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208-029
• IrT~~ga ~roja~t 1~fa11 ~-~istOr°y ~"i~+~ GaVar ~ac~e XHVZF_ This page identifies those items that were not scanned during the ir~itial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. ~Q~ - ~~ _ Well History File Identifier OrganlZing (done) RESCAN ^ Color Items: ^ Greyscale Items: ^ Poor Quality Originals: ^ Other: NOTES: BY: Maria _ Project Proofing BY: ~ Maria _ Scanning Preparation BY: Maria ,~.,a~ iiiuuiiiiiiiuu DIGITAL DATA ^ Diskettes, No. ^ Other, No/Type: ~, Aes~~~~eeced iiiiaiiiruiuii OVERSIZED (Scannable) ^ Maps: ^ Other Items Scannable by a Large Scanner OVERSIZED (Non-Scannable) Date: ~, Date: ~~x30= Date: ~ ~~ / t,/ + c:~ =TOTAL PAGES ~~ (Count does not include cover sheet) t~ , /s/ Y y ~rnP iiiuiumiiiiui m~ Production Scanning (I I II II II (I III I I III -~ Stage 1 Page Count from Scanned File: ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: ~ES NO BY: Maria .Date: / ~, ~ ~ /s/ ~~ Stage 1 If NO in stage 1, page(s) discrepancies were found: YES NO BY: Maria Date: /s/ scanning is complete at this point unless rescanning is required. II I II ~I II I II II I I III ReScanned BY: Maria Date: /s/ Comments about this file: Qualit Checked III II'lll'II II'I III Y ^ Logs of various kinds: ^ Other:: P 10/6/2005 Well History File Cover Page.doc U Company Well Name Date ~b~-o~-~ ConocoPhillips, Alaska, Inc. / ~ ~ ~~ 1 L-28L2-01 12/312009 - - ~~~~~~~~~ ~~ t; ~ ~ 2~~5 ,'~ BAKER 1~`I~Is1E~ Page 1 of 4 DATA SUBMITTAL COMPLIANCE REPORT 12/17/2008 Permit to Drill 2080290 Well Name/No. KUPARUK RIV UNIT 1L-28L2-01 Operator CONOCOPHILLIPS ALASKA INC API No. 50-029-22951-62-00 MD 12116 TVD 5989 Completion Date 2/26/2008 Completion Status 1-OIL Current Status 1-OIL UIC N REQUIRED INFORMATION Mud Log No Samples No Directional Surrey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD DIR / RES / GR Well Log Information: Log/ Electr Data Digital Dataset Type Med/Frmt Number Name D D Asc Directional Survey Directional Survey Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y / Chips Received? Y~ % T~T~ Analysis Y~ lN" Received? Comments: Compliance Reviewed By: (data taken from Logs Portion of Master Well Data Maint Log Log Run Scale Media No Interval OH / Start Stop CH Received Comments 12100 13084 Open 3/10/2008 1 L-28L1 and 1 L-28L2 also on diskette 12100 13084 Open 3/10/2008 Sample Interval Set Start Stop Sent Received Number Comments Daily History Received? Formation Tops ~N 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„ 1 hate to be pickyr 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) Tam -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: iL-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. 1 can give you a breakdown of the numbers ifi you like. but my guess is that solid linerconstitutes -10°k 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. I see some "depth breaks" in the details in block 23. Based on the breaks, I am led to believe that not much solid liner was run in the laterals. Is that correct? Thanks in advance. Tom Maunder, PE AOGCC 5/ 14/2008 • ~ ^ 1 L-28 LINER SUMMARY L,-a - ©~ WELL # KRD1L-28 UNER SIZE f WTIFT f GRADE f THREAD f ID 2~/8° 4..448 $OTTOM OF LINER AT 13,035.00 TOP OF UNER AT 11,314.82 -80 uATE STL zf24f2oo8 NO ITEM OD ID LENGTH TOP BOTTOM Unique Inde~dng Guide Shoe (3 ea 1/2" side pores) 2.650 0.660 1.36 13,033.64 13,035.00 1 2-3/8" 4.4# L-80 STL Solid Tubing PJ 2.375 1.992 9.80 13,023.84 13,033.64 1 2-3/8" 4.4# L-80 STL Solid Tubing PJ 2.375 1.992 9.82 13,014.02 13,023.$4 O-ring Sub 2.392 1.000 0.66 13,013.36 13,014.02 38 2-3/8" 4.4# L-80 STL ubing 2.375 1.992 1195.48 11,817.88 13,013.36 15 2-3/8" 4.4# L-80 STL Solid Tubing 2.375 1.992 471.37 11,346.51 11,817.88 1 2-3/8" 4.4# L-80 STL ubing 2.375 1.992 31.69 11,314.82 11,346.51 BTT Deployment Sleeve w/ 2-318" STL pin 2.700 1.920 1.45 11,313.37 11,314.82 11,313.37 56 1721.63 BHA Total Length 1721.63 STATE OF ALASKA ALASKA OIL AND GAS CONSERVATION COMMISSION RE~~~V~® MAR 2 6 2008 WELL COMPLETION OR RECOMPLETION REPORT AND LOG araska ai ~ G~ cor>s. conrruss;on 1 a. Well Status: ®Ojl ^ Gas ^ Plugged ^ Abandoned ^ Suspended • zoAACZS.~os zoAACZS.~~o ^ GINJ ^ WINJ ^ WDSPL ^ WAG ^ Other No. of Completions One 1 b. Well CI ®Development ^ Exploratory ^ Service ^ Stratigraphic 2. Operator Name: Conoco Phillips Alaska Inc. 5. Date Comp., Susp., or Aband. 2/26/2008 12. Permit to Drill Number 208-029 - 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 2/21/2008 13. API Number 50-029-22951-62-00 ' 4a. Location of Well (Governmental Section): Surface: 89' FSL 216' FWL SEC 29 T11 N R10E 7. Date T.D. Reached 2/24/2008 14. Well Name and Number: Kuparuk 1 L-28L2-01 ' , , . , , , UM Top of Productive Horizon: 3687' FSL, 3158' FWL, SEC. 28, T11 N, R10E, UM g. KB (ft above MSL): 119.9' Ground (ft MSL): 15. Field /Pool(s): Kuparuk River Unit /Kuparuk Total Depth: 2180' FSL, 3010' FWL, SEC. 28, T11 N, R10E, UM 9. Plug Back Depth (MD+TVD) 13035 6019 River Pool - 4b. Location of Well (State Base Plane Coordinates, NAD 27): Surface: x- 540278 • y- 5949060 • Zone- ASP4 10. Total Depth (MD+TVD) 13084 6031 16. Property Designation: ADL 025660 • TPI: x- 548467 y_ 5952705 Zone- ASP4 Total Depth: x- 548340 y- 5951193 • Zone- ASP4 11. SSSV Depth (MD+TVD) None 17. Land Use Permit: 18. Directional Survey ®Yes ^ No Submit electronic and tinted 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): ~ ~ iZ-i%4: ` .~11b MWD DIR / RES / GR ~ ~ ~' ~~ / 22. CASING, LINER AND CEMENTING RECORD ,~+~ $''~ • r'~ CASING SETTING DEPTH MD SETTING DEPTH`TVD HOLE AMOUNT WT. PER FT. GRADE TOP ' BOTTOM TOP BOTTOM SIZE CEMENTING RECORD PULLED 16" 62.5# H-40 Surface 115' Surfa a 115' 24" 9 cu ds Hi h Earl 9-5/8" 40# L-80 Surface 6546' Surface 3586' 12-1/4" 702 sx AS III 806 sx Class 'G' 7" 26# L-80 Surface 11117' Surface 5796' 8-1/2" 115 sx Class'G' 3-1/2" 9.3# L-80 10944' 11 1' 5658' 952' 6-1/8" 255 sx Class'G' 2-3l8" 4.44# L-80 11313' 13035' 5963' 6019' 3" Uncemented Slotted Liner 23. Open to production or inject ion? ®Yes ^ No - 24. TUBING RECORD If Yes, list each interval open (MD+TVD of Top & Bottom; Perforation Size and Number): SIZE DEPTH SET MD PACKER SET MD 2-3/8" Slotted Liner ~ SO~~~ 3-1/2", 9.3#, L-80 10956' 10944' MD ,~ ND M~ TVD 11315' - 11347 5964' - 5992' 11818'- 13013'6013'-6013' 25:' ACID, FRACTURE, CEMENT SQUEEZE, ETC. ' DEPTH INTERVAL MD AMOUNT Ht KIND OF MATERIAL USED 12101' Kick Off From 1 L-28L2 2000' Freeze Protect w/ 35 Bbls Diesel 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: HOUrS Tested: PRODUCTION FOR TEST PERIOD OIL-BBL: GAS-MCF: WATER-BBL: CHOKE SIZE: GAS-OIL RATIO: Flow Tubing PreSS. CaSing PreSS: CALCULATED 24-HOUR RATE OIL-BBL: GAS-MCF: WATER-BBL: OIL GRAVITY-API (CORK): 27. CORE DATA Conventional Core(s) Acquired? ^Yes ®No - Sidewal l Cores Ac uired? ^Yes ®No' If Yes to either question, list formations and intervals cored (MD+TVD of top and bottom of each), and summarize lithology and presence of oil, gas or water (submit separate sheets with this form, if needed). Submit detailed descriptions, core chips, photographs and laboratory analytical results per 20 AAC 250.071. None ~L U!J ~~ { r -.. Form 10-407 ReVISed O2IZOO7 CONTINUED bN REVERSE SIDE ~ ~ \~ / _~/ p~~~ >L ~,1,(.. Gc ~+ `28. GEOLOGIC MARKERS (LIST ALL FORMATIONS AN KERS 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. (From 1 L-28. Parent Welll None Top Kuparuk C 11291' 5943' ------------------------------------------- (From 1 L-28L2) Top Kuparuk B 11374' 6013' Base Kuparuk C /Top Kup B 11793' 6018' (Inverted) - ------------------------------------------ (From 1 L-28L2-011 Top Kuparuk B 13020' 6015' Formation at Total Depth (Name): Top Kuparuk B 13020' 6015' 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the fore oing is true and correct to the best of my knowledge. ~3 ~O Signed Terrie Hubble Title Drilling Technologist Date Kuparuk 1 L-28L2-01 208-029 Prepared i3y Name/Number. Terrie Hubble, 564-4628 Well Number Permit No. / A r val NO. Drilling Engineer: Gary Eller, 263-4172 (Office) INSTRUCTIONS GeNeRAL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. Submit a well schematic diagram with each 10-407 well completion report and 10-404 well sundry report when the downhole well design is changed. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. IreM 4b: TPI (Top of Producing Interval). IreM 8: The Kelly Bushing and Ground Level elevation in feet above mean sea level. Use same as reference for depth measurements given in other spaces on this form and in any attachments. IreM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). IreM 20: Report true vertical thickness of permafrost in Box 20. Provide MD and TVD for the top and base of permafrost in Box 28. IreM 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. IreM 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). IreM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). IreM 27: Provide a listing of intervals cored and the corresponding formations, and a brief description in this box. Submit detailed description and analytical laboratory information required by 20 AAC 25.071. IreM 29: Provide a listing of intervals tested and the corresponding formation, and a brief summary in this box. Submit detailed test and analytical laboratory information required by 20 AAC 25.071. Form 10-407 Revised 02/2007 Submit Original Only w • 1~ BP AMERICA Page 19 of 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: I ` Phase Description of Operations Date From - To Hours Task Code NPT 2/20/2008 07:30 - 10:05 2.58 CASE N DPRB LNR2 0.25bpm/1200psi. Stop ®6000' & fix reel drive plate bolt that fell out (broken reel plate). Wt ck w/pumps off ~ 11250' _ 22.3k, 6k RIW. Close EDC. RIH 60'/min in open hole w/liner w/out pumping. Stop ~ 11500'. 3bbl loss during trip in the hole. 10:05 - 10:20 0.25 CASE N DPRB LNR2 Log down for tie-in (-11ft). 10:20 - 11:00 0.67 CASE N DPRB LNR2 Continue to RIH w/liner. Set down ~ 12060'. RIW = 5k to 4k. Wt ck (~ 12410' = 26k. RIH w/liner & set down ~ 12441'. PU & reconfirm set down depth. Tag at 12441' & set 2.5k# DHWOB. Start pumping ~ 1.7bpm/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 Start pumping at 0.6bpm/1500psi. POH. PJSM regarding handling BHA while POH. 13:20 - 15:05 1.75 CASE N DPRB PROD2 Flow check well. Pop off well. Blow down BHI tools. LD BHI tools onto catwalk, MU HOT to tool string. Test tools. PU BHI sidetrack BHA. Stab coil onto tools. Stab onto well. Power up & test tools. 15:05 - 17:05 2.00 DRILL N DPRB PROD2 Set counters &RIH. 17:05 - 17:20 0.25 DRILL N DPRB PROD2 Log down for tie-in (-10ft). 2bbl loss on trip in the hole. 17:20 - 18:05 0.75 DRILL N DPRB PROD2 Wiper to 12100'. Set down at 11580' (end of build section), PU & reduce rate to ibpm & pass through. _~ i('1 ~J ~ ~ - Continue to wiper to 12100' -clean. Op = 1.47 / 1.39 bpm at 3168 psi ECD /BHP = 11.96 ppg / 3660 psi 18:05 - 18:15 0.17 DRILL N DPRB PROD2 Stop RIH @ 12100'. Zero the WOB sensor. Stop pumping & lightly tag the top of the billet. Tag top of billet ~ 12135'. PU 10' & turn um son. 18:15 - 19:20 1.08 DRILL N DPRB PROD2 Start troughing from 12100' to 12130' 50R of HS 60 r. Made 2 runs -a ~ '1 _,-_ O ` ( Op = 1.60 / 1.37 bpm at 3450 psi cam ` 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 17:46:54 AM • BP AMERICA Page 20 ofi 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task Code ~ NPT Phase Description of Operations 2/21/2008 02:55 - 03:00 0.08 ~ DRILL N DPRB PROD2 12,134.2 ft. Pull up to 58k to get free. Bit stalled 2 ft higher. 03:00 - 03:45 0.75 DRILL N DPRB PROD2 03:45 - 06:20 2.58 DRILL N DPRB PROD2 06:20 - 06:30 0.17 DRILL N DPRB PROD2 06:30 - 07:15 0.75 DRILL N DPRB PROD2 07:15 - 09:15 I 2.001 DRILL I N I DPRB I PROD2 09:15 - 10:10 I 0.921 DRILL (N I DPRB I PROD2 12:25 - 12:50 i 0.421 DRILL I N I DPRB i PROD2 12:50 - 13:20 I 0.50 ~ DRILL N DPRB PROD2 13:20 - 13:35 0.25 DRILL N DPRB PROD2 13:35 - 14:55 1.33 DRILL N DPRB PROD2 14:55 - 17:10 ~ 2.25 I DRILL i N ~ DPRB I PROD2 17:10 - 19:25 I 2.251 DRILL I N I DPRB I PROD2 19:25 - 21:30 I 2.081 DRILL I N I DPRB I PROD2 Believe the liner is along side of us and coming up the hole with us. Pulling up to 60 k (+35k over). Working stuck pipe at 12,125 ft. The liner is coming up the hole wit us. a ieve t e top o e i let is at -12,125'. Pulled up to 60k again and got free. Total of 10 cycles was PUH and called the town team POOH with open EDC Flow check well & PJSM w/ day crew regarding handling BHA. 2 bbl loss on trip out of hole. Pop off well & place injector over bung hole, circ min rate. Blow down tools. LD tools on catwalk. Bit had 1 plugged jet from a piece of aluminum. Replace EDC on tool string. Test tools - good. Discuss w/ town regarding the current situation. Get orders. E-mail pictures. Wait on orders. Made the final decision to run a R60 bit w/ 1.7 ako motor. ~~ Dial down motor to 1.7 AKO setting. MU R-60 bit. PU BHI tools & make up to motor. PU injector & MU to tool string. Stab onto well. Power up & test tools. Set counters & RIH w/out pumping. Log down for tie-in (-9ft) Corr ~ 1 f 230'. Break circulation ~ min rate 0.32bpm/1120psi. Stop pumping & run past whipstock. RIH to 11350' & resume circ ~ 0.31 bpm/1168psi. RIH to TD. Set down & bobble past 11490'. Ratty w/little motor work from 11900' to 12100'. Start pumping at max rate. Op = 1.63 / 1.30 bpm at 3373 psi ECD /BHP = 11.81 ppg / 3595 psi Turn TF 180 degrees opposite of drilled TF &PUH & attempt to knock off brass cap. 23k up wt. Reduce rate &RIH to 12115'. Work back & forth. from 11700' to 12120'. Dry tag ~ 12134', which is 9' deeper than previously thought. PU & repeat 3 times w/ 1.6K to 2.6k WOB. PU to 12110', start pumping &RIH 180 degrees out. Inadvertently tag & stall motor ~ 12132' w/ pumps on while trying to confirm that the brass cap is off. Shut down pumps, 38k overpull. Reduce pump rate &PUH to 12100'. Increase to normal pump rate, let stretch out of coil. Start troughing from 12100' to 12035' 160R of HS ~ 30ft/hr. Op = 1.62 / 1.44 bpm at 3450 psi ECD /BHP = 12.00 ppg / 3660 psi PVT = 243 Reduce pump rate &PUH to 12100'. Increase to normal pump rate, let stretch out of coil. Start troughing from 12100' to 12060' 160R of HS ~ 60ft/hr. Op = 1.62 / 1.44 bpm at 3600 psi ECD /BHP = 12.15 ppg / 3700 psi PVT = 228 RIH and set at 12,100 ft TF at 164 R Op = 1.55 / 1.45 bpm at 3280 psi Time drilling at the start of the ST at 12,100 ft Printed: 3/12/2008 11:46:54 AM l • BP AMERICA Page 21 of 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Event Name: REENTER+COMPLETE Contractor Name: NORDIC CALISTA Rig Name: NORDIC 2 Date ~ From - To ~ Hours Task Code NPT '2/21/2008 19:25 - 21:30 2.08 DRILL N DPRB 21:30 - 23:00 1.50 DRILL N DPRB 23:00 - 00:00 1.00 DRILL N DPRB 2/22/2008 00:00 - 00:45 0.75 DRILL N DPRB 00:45 - 01:45 1.00 DRILL N DPRB 01:45 - 04:15 2.50 DRILL N DPRB 04:15 - 05:00 0.75 DRILL N DPRB 05:00 - 11:00 6.00 BOPSU N DPRB 11:00 - 11:45 0.75 DRILL N DPRB 11:45 - 13:50 2.08 DRILL N DPRB 13:50 - 14:10 0.33 DRILL N DPRB 14:10 - 14:45 0.58 DRILL N DPRB 14:45 - 15:00 0.25 DRILL N DPRB Spud Date: 2/20/2000 Start: 1 /15/2008 End: Rig Release: Rig Number: Phase Description of Operations PROD2 0.1 fU 2 to 3 min PROD2 Took off break and drill ST at a TF 160 deg RHS ROP at 0.1 fpm WOB 0.15 to 0.2 Ib. 3430 psi Pp off bottom at 1.57 bpm No indication on ST status from NBI or WOB sub at 12,103.9 ft to 12,106 ft at 0.1 fpm At 12,106 ft, started pushing on bit. Some evidence of ST at 12,111 ft WOB at 1.67 klbf, Pp at 3,420 psi, hole angle at 92.56 deg. Stacking. PU, 26k, RBIH With TF at 164 R, work way down ramp. Drilling ST ? at 12,114 ft, 29 fph and 2.54 klb WOB, CT weight at -6800 Ib. NBI at 92.9 deg hasn't changed in 16 ft drilled. At -9k coiled tubing wt, PUH to 12,103 ft. RBIH and seen some motor work and WOB at 12,112 ft PROD2 At 12,114 ft lost 1.00 bpm of returns and 300 psi on annulus and CT. PUH and checked all surface equipment and lines, (OK) Back to drilling Op =1.57 / 0.87 bpm. RBIH WOB at 1.87 klb, With NBI at 12,107 ft the hole angle dropped to 91 deg from 92.5 deg. The trough did nothing to achieve this sidetrack. Turning the TF to the left while drillling sidetrack at 12,116 ft. PROD2 Drilling sidetrack from 12,125 ft to 12,129 ft Op = 1.56 / 0.80 bpm. CTP=3,200 psi WOB at 1.08 klb and ROP with R60 at 9-11fph NBI at 12,113 angle at 89.72 deg PROD2 PU and RBIH and no ROP at 12,129 ft Back reamed sidetrack area from 12,129 ft to 12,080 ft at TF on the rside Dry tagged at 12,128 ft PROD2 POOH for BOP test Losing 0.6 bpm while POOH. Regained returns after pulling past 11,380 ft. Open EDC at 11290 ft and POOH pumping at 2.10 bpm. Out micro motion fluid rate increased while POOH Once out of the the hole, no fluid loss is seen PROD2 PJSM, Checked flow and unstabbed injector. LD sidetrack BHA 4 gauge cutters broke off. 1-5-2.71 go. Bit is still gauge on diamond gauge cutters, but matrix below PDC cutters is worn down to 2.65" OD. Closed Swab valve in preparation of BOP test PROD2 BOP test per AOGCC regs. PJSM regarding PU injector. PU injector & remove checks rom BHI tools. Stab onto well. PT inner reel valve & stripper per AOGCC regs. PROD2 Blow down stack. Open master & swab, fill hole. ~ 1 bbl to fill hole. Place injector over bung hole & circ min rate. Place motor & bit in hole. PU BHI tools & MU to motor & bit. PU injector & stab coil onto BHA. Stab injector onto well. Set counters. PROD2 RIH. PROD2 Log down for tie-in (-10ft). PROD2 Wiper to TD. 50% losses. Op = 1.61 / 0.77 bpm. CTP=3,100 psi ECD 11.53 PROD2 Drilling at 12130 ft TF at 60 deg R Op = 1.61 / 0.72 bpm 3100 psi off bottom BHP /ECD = 3484 psi / 11.42 ppg Printed: 3/12/2008 11:46:54 AM ~~ BP AMERfCA Page 22 of 25 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: i Spud Date: 2/20/2000 End: Date ~ From - To Hours Task Code NPT Phase Description of Operations 2/22/2008 14:45 - 15:00 0.25 DRILL N DPRB PROD2 Vp = 120 bbl Drilled to 12135' 15:00 - 15:10 0.17 DRILL N DFAL PROD2 Need to reboot BHI computer. Slowly wiper up hole to clean up sidetrack. 15:10 - 15:35 0.42 DRILL N DFAL PROD2 Need to re-install BHI database on computers. PUH into the tubing. 15:35 - 17:20 1.75 DRILL N DFAL PROD2 Open EDC, circ min rate & slowly PUH. 17:20 - 18:16 0.93 DRILL N DFAL PROD2 Close EDC. Wiper to TD. 18:16 - 20:50 2.57 DRILL N DPRB PROD2 Drilling Lateral 2L-01 at 12134 ft to TF at 73R HS Op = 1.59 (0.68 0.78 bpm at off bottom P= 3200 psi Vp = 429 bbl ROP 30-50 fph BHP = 3532 psi at ECD of 11.6 ppg Kupuark OC called Phase II weather conditions at 1950 hrs. 20:50 - 22:30 1.67 DRILL N DPRB PROD2 Wiper trip Pulled tight with motor work at 11700 ft, 11576 ft and 11, 500 ft- At lower flowrates in the open hole, getting solids break out in the inverted section of the well At 10,420 ft, the out flow rate increased from 0.70 bpm to 1.29 bpm. At 11,325 ft, RIH at Qp = 1.60 / 1.42 bpm to 11, 750 ft (clean out the belly of the well path) RIH and set down at 11,470 ft reduced Op and RIH and at 11,700 ft the out rate dropped off to losing 1.00 bpm. POOH and wait on fluid Burin Phase II in Ku uark 22:30 - 23:00 0.50 DRILL N DPRB PROD2 Open EDC at 11,290 ft and PUH to 6000 ft and wait on fluid from tank farm during this Phase II period. Stopped at 8000 ft and check circulation Op =1.69 / 1.46 bpm. PUH to 6000 ft Op = 1.00 / 1.00 bpm BHP AT 6000 ft 1914 ps 23:00 - 00:00 1.00 DRILL N WAIT PROD2 Cir waiting on fluid truck during Phase II weather condition 2/23/2008 00:00 - 00:50 0.83 DRILL N WAIT PROD2 Wait on vac truck with flo-pro during Phase II weather 00:50 - 02:05 1.25 DRILL N WAIT PROD2 RIH while taking on flo-pro Tie-in at 11216 ft (GR Marker) 02:05 - 02:30 0.42 DRILL N WAIT PROD2 Log tie-in at 11,240 ft (+18 ft) 02:30 - 03:40 1.17 DRILL N DPRB PROD2 RIH with EDC closed and correct TF LC zone at 11,550 ft. Set down at 11580 ft, PU and reduced Op to 0.7 bpm and RIH 03:40 - 05:30 1.83 DRILL N DPRB PROD2 Tagged bottom at 12253 ft Drilling lateral at 45L HS Op = 1.59 / 0.80 bpm at 3010 psi off bottom P Vp = 420 bbl's 05:30 - 07:00 1.50 DRILL N DPRB PROD2 Wiper trip to window & to TD. Ratty through 11480 to 11650 w/ ~, weight bobbles in this section. 07:00 - 09:30 2.50 DRILL N DPRB PROD2 Drill lateral from 12348' TL at 60L HS Op = 1.54 / 0.76 bpm at 3060 psi w/1 k-1.5k DHWOB 1.3k surface Vp = 292 bbl's ROP 30-50 fph BHP = 3480 psi at ECD of 11.44 ppg Occasionally PU for BHA wiper to ensure proper hole cleaning. Drill to 12443'. 09:30 - 10:35 1.08 DRILL N DPRB PROD2 Wiper to window -clean & few weight bobbles. Loss zone is at 11475'-11550' 10:35 - 11:15 0.67 DRILL N DPRB PROD2 Wiper to TD -clean & no set downs or motor work. Printed: 3/12/2008 11:46:54 AM r • BP AMERICA Page 23 of 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name: 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To I ;Hours Task .Code NPT Phase 2/23/2008 11:15 - 13:00 1.75 DRILL N DPRB PROD2 13:00 - 14:50 1.83 DRILL N DPRB PROD2 14:50 - 15:05 0.25 DRILL N DPRB PROD2 15:05 - 15:10 0.08 DRILL N DPRB PROD2 15:10 - 15:55 0.75 DRILL N DPRB PROD2 15:55 - 17:30 1.58 DRILL N DPRB PROD2 17:30 - 19:26 1.93 DRILL N DPRB PROD2 19:26 - 21:33 2.12 DRILL N DPRB PROD2 21:33 - 23:40 2.12 DRILL N DPRB PROD2 23:40 - 00:00 0.33 DRILL N DPRB PROD2 2/24/2008 00:00 - 01:30 1.50 DRILL N DPRB PROD2 01:30 - 02:50 1.33 DRILL N DPRB PROD2 02:50 - 03:45 0.92 DRILL N DPRB PROD2 03:45 - 05:10 1.42 DRILL N DPRB PROD2 05:10 - 07:10 2.00 DRILL N DPRB PROD2 07:10 - 09:10 2.00 DRILL N DPRB PROD2 09:10 - 11:40 2.50 DRILL N DPRB PROD2 11:40 - 12:30 0.83 DRILL N DPRB PROD2 12:30 - 12:35 I 0.081 DRILL I N I DPRB I PROD2 Description of Operations Drill lateral from 12443' TL at 60L HS Op = 1.55 / 0.77 bpm at 3010 psi w/1 k-1.5k DHWOB -1 k surface Vp = 389 bbl's ROP 30-50 fph BHP = 3497 psi at ECD of 11.43 ppg Pump 20 bbl to-vis pill down hole to help clean the hole. Drill to 12522ft. 28k up WT. Chase pill OOH. Wiper to window. Open EDC &PUH to 10500' RIH. Log down for tie-in (+11'). Close EDC. Wiper to TD. Clean. Tag bottom. Drill lateral from 12525' TL at 120R HS Op = 1.48 / 0.82 bpm at 3010 psi w/1 k-1.5k DHWOB -1.5k surface Vp = 232 bbl's ROP 30-80 fph BHP = 3467 psi at ECD of 11.41 ppg Drill to 12625'. Clean PU 24k up wt. Wiper to window. Clean trip out. RIH Drill lateral from 12625' TL at 90L HS Op = 1.54 / 0.76 bpm at 3030 psi DHWOB 1.5 to 0.75k1b and 1.3k surface Vp = 292 bb!'s ROP 30-100 fph BHP = 3495 psi at ECD of 11.50 ppg Wiper trip after drilling 100 ft formation Drill lateral from 12725' TL at 110E HS Op = 1.56 / 0.80 bpm at 3030 psi DHWOB 1.5 to 0.75k1b and 1.3k surface Vp = 433 bbl's ROP 30-100 fph BHP = 3510 psi at ECD of 11.54 ppg Drilling Lateral L2-01 PUH for wiper trip at 12,821 ft Tied in and corrected +11' RIH and tagged bottom at 12,828 ft Drilling lateral TF at 60LHS Op = 1.61 / 0.87 bpm at 3155 psi off bottom pressure WOP = 2-1 klb, ROP = 40 to 100 fph BHP = 3549 psi 11.66 ppg ECD Pulled tight at 12,903 ft (39k over to get free) Wiper trip to window -clean. W iper to TD -clean. swap well to 50/50 2%KCL/Flo-Pro into the pits. Drilling lateral from 12895' TF at 140LHS w/ 50/50 Op = 1.80 / 1.21 bpm at 2900 psi off bottom pressure DHWOB = 2-1 klb, Surface Wt = 0 Ibs, ROP = 40 to 100 fph BHP = 3370 psi, 11.08 ppg ECD Pump 2 10bb1 100% Flo-Pro pills to help clean the hole. Drill to 12980'. Chase pills OOH & wiper to window -clean. Wiper to TD. Drilling lateral from 12977' TF at 75LHS w/ 50/50 Op = 1.80 / 1.24 bpm at 2990 psi off bottom pressure DHWOB = 2-1 klb, Surface Wt = 600 Ibs, ROP = 30 to 60 fph BHP = 3430 psi, 11.21 ppg ECD Pump 10bb1 Flo-pro pill to help in sliding. Drill to 13002' Stacking out & not drilling. 100' wiper -clean. Wiper to TD -clean. Printed: 3/12/2008 11:46:54 AM ` i i BP AMERICA Page 24 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: D T ~ H d C ti D i f O i ate From - o „ ours Task o e NPT i I pera escr pt on o ons Phase 2/24/2008 12:35 - 14:40 2.08 DRILL N DPRB PROD2 Drilling lateral from 13002' TF at 70LHS w/ 50/50 Op = 1.80 / 1.18 bpm at 2990 psi off bottom pressure DHWOB = 2-1 klb, Surface Wt = 600 Ibs, ROP = 30 to 60 fph BHP = 3430 psi, 11.21 ppg ECD Hard drilling @ 13045'. Pump 20 bbl 100% Flo-Pro pill. Drill to 13070' 14:40 - 16:25 1.75 DRILL P PROD2 Chase 20 bbl pill OOH. Wiper to window -clean. 16:25 - 16:40 0.25 DRILL P PROD2 Log for tie-in (+18' corr. 16:40 - 20:39 3.98 DRILL P PROD2 Wiper to TD. 1.5bpm @ 2400psi. Start pumping 100k LSRV liner pill w/ 2ppb Alpine beads while RIH. Tag bottom ~ 13084'. La in liner ill. 20:39 - 21:40 1.02 DRILL P PROD2 LD drilling BHA, Held PJSM on PU and handling liner 21:40 - 00:00 2.33 CASE P LNR3 Run 2-3/8" liner as per summary 2/25/2008 00:00 - 01:10 1.17 CASE P LNR3 Run 2-3/8" Liner as aer aroaramme. Spaced out liner 50' short PU BHI CoilTrac 01:10 - 03:39 2.48 CASE P LNR3 RIH with liner and Coiltrac Up Wt at 11,300 ft = 24.7k1b Logged GR Marker and corrected -11 ft. Set bottom of liner at 13,035 ft and the top of the liners at 11 313 ft 03:39 - 03:43 0.07 CASE P LNR3 Release from liner 03:43 - 05:45 2.03 CASE P LNR3 POOH. PJSM regarding handling BHA while POH. 05:45 - 07:00 1.25 CASE P LNR3 Flow check. Pop off well. Unstab coil from BHI tools. Place injector over bung hole. Blow down & LD BHI tools on catwalk. Liner is missing! 07:00 - 07:35 0.58 FISH P POST PJSM regarding PU fishing BHA. PU J-hook, jars, 1 drill collar, acre erator use oc -fife on each connection, scribe same. PU BHI BHA & MU to fishing BHA, scribe same. PU injector & stab onto BHI tools. Stab onto well. Set counters. 07:35 - 10:00 2.42 FISH P POST RIH w/fishing BHA. Circ at min rate. Pump 10 bbls of 75k LSRV pill to help clean top of the whipstock tray. WT ck ~ 11100' = 22k, RIW = 5.8k 10:00 - 11:00 1.00 FISH P POST log down for tie-in (-11') from 11250'. Replace 4 safety reel plate bolts inside reel. WT ck = 24k up w/out pumping. 11:00 - 15:50 4.83 FISH P POST Orientate hook &RIH. Set down ~ 11314' & set 3k down. PU clean. Orientate 180 degrees out. RIH & set down at 113 6 & set 3k down. PU & slipped off. RIH & fry to latch. Slipped off. Turn to 55 degrees. Set down & latch up ~ 11302'. PU & try to straight pull. Jars went off, continue to PU to 16K DHWOB (49k surface). Fish on. Continue to PU slowly ~ 20'/imn & break circulation @ 1bpm. Up WT=26.8k. Swabbing is occurring. Overpull at 11035', still swabbing. Keep PUH ~ 15'/min. Weight bobbles at 10968'-Liner mule shoe, 10938'-Packer, 10900'-W nipple. Plant whipstock in W nipple. Try to cock jars. Popped free. Continue to POH, still swabbing. Circ through coil to fill hole while POH @ 60'/min. 15:50 - 17:00 1.17 FISH P POST Stop at 150'. Flow check well. PJSM regarding handling BHA. Pop off well. Slowly POH & inspect coil connector. Break off BHI tools & LD on catwalk, blow down same & replace Gamma Ray & test same. Pull rest of fishing BHA from well. LD whipstock -recovered all rubber elements & slip segments. PU J-hook, jars, drill collar & accelerator. Scribe same. PU BHI Printed: 3/12/2008 11:46:54 AM BP AMERICA Page 25 of 25 Operations Summary Report Legal Well Name: 1 L-28 Common Well Name:. 1 L-28 Spud Date: 2/20/2000 Event Name: REENTER+COMPLETE Start: 1/15/2008 End: Contractor Name: NORDIC CALISTA Rig Release: Rig Name: NORDIC 2 Rig Number: Date From - To Hours Task I Code NPT I Phase Description of Operations 2/25/2008 15:50 - 17:00 1.17 FISH P POST 17:00 - 19:00 2.00 FISH P POST 19:00 - 19:25 0.42 FISH P POST 19:25 - 22:22 I 2.95 I FISH I P I I POST 22:22 - 22:50 0.47 FISH P POST 22:50 - 23:20 0.50 FISH P POST 23:20 - 00:00 0.67 FISH P POST 2/26/2008 00:00 - 01:30 1.50 WHSUR P POST 01:30 - 03:30 2.00 WHSUR P POST 03:30 - 05:00 1.50 WHSUR P POST 05:00 - 06:00 1.00 WHSUR P POST 06:00 - 18:00 I 12.00 I RIGD I P I I POST BHA & MU to fishing BHA. Stab coil onto BHA. Stab onto well. Test tools. Set counters. RIH w/fishing BHA. Circ at min rate. Logged tiein at 11,250 ft. Corrected -14 ft, Wt check at 22k up Set jars at 11,315 ft and jarred 5 times at 40k and 1 time at 45k Came lose, PUH POOH at 50 to 60 fph watching the hole for swabbing. Held PJSM on handling whipstock BHA LD Fish and fishing BHA LD fishing BHA and remove RA tag from WS. Load out BOT tools and fill hole. PU nozzle, extension and UOC RIH to turn hole over to seawater RIH to turn hole over to seawater POOH chasing flo-pro out of welt. Stopped at 2000 ft Working to get diesel out of vac truck, Pumped 35 bbl diesel and displaced and POOH chasing diesel to surface Close master & swab. Start circulating cuttings box & super suck it out. Start circulating tiger tank & vac it out. Pop off well. Blow down BOP stack via new pressure hose to wing valve. Install night cap & check for pressure - Opsi. T bar in BPV. Close master & swab. Spot, RU & cool down nitrogen unit. Blow down reel. Opebn doors on 7-1/16" BOP and inspected ram blocks and cavity. OK Closed up and NW same. Installed tree cap and PT to 5000 psi. Rig Released at 18:00 hrs 2/26/2008 Printed: 3/12/2008 11:46:54 AM • i by BP Alaska $ Baker Hughes INTEQ Survey Report iNTE Q Companyss ConocoPhillips AlaskaJnc. Date: 2/27/2008 Time: 11:27;53 Page:. 1 `Field: Kuparuk River Unit Co-ordinate(NE) Reference: - Well:1 L-28, True North - Site: Kuparuk i L Pad Vertical (TVD) Reference: i L-28: 119.9 Well: 1 L-28' Section (VS) Reference: Well {O.OON,O.OOE,75:48Azi) Wellpath; ' i L-28L2-01 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 Datmn: NAD27 (Clarke 1866) Coordinate System: Well Centre Sys Datum: Mean Sea Level Geomagnetic Model: bggm2007 Site: Kuparuk 1L Pad Site Position: Northing: 5949190.90 ft Latitude: 70 16 19.650 N From: Map Easting: 539916.78 ft Longitude: 149 40 37.763 W Position Uncertainty: 0.00 ft North Reference: True Ground Level: 0.00 ft Grid Convergence: 0.30 deg 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-28L2-01 Drilled From: 1 L-28L2 50029229516200 Tie-on Depth: 12100.85 ft Current Datmn: 1 L-28: Height 119.90 ft Above System Datum: Mean Sea Level Magnetic Data: 2/21 /2008 Declination: 22.87 deg Field Strength: 57624 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 75.48 Survey Program for Definitive Wellpath Date: 2/21/2008 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 12100.85 MWD(11301.00-13150.00)(2) MWD MWD-Standard 12118.49 13084.00 MWD (12118.49-13084.00) MWD MWD -Standard Amotation MD TVD ft ft 12100.85 5989.02 TIP / KOP 13084.00 6031.36 TD Survey: MWD Start Date: 2/27/2008 Company: Baker Hughes INTEQ Engineer: Tool: MWD;MWD -Standard Tied-to: From: Definitive Path Survey MD Incl Azim TVD Sys TVD N/S E/W Map1Y MapE VS 1)LS Tooi ft deg .deg ft ft ft ft ft ft ft deg/100ft 12100.85 92.93 204.20 5989.02 5869.12 2975.94 8053.55 5952078.18 548315.00 8542.43 0.00 MWD 12118.49 88.74 206.91 5988.77 5868.87 2960.04 8045.94 5952062.23 548307.48 8531.08 28.29 MWD 12132.65 89.20 209.94 5989.02 5869.12 2947.59 8039.21 5952049.75 548300.81 8521.44 21.64 MWD 12161.64 90.43 216.52 5989.11 5869.21 2923.35 8023.33 5952025.43 548285.06 8499.99 23.09 MWD 12193.51 90.95 217.79 5988.73 5868.83 2897.95 8004.08 5951999.93 548265.95 8474.99 4.31 MWD 12224.07 91.57 213.87 5988.06 5868.16 2873.19 7986.20 5951975.07 548248.21 8451.47 12.98 MWD 12259.22 91.72 206.67 5987.05 5867.15 2842.86 7968.50 5951944.66 548230.67 8426.73 20.48 MWD 12287.86 93.84 202.13 5985.66 5865.76 2816.82 7956.69 5951918.55 548219.00 8408.77 17.48 MWD 12312.93 94.73 199.14 5983.79 5863.89 2793.43 7947.88 5951895.11 548210.31 8394.38 12.41 MWD 12341.63 94.76 195.22 5981.41 5861.51 2766.11 7939.43 5951867.75 548202.01 8379.35 13.61 MWD 12370.87 94.11 189.95 5979.15 5859.25 2737.66 7933.08 5951839.28 548195.82 8366.07 18.11 MWD • • by BP Alaska S Baker Hughes INTEQ Survey Report ><NTE Q Company: ConocoPhillips Alaska lnc. Date: 2/27/2008 Time: 11:27:53 Page: 2 Field: Kuparuk River Unit Co-ordinate(NE) Reference: Well: 1 L-28, True North Site: Kuparuk 1 L Pad Vertical (TVl)) Reference: YL-28: 119.9 Well: 1 L-28 Section (VS) Reference: Well (O.OON,O. OOE,75,48 Azi) Wellpath: i L-28L2-01 Survey Calculation Method: ..Minimum Curvature Db: Sybase Survey MD Incl Azim TVD Sys TVD N/S E/W MapN MapE VS DLS Tooi ft deg deg ft ft ft ft ft ft ft deg/100ft 12401.80 94.42 186.76 5976.85 5856.95 2707.15 7928.60 5951808.75 548191.50 8354.08 10.33 MWD 12435.29 93.81 180.98 5974.44 5854.54 2673.84 7926.35 5951775.43 548189.43 8343.55 17.31 MWD 12466.29 93.50 185.66 5972.46 5852.56 2642.96 7924.56 5951744.54 548187.80 8334.08 15.10 MWD 12499.97 93.53 189.10 5970.40 5850.50 2609.63 7920.24 5951711.19 548183.66 8321.54 10.19 MWD 12523.45 91.04 192.37 5969.46 5849.56 2586.58 7915.87 5951688.12 548179.42 8311.53 17.50 MWD 12552.84 90.15 197.17 5969.16 5849.26 2558.17 7908.38 5951659.68 548172.08 8297.16 16.61 MWD 12579.19 89.69 195.38 5969.19 5849.29 2532.88 7900.99 5951634.35 548164.83 8283.67 7.01 MWD 12610.43 87.72 189.74 5969.90 5850.00 2502.41 7894.20 5951603.85 548158.21 8269.46 19.12 MWD 12639.79 88.10 183.61 5970.97 5851.07 2473.28 7890.80 5951574.70 548154.95 8258.86 20.90 MWD 12668.36 89.14 t 78.84 5971.66 5851.76 2444.74 7890.19 5951546.16 548154.50 8251.11 17.08 M W D 12695.53 88.37 174.04 5972.25 5852.35 2417.63 7891.87 5951519.06 548156.33 8245.95 17.89 MWD 12722.94 86.81 170.35 5973.40 5853.50 2390.51 7895.59 5951491.96 548160.19 8242.74 14.60 MWD 12754.16 85.70 165.85 5975.44 5855.54 2360.03 7902.01 5951461.52 548166.77 8241.32 14.82 MWD 12784.17 86.22 161.76 5977.56 5857.66 2331.29 7910.36 5951432.83 548175.27 8242.20 13.70 MWD 12818.04 85.24 158.05 5980.08 5860.18 2299.58 7921.96 5951401.18 548187.04 8245.48 11.30 MWD 12849.55 85.92 154.46 5982.51 5862.61 2270.82 7934.61 5951372.50 548199.84 8250.51 11.56 MWD 12878.32 85.24 148.47 5984.73 5864.83 2245.64 7948.30 5951347.39 548213.67 8257.46 20.89 MWD 12908.07 82.28 145.71 5987.96 5868.06 2220.81 7964.37 5951322.65 548229.87 8266.78 13.57 MWD 12942.16 76.63 145.71 5994.20 5874.30 2193.13 7983.24 5951295.08 548248.89 8278.11 16.57 MWD 12975.42 73.67 142.30 6002.73 5882.83 2167.13 8002.13 5951269.18 548267.91 8289.88 13.32 MWD 13001.25 74.34 138.85 6009.85 5889.95 2147.95 8017.89 5951250.09 548283.78 8300.33 13.10 MWD 13031.89 75.07 134.80 6017.93 5898.03 2126.40 8038.11 5951228.65 548304.11 8314.50 12.97 MWD • 13084.00 75.07 134.80 6031.36 5911.46 2090.93 8073.84 5951193.37 ~ 548340.02 ~ 8340.19 0.00 MWD KRU 1 L-28 Producer with L1, L2, & L2-01 Laterals 3'/z" .Camco DS nipple, 2.813" min ID at 553' MD Note: Nipple milled out to 2.83" ID on 12/23/07 3'/z' 9.3# L-80 EUE 8rd Tubing 96/•" 40# L-80 @ 6546' MD 7" 26# L-80 @ 11,117 MI L2 KOP 11,300' MD C4 Perfs 11295'-11320' L1 KOP 11,315' MD C3/C4 Perfs - 11334'-11364' A-5 sand Perfs 11518' - 11538' ConocoPhilli s p Alaska, Inc. 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'/Z' Camco W nipple, 2.813" min ID @ 10,912' MD 1 L-28L2 Lateral, TD @ 13,150' MD 3'/i' tubing muleshoe @10976' MD ~~ 2'/." slotted liner: 11,313' - 13,035' MD /~ solid 'nts: 11,347' -11,817' ~ 2'/." slotted liner: 11,324' -13,150' MD solid jots: 11,377' -11,884' interface between liner segments at 12,387' MD KB packers at 11,325 & 11,359 MD • Packer ID = 1.81" • 1.71" RR plug in tailpipe of lowest packer ~ Stuck WRP 11,400' MD (10/8/06) liner 10944' - 11,769' MD 1L-28L2-01 Lateral, TD @ 13,084' MD 1L-28L1 Lateral, TD Ir~ 13,150' MD Updated: 2-28-08 i r~'r~ BAKER HUGHES 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 1 L-28L2-01. Enclosed is: lea 3.5" floppy diskette containing electronic survey file Cc: State of Alaska, AOGCC Christine Mahnken aog- o~g • • Page 1 of 1 Maunder, Thomas E (DOA) From: Eller, J Gary [J.Gary.Eller@conocophillips.com] Sent: Wednesday, February 27, 2008 4:53 PM To: Maunder, Thomas E (DOA) Subject: FW: PTD for 1L-28 L2-01 Lateral Attachments: 1L-2$ L2-01 proposed completion 2-20-08.pdf Tom -Below is a quick note that I sent to Terrie Hubble on Wednesday, February 20 asking her to begin working on a PTD for 1 L-28 L2-01. I had talked to you earlier that day, but I did not follow up with an a-mail to you. In the future I will be sure to send you and a-mail letting you know what we're doing. -Gary Eller CPAI Wells CTD Engineer From: Eller, 7 Gary Sent: Wednesday, February 20, 2008 10:25 AM To: 'Hubble, Terrie L' Subject: 17TD for 1L-28 L2-01 Lateral Terrie -Attached is a proposed wellbore schematic diagram for the L2-01 lateral in 1 L-28 at Kuparuk. We expect to begin sidetracking operations today. I'll get you a directional program today to accompany the drilling permit. In speaking to Tom Maunder, it didn't sound like he'd need much more than this schematic, the directional plan, and a cover letter describing what we're doing to approve the permit. Please let me know if you think I need to provide more info than what is provided below. The 1 L-28L2 lateral could not be drilled to the planned TD of 13,700' MD due to hole instability at 12,850' MD. The L2 lateral was instead TD'd at 13,150' MD. A 2-3/8" slotted liner was run in the L2 lateral from 12853' - 12135' MD. We propose to drill another lateral, L2-01, from 12,135' to 13,100' MD in the Kuparuk C-sand. Geologic objectives remain the same as for the L2 lateral, and the same BOP test pressure of 3500 psi should be used. 7. Gary Eller Wells Engineer ConocoPhillips -Alaska work: 907-263-4172 cell: 907-529-1979 fax: 907-265-1535 2/27/2008 • • ~-~ a` ( SARAH PALIN GOVERN .. ~, OR O~W ~`~ ~ 333 W. 7th AVENUE, SUITE 100 CO1~T3L''RQA'1'IOIQ COrII-IISSI011T ANCHORAGE, ALASKA 99501-3539 Gary Eller PHONE (907} 279-1433 Drilling Engineer FAX (907) 276-7542 C/o BP Exploration Alaska, Inc. PO Box 196612 Anchorage, Alaska 99519-6612 Re: Kuparuk River Unit Field, Kuparuk River Pool, Kuparuk 1 L-28L2-01 Permit No: 208-029 Surface Location: 89' FSL, 216' FWL, SEC. 29, T11N, R10E, UM Bottomhole Location: 2155 FSL, 3116' FWL, SEC. 28, T11N, R10E, 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. While drilling 1L-28L2 (207-154), hole stability problems were encountered that resulted loss of the end portion of that lateral. You contacted Tom Maunder, PE on the morning of February 20 and advised him of the matter. It is acknowledged that. operations drilling operations were not interrupted as allowed by 20 AAC 25.005 (a). This permit to drill does not exempt you from obtaining additional permits or an approval required by law from other governmental agencies and does not authorize conducting drilling operations until all other required permits and approvals have been issued. In addition, the Commission reserves the right to withdraw the permit in the event it was erroneously issued. Operations must be conducted in accordance with AS 31.05 and Title 20, Chapter 25 of the Alaska Administrative Code unless the Commission specifically authorizes a variance. Failure to comply with an applicable provision of AS 31.05, Title 20, Chapter 25 of the Alaska Administrative Code, or a Commission order, or the terms and conditions of this permit may result in the revocation or suspension of the permit. When providing notice for a representative of the Commission to witness any required test, contact the Commission's petroleum field inspector at (907) 659-3607 (pager). incer Dani . Seamount, Jr. Chair DATED this day of February, 2008 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. ~~~~~~ STATE OF ALASKA ALASK~L AND GAS CONSERVATION COMMIS~I ~~I"~ -~"` ~'+ r'(~-3~ PERMIT TO DRILL 20 AAC 25.005 ~ ~~~1 ~,~~~~~ Vii! ,~x ~~ Y ~. 'v' ... sr~;~&i~0 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 rsl ~r' ~ ed for: ^ Coalbed Methane ^ Gas Hydrates ^ Shale Gas 2. Operator Name: Conoco Phillips Alaska Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 59-52-180 11. Well Name and Number: Kuparuk 1 L-28L2-01 • 3. Address: c/o P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 13100 , TVD 5911 ss • 12. Field /Pool(s): Kuparuk River Unit /Kuparuk 4a. Location of Well (Governmental Section): Surface: 89' FSL 216' FWL SEC 29 T11 N UM ' R10E 7. Property Designation: ADL 025660 ' River Pool , , , . , , Top of Productive Horizon: 3682' FSL, 3163' FWL, SEC. 27, T11 N, R10E, UM 8. Land Use Permit: 13. Approximate Spud Date: February 20, 2008 ' Total Depth: 2155' FSL, 3116' 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): 51.49 feet 15. Distance to Nearest Well Within Pool: 691' 16. Deviated Wells: Kickoff Depth: 12135 'feet Maximum Hole An le: 94 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035) Downhole: 3507 Surface: 2887 18: Casin Pro ram: S e ifroatio ns - To '- 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 1795' 11305' 5831' 13100' 5911' Uncemented Slotted Liner lg. PRESE NT WELL CONDITION SUMMARY (To be completed for Redrill and Reentry Operations) Total Depth MD (ft): 13150' Total Depth TVD (ft): 5839' Plugs (measured): None Effective Depth MD (ft): 13150' Effective Depth TVD (ft): 5839' Junk (measured): None 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' Pr d tion Liner 825' 3-1 /2" 255 sx Class 'G' 10944' - 11769' 5658' - 6378' Liner L1 1830' 2-3/8" Uncemented Slotted Liner 11320' - 13150' 5849' - 5944' Lin r L 718' 2-3/8" Uncemented Slotted Liner 12135' - 12853' Perforation Depth MD (ft): (1 L-28) 11295' - 11538' Perforation Depth TVD (ft): 5947' - 6166' 20. Attachments ^ Filing Fee, $100 ®BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Ap oval: Commis ion Representative: Date: 22. I hereby c that the foreg i g is true and correct. Contact Gary Eller, 529-1979 Printed Na Gary Eller Title CT Drilling Engineer Prepared By Name/Number: Si nature Phone 263-4172 Date ~ ~ Terrie Hubble, 564-4628 :Commission Use Onl Permit To Drill Number: ~$~dZ`~ I Number: 50-029-22951-62-00 PermitRpp q~ri~ 7y ~ Date: oL o~ V See cover letter for otherr uirements Conditions of Approval: If box is checked, well may not be used to explore for, test, or produce coalbed me_th/ane, gas hydrates, or gas contained shales: Samples Req'd: ^ Yes L-~ No Mud Log Req'd: ^ Yes ~No q°~ ( HZS Measures: Q~Yes ^ No Directional Survey Req'd: [Yes ^ No Other: ~~~~ ~~ ~ ~~~~ ~ ~S`C. f~ APPROVED BY THE COMMISSION O Date ,COMMISSIONER Form 10-401 Revised 12/2005 r O R I G I N A L ~~~~~/_ _/~,bm~ Duplicate m GIST/ 2. 2?~ ~~ by , ~ BP Exploration (Alaska) Inc. 900 East Benson Boulevard P.O. Box 196612 Anchorage, Alaska 99579-6612 (9071567-5711 February 22, 2008 Alaska Oil and Gas Convervation Commision 333 W. 7th Avenue, Suite 100 Anchorage, Alaska 99501-3539 Dear Sus: Enclosed is a Permit to Drill for well 1L-28L2-01 in the Kupanak River Unit. The 1L-28L2 lateral (# 207-154) could not be drilled to the planned TD of 13.700' NID due to hole instability at 12,850' MD. The L2 lateral was instead TD'd at 13,150' NID. A 2-3/8" slotted liner was run in the L2 lateral from 12,853' to 12,135' MD. This L2-01 lateral will ~` also be drilled in the Kuparuk C Sand from 12,135' to 13,100' MD. Geologic objectives remain the same as for the L2 lateral, and the same BOP test pressure of 3500 psi should be us d. ~. J. ~ ~ Eller Cono hillips Alas KRU 1 L-28 Producer with L1 & L2 Laterals Proposed L2-01 CTD Lateral 3'/" .Camco DS nipple, 2.813" min ID at 553' MD Nipple milled out to 2.83" ID on 12123/07 3'/:" 9.3# L-80 EUE 8rd Tubing Conoco hilli s p Alaska, Inc. 3'/z" Camco MMM GLMs @ 4258', 7197', 9051', 10316', & 10836' MD 9`/." 40# L-80 ~ 6546' MD 7" 26# L-80 ~ 11,117' MD L2 KOP 11,300' MD C4 Perfs 11295'-11320' L1 KOP 11,315' MD 1L-28L2 Lateral, TD ~ 13,150' MD 2-3/8" slotted liner run to 12,853' MD 2'/," liner top @ //~~ ,+/-11,305' MD 3'/Z' Retrievable ~ ~ Baker ZXP Packer w/SBE @ 10,944' MD 3'/z' Camco W nipple, 2.813" min ID crvD 10,912' MD 3'/Z' tubing muleshoe cLD10976' MD whipstocks 2'/." liner top @ 11,319' MD 3" openhole C3/C4 Perfs 11334'-11364' KB packers at 11,309', 11,325, & 11,359 MD .Packer ID =1.81" • 1.71" RR plug in tailpipe of lowest packer Stuck WRP 11,400' MD (10/8/06) A-5 sand perfs 11518' - 11538' 3'/Z' 9.3# L-80 liner 10944' - 11,769' MD / ~ Aluminum bUlet at 12,135 MD 1L-28L2-01 Lateral, TD @ 13,100' MD '~ 1L-28L1 Lateral, TD C~ 13,150' MD Updated: 2-20-08 KR•U 1 L-28 Dual Laterals -Coiled Tub~g 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-lA, MIT-OA. 4. Slickline tag fill and drift 311/2" 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 31/2" liner and tubing. 8. E-line set 31/2" 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 window at 11 315' MD 3. 1L-28L2 Lateral a. Pull the whipstock tray at 11,315' MD, leaving the anchor in place. R1H 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'fo the south with a 2.70" x 3" bi-center bit to 13,700' TD. _ d. Complete the L2 lateral with 23/8" slotted liner. The top of the liner will be just outside the window at 11,300' MD. 4. Pull whipstock trays but not anchor assembly to allow future re-entry into laterals 5. Freeze protect. ND BOPE. RDMO Nordic 2. Post-Rig Work 1. Obtain static BHP 2. Produce well to sales. Mud Program: • Will use chloride-based Biozan brine (8.6 ppg) for milling operations, and chloride-based Flo-Pro mud (8.6 ppg) for drilling operations. Since there is no SCSSV installed in 1L-28, the well will have to be killed prior to running 23/8" slotted liner. Page 1 of 3 October 18, 2007, FINAL KRU 1 L-28 Dual Laterals -Coiled Tung 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: 2%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: 311/z", 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. f 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 i KRU 1 L-28 Dual Laterals -Coiled Tung 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 BOPS 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/s" 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 2'/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 by BP Alaska s Baker Hughes INTEQ Planning Report 1NTE Q Company: ConocoPhillips Alaska Inc. Date: 2/21/2008 Time: '16:03:55 Page: I Field: Kuparuk River Unit Co-ordinate(NE) Reference:. Welli i L-28, True North Site: Kuparuk 1 L Pad Vertical (TVIJ) Reference: 1 L-28:.119.9 Well: iL-28 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: Plan 2, 1 L-28L2-01 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: 5949190.90 ft Latitude: 70 16 19.650 N From: Map Easting : 539916.78 ft Longitude: 149 40 37.763 W Position Uncertainty: 0.00 ft North Reference: True ` Ground Level: 0.00 ft Grid Convergence: 0.30 deg 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: Plan 2, i L-28L2-01 f Drilled From: 1 L-28L2 Tie-on Depth: 12100.85 ft Current Datum: 1 L-28: Height 119.90 ft Above System Datum: Mean Sea Level Magnetic Data: 2/21 /2008 Declination: 22.87 deg Field Strength: 57624 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 0.00 180.00 Plan: Plan #2 Date Composed: 2/21/2008 Version: 1 Principal: Yes Tied-to: From: Definitive Path Targets Map Map <---- Latitude ----> <--- Longitude----> Name Description TVD +N/-S +E/- W Northing Easting Deg Min Sec Deg Min Sec Dip. Dir. Annotation MD TVD ft ft 12100.85 5989.02 TIP 13100.00 6030.46 TD Plan Section Information MD Incl Azim TVD +N/S +E/-W DLS Build Turn TFO Target ft deg deg ft ft ft deg/100ft deg/1OOft deg/100ft deg 12100.85 92.93 204.20 5989.02 2975.94 8053.55 0.00 0.00 0.00 0.00 12110.00 90.00 206.00 5988.79 2967.66 8049.67 37.58 -32.02 19.67 148.42 12120.00 89.00 209.50 5988.88 2958.81 8045.02 36.40 -10.00 35.00 105.96 12130.00 92.25 211.00 5988.77 2950.18 8039.98 35.79 32.50 15.00 24.77 12160.00 94.00 215.00 5987.13 2925.06 8023.67 14.53 5.83 13.33 66.24 12180.00 94.00 218.00 5985.74 2909.02 8011.80 14.96 0.00 15.00 89.90 12260.00 94.00 206.00 5980.14 2841.47 7969.59 14.96 0.00 -15.00 270.42 12310.00 94.00 198.50 5976.64 2795.34 7950.72 14.96 0.00 -15.00 270.26 12360.00 94.00 191.00 5973.15 2747.14 7938.03 14.96 0.00 -15.00 270.26 12410.00 93.00 183.50 5970.09 2697.67 7931.74 15.10 -2.00 -15.00 262.63 12460.00 93.00 176.00 5967.47 2647.77 7931.95 14.98 0.00 -15.00 270.20 12510.00 92.00 168.50 5965.29 2598.31 7938.69 15.12 -2.00 -15.00 262.57 12550.00 89.00 162.50 5964.94 2559.61 7948.70 16.77 -7.50 -15.00 243.48 12600.00 88.00 155.00 5966.25 2513.06 7966.80 15.13 -2.00 -15.00 262.32 12650.00 87.00 147.50 5968.43 2469.30 7990.81 15.12 -2.00 -15.00 262.25 by BP Alaska ~f~r Baker Hughes INTEQ Planning Report 1NTEQ Company: ConocoPhillips Alaska Inc. Dater 2/21/2008 Time: 16:03:55 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: 119.9 Wells 1 L-28 Section (VS) Reference: Well (O.OON,O.OOE,180.OOAzi) Wellpath: Pl an 2, 1 L-28L2-01 SurveyCalculation Method: Minimum Curvature Dh: Sybase Plan Section Information MD Incl Azim TVD +N/S +E/-W DLS Build Turn' TFO Target ft deg. . deg. ft ft ft deg/100ft deg/100ft deg/1OOft deg 12700.00 86.50 140.00 5971.27 2429.07 8020.30 15.01 -1.00 -15.00 265.97 12750.00 86.50 147.50 5974.33 2388.85 8049.79 14.97 0.00 15.00 90.23 12800.00 86.50 155.00 5977.39 2345.13 8073.78 14.97 0.00 15.00 90.23 12850.00 86.00 162.50 5980.66 2298.66 8091.85 15.00 -1.00 15.00 94.06 12900.00 84.00 170.00 5985.02 2250.32 8103.68 15.47 -4.00 15.00 1 05.29 12950.00 76.50 167.00 5993.49 2202.06 8113.49 16.12 -15.00 -6.00 201.28 13000.00 76.50 159.50 6005.18 2155.55 8127.49 14.58 0.00 -15.00 269.12 13050.00 75.00 152.00 6017.50 2111.39 8147.36 14.84 -3.00 -15.00 257.43 13100.00 75.00 144.50 6030.46 2070.36 8172.76 14.49 0.00 -15.00 269.03 Survey MD Incl Azim SS TVD N/S E/W MapN MapE DLS VS TFO , Too ft deg deg ft ft ft ft ft deg/1OOft ft deg 12100.85 92.93 204.20 5869.12 2975.94 8053.55 5952078.18 548315.00 0.00 -2975.94 0.00 MWD 12110.00 90.00 206.00 5868.89 2967.66 8049.67 5952069.87 548311.16 37.58 -2967.66 148.42 MWD 12120.00 89.00 209.50 5868.98 2958.81 8045.02 5952061.00 548306.56 36.40 -2958.81 105.96 MWD 12125.00 90.63 210.25 5868.99 2954.48 8042.53 5952056.65 548304.09 35.79 -2954.48 24.77 MW D 12130.00 92.25 211.00 5868.87 2950.18 8039.98 5952052.34 548301.57 35.79 -2950.18 24.77 MW D 12150.00 93.42 213.67 5867.88 2933.30 8029.30 5952035.41 548290.98 14.53 -2933.30 66.24 MWD 12160.00 94.00 215.00 5867.23 2925.06 8023.67 5952027.14 548285.39 14.53 -2925.06 66.37 MWD 12175.00 94.00 217.25 5866.19 2912.97 8014.85 5952015.01 548276.64 14.96 -2912.97 89.90 MWD 12180.00 94.00 218.00 5865.84 2909.02 8011.80 5952011.04 548273.61 14.96 -2909.02 90.05 MWD 12200.00 94.02 215.00 5864.44 2892.99 7999.94 5951994.94 548261.84 14.96 -2892.99 270.42 MWD 12225.00 94.02 211.25 5862.69 2872.11 7986.31 5951973.99 548248.32 14.96 -2872.11 270.21 MWD 12250.00 94.01 207.50 5860.93 2850.38 7974.08 5951952.20 548236.21 14.96 -2850.38 269.95 MWD 12260.00 94.00 206.00 5860.24 2841.47 7969.59 5951943.27 548231.77 14.96 -2841.47 269.68 MWD 12275.00 94.01 203.75 5859.19 2827.90 7963.30 5951929.66 548225.55 14.96 -2827.90 270.26 MWD 12300.00 94.01 200.00 5857.44 2804.76 7954.01 5951906.48 548216.38 14.96 -2804.76 270.10 MWD 12310.00 94.00 198.50 5856.74 2795.34 7950.72 5951897.04 548213.14 14.96 -2795.34 269.84 MWD 12325.00 94.01 196.25 5855.70 2781.06 7946.25 5951882.74 548208.75 14.96 -2781.06 270.26 MWD 12350.00 94.01 192.50 5853.95 2756.91 7940.06 5951858.56 548202.69 14.96 -2756.91 270.10 MWD 12360.00 94.00 191.00 5853.25 2747.14 7938.03 5951848.78 548200.71 14.96 -2747.14 269.84 MWD 12375.00 93.71 188.75 5852.24 2732.40 7935.46 5951834.02 548198.23 15.10 -2732.40 262.63 MWD 12400.00 93.20 185.00 5850.73 2707.63 7932.48 5951809.24 548195.37 15.10 -2707.62 262.48 MWD 12410.00 93.00 183.50 5850.19 2697.67 7931.74 5951799.28 548194.69 15.10 -2697.67 262.25 MW D 12425.00 93.01 181.25 5849.41 2682.70 7931.12 5951784.31 548194.15 14.98 -2682.70 270.20 MW D 12450.00 93.00 177.50 5848.10 2657.74 7931.39 5951759.36 548194.55 14.98 -2657.74 270.08 MWD 12460.00 93.00 176.00 5847.57 2647.77 7931.95 5951749.39 548195.17 14.98 -2647.77 269.88 MWD 12475.00 92.70 173.75 5846.83 2632.85 7933.29 5951734.48 548196.59 15.12 -2632.85 262.57 MWD 12500.00 92.20 170.00 5845.76 2608.13 7936.82 5951709.78 548200.25 15.12 -2608.13 262.46 MWD 12510.00 92.00 168.50 5845.39 2598.31 7938.69 5951699.97 548202.17 15.12 -2598.31 262.30 MWD 12525.00 90.88 166.25 5845.01 2583.68 7941.96 5951685.36 548205.52 16.77 -2583.68 243.48 MWD 12550.00 89.00 162.50 5845.04 2559.61 7948.70 5951661.33 548212.38 16.77 -2559.61 243.43 MWD 12575.00 88.50 158.75 5845.59 2536.04 7956.99 5951637.80 548220.80 15.13 -2536.04 262.32 MWD 12600.00 88.00 155.00 5846.35 2513.06 7966.80 5951614.88 548230.73 15.13 -2513.06 262.40 MWD 12625.00 87.49 151.25 5847.33 2490.78 7978.09 5951592.66 548242.14 15.12 -2490.78 262.25 MWD 12650.00 87.00 147.50 5848.53 2469.30 7990.81 5951571.25 548254.97 15.12 -2469.30 262.39 MWD 12675.00 86.74 143.75 5849.90 2448.70 8004.90 5951550.73 548269.17 15.01 -2448.70 265.97 MWD 12700.00 86.50 140.00 5851.37 2429.07 8020.30 5951531.18 548284.68 15.01 -2429.07 266.18 MW D 12725.00 86.49 143.75 5852.90 2409.44 8035.70 5951511.64 548300.19 14.97 -2409.44 90.23 MWD 12750.00 86.50 147.50 5854.43 2388.85 8049.79 5951491.13 548314.38 14.97 -2388.85 90.00 MWD 12775.00 86.49 151.25 5855.96 2367.38 8062.50 5951469.73 548327.20 14.97 -2367.38 90.23 MWD 12800.00 86.50 155.00 5857.49 2345.13 8073.78 5951447.54 548338.60 14.97 -2345.13 90.00 MWD 12825.00 86.24 158.75 5859.07 2322.19 8083.58 5951424.65 548348.52 15.00 -2322.19 94.06 MWD • • by BP Alaska $ Baker Hughes INTEQ Planning Report 1NTE Q Company: ConocoPhiltips Alaska Inc. Date: 2/21/2008: Time: 16:03:55 Page: 3 Field: Kuparuk River'Unit Co-ordinate(NE) Reference: Wellt i L-28, True Nor[h Site:. Kuparuk 1 L Pad Vertical (TVD) Reference: 1 L-28: 119.9 Well: 11-28 Section (VS) Reference: Well (O .OON,000E,180.OOAzi} Wellpath: .Plan 2, 1 L-28L2-01 Survey Calculation Method: . Minimu m Curvature Db: Sybase Survey MD Incl Azim SS TVD N1S E/4V MapN MapE I)LS VS TFO Too ft deg deg ft ft ft ft ft deg/100ft ft deg 12850.00 86.00 162.50 5860.76 2298.66 8091.85 5951401.17 548356.92 15.00 -2298.66 93.83 MWD 12875.00 84.99 166.24 5862.73 2274.66 8098.56 5951377.22 548363.76 15.47 -2274.66 105.29 MWD 12900.00 84.00 170.00 5865.12 2250.32 8103.68 5951352.90 548369.01 15.47 -2250.32 105.00 MWD 12925.00 80.25 168.52 5868.55 2225.99 8108.30 5951328.60 548373.75 16.12 -2225.99 201.28 MWD 12950.00 76.50 167.00 5873.59 2202.06 8113.49 5951304.71 548379.07 16.12 -2202.06 201.48 MWD 12975.00 76.47 163.25 5879.43 2178.58 8119.72 5951281.25 548385.43 14.58 -2178.58 269.12 MWD 13000.00 76.50 159.50 5885.28 2155.55 8127.49 5951258.27 548393.32 14.58 -2155.55 270.00 MWD 13025.00 75.72 155.76 5891.28 2133.11 8136.72 5951235.88 548402.67 14.84 -2133.11 257.43 MWD 13050.00 75.00 152.00 5897.60 2111.39 8147.36 5951214.23 548413.43 14.84 -2111.39 258.33 MWD 13075.00 74.97 148.25 5904.08 2090.46 8159.39 5951193.36 548425.56 14.49 -2090.46 269.03 MWD ' 13100.00 75.00 144.50 5910.56 2070.36 8172.76 5951173.33 548439.04 14.49 -2070.36 270.00 MWD r, ~uparuk Managed Pressure Dril~ BOP Configuration for 2" Coil Tubing KB Elevation Well ~ 1 L-28 ~ Rig Floor F 3" 5000 psi ~ ~1 I HCR - Choke Line C C Tree Size 3-1/8", 5M Lubricator ID = 6.375" with 6" Otis Unions 7 1/16" 5000 psi BOP's. ID = 7.06" ~'' 7 1/16" 5000 psi, RX-46 i~ f- 1/4 Tum LT Valve 7 1116" 5000 psi RX-46 ,~;.;~; HCR Kill Line ~2 1/16" 5000 psi , RX-24 j 7 1/16" 5000 psi (RX-46) or f- 4 1/16" 5000 psi (RX-39) Swab Valve ssv ... Master Valve -Base Flange Page 1 STATE OF ALASKA 11/13!07 O IL AND GAS CONSERVATION COMMISSION BOPE Test Report Submit to: Contractor: Nordic Rig No.: 2 DATE: 2/22/08 Rig Rep.: Holmes/Pederson Rig Phone: 659-4398 Rig Fax: 659-4356 Operator: BPX Op. Phone: 659-4393 Op. Fax: 659-4356 Rep.: GoodrichlSevcik E-Mail Well Name: Kuparuk 1 L-28L2-01 PTD # 207-154 Operation: Drlg: X Workover: Explor.: Test: Initial: Weekly: Bi-Weekly X Test Pressure: Rams: 250/3500 Annular: 250/35F}0 Valves: 250/3500 MISC. INSPECTIONS: TEST DATA FLOOR SAFETY VALVES: Test Result Test Result Quantity Test Result Location Gen.: P Weil Sign P Upper Kelly NA Housekeeping: P Dri. Rig P Lower Kelly NA PTD On Location P Hazard Sec. P Ball Type 2 P Standing Order Posted P Inside BOP NA BOP STACK: Quantity SizelType Test Result MUD SYSTEM: Visua! Alarm Stripper 1 2 3/8" P Trip Tank P P Annular Preventer 1 71116" 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 2 3/8" Combi P H2S Gas Detector P P #4 Rams 1 2" Combi P #5 Rams NA Quantity Test Result Choke Ln. Valves 1 3 1/8" P Insiciie Reel waives 1 P HCR Valves 2 31/8" P Kill Line Valves 1 3 118" P ACCUMULATOR SYSTEM: Check Valve 2 2 1/16" P Time/Pressure Test Result System Pressure 3000 P CHOKE MANIFOLD: Pressure After Closure 2400 P Quanti#y Test Resu!# 200 psi Attained 30 sec P No. Valves 14 P Full Pressure Attained 68 sec. P Manual Chokes 1 P Blind Switch Covers: All stations Yes Hydraulic Chokes 1 P Nitgn. Bottles (avg): 4 2100 Test Results Number of Failures: 0 Test Time: 5.5 Hours Components tested 31 Repair or replacement of equipment will t~ made within days. Notify the Nort h Slope Inspector 659-3607, follow wi#h written confirmation to Superviser at: Remarks: 24 HOUR NOTICE GIVEN YES )OC NO Waived By Chuck Sheve Date 2/21/08 Time 1800 Witness Ross / Daniell Test start 0515 Finish 1045 BOP Coil for Rigs BFL 11/13/07 Nordic 2 BOP 2-22-08.x1s ~ ~ TRANSMITTAL LETTER CHECKLIST WELL NAME 1 ~~(~ ~G '`~~- ~ ~'~ ` PTD# Z~~ -' ~ Z9 _ Development Service Exploratory Stratigraphic Test Non-Conventional Well FIELD• ~~~a.Yu,~- ~[~~Y POOL: ~ mac-- /~`~" ~ ar-~.c~. Circle Appropriate Letter /Paragraphs to be Included in Transmittal Letter CHECK ADD-ONS WHAT (OPTIONS) TEXT FOR APPROVAL LETTER APPLIES MULTI LATERAL The permit is for a new wellbore segment of existing well ~~~ ~~-'2~ , (If last two digits in permit No. AP[ No. 50-~- j-~. API number are _ between 60-69) Production should continue to be reported as a function of the original API number stated above. PILOT HOLE In accordance with 20 AAC 25.005(f), all records, data and logs acquired for the pilot hole must be clearly differentiated in both well name ( PH) and API number (50- - -_) from records, data and logs acquired for well SPACING The permit is approved subject to full compliance with 20 AAC EXCEPTION 25.055. Approval to perforate and produce /inject is contingent upon issuance of a conservation order approving a spacing exception. assumes the liability of any protest to the spacing exception that may occur. DRY DITCH All dry ditch sample sets submitted to the Commission must be in SAMPLE no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 10' sample intervals throu h tar et zones. Non-Conventional please note the following special condition of this permit: Well production or production testing of coal bed methane is not allowed for (name of welt) until after (Companv Name) has designed and implemented a water well testing program to provide baseline data on water quality and quantity. (Companv Name) must contact the Commission to obtain advance approval of such water wel! ±es±ing program. 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