66 89.34 MWD 548799.77 12.00 -1744.88 88.61 MWD 548813.78 12.00 -1846.10 87.94 23/8" • • ~uparuk Managed Pressure Drillin~ BOP Configuration for 2" Coil Tubing KB EIS Well 1 L-28 Rig Floor ~--- Lubricator ID = ~J 7 1/16" 5000 psi, RX-46 Blind She TOT ~ 1/4 Turn LT Valve ;, 2 "Combi 3" 5000 psi i ~ 7 1/16" 5000 psi RX-46 HCR MUa cross HCR Choke Line Kill Line 1 z-3I8 " Cambi 2 1/16" 5000 psi , RX-24 TOT 2" Combi ~1 TOT 7 1/16" 5000 psi (RX-46) or ~ 4 1/16" 5000 psi (RX-39) Swab Valve Tree Size Flow Tee 3-1!8". 5f`!1 ~ n Flow Line -• SSV W / l iVlaster ~~ai~,iF Base Flan e Page 1 C7 TRANSMITTAL LETTER CHECKLIST WELL NAME ~~~ ~~ " ~ L Z PTD# ~ ~ ~" / S~` / 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 wet! /</~GC. ~G - Z `~ (If last two digits in permit No. /99'69 API No. 50-bZ 7~Z9-~~ - ~ V API number ~ 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 togs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing the exception.. _ assumes liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals through target zones. Please note the following special condition of this permit: Non-Conventional production or production testing of coal bed methane is not allowed Well for (name of weld until after !Company Name) has designed and implemented a water welt testing program to provide baseline data on water quality and quantity. lComaanv Name) must contact the Commission to obtain advance approval of such water well testing ro ram. Rev: 7/13/2007 • • ~^ o i I w rn a~ a ; i rn ~ ~ ~ ; v. ~ V, O ~~ ~ ~ ~ ~ ~ ~ ~ ~ ~ J' ~ O, ~ c i O: ~ y. N' c 1 0 c. ~ o O' N. 3 c. ° m' ~ m o N' I . _ z' ~ ~ . ~ o ~, , .~ r a m. ~° a~ . ~' ~ 01 ~ y. p~ ~ c. ~ -o. o ~ o. y. n = ~ O g a ~ aai ~ c. ~ '- ~ m. H' ~ .4` ~ O ~ O' ~' N ~ N. ~ ~ ~ ~ ~ ~ ~ O. a' ~ Q. d ~ ~~ U Y > a , ~ ~ °, ° O i ~ ~~ N' i ~~ L~ O~ N N c' C' ~ ~ C' ~ ~ ~ ~ ~ ~ ~ ~ ~ ; ~ ~ ~ ~ ~ t6, O. T N ; N• ~ ~~ ~ y. ~ y, m ~ ~~ p ~ O. ~ ~ _ N. ~ O C' O ~ O C o O. ~ ~ ~ ~ ~ ` ' ~~ ~' L. ~ a. ~ ~ N• , ~ ~ ` ~' m c co ~ a~ i m. 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