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Home My WebLink About204-197• • Image Project Well History File Cover Page XHVZE This page identifies those items that were not scanned during the initial production scanning phase. They are available in the original file, may be scanned during a special rescan activity or are viewable by direct inspection of the file. O2 ~ ~-~- - ~ ~ ~ Well History File Identifier Organizing (done) ^ Two-sided III II~III II III II III ^ Rescan Needed III IIIIII II II III III RESCAN Color Items: DI TAL DATA Diskettes No 1 OVERSIZED (Scannable) Ma s: , . ^ p ^ Greyscale Items: ^ Other, No/Type: ^ Other Items Scannable by a Large Scanner ^ Poor Quality Originals: OVERSIZED (Non-Scannable) ^ Other: ^ Logs of various kinds: NOTES: BY: Maria Date: O ^ Other:: /s/ Project Proofing III IIIIII VIII II III BY: Maria Date: ~ ~ `a~ b lsl Scanning Preparation ~ x 30 = ~ + ~_ =TOTAL PAGES~~ / (Count does not include cover sheet) , ,~ n BY: Maria ~ Date: ~ ® ~ ~ r /s/ uV~ Production Scanning Stage 1 Page Count from Scanned File: r ~ (Count does include cover sheet) Page Count Matches Number in Scanning Preparation: YES NO BY: Maria Date: ~ ~ ~~ I O /s/ I Stage 7 If NO in stage 1, page(s) discrepancies were found: YES N BY: Maria Date: /s/ Scanning is complete at this point unless rescanning is required. II I II II II I II II I I III ReScanned III IIIIIIIIIII VIII BY: Maria Date: /s/ Comments about this file: Quality Checked II I II IIII III (I'I III 10/6/2005 Well Hist ry File Cover Page.doc ~, h. --- • .~, ~' __~. ~,: - - , -. MICROFILMED 0307 zoos DQ NQT PLACE. ANY NEW MATERIAL UNDER THIS PAGE F:\LaserFict~;\CvrPgs_InsertstMicrofilm M~rker.doc !1 DATA SUBMITTAL COMPLIANCE REPORT .7/19/2007 Permit to Drill 2041970 Well Name/No. PRUDHOE BAY UN GRIN L-202L1 Operator BP EXPLORATION (ALASKA) INC API No. 50-029-23229-60-00 MD 12115 TVD 4600 Completion Date 7/11/2005 Completion Status 1-OIL Current Status 1-OIL UIC REQUIRED INFORMATION Mud Log No Samples No Directional Survey Yes DATA INFORMATION Types Electric or Other Logs Run: MWD / GR, MWD / GR /RES /DEN / NEU / PWD, MWD / GR /RES / (data taken from Logs Portion of Master Well Data Maint Well Log Information: Log/ Electr Data Digital Dataset Log Log Run Interval OH / Ty Med/Frmt Number Name Scale Media No Start Stop CH Received Comments D Asc Directional Survey 0 12115 7/14/2005 Rp Directional Survey 0 12115 7/14/2005 D C Lis 14066 Induction/Resistivity 53 12115 Open 4/30/2007 LIS Veri, FET, ROP, GR, RH01, DRHO, NPHI w/Graphics PDS & TXT ~ g 15066 Induction/Resistivity 2 Blu 7084 12115 Open 4/30/2007 MD Vision Service 24-Jun- ~og 15066 Induction/Resistivity 2 Blu 7084 12115 Open 4/30/2007 2005 TVD Vision Service 24-Jun- 2005 Well Cores/Samples Information: Name ADDITIONAL INFORMATION Well Cored? Y~' Chips Received? "`_ Analysis '~/ I~ Received? Interval Start Stop Sent Received Daily History Received? Formation Tops Sample Set Number Comments N ~/N Comments: Compliance Reviewed By: Date: oaiz5lo~ Schlumberger Schlumberger-DCS 2525 Gambell St, Suite 400 Anchorage, AK 99503-2838 ATTN: Beth Well Job # ~~~~~ ~,~ ~~ # l~ ~~ Log Description NO.4223 Company: Alaska Oil & Gas Cons Comm ANn: Christine Mahnken 333 West 7th Ave, Suite 100 Anchorage, AK 99501 Field: Aurora Orion Date BL Color CD L-213 ~ 11649950 MEMORY (PROF 03/17107 1 W-210 S-104 11626075 10563057 USIT INJECTION PROFILE 03106/07 05103/03 1 1 L-218 L-218 10913045 10913045 CEMENTlPERF EVALUATION MDT 09104105 09104/05 1 1 5-111PB1 S-111PB2 40011960 40011960 OH EDIT MWD/LWD _ OH EDIT MWD/LWD 05124105 06/06!05 2 2 1 1 L-202 L-202L1 40012011 40012011 OH EDIT MWD/LWD OH EDIT MWDlLWD O6N 7105 O6/24105 2 2 1 1 L-202L2 L-202L3 40012011 40012011 OH EDIT MWD/LWD OH EDIT MWDlLWD 06/29/05 07/05105 2 2 1 1 S-122 5-122PB1 40012137 40012137 OH EDIT MWDlLWD OH EDIT MWDlLWD 06!17/05 08109/05 2 2 1 1 S-122P82 40012137 OH EDIT MWDlLWD 08/14/05 2 1 5-122PB3 40012137 OH EDIT MWDlLWD 08115/05 2 1 PLEASE ACKNOWLEDGE RECEIPT BY SIGNING AND RETURNING ONE COPY EACH TO: BP Exploration (Alaska) Inc. - ~ ~ ~~' Petrotechnical Dala Center LR2-1 , . ' I - ~ - Schlumberger-DCS 2525 Gambell St, Suite 400 900 E Benson Blvd. Anchorage, AK 99503-2838 Anchorage AK 99508-4254 ^ ~ ~ ~ ~~~~ 6!'ti ATTN: Beth Date Delivered: Received by: ~ ~ ~. ~ ~"cbYl~= ~t~Y1YT'UCrd~ ~~Y~~'4f~r`,~~: 'g'.,: STATE OF ALASKA ALASKA~L AND GAS CONSERVATION COM~SION WELL COMPLETION OR RECOMPLETION REPORT AND LOG Revised: 09/15/05, Put on Production ~ 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAACZS.~os zoAACZS.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other 1b. Well Class: ®Development ^ Exploratory ^ Stratigraphic ^ Service 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 7/11/2005 12. Permit to Drill Number 204-197 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 6/21/2005 13. API Number 50-029-23229-60-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 6/23/2005 14. Well Name and Number: PBU L-202L1 2572 FSL, 3690 FEL, SEC. 34, T12N, R11E, UM Top of Productive Horizon: 938' FSL, 1411' FEL, SEC. 27, T12N, R11 E, UM (OBb) g, KB Elevation (ft): 77.3' 15. Field/Pool{s): Prudhoe Bay Field / Orion Schrader Bluff Total Depth: 4927' FSL, 3449' FWL, SEC. 35, T12N, R11E, UM 9. Plug Back Depth (MD+TVD) 12115 + 4600 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583224 y- 5978293 Zone- ASP4 10. Total Depth (MD+TVD) 12115 + 4600 Ft 16. Property Designation: ADL 028238 _ TPI: x- 585456 y- 5981965 Zone- ASP4 Total Depth: x- 590332 Y- 5980732 Zone- ASP4 11. Depth where SSSV set (Nipple) 2258' MD 17. Land Use Permit: 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD / GR, MWD / GR /RES /DEN /NEU /PWD, MWD / GR /RES /DEN /NEU /PWD /AIM 22. ASING, LINER AND CEMENTING RECORD CASING ETTING DEPTH MD ETTING'D EPTH TVD HOLE AMOUNT SIZE WT. PER FT. GRADE Op OTTOM OP OTTOM SIZE CEMENTING RECORD.. PULLED 20" x 34" 215.5# A53 Surface 109' Surface 109' 48" 260 sx Arctic Set A rox. 10-314" 45.5# L-80 29' 3273' 29' 2635' 13-1 /2" 604 sx AS Lite, 489 sx Class 'G' 7-5/8" 29.7# L-80 26' 7072' 26' 4484' 9-7/8" 603 sx Class 'G' 4-1/2" 12.6# L-80 7067' 11183' 4483' 4568' 6-3/4" Uncemented Slotted Liner 4-1/2" 12.6# L-80 6885' 7040' 4417' 4473' N/A Liner Tieback 23. Perforations open to Produc tion (MD +TV D of Top and " " 24. TUBING RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Section 4-1/2", 12.6#, L-80 6758' 6643' MD TVD MD TVD 7092' - 7346' 4491' - 4512' 7388' - 9372' 4507' - 4503' 25. Aap, FRACTURE, CEMENT SQUEEZE, ETC. 9658' - 10812' 4510' - 4551' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protect w/ 101 Bbls of Diesel 26. PRODUCTION TEST Date First Production: August 20, 2005 Method of Operation (Flowing, Gas Lift, etc.): Gas Lift Date of Test Hours Tested See L-202 PRODUCTION FOR TEST PERIOD OIL-BBL GAS-MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing Press. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none". None ~ SEP ~ ~ 200 Form 10-407 Revised 12/2003 CONTINUED ON REVERSE SIDE r ~--' ~, G ~, r 18. GEOLOGIC MARKERS 29' FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Schrader Bluff OBb 7068' 4483' None 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. Signed Terrie Hubble ~ Title Technical Assistant Date - ~ 5-QS PBU L-202L1 204-197 Prepared By Name/Number: Terrie Hubble, 564-4628 Well Number Permit No. / A rOVal NO. Drilling Engineer: Michael Triolo, 564-5774 INSTRUCTIONS GeNewoL: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. IreM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Satt 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 elevation in feet above mean low low water. 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: True vertical thickness. 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: If no cores taken, indicate "None". IreM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only STATE OF ALASKA ALASKA c~IL AND GAS CONSERVATION COMM SSION WELL COMPLETION OR RECOMPLETION REPORT AND LOG `e~ '. 1a. Well Status: ®Oil ^ Gas ^ Plugged ^ Abandoned ^ Suspended ^ WAG zoAAC zs.,os zoAAC zs.,,o ^ GINJ ^ WINJ ^ WDSPL No. of Completions One Other ib. Well Cla ~ ~ ~vv ®Development ^ Exploratory ~~~~~i~ G7~~!~Q' c;, 2. Operator Name: BP Exploration (Alaska) Inc. 5. Date Comp., Susp., or Aband. 7/11/2005 12. Permit to Dri~Numb~;: 204-197 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Date Spudded 6/21/2005 13. API Number 50-029-23229-60-00 4a. Location of Well (Governmental Section): Surface: ' ' 7. Date T.D. Reached 6/23/2005 14. Well Name and Number: PBU L-202L1 2572 FSL, 3690 FEL, SEC. 34, T12N, R11 E, UM Top of Productive Horizon: 938' FSL, 1411' FEL, SEC. 27, T12N, R11 E, UM (OBb) g, KB Elevation (ft): 77 3' 15. Field /Pool(s): Prudhoe Bay Field / Orion Schrader Bluff Total Depth: 4927' FSL, 3449' FWL, SEC. 35, T12N, R11E, UM 9. Plug Back Depth (MD+TVD) 12115 + 4600 Ft 4b. Location of Well (State Base Plane Coordinates): Surface: x- 583224 y- 5978293 Zone- ASP4 10. Total Depth (MD+TVD) 12115 + 4600 Ft 16. Property Designation: ADL 028238 TPI: x- 585456 y-_ 5981965 Zone- ASP4 Total Depth: x- 590332 Y- 5980732 Zone- ASP4 11 • Depth where SSSV set (Nipple) 2258' MD 17. Land Use Permit: - ----------------- --------- ----- --------------- 18. Directional Survey ®Yes ^ No 19. Water depth, if offshore N/A MSL 20. Thickness of Permafrost 1900' (Approx.) 21. Logs Run: MWD / GR, MWD / GR /RES /DEN /NEU /PWD, MWD / GR /RES /DEN /NEU /PWD /AIM 2. CASING, LINER AND CEMENTING RECORD VASING ETTINQ EPTH MD ETTINO EPTH TVD HOLE ` MOUNT: $tZE WT. FER FT, GRADE OP OTTOM OP TTOM SIZE CEMENTING RECORD 'PULLED 20" x 34" 215.5# A53 Surface 109' Surface 109' 48" 260 sx Arctic Set A rox. 10-3/4" 45.5# L-80 29' 3273' 29' 2635' 13-1/2" 604 sx AS Lite, 489 sx Class 'G' 7-5/8" 29.7# L-80 26' 7072' 26' 4484' 9-7/8" 03 sx Class 'G' 4-1/2" 12.6# L-80 7067' 11183' 4483' 4568' 6-3/4" Uncemented Slotted Liner 4-1/2" 12.6# L-80 6885' 7040' 4417' 4473' N/A Liner Tieback 23. Perforations open to Produc tion (MD +TV D of Top and " " 24. TuBIrvG RECORD Bottom Interval, Size and Number; if none, state none ): SIZE DEPTH SET (MD) PACKER SET (MD) 4-1/2" Slotted Section 4-1/2", 12.6#, L-80 6758' 6643' MD TVD MD TVD 7092' - 7346' 4491' - 4512' 7388' - 9372' 4507' - 4503' 25. AC{D, FRACTURE, CEMENT SQUEEZE, ETC. 9658' - 10812' 4510' - 4551' DEPTH INTERVAL MD AMOUNT & KIND OF MATERIAL USED Freeze Protect w/ 101 Bbls of Diesel 26. PRODUCTION TEST Date First Production: Not on Production Yet Method of Operation (Flowing, Gas Lift, etc.) N/A : Date of Test Hours Tested PRODUCTION FOR TEST PERIOD OIL-BBL GAS'MCF WATER-BBL CHOKE SIZE GAS-OIL RATIO Flow Tubing PreSS. Casing Pressure CALCULATED 24-HOUR RATE OIL-BBL GAS-MCF WATER-BBL OIL GRAVITY-API (CORK) 27. CORE DATA Brief description of lithology, porosity, fractures, apparent dips and presence of oil, gas or water (attach separate sheet, if necessary). Submit core chips; if none, state "none'. ~~ d~ w~~s~ ~ ~~~ ~~J~ y~.~~ ~-v~ ~.~... None ~,, , =; ,:, K ~ -- ' _' ~ ~F~ ~u~ ~ 200 Form 10-407 ~F`i~CtSI'±!!"~"i~003 CONTINUED ON REVERSE SIDE r~ 28. GEOLOGIC MARKERS 29' FORMATION TESTS Include and briefly summarize test results. List intervals tested, NAME MD TVD and attach detailed supporting data as necessary. If no tests were conducted, state "None". Schrader Bluff OBb 7068' 4483' None 30. List of Attachments: Summary of Daily Drilling Reports, Well Schematic Diagram, Surveys 31. I hereby certify that the foregoing is true and correct to the best of my knowledge. Si ned w ~ ~~ ~ l a~' g Terris Hubble Title Technical Assistant Date PBU L-202L1 204-197 Prepared By NameMumber Terris Hubble, 564-4628 Well Number Permit No. / A royal No. Drilling Engineer: Michael Triolo, 564-5774 INSTRUCTIONS GeNeRn~: This form is designed for submitting a complete and correct well completion report and log on all types of lands and leases in Alaska. ITeM 1a: Classification of Service Wells: Gas Injection, Water Injection, Water-Alternating-Gas Injection, Salt Water Disposal, Water Supply for Injection, Observation, or Other. Multiple completion is defined as a well producing from more than one pool with production from each pool completely segregated. Each segregated pool is a completion. ITEM 4b: TPI (Top of Producing Interval). ITeM 8: The Kelly Bushing elevation in feet above mean low low water. Use same as reference for depth measurements given in other spaces on this form and in any attachments. ITEM 13: The API number reported to AOGCC must be 14 digits (ex: 50-029-20123-00-00). ITeM 20: True vertical thickness. Irene 22: Attached supplemental records for this well should show the details of any multiple stage cementing and the location of the cementing tool. Irene 23: If this well is completed for separate production from more than one interval (multiple completion), so state in item 1, and in item 23 show the producing intervals for only the interval reported in item 26. (Submit a separate form for each additional interval to be separately produced, showing the data pertinent to such interval). ITEM 26: Method of Operation: Flowing, Gas Lift, Rod Pump, Hydraulic Pump, Submersible, Water Injection, Gas Injection, Shut-In, or Other (explain). ITEM 27: If no cores taken, indicate "None". ITeM 29: List all test information. If none, state "None". Form 10-407 Revised 12/2003 Submit Original Only BP EXPLORATION Page l of 1 Leak-Off Test Summary Legal Name: L-202 Common Name: L-202 Test Date Test Type Test'Depth (TMD) Test Depth (TVD) AMW ..,Surface Pressure Leak Off Pressure (BHP) EMW 6/9/2005 LOT 3,303.0 (ft) 2,640.0 (ft) 8.90 (ppg) 450 (psi) 1,671 (psi) 12.18 (ppg) 6/15/2005 LOT 7,695.0 (ft) 4,588.0 (ft) 9.20 (ppg) 375 (psi) 2,568 (psi) 10.77 (ppg) Printed: 7/18/2005 11:22:23 AM BP EXPLORATION Page 1 of 21 Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7!11/2005 Rig Name: NABOBS 9ES Rig Number: Date from - To Hours' Task Code NPT Phase Description of Operations - 6/4/2005 00:00 - 03:00 3.00 MOB P PRE Set topdrive in rotary table, disconnect blocks from topdrive, 03:00 -04:30 1.50 MOB P PRE 04:30 - 05:30 1.00 MOB P PRE 05:30 - 07:30 2.00 MOB P PRE 07:30 - 09:30 2.00 BOPSU P PRE 09:30 - 10:30 1.00 MOB P PRE 10:30 - 12:30 2.00 RIGU P PRE 12:30 - 14:00 1.50 RIGU P PRE 14:00 - 16:30 2.50 BOPSU P PRE 16:30 - 18:00 1.50 RIGU P PRE 18:00 - 19:00 1.00 RIGU P PRE 19:00 - 23:00 4.00 RIGU P PRE 23:00 - 00:00 1.00 RIGU P PRE 6/5/2005 00:00 - 01:00 1.00 RIGU P PRE 01:00 - 01:30 0.50 RIGU P PRE 01:30 - 02:00 0.50 BOPSU P PRE 02:00 - 03:00 1.00 RIGU P PRE 03:00 - 03:30 0.50 RIGU P PRE 03:30 - 05:00 1.50 RIGU P PRE 05:00 - 07:00 2.00 DRILL P SURF 07:00 - 07:30 0.50 DRILL P SURF 07:30 - 12:00 4.50 DRILL P SURF 12:00 - 20:30 I 8.501 DRILL I P I I SURF bridle up, prep floor for derrick down move, lay down pipe chute, disconnect power and service lines to pits, move cuttings tank. Pull pits away from sub and position at entrence to pad. Held PJSM, with Toolpusher and rig crew. Un-pin derrick and lay down. Pull sub off L-2141, move sub around pad and position to pull over L-202. move pits around comer. Place well head equipment in cellar, lay mats, spread herculite, hang surface riser in cellar. Spot and level sub on L-202. Nipple up 20" Hydril and 16" diverter line, prior to setting mud pits. Spot and level mud pits, hook up power and service lines to pits. Accept Rig ~ 09:00 hrs 6/4/2005 PJSM, inspect and raise derrick. Raise and pin pipe chute. Perform derrick inspection, bridle down, pin blocks to topdrive, take on water in pits. Mix spud mud, load DP and BHA in pipe shed. Nipple up 20" riser and flow line, hookup accumalator lines to Hydril and knife valve. Service topdrive, install bails, adjust kelly hose. Rig up floor. Pick up 102 joints and rack back 34 stands of 5" DP. Cut and slip drilling line. Held Pre-Spud meeting, with Co. Rep, Toolpusher, and all reig personnel. Pickup 14 joints 5" HW DP, jars and stand back. Make up 3, 8" NM drill collars. Function test Diveter valve and 20" Hydril, Jeff Jones with AOGCC waived witness of diverter test. Rack back stand of drill collars. Make up Bit, motor and MWD, tagged ice at 35', lay down stab and MWD. Fill hole, check suface equipment for leaks. Drill ice from 35' to 108', POH rack back 1 stand HWDP. Pickup remaing BHA per directional driller, PJSM, rig up Sperry e-line unit and Gyro tools. Drill 13.5" Surface hole from 108' to 271, 595 gpm, 580 psi, 60 rpm, torque 1.5 to 2k POH, stand back 2 stands 5" HWDP, pickup NM drill collars and jars. Drill 13.5" hole from 271' to 731',10-15k wob, 680 gpm, 1,395 psi, 80 rpm, torque 2.5k, up wt = 86k, do wt = 66k, rt wt = 73k. ART = 3.70 hrs, AST = .18 hrs. Directional drill 13.5" hole from 731' to 1,580' 30-40k wob, 700 gpm, 2,000 psi on bottom, 1,700 psi off bottom, 80 rpm, torque 5k on bottom, 2k off bottom, up wt = 86k, do wt = 84k, rt wt = 85k, ART = 1.38 hrs, AST = 5.83 hrs. Rig down Gyrodata tools and Sperry a-line unit. no gyro's surveys were taken. Printed: 7/18/2005 17:22:29 AM BP EXPLORATION Page 2 of 21 Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABORS 9ES Rig Number: ~ Dater From - To Hours Task Code NPT Phase Description of Operations 6/5/2005 20:30 - 21:30 1.00 DRILL P SURF Circulate hole clean, 710 gpm, 1,700 psi, 80 rpm, torque 3k. 21:30 - 00:00 2.50 DRILL P SURF Monitor well, POH from 1,580' with no problems, lay down UBHO sub, change out crossover sub and bit. 6/6/2005 00:00 - 01:30 1.50 DRILL P SURF RIH with BHA #2, started taking weight ~ 950'to 1,150' 15 to 20k, stopped and filled pipe, continue to RIH, to 1,489' no further problems. 01:30 - 12:00 10.50 DRILL P SURF Break circulation, wash last stand to bottom, directional drill 13.5" hole from 1,580' to 2,716', 30-40k wob, 700 gpm, 2150 psi on bottom, 1,860 psi off bottom, 80 rpm, torque 10.5k on bottom, 4.5k off bottom, up wt = 96k, do wt = 84k, rt wt = 92k, Encounterd hyrates ~ 1,850' and 2,050' to 2,520' ART = 1.29 hrs. AST = 5.0 hrs. 12:00 - 14:00 2.00 DRILL P SURF Directional drill 13.5" hole from 2,716' to 3,283' 30-40k wob, 710 gpm, 2300 psi on bottom, 1,900 psi off bottom, 80 rpm, torque 10k on bottom, 4.5k off bottom, up wt = 95k, do wt = 82k, rt wt = 94k. ART = 2.06 hrs. 14:00 - 15:00 1.00 DRILL P SURF Circulate 2x bottoms up, 710 gpm, 1,800 psi, 100 rpm, torque 5k. 15:00 - 18:30 3.50 DRILL P SURF Monitor well, POH from 3,283' encountered tight hole @ 3,045', 2,995' to 2,900', 1,800 to 1,766' 45k excess drag. hole not swabbing. Worked pipe ~ 1,766' several times 50k over pull. 18:30 - 20:00 1.50 DRILL P SURF Makeup topdrive, backream out slowly from 1,766' to 1,390', 600 gpm,1,325 psi, 80 rpm, torque 5k, no excess drag or torque. 20:00 - 20:30 0.50 DRILL P SURF Continue POH, from 1,390' to HWDP ~ 640', (pulled good) 20:30 - 00:00 3.50 DRILL P SURF Monitor well, RIH from 640' to 1,650' set down hard ~ 1,650' attempt to work through, no go, Makeup topdrive and break circulation, wash and ream down with 180 gpm, 40 rpm, set down 50k, torque 4 to 17k,no progress, pulled above tight spot, oriented motor to HS work down with out pump or rotatry, set down hard ~ '1,645' no progress. break circulation began reaming ~ 1,640' with 300 gpm, 80 rpm, taking 10 to 30k wob, torque 10 to 18k reamed down to 1,684', backreamed stand up to 1,588' erratic torque, shut down pumps and worked through tight spot with no problems. Continued to RIH, reamed several spots, 2080' to 2,186', 2,245' to 2,340', RIH dry from 2,340 to 2,800'. 6/7/2005 00:00 - 00:30 0.50 DRILL P SURF RIH from 2,800' stacked out 40k ~ 3,110' makeup topdrive and ream from 3,110' to TD ~ 3,283' 300 gpm, 690 psi, 60 rpm, torque 4 to 7k. 00:30 - 02:00 1.50 DRILL P SURF Circulate 3x bottoms up, 700 gpm, 1,850 psi, 100 rpm, torque 4.5k. Monitor well 02:00 -04:00 2.00 DRILL P SURF POH from 3,283' to 640', tight from 2,050' to 1,890' 10-15k, excess drag, worked back thru tight area, no drag. monitor well at BHA. 04:00 - 07:00 3.00 DRILL P SURF Stand back HWDP, jars and 7" NM drill collars, lay down BHA, clear floor. 07:00 - 09:00 2.00 CASE P SURF PU surface casing hanger and landing joint. Make dummy run to ensure ability to land on hanger -good. Change out bails and RU 350 ton casing handling equipment. 09:00 - 16:00 7.00 CASE P SURF PU 10-3/4", 45.5#, L-80, BTC shoe track and RIH. All connections of the shoe track were Bakerlok'd. Continue to PU Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING Rig Name: NABOBS 9ES Start: 6/3/2005 Rig Release: 7/11/2005 Rig Number: Date From - To Hours .Task Code. NPT ''Phase 6/7/2005 09:00 - 16:00 7.00 CASE P SURF 16:00 - 20:00 I 4.001 CASE I P 20:00 - 00:00 I 4.001 CEMT I P 6/8/2005 100:00 - 02:00 I 2.00 02:00 - 07:30 I 5.50 07:30 - 12:00 I 4.50 12:00 - 12:30 I 0.50 12:30 - 14:30 2.00 SURF SURF P SURF P SURF P SURF P (SURF N SFAL (SURF 14:30 - 16:00 I 1.501 BOPSUR P I I SURF Page 3 of 21 Spud Date: 6/5/2005 End: 7/11 /2005 Description of Operations surface casing applying Best-o-life 2000 NM and 8,000 albs of torque to 3,273' MD (78 joints), filling pipe every joint with the Franks fillup tool and circulating down intermittently from 2,370' to 2,500' MD. Ran 25 bow spring centralizers - 10' from float shoe, 10' from float collar, remaining around collars of joints #4 to #26. Landed casing and made up the cement head. Break circulations 3 bpm, 300 psi and slowly stage the pumps up to 10 bpm, 660 psi, PU - 165K, SO - 122K. Circulate and condition the mud while reciprocating the pipe with 10' of movement. Hold PJSM with Schlumberger and members of the rig team. Line up to Schlumberger and pump 5 bbls of fresh water and pressure test the lines to 4,000 psi. Pump 20 bbls of CW 100 pre-flush ~ 7 bpm, 201 psi. Pump 70 bbls of 10.1 ppg Mudpush II Spacer ~ 5 bpm, 123 psi. Shut down and drop bottom plug while getting the 10.7 ppg ArcticSet Lite lead cement up to weight. Kick out the plug (good indication) with 480 bbls of lead cement ~ 8 bpm, 845 psi initial and 916 psi final. Shut down and bring the 15.8 ppg Class G + additives tail slurry up to weight. Pump 102 bbls of tail slurry ~ 4 bpm, 275 psi initial and 150 psi final. Shut down and drop the top plug. Kick out the plug (good indication) with 10 bbls of fresh water from Schlumberger. Shut in and turn over to the rig to displace. Displaced the cement with 297 bbls of 9.5 ppg conditioned mud at 10 bpm and caught the falling cement 27 bbls into the displacement. The rate was dropped to 5 bpm with 127 bbls into the displacement when the thick cement interface with red dye came to the surface. Pipe started to take a little weight on the down stroke, so the casing was landed on the hanger at this time. The rate was increased to 10 bpm by 141 bbls into the displacement. Dropped the rate to 5 bpm with 268 bbls into the displacement and then to 3 bpm to bump the plug on calculated strokes and 95% efficiency. Applied 1,500 psi to bump the plug and held for 5 minutes. The floats were then checked and found to be holding. Good lift pressures and full returns were seen throughout the entire cement job. Approximately 170 bbls of lead cement returns were brought to the surface. Cement was in place ~ 2330 hours. LD cement head and landing joint. ND diverter. Clear the floor of casing handling equipment. Install Base Flange. Test seals to 1,000 psi -good. MU tubing spool and adapter flange. MU BOPE to tubing spool. RU 5' testing equipment and fill the BOPE with fresh water. Test ROPE and floor safety valves to 250 psi / 3,500 psi. Witness of the BOP test was waived by Jeff Jones of the AOGCC. Test was witnessed by BP Wellsite Leader Tom Anglen and Nabors Rig Supervisor Bill Bixby. Attempt to test the blind shear rams to 250 psi. Test failed. Change out the blind shear rams -found pieces of rubber missing from the seal area. Fill the BOPE with fresh water. Test the blind shear rams and door seals to 250 psi / 3,500 psi. Blow down the choke manifold and surface lines. Pull the test plug and install the Printed: 7/18/2005 11:22:29 AM 'BP EXPLORATION Page 4 of 21''' Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABORS 9ES Rig Number: Date From - To Hours_ Task Code NPT Phase Description of.Operations 6/8/2005 14:30 - 16:00 1.50 BOPSU P SURF wear ring. 16:00 - 19:00 3.00 DRILL P INTi PU 60 joints of 5" DP and RIH. Move BHA components which were stood back in the derrick to the drillers side. POH standing back 20 stands of 5" DP. 19:00 - 20:00 1.00 DRILL P INT1 MU BHA#3 - 9-7/8" MXC-1, nb stab, 2 x nm dc's, saver sub, 1 x HWDP, jars, 14 x HWDP. 20:00 - 22:30 2.50 DRILL P INT1 PU 69 x 5" DP singles and RIH. RIH with 4 stands from the derrick to 3,100'. 22:30 - 23:00 0.50 CASE P SURF RU casing testing equipment and circulate the air from the system prior to pressure testing the casing. 23:00 -00:00 1.00 CASE P SURF Hold PJSM with Dowell and the rig team. Line up to Dowell and pressure test lines to 3,800 psi -good. Bleed off pressure. Pressure test the 10-3/4" 45.5# L-80 BTC casing to 3,500 psi - chart and hold for 30 minutes -good test. Bleed off pressure and Rd testing equipment. 6/9/2005 00:00 - 02:00 2.00 DRILL P INT1 Drill the shoe track and cement from top of the float collar ~ 3,187' to the top of the #loat shoe @ 3,271' - 550 gpm, 765 psi, 60 rpm 02:00 -04:00 2.00 DRILL P INT1 Pump high visc sweep and displace the well over to 8.9 ppg LSND drilling fluid, PU - 112K, SO - 74K, ROT - 90K. Drill out the shoe, 13.5" rat hole and 20' of new formation to 3,303'. Place the bit inside the casing shoe ~ 3,273' 04:00 - 05:00 1.00 DRILL P INT1 PJSM with Schlumberger and rig team. RU Schlumberger and fill lines. Perform LOT to 12.18 ppg EMW using Schlumberger pumping unit and 8.9 ppg drilling fluid - 450 psi surface pressure. Repeat LOT two additional times for Stress Cage Test baseline. 05:00 - 06:00 1.00 DRILL P INT1 Circulate and spot 34 bbl Stress Cage Test pill #1 at 5 bpm. 06:00 - 07:00 1.00 DRILL P INT1 Line back up to Schlumberger pumping unit and conduct Stress Cage LOT twice. 07:00 - 09:00 2.00 DRILL P INT1 Circulate out pill#1 and clean the mud cleaning equipment. Add spike fluid to the mud system. Spot 30 bbl Stress Cage pill #2. 09:00 - 09:30 0.50 DRILL P INT1 Perform Stress Cage LOT twice. 09:30 - 12:30 3.00 DRILL P INT1 Circulate out pill #2 and condition the mud system removing the spike fluid - 673 gpm, 1,600 psi. 12:30 - 16:00 3.50 DRILL P INT1 Monitor well -static. LD TIW, head pin and cement line. Pump dry job and POH standing back 5" DP and laying down BHA #3. Clear and clean the floor. 16:00 - 20:00 4.00 DRILL P INT1 Hold PJSM with the rig team. MU BHA#4 - 9-7/8" DS70FNPV, 8.25" 4/5 8.2 stg motor (adjusted to 1.5), xo, nm stab, ARC, MWD, ADN, 2 x nm dc's, saver sub, 1 x HWDP, jars, 14 x HWDP. Shallow test MWD -good. PU remaining BHAff4 - 6 x 5" DP, ghost reamer, 48 x 5" DP, ghost reamer 20:00 - 21:30 1.50 DRILL P INT1 Cut and slip 39' of drilling line. Inspect inside drum and grease fittings. Lubricate rig and top drive. 21:30 - 00:00 2.50 DRILL P INT1 RIH with BHA#4 on 5" DP to 3,240'. MAD pass from 3,240' to 3,303'. Drill from 3,303' to 3,501', 701 gpm, 1,680 psi, TO on - 6k, PU - 115K, SO - 82K, ROT - 100K, 80 rpm, ART - 0.51. 6/10/2005 00:00 - 12:00 12.00 DRILL P INTi Drill ahead directionally from 3,501' to 5,574', 700 gpm, 2,190 psi on bottom, 2,020 psi off bottom, TQ on - 10k, TQ off - 9k, PU - 145k, SO - 94k, ROT - 110k, 80 rpm, Calculated ECO - 10.07 ppg, Actual ECD - 10.4 ppg. AST - 1.8, ART - 4.4 Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Event Name: DRILL+COMPLETE Start: 6/3/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Page 5 of 21 Spud Date: 6/5/2005 End: 7/11 /2005 Date From - To Hours Task Code NPT Phase Description of Operatjons 6/10/2005 12:00 - 00:00 12.00 DRILL P INT1 Drill ahead directionally from 5,574' to 6,895', 700 gpm, 2,250 psi on bottom, 2,130 psi off bottom, TQ on - 12k, TO off - 10k, PU - 145k, SO - 94k, ROT - 110k, 80 rpm, Calculated ECD - 9.9 ppg, Actual ECD - 10.26 ppg. AST - 5.06, ART - 1.18 6/11/2005 00:00 - 06:30 6.50 DRILL P INT1 Drill ahead directionally from 6,895' to 7,675' - 700 gpm, 2,230 psi on bottom, 2,195 psi off bottom, TO on - 10k, TO off - 9k, PU - 155k, SO - i 05k, ROT - i 25k, 80 rpm. AST - 2.91, ART - 1.76. Calculated ECD - 9.97 ppg. Actual ECD - 10.55 ppg. 06:30 - 11:00 4.50 DRILL P INT1 Circulate and condition the mud to POH and run liner. Mud weight prior to circulation and conditioning - 9.3 ppg. Mud weight after circulation and conditioning - 9.0 ppg. Prior to POH, calculated ECD - 9.85 ppg, Actual ECD - 9.95 ppg. 11:00 - 16:00 5.00 EVAL P INT1 MAD pass from 7,675' to 6,518' - 600 gpm, 1,600 psi, ROT - 128k, 80 rpm. 16:00 - 18:00 2.00 DRILL P INT1 Monitor well -stable. POH from 6,518' to 3,782'. Encountered 25k max overpull C~3 5,570' and 4,647'. Worked pipe over these intervals and then pulled clean. 18:00 - 23:00 5.00 DRILL P INT1 Hole started to swab at 3,782'. Attempt to pull without pump - unsuccessful. RIH with 2 stands of 5" DP from the derrick to 3,971'. Backream out of the hole from 3,971' to 3,273' (previous casing shoe) - 600 gpm, 80 rpm, 875 psi. Hole tried to pack off while backreaming -ECD spikes seen up to 14 ppg EMW and losses were induced. Adjusted flowrate and rpm to 475 gpm and 65 rpm as well as running in the hole -50' each time and were able to regain retums. Saw a considerable amount of sandy returns while backreaming. Lost 122 bbls over this interval. 23:00 - 23:30 0.50 DRILL P INT1 Stage up the pump rate and circulate bottoms up at the 10-3/4" shoe at 3,273 - 700 gpm, 1,585 psi, 80 rpm. Hole cleaned up well while in casing. Calculated ECD - 9.7 ppg, Actual ECD - 9.9 ppg. 23:30 - 00:00 0.50 DRILL P INT1 Service the top drive and the crown. 6/12/2005 00:00 - 01:30 1.50 DRILL P INT1 RIH with 5" DP from the derrick from 3,273' to 7,675'. 01:30 - 03:30 2.00 DRILL P INTi Circulate and condition drilling fluid to LDDP and run casing. Calculated ECD - 9.84 ppg, Actual ECD - 10 ppg. 03:30 - 08:00 4.50 DRILL P INTi Monitor well -stable. POH standing back 5 stands of 5" DP. Monitor well -stable. Pump dry job. LD 5" DP singles and upper ghost reamer to 2,361'. 08:00 - 08:30 0.50 DRILL P INT1 RIH with 5" DP from the derrick from 2,361' to 3,121'. 08:30 - 10:00 1.50 DRILL P INT1 LD 5` DP from 3,121' to 855'. 10:00 - 13:00 3.00 DRILL P INTi LD BHA#4 from 855'. LD lower ghost reamer, 6 x 5" DP, 14 x HWDP, jars, 1 x HWDP, saver sub, 2 x nm DC's. Hold PJSM for handling nuclear source. LD ADN, MW D, ARC, nm stabilizer, xo, motor and 9-7/8" DS70FNPV -graded 1-2-BT-G-X-I-ER-TD. Clear and clean the floor. 13:00 - 15:30 2.50 BOPSU P INT1 Pull wear ring and flush the BOP stack with fresh water. Install test plug. Change out the top variable rams to 7-5/8" rams. Test the door seals to 3,500 psi -good test. 15:30 - 17:30 2.00 CASE P INT1 Make dummy run with 7-5/8" landing joint. RU to run 7-5/8" 29.7# L-80 BTGM casing. 17:30 - 22:30 5.00 CASE P INT1 PJSM with all personnel. PU 7-5/8" shoe track, bakerloc connections and RIH. Fill pipe and check floats -holding. Continue PU 7-5/8' casing to 3,265, filling pipe each joint. Printed: 7/18/2005 11:22:29 AM '$P EXPLQ'RATION Page 6 of 21 Operations Summary Report Legal Well Name: L-202 - Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Date Fram - To Hours Task Code NPT' Phase -Description of'.Operations 6/12/2005 17:30 - 22:30 5.00 CASE P INT1 Utilized Best-o-life 2000NM on each connection and torque to teh mark with 9,000 ftlbs. 22:30 - 23:30 1.00 CASE P - INTi Circulate 1.5 times bottoms up while staging up to 8 bpm, 529 psi, with full retums. PU - 112k, SO - 101 k. 23:30 - 00:00 0.50 CASE P INT1 Continue to PU 7-5/8" casing and RIH to 3,554'. 6/13/2005 00:00 - 08:30 8.50 CASE P INT1 Continue to PU 7-5/8" 29.7# L-80 BTC-M casing and RIH from 3,554' to 7,665'. FiII pipe every joint. Break circulation every 5 joints, circulate for 15 minutes every 15 joints and circulate bottoms up every 50 joints while keeping the pipe moving. PU landing joint and land hanger with 117K. Ran a total of 184 joints and 71 centralizers with 23 stop rings. 08:30 - 11:30 3.00 CASE P INT1 LD Franks fillup tool and RU cement head and lines. Break circulation and stage up the pumps to 10 bpm, 698 psi -full returns. Reciprocate pipe while circulating. Hold PJSM with Schlumberger and rig team for the cement job. Batch up the cement. 11:30 - 13:30 2.00 CEMT P INTi Line up to Schlumberger and pump 5 bbls of fresh water ahead. Shut down and pressure test the lines to 4,000 psi - good. Pump 20 bbls of CW 100 followed by 45 bbls of 10.5 ppg Mudpush II spacer. Drop bottom plug. Chase plug with 130 bbls of 15.8 ppg Gasblok slurry. Shut down and drop the top plug. Kick the plug out with 10 bbls of fresh water. Shut down and pump remainder of displacement with the rig pumps. Pump 338 bbls of additional water to bump the plug on calculated strokes with 3,000 psi -hold for 5 minutes. Bleed off pressure and check floats -holding. Cement in place ~ 1310 hours. Good lift and full returns seen throughout entire job. 13:30 - 14:30 1.00 WHSUR P INTi RD cement head and LD landing joint. Install pack-off and test to 5,000 psi -good. 14:30 - 15:30 1.00 CASE P INTt RD casing handling equipment -elevators and long bails. 15:30 - 20:00 4.50 BOPSU P INT1 Flush the stack and install test plug. Change out the 7-5/8" casing rams to 3-i/2" x 6" variables. Change out the blind rams to blind/shear rams. Install secondary annulus valve and change out the quill to 4" HT40. RU to test the door seals, HT40 safety valve, and blind shear rams. 20:00 - 21:30 1.50 BOPSU P INT1 Pressure test variable rams, safety valve, and lower well control valve to 250 psi / 3,500 psi. Attempt to test blind/shear rams -failed. RD testing equipment. 21:30 - 22:30 1.00 BOPSU N SFAL INTi Open up the doors and inspect the blind/shear rams. Change the blind/shear rams back to blind rams. 22:30 - 23:00 0.50 BOPSU P INT1 Test the blind rams to 250 psi / 3,500 psi -good test. 23:00 - 00:00 1.00 CASE P INT1 RD testing equipment and install wear ring - 9" ID. 611412005 00:00 - 05:00 5.00 CASE P INT1 RU 4" DP handling tools. MU mule shoe and PU 180 joints of 4" HT40 DP. RIH. Simops -clean pits to get ready for MOBM. Simops -inject 125 bbls of 9.1 ppg LSND fluid down the 7-5/$" x 10-3/4" annulus to ensure injectability (cement compressive strength>1,000 psi). Establish injection rate of 3 bpm, 680 psi. 05:00 - 07:00 2.00 CASE P INT1 POH standing back 4" DP. 07:00 - 12:00 5.00 DRILL P PRODi Bring BHA tools to the rig floor. PU 18 joints of HWDP and stand back in the derrick. MU BHA#5: 6-3/4" Hycalog DS146H+GJNW (6x10's), 4-3/4" Aim 4/5 6stg motor, bypass sub with float, nm stabilizer, nm lead collar, MWD/LWD, Printed: 7!18/2005 11:22:29 AM • BP EXPLORATION Page 7 of 21' Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Date. -From - To Hours Task Code NPT_ Phase Description of Operations 6/14/2005 07:00 - 12:00 5.00 DRILL P PROD1 VPWD, ADN, 2 x nm flex collars, circ sub, xo, 1 x 4" DP, jars, 1 x 4" DP. 12:00 - 14:00 2.00 DRILL P PRODi RIH with BHA#5 picking up 4" OP from the pipe shed to 1,200' 14:00 - 14:30 0.50 DRILL P PROD1 Shallow test the MWD -good test. 14:30 - 18:00 3.50 DRILL P PROD1 Continue RIH picking up 4" DP from the pipe shed form 1,200' to 6,700'. 18:00 - 19:30 1.50 DRILL P PROD1 Cut and slip 96' of drilling line. Service the top drive, blocks and the crown. 19:30 - 20:00 0.50 DRILL P PROD1 RIH picking up 4" DP from 6,700' to 7,362'. 20:00 - 20:30 0.50 CASE P INT1 Pressure test the 7-5/8" 29.7# L-90 BTC-M casing to 3,500 psi. Chart and hold for 30 minutes -good test. 20:30 - 22:30 2.00 DRILL P PROD1 Tag up on cement ~ 7,456'. Drill cement to the float collar tagged at 7,579'. Drill float collar and cement to 7,661' -above the shoe. PU - 150K, SO - 80K, ROT - 103K, 275 gpm, 1,570 psi, 40 rpm, TO on - 8k. 22:30 - 00:00 1.50 DRILL P PROD1 Circulate bottoms up. Simops: freeze protect the 10-3/4" x 7-5/8` annulus with 100 bbls of dead crude. 6/15/2005 00:00 - 01:00 1.00 DRILL P PROD1 Displace the well over to 9.2 ppg Versapro MOBM - 275 gpm, 2,340 psi, 60 rpm, TO - 5K. 01:00 - 02:00 1.00 DRILL P PROD1 Drill 10' of rat hole and 20' of new formation to 7,695'. Circulate bottoms up. Pull bit inside 7-5/8" casing shoe. 02:00 - 02:30 0.50 DRILL P PROD1 Perform 10.77 ppg EMW FIT on the 7-5/8" shoe - 375 psi surface pressure, 9.2 ppg fluid and 4,588' TVD. 02:30 - 10:30 8.00 DRILL P PROD1 Drill 6-3/4" directionally ahead while geo-steering from 7,695' to 8,570' - PU - 138k, SO - 75k, ROT - 101 k, 300 gpm, 2,850 psi on bottom, 2,550 psi off bottom, 60 rpm, TO on - 6k, TO off - 6k, AST - 0.75, ART - 2.59. Calculated ECD - 10.31, Actual ECD - 10.66 10:30 - 14:00 3.50 DRILL N PROD1 MWD information out of sync. Troubleshoot MWD from surface. Circulate to downlink to tool - no effect. Drilled -30' while trying to troubleshoot the MWD from surface. 14:00 - 00:00 10.00 DRILL P PRODt Attempt to drill) ahead one more time prior to making a decision to trip out of the hole for MWD -successful. Appears that if we stay below 400'/hr instantaneous, the MWD stays in sync. Drill 6-3/4" directionally ahead while geo-steering from 8,600' to 9,565' - PU - 138k, SO - 76k, ROT - 101 k, 300 gpm, 3,000 psi on bottom, 2,725 psi off bottom, 60 rpm, TO on - 6k, TO off - 6k, AST - 1.03, ART - 2.48. Calculated ECD - 10.6, Actual ECD - 10.91. 6/16/2005 00:00 - 12:00 12.00 DRILL P PRODi Drill 6-3/4" directionally ahead while geo-steering from 9,565' to 11,028', pumping sweeps as needed - PU - 150k, SO - 60k, ROT - 100k, 294 gpm, 3,050 psi on bottom, 2,860 psi off bottom, 60 rpm, TO on - 7k, TO off - 6k. Calculated ECD - 10.97, Actual ECD - 11.22. AST - 1.8, ART - 3.30 12:00 - 17:00 5.00 DRILL P PROD1 Drill 6-314" directionally ahead while geo-steering from 11,028' to 11,593', pumping sweeps as needed - PU - 143k, SO - 56k, ROT - 91 k, 299 gpm, 3,400 psi on bottom, 3,000 psi off bottom, 60 rpm, TO on - 7k, TO off - 6k. Calculated ECD - 11.27, Actual ECD - 11.32. 17:00 - 18:00 1.00 DRILL P PROD1 POH to 11,453' and log down to 11,593' to confirm geology. 18:00 - 00:00 6.00 DRILL P PROD1 Drill 6-3/4" directionally ahead while geo-steering from 11,593' to 12,061', pumping sweeps as needed - PU - 149k, SO - 56k, ROT - 96k, 299 gpm, 3,450 psi on bottom, 3,150 psi off Printed: 711 t3/2005 1122:29 AM BP EXPLORATION Page 8 of 21- Operations Summary Report. Legal Well Name: L-202 Common Well Name: L-202 Event Name: DRILL+COMPLETE Start: 6/3/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Spud Date: 6/5/2005 End: 7/11 /2005 Date Frorn - To Hotars Task Code NPT Phase bescription of Operations 6/16/2005 18:00 - 00:00 6.00 DRILL P PROD1 bottom, 60 rpm, TQ on - 8k, TQ off - 7k. Calculated ECD - 6/17/2005 100:00 - 05:00 I 5.001 DRILL I P 05:00 - 06:30 I 1.501 DRILL I P 06:30 - 12:30 I 6.001 DRILL I P 12:30 - 13:00 0.50 DRILL P 13:00 - 13:30 0.50 DRILL P 13:30 - 16:30 3.00 DRILL P 16:30 - 18:30 2.00 DRILL P 18:30 - 19:00 I 0.501 DRILL I P 19:00 - 20:30 1 1.501 DRILL I P 20:30 - 00:00 3.50 DRILL P 8/2005 00:00 - 00:30 0.50 DRILL P 00:30 - 03:30 I 3.00 f DRILL I P 03:30 - 05:30 I 2.001 DRILL I P 05:30 -06:00 0.50 DRILL P 06:00 -06:30 0.50 CASE P 06:30 - 15:00 8.50 CASE P 15:00 - 15:30 0.50 CASE P 15:30 - 21:00 5.50 CASE P 21:00 - 22:00 ~ 1.00 ~ CAS E I P 11.20, Actual ECD - 11.80. For the tour: AST - 1.16, ART - 2.97 PROD1 Drill 6-3/4" directionally ahead while geo-steering from 12,061' to 12,628' (TD), pumping sweeps as needed - PU - 149k, SO - 56k, ROT - 96k, 299 gpm, 3,450 psi on bottom, 3,150 psi off bottom, 60 rpm, TO on - 8k, TO off - 7k. PROD1 Circulate and Condition Hole w/ 9.2 ppg MOBM at 294 gpm / 3,150 psi. Start ECD 11.43 ppg, Final ECD 11.3 ppg. Monitor Well-Static PROD1 Backreaming at drilling rate from TD to the 7-5/8" shoe at 7,665'. Start ECD 11.3 ppg. Final ECD 10.84 ppg PROD1 Circulate Bottoms Up at 7,665'. 299 gpm / 2640 psi. 80 rpm. Start ECD 10.78 ppg, Final ECD 10.49 ppg PROD1 PJSM-Service Top Drive PROD1 RIH f/ 7,665' - U 12,628'. Fill DP ~ 10,623' PROD1 Circulate and Condition Hole w/ 9.2 ppg MOBM at 290 gpm / 3300 psi. Start ECD 10.83 ppg. Final ECD 10.83 ppg PROD1 Attempt to Downlink Downhole Tools w/o Success. As Per MWD Rep. PROD1 Displace Wellbore Fluid w/ Solids Free 9.2 ppg MOBM. Recriprocating and Rotating Drill String While Displacing. 275 gpm / 2755 psi. Dn. Wt. 100K, Up Wt. 110K, 66 rpm ~ 9,000 fUlbs Torque. Start ECD 11.2 ppg, Final ECD 10.69 ppg. Monitor Well-Static PROD1 POH w/ 6-3/4" OBd Lateral BHA U 7-5/8" Shoe ~ 7,665'-Recording Up & Down String Weights Every 5 stds. PROD1 Drop 2" Circulating Sub Ball and Pump Down to Seat. Pressure up U 2,250 psi and Open Cir. Sub. Pump Dry Job. PROD1 POH w14" DP. Recording Up and Down String Weights Every 10 stds. PROD1 POH w/ 6-3/4" Obd Lateral BHA, Stand Back HWDP, Jars and Flex Collars. UD MWD tools, Motor & Bit PROD1 Clear and Clean Rig Fllor RUNPRD PJSM-R/U 4-1/2" Liner Running Equipment RUNPRD RIH w/ 4-1/2" 12.6# L-80 IBT Slotted/Solid Liner. Utilize BOL2000NM Dope f/ Connections. 3,600 fUlbs Torque on Slotted Liner, 3,800 fUlbs Torque on Solid Liner. Run Assorted Jewelry As Per Liner Detail. P/U Seal Bore Extension, Baker "HMC" Liner Hgr./ Baker "HRD" ZXP Liner Top Pkr. and Tie-Back Extension. Up Wt. 85K, Dn. Wt. 70K. Total Liner Length = 5,497.59' RUNPRD R/D 4-1l2" Liner Running Equipment RUNPRD RIH w/ 4-1/2' Liner on 4" DP. Filling Dp Every 10 stds. Tag Bottom at 12,628' RUNPRD M/U Top Drive and Establish Parameters; Up Wt. 175K, Dn. Wt. 70K. Pump Rate at 4 bpm / 700 psi. Drop 1-3/4' Baker Setting Ball and Pump Down at 4 bpm. Set 4-1/2" Liner Shoe at 12,625'. Seat Ball and Pressure Up U 2,000 psi to Set Liner Hanger. Slack Down to 50K to Ensure Liner Hgr. Fully Set. Pressure Up U 3,500 psi to Release from Hgr. (hold 5 min.). Bleed Pressure to 0 psi. P/U to Free Point, 145K (lost 30K), P/U Additional 8' to Expose Dogs. Rotate Down at 10 rpm Until Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Event Name: DRILL+COMPLETE Contractor Name: NABOBS ALASKA DRILLING I Rig Name: NABOBS 9ES Date (From - To Hours Task `.Code NPT 6/18/2005 ~ 21:00 - 22:00 I 1.00 ~ CASE ~ P 22:00 - 00:00 2.00 CASE P 9/2005 00:00 - 02:30 2.50 P 02:30 - 03:00 0.50 CASE P 03:00 - 03:30 0.50 CASE P 03:30 -04:00 0.50 CASE P 04:00 - 05:00 1.00 STWHIP P 05:00 - 09:00 4.00 STWHIP P 09:00 - 14:30 I 5.501 STWHIPI P 14:30 - 15:30 I 1.001 STWHIPI P 15:30 - 16:30 1.00 STWHIP P 16:30 - 23:00 6.50 STWHIP P 23:00 - 00:00 I 1.001 STWHIPI P 6!20/2005 100:00 - 00:30 I 0.50 (STWHIPI P 00:30 - 04:00 I 3.501 STWHIPI P 04:00 -04:30 0.50 STWHIPI P 04:30 - 05:00 0.50 BOPSU P 05:00 - 05:30 I 0.501 BOPSUR P 05:30 - 07:00 1.50 BOPSU P 07:00 - 14:30 7.50 BOPSU P 14:30 - 15:00 0.50 BOPSU P 15:00 - 17:30 2.50 STWHIP P Page 9 of 21 Start: 6/3/2005 Rig Release: 7/11 /2005 Rig Number: Spud Date: 6/5/2005 End: 7/11 /2005 Phase iJescrip#ion of Opera#ions RUNPRD Obsereved Packer Set w/ 50K Dn Wt. Repeat Process to Ensure Pkr. Set. P/U to 145K and Pressure Up Backside V 1,500 psi to Test Pkr. (held 5 min.). P/U 30' to Clear HR Tool. Monitor Well-Static. RUNPRD POH w/ Running Tool on 4" DP RUNPRD POH w/ 4-1/2" Liner Running Tool RUNPRD Clear and Clean Floor RUNPRD Slip and Cut Drilling Line RUNPRD Service Top Drive and Crown WEXIT P/U 9 - 4-3/4" DC's and Stand Back in Derrick WEXIT P/U and M/U Whipstock Assy. #1, Seal Assy.-Locator Sub-Unloader Sub-3 1/2" DP Space Out Pup-XO Blank Sub-Btm. Trip Anchor-Shear Disconnect-Unloader Sub-Boot Basket-Bit Sub XO-Ported Sub-7 5/8" Whipstock Slide-Starting Milt-Lower Mill-Flex Jt.-Upper Mill-1 jt. 3-1/2" HWDP-Float Sub-MWD Assy.-Bumper Jar-9 x 4-3/4" DC's-XO-18 x 4" HWDP = 981.42' Total Length. Shallow Test MWD, 254 gpm at 685 psi. WEXIT RIH w/ Whipstock Assy. #1 on 4" DP.Running Speed of 45 fpm, as per Baker Rep. RIH V 7,043' WEXIT M/U Top Drive and Establish Parameters; Up Wt. 140K, Dn. Wt. 85K, Pump Rate 275 gpm at 1,925 psi. Orient Whipstock 19 deg. Left and Set Same. Top of Window at 7,072'. Btm. of Window at 7,084'. TVD 4,484' WEXIT Displace Wellbore w/ 9.1 ppg MOBM at 275 gpm / 1,875 psi. WEXIT Mill f/ 7,072' - V 7,103', Up Wt. 139K, Dn. Wt. 85K Rt. Wt. 101 K, Pump Rate 298 gpm/ 1,875 psi, 100 rpm Rotary, Torque 5,000 ft /Ibs. Average ROP 3.18 fph. Pumping Hi-Vis Sweep every 2 hrs. WEXIT Circulate 50 bbl Hi-Vis Sweep Surface to Surface. Working Mills Through Window During Circulation WEXIT Circulate 50 bbl Hi-Vis Sweep Surface to Surface. Work Mills Through Window While Circulating. Pump Dry Job and Monitor Welt. Static. WEXIT POH w/ 6-3/4" Whipstock Milling BHA on 4" DP. L/D BHA Components. All Mills In Gauge WEXIT Clear and Clean Rig Floor. Remove All Milling Tools from Rig Floor. WEXIT P/U and M/U BOP Stack Flushing Tool. Circulate at 10 bpm to Remove Excess Metal/Cuttings from Ram Cavities. WEXIT M/U Floor Valves to Test Jt. Pull Wear Ring and Install Test Plug WEXIT Remove Standard Blind Rams and Install Blind /Shear Rams WEXIT Test BOP's, Choke Manifold and Floor Safety Valves. All Tests to 250 psi Low for 5 min. and 3,500 psi High. for 5 min. Test Witnessed by AOGCC Rep. John Crisp and BP Drilling Supervisor Alan Madsen. Blind/ Shear Rams Failed, Replaced w/ Standard Blind Rams and Retested. Remove Test Plug WEXIT Install Wear Ring WEXIT PJSM- P/U 6-3/4" Directional OBb Lateral Drilling BHA, Bit-Motor (1.5 deg. bend)-Bypass Sub-Stabilizer- Lead Collar-MWD /LWD-VPWD-ADN-2x Flex Collars-Circulating Sub-XO-1 Jt.4` DP-Jars-2 Jts. 4' DP =303.48' Total Length. Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Page 10 of 21 Operations Summary Report. Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Date 'From - To Hours Task Cotle NPT Phase Description of Operations 6/20/2005 17:30 - 20:00 2.50 STWHIP P WEXIT RIH w/ 4" DP U 6,741' 20:00 - 23:00 3.00 STWHIP P WEXIT M/U Top Drive and Break Circulation at 270 gpm / 2,100 psi. Log f/ 6,741' - U 6,800'. RA Tag at 6,734.5'. Log f/ 6,930'- 07,020'. RA Tag at 6,900'. Log Run at 120 fpm. 23:00 - 00:00 1.00 STWHIP P WEXIT Obtain Drilling Parameters and ECD Baseline Benchmark. Readings. Up Wt. 130K, Dn. Wt. 80K, Rt Wt. 100K, Circulating Pressures at 300 gpm. On Btm. 2,600 psi, Off Btm. 2,450 psi. Calc. ECD 10.19 at 270 gpm, Calc. ECD 10.55 at 300 gpm 6/21/2005 00:00 - 12:00 12.00 DRILL P PROD2 Directional drill 6.75" OBb lateral from 7,103' to 8,045', 5-15k wob, 300 gpm, 2,930 psi on bottom, 2,630 psi off bottom, 60 rpm, torque on bottom 5.1k, torque off bottom 4.4k, Calculated ECD 10.43, Actual ECD 11.05, AST = 2.23 hrs, ART = 2.04 hrs. 12:00 - 00:00 12.00 DRILL P PROD2 Directional drill 6.75" OBb lateral from 8.045" to 9,347', 5-15k wob, 290 gpm, 3,250 psi on bottom, 2,850 psi off bottom, 60 rpm, torque on bottom 8.4k, torque off bottom 5.4k, Pumped sweep C~3 8,692' slight increase in cuttings. Calculated ECD 10.80, Actual ECD 11.23, AST = 2.02 hrs, ART = 3.64 hrs. 6/22/2005 00:00 - 02:30 2.50 DRILL P i PROD2 Directional drill 6.75" OBb lateral from 9,347' to 9,658 5-15k wob, 290 gpm, 3,250 psi on bottom, 2,850 psi off bottom, 60 rpm, torque on bottom 8.4k, torque off bottom 5.4k, Pumped sweep 9,627' no increase in cuttings. Calculated ECD 11.05, Actual ECD 11.78. 02:30 - 03:00 0.50 DRILL P PROD2 Circulate to reduce ECD, lower ECD from 11.78 to 11.43, clean hole ECD 11.12. 03:00 - 12:00 9.00 DRILL P PROD2 Continue drilling 6.75" OBb lateral from 9,658' to 10,561' S-10k wob, 290 gpm, 3,210 psi on bottom, 3,050 psi off bottom, 60 rpm, torque on bottom 8.4k, torque off bottom 5.4k, Up wt = 145k, do wt = 60k, rt wt = 97k, calculated ECD 11.11, Actual ECD 11.65, AST = 1.30 hrs, ART = 2.78 hrs 12:00 - 16:30 4.50 DRILL P PROD2 Drill 6.75" OBb lateral from 10,561' to 11,401' 5-10k wob, 290 gpm, 3,340 psi on bottom, 3,030 psi off bottom, 60 rpm, torque on bottom 7.4k, torque off bottom 6.8k, up wt = 160k, do wt = 50k, rt wt = 90k, calculated ECD 11.12, Actual ECD 11.84, AST = 1.08 hrs, ART = 1.80 hrs 16:30 - 17:00 0.50 DRILL P PROD2 Circulate, reduce ECD from 11.84 to 11.46 17:00 - 19:00 2.00 DRILL P PROD2 Drill from 11,401' to 11,504' ECD increased from 11.46 to 1 i .80, AST = .17 ART = .10 19:00 - 20:30 1.50 DRILL P PROD2 Circulate to reduce ECD from 11.78 to 11.40 20:30 - 00:00 3.50 DRILL P PROD2 Control drill at 200 fph to maintain an ECD of not more than .60 over clean hole. from 11,504 to 11,775' 2-5k wob, 287 gpm, 3,050 psi on bottom, 2,985 psi off bottom, 65 rpm, torque on bottom 7.4k, torque off bottom 6.8k, up wt = 150k, do wt = 60k, rt wt = 95k, calculated ECD 11.06, Actual ECD 11.46, AST = .22 hrs, ART = 1.16 hrs. 6/23/2005 00:00 - 03:00 3.00 DRILL P PROD2 Control drill at 200 fph to maintain ECD with set limit of .06 from 11,775' to 12,115' TD early due to low resistivity, 2-5k wob, 290 gpm, 3,150 psi on bottom, 3,010 psi off bottom, 60 rpm, torque on bottom 7.8k, torque off bottom 6.6k, up wt = 143k, do wt = 61 k, rt wt = 95k, calculated ECD 10.98, Actual ECD 11.48, AST = .27 hrs, ART = 1.88 hrs. 03:00 - 06:00 3.00 DRILL P PROD2 Circulate bottoms up, 300 gpm, 3180 psi, 80 rpm, torque 7.2k, Pump 20 bbl high vis sweep weighted to 11.5 ppg around ~ Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Page 11 of 21 Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABOBS ALASKA DRILLING 1 Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code.. NPT Phase Description of Operations 6/23/2005 03:00 - 06:00 3.00 DRILL P PR002 300 gpm, 3,180 psi, increase rpm to 120 while pumping sweep, torque 7.5k, had a 30% increase in cuttings when sweep came back, with larger (pencil lead) sized cuttings. 06:00 - 10:30 4.50 DRILL P PROD2 Monitor well, POH from 12,115' to to 7,000', hole taking proper fill, no problem pulling through window, monitor well. 10:30 - 11:00 0.50 DRILL P PROD2 Service Topdrive. 11:00 - 13:30 2.50 DRILL P PROD2 RIH from 7,000' to 12,115', taking 10 to 15k wieght from 11,050' to 11,850', no other hole problems. 13:30 - 16:30 3.00 DRILL P PROD2 Make up topdrive and break circulation, intial rate 300 gpm, 3,565 psi, 80 rpm, torque 8.1 k, ECD 11.98. Reduce circulating rate to 235 gpm, 2,500 psi, 40 rpm for first bottoms up, ECD had dropped to 11.35. Pumped 20 bbl weighted sweep (11.3 ppg) ~ 300 gpm 3,514 psi, rotating 120 rpm, reduced rpm to 80 when sweep was up inside casing. no noticable increase in cuttings when sweep at surface. 16:30 - 19:00 2.50 DRILL N DFAL PROD2 Attempt to down link MWD tools to faster data rate, down link was unsuccessful. 19:00 - 20:30 1.50 DRILL P PROD2 Displace well to SFMOBM, @ 230 gpm, 2205 psi, 80 rpm, torque 8.5k 20:30 - 00:00 3.50 DRILL P PROD2 Monitor well, POH from 12,115' to 7,000', record up and down weights every 5 stands in open hole, no problems pulling through window. 6/24!2005 00:00 - 01:00 1.00 DRILL P PROD2 Monitor well, drop 2" ball to open circ sub, pump to seat ~ 160 gpm 850 psi, sheared at 1,070 psi. Pump dry job, blow down topdrive. 01:00 -04:00 3.00 DRILL P PROD2 POH from 7,000' to BHA, recording up and down weights every 10 stands. monitor well at BHA. 04:00 - 05:30 1.50 DRILL P PROD2 PJSM, lay down BHA, remove sources, clear floor of all directional tools. 05:30 - 06:00 0.50 FISH P PROD2 Clean floor, P!U Baker fishing tools to rig floor. 06:00 - 08:00 2.00 FISH P PROD2 Make up Whipstock retrieval BHA, Retrieval hook, 1 jt 3 1/2' HWDP,float sub, MWD, bumper sub, oil jar, 12 43/4" drill collars,XO, 18 jts 4" HWDP and 1 stand 4" DP to 1,011'. 08:00 - 08:30 0.50 FISH P PROD2 Shallow test MWD, 230 gpm, 650 psi, ok. 08:30 - 11:00 2.50 FISH P PROD2 RIH with whipstock retriving assembly from 1,011' to 7,043', fill DP ~ 4,276' 11:00 - 11:30 0.50 FISH P PROD2 Make up topdrive and break circulation, orient retrieving lug ~ 19L, Up wt = 150k, do wt = 85K, slack down to 7,078', Picked up to engage fish, pulled up to 175K, allow jars to bleed open, pulled up to release bottom anchor, released ~ 215K, pulled seals from from seal bore extension, 165k, once clear up wt = 150k, monitor well, static. 11:30 - 12:00 0.50 FISH P PROD2 Circulate bottoms up ~ 250 gpm, 1,485 psi, no gas at bottoms up, Monitor well, dead. 12:00 - 17:00 5.00 FISH P PROD2 POH slowly with whipstock, rack back HWDP and collars. 17:00 - 18:30 1.50 FISH P PROD2 Lay down fishing BHA, break and lay down whipstock and related tools. 18:30 - 19:00 0.50 FISH P PROD2 Clear floor of Baker fishing tools, Clean floor. 19:00 - 19:30 0.50 CASE P RUNPRD Rig up to run 4.5" slotted liner. 19:30 -00:00 4.50 CASE P RUNPRD PJSM, run 4.5" 12.6# L-80 IBT -BTC slotted liner to 1,810', per running detail, dope with BOL 2000, make up torque 2,400 fUlbs. 6/25/2005 00:00 - 02:00 2.00 CASE P RUNPRD Continue running 4.5" 12.6# L-80 IBT- BTC OBb slotted liner Printed: 7/1 S/2005 11:22:29 AM BP EXPLORATION Page 12 of 21 Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number; Date 'From - To 'Hotars Task Code NPT Phase Description'of Operafions 6/25/2005 00:00 - 02:00 2.00 CASE P RUNPRD per running detail, record up and down weights every 25 joints. Make up Baker hook hanger assembly. Up wt = 70k, do wt = 59k. Ran a total of 76 joints 4.5" 12.6# L-80 IBT slotted liner, 6 joints 4.5" 12.6# 8TC slotted liner, 1 4.5" 12.6# L-BO Slotted crossover joint, 13 joints 4.5" 12.6# L-80 IBT solid liner, 2 swell packers, baker hook hanger and 1 4.5" 12.6# L-80 IBT bent joint with float shoe. Ran a total of 94 5 3/4" straight blade rigid centralizers. 02:00 - 02:30 0.50 CASE P RUNPRD Rig down casing tongs, change over to 4" handling equipment. 02:30 -04:30 2.00 CASE P RUNPRD RIH with OBb slotted liner on 4" DP, to 7,043' Recording up & down weights every 1000' in casing. 04:30 - 05:00 0.50 CASE P RUNPRD Position bent joint at the top of the window @ 7,072' Up wt = 111 k do wt = 79k, slack off slowly, saw a 5-5K increase in drag, continued down tagged up on OBd liner top extension ~ 7,127' pulled back to 7,040' make up topdrive and establish rotation @ 2 rpm torque 2.8 to 3k, rotate ~ 2 rpm while slacking off to i the middle of the window saw a slight increase in torque ~ 200-300 fUlbs, shut down rotary, continued RIH slowly, bent I joint exited window. 05:00 - 08:30 3.50 CASE P RUNPRD Continue RIH with OBb slotted liner, record up & down weights every 500' in open hole. 08:30 - 09:30 1.00 CASE P RUNPRD Make up topdrive, slowly slack off to engage hook wall hanger, ran in 10' past bottom of the window, pulled 20' above top of the window. Up wt = 175k, do wt = 70k, rotate string 3/4 turn and work torque down, slack off slowly engaged hook wall hanger,set down 15k, picked up several times to confirm hanger hooked, marked pipe pulled up above window, rotate string 1/2 turn, and worked hanger 10' past bottom of window, pulled back up and oriented pipe to original mark and engaged hook hanger in the same place.. 09:30 - 10:00 0.50 CASE P RUNPRD Drop 29/32" ball and pump to seat, 2 bpm 500 psi, pressured up to 2,800 psi to release hydraulic setting tool, picked up to A confirm released, pressure up to 3,400 psi and sheared ball seat. 10:00 - 11:00 1.00 CASE P RUNPRD Circulate bottoms up, 350 gpm, 2200 psi, monitor well, pump dry job. 11:00 - 14:30 3.50 CASE P RUNPRD POH with running tool, make service breacks and lay down running tool. clear floor. 14:30 - 15:30 1.00 CASE P RUNPRD Cut and slip drilling line, service rig and topdrive. 15:30 - 16:00 0.50 TIEBAC P OTHCMP Rig up handling tools to run LEM and hanger assembly. 16:00 - 18:30 2.50 TIEBAC P OTHCMP Make up,non locating seal assembly, 2 4.5" 12.6# IBT pup joints, LEM assembly, Baker seal bore extension with swivel, made up 2 7/8" inner siting, ZXP packer assembly and HR running tool. 18:30 - 22:00 3.50 TIEBAC P OTHCMP RIH with LEM on 4" Dp to 7,052' 22:00 - 23:30 1.50 TIEBAC P OTHCMP Make up topdrive, break circulation, up wt = 140k, do wt = 95k, slack off slowly while seal assembly and inner string pass through hook hanger assembly, wash down slowly ~ 3 bpm, 450 psi as inner string enters seal bore extension, set down 25k when non locating seal assembly entered the seal bore extension, 300 psi increase, Pulled inner string 10' above seal bore extension, rotate string 3/4 tum and worked torque down, washed down slowly, taking 5-10k as seal assembly entered Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Page 13 of 21 Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABORS 9ES Rig Number: Date From - To Hours 'Task Code NPT ..Phase Description of Operations 6/25/2005 22:00 - 23:30 1.50 TIEBAC P OTHCMP seal bore, set down 30k with seal assembly 9' into seal bore, worked string back up no overpull, washed back down to calculated latch up depth, set down 50k, pulled up to 150k 10k over to confirm LEM was engaged. Set down 40k drop 1 3/4" ball and pump to seat 160 gpm, 815 psi, pressure up to set ZXP packer, and release from setting tool, indication of packer set ~ 4000 psi continue to pressure up to 4,200 psi. Bled pressure to zero picked up on string to confirm HR tool released, up wt 140k set down 50x. Close annular and test ZXP packer to 1,500 psi for 5 min ok. bled of pressure. 23:30 - 00:00 0.50 TIEBAC P OTHCMP POH with inner string and setting tool to 6,872' 6/26/2005 00:00 - 00:30 0.50 TIEBAC P OTHCMP Monitor well, pump dry job. 00:30 -04:00 3.50 TIEBAC P OTHCMP POH with running tool and 2 7/8" inner string. 04:00 - 05:30 1.50 TIEBAC P OTHCMP lay down running tool, rig up 2 7/8" handling equipment, lay down 2 7/8" inner string. 05:30 - 06:00 0.50 TIEBAC P OTHCMP Clear and clean floor. 06:00 - 09:30 3.50 STWHIP P WEXIT Pickup whipstock and milling assembly for OBa lateral per Baker Rep. Orient MWD RIH with 12 4 3/4" drill collars and 18 joints 4' HW to 1,084' 09:30 - 10:00 0.50 STWHIP P WEXIT Shallow test MWD, 280 gpm, 1050 psi, ok. 10:00 - 13:00 3.00 STWHIP P WEXIT RIH with whipstock and milling assembly on 4' Dp to 6,961' 13:00 - 14:30 1.50 STWHIP P WEXIT Make up topdrive, break circulation, orient whipstock to 14L, up wt = 140k, do wt = $OK, wash down slowly, set down 20k on OBb liner tieback with locater sub, to set bottom trip anchor, Picked up 10k to verify anchor set, set down 40k and shear off whipstock. Top of whipstock ~ 6,946' Bottom of whipstock ~ 6,958' 14:30 - 15:30 1.00 STWHIP P WEXIT Displace well over to 9.2 ppg MOBM, 295 gpm, 2,070 psi. 15:30 - 19:00 3.50 STWHIP P WEXIT Mill window from 6,946' to 6,958, 305 gpm, 2145 psi, 2-6k wob, 60 - 100 rpm, torque 5-8k 19:00 - 21:00 2.00 STWHIP P WEXIT Mill formation from 6,958' to 6,976', 305 gpm, 2,150 psi, 2-4k wob 115 rpm, torque 5-6k, 21:00 - 22:00 1.00 STWHIP P WEXIT Pump 35 bbl weighted (11.2 ppg) sweep, rotate mills through window several times, worked through with no rotation, clean window, considerable amount of metal back with sweep. 22:00 - 22:30 0.50 STWHIP P WEXIT Monitor well, Pump dry job. 22:30 - 00:00 1.50 STWHIP P WEXIT POH with milling assembly. 6/27/2005 00:00 - 02:00 2.00 STWHIP P WEXIT POH with window milling assembly. Stand back HWDP & 4 3/4" drill collars. Lay down MWD, mills and bumper sub. Upper string mill in gauge 02:00 - 02:30 0.50 DRILL P PROD3 Clear floor of all milling tools and related equipment, clean floor: 02:30 - 03:30 1.00 DRILL P PROD3 Make up ported sub and flush stack, function rams and annular, blow down kill and choke lines. 03:30 -04:00 0.50 DRILL P PROD3 Pick up directional tools to rig floor, service rig, held PJSM. 04:00 - 06:00 2.00 DRILL P PROD3 Make up 63/4" OBa drilling assembly, Utilizing RR Hycalog DSX146 form previous lateral, AIM motor, bypass sub, 63/4' OD NM stab, NM lead collar,MWD, PWD, ADN, 2 flex drill collars, cir sub, XO, 1 joint 4" DP, jars, 2 jts 4" DP. Shallow test MWD, 242 gpm, 1,100 psi, ok. 06:00 - 09:30 3.50 DRILL P PROD3 RIH with drilling assembly on 4" DP to 6,926' Printed: 7/18/2(x)5 11:22:29 AM BP .EXPLORATION Page 14 of 21 Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task Code NPT Phase Descriptjon of Operations 6/27/2005 09:30 - 11:00 1.50 DRILL P PRODS Make up topdrive, break circulation, circulate bottoms up ~ 271 gpm, 2,165 psi. establish base line ECD, ~ 271 gpm, 60 rpm, calculated ECD 9.96, actual 10.24, ~ 290 gpm, 60 rpm, calculated ECD 9.99, actual 10.33. 11;00 - 12:00 1.00 DRILL P PRODS Directional drill 6.75" hole from 6,976' to 7,020', 5k wob, 290 gpm, 2,480 psi on bottom, 2,400 psi off bottom, up wt = 115k, do wt = 85k, rt wt = 90k. AST = .26 i2:00 - 00:00 12.00 DRILL P PRODS Directional drill 6.75" hole from 7,020' to 8,228', 5-10k wob, 290 gpm, 2,680 psi on bottom, 2,550 psi off bottom, 60 rpm torque on bottom 6.2k, torque off bottom 5.6k, up wt = 131 k, do wt = 76k, rt wt = 82k. Caluculated ECD 10.66 Actual 10.88, AST 3.60 hrs. ART = 1.59 hrs. 6/28/2005 00;00 - 12:00 12.00 DRILL P PRODS Directional drill 6.75" hole from 8,228' to 9,533', 5-10k wob, 290 gpm, 3,000 psi on bottom, 2,820 psi off bottom, 60 rpm torque on bottom 7.6k, torque off bottom 7.3k, up wt = 139k, do wt = 77k, rt wt = 99k. Calculated ECD 10.89 Actual 11.17, AST = 1.55 hrs ART = 2.89 hrs. 12:00 - 00:00 12.00 DRILL P PRODS Directional drill 6.75" hole from 9,533' to 11,027', 5-10k wob, 290 gpm, 3,180 psi on bottom, 3,060 psi off bottom, 60 rpm torque on bottom 7.7k, torque off bottom 7.4k, up wt = 145k, do wt = 54k, rt wt = 95k. Calculated ECD 10.98 Actual 11.17, AST = 1.88 hrs ART = 3.12 hrs. 6/29/2005 00:00 - 07:00 7.00 DRILL P PRODS Directional drill 6.75" hole from 11,027' to 11,886' 5-10k wob, 290 gpm, 3,270 psi on bottom, 3,150 psi off bottom, 60 rpm torque on bottom 7.Sk, torque off bottom 7.6k, up wt = 146k, do wt = 64k, rt wt = 97k. Calculated ECD 11.04 Actual 11.48, AST = t .08 hrs ART = 1.69 hrs. 07:00 - 08:00 1.00 DRILL P PRODS Circulate 2 open hole annular volumes at 289 gpm, 3260 psi, 80 rpm, 7k torque. 08:00 - 16:30 8.50 DRILL P PRODS Backream out from 11,886' to 6,923', 290 gpm, 2,860 psi, 60 rpm 5-7k torque, ~ 30 to 50 fpm. no hole problems during backreaming. 16:30 - 17:00 0.50 DRILL P PRODS Service rig. 17:00 - 17:30 0.50 DRILL P PRODS Cut and slip drilling line. 17:30 - 20:00 2.50 DRILL P PRODS RIH from 6,923' to 11,775', hole clean, no problems. 20:00 - 21:30 1.50 DRILL P PRODS Wash last stand to bottom from 11,775' to 11,886', pump 25 bbl weighted sweep (11.2 ppg) at 290 gpm, 3,250 psi, 100 rpm, 8.2k torque, minimal amont of cuttings increase at bottoms up. 21:30 - 23:00 1.50 DRILL P PRODS Displace well to 9.2 ppg SFMOBM at 290 gpm, 3250 psi, 100 rpm Bk torque, Flnal ECD prior to POH calculated 11.07, actual 11.10. 23:00 - 00:00 1.00 DRILL P PRODS Monitor well, POH from 11,886' to 11,213' 6/30/2005 00:00 - 01:30 1.50 DRILL P PRODS POH from 11,213' to 6,904', pulled smooth, no problems, hole took proper fill. 01:30 - 02:00 0.50 DRILL P PRODS Drop 1 3/4" ball to open circ sub, pump to seat ~ 220 gpm 1,440 psi, sheared ~ 1500 psi, pump dry job. 02:00 -04:30 2.50 DRILL P PRODS POH from 6,904' to 302' monitor well ~ BHA 04:30 -06:30 2.00 DRILL P PRODS PJSM, stand back jars and flex collars, recover sources, lay down MWD, motor and bit. 06:30 - 07:00 0.50 WHIP P RUNPRD Clear and clean floor, pickup whipstock retriving tools to rig floor. 07:00 - 09:00 2.00 WHIP P RUNPRD Make up Baker fixed lug retriving tool, 1 jt 3.5' HWDP, float sub, MWD, bumper sub, fishing jar, 12 4 3/4" drill collars, XO, Printed: 7/18/2005 11:22:29 AM • BP EXPLORATION Page 15 of 21 Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Date From - To ~ Hours Task 'Code NPT Phase Description of Operations 6/30/2005 07:00 - 09:00 2.00 WHIP P RUNPRD 18 joints 4' HWDP to 1,012' 09:00 - 09:30 0.50 WHIP P RUNPRD Shallow test MWD, 260 gpm, 800 psi, ok. 09:30 - 12:30 3.00 WHIP P RUNPRD RIH from 1,012' to 6,889', fill pipe ~ 4,000' 12:30 - 13:00 0.50 WHIP P RUNPRD Make up topdrive and break circulation, orient retrieving lug Cat 14L, (detection problems with MWD) Up wt = 142k, do wt = S6K, work down to 6,953', Picked up to engage fish, pulled up to 178K, allow jars to bleed open, pulled up 235k before bottom trip anchor released, pulled seals from from seal bore extension, 160k up. Once out of tie back extension up wt = 145k, hole took 3 bbls with seals pulled from tie back, monitor well, static. 13:00 - 14:00 1.00 WHIP P RUNPRD Circulate bottoms up ~ 290 gpm, 1980 psi, no gas at bottoms up. 14:00 - 17:00 3.00 WHIP P RUNPRD Monitor well, pump dry job and POH with whipstock to 1,012'. 17:00 - 20:30 3.50 WHIP P RUNPRD Stand back 4" HWDP and 4 stands 4 3/4" drill collars, lay down retriving lug, break and lay down whipstock and related tools. 20:30 - 21:00 0.50 WHIP P RUNPRD Clear and clean floor. 21:00 - 22:00 1.00 CASE P RUNPRD Rig up to run 4.5" slotted OBa liner, PJSM with all rig personnel. 22:00 - 00:00 2.00 CASE P RUNPRD Run 4.5" 12.6# L-80 BTC -IBT slotted liner to 1,006', per running detail, dope with BOL 2000, make up torque 2,400 ft/Ibs. 7!1/2005 00:00 -04:00 4.00 CASE P RUNPRD Continue running 4.5" 12.6# L-80 BTC OBa slotted liner per running detail, make up Baker hook hanger assembly. Up wt 78k, do wt = 64k. Ran a total of 102 joints 4.5" 12.6# L-80 BTC slotted liner, 1 4.5" 12.6# L-80 Slotted BTC X IBT crossover joint, 6 joints 4.5" 12.6# L-80 IBT solid liner, 2 4.5" 12.6# L-80 BTC X IBT solid crossover joints, 2 4.5" L-80 IBT X BTC solid crossover joints, 2 swell packers, Baker hook hanger, 1 4.5" 12.6# L-80 IBT bent joint with float shoe and 1 4.5" 12..6# L-80 IBT space out pup. Ran a total of 115, 5 314" straight blade rigid centralizers. 04:00 -04:30 0.50 CASE P RUNPRD Rig down finer running equipment. 04:30 - 05:30 1.00 CASE P RUNPRD RIH with 4.5" slotted liner on 4" DP to 6,891' 05:30 - 06:00 0.50 CASE P RUNPRD Make up topdrive, break circulation, 2 bpm ~ 160 psi, up wt = 109k, do wt = 75k, wash down and position bent joint at the middle of the window ~ 6,952', rotate string 3/4 tum, run bent joint through window. no excess down drag. 06:00 - 10:00 4.00 CASE P RUNPRD Continue RIH with 4.5" Liner on 4" DP to i 1,818', recording up and down weights every 500' in open hole. 10:00 - 10:30 0.50 CASE P RUNPRD Make up topdrive, slowly slack off to engage hook wall hanger, ran in 10' past bottom of the window, pulled 10' above top of the window. Up wt = 173k, do wt = 83k, rotate string 3/4 tum and work torque down, slack off slowly engaged hook wall hanger on second attempt, set down 15k, picked up several times to confirm hanger hooked, Picked up above window up wt 185k, rotate string 1/2 turn, and worked hanger 10' past bottom of window, pulled back up and oriented pipe, re-engaged hook hanger at the same depth set down 35k. 10:30 - 11:00 0.50 CASE P RUNPRD Drop 29/32" ball and pump to seat, 2 bpm 400 psi, pressured up to 2,700 psi to release setting tool, picked up to confirm released, pressure up to 3,200 psi and sheared ball seat. Pulled setting tool from Hook hanger up wt 145k. Printed: 7/18/2005 11:22:29 AM BP EXPLORATION Page 16 of 21 Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABORS ALASKA DRiLLtNG I Rig Release: Ili 1/2005 Rig Name: NABORS 9ES Rig Number: Date From. - To Hours Task 'Code NPT Phase Description of Operations 7/1/2005 11:00 - 12:00 1.00 CASE P RUNPRD Circulate bottoms up 160 gpm, 610 psi. 12:00 - 16:00 4.00 CASE P RUNPRD Monitor well, pump dry job, POH with hook hanger running tool. break and lay down same. 16:00 - 17:00 1.00 CASE P RUNPRD Service rig and topdrive, change out topdrive saver sub. 17:00 - 18:00 1.00 CASE P RUNPRD Rig up to run OBa LEM and inner string. 18:00 - 18:30 0.50 CASE P RUNPRD PJSM with all rig personnel, picking up LEM. 18:30 - 20:30 2.00 CASE P RUNPRD Make up, non locating seal assembly, 2 4.5" 12.6# IBT pup joints, LEM assembly, Baker seal bore extension with swivel. Rlg up false rotary table and 2 7/8" handling equipment. Make up 2 7/8" inner siting, ZXP packer assembly and HR running toot, per Baker rep. 20:30 - 00:00 3.50 CASE P RUNPRD RIH with OBa LEM and inner string on 4" DP to 3,899' 7/2/2005 00:00 - 01:00 1.00 CASE P RUNPRD Continue running OBa LEM on 4" DP from 3,899' to 6,960' 01:00 - 01:30 - 0.50 CASE P RUNPRD Make up topdrive and break circulation, 2 bpm, 430 psi. up wt 147k, do wt = 101 k, wash down slowly from 6,960', saw slight pressure increase (50 psi) as inner string entered seal bore extension, continue washing down slowly, began taking weight I, 5-10k 4' from latching up, set down 30k, Pulled up to neutral weight 145k, latched up at calculated depth, pulled up to 160K to confirm latch, slack off to neuteral weight 145k. 01:30 - 02:00 I 0.50 CASE P RUNPRD Drop 13/4" ball and pump to seat ~ 3 bpm 775 psi, pressure up positive indication of packer setting C~ 2,500 psi, (gained 15K weight) continue pressuring up to 3,200 psi to release setting tool, held pressure for 3 min, pressrue up to 4000 psi, set down 30k to equalize pressure, bleed pressure to zero, Picked up on string to confirm release, up wt 142k. 02:00 - 02:30 0.50 CASE P RUNPRD Close annular and pressure up on annulus to 1,500 psi, good test. POH to 6,860'. 02:30 - 06:30 4.00 CASE P RUNPRD Monitor well, pump dry job, POH with 2 7/8" inner string and running toot. 06:30 - 07:30 1.00 CASE P RUNPRD Lay down LEM running tool and 2 7/8" inner string 07:30 - 08:30 1.00 CASE P RUNPRD Clear floor of all liner running equipment, clean floor. 08:30 - 09:00 0.50 STWHIP P WEXIT Pickup window milts and whipstock relaeted tools to rig floor. 09:00 - 12:30 3.50 STWHIP P WEXIT Pickup whipstock and milling assembly for OA lateral per Baker Rep. Orient MWD RIH with 12 4 3/4" drill collars and 18 joints 4' HW to 1,202' 12:30 - 13:00 0.50 STWHIP P WEXIT Shallow test MWD, 255 gpm, 860 psi, ok. 13:00 - 16:30 3.50 STWHIP P WEXIT RIH with OA whipstock & milling assembly from 1,202' to 6,741'. 16:30 - 17:00 0.50 STWHIP P WEXIT Make up topdrive, break circulation, up wt = 145k, do wt = 85k, orient whipstock 16L, wash down to top of OBb liner tie back extension ~ 6,885' set down 20k to set bottom trip anchor, picked up to verify anchor set, set down 35k to shear off wipstock. Top of Whipstock ~ 6,781' Bottom of Whipstock ~ 6,793' 17:00 - 17:30 0.50 STWHIP P WEXIT Close annular, pressure up on Backe side to 1,500 psi to ensure seals properly set in tie back extension, ok. 17:30 - 18:30 1.00 STWHIP P WEXIT Displace well to 9.2 ppg SFMOBM, 300 gpm, 2,130 psi. 18:30 - 22:30 4.00 STWHIP P WEXIT Mill window for OA lateral from 6781' to 6,793', 2-4k wob, 300 gpm, 1950 psi, 75 rpm, torque 7k, good metal returns during milling operation, pumped 25 bbl weighted sweep Printed: 7/18/2005 71:22:29 AM • BP EXPLORATION Page 17 of 21' Operations Summary Report Legal Well Name: L-202 Common Welt Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Date From- To Hours- Task Code NPT Phase Description ofiOperations 7/2/2005 18:30 - 22:30 4.00 STWHIP P WEXIT (super-sweep) ~ 6,793' slight increase of metal cuutings. 22:30 -00:00 1.50 STWHIP P WEXIT Mill formation from 6,793' to 6,810', 2-7k wob, 300 gpm, 1950 psi, 105 rpm torque 5k. 7/3/2005 00:00 - 01:00 1.00 STWHIP P WEXIT Pump 25 bbl weighted (11.2 ppg) sweep, (Super Sweep)rotate mills through window several times, worked miils through window several times with no rotation, no problem. slight increase in metal cuttings with sweep, Monitor well. 01:00 - 01:30 0.50 STWHIP P WEXIT POH from 6,810' to 6,698' 01:30 - 02:30 1.00 STWHIP P WEXIT Cut and slip drilling line. 02:30 - 03:00 0.50 STWHIP P WEXIT Pump dry job. 03:00 - 06:00 3.00 STWHIP P WEXIT POH with window milling assembly. 06:00 - 06:30 0.50 STWHIP P WEXIT Lay down mills, bumper sub and MWD. Upper string mill in gauge. 06:30 - 07:00 0.50 STWHIP P WEXIT Lay mills and related equipment off floor. Pull wear ring. 07:00 - 07:30 0.50 BOPSU P WEXIT Make up ported sub, flush stack, function rams and annular. 07:30 - 08:30 1.00 BOPSU P WEXIT Drain stack, blow down mud line, choke and kill lines, Install test plug, rig up BOP test equipment. 08:30 - 12:00 3.50 BOPSU P WEXIT Test ROPE to 250 psi low, 3,500 psi high, per testing procedure. Chuck Scheeve with AOGCC waived witness of BOP test. Test was witnessed by WSL Bill Decker, Nabors Toolpusher Bill Bixby. 12:00 - 13:00 1.00 BOPSU P WEXIT Blow down choke, choke line and kill line, pull test plug and install wear ring. 13:00 - 15:00 2.00 DRILL P PROD4 Make up 6 3/4" OA drilling assembly, Utilizing RR Hycafog DSX146 form previous 3 laterals, AIM motor, bypass sub, 6 3/4' OD NM stab, NM lead collar,MWD, PWD, ADN, 2 flex drill collars, cir sub, XO, 1 joint 4" DP, jars, 2 jts 4" DP to 570' Shallow test MWD, 291 gpm, 1,380 psi, ok. 15:00 - 18:00 3.00 DRILL P PROD4 RIH with OA lateral drilling assembly on 4" DP from 570' to 6,750', fill DP ~ 3,567' 18:00 - 19:30 1.50 DRILL P PROD4 Circulate bottoms up ~ 290 gpm, 2360 psi, obtain ECD bench mark, Calculated ECD 10.32 19:30 - 20:30 1.00 DRILL P PROD4 Orient motor, slide through window with no pump to 6,800' ream from 6,800' to 6,810' with motor. 20:30 - 00:00 3.50 DRILL P PROD4 Directional drill 6 75" hole by sliding from 6,810' to 7,020', 5-10k wob, 290 gpm, 2,400 psi on bottom, 2300 psi off bottom, up wt = 120k do wt = 81 k, Calculated ECD 10.24, Actual 10.12 AST = 1.7 hrs. 7/4/2005 00:00 - 12:00 12.00 DRILL P PROD4 Directional drill 6.75" hole from 7,020' to 8,506' S-10k wob, 290 gpm, 2,750 psi on bottom, 2,600 psi off bottom, 60 rpm torque on bottom 6.7k, torque off bottom 5.3k, up wt = 128k, do wt = 78k, rt wt = 98k. Pumped 15 bbl weighted (11.2) sweep ~ 7,900' no visible increase in cuttings. Calculated ECD 10.29 Actual 10.53, AST = 1.5 hrs ART = 3.28 hrs. 12:00 - 15:30 3.50 DRILL P PROD4 Directional drill 6.75" hole from 8,506' to 8,941' 5-10k wob, 290 gpm, 2,800 psi on bottom, 2,650 psi off bottom, 60 rpm torque on bottom 6.4k, torque off bottom 5.7k, ECD began climbing at 8900' Calculated ECD 10.45, actual 11.17. 15:30 - 17:30 2.00 DRILL P PROD4 Pump 15 bbl high vis sweep around ~ 290 gpm, 2700 psi, 60 rpm, approximately 30% increase in cuttings, ECD dropped to 10.65 17:30 - 00:00 6.50 DRILL P PROD4 Directional drill 6.75" hole from 8,941' to 9,440', Pumped 15 bbl high vis sweeps ~ 9,000' & 9,250' no visible increase in Printed: 7/16/2005 11:22:29 AM BP EXPLORATION Operations Summary Report Page 18 of 21, Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABORS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABORS 9ES Rig Number: Date ~ From - To ~ Hours ~ Task I Code ~ NPT Phase 7/4/2005 17:30 - 00:00 6.50 DRILL P I PROD4 17/5/2005 00:00 - 06:00 6.00 DRILL P i i I PROD4 06:00 - 07:00 1.00 DRILL P PROD4 07:00 - 12:30 5.50 DRILL P i I ~ PROD4 12:30 - 13:00 0.50 DRILL I i P I PROD4 13:00 - 13:30 0:50 DRILL P ! ! PROD4 13:30 - 16:00 2.50 DRILL P PROD4 16:00 - 16:30 0.50 DRILL P PROD4 16:30 - 18:00 1.50 DRILL P ~ PROD4 18:00 - 20:00 2.00 DRILL P PROD4 20:00 - 22:00 2.00 DRILL P PROD4 22:00 -00:00 2.00 DRILL P PROD4 7/6/2005 00:00 -04:00 4.00 DRILL P PROD4 04:00 - 06:00 2.00 DRILL P PROD4 06:00 - 07:30 1.50 WHIP P RUNPRD 07:30 - 09:30 2.00 WHIP P RUNPRD 09:30 - 10:00 0.50 WHIP P RUNPRD 10:00 - 11:00 1.00 WHIP P RUNPRD Description of Operations cuttings, YP increased from 16 to 23 due to sweeps. 5-10k wob, 290 gpm, 2830 psi on bottom, 2,760 psi off bottom, 60 rpm, torque 6.4k on bottom, 5.7k off bottom, up wt = 124k, do wt = 76k, rt wt = 98k, Calculated ECD 10.83, actual 11.12. AST = 1.0 hrs, ART = 2.52 hrs. Directional drill 6.75" hole from 9,440', to 10,345', 5-10k wob, 290 gpm, 2,975 psi on bottom, 2,805 psi off bottom, 60 rpm, torque 7.5k on bottom, 6.5k off bottom, up wt = 131 k, do wt = 68k, rt wt = 92k, Calculated ECD 10.98, actual 11.37. AST = 1.13 hrs, ART = 2.37 hrs. Circulate 2 x bottoms up, 300 gpm, 3,000 psi, 80 rpm. Calculated ECD - 10.98, Actual ECD - 11.24. PU - 145k, SO - 77k without pumps. Monitor welt -stable. Backream from 10,345' to 8,930' - TO 6.5k, 300 gpm, 60 rpm. The hole started to pack off at 8,930' while backreaming. Work pipe back down to 8,972'. Shut off the pumps and rotary and pull dry from 8,972' to 8,879' - 15k overpull. RIH to 8,972'. Backkream to 8,879'. Shut off the pumps and rotary and pull dry from 8,879' to 8,785'. RIH to 8,879'. Backream to 8,600' without problem. RIH from 8,600' to 8,972' without problems. POH from 8,972' to 8,600', PU - 135k, SO - 87k -minimal overpull. Backream from 8,600' to 7,113', TO - 6.5k, 300 gpm, 60 rpm. Circulate bottoms up - 300 gpm, 2,500 psi, 60 rpm, TO - 4k. Pull pipe into the window to 6,740' - no problems. Cut and slip 85' of drilling line. Service the top drive, draw works, crown and blocks. RIH from 6,740' to 10,345'. Wash the last stand to bottom. No problems. Circulate open hole volume and hi visc/weighted sweep from surface to surface - 300 gpm, 3,100 psi, 80 rpm, TO - 6.3k. Circulate additional bottoms up to ensure hole clean prior to displacement to SFMOBM. Displace the 9.2 ppg MOBM to 9.2 ppg SFMOBM - 300 gpm, 3,100 psi, 80 rpm, TO - 6.3k. POH from 10,345' to 6,740'. Open up the circ sub and pump a dry job. POH from 6,740' to the top of the BHA at 303'. PJSM. LD 6-3/4" OA BHA - 2 jts 4" DP, jars, 1 joint 4" DP, XO, circ sub, 2 flex drill collars, ADN, PWD, MWD, NM lead collar, 6 3/4' OD NM stab, bypass sub, AIM motor, 6-3/4" RR DS146h+gjnw. Bit graded: 0 / 2 / WT / G / X / I / ER / TD. Clear and clean the floor. MU Whipstock #3 Retrieving BHA to 1,012' -fixed lug retrieving tool, 1 x 3.5" HW DP, float sub, MWD, bumper sub, fishing jar, 12 x 4-3/4" drill collars, xo, 18 x 4" HWDP. RIH to 6,750' to retrieve Whipstock #3 PU - 134k, SO - 85k. Orient the retrieving tool to 16 left. Work the lug down the whipstock face. Latch into the retrieval slot. PU to 200k and fire the fishing jars. Pull free with PU - 145k. Lost approximately 3 bbls of fluid when the whipstock released. POH to 6,724'. Circulate bottoms up - 3 bpm, 550 psi. Monitor well -stable. Printed: 7/18/2005 11:22:29 AM • BP EXPLORATION Page 19 of 21 Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task. Code. NPT Phase Description of Operations 7/6/2005 11:00 - 14:30 3.50 WHIP P RUNPRD POH from 6,724 to 1,012' 14:30 - 17:30 3.00 WHIP P RUNPRD Stand back 18 x 4" HWDP and 12 x 4-3/4" drill collars. LD remaining Whipstock #3 Retrieving BHA -fishing jar, bumper sub, MWD, float sub, 1 x 3.5" HWDP, fixed lug retrieving tool, whipstock #3. 17:30 - 19:00 1.50 CASE P RUNPRD PU 12 x drill collars and stand back in the derrick. 19:00 - 20:00 1.00 CASE P RUNPRD RU to run 4.5" OA liner. 20:00 - 00:00 4.00 CASE P RUNPRD PJSM. PU 4.5", 12.6#, L-80, BTC Slotted /IBT-M Solid liner. Utilized Best-o-I{fe 2000 thread lubricant on each connection and torqued to the mark - 3,400 ftlbs BTC, 3,000 ftlbs IBT-M. 7/7/2005 00:00 - 02:00 2.00 CASE P RUNPRD Continue PU 4.5", 12.6#, L-80, BTC Slotted /IBT-M Solid liner. Utilized Best-o-life 2000 thread lubricant on each connection and torqued to the mark - 3,400 ftlbs BTC, 3,000 ftlbs IBT-M. MU Hookwall Hanger and RIH on 4" DP to the window C~ 6,781'. 02:00 - 05:00 3.00 CASE P RUNPRD RIH past the window and tag up on tieback sleeve #2 at 6,898'. POH and stand back 1 stand. Place the shoe in the middle of the window and apply 1 wrap to the pipe. Exit the window. Continue RIH with 4.5" liner on 4" DP, HWDP and 4-3/4" collars. 05:00 - 06:00 1.00 CASE P RUNPRD PU - 161 k, SO - 90k. RIH 10' past the bottom of the window to 6,803'. PU 12' above the window and apply 1/4 turn to the pipe. Repeat. RIH 10' past the bottom of the window. PU 12' above the window and apply 1/4 turn to the pipe. RIH and land the hookwall hanger on the bottom of the window at 6,793'. PU 12' and apply 1/2 turn. RIH to 10' past the bottom of the window. PU 12' above the window and apply 1/4 turn to the pipe. RIH 10' past the bottom of the window. PU 12' above the window and apply 1/4 tum to the pipe. RIH and re-land the hookwall hanger with 65k. Drop the ball. Pump the ball down on seat. Pressure up to 3,000 psi to release the hanger, PU - 144k, verifying release. Increase pressure to 4,000 psi to blow the ball seat. 06:00 - 07:00 1.00 CASE P RUNPRD Monitor the well -stable. Circulate bottoms up at 340 gpm, 2,244 psi. Pump dry job. 07:00 - 11:00 4.00 CASE P RUNPRD POH standing back HWDP, dc's and 4" DP. LD hookwall hanger running tool. Clear and clean the floor. 11:00 - 13:30 2.50 TIEBAC P OTHCMP Bring LEM #3 tools and materials to the rig floor. MU non-locating seal assy, xo joint, 1 joint 4.5", 12.6#, L-80, IBT-M liner, 2 pups, LEM hanger, pup, casing swivel, xo and zxp packer with 11' tieback with 11' of 2-3/8" inner string. 13:30 - 18:00 4.50 TIEBAC P OTHCMP R1H with LEM assy on 4" DP, HWDP and drill collars to 6,888'. 18:00 - 19:30 1.50 TIEBAC P OTHCMP PU - 142k, SO - 103k. Screw in with the top drive and wash down into the seal lwre extension. Observed intermittent 10k-15k drag. Continue down and engage the LEM. PU 15k to verify engagement. SO 35k and drop ball. Pump the ball on seat and pressure up to 4,000 psi to release the LEM and set the packer - no surface indication of packer set. PU and verity LEM release -released. Bleed off pressure from the drill pipe. Attempt liner top test to 1,500 psi - no go. Bleed pressure off of the back side. Apply 4,500 psi down the drill pipe to set packer. Bleed off pressure. Attempt 1,500 psi liner top test - no go. Printed: 7/18/2005 17:22:29 AM ~ ~ BP EXPLORATION _ Page 20 of 21 Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6/5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABOBS ALASKA DRILLING 1 Rig Release: 7!1112005 Rig Name: NABOBS 9ES Rig Number: Date From - To Hours Task .Code NPT Phase Description of Operations 7!7!2005 19:30 - 21:00 1.50 TIEBAC P OTHCMP PU and expose dogs. Set down 70k to set packer - no surface indication. PU and apply 12 rpm with 50k SO. Repeat. Attempt to test liner top packer by applying 1,500 psi down the backside - no go. Bleed off pressure. Apply 1,500 psi on the drill pipe and lock it in. Apply 1,500 psi down the backside to test the liner top packer -chart and hold for 30 minutes -good test. 21:00 - 21:30 0.50 TIEBAC P OTHCMP LD single and stand back 2 stands of 4" DP in the derrick. 21:30 - 23:00 1.50 TIEBAC P OTHCMP Pump 30 bbls of LVT, 25 bbls of hi-visc brine, 50 bbls of Safe-O spacers and displace the well over to 9.3 ppg brine. 23:00 - 00:00 1.00 TIEBAC P OTHCMP Clean under the shakers and the troughs. 7/8/2005 00:00 - 01:00 1.00 TIEBAC P OTHCMP Continue to clean under shakers and troughs 01:00 - 08:30 7.50 TIEBAC P OTHCMP Pump dry job. LD HWDP, drill collars and 4" DP. LD LEM running tools and inner string. 08:30 - 09:30 1.00 TIEBAC N HMAN OTHCMP PU 1 stand of 4" DP and MU mule shoe. Pull stripping rubbers. Dropped a 1" thick x 3' long nylon sling down the ~ , hole. Did not see the sling floating in the stack. Pump through the line -did not find the sling. RIH with one stand of 4" DP. I Circulate at 7 bpm, 60 psi and check the possum belly, flow lines, troughs and pill pit -did not find sling. Notify town and call out Slickline for fishing operation 09:30 - 10:30 1:00 TIEBAC P OTHCMP Service and lubricate the top drive, draw works, blocks and crown. 10:30 - 14:30 4.00 TIEBAC N HMAN OTHCMP Clean rig of the MOBM while waiting on Slickline. 14:30 - 20:30 6.00 TIEBAC N HMAN OTHCMP PJSM. RU slickline. RIH with 4 prong rope grabber to 6,738'. POH. Recovered dropped sling. RD slickline. 20:30 - 22:00 1.50 TIEBAC P OTHCMP RIH with 4" DP from the derrick to 6,600'. 22:00 - 22:30 0.50 TIEBAC P OTHCMP Circulate DP volume to clean out DP prior to laying down. 22:30 - 23:30 1.00 TIEBAC P OTHCMP Cut and slip 78' of drilling line. 23:30 - 00:00 0.50 TIEBAC P OTHCMP LD 4" DP from 6,600'. 7/9/2005 00:00 -04:30 4.50 TIEBAC P OTHCMP Continue to LD 4" DP from 6,600'. 04:30 - 05:30 1.00 BUNCO RUNCMP Pull wear ring and make dummy run with tubing hanger. 05:30 - 08:00 2.50 BUNCO RUNC(YIP RU 4.5" tubing handling tools, tongs, elevators and slips. MU floor safety valve. PU I-wire spool and hang sheave in the derrick. 08:00 - 18:00 10.00 BUNCO RUNCMP MU 4.5" 12.6# L-80 IBT-M completion and RIH to 6,651'. 4.5" completion includes: WLEG/X asst' (3.813" ID), X asst' (3.813" ID) w/RHC-m profile, 7.625" x 4.5" Baker Premier Packer asst', 4.5" Phoenix Jet Pump gauge asst', 4.5" Baker CMD/Phoenix 7" Discharge Pressure gauge asst', 3 - 4.5" x 1" KBG-2 GLM's w/DV, 1 - 4.5" x 1" KBG-2 GLM's w/DCK SV, 155 joints of 4.5" 12.6# L-80 IBT-m tubing and X asst' (3.813" ID). Utilized BOL 2000 NM thread lubricant and torqued connections to mark with 3,200 ftlbs average make-up torque. Connections below the packer asst' have been Bakerlok'd. I-wire run from the Phoenix pressure gauge to surface 18:00 - 20:30 2.50 BUNCO RUNCMP MU 2 additional joints of 4.5" tubing and tag up at 6,759'. LD the 2 additional joints + joint #155 of 4.5' tubing. Add spaceout pups of lengths: 9.81', 9.80', 7.81', 3.81', 2.84' and 1.91'. PU joint #155 and RIH. MU the tubing hanger (1' of blast rings on pup below the hanger held in place with a stop collar). Run 1-wire through the hanger and lock in place. Cut I-wire above hanger and secure to landing joint. Land the tubing on the Printed: 7/18/2005 17:22:29 AM BP EXPLORATION Page 21 of 21 Operations Summary Report Legal Well Name: L-202 Common Well Name: L-202 Spud Date: 6!5/2005 Event Name: DRILL+COMPLETE Start: 6/3/2005 End: 7/11/2005 Contractor Name: NABOBS ALASKA DRILLING I Rig Release: 7/11/2005 Rig Name: NABOBS 9ES Rig Number: Date »Frorn = To Hours Task .Code NPT ' Phase Description of Operations 7/9/2005 18:00 - 20:30 2.50 BUNCO RUNCMP hanger. Run in the lock down screws, RU circulation lines. WLEG - 6758' X Profile - 6730' X Profile w/RHC-M - 6710' Premier Packer - 6643' Jet pump sensor - 6619' CMD Non-elastomer sliding sleeve - 6595' Discharge pressure gauge - 6585' GLM#1 w/DCK -6479' GLM#2 - 6036' GLM#3 - 5007' GLM#4 - 3024' X Profile - 2258' Ran 85 clamps and 2 SS bands 20:30 - 21:30 1.00 BUNCO RUNCMP Reverse circulate 106 bbls of 9.3 ppg brine, 5 bbls of 9.3 ppg i brine w/corrosion inhibitor and 170 bbls of 9.3 ppg brine to spot brine with corrosion inhibitor between the GLM with the shear valve and the packer. 21:30 - 00:00 2.50 BUNCO RUNCMP Break out the circulation head on the rig floor. Drop the 1-7/8" ball and rod w/rollers and allow to seat in the RHC-m plug at 6710'. Pressure up on the tubing to 4,200 psi to set the packer. Bleed off pressure to 3,500 psi -chart and hold for 30 minutes -good test. Bleed pressure on the tubing down to 2,500 psi. Pressure up on the annulus to 3,500 psi -chart and hold for 30 minutes -good test. Bleed pressure on the annulus to 0 psi and then bleed the pressure to 0 psi on the tubing. Pressure up on the annulus to 3,100 psi and observe the shearing of the DCK in the GLM at 6479'. Ensure circulation down the tubing and up the annulus. 7/10/2005 00:00 - 01:30 1.50 BUNCO RUNCMP Blow down circulation lines. Install TWC and test from below to 1,000 psi -good test. 01:30 - 03:00 1.50 BUNCO RUNCMP RU super sucker line to the rig floor and remove fluids from under the rotary table, pipe racks and mouse hole plate. 03:00 - 18:00 15.00 BUNCO RUNCMP RU "hotsy" and man rider basket. Scrub derrick and pit complex of MOBM. 18:00 - 20:00 2.00 BOPSU P WHDTRE ND BOPE. 20:00 - 00:00 4.00 WHSUR P WHDTRE NU adapter flange with I-wire penetration. NU 4-1/8" carbon tree. Test tree to 5,000 psi -good test. Pull TWC with DSM lubricator. RU to reverse circulate. 7/11/2005 00:00 - 00:30 0.50 WHSUR P WHDTRE RU circulation lines. Test to 3,000 psi -good. 00:30 - 01:30 1.00 WHSUR P WHDTRE Reverse circulate 106 bbls of 9.3 ppg brine + corrosion inhibitor. 01:30 -04:00 2.50 WHSUR P WHDTRE RU LRHOS and reverse circulate 101 bbls of diesel freeze protection fluid. Allow fluids to U-tube. RD LRHOS. 04:00 - 06:30 2.50 WHSUR P WHDTRE Install BPV and test from below to 1,000 psi. Remove annulus working valves from the OA and the IA. Install VR plugs in tubing spool outlets. Release rig to L-03 ~ 0630 hours. Printed: 7/18/2005 11:22:29 AM ^ www^ ~ w w , m.. 3~` ~-cuc~ ~ ~urveY rcepvrt Report Date: 23-Jun-05 Survey / DLS Computation Method: Minimum Curvature / Lubinski Client: BP Exploration Alaska Vertical Section Azimuth: 35.000° Field: Prudhoe Bay Unit - WOA Vertical Section Origin: N 0.000 ft, E 0.000 ft Structure I Slot: L-PAD / L-202 TVD Reference Datum: Rotary Table Well: L-202 TVD Reference Elevation: 77.30 ft relative to MSL Borehole: L-202L1 Sea Bed I Ground Level Elevation: 48.00 ft relative to MSL UWIIAPI#: 500292322960 Magnetic Declination: 24.571° Survey Name I Date: L-202L1 /June 23, 2005 Total Field Strength: 57574.067 nT Tort / AHD I DDI / ERD ratio: 378.514° / 9799.12 ft / 6.990 / 2.130 Magnetic Dip: 80.843° Grid Coordinate System: NAD27 Alaska State Planes, Zone 04, US Feet Declination Date: June 23, 2005 Location LaULong: N 70 21 2.394, W 14919 27.488 Magnetic Declination Model: BGGM 2005 Location Grid N/E Y/X: N 5978293.250 ftUS, E 583223.800 ftUS North Reference: True North Grid Convergence Angle: +0.63635414° Total Corr Mag North •> True North: +24.571 ° Grid Scale Factor: 0.99990787 Local Coordinates Referenced To: Well Head L J Comments Measured Inclination Azimuth Sub-Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de 1100 tt ftUS ftUS rt i c u.vu u.uu u.UU -/ r.su u.uu u.uu U.UU U.UU U.UU U.UU U.UU b9/tl293.Zb bt33213.tSU N /U 11 2.394 W 149 19 27.488 First MW D+IFR+MS 300.84 0.34 25.11 223.54 300.84 0.88 0.89 0.89 0.81 0.38 0.11 5978294.06 583224.17 N 70 21 2.402 W 149 19 27.477 391.65 0.36 9.86 314.35 391.65 1.40 1.44 1.44 1.33 0.54 0.10 5978294.59 583224.33 N 70 21 2.407 W 149 19 27.472 576.28 0.53 10.49 498.97 576.27 2.71 2.88 .2.86 2.74 0.80 0.09 5978296.00 583224.57 N 70 21 2.421 W 149 19 27.464 670.46 0.56 14.93 593.15 670.45 3.53 3.77 3.75 3.62 0.99 0.05 5978296.88 583224.75 N 70 21 2.429 W 149 19 27.459 764.71 2.54 25.42 687.36 764.66 6.03 6.32 6.28 5.95 2.01 2.11 5978299.22 583225.74 N 70 21 2.452 W 149 19 27.429 857.53 4.53 18.44 780.00 857.30 11.57 12.03 :,,11.99 11.28 4.05 2.19 5978304.58 583227.73 N 70 21 2.505 W 149 19 27.369 953.21 6.95 15.51 875.19 952.49 20.65 21.60 .21.55 20.45 6.80 2.55 5978313.77 583230.37 N 70 21 2.595 W 149 19 27.289 1047.74 10.47 16.79 968.62 1045.92 34.20 35.91 35.85 34.19 10.81 3.73 5978327.55 583234.23 N 70 21 2.730 W 149 19 27.172 1142.12 13.77 15.29 1060.88 1138.18 52.93 55.73 55.66 53.24 16.25 3.51 5978346.66 583239.45 N 70 21 2.917 W 149 19 27.013 1236.19 16.95 13.24 1151.58 1228.88 76.21 80.64 80.55 77.39 22.34 3.43 5978370.88 583245.28 N 70 21 3.155 W 149 19 2~ 1330.83 19.13 11.06 1241.56 1318.86 103.20 109.94 109.80 106.04 28.48 2.41 5978399.59 583251.10 N 70 21 3.436 W 149 19 2 . 1425.26 20.68 12.40 1330.35 1407.65 132.74 142.09 141.91 137.51 35.03 1.71 5978431.13 583257.29 N 70 21 3.746 W 149 19 26.464 1520.69 23.94 14.64 1418.62 1495.92 166.45 178.31 178.12 172.72 43.54 3.53 5978466.42 583265.42 N 70 21 4.092 W 149 1926.215 1617.99 23.95 13.68 1507.55. 1584.85 203.36 217.80 217.61 211.00 53.20 0.40 5978504.81 583274.65 N 70 21 4.469 W 149 19 25.933 1712.21 28.23 11.54 1592.15 1669.45 241.64 259.22 259.01 251.44 62.19 4.65 5978545.34 583283.18 N 70 21 4.866 W 149 19 25.670 1806.43 30.66 12.06 1674.19 1751.49 284.21 305.53 305.30 296.77 71.67 2.59 5978590.77 583292.16 N 70 21 5.312 W 149 19 25.393 1900.26 33.39 12.61 1753.74 1831.04 330.12 355.28 355.04 345.37 82.30 2.93 5978639.48 583302.25 N 70 21 5.790 W 149 19 25.082 1995.66 38.73 11.57 1830.83 1908.13 381.81 411.42 411.16 400.27 94.03 5.63 5978694.50 583313.37 N 70 21 6.330 W 149 19 24.740 2090.94 43.52 10.77 1902.58 1979.88 439.11 474.07 473.78 461.73 106.14 5.06 5978756.09 583324.80 N 70 21 6.935 W 149 19 24.385 2184.89 47.07 11.00 1968.66 2045.96 500.05 540.83 540.50 527.29 118.75 3.78 5978821.78 583336.68 N 70 21 7.579 W 149 19 24.017 2279.02 50.58 11.89 2030.63 2107.93 564.99 611.67 611.33 596.72 132.83 3.80 5978891.35 583349.98 N 70 21 8.262 W 149 19 23.606 2372.26 54.00 12.29 2087.65 2164.95 632.93 685.42 685.08 668.84 148.28 3.68 5978963.63 583364.63 N 70 21 8.971 W 149 19 23.154 SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-202\L-202\L-202L1\L-202L1 Generated 7/5/2005 4:17 PM Page 1 of 7 Comments Measured Inclination Azimuth Sub•Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft ft de /700 ft ftUS ftUS t400.c0 00.04 IL .GI Ll4l. la [n0.4y /u4. ro roz.00 roz.3"I /44.32 1b4.tl/ G./U 59/9U39 .Zi5 5ti33tiU.1 / N /U 21 9./14 W 149 19 22.615 2560.42 58.25 12 .15 2191.93 2269.23 777.27 841.99 841.64 821.86 181.40 1.82 5979116 .99 583396 .05 N 70 21 10.476 W 149 19 22.186 2654.71 59.04 11 .60 2241.00 2318.30 851.32 922.51 922.15 900.65 197.97 0.97 5979195 .96 583411 .74 N 70 21 11.251 W 149 19 21.701 2749.60 59.40 11 .73 2289.56 2366.86 926.18 1004.03 1003.67 980.49 214.45 0.40 5979275 .97 583427 .33 N 70 21 12.037 W 149 19 21.219 2843.79 59.44 11 .64 2337.47 2414.77 1000.65 1085.12 1084.76 1059.90 230.88 0.09 5979355 .55 583442 .87 N 70 21 12.818 W 149 19 20.739 2939.01 59.34 11 .69 2385.96 2463.26 1075.90 1167.07 1166.70 1140.16 247.45 0.11 5979435. 98 583458 .55 N 70 21 13.607 W 149 19 20.255 3033.56 58.86 11 .85 2434.51 2511.81 1150.45 1248.20 1247.83 1219.59 263.99 0.53 5979515. 58 583474 .21 N 70 21 14.388 W 149 19 19.771 3128.08 58.78 11 .89 2483.45 2560.75 1224.81 1329.07 1328.70 1298.72 280.63 0.09 5979594. 89 583489 .96 N 70 21 15.166 W 149 19 19.285 3223.61 59.32 12 .07 2532.58 2609.88 1300.22 1410.99 1410.62 1378.87 297.63 0.59 5979675. 21 583506 .08 N 70 21 15.954 W 149 19 18.788 3302.79 58.27 13 .26 2573.60 2650.90 1362.86 1478.72 1478.34 1444.94 312.48 1.85 5979741. 44 583520 .18 N 70 21 16.604 W 149 19 18.354 3332.92 58.16 12 .74 2589.47 2666.77 1386.60 1504.33 1503.95 1469.90 318.24 1.51 5979766. 45 583525 .67 N 70 21 16.850 W 149 19 3427.34 57.83 12 .68 2639.52 2716.82 1460.69 1584.40 1584.02 1548.00 335.86 0.35 5979844. 74 583542 .41 N 70 21 17.618 W 149 19 3520.48 59.11 12 .46 2688.22 2765.52 1534.07 1663.78 1663.40 1625.49 353.13 1.39 5979922. 41 583558 .83 N 70 21 18.380 W 149 19 17.165 3614.60 58.90 12 .46 2736.69 2813.99 1608.59 1744.47 1744.08 1704.27 370.54 0.22 5980001. 37 583575 .36 N 70 21 19.155 W 149 19 16.656 3708.59 58.76 12 .33 2785.34 2862.64 1682.83 1824.89 1£324.50 1782.81 387.80 0.19 5980080. 09 583591 .74 N 70 21 19.927 W 149 19 16.151 3803.17 60.00 12 .46 2833.51 2910.81 1757.97 1906.28 1905.89 1862.31 405.27 1.32 5980159. 77 583608 .33 N 70 21 20.709 W 149 19 15.641 3897.73 59.55 12 .44 " 2881.11 2958.41 1833.43 1987.98 1987.60 1942.09 422.89 0.48 5980239. 73 583625 .06 N 70 21 21.494 W 149 19 15.126 3991.42 60.14 12 .38 2928.18 3005.48 1908.22 2068.99 2068.61 2021.21 440.30 0.63 5980319. 03 583641 .58 N 70 21 22.272 W 149 19 14.616 4085.47 60.66 14 .91 2974.64 3051.94 1984.37 2150.76 2150.35 2100.67 459.59 2.40 5980398. 69 583659 .99 N 70 21 23.053 W 149 19 14.052 4180.85 62.09 18 .79 3020.34 3097.64 2063.91 2234.48 2233.80 2180.76 483.87 3.87 5980479. 05 583683 .38 N 70 21 23.841 W 149 19 13.342 4275.50 62.77 19 .74 3064.15 3141.45 2144.67 2318.38 2317.14 2259.96 511.55 1.14 5980558. 54 583710 .18 N 70 21 24.620 W 149 19 12.533 4369.33 61.59 22 .65 3107.95 3185.25 2225.24 2401.36 2399.24 2337.33 541.54 3.02 5980636. 23 583739 .30 N 70 21 25.381 W 149 19 11.656 4463.07 60.92 24. 56 3153.03 3230.33 2305.80 2483.54 2480.08 2412.63 574.45 1.92 5980711. 89 583771. 36 N 70 21 26.121 W 149 19 10.694 4558.50 59.11 25. 99 3200.72 3278.02 2387.26 2566.20 2561.02 2487.38 609.73 2.30 5980787. 01 583805. 81 N 70 21 26.856 W 149 19 9.662 4652.08 58.36 27 .82 3249.29 3326.59 2466.45 2646.18 2638.97 2558.71 645.92 1.85 5980858. 73 583841. 20 N 70 21 27.558 W 149 19 8.604 4745.64 59.00 29 .78 3297.93 3375.23 2545.90 2726.11 2716.37 2628.74 684.42 1.92 5980929. 18 583878. 92 N 70 21 28.247 W 149 19 7.478 4840.53 59.04 32 .79 3346.78 3424.08 2627.07 2807.46 2794.38 2698.25 726.66 2.72 5980999. 15 583920. 38 N 70 21 28.930 W 149 19 6.243 4932.96 58.18 32 .71 3394.93 3472.23 2705.91 2886.36 2869.66 2764.61 769.34 0.93 5981065. 97 583962. 32 N 70 21 29.583 W 149 19 5 5029.33 57.47 34 .52 3446.25 3523.55 2787.45 2967.93 2947.31 2832.54 814.49 1.75 5981134. 39 584006 .71 N 70 21 30.251 W 149 19 5123.41 57.25 34 .96 3496.99 3574.29 2866.67 3047.15 3022.46 2897.64 859.64 0.46 5981199. 98 584051 .13 N 70 21 30.891 W 149 19 2. 5 5217.80 58.51 34. 97 3547.17 3624.47 2946.61 3127.09 3098.40 2963.15 905.45 1.33 5981265. 99 584096 .20 N 70 21 31.535 W 149 19 1.015 5312.23 59.95 35. 35 3595.48 3672.78 3027.75 3208.22 3175.59 3029.48 952.18 1.56 5981332. 83 584142. 18 N 70 21 32.187 W 149 18 59.649 5405.78 61.32 35. 70 3641.36 3718.66 3109.27 3289.75 3253.19 3095.83 999.55 1.50 5981399. 70 584188. 81 N 70 21 32.840 W 149 18 58.264 5500.71 60.71 35 .59 3687.36 3764.66 3192.31 3372.79 3332.37 3163.31 1047.94 0.65 5981467. 71 584236. 45 N 70 21 33.504 W 149 18 56.849 5596.24 61.46 38 .08 3733.55 3810.85 3275.88 3456.41 3411.76 3230.23 1098.07 2.41 5981535. 17 584285. 83 N 70 21 34.162 W 149 18 55.383 5691.12 63.07 42 .66 3777.73 3855.03 3359.45 3540.37 3489.94 3294.17 1152.46 4.60 5981599. 70 584339. 50 N 70 21 34.790 W 149 18 53.792 5785.12 63.56 47 .61 3819.96 3897.26 3442.09 3624.35 3565.68 3353.38 1211.97 4.73 5981659. 57 584398 .34 N 70 21 35.373 W 149 18 52.052 5879.62 63.10 51 .86 3862.39 3939.69 3523.73 3708.79 3639.13 3407.95 1276.38 4.05 5981714. 84 584462. 14 N 70 21 35.909 W 149 18 50.168 5973.89 60.96 55. 76 3906.62 3983.92 3602.53 3792.04 3709.01 3457.12 1343.54 4.30 5981764. 75 584528. 74 N 70 21 36.393 W 149 18 48.205 6069.13 60.11 59. 75 3953.48 4030.78 3678.97 3874.95 3775.96 3501.35 1413.64 3.75 5981809. 76 584598. 34 N 70 21 36.828 W 149 18 46.155 6163.57 61.29 64 .17 3999.71 4077.01 3752.35 3957.30 3839.40 3540.04 1486.32 4.27 5981849. 24 584670. 57 N 70 21 37.208 W 149 18 44.029 SurveyEditor Ver SP 1.0 BId( doc40x_56) L-202\L-202\L-202L1\L-202L1 Generated 7/5/2005 4:17 PM Page 2 of 7 Comments Measured Depth Inclination Azimuth Sub-Sea ND ND Vertical Section Along Hole Departure Closure NS EW DLS Northing Easting Latitude Longitude ft de de ft ft k ft ft ft ft de /100 ft ftUS ftUS 6350.96 56.53 72.30 4096.13 4173.43 3886.58 6445.47 57.16 76.61 4147.83 4225.13 3947.64 6539.08 58.35 80.50 4197.79 4275.09 4004.99 6633.04 63.82 84.48 4243.22 4320.52 4060.47 6727.96 67.49 87.23 4282.34 4359.64 4115.02 6821.91 68.85 90.61 4317.29 4394.59 4166.36 6915.74 69.25 92.21 4350.84 4428.14 4214.84 Tie-In Survey 7010.72 68.67 92.35 4384.94 4462.24 4262.76 Tp Wndw (Bind Inc Only) 7072.00 68.96 92.90 4407.08 4484.38 4293.35 Bs Wndw (Bind Inc only) 7084.00 70.82 92.37 4411.21 4488.51 4299.38 Blind (Inc Only) 7120.36 72.84 94.16 4422.55 4499.85 4317.55 7150.72 76.89 95.61 4430.47 4507.77 4332.25 7182.04 80.98 97.06 4436.48 4513.78 4346.99 Blind (Inc Only) 7213.57 84.67 98.50 4440.42 4517.72 4361.29 First MWD+IFR+MS 7244.95 89.14 99.92 4442.12 4519.42 4374.92 7275.70 92.40 103.46 4441.70 4519.00 4387.08 7307.24 96.05 103.60 4439.38 4516.68 4398.59 7338.21 97.01 103.79 4435.86 4513.16 4409.77 7369.31 96.81 105.04 4432.12. 4509.42 4420.63 7400.99 96.77 105.26 4428.37 4505.67 4431.31 7432.33 96.98 104.59 4424.62 4501.92 4441.99 7463.10 97.12 103.73 4420.84 4498.14 4452.85 7493.85 97.01 105.20 4417.06 4494.36 4463.56 7526.25 94.26 102.99 4413.88 4491.18 4475.06 7557.21 91.10 101.41 4412.43 4489.73 4487.05 7588.06 89.21 101.48 4412.35 4489.65 4499.37 7619.23 89.66 103.48 4412.65 4489.95 4511.31 7649.98 91.06 105.07 4412.46 4489.76 4522.19 7681.42 91.20 104.59 4411.84 4489.14 4533.03 7712.31 91.06 103.61 4411.23 4488.53 4544.05 7743.03 90.75 104.98 4410.75 4488.05 4554.91 7774.41 92.16 104.69 4409.95 .` 4487.25 4565.72 7805.71 92.50 103.75 4408.68 4485.98 4576.82 7836.79 92.13 102.46 4407.42 4484.72 4588.40 7867.67 90.62 102.73 4406.68 4483.98 4600.16 7899.00 90.03 105.82 4406.50 4483.80 4611.25 7930.54 90.51 106.80 4406.35 4483.65 4621.36 7962.02 91.17 107.56 4405.89 4483.19 4630.99 YVJJ.JJ JUJJ.JY JJ/J.VV IJV I.YI 4117.92 3953.62 3599.54 1635.37 4197.03 4004.89 3620.73 1711.57 4276.19 4052.72 3636.41 1789.15 4358.40 4098.84 3647.08 1870.64 4444.86 4144.39 3653.30 1956.87 4532.07 4187.68 3654.93 2044.05 4619.70 4229.26 3652.77 2131.65 4708.34 4271.58 3649.25 2220.22 4.40 Uao 1003. I I oo4r4a.G8 IV /U Gl JrAJ3 VV l4`i ltl 4"I .1534 4.55 5981910.39 584818.94 N 70 21 37.793 W 149 18 39.671 3.88 5981932.42 584894.89 N 70 21 38.001 W 149 18 37.443 3.74 5981948.97 584972.28 N 70 21 38.155 W 149 18 35.174 6.90 5981960.54 585053.65 N 70 21 38.260 W 149 18 32.791 4.68 5981967.71 585139.80 N 70 21 38.321 W 149 18 30.270 3.64 5981970.31 585226.94 N 70 21 38.337 W 149 18 27.721 1.65 5981969.13 585314.55 N 70 21 38.315 W 149 18 25.160 0.63 5981966.58 585403.15 N 70 21 38.280 W 149 18 22.570 0.96 5981964.60 585460.25 N 70 21 38.254 W 149 16 2 1 16.05 5981964.21 585471.51 N 70 21 38.249 W 149 18 2~ 7.26 5981962.62 585506.02 N 70 21 38.230 W 149 18 19.563 14.11 5981960.45 585535.23 N 70 21 38.205 W 149 18 18.710 13.83 5981957.39 585565.81 N 70 21 38.171 W 149 18 17.817 12.55 5981953.50 585596.84 N 70 21 38.130 W 149 18 16.911 14.94 5981948.83 585627.81 N 70 21 38.080 W 149 18 16.007 15.65 5981942.94 585657.98 N 70 21 38.019 W 149 18 15.127 11.58 5981935.92 585688.63 N 70 21 37.947 W 149 18 14.233 3.16 5981928.97 585718.60 N 70 21 37.875 W 149 18 13.359 4.04 5981921.62 565748.58 N 70 21 37.799 W 149 18 12.485 0.70 5981913.74 585779.03 N 70 21 37.718 W 149 18 11.597 2.23 5981906.06 585809.18 N 70 21 37.639 W 149 18 10.718 2.81 5981898.92 585838.87 N 70 21 37.566 W 149 18 9.852 4.76 5981891.62 585868.50 N 70 21 37.491 W 149 18 8.988 10.87 5981884.12 585899.85 N 70 21 37.413 W 149 18 8.074 11.41 5981877.93 585930.14 N 70 21 37.349 W 149 18 7.191 6.13 5981872.14 585960.44 N 70 21 37.289 W 149 18 6.58 5981865.75 585990.94 N 70 21 37.222 W 149 18 5. 17 6.89 5981858.50 586020.81 N 70 21 37.148 W 149 18 4.546 1.59 5981850.79 586051.29 N 70 21 37.068 W 149 18 3.657 3.20 5981843.60 586081.32 N 70 21 36.994 W 149 18 2.782 4.57 5981836.35 586111.16 N 70 21 36.920 W 149 18 1.911 4.59 5981828.65 586141.57 N 70 21 36.840 W 149 18 1.025 3.19 5981821.31 586171.97 N 70 21 36.765 W 149 18 0.139 4.31 5981814.61 586202.28 N 70 21 36.695 W 149 17 59.254 4.97 5981808.21 586232.48 N 70 21 36.629 W 149 17 58.374 10.04 5981800.82 586262.92 N 70 21 36.553 W 149 17 57.486 3,46 5981792.30 586293.29 N 70 21 36.466 W 149 17 56.601 3.20 5981783.34 586323.46 N 70 21 36.374 W 149 17 55.722 4765.48 4299.30 3646.63 2277.30 4776.75 4304.84 3646.11 2288.56 4811.29 4321.61 4840.59 4335.27 4871.33 4349.08 4902.60 4362.61 4933.93 4375.63 4964.67 4387.38 4996.12 4398.65 5026.89 4409.78 5057.76 4420.78 5089.22 4431.80 5120.34 4443.01 5150.87 4454.57 5181.39 4466.15 5213.63 4478.77 5244.55 4491.99 5275.40 4505.72 5306.57 4519.25 5337.32 4531.90 5368.75 4544.74 5399.64 4557.88 5430.35 4571.03 5461.72 4584.37 5493.00 4598.14 5524.05 4612.52 5554.92 4627.22 5586.25 4641.49 5617.79 4655.02 5649.27 4668.27 3644.14 3641.64 3638.25 3634.01 3629.00 3622.77 3615.41 3608.13 3600.44 3592.22 3584.21 3576.74 3569.12 3561.27 3554.73 3548.61 3541.88 3534.29 3526.25 3518.73 3511.14 3503.11 3495.43 3488.39 3481.66 3473.93 3465.07 3455.78 2323.05 2352.24 2382.78 2413.77 2444.69 2474.79 2505.37 2535.26 2565.16 2595.53 2625.59 2655.20 2684.75 2716.02 2746.24 2776.48 2806.91 2836.71 2867.09 2897.05 2926.81 2957.13 2987.45 3017.69 3047.82 3078.18 3108.45 3138.52 SurveyEditor Ver SP 1.0 Bld( doc40x_56 } L-202\L-202\L-202L1\L-202L1 Generated 7!5/2005 4:17 PM Page 3 of 7 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de ft ft ft ft ft ft tt de 100 ft ftUS ftUS ~o- - u.Vi YYVJ.G! YYVG.J! YVJy.IV JVl0..71 4000.OL J'F'#O./L JI00./J 8022.53 90.86 108.97 4404.71 4482.01 4648.53 5709.76 4693.29 3436.94 3196.01 8053.20 90.07 107.74 4404.46 4481.76 4657.31 5740.43 4706.13 3427.28 3225.12 8084.02 88.63 107.27 4404.81 4482.11 4666.58 5771.25 4719.60 3418.01 3254.51 8114.32 88.53 105.68 4405.56 4482.86 4676.20 5801.54 4733.48 3409.42 3283.55 8144.98 87.84 103.44 4406.53. 4483.83 4686.90 5832.19 4748.58 3401.72 3313.21 8174.79 88.18 103.20 4407.57 4484.87 4697.91 5861.98 4763.96 3394.85 3342.20 8206.09 89.31 101.47 4408.25 4485.55 4709.97 5893.27 4780.72 3388.17 3372.77 8236.81 90.69 102.13 4408.25 4485.55 4722.07 5923.99 4797.55 3381.89 3402.84 8267.06 92.43 101.29 4407.43 4484.73 4734.02 5954.23 4814.29 3375.75 3432.45 8297.94 92.02 101.04 4406.23 4483.53 4746.49 5985.08 4831.75 3369.77 3462.72 8328.39 91.65 100.34 4405.26 4482.56 4759.02 6015.52 4849.31 3364.13 3492.63 8358.03 91.34 101.29 4404.48 4481.78 4771.16 6045.15 4866.47 3358.57 3521.73 8389.69 92.54 103.54 4403.41 4480.71 4783.31 6076.79 4884.21 3351.77 3552.63 8420.49 91.75 104.60 4402.26 4479.56 4794.31 6107.57 4900.86 3344.28 3582.49 8450.87 89.18 105.81 4402.01 4479.31 4804.59 6137.94 4916.92 3336.32 3611.80 8482.13 88.73 107.04 4402.58 4479.88 4814.55 6169.20 4933.02 3327.48 3641.78 8513.26 88.42 107.11 4403.35 4480.65 4824.13 6200.32 4948.89 3318.34 3671.52 8544.73 88.53 107.74 4404.19 4481.49 4833.63 6231.78 4964.91 3308.92 3701.54 8574.67 88.87 107.67 4404.87 4482.17 4842.53 6261.71 4980.17 3299.82 3730.05 8606.19 89.28 108.24 4405.38 4482.68 4851.76 6293.23 4996.26 3290.10 3760.04 8636.89 88.94 109.11 4405.86 4483.16 4860.39 6323.92 5011.75 3280.28 3789.11 8668.36 89.04 109.70 4406.41 4483.71 4868.85 6355.39 5027.42 3269.82 3818.79 8699.59 89.07 109.41 4406.93 4484.23 4877.17 6386.61 5043.04 3259.37 3848.22 8730.25 89.21 109.63 4407.39 4484.69 4885.35 6417.27 5058.54 3249.13 3877.11 8762.10 89.31 107.30 4407.80 4485.10 4894.41 6449.12 5075.28 3239.04 3907.32 8793.09 89.11 107.30 4408.23 4485.53 4903.83 6480.10 5092.25 3229.83 3936.90 8823.99 89.11 107.96 4408.71 4486.01 4913.06 6511.00 5109.14 3220.47 3966.35 8855.79 89.55 109.15 4409.08 4486.38 4922.06 6542.80 5126.24 3210.35 3996.49 8886.27 89.93 110.10 4409.22 4486.52 4930.14 6573.28 5142.27 3200.11 4025.20 8917.38 90.45 108.40 4409.11 4486.41 4938.58 6604.39 5158.95 3189.86 4054.57 8948.61 89.14 105.21 4409.22 4486.52 4948.33 6635.62 5176.92 3180.83 4084.46 8979.65 88.42 102.63 4409.89 4487.19 4959.49 6666.65 5196.15 3173.36 4114.58 9011.29 88.63 103.57 4410.70 4488.00 4971.29 6698.28 5216.23 3166.20 4145.39 9042.53 88.73 104.42 4411.42 4488.72 4982.49 6729.51 5235.78 3158.64 4175.69 9073.93 88.39 104.70 4412.21 4489.51 4993.45 6760.90 5255.31 3150.75 4206.07 9104.89 87.70 104.83 4413.27 4490.57 5004.15 6791.84 5274.58 3142.87 4235.99 9136.11 87.60 104.95 4414.55 4491.85 5014.88 6823.04 5294.07 3134.85 4266.14 9167.92 87.43 104.09 4415.92 4493.22 5025.99 6854.81 5314.20 3126.88 4296.90 9200.09 86.98 104.17 4417.49 4494.79 5037.44 6886.95 5334.84 3119.04 4328.06 9229.86 88.80 104.09 4418.59 4495.89 5048.04 6916.70 5354.05 3111.78 4356.91 I.bJ byb"I//4.bu 525bs5"I./ts N /U L7 Jli.'Lt55 W 'toy 1! 54.8y( 3.33 5981765.14 586381.14 N 70 21 36.189 W 149 17 54.041 4.77 5981755.81 586410.35 N 70 21 36.094 W 149 17 53.190 4.91 5981746.87 586439.84 N 70 21 36.002 W 149 17 52.331 5.26 5981738.60 586468.98 N 70 21 35.918 W 149 17 51.482 7.64 5981731.23 586498.72 N 70 21 35.842 W 149 17 50.615 1.40 5981724.69 586527.78 N 70 21 35.774 W 149 17 49.767 6.60 5981718.35 586558.42 N 70 21 35.708 W 149 17 48.874 4.98 5981712.40 586588.55 N 70 21 35.646 W 149 17 47.995 6.39 5981706.59 586618.23 N 70 21 35.586 W 149 17 47.129 1.55 5981700.95 586648.56 N 70 21 35.527 W 149 17 4 2.60 5981695.64 586678.52 N 70 21 35.471 W 149 17 4 3.37 5981690.41 586707.69 N 70 21 35.416 W 149 17 44.519 8.05 5981683.95 586738.66 N 70 21 35.349 W 149 17 43.615 4.29 5981676.80 586768.59 N 70 21 35.276 W 149 17 42.743 9.35 5981669.16 586797.98 N 70 21 35.197 W 149 17 41.886 4.19 5981660.65 586828.06 N 70 21 35.110 W 149 17 41.009 1.02 5981651.85 586857.90 N 70 21 35.020 W 149 17 40.140 2.03 5981642.76 586888:02 N 70 21 34.927 W 149 17 39.262 1.16 5981633.98 586916.63 N 70 21 34.838 W 149 17 38.429 2.23 5981624.60 586946.71 N 70 21 34.742 W 149 17 37.552 3.04 5981615.09 586975.90 N 70 21 34.645 W 149 17 36.702 1.90 5981604.97 587005.69 N 70 21 34.542 W 149 17 35.835 0.93 5981594.85 587035.22 N 70 21 34.439 W 149 17 34.974 0.85 5981584.93 587064.23 N 70 21 34.338 W 149 17 34.130 7.32 5981575.18 587094.54 N 70 21 34.239 W 149 17 33.247 0.65 5981566.29 587124.22 N 70 21 34.148 W 149 17 32.382 2.14 5981557.26 587153.77 N 70 21 34.056 W 149 17 31 3.99 5981547.48 587184.02 N 70 21 33.956 W 149 17 3 3.36 5981537.56 587212.84 N 70 21 33.856 W 149 17 29. 1 5.71 5981527.64 587242.31 N 70 21 33.755 W 149 17 28.942 11.04 5981518.94 587272.30 N 70 21 33.666 W 149 17 28.068 8.63 5981511.81 587302.50 N 70 21 33.592 W 149 17 27.188 3.04 5981504.99 587333.38 N 70 21 33.521 W 149 17 26.287 2.74 5981497.77 587363.76 N 70 21 33.447 W 149 17 25.401 1.40 5981490.22 587394.23 N 70 21 33.369 W 149 17 24.513 2.27 5981482.67 587424.23 N 70 21 33.291 W 149 17 23.639 0.50 5981474.99 587454.46 N 70 21 33.212 W 149 17 22.757 2.75 5981467.36 587485.31 N 70 21 33.134 W 149 17 21.858 1.42 5981459.87 587516.55 N 70 21 33.057 W 149 17 20.947 6.12 5981452.92 587545.48 N 70 21 32.985 W 149 17 20.104 SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-202\L-202\L-202L1\L-202L1 Generated 7/5/2005 4:17 PM Page 4 of 7 Comments Measured Inclination Azimuth Sub•Sea TVD TVD Vertical Along Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure ft de de k k ft ft ft ft k de 100 ft ftUS ftUS JGV I.JV VI .JJ I VY.JJ YY IJ.UG 44yV..~L 9293.38 87.26 106. 77 4421. 05 9324.06 86.71 106. 51 4422. 66 9355.96 86.64 106. 35 4424. 51 9386.25 86.77 107. 92 4426. 25 9416.13 86.67 107. 39 4427. 96 9446.94 87.29 108. 43 4429. 58 9478.77 88.83 105. 40 4430. 66 9509.50 87.63 103. 62 4431. 61 9540.59 89.04 104. 75 4432. 51 9572.15 89.25 104. 97 4432. 99 9603.20 90.03 106. 11 4433. 18 9635.37 90.75 106. 20 4432. 96 9666.18 89.59 104. 67 4432. 87 9695.93 87.74 104. 61 4433. 56 9727.51 88.53 104. 85 4434. 59 9758.77 88.80 105. 63 4435. 32 9789.45 88.25 105. 04 4436. 11 9821.08 87.56 104. 10 4437. 27 9852.06 87.60 104. 56 4438. 57 9882.90 88.18 104. 58 4439. 71 9915.24 9946.23 9977.75 10008.91 10039.02 10070.42 10101.97 10132.89 10164.18 10195.26 10226.98 10258.87 10289.98 10320.77 10352.24 10383.69 10414.05 10444.80 10474.93 10507.20 VJl4.lO JIUJ.yU 430/.y0 4.U/ 0`JO.1440.3`J 5394.69 5413.75 5433.77 5452.59 5471.04 5490.07 5510.29 5530.88 5551.95 5573.16 3095.45 3086.68 3077.67 3068.76 3059.72 4418.24 4447.59 4478.14 4507.04 4535.46 7.60 5981437.29 1.98 5981428.84 0.55 5981420.17 5.19 5981411.59 1.80 5981402.86 3050.25 3041.00 3033.30 3025.69 3017.60 5593.85 3009.28 5615.14 3000.33 5635.90 2992.13 5656.34 2984.61 5678.08 2976.59 5699.50 2968.37 5720.57 2960.26 5742.67 2952.31 5764.50 2944.65 5786.22 2936.89 4564.74 4595.17 4624.90 4655.03 4685.53 4715.45 4746.35 4776.04 4804.82 4835.34 4865.50 4895.07 4925.67 4955.65 4985.48 b0/b/b.bU N /il Z1 3L.`JU/ W 14y 1 / 1y.1 yti 587606.98 N 70 21 32.824 W 149 17 18.311 587636.42 N 70 21 32.738 W 149 17 17.453 587667.06 N 70 21 32.649 W 149 17 16.560 587696.06 N 70 21 32.561 W 149 17 15.715 587724.58 N 70 21 32.472 W 149 17 14.884 587753.95 N 70 21 32.379 W 149 17 14.029 587784.48 N 70 21 32.287 W 149 17 13.139 587814.30 N 70 21 32.212 W 149 17 12.270 587844.51 N 70 21 32.137 W 149 17 11.389 587875.09 N 70 21 32.057 W 149 17 1~ 587905.09 N 70 21 31.975 W 149 17 9.623 587936.09 N 70 21 31.887 W 149 17 8.720 587965.87 N 70 21 31.806 W 149 17 7.852 587994.72 N 70 21 31.732 W 149 17 7.011 588025.33 N 70 21 31.652 W 149 17 6.118 588055.57 N 70 21 31.572 W 149 17 5.237 588085.24 N 70 21 31.492 W 149 17 4.372 588115.91 N 70 21 31.413 W 149 17 3.478 588145.98 N 70 21 31.338 W 149 17 2.602 588175.89 N 70 21 31.261 W 149 17 1.730 588207.29 N 70 21 31.182 W 149 17 0.814 588237.36 N 70 21 31.106 W 149 16 59.938 588267.87 N 70 21 31.025 W 149 16 59.048 588298.07 N 70 21 30.947 W 149 16 58.168 588327.31 N 70 21 30.873 W 149 16 57.316 588357.77 N 70 21 30.796 W 149 16 56.428 588388.37 N 70 21 30.717 W 149 16 5 588418.41 N 70 21 30.642 W 149 16 5~ 588448.89 N 70 21 30.569 W 149 16 53. 1 588479.14 N 70 21 30.496 W 149 16 52.889 588509.87 N 70 21 30.417 W 149 16 51.993 588540.61 N 70 21 30.332 W 149 16 51.097 588570.50 N 70 21 30.248 W 149 16 50.226 588600.14 N 70 21 30.166 W 149 16 49.363 588630.33 N 70 21 30.079 W 149 16 48.483 588660.31 N 70 21 29.984 W 149 16 47.610 588689.17 N 70 21 29.890 W 149 16 46.769 588718.46 N 70 21 29.795 W 149 16 45.916 588747.38 N 70 21 29.709 W 149 16 45.073 588778.48 N 70 21 29.621 W 149 16 44.167 5809.18 2928.88 5016.79 5831.22 2921.14 5046.78 5853.49 2912.95 5077.21 5875.69 2904.98 5107.33 5897.41 2897.56 5136.49 5920.05 2889.72 5166.87 5942.81 2881.72 5197.38 5965.37 2874.11 5227.35 5988.47 2866.69 5257.74 6011.45 2859.27 5287.92 6034.63 2851.25 5318.56 6057.65 2842.71 5349.21 6079.97 2834.11 5379.02 6102.28 2825.81 5408.56 8124.90 2816.98 5438.66 3.93 5981393.72 10.67 5981384.81 6.98 5981377.44 5.81 5981370.16 0.96 5981362.41 4.45 5981354.43 2.26 5981345.82 6.23 5981337.95 6.22 5981330.75 2.61 5981323.07 2.64 5981315.19 2.63 5981307.41 3.68 5981299.80 1.49 5981292.47 1.88 5981285.05 1.80 5981277.39 3.19 5981269.98 2.36 5981262.13 4.01 5981254.50 3.20 5981247.40 2.85 5981239.90 4.79 5981232.24 2.87 5981224.97 0.59 5981217.89 5.98 5981210.80 6.23 5981203.12 2.22 5981194.93 2.20 5981186.65 4.67 5981178.69 8.89 5981170.19 1.25 5981160.94 4.63 5981151.71 10.58 5981142.41 7.75 5981133.97 1.12 5981125.43 SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-202\L-202\L-202L1\L-202L1 Generated 7/5/2005 4:17 PM Page 5 of 7 87.81 88.53 89.07 88.32 87.36 88.11 89.62 89.73 89.66 87.84 86.36 85.85 85.50 85.30 85.74 86.12 87.08 90.10 91.89 91.85 104.13 104.81 105.32 104.32 104.23 104.72 104.68 103.80 103.63 104.01 105.32 105.81 106.40 104.97 107.74 107.84 108.87 107.66 106.16 105.80 4440.84 4441.83 4442.49 4443.20 4444.33 4445.58 4446.20 4446.38 4446.54 4447.22 4448.83 4450.99 4453.34 4455.81 4458.27 4460.50 4462.30 4463.05 4462.53 4461.48 4498.35 4499.96 4501.81 4503.55 4505.26 4506.88 4507.96 4508.91 4509.81 4510.29 4510.48 4510.26 4510.17 4510.86 4511.89 4512.62 4513.41 4514.57 4515.87 4517.01 4518.14 4519.13 4519.79 4520.50 4521.63 :JVJy.J.7 Vy40.lL 5069.85 6980.17 5079.50 7010.80 5089.64 7042.65 5098.91 7072.89 5107.81 7102.72 5116.85 7133.49 5126.72 7165.30 5137.47 7196.01 5148.52 7227.09 5159.38 7258.65 5169.73 5180.12 5190.43 5200.78 5211.72 5222.28 5232.60 5243.64 5254.56 5265.32 5276.71 5287.58 5298.32 5309.07 5319.71 7289.69 7321.86 7352.67 7382.41 7413.98 7445.23 7475.90 7507.51 7538.46 7569.28 7601.60 7632.57 7664.08 7695.24 7725.32 4522.88 5330.72 7756.70 4523.50 5341.66 7788.24 4523.68 5352.62 7819.16 4523.84 5363.98 7850.45 4524.52 5375.20 7881.52 4526.13 4528.29 4530.64 4533.11 4535.57 4537.80 4539.60 4540.35 4539.83 4538.78 5386.21 5396.80 5406.84 5416.99 5427.02 5436.31 5444.99 5453.84 5463.19 5473.70 7913.20 7945.02 7976.04 8006.73 8038.10 8069.47 6147.06 2807.39. 5468.53 8099.78 6168.33 2797.85 5497.30 8130.52 6190.01 2788.22 5526.49 8160.64 6211.83 2779.46 5555.31 8192.90 6235.62 2770.58 5586.31 Comments Measured Inclination Azimuth Sub-Sea ND ND Vertical Atong Hole Closure NS EW DLS Northing Easting Latitude Longitude Depth Section Departure k de de ft ft ft ft k k ft de 1100 ft ftUS ftUS 10537.95 90.31 105.78 4460.90 4538.20 5483.82 8223.64 6258.44 2762.21 5615.90 5.01 5981117.40 588808.15 N 70 21 29.539 W 149 16 43.302 10568.79 86.95 103.47 4461.64 4538.94 5494.55 8254.47 6281 .80 2754.43 5645.72 13.22 5981109.94 588838.05 N 70 21 29.462 W 149 16 42.431 10599.44 86.26 104.02 4463.45 4540.75 5505.64 8285.06 6305 .36 2747.16 5675.44 2.88 5981103.01 588867.85 N 70 21 29.390 W 149 16 41.562 10630.14 87.98 104.24 4464.99 4542.29 5516.56 8315.72 6328 .89 2739.67 5705.17 5.65 5981095.85 588897.66 N 70 21 29.316 W 149 16 40.693 10662.42 87.84 103.38 4466.17 4543.47 5528.22 8347.98 6353 .83 2731.97 5736.50 2.70 5981088.50 588929.07 N 70 21 29.241 W 149 16 39.777 10692.24 87.84 103.56 4467.30 4544.60 5539.16 8377.78 6377 .03 2725.03 5765.48 0.60 5981081.88 588958.12 N 70 21 29.172 W 149 16 38.930 10723.65 88.46 104.90 4468.31 4545.61 5550.29 8409.17 6401 .28 2717.31 5795.91 4.70 5981074.51 588988.63 N 70 21 29.096 W 149 16 38.041 10753.63 87.36 104.41 4469.40 4546.70 5560.71 8439.13 6424 .33 2709.73 5824.89 4.02 5981067.25 589017.69 N 70 21 29.021 W 149 16 37.193 10785.63 84.99 102.75 4471.54 4548.84 5572,37 8471.06 6449 .34 2702.24 5855.93 9.04 5981060.10 589048.81 N 70 21 28.947 W 149 16 36.286 10816.84 84.71 102.60 4474.34 4551.64 5584.17 8502.14 6474 .04 2695.42 5886.25 1.02 5981053.62 589079.20 N 70 21 28.880 W 149 16 35.400 10848.08 85.02 103.91 4477.13 4554.43 5595.70 8533.26 6498 .64 2688.28 5916.54 4.29 5981046.82 589109.56 N 70 21 28.809 W 149 16 10879.22 85.09 105.18 4479.82 4557.12 5606.54 8564.28 6522 .78 2680.49 5946.57 4.07 5981039.36 589139.67 N 70 21 28.733 W 149 16 33.637 10909.16 86.05 106.27 4482.13 4559.43 5616.40 8594.13 6545 .68 2672.40 5975.30 4.84 5981031.59 589168.49 N 70 21 28.653 W 149 16 32.797 10940.86 87.46 107.12 4483.93 4561.23 5626,33 8625.78 6569 .67 2663.31 6005.61 5.19 5981022.84 589198.90 N 70 21 28.563 W 149 16 31.911 10973.28 89.45 108.13 4484.80 4562.10 5636.01 8658.19 6593 .96 2653.50 6036.50 6.88 5981013.37 589229.89 N 70 21 28.466 W 149 16 31.008 11003.51 89.31 108.91 4485.13 4562.43 5644.59 8688.41 6616 .37 2643.90 6065.16 2.62 5981004.09 589258.66 N 70 21 28.372 W 149 16 30.171 11034.29 88.70 109.32 4485.66 4562.96 5653.01 8719.19 6639 .03 2633.82 6094.24 2.39 5980994.34 589287.84 N 70 21 28.272 W 149 16 29.321 11065.68 88.22 108.29 4486.51 4563.81 5661.76 8750.57 6662 .32 2623.70 6123.94 3.62 5980984.55 589317.65 N 70 21 28.173 W 149 16 28.453 11097.43 87.29 108.75 4487.75 4565.05 5670.76 8782.29 6686 .04 2613.63 6154.03 3.27 5980974.81 589347.84 N 70 21 28.073 W 149 16 27.573 11127.63 87.63 108.26 4489.09 4566.39 5679.33 8812.46 6708 .66 2604.05 6182.64 1.97 5980965.56 589376.55 N 70 21 27.979 W 149 16 26.737 11159.09 88.29 106.12 4490.21 4567.51 5688.94 8843.90 6732 .76 2594.76 6212.67 7.11 5980956.60 589406.69 N 70 21 27.887 W 149 16 25.859 11189.44 89.04 107.17 4490.91 4568.21 5698.50 8874.25 6756 .26 2586.07 6241.74 4.25 5980948.23 589435.85 N 70 21 27.802 W 149 16 25.010 11221.23 90.96 106.24 4490.91 4568.21 5708.48 8906.03 6780 .92 2576.93 6272.19 6.71 5980939.43 589466.39 N 70 21 27.711 W 149 16 24.120 11252.70 91.06 105.30 4490.36 4567.66 5718.84 8937.50 6805 .71 2568.38 6302.47 3.00 5980931.22 589496.76 N 70 21 27.627 W 149 16 23.235 11283.61 89.42 104.38 4490.23 4567.53 5729.49 8968.41 6830 .41 2560.46 6332.34 6.08 5980923.64 589526.72 N 70 21 27.549 W 149 16 22.361 11313.67 87.29 103.36 4491.09 4568.39 5740.32 8998.45 6854 .78 2553.26 6361.51 7.86 5980916.76 589555.97 N 70 21 27.478 W 149 16 21.509 11345.52 86.40 102.69 4492.85 4570.15 5752.22 9030.25 6880 .89 2546,09 6392.50 3.50 5980909.94 589587.02 N 70 21 27.407 W 149 16 20.603 11376.72 86.36 103.87 4494.82 4572.12 5763.75 9061.39 6906. 42 2538.94 6422.80 3.78 5980903.12 589617.40 N 70 21 27.337 W 149 16 19 11407.92 86.95 105.01 4496.64 4573.94 5774.68 9092.54 6931 .64 2531.17 6452.96 4.11 5980895.69 589647.65 N 70 21 27.260 W 149 16 1 11439.04 87.12 104.83 4498.25 4575.55 5785.35 9123.62 6956 .70 2523,17 6482.99 0.80 5980888.02 589677.76 N 70 21 27.181 W 149 16 17. 8 11470.32 87.53 104.98 4499.71 4577,01 5796.09 9154.86 6981. 94 2515.14 6513.19 1.40 5980880.32 589708.04 N 70 21 27.102 W 149 16 17.076 11501.66 88.59 106.47 4500.77 4578.07 5806.43 9186.18 7007 .03 2506.65 6543.34 5.83 5980872.17 589738.28 N 70 21 27.018 W 149 16 16.194 11532.90 88.53 105.36 4501.55 4578.85 5816.64 9217.42 7032 .04 2498.08 6573.37 3.56 5980863.94 589768.40 N 70 21 26.933 W 149 16 15.317 11565.30 88.08 106.28 4502.51 4579.81 5827.28 9249.80 7058 .06 2489.26 6604.53 3.16 5980855.46 589799.65 N 70 21 26.846 W 149 16 14.406 11597.20 87.84 107.49 4503.65 4580.95 5837.19 9281.68 7083 .36 2480.00 6635.03 3.86 5980846.54 589830.26 N 70 21 26.755 W 149 16 13.514 11626.59 87.50 106.33 4504.84 4582.14 5846.31 9311.05 7106 .71 2471.45 6663.13 4.11 5980838.31 589858.44 N 70 21 26.671 W 149 16 12.693 11657.80 86.64 105.98 4506.44 4583.74 5856.38 9342.21 7131 .79 2462.78 6693.07 2.97 5980829.98 589888.47 N 70 21 26.585 W 149 16 11.818 11690.02 87.36 105.93 4508.12 4585.42 5866.88 9374.39 7157. 79 2453.94 6724.00 2.24 5980821.48 589919.50 N 70 21 26.498 W 149 16 10.914 11720.87 88.42 104.17 4509.26 4586.56 5877.40 9405.22 7:183 .04 2445.93 6753.77 6.66 5980813.80 589949.36 N 70 21 26.419 W 149 16 10.044 11751.37 87.81 104.46 4510.26 4587.56 5888.16 9435.70 7208 .26 2438.40 6783.31 2.21 5980806.60 589978.97 N 70 21 26.345 W 149 16 9.181 SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-202\L-202\L-202L1\L-202L1 Generated 7/5/2005 4:17 PM Page 6 of 7 Measured Vertical Along Hole Comments Depth Inclination Azimuth Sub-Sea TVD TVD Section Departure Closure NS EW DLS Northing Easting Latitude Longitude ft de de ft ft ft ft ft ft ft de /100 ft ftUS ftUS I IlOJ.J~ OO.GO N4.0! 401I.JO 4000.00 00~~.34 y40/.!V /LJ4./l L43U.30 Otl-14.20 11813.54 87.91 104.22 4512.37 4589.67 5909.92 9497.84 7259.69 2422.83 6843.46 11844.58 88.05 103.53 4513.47 4590.77 5921.10 9528.86 7285.62 2415.39 6873.58 11876.12 88.15 101.15 4514.51 4591.81 5933.24 9560.38 7312.45 2408.66 6904.37 11906.23 87.84 101.72 4515.57 4592.87 5945.27 9590.47 7338.35 2402.69 6933.86 11937.52 87.87 102.10 4516.74 4594.04 5957.53 9621.74 7365.16 2396.24 6964.46 11969.07 87.63 102.17 4517.98 4595.28 5969.78 9653.27 7392.17 2389.61 6995.28 12000.75 87.60 102.23 4519.29 4596.59 5982.05 9684.92 7419.30 2382.92 7026.22 12031.51 87.60 103.35 4520.58 4597.88 5993.66 9715.65 7445.52 2376.12 7056.19 Last MWD+IFR+MS 12060.52 88.94 103.74 4521.46 4598.76 6004.27 9744.65 7470.08 2369.33 7084.38 TD (Projected) 12115.00 88.94 103.74 4522.47 4599.77 6024.02 9799.12 7516.21 2356.39 7137.29 Survey Type: Definitive Survey MWD +IFR + MS - (In-field referenced MWD with mutt-station analysis and correctio n applied in post-processing. Assumes a BHA sag correction is applied to enhan ce inclination accuracy. ) Legal Description: Surface : 2571 FSL 3690 FEL S34 T12N R11 E UM BHL : 4924 FSL 1829 FEL S35 T12N R11 E UM Northing (Y) [ftUS] Easting (X) [ftUS] 5978293.25 583223.80 5980728.53 590333.81 l.~L o9zsu/ytS.t59 b9UU1 U.UJ N /U 11 Lti.1Ei5 W 149 1(i 8.1/5 1.87 5980791.70 590039.29 N 70 21 26.191 W 149 16 7.423 2.27 5980784.60 590069.48 N 70 21 26.118 W 149 16 6.542 7.55 5980778.21 590100.35 N 70 21 26.051 W 149 16 5.642 2.15 5980772.57 590129.90 N 70 21 25.992 W 149 16 4.780 1.22 5980766.46 590160.56 N 70 21 25.928 W 149 16 3.886 0.79 5980760.17 590191.45 N 70 21 25.863 W 149 16 2.985 0.21 5980753.83 590222.46 N 70 21 25.797 W 149 16 2.081 3.64 5980747.36 590252.50 N 70 21 25,730 W 149 16 1.205 4.81 5980740.88 590280.76 N 70 21 25.663 W 149 16 0.381 0.00 5980728.53 590333.81 N 70 21 25.535 W 149 15 SurveyEditor Ver SP 1.0 Bld( doc40x_56) L-202\L-202\L-202L1\L-202L1 Generated 7/5/2005 4:17 PM Page 7 of 7 TREE = FMC 4-1 /8" 5M WELLHEAD = FMC GEN 5 AC`fUATOR = KB. ELEV = 77.30' BF. ELEV = _ _ 51.08' KOP = 700 Max Angle = 92.7 @ 8295' Datum MD = xxxx' Datum TVD = xxxx' SS 20" I 114' I 10.3/4" CSG. 40#, L-80, ~ = 9.95" ~~ 3273' Minimum ID = 3.812" @ 6595' 4-1/2" CMD Sliding Sleeve 4.5"PHOEND( DSCHRG~PRESS SUB,O = 3.85" 6585' PHNDC MULTI-PRESS SENSOR ID = 3.994" ~--~ 6619' RA TAG 6731' 7-5/8" x 5.5" BKR ZXP PACKER ~ = 5.5" 6739' ~ BKR HUGHES HOOK HGR, ID = 5.64" ~-~ 6776' RA TAG 6897' 7-5/8" x 5.5" BKR ZXP PACKER ID = 3.98" 6885' ~ BKR HUGHES HOOK HGR, ID = 3.98" ~-~ 6942' RA TAG 7021' 7-5/8" x 5.5" BKR ZXP PACKER, ID = 4.94" 7011' I BKR HUGHES HOOK HGR ID = 3.98" ~ 7067' PERFORATION SUMMARY REF LOG : ANGLE AT TOP PERF: xx @xxxx' Note: Refer to Roduction DB for historical perf data SIZE SPF INTERVAL Opn/Sqz DATE 4-112" SLTD OA 6781' - 10324' O 07/07/05 4-1/2" SLTD OBa 6946' - 11865' O 06/30/05 4-1/2" SLTD OBb 7072' - 11183' O 06/24/05 4-1/2" 5LTD OBd 7665' - 12625' O 06/16105 I ` I I 7 5/8" CSG, 29.7#, L-80, b= 6.875" 7665' I i I I I PBTD 12623' I- ~ NOTES: 2258' -j4-1/2" HES X NIP, D = 3.813" GAS L~-f MANDRELS ST MD TVO DEV TYPE VLV LATCH PORT DATE 4 3024 2000 59 KBG-2 DMY SBK-2 1" 07/09/05 3 5007 2500 57 KBG-2 OMY SBK-2 1" 07!09/05 2 6036 3500 60 KBG-2 DMY SBK-2 1" 07/09!05 1 3459 4234 59 KBG-2 DCK2 BEK 1" 07/09/05 6595' 4-1/2" BKR CMD SLEEVE, ~ = 3.812" 6643' 7.625" X 4.5" BKR PRM PKR ID = 3.875" 6710' 4-1/2" HES X NIP, ~ = 3.813" 6731' 4-1/2" HES XNIP, O = 3.813" 6758' 4-1/2" Guide shoe ________________~ 75/8"WINDOW@6781' 6781' - 10324' 6-3/4" OA LATERAL, ID = 3.958" 6913' 4-1/2" Seal Assembly ________________~ 75/8"WINDOW@6946' 6946' - 11,865' 6-3/4" OBa LATERAL, ID = 3.958" 7040' 4-1/2" Seal Assembly _________________~ 75/8"WINDOW@7072' 7072' -11,183' 6-3/4" OBb LATERAL, ID = 3.958" 7127' 7.625" X 5.5" BKR ZXP LNR TOP PKR ID = 4.940" 7166' 4-1/2" Seal Assembly 7175' 5-1/2" X 4-1/2" XO, ~ = 3.96" 7538' (-~ RA TAG 7665' -12,625' 6-3/4" OBd LATERAL, ID = 3.958" DATE REV BY C,oMMENTS DATE REV BY COMMENTS ORION UNfT 07!11/05 TAfdf ORIGNJAL COMPLETION WELL: L-202, L-202 L1, L-202 L2, L-202 PERMR No: 204996 (197) (198) (199) API No: 50-029-23229-00 (60) (61) (E SEC 34, T12N, R11 E, 2572' NSL & 3690' WEL SP 6cploration (Alaska) L-202 L-202 L1 L-202 L2 L-202 L3 CCJ$n,,~ a r r: SCHLUMBERGER Survey report Client ...................: BP Exploration (Alaska) Inc. Field ..................... Orion Well ...................... L-202L1 API number ...............: 50-029-23229-60 Engineer .................: St. Amour Rig :...................... Nabors 9ES STATE :.................... Alaska ----- Survey calculation methods------------- Method for positions.....: Minimum curvature Method for DLS...........: Mason & Taylor ----- Depth reference ---- Permanent datum..........: Depth reference........... GL above permanent.......: KB above permanent.......: DF above permanent.......: ------------------ Mean Sea Level Driller's Pipe Tally 48.80 ft N/A (Topdrive) 77.30 ft ----- Vertical section origin---------------- Latitude (+N/S-).........: 0.00 ft Departure (+E/W-)........: 0.00 ft ----- Platform reference point--------------- Latitude (+N/S-).........: -999.25 ft Departure (+E/W-)........: -999.25 ft Azimuth from Vsect Origin to target: 105.00 degrees 23-Jun-2005 07:22:37 Page 1 of 9 Spud date ................: 4-July-05 Last survey date.........: 23-Jun-05 Total accepted surveys...: 236 MD of first survey.......: 0.00 ft MD of last survey........: 12115.00 ft ----- Geomagnetic data ---------------------- Magnetic model...........: BGGM version 2004 Magnetic date ............: 20-Jun-2005 Magnetic field strength..: 1152.32 HCNT Magnetic dec (+E/W-).....: 24.42 degrees Magnetic dip .............: 80.81 degrees ----- MWD survey Reference Reference G ............... Reference H ............... Reference Dip ............: Tolerance of G...........: Tolerance of H............ Tolerance of Dip.........: Criteria --------- 1002.68 meal 1152.32 HCNT 80.81 degrees (+/-) 2.50 meal (+/-) 6.00 HCNT (+/-) 0.45 degrees ----- Corrections --------------------------- Magnetic dec (+E/W-)...... 24.42 degrees Grid convergence (+E/W-).: 0.00 degrees Total az corr (+E/W-)....: 24.42 degrees (Total az corr = magnetic dec - grid cony) Survey Correction Type .... I=Sag Corrected Inclination M=Schlumberger Magnetic Correction S=Shell Magnetic Correction F=Failed Axis Correction R=Magnetic Resonance Tool Correction D=Dmag Magnetic Correction C7 • SCHLUMBERGER Survey Report 23 -Jun-2005 07:22:37 Page 2 of 9 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 1 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 0.00 TIP None 2 300.84 0.34 25.11 300.84 300.84 0.16 0.81 0.38 0.89 25.11 0.11 MWD IFR MS 3 391.65 0.36 9.86 90.81 391.65 0.18 1.33 0.54 1.44 22.12 0.10 MWD IFR MS 4 576.28 0.53 10.49 184.63 576.27 0.06 2.74 0.80 2.86 16.19 0.09 MWD IFR MS 5 670.46 0.56 14.93 94.18 670.45 0.02 3.62 0.99 3.75 15.37 0.05 MWD IFR MS 6 764.71 2.54 25.42 94.25 764.66 0.40 5.95 2.01 6.28 18.67 2.11 MWD_ IFR _MS 7 857.53 4.53 18.44 92.82 857.30 0.99 11.28 4.05 11.99 19.75 2.19 MWD_ IFR _MS • 8 953.21 6.95 15.51 95.68 952.49 1.27 20.45 6.80 21.55 18.38 2.55 MWD IFR MS 9 1047.74 10.47 16.79 94.53 1045.92 1.59 34.19 10.81 35.85 17.54 3.73 MWD IFR MS 10 1142.12 13.77 15.29 94.38 1138.18 1.92 53.24 16.25 55.66 16.97 3.51 MWD IFR MS 11 1236.19 16.95 13.24 94.07 1228.88 1.55 77.39 22.34 80.55 16.10 3.43 MWD IFR MS 12 1330.83 19.13 11.06 94.64 1318.86 0.06 106.04 28.48 109.80 15.03 2.41 MWD IFR MS 13 1425.26 20.68 12.40 94.43 1407.65 -1.76 137.51 35.03 141.91 14.29 1.71 MWD IFR MS 14 1520.69 23.94 14.64 95.43 1495.92 -2.64 172.72 43.54 178.12 14.15 3.53 MWD IFR MS 15 1617.99 23.95 13.68 97.30 1584.85 -3.22 211.00 53.20 217.61 14.15 0.40 MWD IFR MS 16 1712.21 28.23 11.54 94.22 1669.45 -5.01 251.44 62.19 259.01 13.89 4.65 MWD IFR MS 17 1806.43 30.66 12.06 94.22 1751.49 -7.59 296.77 71.67 305.30 13.58 2.59 MWD IFR MS 18 1900.26 33.39 12.61 93.83 1831.04 -9.89 345.37 82.30 355.04 13.40 2.93 MWD IFR MS 19 1995.66 38.73 11.57 95.40 1908.13 -12.77 400.27 94.03 411.16 13.22 5.63 MWD IFR MS 20 2090.94 43.52 10.77 95.28 1979.88 -16.98 461.73 106.14 473.78 12.95 5.06 MWD IFR MS 21 2184.89 47.07 11.00 93.95 2045.96 -21.77 527.29 118.75 540.50 12.69 3.78 MWD_ IFR _MS • 22 2279.02 50.58 11.89 94.13 2107.93 -26.14 596.72 132.83 611.33 12.55 3.80 MWD IFR MS 23 2372.26 54.00 12.29 93.24 2164.95 -29.88 668.84 148.28 685.08 12.50 3.68 MWD IFR MS 24 2466.25 56.54 12.21 93.99 2218.49 -33.59 744.32 164.67 762.31 12.47 2.70 MWD IFR MS 25 2560.42 58.25 12.15 94.17 2269.23 -37.49 821.86 181.40 841.64 12.45 1.82 MWD IFR MS 26 2654.71 59.04 11.60 94.29 2318.30 -41.88 900.65 197.97 922.15 12.40 0.97 MWD IFR MS 27 2749.60 59.40 11.73 94.89 2366.85 -46.62 980.49 214.45 1003.67 12.34 0.40 MWD IFR MS 28 2843.79 59.44 11.64 94.19 2414.77 -51.31 1059.90 230.88 1084.76 12.29 0.09 MWD IFR MS 29 2939.01 59.34 11.69 95.22 2463.26 -56.08 1140.16 247.45 1166.70 12.24 0.11 MWD IFR MS 30 3033.56 58.86 11.85 94.55 2511.81 -60.65 1219.59 263.99 1247.83 12.21 0.53 MWD IFR MS SCHLUMBERGER Survey Report 23-Jun-2005 07:22:37 Page 3 of 9 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool. # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 31 3128.08 58.78 11.89 94.52 2560.75 -65.07 1298.72 280.63 1328.70 12.19 0.09 MWD IFR MS 32 3223.61 59.32 12.07 95.53 2609.88 -69.38 1378.87 297.63 1410.62 12.18 0.59 MWD IFR MS 33 3302.79 58.27 13.26 79.18 2650.90 -72.15 1444.94 312.48 1478.34 12.20 1.85 MWD IFR MS 34 3332.92 58.16 12.74 30.13 2666.77 -73.04 1469.90 318.24 1503.95 12.22 1.51 MWD IFR MS 35 3427.34 57.83 12.68 94.42 2716.82 -76.24 1548.00 335.86 1584.02 12.24 0.35 MWD IFR MS 36 3520.48 59.11 12.46 93.14 2765.52 -79.61 1625.49 353.13 1663.40 12.26 1.39 MWD _IFR _MS • 37 3614.60 58.90 12.46 94.12 2813.99 -83.18 1704.27 370.54 1744.08 12.27 0.22 MWD IFR ` MS 38 3708.59 58.76 12.33 93.99 2862.64 -86.84 1782.81 387.80 1824.50 12.27 0.19 MWD IFR MS 39 3803.17 60.00 12.46 94.58 2910.81 -90.54 1862.31 405.27 1905.89 12.28 1.32 MWD IFR MS 40 3897.73 59.55 12.44 94.56 2958.41 -94.17 1942.09 422.89 1987.60 12.28 0.48 MWD IFR MS 41 3991.42 60.14 12.38 93.69 3005.47 -97.83 2021.21 440.30 2068.61 12.29 0.63 MWD IFR MS 42 4085.47 60.66 14.91 94.05 3051.94 -99.76 2100.67 459.59 2150.35 12.34 2.40 MWD IFR MS 43 4180.85 62.09 18.79 95.38 3097.64 -97.04 2180.76 483.87 2233.80 12.51 3.87 MWD IFR MS 44 4275.50 62.77 19.74 94.65 3141.45 -90.80 2259.96 511.55 2317.14 12.75 1.14 MWD IFR MS 45 4369.33 61.59 22.65 93.83 3185.25 -81.86 2337.33 541.54 2399.24 13.04 3.02 MWD IFR MS 46 4463.07 60.92 24.56 93.74 3230.33 -69.56 2412.63 574.45 2480.08 13.39 1.92 MWD IFR MS 47 4558.50 59.11 25.99 95.43 3278.02 -54.83 2487.38 609.73 2561.02 13.77 2.30 MWD IFR MS 48 4652.08 58.36 27.82 93.58 3326.59 -38.33 2558.71 _ 645.92 2638.97 14.17 1.85 MWD IFR MS 49 4745.64 59.00 29.78 93.56 3375.23 -19.27 2628.74 684.42 2716.37 14.59 1.92 MWD IFR MS 50 4840.53 59.04 32.79 94.89 3424.08 3.54 2698.25 726.66 2794.38 15.07 2.72 MWD IFR MS 51 4932.96 58.18 32.71 92.43 3472.23 27.60 2764.61 769.34 2869.66 15.55 0.93 MWD_ IFR_ MS • 52 5029.33 57.47 34.52 96.37 3523.55 53.63 2832.54 814.49 2947.31 16.04 1.75 MWD TFR MS 53 5123.41 57.25 34.96 94.08 3574.29 80.39 2897.64 859.64 3022.46 16.52 0.46 MWD IFR MS 54 5217.80 58.51 34.97 94.39 3624.47 107.68 2963.15 905.45 3098.40 16.99 1.33 MWD IFR MS 55 5312.23 59.95 35.35 94.43 3672.78 135.65 3029.48 952.18 3175.59 17.45 1.56 MWD IFR MS 56 5405.78 61.32 35.70 93.55 3718.66 164.23 3095.83 999.55 3253.19 17.89 1.50 MWD ~ IFR_ MS 57 5500.71 60.71 35.59 94.93 3764.66 193.51 3163.31 1047.94 3332.37 18.33 0.65 MWD ^ IFR MS 58 5596.24 61.46 38.08 95.53 3810.85 224.61 3230.23 1098.07 3411.76 18.77 2.41 MWD ~ IFR MS 59 5691.12 63.07 42.66 94.88 3855.03 260.60 3294.17 1152.46 3489.94 19.28 4.60 MWD IFR MS 60 5785.12 63.56 47.61 94.00 3897.26 302.76 3353.38 1211.97 3565.68 19.87 4.73 MWD IFR MS SCHLUMBERGER Survey Report 23 -Jun-2005 07:22:37 Page 4 of 9 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 61 5879.62 63.10 51.86 94.50 3939.69 350.85 3407.95 1276.38 3639.13 20.53 4.05 MWD IFR MS 62 5973.89 60.96 55.76 94.27 3983.92 402.99 3457.12 1343.54 3709.01 21.24 4.30 MWD IFR MS 63 6069.13 60.11 59.75 95.24 4030.78 459.26 3501.35 1413.64 3775.96 21.99 3.75 MWD IFR MS 64 6163.57 61.29 64.17 94.44 4077.01 519.44 3540.04 1486.32 3839.40 22.78 4.27 MWD IFR MS 65 6258.13 59.14 68.38 94.56 4124.00 583.42 3573.08 1561.41 3899.34 23.60 4.48 MWD IFR MS 66 6350.96 56.53 72.30 .92.83 4173.43 648.01 3599.54 1635.36 3953.62 24.43 4.55 MWD_ IFR _MS 67 6445.47 57.16 76.61 94.51 4225.13 716.14 3620.73 1711.57 4004.89 25.30 3.88 MWD_ IFR _MS . 68 6539.08 58.35 80.50 93.61 4275.09 787.01 3636.41 1789.15 4052.72 26.20 3.74 MWD IFR MS 69 6633.04 63.82 84.48 93.96 4320.52 862.97 3647.08 1870.64 4098.84 27.15 6.90 MWD IFR MS 70 6727.96 67.49 87.23 94.92 4359.64 944.65 3653.30 1956.87 4144.39 28.18 4.68 MWD IFR MS 71 6821.91 68.85 90.61 93.95 4394.59 1028.44 3654.93 2044.05 4187.68 29.22 3.64 MWD IFR MS 72 6915.74 69.25 92.21 93.83 4428.14 1113.61 3652.77 2131.65 4229.26 30.27 1.65 MWD IFR MS 73 7010.72 68.67 92.35 94.98 4462.24 1200.08 3649.25 2220.22 4271.58 31.32 0.63 MWD IFR MS 74 7072.00 68.96 92,90 61.28 4484.38 1255.89 3646.63 2277.30 4299.30 31.98 0.96 BP_IN C+TREND 75 7084.00 70.82 92.37 12.00 4488.51 1266.90 3646.11 2288.56 4304.84 32.12 16.05 BP IN C+TREND 76 7120.36 72.84 94.16 36.36 4499.85 1300.72 3644.14 2323.05 4321.61 32.52 7.26 BP_IN C+TREND 77 7150.72 76.89 95,61 30.36 4507.77 1329.56 3641.64 2352.24 4335.27 32.86 14.11 BP_IN C+TREND 78 7182.04 80.98 97.06 31.32 4513.78 1359.94 3638.25 2382.78 4349.08 33.22 13.83 BP_IN C+TREND 79 7213.57 84.67 98.50 31.53 4517.72 1390.97 3634.01 2413.77 4362.61 33.59 12.55 BP_IN C+TREND 80 7244.95 89.14 99.92 31.38 4519.42 1422.14 3629.00 2444.69 4375.63 33.97 14.94 MWD IFR MS 81 7275.70 92.40 103.46 30.75 4519.00 1452.82 3622.77 2474.79 4387.38 34.34 15.65 MWD_ IFR_ MS • 82 7307.24 96.05 103.60 31.54 4516.68 1484.26 3615.41 2505.37 4398.65 34.72 11.58 MWD IFR MS 83 7338.21 97.01 103.79 30.97 4513.16 1515.02 3608.13 2535.26 4409.78 35.09 3.16 MWD IFR MS 84 7369.31 96.81 105.04 31.10 4509.42 1545.90 3600.44 2565.16 4420.78 35.47 4.04 MWD IFR MS 85 7400.99 96.77 105.26 31.68 4505.67 1577.35 3592.22 2595.53 4431.80 35.85 0.70 MWD IFR MS 86 7432.33 96.98 104.59 31.34 4501.92 1608.47 3584.21 2625.59 4443.00 36.22 2.23 MWD IFR MS 87 7463.10 97.12 103.73 30.77 4498.14 1639.00 3576.74 2655.20 4454.57 36.59 2.81 MWD IFR MS 88 7493.85 97.01 105.20 30.75 4494.36 1669.52 3569.12 2684.75 4466.15 36.95 4.76 MWD IFR MS 89 7526.25 94.26 102.99 32.40 4491.18 1701.75 3561.27 2716.02 4478.77 37.33 10.87 MWD IFR MS 90 7557.21 91.10 101.41 30.96 4489.73 1732.63 3554.73 2746.24 4491.99 37.69 11.41 MWD IFR MS SCHLUMBERGER Survey Report 23 -Jun-2005 07:22:37 Page 5 of 9 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) {deg) (deg) (ft) (ft) {ft) (ft) (ft) (ft) (deg) 100f) type (deg) 91 7588.06 89.21 101.48 30.85 4489.65 1763.42 3548.61 2776.48 4505.71 38.04 6.13 MWD IFR MS 92 7619.23 89.66 103.48 31.17 4489.95 1794.56 3541.88 2806.91 4519.25 38.40 6.58 MWD IFR MS 93 7649.98 91.06 105.07 30.75 4489.76 1825.31 3534.29 2836.71 4531.90 38.75 6.89 MWD IFR MS 94 7681.42 91.20 104.59 31.44 4489.14 1856.74 3526.25 2867.09 4544.74 39.11 1.59 MWD IFR MS 95 7712.31 91.06 103.61 30.89 4488.53 1887.62 3518.73 2897.05 4557.88 39.47 3.20 MWD IFR MS 96 7743.03 90.75 104.98 30.72 4488.05 1918.33 3511.14 2926.81 4571.03 39.81 4.57 MWD_ IFR _MS 97 7774.41 92.16 104.69 31.38 4487.25 1949.70 3503.11 2957.13 4584.37 40.17 4.59 MWD_ IFR _MS . 98 7805.71 92.50 103.75 31.30 4485.98 1980.97 3495.43 2987.45 4598.14 40.52 3.19 MWD IFR MS 99 7836.79 92.13 102..46 31.08 4484.72 2012.01 3488.39 3017.69 4612.52 40.86 4.31 MWD IFR MS 100 7867.67 90.62 102.73 30.88 4483.98 2042.85 3481.66 3047.82 4627.22 41.20 4.97 MWD IFR MS 101 7899.00 90.03 105.82 31.33 4483.80 2074.17 3473.93 3078.18 4641.49 41.54 10.04 MWD IFR MS 102 7930.54 90.51 106.80 31.54 4483.65 2105.71 3465.07 3108.45 4655.02. 41.89 3.46 MWD IFR MS 103 7962.02 91.17 107.56 31.48 4483.19 2137.16 3455.78 3138.52 4668.27 42.25 3.20 MWD IFR MS 104 7991.67 91.23 108.01 29.65 4482.57 2166.77 3446.72 3166.75 4680.62 42.58 1.53 MWD IFR MS 105 8022.53 90.86 108.97 30.86 4482.01 2197.56 3436.94 3196.01 4693.29 42.92 3.33 MWD IFR MS 106 8053.20 90.07 107.74 30.67 4481.76 2228.18 3427.28 3225.12 4706.13 43.26 4.77 MWD IFR MS 107 8084.02 88.63 107.27 30.82 4482.11 2258.97 3418.01 3254.51 4719.60 43.60 4.91 MWD IFR MS 108 8114.32 88.53 105.68 30.30 4482.86 2289.25 3409.42 3283.55 4733.48 43.92 5.26 MWD IFR MS 109 8144.98 87.84 103.44 30.66 4483.83 2319.89 3401.72 3313.21 4748.58 44.24 7.64 MWD IFR MS 110 8174.79 88.18 103.20 29.81 4484.87 2349.67 3394.85 3342.20 4763.96 44.55 1.40 MWD IFR MS 111 8206.09 89.31 101.47 31.30 4485.55 2380.92 3388.17 3372.77 4780.72 44.87 6.60 MWD_ IFR _MS • 112 8236.81 90.69 102.13 30.72 4485.55 2411.60 3381.89 3402.84 47.97.55 45.18 4.98 MWD IFR MS 113 8267.06 92.43 101.29 30.25 4484.73 2441.78 3375.75 3432.45 4814.29 45.48 6.39 MWD IFR MS 114 8297.94 92.02 101.04 30.88 4483.53 2472.57 3369.77 3462.72 483 1.75 45.78 1.55 MWD IFR MS 115 8328.39 91.65 100.34 30.45 4482.55 2502.92 3364.13 3492.63 4849.31 46.07 2.60 MWD IFR MS 116 8358.03 91.34 101.29 29.64 4481.78 2532.47 3358.57 3521.73 4866.47 46.36 3.37 MWD IFR MS 117 8389.69 92.54 103.54 31.66 4480.71 2564.08 3351.77 3552.63 4884.21 46.67 8.05 MWD IFR MS 118 8420.49 91.75 104.60 30.80 4479.56 2594.85 3344.28 3582.48 4900.86 46.97 4.29 MWD IFR MS 119 8450.87 89.18 105.81 30.38 4479.31 2625.23 3336.32 3611.80 4916.92 47.27 9.35 MWD IFR MS 120 8482.13 88.73 107.04 31.26 4479.88 2656.47 3327.48 3641.78 4933.02 47.58 4.19 MWD IFR MS SCHLUMBERGER Survey Report 23 -Jun-2005 07:22:37 Page 6 of 9 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 121 8513.26 88.42 107.11 31.13 4480.65 2687.57 3318.34 3671.52 4948.89 47.89 1.02 MWD IFR MS 122 8544.73 88.53 107.74 31.47 4481.49 2719.00 3308.92 3701.54 4964.91 48.21 2.03 MWD IFR MS 123 8574.67 88.87 107.67 29.94 4482.17 2748.90 3299.82 3730.05 4980.17 48.50 1.16 MWD IFR MS 124 8606.19 89.28 108.24 31.52 4482.68 2780.37 3290.10 3760.04 4996.26 48.81 2.23 MWD IFR MS 125 8636.89 88.94 109.11 30.70 4483.16 2811.01 3280.28 3789.11 5011.75 49.12 3.04 MWD IFR MS 126 8668.36 89.04 109.70 31.47 4483.71 2842.38 3269.82 3818.79 5027.42 49.43 1.90 MWD_ IFR _MS . 127 8699.59 89.07 109.41 31.23 4484.23 2873.51 3259.37 3848.22 5043.04 49.74 0.93 MWD_ IFR _MS 12$ 8730.25 89.21 109.63 30.66 4484.69 2904.07 3249.13 3877.11 5058.54 50.04 0.85 MWD IFR MS 129 8762.10 89.31 107.30 31.85 4485.10 2935.85 3239.04 3907.32 5075.28 50.34 7.32 MWD IFR MS 130 8793.09 89.11 107.30 30.99 4485.53 2966.82 3229.83 3936.90 5092.25 50.63 0.65 MWD IFR MS 131 8823.99 89.11 107.96 30.90 4486.01 2997.68 3220.47 3966.35 5109.14 50.93 2.14 MWD IFR MS 132 8855.79 89.55 109.15 31.80 4486.38 3029.42 3210.35 3996.49 5126.24 51.23 3.99 MWD IFR MS 133 8886.27 89.93 110.10 30.48 4486.52 3059.80 3200.11 4025.20 5142.27 51.51 3.36 MWD IFR MS 134 8917.38 90.45 108.40 31.11 4486.41 3090.82 3189.86 4054.57 5158.95 51.81 5.71 MWD IFR MS 135 8948.61 89.14 105.21 31.23 4486.52 3122.03 3180.83 4084.46 5176.92 52.09 11.04 MWD IFR MS 136 8979.65 88.42 102.63 31.04 4487.19 3153.05 3173.36 4114.58 5196.15 52.36 8.63 MWD IFR MS 137 9011.29 88.63 103.57 31.64 4488.00 3184.66 3166.20 4145.39 5216.23 52.63 3.04 MWD IFR MS 138 9042.53 88.73 104.42 31.24 4488.72 3215.89 3158.64 4175.69 5235.78 52.89 2.74 MWD IFR MS 139 9073.93 88.39 104.70 31.40 4489.51 3247.28 3150.75 4206.07 5255.31 53.16 1.40 MWD IFR MS 140 9104.89 87.70 104.83 30.96 4490.56 3278.22 3142.87 4235.99 5274.58 53.43 2.27 MWD IFR MS 141 9136.11 87.60 104.95 31.22 4491.85 3309.42 3134.85 4266.14 5294.07 53.69 0.50 MWD_ IFR_ MS • 142 9167.92 87.43 104.09 31.81 4493.22 3341.19 3126.88 4296.90 5314.20 53.96 2.75 MWD IFR MS 143 9200.09 86.98 104.17 32.17 4494.79 3373.32 3119.04 4328.06 5334.84 54.22 1.42 MWD IFR MS 144 9229.86 88.80 104.09 29.77 4495.89 3403.07 3111.78 4356.91 5354.05 54.46 6.12 MWD IFR MS 145 9261.90 87.53 104.39 32.04 4496.92 3435.09 3103.90 4387.95 5374.78 54.73 4.07 MWD IFR MS 146 9293.38 87.26 106.77 31.48 4498.35 3466.53 3095.45 4418.24 5394.69 54.98 7.60 MWD IFR MS 147 9324.06 86.71 106.51 30.68 4499.96 3497.15 3086.68 4447.59 5413.75 55.24 1.98 MWD IFR MS 148 9355.96 86.64 106.35 31.90 4501.81 3528.99 3077.67 4478.14 5433.76 55.50 0.55 MWD IFR MS 149 9386.25 86.77 107.92 30.29 4503.55 3559.21 3068.76 4507.04 5452.58 55.75 5.19 MWD IFR MS 150 9416.13 86.67 107.39 29.88 4505.26 3589.01 3059.72 4535.46 5471.04 56.00 1.80 MWD IFR MS SCHLUMBERGER Survey Report 23-Jun-2005 07:22:37 Page 7 of 9 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 151 9446.94 87.29 108.43 30.81 4506.88 3619.74 3050.25 4564.74 5490.07 56.25 3.93 MWD IFR MS 152 9478.77 88.83 105.40 31.83 4507.96 3651.52 3041.00 4595.17 5510.29 56.50 10.67 MWD IFR MS 153 9509.50 87.63 103.62 30.73 4508.91 3682.24 3033.30 4624.90 5530.88 56.74 6.98 MWD IFR MS 154 9540.59 89.04 104.75 31.09 4509.81 3713.31 3025.69 4655.03 5551.95 56.98 5.81 MWD IFR MS 155 9572.15 89.25 104.97 31.56 4510.29 3744.87 3017.60 4685.53 5573.16 57.22 0.96 MWD IFR MS 156 9603.20 90.03 106.11 31.05 4510.48 3775.91 3009.28 4715.45 5593.85 57.46 4.45 MWD_ IFR _MS . 157 9635.37 90.75 106.20 32.17 4510.26 3808.08 3000.33 4746.35 5615.14 57.70 2.26 MWD IFR MS 158 9666.18 89.59 104.67 30.81 4510.17 3838.88 2992.13 4776.04 5635.90 57.93 6.23 MWD IFR MS 159 9695.93 87.74 104.61 29.75 4510.86 3868.62 2984.61 4804.82 5656.34 58.15 6.22 MWD IFR MS 160 9727.51 88.53 104.85 31.58 4511.89 3900.19 2976.59 4835.34 5678.08 58.38 2.61 MWD IFR MS 161 9758.77 88.80 105.63 31.26 4512.62 3931.44 2968.37 4865.49 5699.50 58.61 2.64 MWD IFR MS 162 9789.45 88.25 105.04 30.68 4513.41 3962.11 2960.26 4895.07 5720.57 58.84 2.63 MWD IFR MS 163 9821.08 87.56 104.10 31.63 4514.57 3993.71 2952.31 4925.66 5742.67 59.06 3.68 MWD IFR MS 164 9852.06 87.60 104.56 30.98 4515.87 4024.66 2944.65 4955.65 5764.50 59.28 1.49 MWD IFR MS 165 9882.90 88.18 104.58 30.84 4517.01 4055.48 2936.89 4985.48 5786.22 59.50 1.88 MWD IFR MS 166 9915.24 87.81 104.13 32.34 4518.14 4087.80 2928.88 5016.79 5809.18 59.72 1.80 MWD IFR MS 167 9946.23 88.53 104.81 30.99 4519.13 4118.77 2921.14 5046.78 5831.22 59.94 3.19 MWD IFR MS 168 9977.75 89.07 105.32 31.52 4519.79 4150.29 2912.95 5077.21 5853.49 60.16 2.36 MWD IFR MS 169 10008.91 88.32 104.32 31.16 4520.50 4181.44 2904.98 5107.33 5875.69 60.37 4.01 MWD IFR MS 170 10039.02 87.36 104.23 30.11 4521.63 4211.52 2897.56 5136.49 5897.41 60.57 3.20 MWD IFR MS 171 10070.42 88.11 104.72 31.40 4522.88 4242.90 2889.72 5166.87 5920.05 60.78 2.85 MWD_ IFR_ MS • 172 10101.97 89.62 104.68 31.55 4523.50 4274.44 2881.72 5197.38 5942.81 60.99 4.79 MWD IFR MS 173 10132.89 89.73 103.80 30.92 4523.68 4305.35 2874.11 5227.35 5965.37 61.20 2.87 MWD IFR MS 174 10164.18 89.66 103.63 31.29 4523.84 4336.64 2866.69 5257.74 5988.47 61.40 0.59 MWD IFR MS 175 10195.26 87.84 104.01 31.08 4524.52 4367.70 2859.27 5287.92 6011.45 61.60 5.98 MWD IFR MS 176 10226.98 86.36 105.32 31.72 4526.13 4399.38 2851.25 5318.56 6034.63 61.80 6.23 MWD IFR MS 177 10258.87 85.85 105.81 31.89 4528.29 4431.19 2842.72 5349.21 6057.65 62.01 2.22 MWD IFR MS 178 10289.98 85.50 106.40 31.11 4530.64 4462.21 2834.11 5379.02 6079.97 62.22 2.20 MWD IFR MS 179 10320.77 85.30 104.97 30.79 4533.11 4492.90 2825.81 5408.56 6102.28 62.41 4.67 MWD IFR MS 180 10352.24 85.74 107.74 31.47 4535.57 4524.26 2816.98 5438.66 6124.90 62.62 8.89 MWD IFR MS SCHLUMBERGER Survey Report 23 -Jun-2005 07:22:37 Page 8 of 9 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 181 10383.69 86.12 107.84 31.45 4537.80 4555.59 2807.39 5468.53 6147.06 62.83 1.25 MWD IFR MS 182 10414.05 87.08 108.87 30.36 4539.60 4585.85 2797.85 5497.30 6168.33 63.03 4.63 MWD IFR MS 183 10444.80 90.10 107.66 30.75 4540.36 4616.53 2788.22 5526.49 6190.01 63.23 10.58 MWD IFR MS 184 10474.93 91.89 106.16 30.13 4539.83 4646.64 2779.46 5555.31 6211.83 63.42 7.75 MWD IFR MS 185 10507.20 91.85 105.80 32.27 4538.78 4678.89 2770.58 5586.31 6235.62 63.62 1.12 MWD IFR MS 186 10537.95 90.31 105.78 30.75 4538.20 4709.63 2762.21 5615.90 6258.44 63.81 5.01 MWD_ IFR _MS • 187 10568.79 86.95 103.47 30.84 4538.94 4740.45 2754.43 5645.72 6281.80 63.99 13.22 MWD_ IFR _MS 188 10599.44 86.26 104.02 30.65 4540.75 4771.04 2747.16 5675.44 6305.36 64.17 2.88 MWD IFR MS 189 10630.14 87.98 104.24 30.70 4542.29 4801.70 2739.67 5705.17 6328:89 64.35 5.65 MWD IFR MS 190 10662.42 87.84 103.38 32.28 4543.47 4833.95 2731.97 5736.50 6353.83 64.53 2.70 MWD IFR MS 191 10692.24 87.84 103.56 29.82 4544.60 4863.74 2725.03 5765.48 6377.03 64.70 0.60 MWD IFR MS 192 10723.65 88.46 104.90 31.41 4545.61 4895.13 2717.31 5795.91 6401.28 64.88 4.70 MWD IFR MS 193 10753.63 87.36 104.41 29.98 4546.70 4925.09 2709.73 5824.89 6424.33 65.05 4.02 MWD IFR MS 194 10785.63 84.99 102.75 32.00 4548.84 4957.00 2702.24 5855.93 6449.34 65.23 9.04 MWD IFR MS 195 10816.84 84.71 102.60 31.21 4551.6.4 4988.06 2695.42 5886.25 6474.04 65.40 1.02 MWD IFR MS 196 10848.08 85.02 103.91 31.24 4554.44 5019.16 2688.28 5916.54 6498.64 65.56 4.29 MWD IFR MS 197 10879.22 85.09 105.18 31.14 4557.12 5050.18 2680.49 5946.57 6522.78 65.74 4.07 MWD IFR MS 198 10909.16 86.05 106.27 29.94 4559.43 5080.03 2672.40 5975.30 6545.68 65.90 4.84 MWD IFR MS 199 10940.86 87.46 107.12 31.70 4561.23 5111.66 2663.31 6005.61 6569.67 66.08 5.19 MWD IFR MS 200 10973.28 89.45 108.13 32.42 4562.10 5144.04 2653.50 6036.50 6593.96 66.27 6.88 MWD IFR MS 201 11003.51 89.31 108.91 30.23 4562.43 5174.21 2643.90 6065.16 6616.37 66.45 2.62 MWD_ IFR_ MS • 202 11034.29 88.70 109.32 30.78 4562.96 5204.90 2633.82 6094.24 6639.03 66.63 2.39 MWD IFR MS 203 11065.68 88.22 108.29 31.39 4563.81 5236.21 2623.70 6123.94 6662.32 66.81 3.62 MWD IFR MS 204 11097.43 87.29 108.75 31.75 4565.05 5267.88 2613.63 6154.02 6686:04 66.99 3.27 MWD IFR MS 205 11127.63 87.63 108.26 30.20 4566.39 5297.99 2604.05 6182.63 6708.66 67.16 1.97 MWD IFR MS 206 11159.09 88.29 106.12 31.46 4567.51 5329.40 2594.76 6212.67 6732.76 67.33 7.11 MWD IFR MS 207 11189.44 89.04 107.17 30.35 4568.22 5359.73 2586.07 6241.74 6756.26 67.49 4.25 MWD IFR MS 208 11221.23 90.96 106.24 31.79 4568.22 5391.51 2576.93 6272.19 6780.92 67.66 6.71 MWD IFR MS 209 11252.70 91.06 105.30 31.47 4567.66 5422.97 2568.38 6302.47 6805.71 67.83 3.00 MWD_ IFR_ MS 210 11283.61 89.42 104.38 30.91 4567.53 5453.88 2560.46 6332.34 6830.41 67.98 6.08 MWD IFR MS SCHLUMBERGER Survey Report 23-Jun-2005 07:22:37 Page 9 of 9 Seq Measured Incl Azimuth Course TVD Vertical Displ Displ Total At DLS Srvy Tool # depth angle angle length depth section +N/S- +E/W- displ Azim (deg/ tool Corr - (ft) (deg) (deg) (ft) (ft) (ft) (ft) (ft) (ft) (deg) 100f) type (deg) 211 11313.67 87.29 103.36 30.06 4568.39 5483.92 2553.26 6361.51 6854.78 68.13 7.86 MWD IFR MS 212 11345.52 86.40 102.69 31.85 4570.15 5515.70 2546.09 6392.49 6880.89 68.28 3.50 MWD IFR MS 213 11376.72 86.36 103.87 31.20 4572.12 5546.82 2538.94 6422.80 6906.42 68.43 3.78 MWD IFR MS 214 11407.92 86.95 105.01 31.20 4573.94 5577.97 2531.18 6452.96 6931.64 68.58 4.11 MWD IFR MS 215 11439.04 87.12 104.83 31.12 4575.55 5609.05 2523.17 6482.99 6956.69 68.73 0.80 MWD IFR MS 216 11470.32 87.53 104.98 31.28 4577.01 5640.29 2515.14 6513.19 6981.94 68.89 1.40 MWD_ IFR_ MS 217 11501.66 88.59 106.47 31.34 4578.07 5671.61 2506.65 6543.34 7007.03 69.04 5.83 MWD IFR MS 218 11532.90 88.53 105.36 31.24 4578.85 5702.84 2498.08 6573.37 7032.04 69.19 3.56 MWD IFR MS 219 11565.30 88.08 106.28 32.40 4579.81 5735.22 2489.26 6604.53 7058.06 69.35 3.16 MWD IFR MS 220 11597.20 87.84 107.49 31.90 4580.95 5767.08 2480.00 6635.03 7083.36 69.51 3.86 MWD IFR MS 221 11626.59 87.50 106.33 29.39 4582.14 5796.43 2471.45 6663.13 7106.71 69.65 4.11 MWD IFR MS 222 11657.80 86.64 105.98 31.21 4583.74 5827.59 2462.78 6693.07 7131.79 69.80 2.97 MWD IFR MS 223 11690.02 87.36 105.93 32.22 4585.42 5859.76 2453.94 6724.00 7157.79 69.95 2.24 MWD IFR MS 224 11720.87 88.42 104.17 30.85 4586.56 5890.59 2445.93 6753.77 7183.04 70.09 6.66 MWD IFR MS 225 11751.37 87.81 104.46 30.50 4587.56 5921.07 2438.40 6783.31 7208.26 70.23 2.21 MWD IFR MS 226 11783.39 88.25 104.67 32.02 4588.66 5953.07 2430.35 6814.28 7234.71 70.37 1.52 MWD IFR MS 227 11813.54 87.91 104.22 30.15 4589.67 5983.20 2422.83 6843.46 7259.69 70.50 1.87 MWD IFR MS 228 11844.58 88.05 103.53 31.04 4590.77 6014.22 2415.39 6873.58 7285.61 70.64 2.27 MWD IFR MS 229 11876.12 88.15 101.15 31.54 4591.81 6045.70 2408.66 6904.37 7312.45 70.77 7.55 MWD IFR MS 230 11906.23 87.84 101.72 30.11 4592.87 6075.74 2402.69 6933.86 7338.35 70.89 2.15 MWD IFR MS 231 11937.52 87.87 102.10 31.29 4594.04 6106.96 2396.24 6964.46 7365.16 71.01 1.22 MWD_ IFR_ MS • 232 11969.07 87.63 102.17 31.55 4595.28 6138.44 2389.61 6995.28 7392.17 71.14 0.79 MWD IFR MS 233 12000.75 87.60 102.23 31.68 4596.60 6170.06 2382.92 7026.22 7419.30 71.27 0.21 MWD IFR MS 234 12031.51 87.60 103.35 30.76 4597.88 6200.77 2376.12 7056.19 7445.52 71.39 3.64 MWD IFR MS 235 12060.52 88.94 103.74 29.01 4598.76 6229.76 2369.33 7084.38 7470.08 71.51 4.81 MWD IFR MS 236 12115.00 88.94 103.74 54.48 4599.77 6284.21 2356.39 7137.29 7516.21 71.73 0.00 Projected to TD [(c)2005 IDEAL ID9_1C_01.4] • Schlumberger Drilling & Measurements MWD/LWD Log Product Delivery Customer BP Exploration (Alaska) Inc. Dispatched To: Helen Warman Well No L-202L1 Date Dispatched: 28-Jun-05 Installation/Rig Nabors 9ES Dispatched By: Mauricio Perdomo LWD Log Delivery V1.1,10-02-03 Data No Of Prints No of Floppies Surveys 2 1 Received By: "f1; ~ Please sign and return to: Drilling & Measurements LWD Division 2525 Gambelt Street, Suite 400 Anchorage, Alaska 99501 nroselC~4slb.com fax: 907-561-8317 ~~til ~- ~`~~7 r ~ I ` ~~ ~~ z ~LASSA OIL A11TD GAS COI~TSER'1TA'TI011T COrII~IISSIOI~T Lowell Crane Senior Drilling Engineer BP Exploration (Alaska) Inc. P.O. Box 196612 Anchorage, Alaska 99519-6612 Re: Prudhoe Bay L-202L1 FRANK H, MURKOWSKI, GOVERNOR a ~ 333 W. 7"' AVENUE, SUITE 100 tj ANCHORAGE, ALASKA 99501-3539 6 PHONE (907) 279-1433 FAX (907) 2767542 BP Exploration (Alaska) Inc. Permit No: 204-197 Surface Location: 2572' NSL, 3690' WEL, SEC. 34, T12N, R11E, UM Bottomhole Location: 4864' NSL, 3616' EWL, SEC. 35, T12N, R11E, UM Dear Mr. Crane: Enclosed is the approved application for permit to redrill the above development well. The permit is for a new wellbore segment of existing well PBU L-202, Permit No. 204-196, API No. 50-029-23229. Production should continue to be reported as a function of the. original API number stated above. This permit to redrill does not .exempt you from obtaining additional permits or approvals 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. Please provide. at least twenty-four (24) hours notice for a representative of the Commission to~itness any required test. Contact the Commission's petroleum field inspector at (907) 659- BY ORDER THE COMMISSION DATED this day of October, 2004 cc: Department of Fish & Game, Habitat Section w/o encl. Department of Environmental Conservation w/o encl. '~ STATE OF ALASKA ALASKA AND GAS CONSERVATION COMSSION I PERMIT TO DRILL ~EQ ~ ;~ 2DC~4 20 AAC 25.005 :.-c„„ 1 a. Type of work ~ Drill ®Redrill ^ Re-Entry 1 b. Current Well Class ^ Exploratory ®D~ Ht i ip a one ^ Stratigraphic Test ^ Service ^ Development G ~ Zone 2. Operator Name: BP Exploration (Alaska) Inc. 5. Bond: ®Blanket ^ Single Well Bond No. 2S100302630-277 11. Well Name and Number: ~. PBU L-202L1 3. Address: P.O. Box 196612, Anchorage, Alaska 99519-6612 6. Proposed Depth: MD 12304 TVp 4602 12. Field /Pool(s): Prudhoe Bay Field / Orion 4a. Location of Well (Governmental Section): Surface: 2572' NSL 3690' WEL SEC T12N 34 R11E UM 7. Property Designation: ADL 028238 Schrader Bluff , , . , , , Top of Productive Horizon: 754' NSL, 569' WEL, SEC. 27, T12N, R11E, UM (OBb) 8. Land Use Permit: 13. Approximate Spud Date: November 8, 2004 Total Depth: 4864' NSL, 3616' EWL, SEC. 35, T12N, R11E, UM 9. Acres in Property: 2560 14. Distance to Nearest Property: 4660' 4b. Location of Well (State Base Plane Coordinates): Surface: x-583224 y- 5978293 Zone-ASP4 10. KB Elevation (Height above GL):Plan 77.3 feet 15. Distance to Nearest well Within Pool L-118 is approximately 580' away 16. Deviated Wells: Kickoff Depth: 7138 feet Maximum Hole Angle: 92 de rees 17. Maximum Anticipated Pressures in psig (see 20 AAC 25.035 Downhole: 2035 Surface: 1580 // 1 asing Program: Size Specifications Setting Depth To Bottom uantity o Cement c.f_ or sacks Hole Casin Wei ht Grade Cou lin Len th MD TVD MD TVD includin sta a data 48" 20" x 34" 215.5# A53 Weld 80' 29' 29' 109' 109' 60 sx Arctic Set A rox. 13-1 /2" 10-3/4" 45.5# L-80 BTC 3171 29' 29' 3200' 2627' 580 sx AS Lite, 442 sx Class 'G' 9-7/8" 7-5/8" 29.7# L-80 BTC-M 7771' 29' 29' 7800' 4635' 562 sx Class 'G' 6-3/4" 4-1/2" 12.6# L-80 IBT 5178' 7126' 4505' 12304' 4602' Uncemented Slotted Liner i 19. PRESENTWELL CONDITION SUMMARY (To be completed for Redrill AND Re-c3ntry Operations) Total Depth MD (ft): 12634 Total Depth TVD (ft): 4722 Plugs (measured): None Effective Depth MD (ft): 12634 Effective Depth TVD (ft): 4722 Junk (measured): None Casing Length Size Cement Vo#ume MD TVD tr t I C n for 80' 20"x34" 260 sx Arctic Set A rox. 109' 109' 3171' 10-3/4" 580 sx AS Lite, 442 sx Class 'G' 3200' 2627' I i 7771' 7-5/8" 562 sx Class 'G' 7800' 4635' Prod tion Li r 4834' 4-112" Uncemented Slotted Liner 7800' - 12634' 4635' - 4722' Perforation Depth MD (ft): None Perforation Depth TVD (ft): None 20. Attachments ^ Filing Fee, $100 ^ BOP Sketch ®Drilling Program ^ Time vs Depth Plot ^ Shallow Hazard Analysis ^ Property Plat ^ Diverter Sketch ^ Seabed Report ®Drilling Fluid Program ®20 AAC 25.050 Requirements 21. Verbal Approval: Commission Representative: Date: 22. I hereby certify that the foregoing is true and correct to the best of my knowledge. Contact Rob Tirpack, 564-4166 Printed Name Lo ell Crane Title Senior Drilling Engineer Prepared By Name/Number: Si nature t ~-~-~'~ % ~'~t-~ Phone 564-4089 Date ~~-~ c'~ ~~y Terrie Hubble, 564-4628 Commission Use Only Permit To Drill Number. .. ` API Number; 50- DZ -2 3 2.'z. f row Permit Approval Date: ~ ~ r See cover letter for other requirements Conditions of Approval: Samples Required ^ Yes No Mud Log Required ^ Yes ~(No Hydrogen Sulfide Measures ^ Yes ~ No Directional Survey Required Yes ^ No ~~.'>+` zG 35 ~~, Cf, ~ ~~ ~~`t''r/t„i. ~~' ~~(~~ tPSf' ~~~ 4'~4'lLfy~ 1 Gj Ct,~ ~j ~ V ~` t~ , ` fl ~ I` 1 '~' ~ t \ ~ APPROVED BY A roved ~ ~ THE COMMISSION Date ~~ ~ 0 ti Form 10-401~evisecl~GC~1004 `~ St'ibm(t In Duplicate r • • ~ Well Name: ~ L-202, L-202 L1, L-202 L2 & L-202 L3 ~ Drill and Complete Plan Summary Type of Well (producer or injector): Schrader OBd, OBb, OBa, and OA Multilateral Producer Surface Location: 2,572' FSL, 3,690' FEL, Sec. 34, T12N, R11 E As Built X = 583,224 Y = 5,978,293 L-202 OBd Target Start: e.!._ u: 877' FSL, 897' FEL, Sec. 27, T12N, R11 E X = 585,970 Y = 5,981,910 Z = 4,547' TVDss L-202 OBd Target End: 4,780 FSL, 1,364' FEL, Sec. 35, T12N, R11 E X = 590.800 Y = 5.980,590 Z = 4,645' TVDss L-202 L1 OBb Target Start: 754' FSL, 569' FEL, Sec. 27, T12N, R11 E X = 586,300 Y = 5,981,790 Z = 4,450' TVDss L-202 L1 OBb Target End: 4,864' FSL, 1,663' FEL, Sec. 35, T12N, R11 E X = 590,500 Y = 5,980,670 Z = 4,525' TVDss ~~ ~~ - ~ ~ ~ ~ ., L-202 L2 OBa Target Start: 815' FSL, 698' FEL, Sec. 27, T12N, R11 E X = 586,170 Y = 5,981,850 Z = 4,415' TVDss L-202 L2 OBa Target End: 4,848' FSL, 1,613' FEL, Sec. 35, T12N, R11 E X = 590,550 Y = 5,980,655 Z = 4,487' TVDss ,. _ L-202 L3 OA Target Start: 650' FSL, 190' FEL, Sec. 27, T12N, R11 E X = 586,680 Y = 5,981,690 Z = 4,340' TVDss L-202 L3 OA Target End: 12' FSL, 3,208' FEL, Sec. 26, T12N, R11 E X = 588,950 Y = 5,981,080 Z = 4,360' TVDss AFE Number: ORD5M3556 Ri : Nabors 9es GL: 48.8' KB: 28.5' KBE: 77.3' Estimated Start Date: November 8, 2004 OBd MD: 12,634' OBb MD: 12,304' OBa MD: 12,349' OA MD 10,674' TVD: 4,722' TVD: 4,602' TVD: 4,564' TVD: 4,437' Current Well Information Distance to Nearest Property: Distance to Nearest Well in Pool: L-202 Original Well API #: L-202 L1 API OBb #: L-202 L2 API OBa #: L-202 L3 API OA #: Well Type: Current Status: Conductor: H2S: BHT: BHP: O eratin da s to com lete: 44.6 Max Inc: 91.5° Max Inc: 91.8° Max Inc: 92.3° Max Inc: 91.0° KOP: 700' KOP: 7,138' KOP: 7,005' KOP: 6,808' 4,660' to PBU Unit Boundary at Top OA 580' to L-118 at Top Nb 50-029-XXXXX-00 50-029-XXXXX-60 50-029-XXXXX-61 50-029-XXXXX-62 Schrader O-sand Quadlateral Producer New well, conductor is set 20" X 34", 215.5 ppf, A53, ERW set at 109' KB 0 ppm from produced fluids (approximated to be around 10 ppm due to contaminated gas lift gas) 84 °F C~1 4,400' TVDss (Estimated) 8.6 - 8.7 ppg in Schrader O-Sands Permit to Drill 09/23/04 Formation Markers Z-21~ PB1(gased nn Schl~~mhornor wn(1Zl Formation To s MD TVD TVDss Pore si EMW H drocarbons G 1 337' 337' 260' 120 8.8 No SV6 968' 967' 890' 409 8.8 No Fault #1 1,284' 1,277' 1,200' SV5 1,578' 1,552' 1,475' 679 8.8 No SV4 1,718' 1,677' 1,600' 736 8.8 Poss. Gas Hydrates Base Permafrost 1,805' 1,752' 1,675' 771 8.8 No SV3 2,156' 2,032' 1,955' 899 8.8 Poss. Gas Hydrates SV2 2,400' 2,202' 2,125' 978 8.8 Poss. Gas Hydrates SV1 2,999' 2,527' 2,450' 1,127 8.8 Poss. Gas Hydrates UG4 3,594' 2,822' 2,745' 1,263. 8.8 Thin coal UG4A 3,650' 2,850' 2,773' 1,276 8.8 Heavy oil between 2770' and 2940' ss UG3 4,381' 3,212' 3,135' 1,442 8.8 Thin coals/poss. Heavy oil Fault #2 5,171' 3,597' 3,520' UG1 5,388' 3,702' 3,625' 1,668 8.8 Heavy oil between 3770' and 3910' ss Schrader Bluff/Ma Sand 5,965' 3,987' 3,910' 1,799 8.8 Heavy Oil between 3910' and 3950' ss Mb1 6,044' 4,027' 3,950' 1,817 8.8 Heavy Oil between 3950' and 4010' ss Mb2 6,164' 4,087' 4,010' 1,807 8.7 Heavy Oil between 4010' and 4095' ss Mc 6,336' 4,172' 4,095' 1,842 8.7 Heavy Oil between 4095' and 4140' ss Na 6,429' 4,217' 4,140' 1,878 8.7 No Nb 6,482' 4,242' 4,165' 1,888 8.7 Yes Nc 6,579' 4,287' 4,210' 1,905 8.7 Yss OA 6,783' 4,377' 4,300' 1,938 8.7 Yes OBa 6,967' 4,447' 4,370'- 1,968 8.7 Yes OBb 7,119' 4,502' 4,425' 1,985 8.6 Yes OBc 7,313' 4,567' 4,490' 2,010 8.6 Yes OBd 7,659' 4,627' 4,550' 2,040 8.6 Yes OBe N/A N/A N/A N/A N/A Not Penetrated Mud Program: 13-1/2" Surface Hole Mud Pro erties: Spud -Freshwater Mud Interval Densit Funnel vis YP PH FL Initial 8.5 - 9.2 250-300 50-70 8.5-9.0 NC-8.0 Base Perm + 9.5 200-250 30-45 8.5-9.0 8.0 Interval TD max 200-250 30-40 8.5-9.0 5.0-7.0 ~.--. 9-7/8" Intermediate Hole Mud Pro rties: Freshwater Mud (LSND) Interval Densit YP PV API Filtrate MBT H Chlorides Surface shoe to interval TD 9.0 - 9.3 26-30 12-18 4-6 < 20 9.0-9.5 <600 6-3/4" Production Hole Mud Pro erties: LVT-200 MOBM (Versa-Pro Interval Densi Stabili Oil:Water Ratio YP PV API Filtrate MBT All four Laterals 9.0 - 9.2 650-900 80:20 15-19 <20 4-5.5 < 6 Survev and Loaaina Proaram: 13-1/2" Hole Section: Surface G ro will be needed (run to 1200' MD or as conditions dictate O en Hole: MWD / GR Cased hole: None 9-7/8" Intermediate Hole: Surve will need to be IFR + MS corrected real time O en hole: MWD / GR / Res /Den / Neu /PWD All realtime with recorded orosi Cased Hole: None 6-3/4" Productton Holes: Surve will need to be IFR + MS corrected real time O en hole: MW D l GR !Res /Den !Neu /PWD /AIM All realtime with recorded orosi Cased Hole: N/A Permit to Drill 09/23!04 ~ • Cacina/Tuhinn Prnaram Hole Size Csg / Tb O.D. WUFt Grade Conn Burst si Collapse si Length Top MD /TVDrkb Bottom MD /TVDrkb 48" 20" X 34" 215.5# A53 Weld 80' 29'/29' 109'/109' 13-'h" 10-3/a" 45.5# L-80 BTC 5,210 2,480 3,171' 29'/29' 3,200'/2,627' 9-'/e" 7-s/a" 29.7# L-80 BTC-M 6,890 4,790 7,771' 29'!29' 7,800'/4,635' 6-3/a" OBd 4-'h" slotted 12.6# L-80 IBT N/A N/A 4,834' 7,800'/4,635' 12,634'/4,722' 6-3/a" OBb 4-'/2" slotted 12.6# L-80 IBT NIA NIA 5,178' 7,126'14,505' 12,304'/4,602' 6-3/a" OBa 4-'/2" slotted 12.6# L-80 IBT N/A N/A 5,356' 6,993'/4,456' 12,349'/4,564' 6-3/a" OA 4-~/2" slotted 12.6# L-80 IBT N/A N/A 3,878' 6,796'/4,382' 10,674'/4,437' Tubin 4-~/a" 12.6# L-80 IBT-M 8,430 7,500 6,735' 29'/29' 6,764'/4,360' Surface and Anti-Collision Issues Surface Shut-in Wells: L-200 will require surface shut-in and wellhouse removal in order to move over well L-202. No other wells should require wellhouse removal and surface shut-in. Close Approach Shut-in Wells: There are NO wells requiring subsurface isolation for this profile. Clesp d-nnreach WPII List: Well Name Ctr-Ctr Distance Reference MD Allowable Deviation Precautiona Comment L-200 15.8' 300' 10.7' Use Travelin C tinder G ro L-216 60.3' 249' 56.2' Use Travelin C tinder G ro L-118 61.9' 1,402' 37.5' Use Travelin C tinder G ro L-103 76.7' 499' 68.9' Use Travelin C tinder G ro L-101 95.2' 1,706' 65.3' Use Travelin C tinder G ro Cement Calculations Casing Size: 10-3/a -in 45.5-Ibfft L-80 BTC surface casing -single stage Basis: Lead: 250% excess over gauge hole in permafrost, 30% excess over gauge hole below permafrost Lead TOC: Surface Tail: 1,000' of open hole with 30% excess, plus 80' shoe track Tail TOC: 2,200' MD 1,000' MD above shoe Total Cement Volume: Spacer 80 bbls of Viscosified Spacer wei hted to 10.60 p (Mud Push .ead 442 bbls, 2484 cuff, 580 sks 10.7 Ib/ al ASL G + adds - 4.28 cuff/: rail 92 bbls, 517 cult, 442 sks 15.8 Ib! al Class G + adds -1.17 cuftlsk emp BHST ~55° F, BHCT ~60° F estimated by Schlumberger In the event that cement is not circulated to surface during the initial surface casing cement job, notify the AOGCC of the upcoming remedial cement work for possible witness of cement to surface. Open TAM Port Cotlar and perform second cement job. Casin Size: 7-5/8", 29.7-Ib/ft L-80 BTC-M intermediate casin Basis: Lead: None Lead TOC: N/A Tail: 2,335' of open hole with 30% excess, plus 80' shoe track Tail TOC: 5,465' MD 500' MD above tanned Mato at 5,965' MD Total Cement Volume: Wash 20 bbls CW100 S acer 35 bbls of Viscosified S acer Mud ush II Desi n Wei hted to 10.3 Tail 120 bbls, 674 cuff, 562 sks 15.8 Ib/ al G + Gasblok -1.20 cuft/sk Temp BHST - 90° F from Temp Loq, BHCT 80° F estimated by Schlumberger 3 Permit to Drill 09/23!04 • • Centralizer Recommendations 10-3/4" Casing Centralizer Placement a) Run (25) 9-s/8" Bow-spring centralizers attached over the collar of each joint of casing from the casing shoe up to 2,200' MD (1,000' MD above the shoe). b) This centralizer program is subject to change pending actual hole conditions. 7-S/e" Casing Space Out a) Space 7-S/a" casing out with pups and long/short joints as required to place the top of a long full joint ~ 5-15' above the top of the OBb, OBa and OA sands to allow for the window to be milled just below the top of each sand and in the middle of a full joint of casing. These KOP's may be altered to enhance reservoir contact depending on the angle of intersection of each zone. b) Place 1 RA tag above each window exit. RA tags to be spaced out -40 - 80' above window depth except on the OBd lateral. It will need to be placed 120' above the casing shoe. c) Emergency 7-s/8" casing slips can be used instead of the 7-5/8" mandrel hanger if required for space out. 7-s/e" String Centralizer Placement a) Centralizer size: 7-5/e" X 9-%8" (this is different then the norm of ~/a" under gauge hole) b) Do not run centralizers on the window joints spaced at the top of each sand. c) Place 2 rigid straight blade centralizers back to back at the very bottom of the shoe joint. Do not run any centralizers on the next two full joints. d) With the exception stated above, alternate 1 rigid straight vane cenralizer floating across a full joint and 2 rigid straight vane centralizers, one floating on the upper half of the joint and one floating on the lower half of the joint separated by a stop collar up to 6,482' MD (Top Nb). Then continue with 1 rigid straight vane centralizer per joint floating to 5,465' MD (500' MD above Ma sand). Zonal isolation with cement is required between the OA and the Nb sands. The centralizer program is subject to change pending modeling and hole conditions. 4 ~/z" Solid Liner Centralizer Placement a) Run one straight blade rigid centralizer per joint, floating between the collars. If any differential sticking is noticed while drilling, it may be necessary to put another centralizer per joint separated by a stop collar. Do not put any centralization on the first two joints above the bent joint. Well Control Well control equipment consisting of 5,000 psi working pressure pipe rams (2), blind/shear rams, and annular preventer will be installed and are capable of handling the maximum potential surface pressures. Based upon calculations below, BOP equipment will be tested to 3,500 psi. Due to test pressures not exceeding S,000psi it will not be necessary to have two sets of pipe rams installed at all times. BOP regular test frequency for.Z-2#fti will be 14 days. Diverter, ROPE and drilling fluid system schematics on file with the AOGCC. Intermediate Section • Maximum anticipated BHP: • Maximum surface pressure: • Planned BOP test pressure: • 10-3/4" Casing Test: • Integrity Test - 9-7/8" hole: • Kick Tolerance: 2,035 psi - Schrader OBd (8.6 ppg C~ 4,550' TVDss) 1,580 psi -Based on a full column of gas ~ 0.10 psi/ft 3,500 psi/250 psi Rams 2,500 psi/250 psi Annular 3,500 psi ~~ LOT 20' from -10-3/4" shoe 50 bbls with an 11.2 ppg EMW LOT 4 - Permit to Drill 09/23/04 Production Section • Maximum anticipated BHP: • Maximum surface pressure; • Planned BOP test pressure: • 7-518" Casing Test: • Integrity Test - 6-3l4" hole: • Kick Tolerance: • Planned completion fluid: • 2,035 psi -Base of Schrader OBd (8.6 ppg ~ 4,550' TVDss) 1,580 psi -Based on a full column of gas C~ 0.10 psi/ft 3,500 psi/250 psi Rams 2,500 psi/250 psi Annular 3,500 psi FIT 20' from 7-5/8" shoe Infinite with an 10.7 ppg EMW FIT Estimated 9.0 ppg Brine / 6.8 ppg Diesel Disposal • No annular injection in this well. • Cuttings Handling: Cuttings generated from drilling operations will be hauled to grind and inject at DS- 04. Any metal cuttings will be sent to the North Slope Borough. • Fluid Handling: Haul all drilling and completion fluids and other Class II wastes to DS-04 for injection. Haul all Class I waste to Pad 3 for disposal. Materials Needed Surtace.Casn Amount Descri tion 3,200' _ 10-3/a", 45.5#, L-80, BTC Casing 1 each 10-3/a", BTC Float Shoe and Float Collar 25 each 10-3/a" x 13-~h" Bow Spring Centralizers 1 assembly FMC 11" 5m Gen 5 Wellhead System 1 lot 10-3/" casing pups 5', 10', 20'. 1 each 10-3/a" TAM Port Collar Intermediate Casin Amount Descri tion 7,800' 7-5/8" 29.7# L-80 BTC-M Casing 1 each 7-5/8" BTC-M Float Shoe and Float Collar 75 each 7-S/" x 9-%8" Rigid Straight Blade Centralizers 20 each 7-%8" Stop Rings 2 lots 7-Ste" casing pups 5', 10', 20' 4 each 7-S/" RA Tag Production Liner: Amount _ Description __ 4 x Production Liners: 19,300' 4'/z", 12.6#, L-80, IBT-Mod Slotted Liner 482 each 4 ~/z" x 5 3/a" x 8" Straight Blade Centralizers 4 each 7 S/e" x 4-'/z" Baker ZXP Liner Top Packer 4 each 4-'h" Halliburton Float Shoes 3 assemblies Baker Level 3 Hookwall Han ers with LEM Com letion: Amount Descri tion 6,800' 4-'/2", 12.6 Iblft, L-80, BTC-M tubing 1 each Baker PRM Production Packer 7-S/" X 4-~h" 1 each 11" X 4-%z" FMC tubing hanger 1 each 4-'/,s", 5m Cameron Tree 2 each Halliburton X-Nipple (3.813" ID) 1 each 4-'h" Baker CMD Sliding Sleeve 4 each Camco 4-'h" X 1" KBG-2 Gas Lift Mandrels 2 each Phoenix pressure gauge 6,800' I-wire for the Phoenix gauge 3 each Half-muleshoed joint of 4-~h" IBT-M tubing 1 each 4-'/2" WLEG 5 Permit to Drill 09/23/04 • • Drilling Hazards and Contingencies POST THIS NOTICE IN THE DOGHOUSE I. We{I Control A. The Schrader in the Polygon 1A fault block is expected to be normal pressured at 8.5-8.6 ppg EMW. This pressure is estimated based on offset well pressures and material balance. Hydrates and Shallow gas A. Gas Hydrates are expected at L-pad near the base of the permafrost. Setting casing through the SV1 should keep hydrate exposure from extending past the surface hole. Recommended practices and precautions for drilling hydrates should be followed in the surface hole. Occasionally hydrates are encountered below the SV1. III. Lost Circulation/Breathing A. Lost circulation is not expected at the L-Pad fault. In addition the fault will be crossed at high angle and move away quickly. B. We do not expect breathing on this well. IV. Kick Tolerance/Integrity Testing A. The 10-3/4" casing will be cemented to surface. B. The 10-3/4" casing test pressure is 3500 psi. C. The Kick Tolerance for the surface casing is 50 bbls with 9.0 ppg mud, 11.2 ppg LOT, and an 8.8 ppg pore pressure. D. 9-7/8" Openhole Integrity Testing -LOT to a minimum of 11.2 ppg EMW 20' from the shoe. E. The 7-5/8" intermediate casing will be cemented with 15.8 Ib/gal tail cement to 500' MD above the Ma sand ~ 5,465' MD. F. The 7-5/8" casing test pressure is 3500 psi. G. The Kick Tolerance for the intermediate casing is infinite with 9.0 ppg mud, 10.5 ppg FIT, and an 8.8 ppg pore pressure. H. 6-3l4" Openhole Integrity Testing -FIT to a minimum of 10.5 ppg EMW 20' from the shoe. V. Stuck Pipe A. We do not expect stuck pipe if the hole is kept adequately clean. VI. Hydrogen Sulfide L Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at L pad as a result of the use of Ivishak gas lift gas. All L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: Adjacent producers at Surface: Adjacent producers at TD: L-02 10 ppm L-101 5 ppm L-116 10 ppm VII. Faults A. Two faults are expected to be crossed at L-202. No losses are expected to be associated with this fault. Details are listed below for reference: Fault Location MD TVD TVDss Throw Direction Uncertainty Fault #1 - SV6 1,285' 1,277' 1,200' 50' to 70' West +/- 150' MD Fault #2 - UG3 5,171' 3,597' 3,520' 40' to 50' South +/- 150' MD CONSULT THE L PAD DATA SHEET AND THE WELL PLAN FOR ADDITIONAL INFORMATION 6 Permit to Dri1109/23/04 L-202. L-202 L1. L-202 L2 & L-202 L3 DRILL AND COMPLETE PROCEDURE SUMMARY Pre-Riq Work• 1. A 34" x 20" insulated conductor has already been set and surveyed. Weld an FMC landing ring for the FMC Gen 5 Wellhead on the conductor. 2. If necessary, level the pad and prepare location for rig move. Prepare neighboring wells for the rig move and production simops. Drilling Riq Operations: 1. MIRU Nabors 9ES. Nipple up diverter spool and riser. Function test diverter. PU 4" DP and stand back in derrick. 2. MU 13-~/z" drilling assembly with MWD/GR and directionally drill surface hole to approximately 3,200' MD. The actual surface hole TD will be +/-100' TVD below the top of the SVi sand. 3. Run and cement the 10-3/a", 45.5#, L-80 surface casing back to surface. ND drilling spool and riser and NU casing /tubing head. NU ROPE and test to 3,500 psi. 4. MU 9'/8" directional drilling assembly with MWD/GR/Res/Den/Neu/PWD and a Weatherford Drill-Mill at t1,000'and 12,000' from the bit. RIH to float collar. Test the 10-3/a" casing to 3,500 psi for 30 minutes. 5. Drill out shoe track. Circulate and condition mud. Displace well to new LSND drilling fluid. Dri1120' of new formation below rathole and perform a LOT. Directionally drill ahead to TD (Near top OBd) as per directional profile to 7,800' MD. 6. Make short trip as needed, work tight spots as seen. Circulate and condition mud at TD. Make sure hole is clean prior to POOH. POOH for casing. 7. MU and run 7-5/8" 29.7# L-80 BTC-M long string casing to TD. Cement in one stage to 500' MD above the Schrader Ma sand. Bump plug with seawater. 8. Clean pits for displacement. Freeze protect 7-S/8" x 10-3/a" annulus with dead crude to 2,200' TVD. 9. PU 6-31a" conventional assembly with MWDJGR/ResJDen /Neu/PWD/AIM and RIH to the float collar. Test the 7-5/8" casing to 3,500 psi for 30 minutes. 10. Displace well over to new Versapro MOBM. Drill out shoe track, circulate and condition mud. Dri1120' of new formation below rathole and perform FIT. Directionally drill ahead to TD geosteering through the OBd to TD at 12,634' MD. (prognosed). Perform wiper trip, circulate and condition mud. 11. POOH to near OBb window depth, log into top OBb (RA marker) with GR, log across the OBa and OA windows as well. POOH. 12. MU and run 4-~/2" 12.6# L-80 BTC-M slotted liner with two swell packers, liner hanger and liner top packer to TD. Position liner top packer 100' below the bottom of the OBb window. i3. PU the 7 5/e" whipstock assembly. Set the whipsock on the OBd liner top packer such that the top of the window is near the top of the OBb sand (planned KOP: 7,113' MD). Orient whipstock to highside. Shear off Whipstock & mill window. POOH. 14. RIH with 6-3/a" conventional drilling assembly with MWD/GR/Res/Den/Neu/PWD/AIM to whipstock. Directionally drill to the planned TD of 12,304' MD. Circulate and condition mud and perform wiper trip. POOH. 15. Pull whipstock #1. Run and set 4-~/z" slotted liner with two swell packers and hook hanger. POOH and LD liner running string. Run Baker Hook Hanger Lateral Entry Module #1 with ZXP liner top packer, POOH. 16. PU the 7-S/8" whipstock assembly. Set the whipsock on the OBb liner top packer such that the top of the window is near the top of the OBa sand (planned KOP: 6,980' MD). Orient whipstock to highside. Shear off Whipstock & mill window. POOH. 17. RIH with 6-3/a" conventional drilling assembly with MWD/GR/ReslDen/Neu/PWD/AIM to whipstock. Directionally drill to the planned TD of 12,349' MD. Circulate and condition mud and perform wiper trip. POOH. 18. Pull whipstock #2. Run and set 4-'h" slotted liner with two swell packers and hook hanger, POOH and LD liner running string. Run Baker Hook Hanger Lateral Entry Module #2 with ZXP liner top packer, POOH. 19. PU the 7 s/8" whipstock assembly. Set the whipsock on the OBa liner top packer such that the top of the window is near the top of the OA sand (planned KOP: 6,783' MD). Orient whipstock to highside. Shear off of Whipstock and mill window. POOH. 7 Permit to Drill 09/23/04 20. RIH with 6-3/a" conventional drilling assembly with MWD/GR/Res/Den/Neu/PWD/AIM to whipstock. Directionally drill to the planned TD of 10,674' MD. Circulate and condition mud and perform wiper trip. POOH. 21. Pull whipstock #3. Run 4-'/z" slotted liner with two swell packers and hook hanger, POOH and LD liner running string. Run Baker Hook Hanger Lateral Entry Module #3 with ZXP liner top packer. Clean pits for displacement. Displace over to 9.0 ppg KCL brine. POOH. 22. MU 4-~/z" 12.6# BTM-M, L-80 completion assembly and RIH. See completion schematic for details. Land tubing hanger and run in lockdown screws. Reverse in brine with Corexit to protect the annulus. 23. Drop RHC ball and rod and set packer as per Baker recommendation and test tubing to 3,500 psi and annulus to 3,500 psi. Shear DCK-1 valve. 24. Install two-way check and test to 1,000 psi. Nipple down the BOPE. Nipple up and test the tree to 5,000 psi. 25. Pull two-way check. Freeze protect the well to 2,200' TVD. Install VR plug in 7-5/e" casing annulus valves. 26. Install BPV. Secure the well and rig down /move off Nabors-9ES. Post-Rig Work: 1. MIRU stickline. Pull the ball and rod /RHC plug. 2. Pull out DCK-1 shear valve, install GLV in all of the other mandrels as per the PE. 8 Permit to Drill 09/23/04 ~ • L-202 Detailed Drilling Procedure Job 1: MIRU Critical Issues: - Ensure the starting head has been welded on the conductor at the right height and there is adequate space to NU the diverter and subsequently the BOP once the rig is spotted (LL on W-2121). Confirm this requirement prior to the rig moving over the well. Verify that the Diverter does not require any additional spacer spools as well. - Ensure the AOGCC receives 24-hour advance notification of the diverter test and subsequent BOP tests. - L-200 will have to be shut in and require wellhouse removal before rig can be moved over the well. All surface flowlines and gas lift lines will need to be depressurized to header pressure. Discuss the move at a pre-job safety meeting and designate a spotter to ensure there is no danger of a collision. - L Pad is not designated as an H2S site, however Standard Operating Procedures for H2S precautions should be followed at all times. No measurable H2S is being produced from the formation at this time. However 10 ppm is measured regularly at L pad as a result of the use of lvishak gas lift gas. All L pad gas lift wells will likely have H2S in this concentration. Note that all injection has been with produced water not seawater. H2S levels are expected to remain low until the waterflood matures. Recent H2S data from the pad is as follows: Adjacent producers at Surface: Adjacent producers at TD: L-02 10 ppm L-101 5 ppm L-116 10 ppm Reference SOP: • "Drilling/ Work over Close Proximity Surface and Subsurface Wells Procedure" Job 2: Drill 13-~h" Surface Hole Critical Issues: - Well Design: The Slimhole well design was adopted due to the production GLM / downhole pressure gauge requirements. This well design also gives us greater flexibility on junction design and reduces ECD's. - Surface Hole Problems: At L-Pad, no significant surface hole drilling problems have been identified. Tight hole, bridging, and obstructions have been encountered while drilling the Permafrost. In only one case has an obstruction caused the well to be sidetracked. Lost circulation has not been a problem on L-pad. Some minor tight hole has also been encountered below the Permafrost. Hydrates are present at L-pad from the base of the Permafrost all the way through the SV-1 sand and should be treated with conventional practices: pretreating mud, cooling mud, increasing weight, etc. - Close Approach: No wells are required to be shut in. There are several close tolerance wells in the surface interval between 300' - 1,700' MD. Follow the traveling cylinder / no-go plot per established procedures. Magnetic interference is expected to be nonexistent by 1,000' MD. - Directional: Every effort should be made to ensure a `smooth' well profile that will benefit torque / drag in the later hole sections. A graduated build profile is planned. Objective is to keep DLS <_1.5° over planned. - Hole Cleaning: Surface rotary speeds should be maximized wherever possible. The BHA is limited to 60 to 80-rpm while drilling because of the 1.5° motor bend. Vary flowrates 400-650 GPM to achieve the required directional response. However it will be possible at TD to raise the rotary speed to +100- rpm prior to POOH #o run casing. At this time flowrates should be increased to 650 - 700 GPM to increase hole cleaning. - Tight spots: During short trips, work out any tight spots as they are seen while pulling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. Consider backreaming across initial tight spots only if washing does not alleviate the problem. 9 Permit to Drill 09/23/04 - Faults: There is one fault that will be crossed in the surface hole section: Fault Location MD TVD TVDss Throw Direction Uncertainty Fault #1 - SV6 1,285' 1,277' 1,200' 50' to 70' West +/- 150' MD - Critical LWD Tools: It is critical for the landing of this hole section to have the GR to pick the top of the SV1 sand. If this tool tails, it will require an immediate trip out of the hole to replace. It is imperative that the surface casing isolates the upper section of the SV1 sands. In order to do this the casing will need to be set -100' TVD below the top of the SV1 sand in the shale. Reference RPs: • "Prudhoe Bay Directional Guidelines" • "Well Control Operations Station Bill" • Follow Schlumberger logging practices and recommendations Job 3: Run 10-3/4" Surface Casing Critical Issues: - Casing to bottom: It is imperative the casing is set in the shale below the SV1 sands to ensure wellbore integrity for the intermediate interval. It may be desirable to stop and roll the mud over half way in the hole to break the gels and reduce surging intensity on the SV sands. This will also help to ensure circulation is attained at TD at the desired cementing rates without losses. Make sure that the hole is clean and obstructions are minimized before running casing as higher doglegs and aggressive directional work could make casing running more difficult. - Casing drift: 10-3/a" special drift casing is being used. Ensure that casing equipment is properly drifted to ensure adequate ID for the 9-'/a" bit, i.e. float equipment, casing hanger, etc. - Cement to surface: A single-stage job will be done on this well using 250% excess in the permafrost and 30% excess below the permafrost. A TAM Port collar will be placed at 1,000-ft MD as a contingency. - Losses during cement job: Lost circulation has been experienced on L-Pad and on offset pads while running and cementing surface casing on past wells. The expected frac gradient for the shale below the SV1 sands is 12.5-Ib/gal EMW. Follow the Schlumberger recommended pumping rates as they have modeled the expected ECD's during the entire cement job to help mitigate the potential for breaking down the formations. Reference RPs; • "Casing and Liner Running Procedure" • "Surface Casing and Cementing Guidelines" • "Surface Casing Port Collar Procedure" Job 4: Drill 9'/S" Intermediate Hole Critical Issues; - Differential Sticking could be a problem if lost circulation is occurring or if the drill string is left stationary for an extended period or time across the permeable Schrader Sands. - LOT: Perform a LOT (minimum 11.2 ppg EMW to satisfy kick tolerance). The Kick Tolerance for the surface casing is 50 bbls with 9.0 ppg mud, 11.2 ppg LOT, and an 8.8 ppg pore pressure (most likely 8.6 ppg based on recent MDT's within the block). If the LOT is less then 11.2 ppg EMW, then the kick tolerance will be < 50 bbls. Based upon off-set drilling data on L-Pad, a minimum leak-off of 12.5 ppg is expected at the 10-3/a" shoe. ECD's at the shoe are expected to be in the 10 ppg range while drilling at the shoe and at TD of the well. - Penetration Rate: Penetration rates should not exceed 600 fph instantaneous. This should allow for ECDs not to exceed 0.6ppg above calculated. If ECDs are sustained above this threshold, it is advised that drilling should be stopped and the hole circulated before continuing. ECD should not exceed 11.0 ppg once the M sand has been penetrated. 10 ~ Permit to Drill 09/23/04 - 7-s/e" casing landing point: The landing point for the 7 5/" casing will be determined by isopaching down to the top of the OBd sand based on changes in GRlRes curves associated with the tops of the previous OB sands. Top setting the OBd will give us the most possible amount of TVD to work with when landing the 6-3/a" horizontal. if tops are coming in 100' or more out from prognosis, then conduct a short trip and notify town. A Rigsite Geologist will be required on site to pick casing point. - Torque: Use lubricants as per the MI program as necessary. If weight transfer problems are encountered during sliding, attempt to circulate and rotate for a minimum of 2 bottoms up to test if lubricants are truly needed or if the hole is loading up with cuttings. - Critical LWD Tools: It is critical to have the GR tool in order to pick the landing point for this hole section. The landing of this well will depend on picking the top of the OBd sand which will be picked by Gamma Ray. If we loose the GR tool, we will need to trip for it. - Faults: There is one fault that will be crossed in this hole section: Fault Location MD TVD TVDss Throw Direction Uncertainty Fault #2 - UG3 5,171' 3,597' 3,520' 40' to 50' South +/- 150' MD - Bowl Protector: With the larger than normal production hole size (9-7/8"), the bowl protector will be very thin. Pull and inspect the bowl protector whenever possible. Replace with any sign of damage. Take caution not to get bawl protector stuck. - Directional Constraints: It is critical to not let the angle get any higher then planned, due to slickline access requirements and junction requirements. It is critical to design a BHA to minimize inclination and walking tendencies and thus minimize wellbore tortuousity. DLS should be kept <_1° over planned. - Tight spots: During short trips, work out any tight spots as they are seen while puling out of the hole instead of waiting and reaming them out after running back in the hole as this could lead to accidental sidetracking. If a tight spot is encountered, run back in the length of the BHA and circulate for at least 30 minutes at max rotation speed and max flowrate while reciprocating at max allowable speed without exceeding the ECD limit. Reference RPs: • "Standard Operating Procedure for Leak-off and Formation Integrity Tests" • "Prudhoe Bay Directional Guidelines" • "Lubricants for Torque and Drag Management" • "ERD Operating Practices" Job 6: Run and Cement 7-s/s" Intermediate Casing Critical Issues: - Cement Job: It is imperative to achieve a good cement job on this well for Nb sand and junction isolation requirements. Good zonal isolation of these sands is imperative to the production success of this well. Therefore reciprocate pipe as long as possible while cementing. A USIT log will be run to confirm the quality of the cement job between the sands if any problems are encountered during the cement job. Keep cementing ECD's below 12.5 ppg EMW during the displacement. - Casing Space out: There are 3 important space out zones for this casing run: o There must be a long full joint of casing just starting above the top of the OA and OBa sands so that the multi-lateral junction window can be milled out as close to the top of the respective sands in the top/middle of a full joint of casing. Run full casing joints across the OA and OBa sands. Any casing pup joints required for space out should be placed below the base of the sands. o The shoe must be within 10 feet of the bottom when the casing is cemented in place. o The mandrel hanger must be spaced out correctly at surface if it is to be used. Emergency slips may be used if necessary to achieve proper space out. 11 Permit to Drill 09/23/04 • • - Freeze Protection: Ensure the lower production cement has reached at least a 70BC thickening value prior to freeze protecting. After freeze protecting the 7-5/" x 10-3/a" casing outer annulus with dead crude to 2,200'TVD, the hydrostatic pressure will be 7.8 ppg vs 8.5 ppg EMW of the formation pressure immediately below the shoe. Ensure adouble-barrier at the surface on the annulus exists until the cement has set up for at least 12 hours. Trapped annulus pressure may be present after pumping the dead crude as the hydrostatic pressure of the mud and crude could be 100 psi underbatance to the open hole. - Centralization/Differential Sticking: See centralizer strategy above. Differential Sticking could be a problem if lost circulation is occurring or if the casing is left stationary for an extended period or time across the permeable sands. Ensure the casing is centralized across any permeable zones if the casing is left stationary while running in the hole. - RA Tags: There will need to be 4 RA tags placed in the 7-S/8" casing for depth control. Placement strategy is ~40 - 80' above each of the windows: Pip #1: OA window, Pip #2: OBa window, Pip #3: OBb window, Pip #4: 120' above the shoe. - Mud Requirements: Thin the mud as per MI's Mud Program. The thinner the mud the better displacement is achieved and the better the cement job will be. Extra time spent circulating is warranted to ensure optimum mud properties and hole cleaning prior to the cement job. - Franks Casing Fill-up tool: Make sure that a casing fill up tool is on location prior to PU 7-s/8' casing. - TIW Valve: Ensure that a TIW valve with a cross over to 7 s/$" BTC casing is on the rig floor Reference RPs: • "Intermediate Casing and Cementing Guidelines" • "Freeze Protecting an Outer Annulus" • "ERD Operating Practices RP" Job #7 /Job #10 /Job #15 /Job #20: Drill 6-3/a" Laterals (OBd / OBb / OBa / OA Sands) Critical Issues: - MOBM: The production intervals will be drilled with a 9.2 ppg VersaPro MOBM. This fluid has been utilized before on past wells, however it has inherent HSE issues associated with its handling and thus all safety procedures should be refreshed. Review the BP MOC, the Nabors Hazard Analysis, and the MI drilling fluids program prior to utilizing this fluid. - Faults: There are no planned fault crossings in any of the laterals intervals. - Geosteering: Geosteering in these lateral intervals is expected to be the most challenging aspect of this well. Anadrill AIM will be used and should help mitigate some of this challenge. A 1.5° bent housing motor will be used to help proactively make corrections quicker to avoid unnecessary undulations throughout this interval. There will be a rigsite geologist on location to help with interpretations. o The structure of the horizontal section is expected to be relatively flat for the first -2,000' and then is expected to drop between 1.5 - 2.5° apparent dip depending on how the actual structure tracks the prognosis. o The well L-202 OBd lateral is designed to undulate in 2 1/2 cycles across the 30 foot vertical extent of the OBd net sand/pay section along the length of the L-202 polygon. The undulating well profile will provide low angle offtake points from all sands in the OBd net sand/pay interval and crosscut potential vertical permeability barriers. o The L-202 OBb lateral will target to stay near the center to lower half of the 13-14 foot vertical extent of the OBb net sand/pay section along the length of the L-202 polygon. However, given the thin character of the OBb target interval, it is likely the drillstring will undulate across the entire OBb net sand thickness several times along the length of the drilling polygon. Dip information gained from drilling the underlying OBd lateral leg should help minimize unplanned excursions out of the OBb target interval. 12 Permit to Drill 09/23/04 • • o The L-202 OBa lateral will be targeted to drill the first 1/3 of the total polygon length in the lower sand and second 2/3's of the polygon in the upper sand. By limiting the drilled length in the lower sand to only the upstructure polygon area, it is possible that a lighter updip fraction of the lower OBa oil column may be contacted. Well L-202L2 will then ramp up into the upper OBa sand and finish drilling the lateral in the thicker sand and lighter oil of the upper OBa interval. o The OA lateral is designed to undulate in 1 1/2 cycles across the OA net sand interval along the length of the up-structure L-202 OA polygon. The L-202 OA lateral was shortened relative to the underlying laterals to maintain standoff from wet OA sands in the interval between the L-216 and L- 210PB1 wells. o The directional plans for each lateral should reflect the learnings derived from the previous laterals but should only be used as a guide and real time adjustments will need to be made to stay within the sands. If for whatever reason we become lost, steer up as hard as possible to determine where within section we are. Once we are able to determine where we are, then we can go back and OH sidetrack. - Surveying: Survey density is critical to achieve vertical positional certainty. It is recommended to survey every 30-45' to ensure accurate vertical positional certainty throughout the horizontal section. This survey density should alleviate the errors associated with vertical section creep. - ECDMoIe Cleaning: Utilize PWD to monitor for good hole cleaning and ECD trends. Cuttings wilt tend to dune up at the window due to hole geometry. Planned ECD hardline 12.0 ppg EMW. - Target Constraints: The North sidelines of the polygon are defined as hard lines due to standoff to injection. The South sidelines of the polygon are defined as hard lines due to fault proximities. Do not extend beyond the endline points due to potential downdip water. Reference RPs: • "Prudhoe Bay Directional Guidelines" • "Standard Operating Procedure: Leak-off and Formation Integrity Tests" • "ERD Operating Practices RP" Job 8: Run 4-~h" Slotted Liner (OBd Sand) Critical Issues: - Liner to bottom: It is imperative that we get this liner to bottom to allow for adequate space-out for subsequent laterals. Liner on bottom will also prevent the sand from collapsing, keeping the entire drilled section in tact, thus capturing aH of the reserves possible for this section length. - Centralizer Placement (5-3/" OD): o See centralizer strategy above Do not run any in the liner lap. - 4-~/~" Rams: Keep VBR's in. Can also utilize annular if necessary. - Have a Baker completion specialists onsite to engineer and supervise this liner job. Reference RPs: • "None Apply" 13 Permit to Drill 09/23/04 • • Job #9 /Job #14 /Job #19: Mill OBb / OBa / OA Windows Critical Issues: - Equipment Measurements: Verify measurements of all assemblies prior to picking up - Whipstock Orientation /Depth: The whipstock should be oriented to t15° left of high side. This will allow for a better window and allow for easier access into the window with the bent joint on the end of the 4-'/2" liner. Exact window depth to be based off of actual logs. Depth control will be very critical on these windows. Space out tubulars below the whipstock may be required to properly position the whipstock at the correct depth while landing out on the ZXP liner top packer used on the previous lateral. A discussion will need to take place to determine the best way to gain accurate depth control for the window setting depth. o Planned OBb window depth is 7,113' MD {4,500' TVD). o Planned OBa window depth is 6,980' MD (4,452' TVD). o Planned OA window depth is 6,783' MD (4,377' TVD). - Window Milling: It is critical to have a smooth uniform full length window. Extra time spent on the window milling will be well worth it when it comes time to land out the hook hanger. Follow the BOT representative during the milling of the window. - Milling Assembly: In the past debris barrier cups have been sliced in order to allow flow bypass while POOH while retrieving whipstocks. From now on, the assembly will be run without slicing the cups and an unloader sub will be run below the debris barrier to facilitate flow by the swab cups and prevent swabbing. No seals below the whipstock unless fluid losses have been observed. - Whipstock Setting: On past wells, only one shear was observed during the whipstock setting procedure. This introduced some uncertainty as to whether or not the slide was oriented correctly. The most likely explanation for this is that on high angle wells cased hole friction may cause the 15-20K bottom trip and the 35K whipstock shear to occur simultaneously. - Hole Cleaning: Well inclination at the planned kick off points is between 65° - 70°. In addition, the wellbore tangent angle above the KOP's has a 61 ° tangent section prior to building up to 87°. Good window milling and hole cleaning practices will be critical to ensure that metal and formation cuttings are removed from the well. Cuttings will tend to dune up at the window due to hole geometry. - FIT: AN FIT is only required on the first lateral. Therefore the mills will only need to be drilled down far enough to ensure an adequate window and not to ensure 20' of open hole below the bottom of the window. Reference RPs: • "Whipstock Sidetracks" RP Job #11 /Job #16 /Job #21: Retrieve Whipstocks #1, #2, & #3 Critical Issues: - Orientation of Retrieval Hook: When scribing to align the MWD to the hook remember that the orientation of the hook will need to be 180° from the orientation of the whipstock. - Whipstock Retrieval: This whipstock must be retrieved in order to land the hook hanger in the window. Extra time should be taken in order to ensure successful retrieval of the whipstock with the hook due to potential problems associated with the back-up retrieval methods. Reference RPs: • None Apply 14 Permit to Drill 09/23/04 ~ • Job #12 /Job #17 /Job #22: Run 4-~/s" Liner w/ Hook Hanger & LEM w/ seals (OBb / OBa / OA) Critical Issues: - Liner to bottom: It is imperative that we get this liner to bottom to allow for proper placement of the Hook Hanger. Liner on bottom will also prevent the sand from collapsing, keeping the entire drilled section in tact, thus capturing ali of the reserves possible for this section length. Current modeling for the OBa liner, based on historical data, we should have plenty of SO weight required to land the junctions. Data collected on the OBd liner iob will be utilized to double check the calibration of the model prior to runnino the OBb liner to confirm additional weight pipe requirements. o If problems are encountered while RIH with the liner call ODE while reciprocating liner and discuss options: • Stop and reposition weight pipe and pick up more if available and try again. • Stop and POOH and make a cleanout run with a hole opener. • Stop and POOH to liner running tool and LD some footage of liner depending on modeling results based on actual drag data. - Liner Swivel: On past wells it was determined that the tension lock liner swivel between the Hook Hanger and the liner was not necessary because the torque needed to orient the Hook with the liner did not present any difficulties landing the junction. The decision has been made to continue with this strategy even on wells with as much as 7,300' of liner (L-201). The swivel requires adequate weight in order to lock it out and allow the liner and the hook io rotate together. Without enough weight acting on the swivel, the bent joint on the bottom of the liner will not be able to be manipulated from surface to facilitate access out into the window. - Centralizer Placement (5-3/a" OD): Run one straight blade rigid centralizer per joint, floating between the collars. If any differential sticking is noticed while drilling, it may be necessary to put another centralizer per joint separated by a stop collar. Do not put any centralization on the first two joints above the bent joint. - 4-~/z" Rams: Keep VBR's in. Can also utilize annular if necessary. - Have a Baker completion specialist onsite to engineer and supervise this liner job. 4 ~/z",12.6#, L-80 lBT ID drift Colla se Burst Tensile 100% 3.833 N/A N/A 288,000Ibs 80% N/A N/A 230,4001bs - Connection make-up information: 4-~/z" IBT - makeup to position Reference RPs: • "None Apply" Job #23 : Run 4-~/s" Completion: Critical Issues: - Barriers: o The well will have the OA, OBa, OBb, and OBd production intervals open with an 8.6 ppg EMW formation pressure during completion operations. o Completion will be run with BOPs in place and kill weight fluid for annulus side barriers. Tubing side barriers will be provided via TIW and kill weight fluid. o Once packer is set the annulus above the packer will be tested to 3,500 psi to verify packer/annulus integrity. Kill weight fluid and the tubing hanger provide additional annulus side barriers. At this point the ball and rod with kill weight fluid and a TIW valve comprise the tubing side barriers. o When the DCK valve is sheared a casing annulus valve must be in place along with kill weight fluid to provide sufficient annular barriers. Tubing side barriers are still kill weight fluid on ball and rod and a TIW. 15 Permit to Drill 09/23/04 o A TWC will be installed and tested from above to 1,000 psi for 30 minutes prior to nippling down the BOP's. With the DCK valve sheared the TWC in addition to kill weight fluid provide the tubing side barrier. The annular side is provided by a casing annulus valve and kill weight fluid. With the TWC in place BOPs can be nippled down and the tree nippled up. o With the tree nippled up freeze protecting removes the kill weight fluid as a barrier. We then count on the tree for tubing side barriers, and two casing annulus valves for annulus side protection. o Before rigging down a BPV tested from below to 1,000 psi will be left in the tubing hanger to provide an additional tubing side barrier once the rig is off. Since the DCK valve is still open it will be necessary to leave one casing annulus valve and a VR plug for annular barriers. Make sure that a lubricator is used to install the VR plug while both casing annulus valves are still in place. - Thread Dope: BOL 2000 NM or BOL 2000 is the BP approved thread compound for Carbon API connections. All IBT-M pipe should arrive on location with one of these two thread compounds. It would stilt be good practice to look over each connection in the pipe shed prior to incorporating them into the tally. - Shear Valve: We will run a DCK shear valve in the GLM directly above the production packer to utilize for freeze protecting after the production packer is set. - Phoenix Pressure Gauge: A downhole pressure gauge with control lines will be run on this well. Ensure that a Baker Centrilift hand and a Schlumberger completions hand (Camco) is on location prior to PU tubing to allow them time to get all of their equipment in order and confirm its working condition. o HSE: Sheaves hung in the derrick and I-wire spools will be utilized during the running of the completion, make sure that this non-routine operation is discussed in length at the PJSM with all relevant personnel prior to PU completion. o Place 1 cannon clamp per joint for the first 10 joints followed by 1 clamp per every 2 joints to surface. o Test the I-wire connection at regular intervals while running in the hole. If the I-wire is damaged in any way contact ODE. - Contact the Field AOGCC Rep with 24 hours of notice to witness the tubing and annulus pressure tests. Reference RPs: • "Completion Design and Running" RP • "Tubing Connections" RP Job #24: ND/NU/Release Rig Critical Issues: - See Job 1 for adjacent well spacing. Identify hazards in a pre-move meeting, and take every precaution to ensure good communication prior to beginning the rig move. Use spotters when moving the rig. - Diesel: Diesel will be used to freeze protect the well. The diesel flash point is 100° F. Diesel vapor pressure is - 0.1 psia at 100° F. Reference RPs: • "Freeze Protecting an Inner Annulus" RP 16 Permit to Dri1109/23104 L-202, L1, L2, & L3 PROPOSED COMPLETION ~ 20"X34" 215.5 Ib/ft, A53 ERW Insulated @ 109` ~ Halliburton X-Nipple (3.813" ID) @ 2200' TVD 4-1/2", 12.61b/ft, L-80, BTC-M Coupling OD: 5.2" Drift/ID : 3.833"/3.958" 10-3/4", 45.5# L-80 BTC Csg @ 3,200' MD TREE: FMC 4-1/16" 5M WELLHEAD: FMC Gen 5 System 11", 5M csg.head w/ 7" mandrel hanger & packoff 11" x 11", 5M, tbg spool w! 11" x 4-1/2" tubing hanger with control Tine ports 11" X 41/16" Adaptor Flange Orig KB elev (N-9ES) = 77.3' 4.5" Baker sliding sleeve with 3.813" ID @ GLM Design: 7-5/8" X 5-1/2" Baker PRM Packer @ #4 - 2500' TVD - 4-1/2" X 1" KBG-2 - SV alliburton X-Nipples (3.813" ID) #3 - 3500' ND - 4-1/2" X 1" KBG-2 - DV #2 - 4 jts above sliding sleeve - 4-1/2" X 1" KBG-2 - DV 4.5" WLEG @ 6,764' MD #1 - 2 jts above sliding sleeve - 4-1/2" X 1"KBG-2 - DV Phoenix Pressure `,~ ti ,. Gauge ~ . , . ~, with control '~' Versapro MOBM in each Lateral and in mother bore from tbg tail down. lines to surface ~,` ~ 6-3/4" OA Lateral 6,796'-10,674` RA Tag TBD ~ -=_ ~ - - - - - - - - - - _ _~ ~ - - - :•- ~ s ~ ~ ~ \ ~ ~ s ~ ~ ~__._.. '~ Swell packer placement TBD Junction St~cifications: / Junction ID through LEM Module without diverter: 3.68" RA Tag TBD LEM run with internal sealbores to allow the use of isolation sleeve across window. Baker Hughes Hookwall Hanger @ 6,779` MD Window in 7-5/8" casing @ 6,783' - 6,796' MD Well Inclination @ Window = 65° Baker Hughes Hookwall Hanger @ 6,976` MD Window in 7-5/8" casing @ 6,980' - 6,993' MD Well tndination @ Window = 69° Baker Hughes Hookwall Hanger @ 7,109` MD Window in 7-5/8" casing @ 7,113' - 7,126' MD Well Inclination @ Window = 69° 7-5/8", 29.7#, L-80, BTC-M @ 7800' Casing Drift: 6.75" Casing ID: 6.875" DATE { REV. BY { COMMENTS RA Tag TBO 6~/4" OBb Latera{ 7,126'-12,304' ~__ _ s _ ~ ~ ~ ~ _ Swell packer placement TBD 9/9/2004 ~ RBT ~ Level 3Multi-Lateral, 4-1/2" GL Completion ~''' ~~, RA Tag TBD \~~ 6-3/4" OBa Lateral 6,993'-12,349` ~:=- - ~ - - - ~ Swell packer placement TBD 6~/4" OBd Lateral 7,800'-12,634' API NO: 50-029-~ocxxx-00 ORION so-029-x~t>Wt-6o WELL: L-202 ML ~-029-xxxxx-61 50-029-: xxxx-62 by L-202L1 (P3 CYmrt BP Expbratlon Alaska Fkdd: Pndhoe Bay Unft • WOA ~~,.,~: L-PAD,L-202 ~ieasibility WaS: Plen L•T02 (N-N) ^ Bonhok: Plan L-Z02L108b UNNAPII: 50029 Survey Name I Datr. L•202Li (P3) / Ocbber 29, 2004 Tort1AND 1 DDI I ERD ratlo: 164.617° / 9961.91 ft / 8.64212.165 Odd CooNinrss Sy~wn: NAD27 Alaska Stale Planes, Zone 04, US Feet Loeatlon Ladlona N 70.35088488, W 149.32430214 Loeatbn Grid NIE YDI: N 5978293.250 ftUS, E 583223.800 ftUS Grid Convs-Ssna AnSN: +0.63635414° ~ Schlumberger v«a«i spa AsMwtl,: 50.000• V WirtleY SaeUon Odpin: N 0.000 ft, E 0.000 ft TVD Rafannca Datum: Rotary Tabb TVD Rafarana Elavatlon: 77.30 ft relative to MSL Sa 8ad lllroeml Lavat EtwMbn: 48.80 ft rela8ve to MSL tiapnatle DadlnMlon: 24.714° Tatty Fk4d BtrMptlr. 57592.723 nT NapnsUe Dip: 80.807° DaeBnMlon DaEa: Ocbber 29, 2004 YpnNk Dadinatbn Modal: BGGM 2004 NoM Rafaarea: True NoM Toth Carr Yp Ibrtli •> Trw IbrM: +24.714° ;; CommsMs D Nu~naBon AdmrM TVD Sub•Saa TVD ~n NS E1N DLS Tool Faa BWId Rab Walk Rats NodMap EaatlnS l.Mlluda LonSNuda R R R R a R R ®0 R o0 R oo R ttus RUS ~~p vvrnpsu,rn r ~ io.w vo.ri vc.ri gani.~o ~cc.oo ~~ro.ia rrro.oc saar.ac ccao.oq u.W M7.uUV V.W V.W .77J8lirDO.1J OoA461.06 rv /V.30lAUL36 YY laEl.JW6JLOtf Base Whi~tock 7128.00 70.24 94.33 4504.71 4427.41 1290.88 4790.70 3837.18 2310.79 16.00 O.OOG 11.37 12.02 5981955.51 585483.84 N 70.38080029 W 148.30553388 KOP Crv 10/100 7138.00 70.24 94.33 4508.78 4431.48 1301.78 4801.99 3838.31 2322.05 0.00 23.826 0.00 0.00 5981954.78 585505.11 N 70.38059795 W 149.30544241 7200.00 75.93 98.81 4526.80 4449.50 1380.28 4881.28 3830.49 2381.05 10.00 23.076 9.18 4.18 5981949.81 585564.18 N 70.38058199 W 149.30498321 7300.00 85.18 100.82 4543.21 4485.91 1458.24 4959.82 3615.28 2478.38 10.00 22.436 8.23 3.92 5981835.47 585881.65 N 70.36054031 W 149.30417273 End Crv 7372.00 91.82 103.58 4545.11 4487.81 1530.08 5031.75 3800.07 2548.89 10.00 O.OOG 9.25 3.81 5981921.08 585732.11 N 70.36049874 W 149.30380174 Crv 8/100 7912.11 91.82 103.56 4527.98 4450.88 2089.75 5571.59 3473.48 3073.47 0.00 134.896 0.00 0.00 5981800.30 588258.22 N 70.38015231 W 149.29933993 L-202L1 OBb Tgt 1 7955.18 90.00 105.40 4527.30 4450.00 2112.78 5814.63 3482.70 3115.14 8.00 90.000 -4.22 4.28 5981790.00 586300.00 N 70.38012288 W 149.29900153 End Crv 7955.47 90.00 105.42 4527.30 4450.00 2113.10 5814.95 3482.81 3115.44 8.00 O.OOG 0.00 6.00 5981789.92 588300.31 N 70.38012283 W 149.28899905 Crv 8/100 8898.52 90.00 105.42 4527.30 4450.00 2858.13 8358.00 3285.05 3831.75 0.00 80.006 0.00 0.00 5981600.35 567018.70 N 70.35958201 W 149.29318218 L-202L1 OBb Tgt 2 8899.87 90.00 105.50 4527.30 4450.00 2857.48 8358.35 3284.89 3833.05 8.00 90.006 0.00 6.00 5981800.00 587020.00 N 70.35958102 W 149.29317159 8700.00 90.00 105.51 4527.30 4450.00 2857.81 8359.47 3284.88 3833.17 8.00 90.006 0.00 8.00 5881599.97 587020.12 N 70.35958093 W 149.28317081 End Crv 8702.73 90.00 105.87 4527.30 4450.00 2860.33 8382.20 3263.93 3835.80 8.Q0 O.OOG 0.00 8.00 5981599.28 587022.75 N 70.35957693 W 148.29314929 Crv 8/100 9952.86 80.00 105.87 4527.30 4450.00 4110.38 7812.33 2928.25 5039.48 0.00 -90.006 0.00 0.00 5881275.00 588229.88 N 70.35885447 W 148.28337545 L-202L1 OBb Tgt 3 9952.88 90.00 105.87 4527.30 4450.00 4110.40 7612.35 2928.24 5038.48 8.00 180.806 0.00 -8.00 5981275.00 568230.00 N 70.35865448 W 149.28337531 End CRv 9973.34 88.84 108.07 4527.51 4450.21 4130.88 7832.81 2920.85 5059.16 8.00 O.OOG 5.87 1.97 5881269.82 588249.74 N 70.35883913 W 149.28321 Crv 6/100 10938.88 88.84 108.07 4547.04 4489.74 5085.81 8597.94 2853.43 5988.55 0.00 -149.876 0.00 0.00 5881012.74 589179.98 N 70.35790724 W 148.27 L-202L1 OBb Tgt 4 10949.08 88.30 105.78 4547.30 4470.00 5108.22 8808.35 2850.57 5996.57 8.00 -150.246 5.19 -3.01 5981010.00 588190.00 N 70.35788942 W 149.27 End Crv 10958.72 87.80 105.47 4547.83 4470.33 5115.85 8817.98 2647.98 6005.85 6.00 O.OOG 5.21 -2.98 5981007.51 569199.30 N 70.35789232 W 149.27552905 Crv 8/100 11724.70 87.80 105.47 4577.08 4499.78 5881.25 9383.40 2443.78 8743.53 0.00 -114.006 0.00 0.00 5980811.53 589939.14 N 70.35733275 W 149.28953890 L-202L1 OBb Tgt 5 11730.77 87.85 105.14 4577.30 4500.00 5887.31 9389.47 2442.18 8749.37 8.00 -113.58Ci -2.44 5.49 5880810.00 589945.00 N 70.35732838 W 149.26949243 End Crv 11737.09 87.50 104.79 4577.57 4500.27 5893.83 9395.78 2440.55 8755.47 8.00 O.OOG -2.40 -5.51 5980808.44 589951.12 N 70.35732388 W 149.28944290 TD / 4-1 /2" Lnr 12303.75 / 87.50 104.78 4602.30 4525.00 8459.75 8981.90 2296.01 7302.84 0.00 O.OOG 0.00 0.00 5980670.00 590500.00 N 70.35892782 W 149.28499908 Surface : 2571 FSL 3890 FEL S34 T12N R11E UM L-202L1 OBb Tgt 1:753 FSL 589 FEL S27 T12N R11 E UM L-202L1 OBb Tgt 2 : 555 FSL 5131 FEL 328 T12N R11 E UM L-202L1 OBb Tgt 3 : 215 FSL 3925 FEL 328 T12N R11E UM L-2G1L1 OBb Tgt 4 : 5219 FSL 2989 FEL S35 T72N R11E UM L-202L1 OBb Tgt 5 : 5010 FSL 2218 FEL S35 T12N R11E UM TD / BHL : 4863 FSL 1883 FEL 335 T12N R11 E UM WeIlDesign Vet 3.1RTSP3.03-HF5.00 Bld( do31rt546 ) Northlno (Y1 fftll 5978293.25 8l Eutlrw OCI IRUSI 583223.80 5981780.00 588300.00 5961600.00 587020.00 5981275.00 588230.00 5981010.00 589190.00 5980810.00 589945.00 5980870.00 580500.00 L-2021PIen L-202 (N-N)1PIan L-202L1 OBb~I-202L1 (P3) Generated 8/3/2004 3:31 PM Page 1 of 1 by Schlumberger `~" L-202L1 (P3) `~`~ Prudhoe Bay Unit - WOA '~"'~ L-PAD Mgiwt rr.,.rn SuYr. ~9o9m Rno1] .mow sum. w... z~F n us c„~ ti.,"iw»o-° MpOR-. 80(ilA 3(101 pp. 30.80]• DM OcbEFr 3B. 30M MO 113.393 Nor1M^9 ,~ '~rv. ,~.. .. ]VD RSi Rosy iads (]1 b3Wwe MSll My 0.c ~3~.1t 3' FS 5]891 ]nT W1t9193]~88 Ewbq SnY mIF OaaEer 29. 3001 1600 2400 3200 4000 4800 5600 6400 4000 ~_ c m `~ 4800 0 1800 2400 3200 4000 4800 5800 6400 Vertical Section (ft) Azim = 105°, Scale = 1(in):800(ft) Origin = 0 WS, 0 E/-W 4000 4800 • t?~.~ Schlumherger "~" L-202L1 (P3) FF1D Prudhoe Bay Unit - WOA "~""'~ L-PAD ."~P..~... $uM1t.latyM wml,,u.Y.s...a~....z--a.usr.w ..-..--. Ibat s010A1ma ob eo.eor O-c Cvaier N.zo01 It M02t z]W wNq !i1lzp0.t5ius om cmr. ~o.esls~u• 9bl L-201 1VD nr: Na-y Tea. (~f.]011 jean ABL1 Mq WC: •N.11~• F8: 61Sp1.]nt lLn W1191911.IM E-IYp: !tl?10l01119 Su1~FC.09iWWM! PIYC L-10dt~Pb) 8rv/QW: 9¢n4v 00. 1'001 1600 2400 3200 4000 4800 5600 6400 7200 4000 n n n z 3200 x c u 2400 v v v 1600 • 4000 3200 2400 • 1600 1600 2400 3200 4000 4800 5600 6400 7200 «< W Scale = 1(in):800(ft) E »> PERMIT TO DRILL 20 AAC 25.005 c: (e) If a well has multiple well branches, each branch requires a separate Permit to Drill. !f multiple well branches are proposed from a single conductor, surface. or production casing, the applicant shall designate one branch as the primary wellbore and include a!1 information required under (c) of this section with the application for a Permit to Dritl for that branch. Fur each subsequent well branch, the application for a Permit to Drill need only include information ands+~ '~} of this section that is unique to that branch ar~r9 need h®Y ie~ctude the ~tit~u #e • • TRAANMMITAL LETTER CHECK LIST CIRCLE APPROPRIATE LETTER/PA.RAGRAPHS TO BE INCLUDED IN TRANSMITTAL LETTER WELL NAME ~°B (~ L - ~, 0 2 ~ PTD# ~ o ~.- ~ ~ 7 _~ Development Service Exploration Stratigraphic CHECK WI3AT ADD-OHS "CLUE"~ APPLIES (OPTIONS) • MULTI The permit is for a new wellbore segment of LATERAL existing well L` ~dZ Permit No,.2~ API No. o - 02 .r ? 3 ~ (If API number Production. should continue io be reported as lass two. (2) digits a funciion•of the original API number. stated are between 60-69) above. PILOT HOLE In accordance .with 20 AAC 25.0050, all (PIS records, data and logs acquired for the pilot • bole must be clearly differentiated ~in both • name (name on permit plus PIS and API number (50 - 70/80) from records, data and logs acquired for well (name on permit). SPACING The permit is approved subject •io full ExCEPTION compliance with 20 AAC 25.055. Approval to perforate and produce is contingent upon issuance of a conservation order approving a spacing exception. (Company Name) assumes the liability of any protest to the spacing .exception that may occur. DRY DITCH ~ All dry ditch sample sets submitted to the SAMPLE Commission must be in no greater than 30' sample intervals from below the permafrost or from where samples are first caught and 0' sample intervals through target zones. _q ELL PERMIT CHECKLIS Field & Pool PRUDHOE BAY, ORION SCHR BL OIL -640135 Well Name: PRUDHOE BAY UN GRIN L-202L1 Program DEV Well bore seg ~ PTD#:2041970 Company BP EXPLORATION (ALASKA) INC Initial Classlfype DEV ! 1-OIL GeoArea Unit OnlOff Shore On Annular Disposal ^ Administration 1 Permit feeattached___-,______________________--__--_ -__-_ -Yes ____ 2 Leasenumkerappropriate______________--_--_--__-_-____ _____Yes_ _--__-._-__-__ -------------------------------------------------------- 3 Uniquewell_nameandnumke[______________________.____ __._-----Yes__ _____-__--_______-_ 4 Well located in a_defnedpool_ - - _ _ _ _ _ _ _ _ _ _ _ _ _ _ Yes . _ - - - - - -- 5 Well located proper distance_from drilling unlit-koundary_ _ . _ _ _ - _ _ _ _ _ _ _ _ _ _ Yes _ _ - _ _ ... _ _ _ .. _ .. _ _ _ _ _ . _ 6 Well located proper distance from other wells______________-__--_ _-.__--_.Yes__ _______---__-___________________- 7 Sufficient acreageayailaklein.dril_lingunit-------------_-_--__-- __--__---Yes_ __--__--__--__- 8 If deviated,is_wehkoreplat_included_________________________ _---_Yes-. __--__--__..-_- 9 Ope[atoi only affected party - - - - - - - - -Yes - - - - - - - - - - - - - - - - - - - - - - - - 10 Ope[atorhasappropriate_kondinf4rGe--------------- ------ ------ --Yes-- --- ----------------- -- --------------- -------- --- -- ---------- --- 11 Permit_cankeissuedwithoutconservati4n4rder___________________ _________Yes-- __-__---___--___-_- Appr Date 12 Permitcan be issued without administrativ_e_approval - - - - - - - - - - - - - - - - - Yes - RPC 10!512004 13 Can permit be approved before 15-day wait Yes 14 Well located within area and_strata authorized ky Injectipn Orde[ # (put1O# in_comments)_(Fpr- NA- - . _ - - . . . . . . .. . ..... . . .. . . .. . . . . . . . . - .. - ... - _ - - - - .. - .. - . 15 All wells within114.milears-aofr-eyiewidentified(ForseNicewellonly)______ _________ NA___ -__--_____.-_______-__-_.___.__.__-...________________--__,__.___._.__.__ 16 Pre-produced injector; duration_of pre-p[oduction less than 3 months_(For service well only) _ _ NA_ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ _ ------------------------- 17 AC_M_P_FindingofConsistency-haskeenissued_for_thisproject----------- --------- NA_,_ _.__..-_--_-_-___-_______________-_-__---_-__---__________________-___-_ Engineering 18 Conductorst[ing_provided___-__________________--__--__ -__--.--__N_A--_ .__-_._-____-_-___________ ----------------------------------------------- 19 Surface casi~gprotects all-known- USDWs - - - - NA - - - - - 20 CMT-vol_adequate_tocircul_ate-onconducto[&surf_csg-..___________ _______. NA--_ _.__--__--_-,___--_- - -- -- - 21 CMT_vol_adequate-to tie-in long string to surfcsg___________________ _________NA--_ ____---_--_-,--____ - - 22 CMT-will coverall known_productive horizons- - - - - - - - - - - - - - - _ _ _ _ _ _ _ _ _N_o_ _ _ _ _ Slotted, _ , -------------------------------------------------------- 23 Casing designsadequafeforC,T,B&_permafrost----------------- --------Yes-- -------------------------- --------------------------------------------- 24 Adequatetankage_orreservepit____________________________ _______Yes_ _--.Nakors_9ES,____-_- -- -- - - 25 Ifa_re-drill,has_a10-403 for abandonment keen approved_____________ _________ NA--_ -___-Lateral.-__-_--_.._-__- - - 26 Adequatewellkoreseparation_proposed.___.__________________ _________ Yes__ ______-.____..__....._._._____. ---------------------------------------- 27 If diverterlequired,doesitmeet_regulations______________________ _________ NA--- _._-_Sidetrack.__________-___________-..--_-----___-___--___-__-_-_- Appr Date 28 Drillingfluid-programschematic&equiplistadequate___--_--------- ---------Yes__ _____MaxMW9,2ppg._____________-_---____--______________-_--__-_ WGA 1015/2004 29 BOPEs,_dotheymeelregulation___________________________ _____Yes-_ _-__-_-__-_-__ __-_--___---_-___-__ ----------------------- 30 BOPS-pressratingapp[op[iate;test to-(putp&igincomments)----------- ---------Yes.- _-_-Test to 3500psi._MSP1580psi.______________-----_--______________---_- ---,- 31 Choke_manifoldcomplieswlAPI-RP-53(May84)___________________ ______ __Yes__ _--_---__--__-_-----__-.__-_--_____ ___ ---------------------------------- 32 Work will occur without operation shutdown-_--_________________ _________Yes__ _--__---_---__-__-_---_.__-__--____ ________. --------------------------- 33 Is presence- of H2S gas prokable - - - - - ~0 - - Not as H2S pad• - - - - - - - - - - 34 Mechanical-condition of wells within AOR verified (For_seruice well only) - - - - - - - - - - - - - - NA_ _ - _ - _ _ - _ _ - , _ - -- - Geology 35 Permitcankeissuedwlohydrogensulfidemeasures-------------__ _,_-.._-_Yes__ __________________________________--_---__-__-___---____--__---___-__ 36 Data_presentedon_pots-ntialoverpressurezones_--______________ ________NA-.- ___----_---__-__-__--_--_-___---__._-______ Appr Date 37 Seismic analysisofshallow gas_zones_ - . .. . . ..... . . . . . . .. . . . . . NA_ , - _ _ - - -- - - RPC 101512004 38 Seabed condition survey_(if off--shore) - - - _ - - . _ . -~ NA--- - -- --- - --- -- 39 Contact namelphone_fgr weekly progress_reports [exploratory only)- NA- - - _ Geologic Engineering Public Commissioner: Date: Date Commissioner: 'sinner Date pTs 161 ~(9.,, ~~% ., •